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Home My WebLink About186-045MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2T-15 KUPARUK RIV UNIT 2T-15 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 2T-15 50-103-20062-00-00 186-045-0 W SPT 5436 1860450 1500 2250 2250 2250 2250 40 40 40 40 4YRTST P Adam Earl 6/21/2025 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2T-15 Inspection Date: Tubing OA Packer Depth 1655 2910 2830 2830IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250625073253 BBL Pumped:1.1 BBL Returned:1.1 Tuesday, July 22, 2025 Page 1 of 1           C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\I1OGWE08\2024-05-15_21179_KRU_2T-215_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21179 KRU 2T-215 50-103-20280-00 Caliper Survey / Log Data 15-May-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 186-045 T38827 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.20 15:06:58 -08'00' MEMORANDUM TO: Jim Regg r--?eft (ZI1 -7C'zt-'Z4 P.I. Supervisor FROM: Austin McLeod Petroleum Inspector Well Name KUPARUK RIV UNIT 2T-15 Ilnsp Num: mitSAM211108195702 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, November 23, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc - 2T -15 KUPARUK RIV UNIT 2T-15 Src: Inspector Reviewed By: P. 1. Supry-1-L'-E Comm API Well Number 50-103-20062-00-00 Inspector Name: Austin McLeod Permit Number: 186-045-0 Inspection Date: 11/8/2021 >/ Tuesday, November 23, 2021 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - Well 2T-15 Type Inj w TVD 5436 - Tubing1760 - 1760 1760 - 1760 PTD 1860450 -Type Test, SPT -,Test psi 1500 IA � 240 2600- 2500 - 2490 BBL Pumped: 1.8 - BBL Returned: 2- OA zo — 20 - zo - zo Interval 4vRTST P/F P Notes: MITIA Tuesday, November 23, 2021 Page 1 of 1 S • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg / DATE: Thursday,June 15,2017 P.I.Supervisor 1 (.1,1•50 17 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-15 FROM: Lou Laubenstein KUPARUK RIV UNIT 2T-15 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry S� NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-I5API Well Number 50-103-20062-00-00 Inspector Name: Lou Laubenstein Permit Number: 186-045-0 Inspection Date: 6/5/2017 Insp Num: mitLOL170607151950 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T-15 Type Inj W TVD 5436 - 1 Tubing 1350 1350 • 1350' 1350 - PTD 1860450 - Type Test SPT Test psi 1500 - IA 450 2200 - 2120 - 2100 - BBL Pumped: 1.7 ' BBL Returned: 1.6 ' OA 20 20 - 20 20 Interval 4YRTST 1P/F P ✓ --Notes: SCANNED EP 132011 Thursday,June 15,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg / DATE: Monday,June 03,2013 bl71I13 SUBJECT: Mechanical Integrity Tests P.I.Supervisor � C g y CONOCOPHILLIPS ALASKA INC 2T-I5 FROM: Lou Grimaldi KUPARUK RIV UNIT 2T-15 Petroleum Inspector Sre: Inspector Reviewed Byi P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-15 API Well Number 50-103-20062-00-00 Inspector Name: Lou Grimaldi Permit Number: 186-045-0 Inspection Date: 6/1/2013 Insp Num: mitLG1 3 060 1 1 44 722 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T-I5 Type Inj W TVD 5436 IA 666 2002 1934 . 1913 PTD ' 1860450 Type Test,SPT''Test psi, 1500 OA 80 . , 80 90 _ 90 Interval 4YRTST P/F P Tubing 2650 . 2650 2650 2660 - Notes: 1.18 bbl's diesel pumped, 1.0 bbl's returned.Good solid test,crew well prepared. SCANNED FEB 2 0 2014 Monday,June 03,2013 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(aDalaska.gov; AOGCC.Inspectorst alaska.00v; phoebe.brooksCrialaska.aov chris.wallaceOalaska.gov OPERATOR: ConocoPhillips Alaska,Inc FIELD/UNIT/PAD: Kuparuk/KRU/2T Pad dell t,1124 t3 046 DATE: 06/01/13 (` r ` OPERATOR REP: Freeborn/Hight/Phillips V � i AOGCC REP: Lou Grimaldi Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min, 60 Min. it). Well 2T-15 Type Inj. W TVD 5,437' Tubing 2,650 2,650 2,650 2,660 Interval 4 P.T.D. 1860450 Type test P Test psi 1500 Casing 666 2,002 1,934 1,913 P/F P Notes: OA 80 80 90 90 Well 2T-18 Type Inj. W TVD 5,759' Tubing 2,650 2,650 2,640 2,640 Interval 4 P.T.D. 1950170 Type test P Test psi 1500 Casing 1,044 2,000 1,971 1,962 P/F P Notes: OA 740 840 850 850 Well 2T-26 Type Inj. W TVD 5,715' Tubing 2,600 2,600 2,620 2,620 Interval 4 P.T.D. 1950820 Type test_ P Test psi 1500 Casing 1,240 2,010 1,991 1,994 P/F P Notes: OA 530 605 605 605 Well 2T-28 Type Inj. W TVD _ 5,706' Tubing 2,660 2,640 2,660 2,675 Interval V P.T.D. 1950920 Type test P Test psi 3000 Casing 746 3,194 3,113 3,100 P/F P Notes:AIO2B.66 MITIA to Max anticpated injection Press OA 68 69 69 69 Well 2T-28 Type Inj. W TVD 5,706' Tubing 2,675 2,675 2,680 2,620 Interval 0 P.T.D. 1950920 Type test M Test psi 3,000' Casing 3,100 2,015 2,074 2,079 P/F p Notes: OA 69 69 69 69 _AOGCC Inspector requested second test Well 2T-32 Type Inj. W TVD 5,731' Tubing 2,900 2,900 2,900 2,900 Interval 4 P.T.D. 1950490 Type test P Test psi 1500 Casing 1,170 1,950 1,910 1,900 P/F P Notes: Non-witnessed test OA 200 200 200 200 AOGCC Inspector left location prior to test _ Well 2T-36 Type Inj. W TVD 5,767' Tubing 1,150 1,150 1,150 1,150 Interval 4 P.T.D. 1951020 Type test P Test psi 1500 Casing 610 2,000 1,940 1,931 P/F P Notes: OA 410 500 490 490 Well 2T-201 Type Inj. W TVD 2,762' Tubing 900 900 900 900 Interval 4 P.T.D. 1951220 Type test P Test psi 1500 Casing 957 3,000 2,986 2,986 P/F P Notes: Non-witnessed test OA 180 180 180 180 AOGCC Inspector left location prior to test Well 2T-217A ' Type Inj. W ' TVD '3,006' Tubing 1,170 1,170 1,170 1,170 Interval 4 P.T.D. 2000740 ' Type test P Test psi - 1500 Casing 280 '2,000 - 1,940 1,920 P/F P ✓ Notes: Non-witnessed test OA AOGCC Inspector left location prior to test SCANNED FEB 2 0 2014 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 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT KRU 2T 4 year 6-01-13Revised.xls • a WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 8, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 -. @ 0 9 201 RE: Injection Profile: 2T -15 Run Date: 2/2/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -15 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50 -103- 20062 -00 Injection Profile Log 1 Color Log 50 -103- 20062 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. / . --C16/ 6 Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 l rafael.barreto @halliburton.com Date: Signed: 0 _ it '� H 2 011 - ,; 3 01A Ka r . • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission kk DATE: Thursday, February 17, 2011 TO: Jim R per 1. ZI Z 1 i( P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T -15 FROM: John Crisp KUPARUK RIV UNIT 2T -15 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv,Tet NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2T - 15 API Well Number: 50 - 103 - 20062 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr110112132556 Permit Number: 186 -045 -0 Inspection Date: 1 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T -15 ' Type Inj. , W ' TVD 5436 ' IA r 0 2220 - 2120 2080 P.T.D 1860450 ' TypeTest SPT Test psi 1500 - OA 50 50 50 50 Interval INITAL - P/F P ' Tubing 1550 1550 1550 1550 Notes: 2.08 bbls pumped f App. A Thursday, February 17, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Thursday, January 20, 2011 Jim Regg P.I. Supervisor 'Ref/ I Z 1 I + SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T -15 FROM: John Crisp KUPARUK RIV UNIT 2T -15 Petroleum Inspector Src: Inspector Reviewed By P.I. Supry \ P NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2T - 15 API Well Number: 50 103 - 20062 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr110112132556 Permit Number: 186 - 045 - Inspection Date: 1/11/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T -15 • Type Inj. W , TVD 5478 - IA I 0 2220 ' 2120 2080 - P.T.D 1860450 ' TypeTest SPT I Test psi 1500 - OA 50 50 50 50 ■ i Interval NT's' p/ji' P ' Tubing 1550 1550 1550 1550 1 Notes: 2.08 bbls pumped AohiNED FEB U d 20' Thursday, January 20, 2011 Page 1 of 1 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Repair w ell r Plug Perforations Stimulate r Other rj Alter Casing r%o Pull Tubing Perforate New Pool Waiver r Time Extension Change Approved Program r Operat. Shutdown I Perforate Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory 186 -045 3. Address: 6. API Number: Stratigraphic "` Service P. O. Box 100360, Anchorage, Alaska 99510 M 50- 103 - 20062 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25569 ` r 2T -15 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7625 feet Plugs (measured) None true vertical 6149 feet Junk (measured) None Effective Depth measured 7469 feet Packer (measured) 6714, 6768, 7250 true vertical 6023 feet (true vertucal) 5437, 5477, 5848 Casing Length Size MD TVD Burst Collapse CONDUCTOR 100 16 100 1"00' SURFACE 3229 9.625 3229 2810 PRODUCTION 7117 7 7117 5741 LINER 696 5 7625 6149 rT 0' Zt1 ��: Perforation depth: Measured depth: 7197'- 7236', 7313' -7342' NO 0 R 2 01 0 True Vertical Depth: 5805'- 5836', 5899' -5922' s oil & Gas Cons. ccrwak 9 Tubing (size, grade, MD, and TVD) 3.5 / 2.375, J -55 / N -80, 6766 / 7274 MD, 5475 / 5865 TVD Packers & SSSV (type, MD, and TVD) 2 PACKERS: BAKER FHL PACKER 6714 AVID and 5437 TVD & BAKER FHL PACKER @ 6768 MD and 5477 TVD PACKER - BAKER'DB' PACKER W/ BE @ 7250 MD and 5848 TVD NIPPLE - CAMCO DS NIPPLE @ 515 MD and 515 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation si Subsequent to operation si 13. Attachments 14. Well Class after work: t Copies of Logs and Surveys run Exploratory r Development r Service r7o Stratigraphic rG STOR Well Status after work: Oil Gas WDSPL Daily Report of Well Operations XXX r WINJ r WAG GINJ SUSP SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -283 Contact J. Brett Packer 17 265 -6845 Printed Name J. Brett Packer Title Wells Engineer Signature � �„� Phone: 265 -6845 Date Form 10 -404 Revised 10/2010 RBDMS NOV 0 5 Submit Origin I Only KU P 2T -15 Conoco PS �.,' r tN.__e_Il AA.trib9tes n�aX an g les s nnD rR l :' Wellbme APUUWI Field Name W Il Status Inci ( °) MD (HKB) (ftKB) 1 _ ` a ` 501032006200 �KUPARUK RIVER UNIT INJ 44.20 5,20 000 6250 .. . - Last Ta SLM 2,200 C I / REV REason' ORKO O R End Date JKB Grd (H) Dafe 'Date An Cation T 15/142c1910,01:36 AM 10/1212010 4180 2/1986 Annotation De th HK End Date Annotation 1Last M d...E dDate $thematic Actual p ( B) l 1 g Imosbor 10/14/2010 HANGER, 32 Casina Strin s - Casing Description String 0... String ID ... Top (HKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 33 - 0 100.0 100.0 62.50 H WELDED Casing Description String 0... string ID .. Top (ftKB) Set Depth (f.., set Depth (ND) ... string Wt... string ... String Top Third SURFACE 95/8 8.765 32.5 3,228.7 2,809.5 36.00 J - 55 Buttress Casing Description String 0... String ID .. Top (ftKB) Set Depth (f... Set Depth (ND) ... String WI... String ... String Top Third PRODUCTION 7 6.276 32.1 1,882.9 1,799.6 26.00 L-80 TCII TIE -BACK CONDUCTOR, Casing Descdptbn string 0... string ID ... Top (111(8) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Third 33 - 100 PRODUCTION 7 6.151 1,881.0 7,115.5 5,739.6 26.00 J -55 BTC _ j Casing Description String 0... String ID Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt. -. String ... String Top ihrd NIPPLE, 515 LINER 5 4.151 6,9294 7,625.0 6,149.2 18.,0 L - FL4 - Pup Jam, 516 Liner Details Top Depth _ (ND) Top In Nomi.. m . ` Top(HKB) (HKB) (% Ite Description Comment _ ID(in) 6,929.4 5,596.7 41.22 HANGER iBAKER MODWTUBING HANGER 5.000 Tubirtg_Strings_ Tubmg Description Suing 0... (String ID... Top (HKB) Set Depth (f... Set Depth (ND) ... Str g Wt... Str g ..- String Top Thrd . TUB ;ion Det - 3 1/2 2 992 32 1 6,76 0 5 475.0 9.30 L-80 EUE 8rd P ails Top Depth PRODUCTION (ND) Top Inci Nomi.. TIEeADK, To B (�B) (* Item Description _ Comment - _.__... -__ 10 (in 32 - 1,883 32.1 32.1 0.43 HANGER MCEVOY Tubing Hanger, G4, 7" x 3 1/2", DP1 -D -S3 3.000 514.9 514.9 0.42 NIPPLE CAMCO DS NIPPLE 2.875 6,685.3 5,415.4 42.63 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.010 l _ _ - _ suRrncE,____.- 6,693.7 5,421.5 42.60 PBR BAKER aoao POLISHED BORE RECEPTACLE 4.000 32'3229 6,714.0 5 42.51 PACKER BAKER FHL PACKER 2.870 6,735.6 5,452.5 42.41 NIPPLE CAMCO DS NIPPLE w /RHC -Plug Installed 2.812 GAS LIFT, - 6,753.1 5,465.5 42.34 Centralizer CENTRALIZER SUB 3.030 6.628 6,755.4 5,467.1 42.33 SEAL ASSY SEAL ASSEMBLY 3 1/2" PBR w/ Muleshoe wt V space out 3.010 Tubing Description String 0... String ID Top (HKB) Set Depth If Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING Original 23/8 1992 6,754.4 7,273,5 5,866.3 4.70 N-80 EUE8rd 3.5x2 -375' �.__. _... _�. SEAL ASSY - C o mple tion Details 6,6115 - --------- -, _-._- - - - - -. _.. _..�__- --- - - - - -- Top Depth _- . PBR, 6,694 T ' (TVD) Top 1-1 Nom "... PACKER, 6,714- 4.1 To B (ftKB) r) Ilan Desaip Comment _ ID (in) -- 6,754.4 5,466.4 42.33 PBR 4.000 -._._ 6,768.1 5,476.5 42.27 PACKER 3.000 NIPPLE, 6,736 > ...�. - �� 6,843.8 5,533.0 42 26 NIPPLE AVA BPL PORTED NIPPLE (SNAP RING NO GO) °`do NOT run 2.750 standard top NO GO sleeves in this well ***' Carmai 6,846] 5,535.2 42.22 XO 3.5x2 375" 1.992 6,753 = 7,172.2 5,784.7 36.72 BLAST RINGS 1.992 SEAL ASSY, 7,248.2 5,845.8 35.70 SEAL ASSY BAKER LOCATOR SEAL ASSY 2.375 6,755 7,250.1 5,847.3 35.72 PACKER BAKER'DB' PACKER w /SBE 2375 7,264.4 5,858.9 35.80 NIPPLE w CAMCO'D' NIPPLE 1.812 7,271.9 5,865.1 35.84 SOS BAKER SHEAROUT SUB w /CROSSOVER- ELMD TTL @ 7274' during 1.995 HRS SPINS on 04125/90 INJECTION,_ 6,806 Other in Hole Wireline retrievable plugs, valves, pumps, fish etc_ Top Depth Si Top Inci NIPPLE, 6.844 T 1'HCB (ftKB) (� Descri ion omment Run Data ID in _. - - 6,843.8 5,533.0 42.26 SLEEVE AVA BPI SLEEVE C 5/7/2000 2.310 Perforations & Slots - snot Top (TVD) at D) (TV Dens Top (111<13) Bon HKB (HKB) (ftKB) Zone Date (sh... Type Comment 7,197.0 7,236.0 5,804.5 5,835.8 C4, 2T -15 10/9/1986 12.0 IPERF 3 378" HyperJet II 7,313.0 7,342.0 5 5,921.9 A -3, 2T -15 10/9/1986 4.0 IPERF 3 318" HyperJet II PRODUCTION Notes: General $ Safet Post W0 End Date Annotation 1.881 -7.116 --._ -_-- M .. 1217/2008 NOTE: Possible collapsed TB @ G 336' SUM; passed restriction W/ 1.5" tools, knuckled @ 3' intervals, IPERF 1011412010 NOTE: VIEW SCHEMATIC w /Alaska Scher ic9.0 , - - 7,197 -7,236 SEAL ASSY, - 1,248 - PACKER, 7,250 - a.: dr D taus. Top Depth Top - - - Port - NIPPLE,7,264 (TVD) Inel OD Valve Latch Site TRO Run Sin To tftlC8 (ftKB) ( °) Mdse Model_ _ (in) Sery Type Type (in) (psi) Run Date Cam... sos 7272- 1 6,625.8 5,374.0 42.88 Camco MMG 1 1 2 GAS LIFT SOV RKP 0.000 0.0 10/11/2010 2 6,806.0 5,505.6 42.72 CAMCO KBUG 1 INJ DMY BK2 0.000 0.0 12/30/1997 IPERF,_ 7,313 -7,342 <. LINER, 6,92 &7,625 TD, 7,625 2T -15 Well Work Summary DATE • SUMMARY 9/6/10 Loaded well with 100 bbl of seawater. Shut in tubing pressure stabilized at 650 psi. Calculated BHP mid pen`s using 8.5 ppg SW is 3263 psi (10.6 ppg). Freeze protected with 20 bbl of diesel. 9/6/10 (PRE -RWO) T POT - PASSED; T PPPOT- PASSED; IC POT- PASSED; IC PPPOT- PASSED; FUNCTION TEST LDS 9/20/10 FLUID PACKED IA/OA, BLED ALL GAS OFF, BLED IA/OA TO 0. 9/28/10 DRIFTED TBG WITH 1.9" DMY PLUG (OAL= 51 1/2 "). SET 1.81" CA -2 PLUG a- 7264' RKB. MITT TO 2500 psi. 15 MIN TEST ON CHART RECORDER. ***PASS * * *. BRUSH & GAUGE TBG TO 2.77" TO 6844' RKB. BAILED POCKETS OF FINE SCALE FROM 2100' TO 6800' SLM. ** *RECOVERED —5 GAL FINE SCALE * * *. SET 2.75" AVA CATCHER (MAX OD= 2.71 " / OAL = 29 ") @ 6800' SLM. —46' P � BELOW PBR. JOB COMPLETE. 9/29/10 STANDBY FOR POSSIBLE TUBING CUT DUE TO STUCK PBR WHILE SLICKLINE SET PLUG, ET CATCHER RAII ED SO-Al E 9/30/10 LOGGE RADIAL CEMENT BOND LOG FROM PBR TO SURFACE LOGGED PDS MIT ON MEMORY FROM 6717' TO SURFACE. HOIST GYRO DATA FROM SURFACE TO 6750' AND REPEAT FROM 6750' TO SURFACE. SHOOT COLLAR AT 1892' WITH 240 GR /FT STRING SHOT. 10/3/10 HOISTED PDS MEMORY CALIPER FROM 1850' TO SURFACE. HOISTED GYRODATA TOOLSTRING FOR CONTINUOUS GYRO SURVEY FROM SURFACE TO 1850'. 10/6/10 PERFORMED DOWNHOLE VIDEO LOG. FLUID LEVEL BLOWN DOWN TO 390' WITH NITROGEN. OBSERVED 9.625" CASING DAMAGE AT 370'. 10/19/10 PULLED BALL & ROD @ 6735' RKB. PULLED SOV @ 6628' RKB & SET DV @ SAME. PULLED RHC PLUG BODY @ 6735' RKB. 30 MIN MIT -T TO 3500 PSI, PASS. BAILED FINE SCALE OFF TOP OF AVA CATCHER f/ 6753' SLM DN TO 6791' SLM. IN PROGRESS 10/20/10 BAIL FILL ON CATCHER SUB @ -y6801' SLM, BAILED f /6801'SLM TO 6805' SLM, MARKS ON PdS� BAILER BOTTOM INDICATING CATCHER, IN PROGRESS. 10/22/10 BAIL FILL OFF CATCHER @ 6805' SLM, PULLED 3 1/2 AVA STYLE CATCHER @ 6806' SLM, IN PROGRESS. 10/24/10 RAN 10'x 2" DD BAILER, BAIL FILL f/ 6808' SLM TO 6833' SLM, NO MARKS �I ConocoPhitlips Time Log & Summary Wellview Web Reporting Report Well Name: 2T -15 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 9/26/2010 4:00:00 PM Rig Release: 10/12/2010 9:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 9/26/2010 24 hr Summary MIRU. Load Pits with Kill Weight Fluid. Bullhead Kill Tubing with 11.1 lb/gal Brine. 14:30 16:00 1.50 MIRU MOVE MOB P Move rig off 2T -06, down well row on riq mats. 16:00 19:00 3.00 MIRU MOVE MOB P lAccepted Nordic 3 Rig @ 1600 hrs 9 -26 -2010. Remove 11" stack from cellar. Remove 11" annular from stack and put on stump for shipping to Anchorage. Move over 13 5/8" stack and set in cellar on stump. 19:00 20:00 1.00 MIRU MOVE MOB P Move BOP Skid. Hang Tree in the Cellar. 20:00 21:00 1.00 MIRU MOVE MOB P Move over Well. Center and level up Rig. 21:00 00:00 3.00 MIRU MOVE RURD P Roll tarps. Berm Cellar. Spot remaining Rig Equipment. Start loading Pits with Kill Weight Fluids 9/27/2010 Set BPV. Nipple Down Tree. Nipple up 13 5/8" BOP Stack. Start initial BOPE test. 00:00 01:00 1.00 COMPZ RPEQPI RURD P Continue loading Pits with KWF. Rig up lines to Tree. Hook up lines to Tank. 01:00 02:30 1.50 COMPZ RPEQPI PULD P PJSM W /Crew. Discuss hazards involved in lubricating out BPV. Overhead load, well control, communications. Pick -up Lubricator. Pull BPV. Lay down same. TP = 660, IAP = est 10 psi, OAP = 0 psi. 02:30 05:00 2.50 COMPZ RPEQPI CIRC P Pressure test line at 300/3,900 psi. Good test. Bring Pump on line slowly. Bullhead kill Tubing-with-an i nitial circulating pressure of 4.0/1900 psi. Final circulating pressure = 4.0 bpm /1,270 psi. Bull headed a total of 100 bbls. ISIP = 550 psi. Let formation head down to 270 psi. Monitor Tubing dead after slowly bleeding back a total of 7 bbls. Blow down lines. 05:00 05:30 0.50 COMPZ RPEQPIOTHR P U nstall 05:30 10:00 4.50 COMPZ RPEQPI NUND P ND tree NU adaptor flanges, inspect hanger threads, OK. 10:00 15:30 5.50 COMPZ RPEQPI NUND P NU BOPE. Page 1 of 16 rime Lo s Date From To ' - Dur S. De th E. De th Phase Code Subcode T Comment 15:30 00:00 8.50 COMPZ RPEQPI PRTS P PJSM W /Crew. Discuss working with high pressure. Test Alarms. Begin initial BOPE test. Attempted to get an initial body test at 250/4,000 psi. However the Double Stud Adaptor Flange is leaking '� between the 13 5/8" Flange and the bottom of the 13 5/8" Single Gate BOP Ram Flange. Attempted to tighten 4 times. No -Joy. Break the BOP Stack loose from the DSA. Lift Stack. 9/28/2010 Complete Initial BOPE test. Rig up S -Line. Run a 1.90" Drift. Set CA -2 Blanking Plug in "D" Nipple at 7,264 -ft. Test same at 2,500 psi x 15 minutes. Good. Attem t to set Catcher Sub. 00:00 02:00 2.00 COMPZ RPEQPI PRTS P Replace BX 160 Ring Gasket. Set Stack back down and nipple back up. Torque up Flange Bolts in sequence. Record initial body test at 250/4,000 psi. Good. 02:00 13:00 11.00 COMPZ RPEQPI PRTS P P erform initial BOPE. Test BOPs and Choke Manifold at 250/4,000 psi. Test Annular at 250/3,500 psi. Perform Koomey draw down test. All test recorded on Chart. Tested Pit Alarms. All test witnessed by AOGCC State Rep, J. Jones. Blow down lines and rig down test e ui ment. 13:00 14:30 1.50 COMPZ RPEQPI THGR P Pull Test Drt and BPV. i 14:30 17:30 3.00 COMPZ RPEQPITHGR P PJSM. BOLDS. Pick up on Tubing to 11 k. rep for S -line operations. 17:30 00:00 6.50 COMPZ RPEQPI SLKL P PJSM W /Rig Crew and S -Line Crew. Discuss overhead loads. red -zone around wire and sheaves. Rig up S -Line. Run in with a 1.90" Drift to the "D" Nipple at 7,264 -ft with no problems. Run in with a CA -2 Blankin Plu Locate the "D" Nipple at 7,264 -ft. Set Plug Apply 200 psi with Rig Pump on top of Plug. Shear free from Plug. POOH. Pressure test Plug at 2.500 psi x 15 minutes and record on Chart. Good test. Run in with a Catcher Sub (2.77" OD). Found scale at 2,100 -ft Work down to 2,370'. POOH. 9/29/2010 Encountered Scale. Run GR to the AVA Nipple. Run Catcher Sub to 5,055'. Bail Scale and got Catcher Sub down to 6,800'. RD S -Line. Pull Seal Assembly free. Reverse circulate Well. Lay down 3 1/2" Completion Page 2 of 16 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 06:00 6.00 COMPZ RPEQPI SLKL P Run in with a 2.71" Catcher Sub. Encountered Scale at 2,100 -ft. Worked down to 2,370 -ft. POOH. Run in with a 2.78" Gauge Ring to 2,370 -ft. Continue to work through Scale pockets and sections down to 5,260 -ft. Continue down to the AVA Nipple at 6,844 -ft with no further problems. POOH. Run in with Catcher Sub. Set down at 5,055 -ft. Attempted to work through several times. No -Joy (may have sheared off while trying to spang through tight spot). POOH. Attempt to fish, tag up @ 5,046'. POOH and "G" retrievin tool was packed with scale. 06:00 19:00 13.00 COMPZ RPEQPI SLKL T Attempt to bail scale in multiple runs and located Catcher sleeve at 5,055' and was able to chase down hole to 6,790 -ft. Continue to bail Scale. Got down to 6,800 -ft on last run. POOH lay down Tool String. Lay down Lubricator. Rig down S -Line. 19:00 19:30 0.50 COMPZ RPEQPI PULL P Pull Seal Assembly fr from PBR at 6,754 M aximum pull = 123K. Dragging at 95K - 11 OK. 19:30 21:00 1.50 COMPZ RPEQPI CIRC P Rig up to reverse circulate. SICP = 60 psi. Bring Rig Pump on line at 2.0 bpm and reverse circulate Take returns through Choke to Tiger Tank. Increase rate to 4.0 bpm /340 psi. Continue to reverse circulate until returns weighed 11.05 lb/gal. Pumped a total of 270 bbls. Shut down pump and monitor Well static. 21:00 22:00 1.00 COMPZ RPEQPI PULL P Blow down Top Drive and Lines. Lay down 3 1/2" Landing Pups. Lay down Tubing Hanger. Hook up Control Line to Spooling Unit. 22:00 00:00 2.00 COMPZ RPCOM PULD P Single down 3 1/2" Completion while 9/30/2010 Make -up 3 1/2" Mule Shoe and Casing Scraper. Trip in. Set down at 388 -ft. POOH. RU HES E -Line. Record CBL, Caliper Lo c, Gyro Survey. 00:00 07:00 7.00 COMPZ RPCOM PULL P Continue to single down 3 1/2" Tubing while spooling Control Line. Lay down SSSV. Recovered 31 SS Band (according to the number ran, one band is missing. However, it appears that the "run count" was wrong, as no sign of a missing band was noticed). Rig down Camco Spooling Unit. Continue to single down 3 1/2" Completion. 07:00 08:00 1.00 COMPZ RPEQPI OTHR P Offload TBG equipment pulled and Bring in BHA #1 Page 3 of 16 Time Logs Date From To Dur , S. De th E. De th Phase Code -- Subc ode T Comment 08:00 08:30 0.50 COMPZ RPEQPI SFTY P Held PJSM with Baker and Rig crew on PU and MU of 7" CSG scraper assy and Running in the hole with the same. Discussed hand placement, pinch points and dangers of running through crokked CSG. 08:30 09:30 1.00 0 388 COMPZ RPEQPI TRIP P PU and MU 7" CSG scraper assv and RIH to 230' and seen the DP attempt to rotate to the right. Continue to RIH and stopped CcD 388 -ft. POOH and lay BHA. 09:30 10:00 0.50 0 COMPZ RPEQPISFTY P Held PJSM with HES, Rig Crew, ConocoPhillips E &P Canada - Well Services OPs, Von Cawvey and Nordic Field Supt. on RU and lworking with E Line. 10:00 11:00 1.00 COMPZ RPEQPI ELOG P RU E Line to 7" Otis Shooting Nipple in Annular. 11:00 15:00 4.00 COMPZ RPEQPI ELOG P RIH w/ RC to 6,754 -ft and I ng mit to sudace- Locate JQfaLJ.9AQ_-ft_ 15:00 17:30 2.50 COMPZ RPEQPI ELOG P RD RCBL and MU PDS 40 ARM Cali er Lo with GR, and memory. 17:30 22:30 5.00 COMPZ RPEQPI ELOG P RIH with Caliper log. Log Well from the PBR at 6,754 -ft back to surface. Lay down PDSCali er Tool String. 22:30 00:00 1.50 COMPZ RPEQPI ELOG P I P' Start run in hole. 7 10/01 /2010 Cont recording Gyro Survey. Rattle Collar at 1,892 -ft. RD E -Line. RIH with Baker IBP. Set at 2,417 -ft. Pressure test. Swap Well over to Sea Water. Dump Sand. Tag Sand at 2,370 -ft. ND BOP Stack. Rig up H drati ht equipment. 00:00 04:00 4.00 COMPZ RPEQPI ELOG P Continue recording Gyro Log data from PBR to surface. Lay down Gyro Tool. 04:00 04:30 0.50 COMPZ RPEQPI ELOG P PJSM. Discuss picking up the String Shot. Crew reminded not to handle the tool string. Pick -up String Shot. Run in hole. 04:30 06:30 2.00 COMPZ RPEQPI ELOG P RIH with string shot and sh at 1 892 -ft. POOH 06:30 07:00 0.50 COMPZ RPEQPI ELOG P RD E line 07:00 07:30 0.50 COMPZ RPEQPI SFTY P PJSM with rig crew on RIH with pipe 07:30 08:00 0.50 0 0 COMPZ RPEQPITRIP P RIH with 581 -ft. had no problems running through the area that the scraper would not go through and POOH 08:00 08:30 0.50 0 0 COMPZ RPEQPI SFTY P PJSM with rig creew and Baker Thru TBG on PU and MU of IBP along with running seed. 08:30 10:00 1.50 0 2,428 COMPZ RPEQPITRIP P Bring IBP to rig floor and MU RIH with IBP at 3 min per stand to 2,428 -ft. Page 4 of 16 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 11:00 1.00 2,428 2,416 COMPZ RPEQPI PACK P RU Test pump equipment and drop ball and pressure up to 620 psi to open inflation valve, set for 5 minutes and stage up to 1,000 psi to inflate ' IBP. set for 5 minutes and stage up to 2,820 psi and shear off IBP with Top of Fishing neck at 2.416 -ft. RD test pum equipment. 11:00 11:30 0.50 2,416 2,416 COMPZ RPEQPISFTY P Held PJSM with rig crew on pulling wet pipe. 11:30 12:30 1.00 2,416 0 COMPZ RPEQPITRIP P POOH with 3 1/2 DP and IBP setting tool. 12:30 13:00 0.50 0 0 COMPZ RPEQPI PRTS P Close Blind Rams and PT IBP 2,500 psi fo 15 minutes a charted - good test. Bleed off and Open Blind rams. 13:00 13:30 0.50 0 0 COMPZ RPEQPI SFTY P Held PJSM with Rig crew on RIH with 3 1/2 DP. 13:30 14:30 1.00 0 2,361 COMPZ RPEQPITRIP P RIH w/ Double box on 3 1/2 DP to 2,361 -ft. 14:30 15:00 0.50 2,361 2,361 COMPZ RPEQPI CIRC P Displace 11.1 ppg KWF with sea water circulating at 9 bpm at 870 psi ICP and 680 psi FCP. 15:00 17:00 2.00 2,361 2,370 COMPZ RPEQPI OTHR P RU and Dump 24 - 60# sacks of maso nary sand on top of IBP and POOH 90 -ft. Wait 1 hr and Tag Top of sand at 2,370 -ft. 17:00 18:00 1.00 2,370 0 COMPZ RPEQPI TRIP P POOH from 2,370 -ft. 18:00 20:00 2.00 0 COMPZ RPEQPI NUND P PJSM W /Crew. Discussed pinch points, overhead loads, line of fire, communications. Nipple down BOP Stack and set on Stump. 20:00 00:00 4.00 COMPZ RPEQPI RURD P PJSM W /Crew, Cameron, Hydratight. Discussed using hammer wrench, pinch points, confined working space, high pressure when using hydraulic tools. Nipple down valves on Tubing Head. Remove excess bolts not needed to rig up Hydratight Equipment Install 6 -ft All- Threads. Rig up Hydratight Equipment Prep to allow 7" Casing to grow. 10/02/2010 Allow 7" Casing to grow using Hydratight Equip. ND Tubing Spool. Spear Casing and re -land in Slips. Cut off Casing. NU BOPE. Install 7" Pipe Rams. MU and RIH with Baker MS Cutter. Cut Casing at 1,957 -ft. Begin to recover Arctic Pack. Page 5 of 16 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 09:30 9.50 COMPZ RPEQPI NUND P B egin to allow the 7" Casino to grow using ' ght Equipment, Start out with 15,000 psi hydraulic pump pressure. After the first 5 cycles, Casing has grown 1/8 inch. After 95 cycles , pressure is 6,500 psi and the total growth is 20 3/8 ". Continue to snub Casing growth. At 180 cycles, pressure dropped to 800 psi with a total of 39.75" of growth Flange to Flange. Remove TBG spool and the Stub measurement was 44.25" 09:30 10:30 1.00 COMPZ RPEQPI OTHR P PJSM, PU spear, Engage 7" CS G stub and PLI 50k asw to 135k. Re land slips. Release spear and lay down same. 10:30 11:00 0.50 COMPZ RPEQPI OTHR P Cut 7" CSG stub 7" above the 11" flange with Wachs cutter. 11:00 11:30 0.50 COMPZ RPEQPI SFTY P Held PJSM on NU of CMT cross and 13 5/8" BOP. Discussed pinch pts, caught between, hand placement. 11:30 18:00 6.50 COMPZ RPEQPI NUND P NU cmt cro C hange out 3 1/2 x 5 1/2" VBR's to 7 in LPR's. R emove HCR and Manual Valve to change out under length studs and install proper studs that meet API standards as per AOGCQ Function t 7" Rams. 18:00 20:30 2.50 COMPZ RPEQPI CPBO P PJSM w /Crew and Baker Fisherman. Discussed pinch points during making up of the MS Cutter. Make up Baker 5 1/2" Multi- Str Cutter. Run in on 3 1/2" Drill Pipe to 1,850 -ft. Up weight = 63K Down weight = 63K. Bring Pump on line at 3.0 bpm /300 psi. Locate Collars at 1,892 -ft and 1,850 -ft. (Note: there is a 10 -ft difference between the E -Line Collar Log and the original Casing Tally. (Also it was noted on the CCL Log that there was a Centralizer near by the planned cut depth of 1,868 -ft.). Position MS Cutter to cut at 1,857 -ft. Ramp Pump up to 4.5 by /610 psi. RPMs = 88. Pressure dropped to 210 psi. Made cut in 5 minutes. Continue for an additional 5 minutes. 20:30 21:30 1.00 COMPZ RPEQPI CIRC P Monitor Well out of balance. Shut in Annu lar. Pressure built up and , stabilized at 120 psi. Bring pump on line with warm Sea Water at 2.0 bpm /90 psi. Route returns though Choke to Open Top Tank and bleed off gas and diesel. Pressure bleed right on down. Monitor Well dead. Page 6 of 16 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 21:30 22:00 0.50 COMPZ RPEQPI TRIP P PJSM. Trip out with 3 1/2" Drill Pipe and MS Cutter. Normal expected Blade wear. All Blades recovered. 22:00 22:30 0.50 COMPZ RPEQPI FISH P Make-up 7" Casing Spear w /Pack -Off and plant in 7" Casing. Pick up Casing 1 -ft. String weight= 90K. Casing is free. 22:30 00:00 1.50 COMPZ RPEQPI CIRC P Begin Arctic Pack recovery. Pumping heated Diesel at 2.0 b m /150 psi. 10/03/2010 Complete Arctic Pack recovery. Rig up Casing equipment. Pull and single down 7" Casing to Pipe Shed. Chan a Pipe Rams and test. Run 9 5/8" Csg Scraper. Set down at 371 -ft. Rig up E -Line. 00:00 04:00 4.00 1,857 1,857 COMPZ RPEQPI CIRC P Continue with Arctic Pack recovery. Finish pumping 200 bbls of heated Diesel. Start hot Sea Water at 3.0 bpm/ Pumped 100 bbls. Then let soak 1 hour. Finish cleaning up Arctic Pack with as additional 160 bbis of hot Sea Water. 04:00 07:30 3.50 1,857 1,857 COMPZ RPEQPI NUND P PJSM W /Crew. Discuss overhead load, double check rigging, pinch points, using hammer wrenches. Break Cement Cross. Lift Stack and p ull 7" Casing Slips. NU BOPE. 07:30 08:30 1.00 1,857 1,827 COMPZ RPEQPI FISH P PJSM on spearing and Pulling 7" CSG to rig floor. Pull 7 " Casing to floor 90k up wt seen 165 max with spear at floor, release spear and lay down same. 08:30 12:00 3.50 1,827 0 COMPZ RPEQPI PULL P Break out 2.60 -ft of stub, POOH w/ cplg @ rig had a 225k max pull, continue laying down 7" CSG. Found connection of 11 to 12 was missing a 4 "x 4" section from cplg. Was able see all cplg and some centralizers pull through tight spot in 9 5/8" CSG. 19 centralizers were recovered with 5 of them being arshals. 12:00 14:00 2.00 0 0 COMPZ RPEQPI OTHR P RD CSG equipment, Clean and clear floor and pipe shed. Loa 9 5/8 CSG s craper assy components and test p lug equipment. 14:00 15:30 1.50 0 0 COMPZ RPEQPI OTHR P Install 11" Test plug, Change out LPR's from 7" to 2 7/8 x 5 1/2" VBR's. 15:30 19:30 4.00 0 0 COMPZ RPEQPI BOPE P RU Test Equipment. Test LPR's a t 250 / 3,000 psi with 3 1/2 Test jt. Low test was good and High test failed. - Ram packing leaking. Change out 2 7/8 x 5 1/2" VBR's to 3 1/2" Solids. Re - test rams at 250 / 3,000 psi. Test HCR and MAnual Choke at 250/3,000 pssi. Good. Record tests on Chart. 19:30 20:30 1.00 0 0 COMPZ RPEQPI BOPE P Pull Test Plug. Set Wear Bushing. Page 7 of 16 Time Logs Date From To Dur S. De th E De th< Phase Code Subcode T Comment 20:30 21:00 0.50 0 94 COMPZ RPEQPI PULD P PJSM w /Crew and Baker Fisherman. Discuss handling large tools, pinch points, lifting tools to floor. Make -up BHA #5 as follows: 3 1/2" Mule Shoe, XO, 9 5/8" Casing Scraper, Bit Sub, Bumper Sub, Oil Jar, XO, 1 ea 6 1/4" Drill Collar, XO, XO. 21:00 21:30 0.50 94 371 COMPZ RPEQPI TRIP P Trip in with BHA #5 and 3 1/2" Drill Pipe from Derri Casing Scraper . s et down at 371 -ft (Mule Shoe depth at 405 -ft). No further progress. ( Spot E -Line Unit). 21:30 22:00 0.50 371 371 COMPZ RPEQPI CIRC P Circulate from 405 -ft at 3.0 bpm /100 psi x two bottoms up to clean up any remaining Arctic Pack that has floated to top of the hole. 22:00 23:00 1.00 371 0 COMPZ RPEQPITRIP P Trip out with 3 1/2" Drill Pipe and BHA. Lay down BHA. 23:00 00:00 1.00 0 COMPZ EVALWE ELOG P PJSM w /Crew, HES, PDS. Discuss bring tool to Rig Floor. Finish rigging up HES E -Line. Pick up 40 -Arm Caliper Tool. Start to run in hole. 10/04/2010 Record Caliper Log and a Gyro Log in the 9 5/8" Casing. Begin Milling Operations. 00:00 05:00 5.00 0 0 COMPZ EVALWE ELOG P C ontinue to run in hole with 40 -Arm Caliper Tool. Stop at 1,850 -ft. Log b ack to surface. Lay down Caliper Tool. Pick up Gyro Tool. Run in hole to 1,850 -ft. Log back to surface. Rig down and release E -Line. 05:00 08:30 3.50 0 0 COMPZ RPEQPI OTHR P Clean and clear rig floor. Load milling BHA and 6.25" OD DC's 08:30 09:00 0.50 0 0 COMPZ RPEQPI SFTY P Held PJSM with Baker Fishing and Rig Crew on MU of milling BHA and handling of tools. 09:00 10:00 1.00 0 316 COMPZ RPEQPI PULD P Make -up BHA #6. 10:00 12:00 2.00 316 1,892 COMPZ RPEQPITRIP P RIH with BHA #6 and tag up at 370 -ft mill depth. PU and Gather Parameters: 65k up wt, do wt and ROT wt. Circulate at 6 bpm @ 60 psi. Rotating at 62 RPM's with 1 k free torque. Begin milling with 2k WOM with 2k torque. Fell through at 371 -ft. Ream through multiple times and continue to RIH to 1,892 -ft with mule shoe and 1,857 - ft. with mill. 12:00 14:00 2.00 1,892 1,892 COMPZ RPEQPICIRC P Circulate at 6 bpm @ 150 psi till clean. 14:00 16:00 2.00 1,892 0 COMPZ RPEQPITRIP P POOH from 1,892 -ft and lay down BHA. 16:00 16:30 0.50 0 0 COMPZ RPEQPI SFTY P Held PJSM with Baker Fishing and Rig crew on PU drill collars, and MU of Back off BHA V. Page 8 of 16 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 16:30 19:30 3.00 0 1,857 COMPZ RPEQPI PULD P Load back off tools and PU and RIH with 9 - 4.75" OD dc's and Back off assy. Tagged top of 7" Casing Stump at 1,857 -ft. Attempted to enter Stump multiple times. No-Joy. 19:30 19:30 0.00 1,857 0 COMPZ RPEQPI TRIP T Trip out with BHA V. Remove 3 1/2" Mule Shoe. Install a 6" x 4" Tapered MITI. 19:30 00:00 4.50 0 1,857 COMPZ RPEQPITRIP P Trip back in with the Tapered Mill on the Back -Off BHA #8. Entered the 7" Casing Stump with no problems. Straddle the 7" Casing Collar at 1,881 -ft dpmd. Set lower and upper anchors. Perform initial connection break at 1200 psi = 1 /2turn. 10/05/2010 Perform initial Casing Collar break. Weekly BOP Test. Continue to Mill tight area in the 9 5/8" Casing @ 370' md. Cont to top of 7" Casing Stump. 00:00 01:00 1.00 1,857 1,881 COMPZ RPEQPI BKOF P Continue to Back -off the 7" Casing Collar at 1,881 -ft. Cycle Tool 6 more times for a total of 3 3/4 turns. 01:00 03:30 2.50 1,881 0 COMPZ RPEQPITRIP P Trip out with 3 1/2" Drill Pipe and L/D BHA #8. 03:30 09:00 5.50 0 1,885 COMPZ RPEQPI MILL P PJSM. M/U BHA #9, RIH and tagged tight spot at 370' w /upper mill. Up Wt =60k down Wt =60k. Begin Milling @ 370' to 372'@ 6 bpm, 60 psi 72 RPM, 1 -2 tq, work thru tight spot. Cont rih f/372' to 1855' unable to enter into 7" csg w/ 4 3/4" DP. Blow TD. 09:00 11:00 2.00 1,885 0 COMPZ RPEQPITRIP P PJSM. POOH f/1855'md. L/D BHA #9 11:00 12:00 1.00 0 0 COMPZ RPEQPI PULD P PJSM. M/U BHA #10 12:00 13:00 1.00 0 271 COMPZ RPEQPITRIP P RIH W /BHA #10 and tagged @ 271' md. NO -GO 13:00 14:00 1.00 271 0 COMPZ RPEQPITRIP P PJSM. POOH w/ BHA #10. L/D BHA. 14:00 15:30 1.50 0 0 COMPZ RPEQPI PULD P Wash Out Stack. Pull Wear Ring. Set Test Plug. 15:30 19:30 4.00 0 0 COMPZ RPEQPI BOPE P P erform Weekly BOP Test. 19:30 20:30 1.00 0 0 COMPZ RPEQPI SFTY P PJSM. Discuss SIM Ops. HouseKeeping, Hand Placement. OverHead Lifting. BHA Order. Commucation. 20:30 23:00 2.50 0 410 COMPZ RPEQPI PULD P M/U BHA #1 & RIH. Set Dow__ 370 MD. 70k Up Wt / 68k Down Wt. Start Milling on Tight Spot @ 6 bpm, k`5 ^►` 60 psi, 60 rpm, w /1k -2k Torque. Mill thru tight spot rotating several times and Drifted thru tight area not rotating with no problem. 23:00 00:00 1.00 410 0 COMPZ RPEQPITRIP P POOH, Laying down DP & DC and BHA #11. Page 9 of 16 Time Logs Date From To : Dur ' S. Depth E. Depth Phase Code Subcode T Comment 10/06/2010 24 hr Summary Milled Thru Tight Spot inside 9 5/8" CSG with 8.5" String Mill. Made Several Attempt To Drift Thru Tight Area With ES Cementer Dummy Drift with No Success. Perform Video Log With HES E -Line to Identify Problem Area Inside 9 5/8" Casin . 00:00 00:30 0.50 0 0 COMPZ RPEQPI PULD P I Done laying Down Milling BHA #11 00:30 01:00 0.50 0 0 COMPZ RPEQPI SFTY P PJSM. 01:00 01:30 0.50 0 64 COMPZ RPEQPI PULD P MU BHA #12. Dummy Drift WES Cementer. 01:30 02:00 0.50 64 370 COMPZ RPEQPI TRIP P RIH w/ Dummy Drift Run. Set Down With Dummy Drift Run @ 370'md. POOH and Lay down BHA #12. 02:00 03:30 1.50 0 0 COMPZ RPEQPI PULD P MU Milling Assembly & RIH 03:30 07:00 3.50 0 370 COMPZ RPEQPI MILL P Set Down @ 370' MD. 70k Up Wt / 68k Down Wt. Start Milling on Tight Spot @ 6 bpm, 60 psi, 60 rpm, w/1 k -2k Torque. 07:00 07:30 0.50 370 401 COMPZ RPEQPI MILL P Crew Change, Dry Drift from 373' -384', Work millina assembly from 385' -395', Able to dry drift thru both areas with no set downs 07:30 09:00 1.50 401 0 COMPZ RPEQPITRIP P POOH Lay Down Milling BHA 09:00 09:30 0.50 0 0 COMPZ RPEQPI SFTY P PJSM for Pick Up Dummy Drift, Discussing Pinch Points, Heavy Lifting, Communication 09:30 10:30 1.00 0 371 COMPZ RPEQPITRIP P Set Down With Drift Assembley At 371' RKB, POOH Call For E -Line Camera, PJSM for POOH and Lay Down Drift Assembl 10:30 11:30 1.00 371 0 COMPZ RPEQPITRIP P OOH, Lay Down Triple Connect Drift Assembl 11:30 12:30 1.00 0 513 COMPZ RPEQPITRIP T T with 3.5" DP to 513' MD and blow down 9 5/8" CSG with N2 12:30 13:00 0.50 513 513 COMPZ RPEQPI OTHR T Wait on SLB with N2 13:00 13:30 0.50 513 513 COMPZ RPEQPI SFTY T PJSM with Nordic and SLB N2 crew 13:30 14:45 1.25 513 0 COMPZ RPEQPI OTHR T 9 5/8" CSG Blow Down to 500' MD with 241 Gal N2 24,441 SCF 14:45 15:30 0.75 0 300 COMPZ RPEQPITRIP T PUH to 300' MD, Rig Up E -Line With Camera 15:30 19:30 4.00 300 370 COMPZ RPEQPI ELOG T Perform Video Loa On Dama e CSG @ 370' m 19:30 23:30 4.00 370 0 COMPZ RPEQPI ELOG T Discuss Plan Forward With Town Engineer After Reviewing Video Log. 23:30 00:00 0.50 0 0 COMPZ RPEQPI PULD T Baker Tools On Location. Un -load and Make Up Milling BHA. 10/07/2010 Finish Milling Out Tight Spot @ 370' and w/ 8.75" Mill. Made Successful Drift Run ES Cementer. Spear and Pulled 23 feet of cut 7" CSG Stub from Old Completion. Clean out any Debris from CSG Stump. 00:00 02:00 2.00 0 400 COMPZ RPEQPI MILL T Finished Making Up Milling BHA. TIH to Tight Spot @ 370' and and started Milling at 6 bpm, rotating at 60 -70 rpm with 40 -50 psi on the DP, 1 -3k Torque. Milling Thru Tight spot several times and was able to drift thru not rotating. Page 10 of 16 Time Logs Date From To Dur' S. De th E De th Phase Code Subcode T Comment 02:00 03:00 1.00 400 0 COMPZ RPEQPI PULD T TOOH and Lay down Milling BHA. 03:00 03:30 0.50 0 0 COMPZ RPEQPISFTY T PJSM. Discuss Spills, High Psi Pumping, Overhead Loads, Dropped Objects, Pinch Points and Sli s,Tri s & Falls. 03:30 04:30 1.00 0 1,857 COMPZ RPEQPI PULD T MU Dummy Drift BHA w /ES Cementer and Beveled Triple Connect Screw In Sub. 04:30 08:00 3.50 1,857 1,857 COMPZ RPEQPI CIRC P Change hole to diesel and allow to soak for 1 hr. Finish circulating diesel off truck and swap to sea water and displace well. 08:00 09:30 1.50 1,857 0 COMPZ RPEQPITRIP P POOH with dummy assy and lay down same. 09:30 11:00 1.50 0 1,857 COMPZ RPEQPITRIP P PU and RIH with spear to 1,857 -ft. 11:00 11:30 0.50 1,857 1,857 COMPZ RPEQPI FISH P Engage stub and finish backing out the same. 11:30 14:00 2.50 1,857 0 COMPZ RPEQPITRIP P Start pulling with 5 to 10k osw. Signs of junk around stub. Continue to POOH with fish to surface and lay down the same. 14:00 15:30 1.50 0 0 COMPZ RPEQPI SLPC P Slip /Cut Drill Line 15:30 16:30 1.00 0 0 COMPZ RPEQPI PULD P PJSM, PU 6 1/8 Tappered Mill, One 4 3/4 DC, 8 3/4 String Mill, Nine 6 1/4 DC to 1881' 16:30 18:00 1.50 0 1,857 COMPZ RPEQPITRIP P RIH on DP to 1857' and 18:00 18:30 0.50 1,857 1,857 COMPZ RPEQPI CIRC P Circulate 30 bbls High -Vis Sweep @ 8 b m / 300 psi. 18:30 21:30 3.00 1,857 0 COMPZ RPEQPITRIP P TOOH From 1857' ft, laying down BHA & Drill Collars. 21:30 22:00 0.50 0 0 COMPZ RPEQPI PULD P Clear Floor of All Baker Tools and Lower to ground storage area. 22:00 22:30 0.50 0 0 COMPZ RPEQPI SEQP P Pull Wear Bushing and Set Test Plug. 22:30 23:00 0.50 0 0 COMPZ RPEQPI CIRC P MU Up Washing Assembly and Flush BOP Stack @ 10 bpm, 40 p si. 23:00 00:00 1.00 0 0 COMPZ RPEQPI PULD P UD Wash Assembly. Blow down Top Drive and Drain BOP Stack. 10/08/2010 Ran 7" CSG Assembly & Screw into csg stub. Pump Cmt Per - Schedule. Landed 7" csg on slips. Installed Vetco gray Packoff assembl . 00:00 02:00 2.00 0 0 COMPZ RPEQPI EQRP P Chan a Out LPR's To 7" Rams.a 02:00 02:30 0.50 0 0 COMPZ RPEQPI PRTS P Pressure Test Rams To 250/3000 p si. 02:30 03:00 0.50 0 0 COMPZ RPEQPI PULD P Blow Down test Lines. RU Equipment To Pull test Plug. 03:00 03:30 0.50 0 0 COMPZ RPEQPI SFTY P PJSM. Discuss Running Order of 7" Completion, Lifting Operation. Inspection Of ES Cementer. Hand Placement While Running CSG.Tripping Speed While Running CSG. Housekeeping On Rig Floor. 03:30 06:30 3.00 0 1,881 COMPZ RPEQPI RCST P RU CSG Equipment. Start Making Up Tie -Back String. Page 11 of 16 Time Logs Date From To Dur S. De th E.De th Phase Code Subcode T - Comment 06:30 09:00 2.50 1,881 1,881 COMPZ RPEQPI RCST P Space Out 7" CSG, Screw into 7" Stub Tripple Connect, Swap to Ling Bails 09:00 09:30 0.50 1,881 1,881 COMPZ RPEQPISFTY P PJSM with SLB,HES,ASRC,CPAI,Nordic Crew, 09:30 10:30 1.00 1,881 1,881 COMPZ RPEQPI PRTS P PT 7' to 2500#, Walk PSI up to 3340# Shear Open HES Cementer, Pump 100 bbls Seawater 10:30 11:00 0.50 1,881 1,881 COMPZ RPEQPICMNT P Cementers on line with 5 bbls seawater ahead, shut down pt lines to 4000# (good), Open downhole close choke for injectivity test. 1 BPM = 96 PSI 2 BPM = 160 PSI 3 BPM = 220 PSI 3.5 BPM = 275 PSI 11:00 11:15 0.25 1,881 1,881 COMPZ RPEQPICMNT P Open chokes to return tanks, Going downhole wit 10 hhls Neat 15.8 P PG AS1, Followed with 30 bbls 15.8 PPG AS1 with 1.6 PPB CemNet, Followed with 77 bbls Neat 15.8 PPG AS1. 11:15 11:48 0.55 1,881 1,881 COMPZ RPEQPICMNT P 117 bbls AS1 away, Launch HES Cementer closure plug,Followed by 3 bbls 15.8 PPG AS1 Neat, Followed by 68 bbls Seawater displacement. 11:48 12:01 0.23 1,881 1,881 COMPZ RPEQPICMNT P 15.8 PPG AS1 Cement to Surface, Close in Choke attempt to hesitation squeeze, Watch for plug to bump. 12:01 12:07 0.10 1,881 1,881 COMPZ RPEQPI SQEZ P Choke closed with 640 psi squeeze pressure, 40 bbls displacement p umped 12:07 12:19 0.20 1,881 1,881 COMPZ RPEQPI SQEZ P Wiper Plug on seat pressure up and close HES Cementer @ 2200# ,Pressure Up on 7" to 3500 #, Bled 7" back to zero. Total Volume Squeezed Away = 20 bbls 15.8 PPG AS1 with 1.6 PPB CemNet. 20 bbls 15.8 PPG AS1 Neat. Starting Squeeze Pressure = 640 PSIG Final Squeeze Pressure = 950 PSI 12:19 12:34 0.25 1,881 1,881 COMPZ RPEQPI OTHR P Wash up cement lines and Cement Cross 12:34 13:14 0.68 1,881 32 COMPZ RPEQPI OTHR P RD cementers and cement equipment 13:14 13:44 0.50 32 32 COMPZ RPEQPI OTHR P PJSM with rig crew on draining stack ND of BOPE 13:44 15:59 2.25 32 32, COMPZ RPEQPI NU ND P ND BOPE and install slips at 135k 15:59 16:59 1.00 32 0 COMPZ RPEQPI OTHR P Cut 7" 26# L -80 CSG with wachs cutter Page 12 of 16 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 16:59 19:59 3.00 0 0 COMPZ RPEQPI OTHR P Break down and lay down head pin, BTC x TCII x -o, 1 - 14'x TCII pup joints, 1 - 10' x TCII pup joints, 1 - 5' x TCII pup joints and 7.2 -ft of 7" stub. Set back on well head and ND cmt cross, set BOP's on stump. 19:59 23:59 4.00 0 0 COMPZ RPEQPI OTHR P S tart Installing Packoff Assembly C/O bails. Had to use 1 stand of 4 3/4" Drill collars to assist with Pack -off installation. 10/09/2010 NU New TBG Head & PT to 3000 psi. Mill Up Plug & Cement. PT Casing to 3500 psi for 30 mins. Dry Drill Debris w/ 6 1/8" Concave Mill. Start Reverse Cirulatin g to clean CSG. 00:00 02:00 2.00 0 0 COMPZ RPEQPI NUND P N/U New 7 1/16" Tubing Head. NU 13 5/8" BOPE 02:00 02:30 0.50 0 0 COMPZ RPEQPI PRTS P PT Packoff to 3000 psi. 02:30 04:30 2.00 0 0 COMPZ RPEQPI NUND P Install test Plug. Installed 3.5" Rams in btm Cavit 04:30 06:00 1.50 0 0 COMPZ RPEQPI PRTS P PT LPR'S 250/4000 psi. Pull Test Plug, Install Wear Bushin 06:00 07:30 1.50 0 0 COMPZ RPEQPI PULD P Crew Change,PJSM,MU Cement Plug Mill in BHA. 07:30 08:45 1.25 0 1,742 COMPZ RPEQPITRIP P TIH to Top Of Cement Plug on top Of ES Cementer. 08:45 09:45 1.00 1,742 1,867 COMPZ RPEQPI DRLG P Set Down @ 1742', PUH, Screw In Top Drive, Begin Drilling Cement @ 60 RPM,1.5 TRQ,70k Up /63k Dwn, 6 BPM, 300 PSI 09:45 10:45 1.00 1,867 1,869 COMPZ RPEQPI DRLG P Tag top of ES Cement @ 1867', Continue Drilling Ahead @ 60 RPM, 6 BPM, 312 PSI 10:45 11:30 0.75 1,869 1,957 COMPZ RPEQPI DRLG P Back Ream Thru ES Cementer, Make Dry Run Thru ES Cementer 11:30 12:30 1.00 1,957 0 COMPZ RPEQPITRIP P POOH and dump boot baskets - very little debris. 12:30 13:15 0.75 0 0 COMPZ RPEQPI PRTS P RU and close blind ra Pressure up on 7" ca to 3.5 psi and chart for 30 minutes. - 13:15 14:00 0.75 0 311 COMPZ RPEQPI PULD P MU 6 1/8" OD concave milling assy and RIH to 311' 14:00 15:18 1.30 311 2,353 COMPZ RPEQPITRIP P TIH w/ Concave Mill, Tag Up @ 2122'. MU Top drive and rotate on junk, torqued up and dropped. Continue to chasae down hole to 2,353-ft. 15:18 16:00 0.70 2,353 2,356 COMPZ RPEQPI MILL P Begin dry Milling from 2,353 -ft to 2,356-ft. 16:00 17:00 1.00 2,356 2,356 COMPZ RPEQPITRIP P PJSM. Blow Down Top Drive. POOH 17:00 18:00 1.00 2,356 0 COMPZ RPEQPI PULD P OOH. Break Down BHA #20. MU BHA #21 18:00 19:30 1.50 0 2,356 COMPZ RPEQPI TRIP P RIH to 2333' md. Push down to 2356' and with Weight Swings. 19:30 20:00 0.50 2,356 2,362 COMPZ RPEQPI CIRC P Wash down f/ 2356' to 2362' @ 5 bpm. 50 RPM, 900 psi. Started Taking Weight @ 2362'md. CBU @ 900 psi. Page 13 of 16 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 20:00 22:00 2.00 2,362 0 COMPZ RPEQPITRIP P POOH. to check Boot Baskets. 22:00 22:30 0.50 0 0 COMPZ RPEQPI PULD P OOH. UD BHA and Break Down tools to check Boot Baskets. ( Recover Large Amount of Slips and 7" CSG Parts and Centralizers. 22:30 22:45 0.25 0 0 COMPZ RPEQPI SFTY P PJSM. Discuss BHA Make Up. Hand Placement. Pipe Handing. Good Commucation. 22:45 23:00 0.25 0 0 COMPZ RPEQPI OTHR P Move Tools from Rig Floor and Wash Slick Area Down with Pressure Washer. 23:00 23:30 0.50 0 321 COMPZ RPEQPI PULD P MU RCJB On DP. 23:30 00:00 0.50 321 1 1,096 COMPZ RPEQPITRIP P RIH w/ RCJB. 10/10/2010 Clean Out Debris From Top Of Sand. Reverse Circulated Hole Clean to top of IBP. Pulled and Layed down IBP. Made Clean out run down to PBR with Mule Shoe. Started POOH UD Drill Pi e. 00:00 00:30 0.50 1,096 2,357 COMPZ RPEQPITRIP P Continue in hole from 1096' and to 2357' md. Up Wt =75k / Down Wt =67k 00:30 01:00 0.50 2,357 2,367 COMPZ RPEQPI CIRC P Wash Down from 2357' to 2367'@ 6 bpm, 800 psi, 30 rpm. Unable to wash any further. CBU @ 6 bpm @ 880 psi. 01:00 02:00 1.00 2,367 321 COMPZ RPEQPITRIP P POOH. 02:00 03:00 1.00 321 0 COMPZ RPEQPI PULD P OOH. UD BHA, Break Down Boot basket & Shoe. Had Tree Small Peaces of Rubber inside Boot Basket. Make Up BHA for Another Clean Out Run. 03:00 03:45 0.75 321 2,367 COMPZ RPEQPI TRIP P R To Top Of Fill @ 2367' 03:45 04:15 0.50 2,367 2,395 COMPZ RPEQPI CIRC P Wash Down from 2357' to 2395'@8 bpm, 1600 psi, 30 rpm. Able to wash down with no problems.. CBU @ 8 bpm @ 1600 psi. Up Wt 75k Down Wt 67k. 04:15 04:30 0.25 2,395 2,357 COMPZ RPEQPITRIP P Seen Sand @ Shakers. Start POOH After seeing clean fluid in Pits. 04:30 05:30 1.00 2,357 0 COMPZ RPEQPITRIP P OOH, Swap to Junk Basket 05:30 05:45 0.25 0 2,395 COMPZ RPEQPITRIP P TIH to top of sand @ 2395' 05:45 06:15 0.50 0 COMPZ RPEQPI SFTY P Crew Change, PJSM 06:15 07:15 1.00 2,395 2 COMPZ RPEQPI WASH P Tag @ 2396', Reverse out down to 2418' @ 8 PBM,1450 PSI,70k Up/68k Dwn 07:15 08:00 0.75 2,418 2,400 COMPZ RPEQPI CIRC P PUH to 2400', Pump HI Vis Sweep at 6 BPM,786 PSI 08:00 09:00 1.00 2,400 0 COMPZ RPEQPITRIP P TOOH 09:00 09:20 0.34 0 0 COMPZ RPEQPI PULD P OOH, Lay Down Junk Run 09:20 10:29 1.15 0 0 COMPZ RPEQPI SFTY P PJSM w/ Crew and BOT,Clean Rig Floor Of Excess Tools, Swap BHA over to RBP Retrieval Head 10:29 11:14 0.76 0 2,400 COMPZ RPEQPITRIP P TIH w/ RBP Retrieval Head to 2400'.0 Page 14 of 16 Time Logs Date From To Dur - S. De th E. De th Phase Code Subcode T Comment 11:14 11:35 0.35 2,400 2,400 COMPZ RPEQPICIRC P Reverse Circ in 85bbls 11.1 PPG Brine 11:35 11:44 0.15 2,400 2,419 COMPZ RPEQPI FISH P TIH to Latch RBP @ 2416' while pumping 2 bpm @ 70 psi, Set down @ 2419' with 400 psi increase in circ psi, shut down pumps and slack off 10k on weight 11:44 11:59 0.25 2,419 2,419 COMPZ RPEQPI FISH P PU 12k over, pull release RBP, wait for RBP to relax 11:59 12:39 0.67 2,419 2,419 COMPZ RPEQPI FISH P TIH 15' free movement, PUH 25' blow down top drive and kell 12:39 13:58 1.33 2,419 0 COMPZ RPEQPITRIP P TOOH and lay down IBP 13:58 14:58 1.00 0 0 COMPZ RPEQPI OTHR P Wash out BOP stack at 8 bpm at 60 p si with swizzle stick. 14:58 1.7:28 2.50 0 330 COMPZ RPEQPI PULD P PU and MU BHA # 26 consisting of 3 1/2" EUE 8rd mule shoe jt, XO, 7" CSG Scraper, XO, LBS, String Magnet, Pump out sub, 9- 4.75" OD DC's. 17:28 18:28 1.00 330 6,766 COMPZ RPEQPITRIP P RIH down to top of PBR @ 6756'md. Rotated 1/4 turn, able to slide into PBR to 6766' md. Pick up 2' and Reverse Circulate High -Vis Sweep @ 8 bpm, 1600 psi 18:28 19:58 1.50 6,766 6,750 COMPZ RPEQPI OTHR P Weight Up Mud From 10.8 ppg to 11.1 ppg and Circulate around @ 6 b m, 1000 psi. 19:58 23:58 4.00 6,750 3,270 COMPZ RPEQPITRIP P Blow Down Top Drive. PJSM. POOH f/6750' md, Laying Down Drill Pipe. 10/11/2010 Ran 3 1/2" Packer Assembly & Tubing Completion. Landed Tubing Hanger. PT TBG to 3500 psi for 30 min & IA Annulus to 3500 psi for 30 mins. ND BOPE. 00:00 03:30 3.50 3,270 330 COMPZ RPEQPITRIP P Continue to POOH Laying Down Drill Pie From 3270' ft. 03:30 04:30 1.00 330 0 COMPZ RPEQPI PULD P OOH. Lay Down BHA. Clear Floor Of Baker Tools. 04:30 05:00 0.50 0 0 COMPZ RPEQPISFTY P PJSM. Clean Rig Floor. 05:00 06:00 1.00 0 0 COMPZ RPEQPI PULD P Start making Up TB Accemhly 06:00 06:15 0.25 0 120 COMPZ RPEQPISFTY P Crew Change,PJSM 06:15 11:45 5.50 120 6,732 COMPZ RPEQPI PULD P Continue to single in completion. 11:45 11:54 0.15 6,732 6,757 COMPZ RPEQPICIRC P 212 As 3.5" 9.3# L -80 in the hole,Locate and No -Go Bottom PBR, PUH 15'& Circ in Inhibited Seawater w/ CRW -132, 93k U - 73k Dwn. 11:54 12:03 0.15 6,757 6,742 COMPZ RPEQPICIRC P Located 10' in on A # 213, Place's No -Go @ 6757', 6767' On Btm of Seal Assembly, PUH 15', Reverse Circ in Seawater to Displace 11.1 PPG Brine 12:03 12:15 0.20 6,742 6,742 COMPZ RPEQPICIRC P Crew Change, PJSM, Begin Pumping Seawater Page 15 of 16 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:15 15:30 3.25 6,742 6,742 COMPZ RPEQPI CIRC P 11.1 Displaced, Pump Seawater w /CRW -132 Inhibitor down tubing with returns up annulus. Start Circulating Down Tubing @ 3 bpm, 200 psi with 240 bbls of Corrosion inhibited SW. 15:30 16:30 1.00 6,742 6,742 COMPZ RPEQPI OTHR P Drop Ball & Rod, Set Packer. L/D 2 Jt From Space Out. M/U & Land han er. Switch Over To Rig Power 16:30 17:00 0.50 6,742 0 COMPZ RPEQPIOTHR P RILDS 17:00 19:00 2.00 0 0 COMPZ RPEQPI PRTS P R/U & Test Tbg 3500 for 30 min. R/U & Test IA for 30 min. Bleed Down Tbg to zero. Pressure Up On IA to 1600 psi and Sheared SOV. 19:00 19:30 0.50 0 0 COMPZ RPEQPI PLUG P Set HP BPV. -7 - 10c— 7 19:30 22:30 3.00 0 0 COMPZ RPEQPI NUND P ND BOPE and Set back On Stump. 22:30 00:00 1.50 0 0 COMPZ RPEQPI NUND P NU 3 1/8" 5 M Tree. 10/12/2010 NU 3 1/8" 5k Tree & Tested. Pumped Freeze Protect Down IA and U -Tube over to Tubing. Set BPV, Dress Tree. 00:00 00:30 0.50 0 0 COMPZ RPEQPI NUND P Done making Up Tree. Rig Test Equipment. 00:30 03:30 3.00 0 0 COMPZ RPEQPI PRTS P PT Packoffs to 250/5000 psi. PT Tree to 250/5000 psi. Both Passed. 03:30 04:00 0.50 0 0 COMPZ RPEQPI OTHR P Pull BPV. Spot Little Red and Rig Up Pum in Equipment. 04:00 04:30 0.50 0 0 COMPZ RPEQPI SFTY P PJSM. 04:30 06:30 2.00 0 COMPZ RPEQPI FRZP P PT lines to 2500 psi. Pump 75 bbls diesel freeze protect down IA and up tubing @ 2 BPM w/ 700 psi ICP and 800 psi FCP. Allow well to U-tube.. 06:30 08:00 1.50 COMPZ RPEQPI NUND P R/D hoses. Set BPV, Dress tree. 08:00 09:00 1.00 COMPZ RPEQPI OTHR P Prep rig floor for rig move. Clean location. Release Nordic 3 rig @ 09:00hrs 10 -12 -2010. Page 16 of 16 • s WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 26, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: String Shot Record: 2T -15 Run Date: 10/ 1 /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 2T -15 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20062 -00 at AMM NOV 16 201D PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. / Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907 -27:3 5 _ 3 , , klinton.wo : l bd to 16k OCT 2- 8 Z010 Date: Signed: �-- '' 4 . 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: Down Hole Video: 2T -15 Run Date: 10/6/2010 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 2T -15 Digital Video File (AVI) 1 DVD Rom 50- 103 - 20062 -00 NOV 1 2410 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. `� Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: Signed: • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 1, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: 2T -15 Run Date: 9/30/2010 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 2T -15 Data in LAS format, Digital Log Image files 1 CD Rom 50 -103- 20062 -00 Cement Bond Log 1 Color Log 50 -103- 20062 -00 5 2U1D PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood UP 6900 Arctic Blvd. \ �� Anchorage, Alaska 99518 l DO Office: 907 - 273 -3527 O Fax: 907 - 273 -3535 klinton wpod@haRi - b zrton�oom_ m Date: �e `�� Signed: • • J. Brett Packer r { °; ~ ~ l Wells Engineer r ~ ~~ ~~~ ~,, , ConocoPhillips Alaska, Inc. ~( °' P.O. Box 100360 ~, U Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T-15 Sundry Number: 310-283 Dear Mr. Packer: 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, Daniel T. Seamount, Jr. O Chair DATED this ~`jd~a-y of September, 2010. Encl. U • . ~~ s r~~~~ ~~~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 2, 2010 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7`h Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2T-15 (PTD 186-045). 2T-15 was originally completed in April of 1986 as a selective single injector. This well is currently shut-in awaiting a workover to replace the corkscrewed tubing and proactively repair the 7" production casing. This well is located in an area with surface subsidence due to permafrost thawing and has subsided approximately 52" between Nov. '95 and Feb. '09. Indications of corkscrewed tubing were noticed in Dec. `08 when slickline tools could not pass 335' WLM. Eventually a 1.75" knuckled toolstring was able to get to 2200' WLM but was unable to fall any further- It is unknown exactly when the tubing may have become undriftable, since the last time a drift run was made prior to Dec_ `08 was in the year 2000. Consequently, we are unable to drift the tubing to set any downhole plugs. The well passed an MIT-IA on 6/1/09, but previously failed an MIT-OA on 3/23/09 indicating competent tubing and production casing, but a leak in the surface casing. Interestingly enough, the OA fluid level could not be depressed below 330' MD, indicating the depth of the leak-the same depth where slickline tools repeatedly stacked out in the tubing. The purpose of this workover is to replace the corkscrewed tubing, cut & pull a portion of the 7" ,~ t~ casing, re-run new 7" casing, and circulate cement into the 9-5/8" x 7" annulus. The 7" casing work is not required to fix an existing problem, but it will be done while the rig is on the well as a proactive measure. New 3'/2" tubing will be run into the well to repair the corkscrewed tubing. , If you have any questions or require any further information, please contact me at 265-6845. Sincerely, ~.~ ,/y~~ J. Brett Packer Wells Engineer CPAI Drilling and Wells (~I "' ,,~ STATE OF ALASKA ' ~ ALAS~IL AND GAS CONSERVATION COMMISS~ p~,g ~~ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ~_~'~$ ~! ~k[~ ~ ~ 2t,1s 1. Type of Request: Abandon ~ Rug for Redrill (~' Perforate New Pool ~'~! Repair well >~~~~ 4 blNl~d'BIr~I{~!~ Suspend ~ Rug Perforations ~ Perforate Pull Tubing ~ • . ;;~,i Tir~(~s,3Extension Operational Shutdown ~` Re-enter Susp. Well ~,' Stimulate ~' Atter casing ~ Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory ~ 186-045 3. Address: Stratigraphic ~ Service 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20062-00 7. If pertorating, 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 ~ No ~, 2T-15 9. Property Designation: 10. Field/Pool(s): ADL 25569 Kuparuk River Field /Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7625 ~ 6149 ~ 7469' 6023' Casing Length Size MD TVD Burst Collapse CONDUCTOR 100 16 100' 100' SURFACE 3229 9.625 3229' 2810' PRODUCTION 7117 7 7117' 5741' LINER 696 5 7625' 6149' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7197'-7236', 7313'-7342' 5805'-5836', 5899'-5922' 3.5 / 2.375 J-55 / N-80 6847 / 7273 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER -BAKER 'FHL' PACKER MD= 6768 TVD= 5476 PACKER -BAKER 'DB' PACKER W/ 5' SEAL BORE EXT. MD= 7250 TVD= 5847 - CAMCO TRDP-1A-SSA MD= 1765 TVD= 1705 12. Attachments: Description Sumitiary of Proposal 13. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch [-j E~loratory Development Service . 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 9/19/2010 pil ~ Gas ~ WDSPL ~ Suspended 16. Verbal Approval: Date: WINJ GINJ ~ WAG [~' Abandoned Commission Representative: GSTOR SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: J. Brett Packer @ 265-6845 Printed Name J. Br aCk r e Title: WeIIs Engineer s ~ ~A ~ "~i~~ i~~ ~"~ D t ~~~ /~J Signature Phone: 265-6845 a e Sundry Number: 3, O + ~f~J Conditions of approval: Notify Commission so that a representative may witness Plug Integrity BOP Test Mechanical Integrity Test ~~Location Cl earance ~' r: * ~ QDU ,O S c. ~j~ P ~ f - Oth e 'Jf" 25~ p S~ ~ n n c~ ~ s f- ~~'~`'"`' Subsequent Form Required: ~ ~y APPROVED BY ~ r r'1 / (~ Approved by' COMMISSIONER THE COMMISSION Date: Form 10-403 ~ EP O 9 1010 ~ { ~ cj, p.~U Submit in D'up cat ~r" a~~Gi~ L ,~ ~~o # • 2T-15 Expense Rig Workover (PTD #: 186-045) Current Status The well is currently shut in awaiting a Workover to replace the corkscrewed tubing and proactively repair the 7" production casing. This well is located in an area with surface subsidence due to permafrost thawing. This well has subsided approximately 52" between Nov. '95 and Feb. '09. Indications of corkscrewed tubing were noticed in Dec. '08 when slickline tools could not pass 335' WLM. Eventually a 1.75" knuckled toolstring was able to get to 2200' WLM but was unable to fall any further. It is unknown exactly when the tubing may have become undriftable, since the last time a drift run was made prior to Dec. `08 was in the year 2000. Consequently, we are unable to drift the tubing to set any downhole plugs. The well passed an MIT-IA on 6/1/09, but previously failed an MIT-OA on 3/23/09 indicating competent tubing and production casing but a leak in the surface casing. Interestingly enough, the OA fluid level could not be depressed below 330' MD, indicating the depth of the leak-the same depth where slickline tools repeatedly stacked out in the tubing. Scone of Work Replace the corkscrewed tubing, proactively cut & pull a portion of the 7" casing, re-run new 7" casing, / cement the 9 6/" x 7" annulus, and install new 3'/2" tubing. General Well info MASP: 1,750 psi (Based upon the SITP on 5/20/09 after 32 days SI, and depressuring ever since.) Reservoir pressure/TVD: Will be determined prior to RWO. Wellhead type/pressure rating: Cameron Gen IV, 11" 3K btm x 7-1/16" 5K top flange BOP configuration: Annular /Pipe Rams /Blind Rams /Mud Cross /Pipe Rams MITIA and MITOA results: MITIA-passed on 5/20/09, MITOA-failed on 3/23/09 Well Type: Injector Estimated Start Date: September 19, 2010 Production Engineer: Mike Balog /Evan Reilly Workover Engineer: Brett Packer (265-6845 / j.brett.packer@conocophillips.com) Pre-Rig Work Request 1. Load well w/ seawater. Wait 1 hour to stabilize & measure SITP to determine SBHP. 2. PT tubing and casing packoffs, FT LDS's. 3. Set BPV. Proposed Procedure 1. MIRU Nordic 3. Pull BPV. Bullhead KWF down the tubing to the formation. Verify well is dead. Set BPV. ND tree. NU 11" 5K BOP. Pressure test BOP including annular to 250/3000 psi. .~- 2. Pull blanking plug and BPV. Pull tubing in tension, set in slips and close the annular around the landing joint. 3. RU slickline: set a WRP in the tubing below the upper packer. Pull the DV from the GLM at 6,714' MD. - I-f Na r Poss: Go,~F,wJt.+~y 7 4. Circulate KWF around. 5. Attempt to pull the tubing from the PBR. If the tubing does not pull free, RU E-line and RIH w/ RCT and cut the tubing mid-joint above PBR. RDMO E-line. 6. POOH laying down tubing and spooling up control line. 7. Run 7" scraper assembly to top of tubing stub. Circulate well clean. ~~Proposed Procedure Continued 8. RU E-Line. Run caliper log, gyro survey, and cement bond log in 7" casing from tubing stub to surface. Based on cement top, determine depth of 7" collar to back off following casing cut. RIH and fire string shot across that collar. RD E-Line. 9. Set retrievable bridge plug below top of cement. Pressure test to 2500 psi and drawdown test to 0 ` psi. Dump sand on top of RBP. POOH standing back workstring. 10. ND BOP stack. ND tubing head using Hydratight Tensioners to safely allow 7" casing to grow. Spear . 7" csg and pull in tension and re-land in slips. RU Wachs cutter and cut 7" casing growth. Tack weld slips to casing. 11. NU 11" 5M BOP on casing head. (Cannot test break due to leak in the surface casing, BOP stack will o!~- be considered a diverter, there are 3 barriers in the well at this point.) 12. Cut 7" casing with mechanical cutter above TOC. Circulate Arctic Pack from the 9-5/8" x 7" annulus with w/heated diesel followed by heated seawater. 13. Spear 7" casing and POOH sideways. - 14. Run 9-5/8" casing scraper to top of 7" stub. Circ clean. 15. RU E-Line. Run caliper log and gyro survey in 9-5/8" casing. RD E-Line. 16. Run back off tool and back off casing stub. 17. Run tandem string mills to gauge the 9 5/" csg for the ES cementer. 18. Spear and recover backed off 7" casing stub. 19. RIH with new 7" casing and Halliburton ES cementer. Screw into top of 7" casing. Pressure test casing. 20. Open ES cementer and pump cement into 9-5/8" x 7" annulus to surface. Close cementer. • 21. WOC. ND BOP, pull 7" casing in tension and land in slips. Cut 7" casing and install packoff. NU new tubing head. 22. NU 11" 5M BOP and test break to 3000 psi. ~./ ~L ~ ^~"Yr• 23. Drill out cement. Pressure test casing to 3500 psi. Continue down until tag up on top of sand, dry drill to break up debris, Circulate well clean. 24. RIH with wash shoe, boot baskets, magnets, etc. and circulate out sand on top of RBP. POOH. ' 25. RIH w/ RBP retrieving tool on work string. Release RBP and POOH laying down drillpipe. 26. RIH with seal assembly on 3-1/2" drill pipe. Locate PBR, space out, circulate corrosion inhibited fluid and land the hanger. RILDS. 27. Pressure test tubing to 2500 psi, PT IA to 3500 psi. Shear SOV. • 28. Set 2-way check. ND BOP. NU tree and pressure test. ' 29. Pull 2-way check. Freeze protect well. Set BPV. RDMO Nordic 3. Post-Rig Work request: 1. Pull SOV and run DV. Pull WRP. 2. Return well to injection. _ __ ~(')('~~~(~~']~$~(~~ i ~) WeII Attributes _ , M_ax l , Welllwre APl/UWI Feld Nmne (Well Sta[us Inc! (°) "'' - '" / 501032006200 KUPARUK RIVER UNIT INJ 44.20 • ~ C ent M25 (ppm) (Date A otation Entl Date '" _.___ SSSV: TRDP 0 7/1/2008 Last WO: ~, W@Il Gonfig -2T-,?5 822/2UU93:5aa Fbt - ~ ',,Annotation -- - _ Scheina[c Ac1ua1 ~A t Lion (Depth (ftKB) ',End Date I t Taa~ SI M ~~ 2 200 0 12/7/200fl ~. Rev Reason add TTL comments coNDUCroR, 1a6 SURFACE, 3,229 GAS LIFT. - _ __. __ 6,T1a PBR, fi,]54 ---- PACKER, 6,T68- - --- I INJECTION, _. 6,806 NIPPLE, 6.8aa--. SLEEVE. 6,Eaa - =--'---- PRODUCTION, _ _ __, - ],117 IPERF, _...-- ],197-],236 PACKER, 7,250 -- ---- NIPPLE, ],26a --- SOS, 7.272 TTL. 7.273 2T-15 Mod By End Date ehelton 5/20/: PRODUC (ION 7 6-151 OOIi 7,11701 57407 2600 J55 Liner 1 51 4.151 6 929 0' 7,625 Oi 6,149 2 18.00 L~O ~ _ Tubing Strings String OD ~ String ID I _ Set Depth ~ Set Depth (ND) ~ String Wt ~ String Tubing Description (in) (in) ~ Top (ftKBJ1 (ftKB) (ftKB) 1 (IbsHt) '~. Grade - String TOp Thrd --- TUBING 3 1/2 2 9921 0 0 6,547 0 5$35 3 9.30 J 55 EUE8rdABMOD TUBING 2 3/8 1 9951 1 I 6,847 0 7 273 O. 5 865 9 4.70JN 80 _ - - ~ 8RD EUE -: __ Other 1n Hole. ( TOp Depth ~~ All Jewelry. Tubin g_Run $ Retrievabl_e,_Ftsh~etc1 - --~- -- ' (ND) Top Inc! Top (ftKBJj (ryK6) (°) Description .Comment - Run Date ID (in) 1,7651 1,704.7 34.37 Safety Valve Camco TRDP-1ASSA 10 /9/1986 ~~ 2.812 6,714 5,436.5 42.51 GAS LIFT OTISI'LBX'/11DMYIRO-5///Comment: STA 1 10 /2517986 ~ 2.907 6,754 - 5 466.1 PBR 42 33 Baker PBR - -- _ - - --- 10 /9/1986 3.000 6,768 5 476.4 PACKER 42 27 Baker'FHL' PACKER 10 /9/1986 2.750 6,806 5,505.5 INJECTION 42.72 CAMCO/KBUG/1lDMYlBK2/// Comment: CLOSED STA 2 12 /30/1997 2.875 6,844 5,533.21 42.26 NIPPLE _ iAVA BPL PORTED NIPPLE - 10 /9!1986 2.750 6,844 5,533.21 42.26 SLEEVE _. __ _.. AVA BPI SLEEVE ~ Si7 /2000 2-310 7,250 5847.2 3572 PACKER Baker'DB'PACKER wl 5'Seal Bore Ezt. 10 19/1986 3-500 7,264 5,858 6 35.79 NIPPLE Camco'D' Nipple NO GO 10 /911986 1.812 7,272 5,865.1 35.84 SOS Camco 10 /9/1986 1.995 7,273 5 865.9 35.85 TTL ELMD TTL @ 7274'tluring HRS SPINS on 04/25/90 10 /9/1986 i 1.995 Btm 1217/2008. (NOTE: Possible collapsed [II @ 3' intervals, IPERF, , ].313-T,3a2 Liner, ],825,. TD, 7,625 -- -- - - MEMORANDUM To: Jim Regg `~ P.I. Supervisor ~~~( ~(>'b(~ FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-15 KUPARUK RIV UNIT 2T-15 Src: Inspector NON-CONFIDENTIAL Reviewed By; P.I. SuprvJ~l~- Comm Well Name: KUPARUK RIV UNIT 2T-15 API Well Number: 50-103-20062-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ090608124129 Permit Number: 186-045-0 ~ Inspection Date: 6/1/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Weld ~2T-15 TYPe Inj. T~ I TVD 5476- IA 440 2420 '~ 2280 2260 ~ - P.T.D 1860450 T),peTeSt I SPT Test psi 1500 QA ]30 ~ 130 130 130 - Interval axxrsT p~F, P ~ Tubing 1700 1700 1675 1676 Notes: 2.8 BBLS diesel pumped, 1 well inspected; no exceptions noted. Wednesday, June 10, 2009 Page 1 of 1 RE: KRU DS2T Suspected Sure Casing Leaks • Page 1 of 2 Regg, James B (DOA) (~2-l~l Z'T'- I5" From: Regg, James B (DOA) I ` I ~~' ~~ Sent: Friday, April 03, 2009 3:47 PM '~~~ ~ 4 (3~~ To: 'NSK Problem Well Supv' Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: RE: KRU DS2T Suspected Surface Casing Leaks This is what we agreed to in phone conversation 3/31/2009. CPAI may continue to inject water only in the listed KRU 2T wells. Please add these 7 wells to the monthly infector integrity report. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 Z]P>;,Y~~~s+ IWwti /-i F 1'~. 1. G~,. L,. t) it .mod From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, April 03, 2009 2:47 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; NSK Problem Well Supv; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: RE: KRU DS2T Suspected Surface Casing Leaks On 04/02/09, the last of a series of diagnostic tests on 7 injectors on Drillsite 2T (2T-02, 2T-04, 2T-09, 2T-10, 2T- 11, 2T-15, and 2T-16) to confirm the existence of 2 barriers was completed. The tests consisted of MITIA's and pose I~'~ve and negative tubing and inner casing pack off tests. All of the tests, without exception, passed and therefore we are continuing to inject water only and have designated each well as being incapable of conversion to miscible injectant (MI). CPAI plans to continue water only injection and begin drafting applications for administrative approval to continue water only injection with a known surface casing leak (OAxForm . Please reply with your concurrence on the proposed plan of action. Martin From: NSK Problem Well Supv Sent: Tuesday, March 31, 2009 6:56 PM To: 'jim.regg@alaska.gov' Cc: 'tom maunder@alaska.gov'; NSK Problem Well Supv; NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: KRU DS2T Suspected Surface Casing Leaks Jim, Recently CPAI conducted MITOA's on 12 wells on Drillsite 2T as a part of a program investigating subsidence. Of 4/3/2009 RE: KRU DS2T Suspected Sur f Casing Leaks • Page 2 of 2 the 12 wells tested, there were 11 failures, 7 of which are injectors. The second phase of our diagnostics included injecting gas down the OA while using an Echometer to monitor the fluid level. The 7 injectors exhibited fluid levels which could not be depressed below 300' - 348'. We suspect that the reflection is possibly due a hole in surface casing or a mechanical obstruction and is consistent with data collected in the region. We began conducting MITIA's today (3/31/09) on all 11 wells and will follow up with tubing and inner casing packoff tests. Provided we can demonstrate the existence of 2 barriers, CPAI requests permission to continue water only injection in the subject wells (2T-02, 2T-04, 2T-09, 2T-10, 2T-11, 2T-15, and 2T-16) until administrative approval can be obtained within a reasonable amount of time. Attached are 90 day TIO plots and Wellbore schematics. « File: 2T-02 TIO Plot.pdf » « File: 2T-04 TIO Plot.pdf » « File: 2T-09 TIO Plot.pdf» « File: 2T-10 TIO Plot.pdf» « File: 2T-11 TIO Plot.pdf » « File: 2T-15 TIO Plot.pdf» « File: 2T-16 TIO Plot .pdf » « File: 2T-02 Wellbore Schematic.pdf » « File: 2T-04 Wellbore Schematic.pdf » « File: 2T-09 Wellbore Schematic.pdf » « File: 2T-10 Wellbore Schematic.pdf » « File: 2T-11 Wellbore Schematic.pdf » « File: 2T-15 Wellbore Schematic.pdf » « File: 2T-16 Wellbore Schematic.pdf » Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 4/3/2009 Well Name 2T-15 Notes: End Date 4/1/2009 Days 90 Start Date 1/1!2009 wHP Annular Communicaton Surveillance IAP ------- -- 140 3000 OAP ---- -- ---- - WHT 120 2500 -- 100 2000 80 LL a 1500 m 60 1000 40 500 - - - - -- --- --- - - - 20 0 0 Jan-09 Feb-09 Mar-09 Apr-09 2000 ,' DGI _ -- -- -_ - ___ 1800 ~~MGI ~PWI 1600 0 14 ~SWI 00 2 m ~BLPD 1 00 1000 ~ a 0 80 ~ - 600 4 00 2 0 - 0 0 • • 3 G~ -4 ConocoPhillips AI.itiK~1. r 1.: SeteN valor, 1.]85 SURFACE, 3.229 GAS LIFT. 6.]14 PBR. 8.754 I PACKER. B.76B I 1 INJECTION. 8 806 NIPPLE. B 644 SLEEVE. 8.844 PRODUCTION. 7,11] IPERF, ].18]-],236 ].250 NIPPLE 7264 508. 7,272 TTL, 7,273 IPERF, ].313-7,342 Liner. ] 625 TD. ] 625 KUP ~ 2T-15 Wellbore API/UWI Field Name Well Statue Prod/Inj Type Inel p) MD (ftKB) Aet Blm (NKB) 507032006200 KU_P_ARUK RIVER UNIT INJ PWI 44.20 5.200.00 7,625.0 Comment N2S (ppm) Date Annotation End Data KB-Grd m7 Rig Release Dats SSSV: TRDP 0 7/1/2008 Last WO: 41.80 4!22/7986 Annotation Depth (NKB) End Date Annotation End Date Last TaO: SLM 2.200.0 12/7/2008 Rev Reason: Collapsed TBG Ca) 336' SLM, TaD Schmoo (a) 2200' 12/12/2008 Top Inc! Run Date ID MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 'kat? 6{7 (0 ì DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-15 KUPARUK RIV UNIT 2T-15 (.)0-..5 \Cl:, FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv -:1ß,l-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2T-15 API Well Number: 50-103-20062-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070603144I18 Permit Number: 186-045-0 Inspection Date: 6/2/2007 ,/ Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-15 Type Inj. w TVD 5476 IA 1200 2520 2460 2460 P.T.D 1860450 TypeTest SPT Test psi 1500 OA 240 240 240 240 Interval 4YRTST P/F P ,/ Tubing 2210 2210 2210 2210 Notes: Pretest pressures observed and found stable. Well demonstrated good mechanical integrity. ../' sCANNED j1JN' 2 0 2007 Wednesday, June 06,2007 Page I ofl ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 'R "'fé¡ q(e>!o",- DATE: Wednesday, August 17,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA fNC 2T-15 KUPARUK RIV UNIT 2T-15 ¡..,0( -S k;'U \~ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~'ìL- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2T-15 Insp Num: mitCS050812190453 Rei Insp Num: API Well Number: 50-103-20062-00-00 Permit Number: 186-045-0 Inspector Name: Chuck Scheve Inspection Date: 8/12/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -:';~l ¡·I::~~~~::;~S~~:~ p.;¡ --r ·::-:·+6fF-\~oO -r~I:: -+-'1:: .~. 21~:=r~~+-_· --_...-~-.. __.L._...._...1.._........ --..-----'... --. ..__...1...__ -.+------.... ·_.._·I·_...._·_-¡..·..._._.._.__.-J_..·._....~...._.... -'-r'-"- '-' - Interval 4YRTST P/F p Tubing! 2000 I 2000 2000 I 2000 I --.. -_..______......_......_.........___ ._ .___..._._.._--'-......_._......_---'-........___..1....-....... ___...,._...____....1. __.._.....L. __,,___._, Notes: Pretest pressures observed for 30+ minutes and found stable. ,c~'" ¡ì\;:\..~¡f::fJ ('-¡"D ~?~ 0 2.005 ì.)~?¡rt~\;~'.Jt""i.- ,,-L~:i Wednesday, August 17,2005 Page I of I MEMORANDUM TO: Julie Heusser Commissioner THRU' Tom Maunder P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL DATE: June 24, 2001 SUBJECT: Mechanical Integrity Tests Phillips 2T Pad (~I°L~"~/Oi 2T-02, 05, 11, 15, 16 KRU Kuparuk Packer Depth Pretest Initial 15 Min. 30 Min. WellI 2T-02 J Typelnj.I G I T.V.D. I 5753 I Tubing J 3800 J 3800 I 3800 J 3800 J l'ntervalI 4 P.T.D.I 1861410 Imypetestl P ImestpsiI 1438 I Casingl 1950 I 2525 I 25251 2525 I P/F I P Notes: WellI 2T-05 I Typelnj. I S I T.V.D. I 5682 I Tubing I 2200 I 2200 I 2200 I 2200 ]IntervalI 4 P.T.D.I 1881440 ITypetestl P ITestpsil 1421 I Casing] 1400I 2375 I 23751 2375 I' P/F I P Notes: I 2T-~ I~I T.v.o.l~o I TubingJ ~200 l~200 I~00 l~200 ],n~.,J 4 P.T.D.I 1860970 ITypetestl P ITestpsil 1330 ICasingI 1600 I 2190 I 2190 I 2190 I P/F I P Notes: WellI 2T-15 J'Typelnj.IG I T.V.D. I 5476 ]Tubing I 3650 J 3650 J3650 I 3650 I Interval] 4 P.T.D.I 1860450 ITypetestl P ITestpsil 1369 I Casing] 750 I 23251 2325] 2325J P/F, I -P,, Notes: we,,I 2T-~ I Type,nj.I S I T.V.D. I8494 I Tubing12400 12400 12400 ]2400 I,.te~a,I 4 P.T.D.I 1860460 Imypetestl P I mestpsil 1374 I CasingI 1300I 2490I 2450I 2450I P/F I ~ Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to 2T Pad in the Kuparuk river field and witnessed the 4 Year MIT on wells 2T-02, 2T-05, 2T-11, 2T-15 and 2T-16. The pretest pressures were observed and found to be stable. A standard annulus pressure test was then performed with all 5 wells demonstrating good mechanical integrity. M.I.T.'s performed: Attachments: Number of Failures: 0 Total l-ime during tests: 4 hours cc: MIT report form 5/12/00 L.G. MIT KRU 2T Pad 6-24-01 CS.xls 6/25/01 MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL .UNDER THIS PAGE DEPT. OF NATURAL RESOURCES DIVISION OF OIL AND GAS April 12, 1991 D. W. Johnston, AOGCC Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Subject: Release of ARCO Kuparuk River Unit 2T Well Data WALTER d. HICKEL, GOVERNOR P.O. BOX 107034 ANCHORAGE, ALASKA 99510-7034 PHONE: (907) 762-2553 ; _. '.'.~ ;'.,:~,. , ' . -.'. ...... ._ --'-"5":( Dear Commissioner Johnston: On August 5, 1988 1 granted extended confidentiality for the Kupanflc River Unit 2T wells. The Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 12A, 13, 14, 15, 16, and 17 wells were granted extended confidentiality until 90 days after the unleased land in Ti 1N R7E Umiat Meridian could be offered for lease. The unleased land in this township was offered for lease in Sale 70A which was held on January 29, 1990. Therefore, the wells no longer qualify for extended confidentiality and the well data should be released on April 30, 1991. By copy of this letter I am notifying ARCO Alaska Inc. of the upcoming release of the above listed wells. Sincerely, ~5:~.mes E. Eason 'Dn-ector cc: J. L. Dees, ARCO Alaska Inc. RECEIVED APR 1 6 199t Alaska 0ii .& Gas Cons. Commission Anchoraga /r~, STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Operation: Operation Shutdown __ Stimulate B Plugging Perforate _ Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc .... 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 27' FSL, 556' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 1485' FSL, 995' FWL, Sec. 12, T11N, R8E, UM At effective depth 1325' FSL, 978' FWL, Sec. 12, T11N, R8E, UM At total depth 1233' FSL, 965' FWL, Sec. 12, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 117 7. Unit or Property name Kuparuk River Unit 8. Well number 2T-15 9. Permit number/approval number 86-45 / 7-146 10. APl number 50-103-20062 11. Field/Pool Kuparuk River Oil Pool feet 7 6 2 5' feet Plugs (measured) 6148' feet Cement: 7469'-7625' Effective depth: measured 7 4 6 9' feet Junk (measured) true vertical 6023' feet None Casing Length Size Cemented Measured depth Structural Conductor 8 0' 1 6" 225 Sx CS II 1 0 0' 1 0 0' Surface 31 9 6' 9 5/8" 970 Sx AS III & 3229' 280 9' Intermediate 335 Sx Class G Production 7083' 7" 200 Sx Class G & 175 Sx AS I 71 1 6' 5740' Liner 6 9 6' 5" 90 Sx Class G 7 6 2 5' 61 4 8' Perforation depth: measured 7196'-7236' 12 SPF, 60 degree phasing 7313'-7342' 4 SPF, 60 degree phasing true vertical 5804'-5835', 5898'-5921' Tubing (size, grade, and measured depth) 3 1/2" J-55 set at 6754', 2 3/8" N-80 set from 6754'to 7280' Packers and SSSV (type and measured depth) FHL Pkr @ 6768', DB Pkr @ 7250', Camco TRDP-1A-SSA @ 1765' True vertical depth 13. Stimulation or cement squeeze summary ~,~.~.,~.'/3~',,' Convert well from A & C Sand production service to A & C Sand injection service..,,~.:.~ Intervals treated (measured) co. Treatment description including volumes used and final pressure ~~~" 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 822 1058 0 - 975 300 Subsequent to operation - 0 - - 0 - 4900 1575 21 20 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector __X._ Oil B Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si,ned ~~(~ '"'~. ~ Title ~'~'~ 0(~.,~~-.~ Form 10-404 Rev 09/12/90 Date ( '-~ -~1 SUBMIT IN DUPLICATE STEVE COWPER, DEPART~IENT OF NATURAL RESOURCES P.O. BOX 7034 DIVISION OF OIL AND GAS August 5, 1988 Jon Wood, Area Landman ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Wood: In your July 8 letter and in our August 3 meeting, you requested extended confidentiality for the data from the Kuparuk River Unit "drillsite 2T" wells. You indicated that reports and information from these wells contain significant information relating to the valuation of unleased land in Township ll North, Range 7 East, U.M. This unleased land is currently scheduled to be offered for lease in Sale 70A in September 1989. Following your written request, the August 3 meeting and further review of the well data by my staff, I agree to extend the confidentiality of the data from the ARCO Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, lO, ll, 12, 12A, 13, 14, 15, 16 and 17 wells. The data from these wells will be released after the aforementioned land is offered for lease. In your letter and supporting data, you requested confidentiality for data from a "2T-16A" well. The Alaska Oil and Gas Conservation Commission (AOGCC) has advised the division that they have no record of a "2T-16A" well. The 2T-16 well was side-tracked but no new number was assigned to the well. Therefore, all of the data from the well are filed under 2T-16 at AOGCC. The first 2T well scheduled to be released is the 2T-12 Well (August 6, 1988) and the last 2T well release date is the 2T-8 Well (January 15, 1989). The division is making a special exception to our policy of considering extended confidentiality no sooner than 90 days prior to a release date because it is prudent to, in this case, grant the extension of confidentiality for the 2T wells as a group. By copy of this letter I am requesting that AOGCC keep confidential the data from all of the Kuparuk River Unit 2T wells until further notice. Sincerely, ames E Eason i recto~ . cc: C.V. Chatterton, Commissioner, AOGCC Judith M. Brady, Commissioner, DNR ARCO Alaska, Inc Post Office .,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 2, 1988 Mr. C. V. Chatterton Alaska Oil and Gas Con~nission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Subject: Kuparuk River Field Water Injection Surveys In compliance with Rule 4 Conservation Order Number 198, Kuparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk water injection wells for the first quarter of 1988. The data is provided in the form of separate zone surveys as or spinner logs listed in Attachment I. The spinner logs will be sent separately. Injection rates determined by separate zone surveys are also listed in Attachment I. If you have any questions concerning the information reported, please contact me at (907) 263-4978. Sincerely, ~4. H. Kraly Operations Engineer MHK/SPT:pg:0163 Attachments ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfleldCompany · · r 3_/-?g / ATTACHMENT 1 PAGE 2 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE 4 - INJECTIVITY pROFILES SECOND QUARTER 1987 SUBMITTAL WELL APl DATE OF NUMBER NUMBER INITIAL 50-029 INJECTION __ 2B-11 21089 11/19/85 2H-01 20033 03/15/86 2H-04 20027 03/15/86 50-103 2T-04 20074 03/30/87 2T-09 20071 03/30/87 2T-11 20075 03/30/87 2T-15 20062 03/30/87 2T-16 20063 03/30/87 50-029 3A-02 21431 01/21/87 3A-O4 211133 01/21/87 3A-10 21457 01/21/87 ~ 21458 01/21/87 DATE OF PROFILE/ SURVEY -- 06/16/87 06/05/87 06/07/87 06/13/87 06/16/87 06/21/87 06/16/87 06/16/87 DATA TYPE REASON FOR WELL PROFILE/ PROFILE/ COMPLETION SURVEY SURVEY SPINNER FOLLOWUP A&C S SPINNER FOLLOWUP A&C S SPINNER FOLLOWUP A&C S SPINNER INITIAL A&C SS SURVEY INITIAL A S SPINNER INITIAL A&C SS SURVEY INITIAL A&C SS SURVEY INITIAL A&C SS SPINNER INITIAL A&C SS SURVEY INITIAL A&C SS SURVEY INITIAL A S INITIAL A&C SS SURVEY INITIAL A S 05/25/87 05/87 05/87 05/27/87 C 3A-14 21490 0t;/14/87 o5/8~L,~ fy-? ZONES TAKING WATER A&C A&C A&C A&C A A&C A A A&C A A A&C A I NJ ECT I ON BWPD RECEIVED 3485 1833 590 Alasl~ 0ii & Gas Cons. Commission Anchorage 25OO 1200 1650 Gas Co~s. Oommiss~o~ ¢,/I ATTACItMENT PAGE WELL NUMBER '"",~ 2B. 11~' "",~2.-o 1~' ~.21t-Oq ,..-/ '"'xJ 2T_Oq J 2T-O0 21-15 21-16 ~x,J 3A-02 ~ 3A-Oq 3A-10 3A-lq KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE 4 - INJECTIVlTY PROFILES SECOND QUARTER 1987 SUBMITTAL APl DATE OF DATE OF DATA TYPE REASON FOR WELL NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION 50-029 INJECTION SURVEY SURVEY SURVEY 21089 11/19/85 06/16/87 SPINNER FOLLOWUP A&C S 20033 03/15/86 06/05/87 SPINNER FOLLOWUP A&C S 20027 03/15/86 06/07/87 SPINNER FOLLOWUP A&C S 50-103 20074 03/30/87 06/13/87 SPINNER INITIAL A&C SS 20071 03/30/87 06/16/87 SURVEY INITIAL A S 20075 03/30/87 06/21/87 SPINNER INITIAL A&C SS 20062 03/30/87 O6/16/87 SURVEY INITIAL A&C SS 20063 03/30/87 O6/16/87 SURVEY INITIAL A&C SS 50-029 21h31 01/21/87 05/25/87 SPINNER INITIAL A&C SS 21433 01/21/87 05/87 SURVEY INITIAL A&C SS 21h57 O1/21/87 05/87 SURVEY INITIAL A S 21458 01/21/87 05/27/87 SPINNER INITIAL A&C SS 21490 04/14/87 05/87 SURVEY INITIAL A S ZONES TAKING WATER A&C A&C A&C A&C A A&C A A A&C A A A&C A INJECTION BWPD 3485 1833 590 2500 1200 1650 RECEIVED Alaska Oil & 6as Cons. 6omraissiorl Anchorage ARCO Alaska, Inc. '-~ Post Office b_.~, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: April 28, 1987 Transmittal #: 5961 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. ~3N-9 ~3N-8A ~2T-7 ~2T-4 ~'~T-15 "~2T-11 CEL 4-7-86 7500-9272 CEL .4-7-86 5100-9272 'CET/CEL 10-29-86 6200-6712 CET/CEL 10-4-86 7350-8160 CET/CEL 10-7-86 6900-7465 CET/CEL 10-11-86 5965-6620 Receipt ~cknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC State of Alaska (+'~epia)' BPAE Chevron ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 9, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear ~r. Chatterton: Attached in triplicate are intent notices 2T-16: Well Action 2T-15 Conversion 2T-16 Conversion If you have any questions, please call me at 265-6840. Sincerely, on Kuparuk Wells 2T-15 and Anticipated Start Date March 9, 1987 March 9, 1987 G. B. ~Smallwood Senior Operations Engineer GBS'pg'O076 Attachments cc- File KOE1.4-9 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALAS, . OIL AND GAS CONSERVATION COMI, ,,SION 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 [1 Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc RKB 117' feet 3. Address 6. Unit or Property name PO Box 100360, Anchorage, AK 99510 Kuparuk River Unit 4. Location of well at surface 7. Well number 27'FSL, 556'FWL, Sec.1, T11N, R8E, UN 2T-15 At top of productive interval 8. Permit number 1485' FSL, 995' FWL, Sec. 12, T11N, R8E, UM Permit #86-45 At effective depth 9. APl number 1325' FSL, 978' FWL, Sec. 12, T11N, R8E, UM 50-- 103-20062 At total depth 10. Pool 1233' FSL, 965' FWL, Sec. 12, T11N, R8E, UM Kuparuk River Oil Pool ~,~ ~,; .~ ~ :, CO F! 11. Present well condition summary ~~,~ Total depth: measured 7625' MD feet Plugs(measured) NOne ~ true vertical 6148' TVD feet ~!;~" Effective depth: measured 7469' MD feet Junk (measured) None ! ....... " true vertical 6023' TVD feet Casing Length Size Cemented Measured depth True Vertical depth XX~,~<~KX Conductor 80' 16" 225 SX CSII 100' MD 100' TVD Surface 3196' 9-5/8" 970 SX ASIII & 3229' MD 2809' TVD XXZr~m~r~4~Ye 335 SX Class G Production 7083' 7" 200 SX Class G 7116' MD 5740' TVD Liner & 175 SX ASI 69.6' 5" 90 SX Class G 6929'-7625' MD 5596'-6148' TVD Perforation depth: measureo 7197'-7236' MD 7313'-7342' MD true vertical 5804'-5835' TVD 5898'-5921' TVD Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail @ 7273' Packers and SSSV (type and measured depth) ~' ' "~ FHL Packer @ 6768', DB Packer @ 7250', TRDP-1A-SSA $$$V Ia 1765' 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch Convert well from production service to water injection service. 13. Estimated date for commencing operation March 9, 1987 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 /-'~ ~.-%,~ ,?;'~ /~,,,.~,,, ~¢:',/' ...,~..~,,~/ Title Sr. Operations Engineer Date (~ /L( /., ,.¢,. i "7 Signed ....... Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No ..... .; [] Plug integrity [] BOP Test [] Location clearancel -'/ .... / ~r !Vi'~::,~:: '~r.~::'~i: ~:~ !:';./?' i~, ~i'i'~. ,~-.: i.":':: .... <'] :'"'~;' :'Y' "V"// ,:-.' ," by order of Form 10-403 Rev 12-1-85 Submit in triplicate STATE OF ALASKA ALASKA uiL AND GAS CONSERVATION CL,.,,IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ax GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-45 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20062 4. Location of well at surface 9. Unit or Lease Name 27' FSL, 556' FWL, Sec. 1, T11N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1485' FSL, 995' FWL, Sec. 12, TllN, R8E, UM 2T-15 At Total Depth 11. Field and Pool 1233' FSL, 965' FWL, Sec. 12, T11N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool 117' RKBI ADL 25569 ALK 2667 , 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore 116. No. of Completions 04/11/86 04/20/86 11/23/86'I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7625'MD,6148'TVD 7469'MD,6023'TVD YES ~( NO [] 1765' feet MDI 1550' (Approx) 22. Type Electric or Other Logs Run D I L/SFL/SP/Cal/GR/FDC/CNL, CET/GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 100' 24" 225 sx CS II 9-5/8" 36.0# J-55 Surf 3229' 12-1/4" 970 sx AS Ill & 335 ~x ~]~ G 7" 26.0# J-55 Surf 7116' 8-1/2" 200 sx AS I & 175 sx AS I 5" 18.0# L-80 6929' 7625' 6-1/8" 90 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) 7197'-7236'MD w/12 spf, 60° phasing 3-1/2" 7273' 676F~'; 7?SO. 7313'-7342'MD w/ 4 spf, 90° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 5804'-5835'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5898'-5921'TVD See attached Addendum. dated 12/1~/R¢;_ fnr 27.N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILR~ATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE ~ 28. CORE DATA BriefNonedeScription of lithology, porosity, fractures, apparent dips and presence of oil, ga water. Submi"Ii 1° , *Note: Drilled RR 4/22/86° Tubing ~as run & ~ell perforated 10/09/86. DAM/WC1 ~167 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ; 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGic MAR :¢i .:- -~ .~ .' ;:' .' MEAS. DEPTH TRUE VERT. DEPTH 7195' ~7237' 7276' 7428' 5802' 5836' 5868' 5990' "FORMATION TESTS. Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Addendum (dated 12/13/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed t~ 0/~ ~-,~.~ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 11~23/86 2T-15 FRACTURE STIMULATION SUMMARY Frac'd Kuparuk "A" sand perfs 7313' & 7342' in 6 stages per 11/12/86 procedure using diesel/5% Musol spear, gelled diesel and 20/40 sand. Press'd ann to 2500 psi w/diesel. Tst lns to 7500 psi; OK. Stage #1 & #2: Pmp'd 26 bbls diesel, 5% Musol spear & displ'd w/6 bbls diesel @ 1.5 BPM, 2350 psi. Stage #3, 4 & 5: Pmp 15.5 bbls of pad, 15.5 bbls of 8 ppg 20/40 slurry and flush w/59 bbls of gelled diesel. Pmp'd 12.3 bbls 20/40 slurry in formation leaving 3.2 bbls. Load to recover 173 bbls of diesel. Job complete @ 1900 hrs, 11/23/86. Drilling Supervisor ~ D~te $ UB-$ URFA CE DIRECTIONAL SURVEY I~UIDANCE r~ONTINUOUS r~OOL Company ~¢o ALASKA, INC. Well Name 2T-15 (27'FSL, 556'FWL, Field/Location KUPARUK, NORTH SLOPE, SEC. 1, TllN, R8E, UM) ALASKA ii Job Reference No. 71760 Logged 8v: SARBER Date ,, 10/8/86 Computed By: flALSTEAD GCT DIRECTIONAL SURVEY CUSTDMER LISTING FOR' ARCO ALASKA, INC. 2T-15 KUPARUK NORTH SLOPEtALASKA SURVEY DATE: 08-0CT-86 ENGINEER: SARBER METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 6 DEG 38 MIN EAST ARCO ALASKA, INC. 27-15 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 21-0CT-86 PAGE I DATE OF SURVEY: 08-0CT-86 KELLY BUSHING ELEVATION: 117.00 FT ENGINEER: SARBER INTERPOLATED VALUES' FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -117.00 0 0 N 0 0 E 100.00 99.99 -17.01 0 27 S 66 42 E 200.00 199.99 82.99 0 29 S 68 22 E 300.00 299.99 182.99 0 34 N 78 12 E 400.00 399.98 282.98 0 26 N 37 33 E 500.00 499.98 382.98 0 22 N 57 21 E 600.00 599.97 482.97 0 42 S 81 51 E 700.00 699.97 582.97 0 38 N 59 20 E 800.00 799.95 682.95 2 13 S 43 36 E gO0.O0 899.73 782.73 5 21 S 23 54 E 0.00 0.00 0.00 N 0.00 E 0.29 0.32 0.20 S 0.79 E 0.70 0.21 0.52 S 1.52 E 0.76 0.44 0.49 S 2.43 E 0.40 0.15 0.03 S 3.14 E -0.06 1.23 0.48 N 3.57 E' 0.20 0.12 0.33 N 4.54 E 0.06 0.35 0.59 N 5.64 E 0.78 3.53 0.06 N 7.26 E 6.68 3.91 5.51 S 10.45 E S 15 30 E S 10 31E S 9 26 E S 8 11 E S 7 47 E S 7 42 E S 7 12 E S 6 57 E S 6 33 E S 6 12 E 1000.00 998.97 881.97 8 28 1100.00 1097.48 980.48 11 18 1200.00 1194.94 1077.94 14 18 1300.00 1290.92 1173.92 18 23 1400.00 1384.69 1267.69 22 17 1500.00 1475.91 1358.91 26 8 1600.00 1564.46 1447.46 29 4 1700.00 1650.50 1533.50 32 11 1800.00 1733.53 1616.53 35 33 1900.00 1812.88 1695.88 39 20 2000.00 1888.45 1771.45 42 16 2100.00 1961.83 1844.83 42 50 2200.00 2035.23 1918.23 42 40 2300.00 2108.83 1991.88 42 30 2400.00 2182.68 2065.68 42 22 2500.00 2256.72 2139.72 42 1 2600.00 2331.30 2214.30 41 38 2700.00 2406.23 2289.23 41 18 2800.00 2481.43 2364.43 41 8 2900.00 2556.94 2439.94 40 48 3000.00 2632.94 2515.94 40 13 3100.00 2709.53 2592.53 39 55 3200.00 2786.47 2669.47 39 30 3300.00 2863.78 2746.78 39 8 3400.00 2941.87 2824.87 38 10 3500.00 3020.86 2903.86 37 38 3600.00 3099.94 2982.94 37 48 3700.00 3179.00 3062.00 37 53 3800.00 3257.84 3140.84 37 51 3900.00 3336.93 3219.93 37 36 18.52 3.23 16.97 S 35.59 3.28 33.71 S 57.89 2.89 55.73 S 85.88 3.89 83.40 S 120.53 4.05 117.74 S 161.45 3.36 158,29 S 207.88 2.92 204.33 S 258.82 3.27 254.89 S 314.51 3.67 310.18 S 375.33 3.29 370.63 S S 5 31 E 440.79 S 5 30 E 508.72 S 5 27 E 576.61 S 5 33 E 644.25 S 5 43 E 711.72 S 5 45 E 778.93 S 5 16 E 845.52 S 5 17 E 911.73 S 5 33 E 977.63 S 5 45 E 1043.18 S 6 I E 1108.16 S 6 8 E 1172.45 S 6 17 E 1236.34 S 7 15 E 1299.76 S 9 8 E 1362.20 S 11 11 E 1423.40 S 12 16 E 1484.35 S 12 25 E 1545.27 S 12 15 E 1606.47 S 11 56 E 1667.39 0.00 N 0 0 f 0.81 S 75 47 E 1.61 S 71 1 E 2.48 S 78 41 f 3.14 S 89 22 E 3.60 N 82 22 E 4.55 N 85 53 E 5.67 N 84 0 E 7.26 N 89 33 E 11.82 S 62 11 E 14.42 E 22.27 S 40 21 E 18.19 E 38.31 S 28 20 E 21.99 E 59.91 S 21 32 E 26.27 E 87.44 S 17 28 E 30.98 E 121.75 S 14 44 E 36.58 E 162.46 S 13 0 E 42.57 E 208.72 S 11 46 f 48.85 E 259.52 S 10 50 E 55.40 E 315.09 S 10 7 E 62.17 E 375.81 S 9 31 E 2.00 0.28 0.47 0.22 0.19 0.66 0.15 0.34 0.27 0.17 435.76 S 68.83 E 441.16 S 8 58 E 503.39 S 75.32 E 508.99 S 8 30 E 570.98 S 81.81 E 576.82 S 8 9 E 638.32 S 88.30 E 644.40 S 7 52 E 705.48 S 94.96 E 711.84 S 7 39 E 772.35 S 101.70 E 779.02 S 7 30 E 838.65 S 108.07 E 845.59 S 7 20 E 904.60 S 114.13 E 911.78 S 7 11 E 970.22 S 120.34 E 977.66 S 7 4 E 1035.46 S 126.82 E 1043.20 S 6 58 E 0.55 0.29 0.41 1.85 1.75 1.06 0.66 0.41 0.26 0.41 1100.10 S 133.52 E 1108.17 S 6 55 E 1164.03 S 140.35 E 1172.46 S 6 52 E 1227.54 S 147.27 E 1236.34 S 6 50 E 1290.55 S 154.59 E 1299.77 S 6 49 E 1352.36 S 163.52 E 1362.21 S 6 53 E 1412.71 S 174.43 E 1423.44 S 7 2 E 1472.61 S 186.99 E 1484.43 S 7 14 E 1532.40 S 200.16 E 1545.42 S 7 26 E 1592.49 S 213.32 E 1606.71 S 7 37 E 1652.33 S 226.17 E 1667.73 S 7 47 E ARCO ALASKA, INC. 27-15 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 21-0CT-86 PAGE 2 DATE OF SURVEY: 08-0CT-86 KELLY BUSHING ELEVATION: 117.00 FT ENGINEER: SARBER INTERPgLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/iO0 FEET FEET FEET DEG MIN 4000.00 3416.22 3299.22 37 30 4100.00 3495.61 3378.61 37 25 4200.00 3575°09 3458.09 37 20 4300.00 3654.20 3537.20 38 8 4400.00 3732.70 3615.70 38 30 4500.00 3810.28 3693.28 39 39 4600.00 3887.17 3770.17 39 40' 4700.00 3964.27 384?.27 39 36 4800.00 4040.45 3923.45 41 25 4900.00 4114.51 3997.51 42 36 S 11 26 E 1728.09 S 10 58 E 1788.70 S 11 0 E 1849.21 S 9 28 E 1910.26 S 9 9 E 1972.13 S 7 1 E 2035.20 S 6 37 E 2099.14 S 6 37 E 2162.81 S 4 24 E 2227.58 S 4 0 E 2294,70 0.35 0.21 0.48 0.69 1.32 1.26 0.32 0.97 2.67 0.32 1712.00 S 238.53 E 1728.54 S 7 55 E 1771.64 S 250.33 E 1789.24 S 8 2 E 1831.21 S 261,90 E 1849.85 S 8 8 E 1891,42 S 272.72 E 1910.98 S 8 12 E 1952.53 S 282.83 E 1972.91 S 8 14 E 2014.99 S 291.75 E 2036.00 S 8 14 E 2078.50 S 299.15 E 2099.92 S 8 11 E 2141.73 S 306.61 E 2163.57 S 8 8 E 2206.20 S 312.93 E 2228.29 S 8 4 E 2273.23 S 317.56 E 2295.31 S 7 57 E 5000.00 4187.97 4070.97 43 5 5100.00 4260.36 4143.36 44 5 5200.00 4332.03 4215.03 44 12 5300.00 4403.78 4286.78 44 8 5400.00 4475.55 4358.55 43 57 5500,00 4547.74 4430.74 43 44 5600.00 4620.17 4503.17 43 23 5700.00 4692.95 4575.95 43 15 5800.00 4765.81 4648.81 43 16 5900.00 4838.67 4721.67 43 5 S 3 38 E 2362.48 S 2 I E 2431.30 S 1 57 E 2500.80 S 1 53 E 2570.23 S 1 53 E 2639.61 S 2 29 E 2708,60 S 2 47 E 2777.38 S 3 7 E 2845.82 S 3 52 E 2914.21 S 4 31 E 2982.64 1.60 0.86 0.44 0.14 0.78 0.86 0.40 0.46 0.66 0.48 2340.91 S 322.33 E 2363.00 S 7 50 E 2409.81 S 325.63 E 2431.71 S 7 41 E 2479.52 S 327.93 E 2501.11 S 7 32 E 2549.14 S 330.31 E 2570.45 S 7 22 E 2618.73 S 332.56 E 2639.76 S 7 14 E 2687.87 S 335.15 E 2708.59 S 7 6 E 2756.75 S 338.40 E 2777.44 S 6 59 E 2825.24 S 341,87 E 2845.85 S 6 53 E 2893.61 S 346.03 E 2914.23 S 6 49 E 2961.91 S 351.09 E 2982.65 S 6 45 E 6000.00 4911.85 4794.85 42 53 6100.00 4985.28 4868.28 42 38 6200,00 5058.97 4941.97 42 28 6300.00 5132.79 5015.79 42 29 6400.00 5206.01 5089.01 43 15 6500.00 5278.93 5161.93 43 7 6600.00 5352.03 5235.03 42 50 6700.00 5425.56 5308.56 42 34 6800.00 5499.36 5382.36 42 8 6900,00 5573.79 5456.79 41 35 S 4 57 E 3050.76 .S 5 31 E 3118.62 S 6 10 E 3186.22 S 6 27 E 3253.67 S 5 59 E 3321.78 S 6 43 E 3390.21 S 7 23 E 3458.44 S 7 44 E 3526.20 S 7 42 E 3593.67 S 7 2 E 3660.44 0.26 0.45 0.52 0.69 0.61 0.53 0.66 0.28 0.70 1.19 3029.83 S 356.78 E 3050.76 S 6 42 E 3097.42 S 362.98 E 3118.62 S 6 41 E 3164.69 S 369.81 E 3186.22 S 6 39 E 3231.71 S 377.37 E 3253.67 S 6 39 E 3299.44 S 384.61 E 3321.78 S 6 38 E 3367.45 S 392.16 E 3390.21 S 6 38 E 3435.16 S 400.55 E 3458.44 S 6 39 E 3502.34 S 409.54 E 3526.20 S 6 40 E 3569.20 $ 418.67 E 3593.67 S 6 41 E 3635.42 S 427.33 E 3660.45 S 6 42 E 7000.00 5649.26 5532.26 40 22 7100.00 5726.54 5609.54 38 30 7200.00 5805.94 5688.94 36 Z 7300.00 5887.11 5770.11 36 0 7400.00 5967.67 5850.67 36 34 7500.00 6047.98 5930.98' 36 33 7600.00 6128.30 6011.30 36 33 7625.00 6148.38 6031.38 36 33 S 5 25 E 3726.04 S 2 49 E 3789.43 S 3 43 W 3849.76 S 5 48 W 3906.96 S 7 10 W 3964.70 S 8 6 W 4022.36 S 8 6 W 4079.97 S 8 6 W 4094.37 2,29 1.69 4.08 1.28 1.61 0.00 0.00 0.00 3700.62 S 434.49 E 3726.04 S 6 41 E 3763.91 S 439.06 E 3789.43 S 6 39 E 3824.63 S 439.14 E 3849.76 S 6 33 E 3882,82 S 434.03 E 3907.00 S 6 22 E 3941.71 S 427.44 E 3964.82 S 6 11 E 4000.71 S 419.22 E 4022.62 S 5 58 E 4059.69 S 410.82 E 4080.42 S 5 46 E 4074.43 S 408.72 E 4094.88 S 5 43 E ARCO ALASKAt INC. ZT-15 KUPARUK NORTH SLOPEsALASKA COMPUTATION DATE: 21-0CT-86 PAGE 3 DATE OF SURVEY: 08-0CT-86 KELLY BUSHING ELEVATION: 117.00 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -117.00 0 0 1000.00 998.97 881.97 8 28 2000.00 1888.45 1771.45 42 16 3000.00 2632.94 Z515.94 40 13 4000.00 3416.22 3299.22 37 30 5000.00 4187.97 4070.97 43 5 6000.00 4911.85 4794.85 42 53 7000.00 5649.26 5532.26 40 22 7625.00 6148,38 6031.38 36 33 N 0 0 E 0.00 S 15 30 E 18.52 S 5 31 E 440.79 S 6 1 E 1108.16 S 11 26 E I728.09 S 3 38 E 2362.48 S 4 57 E 3050.76 S 5 25 E 3726.04 S 8 6 W 4094.37 0.00 3.23 2.00 0.55 0.35 1.60 0.26 2.29 0.00 0.00 N 0.00 E 0.00 N 0 0 E 16.97 S 14.42 E 22.27 S 40 21 E 435.76 S 68.83 E 441.16 S 8 58 E 1100.10 S I33.52 E 1108.17 S 6 55 E 1712.00 S 238.53 E 1728.54 S 7 55 E 2340.91, S 322.33 E 2363.00 S 7 50 E 3029.83 S 356.78 E 3050.76 S 6 42 E 3700.62 S 434.49 E 3726.04 S 6 41 E 4074.43 S 408.72 E 4094,88 S 5 43 E ARCO ALASKA, INC. 27-15 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 21-0CT-86 PAGE 4 DATE OF SURVEY: 08-0CT-86 KELLY BUSHING ELEVATION: 117.00 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOU'TH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -117.00 0 0 N 0 0 E 17.00 17.00 -100.00 1 15 N 70 38 E 117.01 117.00 0.00 0 28 5 68 45 E 217.01 217.00 100.00 0 30 S 75 41 E 317.01 317.00 200.00 0 34 N BO 14 E 417.02 417.00 300.00 0 23 N 37 27 E 517.02 517.00 400.00 0 26 N 88 7 E 617.03 617.00 500.00 0 43 S 83 53 E 717.03 717.00 600.00 0 39 N 64 34 E 817.07 817.00 700.00 2 45 S 37 31 E 917.36 917.00 800.00 5 58 1018.24 1017.00 900.00 9 2 1119.93 1117.00 1000.00 11 58 1222.80 1217.00 1100.00 15 2 1327.58 1317.00 1200.00 19 27 1435.07 1417.00 1300.00 23 30 1546.09 1517.00 1400.00 2? 33 1660.67 1617.00 1500.00 30 5? 1779.74 171?.00 1600.00 34 49 1905.33 1Bl?.O0 1700.00 39 31 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 E 0.35 0.10 0.25 S 0.92 E 0.76 0.58 0.57 S 1.66 E 0.76 0.30 0.46 S 2.60 E 0.31 0.32 0.07 N 3.22 E -O.OB 1.55 0.51 N 3.67 E 0.25 0.25 0.30 N 4.75 E -0.01 0.36 0.68 N 5.81 E 1.40 3.46 0.51 S 7.75 E 2038.80 1917.00 1800.00 42 49 2175.18 2017.00 1900.00 42 44 2311.01 2117.00 2000.00 42 29 2446.43 2217.00 2100.00 42 14 2580.86 2317.00 2200.00 41 40 2714.34 2417.00 2300.00 41 17 2847.20 2517.00 2400.00 40 57 2979.10 2617.00 2500.00 40 20 3109.74 2717.00 2600.00 39 53 3239.53 2817.00 2700.00 39 21 S 22 13 E 8.33 S 14 18 E 21.27 S 10 7 E 39.59 S 9 B E 63.66 S 7 52 E 94.82 S 7 56 E 134.18 S 7 25 E 182.33 S 7 2 E 238.20 S 6 38 E 302.81 S 6 11 E 378.72 3368.29 2917.00 2800.00 38 30 3495.13 3017.00 2900.00 37 39 3621.60 3117.00 3000.00 37 45 3748.20 3217.00 3100.00 37 59 38?4.83 3317.00 3200.00 37 40 4000.99 3417.00 3300.00 37 30 4126.94 3517.00 3400.00 3? 24 4252.82 3617.00 3500.00 37 43 4379.97 3717.00 3600.00 38 20 4508.73 3817.00 3700.00 39 43 S 5 28 E 467.06 S 5 27 E 559.77 S 5 34 E 651.68 S 5 45 E 742.98 S 5 17 E 832.80 S 5 18 E 921.19 S 5 39 E 1008.64 S 5 59 E 1094.64 S 6 9 E 1178.70 S 6 30 E 1261.45 S 8 34 E 1342.54 S 11 7 E 1420.44 S 12 22 E 1497.53 S 12 21 E 1574.?8 S 12 3 E 1652.08 S 11 25 E 1728.69 S 10 56 i 1805.03 S 10 7 E 1881.27 S 9 21 E 1959.71 S 6 53 E 2040.77 0.00 N 0 0 E 0.00 N 90 0 E 0.95 S 74 51 E 1.76 S 70 58 E 2.64 S 79 56 E 3.22 N 88 49 E 3.70 N 82 8 E 4.76 N 86 24 E 5.85 N 83 18 E 7.76 S 86 12 E 3.44 7.10 S 3.23 19.65 S ,3.58 37.66 S 3.76 61.42 S 3.54 92.26 S 3.64 131.26 S 2.93 178.98 S 3.02 234.42 S 3.61 298.56 S 3.12 374.00 S 11.13 E 13.20 S 57 27 E 15.14 E 24.80 S 37 36 E 18.90 E 42.14 S 26 39 E 22.92 E 65.56 S 20 28 E 27.51 E 96.27 S 16 36 E 32.85 E 135.31 S 14 3 E 39.33 E 183.25 S 12 23 E 46.33 E 238.95 S 11 10 E 54.06 E 303.41 S 10 15 E 62.54 E 379.19 S 9 29 E 0.79 0.17 0.19 0.32 0.17 0.28 0.60 0.45 0.38 0.71 461.91 S 71.35 E 467.38 S B 46 E 554.22 S 80.21 E 559.99 S 8 14 E 545.72 S 89.03 E 651.83 S 7 51 E 736.58 S 98.08 E 743.08 S T 35 E 825.99 S 106.90 E 832.87 S 7 22 E 914.02 S 115.01 E 921.23 S ? 10 E 1001.09 S 123.38 E 1008.67 S 7 1 E 1086.65 S 132.11 E 1094.65 S 6 55 E 1170.24 S 141.02 E 1178.71 S 6 52 E 1252.50 S 150.04 E 1261.46 S 6 49 E 1.34 1.11 0.69 0.35 0.34 0.35 0.29 1.68 0.55 1.04 1332.92 S 160.51 E 1342.55 S 6 51 E 1409.80 S 173.85 E 1420.48 S 7 1 E 1485.54 S 189.82 E 1497.62 S 7 16 E 1561.37 S 206.53 E 1574.97 S 7 32 E 1637.28 S 222.97 E 1652.40 S 7 45 E 1712.59 S 238.65 E 1729.14 S 7 55 E 1787.72 S 253.43 E 1805.59 S 8 4 E 1862.80 S 267.83 E 1881.96 S 8 10 E 1940.26 S 280.82 E 1960.48 S 8 14 E 2020.52 S 292.43 E 2041.57 S 8 14 E ARCO ALASKA, INC. 27-15 KUP~RUK NORTH SLOPE,ALASKA COMPUTATION DATE: 21-0CT-86 PAGE 5 DATE OF SURVEY: 08-0CT-86 KELLY BUSHING ELEVATION: ENGINEER: SARBER INTERPOLATEO VALUES FOR EVEN 100 FEET DF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 4638.72 3917.00 3800.00 39 33 4768.90 4017.00 3900.00 40 45 4903.38 4117.00 4000.00 42 36 5039.90 4217.00 4100.00 43 30 5179.01 4317o00 4200.00 44 13 5318.43 4417.00 4300.00 44 7 5457.42 4517.00 4400.00 43 44 5595.63 4617.00 4500.00 43 24 5733.02 4717.00 4600.00 43 13 5870.31 4817.00 4700.00 43 10 6007.03 4917.00 4800.00 42 52 6143.10 5017.00 4900.00 42 32 6278.61 5117.00 5000.00 42 24 6415.10 5217.00 5100.00 43 15 6552.15 5317.00 5200.00 43 I 6688,38 5417.00 5300.00 42 34 6823.77 5517.00 5400.00 41 59 6957.49 5617.00 5500.00 40 49 7087.79 5717.00 5600.00 38 41 7213.62 5817.00 5700.00 35 49 117.00 FT S 6 43 E 2123.83 S 5 7 E 2207.17 S 4 1 E 2296.99 S 2 55 E 2389.81 S 1 53 E 2486.19 S '1 51 E 2583.02 S 2 11 E 2679.22 S 2 46 E 2774.39 S 3 21 E 2868.41 S 4 21 E 2962.36 0.34 2.71 0.27 1.67 0.43 0.20 1.02 0.46 0.53 0.50 2103.02 S 302.01 E 2124.59 S 8 10 E 2185.84 S 311.26 E 2207.89 S 8 6 E 2275.52 S 317.72 E 2297.59 S 7 56 E 2368.24 S 323.90 E 2390.29 S 7 47 E 2464.87 S 327.43 E 2486.52 S 7 34 E 2561.96 S 330.73 E 2583.22 S 7 21 E 2658.44 S 333.95 E 2679.34 S 7 9 E 2753.75 S 338.25 E 2774.45 S 7 0 E 2847.83 S 343.15 E 2868.43 S 6 52 E 2941.68 S 349.53 E 2962.37 S 6 46 E S 4 59 E 3055.54 S 5 44 E 3147.79 S 6 30 E 3239.24 S 6 4 E 3332.13 S 7 4 E 3425.84 S 7 42 E 3518.35 S 7 37 E 3609.61 S 6 7 E 3698.37 S 3 7 E 3781.83 S 4 14 W 3857.57 0.37 0.48 0.32 0.66 0.54 0.29 0.92 1.69 2.02 2.58 3034.60 S 357.20 E 3055.55 S 6 42 E 3126.46 S 365.83 E 3147.79 S 6 40 E 3217.38 S 375.74 E 3239.24 S 6 39 E 3309.73 S 385.69 E 3332.13 S 6 38 E 3402.83 S 396.45 E 3425.84 S 6 38 E 3494.55 S 408.49 E 3518.35 S 6 40 E 3585.00 S 420.80 E 3609.61 S 6 41 E 367.3.09 S 431.68 E 3698.37 S 6 42 E 3756.30 S 438.65 E 3781.83 S 6 39 E 3832.57 S 438.54 E 3857.57 S 6 31 E S 6 13 W 3928.27 S 8 6 W 4000.13 S 8 6 W 4071.86 S 8 6 W 4094.37 0.69 0.00 0.00 0.00 3904.5'3 S 431.72 E 3928.33 S 6 18 E 3977.96 S 422.47 E 4000.33 S 6 3 E 4051.39 S 412.00 E 4072.28 S 5 48 E 4074.43 S 408.72 E 4094.88 S 5 43 E 7337.01 5917.00 5800.00 36 16 7461.43 6017.00 5900.00 36 33 7585.93 6117.00 6000.00 36 33 7625.00 6148.38 6031.38 36 33 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN ARCO ALASKA, INC. 2T-15 KUPARUK NORTH SLOPE,ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBDT TD COMPUTATION DATE: 21-0CT-86 PAGE 6 DATE DF SURVEY: 08-0CT-86 KELLY BUSHING ELEVATION: 117.00 FT ENGINEER: SARBER INTERPOLATED VALUES FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB SURFACE LOCATION AT ORIGIN: 27' FSL, 556' FWL, SEC 1, TllN, R8E, UN TVD RECTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 7195.00 7237.00 7276.00 7428.00 7469.00 7625.00 5801.91 5684.91 3821.68 S 439.31 E 5836.00 5719.00 3846.14 S 437.44 E 5867.68 5750.68 3868.81 S 435.41 E 5990.14 5873.14 3958.25 S 425.26 E 6023.08 5906.08 3982.43 S 421.83 E 6148.38 6031.38 4074,43 S 408.72 E COMPUTATION DATE: 21-0CT-86 PAGE 7 ARCO ALASKA, INC. DATE OF SURVEY: 08-0CT-86 27-15 KUPARUK NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: SARBER llT.O0 M&RKER ORIGIN: 27' FSL, MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA 556 ' SURFACE LOCA AT FWL, SEC 1, TllN, RECTANGULAR COO NORTH/SOUTH E TION R8E, UM ROINATES AST/WEST TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBDT TD 7195.00 5801.91 5684.~1 7237.00 5836.00 5719.00 7276.00 5867.68 5750.68 7428.00 5990.14 5873.14 7469.00 6023.08 5906.08 7625.00 6148.38 6031.38 3821.6 3846.1 3868.8 3958.2 3982.4 4074.4 8 S 4 S 1 S 5 S 3 S 3 S 439.31 E 437.44 E 435.41 E 425.26 E 421.83 E 408.72 E FINAL WELL LOCATION ~T TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN ~T 7625.00 6148.38 6031.38 4094.88 S 5 43 E SCHLUNBF-FROER B I RF'CT I ON~L SURVEY COMPANY ARCO ALASKA INC NELL 2T- 15 FIELO KUPARUK COUNTRY USA RUN ONE DATE LOGGED 08 - OCT - 86 REFERENCE 00007 ] 760 WELL: 2T-15 (27'FSL, 556'FWL, SEC 1,TllN,R8E,UM) HORIZONTAL PROJECTION NORTH 2000 ~000 - ] 000 -2000 -3000 -4000 -SO00 SOUTH -6000 WEST . . , : ~-..~..~ ..... !..'. ....... ~ ..: .... :! -. :., · ' :. ~ .~.-.~ ...... :. .... !.--!-.-i...~--~..-!---.; ..... :"t ....... ,- ~.TT-:~:--.--i.-t---.~ ; .?.-i..-~.---! ..... :....i..-;--¢---i--..!----i.-.-! , :. .m-r~-~-:-.--e ....... e-:----i- ............... ?-;---7-'r~ff-?-~-~-,-;-Fi-~- i-m-7~--rT-~: e-fff~---Tt-~---%-~ ~ ,~ ~-~w ~ . 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"' :'!:' :[ ..... 1F;oob ....... ~'"-'~ .............................. ~"? ........................... ---t PROJECTION ON VERTICAL PLANE 173. - 3S3. SCALED IN VERTICAL OEPTHS HOR[Z SCALE = !/ !900 IH/FT Form to be-inserted in each "Active" well folder to check for timely compliance with our regulations. INDEFINITELY Reports and Materials to be received by:~ ./?-'~:a~.-~_Z ~ ReqUired Date Received Remarks Completion Report Samples Mud Log ~,~ ~ ............ Cor~ Ch~ps ~ ,,, ~~..,~,~. Core Description Registered Survey Plat Directional Survey Production ~est Reports ~~ ~ ._ L~g Rum .o ---~ STATE OF ALASKA .-~- ALASKA L AND GAS CONSERVATION COMMI', 3N REPORT OF SUNDRY WELL OPERATIONS .. Operations performed: Operation shutdown ~ Stimulate ~ Plugging '- Perforate:~ Pull tubing Alter Casing [] Other ~ Com_p'lete 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 9951 0-0360 4. Location of well at surface 27'FSL, 556'FWL, Sec.1, T11N, R8E, UM At top of productive interval 1485' FSL, 995' FWL, Sec.12, TllN, R8E, UM At effective depth 1325' FSL, 978' FWL, Sec.12, TllN, R8E, UM Att~t~I3~IE~PtpsL, 965' FWL, Sec.12, T11N, R8E, UM 5. Datum elevation (DF or KB) RKB I 1 7 ' Feet 6. Unit or Property name Kuparuk River Unit 7. Well number 2T-15 8. Approval number 7 & 78 9. APInumber 50-- 103-20062 10. Pool Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 3196' Production 7083' Liner 696 ' 7625 'MD 6148'TVD 7469'MD 6023'TVD Size 16" feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth True Vertical depth 225 sx CS II 100'ND 100'TVD 9-5/8" 970 SX AS III & 3229'MD 2809'TVD 335 sx Class G 7" 200 sx Class G & 7116'MD 5740'TVD 1 75 sx AS I 5" 90 sx Class G 6929'-7625'MD 5596'-6148' Perforation depth: measured '7197 ' 7313' true vertical 5804 ' 5898' - Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail ~ 7273' Packers and SSSV (type and measured depth) FHL Pkr @ 6768'~ DB pkr @ 7250'~ 12. Stimulation or cement squeeze summary Intel1'~aAIs treated (measured) - 7236'MD - 7342'MD - 5835'TVD 5921'TVD TRDP-1A-SSA SSSV @ 1765' Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Completion Well History Daily Report of Well Operations:x2~: Copies of Logs and Surveys Run X Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title Associate Engineer Submit in Duplicate fDAM) $W0/111 'VD Oil and Gas Company Well History - Initial Report - Daily Instructions: 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 Alaska Field IState I County, parish or borough North Slope Borough I Lease or Unit IWell no. Kuparuk River ADL 25569 2T-15 Auth, or W.O. no. ~Title AFE AK0821 I Complete Nordic 1 API 50-103-20062 Operator ARCO W.I. ARCO Alaska, Inc. 56.24% Prior status if a W.O. Alaska Spudded or W,O, begun Complete Date and depth as of 8:00 a.m. 10/06/86 IDate 10/5/86 IH°ur Complete record for each day reported 10/07/86 1930 hrs. 10/08/86 10/09/86 5" @ 7625', 7" @ 7116' 3080', C&C mud Wt. 12.1 ppg Accept. rig @ 1930 hrs, 10/5/86. ND tbg head. NU & tst BOPE. TIH to 2000', displ diesel w/12.1 ppg mud. TIH, C&C mud. 7625', 7" @ 7116' , Cln mud pits PPg tag cmt @ 6827' & DO to 6923'. Tst lnr lap to 1000 psi, RIH w/4-1/8" bit to 7469', circ & cln mud pits. 5" @ 7469' 12.1 TIH, POH. 5" @ 7625', 7" @ 7116' 7469', Prep to perf 11.6 ppg NaC1 brine C&C mud, tst lnr to 1000 psi. Cln pits, filter brine. Displ well w/wtr thru choke to tank, displ w/ll.6 ppg brine. Filter surf vol & hole. POOH. RU Schl, rn CET/GCT, rn JB & gage ring, POOH. Prep to perf. 5" @ 7625', 7" @ 7116' 7469', ND BOPE 11.6 ppg NaC1 brine Pe~342'-7313' w/4 SPF & 7236'-7197' (twice) for total of 12 SPF/120 '~phasing. RIH, set DB pkr @ 7257' WLM, RD Schl. Rn 10 its, 2-3/8", 4.7#, N-80, 2 jts, 2-3/8" BTC & 218 jts + 1 pup, 3½", 9.3#, J-55 8RD EUE AB Mod tbg w/TT @ 7273', FHL pkr @ 6768', DB pkr @ 6768 & SSSV @ 1765'. Tst tbg, ann & SSSV. ND BOPE. The/~ve is corre,~ IDate I Title Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ..,.,O Oil and Gas Company ,~, Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District County or Parish State Alaska North Slope Borough Field Kuparuk River Auth. or W.O. no. AFE AK0821 Lease or Unit Title ADL 25569 Completion Nordic 1 API 50-103-20062 Alaska IWell no. 2T-15 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete A.R.Co. W.I. 56.24% Date 10/5/86 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prior status if a W.O, I 1930 hrs. Date and depth as of 8:00 a.m. 1o11o/86 Complete record for each day reported 5" @ 7625', 7" @ 7116' 7469' PBTD, RR 6.8 ppg diesel ND BOPE. NU & tst tree to 5000 psi. BPV. RR @ 1130 hrs, 10/9/86. Displ well w/diesel. Set Old TD New TD PB Depth Released rig Date Kind of rig 1130 hrs. 10/9/86 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) 0il Single Producing method Officia~ 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 Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The/~ove is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ITitte Drilling Supervisor ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN T°: ARCO ALASKA, INC · ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 10-20-86 TRANSMITTAL # 5801 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: Schl: Open Hole Logs: One * of each 2T-9 *These are combination Run #1&3 Logs. To save space they are listed as Run #3. '"a5" DIL/SFL ~2" .DIL/SFL '"°5" Comp.Neu/Form. Den (poro) "'02" Comp.Neu/Form. Den (poro) ~'o 5" Comp.Neu/Form. Den '(raw) ~-o2" Comp.Neu/Form. Den (raw) xx'~5" LS$-GR ~.o~, LSS-GR x'~Cyberlook ~5" Dual Dipmeter-GR '-~RFT Log 07-03-86 Run #3 2668-6360 07-03-86 Run #3 2668-6360 07-03-86 Run #3 2668-6334 07-03-86 Run #3 2668-6334 07-03-86 Run #3 2668-6334 07-03-86 Run #3 2668-6334 07-03-86 Run #3 2680-6354 07-03-86 Run #3 2680~6354 07-03-86 Run #3 5800-6300 07-0~-86 Run #3 2680-6364 07-04-86 3112-6056 2T-1~5" DIL/SFL-GR ~-O2" DIL/SFL-GR x'-O5" Den/Neu-GR '<"~2" Den/Neu-GR '"'5" Den/Neu-GR ~'-~2" Den/Neu-GR "-.O Cyberlook (poro) (poro) (raw) (raw) 05-03-86 Run #1 7678-8194 05-03-86 Run #1 7678-8194 05-03-86 Run #1 7678-8168 05-03-86 Run #1 7678-8168 05-03-86 Run #1 7678-8168 05-03-86 Run #1 7678-8168 05-03-86 Run #1 7690-8140 3N-~5" DIL/SFL-GR ~2" DIL/SFL-GR x-.55" Den/Neu-GR "~2" Den/Neu-GR '"05" Den/Neu-GR "o2" Den/Neu-GR '--Cyberlook (poro) (poro) (raw) (raw) 05-04-86 Run #2 2579-7451 05-04-86 Run #2 2579-7451 05-04-86 Run #2 6650-7425 05-04-86 Run #2 6650-7425 05-04-86 Run #2 6650-7425 05-04-86 Run #2 6650-7425 05-04-86 Run #2 6650-7400 / Receipt Acknowledged: NSK Files*bl Rathmell*bl D &M *bl Vault*films ARCO Alalka. Inc. is II Subsidiary of AtllntlcRichfleldCompmny Oi; & Gus Cu.u Commission Anchorage Drilling*bi Alaska,' Inc. Post Office E i00360 Ar~chorage, Alaska 99510-0330 Telephone 907 276 1215 RETURN TO: ARCO A_LASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 ~chorage AK 99510-0360 DATE 10-08-86 T.~SMITTAL ~ 5791 Transmitted herewith are the following items. Flease acknowledge receipt and return one signed copy of this transmittal. Final Prints: Schl: Open Hole: One * of each 3N-t3 ~5" DIL/SFL-GR 04-26-86 Run #1 3773-7836 ~2".DIL/SFL-GR 04-26-86 Run ~1~. 3773-7836 ~5" Den/Neu (poro) 04-26-86 Run #1 5800-7810 ~2" Den/~eu (poro) 04-26-86 Run fl,. 5800-7810 ~5" Den/Neu (raw) 04-26-86 Run #1 5800-7810 . 2" Den/Neu (raw) 04-26-86 Run fl 5800-7810 x,o,_Cyberlook 04-26-~ Run #1 7250-7800 2/-15 ~5" DiL/SFL-GR "2" D!L/SFL-GR "5" Den/Neu-GR (poro) '~2" Dzn/Neu-GR (p ~,ro) ~5" De=/Neu-GR (raw) "2" Der~/Neu-GR (raw) ~ Cybarlook 04-21-86 Run #1 04-21-86 Run 04-21-86 Run 04-21-86 Run 04-21-86 Run 04-21-86 Run 04-21-86 Run 7128-7526 7128-7526 7128-7501 7128-7501 7128-7501 ?~'!8-7501 7128-7501 Receipt Ackrcwledged: NSK Files*bl D & M*bl Drilling*bl Rathmell*bl Vault*films L. Jehnston*Schl Pkgs. AP, CO STATE OF ALASKA ALASK,, OIL AND GAS CONSERVATION COMk. .,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon .,%r. Suspend ~ Operation Shutdown .~ Re-enter suspended well '--' Alter casing . Time extension ~ Change approved program F~ Plugging ~ Stimulate ~, Pull tubing : Amend order :-' Perforate '" Other ' ' 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 117' RKB feet 3. Address 6. Unit or Property name P. O. Box 100360 Anchoraqe, AK 99510 Kuparuk River Unit 4. Location of well at surface 7. Well number 27'FSL, 556'FWL, Sec.1, T11N, R8E, UM 2T-15 At top of productive interval 8. Permit number 1406'FSL, 1010'FWL, Sec.12, T11N, RSE, UM (approx.) 86-45 At effective depth 9. APl number 1264'FSL, 975'FWL, Sec.12, T11N, R8E, UM (approx.) 501103-20062 At total depth 10. Pool 1208'FSL, 979'FWL, Sec.12, T11N, R8E, UM (approx.) Ku'paruk River Oil Pool 11. Present well condition summary Total depth: measured 7625 feet Plugs (measured) None true vertical 6133 feet Effective depth: measured 7536 feet Junk (measured) None true vertical feet 6064 Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" Conductor report IO0'MD IO0'TVD not available. Surface 3196' 9-5/8" 970 sx AS I I I & 3229'MD 2815'TVD 335 sx Class G Production 7083' 7" 200 sx Class G & 7116'MD 5737'TVD I 75 sx AS I Liner 696' 5" 90 sx Class G 6929'-7625'MD 5596'-6133'TVD Perforation depth: measured None -- · true vertical None i...: :- , Tubing (size, grade and measured depth) None . ..;:_:.:. None ¢' ..' ':' Packers and SSSV (type and measured depth) 12.At, t, ac, h,m¢,n, ts Description summary of proposal [] Detailed operations program [] BOP sketch we ~/ ~1~ story 13. Estimated date for commencing operation CO ~E~h~% ~"~'"'J~'~ '~ ~ ~ August, 1986 r'~¢' ,~'--.. ,; ;; ?' ¢. ' 14. if proposal was verbally approved ~ ~ ~' '~;''''',' '":'": ': :' Name of approver J t ~ ~ ~"::;,.' ',..:: ,,: ;; ~ :."':" :4"i ~"~ Date approved 15. I hereby certify that the foregoing is true and co-rrecTto'~'h'e best of my i~no~vledge Signed ~,~ ~ ~~ Title Associate Engineer Date ,/ ( DAM ) SA/040 Commission Use Only Conditions of approval Notify commission so representative may witnessIApproval No. 0 [] Plug integrity [] BOP Test [] Location clearanceI ! '~ ~.~_~. ' /--' ¢¢ by order of Approved by r~ ~.~,~.,~,[ ~, 8~i~,,~!¢: ~'"6mm~ss~oner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ,:~CO Oil andGas Companyv'~ Well History - Initial Report- Daily Instructions: 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 I County. parish or borough I State Alaska I North Slope Borough I Alaska Field ILease or Unit ADL 25569 IWell no. Kuparuk River 2T-15 Auth, or W.O. no. ITitle AFE AK0821 I Drilling Rowan 34 API 50-103-20061 Operator IARCO W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begUnspudded IDate 4/11/86 IH°ur 0230 hrs. IPri°r status if a W'O' Date and depth as of 8;00 a.m. 4/11/86 4112186 thru 4/14/86 4/15/86 4/16/86 Complete record for each day reported 16" @ 100' 300', (190'), Drlg Wt. 9.0, PV 16, YP 42, PH 9.0, WL 16.4, Sol 4.9 Accept rig @ 1730 hfs, 4/10/86. NU diverter sys. 4/11/86. Drl 12¼" hole to 300'. Spud well'@ 0230 hrs, 9-5/8" @ 3229' 3245', (2945'), Drlg cmt Frsh wtr Drl & surv 12¼" hole to 3245', make wiper trip, C&C, POOH. RU & rn 80 its, 9-5/8", 36#, J-55 HF/ERW cs$ w/FC @ 3145', FS @ 3229'. Cmt w/970 sx AS III, followed by 335 sx C1 "G" w/2% S-1 & .2% D-46. Displ using tis pmps, bump plug. CIP @ 0845 hfs, 4/13/86. Had full rtns. ND 20" diverter sys. NU & tst BOPE. RIH, tag cmt @ 3132', tst csg to 2000 psi. Drl cmt & flt equip. 829', 2.9°, S29.2E, 828.93 TVD, -2.73 VS, 2.51N, 2.04E 1010', 8.7°, S12.3E, 1008.93 TVD, 14.94 VS, 14.53S, 4.41E 1440', 23.9°, S 6.3E, 1421.53 TVD, 131.96 VS, 130.55S, 19.72E 1855'· 36.7°, S 4.6E, 1778.58 TVD, 342.49 VS, 340.37S, 38.14E 2417', 42.3°, S 4.2E, 2201.60 TVD, 712.08 VS, 708.85S, 69.11E 3200', 39.7°, S 5.2E, 2791.85 TVD, 1226.33 VS, 1221.10S, 116.24E 9-5/8" @'3229' 4496', (1251'), Drlg Wt. 9.0, PV 5, YP 5, PH 10.5, WL 18.2, Sol 5 Drl cmt & flt equip + 10' new hole. Conduct leak-off tst to 11.3 ppg EMW. Drl & surv 8½" hole to 4496'. 3630', 38°. S13.8E, 3126.73 TVD, 1495.72 VS, 1487.13S,160.76E 4121'' 37'5o, S9.4E, 3475.42 TVD, 1764.69 VS, 1751.60S,215.05E 9-5/8" @ 3229' 6761', (2265'), POH Wt. 10.5, PV 13, YP 7, PH 8.5, WL 7.2, Sol 14 Turbine drl f/4496'-6761', inc mud wt @ 6500' gradually f/9.8 ppg - 10.5 ppg. Began losing fluid while drlg after wt reached 10.5 ppg. Decrease mud wt in pits f/10.5 - 10.3 ppg, POH. 4515' 5582 ' 6579' , 40.0°, S6.9E, 3821.69 TVD, 2042.50 VS, 2026.70S, 254.45E · 43.7~, S2.9E, 4605.39 TVD, 2765.38 VS, 2748.90$, 302.11E , 43.3 ~ S6.7E, 5332.12 TVD, 3447.56 VS,.342i8.48S, 363.97E The above is correct see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate __ Title I Drilling Supervisor Oil and Gas Company Daily Well History--Interim '! Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2} on Wednesday of the week in which oit string is set. Submit weekly,for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a,m. Alaska County or Parish North Slope Borough Kuparuk River tease or unt ADL 25569 Complete record for each day while drilling or workover in progress 4/17/86 4118186 4/19/86 thru 4/21/86 4/22/86 State Alaska JWell no. 2T-15 9-5/8" @ 3229' 7130', (369'), POH f/7" Wt. 10.2, PV 12, YP 8, PH 8.5, WL 8.6, Sol 13 TOH, chg BHA. TIH, wsh 60' to 6761', drl to 7130', short trip to 3220'. TIH, wsh 60', circ some gas, spot 600' 11.5 mud on btm, TOH, LD DP. 7085', 39°, S4.7E, 5713 TVD, 3780 VS, 3760S, 397E 7" @ 711~' 7130', (0'), PU 3½" DP Wt. 10.3+, PV 14, YP 5, PH 8.5, WL 8.6, So1 15 Fin POOH, LD DP. RU & rn 174 jts, 26#, J-55 BTC csg to 7115'. Cmt w/200 sx C1 "G". Displ using rig pmps, bump plug. Well flowing on ann. SI, 40 psi build up in 4.5 hrs. Prep to Arctic Pak 9-5/8" x 7" ann. 7" @ 711~ 7625', (214'), Logging Wt. 12.1, PV 20, YP 9, PH 8.0, WL 7.0, Sol 18 PU 3½" DP, pmp 175 sx AS I cmt & 57 bbls Arctic Pak. WO Pak 4 hrs; well dead. NU & tst pack-off to 3000 psi, tst BOPE to 3000 psi. RIH w/bit & 3½" DP to 6942', wsh to 7032'. DO cmt & flt equip + 10' new formation. Conduct formation tst to 13.5 ppg EMW. Drl 6-1/8" hole to 7625', 8 std short trip, circ, POOH. RU Schl, rn DIL/SFL/SP/CAL/GR/FDC/CNL. (Rn 173 + 1 cut jt, 7", 26#, J-55 BTC csg w/FC @ 7030', FS @ 7115') 7625', 39°, S4E, 6133 TVD, 4120 VS, 4099, 423 7" @ 711~' 7625', (0'), RIH w/lnr Wt. 12.1, PV 18, YP 9, PH 8.0, WL 7.1, Sol 18 Fin logging f/7534'-7128', TOH, RD loggers. TIH, rm f/7465'-7625', 8 std short trip, circ, TOH. Rn 16 jts, 5", 18# FL4-S. TIH to 7485', mud flowed back thru DP, circ, TOH. Repl hgr, TIH. The above is correct Signatur ' . ~ · For form p~eparation and dist~bullon Drilling Supervisor see Procedures Manual Section 10, Drilling, Pages 86 and 87 CO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK0821 Rowan 34 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded 4/23/86 Date and depth as of 8:00 a.m. County or Parish Lease or Unit Tit e North Slope Borough ADL 25569 Drill Accounting cost center code API 50-103-20061 A.R.Co. W.I. 56.24% Date 4/11/86 Complete record for each day reported State Iotal number of wells (active or inactive) on this i ost center prior to plugging and ~ bandonment of this well I our I Prior status if a W.O. 0230 hrs. I Displ Instl 5" @ 7625' 7625', (0'), RR Diesel Fin rn'g 5" lnr f/7625'-6929'. Cmt w/90 sx Cl "G". w/rig & bump plug. Pmp 2000' diesel cap. ND BOPE. master vlv. RR @ 2230 hfs, 4/22/86. Alaska Well no. 2T-15 o1~ TO ~ew TO ,~ 7536 ' PBTD Released rig Date 2230 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing POtential test data PB Depth 7625 ' TD Kind of rig 4/22/86 IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective' date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor AR CO Alaska, In Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. return one signed copy of this transmittal. Open Hole LIS Tape plus Listing Schl' One copy of each 2T-15 04-21-86 Run ~/1 7094.5-7577.5 DATE 05-01-86 TRANSMITTAL # 5656 Please acknowledge receipt and Receipt Acknowledged: Date: State of AK ARCO Alaska. Inc. ,s a Subsidiary of AtlanticRichtieldCompany ARCO Alaska. Inc. Post Office Box 100360 Anchorage. Alaslca 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATe 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 04-15-86 TRANSMITTAL # 5628 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tapes plus Listings: Schl: One copy of each 2T-16 04-08-86 31-14 03-30-86 ~'31-15 04-06-86'-i N-10 04-03-86 N-9*** 03-27-86 ***There was previously transmitted on transmittal #5613 a 3N-9 OH LIS tape · but it was for Run #1 only. Receipt Acknowledged: ~ :. state of AK ARCO AIIIkl. Inc. ,s a SuOl,Ch(try of AIIInllclRlctlfleldComg)lny STATE OF ALASKA ALASK,-, OIL AND GAS CONSERVATION COMN, _SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Reques,t,: Abandon-[] Suspend [] Operation Shutdown r-1 Re-enter suspended well [] Alter casing,,~,, program'~,.,Plugging [] Stimulate [] P'ull.tubing Time extension Change approved 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc 117' RKB PAD 82' feet 3. Address 6. Unit or Property name P. O. Ro× 1F)F)~Gn An~hnrao¢' AW 99510 Kup3ruk River Umit 4. Location of well at surface 7. Well number 57~FSL~ 556~FWL~ Sec.l~ T11N~ RaE~ UH 2T-15 At top of productive interval 8. Permit number 1406'FSL, 1010'FWL, Sec.12, T11N, RaE, UN 86-45 At effective depth 9. APl number 50~ 103-20062 At total depth 10. Pool 1101~FSL~ 1085~FNL~ Sec.12¢ T11N~ RaE~ UN Kuparuk River 0~1 Pool 11. Present well condition summary Total depth: measured 6761 ' HD feet Plugs (measured) as of 4/1 6/86TM vertical 5465 ' TVD feet Effective depth: measured feet Junk (measured) true vertical N/A feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 200 cf 100' 100' Surface 3229' 9-5/8" 970 sx AS I I I & 3229' 2901 ' 335 sx Class G Perforation depth: measured None RECEIVED true vertical NoneAPR 1 6 1986 Tubing (size, grade and measured depth) None ~ 0ii ~ Gas ~ns. ~mmi~i0n ., ~mge Packers and SSSV (type and measured depth) None 12.Attachments Description summary of proposal~ Detailed operations program BOP sketch 13. Estimated date for commencing operation April 17~ 1986 14. If proposal was verbally approved Name of approver 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~ Title Associ ate Engineer Date 4'1~-8G Commission Use Only ( HBW ) SA/006 Conditions of approval Notify commission so representative may witness [ Approval No. ~ Plug integrity Q BOP Test ~ Location clearanceI // l, Sllllj '/.-//.-.i by order of Approved by ................................... ~ommissioner the commission Date ~- /7.-'~ ,, Form 10-403 Rev 12-1-85 Submit in triplicate 2T-15 APPLICATION FOR SUNDRY APPROVALS SUMMARY OF PROPOSAL Due to lost circulation zone encountered above the Kuparuk Sand, ARCO Alaska, Inc., proposes to: 1. Drill 8-1/2" hole to 7176'. 2 · 4 · Run and cement 7" casing as per drilling permit ~ 7176'MD. Drill 6~"hole to original planned TD ~ 7732'MD. Run and cement 5", 18.0#, L-80, FL4S production liner from 6976' - 7732 'MD wi th 100 sx Class "G" cement. 5. Complete well as per drilling permit. SA/OO6a: tw 04/16/86 February' 19, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 2T-15 ARCO Alaska, Inc. Permit No. 86-~45 Sur. Loc. ~7'F. SL, 556'FWL, Sec. 1, TI]N, RSE, UM. Btmhole Loc. II01'FSL, 1045'FWL, Sec. 12, TllN, RSE, 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 co~encing 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, l~here 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. truly~-~Rrs, C. V. Cha~¢er~ton Chairman of Alaska Oil and Gas Conservation Commission '\ BY O~ER 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, Post Oh,,~e Be,._ ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 3, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 2T-15 Dear Mr. Chatterton' Enclosed are- An application for Permit to Drill 2T-15, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore o 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 March 5, 1986. If you have any questions, please call me at 263-4970. Sincerely, Regional Drilling Engineer JBK/LWK/tw PD/L227 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ........ STATE OF ALASKA '- ALASK~ OI- AND GAS CONSERVATION UON,,¢IISSION PERMIT TO DRILL 20 AAC 25.005 SERVICE [] SINGLE ZONE MULTIPLE ZONE la. Type of work. DRILL REDRILL DEEPEN 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] 2. Name of operator ARCO ^laska, Inc, 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name -~ FSL, 556' FWL, Sec.1, T11N, R8E, UMFwL, Sec.12, T11N, R8E, UM C~...'~''~!h~7~ ~ ~1 Kuparuk River unit2T~15 At--~t f ' ' :i;'ii i~iI 10. Well number t topo proposed producing interval 1406' FSL, 1010' At total depth ~F i!:~ "L"'"" :* ?/, 11. Field and P-~0~ 1101' FSL, 1045' FWL, Sec.12, T11N, R8E, UM ~i ~ ~Ji~ L; ~.~-~ :, ~ Kuparuk River Field 5. [~le~a-at[o~ in ~eet Yi~dndi~:a~ee ~-~, DF etc.) 6. Lease de"~na~t~n a~i~er~ffn(Y.~' ;; .,~;,~a ~tl Kuparuk R~ver 0il Pool RKB 117', PAD 82' ADL 25569 ALK 2667 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500~000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 2T-16well 25' @ surface feet 16. Proposed depth (MD & TVD) 7732' MD~ 6i 69' TVD 18. Approximate spud date 03105186 14. Distance to nearest property or lease line miles 1045 feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 42 o (see 20AAC25.035 (c) (2) 19. If deviated (see 20 AAC 25.050) 2972 psig@___80°F Surface KICK OFF POINT 750 feet. 3413 psig@ 6021__ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE Hole 8'i/2" Casing 16" 9-5/8" 7'! Weight 62.5# Length 80' CASING AND LINER Grade Coupling H-40 Weld -55/HF-Ei~W BTC -55/HF-Ef'.W BTC SETTING DEPTH MD TOP TVD 35' 35' 36.0# 3171 ' 35' 35' I 26.0# 34 I I 34' 7698' MD BOTTOM TVD 115t 115' ! 32061 2811 , 7732~ 6169' QUANTITY OF CEMENT (include stage data) + 200 cf 970 sx AS III & 335 sx Class G blend 300 sx Class G 22. Describeproposed program: ARCO Alaska, Inc.~ proposes to drill a Kuparuk River Field development well to approximately 7732'ND(6169'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 2972 psi. 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. 2T-15 will be 25' away from 2T-16 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. (Contin~e~ on attached sheet) · 23. I hereby cer,~ that the foregoing is true and correct to the best of my knowledge // SIGNED / ~ ,-- ,- _-_ TITLE The spac~z~ow f~ ~/o~issiOn use Regional Drilling Engineer DATE CONDITIONS OF APPROVAL Samples required Mud Icg required [~YES ~O []YES ~O Permit number Approval date ~¢'b' ut~ 02/19/86 APPROVED BY Form 10-401 (LWK) ' PD/P-¢22¥ / Directional Survey required I APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE by order of the Commission _ February ]9; ]986 Submit in triplicate PERM IT TO DRILL 2T-15 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. ARCO ALASKA; '- PAD 2T. WELL .NO, 15 PROPEO.SED KUPARUK_FIELD NORTH _SLOP. ALASKA _. ' EASTMAN WHIPSTOCK. INC. SURFACE KOP TVD=750 THD=?50 DEP=O ............. 1000 ...................... ' 9 BUILD 3 DEO PER 1 O0 FT ...................... 21 BASE-PERMAFROST- TVD=1561 TMD=1588 DEP=18I 27 TOP UGNU SNDS TVD=I 706 TMD=1751 DEP=256 ' 2000 ..... 39- EOC --. TVD=2031 .... TMD=21 54 DEP=49:3-- · TOP ~ SAK SNDS TVD=2271 THD=2478 DEP=710 ~ ---K-12 TVD=2611 1HD=2936 DEP=IO18 c / 9 5/8" CSG PT m _ . 3000 .............. TVD=2811 THD=3206 DEP=1198 ~ 4000 ........ 5000 _ T/ ZONE C TVD=5831 .THD=7276 DEP=39.28~ ............ 6000. T/ ZONE A TVD=5900 THD=7369 DEP=3990 ·: 'TARGET CNTR' TVD=5926 TMD=7404 DEP=401 - ~ B/ KUP SNDS TVD=6021~ THD=7532 DEP=4100 - TD (LOG PT) TVD=6169 TMD=7732 DEP=4234 · ."'"""'_'.,,'uuu ' I i I ' 0 1000 2000 . 3000 4000 ' ' VERTICAL SECTION .... 5 TVD=4361 THD=5295 DEP=2599 AVERAGE ANGLE ' ....... _42. DE.G ..... 7 .... HIN kECEiVED I SO00 HORI 7-ONTAL PROJECT I Oki'. S..~E 1 IN. = 1000 FEET PAD 2T, WELL NO~ 15 'PROPOSED KUP,ARUK. _FIELD_:_ NORT, H:_S~.OpE.: .... ALASKA . · EASTHAN WHIPSTOCK._ '. . INC. '" ' WEST-EAST 000 0 1000 _ I I . _ .. . _ 1 000 .... '- 2000._ TD LOCAT ! OH ' 2000 ;~000 I J .... ............................ ~--': ............................ "S .... 6' DEC; :38-'HIN' E ..................... ........... ~' 401 4' (TO TARGET) TI'ID=?44>4. ...... , ..................... DE:P=4014 `3987 TAROE:T LOCAT!O#, ~4, ....... !.320'. FSL · ! 020;. FWL SEC. 12. T IIN. RBE 0 0 0 CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No... /~~ ITEM APPROVE DATE (1) Fee , · <2> Loc (2: thru 8) / / (3) Admin ~--. (9, thru 12) /' :: ! ./t' if...,". (10 and 12)' (13 thru 21) (5) (22 thru 26) 1. Is 2. 3. Is 4. Is 5. Is 6. Is 7. Is 8. Can permit be approved before ten-day wait . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. YES NO 27. the permit fee attached .......................................... ~__~.._~. well to be located in a defined pool ........................... r s ance rom ..... well located proper distance from other wells ......... sufficient undedicated acreage available tn this P°°i i : .... well to be deviated and is wellbore Plat included .. operator the only affected party ..................... REMARKS Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surfac~ ......... 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 ,,,,..., ........... , ................... z~ Are necessary diagrams of diverter and BOP equipment attached ........ //~ .... Does BOPE have sufficient pressure rating - Test to ~O~ psig .. :~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. . .... ~ Additional requirements Additional Remarks: J~v ~ Engineering: WVA ~ MTM ~ HJH,~--~ JAL ~_ ' rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE - LJ o ~ o KUPARUK RIVER UNIT 20" DIVEBTER SCHEMATIC DE SCR I P T I ON 6 I. IG" C~CTOR. 2. TAhI<O STARTER HEAD. 5. T ANKO SAVER SUB. 4. TAhI<O LOWER OUICK-C~CT ASSY. 5. TANKO UPPER OUICK-C~CT ASSY. AUT~TICALLY UPm CLARE ~ 8. 20" 2~ PSi A~LAR P~VE~ER. ,. ~. ~ (~,;I. ~4r~') ,r~~ ~ IWW! NTENANCE & OPERAT.! O__.~N ' I. UPON INITIAL INSTALLATION- CLOSE PREVENTER AND VERIFY THAT VALVES · -HAVE OPENED PROPERLY. , 2. CLOSE A~',~ULAR PREVENTER AND BLOW AIR THROUC~ DIVERTER LIliES EVERY 12 HOURS. 5, CLO~3E ANI'~LAR PREVENTER IN THE EVENT 'THAT AN IN:LUX OF WELLBORE " FLUIDS OR GAS IS DETECTED. IF · NECESSARY, · CLOSE APPROPRIATE VALVE TO ~ ACHIEVE DOWNWIND DIVERSION. RECEI.V D DO NOT SHUT IN ~L_L UNDER ANY CIRCUMSTA~ES. CON',FIn IT I~ ~"~ii~' ~!~,. ;,~ .'~ :~ 7 ] '1 6 DIAGRAM #1 .13 '8' '000 PSI RSRRA ~0c:' STACX 1, 16' - 2000 Ps]: TAN(CO STARTING If_AD 2, 11' - DC:OD PsI CA~ING t-F_AD 3. I1' - 3COD PSI X 13"'5/8' - 5090 PsI SPACER ~ 4. 13--5/8' - ~ Ps]: PII::~ ~ 5. 13-5/8' - 5000 PsI DRILLING SPOOL W/O~ZKE AND KILL LI~ES 6. 13-5/8' - 5000 PSI D(~ RA~ W/PIPE R~ CIN TCP, 7. 13-5/'8' - 5000 PSI AN~ ACCUMJLATOR CAPACITY TEST I. CHECX AAD FILL AC~TCR RESERVOIR TO'PR~ LEVEL WITR RYDRAII. IC ~UID. 2. ~ ~T A~T~ ~~ IS ~ ~I WI~ I~ ~I ~T~ ~ ~ ~~T~. 3. ~~ TI~, ~ ~ ~ ~ITS SIXThlY ALL ~ITS ~ ~~ WI~ ~I~ ~ ~. 4. ~~ ~ ~ ~T, ~ A~T~E L~ LI~IT IS ~5 ~~ ~I~ TI~ ~ ~ ~I ~INI~ P~~. 5 4 3 2 13-5/8" BOP STACX TEST 13, I. FILL BCP STAC~ AhD C~ ~IF~l~ WITH ARCTIC DIESEL. 2. C~ECX TNAT ALL LOC~ DC~ S~ IN t~E1.L~ AR~ FLLLY RETRACTED. SEAT TF_ST PLUG IN WITH RLI~RING JT AND R~N IN LC)(~ 3. CLOSE AN~ P~ At~D MANJAL KILL A~ CE;NE LI~E VALVES ADJACE]VT TO BCP STACX. ALL OTHER VALVES AND ~ SHCU_D BE CPEN. 4. PRE~ UP TO 250~ FOR I0 MIN. IN- CREASE PRE~ T0J~AN:) ~ FCR 10 MIN. BL-mFD PRE~ TO O-PSI. 5. OPEN AI'd',iA_AR PREVENTER A, hID MAI',IJAL KILL AhD CHO<E L.I~",E VALVES. CLCSE TCP P:IPE ~ AND HCR VALVES CN K,ILL AhD G-tC~E 6. TEST TO 2,50 PSI AN2~ :IN STEP 7. CX2NTI~ TESTING ALL~ACVES, LINES, A~ C~S WITH A 250 PSI LC~ AhD 3000 PSI HIGR. TEST AS IN STEP 4. DO bDT F~_~U~ TEST A~ (]-ICI<E THAT IS ~QT A FULL O-C~.~N~ POSITIVE SEAL CHOKE, Cr4.Y F~ICN TE57 (~$ THAI DO bDT FII. LY CLOSE. 8. ~ TCI~ PIPE RA~ A~ CLOSE BOT'FCM PIPE RA~. TEST BOTTC~ PIPE RA~ TO 2_50 PSI Ahl3 3000 P~I. 9. CPEN 60TTCI~ PIPE RA~o BACX ~ R~NNING JT AI~ .10. CLOSE BLIN3 RA~ AhD TEST TO 250 PSI AI~.3000 PSI. 11. CPEN BLII~D RA~ AI~ RETRIEVE TEST PLUG. ~ SURE I~IFOLD AhD LINES ARE FLLL. OF NCN-FREEZING. FLUID. SET ALL VALVES IN DRILLING POSITICI~ 1~- TEST STAN]PIPE VALVES, K~_I Y, KELLY COC~S, DRILL' PIPE SAFETY VALVE, AN3 INSIDE B~P TO 2,50 PSI AhD 3000 PSI. RECCRD TEST INFC~TIC~ QN BLC~ ~ TEST FCI~, SIGN, Ah~ SEN3 TO DRILLING SUPERVISDR. L CI:~ CO~ETE 0C~ TEST AFTER NIPPLING UP Aha) Y THEREAFTER F~IC~IALLY CPERATE BCI~ DAILY. s~ oo'~4oo~ R~'v. ~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2T Pad (Wells 2- 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 If JG/tw GRU13/L44 Enclosure CONFIDENTIAL RECEIVED ARCO Alaska, Inc. is ~ Subsidiary o~ AtlanticRichfieldCompanY t ' ·~ II'~ ~'F=' ~ · 14 , LOCATED IN PROT~ACTEO LOCATED IN ~ SEC. Iv TIIN~RBE~ U.M. SEC. I~ TIIN~RSE~ U.M. 2- Y = ~,970,382.43 LAT. 70~Z9'49.~287" ~0 - Y : 5,970,~32.65 L~T. 70~19'46.67Z9" X ~ 498,944.93 LONG.150o00'30.807" X = 498,945.~7 LONG.150°00'30.796" ~2' ~SL, 55~' F~L 0G = 77' PAD = 8~.5 152'FSL, 556' F~L ~ - 76.0 PAD = 8~.7 3 - Y = ~,970,3~7.42 ~T. 70~9'48.8828'' ~Z = Y = 5,970,Z07.7~ LAT. 70°Z9'46.4267" X = 498,944.91 LONG. 150~00"30.808" X = 498,945. ~0 LONG. 150"00' 30. 801" 377' ~SL, 55~' F~L 0G = 77' PAD = 8z.5 ~27' FSL, 556' F~L 0G = 75.9 PAD = 81.7 4 - Y = 5,970,332.46 LAT. 70~Z9'~.6~72" ~2 - Y = 5,970,082.58 LAT. 70~9'46. Z794" X = 498,944.84 LONG. ~50~00' 30.809" ~ " o X = 498,944.98 LONG. ~50°00' 30.804 352" FSL, 556' FWL OG = 77' PAD = 81.6 '~ 102' FSL, 556' FWL OG = 75.7 PAD = 81.7 5 - Y = 5,970,307.52 LAT. 70~19'48.3919'' ~ 13 - Y = 5,970,057.59 LAT. 70~19'45.9336' X = 498,944. gl LONG. 150°00' 30.808" ~ E X = 498,945.08 LONG. 150000, 30. 801" 327' FSL, 556' FWL OG = 77' PAD : 81.6 o 77' FSL, 556' FWL OG = 75.5 PAD - 81.6 6 - Y = 5,970,282.50 LAT. 70~19'~.1459'' ~ 14 - Y = 5,970,032 60 LAT. 70:19'45.6879" X = 498,944.95 LONG. ZSO~O0' 30.806'' ~ ~ ~ X = 498,944.9Z LONG. ~50"00' 30.806" 302' ESL, 556' ~NL OG = 77' PAD ~ 8~.7 ~ ~ ~ ~ ~ 5~' FSL, 556' FNL OG = 75.~ PAD = 8~.7 7 - Y : 5,970,257.54 LAT. 70°19'47.9003" ~ O ~ ~ 15 -'Y = 5,970,007.69 LAT. 70°19'45.4428'' X : 498,944.95 LONG. 150o00'30.806" ~ ~ ~ X 498,944 93 LONG. 150°O0'30.806" 277' FSL, 556' FWL OG = 77' PAD = 81.6 ~ 27' FSL, 556' FWL OG : 75.2 PAD = 81.6 8 - Y = 5,970,232.63 LAT. 70~19'47.6553'' .: 16 - Y = 5,969,982.85 LAT. 70~19'45.1985'' ' X = 498,944.96 LONG.150~O0'30.806'' ~ ~ ~ X = 498,944.88 LONG.150°O0'30.807'' - 252' FSL, 556' FWL OG : 76.9 PAD : 81.6 ~ 2' FSL, 556' FWL OG = 75.1 PAD : 81.7 9- Y : 5,970.207.62 LAT. 70°19'47.4093'' c~ LOCATED IN PROTRACTED x = 498,945.01 LONG. 150°00'30.804'' ~ SEC.I~ , TI I N~ RBE, U.M. 227' FSL, 556' FWL OG : 76.3 PAD = 81.6 17 - y : 5,969,957.72 LAT. 70°19'44.9514" X : 498,944.94 LONG. 150000. 30.805" 23' FNL, 556' FWL 0G : 75.0 PAD = 81.6 I. ALL COORDINATES ARE A.S.P.,ZONE4. ~ . 2. SECTION LINE DISTANCES ARE TRUE. ~:~:~:~ ~'~;' ].HORIZ, POSITIONS BASED ON TEME MON~ 2T-EAST, 2T-WEST ~ .2~;~IDDLE PER LHD'~'ASSOC. 4. VERT. POSITIONS BASED ON TBM's 2T-6 ~ NI9+75, Ell+ 52 PER F.R,B. 5.C.G. ELEVATIONS 'INTERPOLATED FROM S/C DRAWING CED- RIXX-~140 rev. CErTIFIC ~TE OF SURVEYOR: I HEREBY CERTIFY THaT I ~M PROPERLY - ~Eg)STERED ~ND LICENSED tO ~R~CTiCE L~ND ,, SURVEYING ~~N THE STATE OF ALASKA ~D THAT .11 SURVEYED FOR. __ ~ mmmmm ~ ~ KUPARUK PROJECT a""~""---'~''~'~ camm DRAWN WM U~iLL OI/E ~/ UUI~UU/U~ e = daaUb, ~,.,.,.,~z, AS- BUILT LOCATIONS ~5 Arctic Boulevard, Suite 201, Anchorage, Alaska 99503 [Is~LE N.T.S. 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. L.!S T~6~E VSRi=iC~TI~N L!STiN^ LV~, OlO.H~2~ YE~i~I~,IT.iJN: w LiST.iN5 ,~A G= i =ILE N&;4E :EDIT SERVICE N A :,q E : VERSION ~ : DgT' : qz~XiMUM LENGT~ : 1024 =ZLE TYPE : ~R=ViSUS ~!L:E : '4N ,= ,',i C O NT E N T S ',1 N = ,4 S 3 :,,t T E N T S Ty~,= O00 0 'D C.' 00 0 J 'U D 3 C', C O0 ,.,~. TY 0 J 0 S O0 0 0 :} 300 J 0 :D S. IZ: 014 002 004 .312 005 ,~ZTM~ C' f} ! IIII 05.5 05 05.5 CV~= 010 CO2 V~IFiCaTiON ~ iSTiNG ~,~G~ ~ ~:~ S C ~ L U M ~C E R 3 E R ::~ ::~ AL&SKA COMPU'TiNG T,~?iT~R ::~ WELL = 2T-I 5 =!ELD = ~UP~RUK ST~T:5 : ~LAS,<& JOS NU!qBER AT A ~: 71437 RUN ,~1, DATE LOGGED: LOP: R. KRUWEL~L CASING : '7.000" 9 7115' - :BIT SIZE : 6,125" TO 7525' TYPE :=LUiD : LSND DENSITY = 12.1 L~/G RM = 3.11 ~3 66 OF VISCOSITY : 39 $ q'",!~ : 2.57 ~ 66 3F PM = ~3.0 R~qC : 3.25 3 66 DF $LJID LOSS : 7 C3 RM ~aT 8HT : 1.~94 3 145 DF MATRIX SANDSTONE -~-~:::',~=::~',: TH~S,.~AT~ H.AS NOT $~Eq JcPTH SHI.. T~D - OV'mR'-.AYS F~ELD ~R~N'TS ,,. D~TA ~V~iL~LE: 't~2~' TO 71~' "' FOR'~T'IOX~ J=N~ITY ~O~z;'EN~,AT~ED LOG (;~N) <~ C3MPENS~T;D qEUT~N L~a ~: D~TA ~Va, ILABLE: 7501' TO 7128 .... · ,--,- DP,,T~ ENTRY BLOCKS MN=M S=RVI$E S-2ViC[ J"~iT ~o'l ~P! A~i ~Pi Fit~:: SiZE SPt R'P~ mROCfS< lC ORDER ~ LOG TYP~ CL~SS ~.~OO NO. CGO~ (OCT4L) D~PT ;t OO 000 09 0 0 4 I 5~ LVP OIO.MOZ V~R!~iCATiSN LiSTiNg O~GE ~ -,-"' :',: D .t T A :;-' :;: DE~T '7577,.5000 SFLJ SP -35.3533 SR ~H3~ 2.4163 OqH3 NP~I ~3.750S NCNL 3~PT 7500.0000 SFLJ SP -35.3533 SR RHJ5 ;2.3570 g~H2 NP~I 45.2143 NCN_ OEPT 7400.0300 SFLJ Sm -35.8533 G~ ~d35 2.3~3i D2q] NP¢Z 3~.~73 NCNL J E ~ T 7200. O 00 J S ~=LJ £2 '12 Ol 31 31 33 42 O0 ~3 115. 2251. 11 !. O. 2405. 6. 36. 29~! . !2. 55. ¢ '3 , Z ~ 3 9. 164. -~, 1457. 2. 15.55. 9005 7148 3303 6523 0308 Ol Oi Oi Ol 0 i 02 O! Ol O0 31 015 000 42,5 273 015 GOO 5 7.5 375 ill NR&T NR,AT iL2 F-CNL St Nq&T =CNL iLO NRAT iLL) 2.3515 3.37'33 2.&573 111.5523 3.4495 5.5554 4. '3125 iI.6~18 85.5273 2.2~95 1472.6~'75 1300. ~i25 i4.3513 15~.f5,15 4.0~32 i 58 I 85 00000000000000 i 83 i 8~ i 5S O000CO0000000O 1 5~ O00OO000000000 ! 58 O0000OOOOO0000 i 6¢ 00000000000000 i 5~ JO000000000000 1 5;~ O00OOOO0000000 i 55 O000OO00000OO0 I 58 00000000000000 ! 5~ 00000000000000 I 58 00000000000000 iLM 2.6732 CALl 5.0739 RN2i 13.88'7:0 i L:q 6. I 062 CALl 6.51£5 iL~ 35. C,~_i 5.5755 ~,. q~ A 2. 5352 5.2273 ~ ~ ~ I 2 J · 5 S 7. 5 5.2273 ILM 2.5 $ 62 C A L i 6.1 Z 57 ,--,- REEL SERVICE NSME :,EDIT IR 'IGiN : ~ONT!N~JATZON ~ :0i '~XT R~L NA:',I= : 'CMM:ENTS :LIBRARY TAP~