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Home My WebLink About212-095MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3N-11A KUPARUK RIV UNIT 3N-11A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 3N-11A 50-029-21580-01-00 212-095-0 W SPT 6168 2120950 1542 2935 2935 2935 2935 0 0 0 0 REQVAR P Bob Noble 8/25/2024 MIT-IA to max inj psi. as perAIO 2B.072 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3N-11A Inspection Date: Tubing OA Packer Depth 460 3500 3420 3410IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240827112932 BBL Pumped:2.8 BBL Returned:2.7 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 12:51:33 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, September 12, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3N-11A KUPARUK RIV UNIT 3N-11A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/12/2023 3N-11A 50-029-21580-01-00 212-095-0 W SPT 6168 2120950 3000 1250 1250 1250 1250 1 1 1 1 REQVAR P Guy Cook 7/23/2023 MITIA to maximum anticipated injection pressure per AIO 2B.072. Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3N-11A Inspection Date: Tubing OA Packer Depth 870 3310 3220 3210IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230722072624 BBL Pumped:2.1 BBL Returned:2.1 Tuesday, September 12, 2023 Page 1 of 1 9 9 9 9 9 9999 9 9 9 9 9 MITIA to maximum anticipated injection pressure per AIO 2B.072. James B. Regg Digitally signed by James B. Regg Date: 2023.09.12 15:19:38 -08'00' 1 Regg, James B (OGC) From:Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent:Friday, August 12, 2022 6:50 AM To:Regg, James B (OGC); Wallace, Chris D (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay Subject:KRU SW MITIAs Attachments:MIT KRU 3N-11 SI TEST 08-10-22.xlsx; MIT KRU 3N-16A 08-10-22.xlsx; MIT KRU 3Q-21 08-10-22.xlsx; MIT KRU 3R-11D and 3R-25 08-10-22.xlsx All, KRU SW MITIAs completed on 8/10/22. Please let me know if you have any questions. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2120950 Type Inj N Tubing 1985 1980 1965 1955 Type Test P Packer TVD 6168 BBL Pump 2.8 IA 290 3300 3250 3250 Interval V Test psi 3000 BBL Return 2.8 OA 0 0 0 0 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mec han ical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:MITIA to maximum anticipated injection pressure per AIO 2B.072 Notes: 3N-11A Notes: Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 3N Pad Hembree / Hills 08/10/22 Form 10-426 (Revised 01/2017)2022-0810_MIT_KRU_3N-11A MEMORANDUM To: Jim Regg ��:��(11,51� P.I. Supervisor t -Z FROM: Brian Bixby Petroleum Inspector I Well Name KUPARUK RIV UNIT 3N -I IA IInsp Num: mitBDB200816081915 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 18, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3N-1 IA KUPARUK RIV UNIT 3N -11A Src: Inspector Reviewed By: P.I. Supry -� NON -CONFIDENTIAL Comm API Well Number 50-029-21580-01-00 Inspector Name: Brian Bixby Permit Number: 212-095-0 Inspection Date: 8/15/2020 Tuesday, August 18, 2020 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well3N-IIA- — - Tubing' 2900 2900 2900 " 2900 PTD 2120950 Type Test' SPT Test Sl 3000 580 3500 3410. 3400 BBL Pumped: 2.7 - 11313L Returned: 2.7 OA o 0 0 1 0 Interval RHQvAR P/F - P- Notes: MITIA as per — AIO 213.072 v — Tuesday, August 18, 2020 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,August 08,2016 TO: Jim Reggl P.I.Supervisor t---0, SUBJECT:I/F!`�j SUBJECT: Mechanical Integrity Tests I/ CONOCOPHILLIPS ALASKA INC 3N-11A FROM: Bob Noble KUPARUK RIV UNIT 3N-11A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3N-I IA API Well Number 50-029-21580-01-00 Inspector Name: Bob Noble Permit Number: 212-095-0 Inspection Date: 8/1/2016 Insp Num: mitRCN160801173149 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3N-11A .- 6168 Inj W TVD 6168 Tubing; 2850 . 2850 . 1 2850 - 2850 . PTD 1 2120950 Type Test SPT Test psi 3000 • IA 3153400 3330 . 3320 Interval1REQVAR P/F P / OA o 1 - 1 0 Notes: MIT-IA per AIO 2B.072 to max injection pressure. 'SCANNED MAY 0 1 0,? Monday,August 08,2016 Page 1 of 1 ConocoPh i l l i ps Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 June 22, 2015 SCAMS J U L 1 6 2015 cQ I °'?g- Commissioner Cathy Foerster J L� Alaska Oil & Gas Commission 3 NI \. 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement(one with carbolite) and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, �f� at-1 MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 6/22/2015 1 E,1Y,2E,2F,2M,2N,2V,3N&3S Pads Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# , PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal 1E-32 50029227880000 1971320 15" na 15" na 1.8 6/18/2015 1Y-10 50029209340000 1830510 36' 3.70 13" 5/10/2015 4.6 6/20/2015 2E-02 50029235170000 2140780 9' 0.60 24" 6/14/2015 5.1 6/16/2015 2E-03 50029235090000 2132030 4' 0.62 7" 6/13/2015 3.9 6/16/2015 2E-04 50029235050000 2131680 10' 1.29 19" 6/15/2015 7.7 6/16/2015 2F-20 50029227390000 1970160 6' 0.80 13" 4/20/2015 3 6/20/2015 2F-21 50029223525000 2141360 22" 0.10 22" 4/25/2015 15.3 6/19/2015 2F-22 5002923530000 2141500 64" 1.10 17" 4/25/2015 11.5 6/19/2015 2M-36 50103206910000 2141020 8'7" 0.70 10" 5/23/2015 2.1 6/20/2015 2N-322 50103206780000 2131790 13" na 13" na 2.5 6/19/2015 2V-02 50029210370000 1831610 11" 1.00 14" 5/20/2015 2 6/16/2015 eo• 3N-11A 50029215800100 2120950 34' 27 cu.ft carbolite 10" 5/26/2015 2 6/18/2015 3S-620 50103206950000 2141670 6'3" 0.60 12" 4/26/2015 2.6 6/18/2015 STATE OF ALASKA AL, ,(A OIL AND GAS CONSERVATION COIF. 3SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r Other r Cond, .ameual Crq-oc.1— Alter Casing r Pull Tubing r Stimulate- Frac r Waiver r Time Extension r Change Approved Program rOperat Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name. 4 Well Class Before Work: 5 Permit to Drill Number ConocoPhillips Alaska, Inc. Development r Exploratory r 212-095-0 3.Address: 6 API Number. Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-21580-01 7. Property Designation(Lease Number). 8.Well Name and Number: ADL25512 ADL 25521 KRU 3N-11A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary. Total Depth measured 10923 feet Plugs(measured) None true vertical 6387 feet Junk(measured) None Effective Depth measured 10600 feet Packer(measured) 8153 true vertical 6387 feet (true vertical) 6184 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 1640 630 WINDOW AL2-01 6 8 8483 3632 3520 2020 PRODUCTION 8470 7 8500 6429 4980 4330 6464 7780 6350 SCANNED f4k 1 8 2015E F J V D Perforation depth: Measured depth. 10441-10600 True Vertical Depth: 6390-6387 MAY 0 5 2015 Tubing(size,grade,MD,and ND) 3-1/2, L-80, 8173 MD,6329 ND AOGCC Packers&SSSV(type,MD,and TVD) SEAL ASSY- BAKER 80-40 SEAL ASSEMBLY FOR SBE HALF MULE SHOE @ 8153 MD and 6184 TV[ SAFETY VLV-CAMCO TRMAXX-CMT-5-SR SAFETY VALVE @ 1796 MD and 1731 ND 12 Stimulation or cement squeeze summary NA Intervals treated(measured). Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation NA 14 Attachments 15.Well Class after work. 1 Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16 Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt 314-346 _ Contact MJ Loveland/Martin Walters Email n1878@cop.com Printed Name MJ Loveland Title Well Integrity Project Signature 9 Phone:659-7043 Date 7/ rit."--4- effiC9-V/5--- VrL- 5-714111,-- RBDMBak MAY - 6 2015 Form 10-404 Revised 10/2012 ij f/L{,' Submit Original Only ~v • • ConocoPhillips RECEIVED Alaska P.O. BOX 100360 !At, 0 5 2015 ANCHORAGE,ALASKA 99510-0360 "� AOGCC May 03, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 3N-11A, PTD 212-095-01 conductor removal, casing inspection, and conductor replacement. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, czo,...c./, MJoveland Well Integrity Projects Supervisor ConocoPhillips 3N-11A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary Summary-Surface casing inspection using LRUT, Boroscope and MID log. 06/05/14 Initial T/1/O= Si1750/0/0. Made two vertical cuts on previously Wach's cut conductor to expose SC. Total piece of conductor removed was 20.5". TOC=-36'. Final T/I/O= Si1750/0/0. 06/06/14 Initial T/I/O= Si1800/0/0. Set up and installed LRUT machine on SC. Took multiple shots collecting data at different frequencies. Set up 2nd LRUT machine and repeated same steps. Waiting on data results. FL in conductor @ 21.25'. Final T/I/O= Si1800/0/0. 06/14/15 Boroscope inspection with N2 - FL @ 24' 06/17/14 remove more fluid,Found leak at 24'4" 01/12/15 Ran TGT MID log 3 passes 300 ft to surface 02/02/15 Removed fluid in conductor to 34' 04/04/15 T/I/O=2885/200/0. Used bore scope to inspect SC for damage and leak. Damage was found at 16', a leak at 24'4"and more damage at 26' 9". TOC= 34'. 04/30/15 Welded 16"X .375"wall X 65 replacement conductor onto exisiting conductor. �., • s' i it .n q • .,*--- .'•:44.4-i•--• -------• -- -- :' "...••-,•""":"•:•:.::•••,•:4.m.,..-••• • - ' '.,, ' •,... ...:::•;-••.---.-,,,,-,,,,•-.g.,i-i,q1P1.4',1!:-.:Ii!,:.-7.:.::'.1;,..• •• ., T.- ... r .•:.--,.:,.„,;',1;,- ''.;:i.,.•-• .,04.1gmil: 7 "� a+ . r • s3a:' N 'rte 1*.«,:':.:.----...::.,-'4L,:',...4i4t.A.A•."'•.:`- --••*'.4'.'•:',"','''.1'!!!'•'•.14..-,.-:,F,'",•`: 4--:-•:iidg-ii-f.11 ',1-; ••:::•:••---:::••••A4)44-4°•40:Ii.:'1:11.!tiV . 144.......„,:W11-1;:•,„„!""iii:E:7:1...--:T. illill„:•::j1w-.„„ • a "� res •$"+ ' "x ff �• s �,' 'i At ;: + ■ 5 v pr .il oma . ,, a. LC) to CO 1;D a; z ert 44. ..._, . s,, iTt (D . -ict: .-: To, -4--' 0 < ' O L c) 4-:^4.--it— ---Cf) . ' Nom- U � �' � - •lif 0 U o k' r„ 1 U — CU O �- 0 (J, . 4 .,� s` » E . . ...... . 1:,•.14.41E... ..•.••.7.q!..•i•';:.7.',P. s k i 6• i -,- = , Fi. f 1 0 r :: ter ;. � ; = p-t V m41, � ii :. • :',.,-.-,,,46,..1,:..-.4,B..........,:,. :...,,-.-:,. . - 6..,-;', 1,4i.,-Mi...:'....'.:::: '1, ut 8 ■ • a 0 — w„ L.(') to ` 't, *— — -... fl PI' --: -,:' 4••• .. r. s- i f,, — Cl cu „,.. .4.if••,. „-P.,.?-,f• ..4,f, f4a...,... • ,, CIS . t ,t Ho- oro UO N O O _4 . Q c.a c� c) � C � o � "' oo KUP 3N-11A ConocoPhillips , Well Attributes _ Max Angle&MD TD Alaska,Inc, Wellbore API/UWI Field Name Well Status Incl 1^) MD(ftKB) Act Btm(ftKB) c.«oeaFtnilips 500292158001 KUPARUK RIVER UNIT INJ 99.52 9,880.48 10,923.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date ••• Well Confg:'DEVIATED-3N-11 A,Z27/20132:30:48PM SSSV:TRDP Last WO: 1/12/2012 39.49 4/13/1986 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WELL H^ REVIEW osborl 2/27/2013 HANGER,24. Caslflg"SSF ig0 1 Wi& 4,A:iEa&1&ad d lana ,.,,,,64,1b,�,: u w, nom;, CasingDescription String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)... String Wt...String...String Top Thrd CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing DeecripSon String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd r SURFACE 95/8 8.765 35.0 4,558.0 3,631.7 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd 2 } WINDOW AL2-01 8 6.000 8,477.0 8,483.0 6,416.8 26.00 Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd ssa, PRODUCTION 7 6.276 30.4 8,500.0 6,428.9 26.00 J-55 BTC ata POST S/T Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd CONDUCTOR, SCAB LINER 4 12 3.476 8,130.2 8,625.2 6,464.2 11.60 L-80 BTC 36-715 -- Liner Details atI Top Depth SAFETY VLV, (ND) Top Incl Nomi... 1,796 -rt '' Top(ftKB) IRKS) (^I Item Description Comment ID(in) IR 8,130.2 6,168.5 45.36 PACKER BAKER C2 ZXP LINER TOP PACKER 4.400 IS 8,150.5 6,182.7 45.30 HANGER BAKER HYDRAULIC FLEXLOCK HANGER 4.320 8,160.3 6,189.6 45.28 SBR BAKER 80-40 SEAL BORE EXTENSION 4.000 GAS LIFT, ar Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd 2'908 LINER A 2 3/8 1.992 10,430.1 10,600.0 6,386.9 4.70 L-80 STL a,a. Liner Details "4"1"1'1'iligiiiiiiiiingi Top Depth, (TVD) Top Incl Nomi... Top(ftKB) (ftKB) El Item Description Comment ID(in) 10,430.1 6,390.1 91.37 BILLET OH ANCHORED BILLET 1.000 SURFACE, A Tubing Strings 35-4.558 Tubing Description String 0... String ID...I Top(ftKB) Set Depth(f...Set Depth(ND).. String Wt.. String... String Top Thrd TUBING WO 3 1/2 2.992 I 23.6 8,173.4 6,198.8 9.30 L-80 EUEBrdABMOD GAS LIFT, IV Completion Details 5,099 Top Depth (ND) Top Incl Nomi... ,; Top(ftKB) (RKB) l°) Rem Description Comment ID(In) 23.6 23.6 -0.06 HANGER TUBING HANGER&PUP 3.500 1I 1,796.3 1,730.8 34.83 SAFETY VLV CAMCO TRMAXX-CMT-5-SR SAFETY VALVE 2.812 GAS LIFT, 6.571 1 8,081.1 6,133.7 45.19 NIPPLE CAMCOX NIPPLE 2.812 '- 8,128.1 6,167.0 45.36 LOCATOR LOCATOR SEALS 7'OUT 2.970 _ 8,153.0 6,184.4 45.30 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY FOR SBE HALF MULE SHOE 2.990 8,172.9 6,198.4 45.24 WLEG 2.990 GAS LIFT, 7.524 Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) Ir Top Depth (TVD) Top Incl Top(ftKB) (RKB) (") Description Comment Run Date ID(in) '., 8,470.0 6,408.8 44.79 WHIPSTOCK WHIPSTOCK FOR'A'SIDETRACK,BAKER THRU-TBG 7/25/2012 GAS UFT. GEN II 8,052 11 Perforations&Slots NIPPLE 8,081 Shot Top(ND) Btm(TVD) Dens Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (sh.- Type Comment IF 10,441.5 10,599.6 6,389.9 6,386.9 A-2,3N-11A 8/1/2012 32.0 SLOTS SLOTTED LINER Notes:General&Safety LOCATOR. End Date Annotation 8,120 11/16/2007 NOTE:WORKOVER 1/15/2008 NOTE:WAIVERED WELL-OA x ATMOSPHERE COMMUNICATION i-_- I2242012 NOTE:APPLY 5500 PSI TO CONTROL LINE TO KEEP TRMAXX FULLY OPEN 8/21/2012 NOTE:WELL SIDTRACKED A,AL1,AL2,AL2-01,AL3(AL2-01 off main wellbore-see Multi-lat Drawing) SEAL A8.153SSY, ,NE6 b WLEG.8.173- I APERF, 8,4208.435 WHIPSTOCK. 8,470 WINDOW AL2-01, 8,477-8.483 Mandrel Details "6 L Top Depth Top Port PRODUCTION S... (ND) Incl OD Valve Latch Size TRO Run POST SIT. N...Top(ftKB) MKS) (°) Make Model (in) Sem Type Type (in) (PO Run Date Com... 30-8,500 1 2,907.9 2,491.0 46.34 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 2 5,099.0 4,001.6 4628 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 10/8/2012 3 6,570.7 5,055.9 42.98 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 4 7,523.7 5,741.2 45.23 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 5 8,052.1 6,113.3 45.23 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 2/102012 SCAB UNER, 8,1308,625 SLOTS, 70,44NER A, LINER A 10.430.10.600 N 1 TD(3N-11A), 10.923 2. 22O05 Z (4:761 I I �0 oiAqNos,;� RECEIVED 44' `r4 APR 0 9 2015 I 75. AOGCC ; „7" ''' 461 ,,,,1 PROACTIVE DIAgNOSTIC SERVICES WI. I MID REPORT 3N - 11A Single Completion I Injector 0.111. Conoco Phillips Alaska, Inc. i Company: Conoco Phillips Alaska, Inc. Country: USA 1 Field: Kuparuk Logging Date: 12—Jan—2015 I 1 SatiNED MAY 0 8 2015 1 b it74...1 it I int lik iJitiItI Company: ConocoPhillips Alaska,Inc. ' Field: Kuparuk Service: MID Well: 3N 11A 1St Barrier: 3.5"9.3#L-80 Tubing ConocoPhillips Log Date: 2015-Jan-12 2nd Barrier: 7"26#J-55 Casing 3rd Barrier: 9 5/8"36#J-55 Casing DATA RECORDED BY Bob Suhanek ' ANALYST Alfiia Gabdrakhmanova ' REVIEWED BY Matthew Lawrence, Maxim Volkov ' Interpretations made by TGT OILFIELD SERVICES at the request of ConocoPhillips are based on information provided to TGT OILFIELD SERVICES by ConocoPhillips. All conclusions and recommendations were produced using measurements and ' empirical relationships and assumptions. All representations and warranties, expressed or implied, in respect of this report are hereby excluded. TGT OILFIELD SERVICES cannot, except in the case of negligence on part of TGT OILFIELD SERVICES, be held liable or responsible for any losses, costs, damages or expenses which might be incurred by anyone in relation to the contents of this report. r I Page 2 of 27 I ` 1 I I Company: ConocoPhillips Alaska,Inc. I Field: Kuparuk Service: MID 6 1 1 Well: 3N 11A 1s`Barrier: 3.5"9.3#L-80 Tubing ConocoPhillips Log Date: 2015-Jan-12 2"d Barrier: 7"26#J-55 Casing I3rd Barrier: 9 5/8"36#J-55 Casing CONTENTS I 3 CONTENTS 4 EXECUTIVE SUMMARY 6 Fig. 1 9 5/8" Casing Joint#1—Metal Loss I7 Fig. 2 9 5/8" Casing Joint#2 —Metal Loss 8 Fig. 3 9 5/8" Casing Joint#3 —Metal Loss 9 Fig. 4 9 5/8" Casing Joint#6—Metal Loss I10 Fig. 5 7" Casing Joint#2—Casing Corrosion with 23%and 20%of Metal Loss 11 Fig. 6 7" Casing Joint#2—Casing Corrosion with 21%of Metal Loss I 12 Fig. 7 7" Casing Joint#5—Casing Corrosion with 20%of Metal Loss 13 Fig. 8 Tubing Joint#1.4—Tubing Corrosion with 20% of Metal Loss 16 SURVEY RESULTS I16 Fig. 9 Magnetic Imaging Defectoscope within Interval 20—330 ft—3rd Pass 17 Fig. 10 Magnetic Imaging Defectoscope within Interval 20—330 ft—1st Pass I 18 Fig. 11 Magnetic Imaging Defectoscope within Interval 20—330 ft—2nd Pass 19 ATTACHMENTS 20 SEQUENCE OF EVENTS I 22 WELL SCHEMATICS (Provided by Client) 23 ABBREVIATIONS 24 QUALITY CONTROL I 26 TGT MID LOGGING TOOL STRING SCHEMATIC 27 DESCRIPTION OF LOGS I II Page 3 of 27 f I I I I I I Company: ConocoPhillips Alaska,Inc. I Field: 1st KuparukService: MID Well: 3N 11A 1st Barrier: 3.5"9.3#L-80 Tubing 'IP-' Log Date: 2015-Jan-12 2nd Barrier: 7"26#J-55 Casing I 3rd Barrier: 9 5/8"36#J-55 Casing EXECUTIVE SUMMARY IOBJECTIVES • To identify metal loss(corrosion)in the 3 1/2"tubing(first barrier) I • To identify metal loss(corrosion)in the 7"casing behind the 3 1/2"tubing—total metal content loss • To ascertain the 9 5/8"casing conditions below the known leak at approximately 23'below surface IFINDINGS A Magnetic Imaging Defectoscope (MID)survey was run in 3N-11A to identify the metal loss* in the 3 1/2"tubing and in the 7"casing behind the 3 1/2"tubing. MID data indicates the 3 1/2"tubing and 7"casing appears to range Ifrom good to poor condition in the surveyed interval. Metal loss* from 6%to 20% is recorded in the tubing and from 12%to 23%in the casing. IThe MID-2M tool cannot provide quantitative analysis of the third barrier. However, the tool operates in a way that magnetic responses from the third barrier may be recorded in the late time channels of the 13" long sensor, evident by the presence of raw amplitude increases at late channel times correlating with third barrier collars. I According to the 47th far response channel several suspect corroded zones in 9 5/8" casing are detected (see the table below). INo particularly specific deviation from the raw amplitude corrosion baseline is detected at approximately 23' below surface (^'47 ftKB), in the vicinity of a known surface casing leak. It is probable that due to the broadly distributed nature of corrosion in the surface casing immediately below surface that the relative volume of metal Iloss at the leak source is not significantly greater than the volume of metal loss in the vicinity, so that no single event stands out from the baseline. IWhile the overall raw amplitude trend across the log interval indicates a nearly vertical corrosion baseline for each casing joint, the first casing joint has a sloping trend (see track "FR47" on page 16). This slope in the raw I amplitude may be induced by a decrease in overall metal volume, which would match the historical pattern of heavily corroded surface casing indicated in other excavated wells in this field. By extension, this would suggest the heavy damage to the surface casing may extend as far as approximately 54' below surface (77 ftKB), although I additional suspect corrosion zones in the surface casing are recorded below this depth. 9 5/8" CASING MAXIMUM METAL LOSS EVENTS IJoint Number Suspect Corrosion Depth What page in this report? (ftKB) Tabulation Log Plot 1 36.6 15 6 1 75.3 15 6 2 79.6 15 7 2 81.7 15 7 I 3 126.2 15 8 3 141.3 15 8 6 259.4 15 9 I go 1 I Page 4 of 27 1 / ` / 1 A, I Company: ConocoPhillips Alaska,Inc. I Field: Kuparuk Service: MID lat Well: 3N-11A 1st Barrier: 3.5"9.3#L 80 Tubing ConocoPhillips Log Date: 2015-Jan-12 2"d Barrier: 7"26#J-55 Casing I3rd Barrier: 9 5/8"36#1-55 Casing 7" CASING MAXIMUM METAL LOSS EVENTS I Joint Number Metal Loss* Max.Metal Loss Depth What page in this report? (%) (ftKB) Tabulation Log Plot 2 23 81.5 14 10 I 7 21 278.7 14 11 2 20 80.4 14 10 5 20 199.7 14 12 I 3 1/2"TUBING MAXIMUM METAL LOSS EVENTS Joint Number Metal Loss* Max.Metal Loss Depth What page in this report? (%) (ftKB) Tabulation Log Plot I 1.4 20 81.8 14 12 * - Metal loss is averaged circumferentially and along the tool's sensor length, which is 5 in. for the tubing and 13 in. for the casing. I II 14 i I Page 5 of 27 I iii I Company: ConocoPhillips Alaska,Inc. I tat Field: KuparukService: MID Well: 3N 11A 15I Barrier: 3.5"9.3#L 80 Tubing ConocoPhillips Log Date: 2015-Jan-12 2"d Barrier: 7"26#J-55 Casing I 3rd Barrier: 9 5/8"36#J-55 Casing Fig. 1 9-5/8" Casing Joint#1—Metal Loss IField : Kuparuk Date of survey :01/12/2015 I Well : 3N-11A Date of interpretation :01/15/2015 Completion : Single Completion Injector Survey : MID logging I Depths : measured from RKB NEAR DELTA 31/7 TUBING FAR DELTA 7•CASING DEPTH _1 i • 1 VN Thickness 1 NR 26 WELL -1 0 A 1 V/V Thickness 2 FR 41 FR 47 ft 0_175i 75 ms 58.2 0 in 05 6.5 mV 85 SKETCH 2.37 ms 274 0 in 0.8 3 my 5 0 mV 0.6 I — .111118110-- .c. 1. p ` r 30 �kill, - ---e. ‘...7,1 ....."' _.—. . I - C. . , - -. 31/2"i tubing 7" asing thickness thi ness 40 )I — - CLI CL C cLi Tubing corrosion line,I Tubi g co r-osien line .1 - - 9 5/8" asing corros n fine . I _ _ i 7' Casing gorolien line .. !.. i.... 50 u 3I/2"tubin ii casing I I 9 5/8"Cas' g Corrosion;'aseline I \/ g r - 9 i 8"casing 60 I I I I _ G 0 — OF 7"Casin co lar I I I",4.11110111 _ . 1 .481111111111 70 Tubingcollar __ ; I \ 1-' } II - ■ 5106 r` IP ■ 10-20% _ 1 ■ >20% I iPage 6of27I I I Company: ConocoPhillips Alaska,Inc. I �� Field: Kuparuk Service: MID 15S Well: 3N 11A Barrier: 3.5"9.3#L-80 Tubing ConocoPhillips Log Date: 2015-Jan-12 2"d Barrier: 7"26#J-55 Casing I 3rd Barrier: 9 5/8"36#J-55 Casing Fig. 2 9-5/8" Casing Joint#2—Metal Loss I Field : Kuparuk Date of survey :01/12/2015 Well 3N 11A Date of interpretation :01/15/2015 Completion : Single Completion Injector Survey : MID logging I Depths measured NEAR DELTA 31/T TUBING FAR DELTA DEPTH _1 I1 VNThickness 1 NR 26 WELL -1 I A 1 y/y ThickCASINGness :7 2 from RKB FR 41 FR 47 fl 075 ms 56.2 0 in 05 6.5 mV 9.5 SKETCH 2.37 ms 274 0 in 0.8 3 mV 5 0 mV 0.6 Itilliiii, ,...,.., t Bo 31/2" ubing r ,, ; 7„ •.i:sing 1 -I thick ss - it,,,,, . th kness ; - -01) 4411P- - , 1 , , I � I , I ' J 9 5 ng cqr..Bions -ra 1 Tt bi c� psi an line ' 3 � Tubing corrosion line '� ! 7' Casing r±orhoSion line )/ S 40 I II • r ; - - � • w ' I — — • 44 I100 3 1/2"tubing _ 7' casing , �_. - ), \ , • - 1I ' -I 9 0/8„casilhg I 110 . i I I I • � ' I it411044 ' • I i - - ) i -:›_ - -0 . 5-10% 13.----- .-i — I 120IV I -I _ ' ` • 10-20% ■ >20% - 1 f 4 II f 1 S> 40 lPage 7of27I dF.L.l I I Company: ConocoPhillips Alaska,Inc. Field: Kuparuk Service: MID Well: 3N 11A 1St Barrier: 3.5"9.3#L-80 TubingConocoPhillips Log Date: 2015-Jan-12 2"d Barrier: 7"26#J-55 Casing I 3rd Barrier: 9 5/8"36#J-55 Casing Fig. 3 9-5/8" Casing Joint#3—Metal Loss I Field : Kuparuk Date of survey :01/12/2015 Well 3N 11A Date of interpretation :01/15/2015 Completion : Single Completion Injector Survey : MID logging I Depths : measured from RKB NEAR DELTA 3 112"TUBING FAR DELTA r CASING DEPTH _1 411 VN Thickness 1 NR 26 WELL _1 1 WV Thickness G2 FR 41 FR 47 ft 075 ms 56.2 0 in 0 5 6 5 mV 9 5 SKETCH 2.37 ms 274 0 in 0.8 3 mV 5 0 mV 0.6 I 120 I II ` f. \ -31/2" ubing 7"c �., sing thickn ss �l thic ness . ilk 0, 411100, ; ' 130 Tubing Corrosion line Tubing corrosion line 9 5/8" asing corrosion line 4. 7"Casing dorfoWan line ' 9 .J8"Casing '.rrosions 1 - - 140 ( '411.144/ . -- ■ _ , l 1 1 } 3,1/2"tubing 7 casing R I 9 5/8' Am 150 t r■I �I w► — ......... i e I I I 1111 _ # . l 1 • 5-10% 180 j I I * 10-20% ' 1 ;•.r r I ■ >20% � ,,n !:11,1 1 Page 8 of 27 I s i1 I Company: ConocoPhillips Alaska,Inc. I Field: Well: Kuparuk Service: MID Q. fir.: 3N 11A 1St Barrier: 3.5"9.3#L-80 TubingConcscoPhillips Log Date: 2015-Jan-12 2nd Barrier: 7"26#J-55 Casing I 3rd Barrier: 9 5/8"36#J-55 Casing Fig.4 9-5/8" Casing Joint#6—Metal Loss I Field : Kuparuk Date of survey :01/12/2015 Well 3N 11A Date of interpretation :01/15/2015 Completion : Single Completion Injector Survey : MID logging I Depths : measured from RKB NEAR DELTA 31/2 TUBING FAR DELTA G DEPTH -1 t VN Thickness 1 NR 26 WELL t • 1 y!y Thick7'CASINness 2 FR 41 FR 47 ft 075 ms 562 0 in 0.5 6.5 my 9.5 SKETCH 2.37 ms 274 0 in 0.8 3 mV 5 0 mV 0.6 Ilk . 1 31911111 27 :t3h,..,,2" ubing7"cas1ing :ss i thickness e - t- I 1M , I 1 ' 4 - 250 Tubi g Forrosion line Tubi v c• lesion line 9 5/S" asing corrosion line 1 =-- 7" Casing Corm;ion line -_ e I I I - - 260 �� " , c 1 _ ' 1 2"tubi " / � casing 5/8 Casing• orrosion I i _ \ Z 9 5/8"casing \-_________ I - 1114 1 270 . r.------- . l I I a. 4 lifir I I ■ 51056 �.1veil. * ■ 10-2056 i c 11 ■ >2056 Ia 140 1 qii I Page 9 of 27 I I ,• I I . . . Company: ConocoPhillips Alaska, Inc. Field: Kuparuk Service: MID Well: 3N 11A 1St Barrier: 3.5"9.3#L-80 TubingConocoPhillips Log Date: 2015-Jan-12 2nd Barrier: 7"26#J-55 Casing I 3rd Barrier: 9 5/8"36#J-55 Casing Fig. 5 7" Casing Joint#2—Casing Corrosion with 23%and 20%of Metal Loss I Field : Kuparuk Date of survey :01/12/2015 Well 3N 11A Date of interpretation :01/15/2015 Completion : Single Completion Injector Survey : MID logging U Depths : measured from RKB NEAR DELTA 3 12"TUBING FAR DELTA 7"CASING DEPTH _1 1 VN Thickness 1 NR 26 WELL .1 1 V/V Thickness 2 FR 41 FR 47 ft 0.75 ms 56.2 0 in 0.5 6.5 mV 9.5 SKETCH 2.37 ms 274 0 in 0.6 3 mV 5 0 mV 0.6 II eft 1 31/2" ubing I 7„cas` g I ♦ lap thickn:ss tithickn � I III I C 1 f II 80 * - 1 1 ' 'f �,i 7"Casingcorrosion wit 1 7 iii JGMl r � P OP �f 23h and l metal loss _ .. 1 _ Tubing Corrosion lineubi-g car•esi on line 9 5/8„ using corrosi I line 90 Casing<or 7 ' rosioW line I. - 1 . • • I _ _ois I „Ilk iti JI t1 I! _.... -........... ..._ „ ,,,, e. 100 ..�.. 3 1/2”to rig ;2 sing I Ns* ort l i5/E"casing ' 1 )r 1 1 1 ■ 5-10% 110 ; 10-20% ■ >20% I tot go ! Page 10 of 2714 , t ' 1 i 1 Company: ConocoPhillips Alaska,Inc. I Field: Kuparuk Service: MID Well: 3N-11A 15S Barrier: 3.5"9.3#L-80 TubingConocoPhillips Log Date: 2015-Jan-12 2nd Barrier: 7"26#1-55 Casing 1 3rd Barrier: 9 5/8"36#J-55 Casing Fig. 6 7" Casing Joint#7—Casing Corrosion with 21%of Metal Loss IField : Kuparuk Date of survey :01/12/2015 Well : 3N-11A Date of interpretation :01/15/2015 Completion : Single Completion Injector Survey : MID logging I Depths : measured from RKB _ NEAR DELTA 3 112"TUBING FAR DELTA 7"CASING DEPTH -1 i • 1 vN Thickness 1 NR 26 WELL _1 1 t■ 1 VN Thickness 2 FR 41 FR 47 ft 0.75 ms 562 0 m 0.5 6.5 mV 9.5 SKETCH 2.37 ms 274 0 in 0.8 3 mV 5 0 mV 0.6 I _ 7 , - - 3 1/2" ubing 7"casing 1 I thickn ss I +� thickness I • j 4„ . ...r � � I ,-- i ii I 280 -- I 7"-Casing orrosion wi 21A meta loss I 4 I 11 2 1 I ' ' Wi t 1I * ,, , d -TubingCorrosion line Tubirgcar'esion me I i ►- I 9 5/8" asing corrosion line 1 - , 7"C sing Corrosion line I - -I A 30e i ■ ' I 1 1r'.` 3 1/2"tubing ,,,c, i„e f"`°11” , 1 - 1 1 l 310 ' T 1IlitS 5/8"casing wewilat .1:';71A 4.4. 1 I r • 5-10% 1 ■ 10-20% ' I ■ >20% 1 1a ii I Page 11 of 271 MI' II - Company: ConocoPhillips Alaska,Inc. I Field: Kuparuk Service: MID Well: 3N 11A 1st Barrier: 3.5"9.3#L-80 TubingConocoPhillips Log Date: 2015-Jan-12 2"d Barrier: 7"26#J-55 Casing I 3rd Barrier: 9 5/8"36#J-55 Casing Fig. 7 7" Casing Joint#5—Casing Corrosion with 20%of Metal Loss IField : Kuparuk Date of survey :01/12/2015 Well : 3N-11A Date of interpretation :01/15/2015 Completion : Single Completion Injector Survey : MID logging I Depths : measured from RKB NEAR DELTA 3112"TUBING FAR DELTA 7"CASING DEPTH .1 ,I 1 VN Thickness 7 NR 26 WELL .1 I i i VN Thickness__2 FR 41 FR 47 ft 0.75 ms 56.2 0 in 0.5 6-5 mV 9.5 SKETCH 2.37 ms 274 0 in 0.8 3 mV 5 0 mV 0.6 d{ ii ii - 3 1/2"'tubing 7"�:casing 11 thickness t thickness D , i I 200 4i, I T,fit I — ` ai : l`) , ` 4003, / 1. __ i 7"Casing,corrosion wit . II 20%meta loss - - I, t______ if ) J 210 0 lentil* 1111111 '' 1 r 1 I i ori s p I -Tubing corrosion line -ubi;c• f Psion line ilil" 9 5/8" asing corrals"ion line - - 7"Casing 'or'onion line tipI ) r 220I 000, 10 { ., I 331/2"tubin; ' "casing .60 r — 19 5/8"casing I I 230 r qt tI Y t - - .a. • 5-10% I ' • i _ _ a ■ 10-20% ■ >20% I l I 1 • Ar Y s 1 Page 12 of 271 Irl i� 1 Company: ConocoPhillips Alaska,Inc. I / ` Field: Kuparuk Service: MID ✓ (\ . l Well: 3N 11A 151 Barrier: 3.5"9.3#L-80 Tubing ConocoPhillips Log Date: 2015-Jan-12 2nd Barrier: 7"26#J-55 Casing I 3rd Barrier: 9 5/8"36#J-55 Casing Fig. 8 Tubing Joint#1.4—Tubing Corrosion with 20%of Metal Loss IField : Kuparuk Date of survey :01/12/2015 Well : 3N-11A Date of interpretation :01/15/2015 Completion : Single Completion Injector Survey : MID logging I Depths : measured from RKB NEAR DELTA 312 TUBING FAR DELTA 7"CASING DEPTH -1 11 :i 1 VN Thickness 1 NR 26 WELL _1 { I 1 VN Thickness 2 FR 41 FR 47 ft 0.75 ms 562 0 in 0.5 65 mV 9.5 SKETCH 2-37 ms 274 0 in 0.8 3 mV 5 0 mV 0.6 -* I i 114 _____ 31/2"tubing v • 7"casing thickn ss / / thickness I 1 .......... . 70 -11- I I 1/ I 2r1 Tubing corrosion line -ubiigcar'osim line 1 i 9 5/8" asing corrosion me 7'Casing orrotion line 11: 1 -r 1 C re...„, I 1(4 rigs- ,_ __ f I Tubin:corrosion, ,r--- B •r --with \ I ' \L rr F I i ilfr ' 3 1/2"tubin; 7' Asing -35 r- i I \ .14 { 9:/8"casing �� 1 ■ 5-10% ' i ■ 10-2056 I ■ >20% 90 _ _ I 1 II11, Til I Page 13 of 271A' I ii Company: ConocoPhillips Alaska,Inc. I Field: Well: Kuparuk Service: MID Nov3N 11A 1st Barrier: 3.5"9.3#L-80 Tubing ConocoPhillips Log Date: 2015-Jan-12 2nd Barrier: 7"26#J-55 Casing 3rd Barrier: 9 5/8"36#J-55 Casing First Barrier: 3.5"Tubing Joint Tabulation Report I Joint Top Bottom Condition Max.Metal Loss Depth Metal loss* Number (ft) (ft) (ft) (%) 1.1 23.6 65.7 I 1.2 65.7 73.9 corroded 67.3 6 1.3 73.9 77.6 1.4 77.6 86.0 corroded 81.8 20 2 86.0 116.9 I3 116.9 147.9 corroded 125.3 11 3 corroded 140.9 11 4 147.9 178.1 corroded 171.3 11 IS 178.1 209.0 corroded 199.9 10 6 209.0 238.0 7 238.0 268.8 corroded 247 9 I 7 corroded 262.6 7 8 268.8 299.4 corroded 290.3 13 ISecond Barrier: 7"Casing Joint Tabulation Report Joint Top Bottom Condition Max.Metal Loss Depth Metal loss* Number (ft) (ft) (ft) (%) I 1 30.4 69.8 2 69.8 109.6 corroded 80.4 20 2 _ corroded 81.5 23 I 2 corroded 92.8 17 3 109.6 151.2 corroded 124.9 14 4 151.2 192.5 corroded 172.7 15 5 192.5 234.0 corroded 199.7 20 5 corroded 214.5 10 6 234.0 275.2 corroded 244 13 6 corroded 246.2 14 I 6 6 . corroded 247 15 corroded 253.1 14 6 corroded 259.2 17 7 275.2 316.8 corroded 278.7 21 I 7 corroded 304.9 12 *-Metal loss is averaged circumferentially and along the tool's sensor length,which is 5 in.for tubing and 13 in.for casing. I • a i i ': I Page 14 of 271 ti SII Company: ConocoPhillips Alaska,Inc. I ' Field: Kuparuk Service: MID `% Well: 3N 11A 15`Barrier: 3.5"9.3#L-80 Tubing ConocoPhillips Log Date: 2015-Jan-12 2nd Barrier: 7"26#J-55 Casing I 3rd Barrier: 9 5/8"36#J-55 Casing Third Barrier: 9 5/8"Casing Joint Tabulation Report I Joint Top Bottom Condition Max.Metal Loss Depth Number (ft) (ft) (ft) 1 35 78.0 corroded 36.6 Ii corroded 75.3 2 78.0 119.7 corroded 79.6 2 corroded 81.7 3 119.7 159.7 corroded 126.2 I 3 corroded 141.3 4 159.7 199.0 5 199.0 239.0 I 6 239.0 278.0 corroded 259.4 7 278.0 318.0 I jl I Page 15 of 271 1 1 a I I I I Company: ConocoPhillips Alaska,Inc. I .- 't Field: Kuparuk Service: MID C Well: 3N 11A 15S Barrier: 3.5"9.3#L 80 Tubing onocoPhillips Log Date: 2015-Jan-12 2nd Barrier: 7"26#J-55 Casing I 3rd Barrier: 9 5/8"36#J-55 Casing SURVEY RESULTS IFig. 9 Magnetic Imaging Defectoscope within Interval 20—330 ft—3rd Pass Field : Kuparuk Date of survey :01/12/2015 I Well3N 11A Date of interpretation :01/15/2015 Completion : Single Completion Injector Survey : MID logging Depths : measured from RKB NEAR DELTA 3 ill'TUBING FAR DELTA 7"CASING DEPTH _1 Ili a 1 VN Thickness 1 INE - NR 26 WELL _1 11 1 VN Thickness 2 FR 41 FR 47 It 0.75 ms 562 0 n 0.5 6.5 mV 9-5 SKETCH 2.37 ms 274 0 in 0.8 3 mV 5 0 mV 0 6 • 50 2r' cu .3 1/2 tubing CU'Cur CO 7"' .sing L Tubing Corrosion line j.. T in;c• rosion line 9 5/8" asing corrosiojline I "`� — II . T Casing on line : ` i100 1. « �— TIlars _ -_., — I - ---T 1/2"tubi ; casing 7" 150 — — -- - _. • ro c • \ ` - - 9 5/8"casing .1.1 . . � li • • t--"4", , =4-I N.-/8"Casing tars -+-- Ilk- ' S `"�� r �` 7"Ca inoliars I i' j 1 _ _ „,_..,.......... _ _ _ ...... , 250 �—F- - I — — - I - +.- nI — II ,, t R 300 • IL....- ■ -T- 1 ■ 5-10% i 4,..,-.,.... ♦ — i............,...7.4.: _ - II---s ---7' __ 5, 10-20% I I to '141 �` I I I Page 16 of 271 � '. I • Company: ConocoPhillips Alaska,Inc. I 8,..t Field: KuparukService: MIDIP,'Well: 3N 11A 152 Barrier: 3.5"9.3#L-80 Tubing ConocoPhillips Log Date: 2015-Jan-12 2nd Barrier: 7"26#J-55 Casing 3rd Barrier: 9 5/8"36#J-55 Casing Fig. 10 Magnetic Imaging Defectoscope within Interval 20-330 ft-1st Pass IField : Kuparuk Date of survey :01/12/2015 Well : 3N-11A Date of interpretation :01/15/2015 I Completion : Single Completion Injector Survey : MID logging Depths : measured from RKB NEAR DELTA 3 l/2 TUBING FAR DELTA 7-CASING DEPTH -1 i 'i i VN Thickness 1 NR 26 WELL -1 R "• 1 VN Thickness 2 FR 41 FR 47 '.. R 0.75 ms 56.2 0 In 0 5&5 mV 9-5 SKETCH 2-37 ms 274 0 n 0-8 3 mV 5 0 mV 0.6 I - mfr`r.�-� _ -IM- o 31/2• tubing One+ cu cu cu cL' - 50- A _thic essiime Tubing Corrosion line . T ing co^rasion lin—.I _-! corrosi line 4s I. 7' Casing cprrolion lin- ., 1 _— . : ' MN= . �_.. - - . l 100 S Tubin: collars -r - - ■ 1/2"tubin. rasing 150 =r1r .„,____ L I...- ..4., , {% . 9\ • - 5/8"casing. -"" _ I ' :.;5/8"Ca ng lays Sjw ■ _ RRR 200 -�.�., 8 ■ .�.=�. .j.... ' - - L , 7 Ca 1ngolTars - - - \I } i - - ..""" I 250 _a ,, r ti ` - .-t I _ _ ___, 300 , - -*--- - i - r ■ 5-10% j- -_.� - - ■ >1200-2960% I -- t I 6It, 1 Page 17 of 271x,11' � Company: ConocoPhillips Alaska,Inc. U Field: tatKuparukService: MID �, Well: 3N-11A 15`Barrier: 3.5"9.3#L 80 TubingConocoPhillips Log Date: 2015-Jan-12 2"d Barrier: 7"26#J-55 Casing I 3rd Barrier: 9 5/8"36#J-55 Casing Fig. 11 Magnetic Imaging Defectoscope within Interval 20—330 ft—2nd Pass IField : Kuparuk Date of survey :01/12/2015 Well : 3N-11A Date of interpretation :01/15/2015 U Completion : Single Completion Injector Survey : MID logging Depths : measured from RKB NEAR DELTA 3 117 TUBING FAR DELTA r CASING DEPTH _1 I 'u 1 VN Thickness 1 NR 26 WELL _1 I 1 1 VN Thickness 2 FR 41 FR 47 fl 0.75 ms 562 0 in 0.5 6.5 mV 9.5 SKETCH 2.37 ms 274 0 in 0.8 3 mV 5 0 mV 0.6 - 3 1/ tubing — � 7" sing CLt CLL FL2 CLQ I - 50- Jr thick•ess /• Y� Tubing Corrosion line iT ingco slit line I } # • 5/8" asing c.rrosioo line V___ - - ..- ., I � T asing c;000*■n lineI 01.10 _ - sMI - 100 5 - - � Tu`�bncollars ,L.__ . I ' - - J-_--- - 131/2"tubir2; I 7" .asing H. - -' 150 _ " ' . __ _u ' sl► - 9 5 8"casing t-.. .. :5/8"Ca ng . lars zoo _ �. _ . I_ I '---f■■ " 7"Ca in tColTars . WA '1 . ..• , 2501.-"%"7...""--"..""P'--'-- � ww / 1 t - J y.; I I II i� - I . _ 300 �-rr • 5-10% 1 4 = I l ■ 10-20% :ilii 7 , ... I II II ! Page 18 of 271 `$• I 1 . Company: ConocoPhillips Alaska,Inc. 1 lat Field: Kuparuk Service: MID 15t Well: 3N 11A Barrier: 3.5"9.3#L-80 Tubing ConocoPhillips Log Date: 2015-Jan-12 2" Barrier: 7"26#J-55 Casing 1 3rd Barrier: 9 5/8"36#J-55 Casing ATTACHMENTS 1 1 l Page 19 of 271 1 1 1 1 1 1 1 1 1 1 i 1 1 1 Company: ConocoPhillips Alaska,Inc. I :SiField: Kuparuk Service: MID 15` �, Well: 3N 11A Barrier: 3.5"9.3#L 80 Tubing ConocoPhillips Log Date: 2015-Jan-12 2" Barrier: 7"26#J-55 Casing I3rd Barrier: 9 5/8"36#J-55 Casing ATTACHMENT 1 I SEQUENCE OF EVENTS Well 3N-11A ICompletion Single Completion Injector Oil field Kuparuk I Date State 2015/01/12 Well is shut-in Survey MID survey IThe MID (Magnetic Imaging Defectoscope) was recorded with TGT memory tools by PDS on an HAL SL I unit. Start of End of Logging I Date Time interval, Interval, speed, Las Name Event ft ft ft/min MID Survey I 05:00 Travel 06:45 Arrive-On Location 06:50 Sign in w/unit,conduct safety I .07:00 meeting Standby 07:00 Standby for unit to rig up&for arrival of pump truck to pressure test PCE I 08:30 End Standby 08:40 Connect battery, program tool 08:50 Flip switch to"logging mode" I 09:09 Stab on Lubricator-Run 1 14 09:15 SL unit uses pump truck to PT PCE to 3,500 psi 09:23 0 300 150 RIH @ 150 fpm I ,-I 09:26 300 300 Stop @ 300' 09:27 300 0 10 SSU1 Begin pass#1 logging up @ 10 fpm 09:58 At surface I 09:59 0 300 150 RIH @ 150 fpm 10:01 300 300 Stop @ 300' 10:02 300 0 10 S5U2 Begin pass#2 logging up @ 10 fpm 10:35 At surface I 10:36 0 300 300 150 RIH @ 150 fpm 10:39 300 Stop @ 300' 10:40 300 0 10 S5U3 Begin pass#3 logging up @ 10 fpm I 11:18 11:20 At surface Download DTR(enter tool start time as 08:50:00),convert.dpt to.dxt 11:45 Break Off Lubricator-Run 1 I ( I IPage20of271 '' 1 ! 1 Company: ConocoPhillips Alaska,Inc. • , Field: Well: Kuparuk Service: MID 1"3N 11A Barrier: 3.5"9.3#L-80 Tubing ConocoPhillips Log Date: 2015-Jan-12 2"d Barrier: 7"26#J-55 Casing 3rd Barrier: 9 5/8"36#J-55 Casing 12:00 Download MID tool,confirm good data 12:30 Travel 14:15 Arrive-Not On Location 14:15 _ Service tools 15:00 End Ticket �� If I Page 21 of 271 1 I Company: ConocoPhillips Alaska,Inc. ' 4i. Field: Kuparuk Service: MID C 1"=`. Well: 361 1113 1St Barrier: 3.5"9.3#L-80 Tubing ConocoPhillips v Log Date: 2015-Jan-12 2nd Barrier: 7"26#J-55 Casing I3rd Barrier: 9 5/8"36#J-55 Casing ATTACHMENT 2 I WELL SCHEMATICS (Provided by Client) I KUP 3N-11A ConocoPhillips I ) omi 13.42451 !4a Angle&MO ^Da 1 UM 014 auw 4 P18e1 0,1210 500292158001 KUPARUK RIVER UNIT NJ 99.52 9680.48 `'10,9210 x281.841 0w LAB 0001 EPP 041 K6.ON 01 138POW.IS/i Dab vr4 CRAM CFW7E0 30r•A inlhoIsxucM SSSV.TRDP LAM WO. 1112/2012 3949 41311986 I •i.m l•_• k.+00r1 524 A 05561481 6.50.1 589802 Lam ho4..E2/Coo Lay Rev ROMP,P,WELL REVIEW ostial 2272013 f.Casing0504.1160. 5030 8•9•042..Tw819161 404418.4•404•60V01..8144`..8464-MM Tw584 CONDUCTOR 16 15.062 360 115.0 1150 6250 14-40 WELDED 0800804(00640 0.. 40681.T.8 1163 5.00.8611.40096IPM..86434.1314...8MB:1398"":" TN I F SURFACE 13 8.785 350 4,5580 3,6317 36.00 }55 C 94616/11460 0. 4wy ..ret II6L81 5.03610.48166(7.1301 44343`..164..4088704 um.........,...., I LSSDOWAI2-01 8000 8.4770 8.4830 6418.6 26.00 I 9401604(1400 ::::: 0 406810..741804 10055310.40.86 Mol 63437..6161..8051 734PRODUCTION6.27630.4850008428.926.004.55C000S r( 01055706640014%OTd. SCR LINER 2 3478 8,1302 8.5251 8.464.2 11.60 L-80 C Liner DetailsDe 4045 MFfIY MY Top 88111 466... 1>. .�.. T.181081 13(6 ;y 13.6 o.«ra64 54414 104 8.I3U3 6.168 5 S 00 PACKER BAKER C2 LOP LINER TOP PACKER 4 400 6.150.5 .811.61375 .112.7 15.3110640568 BAKER HYDRAULIC FLE%LOCK MANGER 4 320 8.160.3 6.189.6 45.26 SBR BAILER 6948 SEAL BORE EXTENSION 4000 I lake>108 co5.c4(0044n 80680.. 8.808,.74813341 5.505560.1600611001..640130..1068..16010.81104 LINER 218 1992 10.4301 10.6000 03869 470 1.80 STL Linn Details '.. pth Top 746(1 1 . 344 .I \ 01 Too iNUN 61BI r1 BILLET Tubing Common 1I SO • U 301 190 91.17 B141EY OH ANCHORED BILLET 1(p0 ON "",7: "";50;1 To,inp Strings 11..(2111112 86310 5640.14236 A 1734.s.511461741...60(0473 50158._ 0415,4 TUBING'NO 11,2 2992 216 8.'734 G.1986 930 080 FUE614ABM01) • Completion Details ea4 554.41 mol 1 46(1445 (4.2011 ' Mv1 *41163 6323 11..(2440 218 6 216 -0-0 06 HANGER TunNG HANGER 9 PUP 3 500 1.7963 1,7308 3483 SAFETY VLV CAMCO TRMAx%CMT-S,SR SAFETY VALVE 2812 8.061.1 8.194.7 45.19 NIPPLE CAMCO%NIPPLE 0111 2812 8.128.1 6.1670 4538 LOCATOR LOCATOR SEALS 7 OUT 2970 6,153.0 6.1644 45.30 SEAL ASSY BAKER 8040 SEAL ASSEMBLY FOR SBE HALF MULE SHOE 2990 8.1729 6.198.4 4524 WLEG 2.990 I u' t, 0.b.,In Fist.(Wretlna 7shlevabls plugs.8.1031,pumps,fish file.) 64111.5. Top 141306 0161 64700 64068 4479 WHINST OEN WNPSTGCK FOR--SDE TRAI1 BAKEa Tr:RJTBG 714'2012 • .PT ■ GENII P..fu.eaons&fats 1 POKE SNP 1 741 1 A4r Na 110 04.5.1 140 INA,PPP 11V01 661 53.186411330 I 1336 Nr NA- 10021.5 0.599.6 9.389.9 6386093.36-113 8.1;2012 320 SLOTS SLOTTED LINER NOW:WnMI f Safety 10'114/0 464 Arn �( 11/161200707 4r5.NOTE.WORKOVER 1115/2008 NOTE'WAIVERED WELL.00 M ATMOSPHERE COMMWICATION ,1v 2242012 NOTE:APPLY 5600 P51 TO CONTROL LINE TO KEEP TRMAX%FULLY OPEN 821/2012 NOTE WELL SIDTRACKED A.AL 1,012.AL2-01.AL3(AL2-01 off man$*,40-4 4 5o 414 4110 006 64119) I1114104.44 . ' *COW e Mandrel Details T40.84 1 Pen 01002010& 6.. 1TM0 01 00 1204 04190 809 11066 808104 K..TM61888) 0681 I'1 Wks WAY IN/ N6 106. Two 611 1651 8441 Co.... I .10'61911 1 2.9079 2,49104634 CAMCO MAG 112 CAS UFT AMY RK 00/0 001/122012 2 5099.0 4001.6 46 28 CNACCI MNG 1 12 GAS LIFT DMY RK 0.000 00 19/2012 3 6,5707 505594298 CAMCO MMG 112 GAS LIFT AAV RK 0000 00 1(122012 4 7.523.7 574124523 CAMCO MAG 112 GAS LIFT AAV RK 0000 001/122012 5 8052.1 6,113.3 4533 CAMCO HMG 1 12 GAS LIFT AAV RK 0.000 00 2/10,2012 NM We,13188•85 •4 8i 1 83 482,0 CO I SIAM lmilw'n OD J I I • I 1 Page 22 of 271 41,, Company: ConocoPhillips Alaska,Inc. ' / \ Field: Well: Kuparuk Service: MID 3N 11A 1'Barrier: 3.5"9.3#L-80 Tubing ConocoPhillips Log Date: 2015-Jan-12 2"d Barrier: 7"26#J-55 Casing ' 3rd Barrier: 9 5/8"36#J-55 Casing ATTACHMENT 3 ABBREVIATIONS r- Nomenclature Description G/C Gauge cutter MIDMagnetic imaging defectoscope HPT_ HUD High precision temperature F Hold up depth POOH Pull out of hole R/D Rig down ' R/U Rig up RIH Run in hole RU Reservoir unit THP Tubing head pressure r _ IPage 23of271 t 1 1 I Company: ConocoPhillips Alaska,Inc. I Field: Kuparuk Service: MID 1st Well: 3N 11A Barrier: 3.5"9.3#L-80 Tubing ConocoPhillips 1 Log Date: 2015-Jan-12 2nd Barrier: 7"26#J-55 Casing I3rd Barrier: 9 5/8"36#J-55 Casing ATTACHMENT 4 I QUALITY CONTROL I Logging speed while MID runs was 10±2 ft/min. Depth was correlated using well sketch provided by ConocoPhillips. NEAR DELTA 3112"TUBING FAR DELTA r CASING DEPTH _1 f ;ii 1 Vny Thickness 1 NR 26 YYELL .1 [ i 1 VN Thickness 2 FR 41 FR 47 I _ R 0 75 ms 58 2 0 in 0 5 8 5 mV 0 5 SKETCH 2 37 ms 274 0 in 0-8 3 mV 13 0 mV 3 e �� — — ` �- _ .p of Tubing I _ _ iriii of 7" .using I 40 , CL1 CLi I CU I- Gi7 3 1/ "tubing r ca ing _ - thickness thick ess so — r, p I 60 I I • 1_ „casi g collar Ilk - 70 i i .,4- ' - I - - �AC- - , ,IL= . r - r_ _r r Iao y I100_ — -110 ow } I �. I =--� `?1541110111-4 -120 ` . -i Iit :la I Page 24 of 27! 1 ,1111 il I I ft • Company: ConocoPhillips Alaska,Inc. I lat Field: Kuparuk Service: MID 1St Well: 3N-11A Barrier: 3.5"9.3#L-80 TubingConocoPhillips Log Date: 2015-Jan-12 2nd Barrier: 7"26#J-55 Casing I 3rd Barrier: 9 5/8"36#J-55 Casing MID data recorded at different passes correlates well and has good repeatability. I NEAR DELTA 5501 NEAR DELTA_S5U2 NEAR DELTA_S5V3 FAR DELTA 5501 FAR DELTA SSU2 FAR DELTA_S5U3 - - DEPTH -I i I VN .1 AI VN -,• 1 VN NR 26_55U 1 WELL .1• se 1 vv 1• 411 1 VN -1• S 1 VN FR 41 5501 8 0.75 ms 562 0.75 , 562 075 rob 562 85 mV 95 SKETCH 237 ms 274 237 ms 271 237 ms 274 3 mV 13 0 mV 3 NR 26_S5U2 Fq__4_t SSUFR 17 5511 2 FR 17_5502 85 mV 95 3 mV 73 0 mV 3 NR 26 55113 FR 41S5U3 FR 17 5503 IRS mV BS -'— --"ear----- , ..i_.3�3 0 mV 3 .- z '_"wN .-..iM .". .... ,.:".1r.�. .6_____. _ - - - 1 I cu .., _ .. cL1 Cu cLp I 50 _.. _. IPIIIIIC:::CIIIIE=VIIII .07e". -7► -moi- -+iiF Iiiir I i► ► ;ice"I um I .+— ..... . t ,. . ,- �. .._� -_ C lot ,. +"�': ,- - -- -- - . 4 — --- • -- ,,=-1111111.0. � EI150 r----39,3114719.9.r -111413114=9.1.mr .• +e / e+ 4 . IrIS Mr, i - 3 - _ T- - ..-14.1.................4... - e...... 250 1►: .... -.- J-=..- .... .,.. 4r 4- -.':. ' ____Lt. I _ ,. .- . . .:p,Z 4 { 4-z-,:.4- 300 �'I , 1 • ` �.-.-d^" 411..—.. .� "-1'x"1.... .,.".'' .......$. ...''•"'..."'F"_I 1' io • I1 Page 25 of 271 �� I Company: ConocoPhillips Alaska,Inc. I la Field: 3N-11 A k Service: MID Well: 3N 111st Barrier: 3.5"9.3#L-80 Tubing C0noCOPhillips Log Date: 2015-Jan-12 2"d Barrier: 7"26#J-55 Casing I3rd Barrier: 9 5/8"36#J-55 Casing ATTACHMENT 5 I TGT MID LOGGING TOOL STRING SCHEMATIC A 10.97 ft(Top of Tool String) UpperCentraliser Length:2.3 ft I Max Hole Diameter:9.45 in Min Hole Diameter:1.65 In .i BatteryCompartment Length:1.9 ft Mode Max OD:1.65 in Switch 1 • S.77 ft(Very Longsensor) Ip i IIII ■ 10.97 ft Electronics Length:4.5 ft I Max OD:1.65 in .[. 4.1 ft(Short Sensor) _ C I Pressure/Temperature Unit 3 ft(Pressure Channel) I 2.73ft(Thermometer) ILower Cent raliser <: ) Length:2.27ft I = Max Hole Diameter:9.45 in Total Tool String Weight:41.61ba Min Hole Diameter:1.65 In Total Tool String Length:10.97ft I Total Tool String OD:1.65 in 0 ft Zero Point I it ` ii f, .it I Page 26 of 271 Ai I * 4 Company: ConocoPhillips Alaska, Inc. I fi Field: Well: Kuparuk Service: MIDIV 1St 3N 11A Barrier: 3.5"9.3#L-80 Tubing ConocoPhillips Log Date: 2015-Jan-12 2nd Barrier: 7"26#J-55 Casing I3rd Barrier: 9 5/8"36#J-55 Casing ATTACHMENT 6 I DESCRIPTION OF LOGS Original logs IA list of recorded logs is given below. LOG UNIT DESCRIPTION COMMENTS j DEPTH ft Measured depth Calculated from RKB ILSPD ft/min Cable speed SS RESPONSE mV Short sensor response 42 points of time response I (0.133-75 ms) _ LS RESPONSE mV Long sensor response 51 points of time response (0.133-274 ms) ICalculated profiles I A list of all profiles derived from original logs is given below. LOG UNIT DESCRIPTION COMMENTS IThickness 1 inch 3 1/2"tubing thickness Thickness 2 inch 7"casing thickness I NEAR DELTA V/V Near Zone Model Deviation 31 points of time response (0.75-56.2 ms) IFAR DELTA V/V Far Zone Model Deviation 34 points of time response (2.37-274 ms) Ii 1, 1 Page 27 of 271 , E ' 1 2�2�0�5 �:SCoC�1 WALL LOG 11-14S TRANSMITTAL `DECEIVED PRoAcrivE DiAgNosric SERVICES, INC. 0 9 2 015 DATA LOGGED /2015 AOGCCM.K.BENDER AOGCC To: AOGCC Makana Bender 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 SCANNED MA)' 0 7 2015 [907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection[Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 . 1) MID Report 12-Jan-15 3N-11A 1 Report / CD 50-029-21580-01 2) Signed : /"2LdL2..#z ] fr) I5 e.tk t Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D\Archives\MasterTemplateFiles\Templates\Distnbution\TransmittalSheets\ConocoPhdltps_Transmit docx MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,January 07,2015 Jim Regg P.I.Supervisor Z 112� /� SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-1 IA FROM: Matt Herrera KUPARUK RIV UNIT 3N-11A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry (IV-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3N-I IA API Well Number 50-029-21580-01-00 Inspector Name: Matt Herrera Permit Number: 212-095-0 Inspection Date: 12/13/2014 Insp Num: mitMFH141220142850 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well r 3N-11A • Type Inj W TVD 6168 - Tubing 2810 2810 2810 2810 • PTD 2120950 Type Test SPT Test psi 2900 - IA 331 3403 • 3330 - 3308 . Interval REQVAR / P/F P OA 0 I 2 2 Notes: 2 8 BBIs Disel to pressure up IA A--o 2-13,O 7z SCANNE© , Wednesday,January 07,2015 Page 1 of 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. a.I Q - 0 S Well History File Identifier Organizing (done) Two-sided ❑ Rescan Needed RE CAN: OVERSIZED: NOTES: Co r Items: ❑ Maps: rayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: I ' / BY: el, Date: ` I p2//- i /s/ Ua Project Proofing I I BY: dift Date: a /s/ 11 Scanning Preparation c2 x 30 = tp, + 1 1 = TOTAL PAGES 7/ / (Count does not include cover sheet) BY: Maria Date: '1 a {tt t'14f Production Scanning Stage 1 Page Count from Scanned File: 7a (Count does include cover eet) Page Count Matches Number in Scanning Preparation: YES NO BY: all Date: 1 ` a,ti-/` /s/ yvt to Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michel Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc I O I O al E co c a) co E co >a co / Z /1> >- I c 0 E E �-o r N f4 w E E co 0. o) U �I > o 0 E._ a 9 p 2'} a) `� w > m '" t O y '> > 0� N c O N ur a) '> N a O Z` Z 7 + O N E L 0 O O_ IC N p c c N y 0 d fa Q o W a d O O L a) a) �O C c4 al 0 0 0 2 2 , m cc N 0 0 J Z Zm o a) a) o a a m 0 a, a a 0 r EcI' of a) o a) o 0o r Q N d i0 = -6.J aJ d --I d z z ▪ cn U E 0 >. pm pm oma E O / m/ N LCL Q y o D � � �� ;� o m o w " d O C y N N N N N a 1- d To ca a U Y i o 0 0 0 o Evi E 0 0 W N N N N 7 p N d COm O N N N N N CO Z w cm Ce To' CL CO co co co CO It CD ca U u W 0 � I1 c a)m mm mm a)m a)m ui cp C.) U• J1 2 2 a O U O U 0 0 0 co p Hco cZ Q a N 0) N N N N 0 a c L.. w N10 0 0 0 0 V E a 0a S. I m U U co, c O 11 /ZI C `2 v v .- v v H I le O N ;I I to 1 c CO 00 CO O I cO N a 1 j E 'Il a 1 C) U E /Z Q 11 Z ZI >- >- Q II / p/ r Z 1 III c0 a a) E I— N IIII p d O O O co O Z; J2 U U U �a as c 2c7) co N z z • /� O) R 2 N E 03 re CO Ju) U) N In C O E T a) t C '� (n (A To U) U a) c V� Q p c C O a — - Q c III I— Y O 1 C .CO2 a) 11 o II El o m O I Q o E / w v11 Q Z O Q' w .�. N y co 1 m 0 11 0 > > > > p p fE0 I J I X Z ._ ,N N co Z 1 (7 I cn a) a) a) a) c E' o 0 0 0 0 E Q ns''= _ O Z / M ct V U U U U Cp 11 zry c 7 c c 'o 1 orncc c c I r }Z LLdi° Q a0o a0o CO coo E/a N CL 11 1 O O .2 W 0 Z N N N N �1 W O F- co a. 0- a) O C — u_ Q O € � ! 2 E z o x I T. M i Z 2 V O E . .. O cc O p rn Ce 1, rnv ! co Z H c1— ca I H p / 0 W y O 0 a) �i Q O_ O C 1 Z w o 0 U .0 ._ E a a O E• p O a =y orn'Bc.ii o 0 o 0 1w OLL o 2 aa) o a j 0 I- 3 —IOH;� J J J w 3 Z 0 a c� 0 0 9 o 0 o InN c) 0 N 5 O h 'N O `9 Z _ \\ a a z U z_ co 7 H grii o Ce a 12 O co a 0.. J J W�/ = IX a 0 (..) W z U c°, o Z 8 Q N 1 J Zr) Y Om C � o C O a N p ♦� u7 E V U c a Q z co 1 _N E O N Lo I W CO a o Q a Yg I . m Q O a z_ Eo 0 m 0 1 E co z m co m o'o N d N .> d Q' C rn 0 2 o co 41) E °' ` 0 o m 0. U I .?,.•.;. -. n.-._-e3' - wh' .4,..-.+ .x.'r-...5. 4..4,44.!5 , •.t:. , t4ir... .-%r 30 .p•,. •i..'..1 , A 2...: f.,.,14, 444,4 ,' '4,..1,=.00•,}1:.;,--+a.: 'F • �v\ 11//- ' 1-lE STATE , r . - .>G st ..11 ) - - (� �_-_6_ 333 `f✓e Se en!h Ainr�r: /y4=' GO\'l,ltl0i Vii,:\\' I';\1:\LL?_ PrIchoroc_te, Picska 99554-3572 Martin Walters Well Integrity Project ( � d -5'ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N-11A Sundry Number: 314-346 Dear Mr. Walters: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a/67 ia..720tes (76....____Cathy Poerster Chair I DATED this 2 day of June, 2014. Encl. . STATE OF ALASKA RECEWED ALASKA OIL AND GAS CONSERVATION COMMIooION JUN 0 2 2014 APPLICATION FOR SUNDRY APPROVALS errs 6//Z AG. 20 AAC 25.280 AOGGC 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: Cond Removal f+i-• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. • Exploratory r Development r 212-095-0 - 3.Address: 6.API Number: Stratigraphic r Service (- , P.0. Box 100360,Anchorage,Alaska 99510 50-029-21580-01 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No2P / 3N-11A , 9.Property Designation(Lease Number): 'T> 10.Field/Pool(s): ADL25512 AL-le553-AbL 2SS ( Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MDA Effective Depth ND(fpit Plugs(measured): Junk(measured): 10923 6387 /0(oOp 3g?' Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115' - 115' 1640 630 SURFACE 4528 9-5/8 4558' 3632' 3520 2020 PRODUCTION 8470 7 8500' 6429' 4980 4330 LINER 495 4-1/2 8625' 6464' 7780 6350 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10441-10600 • 6390-6387 3-1/2 L-80 8173 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-BAKER 80-40 SEAL ASSEMBLY MD=8153 ND=6184 SSSV-CAMCO TRMAXX-CMT-5-SR MD= 1796 ND= 1731 • 12.Attachments: Description Summary of Proposal . ri 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r- • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/1/2014 Oil r Gas., r WDSPL r Suspended r 16.Verbal Approval: Date: VVINJ p-i GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Martin Walters Email: n 1878(a�cop.com Printed Name Martin Wa ters Title: Well Integrity Project Signature //lh 1•� ✓' �4;f��ti� Phone:659-7043 Date:05-27-14 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3\'•-1-3 '--1 t,_t Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: !r 0/,_,F0 ja C-:..1.-mrdK- Cai, t.- Y 0,-1--L' £ e-p A z t_p—e. . Spacing Exception Required? Yes 0 No [f Subsequent Form Required: i 0--y 0‘-i APPROVED BY Approved by: ,7 COMMISSIONER THE COMMISSION Date: G - 2 -l Ap � li f rove I I v 1 months fro n the date of a roval. G z / Rettig(P,gyj;ed 1§2q sP/'� 6/�/7 pp Form and Attachm is in Duplicate y' RECEIVED ConocoPhillips JUN 0 2 Alaska 2014 P.O. BOX 100360 A OG CC ANCHORAGE,ALASKA 99510-0360 A'1 May 27, 2014 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 •• Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 3N-11A, PTD 212-095-01 conductor removal. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, /67 1,7,* Martin Walters ConocoPhillips . Well Integrity Projects Supervisor ConocoPhillips Alaska P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 ConocoPhillips Alaska,Inc. Kuparuk Well 3N-11A (PTD 212-095-01) SUNDRY NOTICE 10-403 APPROVAL REQUEST May 27, 2014 This application for Sundry approval for Kuparuk well 3N-11A is to remove approximately the upper 2 feet of conductor to allow for attachment of an ultrasonic surveying instrument to the surface casing. The conductor will be returned to it's original height once the survey is completed. With approval, the conductor extension will require the following general steps: 1. Remove the upper section of conductor and landing ring as necessary. 2. Examine surface casing for any corrosion damage. 3. Perform surface casing ultrasonic survey. 4. Extend the conductor back to the starter head. 5. File 10-404 with the AOGCC. 1 StY� ter% eir (or(1,rA"j2-- NSK Well Integrity Projects Supervisor r . s. _...-._.-....-....�..... KUP 3N-11A ConocoPhigips a r1- ' wejjAttributes 1Max Angle&MD TD INWellbore APWI Field Name Well Status Incl() MD(ftKB) Act Btm(ftKB) Alaska he- 500292158001 KUPARUK RIVER UNIT INJ 99.52 9,880.48 10,923.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date • Well Conf9.DEVIATED-3N-11A 2272013 2:30:48 PM SSSV:TRDP Last WO: 1/12/2012 39.49 4/13/1986 __..,_. Schematic•Aclaal Annotation 'Depth(ftKB) 'End Date Annotation Lest Mod...End Date Last Tag: 'Rev Reason:WELL REVIEW _osborl 2/27/2013 HANGER.24 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 11-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 95/8 8.765 35.0 4,558.0 3,631.7 36.00 J-55 BTC il , r Casing Description String 0... String ID...Top(61KB) Set Depth(t..Set Depth(ND)...String Wt..String String Top Thrd WINDOW AL2-01 8 6.000 8,477.0 - 8,483.0 6,416.8 26.00 Casing Description String 0... String ID...Top(8KB) Set Depth(t.,Set Depth(TVD)...String Wt..String...String Top Thrd I PRODUCTION 7 6276 30.4 8,500.0 6,428.9 26.00 J-55 BTC POST SIT Caning Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd CONDUCTOR, SCAB LINER 412 3.476 8,130.2 8,625.2 6,464.2 11.60 L-80 BTC 35715 Liner Details Top Depth SAFETY VLV, (ND) Top led Rend... 1.796 Top(ftKB) (ftKB) (°) Item Description Comment ID(In) EL 8,130.2 6,168.5 45.36 PACKER BAKER C2ZXP LINER TOP PACKER 4.400 1117 8,150.5 6,182.7 45.30 HANGER BAKER HYDRAULIC FLEXLOCK HANGER 4.320 Irt 8,160.3 6,189.6 45.28 SBR BAKER 80-40 SEAL BORE EXTENSION 4.000 GAS LIFT. Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd 1 2.900 t - LINER A 2 3/8 1.992 10,430.1 10,600.0 6,386.9 4.70 L-80 STL Liner Details Top Depth (ND) Top Inc! Novel... Top(ftKB) (ftKB) P) Item Description Comment ID(in) 10,430.1 6,390.1 91.37 BILLET OH ANCHORED BILLET 1.000 .- SURFACE, ..A dt•1. Tubing Strings •35-058 ,.. Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd - TUBING WO 3 1/2 2.992 23.6 8,173.4 6,198.8 _ 9.30 L-80 EUE8rdABMOD GAS LIFT, t Completion Details , 5,099 L Top Depth (TVD) Top Incl Novel.., Top(ftKB) (ftKB) (°) Item Description Comment ID(in) - 23.6 23.6 -0.06 HANGER TUBING HANGER&PUP 3.500 - 1,796.3 1,730.8 34.83 SAFETY VLV CAMCO TRMA)0(-CMT-5-SR SAFETY VALVE 2.812 GAS LIFT, _ 6,571 °- 8,081.1 6,133.7 45.19 NIPPLE CAMCOXNIPPLE 2.812 al 8,128.1 6,167.0 45.36 LOCATOR LOCATOR SEALS 7'OUT 2.970 8,153.0 6,184.4 45.30 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY FOR SBE HALF MULE SHOE 2.990 _.__ 8,172.9 6,198.4 45.24 WLEG 2.990 GAS LIFT. 7,524 -t Other In Holeireline retrievable plugs,valves,pumps,fish,etc.) Top Depth il (ND) Top Incl Top(ftKB) (ftKB) (1 Description Comment Run Drte ID(in) 8,470.0 6,408.8 44.79 WHIPSTOCK WHIPSTOCK FOR'A'SIDETRACK.BAKER THRU-TBG 7252012 GAS 8,052 LIFT__ I GENII s. Perforations&Slots NIPPLE,8,081fir Shot Top(ND) Btm(TVD) Dens Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (oh... Type Comment 10,441.5 10,599.6 6,389.9 6,386.9 A-2,3N-11A 8/1/2012 32.0 SLOTS SLOTTED LINER Notes:General&Safety LOCATOR, _.. End Date Annotation 0.120 11/162007 NOTE:WORKOVER Mk 1/152008 NOTE:WAIVERED WELL-OAXATMOSPHERECOMMUNICATION 2/24/2012 NOTE:APPLY 5500 PSI TO CONTROL LINE TO KEEP TRMAXX FULLY OPEN 8/21/2012 NOTE:WELL SIDTRACKED A,AL1,AL2,AL2-01,AL3(AL2-01 off main wellbore-see Multi-lat Drawing) SEAL ASSY, 8.153 WLEG,8,173 II APERF, 8,420-8,435 WHIPSTOCK_ 8,470 il - WINDOW AL2-01. - 6,477-8,483 Mandrel Details Top Depth Top Port PRODUCTION S... (TVD) Incl OD Valve Latch Size TRO Run POST Sit, - N...Top(ftKB) (ftKB1 1°) Make Model (in) Sery Type Type (In) (psi) Run Date Com... 30-8,500 1 2,907.9 2,491.0 46.34 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 2 5,099.0 4,001.6 46.28 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/8/2012 3 6,570.7 5,055.9 42.98 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 , ( 4 7,523.7 5,741.2 45.23 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 , 5 8,052.1 6,113.3 45.23 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 2/102012 SCAB LINER, 8,1308,625 SLOTS, V im 10,442-10,600 1 LINER A 10,430-10600� I I TD(3N-11A). 10,923 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg �� DATE:Wednesday,December 12,2012 P.I.Supervisoref(`1 I ZI t 2'11 v SUBJECT:Mechanical Integrity Tests l CONOCOPHILLIPS ALASKA INC 3N-11A FROM: Chuck Scheve KUPARUK RIV UNIT 3N-11A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry_—'-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3N-I IA API Well Number 50-029-21580-01-00 Inspector Name: Chuck Scheve Permit Number: 212-095-0 Inspection Date: 12/7/2012 Insp Num: mitCS 121208080145 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3N-I IA - Type Inj W TVD J 6168 • IA 240 3200• I 3180 3180 - PTD 2120950 - Type Test SPT Test psi l 2900 . OA 3 4 4 4 • - Interval REQVAR P/F P -' Tubing 2300 2300 2300 2300 AID 2B 072 —--- - -------- Notes: - Wednesday,December 12,2012 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �� DATE:Monday,December 03,2012 P.I.Supervisor rt ��I(/1 v SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-11A FROM: Bob Noble KUPARUK RIV UNIT 3N-1I A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 3 __ NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3N-11A API Well Number 50-029-21580-01-00 Inspector Name: Bob Noble Permit Number: 212-095-0 Inspection Date: 11/22/2012 Insp Num: mitRCN121123090251 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3N-11A - Type Inj W'TVD ' 6168 - IA 340 2900 ' 2820 • 2800 - PTD 2120950 ' Type Test SPT,Test psi 1542 • OA 3 6 5 4 Interval 1INITAL P/F F ' Tubing 2075 2075 2075 2075 Notes: AIO 2B 072.Per CPA!,test does not meet the definition of a passing test.They will have DHD schedule a redo of the test with the inspectors as soon as possible. /VO 7-6.0 7a_ 2yit.a MJT.J-4 40 ` a. 11/4A0.44,tit ll01„n,kc.,Welrefi litiCC•emi reSSi,A/e , 1-C4'Gcs.A- 1'1`ec ltiN p1 x -r AA_ :utn- L( TSU ere-SS t t _ S A- J is '>Zt f. ,;wf-4 Monday,December 03,2012 Page 1 of I Wallace, Chris D (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, October 17, 2012 4:25 PM To: NSK Problem Well Supv Cc: Regg, James B (DOA); Wallace, Chris D (DOA) Subject: RE: 3N-11A AA justification (PTD 212-095) Brent, As we discussed you have verbal approval to start water injection into 3N-11A (PTD 212-095)while the new AA (Administrative Approval ) is being processed to replace AA A1O 26.024. The motherbore 3N-11 (PTD 186-077)was operated under AA AIO 2B.024 and has been cancelled since the well was sidetracked by CTD recently. A scab liner was set over the perf intervals and then CTD drilled a sidetrack(and subsequent CT laterals). There is no physical change in the wellbore in regards to the production and surface casing so the same AA restrictions will apply to the new permitted wellbore 3N-11A. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Wednesday, October 17, 2012 3:13 PM To: Schwartz, Guy L(DOA) Subject: 3N-11A AA justification Guy, As per our phone conversation, attached is a copy of the AA justification for 3N-11A. The paper copy is in the mail. Please let me know if you have any questions. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 Pager(907) 659-7000 pgr. 909 RECEIVED STATE OF ALASKA F P 1 2 ? 12 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORTAND LOG Commission la Well Status: Oil ❑✓ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ lb.Well Class: Anchorage 20AAC 25 105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions Service ❑ Stratigraphic Test❑ 2 Operator Name 5.Date Comp.,Susp, 12.Permit to Drill Number. ConocoPhillips Alaska, Inc. or Aband.: August 15,2012 212-095/ • 3.Address' 6 Date Spudded' 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 July 26,2012 ' 50-029-21580-01• 4a Location of Well(Governmental Section) 7 Date TD Reached 14.Well Name and Number: Surface: 1561'FSL, 155'FEL,Sec.29,T13N, R9E, UM . July 30,2012 • 3N-11A Top of Productive Horizon: 8. KB(ft above MSL): 68'RKB • 15.Field/Pool(s): 365'FSL,2105'FEL,Sec.20,T13N,RO9E,UM GL(ft above MSL): 33.8'AMSL• Kuparuk River Field • Total Depth 9.Plug Back Depth(MD+TVD) 47 FNL,2362'FEL,Sec.29,T13N, RO9E, UM 10600'MD/6387'TVD • Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10 Total Depth(MD+TVD): 16.Property Designation Surface: x-518246 y- 6013799 Zone-4 10923'MD/6387'TVD • ADL 25521,25512 TPI: x-516274 y- 6017878 Zone-4 11.SSSV Depth(MD+ND) 17.Land Use Permit: Total Depth: x-516019 y- 6017466 Zone-4 SSSV @ 1797'MD/1731'TVD 2557,2553 18.Directional Survey: Yes 0 . No❑ 19 Water Depth,if Offshore 20 Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1700'MD/1650'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 8471'MD/6410'TVD 23 CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 36' 115' 36' 115' 24" 250 sx CS II 9.625" 36# J-55 35' 4558' 35' 3632' 12.25" 1300 sx AS III,350 sx Class G 7" 26# J-55 30' 8777' 30' 6627' 8.5" 300 sx Class G,175 sx AS I 4.5" 11.6# L-80 8130' 8625' 6168' 6519' 15 bbls 16ppg Class G w/GASBLOK 2.375" 4.7# L-80 10430' 10600' 6390' 6387' 3" slotted liner 24.Open to production or injection" Yes ❑✓ . No ❑ If Yes,list each 25 TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number) SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 8173' 8130'MD/6169'TVD slotted liner from 10430'-10600'MD 6390'-6387'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. ::.'_i'.f;:j/b / DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED III i J N n I419 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc) August 31,2012 pre-produced injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 9/6/2012 12 hours Test Period--> 39.5 23 911 124% 718 1 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press.145 psi not available 24-Hour Rate-> 73 49 1806 not available 28 CORE DATA Conventional Core(s)Acquired" Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed) Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25 071 NONE RBDMS SEP 1 2 20124 0 1 1 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only X 2./t6t2 1 ORIGINAL q,,,sixt,\,b ,,,.."---.,47 28. GEOLOGIC MARKERS(List all formations and m�.,.ers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 2 No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1700' 1650' needed,and submit detailed test information per 20 AAC 25.071. Top Kuparuk Al 8755' 6460' Bottom Kuparuk Al 9060' 6465' Top Kuparuk A2 8500' 6429' Bottom Kuparuk A2 10923' 6387' N/A Formation at total depth: Kuparuk A 30 LIST OF ATTACHMENTS kit1/414 Summary of Daily Operations,schematic,final directional survey 31 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike A.Winfree 2 5-6820 Printed Nam " L.G tt C Title. CTD Supervisor Signature j QNIA�IIL D1r Phone 263-4021 Date 67//e)/i 2 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 OD o0 00 Op Nie bM aZo - - M R M 4 S'') M r) `2.1 N u 1 J t") Q�O1 JAM JAM Q!;.-' 06O 46, 4a ,. YI- YI Y � O N.- •--7--N I i to O C 0 C co ti b - • , ` v u) co J Y g O n U > i r'I m t0 E Cl) a) (n C C ��11 Q- a) /'`-� U) CO V u) 0_a 7.5 3' E a> 2 2 H 0. 0 Q @ N6 N c c (0 E— >. omo U co u7 (p CO a. W L N Y o Q 00 .,::: .,:.:,'"''. !4.p . X XQ H _ ` `m *k Et° Uc--.4. a) J M E0 W C ,- OC On O U C Z M J 4 Op J 4 & N N d N a) N Q) m a0 _.C _. Y N M M M 1- M an 4 m m Nco O U `' t I'''. . , N Q t) d �N O T O X m a Q O ,,0 eq .0 0 A ah I I d De /41:02)d U J i I i • ��i Al 1 W n 1 • U III II IIAlI y � 0 = t 2o L 0 0 m0 aM o.co o � g cm fa c � u�oti _ 6OD C N t0# 00 St '.- u h N 1 p, CO of U a N CO co L N� Cl N T KUP 3N-11A ConocoPhillips "'"'e""' Well Attributes Max Angle&MD TD Alaska Inc. Wellbore API/UWI Field Name Well Status Incl(°) MD(FMB) Act Btm(ftKB) 500292158001 KUPARUK RIVER UNIT PROD 99.52 9,880.48 10,923.0 Comment H2S(ppm) Date Annotation End Date KBGrd(ft) Rig Release Date ••• Well ConBg:-3N-11-882120121:02:31 PM SSSV:TRDP Last WO: 1/12/2012 39.49 4/13/1986_ Schematic-Actual Annotation Depth(MB) End Date Annotation Last Mod...End Date Last Tag: 8,533.0 2/12/2012 Rev Reason:LATERALS ninam 8/21/2012 HANGER,24- Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(ND)... String Wt...String... String Top Thrd CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 41 I r SURFACE 95/8 8.765 35.0 4,558.0 3,631.7 36.00 J-55 BTC Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 30.4 8,776.6 6,465.1 26.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(L..Set Depth(TVD)...String Wt...String...String Top Thrd SCAB LINER 4 1/2 3.476 8,130.2 8,6252 6,4642 11.60 L-80 BTC Liner Details CONDUCTOR, Top Depth 36-115 (TVD) Top Incl Nom)... MI Top(MB) (RKB) El Rem Description Comment ID(In) 8,1302 6,168.5 45.36 PACKER BAKER C2 ZXP LINER TOP PACKER -4.400 SAFETY VLV. 1,798 8,150.5 6,182.7 45.30 HANGER BAKER HYDRAULIC FLEXLOCK HANGER 4.320 8,160.3 6,189.6 45.28 SBR BAKER 80-40 SEAL BORE EXTENSION 4.0001 - Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd LINER A 23/8 1.992 10,430.1 10,600.0 6,386.9 4.70 L-80 STL GAS LIFT, • Liner Details 2.908 • Top Depth (ND) Top Incl Nomi... Top(RKB) (R") 1°) Item Description Comment ID(in) O10,430.1 6,390.1 91.37 BILLET OH ANCHORED BILLET 1.000 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)... String Wt...String... String Top Thrd SURFACE, TUBING WO 31/2 2.992 23.6 8,173.4 6,198.8 9.30 L-80 EUE8rdABMOD 35-4,558 Completion Details Top Depth GAS LIFT, (TVD) Top Incl Nomi... 5,099 Top(MB) (RIO) (°) Item Description Comment ID PN - 23.6 23.6 -0.06 HANGER TUBING HANGER&PUP 3.500'' MN 1,796.3 1,730.8 34.83 SAFETY VLV CAMCO TRMAXX-CMT-5SR SAFETY VALVE 2.81i - 8,081.1 6,133.7 45.19 NIPPLE CAMCO XNIPPLE 2.812' GAS LIFT1,_ 8,128.1 6,167.0 45.36 LOCATOR LOCATOR SEALS 7 OUT 2.970 ilir 8,57 8,153.0 6,184.4 45.30 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY FOR SBE HALF MULE SHOE 2.990' 8,172.9 6,198.4 45.24 WLEG 2.990 Ill Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT, 7 Top Depth 7,524 ( . (TVD) Top Incl Top(RKB) (RKB) El Description Comment Run Date ID(In) - 8,790 6,464.7 90.79 FISH 1"BK Latch Ring Lost in Hole '1/12/2012 1. 10,430 6,390.2 91.37 WHIPSTOCK ANCHORED BILLET AL3 LATERAL 8/1/2012 1.000 GAS L =..' 3,osIFTz Perforations&Slots - Shot NIPPLE 8 081 - MIRTop(ND) Btm(TVD) Dens Top(ftKB)Bim(ftKB) (RKB) (MD) Zone Date OK- Type Comment Ell 10,442 10,600 6,389.9 6,386.9 8/1/2012 32.0 SLOTS MIit Notes:General&Safety End Date Annotation LOCATOR. _ 2/24/2012 NOTE:APPLY 5500 PSI TO CONTROL LINE TO KEEP TRMAXX FULLY OPEN 8.128 8/21/2012 NOTE:WELL SIDTRACKED,ADDED LATERALS AL1,AL2,AL2-01,AL3(See Muli-tat Drawing) 1 I I� i SEAL ASSY._ 8.153 ,ii,.a WLEG.8,173 ''' -, S. 8,420-8,43 APERF5, ,,. WHIPSTOCK, 8.470 Mandrel Details SCAB LINER, Top Depth Top Port 8.130-8,825 (ND) Incl OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) el Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 2,907.9 2,491.8 47.16 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 2 5,099.0 4,001.6 46.28 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 PRODUCTION, 3 6,570.7 5,055.9 42.97 CAMCO MMG 1 12 GAS LIFT 'DMY RK 0.000 0.0 1/12/2012 30-8,777 4 7,523.7 5,741.2 45.23 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 FISH,8,7901 5 8,052.1 6,113.2 45.17 CAMCO MMG 1 12 GAS LIFT DMY 'RK 0.000 0.0 2/10/2012 WHIPSTOCK, 10.430 SLOTS, 10,442-10.600 LINER A, 10,430-10,800 TD(3N-11A), 10.923 ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 3N-11 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 7/24/2012 2:00:00 AM Rig Release: 8/15/2012 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/23/2012 24 hr Summary Start Rig move at 12:00 11:00 12:00 1.00 MIRU MOVE MOB P PJSM,Move off of well, install jeeps 12:00 18:00 6.00 MIRU MOVE MOB P Start move from 2D to 3N-11 18:00 00:00 6.00 MIRU MOVE MOB P Arrive on location. Spot Sub and Mud Module over well. RU 07/24/2012 Rig move from 2D-05 to 3N-11 16 miles. Spot Rig Modules. NU BOPE. Load Pits with 150 bbls of SW,216 bbls of Used 9.4 ppg flowpro, 192 bbls of 13.1 ppg. BOPE test 250/3500psi.AOGCC Waived by John Crisp.Pull BPV. Slack MNGT, cut 5ft of coil. Rehead, pull/pressure test.test PDL&Tiger tank lines. 00:00 02:00 2.00 0 0 MIRU MOVE MOB P NU BOP's on well. Fill rig lines with water.Valve crew serviced tree. IA= 250,OA 0 02:00 04:00 2.00 0 0 MIRU WHDBO NUND P ***Rig accept at 0200*** NU Bop stack 04:00 14:00 10.00 0 0 MIRU WHDBO BOPE P Begin BOPE test,AOGCC witnessing waived by John Crisp. 1 Failure, R2. 14:00 15:00 1.00 0 0 MIRU WHDBO BOPE P Changeout R2 and test, Pull BPV 15:00 18:00 3.00 0 0 SLOT WELLPF CTOP P Remove BHI's drilling head,cut CTC. MU injector to wellhead. Reverse circulate for slack management. Cut 5ft of coil to find cable. 18:00 22:00 4.00 0 0 SLOT WELLPF CTOP P Crew change. Make up CTC, pull& pressure test. Pressure test PDL& Tiger tank line. Clean up rig floor& tools. 22:00 22:30 0.50 0 0 SLOT WELLPF SFTY P Pre-Spud meeting with Maddy's crew. 22:30 00:00 1.50 0 0 PROD1 RPEQPI PULD P Check Well pressure-zero-PJSM- P/U Whipstock assembly. BHA#1 07/25/2012 RIH with_Whipstock,could not drift past 8277'POOH&P/U 2.80"motor&D331. Drift to 8500'. P/U Whipstock and set TOWS @ 8470'. 00:00 00:30 0.50 0 74 PROD1 RPEQPI PULD P Line up stack for ease of injector make up. 00:30 03:00 2.50 74 8,175 PROD1 RPEQP1TRIP P RIH with EDC open pumping.4 bpm. 03:00 04:30 1.50 8,175 8,276 PROD1 RPEQPI DLOG P Tie into K-1 marker @ 8175',Cannot get a good tie in, P/U to 8145'and log down. P/U weight 36K.Set down weight at 8276'P/U weight 35K. Could not make it down past 8277'. Did not get rough with it. 04:30 07:15 2.75 8,276 0 PROD1 RPEQP1TRIP T POOH Page 1 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:15 07:30 0.25 0 0 PROD1 RPEQP1SFTY T At surface, Flow check, PJSM 07:30 08:00 0.50 0 0 PROD1 RPEQP1 PULD T LD whipstock,excessive amounts of sludge on WS/BHA 08:00 08:45 0.75 0 0 PROD1 RPEQP1 PULD T PU BHA#2(Coiltrack,0.6 AKO with D331 w/side reamers 08:45 10:30 1.75 0 7,845 PROD1 RPEQP1TRIP T RIH,circulating seawater thru mill 1 BPM 10:30 11:15 0.75 7,845 7,958 PROD1 RPEQP1 DLOG T Tie in depth HRZ(highly Radio Active Zone),-11'correction 11:15 11:45 0.50 7,958 8,500 PROD1 RPEQP1 FCO T Weight check 35K up, RIHW 18K, RIH down 8388'.Wt.chk 33K. Cont. RIH 1.53 BPM,2976 CTP, circulating SW. 11:45 12:15 0.50 8,500 8,200 PROD1 RPEQP1 FCO T PUH to 8200', 1.54bpm,2900ctp, 34K ctw 12:15 12:21 0.10 8,200 8,200 PROD1 RPEQPI FCO T Test backside line to TT.500psi. Line broke to arrange rig up.Test good 12:21 13:00 0.65 8,200 8,500 PROD1 RPEQPI FCO T RBIH to 8500 , PU to 8200' circulating SW out to TT.Circulate 9.4ppg used flow pro to EDC. 13:00 15:15 2.25 8,500 0 PROD1 RPEQP1TRIP T Looked good. Did not see anything across shakers.Open EDC, POOH displacing well to Flo-Pro 15:15 15:30 0.25 0 0 PROD1 RPEQP1SFTY T At surface, Flow check, PJSM 15:30 16:00 0.50 0 0 PROD1 RPEQPI PULD T LD BHA#2 16:00 17:00 1.00 0 0 PROD1 RPEQP1PULD T PU BHA#3(Coiltrack with thru-tubing WS) 17:00 18:45 1.75 0 5,100 PROD1 RPEQP1TRIP T RIH with EDC open. 18:45 19:15 0.50 5,100 5,132 PROD1 RPEQP1RGRP T Stop RIH-pump problems cannot keep prime. 19:15 20:15 1.00 5,132 8,490 PROD1 RPEQP1TRIP T RIH pumping.3 bpm.Tie in with-10 ft correction. 20:15 20:45 0.50 8,490 8,482 PROD1 RPEQP1WPST P P/U to setting depth TOWS 8470'. HS. Close EDC. P/U weight 35K. zero WOB. Pump pressure 2900 set, set down 3K WOB. 20:45 22:45 2.00 8,482 72 PROD1 RPEQP1TRIP P POOH laying in flo-pro. 22:45 23:30 0.75 72 0 PROD1 RPEQPI PULD P PJSM fopr laying down BHA 23:30 00:00 0.50 0 0 PROD1 WHPST PULD P P/U milling BHA with 2.80"window mills. 07/26/2012 Mill window from 8473'to exit point of 8482.55'continue time milling rathole to 8500'. 00:00 03:00 3.00 72 8,474 PROD1 WHPST TRIP P P/U&RIH with 2.80"window/string mill with 10'vibration joint. Minus 10ft correction. RIH dry tag 8473.5' 03:00 08:00 5.00 8,474 8,479 PROD1 WHPST MILL P P/U free spin 3200psi and start milling window as per procedure from 8474'at 1.45 bpm,3300, diff 526psi, 1 WHP 0,WOB.5K. 8475.4'-Light metal shavings over shaker, on auto driller. 08:00 08:30 0.50 8,479 8,479 PROD1 WHPST REAM P 5'milled. Make 3 reaming passes looks good Page 2 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 10:30 2.00 8,479 0 PROD1 WHPST TRIP P POOH 10:30 11:00 0.50 0 0 PROD1 WHPST PULD P At surface,monitor well for flow, PJSM 11:00 11:30 0.50 0 0 PROD1 WHPST PULD P LD BHA 4. Mills gauge 2.79 No-GO 11:30 12:00 0.50 0 0 PROD1 WHPST PULD P PU BHA#5(Weatherford fixed 1.25 ako with window mill,string mill,and 10'vibration joint.) 12:00 13:45 1.75 76 7,920 PROD1 WHPST TRIP P RIH 13:45 14:00 0.25 7,920 7,920 PROD1 WHPST DLOG P Tie in depth-11'correction 14:00 14:15 0.25 7,920 8,479 PROD1 WHPST TRIP P RIH To TOW 14:15 14:30 0.25 8,479 8,479 PROD1 WHPST MILL P Dry tag 8479.37'. PU 10', bring pumps on. RIH slowly. off bottom parammeters 1.5 bpm,3500 ctp, 16k rihw, 3869 bhp,688 diff psi. 14:30 19:30 5.00 8,479 8,482 PROD1 WHPST MILL P Start milling as per program 8478.9' 1.5 bpm, 17.5K CTW,3845 bhp, 760 diff psi, .6k wob. 19:30 21:30 2.00 8,482 8,485 PROD1 WHPST MILL P 8482.55 WOB dropped off,window exit, 1.45 bpm,3600, BHP 3876,diff 880,WOB 0.4K, ROP 1.3 fph. 21:30 23:00 1.50 8,485 8,488 PROD1 WHPST MILL P Increase to 2 fph. 98%formation in returns 1%cement. 23:00 00:00 1.00 8,488 8,500 PROD1 WHPST MILL P Start increasing speed&WOB- 1.45 bpm,3700, BHP 3930,WHP 150,WOB 2.3K, ROP 17 fph. 07/27/2012 Drill build section to 8780'. P/U Drilling BHA with.8 ako&3"Bi-center. Fluid loses from 8680'roughly 1/4 bpm.24 hour losses=145 bbls Tie into RA marker window depths: TOWS=8471' TOW=8473 BOW=8482.5' 00:00 01:45 1.75 8,500 8,500 PROD1 WHPST REAM P Make three reaming passes. Seen motor work @ 8474',did get lighter with each pass. Dry run @ 10 fpm- clean. P/U weight 33K. 01:45 02:15 0.50 8,468 8,468 PROD1 WHPST SIPB P Sit just above the window and do static test. Start-Circ 870,WHP 522, BHP 3760 psi. END-Circ 615,WHP 514, BHP 3689 psi 02:15 05:00 2.75 8,468 0 PROD1 WHPST TRIP P Open EDC-POOH holding MPD. 05:00 05:15 0.25 0 0 PROD1 WHPST SFTY P At surface-Close SSSV monitor well for 15 minutes. Crew change. PJSM for laying down BHA. 05:15 05:45 0.50 0 0 PROD1 WHPST PULD P LD BHA 5 Mills 2.80 Go,2.79 No-Go.Window mill has good wear in core 05:45 06:15 0.50 0 0 PROD1 DRILL PULD P PU BHA 6.(2 deg heavy AKO, Bi-Center bit) 06:15 06:45 0.50 0 0 PROD1 DRILL SVRG P Service injector head, reel, levelwind. 06:45 08:15 1.50 62 7,920 PROD1 DRILL TRIP P RIH, EDC open Page 3 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 08:30 0.25 7,920 7,920 PROD1 DRILL DLOG P Tie in depth-10'correction 08:30 08:45 0.25 7,920 8,500 PROD1 DRILL TRIP P Close EDC, RIH drift window with build BHA. PUH above window 08:45 09:45 1.00 8,450 8,450 PROD1 DRILL CIRC P Open EDC,Swap out milling fluid to 9.5ppg Drilling Mud. Flo-Pro 09:45 11:00 1.25 8,500 8,550 PROD1 DRILL DRLG P Drill Ahead 1.5 bpm, 3500 ctp,3966 bhp,2-3 wob, 14k ctw 11:00 11:15 0.25 8,550 8,550 PROD1 DRILL DLOG P PU log RA marker, allow time for DD to calculate build. RIH TOWS 8471' TOW 8473' RA 8478' BOW 8482.5' 11:15 13:15 2.00 8,550 8,680 PROD1 DRILL DRLG P Drill Ahead 1.5 bpm, 3700 ctp, 3978 bhp,0 whp, 15 ctw, 13:15 13:30 0.25 8,680 8,630 PROD1 DRILL WPRT P Start losing returns. intially.5 bpm. PU 30K looks good.Wipe 50'.RBIH 13:30 14:30 1.00 8,680 8,780 PROD1 DRILL DRLG P RBIH Cont drilling 1.5 bpm in, 1.14 out, 3498 ctp, 52 whp,3968 bhp 14:30 17:30 3.00 8,780 72 PROD1 DRILL TRIP P Land build. 8780'. POOH 30K puw. 17:30 18:15 0.75 72 72 PROD1 DRILL SFTY P PJSM crew change-Undeploy BHA 18:15 19:45 1.50 72 0 PROD1 DRILL PULD P Undeploy BHA#6-well losing roughly 1/4 bpm.Order more mud. 19:45 20:30 0.75 0 0 PROD1 DRILL SFTY P Pre-spud with Gary crew 20:30 22:00 1.50 0 72 PROD1 DRILL PULD P PJSM-deploy BHA#7 with .8 AKO &new Bi-center. Injected roughly 25 bbls at surface holding MPD. 22:00 00:00 2.00 72 8,520 PROD1 DRILL TRIP P RIH with EDC open. Lost 30 bbls while RIH.Tie in-10ft.Clean through window. 07/28/2012 Continue drilling ahead on A lateral. Total losses for 24 hours= 199 bbls. 00:00 02:15 2.25 8,780 8,930 PROD1 DRILL DRLG P 1.50 bpm, 3680, BHP 4010, ECD 12, WOB 1.3K, ROP 95, rate out 1.15 bpm. 02:15 03:15 1.00 8,930 8,930 PROD1 DRILL WPRT P Wiper trip with MADD pass from 8765'P/U weight 32K. 03:15 05:45 2.50 8,930 9,080 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,3680, BHP 3990, ECD 12, ROP 35,WOB 2.1K, Ct weight 15K, rate out 1.25 05:45 06:30 0.75 9,080 8,500 PROD1 DRILL WPRT P Wiper trip back to window 30K puw 06:30 07:30 1.00 9,080 9,100 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,3680, BHP 3990, ECD 12, ROP 35,WOB 2.1K, Ct weight 15K, rate out 1.25 07:30 08:00 0.50 9,100 8,690 PROD1 DRILL WPRT P PU 30K. Large amounts of magentic interference. Peform check shot to compare surveys. RBIH 08:00 08:15 0.25 9,100 9,135 PROD1 DRILL DRLG P Drill Ahead- 1.45 bpm,3640, BHP 3990, ECD 12.06,WOB 1-2K,Ct weight 15K, rate out 1.25 08:15 08:45 0.50 9,135 8,890 PROD1 DRILL WPRT P PUH discuss with town, surveys out of BHI spec. Magnetic Interference p 9 shows to be high on USGS website. RBIH Page 4 of 18 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 08:45 12:00 3.25 9,135 9,290 PROD1 DRILL DRLG P Drill Ahead sending surveys for IIFR after every 150'drilled. 1.45 bpm, 3590, BHP 4001,WOB 1-2K,Ct weight 15K, rate out 1.25 12:00 13:15 1.25 9,290 8,500 PROD1 DRILL WPRT P Wiper trip to window,30K puw. Log RA marker for depth tie in.+1' _correction 13:15 16:00 2.75 9,290 9,440 PROD1 DRILL DRLG P Drill Ahead-1.45 bpm in, 1.25 out, 3640, BHP 4050, ECD 12.2,WOB 1-2K,Ct weight 15K, 16:00 17:00 1.00 9,440 8,500 PROD1 DRILL WPRT P Wiper trip to window 30K puw 17:00 19:00 2.00 9,440 9,590 PROD1 DRILL DRLG P Drill ahead 19:00 20:00 1.00 9,590 8,500 PROD1 DRILL WPRT P Wiper trip-P/U weight33K. Follow wiper schedule. 20:00 22:00 2.00 9,590 9,740 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm, 3780, BHP 4065, ECD 12.2, ROP 98,WOB 2K, Ct weight 14K, rate out 1.33 22:00 00:00 2.00 9,740 8,180 PROD1 DRILL WPRT P Wiper to 3.5"-P/U weight 33K.Tie in correction+1ft. 07/29/2012 Continue drilling ahead on A lateral. Mud swap with 2220'on system.Total losses for 24 hours= 171 bbls. 00:00 02:00 2.00 9,740 9,890 PROD1 DRILL DRLG P Drilling ahead-turning up sharp to find sand. 1.45 bpm,3600, BHP 4020, ECD 12.2, ROP 90,WOB 2K, CT weight 15K. rate out 1.32 bpm. Pump 100 bbls of new mud down to top up the active pits. 02:00 02:45 0.75 9,890 9,000 PROD1 DRILL WPRT P Wiper trip-P/U weight 31K. 890;' wiper trip 02:45 05:15 2.50 9,890 10,040 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,3750, BHP 4090, ECD 12.3,WOB 2K,Ct weight 10K. rate out 1.35 bpm 05:15 06:00 0.75 10,040 8,890 PROD1 DRILL WPRT P Wiper trip.30K puw 1150' 06:00 08:15 2.25 10,040 10,190 PROD1 DRILL DRLG P Drilling ahead-1.48 bpm,3830, BHP 4118, ECD 12.3,WOB 1-2k,Ct weight 11K. rate out 1.30 bpm 08:15 10:45 2.50 10,190 8,200 PROD1 DRILL WPRT P Wiper trip up to window 30k puw. PU to 8200'jetting 4 1/2"tubing. RBIH. Log RA marker. 0 Correction. 10:45 12:30 1.75 10,190 10,340 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,3750, BHP 4090, ECD 12.3,WOB 2K,Ct weight 10K. rate out 1.35 bpm 12:30 13:30 1.00 10,340 10,340 PROD1 DRILL WPRT P Wiper trip 30K puw. 850' 13:30 15:00 1.50 10,340 10,490 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm, CTP 3890, BHP 4160, ECD 12.3,WOB 2K, Ct weight 9K. rate out 1.35 bpm 15:00 16:15 1.25 10,490 9,340 PROD1 DRILL WPRT P Wiper trip 30k PUW, 1150' 16:15 18:00 1.75 10,490 10,627 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm, CTP 3890, BHP 4160, ECD 12.3,WOB 2K, Ct weight 9K. rate out 1.35 bpm. Stacking weight, negative 5K. Page 5 of 18 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 18:00 19:00 1.00 10,627 10,630 PROD1 DRILL DRLG P P/U 300'due to weight stacking and noise on injector, Ct weight 33K RIH to inspect injector and drill final 20ft. Injector sounds good, increase chain tension.Try drill ahead-WOB 1.9K, Ct weight-5K,slow ROP 5,ankerite in samples.Trucks enroute for mud swap. 19:00 22:00 3.00 10,630 8,180 PROD1 DRILL WPRT P Wiper trip to 3.5"P/U weight 33K. Tie in correction Zero.Start pumping new mud while RIH. 22:00 23:30 1.50 10,630 10,720 PROD1 DRILL DRLG P New mud at bit-Drilling ahead- drilled through ankerite.Weights back to normal. 1.45 bpm, 3780, BHP 4157, ECD 12.6, ROP 66, WOB 2K,Ct weight 10K. New mud _around holding 90 psi WHP. 23:30 00:00 0.50 10,720 10,750 PROD1 DRILL DRLG P P/U 100'due to losing prime on pumps-33K. Drill ahead. 07/30/2012 BHA Bit stuck @ 10923',TOF 10867'.Try to work free, no luck-discconnect from BHA. P/11 Fishing BHA with GS, Up jars,weight bars&intensifier. Latch in to fish,20 hits,string weight 60K,WOB-15K. No luck, spot mineral oil&diesel. No luck.39 hits total.Try to relatch fish, no luck. POOH to inspect BHA. 00:00 00:30 0.50 10,750 10,780 PROD1 DRILL DRLG P Drill ahead 00:30 01:30 1.00 10,780 10,780 PROD1 DRILL WPRT P Wiper trip 850'P/U weight 32K. 01:30 03:30 2.00 10,780 10,923 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm, 3780, BHP 4190,WJP 110, ECD 12.8,WOB 2K,CT weight 8K, ROP 105, rate out 1.32 bpm. Pump 5/5 sweep prior to wiper. 03:30 05:00 1.50 10,923 10,867 PROD1 DRILL WPRT T Hard stall, P/U weight 44K, Bit stuck.Try to cycle 5 times no luck Max P/U 50K&-6 WOB. Sit in nuetral and try to pump to move fluid. Pressure up immediately . BHP leaks down to 3760' Discuss with town,try pump down Backside to 850 psi WHP-no luck. Try max pull of 60K -11.8 K WOB cycle three more times. Go to nuetral weight, bleed down CT string and Disconnect BHA.@ 10923 Bit depth. Fishing neck 10867' 05:00 09:00 4.00 10,867 0 PROD1 DRILL TRIP T Total cycle 14 times. P/U 5 ft-start pumping 1.5 bpm and circ to clean fishing neck. Reset depths. POOH for fishing BHA following WHP for MPD. 09:00 09:15 0.25 0 0 PROD1 DRILL SFTY T At surface. Close SSSV.Monitor well for flow 09:15 09:45 0.50 0 0 PROD1 DRILL PULD T SSSV tested good. LD BHA 7. 09:45 10:45 1.00 0 0 PROD1 DRILL SVRG T Service inj. head, reel,service MP choke, Function test BOPE 10:45 12:15 1.50 0 0 PROD1 DRILL PULD T MU fishing BHA 8 12:15 14:15 2.00 61 8,450 PROD1 DRILL TRIP T Open SSSV, RIH Page 6 of 18 Time Logs Date From To Dur S. Depth E. Deoth Phase Code Subcode T Comment 14:15 15:15 I 1.00 8,450 10,867 PROD1 DRILL TRIP T Weight check 30K up, 16k down. RIH to fish 15:15 16:30 1.25 10,867 10,867 IPROD1 DRILL FISH T Weight check 31k up, 14k RIW. RIH latch into fish 3K down.Trap MP pressure 4193 BHP. Bleeds down rapidly, PU 50k.jar hit, PU 60K. No luck. Cock jars PU 60k.Jar hit. No luck.. Pump ann. psi up to 4200 psi. PU 60K X 5. No luck. Bleed down psi on well 3600 BHP..Jar X 5, no luck. _Total jars 15. 16:30 17:00 0.50 10,863 10,863 PROD1 DRILL FISH T Set down 2K 10863'. Pump mineral down to bit thru CT 7 bbrls total. Possibly pulled fish 4'up hole. 17:00 17:18 0.30 10,864 10,864 PROD1 DRILL FISH T Shut in choke.squeeze 7bbrls mineral away around BHA.Attempt to jar 1 time. No luck RBIH.set down ::4k 17:18 17:27 0.15 10,864 10,864 PROD1 DRILL FISH T Let mineral oil soak. 17:27 18:57 1.50 10,864 10,864 PROD1 DRILL FISH T Pick up attempt to jar fish free. 11 18:57 19:57 1.00 10,864 10,864 PROD1 DRILL FISH T Spot mineral 7bbrls. let soak 30min. Order out Slick Diesel. 19:57 20:30 0.55 10,864 10,864 PROD1 DRILL FISH T Pick up attempt to jar fish free 7 pulling 65-70k 13-15k wob. 20:30 21:15 0.75 10,864 10,864 PROD1 DRILL FISH T ,Spot Slick Diesel around fish. 10 bbrls 21:15 21:30 0.25 10,864 10,864 PROD1 DRILL FISH T Let diesel soak 21:30 22:00 0.50 10,864 10,866 PROD1 DRILL FISH T Attempt to jar fish free,pulling 65 K 13-18k wob. 22:00 23:00 1.00 10,866 10,866 PROD1 DRILL FISH T Disconnect off fish.Wipe pipe and gripper blocks clean of oil for more pull without slipping. RBIH unable to latch fish.. 23:00 00:00 1.00 10,866 10,867 PROD1 DRILL FISH T P/U 300ft and circ B/U to clean up ;diesel. RIH pumping 1.35 bpm to clean up GS,sat down @ 10,863'. 3K WOB.Stop pumping. RIH to 10866'Not gaining WOB. P/U weight 36K. RIH set down @ 10867'WOB 3K. P/U 37K POOH pumping down backside. Unable to latch or have fish? 07/31/2012 Perform clean out to 10864'W/D331 mill. Latched fish easily after cleanout.Activate Hipp tripper down for 10 minutes, up for 1 hour,tools came free when pulling 55k.TOOH to check BHA. Total fluid losses to formation 181 bbls. 00:00 03:30 3.50 10,867 60 PROD1 DRILL TRIP T POOH pumping down the backside in case fish is latched. Small weight bobble at window. 03:30 04:00 0.50 60 0 PROD1 DRILL SFTY T Shut SSSV-flow check at surface. PJSM for laying down BHA. Page 7 of 18 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 04:00 05:00 1.00 0 0 IPROD1 DRILL PULD T Lay down BHA-GS looks like it was lodged in the down(latch position). Took apart and packed with gravel/formation.Set back up on MP, Open SSSV. Call town to discuss tool being packed off. 05:00 06:00 1.00 0 0 PROD1 DRILL PULD T Decision made to P/U 2.79"D331 with upcutters for a clean out run. PJSM to P/U new BHA and set up motor to.8 AKO. 06:00 07:30 1.50 0 72 PROD1 DRILL PULD T Crew change-Close SSSV-flow check. P/U Clean out BHA. 07:30 11:00 3.50 72 10,856 PROD1 DRILL TRIP T RIH pumping.6 bpm.Tie in-11.5 ft. Clean through window.Continue RIH. 1.5 bpm. Started to get light crude/diesel across shakers near TD. Rate out increased after well cleaned up.Sitting down on fill, WOB 1K, lower pump rates&P/U 38K. 11:00 12:00 1.00 10,856 10,864 PROD1 DRILL FCO T RIH 20 fph, 1.5 bpm,3400, BHP 4120. diff 392,Tag @ 10864', P/U 32K. RIH 10 fph,-Stall again @ 10864'.Wipe up slowly, RIH dry tag, 1K down.clean to tag. 12:00 16:00 4.00 10,864 62 PROD1 DRILL TRIP T POOH pumping 1.5 bpm. 16:00 17:00 1.00 62 51 PROD1 DRILL PULD T Close SSSV-flow check. lay down FCO BHA. P/U Hip tripper BHA#10. 17:00 20:15 3.25 51 10,667 PROD1 DRILL TRIP T Pre-set depth-10ft at surface. RIH 100ft test hip-tripper.Good test. Open EDC&RIH.Stop above window, close EDC.WT check @ 31k,continue RIH 20:15 21:45 1.50 10,867 10,850 PROD1 DRILL FISH T Latch fish @ 10667'with no problem. Stack 1.6 WOB, hip trip down for 10 minutes,stack a little more&stall out. Pull up on fish to 39,000k(-3000k)Pump @.9 BPM. Gradually increase pull on fish. Hipp Trip for 1 —hour, pull 55k,came free. 21:45 00:00 2.25 10,850 4,000 PROD1 DRILL TRIP T POOH pumping over the top. 08/01/2012 Recovered fish from 10867'.Set anchored billet&5 jts of slotted liner(TOB @ 10430') Total fluids losses to formation 103 bbls. 00:00 00:45 0.75 4,000 0 PROD1 DRILL TRIP T Get well above SSSV.dump. bump up. 00:45 01:15 0.50 0 0 PROD1 DRILL SFTY T Perform no flow test, looks good. 01:15 03:00 1.75 0 0 PROD1 DRILL PULD T Lay down BHA, no fish. BHA&GS look good. Discuss options, Baker tool hand suspects GS came loose when fish rapidly pulled free.Conduct TGSM, load BHA back in the hole. Inspect injector,change out shaker baskets. Page 8 of 18 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 03:00 06:15 3.25 51 10,821 PROD1 DRILL TRIP T RIH to 300',test Hip Tripper,good. RIH W/EDC open stop @ 8450'. close EDC.Continue RIH. 06:15 07:00 0.75 10,821 10,867 PROD1 DRILL FISH T Weight check 32K, .4 bpm,2900, BHP 4120,diff 1240.Sit down @ 10,863'-pressure spike. Stop pumping sit down on fish 2.5K. Let the coil bleed down. P/U weight 34K. RIH tag bottom again-10864'2.5K WOB P/u 35K. RIH-3K 10, 866.83'-P/U 34K RIH-3.2K 10,867'-P/U 35K. RIH-Start losing weight earlier- push down 10,868'WOB 2.8K- bleed CT down, Good indication of set down. P/U weight 37K P/U 07:00 11:30 4.50 10,867 110 PROD1 DRILL TRIP T POOH pumping down backside. Seen over pulls to 40K @ 10600& 10240'. Keep speed 50 fpm in cased hole. 11:30 13:30 2.00 110 0 PROD1 DRILL PULD T Close SSSV-15 minute flow check, PJSM for laying down fish. Entire BHA recovered. Set back up on MP. 13:30 14:00 0.50 0 0 PROD1 DRILL PULD T Clean up rig floor and call town to discuss next step. 14:00 15:00 1.00 0 0 PROD1 DRILL SFTY P "I Believe"presentation from Shon& Vance. 15:00 17:00 2.00 0 231 COMPZ CASING PUTB T Start P/U 5 joints of slotted liner& anchored billet. 17:00 20:45 3.75 231 10,600 COMPZ CASING RUNL T RIH Anchored Billet&5 jts of liner. Tie in for a-11'. RIH to just above window @ 8420'WP4 is getting the final blessing. Shut down the pumps, trap pressure.Close EDC. PUH& get 31k pu wt. Plan is on E-mail. TOB @ 10430'set slip @ 190 deg. Continue RIH to 10,600', Pull to neural wt. 10,600'-169.88 liner assembly tob billet @ 10,430' Pressure up to 3850 psi,to set billet. WOB @ 6k. 20:45 00:00 3.25 10,600 2,100 COMPZ CASING TRIP T Pick up slowly,start pumping a Btm's up while while moving tools slowly, pick up speed once 20 bbls ahead. 08/02/2012 Tagged top of billet al0432'. Kicked off billet&drilled ahead in AL3 to10915'.Wiper trip in progress.Total fluid losses to-formation-1-72 bbls 00:00 01:00 1.00 2,100 61 COMPZ DRILL TRIP T Continue TOOH. 01:00 03:00 2.00 61 72 PROD2 DRILL PULD T Watch 30 minutes no flow,while conduct pre-job for laying down BHA. Laydown BHA, pick-up drilling BHA, MWD re-boot computers. 03:00 06:00 3.00 72 10,432 PROD2 STK TRIP T RIH W/drilling BHA. 7930',tie in for a-11.5 correction. Page 9 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 09:00 3.00 10,432 10,432 PROD2 STK KOST T Dry tag TOB-KOTB as per procedure from 10431.45' 155 ROHS, 1.45 bpm,3350, BHP 4131, ROP 1fph,WOB.7K, Ct weight 13K, rate out 1.30. Stall @ 10481'X 2 Slip sticking, stacking CT weight.8-9K Stall @ 10482'X 2 slip sticking- Wipe up 100'try again. Better weight tranfer. 09:00 12:00 3.00 10,432 10,452 PROD2 STK KOST T 10431.75'-Increase 776 lubes to 2%. Start milling again-1.45 bpm, 3518, BHP 4148, ROP 1 fph, rate out 1.30 bpm,WHP 155. Ct weight 14K. Light Alum shaving over shaker. Better weight transfer. 12:00 15:00 3.00 10,452 10,615 PROD2 DRILL DRLG T Start drilling ahead-1.45 bpm,3600, BHP 4180, ROP 70,WOB 1.3K, CT weight 12K, rate out 1.33 bpm. 15:00 17:30 2.50 10,615 10,615 PROD2 DRILL WPRT T Wiper trip to window P/U weight 32K 17:30 19:30 2.00 10,615 10,765 PROD2 DRILL DRLG T Drilling ahead 19:30 21:00 1.50 10,765 10,765 PROD2 DRILL WPRT T Pull 1150'wiper trip to 9615', RBIH 21:00 22:45 1.75 10,765 10,915 PROD2 DRILL DRLG T Drill ahead, 1.43 BPM @ 3686 PSI, 12.70 ECD 4190 BHP ROP 67 22:45 00:00 1.25 10,915 8,509 PROD2 DRILL WPRT T Wiper,35k off btm, one bobble to 38k. long wiper up. 08/03/2012 Drill AL3 to TD of 11,366'. Lay in liner pill.Total fluid losses to formation 166 bbls. 00:00 02:30 2.50 8,509 10,915 PROD2 DRILL WPRT T Continue wiper, Make a second trip in 4.5"liner. Log for tie in @ 8500, +1'correction. RBIH 02:30 05:30 3.00 10,915 11,065 PROD2 DRILL DRLG P Drill ahead, 1.43 BPM @ 3771 PSI, 4206 BHP WOB 1.5 ROP 81.5. Res off&gamma spike©—10970' ROP @ 30.Geo made call to town, continue drilling. 05:30 07:00 1.50 11,065 11,065 PROD2 DRILL WPRT P Wiper up, 35k off BTM. P/U 1100ft. 07:00 09:00 2.00 11,065 11,200 PROD2 DRILL DRLG P Drilling ahead-1.45 bpm, BHP 4215, ECD 12.7,WOB 1.7K, CT weight 6K, ROP 110, rate out 1.35 bpm. 09:00 12:00 3.00 11,200 11,200 PROD2 DRILL WPRT P Wiper trip 15ft early due to CT weight transfer. P/U weight 39K.Wipe to the 3.5"for final 150ft drilled. 12:00 17:00 5.00 11,200 11,366 PROD2 DRILL DRLG P Drilling ahead-1.45 bpm, 3770, BHP 4230,WOB 2.3K,CT weight 6K, ROP 7-possible ankerite. Drilled through, 150'wiper trip due to weight transfer. Drill ahead better CT weight transfer. 17:00 20:45 3.75 11,366 11,366 PROD2 DRILL WPRT P TD, pump sweeps -Wiper to window P/U weight 32K. Run back down& up. RBIH,send pill down coil to be at the bit. Page 10 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 00:00 3.25 11,366 1,000 PROD2 DRILL TRIP P Liner pill @ the bit,start laying in 45 bbls of flo pro liner pill.Chase out in the 3.5"TBG @ 80 FPM. Pull up past SSSV to 1000', keep pumps up until BTM's up.Shut down and open EDC. 08/04/2012 Ran liner in AL3,top of liner at 10,020'. Performed full BOP test.Test waved by Chuck Scheve. 00:00 01:00 1.00 1,000 72 PROD2 DRILL TRIP P @ 1000'RBIH W/Edc open,wash SSSV @ 1796'.Trip out to surface. 01:00 01:30 0.50 72 72 PROD2 DRILL SFTY P Shut SSSV,watch for 30 minutes for no flow.Conduct pre-job. 01:30 03:00 1.50 0 0 PROD2 DRILL PULD P Lay down BHA 03:00 06:00 3.00 0 1,390 COMPZ CASING PUTB P Conduct pre-job. Pick-up liner& BHA. 06:00 07:30 1.50 1,390 1,389 COMPZ CASING PUTB P Crew change PJSM for completing P/U liner&coiltrack assembly with a liner top billet. 07:30 10:00 2.50 1,389 11,366 COMPZ CASING RUNL P Open SSSV-600 psi below. RIH EDC closed pumping .3 bpm.Tie in -12ft, 32K P/U weight-5 WOB.Clean through window-tag bottom.4K WOB.clean to TD. 10:00 10:30 0.50 11,366 10,020 COMPZ CASING RUNL P P/U weight-38K,-2 WOB, RIH.Tag bottom set down 5K,bring pump rate up to 1.3 bpm,4100psi, P/U weight 31K. BOL=11366' TOB=10,020' 10:30 13:30 3.00 10,020 48 COMPZ CASING TRIP P Subtract out BHA-POOH pumping 1.3 bpm. 13:30 14:30 1.00 48 0 COMPZ CASING PULD P Close SSSV-flow check, PJSM for laying down BHA. Lay down BHA. 14:30 16:00 1.50 0 0 COMPZ CASING CIRC P Start Pumping MPD-Grease tree, choke manifold and surface valves. Install stinger on CT and flush CT string&stack with fresh water. 16:00-00:00 8.00 0 0 COMPZ CASING BOPE P Start BOPE testing 250 low/3500 high.Test inner reel iron. Shut down MPD until step 3. Note:went back on MPD @ 2030. Finished BOP test. Rig down associated equip. 08/05/2012 Tag billet @ 10020'. Kick off billet @ 40 ROH. Drilling ahead in AL1 lateral. 00:00 01:00 1.00 0 0 PROD3 STK BOPE P Finish rigging down after BOP test. Displace water out of coil to flo-pro. Shut SSSV,watch for no flow. 01:00 02:30 1.50 0 72 PROD3 STK PULD P Conduct pre-job. PU drilling BHA with.8 AKO and re-run Bi-center bit. 02:30 06:00 3.50 72 10,020 PROD3 STK TRIP P RIH W/drilling BHA, EDC closed, pump minium rate.open SSSV, pressure to 5500 PSI. @ 7945',tie in for a-12 correction. Continue Down, tag TOB @ 10,020 Page 11 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 09:00 3.00 10,020 10,050 PROD3 STK KOST P Start KOTB 40 ROHS-1.40 bpm, 3660, BHP 4161,WOB 1.2K, Ct weight 13K, ROP 1 fph, rate out 1.28. Good Al.Shavings over shaker, increase ROp as per procedure. Pulled a little heavy through billet, small weight bobble. 09:00 10:30 1.50 10,050 10,170 PROD3 DRILL DRLG P Start pumping new mud-drilling ahead 1.45 bpm, 3600, BHP 4131, WHP 50,WOB 1.3K,Ct weight 11K, ROP 70, rate out 1.38 bpm. 10:30 12:30 2.00 10,170 10,170 PROD3 DRILL WPRT P Wiper trip to window, P/U weight 32K-Clean through billet,clean mud to surface. Blow down the choke. RIH 12:30 15:00 2.50 10,170 10,320 PROD3 DRILL DRLG P Drilling ahead.Getting into betterA-3 sand. 15:00 16:00 1.00 10,320 10,320 PROD3 DRILL WPRT P Wiper trip-P/U weight 31K. Started to pull heavy at the billet-RIH and bring up pump rate. Lower rate and pull through with a little weight bobble,Wipe up 1000' RIH-clean through billet. 16:00 18:00 2.00 10,320 10,470 PROD3 DRILL DRLG P Drilling ahead-1.45 bpm,3680, BHP 4187, ROP 124,WOB 1K,Ct weight 12K, ECD 12.7, rate out 1.30 bpm. 18:00 21:00 3.00 10,470 10,470 PROD3 DRILL WPRT P Wiper trip P/U weight 31K.Slowed to 10 fpm coming through billet,3 K surface weight gain and 1.3 WOB. continue to wiper to window. 21:00 22:30 1.50 10,470 10,620 PROD3 DRILL DRLG P Drilling ahead-1.40 bpm,3550, BHP 4166,WHP 120,WOB 2K, Ct weight 10K, ROP 110, rate out 1.30 bpm. 22:30 23:30 1.00 10,620 10,620 PROD3 DRILL WPRT P Slow wiper to below Billet-P/U weight 31K. 23:30 00:00 0.50 10,620 10,650 PROD3 DRILL DRLG P Drill ahead 1.44 BPM @ 3762 PSI, BHP 4175 08/06/2012 Drill Ahead AL1 00:00 00:45 0.75 10,650 10,713 PROD3 DRILL DRLG P Drilling ahead. 00:45 01:00 0.25 10,713 10,713 PROD3 DRILL WPRT P Weight transfer down @ 10713', pull BHA wiper,34k pick-up wt. Pull up 100'. RBIH 01:00 01:45 0.75 10,713 10,770 PROD3 DRILL DRLG P Drill ahead to 10,770' 01:45 04:30 2.75 10,770 10,770 PROD3 DRILL WPRT P Wiper,33k off BTM.Turn around just before billet,jog down 50'. Pull up past billet,still see 4k spike, continue wiper to the window. RBIH 04:30 07:00 2.50 10,770 10,920 PROD3 DRILL DRLG P Drill ahead 1.44 BPM @ 3723 PSI, 4165 BHP, 12.75 ECD, 120 ROP 07:00 10:45 3.75 10,920 10,920 PROD3 DRILL WPRT P Wiper 31k pu wt. Pull up past billet @ 10020', pumps down,just a slight bobble-wiper up for a tie in,for a+1' correction.Continue back down Page 12 of 18 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 10:45 14:45 4.00 10,920 11,070 PROD3 DRILL DRLG P Drill ahead 1.45 BPM @ 3945 PSI, 4220 BHP, 1.6 WOB,slow going starting at 11,025'. broke out @ 11,046'back up to 93 ROP 14:45 16:30 1.75 11,070 11,070 PROD3 DRILL WPRT P Wiper up 30k off BTM. Sent 5 X 5 sweep down.decided to pull a 1150' wiper. 16:30 19:00 2.50 11,070 11,178 PROD3 DRILL DRLG P Drill ahead 1.46 BPM @ 3843 PSI, BHP 4217 PSI,80 ROP 1.22 WOB 10k surface wt. 19:00 20:48 1.80 11,180 8,500 PROD3 DRILL WPRT P No Weight Transfer, PUW 29K, Wiper to the window to clean hole. 20:48 22:12 1.40 8,500 11,180 PROD3 DRILL WPRT P Wrper back in hole, RIHW 13K 22:12 00:00 1.80 11,180 11,267 PROD3 DRILL DRLG P Drill Ahead, 1.46 bpm @ 3782 psi, BHP 4236, 1.8 WOB,2K surface Coil surface weight. 08/07/2012 TD Lateral AL1 11336', POOH, MU first liner section RIH to TD. POOH,MU second liner section, RIH 00:00 01:30 1.50 11,267 11,335 PROD3 DRILL DRLG P Drilling Ahead, 1.47 bpm,3813 psi, BHP 4271,3K Coil weight,WOB 1.3K, ROP 50fph 01:30 04:06 2.60 11,335 8,173 PROD3 DRILL WPRT P TD AL1 @ 11335', Pump 10/10 sweep,Wiper to the window. 04:06 04:30 0.40 8,173 11,336 PROD3 DRILL DLOG P RIH to RA Marker fora tie in, correction of+2.5'. RBIH tag @ 11,336' 04:30 09:30 5.00 11,336 0 PROD3 DRILL TRIP P lay in flo-pro liner pill,40 bbls. Continue out of hole,jetting tbg. 09:30 10:00 0.50 0 0 PROD3 DRILL SFTY P On surface,shut in SSSV,watch for no flow.Conduct PJSM. 10:00 11:00 1.00 0 0 PROD3 DRILL PULD P Lay down drilling BHA. 11:00 13:45 2.75 0 1,387 COMPZ CASING PUTB P PJSM. Pick-up liner, run#1. 13:45 17:15 3.50 1,387 11,334 COMPZ CASING RUNL P RIH W/AL1 liner run#1.See BTM flag for a+1' . Set liner @ 11,334'. Pump off,good. 17:15 17:27 0.20 11,334 8,478 COMPZ CASING DLOG P PUH and Tie into RA Marker 8478', No correction.Top of deployment sleeve is 9991'PUH to paint EOP flag at 8000' 17:27 20:03 2.60 8,478 0 COMPZ CASING RUNL P POOH 20:03 21:03 1.00 0 0 COMPZ CASING PULD P OOH, Shut SSSV, no flow. PJSM LD BHA 21:03 23:33 2.50 0 328 COMPZ CASING RUNL P PJSM,MU Liner BHA#17 23:33 00:00 0.45 328 COMPZ CASING RUNL P RIH with liner running BHA#17 08/08/2012 Finish setting AL1 second liner section,top of liner at 9721'. Kick off of billet into AL2 lateral. Drill Ahead 00:00 02:30 2.50 1,796 8,234 COMPZ CASING RUNL P Continue Running in hole with second AL1 liner BHA#17, Bit Speed 20 fpm passing all Jewelry with Anchor Billet. 02:30 02:42 0.20 8,234 8,258 COMPZ CASING DLOG P Tie into Marker in the HRZ(7919'), correction of-12.5', No correction at flag.Close EDC adjust choke to maintain BHP. Page 13 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:42 03:12 0.50 8,258 8,424 COMPZ CASING RUNL P Continue into the hole,Set down 3-4K surface weight, No Down hole WOB. PUH weight 29.7k, RBIH little weight bobble RIH 03:12 04:30 1.30 8,424 9,990 COMPZ CASING RUNL P Continue in hole,Set down 2K. 04:30 04:42 0.20 9,990 9,986 COMPZ CASING RUNL P Orient and Set Anchor at 200 degrees ROHS.Anchored billet at 9723', PUH 31K 04:42 06:42 2.00 9,986 53 COMPZ CASING RUNL P POOH 06:42 07:00 0.31 53 53 COMPZ CASING SFTY P Shut in SSSV,watch for no flow. Conduct PJSM 07:00 08:00 1.00 53 0 COMPZ CASING PULD P Lay down BHA#17. 08:00 09:00 1.00 0 72 PROD4 DRILL PULD P PJSM, pick-up drilling BHA 09:00 12:00 3.00 72 9,722 PROD4 STK TRIP P RIH tie in for-12'correction. Dry tag TOB @ 9721'. 12:00 14:30 2.50 9,722 9,727 PROD4 STK WPST P Pick up. back on pumps, 1.47 BPM @ 3786 PSI ease down,TF 170 ROHS.start out @ 1 FPH,then go to 2' FPH 14:30 16:30 2.00 9,727 9,880 PROD4 DRILL DRLG P 5'past billet, Drill ahead 1.46 BPM @ 3832 PSI, ROP 70 1.16 WOB 16k surface weight. Drill down to 9760'. Pull up past billet with pumps down, drift looks good. RBIH and continue �( drilling. 16:30 17:30 1.00 9,880 8,510 PROD4 DRILL WPRT P Wiper up to window 31k off BTM 17:30 18:30 1.00 8,510 9,880 PROD4 DRILL WPRT P Wiper back in hole, RIHW 17k 18:30 20:00 1.50 9,880 10,020 PROD4 DRILL DRLG P BOBD 1.46 bpm 3760psi, BHP 4149, 13k surface weight. 20:00 20:36 0.60 10,020 9,000 PROD4 DRILL WPRT P Wiper, PUW 33k 20:36 21:18 0.70 9,000 10,020 PROD4 DRILL WPRT P Wiper back in hole, RIHW 16k 21:18 22:48 1.50 10,020 10,170 PROD4 DRILL DRLG P BOBD, 1.46bpm, 3833psi, BHP 4185,Surface weight 13k 22:48 00:00 1.20 10,170 8,508 PROD4 DRILL WPRT P Wiper to the tubing tail, PUW 33k 08/09/2012 Drill AL2 Lateral 00:00 01:42 1.70 8,508 10,170 PROD4 DRILL WPRT P Wiper back in hole, RIHW 17k 01:42 03:30 1.80 10,170 10,320 PROD4 DRILL DRLG P BOBD, 1.42bpm, 3620psi, BHP 4181, ROP 140fph, Surface weight 12K. Start Mud swap 03:30 04:12 0.70 10,320 9,450 PROD4 DRILL WPRT P Wiper up to 9450', PUW 33k 04:12 04:48 0.60 9,450 10,320 PROD4 DRILL WPRT P Wiper back in hole, RIHW 04:48 06:09 1.35 10,320 10,470 PROD4 DRILL DRLG P BOBD 1.46bpm,3622psi, BHP 4205, ROP 100 fph, 12k surface weight. 06:09 07:30 1.36 10,470 10,470 PROD4 DRILL WPRT P 1200'wiper. RBIH 07:30 09:15 1.75 10,470 10,620 PROD4 DRILL DRLG P Drill ahead 1.45 BPM @ 3900 PSI 4219 BHP 1.6 WOB 10k surface wt. 09:15 12:15 3.00 10,620 10,620 PROD4 DRILL WPRT P Wiper up to TT&tie in. 33k off BTM. jog the 4.5"liner, RBIH tie in for a +1. Page 14 of 18 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 12:15 17:33 5.30 10,620 10,770 PROD4 DRILL DRLG P Drill ahead 1.44 BPM @ 3790 PSI, 4190 BHP, 1.30 WOB, 11.2 coil wt. 17:33 18:03 0.50 10,770 9,800 PROD4 DRILL WPRT P Wiper up hole, PUW 30k 18:03 18:33 0.50 9,800 10,770 PROD4 DRILL WPRT P Wiper back in hole, RIW 16k 18:33 21:03 2.50 10,770 10,920 PROD4 DRILL DRLG P Drilling Ahead 1.40 bpm, 3660 psi, Surface weight 11k, ROP 70fph 21:03 22:51 1.80 10,920 8,200 PROD4 DRILL WPRT P Wiper to the window, PUW 31k 22:51 23:59 1.14 8,200 10,185 PROD4 DRILL WPRT P Wiper back in hole, RIHW 08/10/2012 Drill AL2 lateral as per plan 00:00 00:12 0.20 10,185 10,900 PROD4 DRILL WPRT P Continue wiper back in hole 00:12 01:48 1.60 10,900 11,015 PROD4 DRILL DRLG P BOBD, 1.45bpm at 3620psi, ROP 66fph,5k surface weight,2k WOB 01:48 02:00 0.20 11,015 10,915 PROD4 DRILL WPRT P Drilling on Ankerite, BHA wiper 02:00 04:30 2.50 10,915 11,070 PROD4 DRILL DRLG P BOBD, 1.45 bpm at 3830, BHP 4284, ROP 4fph 04:30 06:00 1.50 11,070 11,070 PROD4 DRILL WPRT P Wiper to the Billet, PUW 30k. RBIH 06:00 07:45 1.75 11,070 11,173 PROD4 DRILL DRLG P Drill ahead 1.44 BPM @ 3980 PSI, 4283 BHP, 1.3 WOB,70 ROP @ 11,173'having wt transfer issues. 07:45 08:00 0.25 11,173 11,173 PROD4 DRILL WPRT P Pull 200'wiper, RBIH 08:00 09:00 1.00 11,173 11,207 PROD4 DRILL DRLG P Drill ahead.Still having wt transfer problems. Pump 5 X 5 sweep 09:00 11:45 2.75 11,207 11,207 PROD4 DRILL WPRT P Wiper to window 31k off BTM 11:45 14:00 2.25 11,207 11,350 PROD4 DRILL DRLG P Drill ahead 1.4 BPM @ 4043 PSI, 4265 BHP, 90 ROP, reach TD of 11,350'. 10 x 10 sweep already on the way down. 14:00 16:24 2.40 11,350 8,200 PROD4 DRILL WPRT P Wiper up to the TT, PUW 31k 16:24 18:24 2.00 8,200 11,350 PROD4 DRILL WPRT P Wiper back in hole, RIW 17k 18:24 19:54 1.50 11,350 8,500 PROD4 DRILL DISP P Lay in liner running pill with beads 19:54 21:54 2.00 8,500 0 PROD4 DRILL TRIP P POOH 21:54 22:12 0.30 0 0 PROD4 DRILL TRIP P OOH,Shut SSSV w/800psi, bleed pressure down and monitor for 15min. 0 PROD4 DRILL PULD PJSM LD Drilling BHA#18 22:12 23:12 1.00 0 0 COMPZ CASING RUNL P PJSM, MU first liner section, Kick while tripping tubing drill duration of 1 min 40sec. 23:12 00:00 0.80 0 492 COMPZ CASING RUNL P Continue to MU first liner section 08/11/2012 TD AL2 Lateral section, RIH and set both liner sections to TD 11349'. MU RIH with AL2-01 Build drilling BHA. 00:00 01:45 1.75 0 1,237 COMPZ CASING PUTB P Cont PU Liner section#1 35jts+2 Pups 01:45 03:45 2.00 1,237 8,349 COMPZ CASING PUTB P RIH W/Al2 liner run#1 Page 15 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:45 04:45 1.00 8,349 11,349 COMPZ CASING RUNL P Stop @ flag correct depth(Minus 12 ft).Cont RIH,Tag bottom. Release off liner, PUH, Log RA tie in, no correcetion. 04:45 07:45 3.00 8,337 0 COMPZ CASING RUNL P Cont POOH, painted 6900 EOP flag 07:45 08:45 1.00 0 0 COMPZ CASING PUTB P On surface.Shut SSSV&watch for flow. PJSM, Lay down BHA. 08:45 13:15 4.50 0 1,502 COMPZ CASING RUNL P PJSM, Pick-up liner run#2, mu coil trak,and strip on. 13:15 17:15 4.00 1,502 10,155 COMPZ CASING RUNL P RIH,AL2 liner section#2 to flag @ 6900'-10'correction. Continue in hole Tag up @ 10,155. Pu wt 34.5k. Set back down, pump off. 17:15 19:15 2.00 10,155 0• COMPZ CASING RUNL P TOOH 19:15 19:33 0.30 0 0 COMPZ CASING RUNL P OOH, Shut SSSV w/800psi, Bleed down and monitor well for flow at the shaker. No Flow. 19:33 20:03 0.50 0 0 COMPZ CASING RUNL P LD AL2 second liner running BHA. 20:03 20:33 0.50 0 0 PROD5 DRILL BOPE P Perfom Function test of BOPE 20:33 21:15 0.70 0 0 PRODS DRILL CTOP P RU and PT Drillers side PDL 21:15 22:33 1.30 0 0 PRODS STK PULD P MU KOB BHA#21,with a 1.5 degree motor and RR HCC Bit.Test BHI tools 22:33 00:00 1.45 0 5,895 PROD5 STK TRIP P RIH W/drilling BHA. 08/12/2012 Run Completion in AL2 lateral,set billet top at 8695, Kick off of billet&drill build section to 9000'. POOH for Lateral section BHA. RIH and drill from 9000'-9317' 00:00 00:30 0.50 5,895 7,940 PRODS STK TRIP P Continue in hole 00:30 00:42 0.20 7,940 7,964 PRODS STK DLOG P Tie in correction of-12' 00:42 01:06 0.40 7,964 8• ,695 PRODS STK TRIP P Coniine to RIH 01:06 03:36 2.50 8,695 8,717 PROD5 STK WPST P RIW 18k, PUW 29.5k, 1.42bpm, 3580psi, BHP 4063. Kick off Billet as per plan. Near Bit Inclination is showing 92.1 degrees. 03:36 04:12 0.60 8,717 8,683 PRODS DRILL WPST P Dry Drift KOP clean out of hole and in hole. PUW 29.5k 04:12 04:24 0.20 8,683 8,717 PRODS DRILL WPST P RBIH, RIW 15k 04:24 06:24 2.00 8,717 8,840 PROD5 DRILL DRLG P BOBD, 1.45bpm at 3583psi BHP 4066, Surface weight 14k,WOB 1900lbs ROP 70fph 06:24 07:00 0.60 8,840 8,840 PRODS DRILL WPRT P Wiper up the window, RBIH 07:00 09:15 2.25 8,840 9• ,000 PRODS DRILL DRLG P Drill ahead drilling build to 9000' 09:15 13:00 3.75 9,000 72 PROD5 DRILL TRIP P Trip out for different drilling BHA 13:00 15:00 2.00 0 72 PRODS DRILL PULD P On surface. Shut in SSSV,watch for flow.Conduct PJSM for BHA lay down. PJSM,pick-up drilling BHA. Perform injector maintenance,suck out grease out of the sump. 15:00 17:00 2.00 72 7,940 PROD5 DRILL TRIP P RIH W/drilling BHA Page 16 of 18 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 17:00 17:15 0.25 7,940 7,978 PROD5 DRILL DLOG P 7940'Log for tie in (-12') 17:15 17:45 0.50 7,978 9,000 PROD5 DRILL TRIP P Continue RIH 17:45 19:33 1.80 9,000 9,140 PROD5 DRILL DRLG P BOBD, 1.42bpm at 3620psi, 15k surface weight,WOB 2k, ROP 80fph 19:33 20:03 0.50 9,140 8,500 PROD5 DRILL WPRT P Wiper to the window, PUW 31k, BHP4130 20:03 20:45 0.70 8,500 9,140 PROD5 DRILL WPRT P Wiper back in hole, RIHW 16k, .8% drill solids, 1584'drilled on Mud System.Start new mud down hole 20:45 22:45 2.00 9,140 9,290 PRODS DRILL DRLG P BOBD, 1.45bpm @ 3740psi, BHP 4125,surface weight 13k, WOB 2k, ROP 80fph. New Mud at 9156'. 22:45 23:15 0.50 9,290 8,500 PRODS DRILL WPRT P Wiper to the window, PUW 30k 23:15 23:45 0.50 8,500 9,290 PRODS DRILL WPRT P Wiper back in hole, RIW 17k 23:45 00:00 0.25 9,290 9,317 PRODS DRILL WPRT P BOBD, 1.45bpm,at 3598psi.15k surface weight,WOB 2k, ROP 92fph BHP 4051 psi 08/13/2012 TD AL2-01 Lateral, MU Liner and RIH 00:00 01:30 1.50 9,317 9,440 PROD5 DRILL DRLG P OBD, 1.45bpm at 3600psi,WOB 1.6k, ROP 100fph, BHP 4064psi 01:30 02:06 0.60 9,440 8,500 PROD5 DRILL WPRT P Wiper to the window, PUW 30k 02:06 02:18 0.20 8,500 8,526 PROD5 DRILL DLOG P Tie in correction of plus 1' 02:18 02:48 0.50 8,526 9,440 PROD5 DRILL WPRT P Wiper back in hole, RIW 15k 02:48 06:00 3.20 9,440 9,590 PROD5 DRILL DRLG P BOBD, 1.45bpm at 3468psi,WOB 1.5k, ROP 90fph 06:00 07:30 1.50 9,590 9,590 PRODS DRILL WPRT P Wiper to window, RBIH 07:30 09:30 2.00 9,590 9,740 PROD5 DRILL DRLG P Drill ahead, 1.44 BPM @ 3809 PSI, ROP 84, BHP 4100,WOB 1.4, 13k coil wt. 09:30 11:00 1.50 9,740 9,740 PRODS DRILL WPRT P Wiper to 8710'31k off btm. RBIH 11:00 13:00 2.00 9,740 9,890 PROD5 DRILL DRLG P Drill ahead, 1.42 BPM @ 3800 PSI, BHP 4092, 1.43 WOB,65 ROP Pump 10 X 10 sweep to time out @ TD. 13:00 14:45 1.75 9,890 8,500 PROD5 DRILL WPRT P Reach TD @ 9890'.Wiper up W/10 X 10 sweep,wipe up to the TT.Jog the 4.5"liner. 14:45 15:00 0.25 8,500 8,600 PROD5 DRILL DLOG P Log for a+2'correction. 15:00 15:45 0.75 8,600 9,891 PROD5 DRILL WPRT P Continue RIH,tag BTM @ 9891.0 15:45 18:00 2.25 9,891 72 PROD5 DRILL TRIP P Liner beads at the bit,start laying in 30 bbls in the open hole,trip out to surface while jetting @ max rate. 18:00 20:00 2.00 72 0 PROD5 DRILL PULD P Conduct PJSM. Lay down drilling BHA. 20:00 23:30 3.50 0 1,491 COMPZ CASING PUTB P PJSM for liner run. Pick-up 43 jts. Mu Coil trak BHA,strip on. 23:30 00:00 0.50 1,491 6,290 COMPZ CASING RUNL P RIH Page 17 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/14/2012 24 hr Summary Release AL2-01 liner 9891',TOL 8443'.Swap well to SW and freeze protect. Undeploy BHA, Set BPV. Prepare to swap reels 00:00 02:00 2.00 6,290 9,891 COMPZ CASING RUNL P Continue to run in hole with liner. Correction at the flag of minus 11' 02:00 03:00 1.00 9,891 7,900 COMPZ CASING RUNL P No correction at the TD flag,Tag BTMat 9891', PUW 38k Set back down and pump 1.27bpm release from liner, PUW 30k 03:00 03:12 0.20 7,900 7,932 DEMOB WELLPF DISP P Displace well over to SW. POOH to tie in to the HRZ correction of plus 3' 03:12 04:12 1.00 7,932 2,500 DEMOB WELLPF RUNL P POOH 04:12 06:12 2.00 2,500 0 DEMOB WELLPF FRZP P Freeze Protect well 06:12 08:12 2.00 0 0 DEMOB WELLPF RUNL P OOH, PJSM-Pressure undeploy Liner running BHA 08:12 09:42 1.50 0 0 DEMOB WELLPF NUND P Flush surface lines with inhibitor 09:42 11:12 1.50 0 0 DEMOB WHDBO NUND P PJSM-Set BPV 11:12 14:12 3.00 0 0 DEMOB WHDBO CTOP P PJSM-RU and Pump N2 to blowdown Coiled Tubing Reel. 14:12 17:42 3.50 0 0 DEMOB WHDBO CTOP P Continue to flush surface lines 17:42 18:12 0.50 0 0 DEMOB WHDBO CTOP P Crew change, PJSM 18:12 00:00 5.80 0 0 DEMOB WHDBO CTOP P Unstab CT,secure to reel. RD old reel. Swap out reels 08/15/2012 ND BOP.Wait on Trucks. 00:00 03:00 3.00 0 DEMOB WHDBO NUND P ND BOP's 03:00 06:00 3.00 DEMOB WHDBO DMOB P Wait on trucks Page 18 of 18 IP W MI zikarle gi a ,F, � L la' o . 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CO 0 CO O Z Z Z = - 0 C V COD �' ,L; CD m CCD 0 Cc[j V CN] a0 O La O V N 0 m (00 O W M M M H 2 W O..- co M co o N N N N N N N N N O 0 0 O R N r CO CD CD CD C0 6 CO CO CO CO CD CO 6 CO CD CD C0 CD CD CO C0 CO /�( W LOU) UO LO CO O o O CO CCI N ICI 111 N CN CO 0 10 CO 0 00 a t W o d N 0 O aL O N O O COCO 2222 '.`;' 81?- `42 p O N N CV V Z2. O p) V CP V r O N M V o r• 0 M r• C) O) a 0 O) COM co 6 >. w CL c CO' W 'a; rn rn m COO m m n r n CWO CCD m m m UO COO Ca z; v 0) > 0 2 t x m n r= r= r; r- r_ r_ r_ r_ r_ r= r= r= r= r= ti r= r= r- N- ti d CO E 0 O o O O o 0 o 000 0 0 o 0 O 00000 0 0 1:0 co y ._ z E co 6m CD CD co m m co m m co m co m CD 6 co co of LL) E 'ZS' c 2 I 1 T c O m O Q L c O C) i 6r U N co N- M V O o M W ton V O N m n M N A 00 GI ._— w N 0 0 0 003 CO CO N- 0 m M O N- O C)O W 0 N V .Y N U m AL C) L N 5 m O N CV) V h m CC Si m O W O O. O O Or N gi ro 2 N v ❑ r cci 3 m CO rn CO W 0 W CO 0) CO o 0 O. 0 CO O ❑ O 7 REzcno W - . C C C C C C C C C N M CV CV ell N Ell CV Cil N N c? 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N O OWOCC WO CO n N NN O N N N ^ NO O O NN r, Y dd a ► N N N N N N N N N N N N N N N N N ( L a c,)▪ Q • d Y Y — 00 -Co R R C Z Z r r r CO LCILOCOCD O CDn M o V r O m t0 M O W CD c0 NCnr: MCO NC) rNW COO01r, W N rWCDr• rr CV N N (J O O CD CD rA CD CD U Y Y co co co C 2... W W W W W W W W W W W W W W W W W m cow W W O O. V N W N N V COCO W M O N 0 R CD 0 M CD 0 M 0 CO 0 CO O V CO r` CO m O W CO CO W CO CO CC) 0 W CO O CO O CO CO O .. n h O O D fD O O O O O O O O O O O O C O NM to C C ❑ COW N o CO 10 CO CD W N CO m .-V N N M CO CO V 0 V W CO W W 0 CO CO rr` I.- CO CO CD W N O C, l) E O O 0 O O O O O O O O O O O O O 0 O 0 O O O a ° c v o y rn U E • r - N . O y m v a` w 3 o U) '.." ___.... ..e.�.... ._.__.__a_._.w....._.......__..-...._ ...�.......,, CO STATE OF ALASKA I 0 ` AL A OIL AND GAS CONSERVATION COM, 31ON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well E Plug Ibrforations rl Stimulate r Other Convert Oil Prod. to WIND Alter Casing r Pull Tubing r Fprforate New Pool r Waiver r Time Extension r Change Approved Program r Operat.Shutdown r Perforate r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development [ Exploratory r ` 212-095-0 3.Address: 6.API Number: Stratigraphic r Service r P. 0. Box 100360,Anchorage,Alaska 99510 - 50-029-21580-01 -00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL-25521,25512 " f 3N-11A 9.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10. Present Well Condition Summary: . Total Depth measured 10923 feet Plugs(measured) None true vertical 6387 feet Junk(measured) 8,790 and Effective Depth measured 8682 feet Packer(measured) 0 true vertical 6560 feet (true vertucal) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115' SURFACE 4518 9.625 4558 3631.7 PRODUCTION 8746 7 8777 6465 LINER A 170 2.7 10600 6387 4Ik Perforation depth: Measured depth: Slotted Liner from 10442 to 10,600v e'vo True Vertical Depth: 6390 �C 0 3 20 D '1 O� 1? Tubing(size,grade,MD,and TVD) 3.5, L-80, 8173 MD,6329 TVD Ce Packers&SSSV(type,MD,and ND) 11.Stimulation or cement squeeze summary: Intervals treated(measured): 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 55 33 1447 300 114 Subsequent to operation 0 0 5022 420 2193 13.Attachments 14.Well Class after work: - Copies of Logs and Surveys run Exploratory r Development r Service [ Stratigraphic r 15.Well Status after work: Oil r; Gas r WDSPL r Daily Report of Well Operations X GSTOR n WINDJ WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 312-371 Contact Darrell Humphrey/Bob Christensen Email n1139(c,Dconocophillips.net Printed Name Darrell Humphrey/Bob Christensen Title Production Engineering Specialist Signature D , 1 Phone:659-7535 Date /,Z9 y Z RRDMS ::::� ,3 3 mg cdriAl ,_i,r Form 10-404 Revised 10/2010 I 13 01-3 �'Submit Original Only 4, 1 3N-11A DESCRIPTION OF WORK COMPLETED l SUMMARY Date Event Summary 11/14/12 Commenced Seawater Injection 11/22/12 STATE WITNESSED MITIA(PASSED @ 2900 PSI) KUP 3N-11A j ' ConocoP iUips /° Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Well Status Inc;(°) MD(ftKB) Act Btm(ftKB) CorlocARvllips 500292158001 KUPARUK RIVER UNIT PROD 99.52 9,880.48 10,923.0 '"" Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date •••Well Con89:DEVIATED-3N-11 A,10/1100123.48.10 PM SSSV:TRDP Last WO: 1/12/2012 39.49 4/13/1986 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: 8,533.0 2/12/2012 Rev Reason:GLV C/O ninam 10/11/2012 HANGER,24 ; Casing Strings MEM Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description String 0... String ID...c- Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.765 35.0 4,558.0 3,631.7 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(I...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6276 30.4 8,776.6 6,465.1 26.00 J-55 ETC Casing Description String 0... String ID...Top(ftKB) Set Depth(I...Set Depth(TVD)...String Wt...String...String Top Thrd - SCAB LINER 4 1/2 3.476 8,130.2 8,625.2 6,464.2 11.60 L-80 BTC • Liner Details CONDUCTOR,_ . Top Depth 38-115 (TVD) Top Incl Nomi... 1.11 Top(ftKB) (ftKB) C) Item Description Comment ID(in) 8,130.2 6,168.5 45.36 PACKER BAKER C2 ZXP LINER TOP PACKER 4.400 • SAFETY VLV, 1,796 8,150.5 6,182.7 45.30 HANGER BAKER HYDRAULIC FLEXLOCK HANGER 4.320 8,160.3 6,189.6 45.28 SBR BAKER 80-40 SEAL BORE EXTENSION 4.000 Casing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(TVD)...String Wt...String...String Top Thrd LINER A 23/8 1.992 10,430.1 10,600.0 6,386.9 4.70 L-80 STL GAS LIFT, Liner Details 2,908 11111 Top Depth (TVD) Top Incl Noml... Top(ftKB) (ftKB) 1°) Item Description Comment ID(In) 10,430.1 6,390.1 91.37 BILLET OH ANCHORED BILLET 1.000 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE, TUBING WO 3 1/2 2.992 23.6 8,173.4 6,198.8 9.30 L-80 EUE8rdABMOD 35-4,558 Completion Details Top Depth GAS LIFT, I (ND) Top Incl Nomi... 5,099 1 Top(KKB) (ftKB) (°) Item Description Comment ID(in) 23.6 23.6 -0.06 HANGER TUBING HANGER&PUP a500 1,796.3 1,730.8 34.83 SAFETY VLV CAMCO TRMAXX-CMT-5-SR SAFETY VALVE 2.812 • 8,081.1 6,133.7 45.19 NIPPLE CAMCO X NIPPLE 2.812 GAS LIFT, 8,128.1 6,167.0 45.36 LOCATOR LOCATOR SEALS T OUT 2.970 6,571 8,153.0 6,184.4 45.30 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY FOR SBE HALF MULE SHOE 2.990 ® 8,172.9 6,198.4 45.24 WLEG 2.990 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT_ I Top Depth • 7,524 1 (ND) Top Incl Top(ftKB) MB) C) Description Comment Run Date ID(in) g. 8,790 6,464.7 90.79 FISH 1"BK Latch Ring Lost in Hole 1/12/2012 • IIII 10,430 6,390.2 91.37 WHIPSTOCK ANCHORED BILLET AL3 LATERAL 8/1/2012 1.000 GAS LIFT, • 8,052 Perforations&Slots Shot NIPPLE,8,081 -- I Top(TVD) Btm(TVD) Dene Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (sh..._ Type Comment • Ell 10,442 10,600 6,389.9 6,386.9 8/1/2012 32.0 SLOTS Notes:General&Safety • End Date Annotation LOCATOR,8,128_ -- 2/24/2012 NOTE:APPLY 5500 PSI TO CONTROL LINE TO KEEP TRMAXX FULLY OPEN • 8/21/2012 NOTE:WELL SIDTRACKED,ADDED LATERALS AL1,AL2,AL2-01,AL3(See Multi-let Drawing) • • SEAL ASSY, 8,153 lil WLEG,8.173 APERF, 8,420A.135 WHIPSTOCK, 8,470 Mandrel Details SCAB LINER. Top Depth Top Pon 8,130.8.825 4. (ND) Incl OD Valve Latch Sian TRO Run Stn Top(KKB) (RIO) C) Make Model lin) Sery Type Type (in) (psi) Run Date Com... 1 2,907.9 2,491.0 46.34 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 2 5,099.0 4,001.6 46.28 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/8/2012 PRODUCTION, 3 6,570.7 5,055.9 42.98 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 30-8,7774 7,523.7 5,7412 45.23 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 FISH,8,790 5 8,052.1 6,113.3 45.23 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 2/10/2012 WHIPSTOCK, 10,430 SLOTS, 10,442-10,800 • LINER A, 10,430-10,800" I TD(3N-11A). J 10,923 w \\O�� s7 THE STATE Alaska Oil and Gas F +y��"' °fALAS� Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Off, e. Anchorage, Alaska 99501-3572 (LAS Main: 907.279.1433 Fax: 907.276.7542 Darrell Humphrey _ 0 Y Production Engineering Specialist I �-- ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N-11A Sundry Number: 312-371 Dear Mr. Humphrey: 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, /°-4eA4`1,L_ Cathy P Foerster Chair DATED this 9 )1k, y of October, 2012. Encl. RECEIVED OCT 022012 . w y Robert Christensen/Darrell Humphrey AOGCC Production Engineering Specialists. Greater Kuparuk Unit,NSK-69 PO Box 196105 ConocoPh i I i ps Anchorage,AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 September 28, 2012 Dan Seamount AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit wells 3N-11A, 3N-11AL1, 3N-11A2, 3N-11AL2-01 and 3N-11AL3 from Oil Production to Water Injection service. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 3N-11A, 3N-11AL1, 3N-11A2, 3N-11AL2-01 and 3N-11AL3. (PTD 212-095, 212-096, 212-097, 212-098, 212-110). If you have any questions regarding this matter,please contact myself or Bob Christensen at 659-7535. Sincerely, Darrell Humphrey Attachments Sundry application Well schematic ' . STATE OF ALASKA ' ANMP , A, .(A OIL D GAS CONSERVATION COM �� , ' APPLICATION FOR SUNDRY APPROVALS ��y �go, �o 20 AAC 25.280 1.Type of Request: Abandon r Flug for Redrill [ Perforate New Pool r Repair well r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown [ Re-enter Susp.Well r Stimulate rAlter casing C Other:Convert Oil Prod.to WINJ Fi, . 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r' . Exploratory r 212-095-0 - 3.Address: Stratigraphic r Service �" 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-21580-01 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: R E C E I D where ownership or landownership changes: Spacing Exception Required? Yes r No r 3N-11A . 1)O C T� 121' 0V1?--- 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL-25521,25512 ' Kuparuk River Field/Kuparuk River Oil Pool, 11. PRESENT WELL CONDITION SUMMARY AOGCC Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured):-(Fish) 10923 - 6387 • 8682' 6560' 8,790 and Casing Length Size MD ND Burst Collapse CONDUCTOR 79 16 115' 115' SURFACE 4518 9 5/8 4558' 3632' PRODUCTION 8746 7 8777' 6465' LINER A 170 2 3/8 10600' 6387' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slotted Liner from 10442 to 10,600 6390 3 1/2 L-80 8173 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) BAKER C2 ZXP LINER TOP PACKER 8,130.2 MD - 6,168.5 ND CAMCO TRMAXX-CMT-5-SR SAFETY VALVE 1,796.3 MD - 1,730.8 ND 12.Attachments: Description Surrmary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program 17 BOP Sketch r Exploratory r Development r Service ' 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/1/2012 Oil r Gas [ WDSPL r Suspended r 16.Verbal Approval: Date: /64-/t- WINJ GINJ r WAG r Abandoned [r' Commission Representative: 6'5G GSTOR [ SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Darrell Humphrey/Bob Christensen Printed Name Darrell Humphrey/Bob Christensen Title: Production Engineering Specialist Signature 1✓ Phone:659-7535 Date ?.2.4S- /7____ Co mission Use Only Sundry Number:. J2_.31 f Conditions of approval: Notify Commission so that a representative may witness JJJJJJ Plug Integrity r BOP Test r Mechanical Integrity Test Location Clearance r Other: Subsequent Form Required: ! a yo APPROVED BY Approved by: (4:_--147 ? --).,A4,..7(./.., COMMISSIONER THE COMMISSION Date:/ - j —/ ?-- i/ Form 10-403 Re ised 1/2010 S/t� ' ` ` r ..DMS OCT 1 !�< Submit in Duplicate >/ , / 1 `dry "' 1 (�.4//z 'iU 3N-11A DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 3N-11A and its associated laterals from Oil Production service to Water Injection service. The CTD Permit to Drill (which added multi-laterals AL1, AL2, AL2-01, AL3)was completed with the well as an injection well, but the completion report was filed as an oil producer to allow for extended pre-production. The pre-production period following CTD operations has now been completed and the well is being prepared for initial water injection. • 4 /1-01( e-47,44, prD /44-4- , `, KUP 3N-11A 4. ConocoPhillips ' Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) � n,w onPp: 500292158001 KUPARUK RIVER UNIT PROD 9952 9880.48 10,923.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••• Well Confie'.-3N-71A,9I1tG0722'S0:21 PM -SSSV:TRDP Last WO: 1/12/2012 39.49 4/13/1986 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: 8,533.0 2/12/2012 Rev Reason:GLV C/O ninam 9/11/2012 HANGER,24 f II Casing Strings l Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(I...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 95/8 8.765 35.0 4,558.0 3,631.7 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(I...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 _ 6.276 30.4 8,776.6 6,465.1 26.00 J-55 BTC Casing Description String 0... -String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd • SCAB LINER 41/2 3.476 8,130.2 8,625.2 6,464.2 11.60 L-80 BTC Liner Details • CONDUCTOR, Top Depth 08-115 (TVD) Top Incl Noed... Top(ftKB) (RKB) (°) it..Description Comment ID(in) 8,130.2 6,168.5 45.36-PACKER BAKER C2 ZXP LINER TOP PACKER 4.400 SAFETY VLV. 1.798 1 G I 8,150.5 6,182.7 45.30 HANGER BAKER HYDRAULIC FLEXLOCK HANGER 4.320 8,160.3 6,189.6 45.28-SBR BAKER 80-40 SEAL BORE EXTENSION 4.000 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd LINER A 23/8 1.992 10,430.1 10,600.0 6,386.9 4.70 L-80 STL GAS LIF3.T, § 41. Liner Details Top Depth (ND) Top Inel Nomi... Top(ftKB) (RKB) (°I Item Description Comment ID(in) 10,430.1 6,390.1 91.37.BILLET OH ANCHORED BILLET 1.000 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd SARFACE.____._..-� TUBING WO 31/2 2.992 23.6 8,173.4 6,198.8 9.30 L-80 EUE8rdABMOD 35-4,558 Completion Details Mill Top Depth GAS LIFT, (TVD) Top Incl Nome... 5.099-- TIMPop(ftKB) (RKB) (•) Rem Description Comment ID(in) - 23.6 23.6 -0.06 HANGER TUBING HANGER&PUP 3.500 1,796.3 1,730.8 34.83 SAFETY VLV CAMCO TRMAXX-CMT-5-SR SAFETY VALVE 2.812 -__ 8,081.1 6,133.7 45.19 NIPPLE CAMCO XNIPPLE 2.812 GAS UFT 8,128.1 6,167.0 45.36 LOCATOR LOCATOR SEALS 7 OUT 2.970 6,571 8,153.0 6,184.4 45.30 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY FOR SBE HALF MULE SHOE 2.990 - 8,172.9 6,198.4 45.24 WLEG 2.990 MI Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) • GAS LIFT,_ . Top Depth 1 7,526 - IND) Top Incl Top(R(B) (RKB) (°) Description Comment Run Date ID(in) 1.11 8,790 6,464.7 90.79 FISH 1"BK Latch Ring Lost in Hole 1/12/2012 MI 10,430 6,390.2 91.37 WHIPSTOCK ANCHORED BILLET AL3 LATERAL 8/1/2012 1.000 GAS= Perforations&Slots Shot NIPPLE,8,087lal Top(TVD) Btm(TVD) Dene Top(ftKB) Btm(ftKB) (ftKB) (RKB) Zone Date leh^• Type _ Comment 10,442 10,600 6,389.9 6,386.9 8/1/2012 32.0 SLOTS IIIIIII Notes:General&Safety End Date Annotation LOCATOR, 2/24/2012 NOTE:APPLY 5500 PSI TO CONTROL LINE TO KEEP TRMAXX FULLY OPEN • 8,128 8/21/2012 NOTE:WELL SIDTRACKED,ADDED LATERALS AL1,AL2,AL2-01,AL3(See Muli-lat Drawing) SEAL ASSY, i 8.153 1 111111 WLEG.8,173 P APERF. 13420-8435 E WHIPSTOCK. 8.470 Mandrel Details SCAB LINER, Top Depth Top Port 0.130E,825 (ND) Ind OD Valve Latch SM. TRO Run Stn Top(ftKB) (RKB) (°) Make Model (in) Sery Type Type (in) (ps1) Run Date Com... 1 2,907.9 2,491.0 46.34 CAMCO MMG -1 1/2 GAS LIFT DMY RK 0.000 0.0 1/12/2012 2 5,099.0 4,001.6 46.28 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 8/23/2012 PRODUCTION. 3 6,570.7 5,055.9 42.98 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 3043777 4 7,523.7 5,741.2 45.23 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 FISK6,790 $ 5 8,052.1 6,113.3 45.23 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 2/10/2012 WHIPSTOCK. 10,430 SLOTS, 10,442-10,800 LINER A, 10430-10,800 TD(3N-11A). 10,023 Page 1of1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, October 08, 2012 8:34 AM To: 'NSK Prod Engr Specialist' Cc: CPF3 Prod Engrs; McMains, Stephen E (DOA) Subject: RE: Verbal approval to convert 3N-11A to water injection You have verbal approval to convert to water injection. The AOR (Area of Review) was completed and reviewed in the PTD applications for these wells so conversion is approved as soon as you are able. Please submit a 10-404 with the date of conversion to WINJ indicated on the form. A witnessed MIT-IA is required as normal as soon as the well is stable... Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: NSK Prod Engr Specialist [mailto:n1139@conocophillips.com] Sent: Friday, October 05, 2012 1:33 PM To: Schwartz, Guy L (DOA) Cc: CPF3 Prod Engrs Subject: Verbal approval to convert 3N-11A to water injection Guy-as per our phone conversation ConocoPhillips would like to request verbal approval to convert 3N- 11A, 3N-11AL1, 3N-11AL2, 3N-11AL2-01, 3N-11AL3 (P10212-095, 212-096, 212-097, 212-098, 212- 110), to water injection service. The 10-403 Sundry requesting this service change has been filed with your office. Your assistance in this matter is appreciated. Thanks, Darrell Humphrey / Bob Christensen ConocoPhillips Alaska, Inc Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager(907) 659-7000 (924) 10/8/2012 z5 LAS oc BAKER PRINT DISTRIBUTION LIST HUGHES COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes WELL NAME 3N-11A RUN NUMBER FIELD Kuparuk BH SALESMAN Woods,Jim (mandato (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) ,ndat STATE Alaska _ PAGE OF (mandatory) LOG DATE: July 30,2012 TODAYS DATE: 8/27/2012 ,mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. ;mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY D FIELD FINAL (digital il/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Ur NKIN I s #OF COPIES #OF COPIES y v v v v V v-` 1 ConocoPhillips Alaska,Inc. 1 NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC 1 1 I Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3 BP 1 1 Petrotechnical Data Center,M1133 i zz David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP I 1 1 I I Glenn Fredrick 3800 Center Point Drive,Suite 100 .- Anchorage,Alaska 99503 •1 5 Brandon Tucker,NRT 1 I �" State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 Letter of Transmittal rI BAKER Date: August 17, 2012 HUGHES To: From: Christine Mahnken Carl Ulrich/Sachin Gandra AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage,Alaska 99515 Please find enclosed the directional survey data for the following well(s): 3N-11A a 0., 0 N-11ALf oZ , all 3N-11AL2 RECEIVES 3N-11AL2-01 AUG 2 0 3N-11AL3 a' 2012 aiD, - ita (5) Total prints AOGCC Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files c., tp-Okfat 12 - 0 6/-5 - Note: Please feel free to send us an email in place of retu mai ) Sachin Gandra, Baker Hughes, Project Engineer Sachin.Gandra@BakerHughes.com Carl.Ulrich, Baker Hughes, Survey Manager Carl.Ulrich@BakerHughes.com s r 1 " SEAN PARNELL, GOVERNOR � .r ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSIONT ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 L. Gantt CTD Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N-11A ConocoPhillips Alaska, Inc. Permit No: 212-095 Surface Location: 1561' FSL, 155' FEL, SEC. 29, T13N, R9E, UM Bottomhole Location: 382' FNL, 2444' FEL, SEC. 29, T13N, R9E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, aWi Cathy 1�Foerster Chair �L- DATED this/V day of July, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 1 8 2012 PERMIT TO DRILL AOGCC 20 AAC 25.005 1 a.Type of Work- - 1 b.Proposed Well Class: Development-Oil ❑ Service-Winj ❑✓ - Single Zone ❑✓ lc.Specify if well is proposed for: Drill ❑ Re-drill ❑✓ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name. 5 Bond. U Blanket LJ Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • 3N-11A • 3 Address. 6 Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 11280' • TVD: 6378' Kuparuk River Field 4a Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1561'FSL, 155'FEL,Sec.29,T13N,R9E,UM ' ADL 25521,25512' Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit 13.Approximate Spud Date 1264'FSL, 1556'FEL,Sec.20,T13N,RO9E,UM 2557,2553 7/22/2012 Total Depth: 9 Acres in Property: 14 Distance to 382'FNL,2444'FEL,Sec.29,T13N,RO9E,UM 2560 Nearest Property: 11500 . 4b Location of Well(State Base Plane Coordinates-NAD 27) 10.KB Elevation above MSL: • 68 feet 15 Distance to Nearest Well Open Surface:x- 518246 ' y- 6013799 - Zone- 4 GL Elevation above MSL - 33 8 feet to Same Pool 3N-09,1400 . 16.Deviated wells Kickoff depth 8472' ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle: 94" deg Downhole:3766 psig •• Surface: 3125 psig , 18 Casing Program. / Specifications Top - Setting Depth -Bottom Cement Quantity,c f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 1900' 9380' 6393' 11280' 6378' slotted liner / 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft) Plugs(measured) Effective Depth MD(ft) Effective Depth ND(ft). Junk(measured) 8790' 6637' 8682' 6560' Casing Length Size Cement Volume MD TVD Conductor/Structural 16" 250 sx CSII 115' 115' Surface 9.625" 1300 sx ASIII,350 sx Class G 4558' 3632' Intermediate 7" 300 sx Class G,175 sx AS I 8777' 6627' Production Liner 4.5" 15 bbls Class G w/GASBLOK 8625' 6519' Perforation Depth MD(ft): Perforation Depth ND(ft): perfs cemented off at 8420'-8589' 6374'-6493' 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program O Time v Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 MC 25`050 ❑✓ (requirements 21.Verbal Approval Commission Representative ,,��, Date 41\j �IF7I�Z 22 I hereby certify that the foregoing is true and correct. Contact Mike Winfree @ 265-6820 Printed Name L. Gantt Title CTD Supervisor Signature t il� &mji-- Phon 263-4021 Date ,%t7//z Commission UseOnly Permit to Drill API Number /sePermit Approv I See cover letter Number 21 2 '`} 50- �'),�--2/ d_G/ti Date 1�I G 11- for other requirements Conditions of approval• If box is checked,ckwell may not be u ed to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales E .x--- 35— Si. , )/9 r Samples req'd: Yes ❑ No LJ Mud log req'd: Yes ❑ • No Er Other: ( / H2S measures:nYes Q No ❑ Directional svy req'd: Yes A No ❑ �(7/.-- 'en_ o i et A c-c- 'V LI/ .4,D z l��i r r el'4-1.----f2' f�1�fXl. l /oic.4�` �O1/-tevn► rtiIer pyet- ZOA�4c-- Z5.`-l1ILL) APP OVED BY THE COMMISSION DATE: r\-!-ACII-Ly /0 COMMISSIONE Form 10-401 (Revised 7/2009) Thispermit is valid for 2b o th fro 4the datelo roval(20 AAC 25.005 Submit 74 in Duplicate C �P (g)) P �C6 ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 JUL 1 8 2012 AOGCC July 17, 2012 Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Permit to Drill (PTD) applications to drill and complete 3N-11A, 3N- 11AL1, 3N-11AL2, and 3N-11AL2-01 from Kuparuk well 3N-11 (PTD# 186-077). Coiled tubing drilling (CTD) - operations are scheduled to begin July 22, 2012 using the Nabors CDR2-AC rig. The objective of the CTD project is to improve Kuparuk A-Sand sweep efficiency and oil recovery within the target pattern by drilling lateral sidetracks. A workover has recently been completed which installed a 4%2" scab liner inside the 7" casing adjacent to the Kuparuk sands. The cementing of that scab liner also effectively ✓ squeezed the existing A and C-sand perfs as per sundry 311-372. Once CTD operations are completed then a 10-407 will be submitted to classify the original et=21 completion as 'Abandoned'. 3ij 7.14•lL Attached to this application are the following documents that explain the proposed job operations. A BOP schematic for slimhole CTD operations from Nabors CDR2 is already on file with the Commission. — Drilling program summary — Permit to Drill application forms for 3N-11A, 3N-11AL1, 3N-11AL2, and 3N-11AL201 — Directional plans for 3N-11A, 3N-11AL1, 3N-11AL2, and 3N-11AL201 — Current wellbore schematic following the rig workover — Proposed wellbore schematic If you have any questions or require additional information please contact me at my office 907-265-6820. Sincer ly, V � Mike A. ree ConocoPhillips Alaska Coiled Tubing Drilling Engineer Kuparuk CTD Laterals NABORS ALASKA 3N-11A, 3N-11AL1, 3N-11AL2, 3N-11AL2-01 ConocoPhAps Application for Permit to Drill Document RC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(1)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Pressure Deployment of BHA 6 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 16. Quarter Mile Injection Review (for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Construction of Injection Wells 7 (Requirements of 20 AAC 25.412) 7 Attachment 1: Directional Plans for 3N-11A,3N-11AL1,3N-11AL2, &3N-11AL2-01 7 Attachment 1: Quarter Mile Pool Scan 7 Attachment 2: Current Well Schematic for 3N-11 7 Attachment 3: Proposed Well Schematic for 3N-11 CTD Laterals 7 ORIG ! N!AJ 17,2012 Page 1 of 7 July PTD Application for KRU 3N-11A, AL1, AL2, & AL2-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) There are four proposed laterals described in this document: KRU 3N-11A, 3N-11AL1, 3N-11AL2, and 3N-11AL2-01. 3N-11A will be a sidetrack from the 3N-11 motherbore, and the remainder will be horizontal laterals branching off the 3N-11A. All will be classified as "Service— Water Injection"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Each of these laterals will target the A3, A2, and Al sands in the Kuparuk reservoir. See the attached 10-401 forms for surface and subsurface coordinates of each of the 3N-11 laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and 3600 psi. Using a maximum potential formation pressure of 3766 psi, the maximum potential surface pressure is 3125 psi assuming a gas gradient of 0.1 psi/ft. See the"Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) .ny'The most recent static BHP measurement in well 3N-11 was taken in December 2011 recording a pressure of (0.5 11 3441 psi at 8504' MD. 6433' TVD for=a-10.3 ppg gradient, During the workover of January 2012 however the fluid weight had to be increased t911.3 ppg (equivalent of 3780 psi SBHP)to maintain pressure overbalance. The proposed 3N-11 CTD lateralg will approach existing production wells so our expectation is that we will not encounter significantly increased formation pressure. The most likely sources of elevated formation pressure, if we encounter such, would be from injection wells 3N-13 to the southeast and 3N-04 to the southwest. These wells have recent formation pressures of 3755 psi (11.2 ppg EMW, Feb-12) and 3715 psi (11.3 ppg EMW, Apr- 12) respectively. Maximum potential formation pressure is based on the April 2012 pressure from 3N-04 to-the southwest, which had measured formation pressure of 3715 psi at 7630' MD, 6323' TVD for a gradient of 11.3 ppg. In 3N-11A this equates to a maximum potential formation pressure of 3766 psi (8470' MD, 6409' TVD) and a maximum potential surface pressure of 3125 psi assuming a gas gradient to surface, 4c, Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled. 3N pad is a water only injection pad. It is unlikely that an influx while • drilling will produce a significant amount of gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected downhole risk in the 3N-11 laterals is hole stability due to interbedded shales and silts in the A-sand. We will mitigate hole instability by maintaining a minimum ECD target of 12.0 ppg EMW at the window while drilling the CTD laterals, as well as using mud additives that minimize chemical instability. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) Each of the 3N-11 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so formation integrity tests are not required. ORGNPage2of7 ` July 17, 2012 PTD Application for KRU 3N-11A, AL1, AL2, & AL2-01 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Liner Liner Liner Liner Lateral Name Top MD Btm Top Btm Liner Details MD TVD TVD 3N-IIA 9380' 11,280' 6393' 6378' 2'/8', 4.7#, L-80, ST-L slotted liner; .i aluminum billet on top 3N-11AL1 8800' 11,280' 6392' 6391' 23/", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3N-11AL2 8945' 9,445' 6440' 6351' 2'/", 4.7#, L 80, ST-L slotted liner; aluminum billet on top 3N-11AL2-01 8460' 11,330' 6333' 6353' 23/", 4.7#, L-80, ST-L slotted liner up inside 4'/" liner Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62 H-40 Welded 0' 115' 0' 115' Surface 9%" 36 J-55 BTC 0' 4558' 0' 3632' 3520 2020 Casing 7" 26 J-55 BTC 0' 8777' 0' 6627' 4980 4320 Scab liner 4'/2" 12.6 L-80 IBT& BTC 8130' 8625' 6168' 6519' 8430 7500 Tubing 3W 9.3 L-80 EUE 8rd-Mod 0' 8173' 0' 6199' 10,160 10,530 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036 for thru-tubing drilling operations so no diverter system is required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System - Window milling operations: Chloride-based Biozan brine or used drilling mud (-9.5 ppg) - Drilling operations: Chloride-based Flo-Pro Flo Vis mud (9.5 ppg). This mud weight alone will not hydrostatically overbalance formation pressure in the 3N-11 motherbore, but overbalanced conditions will be maintained using MPD practices described below. - Completion operations: 3N-11 contains a subsurface safety valve (SSSV) at 1796' MD. The SSSV will be used to pressure deploy the liner in lieu of loading the well with completion fluid. In the event that the SSSV becomes inoperable, the well will be loaded with 12.0 ppg sodium bromide completion fluid in order to maintain pressure over-balance while picking up liner. - Emergency Kill Weight fluid: Two well bore volumes (-200 bbl) of 13.1 ppg emergency kill weight fluid will be within a short drive of the rig during drilling operations. Page 3 of 7 July 17, 2012 PTD Application for KRU 3N-11A, AL1, AL2, & AL2-01 Managed Pressure Drilling Practice Managed pressure drilling (MPD)techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time�r viding pressure over- balance to the formation. In the 3N-11 laterals we will target a constant BHP of/12.0 ppg EMW at the window. If increased formation pressure is encountered, mud weight or choke pressure(will be increased to maintain ✓ overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability but not necessarily for well control. Pressure at the 3N-11A Window(8470' MD, 6409'TVD, 6341' SSTVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (11.3 ppg) 3766 psi 3766 psi Mud Hydrostatic(9.5 ppg) 3166 psi 3166 psi Annular friction (i.e. ECD, 0.095 psi/ft) 808 psi 0 psi Mud + ECD Combined 3974 psi 3166 psi (no choke pressure) (overbalanced (underbalanced —208 psi) —600 psi) Target BHP at Window(12.0 ppg) 3999 psi 3999 psi Choke Pressure Required to Maintain 25 psi 840 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 3N-11 is an NC-sand injector that was recently worked over to install a 4W scab liner over damaged 7" casing near the existing Kuparuk perfs. The existing NC-sand perfs were squeezed with cement as part of that workover, and our plans are to not re-perf the C-sand. Four proposed A-sand CTD laterals will increase reservoir exposure and improve waterflood sweep. A separate sundry request (311-372)was approved for the abandonment of the original 3N-11 completion in preparation for these CTD sidetracks. A mechanical whipstock will be placed in the 4W scab liner at the planned kickoff point. The 3N-11A sidetrack will exit the 4W liner and 7" casing at 8472' MD and will target the A1/A2 sands south of the existing well with a 2780' lateral. The hole will be completed with a 2%"slotted liner to the TD of 11,280' MD with an aluminum billet at 9380' MD. ORIGINAL Page 4 of 7 July 17, 2012 PTD Application for KRU 3N-11A, AL1, AL2, & AL2-01 The 3N-11AL1 lateral will kick off from the aluminum billet at 9380' MD and will target the Al sand south of the existing well with an 1900' lateral. The hole will be completed with a 2%"slotted liner to the TD of 11,280' MD with an aluminum billet at 8800' MD. The 3N-11AL2 lateral will kick off from the aluminum billet at 8800' MD and will target the A3 sand south of the existing well with a 645' lateral. The hole will be completed with a 2%" slotted liner to the TD of 9445' MD with an aluminum billet at 8945' MD. The 3N-11AL1 lateral will kick off from the aluminum billet at 8945' MD and will target the A2/A3 sands south of the existing well with a 2385' lateral. The hole will be completed with a 2%"slotted liner to the TD of 11,330' MD with the final liner top located inside the 4W liner at 8460' MD. Pre-CTD Work 1. RU e-line. 2. Run whipstock dummy. 3. Prep site for Nabors CDR2-AC, including setting BPV Rig Work Quik 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 11 3� i1 2. 3N-11A Sidetrack (Al &A2 sand, south) a. Set whipstock at 8470' MD with high-side orientation. b. Mill 2.80"window through 4W liner and Tcasing at 8470' MD c. Drill 2.70" x 3" bi-center lateral to TD of 11,280' MD 'IY d. Run 2%"slotted liner with an aluminum billet from TD up to 9380', using the SSSV as a barrier to formation pressure if available0 3. 3N-11AL1 Lateral (Al sand, south) a. Kick off of the aluminum billet at 9380' MD b. Drill 2.70" x 3" bi-center lateral to TD of 11,280' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 8800', using the SSSV as a barrier to formation pressure if available 4. 3N-11AL2 Lateral (A3 sand, south) a. Kick off of the aluminum billet at 8800' MD b. Drill 2.70" x 3" bi-center lateral to TD of 9445' MD c. Run 2%"slotted liner with an aluminum billet from TD up to 8945', using the SSSV as a barrier to formation pressure if available 5. 3N-11AL2-01 Lateral (A2 &A3 sands, south) a. Kick off of the aluminum billet at 8945' MD b. Drill 2.70" x 3" bi-center lateral to TD of 11,330' MD c. Run 23/8" slotted liner from TD up to 8460' MD, inside the 4W liner. Will use the SSSV as a barrier to formation pressure if available while picking up liner. 6. Freeze protect. Set BPV, ND BOPE. 7. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV and install gas lift design. 2. Perform static BHP survey 3. Put on production. a. Note: The 3N-11 laterals will be pre-produced for over 30 days before being converted to water injection service. • Page 5 of 7 July 17, 2012 PTD Application for KRU 3N-11A, AL1, AL2, & AL2.-01 Pressure Deployment of BHA The planned bottomhole assemblies (BHAs)are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment the steps listed above are conducted in reverse. Liner Running — Since 3N-11 is equipped with a S_S.S.V, the CTD laterals will not need to be displaced to an over-balancing fluid prior to running liner unless the SSSV fails. In that case, fluid of sufficient density to over-balance the formation will be used to provide well control. See the"Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" pipe rams provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) — No annular injection on this well. — Class II liquids to KRU 1R Pad Class II disposal well - — Class II drill solids to Grind & Inject at PBU Drill site 4 — Class I wastes will go to Pad 3 for disposal. 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — There are no other affected owners — Please see attached directional plans for each lateral. — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to nearest property line and nearest well in the same pool. Distance Distance to Directional to Unit Nearest Lateral Name Plan Boundary Well Nearest Well 3N-11A 07 11,500' - 1,400' • 3N-09 3N-11AL1 02 12,150' 1,400' 3N-09 3N-11AL2 02 11,750' 1,750' 3N-09 3N-11 AL2-01 02 11,950' 1,350' 3N-09 Page 6 of 7 E t . July 17, 2012 PTD Application for KRU 3N-11A, AL1, AL2, & AL2-01 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) 3N-09 is the only well within the 1/4 mile scan in the pool. The CBL for 3N-09 shows good cement. Nearest Distance to Lateral Name Well in Nearest Comments Pool Well in Pool 3N-11A 3N-09 1,400' Waivered well for IA x OA Communication. MITOA Passed 7/6/2010 3N-11AL1 3N-09 1,400' Waivered well for IA x OA Communication. MITOA Passed 7/6/2010 3N-11AL2 3N-09 1,750' Only the 3N-11 laterals are with the'/.scan for L2. 3N-11AL2-01 3N-09 1,350' Waivered well for IA x OA Communication. MITOA Passed 7/6/2010 17. Construction of Injection Wells (Requirements of 20 AAC 25.412) ConocoPhillips received a variance on the packer placement requirements of 20 AAC 25.412(b)for the 3N-11 rig workover. The variance was approved with the sundry number 311-372. 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Cr) E O N a tr) 0 0 CO co 0 I, O Nb a) O N o co co ' 0 v u) - V © > O co L �1 (n 0, -O co r' N V N wC (Cco E V �\ U 0 N Q V N O _o u) E E O Q Q .;1'- X-') UL U 0) o) � � w Q - D c CD Ci CZ T6 in En m co N O W r C _ p cn of U co 2 r3 v> ao cot N N N N N N N N N 0 N Y W M M M N. M m Ti- m m Op d' N cV N co coo co rr t x O _ V co dr 0 Q Q cn I \ Q QN I2):/: J 7/V II CUL t 1 U .. w -1-r- CD CO O III III III HI O L (0 (c12. o L) OU V N-cn En co m a) 0 O L N `Ccn p Ln Q'co N NLU r 1 -) 0 -o � n.0 - ;4- � 0 r 2 ' It @ O O N C rn(13 , It Z N CO FLr)20 U coo cn co 4 © N o M co m Co < oo - ° 0 -Lb- �� F-- co N 6) © ConocoPhilli s p Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3N Pad 3N-11 3N-11A Plan: 3N-11A_wp07 Standard Planning Report 16 July, 2012 BAKER HUGHES ,r•-' ConocoPhillips or its affiliates Fa' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3N-11 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3N-11 @ 68.00ft(3N-11) Site: Kuparuk 3N Pad North Reference: True Well: 3N-11 Survey Calculation Method: Minimum Curvature Wellbore: 3N-11A - Design: 3N-11A_wp07 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3N Pad Site Position: Northing: 6,013,799.17ft Latitude: 70°26'55.957 N From: Map Easting: 517,946.19ft Longitude: 149°51'12.938 W, Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.14 ° Well 3N-11 Well Position +N/-S 0.00 ft Northing: 6,013,799.32 ft ' Latitude: 70°26'55.951 N +EI-W 0.00 ft Easting: 518,246.03 ft Longitude: 149°51'4.133 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 33.80ft Wellbore 3N-11A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 8/1/2012 16.11 80.00 57,386 Design 3N-11A_wp07 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,400.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) -33.80 0.00 0.00 215.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +EI-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 8,400.00 44.72 345.25 6,291.13 4,961.83 -778.60 0.00 0.00 0.00 0.00 8,472.00 44.79 345.07 6,342.26 5,010.83 -791.58 0.20 0.10 -0.25 -61.15 8,497.00 49.29 345.07 6,359.29 5,028.50 -796.30 18.00 18.00 0.00 0.00 8,622.00 93.04 345.07 6,398.67 5,140.06 -826.04 35.00 35.00 0.00 0.00 8,837.00 89.71 269.86 6,392.62 5,261.49 -984.68 35.00 -1.55 -34.98 268.90 9,470.00 90.22 193.90 6,393.06 4,898.71 -1,446.99 12.00 0.08 -12.00 270.30 9,750.00 90.18 227.50 6,392.04 4,661.39 -1,587.89 12.00 -0.01 12.00 90.00 9,975.00 90.16 200.50 6,391.34 4,476.58 -1,712.55 12.00 -0.01 -12.00 270.00 10,225.00 89.14 230.48 6,392.89 4,275.34 -1,856.03 12.00 -0.41 11.99 92.00 10,545.00 94.28 192.40 6,382.96 4,007.61 -2,019.88 12.00 1.61 -11.90 278.00 10,770.00 91.10 219.24 6,372.19 3,807.21 -2,116.92 12.00 -1.41 11.93 96.00 11,050.00 88.71 185.73 6,372.67 3,552.19 -2,222.48 12.00 -0.86 -11.97 266.00 11,280.00 88.85 213.33 6,377.66 3,337.56 -2,298.61 12.00 0.06 12.00 90.00 7/16/2012 4:27:06PM Page 2COMPASS 2003.16 Build 69 OR \ GINAL ti-' ConocoPhillips or its affiliates lIf' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3N-11 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3N-11 @ 68.00ft(3N-11) • Site: Kuparuk 3N Pad North Reference: True - Well: 3N-11 Survey Calculation Method: Minimum Curvature • Wellbore: 3N-11A Design: 3N-11A_wp07 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (0) (ft) (ft) 8,400.00 44.72 345.25 6,291.13 4,961.83 -778.60 -3,617.90 0.00 0.00 6,018,758.73 517,455.36 TIP 8,472.00 44.79 345.07 6,342.26 5,010.83 -791.58 -3,650.60 0.20 -61.15 6,018,807.70 517,442.26 KOP 8,497.00 49.29 345.07 6,359.29 5,028.50 -796.30 -3,662.37 18.00 0.00 6,018,825.36 517,437.51 3 8,500.00 50.34 345.07 6,361.23 5,030.72 -796.89 -3,663.85 35.00 0.00 6,018,827.57 517,436.91 8,600.00 85.34 345.07 6,398.36 5,118.82 -820.38 -3,722.54 35.00 0.00 6,018,915.60 517,413.21 8,622.00 93.04 345.07 6,398.67 5,140.06 -826.04 -3,736.69 35.00 0.00 6,018,936.83 517,407.49' 4 8,700.00 92.20 317.75 6,395.04 5,207.82 -862.98 -3,771.02 35.00 -91.10 6,019,004.50 517,370.39 8,800.00 90.44 282.79 6,392.67 5,257.43 -947.99 -3,762.89 35.00 -92.37 6,019,053.89 517,285.27!, 8,837.00 89.71 269.86 6,392.62 5,261.49 -984.68 -3,745.17 35.00 -93.20 6,019,057.86 517,248.57 II End 35d1s 1 8,900.00 89.75 262.30 6,392.91 5,257.19 -1,047.49 -3,705.62 12.00 -89.70 6,019,053.40 517,185.781 9,000.00 89.83 250.30 6,393.28 5,233.54 -1,144.47 -3,630.63 12.00 -89.66 6,019,029.52 517,088.87', 9,100.00 89.91 238.30 6,393.51 5,190.25 -1,234.41 -3,543.58 12.00 -89.62 6,018,986.02 516,999.04 9,200.00 90.00 226.30 6,393.59 5,129.21 -1,313.38 -3,448.28 12.00 -89.59 6,018,924.79 516,920.23 9,300.00 90.08 214.30 6,393.51 5,053.08 -1,377.94 -3,348.89 12.00 -89.58 6,018,848.51 516,855.86!I 9,400.00 90.17 202.30 6,393.29 4,965.19 -1,425.26 -3,249.75 12.00 -89.59 6,018,760.51 516,808.76 9,470.00 90.22 193.90 6,393.06 4,898.71 -1,446.99 -3,182.83 12.00 -89.62 6,018,693.99 516,787.20 6 9,500.00 90.22 197.50 6,392.94 4,869.84 -1,455.10 -3,154.53 12.00 90.00 6,018,665.10 516,779.16 9,600.00 90.21 209.50 6,392.56 4,778.30 -1,494.90 -3,056.71 12.00 90.01 6,018,573.47 516,739.58 9,700.00 90.20 221.50 6,392.20 4,697.04 -1,552.86 -2,956.90 12.00 90.06 6,018,492.07 516,681.83 9,750.00 90.18 227.50 6,392.04 4,661.39 -1,587.89 -2,907.61 12.00 90.10 6,018,456.34 516,646.89 7 9,800.00 90.18 221.50 6,391.88 4,625.74 -1,622.92 -2,858.32 12.00 -90.00 6,018,420.61 516,611.95 9,900.00 90.18 209.50 6,391.56 4,544.48 -1,680.88 -2,758.50 12.00 -90.02 6,018,339.22 516,554.19 9,975.00 90.16 200.50 6,391.34 4,476.58 -1,712.55 -2,684.72 12.00 -90.06 6,018,271.24 516,522.70 8 10,000.00 90.06 203.50 6,391.29 4,453.40 -1,721.91 -2,660.36 12.00 92.00 6,018,248.05 516,513.40 10,100.00 89.64 215.49 6,391.56 4,366.52 -1,771.05 -2,561.01 12.00 92.01 6,018,161.05 516,464.47, 10,200.00 89.24 227.48 6,392.54 4,291.75 -1,837.17 -2,461.83 12.00 91.97 6,018,086.13 516,398.54 10,225.00 89.14 230.48 6,392.89 4,275.34 -1,856.03 -2,437.58 12.00 91.86 6,018,069.68 516,379.72 9 10,300.00 90.40 221.57 6,393.19 4,223.32 -1,909.95 -2,364.04 12.00 -82.00 6,018,017.53 516,325.94' 10,400.00 92.06 209.68 6,391.04 4,142.21 -1,968.08 -2,264.25 12.00 -81.96 6,017,936.28 516,268.01 10,500.00 93.63 197.77 6,386.06 4,050.94 -2,008.20 -2,166.48 12.00 -82.22 6,017,844.93 516,228.12 10,545.00 94.28 192.40 6,382.96 4,007.61 -2,019.88 -2,124.29 12.00 -82.81 6,017,801.58 516,216.55• 10 10,600.00 93.57 198.97 6,379.19 3,954.82 -2,034.71 -2,072.53 12.00 96.00 6,017,748.75 516,201.851 10,700.00 92.15 210.91 6,374.18 3,864.42 -2,076.75 -1,974.37 12.00 96.45 6,017,658.26 516,160.03 10,770.00 91.10 219.24 6,372.19 3,807.21 -2,116.92 -1,904.47 12.00 97.05 6,017,600.96 516,120.00 11 10,800.00 90.85 215.65 6,371.68 3,783.40 -2,135.16 -1,874.50 12.00 -94.00 6,017,577.10 516,101.83 10,900.00 89.99 203.68 6,370.95 3,696.67 -2,184.56 -1,775.12 12.00 -94.06 6,017,490.26 516,052.64 11,000.00 89.13 191.71 6,371.72 3,601.58 -2,214.91 -1,679.82 12.00 -94.15 6,017,395.11 516,022.53', 11,050.00 88.71 185.73 6,372.67 3,552.19 -2,222.48 -1,635.02 12.00 -94.06 6,017,345.70 516,015.08 12 11,100.00 88.71 191.73 6,373.80 3,502.80 -2,230.06 -1,590.22 12.00 90.00 6,017,296.30 516,007.62 11,200.00 88.77 203.73 6,376.00 3,407.75 -2,260.45 -1,494.92 12.00 89.86 6,017,201.18 515,977.47 7/16/2012 4:27:06PM Page 3 COMPASS 2003.16 Build 69 ORIGINAL 'iv' ConocoPhillips or its affiliates red r ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3N-11 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3N-11 @ 68.00ft(3N-11) Site: Kuparuk 3N Pad North Reference: True Well: 3N-11 Survey Calculation Method: Minimum Curvature Wellbore: 3N-11A Design: 3N-11A_wp07 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +El-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°l100ff) (°) (ft) (ft) •11,280.00 88.85 213.33 6,377.66 3,337.56 -2,298.61 -1,415.54 12.00 89.60 6,017,130.91 515,939.49 TD at 11280.00 1 7/16/2012 4:27:06PM Page 4 COMPASS 2003.16 Build 69 ►-' ConocoPhillips or its affiliates (/' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3N-11 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3N-11 @ 68.00ft(3N-11) Site: Kuparuk 3N Pad North Reference: True Well: 3N-11 Survey Calculation Method: Minimum Curvature Wellbore: 3N-11A Design: 3N-11A_wp07 • Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 13N-11A_T5 0.00 0.00 6,380.00 3,950.31 -2,025.29 6,017,744.27 516,211.27 70°27'34.799 N 149°52'3.639 WI -plan misses target center by 10.46ft at 10600.07ft MD(6379.18 TVD,3954.75 N,-2034.73 E) -Point 3N-11A_CTD Fault2 0.00 0.00 6,394.00 4,463.12 -1,527.96 6,018,258.25 516,707.30 70°27'39.843 N 149°51'49.030 W -plan misses target center by 173.59ft at 9877.38ft MD(6391.63 TVD,4563.89 N,-1669.29 E) -Polygon Point 1 6,394.00 4,463.12 -1,527.96 6,018,258.25 516,707.30 Point 2 6,394.00 3,667.41 -846.80 6,017,464.28 517,390.34 Point 3 6,394.00 3,460.71 -564.26 6,017,258.30 517,673.35 Point 4 6,394.00 3,667.41 -846.80 6,017,464.28 517,390.34 3N-11A_T1 0.00 0.00 6,400.00 5,210.57 -875.03 6,019,007.22 517,358.33 70°27'47.195 N 149°51'29.847 W -plan misses target center by 8.73ft at 8711.86ft MD(6394.61 TVD,5216.30 N,-871.26 E) -Point 3N-11A_T2 0.00 0.00 6,394.00 5,044.78 -1,366.51 6,018,840.23 516,867.31 70°27'45.564 N 149°51'44.289 W -plan misses target center by 14.20ft at 9301.89ft MD(6393.51 TVD,5051.51 N,-1379.00 E) -Point 3N-11A_T6 0.00 0.00 6,371.00 3,668.67 -2,181.01 6,017,462.27 516,056.27 70°27'32.028 N 149°52'8.212 W -plan misses target center by 13.89ft at 10925.64ft MD(6371.00 TVD,3672.92 N,-2194.23 E) -Point 3N-11A_CTD Faultl 0.00 0.00 6,394.00 5,112.71 -1,338.34 6,018,908.23 516,895.31 70°27'46.232 N 149°51'43.461 W -plan misses target center by 6.24ft at 9228.77ft MD(6393.58 TVD,5108.71 N,-1333.57 E) -Polygon Point 1 6,394.00 5,112.71 -1,338.34 6,018,908.23 516,895.31 Point2 6,394.00 4,996.44 -1,232.61 6,018,792.23 517,001.32 Point 3 6,394.00 4,818.03 -1,066.02 6,018,614.25 517,168.33 3N-11 CTD Polygon 0.00 0.00 68.00 5,125.00 -647.21 6,018,922.21 517,586.34 70°27'46.354 N 149°51'23.152 W -plan misses target center by 6226.66ft at 8400.00ft MD(6291.13 TVD,4961.83 N,-778.60 E) -Polygon Point 1 68.00 5,125.00 -647.21 6,018,922.21 517,586.34 Point 2 68.00 5,493.63 -894.35 6,019,290.20 517,338.32 Point 3 68.00 5,445.08 -1,503.53 6,019,240.16 516,729.32 Point4 68.00 4,803.97 -1,899.11 6,018,598.15 516,335.35 Point 5 68.00 4,061.92 -2,326.93 6,017,855.13 515,909.39 Point 6 68.00 3,179.50 -2,608.07 6,016,972.11 515,630.44 Point 7 68.00 3,191.30 -2,105.99 6,016,985.14 516,132.44 Point 8 68.00 4,079.82 -1,868.84 6,017,874.15 516,367.39 Point 9 68.00 5,107.32 -1,200.31 6,018,903.18 517,033.34 Point 10 68.00 5,150.92 -1,028.19 6,018,947.20 517,205.33 Point 11 68.00 4,890.20 -742.78 6,018,687.20 517,491.35 3N-11A_CTD Fault4 0.00 0.00 6,394.00 4,382.09 -2,323.27 6,018,175.27 515,912.27 70°27'39.044 N 149°52'12.398 W -plan misses target center by 428.61ft at 10400.00ft MD(6391.04 TVD,4142.21 N,-1968.08 E) -Polygon Point 1 6,394.00 4,382.09 -2,323.27 6,018,175.27 515,912.27 Point 2 6,394.00 4,175.87 -2,240.76 6,017,969.27 515,995.28 Point 3 6,394.00 3,964.41 -2,057.24 6,017,758.28 516,179.29 Point 4 6,394.00 4,175.87 -2.240.76 6,017,969.27 515,995.28 3N-11A_CTD Fault5 0.00 0.00 6,394.00 3,509.06 -1,942.37 6,017,303.27 516,295.27 70°27'30.459 N 149°52'1.199 W -plan misses target center by 284.18ft at 11050.60ft MD(6372.68 TVD,3551.59 N,-2222.54 E) -Polygon Point 1 6,394.00 3,509.06 -1,942.37 6,017,303.27 516,295.27 Point 2 6,394.00 3,058.80 -1,854.44 6,016,853.27 516,384.30 Point 3 6,394.00 2,652.59 -1,782.41 6,016,447.28 516,457.31 Point4 6,394.00 3,058.80 -1,854.44 6,016,853.27 516,384.30 7/16/2012 4:27:06PM Page 5 COMPASS 2003.16 Build 69 ►. ' ConocoPhillips or its affiliates Ire' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3N-11 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3N-11 @ 68.00ft(3N-11) Site: Kuparuk 3N Pad North Reference: True Well: 3N-11 Survey Calculation Method: Minimum Curvature Wellbore: 3N-11A Design: 3N-11A_wp07 3N-11A_T7 0.00 0.00 6,376.00 3,332.90 -2,287.85 6,017,126.28 515,950.26 70°27'28.726 N 149°52'11.348 W -plan misses target center by 11.71ft at 11278.92ft MD(6377.64 TVD,3338.47 N,-2298.01 E) -Point 3N-11A_CTD Fault3 0.00 0.00 6,394.00 4,170.35 -2,034.75 6,017,964.26 516,201.28 70°27'36.963 N 149°52'3.919 W', -plan misses target center by 72.33ft at 10400.92ft MD(6391.01 TVD,4141.41 N,-1968.53 E) -Polygon Point 1 6,394.00 4,170.35 -2,034.75 6,017,964.26 516,201.28 Point 2 6,394.00 4,387.06 -1,906.22 6,018,181.27 516,329.26 Point 3 6,394.00 4,624.81 -1,789.64 6,018,419.28 516,445.25 Point4 6,394.00 4,387.06 -1,906.22 6,018,181.27 516,329.26 3N-11A T3 0.00 0.00 6,392.00 4,559.45 -1,654.74 6,018,354.25 516,580.30 70°27'40.790 N 149°51'52.755 W -plan misses target center by 14.68ft at 9872.58ft MD(6391.65 TVD,4567.94 N,-1666.71 E) -Point 3N-11A_T4 0.00 0.00 6,393.00 4,245.93 -1,859.54 6,018,040.26 516,376.28 70°27'37.706 N 149°51'58.771 W -plan misses target center by 19.97ft at 10247.98ft MD(6393.16 TVD,4260.31 N,-1873.40 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 115.00 47.00 16" 16 16 4,557.99 3,563.65 9 5/8" 9-5/8 13-1/2 11,280.00 6,377.66 2-3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 8,400.00 6,291.13 4,961.83 -778.60 TIP 8,472.00 6,342.26 5,010.83 -791.58 KOP 8,497.00 6,359.29 5,028.50 -796.30 3 8,622.00 6,398.67 5,140.06 -826.04 4 8,837.00 6,392.62 5,261.49 -984.68 End 35d1s 9,470.00 6,393.06 4,898.71 -1,446.99 6 9,750.00 6,392.04 4,661.39 -1,587.89 7 9,975.00 6,391.34 4,476.58 -1,712.55 8 10,225.00 6,392.89 4,275.34 -1,856.03 9 10,545.00 6,382.96 4,007.61 -2,019.88 10 10,770.00 6,372.19 3,807.21 -2,116.92 11 11,050.00 6,372.67 3,552.19 -2,222.48 12 11,280.00 6,377.66 3,337.56 -2,298.61 TD at 11280.00 7/16/2012 4:27:06PM Page 6 COMPASS 2003.16 Build 69 lCf"` /\ I • \ ConocoPhillips Well: 3N-11 2011 RWO Proposed Completion (CTD Setup) 116"62#H-40 to 115'MD ' a sem• 19-5/8"36#J-55 to 4558'MD — `—_ O,�O 3-1/2"Gas Lift Completion 3-1/2"9.3#L-80 EUE 8rd Tubing to surface. �i � B / 4" ) `l5 "7 3-1/2"TRMAXX-CMT SSSSV @-1800'TVD V PKC S[2 57� .:", 3-1/2"Camco MMG gas lift mandrels @ TBD r v 2 Z 2.813"Landing Nipple w/'X'profile @XXXX'MD rib 16 Baker GBH-22 seal assy.@ XXXX'MD(3"ID) r----2* r- 4-112"Scab Liner ( Baker 4-1/2"x 7"ZXP liner top pkr @-8,320'MD Baker 4-1/2"x 7"HMC liner hanger @ XXXX'MD I Baker 80-40 SBE(12'length with 4"ID seal bore) 4-1/2"11.6#L-80 BTC Casing to-8,690'MD C-sand perfs 8420'-8435'MD - A-3 sand perfs 8475'-8490'MD A-2 sand perfs 8498'-8560'MD — 1 "- OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHaECKLIST �f WELL NAME K2� .�JAd( ---// PTD# - 12 DevelopmentV Service Exploratory Stratigraphic Test Non-Conventional Well :;) FIELD: erCiv a lam° �s-r----( POOL: e czar c_ A,--?,_,, i Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter ADD-ONS CHECK (OPTIONS) WHAT OTEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 O Di c 0 N To a`) co n o 0 W U a) 6 N 4a) c c .) c m Q m CN C CO CO o N 0 a- -° C OJ C O 2 -0LL E s o a) c - S1 0 d a 3 0 co 0 3 ON— O cr t 0 "0 C . p ) . m O) Y a Wn F O 0 a 0 co O a` U r -p - c L o a c a o . O o ma .0 N 3 o 0 E O csi ° °(,) a) ) om " 0 D U _ 2 CO ` a) 0_ m N = s a)=aom U L N aa aam a ) ia o •o > 0 .aJ V N aa) c a) = E m 0 OCN ` O C - 0 0) < ° a) , m 3 Eo z0o ao O C N N E NcT3 7 0 2 0 0 > a) °) O LU EO 4-' p cn _� a) a) aa.) 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