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212-096
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 b direct inspection of the file. i c - aqi,, Well History Ile Identifier Organizing (done) Two-sided ❑ Rescan Needed RES AN: OVERSIZED: NOTES: for Items: ❑ M s: Grayscale Items: ogs: E Poor Quality Originals: ❑ Other: ❑ Other: BY: Maria Date: f i (2..5-1/Li- is, niP Project Proofing I BY: Alllift Date: 1 I a�51/ I4- /s/ }Me Scanning Preparation a x 30 = (p 0 + ,,Q, Li- = TOTAL PAGES V ql- c2� (Count does not include cover sheet) BY: Mg' Date: I / /s/ Production Scanning L Stage 1 Page Count from Scanned File: 1.S (Count does include cov sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: #111!. Date: I II a 1I/f /s/ vvif 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 .E a) n o m c o C ca 0 o m -Tii a) ..m� as..-E aa) /Q/'Q .1Q c ty p ,x Z Z Z co It 1• Z 0 --- CO a, m -E .0 E0 E m > >- >- `11 U Q) 2 0- N p) a a 0) a m m'. ? N N I C a)Cd O 7 C o v O O C� O= c y y 4 y Oay . 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N z W N N U Q11 N 0 Z a a J_ U QZ i � Y , m c iial J a O w a `_ CL J_ I W = IX a O U W z J U . o Z Q r+ tH d 7 ii J a Tu C M CL • coo O 0 N Vo ti v J a Q z A N 1 5r I—Z r E.N n W a' n N ,\ CO ct a ° Q a Yg ` a> 1 Q o a E O m U I 411 Z `' 3 gib..•I M H o ° m c N_ 3 N I 0 c Ce 0 2• / C A d E EE ° o o a I 2 O I 0 STATE OF ALASKA AL A OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon ❑ Repair w ell r Rug Perforations ❑ Stimulate ❑ Other Convert Oil Prod. Alter Casing r Pull Tubing r Perforate New Pool r Time 6ttension Waiver to WINJ Change Approved Program r Operat.Shutdown r Perforate r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development pj Exploratory ❑ 212-096-0 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-21580-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL-25521,25512 3N-11 AL1 9.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10.Present Well Condition Summary: Total Depth measured 11336 feet Plugs(measured) None true vertical 6366 feet Junk(measured) None Effective Depth measured 8682 feet Packer(measured) 0 true vertical 6560 feet (true vertucal) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115' SURFACE 4518 9.625 4558 3631.7 PRODUCTION 8746 7 8777 6465 LINER AL1 1611 2.7 11336 6366 Perforation depth: Measured depth: Top 9,737 Btm 9,770Top 9,790 Btm 11,336 True Vertical Depth: Top 6,440.4 Btm 6,434.5Top 6,431.6 Btm 6,365.8 Tubing(size,grade,MD,and ND) 3.5, L-80, 8173 MD,6199 TVD Packers&SSSV(type,MD,and ND) 11.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 55 33 1447 300 114 Subsequent to operation 0 0 5022 420 2193 13.Attachments 14.Well Class after work: Copies of Logs and Surveys run Exploratory f j Development ❑ Service j Stratigraphic 15.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X 1 GSTOR ❑ WINJ J WAG r GINJ r SUSP r SPLUG r 16.I hereby certify that the foregoing is true and correct to the best of my knowledge. .%Sundry Number or N/A if C.O.Exempt 312-374 Contact Darrell Humphrey/Bob Christensen Email n1139Ca conocophillips.Com I Printed Name Darrell Humphrey/Bob Christensen Title Production Engineering Specialist Signature 1 Phone:659-7535 Date -4_,....1x. .c.________ _r_i Form 10-404 Revised 10/2010 6 / 3 / 0 Submit Original Only/1 1•3 1' 3N-11AL1 N DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/14/12 Commenced Seawater Injection 11/22/12 STATE WITNESSED MITIA(PASSED @ 2900 PSI) KUP 3N-11AL1 ConocoPhillips ° Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APSUWI Field Name Well Status Incl Ii MD(RKB) Act Btm(ORB) Cora URYllips 500292158060 KUPARUK RIVER UNIT PROD 9952 9880.48 11,335.0 Comment H2S(ppm) Date Annotation End Date KB,Grd(R) Rig Release Date ' SSSV:TRDP Last WO: 1/12/2012 39.49 4/13/1986 Well Conan:DEVIATED_3N-11 AL1,10/11/2012 3.44.07 PM Schematic-Acuai Annotation Depth(kKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:GLV C/O ninam 10/11/2012 HANGER,24 Casing Strings ICasing Description String 0... String ID...Top(ORB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd • LINER AL1 23/8 1.992 9,725.1 11,336.0 4.70 L-80 STL Liner Details Top Depth (TVD) Top Incl Nora.. Top(RKB) (RKB) (°) Item Description Comment ID(In) = 9,725.1 6,441.0 96.40 BILLET ANCHORED BILLET 1.000 CONDUCTOR, El9,992.4 6,403.2 93.79 DEPLOY SHORTY DEPLOYMENT 1.900 3&115 Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) — Top Depth SAFETY ALV, _ j, (TVD) Top Incl 1,798 'W Top(kKB) (Odd) (°) Description Comment Run Date ID(In) 9,725 6,441.0 96.40 WHIPSTOCK ANCHORED BILLET FOR AL2 8/8/2012 1.000 .7_ Perforations&Slots GAS LIFT, j Shot 2,908 1 Top(TAD) Btm(TVD) Dens Top(RKB)Btm(RKB) (RKB) (ORB) Zone Date (oh••• Type _ Comment r 9,737 9,770 6,440.4 6,434.5 8/7/2012 32.0 SLOTS ll 9,790 11,336 6,431.6 6,365.8 • 8/7/2012 32.0 SLOTS 11 ' Notes:General&Safety SURFACE. _.JL End Date__ Annotation 35-4.558 8/21/2012 NOTE:WELL SIDTRACKED,ADDED LATERALS AL1,AL2,AL2-01,AL3(See Multi-lat Drawing) L 8/21/2012 NOTE:LATERAL 3N-11AL1 OFF 3N-11Al2(See Multi-lat Drawing) GAS LFT — H 5 C__ GAS LFT, 6,571 GAS LIFT, 7.524 I MI GAS LIFT, 8.052 IIIII NIPPLE,8,081 MI MIN IIII LOCATOR. MN 8,128 SEAL A8,153SSY, WLEO.8.173- PE , Ell II.8,42A0d,4RF35 WHIPSTOCK, 8,470 SCAB LINER, 8,130$625 PRODUCTION. _41. A\ 308,777 FISH,8,790 --11 Mandrel Details Top Depth Top Port (TVD) Incl 0D Valve Latch Size TRO Run WHIPSTOCK, 9,725 b. Stn Top(ORB) MKS/ (°) Make Model (in) Sery Type Type On) (psi) Run Date Com... 16, 1 2,907.9 2,491.0 46.34 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 SLOTS, 2 5,099.0 4,001.6 46.28 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 10/8/2012 9,737-9,770 3 6,570.7 5,055.9 42.98 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 4 7,523.7 5,741.2 45.23 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 5 8,052.1 6,113.3 45.23 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 2/102012 SLOTS. 0li 9,790-11,338 = TD(3N-HALT), -. _ 11,335 LINER AL1. 9.725-11,336 w\,71�y� s THE STATE Alaska Oil and Gas °ALASKA Conservation Commission GOVERNOR SEAN PARNELL��,� • 333 West Seventh Avenue Oja"+ „••- �. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Darrell Humphrey _ 0 L Production Engineering Specialist a, t i 9 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N-11AL1 Sundry Number: 312-374 Dear Mr. Humphrey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, (I; /944,-)44A--- Cathy P Foerster Chair DATED this 1 day of October, 2012. Encl. STATE OF ALASKA ciiik. Y P <A OIL AND GAS CONSERVATION COMA ION ' APPLICATION FOR SUNDRY APPROVALS 10 20 MC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well fl Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown 0 Re-enter Susp.Well 0 StimulateAlter casing g r Other:Convert Oil Prod.to WINJ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Development Exploratory r 212-096-0 3.Address: Stratigraphic r Service 0 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-21580-60 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: R E D E 1`/ D where ownership or landownership changes:r` ‘a2/2FdrL G Spacing Exception Required? Yes No r' 3N-11AL1 P -1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL-25521,25512 Kuparuk River Field/Kuparuk River Oil Pool n/'� 11. PRESENT WELL CONDITION SUMMARY /"//��10GCC Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 11336 6366 8682' 6560' Casing Length Size MD ND Burst Collapse CONDUCTOR 79' 16 115' 115' SURFACE 4,518' 9 5/8 4,558' 3,632' PRODUCTION 8,746' 7 8,777' 6,465' LINER AL1 1,611' 2 3/8 11,336' 6,366' PerforationDepth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Top 9,737 Btm 9,770 Top 6,440.4 Btm 6,434.5 3 1/2 Top 9,790 Btm 11,336 Top 6,431.6 Btm 6,365.8 L-80 8173 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) BAKER C2 ZXP LINER TOP PACKER 8,130.2 MD - 6,168.5 ND 1 CAMCO TRMAXX-CMT-5-SR SAFETY VALVE 1,796.3 MD - 1,730.8 ND 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/1/2012 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ [.,7 GINJ r WAG r Abandoned r Commission Representative: GSTOR 0 SPLUG t 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Darrell Humphrey/Bob Christensen Printed Name Darrell Humphrey/Bob Christensen Title: Production Engineering Specialist 1 Signature ' > lJjPhone:659-7535 Date ct- LS- I Z_. Co mission Use Only Sundry Number:31 2 2J.// Conditions of approval: Notify Commission so that a representative may witness ✓11 `r Plug Integrity 0 BOP Test r Mechanical Integrity Test i Location Clearance 0 Other: Subsequent Form Required: /40 —(ye�,/ / �,^6- / APPROVED BY Approved by: G ` 114 Lic--— COMMISSIONER THE COMMISSION Date: /11 Form 10-403 Revi ed 1/2010 7/4840 .5-'/L r AI Submit in Duplicate DMS OCT102� R1tJlI\ii— 6 � 1 3N-11AL1 • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 3N-11A and its associated laterals from Oil Production service to Water Injection service. The CTD Permit to Drill (which added multi-laterals AL1, AL2, AL2-01, AL3)was completed with the well as an injection well, but the completion report was filed as an oil producer to allow for extended pre-production. The pre-production period following CTD operations has now been completed and the well is being prepared for initial water injection. _ KUP 3N-11AL1 • ConocoPhillips tr a wadi Di. Well Attributes Max Angle&MD TD • A18S1(a In(' Wellbore API/UWI Field Name Well Status Incl ll MD(RKB) Act Btm(ftKB) 500292158060 KUPARUK RIVER UNIT PROD 99.52 9,880.48 11,335.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date --- Well Coned:-3N-71AL18I1120122'S3'16 PM SSSV:TRDP Last WO: 1/12/2012 39.49 4/13/1986 schematk-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:GLV C/O ninam 9/11/2012 HANGER,24Casing Strings Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd LINER AL1 2 3/8 1.992 9,725.1 11,336.0 4.70 L-80 STL Liner Details Top Depth (TVD) Top Mel Norni... Top(RKB) (RKB) II Item Description Comment ID(in) 9,725.1 6,441.0 96.40 BILLET ANCHORED BILLET 1.000 cokoucroR, 9,992.4 6,403.2 93.79 DEPLOY SHORTY DEPLOYMENT 1.900 36-115 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth SAFETY VLV. II (TVD) Top Incl 1,796 1 o I Top(ftKB) (RKB) (°) Description Comment _ Run Date ID(in) 9,725 6,441.0 96.40 WHIPSTOCK ANCHORED BILLET FOR AL2 8/8/2012 1.000 Perforations&Slots GAS LIFT, Shot 2,908 Top(TVD) Btm(TVD) Dens Top(MB) Btm(RKB) (RKB) (RKB) Zone Date Intl.•. Type Comment 9,737 9,770 6,440.4 6,434.5 8/7/2012 32.0 SLOTS [111:-. 9,790 11,336 6,431.6 6,365.8 8/7/2012 32.0 SLOTS l Notes:General&Safety SURFACE, End Date Annotation 35-4,558 8/21/2012 NOTE:WELL SIDTRACKED,ADDED LATERALS AL1,AL2,AL2-01,AL3(See Multi-lat Drawing) 8/21/2012 NOTE:LATERAL 3N-11AL1 OFF 3N-11AL2(See Multi-lat Drawing) GAS LIFT. f �_ 5.099 - GAS LIFT. _ 6,571 l GAS LIFT,_ 7,524 4 GAS 8,052 LIFT,__ 1 IIMI NIPPLE,8.081 IN MEI LOCA8,120TOR,_- lemma ! SEAL A8.SSY, ,O, 153 -, WLEG.8,173 ■ 6 APER IN WHIPSTOCK,WHIPSTOCK 8,470 SCAB LINER. 8,1308,625 PRODUCTION, 4 4 30-8.777 FISH,8,790 ! Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run WHIPSTOCK,9,725 Stn Top(RKB) (RKB) (') Make Model (in) Sery Type Type (Inl (psi) Run Date Corn... 1 2,907.9 2,491.0 46.34 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 a,7iSL no 2 5,099.0 4,001.6 46.28 CAMCO MMG 1 12 GAS LIFT OV RK 0.250 0.0 8/23/2012 3 6,570.7 5,055.9 42.98 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 4 7,523.7 5,7412 45.23 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 ISI 5 8,052.1 6,113.3 45.23 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 2/102012 SLOTS. 9,79011,338 TD(3N-11AL1), 11,335 LINER AL1, 9,725-11,338 • ••-.V`I V GLJ STATE OF ALASKA SEP 1 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION 'aska Ori & Gas Cons. Commission WELL COMPLETION OR RECOMPLETION REPORT ANDALQGle la Well Status: Oil 0,, Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ lb Well Class 20AAC 25.105 20AAC 25 110 Development 0 ' Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No of Completions Service ❑ Stratigraphic Test❑ 2 Operator Name. 5.Date Comp,Susp, 12 Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband August 15,2012 212-096/ 3.Address: 6.Date Spudded: 13 API Number P.O.Box 100360,Anchorage,AK 99510-0360 August 5,2012 / 50-029-21580-60• 4a Location of Well(Governmental Section): 7.Date TD Reached. 14.Well Name and Number: Surface: 1561'FSL, 155'FEL,Sec.29,T13N,R9E, UM• August 7,2012 / 3N-11AL1 • Top of Productive Horizon: 8. KB(ft above MSL): 68'RKB • 15.Field/Pool(s). 952'FSL, 1731'FEL,Sec.20,T13N, RO9E, UM GL(ft above MSL): . 33.8'AMSL• Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD) 148'FNL,2820'FEL,Sec.29,T13N, RO9E, UM 11336'MD/6366'TVD ' Kuparuk River Oil Pool • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-518246 y- 6013799 Zone-4 11336'MD/6366'TVD• ADL 25521,25512 TPI: x-516645 y- 6018466 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit Total Depth: x-515562 y- 6017364 Zone-4 SSSV @ 1797'MD/1731'TVD 2557,2553 18.Directional Survey: Yes 0• No❑ 19 Water Depth,if Offshore. 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1700'MD/1650'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25 071) 22.Re-drill/Lateral Top Window MD/TVD GR/Res 10020'MD/6402'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" _ 62.5# H-40 36' 115' 36' 115' 24" 250 sx CS II 9.625" 36# J-55 35' 4558' 35' 3632' 12.25" 1300 sx AS III,350 sx Class G 7" 26# J-55 30' 8777' 30' 6627' 8.5" 300 sx Class G,175 sx AS I 4.5" 11.6# L-80 8130' _ 8625' 6168' 6519' 15 bbls 16ppg Class G w/GASBLOK 2.375" 4.7# L-80 9725' 11336' 6440' 6366' 3" slotted liner 24.Open to production or injection? Yes ❑✓ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom,Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 8173' 8130'MD/6169'ND •slotted liner from 9726-11336'MD 6440'-6366'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC , ,,,;"i:'11-1: DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED S eja�r' -4 3 *M'I�M I 27 PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) August 31,2012 pre-produced injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 9/6/2012 12 hours Test Period--> 39.5 23 911 124% 718 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 145 psi not available 24-Hour Rate-> 73 49 1806 not available 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Ey Sidewall Cores Acquired? Yes ❑ No 0.. 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 �R���� SS SEP 1 a int h Form 10•407'f�VIM T2J2009 CONT 1l RNr 1SN /\ L Submit original only fe%-4U � 3 lY•i3 \t� 28. GEOLOGIC MARKERS(List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes E No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1700' 1650' needed,and submit detailed test information per 20 AAC 25.071. Top Kuparuk A3 10125' 6389' Bottom Kuparuk A3 11336' 6366' N/A Formation at total depth: Kuparuk A3 30 LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey tekiW +119%1°31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike A.Winf265-6820 Printed Nam L.Ga Title CTD Supervisor / Signature �,e-& - ,(/11'T Phone 263-4021 Date 9//611?- INSTRUCTIONS INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 KUP 3N-11AL1 Conoco'Phillips /a Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Well Status Incl(°) MD(P0<8) Act Btm(ftKB) 500292158060 KUPARUK RIVER UNIT PROD 99.52 9,880.48 Comment H2S(ppm) Date Annotation End Date KB-Grd(B) Rig Release Date "' SSSV:TROP Last WO: 1/12/2012 39.49 4/13/1986 Welt Conk,:-314-11AL1,8/210012 103.53 PM Schematic-Actual Annotation Depth(ORB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:LATERALS ninam 8/21/2012 HANGER.24 IF 1 Casing Strings Casing Description String 0... String ID...Top(kKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd LINER AL1 23/8 1.992 9,725.1 11,336.0 4.70 L-80 STL 1191 F Liner Details Top Depth (TVD) Top Incl Nomi... Top(ftKB) (MB) P) Item Description Comment ID(in) 9,725.1 6,441.0 96.40 BILLET ANCHORED BILLET 1.000 CONDUCTOR. 9,992.4 6,403.2 93.79 DEPLOY SHORTY DEPLOYMENT 1.900 38-115 Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) SAFETY PLO. }± Top Depth 1,796 L (IVO) Top Incl Top(MB) (SKS) (•) Description Comment Run Date _ID(in) 9,725 6,441.0 96.40 WHIPSTOCK ANCHORED BILLET FOR AL2 8/8/2012 1.000 GAS UFT, Perforations&Slots 2,908 Shot Top(TVD) Btm(TVD) Dens Top(ftKB) Btm(ftKB) (kKB) (ftKB) Zone Dete (oh.. Type Comment 9,737 9,770 6,440.4 6,434.5 8/7/2012 32.0 SLOTS 9,790 11,336 6,431.6 6,365.8 8/7/2012 32.0 SLOTS SURFACE. Notes:General&Safety 353,558 - •J End Date Annotation 1,4 8/21/2012 NOTE:WELL SIDTRACKED,ADDED LATERALS AL1,AL2,AL2-01,AL3(See Muli-lat Drawing) GAS LIFT. 5.099 8/21/2012 NOTE:LATERAL 3N-11AL1 OFF 3N-11AL2(See Multi-lat Drawing) GAS LIFT. - [ 8,571 Y GAS LIFT, 7,524 _-- fil GAS LIFT, 8,052 NIPPLE.8.081 LOCATOR, 8128 SEAL ASSY, 8,153tMt IIF WLEG,8,173 1. APERF, 1111 III 8.420$435 WHIPSTOCK 8,470 I SCAB LINER. - 8.130-8,62S PRODUCTION. ♦ A 300777 FISH.8,790 WHIPSTOCK. 9,725 69. al. 111 SLOTS, Mandrel Details 9,737 ,770 Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run Stn Top(kKB) (MB) 1') Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 2,907.9 2,491.8 47.16 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 2 5,099.0 4,001.6 46.28 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/12/2012 3 6,570.7 5,055.9 42.97 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 1 4 7,523.7 5,741.2 45.23 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 1/12/2012 WHIPSTOCK I 5 8,052.1 6,113.2 45.17 CAMCO MMG 1 12 GAS LIFT DMY RK 10.0001 0.012/10/2012 10.430 SLOTS. I 10.442-10.600 1 SLOTS. 9.790-11,338 LINER A, 10.430-10800 TO(3N-11AL1), 10,923 LINER AL1, 9,725-11.338 °0 00 00 00 CD N b q M q i q el Jq�M 4^N `21,T. N Ncye? 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Spot Sub and Mud Module over well. RU 07/24/2012 Rig move from 2D-05 to 3N-11 16 miles. Spot Rig Modules. NU BOPE. Load Pits with 150 bbls of SW,216 bbls of Used 9.4 ppg flowpro, 192 bbls of 13.1 ppg. BOPE test 250/3500psi.AOGCC Waived by John Crisp.Pull BPV.Slack MNGT, cut 5ft of coil. Rehead,pull/pressure test.test PDL&Tiger tank lines. 00:00 02:00 2.00 0 0 MIRU MOVE MOB P NU BOP's on well. Fill rig lines with water.Valve crew serviced tree. IA= 250,OA 0 02:00 04:00 2.00 0 0 MIRU WHDBO NUND P ""Rig accept at 0200*"* NU Bop stack 04:00 14:00 10.00 0 0 MIRU WHDBO BOPE P Begin BOPE test,AOGCC witnessing waived by John Crisp. 1 Failure, R2. 14:00 15:00 1.00 0 0 MIRU WHDBO BOPE P Changeout R2 and test, Pull BPV 15:00 18:00 3.00 0 0 SLOT WELLPFCTOP P Remove BHI's drilling head,cut CTC. MU injector to wellhead. Reverse circulate for slack management. Cut 5ft of coil to find cable. 18:00 22:00 4.00 0 0 SLOT WELLPF CTOP P Crew change.Make up CTC, pull& pressure test. Pressure test PDL& Tiger tank line.Clean up rig floor& tools. 22:00 22:30 0.50 0 0 SLOT WELLPF SFTY P Pre-Spud meeting with Maddy's crew. 22:30 00:00 1.50 0 0 PROD1 RPEQPI PULD P Check Well pressure-zero-PJSM- P/U Whipstock assembly. BHA#1 07/25/2012 RIH with Whipstock, could not drift past 8277'POOH&P/U 2.80"motor&D331. Drift to 8500'. P/U Whipstock and set TOWS @ 8470'. 00:00 00:30 0.50 0 74 PROD1 RPEQPI PULD P Line up stack for ease of injector make up. 00:30 03:00 2.50 74 8,175 PROD1 RPEQP1TRIP P RIH with EDC open pumping .4 bpm. 03:00 04:30 1.50 8,175 8,276 PROD1 RPEQP1DLOG P Tie into K-1 marker @ 8175',Cannot get a good tie in, P/U to 8145'and log down. P/U weight 36K. Set down weight at 8276' P/U weight 35K. Could not make it down past 8277'. Did not get rough with it. 04:30 •07:15 2.75 8,276 0 PROD1 RPEQP1TRIP T POOH Page 1 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:15 07:30 0.25 0 0 PROD1 RPEQP1SFTY T At surface, Flow check, PJSM 07:30 08:00 0.50 0 0 PROD1 RPEQPI PULD T LD whipstock,excessive amounts of sludge on WS/BHA 08:00 08:45 0.75 0 0 PROD1 RPEQPI PULD T PU BHA#2(Coiltrack,0.6 AKO with D331 w/side reamers 08:45 10:30 1.75 0 7,845 PROD1 RPEQPI TRIP T RIH,circulating seawater thru mill 1 BPM 10:30 11:15 0.75 7,845 7,958 PROD1 RPEQPI DLOG T Tie in depth HRZ(highly Radio Active Zone),-11'correction 11:15 11:45 0.50 7,958 8,500 PROD1 RPEQPI FCO T Weight check 35K up, RIHW 18K, RIH down 8388'.Wt.chk 33K.Cont. RIH 1.53 BPM,2976 CTP, circulating SW. 11:45 12:15 0.50 8,500 8,200 PROD1 RPEQP1 FCO T PUH to 8200', 1.54bpm,2900ctp, 34K ctw 12:15 12:21 0.10 8,200 8,200 PROD1 RPEQPI FCO T Test backside line to TT.500psi. Line broke to arrange rig up.Test good 12:21 13:00 0.65 8,200 8,500 PROD1 RPEQP1 FCO T RBIH to 8500, PU to 8200' circulating SW out to TT. Circulate 9.4ppg used flow pro to EDC. 13:00 15:15 2.25 8,500 0 PROD1 RPEQP1TRIP T Looked good. Did not see anything across shakers.Open EDC, POOH displacing well to Flo-Pro 15:15 15:30 0.25 0 0 PROD1 RPEQP1SFTY T At surface, Flow check, PJSM 15:30 16:00 0.50 0 0 PROD1 RPEQPI PULD T LD BHA#2 16:00 17:00 1.00 0 0 PROD1 RPEQPI PULD T PU BHA#3(Coiltrack with _ thru-tubing WS) 17:00 18:45 1.75 0 5,100 PROD1 RPEQP1TRIP T RIH with EDC open. 18:45 19:15 0.50 5,100 5,132 PROD1 RPEQP1RGRP T Stop RIH-pump problems cannot keep prime. 19:15 20:15 1.00 5,132 8,490 PROD1 RPEQP1TRIP T RIH pumping.3 bpm.Tie in with-10 ft correction. 20:15 20:45 0.50 8,490 8,482 PROD1 RPEQPI WPST P P/U to setting depth TOWS 8470'. HS.Close EDC. P/U weight 35K. zero WOB. Pump pressure 2900 set, set down 3K WOB. 20:45 22:45 2.00 8,482 72 PROD1 RPEQP1TRIP P POOH laying in flo-pro. 22:45 23:30 0.75 72 0 PROD1 RPEQPI PULD P PJSM fopr laying down BHA 23:30 00:00 0.50 0 0 PROD1 WHPST PULD P P/U milling BHA with 2.80"window mills. 07/26/2012 Mill window from 8473'to exit point of 8482.55'continue time milling rathole to 8500'. 00:00 03:00 3.00 72 8,474 PROD1 WHPST TRIP P P/U&RIH with 2.80"window/string mill with 10'vibration joint. Minus 10ft correction. RIH dry tag 8473.5' 03:00 08:00 5.00 8,474 8,479 PROD1 WHPST MILL P P/U free spin 3200psi and start milling window as per procedure from 8474'at 1.45 bpm, 3300,diff 526psi, WHP 0,WOB.5K. 8475.4'-Light metal shavings over shaker,on auto driller. 08:00 08:30 0.50 8,479 8,479 PROD1 WHPST REAM P 5'milled.Make 3 reaming passes looks good Page 2 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 10:30 2.00 8,479 0 PROD1 WHPST TRIP P POOH 10:30 11:00 0.50 0 0 PROD1 WHPST PULD P At surface,monitor well for flow, PJSM 11:00 11:30 0.50 0 0 PROD1 WHPST PULD P LD BHA 4. Mills gauge 2.79 No-GO 11:30 12:00 0.50 0 0 PROD1 WHPST PULD P PU BHA#5(Weatherford fixed 1.25 ako with window mill,string mill,and 10'vibration joint.) 12:00 13:45 1.75 76 7,920 PROD1 WHPST TRIP P RIH 13:45 14:00 0.25 7,920 7,920 PROD1 WHPST DLOG P Tie in depth-11'correction 14:00 14:15 0.25 7,920 8,479 PROD1 WHPST TRIP P RIH To TOW 14:15 14:30 0.25 8,479 8,479 PROD1 WHPST MILL P Dry tag 8479.37'. PU 10',bring pumps on. RIH slowly.off bottom parammeters 1.5 bpm,3500 ctp, 16k rihw, 3869 bhp,688 diff psi. 14:30 19:30 5.00 8,479 8,482 PROD1 WHPST MILL P Start milling as per program 8478.9' 1.5 bpm, 17.5K CTW,3845 bhp, 760 diff psi, .6k wob. 19:30 21:30 2.00 8,482 8,485 PROD1 WHPST MILL P 8482.55'WOB dropped off,window exit, 1.45 bpm, 3600, BHP 3876,diff 880,WOB 0.4K, ROP 1.3 fph. 21:30 23:00 1.50 8,485 8,488 PROD1 WHPST MILL P Increase to 2 fph. 98%formation in returns 1%cement. 23:00 00:00 1.00 8,488 8,500 PROD1 WHPST MILL P Start increasing speed&WOB- 1.45 bpm,3700, BHP 3930,WHP 150,WOB 2.3K, ROP 17 fph. 07/27/2012 Drill build section to 8780'.P/U Drilling BHA with.8 ako&3"Bi-center. Fluid loses from 8680'roughly 1/4 bpm.24 hour losses= 145 bbls Tie into RA marker window depths: TOWS=8471' TOW=8473 BOW=8482.5' 00:00 01:45 1.75 8,500 8,500 PROD1 WHPST REAM P Make three reaming passes. Seen motor work @ 8474',did get lighter with each pass. Dry run @ 10 fpm- clean.P/U weight 33K. 01:45 02:15 0.50 8,468 8,468 PROD1 WHPST SIPB P Sit just above the window and do static test. Start-Circ 870,WHP 522, BHP 3760 psi. END-Circ 615,WHP 514, BHP 3689 psi 02:15 05:00 2.75 8,468 0 PROD1 WHPST TRIP P Open EDC-POOH holding MPD. 05:00 05:15 0.25 0 0 PROD1 WHPST SFTY P At surface-Close SSSV monitor well for 15 minutes.Crew change. PJSM for laying down BHA. 05:15 05:45 0.50 0 0 PROD1 WHPST PULD P LD BHA 5 Mills 2.80 Go,2.79 No-Go.Window mill has good wear in core 05:45 06:15 0.50 0 0 PROD1 DRILL PULD P PU BHA 6. (2 deg heavy AKO, Bi-Center bit) 06:15 06:45 0.50 0 0 PROD1 DRILL SVRG P Service injector head,reel, levelwind. 06:45 08:15 1.50 62 7,920 PROD1 DRILL TRIP P RIH, EDC open Page 3 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 08:30 0.25 7,920 7,920 PROD1 DRILL DLOG P Tie in depth-10'correction 08:30 08:45 0.25 7,920 8,500 PROD1 DRILL TRIP P Close EDC, RIH drift window with build BHA. PUH above window 08:45 09:45 1.00 8,450 8,450 PROD1 DRILL CIRC P Open EDC, Swap out milling fluid to 9.5ppg Drilling Mud. Flo-Pro 09:45 11:00 1.25 8,500 8,550 PROD1 DRILL DRLG P Drill Ahead 1.5 bpm,3500 ctp,3966 bhp, 2-3 wob, 14k ctw 11:00 11:15 0.25 8,550 8,550 PROD1 DRILL DLOG P PU log RA marker, allow time for DD to calculate build. RIH TOWS 8471' TOW 8473' RA 8478' BOW 8482.5' 11:15 13:15 2.00 8,550 8,680 PROD1 DRILL DRLG P Drill Ahead 1.5 bpm,3700 ctp,3978 bhp,0 whp, 15 ctw, 13:15 13:30 0.25 8,680 8,630 PROD1 DRILL WPRT P Start losing returns. intially.5 bpm. PU 30K looks good.Wipe 50'.RBIH 13:30 14:30 1.00 8,680 8,780 PROD1 DRILL DRLG P RBIH Cont drilling 1.5 bpm in, 1.14 out,3498 ctp,52 whp,3968 bhp 14:30 17:30 3.00 8,780 72 PROD1 DRILL TRIP P Land build.8780'. POOH 30K puw. 17:30 18:15 0.75 72 72 PROD1 DRILL SFTY P PJSM crew change-Undeploy BHA 18:15 19:45 1.50 72 0 PROD1 DRILL PULD P Undeploy BHA#6-well losing roughly 1/4 bpm.Order more mud. 19:45 20:30 0.75 0 0 PROD1 DRILL SFTY P Pre-spud with Gary crew 20:30 22:00 1.50 0 72 PROD1 DRILL PULD P PJSM-deploy BHA#7 with.8 AKO &new Bi-center. Injected roughly 25 bbls at surface holding MPD. 22:00 00:00 2.00 72 8,520 PROD1 DRILL TRIP P RIH with EDC open. Lost 30 bbls while RIH.Tie in-10ft. Clean through window. 07/28/2012 Continue drilling ahead on A lateral. Total losses for 24 hours=199 bbls. 00:00 02:15 2.25 8,780 8,930 PROD1 DRILL DRLG P 1.50 bpm, 3680, BHP 4010, ECD 12, WOB 1.3K, ROP 95, rate out 1.15 bpm. 02:15 03:15 1.00 8,930 8,930 PROD1 DRILL WPRT P Wiper trip with MADD pass from 8765'P/U weight 32K. 03:15 05:45 2.50 8,930 9,080 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,3680, BHP 3990, ECD 12, ROP 35,WOB 2.1K, Ct weight 15K, rate out 1.25 05:45 06:30 0.75 9,080 8,500 PROD1 DRILL WPRT P Wiper trip back to window 30K puw 06:30 07:30 1.00 9,080 9,100 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,3680, BHP 3990, ECD 12, ROP 35,WOB 2.1K, Ct weight 15K, rate out 1.25 07:30 08:00 0.50 9,100 8,690 PROD1 DRILL WPRT P PU 30K. Large amounts of magentic interference. Peform check shot to compare surveys. RBIH 08:00 08:15 0.25 9,100 9,135 PROD1 DRILL DRLG P Drill Ahead-1.45 bpm, 3640, BHP 3990, ECD 12.06,WOB 1-2K,Ct weight 15K, rate out 1.25 08:15 08:45 0.50 9,135 8,890 PROD1 DRILL WPRT P PUH discuss with town,surveys out of BHI spec. Magnetic Interference shows to be high on USGS website. RBIH Page 4 of 18 • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 08:45 12:00 3.25 9,135 9,290 PROD1 DRILL DRLG P Drill Ahead sending surveys for IIFR after every 150'drilled. 1.45 bpm, 3590, BHP 4001,WOB 1-2K,Ct weight 15K, rate out 1.25 12:00 13:15 1.25 9,290 8,500 PROD1 DRILL WPRT P Wiper trip to window,30K puw. Log RA marker for depth tie in.+1' correction 13:15 16:00 2.75 9,290 9,440 PROD1 DRILL DRLG P Drill Ahead-1.45 bpm in, 1.25 out, 3640, BHP 4050, ECD 12.2,WOB 1-2K,Ct weight 15K, 16:00 17:00 1.00 9,440 8,500 PROD1 DRILL WPRT P Wiper trip to window 30K puw 17:00 19:00 2.00 9,440 9,590 PROD1 DRILL DRLG P Drill ahead 19:00 20:00 1.00 9,590 8,500 PROD1 DRILL WPRT P Wiper trip-P/U weight33K. Follow wiper schedule. 20:00 22:00 2.00 9,590 9,740 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,3780, BHP 4065, ECD 12.2, ROP 98,WOB 2K, Ct weight 14K, rate out 1.33 22:00 00:00 2.00 9,740 8,180 PROD1 DRILL WPRT P Wiper to 3.5"-P/U weight 33K.Tie in correction+1ft. 07/29/2012 Continue drilling ahead on A lateral. Mud swap with 2220'on system.Total losses for 24 hours= 171 bbls. 00:00 02:00 2.00 9,740 9,890 PROD1 DRILL DRLG P Drilling ahead-turning up sharp to find sand. 1.45 bpm, 3600, BHP 4020, ECD 12.2,ROP 90,WOB 2K, CT weight 15K. rate out 1.32 bpm. Pump 100 bbls of new mud down to top up the active pits. 02:00 02:45 0.75 9,890 9,000 PROD1 DRILL WPRT P Wiper trip-P/U weight 31K.890;' wiper trip 02:45 05:15 2.50 9,890 10,040 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,3750,BHP 4090, ECD 12.3,WOB 2K,Ct weight 10K. rate out 1.35 bpm 05:15 06:00 0.75 10,040 8,890 PROD1 DRILL WPRT P Wiper trip. 30K puw 1150' 06:00 08:15 2.25 10,040 10,190 PROD1 DRILL DRLG P Drilling ahead-1.48 bpm,3830, BHP 4118, ECD 12.3,WOB 1-2k,Ct weight 11K. rate out 1.30 bpm 08:15 10:45 2.50 10,190 8,200 PROD1 DRILL WPRT P Wiper trip up to window 30k puw. PU to 8200'jetting 4 1/2"tubing. RBIH. Log RA marker. 0 Correction. 10:45 12:30 1.75 10,190 10,340 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,3750,BHP 4090, ECD 12.3,WOB 2K,Ct weight 10K. rate out 1.35 bpm 12:30 13:30 1.00 10,340 10,340 PROD1 DRILL WPRT P Wiper trip 30K puw. 850' 13:30 15:00 1.50 10,340 10,490 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm, CTP 3890, BHP 4160, ECD 12.3,WOB 2K, Ct weight 9K. rate out 1.35 bpm 15:00 16:15 1.25 10,490 9,340 PROD1 DRILL WPRT P Wiper trip 30k PUW, 1150' 16:15 18:00 1.75 10,490 10,627 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm, CTP 3890, BHP 4160, ECD 12.3,WOB 2K, Ct weight 9K. rate out 1.35 bpm. Stacking weight, negative 5K. Page 5 of 18 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 18:00 19:00 1.00 10,627 10,630 PROD1 DRILL DRLG P P/U 300'due to weight stacking and noise on injector,Ct weight 33K RIH to inspect injector and drill final 20ft. Injector sounds good, increase chain tension.Try drill ahead-WOB 1.9K, Ct weight-5K,slow ROP 5,ankerite in samples.Trucks enroute for mud swap. 19:00 22:00 3.00 10,630 8,180 PROD1 DRILL WPRT P Wiper trip to 3.5"P/U weight 33K. Tie in correction Zero.Start pumping new mud while RIH. 22:00 23:30 1.50 10,630 10,720 PROD1 DRILL DRLG P New mud at bit-Drilling ahead- drilled through ankerite.Weights back to normal. 1.45 bpm,3780, BHP 4157, ECD 12.6, ROP 66, WOB 2K, Ct weight 10K. New mud around holding 90 psi WHP. 23:30 00:00 0.50 10,720 10,750 PROD1 DRILL DRLG P P/U 100'due to losing prime on pumps-33K. Drill ahead. 07/30/2012 BHA Bit stuck @ 10923',TOF 10867'.Try to work free, no luck-discconnect from BHA. P/U Fishing BHA with GS, Up jars,weight bars&intensifier. Latch in to fish,20 hits,string weight 60K,WOB-15K. No luck, spot mineral oil&diesel. No luck.39 hits total.Try to relatch fish, no luck. POOH to inspect BHA. 00:00 00:30 0.50 10,750 10,780 PROD1 DRILL DRLG P Drill ahead 00:30 01:30 1.00 10,780 10,780 PROD1 DRILL WPRT P Wiper trip 850'P/U weight 32K. 01:30 03:30 2.00 10,780 10,923 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,3780, BHP 4190,WJP 110, ECD 12.8,WOB 2K,CT weight 8K, ROP 105, rate out 1.32 bpm. Pump 5/5 sweep prior to wiper. 03:30 05:00 1.50 10,923 10,867 PROD1 DRILL WPRT T Hard stall, P/U weight 44K, Bit stuck.Try to cycle 5 times no luck Max P/U 50K&-6 WOB. Sit in nuetral and try to pump to move fluid. Pressure up immediately . BHP leaks down to 3760' Discuss with town,try pump down Backside to 850 psi WHP-no luck. Try max pull of 60K -11.8 K WOB cycle three more times.Go to nuetral weight,bleed down CT string and Disconnect BHA. @ 10923 Bit depth. Fishing neck 10867' 05:00 09:00 4.00 10,867 0 PROD1 DRILL TRIP T Total cycle 14 times. P/U 5 ft-start pumping 1.5 bpm and circ to clean fishing neck. Reset depths. POOH for fishing BHA following WHP for MPD. 09:00 09:15 0.25 0 0 PROD1 DRILL SFTY T At surface. Close SSSV.Monitor well for flow 09:15 09:45 0.50 0 0 PROD1 DRILL PULD T SSSV tested good. LD BHA 7. 09:45 10:45 1.00 0 0 PROD1 DRILL SVRG T Service inj. head,reel,service MP choke, Function test BOPE 10:45 12:15 1.50 0 0 PROD1 DRILL PULD T MU fishing BHA 8 12:15 14:15 2.00 61 8,450 PROD1 DRILL TRIP T Open SSSV, RIH Page 6 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 15:15 1.00 8,450 10,867 PROD1 DRILL TRIP T Weight check 30K up, 16k down. RIH to fish 15:15 16:30 1.25 10,867 10,867 PROD1 DRILL FISH T Weight check 31k up, 14k RIW. RIH latch into fish 3K down.Trap MP pressure 4193 BHP. Bleeds down rapidly, PU 50k.jar hit, PU 60K. No luck.Cock jars PU 60k.Jar hit. No luck.. Pump ann.psi up to 4200 psi. PU 60K X 5. No luck. Bleed down psi on well 3600 BHP..Jar X 5, no luck. Total jars 15. 16:30 17:00 0.50 10,863 10,863 PROD1 DRILL FISH T Set down 2K 10863'. Pump mineral down to bit thru CT 7 bbrls total. Possibly pulled fish 4'up hole. 17:00 17:18 0.30 10,864 10,864 PROD1 DRILL FISH T Shut in choke.squeeze 7bbrls mineral away around BHA.Attempt to jar 1 time. No luck RBIH.set down 4k 17:18 17:27 0.15 10,864 10,864 PROD1 DRILL FISH T Let mineral oil soak. 17:27 18:57 1.50 10,864 10,864 PROD1 DRILL FISH T Pick up attempt to jar fish free. 11 18:57 19:57 1.00 10,864 10,864 PROD1 DRILL FISH T Spot mineral 7 bbrls. let soak 30min. Order out Slick Diesel. 19:57 20:30 0.55 10,864 10,864 PROD1 DRILL FISH T Pick up attempt to jar fish free 7 pulling 65-70k 13-15k wob. 20:30 21:15 0.75 10,864 10,864 PROD1 DRILL FISH T Spot Slick Diesel around fish. 10 bbrls 21:15 21:30 0.25 10,864 10,864 PROD1 DRILL FISH T Let diesel soak 21:30 22:00 0.50 10,864 10,866 PROD1 DRILL FISH T Attempt to jar fish free,pulling 65 K 13-18k wob. 22:00 23:00 1.00 10,866 10,866 PROD1 DRILL FISH T Disconnect off fish.Wipe pipe and gripper blocks clean of oil for more pull without slipping. RBIH unable to latch fish.. 23:00 00:00 1.00 10,866 10,867 PROD1 DRILL FISH T P/U 300ft and circ B/U to clean up diesel. RIH pumping 1.35 bpm to clean up GS,sat down @ 10,863'. 3K WOB. Stop pumping. RIH to 10866'Not gaining WOB. P/U weight 36K. RIH set down @ 10867'WOB 3K. P/U 37K POOH pumping down backside. Unable to latch or have fish? 07/31/2012 Perform clean out to 10864'W/D331 mill. Latched fish easily after cleanout.Activate Hipp tripper down for 10 minutes, up for 1 hour,tools came free when pulling 55k.TOOH to check BHA. Total fluid losses to formation 181 bbls. 00:00 03:30 3.50 10,867 60 PROD1 DRILL TRIP T POOH pumping down the backside in case fish is latched. Small weight bobble at window. 03:30 04:00 0.50 60 0 PROD1 DRILL SFTY T Shut SSSV-flow check at surface. PJSM for laying down BHA. Page 7 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 05:00 1.00 0 0 PROD1 DRILL PULD T Lay down BHA-GS looks like it was lodged in the down(latch position). Took apart and packed with gravel/formation. Set back up on MP, Open SSSV.Call town to discuss tool being packed off. 05:00 06:00 1.00 0 0 PROD1 DRILL PULD T Decision made to P/U 2.79"D331 with upcutters for a clean out run. PJSM to P/U new BHA and set up motor to.8 AKO. 06:00 07:30 1.50 0 72 PROD1 DRILL PULD T Crew change-Close SSSV-flow check. P/U Clean out BHA. 07:30 11:00 3.50 72 10,856 PROD1 DRILL TRIP T RIH pumping.6 bpm.Tie in-11.5 ft. Clean through window.Continue RIH. 1.5 bpm.Started to get light crude/diesel across shakers near TD. Rate out increased after well cleaned up.Sitting down on fill, WOB 1K, lower pump rates&P/U 38K. 11:00 12:00 1.00 10,856 10,864 PROD1 DRILL FCO T RIH 20 fph, 1.5 bpm,3400,BHP 4120.diff 392,Tag @ 10864', P/U 32K. RIH 10 fph,-Stall again @ 10864'.Wipe up slowly, RIH dry tag, 1K down.clean to tag. 12:00 16:00 4.00 10,864 62 PROD1 DRILL TRIP T POOH pumping 1.5 bpm. 16:00 17:00 1.00 62 51 PROD1 DRILL PULD T Close SSSV-flow check. lay down FCO BHA. P/U Hip tripper BHA#10. 17:00 20:15 3.25 51 10,667 PROD1 DRILL TRIP T Pre-set depth-10ft at surface.RIH 100ft test hip-tripper.Good test. Open EDC&RIH. Stop above window,close EDC.WT check @ 31k,continue RIH 20:15 21:45 1.50 10,867 10,850 PROD1 DRILL FISH T Latch fish @ 10667'with no problem.Stack 1.6 WOB,hip trip down for 10 minutes,stack a little more&stall out. Pull up on fish to 39,000k(-3000k)Pump @.9 BPM. Gradually increase pull on fish. Hipp Trip for 1 —hour, pull 55k,came free. 21:45 00:00 2.25 10,850 4,000 PROD1 DRILL TRIP T POOH pumping over the top. 08/01/2012 Recovered fish from 10867'.Set anchored billet&5 jts of slotted liner(TOB @ 10430') Total fluids losses to formation 103 bbls. 00:00 00:45 0.75 4,000 0 PROD1 DRILL TRIP T Get well above SSSV.dump. bump up. 00:45 01:15 0.50 0 0 PROD1 DRILL SFTY T Perform no flow test, looks good. 01:15 03:00 1.75 0 0 PROD1 DRILL PULD T Lay down BHA,no fish. BHA&GS look good. Discuss options, Baker tool hand suspects GS came loose when fish rapidly pulled free.Conduct TGSM, load BHA back in the hole. Inspect injector,change out shaker baskets. Page 8 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 06:15 3.25 51 10,821 PROD1 DRILL TRIP T RIH to 300',test Hip Tripper,good. RIH W/EDC open stop @ 8450'. close EDC.Continue RIH. 06:15 07:00 0.75 10,821 10,867 PROD1 DRILL FISH T Weight check 32K, .4 bpm,2900, BHP 4120,diff 1240.Sit down @ 10,863'-pressure spike. Stop pumping sit down on fish 2.5K. Let the coil bleed down. P/U weight 34K. RIH tag bottom again-10864'2.5K WOB P/u 35K. RIH-3K 10,866.83'-P/U 34K RIH-3.2K 10,867'-P/U 35K. RIH-Start losing weight earlier- push down 10,868'WOB 2.8K- bleed CT down,Good indication of set down. P/U weight 37K P/U 07:00 11:30 4.50 10,867 110 PROD1 DRILL TRIP T POOH pumping down backside. Seen over pulls to 40K @ 10600& 10240'. Keep speed 50 fpm in cased hole. 11:30 13:30 2.00 110 0 PROD1 DRILL PULD T Close SSSV-15 minute flow check, PJSM for laying down fish. Entire BHA recovered.Set back up on MP. 13:30 14:00 0.50 0 0 PROD1 DRILL PULD T Clean up rig floor and call town to discuss next step. 14:00 15:00 1.00 0 0 PROD1 DRILL SFTY P "I Believe"presentation from Shon& Vance. 15:00 17:00 2.00 0 231 COMPZ CASING PUTB T Start P/U 5 joints of slotted liner& anchored billet. 17:00 20:45 3.75 231 10,600 COMPZ CASING RUNL T RIH Anchored Billet&5 jts of liner. Tie in for a-11'. RIH to just above window @ 8420'WP4 is getting the final blessing.Shut down the pumps, trap pressure. Close EDC. PUH& get 31k pu wt. Plan is on E-mail. TOB @ 10430'set slip @ 190 deg. Continue RIH to 10,600', Pull to neural wt. 10,600'-169.88 liner assembly tob billet @ 10,430' Pressure up to 3850 psi,to set billet. WOB @ 6k. 20:45 00:00 3.25 10,600 2,100 COMPZ CASING TRIP T Pick up slowly,start pumping a Btm's up while while moving tools slowly,pick up speed once 20 bbls ahead. 08/02/2012 Tagged top of billet @ 10432'. Kicked off billet&drilled ahead in AL3 to 10915'.Wiper trip in progress.Total fluid losses to formation 172 bbls 00:00 01:00 1.00 2,100 61 COMPZ DRILL TRIP T Continue TOOH. 01:00 03:00 2.00 61 72 PROD2 DRILL PULD T Watch 30 minutes no flow,while conduct pre-job for laying down BHA. Laydown BHA, pick-up drilling BHA, MWD re-boot computers. 03:00 06:00 3.00 72 10,432 PROD2 STK TRIP T RIH W/drilling BHA.7930',tie in for a-11.5 correction. Page 9 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 09:00 3.00 10,432 10,432 PROD2 STK KOST T Dry tag TOB-KOTB as per procedure from 10431.45'155 ROHS, 1.45 bpm,3350, BHP 4131, ROP 1fph,WOB.7K,Ct weight 13K, rate out 1.30. Stall @ 10481'X 2 Slip sticking, stacking CT weight.8-9K Stall @ 10482'X 2 slip sticking- Wipe up 100'try again. Better weight tranfer. 09:00 12:00 3.00 10,432 10,452 PROD2 STK KOST T 10431.75'-Increase 776 lubes to 2%.Start milling again-1.45 bpm, 3518, BHP 4148, ROP 1 fph, rate out 1.30 bpm,WHP 155.Ct weight 14K. Light Alum shaving over shaker. Better weight transfer. 12:00 15:00 3.00 10,452 10,615 PROD2 DRILL DRLG T Start drilling ahead-1.45 bpm, 3600, BHP 4180, ROP 70,WOB 1.3K,CT weight 12K, rate out 1.33 bpm. 15:00 17:30 2.50 10,615 10,615 PROD2 DRILL WPRT T Wiper trip to window P/U weight 32K 17:30 19:30 2.00 10,615 10,765 PROD2 DRILL DRLG T Drilling ahead 19:30 21:00 1.50 10,765 10,765 PROD2 DRILL WPRT T Pull 1150'wiper trip to 9615', RBIH 21:00 22:45 1.75 10,765 10,915 PROD2 DRILL DRLG T Drill ahead, 1.43 BPM @ 3686 PSI, 12.70 ECD 4190 BHP ROP 67 22:45 00:00 1.25 10,915 8,509 PROD2 DRILL WPRT T Wiper,35k off btm, one bobble to 38k. long wiper up. 08/03/2012 Drill AL3 to TD of 11,366'. Lay in liner pill.Total fluid losses to formation 166 bbls. 00:00 02:30 2.50 8,509 10,915 PROD2 DRILL WPRT T Continue wiper, Make a second trip in 4.5"liner. Log for tie in @ 8500, +1'correction. RBIH 02:30 05:30 3.00 10,915 11,065 PROD2 DRILL DRLG P Drill ahead, 1.43 BPM @ 3771 PSI, 4206 BHP WOB 1.5 ROP 81.5. Res off&gamma spike @—10970' ROP @ 30. Geo made call to town, continue drilling. 05:30 07:00 1.50 11,065 11,065 PROD2 DRILL WPRT P Wiper up,35k off BTM. P/U 1100ft. 07:00 09:00 2.00 11,065 11,200 PROD2 DRILL DRLG P Drilling ahead-1.45 bpm, BHP 4215, ECD 12.7,WOB 1.7K,CT weight 6K, ROP 110, rate out 1.35 bpm. 09:00 12:00 3.00 11,200 11,200 PROD2 DRILL WPRT P Wiper trip 15ft early due to CT weight transfer. P/U weight 39K.Wipe to the 3.5"for final 150ft drilled. 12:00 17:00 5.00 11,200 11,366 PROD2 DRILL DRLG P Drilling ahead-1.45 bpm,3770, BHP 4230,WOB 2.3K,CT weight 6K, ROP 7-possible ankerite. Drilled through, 150'wiper trip due to weight transfer. Drill ahead better CT weight transfer. 17:00 20:45 3.75 11,366 11,366 PROD2 DRILL WPRT P TD, pump sweeps -Wiper to window P/U weight 32K. Run back down& up. RBIH,send pill down coil to be at the bit. Page 10 of 18 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 20:45 00:00 3.25 11,366 1,000 PROD2 DRILL TRIP P Liner pill @ the bit,start laying in 45 bbls of flo pro liner pill.Chase out in the 3.5"TBG @ 80 FPM. Pull up past SSSV to 1000',keep pumps up until BTM's up.Shut down and open EDC. 08/04/2012 Ran liner in AL3,top of liner at 10,020'. Performed full BOP test.Test waved by Chuck Scheve. 00:00 01:00 1.00 1,000 72 PROD2 DRILL TRIP P @ 1000' RBIH W/Edc open,wash SSSV @ 1796'.Trip out to surface. 01:00 01:30 0.50 72 72 PROD2 DRILL SFTY P Shut SSSV,watch for 30 minutes for no flow.Conduct pre-job. 01:30 03:00 1.50 0 0 PROD2 DRILL PULD P Lay down BHA 03:00 06:00 3.00 0 1,390 COMPZ CASING PUTB P Conduct pre-job. Pick-up liner& BHA. 06:00 07:30 1.50 1,390 1,389 COMPZ CASING PUTB P Crew change PJSM for completing P/U liner&coiltrack assembly with a liner top billet. 07:30 10:00 2.50 1,389 11,366 COMPZ CASING RUNL P Open SSSV-600 psi below. RIH EDC closed pumping .3 bpm.Tie in -12ft,32K P/U weight-5 WOB.Clean through window-tag bottom.4K WOB.clean to TD. 10:00 10:30 0.50 11,366 10,020 COMPZ CASING RUNL P P/U weight-38K,-2 WOB, RIH.Tag bottom set down 5K,bring pump rate up to 1.3 bpm,4100psi, P/U weight 31K. BOL=11366' TOB=10,020' 10:30 13:30 3.00 10,020 48 COMPZ CASING TRIP P Subtract out BHA-POOH pumping 1.3 bpm. 13:30 14:30 1.00 48 0 COMPZ CASING PULD P Close SSSV-flow check, PJSM for laying down BHA. Lay down BHA. 14:30 16:00 1.50 0 0 COMPZ CASING CIRC P Start Pumping MPD-Grease tree, choke manifold and surface valves. Install stinger on CT and flush CT string&stack with fresh water. 16:00 00:00 8.00 0 0 COMPZ CASING BOPE P Start BOPE testing 250 low/3500 high.Test inner reel iron.Shut down MPD until step 3. Note:went back on MPD @ 2030. Finished BOP test. Rig down associated equip. 08/05/2012 Tag billet @ 10020'. Kick off billet @ 40 ROH. Drilling ahead in AL1 lateral. 00:00 01:00 1.00 0 0 PROD3 STK BOPE P Finish rigging down after BOP test. Displace water out of coil to flo-pro. Shut SSSV,watch for no flow. 01:00 02:30 1.50 0 72 PROD3 STK PULD P Conduct pre-job. PU drilling BHA with.8 AKO and re-run Bi-center bit. 02:30 06:00 3.50 72 10,020 PROD3 STK TRIP P RIH W/drilling BHA, EDC closed, pump minium rate.open SSSV, pressure to 5500 PSI. @ 7945',tie in for a-12 correction. Continue Down, tag TOB @ 10,020 Page 11 of 18 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06:00 09:00 3.00 10,020 10,050 PROD3 STK KOST P Start KOTB 40 ROHS-1.40 bpm, 3660, BHP 4161,WOB 1.2K,Ct weight 13K, ROP 1 fph, rate out 1.28.Good Al.Shavings over shaker, increase ROp as per procedure. Pulled a little heavy through billet, small weight bobble. 09:00 10:30 1.50 10,050 10,170 PROD3 DRILL DRLG P Start pumping new mud-drilling ahead 1.45 bpm,3600, BHP 4131, WHP 50,WOB 1.3K,Ct weight 11K, ROP 70, rate out 1.38 bpm. 10:30 12:30 2.00 10,170 10,170 PROD3 DRILL WPRT P Wiper trip to window, P/U weight 32K-Clean through billet,clean mud to surface. Blow down the choke. RIH 12:30 15:00 2.50 10,170 10,320 PROD3 DRILL DRLG P Drilling ahead.Getting into betterA-3 sand. 15:00 16:00 1.00 10,320 10,320 PROD3 DRILL WPRT P Wiper trip-P/U weight 31K.Started to pull heavy at the billet-RIH and bring up pump rate. Lower rate and pull through with a little weight bobble,Wipe up 1000'RIH-clean through billet. 16:00 18:00 2.00 10,320 10,470 PROD3 DRILL DRLG P Drilling ahead-1.45 bpm,3680, BHP 4187, ROP 124,WOB 1K,Ct weight 12K, ECD 12.7, rate out 1.30 bpm. 18:00 21:00 3.00 10,470 10,470 PROD3 DRILL WPRT P Wiper trip P/U weight 31K.Slowed to 10 fpm coming through billet,3 K surface weight gain and 1.3 WOB. continue to wiper to window. 21:00 22:30 1.50 10,470 10,620 PROD3 DRILL DRLG P Drilling ahead-1.40 bpm,3550, BHP 4166,WHP 120,WOB 2K,Ct weight 10K, ROP 110, rate out 1.30 bpm. 22:30 23:30 1.00 10,620 10,620 PROD3 DRILL WPRT P Slow wiper to below Billet-P/U weight 31K. 23:30 00:00 0.50 10,620 10,650 PROD3 DRILL DRLG P Drill ahead 1.44 BPM @ 3762 PSI, BHP 4175 08/06/2012 Drill Ahead AL1 00:00 00:45 0.75 10,650 10,713 PROD3 DRILL DRLG P Drilling ahead. 00:45 01:00 0.25 10,713 10,713 PROD3 DRILL WPRT P Weight transfer down @ 10713',pull BHA wiper,34k pick-up wt. Pull up 100'. RBIH 01:00 01:45 0.75 10,713 10,770 PROD3 DRILL DRLG P Drill ahead to 10,770' 01:45 04:30 2.75 10,770 10,770 PROD3 DRILL WPRT P Wiper,33k off BTM.Turn around just before billet,jog down 50'. Pull up past billet,still see 4k spike, continue wiper to the window. RBIH 04:30 07:00 2.50 10,770 10,920 PROD3 DRILL DRLG P Drill ahead 1.44 BPM @ 3723 PSI, 4165 BHP, 12.75 ECD, 120 ROP 07:00 10:45 3.75 10,920 10,920 PROD3 DRILL WPRT P Wiper 31k pu wt. Pull up past billet @ 10020', pumps down,just a slight bobble-wiper up for a tie in,for a+1' correction.Continue back down Page 12 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:45 14:45 4.00 10,920 11,070 PROD3 DRILL DRLG P Drill ahead 1.45 BPM @ 3945 PSI, 4220 BHP, 1.6 WOB,slow going starting at 11,025'.broke out @ 11,046'back up to 93 ROP 14:45 16:30 1.75 11,070 11,070 PROD3 DRILL WPRT P Wiper up 30k off BTM.Sent 5 X 5 sweep down.decided to pull a 1150' wiper. 16:30 19:00 2.50 11,070 11,178 PROD3 DRILL DRLG P Drill ahead 1.46 BPM @ 3843 PSI, BHP 4217 PSI, 80 ROP 1.22 WOB 10k surface wt. 19:00 20:48 1.80 11,180 8,500 PROD3 DRILL WPRT P No Weight Transfer, PUW 29K, Wiper to the window to clean hole. 20:48 22:12 1.40 8,500 11,180 PROD3 DRILL WPRT P Wiper back in hole, RIHW 13K 22:12 00:00 1.80 11,180 11,267 PROD3 DRILL DRLG P Drill Ahead, 1.46 bpm @ 3782 psi, BHP 4236, 1.8 WOB,2K surface Coil surface weight. 08/07/2012 TD Lateral AL1 11336', POOH, MU first liner section RIH to TD. POOH,MU second liner section, RIH 00:00 01:30 1.50 11,267 11,335 PROD3 DRILL DRLG P Drilling Ahead, 1.47 bpm,3813 psi, BHP 4271,3K Coil weight,WOB 1.3K, ROP 50fph 01:30 04:06 2.60 11,335 8,173 PROD3 DRILL WPRT P TD AL1 @ 11335', Pump 10/10 sweep,Wiper to the window. 04:06 04:30 0.40 8,173 11,336 PROD3 DRILL DLOG P RIH to RA Marker fora tie in, correction of+2.5'. RBIH tag @ 11,336' 04:30 09:30 5.00 11,336 0 PROD3 DRILL TRIP P lay in flo-pro liner pill,40 bbls. Continue out of hole,jetting tbg. 09:30 10:00 0.50 0 0 PROD3 DRILL SFTY P On surface,shut in SSSV,watch for no flow.Conduct PJSM. 10:00 11:00 1.00 0 0 PROD3 DRILL PULD P Lay down drilling BHA. 11:00 13:45 2.75 0 1,387 COMPZ CASING PUTB P PJSM. Pick-up liner, run#1. 13:45 17:15 3.50 1,387 11,334 COMPZ CASING RUNL P RIH W/AL1 liner run#1.See BTM flag for a+1'.Set liner @ 11,334'. Pump off,good. 17:15 17:27 0.20 11,334 8,478 COMPZ CASING DLOG P PUH and Tie into RA Marker 8478', No correction.Top of deployment sleeve is 9991' PUH to paint EOP flag at 8000' 17:27 20:03 2.60 8,478 0 COMPZ CASING RUNL P POOH 20:03 21:03 1.00 0 0 COMPZ CASING PULD P OOH,Shut SSSV, no flow. PJSM LD BHA 21:03 23:33 2.50 0 328 COMPZ CASING RUNL P PJSM, MU Liner BHA#17 23:33 00:00 0.45 328 COMPZ CASING RUNL P RIH with liner running BHA#17 08/08/2012 Finish setting ALA second liner section,top of liner at 9721'. Kick off of billet into AL2 lateral. Drill Ahead 00:00 02:30 2.50 1,796 8,234 COMPZ CASING RUNL P Continue Running in hole with second AL1 liner BHA#17, Bit Speed 20 fpm passing all Jewelry with Anchor Billet. 02:30 02:42 0.20 8,234 8,258 COMPZ CASING DLOG P Tie into Marker in the HRZ(7919'), correction of-12.5', No correction at flag. Close EDC adjust choke to maintain BHP. Page 13 of 18 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 02:42 03:12 0.50 8,258 8,424 COMPZ CASING RUNL P Continue into the hole, Set down 3-4K surface weight, No Down hole WOB. PUH weight 29.7k, RBIH little weight bobble RIH 03:12 04:30 1.30 8,424 9,990 COMPZ CASING RUNL P Continue in hole,Set down 2K. 04:30 04:42 0.20 9,990 9,986 COMPZ CASING RUNL P Orient and Set Anchor at 200 degrees ROHS.Anchored billet at 9723', PUH 31K 04:42 06:42 2.00 9,986 53 COMPZ CASING RUNL P POOH 06:42 07:00 0.31 53 53 COMPZ CASING SFTY P Shut in SSSV,watch for no flow. Conduct PJSM 07:00 08:00 1.00 53 0 COMPZ CASING PULD P Lay down BHA#17. 08:00 09:00 1.00 0 72 PROD4 DRILL PULD P PJSM,pick-up drilling BHA 09:00 12:00 3.00 72 9,722 PROD4 STK TRIP P RIH tie in for-12'correction. Dry tag TOB @ 9721'. 12:00 14:30 2.50 9,722 9,727 PROD4 STK WPST P Pick up. back on pumps, 1.47 BPM @ 3786 PSI ease down,TF 170 ROHS.start out @ 1 FPH,then go to 2'FPH 14:30 16:30 2.00 9,727 9,880 PROD4 DRILL DRLG P 5'past billet, Drill ahead 1.46 BPM @ 3832 PSI, ROP 70 1.16 WOB 16k surface weight. Drill down to 9760'. Pull up past billet with pumps down, drift looks good. RBIH and continue drilling. 16:30 17:30 1.00 9,880 8,510 PROD4 DRILL WPRT P Wiper up to window 31k off BTM 17:30 18:30 1.00 8,510 9,880 PROD4 DRILL WPRT P Wiper back in hole, RIHW 17k 18:30 20:00 1.50 9,880 10,020 PROD4 DRILL DRLG P BOBD 1.46 bpm 3760psi, BHP 4149, 13k surface weight. 20:00 20:36 0.60 10,020 9,000 PROD4 DRILL WPRT P Wiper, PUW 33k 20:36 21:18 0.70 9,000 10,020 PROD4 DRILL WPRT P Wiper back in hole, RIHW 16k 21:18 22:48 1.50 10,020 10,170 PROD4 DRILL DRLG P BOBD, 1.46bpm,3833psi, BHP 4185,Surface weight 13k 22:48 00:00 1.20 10,170 8,508 PROD4 DRILL WPRT P Wiper to the tubing tail, PUW 33k 08/09/2012 Drill AL2 Lateral 00:00 01:42 1.70 8,508 10,170 PROD4 DRILL WPRT P Wiper back in hole, RIHW 17k 01:42 03:30 1.80 10,170 10,320 PROD4 DRILL DRLG P BOBD, 1.42bpm, 3620psi, BHP 4181, ROP 140fph,Surface weight 12K. Start Mud swap 03:30 04:12 0.70 10,320 9,450 PROD4 DRILL WPRT P Wiper up to 9450', PUW 33k 04:12 04:48 0.60 9,450 10,320 PROD4 DRILL WPRT P Wiper back in hole, RIHW 04:48 06:09 1.35 10,320 10,470 PROD4 DRILL DRLG P BOBD 1.46bpm, 3622psi, BHP 4205, ROP 100 fph, 12k surface weight. 06:09 07:30 1.36 10,470 10,470 PROD4 DRILL WPRT P 1200'wiper. RBIH 07:30 09:15 1.75 10,470 10,620 PROD4 DRILL DRLG P Drill ahead 1.45 BPM @ 3900 PSI 4219 BHP 1.6 WOB 10k surface wt. 09:15 12:15 3.00 10,620 10,620 PROD4 DRILL WPRT P Wiper up to TT&tie in.33k off BTM. jog the 4.5"liner, RBIH tie in for a +1. Page 14 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:15 17:33 5.30 10,620 10,770 PROD4 DRILL DRLG P Drill ahead 1.44 BPM @ 3790 PSI, 4190 BHP, 1.30 WOB, 11.2 coil wt. 17:33 18:03 0.50 10,770 9,800 PROD4 DRILL WPRT P Wiper up hole, PUW 30k 18:03 18:33 0.50 9,800 10,770 PROD4 DRILL WPRT P Wiper back in hole, RIW 16k 18:33 21:03 2.50 10,770 10,920 PROD4 DRILL DRLG P Drilling Ahead 1.40 bpm,3660 psi, Surface weight 11k, ROP 70fph 21:03 22:51 1.80 10,920 8,200 PROD4 DRILL WPRT P Wiper to the window, PUW 31k 22:51 23:59 1.14 8,200 10,185 PROD4 DRILL WPRT P Wiper back in hole, RIHW 08/10/2012 Drill AL2 lateral as per plan 00:00 00:12 0.20 10,185 10,900 PROD4 DRILL WPRT P Continue wiper back in hole 00:12 01:48 1.60 10,900 11,015 PROD4 DRILL DRLG P BOBD, 1.45bpm at 3620psi, ROP 66fph, 5k surface weight,2k WOB 01:48 02:00 0.20 11,015 10,915 PROD4 DRILL WPRT P Drilling on Ankerite, BHA wiper 02:00 04:30 2.50 10,915 11,070 PROD4 DRILL DRLG P BOBD, 1.45 bpm at 3830, BHP 4284, ROP 4fph 04:30 06:00 1.50 11,070 11,070 PROD4 DRILL WPRT P Wiper to the Billet, PUW 30k. RBIH 06:00 07:45 1.75 11,070 11,173 PROD4 DRILL DRLG P Drill ahead 1.44 BPM @ 3980 PSI, 4283 BHP, 1.3 WOB, 70 ROP @ 11,173'having wt transfer issues. 07:45 08:00 0.25 11,173 11,173 PROD4 DRILL WPRT P Pull 200'wiper, RBIH 08:00 09:00 1.00 11,173 11,207 PROD4 DRILL DRLG P Drill ahead. Still having wt transfer problems. Pump 5 X 5 sweep 09:00 11:45 2.75 11,207 11,207 PROD4 DRILL WPRT P Wiper to window 31k off BTM 11:45 14:00 2.25 11,207 11,350 PROD4 DRILL DRLG P Drill ahead 1.4 BPM @ 4043 PSI, 4265 BHP,90 ROP, reach TD of 11,350'. 10 x 10 sweep already on the way down. 14:00 16:24 2.40 11,350 8,200 PROD4 DRILL WPRT P Wiper up to the TT, PUW 31k 16:24 18:24 2.00 8,200 11,350 PROD4 DRILL WPRT P Wiper back in hole, RIW 17k 18:24 19:54 1.50 11,350 8,500 PROD4 DRILL DISP P Lay in liner running pill with beads 19:54 21:54 2.00 8,500 0 PROD4 DRILL TRIP P POOH 21:54 22:12 0.30 0 0 PROD4 DRILL TRIP P OOH,Shut SSSV w/800psi, bleed pressure down and monitor for 15min. 0 PROD4 DRILL PULD PJSM LD Drilling BHA#18 22:12 23:12 1.00 0 0 COMPZ CASING RUNL P PJSM,MU first liner section, Kick while tripping tubing drill duration of 1min 40sec. 23:12 00:00 0.80 0 492 COMPZ CASING RUNL P Continue to MU first liner section 08/11/2012 TD AL2 Lateral section, RIH and set both liner sections to TD 11349'.MU RIH with AL2-01 Build drilling BHA. 00:00 01:45 1.75 0 1,237 COMPZ CASING PUTB P Cont PU Liner section#1 35jts+2 Pups 01:45 03:45 2.00 1,237 8,349 COMPZ CASING PUTB P RIH W/Al2 liner run#1 Page 15 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:45 04:45 1.00 8,349 11,349 COMPZ CASING RUNL P Stop @ flag correct depth(Minus 12 ft). Cont RIH,Tag bottom. Release off liner, PUH, Log RA tie in, no correcetion. 04:45 07:45 3.00 8,337 0 COMPZ CASING RUNL P Cont POOH, painted 6900 EOP flag 07:45 08:45 1.00 0 0 COMPZ CASING PUTB P On surface.Shut SSSV&watch for flow. PJSM, Lay down BHA. 08:45 13:15 4.50 0 1,502 COMPZ CASING RUNL P PJSM, Pick-up liner run#2,mu coil trak,and strip on. 13:15 17:15 4.00 1,502 10,155 COMPZ CASING RUNL P RIH,AL2 liner section#2 to flag @ 6900'-10'correction.Continue in hole Tag up @ 10,155. Pu wt 34.5k. Set back down, pump off. 17:15 19:15 2.00 10,155 0 COMPZ CASING RUNL P TOOH 19:15 19:33 0.30 0 0 COMPZ CASING RUNL P OOH,Shut SSSV w/800psi,Bleed down and monitor well for flow at the shaker. No Flow. 19:33 20:03 0.50 0 0 COMPZ CASING RUNL P LD AL2 second liner running BHA. 20:03 20:33 0.50 0 0 PROD5 DRILL BOPE P Perfom Function test of BOPE 20:33 21:15 0.70 0 0 PROD5 DRILL CTOP P RU and PT Drillers side PDL 21:15 22:33 1.30 0 0 PROD5 STK PULD P MU KOB BHA#21,with a 1.5 degree motor and RR HCC Bit.Test BHI tools 22:33 00:00 1.45 0 5,895 PROD5 STK TRIP P RIH W/drilling BHA. 08/12/2012 Run Completion in AL2 lateral,set billet top at 8695', Kick off of billet&drill build section to 9000', POOH for Lateral section BHA. RIH and drill from 9000'-9317' 00:00 00:30 0.50 5,895 7,940 PROD5 STK TRIP P Continue in hole 00:30 00:42 0.20 7,940 7,964 PROD5 STK DLOG P Tie in correction of-12' 00:42 01:06 0.40 7,964 8,695 PROD5 STK TRIP P Coniine to RIH 01:06 03:36 2.50 8,695 8,717 PROD5 STK WPST P RIW 18k, PUW 29.5k, 1.42bpm, 3580psi, BHP 4063. Kick off Billet as per plan. Near Bit Inclination is showing 92.1 degrees. 03:36 04:12 0.60 8,717 8,683 PROD5 DRILL WPST P Dry Drift KOP clean out of hole and in hole. PUW 29.5k 04:12 04:24 0.20 8,683 8,717 PRODS DRILL WPST P RBIH, RIW 15k 04:24 06:24 2.00 8,717 8,840 PROD5 DRILL DRLG P BOBD, 1.45bpm at 3583psi BHP 4066,Surface weight 14k,WOB 1900Ibs ROP 70fph 06:24 07:00 0.60 8,840 8,840 PROD5 DRILL WPRT P Wiper up the window, RBIH 07:00 09:15 2.25 8,840 9,000 PRODS DRILL DRLG P Drill ahead drilling build to 9000' 09:15 13:00 3.75 9,000 72 PROD5 DRILL TRIP P Trip out for different drilling BHA 13:00 15:00 2.00 0 72 PRODS DRILL PULD P On surface.Shut in SSSV,watch for flow.Conduct PJSM for BHA lay down. PJSM, pick-up drilling BHA. Perform injector maintenance,suck out grease out of the sump. 15:00 17:00 2.00 72 7,940 PROD5 DRILL TRIP P RIH W/drilling BHA Page 16 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 17:15 0.25 7,940 7,978 PROD5 DRILL DLOG P 7940' Log for tie in (-12') 17:15 17:45 0.50 7,978 9,000 PROD5 DRILL TRIP P Continue RIH 17:45 19:33 1.80 9,000 9,140 PROD5 DRILL DRLG P BOBD, 1.42bpm at 3620psi, 15k surface weight,WOB 2k, ROP 80fph 19:33 20:03 0.50 9,140 8,500 PROD5 DRILL WPRT P Wiper to the window, PUW 31k, BHP4130 20:03 20:45 0.70 8,500 9,140 PROD5 DRILL WPRT P Wiper back in hole, RIHW 16k, .8% drill solids, 1584'drilled on Mud System.Start new mud down hole 20:45 22:45 2.00 9,140 9,290 PRODS DRILL DRLG P BOBD, 1.45bpm @ 3740psi, BHP 4125,surface weight 13k, WOB 2k, ROP 80fph. New Mud at 9156'. 22:45 23:15 0.50 9,290 8,500 PRODS DRILL WPRT P Wiper to the window, PUW 30k 23:15 23:45 0.50 8,500 9,290 PRODS DRILL WPRT P Wiper back in hole, RIW 17k 23:45 00:00 0.25 9,290 9,317 PROD5 DRILL WPRT P BOBD, 1.45bpm, at 3598psi.15k surface weight,WOB 2k, ROP 92fph BHP 4051 psi 08/13/2012 TD AL2-01 Lateral,MU Liner and RIH 00:00 01:30 1.50 9,317 9,440 PRODS DRILL DRLG P OBD, 1.45bpm at 3600psi,WOB 1.6k, ROP 100fph, BHP 4064psi 01:30 02:06 0.60 9,440 8,500 PROD5 DRILL WPRT P Wiper to the window, PUW 30k 02:06 02:18 0.20 8,500 8,526 PROD5 DRILL DLOG P Tie in correction of plus 1' 02:18 02:48 0.50 8,526 9,440 PRODS DRILL WPRT P Wiper back in hole, RIW 15k 02:48 06:00 3.20 9,440 9,590 PROD5 DRILL DRLG P BOBD, 1.45bpm at 3468psi,WOB 1.5k, ROP 90fph 06:00 07:30 1.50 9,590 9,590 PRODS DRILL WPRT P Wiper to window, RBIH 07:30 09:30 2.00 9,590 9,740 PRODS DRILL DRLG P Drill ahead, 1.44 BPM @ 3809 PSI, ROP 84, BHP 4100,WOB 1.4, 13k coil wt. 09:30 11:00 1.50 9,740 9,740 PRODS DRILL WPRT P Wiper to 8710'31k off btm. RBIH 11:00 13:00 2.00 9,740 9,890 PRODS DRILL DRLG P Drill ahead, 1.42 BPM @ 3800 PSI, BHP 4092, 1.43 WOB,65 ROP Pump 10X 10 sweep to time out@ TD. 13:00 14:45 1.75 9,890 8,500 PRODS DRILL WPRT P Reach TD @ 9890'.Wiper up W/10 X 10 sweep,wipe up to the TT.Jog the 4.5"liner. 14:45 15:00 0.25 8,500 8,600 PRODS DRILL DLOG P Log for a+2'correction. 15:00 15:45 0.75 8,600 9,891 PRODS DRILL WPRT P Continue RIH,tag BTM @ 9891.0 15:45 18:00 2.25 9,891 72 PRODS DRILL TRIP P Liner beads at the bit,start laying in 30 bbls in the open hole,trip out to surface while jetting @ max rate. 18:00 20:00 2.00 72 0 PRODS DRILL PULD P Conduct PJSM. Lay down drilling BHA. 20:00 23:30 3.50 0 1,491 COMPZ CASING PUTB P PJSM for liner run. Pick-up 43 jts. Mu Coil trak BHA,strip on. 23:30 00:00 0.50 1,491 6,290 COMPZ CASING RUNL P RIH Page 17 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/14/2012 24 hr Summary Release AL2-01 liner 9891',TOL 8443'.Swap well to SW and freeze protect. Undeploy BHA,Set BPV. Prepare to swap reels 00:00 02:00 2.00 6,290 9,891 COMPZ CASING RUNL P Continue to run in hole with liner. Correction at the flag of minus 11' 02:00 03:00 1.00 9,891 7,900 COMPZ CASING RUNL P No correction at the TD flag,Tag BTMat 9891', PUW 38k Set back down and pump 1.27bpm release from liner, PUW 30k 03:00 03:12 0.20 7,900 7,932 DEMOB WELLPF DISP P Displace well over to SW. POOH to tie in to the HRZ correction of plus 3' 03:12 04:12 1.00 7,932 2,500 DEMOB WELLPF RUNL P POOH 04:12 06:12 2.00 2,500 0 DEMOB WELLPF FRZP P Freeze Protect well 06:12 08:12 2.00 0 0 DEMOB WELLPF RUNL P OOH, PJSM-Pressure undeploy Liner running BHA 08:12 09:42 1.50 0 0 DEMOB WELLPF NUND P Flush surface lines with inhibitor 09:42 11:12 1.50 0 0 DEMOB WHDBO NUND P PJSM-Set BPV 11:12 14:12 3.00 0 0 DEMOB WHDBO CTOP P PJSM-RU and Pump N2 to blowdown Coiled Tubing Reel. 14:12 17:42 3.50 0 0 DEMOB WHDBO CTOP P Continue to flush surface lines 17:42 18:12 0.50 0 0 DEMOB WHDBO CTOP P Crew change, PJSM 18:12 00:00 5.80 0 0 DEMOB WHDBO CTOP P Unstab CT,secure to reel. RD old reel.Swap out reels 08/15/2012 ND BOP.Wait on Trucks. 00:00 03:00 3.00 0 DEMOB WHDBO NUND P ND BOP's 03:00 06:00 3.00 DEMOB WHDBO DMOB P Wait on trucks Page 18 of 18 o rteWill BAKER PRINT DISTRIBUTION LIST HUGHES COMPANY ConocoPhillips, Alaska Inc. INTERMEDIATE FINAL Yes tmandatory) WELL NAME 3N-11AL1 RUN NUMBER (mandatory) FIELD Kuparuk BH SALESMAN Woods,Jim (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandate n yl STATE Alaska PAGE OF (mandatory) LOG DATE: August 7,2012 TODAYS DATE: 8/27/2012 mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY CD (FIELD FINAL digital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Oh 1-KIN I5 #OF COPIES #OF COPIES 1 ConocoPhillips Alaska,Inc. 1 NSK Wells Aide,NSK 69 ATfN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC 1 1 Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3 BP 1 1 Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP 1 1 Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 Brandon Tucker,NRT 1 State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 4 4 0 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 Letter of Transmittal BAKER Date: August 17, 2012 HUGHES To: From: Christine Mahnken Carl Ulrich/ Sachin Gandra AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage,Alaska 99501 Anchorage,Alaska 99515 Please find enclosed the directional survey data for the following well(s): ' 05 3N-11AL1 � a ' 0 RECEIVED 3N-11AL2-01,A O, 2 AUG 2 0 3N-11AL3 2012 ! t l 4 AOGCC 4 (5) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files -4/YL 1),L-e,ikt4 0112 - 0 '[5. Note: Please feel free to send us an email in place of ret mai ) Sachin Gandra, Baker Hughes, Project Engineer Sachin.Gandra@BakerHughes.com Carl.Ulrich, Baker Hughes, Survey Manager Carl.Ulrich@BakerHughes.com LASEA SEAN PARNELL, GOVERNOR 0 ALASKA OIL AND GAS 333 W 7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 L. Gantt CTD Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N-11AL1 ConocoPhillips Alaska, Inc. Permit No: 212-096 (revised) Surface Location: 1561' FSL, 155' FEL, SEC. 29, T13N, R9E, UM Bottomhole Location: 158' FNL, 2464' FWL, SEC. 29, T13N, R9E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to redrill the above referenced service well. This permit supersedes and replaces the permit previously issued for this well dated July 19, 2012. The permit is for a new wellbore segment of existing well 3N-11A, Permit No 212-095, API 50-029-21580-01. Injection should continue to be reported as a function of the original API number stated above. 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, 44 Cathy P' Foerster Chair (� DATED this / day of August, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) REC EPI' STATE OF ALASKA AUG 0 6 ZQDQASKA OIL AND GAS CONSERVATION COMMISSION �n± j'� PERMIT TO DRILL 15 r AO G C v 20 AAC 25.005 1 a.Type of Work- -, 1 b Proposed Well Class' Development-Oil ❑ Service-Winj a -Single Zone ❑✓ 1 c Specify if well is proposed for: Drill ❑ Re-drill ❑i 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 ❑Single Well 11.Well Name and Number ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • 3N-11AL1 3.Address 6 Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 11335 . TVD: 6290' - Kuparuk River Field 4a Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1561'FSL, 155'FEL,Sec.29,T13N,R9E, UM . ADL 25521,25512 - Kuparuk River Oil Pool - Top of Productive Horizon: 8 Land Use Permit: 13.Approximate Spud Date: 1538'FSL, 1088'FEL, Sec.20,T13N,RO9E,UM 2557,2553 8/6/2012 Total Depth: 9.Acres in Property 14 Distance to 158'FNL,2464'FWL,Sec.29,T13N,RO9E,UM 2560 Nearest Property 11500 - 4b Location of Well(State Base Plane Coordinates-NAD 27) 10.KB Elevation above MSL: , 68 feet 15.Distance to Nearest Well Open Surface:x- 518246 - y- 6013799 • Zone- 4 GL Elevation above MSL• 33.8 feet to Same Pool. 3N-09,1020 16 Deviated wells: Kickoff depth: 10020- ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25 035) Maximum Hole Angle 98' deg Downhole:3766 psig Surface:3125 psig • 18 Casing Prosram: Specifications Top - Setting Depth -Bottom Cement Quantity,c f or sacks Hole Casing Weight Grade Coupling Length _ MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 1610' 9725' 6460' 11335' 6378' 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) 8790' 6637' 8682' 6560' Casing Length Size Cement Volume MD ND Conductor/Structural 16" 250 sx CSII 115' _ 115' Surface 9.625" 1300 sx ASAI,350 sx Class G 4558' 3632' Intermediate 7" 300 sx Class G,175 sx AS I 8777' 6627' Production Liner 4.5" s 15 bbls Class G w/GASBLOK 8625' 6519' Perforation Depth MD(ft): Perforation Depth ND(ft): perfs cemented off at 8420'-8589' 6374'-6493' 20.Attachments. Property Plat❑ BOP Sketch O Drilling Program❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25 050 requirements E 21 Verbal Approval Commission Representative. Guy Schwartz Date 8/3/2012 C 22. I hereby certify that the foregoing is true and correct. Contact Gary Eller @ 263-4172 1�� Printed Nam . G tt / Title CTD Supervisor '\ • SignaturQ� ,/f4f 4,, _/` / - 6Airt,LL Phon 263-4021 Date 3 - (/j, -- i 7._,l� j 7 c f ( Commission Use Only Permit to Drill API Number 1 Permit Appro I I See cover letter Number 2—C9 , 50- c.6 Date: 1 I g I Pa. for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed n2-pane,gas hydrates,or gas contained in shales 1� Q�'� �T / L, Samples req'd: Yes ❑ NoMud log req'd: Yes ❑ No El/ Other O/�fyr t40 / ' -11?"4 4-M H2S measures: Yes El/ No ❑ Directional svy req'd: Yes El/ No ❑ Q ��') APPROV D BY THE COMMISSION DATE 6f//�'-g-(,=.\1 Iktt,t5.11te\ I ,.t I / ONER -/Form 10-401 (Revised 7 009) This permit is valid fpr;4(}t{pn1h ri ef pproval(2FAAC 25.005(g)) Submit i u li st %�.\.'tqLvvv ` ` `��.JJJt ` / ( rL ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 August 6, 2012 RECE161/2.0! VED Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission AUG 0 6 2012 333 West 7th Avenue Suite 100 ppGCC Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a revision to the approved Permit to Drill (PTD) application for well 3N-11AL1 (PTD#212-096). Verbal approval to continue with drilling operations on the AU lateral was granted by Guy Schwartz via e-mail on Friday, August 3. A revision is needed due to a change in the kick-off point by more than 500'. Additionally, the TD location has been moved further west in response to an updated geologic interpretation of faulting in the area. The AL1 lateral is targeting the Kuparuk A3 sand. Attached to this application are the following documents that explain the revision to the 3N-11AL1 directional plan. — Revised drilling program summary — Revised Permit to Drill application form for 3N-11AL1 — Updated Directional plan for 3N-11AL1 — Updated proposed wellbore schematic If you have any questions or require additional information please contact me at my office 907-263-4172. incerely, Gary Eller ConocoP lips Alaska Coiled Tubing Drilling Engineer Kuparuk CTD Lateral NABOR.ALASKA 3N-11AL1 Revision CIJ Application for Permit to Drill Document 2AC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(t)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 253005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 2 (Requirements of 20 AAC 25.005(c)(6)) 2 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Pressure Deployment of BHA 5 Liner Running 5 14. Disposal of Drilling Mud and Cuttings 5 (Requirements of 20 AAC 25.005(c)(14)) 5 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 16. Quarter Mile Injection Review (for injection wells only) 6 (Requirements of 20 AAC 25.402) 6 17. Construction of Injection Wells 6 (Requirements of 20 AAC 25.412) 6 ORIGINAL Page 1 of 6 Revised:August 6, 2012 Revised PTD Application for KRU 3N-11AL1 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) There is one proposed lateral described in this document: KRU 3N-11AL1. It will be classified as a"Service— Water Injection"well. Updates to this document have been shown in blue font. 2. Location Summary (Requirements of 20 AAC 253005(c)(2)) This lateral will target the A2 sand in the Kuparuk reservoir. See the attached 10-401 forms for surface and subsurface coordinates. 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 3500 psi. Using a maximum potential formation pressure of 3766 psi, the maximum potential surface pressure is 3125 psi assuming a gas gradient of 0.1 psi/ft. See the"Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) The most recent static BHP measurement in well 3N-11 was taken in December 2011 recording a pressure of 3441 psi at 8504' MD, 6433' TVD for a 10.3 ppg gradient. During the workover of January 2012 however the fluid weight had to be increased to 11.3 ppg (equivalent of 3780 psi SBHP) to maintain pressure overbalance. The proposed 3N-11 CTD laterals will approach existing production wells so our expectation is that we will not encounter significantly increased formation pressure. The most likely sources of elevated formation pressure, if we encounter such, would be from injection wells 3N-13 to the southeast and 3N-04 to the southwest. These wells have recent formation pressures of 3755 psi (11.2 ppg EMW, Feb-12) and 3715 psi (11.3 ppg EMW, Apr- 12) respectively. Maximum potential formation pressure is based on the April 2012 pressure from 3N-04 to the southwest, which had measured formation pressure of 3715 psi at 7630' MD, 6323' ND for a gradient of 11.3 ppg. In 3N-11A this equates to a maximum potential formation pressure of 3766 psi (8470' MD, 6409' TVD) and a maximum potential surface pressure of 3125 psi assuming a gas gradient to surface. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled. 3N pad is a water only injection pad. It is unlikely that an influx while drilling will produce a significant amount of gas. Potential Causes of Hole Problems (Requirements of 20 AA C 25.005(c)(4)(c)) The major expected downhole risk in the 3N-11 laterals is hole stability due to int bedded shales and silts in the A-sand. We will mitigate hole instability by maintaining a minimum ECD target 12.0 ppg EMW at the window while drilling the CTD laterals, as well as using mud additives that minimize the ical instability. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) Each of the 3N-11 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so formation integrity tests are not required. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Page 2 of 6 ORIGINAL Revised:August 6,2012 Revised PTD Application for KRU 3N-11AL1 New Completion Details Liner Liner Liner Liner Lateral Name Top MD Btm Top Btm Liner Details MD TVD TVD 3N-11AL1 9725' 11,335' 6460' 6378' 23/8', 4.7#, L-80, ST-L slotted liner; aluminum billet on top Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62 H-40 Welded 0' 115' 0' 115' Surface 9%" 36 J-55 BTC 0' 4558' 0' 3632' 3520 2020 Casing 7" 26 J-55 BTC 0' 8777' 0' 6627' 4980 4320 Scab liner 4W 12.6 L-80 IBT& BTC 8130' 8625' 6168' 6519' 8430 7500 Tubing 3W 9.3 L-80 EUE 8rd-Mod 0' 8173' 0' 6199' 10,160 10,530 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036 for thru-tubing drilling operations so no diverter system is required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based Biozan brine or used drilling mud (-9.5 ppg) — Drilling operations: Chloride-based Flo-Pro Flo Vis mud (9.5 ppg). This mud weight alone will not hydrostatically overbalance formation pressure in the 3N-11 motherbore, but overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 3N-11 contains a subsurface safety valve (SSSV) at 1796' MD. The SSSV will be used to pressure deploy the liner in lieu of loading the well with completion fluid. In the event that the SSSV becomes inoperable, the well will be loaded with 12.0 ppg sodium bromide completion fluid in order to maintain pressure over-balance while picking up liner. — Emergency Kill Weight fluid: Two well bore volumes (-200 bbl) of 13.1 ppg emergency kill weight fluid will be within a short drive of the rig during drilling operations. Page 3 of 6 ORIGINA L Revised:August 6, 2012 Revised PTD Application for KRU 3N-11AL1 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 pressure over- balance to the formation. In the 3N-11 laterals we will target a constant BHP of 12.0 ppg EMW at the window. If increased formation pressure is encountered, mud weight or choke pressure will be increased to maintain overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability but not necessarily for well control. Pressure at the 3N-11AL1 Window(8470' MD, 6409' TVD, 6341' SSTVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (11.3 ppg) 3766 psi 3766 psi Mud Hydrostatic (9.5 ppg) 3166 psi 3166 psi Annular friction (i.e. ECD, 0.095 psi/ft) 808 psi 0 psi Mud + ECD Combined 3974 psi 3166 psi (no choke pressure) (overbalanced (underbalanced —208 psi) —600 psi) Target BH at Window(12.0 ppg) 3999 psi 3999 psi Choke Pressure Required to Maintain 25 psi 840 psi arget UH-' 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 3N-11 is an NC-sand injector that was recently worked over to install a 4'/z" scab liner over damaged 7" casing near the existing Kuparuk perfs. The existing NC-sand perfs were squeezed with cement as part of that workover, and our plans are to not re-perf the C-sand. Four proposed A-sand CTD laterals will increase reservoir exposure and improve waterflood sweep. A separate sundry request (311-372)was approved for the abandonment of the original 3N-11 completion in preparation for these CTD sidetracks. A mechanical whipstock has been placed in the 4%" scab liner at the planned kickoff point. The 3N-11A sidetrack exited the 4'/z" liner and 7" casing at 8472' MD and will targeted the A1/A2 sands south of the existing well. The BHA became stuck while drilling ahead at 10,923' MD. Page 4 of 6 ORIGINAt_ Revised: August 6, 2012 . Revised PTD Application for KRU 3N-11AL1 The 3N-11AL3 lateral kicked off from an aluminum billet at 10,430' MD and targeted the A2 sand. It was drilled to a TD of 11,366' MD and completed with 2%" slotted liner from TD to 10,020' with an aluminum billet on the liner top. The 3N-11AL1 lateral kicked off from the aluminum billet at 10,020' MD and is targeting the A3 sand. Verbal approval to continue uninterrupted drilling operations on the AL1 lateral was granted August 3. We are currently drilling at 10,920'with a projected TD of 11,335'. It will be completed with 2%' slotted liner from TD to 9725'with an aluminum billet on the liner top for the kickoff of the AL2 lateral. Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment the steps listed above are conducted in reverse. Liner Running — Since 3N-11 is equipped with a SSSV, the CTD laterals will not need to be displaced to an over-balancing fluid prior to running liner unless the SSSV fails. In that case, fluid of sufficient density to over-balance the formation will be used to provide well control. See the"Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" pipe rams provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) — No annular injection on this well. — Class II liquids to KRU 1R Pad Class II disposal well — Class II drill solids to Grind & Inject at PBU Drill site 4 — Class I wastes will go to Pad 3 for disposal. Page 5 of 6 a Revised:August 6,2012 Revised PTD Application for KRU 3N-11AL1 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — There are no other affected owners — Please see attached 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 and nearest well in the same pool. Distance Distance to Directional to Unit Nearest Lateral Name Plan Boundary Well Nearest Well 3N-11AL1 03 11,500' 1,020' 3N-09 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) 3N-09 is the only well within the 1/4 mile scan in the pool. The CBL for 3N-09 shows good cement. Nearest Distance to Lateral Name Well in Nearest Comments Pool Well in Pool 3N-11AL1 3N-09 1,020' Waivered well for IA x OA Communication. MITOA Passed 7/6/2010 17. Construction of Injection Wells (Requirements of 20 AAC 25.412) ConocoPhillips received a variance on the packer placement requirements of 20 AAC 25.412(b) for the 3N-11 rig workover. The variance was approved with the sundry number 311-372. Page 6 of 6 ORIGINAL Revised:August 6,2012 N b 0 o ❑ 3 (a a 0 0 g o co o o coc') 0 co CO 0) 0 ,- O - O O .- _ o N .-- t N ❑ C -0 © ©iim .c D O I- N co as N C2 p Q, Q 6 Co U) JN J M N 00 N _ J Q to ❑ Q C_ Co E co0 0 so N ❑ co `° 1r j 2 0 Cil ti as N 0 co in _ ❑ ct 0N � g a)co i II O N co Cl) -p co — m Ua (1) , c CO v 0 N CO E a) Q a I— F a 2` 0 J II CP N a) co Q 0 C (U C g — u1 c ca a XX 03 o (Y c of XEN o0_ o11 Nzo co co (B G W N- C X O O U) ai U co I r) _ in co co 11r11 0 N CV N N Y (-N Y Y NZ �` ❑ N- E.61 06 (6 (E ❑ Lll M Cr) M P M CO 4 CO CO 0 N O N O N H p00 co f— ,_ 'O t : O _ Al 00 V' d No N O U O - < N Y A c - ENJ 4 i II Y • 111 M Ill C) s- 4-.4 s_ N II!i1IIi CD CI Pl! t U .a O N O O L I En (0 0 000 c ❑ o 1- Er) -3 ❑ -o 1 n❑ _ N (n ❑ r I * mo -02 N 0 -) (a C O Z N IM Co U 00 (0 CO V © N Ca co T 00 LO L".I C) ❑ (n "Cr r..- < CO F CO (ro u) 2 co @) ORIGINAL ConocoPhilli s p Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3N Pad 3N-11 3N-11AL1 Plan: 3N-11AL1_wp03 Standard Planning Report 04 August, 2012 BAKER HUGHES ! G1NAL I% Baker Hughes INTEQ F,r'- ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3N-11 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3N-11 @ 68.00ft(3N-11) Site: Kuparuk 3N Pad North Reference: True Well: 3N-11 Survey Calculation Method: Minimum Curvature Wellbore: 3N-11 AL1 Design: 3N-11AL1_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 3N Pad 1 Site Position: Northing: 6,013,799.17ft Latitude: 70°26'55.957 N From: Map Easting: 517,946.19ft Longitude: 149°51'12.938 W, Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.14 ° j Well 3N-11 Well Position +N/-S 0.00 ft Northing: 6,013,799.32 ft • Latitude: 70°26'55.951 N +E/-W 0.00 ft Easting: 518,246.03 ft • Longitude: 149°51'4.133 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 33.80ft Wellbore 3N-11AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (') (°) (nT) BGGM2011 8/1/2012 16.11 80.00 57,386 Design 3N-11AL1_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,995.79 Vertical Section: Depth From(ND) +N/-S +El-W Direction (ft) (ft) (ft) (°) -33.80 0.00 0.00 240.00 Plan Sections Measured ND Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) r) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 9,995.79 93.69 207.80 6,334.98 4,436.03 -1,715.20 0.00 0.00 0.00 0.00 10,020.00 92.98 211.66 6,333.57 4,415.04 -1,727.18 16.18 -2.93 15.94 100.32 10,050.00 95.73 213.98 6,331.29 4,389.91 -1,743.39 12.00 9.18 7.75 40.00 10,080.00 97.13 217.32 6,327.93 4,365.69 -1,760.76 12.00 4.65 11.13 67.00 10,180.00 95.52 229.29 6,316.87 4,293.51 -1,828.82 12.00 -1.61 11.97 97.00 10,305.00 94.82 214.24 6,305.54 4,200.92 -1,911.49 12.00 -0.56 -12.04 268.00 10,405.00 90.07 203.21 6,301.26 4,113.47 -1,959.41 12.00 -4.75 -11.03 247.00 10,605.00 90.47 227.21 6,300.30 3,951.25 -2,073.88 12.00 0.20 12.00 89.00 10,705.00 88.54 215.36 6,301.17 3,876.25 -2,139.74 12.00 -1.94 -11.84 260.70 10,945.00 90.64 244.09 6,302.93 3,722.74 -2,320.93 12.00 0.88 11.97 86.00 11,025.00 98.49 249.64 6,296.56 3,691.43 -2,394.17 12.00 9.81 6.94 35.00 11,110.00 90.06 255.40 6,290.23 3,666.02 -2,474.92 12.00 -9.92 6.77 145.50 11,335.00 90.05 228.40 6,290.02 3,561.01 -2,671.56 12.00 0.00 -12.00 270.00 8/4/2012 5:23::25PM Page 2 COMPASS 2003.16 Build 69 r\ i1 t� 1 ',: _ N-' Baker Hughes INTEQ Wil 1...-- ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3N-11 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level ' Project: Kuparuk River Unit MD Reference: 3N-11 @ 68.00ft(3N-11) Site: Kuparuk 3N Pad North Reference: True Well: 3N-11 Survey Calculation Method: Minimum Curvature Wellbore: 3N-11AL1 Design: 3N-11AL1_wp03 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S +E/-W Section Rate Azimuth Northing Easting (ft) (') (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 9,995.79 93.69 207.80 6,334.98 4,436.03 -1,715.20 -732.61 0.00 0.00 6,018,230.69 516,520.15 TIP 10,000.00 93.57 208.47 6,334.71 4,432.32 -1,717.18 -729.04 16.18 100.32 6,018,226.98 516,518.18 c 10,020.00 92.98 211.66 6,333.57 4,415.04 -1,727.18 -711.74 16.18 100.37 6,018,209.68 516,508.22 KOP 10,050.00 95.73 213.98 6,331.29 4,389.91 -1,743.39 -685.14 12.00 40.00 6,018,184.51 516,492.07 3 10,080.00 97.13 217.32 6,327.93 4,365.69 -1,760.76 -657.98 12.00 67.00 6,018,160.25 516,474.76 1 4 10,100.00 96.83 219.72 6,325.50 4,350.16 -1,773.13 -639.51 12.00 97.00 6,018,144.69 516,462.441 10,180.00 95.52 229.29 6,316.87 4,293.51 -1,828.82 -562.95 12.00 97.29 6,018,087.91 516,406.89' 5 10,200.00 95.44 226.88 6,314.96 4,280.21 -1,843.63 -543.48 12.00 -92.00 6,018,074.58 516,392.11 10,300.00 94.85 214.85 6,305.96 4,205.03 -1,908.67 -449.56 12.00 -92.23 6,017,999.24 516,327.26 10,305.00 94.82 214.24 6,305.54 4,200.92 -1,911.49 -445.06 12.00 -93.31 6,017,995.13 516,324.45 6 10,400.00 90.31 203.76 6,301.28 4,118.05 -1,957.42 -363.85 12.00 -113.00 6,017,912.16 516,278.73 10,405.00 90.07 203.21 6,301.26 4,113.47 -1,959.41 -359.83 12.00 -113.47 6,017,907.57 516,276.75 7 10,500.00 90.27 214.61 6,300.98 4,030.44 -2,005.26 -278.61 12.00 89.00 6,017,824.44 516,231.11 10,600.00 90.46 226.61 6,300.34 3,954.67 -2,070.23 -184.46 12.00 89.03 6,017,748.51 516,166.33: 10,605.00 90.47 227.21 6,300.30 3,951.25 -2,073.88 -179.59 12.00 89.11 6,017,745.09 516,162.691, 8 1 10,700.00 88.63 215.96 6,301.05 3,880.31 -2,136.83 -89.61 12.00 -99.30 6,017,674.00 516,099.92 10,705.00 88.54 215.36 6,301.17 3,876.25 -2,139.74 -85.05 12.00 -99.21 6,017,669.93 516,097.02 9 10,800.00 89.35 226.74 6,302.93 3,804.74 -2,202.02 4.63 12.00 86.00 6,017,598.28 516,034.92 10,900.00 90.24 238.70 6,303.28 3,744.28 -2,281.44 103.65 12.00 85.79 6,017,537.63 515,955.66 10,945.00 90.64 244.09 6,302.93 3,722.74 -2,320.93 148.62 12.00 85.75 6,017,516.00 515,916.22 10 11,000.00 96.04 247.89 6,299.73 3,700.41 -2,371.06 203.19 12.00 35.00 6,017,493.55 515,866.16 11,025.00 98.49 249.64 6,296.56 3,691.43 -2,394.17 227.70 12.00 35.22 6,017,484.51 515,843.07 11 11,100.00 91.05 254.72 6,290.33 3,668.60 -2,465.26 300.68 12.00 145.50 6,017,461.51 515,772.04 11,110.00 90.06 255.40 6,290.23 3,666.02 -2,474.92 310.33 12.00 145.92 6,017,458.90 515,762.39 12 11,200.00 90.05 244.60 6,290.15 3,635.28 -2,559.36 398.84 12.00 -90.00 6,017,427.96 515,678.03: 11,300.00 90.05 232.60 6,290.05 3,583.27 -2,644.56 498.62 12.00 -90.01 6,017,375.74 515,592.97 ° 11,335.00 90.05 228.40 6,290.02 ' 3,561.01 -2,671.56 533.14 12.00 -90.02 6,017,353.42 515,566.03 TD at 11335.00 8/4/2012 5:23:25PM Page 3 COMPASS 2003.16 Build 69 D 1r 1 `Y,, 'L) ,, u... Baker Hughes INTEQ Fri..- ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3N-11 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3N-11 @ 68.00ft(3N-11) Site: Kuparuk 3N Pad North Reference: True Well: 3N-11 Survey Calculation Method: Minimum Curvature Wellbore: 3N-11 AL1 Design: 3N-11 AL1_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 j 3N-11A_CTD Fault4( 0.00 0.00 6,394.00 4,382.09 -2,323.27 6,018,175.27 515,912.27 70°27'39.044 N 149°52'12.398 W', -plan misses target center by 455.13ft at 10342.19ft MD(6302.98 TVD,4169.54 N,-1931.25 E) -Polygon Point 1 6,394.00 4,382.09 -2,323.27 6,018,175.27 515,912.27 Point 2 6,394.00 4,175.87 -2,240.76 6,017,969.27 515,995.28 Point 3 6,394.00 3,964.41 -2,057.24 6,017,758.28 516,179.29 Point 4 6,394.00 4,175.87 -2,240.76 6,017,969.27 515,995.28 3N-11A_CTD Fault3( 0.00 0.00 6,394.00 4,170.35 -2,034.75 6,017,964.26 516,201.28 70°27'36.963 N 149°52'3.919 W -plan misses target center by 130.60ft at 10387.56ft MD(6301.41 TVD,4129.37 N,-1952.27 E) -Polygon Point 1 6,394.00 4,170.35 -2,034.75 6,017,964.26 516,201.28 Point 2 6,394.00 4,387.06 -1,906.22 6,018,181.27 516,329.26 Point 3 6,394.00 4,624.81 -1,789.64 6,018,419.28 516,445.25 Point4 6,394.00 4,387.06 -1,906.22 6,018,181.27 516,329.26 3N-11A_CTD Faultl ( 0.00 0.00 6,394.00 5,112.71 -1,338.34 6,018,908.23 516,895.31 70°27'46.232 N 149°51'43.461 W -plan misses target center by 776.79ft at 9995.79ft MD(6334.98 TVD,4436.03 N,-1715.20 E) -Polygon Point 1 6,394.00 5,112.71 -1,338.34 6,018,908.23 516,895.31 Point 2 6,394.00 4,996.44 -1,232.61 6,018,792.23 517,001.32 Point 3 6,394.00 4,818.03 -1,066.02 6,018,614.25 517,168.33 3N-11AL3 Polygon(cc 0.00 0.00 68.00 3,989.46 -2,083.20 6,017,783.27 516,153.27 70°27'35.183 N 149°52'5.341 W -plan misses target center by 6232.42ft at 10605.00ft MD(6300.30 TVD,3951.25 N,-2073.88 E) -Polygon Point 1 68.00 3,989.46 -2,083.20 6,017,783.27 516,153.27 Point 2 68.00 3,928.69 -2,183.36 6,017,722.26 516,053.27 Point 3 68.00 3,889.94 -2,286.46 6,017,683.26 515,950.28 Point 4 68.00 3,735.86 -2,678.87 6,017,528.23 515,558.29 Point 5 68.00 3,633.48 -2,940.14 6,017,425.23 515,297.29 Point 6 68.00 3,427.25 -2,854.63 6,017,219.23 515,383.30 Point 7 68.00 3,532.61 -2,582.35 6,017,325.24 515,655.29 Point 8 68.00 3,700.70 -2,194.90 6,017,494.26 516,042.29 Point 9 68.00 3,814.29 -2,019.61 6,017,608.27 516,217.29 3N-11AL1_73(copy)i 0.00 0.00 6,300.00 3,934.38 -2,053.34 6,017,728.27 516,183.27 70°27'34.642 N 149°52'4.463 W -plan misses target center by 26.35ft at 10601.53ft MD(6300.33 TVD,3953.62 N,-2071.34 E) -Point 3N-11AL1_T5(copy)1 0.00 0.00 6,290.00 3,694.28 -2,426.98 6,017,487.28 515,810.26 70°27'32.279 N 149°52'15.439 W -plan misses target center by 13.84ft at 11055.84ft MD(6292.83 TVD,3681.31 N,-2423.05 E) -Point 3N-11AL1_T4(copy)i 0.00 0.00 6,303.00 3,721.02 -2,320.90 6,017,514.28 515,916.26 70°27'32.543 N 149°52'12.322 W -plan misses target center by 1.57ft at 10945.66ft MD(6302.93 TVD,3722.45 N,-2321.53 E) -Point 3N-11 CTD Polygon(1 0.00 0.00 68.00 5,125.00 -647.21 6,018,922.21 517,586.34 70°27'46.354 N 149°51'23.152 W' -plan misses target center by 6394.55ft at 9995.79ft MD(6334.98 TVD,4436.03 N,-1715.20 E) -Polygon Point 1 68.00 5,125.00 -647.21 6,018,922.21 517,586.34 Point 2 68.00 5,493.63 -894.35 6,019,290.20 517,338.32 Point 3 68.00 5,445.08 -1,503.53 6,019,240.16 516,729.32 Point4 68.00 4,803.97 -1,899.11 6,018,598.15 516,335.35 Point 5 68.00 4,061.92 -2,326.93 6,017,855.13 515,909.39 Point 6 68.00 3,179.50 -2,608.07 6,016,972.11 515,630.44 Point 7 68.00 3,191.30 -2,105.99 6,016,985.14 516,132.44 Point 8 68.00 4,079.82 -1,868.84 6,017,874.15 516,367.39 Point 9 68.00 5,107.32 -1,200.31 6,018,903.18 517,033.34 Point 10 68.00 5,150.92 -1,028.19 6,018,947.20 517,205.33 8/4/2012 5:23:25PM Page 4 COMPASS 2003.16 Build 69 ORIGINAL ♦•' Baker Hughes INTEQ (f'' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3N-11 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3N-11 @ 68.00ft(3N-11) Site: Kuparuk 3N Pad North Reference: True Well: 3N-11 Survey Calculation Method: Minimum Curvature Wellbore: 3N-11AL1 Design: 3N-11 AL1_wp03 Point 11 68.00 4,890.20 -742.78 6,018,687.20 517,491.35 3N-11AL1_T1 (copy)i 0.00 0.00 6,319.00 4,310.81 -1,809.38 6,018,105.25 516,426.29 70°27'38.344 N 149°51'57.297 W -plan hits target center -Point 3N-11A_CTD Fault5( 0.00 0.00 6,394.00 3,509.06 -1,942.37 6,017,303.27 516,295.27 70°27'30.459 N 149°52'1.199 W -plan misses target center by 403.90ft at 10800.00ft MD(6302.93 TVD,3804.74 N,-2202.02 E) -Polygon Point 1 6,394.00 3,509.06 -1,942.37 6,017,303.27 516,295.27 Point 2 6,394.00 3,058.80 -1,854.44 6,016,853.27 516,384.30 Point 3 6,394.00 2,652.59 -1,782.41 6,016,447.28 516,457.31 Point4 6,394.00 3,058.80 -1,854.44 6,016,853.27 516,384.30 3N-11AL1_T2(copy)i 0.00 0.00 6,304.00 4,200.07 -1,919.66 6,017,994.26 516,316.28 70°27'37.255 N 149°52'0.537 W -plan misses target center by 6.42ft at 10309.78ft MD(6305.14 TVD,4196.97 N,-1914.16 E) -Point 3N-11AL1 T6 0.00 0.00 6,290.00 3,641.57 -2,544.12 6,017,434.28 515,693.25 70°27'31.761 N 149°52'18.880 W -plan hits target center -Point 3N-11AL1 T7 0.00 0.00 6,290.00 3,549.85 -2,661.37 6,017,342.29 515,576.25 70°27'30.858 N 149°52'22.324 W -plan misses target center by 15.12ft at 11334.23ft MD(6290.02 TVD,3561.52 N,-2670.99 E) -Point 3N-11A_CTD Fault2( 0.00 0.00 6,394.00 4,463.12 -1,527.96 6,018,258.25 516,707.30 70°27'39.843 N 149°51'49.030 W -plan misses target center by 198.18ft at 9995.79ft MD(6334.98 TVD,4436.03 N,-1715.20 E) -Polygon Point 1 6,394.00 4,463.12 -1,527.96 6,018,258.25 516,707.30 Point 2 6,394.00 3,667.41 -846.80 6,017,464.28 517,390.34 Point 3 6,394.00 3,460.71 -564.26 6,017,258.30 517,673.35 Point 4 6,394.00 3,667.41 -846.80 6,017,464.28 517,390.34 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name C) C') 115.00 47.00 16" 16 16 4,557.99 3,563.65 9 5/8" 9-5/8 13-1/2 11,335.00 6,290.02 2 3/8" 2-3/8 3 ------------- Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 9,995.79 6,334.98 4,436.03 -1,715.20 TIP 10,020.00 6,333.57 4,415.04 -1,727.18 KOP 10,050.00 6,331.29 4,389.91 -1,743.39 3 10,080.00 6,327.93 4,365.69 -1,760.76 4 10,180.00 6,316.87 4,293.51 -1,828.82 5 10,305.00 6,305.54 4,200.92 -1,911.49 6 10,405.00 6,301.26 4,113.47 -1,959.41 7 10,605.00 6,300.30 3,951.25 -2,073.88 8 10,705.00 6,301.17 3,876.25 -2,139.74 9 10,945.00 6,302.93 3,722.74 -2,320.93 10 11,025.00 6,296.56 3,691.43 -2,394.17 11 11,110.00 6,290.23 3,666.02 -2,474.92 12 11,335.00 6,290.02 3,561.01 -2,671.56 TD at 11335.00 8/4/2012 5:23:25PM Page 5 COMPASS 2003.16 Build 69 ORIGINAL lig. iamIbmWmumatiwo:aamlrmm Hft iriwli� Nif!! ii0 iii�imiRiiiiiieuiiii� _ m mdmmf � i momiik, iim 1 IHIIIImrnHI1HOHHIHOIIIIHHIHNIIII 1OhIHlIffl 1! 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O o ceomll�.-mm0cr �Voo .0 Mcsi ir.:,0a GOm m O00 .... -- m m m m m m m m m m m m m CL, S oNop0000S$S$000 0 8 0 8 0 8 2 ysy 2 s 2 O1�0 �Om]NLLOJOOOOO X00 mN Oc�'l b b b b b b b 3 b b b U S'88002oo180='-m lanai ees ueevi O 9 oo „„_,.,,m uI/3 OS)4;da ILSu aA ani i,• (n•-NMV mml�mm.-.-.-.- ORIGINAL ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3N Pad 3N-11 3N-11AL1 3N-1 1AL1_wp03 Travelling Cylinder Report 04 August, 2012 BAKER HUGHES ORIGINAL - ConocoPhillips or its affiliates Fa iii ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3N-11 Project: Kuparuk River Unit TVD Reference: 3N-11 @ 68.00ft(3N-11) Reference Site: Kuparuk 3N Pad MD Reference: 3N-11 @ 68.00ft(3N-11) Site Error: 0.00ft North Reference: True Reference Well: 3N-11 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3N-11AL1 Database: EDM Alaska Prod v16 Reference Design: 3N-11AL1_wp03 Offset TVD Reference: Offset Datum Reference 3N-11AL1_wp03 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 9,995.79 to 11,335.005 Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,330.08ft Error Surface: Elliptical Conic Survey Tool Program Date 8/4/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 100.00 8,400.00 3N-11 (3N-11) GCT-MS Schlumberger GCT multishot 8,471.00 9,995.79 3N-11A(3N-11A) MWD MWD-Standard 9,995.79 11,335.00 3N-11AL1_wp03(3N-11AL1) MWD MWD-Standard r-- Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 115.00 115.00 16" 16 16 4,557.99 3,631.65 9 5/8" 9-5/8 13-1/2 I 11,335.00 6,358.02 2 3/8" 2-3/8 3 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 8/4/2012 4:23:56PM Page 2 of 10 COMPASS 2003.16 Build 69 fln1 1t\ ) 1 E r t 6.... i t , , :,_ ,f, ConocoPhillips or its affiliates Fr— Conoco — ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3N-11 Project: Kuparuk River Unit TVD Reference: 3N-11 @ 68.00ft(3N-11) Reference Site: Kuparuk 3N Pad MD Reference: 3N-11 @ 68.005(3N-11) Site Error: 0.00ft North Reference: True Reference Well: 3N-11 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3N-11AL1 Database: EDM Alaska Prod v16 Reference Design: 3N-11AL1_wp03 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 3N Pad 3N-02-3N-02-3N-02 Out of range 3N-02-3N-02A-3N-02A Out of range 3N-02A-3N-02A-3N-02A Out of range 3N-03-3N-03-3N-03 Out of range 3N-04-3N-04-3N-04 Out of range 3N-05-3N-05-3N-05 Out of range 3N-06-3N-06-3N-06 Out of range 3N-07-3N-07-3N-07 Out of range 3N-07-3N-07A-3N-07A Out of range 3N-07-3N-07AL1 -3N-07AL1_wp06 Out of range 3N-07-3N-07AL1-01 -3N-07AL1-01_wp02 Out of range 3N-07-3N-07AL1-02-3N-07AL1-02_wp02 10,800.00 8,400.00 1,327.11 208.20 1,124.05 Pass-Major Risk 3N-07-3N-07AL2-3N-07AL2_wp08 Out of range 3N-07-3N-07AL2-01 -3N-07AL2-01_wp02 Out of range 3N-07-3N-07AL2-02-3N-07AL2-02_wp02 Out of range 3N-08-3N-08-3N-08 Out of range 3N-08-3N-08A-3N-08A Out of range 3N-09-3N-09-3N-09 11,150.00 8,125.00 848.07 274.84 577.39 Pass-Major Risk 3N-10-3N-10-3N-10 Out of range 3N-11 -3N-11 -3N-11 Out of range 3N-11 -3N-11A-3N-11A 10,025.00 10,025.00 0.03 0.73 -0.52 FAIL-Minor 1/10 3N-11 -3N-11AL3-3N-11AL3 10,025.00 10,025.00 0.03 0.73 -0.52 FAIL-Minor 1/10 3N-12-3N-12-3N-12 Out of range 3N-13-3N-13-3N-13 Out of range 3N-14-3N-14-3N-14 Out of range 3N-14-3N-14A-3N-14A Out of range 3N-14-3N-14APB1 -3N-14APB1 Out of range 3N-15-3N-15-3N-15 Out of range 3N-16-3N-16-3N-16 Out of range 3N-16-3N-16A-3N-16A Out of range 3N-16-3N-16AL1 -3N-16AL1 Out of range 3N-16-3N-16AL1-01 -3N-16AL1-01 Out of range 3N-16-3N-16AL1 PB1 -3N-16AL1 PB1 Out of range 3N-16-3N-16APB1 -3N-16APB1 Out of range 3N-16-3N-16APB2-3N-16APB2 Out of range 3N-16-3N-16APB3-3N-16APB3 Out of range 3N-17-3N-17-3N-17 Out of range 3N-18-3N-18-3N-18 Out of range 3N-18-3N-18L1 -3N-18L1 Out of range 3N-18-3N-18L1 PB1 -3N-18L1 PB1 Out of range 3N-19-3N-19-3N-19 Out of range 3N-19-3N-19PB1 -3N-19PB1 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 8/4/2012 4:23:56PM Page 3 of 10 COMPASS 2003.16 Build 69 ORG ft. A L ConocoPhillips or its affiliates redk ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3N-11 Project: Kuparuk River Unit TVD Reference: 3N-11 ©68.00ft(3N-11) Reference Site: Kuparuk 3N Pad MD Reference: 3N-11 @ 68.00ft(3N-11) Site Error: 0.00ft North Reference: True Reference Well: 3N-11 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 3N-11AL1 Database: EDM Alaska Prod v16 Reference Design: 3N-11AL1_wp03 Offset TVD Reference: Offset Datum Reference Depths are relative to 3N-11 @ 68.00ft(3N-11) Coordinates are relative to:3N-11 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:0.14° Ladder Plot I I I I I 1 1400 I I I I I I I I I I I , I I I I I I I I I I I I 1 I I I I I I I I I ) 1050 C I I I I I I I I I I I I I 1 I I C1) I I 1 I I 1 U3 1 I I I I I O I I I I I I I I I I I I m 700 0 I I I I I I I I I I I I O I I I I 1 I C I I I 1 I O I I I I I U I I I I 350 1 I 1 I I I I I I I I I I I I I I 1 I I I I I 1 J J J J J J I 1 I I I 1 I 1 I I I I 1 I I 0 I I i I 0 2000 4000 6000 8000 10000 12000 M easured Depth LEGEND - '; 3 N-07,3 N-07AL 1-02,3N-07ALI-02 wp02V0 3N-11,3N-11A,3N-11AV0 --s- 3 N-09.3 N-09.3 N-09 VI 3N-11,3 N-11 AL3,3 N-11 AL3 V0 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 8/4/2012 4:23:55PM Page 10 of 10 COMPASS 2003.16 Build 69 ORIGINAL Page 1 of 3 Schwartz,Guy L(DOA) From: Schwartz,Guy L(DOA) Sent Friday,August 03,2012 4:07 PM To: 'Winfree,Michael Alex(Jr)' Cc: Davies,Stephen F(DOA) Subject:RE'3N-11AL1 CTD Request to Revise Approved Permit to Drill(212 096) / You have verbal approval to modify the approved PTD for 3N-11AL1 as proposed below Submit a ✓ revised PTD application as soon as possible Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433(cell) From:Winfree,Michael Alex(Jr.)[mailto:Michael.A.Winfree@conocophillips.com] Sent:Friday,August 03,2012 3:18 PM To:Schwartz,Guy L(DOA) Cc:Winfree,Michael Alex(Jr.) Subject:3N-11AL1 CTD Request to Revise Approved Permit to Drill(212 096) Guy, As we discussed,ConocoPhillips requests verbal approval to revise the Approved Permit to Drill for 3N- 11AL1. The 3N-11AL1 lateral was onginally planned to target an area east of a known fault After drilling the 3N- 11AL3,the fault was re-characterized as having the potential to restrict support to the offset producers The proposed BHL for 3N-11AL1 was moved west across the fault to improve the sweep efficiency. The proposed bottom hole location is-430 feet from the original location,but the kick off point moves down hole by-640'from the permitted kick off point We are currently drilling ahead in the AL3 lateral and expect to TD sometime this evening. The plan forward after TD,is to run liner from TD(-11,285')to 10,020'MD(-40 joints),test BOPE and then pick up the lateral drilling assembly and run in the hole to kick off the billet and drill the 3N-11AL1 lateral pending AOGCC approval. AL1 lateral drilling could begin as early as Saturday evening. If verbal approval is granted to revise the Permit to Drill for the AL1 lateral,the required paperwork will be submitted per regulations as soon as practical. The proposed directional plan in NAD 27 is attached Below are schematics showing the proposed revision. Fault Map Showing Old and Proposed Position of the ALA BHL Relative to the Fault. 8/3/2012 Page 1 of 2 Schwartz, Guy L(DOA) From: Winfree, Michael Alex(Jr.)[Michael.A.Winfree@conocophillips.com] Sent: Friday,August 03,2012 3:18 PM To: Schwartz,Guy L(DOA) Cc: Winfree,Michael Alex(Jr.) Subject: 3N-11AL1 CTD Request to Revise Approved Permit to Drill(212 096) Attachments:3N-11AL4 wp01 Planning Report-NAD27.pdf Guy, As we discussed,ConocoPhilyps requests verbal,approval to revise the Approved Permit to Drill for 3N- 11AL1. The 3N-11AL1 lateral was originally planned to target an area east of a known fault. After drilling the 3N- 11AL3,the fault was re-characterized as having the potential to restrict support to the offset producers. The proposed BHL for 3N-11AL1 was moved west across the fault to improve the sweep efficiency. The proposed bottom hole location is-430 feet from the original location,but the kick off point moves down hole by-640'from the permitted kick off point. We are currently drilling ahead in the AL3 lateral and expect to TD sometime this evening. The plan forward after TD,is to run liner from TD(-11,285')to 10,020'MD(-40 joints),test BOPE and then pick up the lateral drilling assembly and run in the hole to kick off the billet and drill the 3N-11AL1 lateral pending AOGCC approval. AL1 lateral drilling could begin as early as Saturday evening. If verbal approval is granted to revise the Permit to Drill for the AL1 lateral,the required paperwork will be submitted per regulations as soon as practical. The proposed directional plan in NAD 27 is attached. Below are schematics showing the proposed revision: Fault Map Showing Old and Proposed Position of the AL1 BHL Relative to the Fault. R t 1 . •5 / : 14 r, L' • 3N-11AL1 Proposed Location(Red) 1,, % 4 New 0°LsPolygon N-11AL1 Original Location(Blue) (Gree.: rj', N-S Fault (Grey) ', l • Below is a screen shot of the 3N-11 laterals as permitted: 8/3/2012 Page 2 of 2 KOP @ 8472'MD 3-1/2"x 4-1/2"GEN2 I . ^1 I Anchored billet @-8945' = IAL2 wp02 @-9445'MD i \ A a r ® 7,_ = I-I AL2-01 wp02©-11330' _ , 1 Liner billet©-9380'MD J — -lair _ = 1 \ _ _ 1® A wp07 @-11280'MD Liner billet @-8800'MD —__ J1:::1AL1 wp02 @-11280' 4-1/2"shoe @-8624'MD This is the current status of the well and proposed 3N-11AL1 lateral: Proposed revision to 3N-11AL1 ' (".7:4-"41)1 , 1KOP@8471'MD .3-1P_-x 4.1x2•GEN2 KOP= 10.020'MD - TD=10,295'MD E 1 J4141111, i BHA Recovered From 10,923'MD Ig Kli A, Al Verbally Approved 3N11AL3 Lateral Aid? Permit Pending 41/2'shoe @-8624'MD Please let me know if you need additional information regarding this request for the revision of the permit to drill 3N-11AL1. Thanks, ! -Mike Mike A.Winfree Drilling Engineer 907.265.6820 Direct 907.242.0246 Cell 8/3/2012 TRANSMITTAL LETTER CHECKLIST WELL NAME Kuparuk River Unit 3N-11AL1 (Revised) PTD 212096 X Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: KUPARUK RIVER POOL: KUPARUK RIVER OIL POOL Circle 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 Kuparuk River Unit 3N-11A _Permit_ No. 212095, X (If last two digits in API No. 50-029-21580-01-00. continue to be API number are reported as a function of the original API number stated above. between 60-69) PILOT HOLE In accordance with 20 AAC 25.005(1), 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 perforate and 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. Should conventional core be acquired in this well, representative chip samples from each foot of core must be submitted to the Commission in accordance with 20 AAC 25.071. 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. 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V, V .0 0, 0 L, 0 a as a) l0, Cl) a) o 0 zaJo; ss' sco ,- ooaac� sQa, ocoU, v. U (.) QwQwo, m, mU5' N2 ao, cnm, 0 W a' Z E I N c,) v 10 CO n CO 0) 0 - Ns- M u) CO a°°o 99)) O r N M N N (N N- aN N O ,- M M M i,g3 CO M ao CO) U t N N N w O w O O C 2 O c m N CO N !0 N O CO ", O c0 01 c0 o ea H W o c co c co cop 0 W N >, 0 E J C C O O W alQ Q o W Q0 . Q o 0 3 , j' SEAN PARNELL,GOVERNOR ) L 4t, ki IAEA d U 6J ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 L. Gantt CTD Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N-11AL 1 ConocoPhillips Alaska, Inc. Permit No: 212-096 Surface Location: 1561' FSL, 155' FEL, SEC. 29, T13N, R9E, UM Bottomhole Location: 384' FNL, 2414' FEL, SEC. 29, T13N, R9E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well 3N-11A, Permit No 212-095, API 50-029-21580-01. Production should continue to be reported as a function of the original API number stated above. 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, 1/4._.,414.1 Cathy I Foerster Chair /11 DATED this //C day of July, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 1 8 2012 PERMIT TO DRILL AOGCC 20 AAC 25.005 1 a.Type of Work , 1 b Proposed Well Class: Development-Oil ❑ Service-Win) a - Single Zone ❑✓ 1c.Specify if well is proposed for: Drill ❑ Re-drill ❑✓ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5 Bond: U Blanket u Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 _ 3N-11AL1 - 3.Address: 6 Proposed Depth. 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 11280' _ ND: 6391' - Kuparuk Ri r Field 4a. Location of Well(Governmental Section): 7 Property Designation(Lease Number): Surface: 1561'FSL, 155 FEL,Sec.29,T13N, R9E,UM . ADL 25521,25512 ' Ku ruk River Oil Pool - Top of Productive Horizon 8.Land Use Permit: roximate Spud Date: 1538'FSL, 1088'FEL,Sec.20,T13N, RO9E, UM 2557,2553 7/22/2012 Total Depth 9.Acres in Property14 Distance to 384'FNL,2414'FEL,Sec.29,T13N, RO9E, UM 2560 Nearest Property: 12150 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10 KB Elevation ab = SI:: 68 feet 15.Distance to Nearest Well Open Surface:x- 518246 ' y- 6013799 , Zone- 4 GL Elevation ab.- : 33 8 feet to Same Pool 3N-09,1400 • 16.Deviated wells Kickoff depth. 9380 \ ft. 17 Maximum Anticipat-f r- sures in psig(see 20 MC 25 035) Maximum Hole Angle: 94.5° deg Downhole:3766 p •. Surface:3125 psig 18.Casing Program: I Specifications Top - Setting D=.th -Bottom Cement Quantity,c.f.or sacks Hole Casing ` Weight Grade Coupling Length MD TVD MD ND (including stage data) 1 (L / 3" 2.375" 4.7# L-80 ST-L 2480' 00' 6 . llicy't 6391' slotted liner tck) 19 PRESENT WELL CONDITION SUMMA (To b completed for Redd!and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft) Plugs(mea - ective Depth M i(ft): Effective Depth ND(ft): Junk(measured) 8790' 6637' 8682' 6560' Casing Length Siz- Cement Volume MD ND Conductor/Structural 250 sx CSII 115' 115' Surface 9 6,•" 1300 sx ASlll,350 sx Class G 4558' 3632' Intermediate " 300 sx Class G,175 sx AS I 8777' 6627' Production �J Liner V` 4.-' 15 bbls Class G w/GASBLOK 8625' 6519' Perforation Depth MD(ft): Perforation Depth ND(ft): perfs cemented off at 8420'-8 89' 6374'-6493' 20 Attachments Property Plat❑ BOP ketch❑✓ Dnlling Program❑✓ Time v Depth Plot ❑ Shallow Hazard Analysis ❑ Dive -r Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements ❑✓ 21.Verbal Approval Commission Representati -• Date 4,4 e"I'nI.w17_ 22. I hereby certify that the foregoing is true a,d correct Contact Mike Winfree @ 265-6820 Printed Name L. Gan' Title CTD Supervisor Signature Qi )V0 jf Phon 263-4021 Date 7/I 7// ? Commission Use Only Permit to Drill API Number c_^ /� Permit Approva See cover letter Number (2— ? , 50-( '. �i/•>C L ' CSL �`� Date I�1°1 I2 for other requirements Conditions of approval:, If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: 17 eb it- 35i.,S� III P / Samples req'd: Yes ❑ No IY Mud log req'd: Yes ❑ No [f Other , /, V � � `� �;` H2S measures: Yes LJ No ❑ Directional svy req'd: Yes Q' No ❑ - M l 7- re ra DATE: Q ?/ "'t , ! C.I. .---"eezi y'�,jo , P, / PROVED BY THE COCOISSION / /`,.'�,��ri`-- ,COMMISSIONER Form 10-401 (Revised 7/2009) This permit is valid for 24 Months{'rdm the d'atb of approval0 AAC 25.005(g)) Submit in Duplicate fay ConocoPhillips RECEIVED Alaska P.O. BOX 100360 J U L 18 2012 ANCHORAGE,ALASKA 99510-0360 AOGCC July 17, 2012 Commissioner-State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Permit to Drill (PTD)applications to drill and complete 3N-11A, 3N- 11AL1, 3N-11AL2, and 3N-11AL2-01 from Kuparuk well 3N-11 (PTD# 186-077). Coiled tubing drilling (CTD) operations are scheduled to begin July 22, 2012 using the Nabors CDR2-AC rig. The objective of the CTD project is to improve Kuparuk A-Sand sweep efficiency and oil recovery within the target pattern by drilling lateral sidetracks. A workover has recently been completed which installed a 4W scab liner inside the 7" casing adjacent to the Kuparuk sands. The cementing of that scab liner also effectively squeezed the existing A and C-sand perfs as per sundry 311-372. Once CTD operations are completed then a 10-407 will be submitted to classify the original 3K-11 completion as `Abandoned'. Attached to this application are the following documents that explain the proposed job operations. A BOP schematic for slimhole CTD operations from Nabors CDR2 is already on file with the Commission. — Drilling program summary — Permit to Drill application forms for 3N-11A, 3N-11AL1, 3N-11AL2, and 3N-11AL201 — Directional plans for 3N-11A, 3N-11AL1, 3N-11AL2, and 3N-11AL201 — Current wellbore schematic following the rig workover — Proposed wellbore schematic If you have any questions or require additional information please contact me at my office 907-265-6820. Sincer ly, V � Mike A. ree ConocoPhillips Alaska Coiled Tubing Drilling Engineer Kuparuk CTD Laterals NABOBS ALASKA fiA 3N-11A, 3N-11AL1, 3N-11AL2, 3N-11AL2-01 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 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Pressure Deployment of BHA 6 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 16. Quarter Mile Injection Review (for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Construction of Injection Wells 7 (Requirements of 20 AAC 25.412) 7 Attachment 1: Directional Plans for 3N-11A, 3N-11AL1, 3N-11AL2, &3N-11AL2-01 7 Attachment 1: Quarter Mile Pool Scan 7 Attachment 2: Current Well Schematic for 3N-11 7 Attachment 3: Proposed Well Schematic for 3N-11 CTD Laterals 7 Page 1 of 7 - July 17,2012 PTD Application for KRt, JN-11A, AL1, AL2, & AL2-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) There are four proposed laterals described in this document: KRU 3N-11A, 3N-11AL1, 3N-11AL2, and 3N-11AL2-01. 3N-11A will be a sidetrack from the 3N-11 motherbore, and the remainder will be horizontal laterals branching off the 3N-11A. All will be classified as"Service- Water Injection"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Each of these laterals will target the A3, A2, and Al sands in the Kuparuk reservoir. See the attached 10-401 forms for surface and subsurface coordinates of each of the 3N-11 laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AA C 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and 3600 psi. Using a maximum potential formation pressure of 3766 psi, the maximum potential surface pressure is 3125 psi assuming a gas gradient of 0.1 psi/ft. See the"Drilling Hazards Information and Reservoir Pressure" section for more details. - The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) The most recent static BHP measurement in well 3N-11 was taken in December 2011 recording a pressure of 3441 psi at 8504' MD, 6433' TVD for a 10.3 ppg gradient. During the workover of January 2012 however the fluid weight had to be increased to 11.3 ppg (equivalent of 3780 psi SBHP)to maintain pressure overbalance. The proposed 3N-11 CTD laterals will approach existing production wells so our expectation is that we will not encounter significantly increased formation pressure. The most likely sources of elevated formation pressure, if we encounter such, would be from injection wells 3N-13 to the southeast and 3N-04 to the southwest. These wells have recent formation pressures of 3755 psi (11.2 ppg EMW, Feb-12) and 3715 psi (11.3 ppg EMW, Apr- 12) respectively. Maximum potential formation pressure is based on the April 2012 pressure from 3N-04 to the southwest, which had measured formation pressure of 3715 psi at 7630' MD, 6323' TVD for a gradient of 11.3 ppg. In 3N-11A this equates to a maximum potential formation pressure of 3766 psi (8470' MD, 6409' TVD) and a maximum potential surface pressure of 3125 psi assuming a gas gradient to surface. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled. 3N pad is a water only injection pad. It is unlikely that an influx while drilling will produce a significant amount of gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The major expected downhole risk in the 3N-11 laterals is hole stability due to interbedded shales and silts in the A-sand. We will mitigate hole instability by maintaining a minimum ECD target of 12.0 ppg EMW at the window while drilling the CTD laterals, as well as using mud additives that minimize chemical instability. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) Each of the 3N-11 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so formation integrity tests are not required. Page 2 of 7 r) I1 July 17, 2012 PTD Application for KRB sN-11A, AL1, AL2, & AL2-01 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Liner Liner Liner Liner Lateral Name Top MD Btm Top Btm Liner Details MD TVD TVD 3N-11A 9380' 11,280' 6393' 6378' 23/", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3N-11AL1 8800' 11,280' 6392' 6391' 23/", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3N-11AL2 8945' 9,445' 6440' 6351' 23/", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 3N-11AL2-01 8460' 11,330' 6333' 6353' 2'/" 4.7#, L-80, ST-L slotted liner up inside 4%2" liner Existing Casing/Liner Information Weight Top Btm Top Btm Burst Collapse Category OD (POGrade Connection MD MD TVD TVD psi psi Conductor 16" 62 H-40 Welded 0' 115' 0' 115' Surface 9%" 36 J-55 BTC 0' 4558' 0' 3632' 3520 2020 Casing 7" 26 J-55 BTC 0' 8777' 0' 6627' 4980 4320 Scab liner 4W 12.6 L-80 IBT& BTC 8130' 8625' 6168' 6519' 8430 7500 Tubing 3W 9.3 L-80 EUE 8rd-Mod 0' 8173' 0' 6199' 10,160 10,530 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036 for thru-tubing drilling operations so no diverter system is required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based Biozan brine or used drilling mud (-9.5 ppg) — Drilling operations: Chloride-based Flo-Pro Flo Vis mud (9.5 eppg). This mud weight alone will not hydrostatically overbalance formation pressure in the 3N-11 motherbore, but overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 3N-11 contains a subsurface safety valve (SSSV) at 1796' MD. The SSSV will be used to pressure deploy the liner in lieu of loading the well with completion fluid. In the event that the SSSV becomes inoperable, the well will be loaded with 12.0 ppg sodium bromide completion fluid in order to maintain pressure over-balance while picking up liner. — Emergency Kill Weight fluid: Two well bore volumes (-200 bbl) of 13.1 ppg emergency kill weight fluid will be within a short drive of the rig during drilling operations. RI I ? AL Page 3 of 7 July 17, 2012 PTD Application for KRLi ,iN-11A, AL1, AL2, & AL2-01 Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing pressure over- balance to the formation. In the 3N-11 laterals we will target a constant BHP of 12.0,ppg EMW at the window. If increased formation pressure is encountered, mud weight or choke pressure will be increased to maintain overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability but not necessarily for well control. Pressure at the 3N-11A Window(8470' MD, 6409' TVD, 6341' SSTVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (11.3 ppg) 3766 psi 3766 psi Mud Hydrostatic (9.5 ppg) 3166 psi 3166 psi Annular friction (i.e. ECD, 0.095 psi/ft) 808 psi 0 psi Mud + ECD Combined 3974 psi 3166 psi (no choke pressure) (overbalanced (underbaiancea -208 psi) -600 psi) ,Pat Window(12 0 ppg) 3999 psi 3999 psi Choke Pressure Required to Maintain 25 psi 840 psi Target BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 3N-11 is an A/C-sand injector that was recently worked over to install a 4'/z" scab liner over damaged 7" casing near the existing Kuparuk perfs. The existing NC-sand perfs were squeezed with cement as part of that workover, and our plans are to not re-perf the C-sand. Four proposed A-sand CTD laterals will increase reservoir exposure and improve waterflood sweep. A separate sundry request (311-372) was approved for the abandonment of the original 3N-11 completion in preparation for these CTD sidetracks. A mechanical whipstock will be placed in the 4%" scab liner at the planned kickoff point. The 3N-11A sidetrack will exit the 4'/z" liner and 7" casing at 8472' MD and will target the A1/A2 sands south of the existing well with a 2780' lateral. The hole will be completed with a 2%' slotted liner to the TD of 11,280' MD with an aluminum billet at 9380' MD. ORG1NAL Page 4 of 7 July 17, 2012 PTD Application for KRI, AL1, AL2, & AL2-01 The 3N-11AL1 lateral will kick off from the aluminum billet at 9380' MD and will target the Al sand south of the existing well with an 1900' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,280' MD with an aluminum billet at 8800' MD. The 3N-11AL2 lateral will kick off from the aluminum billet at 8800' MD and will target the A3 sand south of the existing well with a 645' lateral. The hole will be completed with a 2%' slotted liner to the TD of 9445' MD with an aluminum billet at 8945' MD. The 3N-11AL1 lateral will kick off from the aluminum billet at 8945' MD and will target the A2/A3 sands south of the existing well with a 2385' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,330' MD with the final liner top located inside the 41/2" liner at 8460' MD. Pre-CTD Work 1. RU e-line. 2. Run whipstock dummy. 3. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3N-11A Sidetrack (Al &A2 sand, south) a. Set whipstock at 8470' MD with high-side orientation. b. Mill 2.80" window through 4W liner and 7"casing at 8470' MD c. Drill 2.70" x 3" bi-center lateral to TD of 11,280' MD d. Run 2%" slotted liner with an aluminum billet from TD up to 9380', using the SSSV as a barrier to formation pressure if available _ •. 3. 3N-11AL1 Lateral (Al sand, south) a. Kick off of the aluminum billet at 9380' MD b. Drill 2.70" x 3" bi-center lateral to TD of 11,280' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 8800', using the SSSV as a barrier4 to formation pressure if available i)-(1) 4. 3N-11AL2 Lateral (A3 sand, south) a. Kick off of the aluminum billet at 8800' MD b. Drill 2.70" x 3" bi-center lateral to TD of 9445' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 8945', using the SSSV as a barrier to formation pressure if available 5. 3N-11AL2-01 Lateral (A2 &A3 sands, south) a. Kick off of the aluminum billet at 8945' MD b. Drill 2.70" x 3" bi-center lateral to TD of 11,330' MD c. Run 2%" slotted liner from TD up to 8460' MD, inside the 4W liner. Will use the SSSV as a barrier to formation pressure if available while picking up liner. 6. Freeze protect. Set BPV, ND BOPE. 7. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV and install gas lift design. 2. Perform static BHP survey 3. Put on production. a. Note: The 3N-11 laterals will be pre-produced for over 30 days before being converted to water injection service. nnlrito Page5of7 July 17, 2012 PTD Application for KRI, JN-11A, AL1, AL2, & AL2-01 Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. - Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. - Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. - When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. - The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment the steps listed above are conducted in reverse. Liner Running - Since 3N-11 is equipped with a SSSV, the CTD laterals will not need to be displaced to an over-balancing fluid prior to running liner unless the SSSV fails. In that case, fluid of sufficient density to over-balance the formation will be used to provide well control. See the"Drilling Fluids" section for more details. - While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" pipe rams provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) - No annular injection on this well. - Class ll liquids to KRU 1R Pad Class II disposal well - Class II drill solids to Grind & Inject at PBU Drill site 4 - Class I wastes will go to Pad 3 for disposal. 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) - There are no other affected owners - Please see attached directional plans for each lateral. - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire openhole section. - Distance to nearest property line and nearest well in the same pool. Distance Distance to Directional to Unit Nearest Lateral Name Plan Boundary Well Nearest Well 3N-11A 07 11,500' 1,400' 3N-09 3N-11AL1 02 12,150' - 1,400' 3N-09 3N-11AL2 02 11,750' 1,750' 3N-09 3N-11AL2-01 02 11,950' 1,350' 3N-09 Page6of7 July 17,2012 PTD Application for KRI, ‘IN-11A, AL1, AL2, & AL2-01 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) 3N-09 is the only well within the '/4 mile scan in the pool. The CBL for 3N-09 shows good cement. Nearest Distance to Lateral Name Well in Nearest Comments Pool Well in Pool 3N-11A 3N-09 1,400' Waivered well for IA x OA Communication. MITOA Passed 7/6/2010 3N-11AL1 3N-09 1,400' Waivered well for IA x oA7/6/20m10 Comunication.MITOA Passed 3N-11AL2 3N-09 1,750' Only the 3N-11 laterals are with the Y4 scan for L2. 3N-11AL2-01 3N-09 1,350' Waivered well for IA x OA Communication. MITOA Passed 7/6/2010 17. Construction of Injection Wells (Requirements of 20 AAC 25.412) ConocoPhillips received a variance on the packer placement requirements of 20 AAC 25.412(b)for the 3N-11 rig workover. The variance was approved with the sundry number 311-372. Attachment 1: Directional Plans for 3N-11A, 3N-11AL1, 3N-11AL2, & 3N-11AL2-01 Attachment 1: Quarter Mile Pool Scan Attachment 2: Current Well Schematic for 3N-11 Attachment 3: Proposed Well Schematic for 3N-11 CTD Laterals Page 7 of 7 July 17, 2012 South(-)/North(+)(250 ft/in) . I i - :44 - lin 0- 7, --: r 4 ' t la 8 '4 4... . §11 matimi. E IHE I Ita ,in 8 I WI, h t w II ?* o 1 0 ,....,I 0 , i .....“...xx L.• •-0-0 I 0- t g 1 4) \ illhh 1 I C4 7:1 F Z 1 a a • _____, or ,,,, aP4L -: %''d, I 1 _ 3 = !INI k , .._ . „. , 14„,,ili ” .A,,,..iiii. 1 .....11,, 0,.>./. 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J Q Q Q N O p a a (O - C _ Co E p O -Ni O wn 2 Co co p 0 f n 0 N p M -OCO n co V O �1 1 Q p M 1 1n 0) -0 co r N ��11 N C N V co U p N Q To_ p O 3 C )- i'li) CO N V i t J 0 CO Q D (9 (6 V _ __ • 0 2 0 (0 (6 jX�� m Q' e0 F- O X N O '" W O m *k c in CI) N N X rf ._J (9 co co W C _ O L O) U) O 0 co I co J Lr) CO 2i co N N CV Tr N N N U) 4) N 2t,`� Q N Y Y Y Z V 2 2 e- i ll) i N •- N (0 0 W M M M 1, M m m m 2 0 i) C) N 18- co co r N 'O ., \ \ 1 a0 CO •Cr v X U \\�� N d N O O Q - - Y M a ¢ I Q Zia II NI- iiCU . . ii ////..1 i; iJ r 1 t 1 C..,: N O III 11 H I I II 0 L N CL 0 En O) V Or 0) a) (n u) ii) co c O O _ in n.COnn v in =) 0 -a , a) 0 CV in r I � *kms ccn0 a2 Nu) � ° �1 (n N ' V M O N O O M m w � Ueo � � � � co N � O p Lo- .c0 'V Q co r CO U) 2 8) @) t� t � L ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3N Pad 3N-11 3N-11AL1 Plan: 3N-11AL1_wp02 Standard Planning Report 16 July, 2012 RIO BAKER HUGHES ConocoPhillips or its affiliates Eer. ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3N-11 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3N-11 @ 68.00ft(3N-11) Site: Kuparuk 3N Pad North Reference: True Well: 3N-11 Survey Calculation Method: Minimum Curvature Wellbore: 3N-11AL1 Design: 3N-11AL1_wp02 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 1 Site Kuparuk 3N Pad Site Position: Northing: 6,013,799.17ft Latitude: 70°26'55.957 N From: Map Easting: 517,946.19ft Longitude: 149°51'12.938 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.14 ° Well 3N-11 Well Position +N/-S 0.00 ft Northing: 6,013,799.32 ft Latitude: 70°26'55.951 N +E/-W 0.00 ft Easting: 518,246.03 ft Longitude: 149°51'4.133 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 33.80 ft Wellbore 3N-11AL1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGG M2011 8/1/2012 16.11 80.00 57,386 Design 3N-11AL1_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,380.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) -33.80 0.00 0.00 205.00 Plan Sections Measured ND Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 9,380.00 90.15 204.70 6,393.35 4,983.53 -1,417.29 0.00 0.00 0.00 0.00 9,455.00 81.15 204.70 6,399.03 4,915.66 -1,448.50 12.00 -12.00 0.00 180.00 9,595.00 81.53 221.69 6,420.26 4,800.29 -1,523.99 12.00 0.27 12.14 90.00 9,675.00 89.13 227.58 6,426.78 4,743.63 -1,579.96 12.00 9.50 7.37 38.00 10,000.00 91.84 188.67 6,423.93 4,462.54 -1,730.26 12.00 0.83 -11.97 274.00 10,330.00 91.03 228.28 6,415.31 4,178.31 -1,884.44 12.00 -0.24 12.00 90.60 10,630.00 90.84 192.27 6,410.25 3,923.50 -2,033.19 12.00 -0.07 -12.00 270.00 10,880.00 90.07 222.26 6,408.22 3,703.82 -2,146.42 12.00 -0.30 12.00 91.30 11,280.00 94.50 174.42 6,391.25 3,335.59 -2,268.78 12.00 1.11 -11.96 276.00 7/16/2012 4:29:08PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates Fir ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3N-11 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3N-11 @ 68.00ft(3N-11) Site: Kuparuk 3N Pad North Reference: True Well: 3N-11 Survey Calculation Method: Minimum Curvature Wellbore: 3N-11AL1 Design: 3N-11 AL1_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map I Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (') (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 9,380.00 90.15 204.70 6,393.35 4,983.53 -1,417.29 -3,917.64 0.00 0.00 6,018,778.87 516,816.69 TIP/KOP 9,400.00 87.75 204.70 6,393.72 4,965.36 -1,425.64 -3,897.65 12.00 -180.00 6,018,760.68 516,808.38 9,455.00 81.15 204.70 6,399.03 4,915.66 -1,448.50 -3,842.94 12.00 -180.00 6,018,710.93 516,785.64 1 2 9,500.00 81.19 210.16 6,405.94 4,876.21 -1,468.98 -3,798.53 12.00 90.00 6,018,671.43 516,765.26 9,595.00 81.53 221.69 6,420.26 4,800.29 -1,523.99 -3,706.47 12.00 89.16 6,018,595.38 516,710.44 3 9,600.00 82.00 222.06 6,420.98 4,796.60 -1,527.30 -3,701.73 12.00 38.00 6,018,591.69 516,707.15 9,675.00 89.13 227.58 6,426.78 4,743.63 -1,579.96 -3,631.47 12.00 37.95 6,018,538.60 516,654.61 4 9,700.00 89.34 224.59 6,427.11 4,726.30 -1,597.97 -3,608.15 12.00 -86.00 6,018,521.22 516,636.65 9,800.00 90.19 212.62 6,427.52 4,648.29 -1,660.25 -3,511.13 12.00 -85.96 6,018,443.07 516,574.57 9,900.00 91.04 200.65 6,426.44 4,559.07 -1,705.00 -3,411.36 12.00 -85.91 6,018,353.75 516,530.05 10,000.00 91.84 188.67 6,423.93 4,462.54 -1,730.26 -3,313.20 12.00 -86.04 6,018,257.16 516,505.03 5 10,100.00 91.67 200.68 6,420.85 4,366.02 -1,755.53 -3,215.04 12.00 90.60 6,018,160.60 516,479.99 ' 10,200.00 91.43 212.68 6,418.13 4,276.86 -1,800.33 -3,115.30 12.00 90.97 6,018,071.34 516,435.41 10,300.00 91.13 224.68 6,415.88 4,198.96 -1,862.70 -3,018.34 12.00 91.30 6,017,993.29 516,373.25 10,330.00 91.03 228.28 6,415.31 4,178.31 -1,884.44 -2,990.44 12.00 91.57 6,017,972.59 516,351.55 6 10,400.00 91.02 219.88 6,414.06 4,128.07 -1,933.08 -2,924.35 12.00 -90.00 6,017,922.24 516,303.04 10,500.00 90.97 207.87 6,412.31 4,045.21 -1,988.71 -2,825.74 12.00 -90.15 6,017,839.25 516,247.62' 10,600.00 90.87 195.87 6,410.70 3,952.59 -2,025.89 -2,726.09 12.00 -90.36 6,017,746.55 516,210.67 , 10,630.00 90.84 192.27 6,410.25 3,923.50 -2,033.19 -2,696.64 12.00 -90.55 6,017,717.44 516,203.45 7 10,700.00 90.64 200.67 6,409.35 3,856.44 -2,053.02 -2,627.48 12.00 91.30 6,017,650.34 516,183.78 10,800.00 90.33 212.67 6,408.50 3,767.25 -2,097.82 -2,527.71 12.00 91.41 6,017,561.04 516,139.21 10,880.00 90.07 222.26 6,408.22 3,703.82 -2,146.42 -2,449.69 12.00 91.51 6,017,497.51 516,090.76 8 10,900.00 90.32 219.88 6,408.15 3,688.75 -2,159.56 -2,430.47 12.00 -84.00 6,017,482.40 516,077.66 11,000.00 91.56 207.94 6,406.50 3,605.92 -2,215.24 -2,331.87 12.00 -84.01 6,017,399.45 516,022.19 11,100.00 92.73 195.99 6,402.74 3,513.41 -2,252.55 -2,232.26 12.00 -84.21 6,017,306.86 515,985.11 11,200.00 93.78 184.01 6,397.04 3,415.27 -2,269.87 -2,136.00 12.00 -84.65 6,017,208.69 515,968.04 - 11,280.00 94.50 174.42 6,391.25 3,335.59 -2,268.78 -2,064.24 12.00 -85.34 6,017,129.01 515,969.32 TD at 11280.00 7/16/2012 4:29:08PM Page 3 COMPASS 2003.16 Build 69 Ag--- ConocoPhillips or its affiliates Irfjr ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3N-11 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3N-11 @ 68.00ft(3N-11) Site: Kuparuk 3N Pad North Reference: True Well: 3N-11 Survey Calculation Method: Minimum Curvature Wellbore: 3N-11AL1 Design: 3N-11AL1_wp02 Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +N/-S +EI-W Northing Easting 1 -Shape (°) r) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3N-11A_CTD Fault2 0.00 0.00 6,394.00 4,463.12 -1,527.96 6,018,258.25 516,707.30 70°27'39.843 N 149°51'49.030 W -plan misses target center by 200.64ft at 9948.91ft MD(6425.39 TVD,4512.52 N,-1719.88 E) -Polygon Point 1 6,394.00 4,463.12 -1,527.96 6,018,258.25 516,707.30 Point 2 6,394.00 3,667.41 -846.80 6,017,464.28 517,390.34 Point 3 6,394.00 3,460.71 -564.26 6,017,258.30 517,673.35 Point 4 6,394.00 3,667.41 -846.80 6,017,464.28 517,390.34 3N-11AL1_T2 0.00 0.00 6,420.00 4,343.70 -1,764.29 6,018,138.25 516,471.29 70°27'38.668 N 149°51'55.973 W -plan hits target center -Point 3N-11AL1 T3 0.00 0.00 6,412.00 4,024.24 -1,996.11 6,017,818.26 516,240.28 70°27'35.526 N 149°52'2.782 W -plan misses target center by 2.76ft at 10522.26ft MD(6411.94 TVD,4025.30 N,-1998.65 E) -Point I 3N-11A_CTD Faultl 0.00 0.00 6,394.00 5,112.71 -1,338.34 6,018,908.23 516,895.31 70°27'46.232 N 149°51'43.461 W -plan misses target center by 151.40ft at 9380.00ft MD(6393.35 TVD,4983.53 N,-1417.29 E) -Polygon Point 1 6,394.00 5,112.71 -1,338.34 6,018,908.23 516,895.31 Point 2 6,394.00 4,996.44 -1,232.61 6,018,792.23 517,001.32 Point 3 6,394.00 4,818.03 -1,066.02 6,018,614.25 517,168.33 3N-11AL1 T5 0.00 0.00 6,392.00 3,336.86 -2,271.84 6,017,130.28 515,966.26 70°27'28.765 N 149°52'10.877 W -plan misses target center by 3.00ft at 11278.63ft MD(6391.36 TVD,3336.95 N,-2268.91 E) I -Point I 3N-11AL1_T1 0.00 0.00 6,428.00 4,679.21 -1,553.43 6,018,474.24 516,681.30 70°27'41.968 N 149°51'49.779 W' -plan misses target center by 65.05ft at 9709.03ft MD(6427.21 TVD,4719.81 N,-1604.25 E) -Point 3N-11 CTD Polygon 0.00 0.00 68.00 5,125.00 -647.21 6,018,922.21 517,586.34 70°27'46.354 N 149°51'23.152 W -plan misses target center by 6373.62ft at 9380.00ft MD(6393.35 TVD,4983.53 N,-1417.29 E) -Polygon Point 1 68.00 5,125.00 -647.21 6,018,922.21 517,586.34 Point 2 68.00 5,493.63 -894.35 6,019,290.20 517,338.32 Point 3 68.00 5,445.08 -1,503.53 6,019,240.16 516,729.32 Point4 68.00 4,803.97 -1,899.11 6,018,598.15 516,335.35 Point 5 68.00 4,061.92 -2,326.93 6,017,855.13 515,909.39 Point 6 68.00 3,179.50 -2,608.07 6,016,972.11 515,630.44 Point 7 68.00 3,191.30 -2,105.99 6,016,985.14 516,132.44 Point 8 68.00 4,079.82 -1,868.84 6,017,874.15 516,367.39 Point 9 68.00 5,107.32 -1,200.31 6,018,903.18 517,033.34 Point 10 68.00 5,150.92 -1,028.19 6,018,947.20 517,205.33 Point 11 68.00 4,890.20 -742.78 6,018,687.20 517,491.35 3N-11A_CTD Fault4 0.00 0.00 6,394.00 4,382.09 -2,323.27 6,018,175.27 515,912.27 70°27'39.044 N 149°52'12.398 W -plan misses target center by 465.29ft at 10406.95ft MD(6413.93 TVD,4122.71 N,-1937.50 E) -Polygon Point 1 6,394.00 4,382.09 -2,323.27 6,018,175.27 515,912.27 Point 2 6,394.00 4,175.87 -2,240.76 6,017,969.27 515,995.28 Point 3 6,394.00 3,964.41 -2,057.24 6,017,758.28 516,179.29 Point 4 6,394.00 4,175.87 -2,240.76 6,017,969.27 515,995.28 3N-11A_CTD Faults 0.00 0.00 6,394.00 3,509.06 -1,942.37 6,017,303.27 516,295.27 70°27'30.459 N 149°52'1.199 W -plan misses target center by 282.95ft at 10928.23ft MD(6407.90 TVD,3666.56 N,-2177.02 E) -Polygon Point 1 6,394.00 3,509.06 -1,942.37 6,017,303.27 516,295.27 Point 2 6,394.00 3,058.80 -1,854.44 6,016,853.27 516,384.30 Point 3 6,394.00 2,652.59 -1,782.41 6,016,447.28 516,457.31 Point 4 6,394.00 3,058.80 -1,854.44 6,016,853.27 516,384.30 7/16/2012 4:29:08PM Page 4 COMPASS 2003.16 Build 69 , „ ConocoPhillips or its affiliates IIIrei ' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 3N-11 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3N-11 @ 68.00ft(3N-11) Site: Kuparuk 3N Pad North Reference: True Well: 3N-11 Survey Calculation Method: Minimum Curvature Wellbore: 3N-11AL1 Design: 3N-11AL1_wp02 3N-11AL1_T4 0.00 0.00 6,408.00 3,669.65 -2,173.00 6,017,463.27 516,064.27 70°27'32.038 N 149°52'7.976 W -plan misses target center by 1.37ft at 10923.39ft MD(6407.96 TVD,3670.44 N,-2174.12 E) -Point 3N-11A_CTD Fault3 0.00 0.00 6,394.00 4,170.35 -2,034.75 6,017,964.26 516,201.28 70°27'36.963 N 149°52'3.919 W -plan misses target center by 107.99ft at 10421.95ft MD(6413.67 TVD,4110.91 N,-1946.76 E) -Polygon Point 1 6,394.00 4,170.35 -2,034.75 6,017,964.26 516,201.28 Point 2 6,394.00 4,387.06 -1,906.22 6,018,181.27 516,329.26 Point 3 6,394.00 4,624.81 -1,789.64 6,018,419.28 516,445.25 Point4 6,394.00 4,387.06 -1,906.22 6,018,181.27 516,329.26 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter 1 (ft) (ft) Name C') (") 115.00 47.00 16" 16 16 4,557.99 3,563.65 9 5/8" 9-5/8 13-1/2 11,280.00 6,391.25 2-3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +EJ-W (ft) (ft) (ft) (ft) Comment 9,380.00 6,393.35 4,983.53 -1,417.29 TIP/KOP 9,455.00 6,399.03 4,915.66 -1,448.50 2 9,595.00 6,420.26 4,800.29 -1,523.99 3 9,675.00 6,426.78 4,743.63 -1,579.96 4 10,000.00 6,423.93 4,462.54 -1,730.26 5 10,330.00 6,415.31 4,178.31 -1,884.44 6 10,630.00 6,410.25 3,923.50 -2,033.19 7 10,880.00 6,408.22 3,703.82 -2,146.42 8 11,280.00 6,391.25 3,335.59 -2,268.78 TD at 11280.00 7/16/2012 4:29:08PM Page 5 COMPASS 2003.16 Build 69 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME KZ � � fi LI PTD# 2-1 z C !f Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: t,t . G GC / � --e--4 POOL: Z�- 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 9f existing well /,l(' /1 (If last two digits in Permit No. 7/Z '�,, API No. 50-021 - -n( . 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 00 V) J (0 o -3 aai 0 _Z O f,0 O a3 C NO C c a' S 0 E' t o O - E a) .n 0 a '3, • >. ca U0c 0- O UO O. a O Q' , c , N ' .) -a p) 0 m p, il_l, 4 a w p H U' _� c vi; 0 Lo • j v, a o . �, . a, 0), a •c 3, , , o. 3 t a a cr) E a) m, o c N, p: a. N 3 = 3 n Co No Z •-' �, N, c _ 3 0 a) a c' v,• • • • • a' E a a iri • C, 0) 0 co � N 'p O c, C, 4 L «.� L, �� U N, 2 d, >, a1„ J N _ •C : 03,' , a �' 'Q a t y, C. a N, 0)ZCO 0 0 _ E .M0NN C Ed NO0 C) C >+ adN d O Ha0 C 7 . Y, E 7 -a 2 0' • 60 co N. a oE N Caa 3 UNMM _ LZ OZ. 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