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212-128
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, August 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2F-11A KUPARUK RIV UNIT 2F-11A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/16/2024 2F-11A 50-029-21095-01-00 212-128-0 W SPT 5902 2121280 1500 2875 2875 2875 2850 533 548 548 550 4YRTST P Bob Noble 7/6/2024 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 2F-11A Inspection Date: Tubing OA Packer Depth 730 1790 1775 1770IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240707133323 BBL Pumped:1.2 BBL Returned:1.1 Friday, August 16, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 99 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.08.16 16:00:46 -08'00' MEMORANDUM State of Alaska Permit Number: 212-128-0 Inspection Date: 7/12/2020 i Alaska Oil and Gas Conservation Commission To: Jim Regg 7��r{acn.� DATE: Tuesday, July 21, 2020 P.I. Supervisor SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 15 Min 30 Min 45 Min 60 Min 217-11A FROM: Matt Herrera KUPARUK RIV UNIT 2P -11A Petroleum Inspector w -TVD Src: Inspector Reviewed By: zzso P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 217-1 IA API Well Number 50-029-21095-01-00 Inspector Name: Matt It r m Permit Number: 212-128-0 Inspection Date: 7/12/2020 i Insp Num: mitMFH2O0714161300 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well zPa1A Type Inj w -TVD ssoz •Tubing zzso - zzso z7ao 2700 2760 PTD 2121280 Type Test SPT Test psi 1500 TA 530 1700 1660 1630 1630 " BBL Pumped: t.3 B&L Returned: 1.I OA aao szo szo aao szo Interval 4YRTST P/F P .— Notes: Tuesday, July 21, 2020 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,August 29,2016 TO: Jim Regg q �� ,�[6P.I.Supervisor ( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2F-11A FROM: Johnnie Hill KUPARUK RIV UNIT 2F-11A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry.31Y---- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2F-1 IA API Well Number 50-029-21095-01-00 Inspector Name: Johnnie Hill Permit Number: 212-128-0 Inspection Date: 7/8/2016 Insp Num: mitJWH160826172704 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well li 2F-11A1 Inj IIITVD 5902 . Tubing 2625 - 2625 .I 2625 ! 2625 - I PTD 2121280 Type Test,SPT Test psi 1500 IA 365 2000 , 1920 - 1900 Interval l4YRTST P/F P / OA 225 235 235 - 235 - 1 I 1 Notes: alt'[ . ' WOW ` Monday,August 29,2016 Page 1 of 1 Z.- l 256 • WELL LOG TRANSMITTAL#903074950 To: Alaska Oil and Gas Conservation Comm. March 4, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 MAR 08 2f1V j iU 3 i1 i2014 M.K.BENDER A 000 RE: Static Bottom Hole Pressure Record: 2F-11A Run Date: 1/22/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2F-11A Digital Data in LAS format,Digital Log Image file 1 CD Rom 50-029-21095-01 Static Bottom Hole Pressure Record (Field Print) scANNED 1 Color Log 50-029-21095-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: � 60,e • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,November 03,2015 TO: Jim Regg P.I.Supervisor "E'�C fit 7 j - SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2F-1 IA FROM: Johnnie Hill KUPARUK RIV UNIT 2F-11A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J � NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2F-11A API Well Number 50-029-21095-01-00 Inspector Name: Johnnie Hill Permit Number: 212-128-0 Inspection Date: 11/1/2015 Insp Num: mitJWH151101165721 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2F-11A 5902 Tubing 2750 2760 '1 2760 - 2760 PTD 2121280 'Type Test SPT Test psi 1500 I IA 118 . 1810 • 1765 - 1755 Interval IINITAL P/F P v OA ! 105 108 - 109 109 - Notes: Post Conversion to injection per Sundry#314-628 SCANNED SEP 16 2015, Tuesday,November 03,2015 Page 1 of 1 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations fl Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend J Perforate r" Other Stimulate Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Prod to WIND 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development R7 Exploratory r 212-128-0 3.Address: Stratigraphic r Service 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-21095-01 7. Property Designation(Lease Number): 8.Well Name and Number: ADL025657;ADL025665;ADL025658 KRU 2F-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 13620 feet Plugs(measured) None true vertical 6037 feet Junk(measured) None Effective Depth measured 13529 feet Packer(measured) 9344 true vertical 6054 feet (true vertical) 5902 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 110 110 SURFACE 3781 12 3810 2860 WINDOW AL2 6 7 9512 6013 "4 ( " I ' ° ' 0 PRODUCTION 10108 7 10137 6471 LINERA 3372 2.7 13529 6054 0L,1 2 cy 23 ; , Ate ~ Perforation depth: Measured depth: 10168- 10471; 10493- 13528 True Vertical Depth: 6089-6091;6092-6054 1 %MOI Tubing(size,grade, MD,and TVD) 3.5, J-55, 9374 MD, 5920 TVD Packers&SSSV(type, MD,and TVD) PACKER- BAKER FHL RETRIEVABLE PACKER @ 9344 MD and 5902 TVD SAFETY VLV-BAKER FVL SAFETY VALVE @ 2010 MD and 1844 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 400 143 Subsequent to operation 4000 200 2742 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations pr Exploratory r Development r- Service 17 Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ WAG i-- GINJ r- SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-628 Contact Darrell Humphrey/Bob Christensen Email n1139(c�conocophillips.com Printed Name Ro•ert D. Christen n Title NSK Production Engineering Specialist Signature IF / Phone:659-7535 Date /0/g. i 11 V`rL `(2//Z 7/1 1Rwwmw 01.1 13101 Form 10-404 Revised 5/2015 /0l (i Submit Original Only • • 2F-11A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/27/14 PERFORMED MIT-IA TO 3000@#. PASSED. PULLED 2..80"AVA CATCHER FROM TOP OF WRP @ 9313' RKB. PULLED 2.78"WRP FROM 9313' RKB. 01/02/15 TAGGED LINER TOP @ 9362' RKB, MEASURE BHP @ 9352' RKB (2699 PSI) 10/17/15 Opened well to Water Only injection service KUP PROD 0 2F-11A ConocoPhillips p Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Statusncl(°) MD(ftK8) Act Btm(ftKB) Csmre'Milapi 500292109501 KUPARUK RIVER UNIT PROD 101.28 13,405.45 13,620.0 -- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date DEVIATED-2F-11A,1/7/2015 a 21:14 PM SSSV:TRDP 90 1/14/2014 Last WO: 33.01 4/10/1984 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ......._ ..Last Tag.SLM 9,558.0 6/22/2012 Rev Reason:GLV C/O lehallf 1/7/2015 HANGER;23.7 1 Casing Strings _, Casing Description OD(in) ID(n) Top(kKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 30.0 110.0 110.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread li 11 SURFACE 9 5/8 8.921 29.3 3,810.0 2,860.4 36.00 J-55 BTC .Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 29.0 10,137.2 6,089.1 26.00 J-55 BTC 'Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(L..Grade Top Thread WINDOW AL2 7 6.000 9,506.0 9,512.0 6,012.9 26.00 J-55 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread LINER A 23/8 1.995 10,156.8 13,529.0 6,054.1 4.60 L-80 STL .n.AI CONDUCTOR 3D.o-1t0.0• Liner Details Nominal ID it Top(ftKB) Top(TVD)(kKB) Top Incl(°) Item Des Com (in) SAFETY VLV;2,009.8 j 10,156.8 6,089.0 90.48 BILLET ANCHORED BILLET I.000 10,492.1 6,092.0 88.18 DEPLOY SHORTY DEPLOYMENT SLEEVE 1910 11,892.6 6,121.7 86.70 DEPLOY SHORTY DEPLOYMENT SLEEVE 1910 GAS LIFT;2,122 3Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(ib/ft( Grade Top Connection TUBING 3 1/2 2.9921 23.71 9.373.91 5,921.21 9.301 J-55 I EUE8RD Completion Details Nominal ID SURFACE;29.3/,810.0-� Top(ftKB) Top(ND)(ftKB) Top Inc)(°) Item Des Com (in) 23.7 23.7 0.00 HANGER FMC GEN II TUBING HANGER 3.500 GAS LIFT;4,930.9 I 2,009.8 1,843.7 47.57 SAFETY VLV BAKER FVL SAFETY VALVE 2.810 9,330.1 5,893.8 51.89 PBR BAKER PBR 3.000 GAS LIFT;7,483.0 9,343.8 5,902.3 51.79 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 9,360.9 5,912.9 51.04 NIPPLE CAMCO D NIPPLE NO GO 2.75"ID MILLED TO 2.80" 2.800 GAS LIFT;9,288.1 FOR SIDETRACK 9,372.4 5,920.2 50.31 Gun Release VANN GUN RELEASE 1.810 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PBR;9,330.1 S Top(ND) Top Incl PACKER;9,343.8 ' Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 9,354.0 5,908.6 51.48 PUNCHES TUBING PUNCHES FOR CMT SQZ/PLUG PRE- 7/2/2012 2.992 SIDETRACK-6 SPF,60 deg,Big Hole Charges PUNCHES;9,354.0 9503.0 6,006.8 46.68 WHIPSTOCK WHIPSTOCK IN CEMENT PILOT HOLE FOR 2F- 10/8/2012 11A NIPPLE;9,3509 Perforations&Slots Shot Dens Top(ND) Btm(TVD) (shots/f ' Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 10,168.2 10,470.8 6,088.9 6,091.3 A-4,2F-11A 10/17/2012 32.0 SLOTS Gun Release,9,372.4 "iii- 10,492.5 13,528.2 6,092.0 6,054.3 A-4,A-5,2F- 10/17/2012 32.0 SLOTS 11A SOZ'd;9,376.0.9,3780-,4 Mandrel Inserts APERF;9,451.0-9,4640-'f ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB( Make Model OD(in) Sery Type Type (in) (psi) Run Date Com f 2,122.3 1,916.6 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 12/26/2014 SOzd;9,506.0-9,508.0- r= 2 4,930.9 3,520.0 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 12/26/2014 WHIPSTOCK;9.5030 3 7,483.0 4,839.1 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 12/26/2014 WINDOW AL2;9.506.139,512.0 I• 4 9,288.1 5,868.4 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 12/26/2014 Notes:General&Safety SLOTS;9,552.3-10,959.7- End Date Annotation LINER AL2;9,361.7-10,970.0 11/6/2012 NOTE:WELL SIDETRACKED,ADDED LATERALS AL1&AL2(AL2 OFF MAIN WELLBORE.see drawing) h_ SLOTS;9.802.9-10,037 0 _I _ I % SLOTS;10,039.0.11,779.0 PRODUCTION;29.0-10,137.2 LINER AL1;9,770.1-13719.0 Ir SLOTS;10,168.2-10,470.8 i SLOTS;10,492.5.13,528.2 LINER A;10,156.8-13,529.0 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. cQ I O? - 10:6' Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RE AN: OVERSIZED: NOTES: Co Items: ❑ Maps: Grayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: riq p BY: Maria Date: G /s/ Project Proofing BY: CMaria Date: 1 C9161/4 /s/ Scanning Preparation 1 x 30 = 30 + a Fr = TOTAL PAGES 3 imp (Count does not include cover sheet) BY: 112110 Date: „9... ` /s/ Production Scanning Stage 1 Page Count from Scanned File: 5of (Count does include cover sheet) Page Count Matches Number in Scannin Pre aration: 1/ YES NO BY: da, Date: / cg, Cc /174- /s/ 1/413 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 Michal 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 C G Q z z 1 N c cc �Z . Z Z o Z II c m >- > >-N O) U N IIICTI U N 9 }I1� o O. a a CO _ I m c N N co N 0 Q II .I O a) ilL -o a a. III Z 7 1 + ye- L O �I Y. cn �, r U a m I Q 7C N 2 000 a). 1, N a) .8 J ') i a I) ami U U J 11 1 c z O 0 Oo a Z E C7 I ' sca m o,rn a s U J ` E >- >- ›- cn 0o 0 y o 0 Dva U l� Ce < c O 0_ . a) 0 /� 0. j C ,O N N N N N a a+ .O• a1 A J 0 >iN N N N N E N > 0 1 J wN aI rn rn rn M c z y ai 1.e 0 co ce '- a- a- 0o m U -o I� it E I' 0 c c c C . ui y 1 W Z J 2 2I'1 a Cl) a a d coon co a 0 0 O 0 010 0 0 0 0 E . E Z w m 13. O-I N N N N N 0: I 0 0 N N i' < N 7 i 1a N S M CO CO CO 0 CO CO 0 M ' 'O E '47.— II' i J a m Z c O .c O. p in :) 1 c U U it S !M' O ZI C ao .- 0 0 0 I a) CO G O -,- co co Q) O) O) Q) O) it O N Ta. O E a Q V = 0 E �? J I---• Q ›- >- >- Q Q cez c / I e' o N E H N co la o a) O O O w p , II Z N ..J U U U �o y Cl) c I 2 / CO z z �t • N co f0 +O+ O a) E• 03 ,` 03 ce O J co N In N C O F- E w E rnSC • Cl)re C 0) N' 1111�/ Q0 C o to E' `• < 0_ c • o l m m . m 0c z 'o Lo U /- m m Q Z w w m0Dd 0 co > > > > ai coEJ N o) N co Z Z 7 I 0 aa)) CDacn y) Cl) 1 M II '' C 1 i E -2 O .o .`O_ 0 CO 1 c Q / 0 11 ZIt) o o v C � Z O 0 Z 0 a+ ,en U E D c / CO p �1 J ` N d I p lw LU, O m H m uS3 E o W E• a 1 m N p r W O Z IN CO W O O ',' a) IX H CD a+ 1 a y O E N I� > 0LL • 2 u €o Z 1i N to CD 0 y• - ° N ? ' Q: r w •'� I._ V) z 1--' 16 a) G / co 0 0 c p y J y Q o c l c o W LL °' Ucp - ° y , C6 .+ �_ Z W J V re a) U rn E a E 5 I Q ayi 0 a v' o E E m w Q a d rn2 S) ,0 0 0 0 a m z o o a) 0 0 a CL 0 J G H W J J J D 3 _ U a 0 0 , 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number. ConocoPhillips Alaska, Inc. or Aband: October 27,2012 212-128/ • 3.Address: 6.Date Spudded: 13.API Number P.O.Box 100360,Anchorage,AK 99510-0360 October 10,2012 50-029-21095-01 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 155'FNL, 1450'FEL,Sec.33,T11N,R9E,UM October 16,2012 2F-11A Top of Productive Horizon: 8.KB(ft above MSL): 125'RKB 15.Field/Pool(s) 548'FSL,898'FEL,Sec.34,T11N,R9E,UM GL(ft above MSL): 92'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 2565'FNL,5059'FEL,Sec.2,T1 ON,R9E, UM 13529'MD/6054'TVD Kupuruk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x-517782 y- 5948729 Zone-4 13620'MD/6037'TVD ADL 25657,25665,25658 TPI: x-523635 y- 5944168 Zone-4 11.SSSV Depth(MD+ND). 17.Land Use Permit: Total Depth: x-524767 y- 5941059 Zone-4 2010'MD/1844'ND 2583,2586 18.Directional Survey: Yes ❑✓ No❑ 19.Water Depth,if Offshore. 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) na (ft MSL) 3825'MD/2869'ND 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 9506'MD/6009'ND 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 30' 110' 30' _ 110' 24" 225 sx Cold Set II 9.625" 36# J-55 _ 29' 3810' 29' 2860' 12.25" 1050 sx AS III,780 sx Class G 7" 26# J-55 29' 10137' 29' 6471' _ 8.5" 350 sx Class G,250 sx AS I 2.375": 4.6# L-80 10157' 13529' 6089' 6054' 3" slotted liner 24.Open to production or injection? Yes i Nor 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" 9374' 9344'MD/5902'ND slots from 10168'-10471'MD 6089'-6091'ND slots from 10493'-13528'MD 6091-6054'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. RECEIVEDC E I V E D Was hydraulic fracturing used during completion? Yes❑ No E..„-..i...,,,,,,, DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED • '11� ... a, NOV 2 8 2(iiL '*._� AOGCC . .__- 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period-> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press . 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No O` 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 ) .4411 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only 29. GEOLOGIC MARKERS(List all formations and markers encountered) 30 FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑✓ 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 3825' 2869' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk A6 9522' 6020' Kuparuk A5 9544' 6033' Kuparuk A4 9596' 6059' Base A5/Top A4 inverted 13368' 6085' Base A6/Top A5 inverted 13530' 6054' N/A Formation at total depth: Kuparuk A6 31 LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Contact: Gary Eller 263-4172 Email: J.Gary.Eller(r conocophillips.com Printed Name _1 amar antt Title: CTD Supervisor � r Signatu , E-- 7D - 1 ^ Phone 263-4021 //—%7- Z Date \ ( lZ 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 10/2012 KUP 2F-11A • ConocoPhillips 0:4 Well Attributes Max Angle&MD TD Alaska.Inc, Wellbore API/UWI Field Name Well Status not e) MD(ftKB) Act Min(RKB) ConocOPTIRips 500292109501 KUPARUK RIVER UNIT PROD 101.28 13,405.45 13,620.0 "" Comment H2S(ppm) Date Annotation End Date KB-3rd(ft) Rig Release Date Well Gaffs:-zF-itA.lvey20121041:02 AM SSSV:TRDP 45 10/5/2011 Last WO: 33.01 4/10/1984 Schematic-Actual Annotation Depth(MB) End Date Annotation Last Mod...End Date Last Tag:SLM 9,558.0 6/22/2012 Rev Reason:SIDETRACK ninam 11/6/2012 HANGER,24------- .? :Flom" Casing Strings a Casing Description String 0... String ID...Top(ROB) Set Depth(f...Set Depth(TVD)... String Wt...String.. String Top Thrd CONDUCTOR 16 15.062 30.0 110.0 110.0 62.50 H-40 WELDED jramiiim Casing Description String 0... String ID...Top(RKB) Set Depth(I...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 9 5/8 8.921 29.3 3,810.0 2,860.3 36.00 J-55 BTC Casing Description String 0... String ID...Top(RKB) Set Depth(I...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6276 29.0 10,137.2 6,089.1 26.00 J-55 BTC Casing Description String 0... String ID...Top(RKB) Set Depth(1...Set Depth(ND)...String Wt...String...String Top Thrd WINDOW A 7 6.000 9,506.0 9,512.0 6,012.9 Casing Description String 0... String ID...Top(RKB) Set Depth(1...Set Depth(TVD)...String Wt...String...String Top Thrd LINER A 23/8 1.995 10,156.8 13,529.0 6,054.1 4.60 L-80 STL Liner Details Top Depth (TVD) Top2:18 Incl Nomi... 31.111 Top(MB) (RKB) P) Item Description Comment ID(in) CONDUCTOR. 10,156.8 6,089.0 90.55 BILLET ANCHORED BILLET 1.000 Sat 19 I 10,492.1 6,091.4 86.40 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.995 � �J I 11,892.6 6,121.7 86.84 DEPLOY SHORN DEPLOYMENT SLEEVE 1.995 SAFETY VLV, 2.010 Tubing Strings Tubing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd TUBING 31/2 2.992 23.7 9,373.9 5,921.2 9.30 J-55 EUE8RD GAS LIFT, j Completion Details 1 2.122 - Top Depth t-r (TVD) Top Incl Nomi... Top IRKS) (R03) PI Item Description Comment ID(In) 11 23.7 23.7 -0.29 HANGER FMC GENII TUBING HANGER 3.500 2,009.8 1,843.6 47.43 SAFETY VLV BAKER FVL SAFETY VALVE 2.810 l 7,483.0 4,839.1 58.91 GASLIFT MMH FMHO 2.875 SURFACE, 29 3.010 9,330.1 5,893.8 51.89 PER BAKER PBR 3.000 GAS LIFT. L t _ 9,343.8 5,902.3 51.79 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 4,937 9,360.9 5,912.9 50.22 NIPPLE CAMCO D NIPPLE NO GO 2.750 ai..I r 9,372.4 5,920.2 50.15 SOS VANN GUN RELEASE 1.810 GAS LIFT, GASLIFT,7,483 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc,), Top Depth (ND) Top Incl 9,280 Top(RKB) (RKB) (") Description Comment Run Date ID(In) 9,354 5,908.4 50.26 PUNCHES TUBING PUCNHES FOR CMT SQZ/PLUG 7/2/2012 2.992 t PRE-SIDETRACK-6 SPF,60 deg,Big Hole Charges POR.9,330 I 9,503 6,006.8 46.01 WHIPSTOCK WHIPSTOCK IN CEMENT PILOT HOLE FOR 2F-19A 10/8/2012 9,770 6,085.2 88.49 WHIPSTOCK KICKOFF POINT FOR AL2 LATERAL 10/24/2012 - ' PACKER.9.344 1.111101 10,156 6,089.0 90.55 WHIPSTOCK KICKOFF POINT FOR 2F-11AL1 LATERAL 10/18/2012 itPerforations&Slots PUNCHES, j Shot 9,354 } Top(ND) Btm(ND) Dens • Top(RKB) Bon(RKB) (RKB) (RKB) Zone Date (ah-•- Type Comment 10,168 10,471 6,088.9 6,091.3 10/17/2012 32.0 SLOTS NIPPLE,9.361 ft. 10,493 13,528 6,091.4 6,054.3 10/17/2012 32.0 SLOTS Notes:General&Safety SOS,9.372 End Date Annotation sora, 11/6/2012 NOTE: LATERAL 2F-11A OFF OF 2F-11AL1(See Multi-lat Drawing) 9.376-9.378 Cement,9,376 11/6/2012 NOTE:WELL SIDETRACKED,ADDED LATERALS AL1&AL2 CEMENT. _. • 9.351 APERF,l\ 9.451-9.464 sora. 8.5069.508 WHIPSTOCK 9,503 Cement, WIWA, WINDD OW A, 9.506-9512 CEMENT, 8.357 • • WHIPSTOCK 9,770 PRODUCTION, h • 29-10,137 WHIPSTOCK. Mandrel Details 10,158 Top Depth Top . Port (ND) Incl OD Valve Latch Sian TRO Run Stn Top(MB) (RKB) C) Make Model _ (in) Sory Type Type (in) (psi) Run Date Corn... SLOTS, 1 2,122.3 1,916.6 51.59 MMH FMHO 1 GAS LIFT GLV BK 0.156 1,318.0 11/2/2012 1 o,t68-10,471 2 4,930.9 3,520.0 53.50 MMH FMHO 1 GAS LIFT GLV BK 0.188 1,338.0 11/2/2012 i 3 7,483.0 4,839.1 58.91 MMH FMHO 1 GAS LIFT OV BK 0.250 0.0 11/1/2012 4 9,288.1 5,868.3 53.03 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 7/7/2012 I SLOTS, 10,493-13528 LINER A. 10,157-13529 TD(2F-110), 13,820 1 ` N N N m U �.- N co on O M M N M O g g m g O N aU sj Q r n N o2m J D Q O E -Iin _ \, 1. 03 `ta 7 U7 — V N - `° n M a 0 T2 O O/�)� C V c co 9 E 0 N Cfl —2 o • ~ N "� a Ct 2 O O) Q M (V O O O] N- co r O W O)oH c�0 O -CO el rn O V O C W � r co •- al o g a O Y O 'I N M 11_• ,0LLM (A)as N g -rn 0 O) V O 0. 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CO `,....s': `,"•': M M "r-4-"- v V t0 u1 u) u) CO W W + ) O O n N 0 V O W v N N N W CO CO 1r) O r W Cr N u) CO W O CO N N 0 W I 1i) v- O W CO N O M n N t0 u1 O V W , 0) co co n n n CO W u) N V Cr CO N N I o C rn w co, O) O O CO.. 01 0) 0) rn 0) CO m o) 01 0 Ir) to 1n Ln LO 0 In N In tO LO 10 0 N 0 9 {{[ O O r v- N CO v- Cr O U) V N CO N W 1r) L M t[1 O r W v N In. W W O M N N O W ( W W M W v W N [-.-_ ,R. 83 ,7„ O M W o O O O O O O W W V V M g U — — — — O O O O O O O O O O O O F5- .5 .s .5 .5 CO W co- co- co- co- W W W W co- co- C s€ Y t N N 0 M u) ON r N LOCO V W W 1 N " M •- n O W N CO N Cr W CO v CO V Q .0 Q) Cl )- W W rp O co O C) 4) Ci n Cl Cl m ) .A g N O aN o^ r n n r r r n r n n N- N- n r r n ifif"11'iia •� f L 12 , d N •� ; c = N N v N CO O V N CO CO V 0 CO v- v- /� O 8 a) lr1 lO CO CO LO LO n O W CO O O O i c n n u O 3 = LI_N ti ti c t,. 001 co rn m co rn o o O o 0 0 0 0 0 0 U Y Y N N N . . . . . . .- .- ,- Q O V Od VCR O O O O 0 N M M N 0 N O O V V V V N N N M N M v v M N N O CO co O O In tri IO 6 to 1n O O In to m 6r; O ✓ >,C .. `O C T 0 W O N O CI .- uW O co co O N O CO N= r- N N N CO CO CO v v v v u) W 2 — M N M M M M M M M M M M M 0 0 M N Oa d a a a � V p •.O N d y 7 0 a 'm 3 3 o to 0 ConocoPhiIIips Time Log & Summary We!Mew Web Reporting Report Well Name: 2F-11 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 10/5/2012 8:00:00 AM Rig Release: 10/28/2012 12:00:00 AM Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 10/03/2012 24 hr summary RDMO 1J-09 MOB to 2F-11 12:00 00:00 12.00 0 0 MIRU MOVE MOB P Mobilize rig to 2F-11, Exception move 10/04/2012 Move Rig to CPF 2 00:00 19:00 19.00 0 0 MIRU MOVE MOB P Stand by at CPF 2 for Rig Mat placement on 2F access road 19:00 00:00 5.00 0 0 MIRU MOVE MOB P Begin moving from CPF2 to 2F pad. Moving Sub module first then following with pit sub. 10/05/2012 Move Rig to Fpad 00:00 01:30 1.50 0 0 MIRU MOVE MOB P Rig modules on 2F pad.Prep well for sub. 01:30 03:00 1.50 0 0 MIRU MOVE MOB P Spot pit sub. 03:00 08:00 5.00 0 0 MIRU MOVE RURD P RU Putz,berm up around cellar, Complete post rig move checklist. 08:00 10:00 2.00 0 0 MIRU WHDBO NUND P Nipple up BOPE Equipment and shell test Rig Accept @ 08:00 10:00 12:30 2.50 0 0 MIRU WHDBO BOPE T Leaking flanges during initial shell test,Tango flanges(MPD line),swab flages,tree flanges. Hammer up all flanges 12:30 14:00 1.50 0 0 MIRU WHDBO BOPE P Good Shell test, R/U BPV Lubricator, Pull BPV, R/D and load out equipment pve 14:00 22:00 8.00 0 0 MIRU WHDBO BOPE P Start full BOPE Test.Test witness P �/' waived By Chuck Shieve,AOGCC ✓ 22:00 00:00 2.00 0 0 SLOT WELLPF BOPE P PT PDL's to 2000psi,and the tiger tank line to 1500psi. 10/06/2012 Spotted Rig modules on 2F-11. Nipple up BOPE. Pulled BPV,Start BOPE Test.Witness waived by Chuck Shelve,AOGCC 00:00 01:00 1.00 0 0 SLOT WELLPF BOPE P Finish testing tiger tank line. 01:00 01:30 0.50 0 0 SLOT WELLPF SFTY P Pre-Spud with crew. 01:30 02:00 0.50 0 0 SLOT WELLPF RURD P Hook up IA to bleed and get RKB measurements. 02:00 04:00 2.00 0 0 PROD1 WHPST PULD P MU Milling BHA#1 with a New D331 (7134166)with a 0.9 AKO motor bend. 04:00 05:00 1.00 0 0 PROD1 WHPST TRIP P Open SSSV,troubleshoot BHI counter issues 05:00 07:30 2.50 0 9,200 PROD1 WHPST TRIP P RIH, EDC open pumping Seawater Page 1 of 20 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 07:30 08:00 0.50 9,200 9,261 PROD1 WHPST DLOG P Log Gamm tie in for-19.5 08:00 08:06 0.10 9,348 9,320 PROD1 WHPST TRIP P Tag TOC, PUH circ well to 8.6 PPG Power Vis 08:06 09:12 1.10 9,320 9,320 PROD1 WHPST CIRC P Roll well to milling fluid,Shut EDC RIH to start milling cement pilot hole 09:12 15:00 5.80 9,349 9,450 PROD1 WHPST MILL P Start Milling pilot hole @ 9349', 1.5 BPM @ 2730 PSI FS.TF=10 ROHS. ROP-20 FPH 15:00 15:15 0.25 9,450 9,334 PROD1 WHPST WPRT P Wiper up to 9334'from 9450', PUW 32k 15:15 15:30 0.25 9,334 9,450 PROD1 WHPST WPRT P Wiper back in hole,RIW 16k 15:30 17:00 1.50 9,450 9,490 PROD1 WHPST MILL P Continue milling pilot hole @ 9450'- 9490'@ 1.5 bpm @ 2900 psi FS.22 fph 17:00 17:15 0.25 9,490 9,329 PROD1 WHPST WPRT P Wiper up to 9329', RIW 16k 17:15 17:30 0.25 9,329 9,490 PROD1 WHPST WPRT P Wiper back in hole. RIW 16k 17:30 20:00 2.50 9,490 9,540 PROD1 WHPST MILL P Continue milling pilot hole from 9490' -9540'@ 1.5 bpm at 2900psi FS.22 FPH 2.5k WOB 20:00 20:30 0.50 9,540 9,340 PROD1 WHPST WPRT P TD pilot hole. PUW 32k PU hole to TOC(9349')Dry drift transition area 400lbs of weight. 20:30 23:00 2.50 9,340 9,390 PROD1 WHPST REAM P Dress transition area as per plan page#9 with low side TF at 60 fph. 9340'-9390'four times. 23:00 00:00 1.00 9,390 5,862 PROD1 WHPST TRIP P Open EDC,flowcheck well, POOH Tie into K1 marker with a-1ft correction. Depth at midnight 5862' 10/07/2012 Finished testing PDL's and tiger tank line.MU pilot hole milling BHA#1. RIH Mill from 9349'to 9540'. Back ream transition area at 60 fph four times from 9340'-9390'. POOH 00:00 01:30 1.50 5,862 0 PROD1 WHPST TRIP P Continue to POOH depth at midnight 5862' 01:30 02:30 1.00 0 0 PROD1 WHPST PULD P OOH PJSM-LD BHA#1 02:30 03:00 0.50 0 0 PROD1 WHPST PULD P MU jet nozzle and jet BOPE 03:00 03:20 0.34 0 0 PROD1 RPEQP1 SFTY P PJSM for RU eline on rig. 03:20 07:02 3.70 0 0 PROD1 RPEQP1 ELOG P RU e-line equipment 07:02 10:02 3.00 0 0 PROD1 RPEQP1 ELOG P Trip in hole with Multifinger imaging tool on E-Line,Get down to 9535', Make two passes in pilot hole up to 9200',Trip out 10:02 11:32 1.50 0 0 PROD1 RPEQP1ELOG P At surface, PJSM,start rig down of e-line equip 11:32 12:32 1.00 0 71 PROD1 RPEQP1PULD P PJSM,P/U Dummy whipstock,M/U to coil track and surface test tool 12:32 14:44 2.20 71 9,220 PROD1 RPEQP1TRIP P RIH with Dummy whipstock, EDC Open pump Min Rate 14:44 15:02 0.30 9,220 9,256 PROD1 RPEQP1DLOG P Run Gamma Tie in for-26' 15:02 15:20 0.30 9,256 9,540 PROD1 RPEQP1TRIP P Trip in to bottom with dummy, clean trip to 9540 Page 2 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:20 17:56 2.60 9,540 0 PROD1 RPEQP1TRIP P POOH with Dummy Whipstock, PUW=33K 17:56 18:11 0.25 0 0 PROD1 RPEQP1SFTY P PJSM-for Laydown dummy WS 18:11 19:11 1.00 0 0 PROD1 RPEQP1PULD P BHA#2, Laydown Dummy WS BHA#2 19:11 20:00 0.82 0 0 PROD1 RPEQP1PULD P PSJM-for PU WS and setting tools up beaver slide. 20:00 22:00 2.00 0 9,133 PROD1 RPEQP1TRIP P RIH w/open EDC,with WS setting BHA#3 22:00 23:00 1.00 9,133 9,090 PROD1 RPEQP1 DLOG P 9133'Tie into the HRZ. PU higher and start tie in again.Correction of -28' 23:00 23:30 0.50 9,090 9,416 PROD1 RPEQP1 DLOG P RIH to K1 marker to verity tie in correction of-1' 23:30 23:45 0.25 9,416 9,513 PROD1 RPEQP1TRIP P RIH to set depth 9503'TOWS 23:45 23:54 0.15 9,513 9,514 PROD1 RPEQP1 WPST P Set WS. Bring pumps up,set TOWS W 5 at 9503'.Set down 4k. 23:54 23:59 0.09 9,514 8,800 PROD1 RPEQP1TRIP P POOH with WS setting BHA#3 10/08/2012 RU e-line unit. RIH w/caliper on e-line into cement pilot hole.POOH-MU&RIH with WS BHA. POOH- MU/RIH set TOWS at 9503'. Mill window. 00:00 02:30 2.50 8,800 0 PROD1 RPEQP1TRIP P Continue POOH with WS setting BHA#3 02:30 02:45 0.25 0 0 PROD1 RPEQP1 SFTY P OOH,Check Well for flow. PJSM for laying down WS setting BHA#3 02:45 03:15 0.50 0 0 PROD1 RPEQPI PULD P LD WS setting BHA#3 03:15 03:45 0.50 0 0 PROD1 WHPST PULD P PJSM-MU window milling BHA#4 03:45 04:00 0.25 0 0 PROD1 WHPST PULD P Testing MWD tools. BAD TEST on DGS.GTs out of spec. 04:00 04:30 0.50 0 0 PROD1 WHPST PULD T PJSM-LD bad DGS/MU New DGS and test. 04:30 07:45 3.25 0 9,230 PROD1 WHPST TRIP P RIH with Milling assy BHA#4 w/.6 2' AKO motor 07:45 08:15 0.50 9,230 9,281 PROD1 WHPST DLOG P Log Gamma tie in for-28.5 08:15 08:30 0.25 9,281 9,507 PROD1 WHPST TRIP P Trip in and dry tag Whip stock @ 9506.7,PUH PUW no pumps 36K A kick on pumps 08:30 13:00 4.50 9,507 9,511 PROD1 WHPST MILL P Tag with pumps on @ 9506.3 Start milling, 1.47 BPM @ 2900 PSI FS, follow window milling procedure 13:00 18:54 5.90 9,511 9,527 PROD1 WHPST MILL P See Drop on WOB,Call bottom of window @ 9511.3 Continue on milling procedure. FMC Tech called out to check for control line communication to GrIt-P( adapter void(3000 psi tubing head flange).Stung into adapter void and (Z� found no pressure. Al2/ 18:54 20:18 1.40 9,527 9,527 PROD1 WHPST REAM P Start reaming passes,PUW=30K 20:18 23:18 3.00 9,527 78 PROD1 WHPST TRIP P Complete reaming passes looks good,POOH, PUW=30K, Power wash injector chains in prep for skate change out Page 3 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:18 00:00 0.70 78 0 PROD1 WHPST PULD P PJSM, Flow check well, Lay down window milling BHA. Trap 900 psi on well during reel swap. 10/09/2012 Swap out CT reels,Complete injector skate change. 00:00 00:15 0.25 0 0 PROD1 DRILL SFTY P PJSM-RU SLB for Blowing down reel with N2. 00:15 01:00 0.75 0 0 PROD1 DRILL CTOP P Blow down reel with N2. RD SLB N2 01:00 04:00 3.00 0 0 PROD1 DRILL CTOP P PJSM-for bleeding coil down to O. Prep coiled tubing end for unstabbing out of INJH. Remove inner reel iron and e-line bulk head. 04:00 06:00 2.00 0 0 PROD1 DRILL CTOP P PJSM-Unstab Coiled Tubing and secure free end to reel.Unhook King pin for lowering Coiled Tubing Reel. 06:00 07:30 1.50 0 0 PROD1 DRILL CTOP P PJSM-for lowering the reel onto trailer. 07:30 09:30 2.00 0 0 PROD1 DRILL CTOP P PJSM-Load Coiled Tubing Reel into rig. 09:30 11:30 2.00 0 0 PROD1 DRILL CTOP P PJSM-install internal graple, Remove reel packaging. 11:30 00:00 12.50 0 0 PROD1 DRILL SVRG P PJSM-Changeout skates on INJH. 10/10/2012 Complete reel swap&Injector skate change.Perform slack management,cut 12'CT.Deploy build section BHA(1.5 AKO,Bi-Center bit).Drill build. 00:00 02:00 2.00 0 0 PROD1 DRILL CTOP P PJSM,Secure CT reel into rig 02:00 04:00 2.00 0 0 PROD1 DRILL CTOP P PJSM,Stab CT into injector 04:00 06:00 2.00 0 0 PROD1 DRILL CTOP P PJSM,MU Inner reel iron, replace all hardline o-rings. 06:00 09:30 3.50 0 0 PROD1 DRILL CTOP P Install e-line Pressure Bulkhead inside reel. Install rubber boot on end of eline for performing slackmanagement.Clean area around INJH after skate change. • Grease all 2X2 valves. 09:30 11:00 1.50 0 0 PROD1 DRILL CTOP P RU hand rails back onto INJH. Fill pit with fresh water for slackmanagement.Grease bulkhead.Secure inner reel iron.Line up to pressure test all hardline and wash pipe installed during reel swap. 11:00 13:00 2.00 0 0 'PROD1 DRILL CTOP P Fill Coil by reversing in fresh water • watching for leaks. Perform slackmanagement,cut 12 ft of coil found wire leaving 1.3%slack in reel. PT inner reel valve and pac-off to 3500psi. 13:00 15:30 2.50 0 0 PROD1 DRILL CTOP P Install CTC. Pull Test CTC to 30k. 15:30 17:30 2.00 0 0 PROD1 DRILL CTOP P Install BHI eline head and UQ. Meg test e-line 65 meg ohms >2000 ohms. PT CTC and BHI flowsub.Swap Coil over to drilling mud. 17:30 18:00 0.50 0 0 PROD1 DRILL SFTY P PJSM,Crew change Page 4 of 20 Time Logs Date From To Dur S.Depth E.Death Phase Code Subcode T Comment 18:00 20:00 2.00 0 0 PROD1 DRILL PULD P Deploy BHA 20:00 22:30 2.50 72 9,360 PROD1 DRILL TRIP P RIH. Inspect CT for marking to assure gooseneck alignment. Looks good Cont. RIH 22:30 22:45 0.25 9,360 9,360 PROD1 DRILL DLOG P Tie in depth to K1 marker 22:45 23:15 0.50 9,360 9,527 PROD1 DRILL TRIP P RIH to drill.Smal set down at bottom of window.PU Slip thru window without any problem on second _ attmept 23:15 00:00 0.75 9,527 9,561 PROD1 DRILL DRLG P Drill Ahead 1.45 bpm,3212 ctp,3609 bhp, 14 ctw 10/11/2012 Land Build 9701'. POOH Undeploy BHA 5, Deploy BHA 6(RSM). Drill"A"lateral. Perform BOPE function test 00:00 02:00 2.00 9,561 9,680 PROD1 DRILL DRLG P Cont.drilling build 02:00 02:09 0.15 9,680 9,530 PROD1 DRILL WPRT P Wiper trip back to window 9530 02:09 02:21 0.20 9,530 9,530 PROD1 DRILL DLOG P Log RA marker TOW 9506, BOW 9512', RA 9513 02:21 02:36 0.25 9,530 9,680 PROD1 DRILL WPRT P RBIH 02:36 03:51 1.25 9,680 9,701 PROD1 DRILL DRLG P Drill ahead 1.4 bpm,3202 ctp,3612 bhp, 14k ctw 03:51 06:06 2.25 9,701 0 PROD1 DRILL TRIP P Land build 9701'. PUW 33k POOH 06:06 08:06 2.00 0 0 PROD1 DRILL PULD P Undeploy BHA#5(Build) 08:06 08:36 0.50 0 0 PROD1 DRILL SVRG P Service INJH, Inner reel iron inspection,and maint. reel hubs. 08:36 09:36 1.00 0 0 PROD1 DRILL BOPE P Function test BOPE 09:36 09:51 0.25 0 0 PROD1 DRILL SFTY P PJSM-lateral BHA 09:51 10:51 1.00 0 0 PROD1 DRILL PULD P MU lateral BHA#6 RSM-Pressure deploy 10:51 13:06 2.25 0 9,360 PROD1 DRILL TRIP P RIH w/RSM BHA#6 13:06 13:24 0.30 9,360 9,428 PROD1 DRILL DLOG P Tie in to K1 marker correction of- 19.5' 13:24 13:42 0.30 9,428 9,512 PROD1 DRILL TRIP P RIH 13:42 13:57 0.25 9,512 9,512 PROD1 DRILL TRIP T Can't pass through BOW at 9512'. Attempt three times at 20fpm,18fpm, and 14fpm. No go. POOH and call town. 13:57 14:27 0.50 9,512 9,334 PROD1 DRILL TRIP T Wait on Town to make call on plan forward. 14:27 14:36 0.15 9,334 9,506 PROD1 DRILL TRIP P Discussed with town 3 options-#1 RIH at 30 fpm,#2 Roll pump, and#3 Use Ribs on RSM.We are going to try option 1 first. RIH 14:36 14:45 0.15 9,506 9,701 PROD1 DRILL TRIP P Made it through the window with option 1. No pump,ribs off,and 34 fpm. 14:45 17:45 3.00 9,701 9,840 PROD1 DRILL DRLG P OBD-1.46 bpm at 3020 FS. BHP 3641.WHP 121 WOB 2.5k ROP 13fph 17:45 18:15 0.50 9,840 9,530 PROD1 DRILL WPRT P Wiper trip to window 29k puw Page 5 of 20 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 18:15 23:15 5.00 9,840 9,990 PROD1 DRILL DRLG P Drill Ahead-1.43 bpm 3300 ctp. BHP 3687.WHP 124 WOB 2.5-3k 23:15 23:45 0.50 9,990 9,535 PROD1 DRILL WPRT P Wiper trip to window,29k puw 23:45 00:00 0.25 9,990 10,009 PROD1 DRILL DRLG P Drill Ahead-1.43 bpm 3300 ctp. BHP 3687.WHP 124 WOB 2.5-3k 10/12/2012 Continue drilling"A"Lateral 10009'-11088'. Pull back to window(9530')every 150'drilled. Projected TD for"A" lateral 13500'. 00:00 01:30 1.50 10,009 10,140 PROD1 DRILL DRLG P Drill Ahead-1.43 bpm 3270 ctp. BHP 3710.WHP 124 WOB 2.5-3k 01:30 02:30 1.00 10,140 9,530 PROD1 DRILL WPRT P Wiper trip to window 32K PUW,tie in depth to RA marker.0 correction. RBIH 02:30 04:00 1.50 10,140 10,290 PROD1 DRILL DRLG P Drill Ahead-1.53 bpm 3310 ctp. BHP 3720.WHP 80WOB 2.5-3k 04:00 04:45 0.75 10,290 9,540 PROD1 DRILL WPRT P Wiper trip 32K PUW 33k 04:45 05:15 0.50 9,540 10,290 PROD1 DRILL WPRT P Wiper back in hole. RIW 17k 05:15 07:30 2.25 10,290 10,440 PROD1 DRILL DRLG P BOBD 10290 ft-1.53 bpm at 3146 psi.4320 BHP WOB 1.6k ROP 70 fph. 07:30 08:15 0.75 10,440 9,540 PROD1 DRILL WPRT P Wiper trip to the window 9540 ft- PUW 33k. 08:15 08:45 0.50 9,540 10,440 PROD1 DRILL WPRT P Wiper back in hole from 9540 ft- RIW 17k 08:45 10:45 2.00 10,440 10,590 PROD1 DRILL DRLG P BOBD 10440 ft-1.53bpm at 3320psi. BHP 3780.WOB 1.7k, ROP 80fph. 10:45 11:30 0.75 10,590 9,539 PROD1 DRILL WPRT P Wiper trip to the window from 10590 ft-PUW 33k 11:30 11:45 0.25 9,539 9,551 PROD1 DRILL DLOG P Tie into RA-correction of-1 ft. 11:45 12:15 0.50 9,551 10,590 PROD1 DRILL WPRT P Wiper back in hole from 9551ft 12:15 15:15 3.00 10,590 10,740 PROD1 DRILL DRLG P BOBD 10590 ft-1.54 bpm at 3318 FS. BHP 3789.WOB 2.2k,ROP 80 fph 15:15 16:15 1.00 10,740 9,539 PROD1 DRILL WPRT P Wiper trip to window from 10740 ft- PUW 33k 16:15 17:15 1.00 9,539 10,740 PROD1 DRILL WPRT P Wiper back in hole from 17:15 18:00 0.75 10,740 10,890 PROD1 DRILL DRLG P BOBD 10740'-1.54 bpm at 3362 psi FS. BHP 3791,WHP 30 psi.WOB / 1.6k ROP 140 fph ✓ 18:00 19:00 1.00 10,890 9,530 PROD1 DRILL WPRT P Wiper trip 32K PUW 19:00 19:45 0.75 9,530 10,890 PROD1 DRILL WPRT P RBIH 19:45 21:30 1.75 10,890 11,040 PROD1 DRILL DRLG P Drill Ahead-1.54 bpm at 3362 psi FS. 3570 ctp on bottom,BHP 3791, WHP 30 psi. 21:30 22:30 1.00 11,040 9,530 PROD1 DRILL WPRT P Wiper trip to window 33K PUW 22:30 22:45 0.25 9,530 9,530 PROD1 DRILL DLOG P Tie in depth RA marker.-2'correction 22:45 23:30 0.75 9,530 11,040 PROD1 DRILL WPRT P RBIH Page 6 of 20 Time Logs Date From To Dur S.Depth E. Death Phase Code Subcode T Comment 23:30 00:00 0.50 11,040 11,088 PROD1 DRILL DRLG P Drill Ahead-1.54 bpm at 3362 psi FS. 3570 ctp on bottom, BHP 3791, WHP 30 psi. Start sending new mud downhole. 10/13/2012 Continue drilling"A"lateral,performing 1150'wiper trips after 150'drilled,pulling back to the window correlating depth with RA marker every third wiper trip. Mud Losses=50 brls last 24 hrs. 00:00 01:15 1.25 11,088 11,140 PROD1 DRILL DRLG P Cont Drilling 1.54 bpm,3806 ctp, 12k CTVV, 1.8k wob, 01:15 01:45 0.50 11,140 11,190 PROD1 DRILL DRLG P New mud around.Cont. Drilling 1.45 bpm,3702 ctp,92 whp, 3847 bhp, 01:45 02:45 1.00 11,190 10,040 PROD1 DRILL WPRT P Wiper trip 1150'. 02:45 03:15 0.50 10,040 11,190 PROD1 DRILL WPRT P RBIH,3400 free spin 1.5 bpm 03:15 05:27 2.20 11,190 11,340 PROD1 DRILL DRLG P Drill Ahead 1.5 bpm,3580 ctp,82 whp,3793 bhp, 05:27 06:27 1.00 11,340 10,191 PROD1 DRILL WPRT P Wiper trip up to 10191 ft-PUW 33k 06:27 07:00 0.55 10,191 11,340 PROD1 DRILL WPRT P Wiper back in hole from 10191 ft- RIW 17k 07:00 09:30 2.50 11,340 11,490 PROD1 DRILL DRLG P BOBD 11340 ft-1.51 bpm at 3467 FS. BHP 3805.WHP 120. ECD 12.09.WOB 1.5k. ROP 85 fph 09:30 10:45 1.25 11,490 9,525 PROD1 DRILL WPRT P Wiper trip up to 9525 ft. PUW 33k 10:45 11:00 0.25 9,525 9,548 PROD1 DRILL DLOG P Tie into RA Marker correction of-1.5 ft 11:00 12:00 1.00 9,548 11,490 PROD1 DRILL WPRT P Wiper back in hole from 9548 ft. RIW 16k 12:00 13:45 1.75 11,490 11,640 PROD1 DRILL DRLG P BOBD- 1.46 bpm at 3460 psi. BHP 3852.WHP 149.WOB 2k. ROP 105 fph. 13:45 14:45 1.00 11,640 10,488 PROD1 DRILL WPRT P Wiper up to 10488 ft. PUW 33k-15 bbls of mud lost since 0600 this morning. 14:45 15:15 0.50 10,488 11,640 PROD1 DRILL WPRT P Wiper back in hole from 10488 ft- RIW 16k 15:15 18:00 2.75 11,640 11,790 PROD1 DRILL DRLG P BOBD 11640 ft-1.47 bpm at 3487. BHP 3840.WHP 129.WOB 1.6k. ROP 100 fph. 18:00 18:45 0.75 11,790 10,640 PROD1 DRILL WPRT P Wiper trip 1150'back 24 fpm for bottoms up,40 fpm after that. 18:45 19:30 0.75 10,640 11,790 PROD1 DRILL WPRT P RBIH 19:30 21:30 2.00 11,790 11,940 PROD1 DRILL DRLG P Drill Ahead 1.46 bpm,3937 ctp, 3865 bhp, 150 whp, 12.5k ctw. 21:30 22:30 1.00 11,940 9,530 PROD1 DRILL WPRT P Wiper trip back to window 22:30 22:45 0.25 9,530 9,530 PROD1 DRILL DLOG P Tie in depth to RA marker-1' correction 22:45 23:45 1.00 9,530 11,940 PROD1 DRILL WPRT P RBIH 23:45 00:00 0.25 11,940 11,960 PROD1 DRILL DRLG P Drill Ahead 1.46 bpm,3886 ctp,3894 bhp,71 whp, 12.5k ctw. Losses=3 BPH 10/14/2012 Continue drilling"A"lateral,continue 1150'wiper trips after 150'drilled,correlating depth with RA marker every third wiper trip. Mud losses=60 brls last 24 hrs. Perform mud swap. 1730'drilled on old system. Page 7 of 20 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 00:00 01:45 1.75 11,960 12,090 PROD1 DRILL DRLG P Drill Ahead 1.46 bpm,3981 ctp,79 whp, 12k ctw. 01:45 02:30 0.75 12,090 10,940 PROD1 DRILL WPRT P Wiper trip 1150',24 fpm till bottoms up,40 fpm after that 02:30 03:00 0.50 10,940 12,090 PROD1 DRILL WPRT P RBIH 03:00 05:00 2.00 12,090 12,195 PROD1 DRILL DRLG P Drill Ahead 1.46 bpm,3750 fs,3861 ctp,71 whp, 12k ctw,3910 bhp.Geo wants to go up to 6000'TVD @ 90°. 05:00 05:30 0.50 12,195 12,240 PROD1 DRILL DRLG P 12195'. 1.46 bpm at 3620psi FS. BHP 4249. ROP 76 fph.WOB 1.3k Coiled Tubing Weight 11.5k.Geo wants to hold 92° 05:30 06:30 1.00 12,240 11,089 PROD1 DRILL WPRT P Wiper trip up to 11089 ft. PUW 34k 06:30 07:00 0.50 11,089 12,240 PROD1 DRILL WPRT P Wiper back in hole from 11089 ft. RIW 16k 07:00 07:30 0.50 12,240 12,284 PROD1 DRILL DRLG P BOBD-1.45 bpm at 3620 psi FS. WOB 1.4k. ROP 70 fph.Coiled tubing weight 11k.Geo wants to target 93.5° 07:30 09:00 1.50 12,284 12,390 PROD1 DRILL DRLG P OBD-1.46 bpm.WOB 2.6k ROP 100 fph.Waiting to see separation before leveling off. 09:00 10:30 1.50 12,390 9,525 PROD1 DRILL WPRT P Wiper up to 9525 ft. PUW 34k 10:30 10:45 0.25 9,525 9,549 PROD1 DRILL DLOG P 9525 ft-Tie in correction of-3.5 ft. 10:45 11:45 1.00 9,549 12,390 PROD1 DRILL WPRT P Wiper back in hole from 9549 ft. 11:45 13:30 1.75 12,390 12,540 PROD1 DRILL DRLG P BOBD-12390' 1.42 bpm at 3620 psi.BHP 3938 ft.WOB 1.6k.ROP 90 fph. 12k Coiled Tubing Weight. 13:30 14:15 0.75 12,540 11,384 PROD1 DRILL WPRT P Wiper up to 11384 ft. PUW 33k 14:15 14:45 0.50 11,384 12,540 PROD1 DRILL WPRT P Wiper back in hole from 11384 ft RIW 16k 14:45 16:15 1.50 12,540 12,650 PROD1 DRILL DRLG P BOBD-12540 ft 1.42 bpm at 3770 psi FS. BHP 3953.WOB 1.6k.ROP 105 fph.Coiled Tubing Weight 12k. 16:15 16:45 0.50 12,650 12,690 PROD1 DRILL DRLG P OBD-12650 ft.3.6 bph losses a total of 58 bbls. 16:45 17:30 0.75 12,690 11,540 PROD1 DRILL WPRT P Wiper up to 11540' 17:30 18:15 0.75 11,540 12,690 PROD1 DRILL WPRT P RBIH 18:15 20:45 2.50 12,690 12,840 PROD1 DRILL DRLG P Drill ahead 1.42 bpm in, 1.36 out, 10k ctw,4027 ctp,4000 bhp, 20:45 22:30 1.75 12,840 9,530 PROD1 DRILL WPRT P Wiper trip to window 33k puw. ✓ 22:30 22:45 0.25 9,530 9,530 PROD1 DRILL DLOG P Tie in depth to window-4.5' correction 22:45 00:00 1.25 9,530 12,840 PROD1 DRILL WPRT P RBIH 10/15/2012 Continue drilling"A"lateral,continue 1150'wiper trips after 150'drilled,correlating depth with RA marker every third wiper trip. Mud losses=20 brls last 24 hrs. 00:00 00:15 0.25 12,500 12,840 PROD1 DRILL WPRT P Cont RIH Page 8 of 20 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 00:15 01:15 1.00 12,840 12,915 PROD1 DRILL DRLG P Drill ahead 1.42 bpm in, 1.36 out, 10k ctw,4000 ctp,4052 bhp, Swap out Drilling mud 01:15 02:00 0.75 12,915 12,990 PROD1 DRILL DRLG P Cont drilling, 1.42 bpm in, 1.36 out, 3850 ctp,9.6k ctw,3993 bhp, New mud to surface. 02:00 02:45 0.75 12,990 11,840 PROD1 DRILL WPRT P Wiper trip 1150'.32K PUW 02:45 03:30 0.75 11,840 12,990 PROD1 DRILL WPRT P RBIH 03:30 06:45 3.25 12,990 13,140 PROD1 DRILL DRLG P Drill Ahead 1.40 bpm in, 1.38 out, 3709 ctp,wide open choke,8.5k ctw,4026 bhp 06:45 07:30 0.75 13,140 11,947 PROD1 DRILL WPRT P Wiper up to 11947 ft. PUW 33k 07:30 08:00 0.50 11,947 13,140 PROD1 DRILL WPRT P Wiper back in hole from 11947 ft. RIW 13k 08:00 10:30 2.50 13,140 13,232 PROD1 DRILL DRLG P 13140 ft BOBD-1.42 bpm at 3475 psi. BHP 4047.Wide open choke. WHP 22.WOB 1.7k Coiled Tubing Weight 7k. ROP 72 fph. 10:30 10:45 0.25 13,232 12,940 PROD1 DRILL WPRT P Wiper-Lost WOB and motor work. PUH 13238 ft-12940 ft. 10:45 11:00 0.25 12,940 13,232 PROD1 DRILL WPRT P Wiper back in hole from 12940 ft RIW 11k 11:00 13:00 2.00 13,232 13,320 PROD1 DRILL DRLG P 13232 ft BOBD-1.43 bpm at 3506 psi FS. BHP 4024.Open Choke WHP 20.WOB-3k.ROP 6 fph. 13:00 15:00 2.00 13,320 9,525 PROD1 DRILL WPRT P 13320 ft Wiper up to 9525 ft.for tie in. 15:00 15:15 0.25 9,550 9,550 PROD1 DRILL DLOG P 9525 ft-Tie into RA marker correction of-5 ft. 15:15 16:45 1.50 9,550 13,320 PROD1 DRILL WPRT P 9550 ft.Wiper back in hole. RIW 13k 16:45 20:00 3.25 13,320 13,470 PROD1 DRILL DRLG P 13320 ft-BOBD 1.40 bpm at 3575psi FS. BHP 4024.Open Choke WHP 18.WOB 1.9k ROP 75 fph 20:00 21:00 1.00 13,470 12,320 PROD1 DRILL WPRT P 13470 ft-Wiper up to 12320 ft. PUW 33k 21:00 21:30 0.50 12,320 13,470 PROD1 DRILL WPRT P 12320 ft-Wiper back in hole.RIW 13k 21:30 00:00 2.50 13,470 13,574 PROD1 DRILL DRLG P 13470 ft BOBD-1.4 bpm at 3600psi FS. BHP 4103.Open choke.WHP 19.WOB 1.4k. ROP 61 fph 10/16/2012 Drilled to TD of A lateral 13,620'.Wiper trip swabs, RIH and lay in liner pill&KWF. P/U 49 joints of slotted liner for first run. 00:00 01:45 1.75 13,574 13,620 PROD1 DRILL DRLG P Drill ahead 1.4 bpm at 3600psi FS. BHP 4135.Open choke.WHP 19. WOB 1.4k. ROP 61 fph 01:45 02:00 0.25 13,620 13,000 PROD1 DRILL WPRT P Hit hard streak,possible A6/B1 interface. Pump 10brls low/high sweeps.Once at bit, PUH 30k. 1 .0 discuss with town Geo's on calling ZF 02:00 06:15 4.25 13,000 0 PROD1 DRILL WPRT P TD calle•. POOH to swab valves. Page 9 of 20 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06:15 08:15 2.00 0 9,360 PROD1 DRILL WPRT P RBIH 08:15 08:30 0.25 9,360 9,360 PROD1 DRILL DLOG P Tie in depth-19'correction 08:30 08:45 0.25 9,360 13,538 PROD1 DRILL WPRT P Cont RIH to TD.Tag window 20FPM, PU RIH 2nd attempt 08:45 10:45 2.00 13,538 13,538 PROD1 DRILL WPRT P Cont RIH. 12k RIW, Unable to get past 13538'.Multiple attempts lowering pump rate to.75bpm, 10,20,30 fpm. 13500'logs show A6. 10:45 12:45 2.00 13,538 9,375 PROD1 DRILL TRIP P POOH laying liner running pill. (12ppg NaBr,4%lubes with beads) to Tubing Tale. Paint EOP flag 12:45 14:45 2.00 9,375 0 PROD1 DRILL TRIP P POOH laying in KWF(12ppg NaBr, 2%lubes without beads)to surface 14:45 15:15 0.50 0 0 PROD1 DRILL SFTY P At surface, PJSM,Monitor well for no flow. 15:15 16:15 1.00 0 0 PROD1 DRILL PULD P LD BHA 6 16:15 16:45 0.50 0 0 COMPZ CASING PUTB P Prep floor to PU liner,service tongs 16:45 20:45 4.00 0 1,680 COMPZ CASING PUTB P PU"A"liner with 49 joints of 2 3/8" slotted&shorty GS. 20:45 00:00 3.25 1,680 9,800 COMPZ CASING RUNL P RIH Pumping.3bpm EDC closed.Tie in at window-15ft.P/U weight 35K. Clean drift through window. 10/17/2012 Complete all three liner runs.Total liner lenght from 13,528'to top of anchored billet p 10,156'. POOH laying in KWF. 00:00 01:00 1.00 9,800 13,538 COMPZ CASING RUNL P Continue RIH with liner assembly. +5ft depth correction 13,485'. RIH clean to 13,550'. P/U weight 44K, WOB-4.74K. up to 13,500'. RIH pumping 1.3 bpm to 13,538'- POOH quickly P/U weight 33K, WOB-2.3K.Stop pumping after 30ft. BOL=13,538' TOL=11,901' 01:00 05:00 4.00 11,901 44 COMPZ CASING TRIP P Set up to pump down backside while POOH in open hole.Correct depth to 11,820'-POOH.Stop inside window and pump down the coil. EOP flags at 8043'&10,443' 05:00 06:00 1.00 44 44 COMPZ CASING SFTY P Flow check for 30 minutes. PJSM for laying down BHA&rigging up for liner run#2. 06:00 06:30 0.50 0 0 COMPZ CASING PULD P LD BHA 06:30 07:00 0.50 0 0 COMPZ CASING PUTB P Prep floor for running liner 07:00 09:00 2.00 0 0 COMPZ CASING PUTB P PU"A"liner run#2.42 joints of slotted liner 09:00 11:00 2.00 1,444 9,447 COMPZ CASING RUNL P RIH pumping minimum rate.Tie in depth with EOP flag.-3'correction. Cont RIH. Record up and down weights above window 34K up, 19k RIW.Cont RIH clean thru window. Page 10 of 20 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 9,447 11,910 COMPZ CASING RUNL P Tie in depth with EOP flag. Correct depth-3'correction. Come offline with pump. Cont RIH. Record up and down weights above window 34K up, 19k RIW.Cont RIH clean thru window. 12:00 12:06 0.10 11,910 11,850 COMPZ CASING RUNL P -5'correction at second EOP flag. Did not change depth. 11850' Record up weight 40k.-3.4k wob. Cont RIH.Tag 11911'.3.25k wob. Online with pumps 1.3bpm 3450ctp. PU to release off liner.34K puw,Ok wob. 12:06 12:30 0.40 11,850 9,375 COMPZ CASING RUNL P Line up to pump across top. POOH to Tubing Tale. 12:30 13:00 0.50 9,375 9,043 COMPZ CASING DLOG T Line up to pump down CT,Tie in depth to K1 marker.Correct depth -18'correction.TOL-11893'. Paint EOP flag 9043'MD 13:00 15:00 2.00 9,043 0 COMPZ CASING RUNL P Cont.POOH 15:00 15:30 0.50 0 0 COMPZ CASING PULD P At surface.Monitor well for flow for 30 minutes. PJSM for laying down liner. 15:30 16:00 0.50 0 0 COMPZ CASING PULD P LD BHA, 16:00 16:15 0.25 0 0 COMPZ CASING PUTB P Prep floor to PU liner 16:15 19:15 3.00 0 395 COMPZ CASING PUTB P PU 3rd section of liner with 9 joints and 2 pups&anchored billet. 19:15 22:15 3.00 395 10,491 COMPZ CASING RUNL P Rih with EDC open pumping.3bpm. Tie into EOp flag-18ft correction.Tie into K-1 minus 1ft correction. RIH to TD 22:15 22:45 0.50 10,491 10,156 COMPZ CASING RUNL P Tag bottom-P/U weight 37K to 10475'.Orient 20 ROHS. RIH tag bottom again. P/U neutral weight, orient anchor to 20 deg ROHS. Pump and set anchored billet with 2800 psi at 10,156'.Set down 2.5K. POOH. 22:45 00:00 1.25 10,156 7,000 COMPZ CASING TRIP P POOH laying in KWF. 10/18/2012 Completed liner run.Perform BOPE test 250 low/4500 psi high. P/U BHA#10 with.8 AKO&Bi-center bit. KOTB from 10,155'. 00:00 02:00 2.00 7,000 62 COMPZ CASING TRIP P POOH. 02:00 03:30 1.50 62 0 COMPZ CASING PULD P 30 minute flow check.PJSM for laying down the BHA.Lay down BHA. 03:30 05:30 2.00 0 0 PROD2 STK CIRC P Prep rig floor for BOPE test.Circ fresh water into CT string&flush stack.Grease Stack.Pressure test inner reel valve&stripper. 05:30 13:30 8.00 0 0 PROD2 STK BOPE P Start BOPE test.**Witness waived p n by John Crisp** j Page 11 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 16:30 3.00 0 0 PROD2 STK SVRG P Completed BOP test with no failures. Service reel and inj. head,depth counters,MP choke.Swap reel to KWF and install check valves. Calibrate Micro motion meters. 16:30 17:00 0.50 0 0 PROD2 STK SFTY P PJSM 17:00 18:00 1.00 0 0 PROD2 STK PULD P PU BHA 10 with 0.8 AKO 18:00 22:00 4.00 0 10,156 PROD2 STK TRIP P RIH with EDC open.Tie in-20ft.Circ out KWF.Clean drift through window. Stop pumping above billet.Dry tag @ 10,156. P/U weight 35K. 22:00 00:00 2.00 10,155 10,156 PROD2 STK KOST P Stall initial tag @ 10,155.9'-P/0 and mill as per procedure from 10,155.7'. 1.40 bpm, 3256, BHP 3788,Diff 415, ROP 1 fph, 10 LOHS,ECD 12.2,Ct t.` weight 18.7K,WOB 0.28K. � ` Couple of slip stick stalls at start but c2„ / went smooth after 1 ft.Good Al. returns to surface. 10/19/2012 KOTB from 10,156'drill build to 10,345'.P/U RSM BHA and perform mud swap. Drill ahead on AL1 lateral. 00:00 02:30 2.50 10,156 10,190 PROD2 STK KOST P Good Alum returns, 1.45 bpm,3430, BHP 3757, ROP 1 fph,WOB 1K,CT weight 17K. 2 fpm @ 10,157 3 fpm @ 10,158' 15 fpm @ 10,160' Drilling ahead-10, 166'-ROP 66 _ 02:30 03:00 0.50 10,190 10,135 PROD2 DRILL WPRT P Wipe up through billet&dry-drift. Clean. 03:00 07:00 4.00 10,190 10,345 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3500, BHP 3830, ROP 77,WOB 2K,Ct weight 13K. Land Build 10345. 07:00 09:00 2.00 10,345 0 PROD2 DRILL TRIP P POOH 09:00 09:15 0.25 0 0 PROD2 DRILL SFTY P PJSM 09:15 10:45 1.50 0 0 PROD2 DRILL PULD P Undeploy BHA 10 10:45 11:45 1.00 0 0 PROD2 DRILL SFTY P Crew change. PJSM(Nabors crew only) 11:45 12:45 1.00 0 0 PROD2 DRILL PULD P Deploy BHA 11 12:45 15:15 2.50 68 9,360 PROD2 DRILL TRIP P RIH 15:15 15:45 0.50 9,360 9,360 PROD2 DRILL DLOG P Tie in depth to K1.-28'correction. Inspect both counters to assure operating correctly due to inconsistent depth correction.All looks good. 15:45 16:45 1.00 9,360 10,345 PROD2 DRILL TRIP P Close EDC. RIH,swap out drilling mud. 16:45 18:45 2.00 10,345 10,490 PROD2 DRILL DRLG P Drilling ahead 18:45 19:15 0.50 10,490 9,550 PROD2 DRILL WPRT P Wiper trip-P/U weight 32K. Pulled heavy from 10,265-10,248'.Motor work increase as well.Slow POOH speed.Shale returns over shaker. Page 12 of 20 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 19:15 19:45 0.50 9,550 10,490 PROD2 DRILL WPRT P RIH,slow through troubled spot with min rate,clean. P/U through it full rate,P/U weight 32K.clean pass. RIH at 1 bpm,quick sit down at 10,242', lower to.5 bpm,continue to RIH. 19:45 21:15 1.50 10,490 10,640 PROD2 DRILL DRLG P Drilling ahead-1.45 bpm,3580, BHP 3805, ROP 130,WOB 1.2K,Ct _ weight 14K. 21:15 21:45 0.50 10,640 9,600 PROD2 DRILL WPRT P Wiper trip-P/U weight 33K.Seen a little weight bobble at Billet. 21:45 22:15 0.50 9,600 10,640 PROD2 DRILL WPRT P RIH-clean drift through troubled spot. 22:15 23:45 1.50 10,640 10,790 PROD2 DRILL DRLG P Drilling ahead-1.45 bpm,3830,BHP 3810, ROP 145,WOB 1.3K,Ct weight 13K. 23:45 00:00 0.25 10,790 9,535 PROD2 DRILL WPRT P Wiper trip P/U weight 33K with tie. 10/20/2012 Continue drilling on AL1 lateral.Mud swap with 1600'on system. 00:00 01:15 1.25 9,535 10,790 PROD2 DRILL WPRT P 1.5 ft correction on tie in.RIH. 01:15 02:15 1.00 10,790 10,940 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3530, BHP 3840, ROP 155,WOB 1.8K,Ct weight 14K. Heavy oil in sand samples. 02:15 03:15 1.00 10,940 9,550 PROD2 DRILL WPRT P Wiper trip-P/U weight 32K,Speed 38fpm.Small weight bobble at billet, but cleaner than earlier run. 03:15 03:45 0.50 9,550 10,940 PROD2 DRILL WPRT P RIH-clean through Billet 03:45 04:45 1.00 10,940 11,090 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3770, BHP 3880, ROP 150,WOB 2K,Ct weight 11K, ECD 12.3 04:45 05:15 0.50 11,090 10,190 PROD2 DRILL WPRT P Wiper trip P/U weight 32K-wipe up 900' 05:15 05:45 0.50 10,190 11,090 PROD2 DRILL WPRT P RBIH 05:45 06:45 1.00 11,090 11,240 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3750, BHP 3890,ROP 150,WOB 2K,Ct weight 11K, ECD 12.3 06:45 07:15 0.50 11,240 9,513 PROD2 DRILL WPRT P Wiper trip to window 31k puw, 10265-10242 looked good 07:15 07:30 0.25 9,513 9,513 PROD2 DRILL DLOG P Log RA marker-4'correction 07:30 08:15 0.75 9,513 11,240 PROD2 DRILL WPRT P RBIH / 08:15 10:15 2.00 11,240 11,390 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3800, 3899 BHP, ROP 150,WOB 2K,Ct weight 11K, ECD 12.3 10:15 11:15 1.00 11,390 10,340 PROD2 DRILL WPRT P Wiper trip 31k puw.back to 10340' 11:15 11:40 0.42 10,340 11,390 PROD2 DRILL WPRT P RBIH 11:40 12:40 1.00 11,390 11,540 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3800, 3963 BHP, ROP 150,WOB 2K,Ct weight 11K,ECD 12.8 12:40 13:40 1.00 11,540 10,354 PROD2 DRILL WPRT P Wiper trip 31k puw back to 10354' 13:40 14:10 0.50 10,354 11,540 PROD2 DRILL WPRT P RBIH Page 13 of 20 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 14:10 15:22 1.20 11,540 11,690 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3800, 3963 BHP, ROP 150,WOB 2K,Ct weight 11K, ECD 12.8 15:22 16:22 1.00 11,690 9,500 PROD2 DRILL WPRT P Wiper trip back to window 30k puw. Shales looked good 16:22 16:37 0.25 9,500 9,500 PROD2 DRILL DLOG P Log RA marker.-1'correction 16:37 17:29 0.88 9,500 11,690 PROD2 DRILL WPRT P RBIH.Small bobble at billet,.shales looked good. .7bpm 20fpm 17:29 18:59 1.50 11,690 11,840 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3930, 3975 BHP, ROP 100-150,WOB 2K,Ct weight 11K, ECD 12.8 18:59 19:29 0.50 11,840 10,800 PROD2 DRILL WPRT P Wiper trip P/U weight 32K,pull to 10,950' 19:29 19:59 0.50 10,800 11,840 PROD2 DRILL WPRT P RIH 19:59 21:14 1.25 11,840 11,990 PROD2 DRILL DRLG P Drilling ahead-start pumping new mud.Circ pressure dropped from 4080 psi to 3650 psi with new mud. 21:14 21:44 0.50 11,990 10,850 PROD2 DRILL WPRT P Wiper trip-P/U weight 32K. 21:44 22:14 0.50 10,850 11,990 PROD2 DRILL WPRT P RIH 22:14 23:29 1.25 11,990 12,140 PROD2 DRILL DRLG P Drilling ahead-1.45 bpm,3740, BHP 3950,ROP 150,WOB 1.7,Ctweight 12K, ECD 12.8 23:29 23:59 0.50 12,140 10,500 PROD2 DRILL WPRT P Wiper to window with tie in. 10/21/2012 Continue drilling AU lateral.Mud swap with 1190'ft on system. 00:00 00:45 0.75 10,500 9,530 PROD2 DRILL DLOG P Wiper trip Tie in=minus 1.5 ft. 00:45 01:45 1.00 9,530 12,140 PROD2 DRILL WPRT P RIH 01:45 03:00 1.25 12,140 12,290 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3850, BHP 4000, ROP 144,WOB 2K,Ct weight 8K. 03:00 03:30 0.50 12,290 11,190 PROD2 DRILL WPRT P Wiper trip-P/U weight 32K speed 39 fpm 03:30 04:00 0.50 11,190 12,290 PROD2 DRILL WPRT P RIH 04:00 05:00 1.00 12,290 12,440 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3850, BHP 4080, ROP 144,WOB 2K, Ct weight 8K. 05:00 05:45 0.75 12,440 11,280 PROD2 DRILL WPRT P Wiper trip to 11280'34K PUW 05:45 06:15 0.50 11,280 12,440 PROD2 DRILL WPRT P RBIH 06:15 08:15 2.00 12,440 12,589 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3850, BHP 4110,WOB 2K,Ct weight 6K. 08:15 09:45 1.50 12,589 9,532 PROD2 DRILL WPRT P Wiper trip to window 36.5K PUW 09:45 10:00 0.25 9,532 9,532 PROD2 DRILL DLOG P Log RA marker.-4.5'correction 10:00 11:30 1.50 9,532 12,589 PROD2 DRILL WPRT P RBIH 11:30 13:00 1.50 12,589 12,740 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3850, BHP 4130,WOB 2K,Ct weight 6K. 13:00 13:45 0.75 12,740 11,475 PROD2 DRILL WPRT P Wiper trip back to 11475'.31K PUW 13:45 14:15 0.50 11,475 12,740 PROD2 DRILL WPRT P RBIH Page 14 of 20 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 14:15 15:30 1.25 12,740 12,890 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3910, BHP 4135,WOB 1.2K,Ct weight 7-8K. 15:30 16:15 0.75 12,890 11,727 PROD2 DRILL WPRT P Wiper trip back to 11730' 16:15 17:00 0.75 11,727 12,890 PROD2 DRILL WPRT P RBIH 17:00 18:30 1.50 12,890 13,040 PROD2 DRILL DRLG P Drill ahead 1.38 bpm,3900 ctp,4142 bhp,Open choke. 100-130 rop, 1.5k wob,7k ctw, 12.9 ecd. Weight transfer starting to drop off last 40 ft. 18:30 20:00 1.50 13,040 9,520 PROD2 DRILL WPRT P Wipe up to the window P/U weight 33K.Minus 9ft correction. Unloaded a good slug of cutting from B/U. 20:00 21:30 1.50 9,520 13,040 PROD2 DRILL WPRT P RIH,start taking returns to TT for mud swap. 21:30 23:00 1.50 13,040 13,190 PROD2 DRILL DRLG P Drilling ahead-1.38 bpm,4110,BHP 4250, ROP 88,WOB 1.9K,CT weight 1K. 13130-start pumping new mud. 13160-new mud at bit 23:00 23:45 0.75 13,190 11,687 PROD2 DRILL WPRT P Wipe up 1500ft. P/U weight 32K. • New mud fully around. 23:45 00:00 0.25 11,687 12,000 PROD2 DRILL WPRT P RIH 10/22/2012 TD AL1 Lateral 13709'. Pump low/high sweeps, POOH to swab valves.Swap out depth counter on injector head. 00:00 00:30 0.50 12,000 13,190 PROD2 DRILL WPRT P RIH 00:30 01:45 1.25 13,190 13,340 PROD2 DRILL DRLG P Drilling ahead-1.45 bpm,3980, BHP 4100, ROP 105,WOB 1.7K,Ct weight 3.3K. 01:45 02:30 0.75 13,340 11,800 PROD2 DRILL WPRT P Wiper trip P/U 33K. Increase lubes by 1%Lube776&0.5%LoTorq. Total of 3.5%lubes in system. 02:30 03:00 0.50 11,800 13,340 PROD2 DRILL WPRT P RIH 03:00 04:45 1.75 13,340 13,490 PROD2 DRILL DRLG P Drilling ahead-1.45 bpm,3880, BHP 4110, ROP 99,WOB 1.8K,Ct weight 2K.Ct weight dropped off to zero-1 before wiper,still good weight transfer. 04:45 06:30 1.75 13,490 9,530 PROD2 DRILL WPRT P P/U weight 34K.Wiper trip to window with tie in. 06:30 08:00 1.50 9,530 9,360 PROD2 DRILL DLOG T Log RA marker 9530'. During RIH 3 V FPM logging set down 4.5k WOB at 9541'. Shut down pumps PU to log K1 for depth correlation. Inspect counter.Mechanically working. Change out BHI encoder cable.-33' correction after logging K1. 08:00 08:15 0.25 9,360 9,530 PROD2 DRILL DLOG P RIH,Small weight bobble at bottom of window. Have seen this since window milled.log RA marker.0 correction 08:15 10:00 1.75 9,530 13,490 PROD2 DRILL WPRT P RIH to drill 10:00 12:45 2.75 13,490 13,600 PROD2 DRILL DRLG P Drill Ahead 1.35 BHP,3800 CTP, 4125 BHP, 12.9 ECD Page 15 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:45 13:30 0.75 13,600 12,100 PROD2 DRILL WPRT P Wiper trip back 1500'. 12100'. Unable to drill with rib force is enabled. Pull wiper trip 40'early. 13:30 14:15 0.75 12,100 13,600 PROD2 DRILL WPRT P RBIH 14:15 15:15 1.00 13,600 13,700 PROD2 DRILL DRLG P Drill Ahead, 1.42 BPM,4127 CTP, 4165 BHP, 13.5 ECD,-2K CTW,2K WOB,Minimize rib force to cont drilling. 15:15 16:45 1.50 13,700 13,730 PROD2 DRILL DRLG P Stacking, PU-100-200'RBIH trying to get drilling.Slowly making progress. 16:45 17:45 1.00 13,730 13,730 PROD2 DRILL DRLG P CaII TD 13700'. Pump low high sweeps. Recip CT pumping sweeps to bit. 17:45 19:45 2.00 13,730 9,360 PROD2 DRILL WPRT P POOH to K1 19:45 20:30 0.75 9,375 9,431 PROD2 DRILL DLOG T OPen EDC, Log K1 marker-31' correction.Swap out counter on injector head. 20:30 22:45 2.25 9,400 0 PROD2 DRILL WPRT P Cont.to POOH to swab valves 22:45 23:00 0.25 72 69 PROD2 DRILL WPRT P At surface.Tag stripper at 55.98. Reset depth to 68.45'. 23:00 00:00 1.00 69 8,000 PROD2 DRILL WPRT P RBIH 10/23/2012 Condition Hole, Pump beaded liner running pill, POOH M/U BHA#12 58 Jts slotted liner 00:00 01:15 1.25 8,000 9,600 PROD2 DRILL TRIP P RIH.Tie into K1 with-10 ft correction. Tagged window first time 5K, P/U,RIH slid through with a bobble 2K.Tie into RA-zero correction. 01:15 03:30 2.25 9,600 13,709 PROD2 DRILL TRIP P RIH to TD.Tagged bottom @ 13709' P/U weight 35K. Beads are close to bit.cycle pipe. 03:30 08:30 5.00 13,709 68 PROD2 DRILL TRIP P POOH laying in Beads&completion fluid. EOP flags @ 11,600&7400'. Tie into K-1 +3ft correction. POOH. 08:30 10:00 1.50 68 0 PROD2 DRILL PULD P Flow check and hold PJSM for laying down BHA. Lay down BHA,service injector. 10:00 14:30 4.50 0 1,984 COMPZ CASING PUTB P Start P/U liner assembly with 58 joints of slotted liner.Safety joint drill,3 minutes. 14:30 17:30 3.00 1,984 9,550 COMPZ CASING RUNL P RIH with EDC closed pumping.3 bpm.Minus 12 ft correction at flag. Shut down pumps, P/U weight-36K. RIH clean through window 17:30 18:54 1.40 9,550 13,717 COMPZ CASING RUNL P RIH to TD pumping.3 bpm.,Tag �• bottom @ 13717,PUW=42K. Pumps on @ 1.28 BPM, PUW=33K Liner released, P - obi '- • '.• - Estimat' OL=11,777, BOL=13717 18:54 20:00 1.10 13,717 9,500 COMPZ CASING TRIP P Trip out t• • - e L - - 20:00 20:42 0.70 9,500 7,643 COMPZ CASING DLOG P Log RA marker for+2.5', Remove liner length left in hole Page 16 of 20 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 20:42 22:36 1.90 7,643 52 COMPZ CASING TRIP P Trip to surface pumping 12PPG completion fluid, Paint EOP flag @ 7600 22:36 23:48 1.20 52 0 COMPZ CASING PULD P At surface,flow check well, PJSM, Lay down liner running BHA#12, Prep floor for liner run 23:48 00:00 0.20 0 155 COMPZ CASING PUTB P P/U BHA#13, Ported Bullnose,52 Jts slotted liner and shorty deployment sleeve, Held safety joint drill,4 Min 10/24/2012 Completed AL1 Liner ops with Anchored Billet @ 9770, Perform BOPE function test. 00:00 02:30 2.50 155 1,740 COMPZ CASING PUTB P Continue to make up BHA#13, Ported Bullnose,52 Jts Slotted, shorty deployment sleeve 02:30 03:30 1.00 1,740 1,785 COMPZ CASING PULD P Liner run#2 in well, PJSM,Pick up coil track and make up to deployment sleeve, RIH and position to strip on with injector,Surface test tool 03:30 05:30 2.00 1,785 9,394 COMPZ CASING RUNL P RIH, EDC Shut, Pump min rate 05:30 05:36 0.10 9,396 9,385 COMPZ CASING DLOG P Correct to 7600'EOP Flag for-11' P/U weight 36K 05:36 07:06 1.50 9,385 11,779 COMPZ CASING RUNL P Trip in to tie in+1.5ft. P/U weight 42K-RIH toTD 07:06 07:21 0.25 11,779 10,038 COMPZ CASING RUNL P Set down to 11,779' WOB 2K,Bring pumps up ease liner. OL=11,779' TOL=10,038' 07:21 09:51 2.50 10,038 42 COMPZ CASING TRIP P • completion fluid. 09:51 11:06 1.25 42 0 COMPZ CASING PULD P Flow check, Lay down BHA.PJSM for P/U liner assembly. 11:06 13:06 2.00 0 268 COMPZ CASING PUTB P PJSM P/U liner-7 joints of slotted,3 (i Ny �,� pups&anchored billet. P/U coiltrac f`�k assembly 13:06 16:06 3.00 268 9,400 COMPZ CASING RUNL P RIH with EDC open pumping.3 bpm. minus 12 ft correction. P/U weight 35K.Close EDC 16:06 16:51 0.75 9,400 10,038 COMPZ CASING RUNL P RIH-tagged up @ 9560'-P/U • weight 36K, P/U 30'-RIH saw small weight bobble @ 9525'-continue RIH. 16:51 17:21 0.50 10,038 9,770 COMPZ CASING RUNL P Tag TOL @ 10,038'Set down 2.5k. P/U weight 37K RIH tag again. P/U to neutral weight-Set 3100 psi-170 g:<< /1'1d ROHS.Set down 3K. ZQB 9770'+ 17:21 19:45 2.40 9,770 55 COMPZ CASING TRIP P POORraying in completion fluid. 19:45 20:45 1.00 55 0 COMPZ CASING PULD P At surface, Flow check well. PJSM lay down BHA on dead well 20:45 21:03 0.30 0 0 PROD3 STK BOPE P Function test BOPE 21:03 22:15 1.20 0 72 PROD3 STK PULD P PJSM, P/U BHA#15,0.7 degree motor and RR Bi Center bit,M/U to coil and surface test tool 22:15 00:00 1.75 72 6,650 PROD3 STK TRIP P Trip in well, EDC open Page 17 of 20 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 10/25/2012 24 hr Summary Kick off LTB @ 9770', Drill Ahead to 10544 00:00 00:36 0.60 6,650 9,380 PROD3 STK TRIP P Continue trip in well 00:36 00:54 0.30 9,380 9,418 PROD3 STK DLOG P Log K-1 marker,-16 foot correction 00:54 01:00 0.10 9,418 9,490 PROD3 STK TRIP P Trip into just above window to roll well back to Flo Pro 01:00 02:30 1.50 9,490 9,490 PROD3 STK CIRC P Roll well to 8.8 PPG Flo Pro 02:30 03:00 0.50 9,490 9,770 PROD3 STK TRIP P Shut EDC,PUW=33K, RIH to drill off billet,clean pass through window 03:00 04:06 1.10 9,770 9,771 PROD3 STK KOST P Dry tag billet @ 9770, PUH,Pumps on 1.4 BPM @ 3625,See motor work @ 9770.3,Start time milling off billet, 140 ROHS, 1 FPM 04:06 05:30 1.41 9,771 9,775 PROD3 STK KOST P Go to 2 FPH, No stalls, 1.4 BPM @ 3500 PSI FS,BHP=3840, Blow down drilling choke.kick off,drill down to Ai N°21 9811'.puh and drift billet clean. a. 05:30 07:15 1.75 9,775 9,920 PROD3 DRILL DRLG P Drill ahead to 9811'. PUH&drift billet clean. Drill ahead 1.36 BPM @ 3600 PSI drill to 9920.0 07:15 08:00 0.75 9,920 9,920 PROD3 DRILL WPRT P Wiper up 34k off btm.wipe up to window. 08:00 11:00 3.00 9,920 10,070 PROD3 DRILL DRLG P Drill ahead to 10070' 11:00 11:45 0.75 10,070 10,070 PROD3 DRILL WPRT P Wiper Trip,35.5k off btm.wiper to window. 11:45 13:45 2.00 10,070 10,220 PROD3 DRILL DRLG P Drill ahead, 1.41 BPM @ 3700 PSI, BHP 3934. Drill to 10220' 13:45 15:00 1.25 10,220 10,220 PROD3 DRILL WPRT P Wiper up 36k off btm.wipe up to window. 15:00 18:54 3.90 10,220 10,370 PROD3 DRILL DRLG P Drill ahead 1.38 BPM @ 3850 PSI. BHP 3929 18:54 19:42 0.80 10,370 10,370 PROD3 DRILL WPRT P 10370',Wiper to window PUW=34K, BHP=3980 19:42 22:18 2.60 10,370 10,520 PROD3 DRILL DRLG P 10370', Drill Ahead, 1.4 BPM @ 3750 PSI FS, BHP=3977, RIW=16K 22:18 23:18 1.00 10,520 10,520 PROD3 DRILL WPRT P 10520',Wiper to window, PUW=35K, BHP=3995 23:18 23:59 0.69 10,520 10,544 PROD3 DRILL DRLG P 10520', Drill Ahead, 1.38 BPM @ 3700 PSI FS,BHP=4010, RIW=16K Midnight dEPTH 10544 10/26/2012 TD AL2 Lateral @ 10970',Condition hole, Kill Well 00:00 02:18 2.30 10,544 10,670 PROD3 DRILL DRLG P Drill Ahead 02:18 02:54 0.60 10,670 9,530 PROD3 DRILL WPRT P Wiper trip to window with tie, PUW=35K, BHP=4045 02:54 03:00 0.10 9,530 9,549 PROD3 DRILL DLOG P Log RA Marker for+2'correction 03:00 03:33 0.55 9,549 10,670 PROD3 DRILL WPRT P Continue wiper back to bottom,clean trip past billet and clear to bottom 03:33 05:18 1.75 10,670 10,820 PROD3 DRILL DRLG P 10670', Drill Ahead, 1.35 BPM @3650 PSI FS, BHP=4047 05:18 06:48 1.50 10,820 9,600 PROD3 DRILL WPRT P Wiper to window, PUW=35.5K RIH. Page 18 of 20 Time Logs Date _ From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:48 11:18 4.50 10,820 10,970 PROD3 DRILL DRLG P Drilling ahead-1.35 bpm,4050, BHP 4080, ECD 12.8, ROP 15,WOB 2.7K. Pump sweeps prior to TD 11:18 14:48 3.50 10� 72 PROD3 DRILL WPRT P TD Well-yViper trip to Swab valves. P/U weight34K.Cuttings increase 1800'from surface. 14:48 16:48 2.00 72 9,380 PROD3 DRILL TRIP P Reset depth coutner at surface-RIH. Tie in- 16:48 17:00 0.20 9,380 9,397 PROD3 DRILL DLOG P Tie into K-1 for-23'correction 17:00 18:06 1.10 9,397 10,970 PROD3 DRILL TRIP P Continue trip in hole,tag TD @ 10970,circulate liner running pill down hole 18:06 21:06 3.00 10,970 42 PROD3 DRILL TRIP P Trip out of well laying in beaded liner running pill 12 PPG followed by completion fluid, Paint EOP flags @ 9200 and 7800' 21:06 22:18 1.20 42 0 PROD3 DRILL PULD P At surface, Flow check well,PJSM pull BHA#15 from dead well 22:18 23:18 1.00 0 0 COMPZ CASING PUTB P Rig up floor to run liner, PJSM to pick up tubing 23:18 00:00 0.70 0 400 COMPZ CASING PUTB P M/U BHA#16 AL2 Liner with non ported bullnose, 1-9.82'pup,42 jts 2 3/8"slotted liner,6 CS/H 511,2 3/8" solid and shorty deployment sleeve 10/27/2012 Run AL2 Liner to TD, Freeze Protect well. N2 Reel blowdown, RDMO, Rig Release©24:00 00:00 01:42 1.70 400 1,600 COMPZ CASING PUTB P P/U AL2 liner,perform Safety joint drill, R/D floor from liner ops 01:42 02:42 1.00 1,600 1,652 COMPZ CASING PULD P PSJM,P/U Coil track tools,stab onto liner,space out into well and secure with deployment rams,Make up coil and surface test tools. Strip onto well, 02:42 06:27 3.75 1,652 10,970 COMPZ CASING RUNL P RIH, EDC Shut.Tie in-23ft.RIH Tag bottom.+2ft on TD flag. 06:27 06:42 0.25 10,970 9,361 COMPZ CASING RUNL P P/U weight 41K WOB-9K. Pick up 20 feet-RIH set down 3K @ 10,966'. Bring pumps online P/U weight 33K, WOB-3_4 L (�` cOL=10,97 OL=9361' 06:42 08:00 1.30 9,332 9,332 COMPZ CASING CIRC P Sit and circ out KWF with SW. Review procedure for freeze protecting well. Hi-line crew on location.Switch to generator power prior to circulating out well. 08:00 09:30 1.50 9,332 3,000 COMPZ CASING TRIP P POOH Pumping SW followed by diesel.Recover Completion fluid then take SW&diesel returns to Tiger tank. 09:30 11:00 1.50 3,000 52 COMPZ CASING TRIP P Freeze protect well from 3000'- surface.900 psi on tubing,taking returns to Tiger tank. 11:00 13:00 2.00 52 0 COMPZ CASING PULD P PJSM-undeploy BHA Page 19 of 20 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 13:00 15:00 2.00 0 0 DEMOB WHDBO CTOP P Stab injector over the well&start pumping corrosion inhibitor.30 fresh/30 corrssion/30 fresh.Stop pumping. 15:00 15:30 0.50 0 0 DEMOB WHDBO CTOP P PJSM with SLB N2.Set up valves and purge CT string. Put 5 gallon of methanol prior to N2 into reel. 15:30 16:30 1.00 0 0 DEMOB WHDBO CTOP P Start pumping LN2- 1500 scfs for 12-14 minutes.Total of 21,000 scfs pumped.Shut down. 16:30 17:30 1.00 0 0 DEMOB WHDBO CTOP P Bleed down reel and blow down lines. 17:30 19:30 2.00 0 0 DEMOB WHDBOOTHR P PJSM-Rig up to install BPV. Rig down BPV lubricator 19:30 21:00 1.50 0 0 DEMOB WHDBO OTHR P Blow down stack and putz, 21:00 00:00 3.00 0 0 DEMOB WHDBO NUND P Nipple down BOPE,MP line, R/D SSSV remote panel, remove fusable. Lift and secure BOPE Rig Release Midnight Page 20 of 20 21- 11 Post-Rig Well Work Summary DATE SUMMARY 11/1/12 TAGGED LINER TOP @ 9361' RKB, MEASURED BHP @ 9300' RKB, SET AVA CATCHER @ 9381' SLM, PULLED DV& REPLACED w/OV @ 7483' RKB, PULLED DV @ 4930' RKB. IN PROGRESS. 11/2/12 SET GLV @ 4930' RKB. PULLED DV& REPLACED w/GLV @ 2122' RKB. PULLED CATCHER SUB @ 9381'SLM. COMPLETE. Iram BAKER PRINT DISTRIBUTION LIST HUGHES COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes (mandatory) WELL NAME 2F-11A RUN NUMBER (mandator FIELD Kuparuk BH SALESMAN Woods,Jim (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: October 16,2012 TODAYS DATE: 11/15/20.12 (mandato DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY D FIELD FINAL (digital ital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #OF PKIN I5 #OF COPIES #OF COPIES v v v v L v 1 ConocoPhillips Alaska,Inc. 1 NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC 1 1 Christine Mahnken- 2.2b ( 0 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3 BP — I 1 1 Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP I 1 1 I Glenn Fredrick ' 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 — 5 Brandon Tucker,NRT I I 1 I 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 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 2../3 Letter of Transmittal FARM BAKER Date: RECEIVD October 29, 2012 HUGHES OCT 31201 To: From: AOGCC 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): 2F-11A • .e 2F-11AL1 2,1 ?‘ 1 a 9 2F-11AL2 t 3 DAA •4U1/1-- tAJ/I-10 • X ' )-:R (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files I Note: Please feel free to send us an email in place of return mail. Sachin Gandra, Baker Hughes, Project Engineer Sachin.Gandra@BakerHughes.com Carl.Ulrich, Baker Hughes, SurveyManager g g Carl.Ulrich@BakerHughes.com Sli TN) SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W 7th AVENUE,SUITE 100 CONSERVATION COMDIISSION 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, 2F-11A ConocoPhillips Alaska, Inc Permit No: 212-128 Surface Location: 154'FNL, 1450' FEL, SEC. 33, T11N, RO9E,UM Bottomhole Location: 2263' FSL, 4937' FEL, SEC. 2, T1ON, RO9E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re-drill the above referenced development 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, Cathy P. oerster Chair, Commissioner DATED this Ay of September, 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 AUG 2 3 2012 PERMIT TO DRILL Alaska Oil& Gas Cons. Commission 20 AAC 25.005 A., la.Type of Work: • lb.Proposed Well Class: Development-Oil 2 • Service-Winj ❑ Single Zone ❑ . 1c.Specify ifikaat1Qfi ged 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 U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 , 2F-11A 3.Address: 6.Proposed Depth 12.Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 13500' ' TVDSS: 6000' • Kuparuk River Field 4a Location of Well(Governmental Section): 7 Property Designation(Lease Number): Surface: 154'FNL, 1450'FEL,Sec.33,T11N, RO9E, UM ADL 25657,25665, I...7.. (c' Kuparuk River Oil Pool - Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date 4591'FNL, 1116'FEL,Sec.34,T11N,RO9E,UM 2583,2586 V'2�'/L 10/15/2012 Total Depth: 9.Acres in Property 14.Distance to r 2263'FNL,4937'FEL,Sec.2,T10N, RO9E, UM 2560 Nearest Property. 5750 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: . 125 feet 15.Distance to Nearest Well Open Surface:x- 517782 ' y- 5948729 ' Zone- 4 GL Elevation above MSL: 92 feet to Same Pool. 2E-09,980 ' 16.Deviated wells: Kickoff depth' 9500 - ft. 17.Maximum Anticipated Pressures in psig(see 20 AAc 25 035) Maximum Hole Angle: 94' deg Downhole:4862 psig ' Surface:4272 psig • 18 Casing Program. Specifications Top - Setting Depth -Bottom Cement Quantity,c f.or sacks Hole Casing Weight Grade Coupling Length MD TVDSS MD TVDSS (including stage data) • 3" 2.375" 4.7# L-80 ST-L 3600 9900' 5968' 13500' 6000' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft) Effective Depth ND(ft): Junk(measured) 10160 6488 10047 6404 Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 225 sx CS II 110' 110' Surface 3781' 9.625" 1050 sx AS III,780 sx Class G 3810' 2860' Intermediate Production 10108' 7" 350 sx Class G,250 sx AS I 10137' 6471' Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 9376-9378,9451-9464,9506-9508,9543-9564,9585-9618,9630-9640 5923-5924,5972-5980,6009-6010,6035-6049,6064-6087,6096-6103 20 Attachments Property Plat❑ BOP Sketch 2 Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Dnlling Fluid Program Q 20 AAC 25.050 requirements Q 21 Verbal Approval: Commission Representative. Date: 22. I hereby certify that the foregoing is true and correct. Contact James Ohlinger @ 265-1102 Printed Name L. Gantt Title CTD Supervisor Signature �e...oltak sAc4a44Phon 263-4021 Date c, / / Commission Use Only Permit to Drill �7�? API Number Permit Appro7I See cover letter .2..1Number I 2- 12- ! > 50-02_ct—21( /�C/— Date: #/ii i 2. for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed thane,gas hydrates,or gas contained in shales [i I S�I'1;t i3i) I /emsf ,s Samples req'd: Yes ❑ No Mud log req'd: Yes El No [3' Other: H2S measures: Yes d No ❑ Directional svy req'd: Yes [ No ❑ / /�� APP OVED BY THE COMMISSION DATE:Ci / COMMISSIONER � � Form 10-401 (Revised 7/2009) This permit is valid for 2 n fLe e�of+ap� I(20 C 25.005(g)) Submit in Duplicate ���' ConocoPhillips Alaska UcECEI P.O.BOX 100360 ���2012 ANCHORAGE,ALASKA 99510-0360 AUG 2 Alaska Oil 3 August 22,2012 Anchorage as Cons, Comn1iSSlpn Commissioner- State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permits to drill a tri-lateral out of the Kuparuk Well 2F-11 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin in mid-October 2012. The CTD objective will be to drill tri-laterals (2F-11A, 2F- 11A L1, and 2F-11AL2), targeting the A sand intervals. The original NC-sand perforations will have been cemented off before CTD operations commence, as per Sundry 312-240. Attached to this application are the following documents: — Permit to Drill Application Form for 2F-11A,2F-11A L1, and 2F-11AL2 — Detailed Summary of Operations . — Proposed Schematic — Directional Plans If you have any questions or require additional information please contact me at 907-265-1102. Sincerely, o�James J. Ohlinger Coiled Tubing Drilling Engineer • NABORS ALASKA Kuparuk CTD Laterals 0.8% 2F-11A, 2F-11AL1and 2F-11AL2 Application for Permit to Drill Document 2AC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 3 (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information and Reservoir Pressure 3 (Requirements of 20 AAC 25.005(c)(4)) 3 5. Procedure for Conducting Formation Integrity tests 3 (Requirements of 20 AAC 25.005(c)(5)) 3 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 4 (Requirements of 20 AAC 25.005(c)(7)) 4 8. Drilling Fluids Program 4 (Requirements of 20 AAC 25.005(c)(8)) 4 9. Abnormally Pressured Formation Information 5 (Requirements of 20 AAC 25.005(c)(9)) 5 10. Seismic Analysis 5 (Requirements of 20 AAC 25.005(c)(10)) 5 11. Seabed Condition Analysis 5 (Requirements of 20 AAC 25.005(c)(11)) 5 12. Evidence of Bonding 5 (Requirements of 20 AAC 25.005(c)(12)) 5 13. Proposed Drilling Program 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations 5 Pressure Deployment of BHA 6 Liner Running 7 14. Disposal of Drilling Mud and Cuttings 7 (Requirements of 20 AAC 25.005(c)(14)) 7 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Quarter Mile Injection Review(for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Attachments 7 Attachment 1: Directional Plans for 2F-11A,2F-11A L1, and 2F-11AL2 7 Attachment 2: Current Well Schematic for 2F-11 7 Attachment 3: Proposed Well Schematic for 2F-11A, 2F-11A L1, and 2F-11AL2 7 Page 1 of 7 I p 8/22/2012 PTD Application: 2F-11A, 2F-11AL1, and 2F-11AL2 1. Well Name and Classification (Requirements of 20 AAC 25.005(t) and 20 AAC 25.005(b)) The proposed laterals described in this document are 2F-11A, 2F-11AL1, and 2F-11AL2. All three of these laterals will be classified as"Development'wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This wellbore is planned to be a lateral targeting the A sand package in the Kuparuk reservoir. Location at Surface 154' FNL, 1450' FEL, Sec 33, T11N, RO9E, UM NAD 1927 RKB Elevation 125 AMSL Northings: 5,948,729 ' Eastings: 517,782 Pad Elevation 92 AMSL iF-1IA Location at Top of Productive Horizon 4591' FNL, 1116' FEL, Sec 34, T11N, RO9E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 9,900' Northings: 5,944,308 Eastings: 523,416 Total Vertical Depth, SS: 5,968' Location at Total Depth 2263' FNL, 4937' FEL, Sec 2, T10N, RO9E, UM NAD 1927 Measured Depth, RKB: _ 13,500' Northings: 5,941,361 Eastings: 524,889 Total Vertical Depth, SS: 6,000' 2F-11AL1 Location at Top of Productive Horizon 4570' FNL, 1161' FEL, Sec 34, T11N, RO9E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 9,850' Northings: 5,944,329 Eastings: 523,371 Total Vertical Depth, SS: 5,968' Location at Total Depth 2296' FNL, 5002' FEL, Sec 2, T10N, RO9E, UM NAD 1927 Measured Depth, RKB: 13,500' Northings: 5,941,328 Eastings: 524,824 Total Vertical Depth, SS: 5,979' 2D-05L1-02 Location at Top of Productive Horizon 4373' FNL, 1416' FEL, Sec 34, T11N, RO9E, UM (Kuparuk) NAD 1927 Measured Depth, RKB: 9,503' Northings: 5,944,525 Eastings: 523,115 Total Vertical Depth, SS: 5,881' Location at Total Depth 5151' FNL, 421' FEL, Sec 34, T11N, RO9E, UM NAD 1927 Measured Depth, RKB: 10,805' Northings: 5,943,750 Eastings: 524,114 Total Vertical Depth, SS: 6,006' Page 2 of 7 8/22/2012 PTD Application: 2F-11A, 2F-11AL1, and 2F-11AL2 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4700 psi. (Using the maximum pressure in the area of 4862 psi, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 4272 psi. See the"Drilling Hazards Information and Reservoir Pressure" section for more details.) — The annular preventer will be tested to 250 psi and 2500 psi. — 2F-11 currently has an FMC Gen II wellhead with 3000 psi working pressure. It will be refitted with a `' new 5000 psi modified tubing head adapter and tree. 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)) A static bottom hole pressure of 2F-11 in June 2012 indicated a reservoir pressure of 2173 psi or 7.1 ppg ,,. equivalent mud weight. The maximum downhole pressure in the 2F-11 pattern is at injector 2F-14 with 4862 psi. It is not expected that reservoir pressure as high as 2F-14 well will be encountered while drilling the 2F-11 laterals because of offset distance and faulting. Using the 2F-14 pressure as the maximum possible in 2F- 11,the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 4272 psi. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; however, 2F pad did have some wells on miscible gas injection (MI) in 2009, so encountering MI gas is a possibility. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 2F-11 laterals will be crossing a fault into an over pressurized reservoir block. The surrounding injectors have been shut in to bring the reservoir pressure down. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(1), thru-tubing drilling operations need not perform additional formation integrity tests. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 2F-11A 9900' 13500' 5968' 6000' 23/", 4.7#, L-80, ST-L slotted liner; • aluminum billet on top. 2%", 4.7#, L-80, ST-L slotted liner; • 2F-11AL1 9850' 13500' 5968' 5979' aluminum billet on top. 2F-11AL2 9503' 10805' 5881' 6006' 2%", 4.7#, L-80, ST-L slotted liner; deployment sleeve on top. Page 3 of 7 8/22/2012 s,,, tt °: .. PTD Application: 2F-11A, 2F-11AL1, and 2F-11AL2 Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62.55 H-40 Welded 30' 110' 0' 110' 1640 630 Surface 9-5/8" 36.0 J-55 BTC 29' 3810' 0' 2856' 3520 2020 Casing 7" 26.0 J-55 BTC 29' 10137 0' 6461' 4980 4330 Tubing 3-1/2 " 9.3 J-55 EUE 8rd-mod 24' 9374' 0' 5910' 6,990 7400 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System 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(8.8 ppg) — Drilling operations: Chloride-based Flo-Pro Flo Vis mud (8.8 ppg). While this mud weight may hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 2F-11 does not contain a subsurface safety valve (SSSV). The well will be loaded with 12.0 ppg Sodium Bromide completion fluid in order to maintain managed pressure on open reservoir while running completions. — Emergency Kill Weight fluid: Two well bore volumes(-237 bbl) of 13.1 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. In this situation, a"wellbore volume" is defined as the tubing volume plus the volume of the longest lateral. 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 providing an overbalance on the reservoir. Through experience with drilling CTD laterals in the Kuparuk sands, 11.8: ppg has been identified as the minimum EMW to ensure stability of shale sections. Since this well is proposed as an infield development candidate in an actively water flooded field, expected reservoir pressures can be difficult to estimate. In this case, however, a constant BHP of 11.8 ppg will be initially targeted at the window based on the recent static bottom hole pressure. The constant BHP target will be adjusted to maintain overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 4 of 7 ORIGIN,1\- , L 8/22/2012 PTD Application: 2F-11A, 2F-11AL1, and 2F-11AL2 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 2F-11 is a Kuparuk A-sand/C-sand production well equipped with 31/2"tubing and 7"production casing. Three proposed A-sand CTD laterals will increase reservoir exposure and probe_the southern periphery of 2F pad. Prior to drilling,the existing perfs in 2F-11 will be squeezed with cement to provide a means to kick out of the 7"casing. A cement retainer will be set above a known obstruction in the casing. between the A and C sand perforations. The A-sand perforations will be permanently abandoned by bullheading cement through the retainer and the C-sand perfs will be squeezed above the retainer. After plugging off the existing perfs with cement,a pilot hole will be drilled through the cement to top of cement retainer.A mechanical whipstock will be set in the pilot hole at the planned kickoff point. The 2F-11A A sidetrack will exit the 7"casing at 9503' MD and will target the upper A4 sand south of the existing well with a 4000' lateral. The hole will be completed with a 2%" slotted liner to the TD of 13,500' MD with an aluminum billet at 9900' MD. The 2F-11AL1 lateral will kick off from the aluminum billet at 9900' MD and will target the A5 sand above the L I first lateral with a 3650' lateral. The hole will be completed with a 2%" slotted liner to the TD of 13,500' MD with an aluminum billet at 9850' MD. The_2F-11AL2 lateral will kick off from the aluminum billet at 9850' MD and will target the lower A4 sand L'7-- below below the first lateral with an 955' lateral. The hole will be completed with a 2%" slotted liner to the TD of 10,805' MD with the final liner top located just inside the 31/2"tubing at 9360' MD. Pre-Rig Work (As per Sundry 312-240) 1. RU slickline. Install dummy GLV's. Load &test IA and OA 2. Perform injectivity test. 3. RU e-line. Perf holes in 3'/"tubing tail at 9354'MD. RD e-line. 4. RU coil. Mill out D-nipple at 9361'to 2.80" ID. Page 5 of 7 8/22/2012 PTD Application: 2F-11A, 2F-11AL1, and 2F-11AL2 5. RU coil. Set inflatable cement retainer in 7"@ 9530' MD. Squeeze A-sand perfs with cement thru retainer. Un-sting from retainer, squeeze C-sand perfs above retainer. Leave cement top at 9345' MD above tubing tail perfs. RD coil. 6. RU slickline. Tag top of cement, test to 1500 psi. RD slickline. 51Z-- Z'LL( • Notify inspector 24 hours prior 7. Prep site for Nabors CDR2-AC, including setting BPV it 241"C Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16" BOPE, test. 2. 2F-11A Sidetrack(upper A4 sand, south) a. Drill 2.80" high-side pilot hole through cement to 9530' MD'. b. Drift pilot hole with whipstock dummy - Set whipstock at 9503' MD with high-side orientation. � d. Mill 2.80"window at 9503' MD. 1 e. Drill 2.70"x 3"bi-center lateral to TD of 13,500' MD • f. Run 2%"slotted liner with an aluminum billet from TD up to 9900' MD 3. 2F-11AL1 Lateral (A5 sand, south) a. Kick off aluminum billet at 9900' MD b. Drill 2.70"x 3"bi-center lateral to TD of 13,500' MD c. Run 2%"slotted liner with an aluminum billet from TD up to 9850' MD 4. 2F-11AL2 Lateral (Lower A4 sand, south) a. Kick off of the aluminum billet at 9850' MD b. Drill 2.70"x 3" bi-center lateral to TD of 10,805' MD c. Run 2%"slotted liner from TD up to 9360' MD, up inside the 3W tubing tail 5. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Put well on production 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 listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during deployment the de to ment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Page 6 of 7 R t AL 8/22/2012 PTD Application: 2F-11A, 2F-11AL1, and 2F-11AL2 Liner Running — The 2F-11 CTD laterals will be displaced to an overbalancing fluid (12 ppg Na-Br) prior to running liner. 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 23/" rams will provide secondary well control while running 2%"liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) — No annular injection on this well. — 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)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to Nearest Property Line(measured to KPA boundary at closest point) Lateral Name Distance 2F-11A 5750 ' 2F-11 AL1 5700 2F-11AL2 8025 — Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Well 2F-11A 980 2E-09 2F-11AL1 1050 2E-09 2F-11AL2 2050 2E-13 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) N/A-Application is not for a"Service"well. 17. Attachments Attachment 1: Directional Plans for 2F-11A, 2F-11AL1, and 2F-11AL2 Attachment 2: Current Well Schematic for 2F-11 Attachment 3: Proposed Well Schematic for 2F-11A, 2F-11AL1, and 2F-11AL2 Page 7 of 7 8/22/2012 ORIGINAL KUP 2F-11 ConocoPhillipc.s Well Attributes Max Angle&MD TD Ala ')f Wellbore API/UWI Field Name Well Status Incl(') MD(MB) Act Btm(MB) ska. l<,,,n„ „Il,p, 500292109500 KUPARUK RIVER UNIT PROD 61.30 5,900.00 10,160.0 Comment H2S(ppm) Date Annotation End Date KBGrd(R) Rig Release Date ••• Well Conte.2F-11,3/2/20128:19:50 AM SSSV:TRDP_ 45 10/5/2011 Last WO: 33.01 4/10/1984 Schematic-Actual Annotation Depth(MB) End Date Annotation Last Mod By End Date Last Tag:SLM 988.0 2/24/2012 Rev Reason:TAG ninam 3/2/2012 Casing Strings HANGER,24 Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd I CONDUCTOR 16 15.062 30.0 110.0 110.0 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 SURFACE 95/8 8.921 29.3 3,810.0 2,855.6 36.00 J-55 BTC Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd PRODUCTION 7 6.276 29.0 10,137.2 6,460.5 26.00 J-55 BTC I F Tubing Strings Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd - ' TUBING 31/2 2.992 23.8 9,374.0 5,910.0 9.30 J-55 EUE8RD Completion Details Top Depth (TVD) Top Incl Need... Top(RKB) (MB) 1°) Rem Description Comment ID(in) __ 23.8 23.8 -0.09 HANGER FMC GEN II TUBING HANGER 3.500 2,009.9 1,834.5 46.02 SAFETY VLV BAKER FVL SAFETY VALVE '2.810 7,483.0 4,829.3 59.00 GASLIFT MMH FMHO 2.875 coNouroR.0-110_ 9,330.2 5,882.3 51.38 PBR BAKER PBR 3.000 _ 9,343.9 5,891.1 50.88 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 9,361.0 5,901.9 50.24 NIPPLE CAMCO D NIPPLE NO GO 2.750 SAFETY VLV f, 9,372.5 5,909.1 49.82 SOS VANN GUN RELEASE 2.992 2.010 1.,�,p Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (TVD) Top Incl Top(RKB) (RKB) (°) Description Comment Run Date ID(in) GAS LIFT, _ 9,757 6,179.3 42.30 FISH 5"Vann Gun 272.67 long 5/4/1984 2,122 Perforations&Slots Shot 0 (TVD)Top(TVD) Btm Dena Top(MB)Btm(RKB) MKS) (RKB) Zone Date (sh... Type Comment 9,376 9,378 5,911.3 5,912,6 Lower Kalubik, 4/30/1984 4.0 SQZ'd Squeezed;4"Dresser Atlas 2J -411 SURFACE, 9,451 9,464 5,961.0 5,969.7 C-4,2F-11 12/23✓1987 8.0 APERF 2 1/8"EnerJet z9-3,a10 9,506 9,508 5,998.5 5,999.8 UNIT B,2F-11 4/30/1984 4.0 SQZ'd Squeezed;4"Dresser Atlas GAS LIFT, _ _ 9,543 9,564 6,024.4 6,039.1 A-5,2F-11 5/4/1984 4.0(PERF 5"Geo Vann Tubing G 4,931 9,585 9,618 6,053.9 6,076.5 A-4,2F-11 5/4/1984 4.0 IPERF 5"Geo Vann Tubing G �.- 9,630 9,640 6,085.4 6,092.8'A-4,2F-11 5/4/1984 4.0 IPERF 5"Geo Vann Tubing G GASLIFT,7,483f C Cement Squeezes Top Depth Btm Depth (TVD) (TVD) _c Top(RKB)elm(MB) MKS) (RKB) Description Start Date Comment Gns912 s 9,376.0 9,378.0 5,911.3 5,912.6 Cement Squeeze 4/30/1984 9,506.0 9,508.0 5,998.5 5,999.8 Cement Squeeze 4/30/1984 Notes:General&Safety iEnd Date Annotation �_. 7/16/2007 NOTE:ELINE CALIPER VERIFIED HISTORICAL TIGHT SPOT @ 9600',POSSIBLE CSG DMG PBR,9,330 --- ___ 7/28/2007 NOTE:TREE IS ONLY RATED FOR 3000PSI PACKER,9,344 s.. �^<.� 8/8/2009 NOTE:ENCOUNTERED OBSTRUCTION @ 6400'SLM Ir10/12/2010 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE,9,301 11 Ik r SOS,9.372 1 7{ SO2d,_ 111 9,3769,378 _ - Cement,9,376 APERF, 8,451-9,484 Sold, r 9,5069,508 Cement,9,506 PERF, ■ . 9,5439,564 IPERF, II . Mandrel Details 9,585-9,618 Top Depth Top Port (TVD) Inel OD Valve Latch Size TRO Run Stn Top(ftKB) (RKB) el Make Model (in) Sery Type Type lin) (psi) Run Date Com... IPERF, ■ III 2,122.4 1,914.0 58.08 MMH FMHO 1 GAS LIFT GLV BK 0.156 1,351.0 9/10/2001 9,630.9,640 2 4,931.0 3,516.2 53.66 MMH FMHO 1 GAS LIFT GLV BK 0.156 1,325.0 9/10/2001 3 7,483.0 4,829.3 59.00 MMH FMHO 1 GAS LIFT GLV BK 0.188 1,338.0 9/10/2001 FISH,9,757 1. 4 9,288.2 5,856.3 52.94 MMH FMHO 1 GAS LIFT OV BK 0.250 0.0 9/10/2001 PRODUCTION, CO 2 co N ✓ Q in 2 co o_O V Q O pp`` C ....O V Q �M- coE J 2 of Q o .- 11 E vL.1.�.a 2. ti ,-- n N N I-Q N- N N OF J N_ a) N U - o I I v u (0 u `7 O cn C _ C c C 0 a) m 0al 0 .43N = - n Y Q n W I- M V a`)a o O co V C p m 0 CO p 'rn o_ 0 O e0 O NI 0) C N co `-'..0 qq‘ © (�l N O lJ W v Q'(�� ] Q O J 2 co a) - O - U_ O U a5 in 11 LL. //��1� N Y7 N H J N OU LJ Q O O m ,pOpp`` as (') al m = (d o 2 V C CO rn U [L L_ U o o ai N N N a) a) N '2 'uoi p . / Y �C _ a _O / a3 a7 C N co co r) CO CO c7 E A - nCo O i.;.--? O 7 N O. I I— I dill/i/21111 iiili ri' ii i CZ i\ , ;,CJ E m c .. U ii 0 C...) 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I �q o }. aW.■/� a : , ,.. aaaau■Wa■e/aaB ; = I I gWW/a■'■ I i/W /WBS/ r— -- ---- --Y-- N/ ! -- — --- - f o $$$ $ I {o ii :a�m I � . W I m�ii 8 IIIIIIMIfflinllinI -- o i.Waa/■WW — ..a -T' } Na111 EIWISIEMBI:---t ILI: .WW .... - . + ■• N��: 1 C. aam ■WW :i��im��i i ::i S : iim:� + :ii I .0 W iWW _i■ i.__-_ WW I _ __-_1- N o ,- .: {:. 1 '' V .... .... ....�.. ....J:... o. b. ..�.:.. �... rrr Id .1- b -. 0 0 N Nc g o T o oP. _ 8ngO o ^ 7 7 N , Tc' Y v `4 r ' v Cl (uTof Eb+ o ) noS ConocoPh i l l i s Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2F Pad 2F-11 2F-11A Plan: 2F-11A_wp03 Standard Planning Report 03 July, 2012 BAKER HUGHES ORU3I -0-' ConocoPhillips or its affiliates VC" ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-11 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level • Project: Kuparuk River Unit MD Reference: 2F-11 @ 125.00ft • Site: Kuparuk 2F Pad North Reference: True Well: 2F-11 Survey Calculation Method: Minimum Curvature Wellbore: 2F-11A Design: 2F-11 A_wp03 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 2F Pad Site Position: Northing: 5,949,341.83ft Latitude: 70°16'21.978 N From: Map Easting: 517,392.55ft Longitude: 149°51'33.576 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.13° Well2F-11 Well Position +N/-S 0.00 ft Northing: 5,948,728.56 ft ' Latitude: 70°16'15.937 N +E/-W 0.00 ft Easting: 517,781.64 ft - Longitude: 149°51'22.289 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 92.00ft • Wellbore 2F-11A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 8/1/2012 16.11 79.88 57,366 Design 2F-11A_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,500.00 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (ft) (ft) (ft) (°) -92.00 0.00 0.00 150.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 9,500.00 46.76 135.62 5,879.75 -4,215.27 5,322.28 0.00 0.00 0.00 0.00 9,503.00 46.68 135.56 5,881.80 -4,216.83 5,323.81 3.04 -2.67 -2.00 -151.39 9,524.00 49.62 135.56 5,895.81 -4,228.00 5,334.76 14.00 14.00 0.00 0.00 9,624.00 69.62 135.56 5,946.13 -4,289.28 5,394.85 20.00 20.00 0.00 0.00 9,748.73 90.00 120.86 5,968.20 -4,364.20 5,490.85 20.00 16.34 -11.79 323.00 9,950.00 90.00 112.81 5,968.20 -4,454.96 5,670.30 4.00 0.00 -4.00 270.00 10,550.00 90.00 136.81 5,968.20 -4,794.94 6,159.37 4.00 0.00 4.00 90.00 10,900.00 86.29 123.30 5,979.57 -5,019.50 6,426.45 4.00 -1.06 -3.86 254.50 11,450.00 86.56 145.34 6,014.26 -5,400.63 6,816.76 4.00 0.05 4.01 90.00 11,650.00 89.40 152.82 6,021.31 -5,571.96 6,919.37 4.00 1.42 3.74 69.40 12,150.00 89.44 172.82 6,026.45 -6,047.22 7,066.27 4.00 0.01 4.00 90.00 12,450.00 90.03 184.81 6,027.85 -6,346.60 7,072.46 4.00 0.20 4.00 87.20 12,650.00 94.02 191.75 6,020.78 -6,544.24 7,043.71 4.00 2.00 3.47 60.00 13,300.00 89.69 166.09 5,999.38 -7,188.20 7,056.03 4.00 -0.67 -3.95 261.00 13,500.00 89.69 174.09 6,000.46 -7,385.05 7,090.41 4.00 0.00 4.00 90.00 7/3/2012 2:41:11 PM Page 2 COMPASS 2003.16 Build 69 ' ConocoPhillips or its affiliates ,�'f ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-11 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2F-11 @ 125.00ft Site: Kuparuk 2F Pad North Reference: True Well: 2F-11 Survey Calculation Method: Minimum Curvature Wellbore: 2F-11A Design: 2F-11 A_wp03 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N1-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 9,500.00 46.76 135.62 5,879.75 -4,215.27 5,322.28 6,311.67 0.00 0.00 5,944,526.29 523,113.33 TIP 9,503.00 . 46.68 135.56 5,881.80 -4,216.83 5,323.81 6,313.79 3.04 -151.39 5,944,524.74 523,114.86 KOP 9,524.00 49.62 135.56 5,895.81 -4,228.00 5,334.76 6,328.93 14.00 0.00 5,944,513.60 523,125.841 3 9,600.00 64.82 135.56 5,936.84 -4,273.49 5,379.36 6,390.63 20.00 0.00 5,944,468.22 523,170.55 9,624.00 69.62 135.56 5,946.13 -4,289.28 5,394.85 6,412.05 20.00 0.00 5,944,452.46 523,186.07' 4 9,700.00 81.97 126.39 5,964.78 -4,337.32 5,450.41 6,481.43 20.00 -37.00 5,944,404.56 523,241.74 9,748.73 90.00 120.86 5,968.20 -4,364.20 5,490.85 6,524.93 20.00 -34.73 5,944,377.78 523,282.23 5 9,800.00 90.00 118.81 5,968.20 -4,389.70 5,535.32 6,569.25 4.00 -90.00 5,944,352.39 523,326.76 9,900.00 90.00 114.81 5,968.20 -4,434.78 5,624.56 6,652.91 4.00 -90.00 5,944,307.52 523,416.10 9,950.00 90.00 112.81 5,968.20 -4,454.96 5,670.30 6,693.26 4.00 -90.00 5,944,287.45 523,461.88 Start RSM 10,000.00 90.00 114.81 5,968.20 -4,475.14 5,716.04 6,733.61 4.00 90.00 5,944,267.38 523,507.67 10,100.00 90.00 118.81 5,968.20 -4,520.23 5,805.28 6,817.27 4.00 90.00 5,944,222.51 523,597.00 110,200.00 90.00 122.81 5,968.20 -4,571.43 5,891.15 6,904.55 4.00 90.00 5,944,171.51 523,682.99 110,300.00 90.00 126.81 5,968.20 -4,628.50 5,973.25 6,995.02 4.00 90.00 5,944,114.65 523,765.21 10,400.00 90.00 130.81 5,968.20 -4,691.15 6,051.16 7,088.24 4.00 90.00 5,944,052.18 523,843.26 10,500.00 90.00 134.81 5,968.20 -4,759.09 6,124.51 7,183.75 4.00 90.00 5,943,984.43 523,916.77 10,550.00 90.00 136.81 5,968.20 -4,794.94 6,159.37 7,232.22 4.00 90.00 5,943,948.66 523,951.70 7 10,600.00 89.47 134.88 5,968.43 -4,830.81 6,194.19 7,280.70 4.00 -105.50 5,943,912.88 523,986.61 10,700.00 88.40 131.02 5,970.30 -4,898.92 6,267.36 7,376.27 4.00 -105.49 5,943,844.95 524,059.93 10,800.00 87.34 127.16 5,974.01 -4,961.92 6,344.91 7,469.60 4.00 -105.42 5,943,782.14 524,137.62 10,900.00 86.29 123.30 5,979.57 -5,019.50 6,426.45 7,560.24 4.00 -105.28 5,943,724.75 524,219.29 8 11,000.00 86.30 127.30 5,986.03 -5,077.15 6,507.87 7,650.88 4.00 90.00 5,943,667.30 524,300.841 11,100.00 86.33 131.31 5,992.46 -5,140.36 6,585.07 7,744.22 4.00 89.74 5,943,604.28 524,378.18 11,200.00 86.37 135.32 5,998.82 -5,208.81 6,657.67 7,839.80 4.00 89.48 5,943,536.01 524,450.93 11,300.00 86.44 139.33 6,005.09 -5,282.17 6,725.31 7,937.15 4.00 89.23 5,943,462.82 524,518.74 11,400.00 86.52 143.33 6,011.24 -5,360.08 6,787.66 8,035.80 4.00 88.98 5,943,385.06 524,581.27 11,450.00 86.56 145.34 6,014.26 -5,400.63 6,816.76 8,085.46 4.00 88.73 5,943,344.59 524,610.46 9 11,500.00 87.27 147.21 6,016.95 -5,442.15 6,844.48 8,135.28 4.00 69.40 5,943,303.14 524,638.27 11,600.00 88.69 150.95 6,020.48 -5,527.87 6,895.81 8,235.18 4.00 69.30 5,943,217.55 524,689.81 11,650.00 89.40 152.82 6,021.31 -5,571.96 6,919.37 8,285.15 4.00 69.17 5,943,173.51 524,713.46 10 11,700.00 89.40 154.82 6,021.84 -5,616.83 6,941.42 8,335.03 4.00 90.00 5,943,128.70 524,735.62 1 11,800.00 89.40 158.82 6,022.88 -5,708.74 6,980.77 8,434.30 4.00 89.98 5,943,036.90 524,775.18 11,900.00 89.41 162.82 6,023.92 -5,803.16 7,013.61 8,532.49 4.00 89.94 5,942,942.56 524,808.24 12,000.00 89.42 166.82 6,024.95 -5,899.65 7,039.78 8,629.14 4.00 89.90 5,942,846.14 524,834.64 12,100.00 89.43 170.82 6,025.95 -5,997.73 7,059.16 8,723.77 4.00 89.85 5,942,748.12 524,854.25 112,150.00 89.44 172.82 6,026.45 -6,047.22 7,066.27 8,770.18 4.00 89.81 5,942,698.66 524,861.47 11 12,200.00 89.53 174.82 6,026.90 -6,096.92 7,071.65 8,815.91 4.00 87.20 5,942,648.97 524,866.97 12,300.00 89.73 178.82 6,027.54 -6,196.74 7,077.20 8,905.14 4.00 87.18 5,942,549.17 524,872.75 i 12,400.00 89.93 182.81 6,027.84 -6,296.71 7,075.78 8,991.00 4.00 87.16 5,942,449.21 524,871.57 12,450.00 90.03 184.81 6,027.85 -6,346.60 7,072.46 9,032.55 4.00 87.14 5,942,399.32 524,868.371 12 7/3/2012 2:41:11 PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates F/,- ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-11 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2F-11 @ 125.00ft Site: Kuparuk 2F Pad North Reference: True Well: 2F-11 Survey Calculation Method: Minimum Curvature Wellbore: 2F-11A Design: 2F-11 A_wp03 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map 1 Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 12,500.00 91.03 186.54 6,027.39 -6,396.35 7,067.51 9,073.16 4.00 60.00 5,942,349.56 524,863.54 12,600.00 93.03 190.01 6,023.85 -6,495.23 7,053.13 9,151.60 4.00 60.02 5,942,250.66 524,849.39 12,650.00 94.02 191.75 6,020.78 -6,544.24 7,043.71 9,189.33 4.00 60.14 5,942,201.63 524,840.09 13 12,700.00 93.70 189.77 6,017.41 -6,593.24 7,034.40 9,227.11 4.00 -99.00 5,942,152.61 524,830.90 12,800.00 93.06 185.81 6,011.51 -6,692.12 7,020.87 9,305.99 4.00 -99.13 5,942,053.71 524,817.60 12,900.00 92.40 181.86 6,006.74 -6,791.77 7,014.18 9,388.93 4.00 -99.37 5,941,954.06 524,811.15 13,000.00 91.73 177.92 6,003.13 -6,891.68 7,014.37 9,475.56 4.00 -99.56 5,941,854.16 524,811.581 13,100.00 91.06 173.98 6,000.69 -6,991.38 7,021.44 9,565.43 4.00 -99.70 5,941,754.48 524,818.881 13,200.00 90.37 170.03 5,999.44 -7,090.38 7,035.35 9,658.12 4.00 -99.79 5,941,655.53 524,833.02 13,300.00 89.69 166.09 5,999.38 -7,188.20 7,056.03 9,753.18 4.00 -99.84 5,941,557.77 524,853.92 14 13,400.00 89.69 170.09 5,999.92 -7,286.02 7,076.65 9,848.21 4.00 90.00 5,941,460.00 524,874.78 13,500.00 89.69 174.09 6,000.46 • -7,385.05 7,090.41 9,940.85 4.00 89.98 5,941,361.01 524,888.77 TD at 13500.00 7/3/2012 2:41:11 PM Page 4 COMPASS 2003.16 Build 69 ORIGINAL v.' ConocoPhillips or its affiliates FS' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-11 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2F-11 @ 125.00ft Site: Kuparuk 2F Pad North Reference: True Well: 2F-11 Survey Calculation Method: Minimum Curvature Wellbore: 2F-11A Design: 2F-11A_wp03 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 2F-11A_T1 0.00 0.00 5,967.00 -4,354.49 5,478.56 5,944,387.46 523,269.93 70°15'33.091 N 149°48'42.889 W -plan misses target center by 1.99ft at 9733.06ft MD(5967.84 TVD,-4355.96 N,5477.53 E) -Point 2F-11A_T2 0.00 0.00 5,968.00 -4,785.21 6,190.64 5,943,958.46 523,982.95 70°15'28.849 N 149°48'22.181 W -plan misses target center by 29.39ft at 10564.81ft MD(5968.22 TVD,-4805.68 N,6169.55 E) -Point 2F-11A_T5 0.00 0.00 5,999.00 -7,214.47 7,058.00 5,941,531.50 524,855.96 70°15'4.950 N 149°47'57.013 W -plan misses target center by 4.19ft at 13326.12ft MD(5999.52 TVD,-7213.60 N,7062.07 E) -Point 2F-11A_T4 0.00 0.00 6,028.00 -6,347.28 7,007.05 5,942,398.48 524,802.96 70°15'13.480 N 149°47'58.471 W -plan misses target center by 65.11ft at 12457.14ft MD(6027.84 TVD,-6353.72 N,7071.84 E) -Point 2F-11A_T3 0.00 0.00 6,014.00 -5,402.79 6,831.26 5,943,342.47 524,624.96 70°15'22.770 N 149°48'3.560 W -plan misses target center by 10.77ft at 11459.82ft MD(6014.84 TVD,-5408.71 N,6822.31 E) -Point 2F-11 CTD Polygon 0.00 0.00 125.00 -4,381.85 5,210.46 5,944,359.47 523,001.92 70°15'32.824 N 149°48'50.690 W -plan misses target center by 5758.24ft at 9500.00ft MD(5879.75 TVD,-4215.27 N,5322.28 E) -Polygon Point 1 125.00 -4,381.85 5,210.46 5,944,359.47 523,001.92 Point 2 125.00 -4,092.41 5,465.16 5,944,649.48 523,255.91 Point 3 125.00 -4,576.60 6,392.13 5,944,167.53 524,183.93 Point 4 125.00 -5,163.02 6,981.84 5,943,582.56 524,774.97 Point 5 125.00 -5,880.72 7,251.20 5,942,865.57 525,045.99 Point 6 125.00 -6,839.48 7,103.97 5,941,906.56 524,901.04 Point 7 125.00 -7,370.60 7,133.75 5,941,375.57 524,932.08 Point 8 125.00 -7,822.63 7,126.70 5,940,923.57 524,926.09 Point 9 125.00 -7,797.79 6,764.72 5,940,947.55 524,564.09 Point 10 125.00 -7,284.59 6,699.90 5,941,460.54 524,498.07 Point 11 125.00 -6,856.45 6,657.89 5,941,888.54 524,455.05 Point 12 125.00 -5,952.56 6,744.99 5,942,792.54 524,540.01 Point 13 125.00 -5,306.55 6,336.44 5,943,437.52 524,129.97 Point 14 125.00 -4,550.13 5,325.08 5,944,191.48 523,116.93 Point 15 125.00 -4,381.85 5,210.46 5,944,359.47 523,001.92 2F-11A_T6 0.00 0.00 5,992.00 -7,543.29 6,973.21 5,941,202.51 524,771.96 70°15'1.717 N 149°47'59.488 W -plan misses target center by 197.10ft at 13500.00ft MD(6000.46 TVD,-7385.05 N,7090.41 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name ( ) (") 3,810.00 2,735.34 9 5/8" 9-5/8 12-1/4 13,500.00 6,000.46 2-3/8" 2-3/8 3 7/3/2012 2:41:11 PM Page 5 COMPASS 2003.16 Build 69 ORIGINAL N.- ConocoPhillips or its affiliates Irg' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-11 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2F-11 @ 125.00ft Site: Kuparuk 2F Pad North Reference: True Well: 2F-11 Survey Calculation Method: Minimum Curvature Wellbore: 2F-11A Design: 2F-11 A_wp03 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 9,500.00 5,879.75 -4,215.27 5,322.28 TIP 9,503.00 5,881.80 -4,216.83 5,323.81 KOP 9,524.00 5,895.81 -4,228.00 5,334.76 3 9,624.00 5,946.13 -4,289.28 5,394.85 4 9,748.73 5,968.20 -4,364.20 5,490.85 5 9,950.00 5,968.20 -4,454.96 5,670.30 Start RSM 10,550.00 5,968.20 -4,794.94 6,159.37 7 10,900.00 5,979.57 -5,019.50 6,426.45 8 11,450.00 6,014.26 -5,400.63 6,816.76 9 11,650.00 6,021.31 -5,571.96 6,919.37 10 12,150.00 6,026.45 -6,047.22 7,066.27 11 12,450.00 6,027.85 -6,346.60 7,072.46 12 12,650.00 6,020.78 -6,544.24 7,043.71 13 13,300.00 5,999.38 -7,188.20 7,056.03 14 13,500.00 6,000.46 -7,385.05 7,090.41 TD at 13500.00 7/3/2012 2:41:11PM Page 6 COMPASS 2003.16 Build 69 1 1 ci 1i O P 0 O O 8 O 1 c, O kidO m O h �o O O 8 w ¢ o m pp N g O 0. - 00 .-i ` N .1 ryf a O Cf am, N O m N O \ I N Gt o' L m O 1 F o V O II ia, [ br� O 1 I , N \ I 1 I / T C. 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These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER�/ CHECKLIST / WELL NAME E( PTD# 2-1 l Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: /d..)-e-2-POOL: /-L-POOL: �-�c L �cr� t ( '/ ( Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT 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 0 (/) 0) 0 a) a - U a) a I O m L @ O T.) € a Q . c L u - c c , a0, • , c: • O' 3 T O e • • • • • • • • c 6 a 0 Q g: ti o.: c 0 Cs- C O) C '- a), L -2 .0. C: O ,, 0) v o ° 22Vcuw yt' 2,, ' ..c(0020m i::: CO 0 cd, p vip • = $ u a) 0 WZ C �: C, N � O. C U N > COc. •3 j= 3 wLL ` ; E ._0 ° cQya) E m � Nco. 0)v' a •a, C. C. N. y, 0, y. c0 10 y. 0 N, E' a 7 .5 .aa, 172-: 0.In x c O: L: y, U -- CO a. 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