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211-049
New Plugback Esets 7/3/2024 Well Name API Number PTD Number ESet Number Date 1D-141A PB1 50-029-22967-73-00 208-016 T39107 7-16-2008 1D-141APB2 50-029-22967-74-00 208-016 T39108 7-16-2008 1D-141APB3 50-029-22967-75-00 208-016 T39109 7-16-2008 2K-08APB2 50-103-20111-71-00 211-049 T39110 6-13-2011 2K-08APB3 50-103-20111-71-00 211-049 T39111 6-13-2011 2K-08B PB1 50-103-20111-73-00 211-152 T39112 2-15-2012 2K-08B PB2 50-103-20111-74-00 211-152 T39113 2-15-2012 2K-08B PB3 50-103-20111-75-00 211-152 T39114 2-15-2012 3K-105L1 PB1 50-029-23479-72-00 212-166 T39115 3-12-2013 3K-105L1 PB2 50-029-23479-73-00 212-166 T39116 3-12-2013 3K-105L1 PB3 50-029-23479-74-00 212-166 T39117 3-12-2013 SP22-FN01 PB3 50-629-23478-72-00 212-162 T39118 3-20-2013 V-214 PB2 50-029-23275-71-00 205-134 T39119 1-29-2007 V-214 PB3 50-029-23275-72-00 205-134 T39120 1-29-2007 V-214 PB4 50-029-23275-73-00 205-134 T39121 1-29-2007 2K-08A PB2 50-103-20111-71-00 211-049 T39110 6-13-2011 2K-08A PB3 50-103-20111-71-00 211-049 T39111 6-13-2011 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q,1_ L - 0 4_9 Well History File Identifier Organizing(done) ❑ Two-sided 111111111111111111 ❑ Rescan Needed 11111111111 11111 RAN DIGITAL DATA OVERSIZED ZED (Scannable) • or Items: G eyscale Items: ❑ Diskettes, No. ❑ Other, No/Type: ❑ s: er Items Scannable by a Large Scanner for ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: VIIILt /s/ ifill P Project Proofing II IIII1111111111 BY: Maria Date: 7/1/1% /s/ 61 f Scanning Preparation 14. x 30 = l a 0 + a 9 = TOTAL PAGES (Count does not include cover sheet ilVi BY: ACM Date: 171/1111. /s/ 11-1- Production ' 1-Production Scanning IIIIIIIIIIIIIIIIII Stage 1 Page Count from Scanned File: ISO (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: �ES NO BY: WM. Date: 7/i JLf. 1/s/ 1— Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 11111111111111111 ReScanned 111111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked II 11111113M I r 0 c ' v u_ 4 I w a J W 4 Z o iw a o w 0 w co �� co m `° s M U !, y a) 1/1 �j a c4 a 0 a a 0 O d�� W 0 0 y O mQ'V(' 1 °? EIIay. o of o� of � � a5 2u_ �' >, co E''00 p 2° � a) 2a a) UJ C 2 o cL m 0 NIX N m MCC co ns Z w ID z 0 L [0 m L 00 CO L _C7 " , Iii c �' 1' o a 0-UJ as CL UJ as WUvas d co 1 ¢ 1a v I c I c a, _ O o > CL m'0 ,0 IO O O 0 0 0 0 G'. i N N N N N N N ._ co co co co co co M U Q. E iii ib-. c0 co co p c0 c Z Nd 2 C C C C C C C E c =OU a a) a) a a a) 0. 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LQ .- Of L .z �OE mu Ip ° 1 c 6 a)0 ly N P O V rnC tiZW O 0 X > m a O c O a ~ -a,lo, a; o0000 2\2i a a2 1 1 d 3 3 J 3 9 3 W 1 0 J 0 H _ ¢ 0 UC Q w O 9 ‘i' r •' Cr- ‘- O Z N r> 0 o h p i.. 4.--' a Q ` U d 2 Q01 Y ' m m O N a CZa �i. 0 O I, UJ W Z it U ° ad Z 8 a Q w R N d J O I, a H N;, 1 O E U � a 4 Y II"'" N r- 1 ~ O 2 N GM W Q' COp NC d• Ti Q Yg a) Q c a z E Q E U j'I 'asZ .) I 3 alI 0) m O y N N d Q. V rn y CO E n O 0 o a 2 0 0 ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑✓ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., i xI( % if 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: J 211-049/311-363 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 April 28,2011 50-103-20111-01 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 121'FSL,94'FEL,Sec.2,T1ON,RO8E, UM May 31,2011 2K-08A Top of Productive Horizon: 8. KB(ft above MSL): 146'RKB 15.Field/Pool(s): not reached GL(ft above MSL): 118'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 929'FSL, 1364'FEL,Sec.3,T1ON,R8E,UM 9441'MD/6098'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-498310 y- 5938425 Zone-4 9441'MD/6098'TVD ADL 25588,25589 TPI: x-na y- na Zone-4 11,SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-491760.6 y- 5939237 Zone-4 none 2674,2675 18.Directional Survey: Yes ❑✓ No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1464'M/1424'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 7512'MD/5268'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 35' 115' 35' 115' 24" 179 sx AS II 9.625" 36# J-55 35' 3770' 35' 2905' 12.25" too sx AS III,520 sx Class G 7" 26# J-55 41' 7434' 41' 5227' 8.5" 230 sx Class G 4.5" 12.6# L-80 7222' 9441' 5097' 6098' 7" 310 sx Class G v 24.Open to production or injection? Yes ❑ No 0 If Yes,list each 25. TUBING RECORD Interval open(MD+ND of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) 4.5" 7222' 7222'MD/5097'ND none 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. i o:,,_ , DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 7601'-8357' 204 sx Class G '�^ 7900-8500' 185 sx Class G 6830-7482 140 sx Class G 7301'-7581' 63 sx Class G 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(torr) Press. psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and C'IMIt.H7P lithningy and presence of oilaas 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. RECEIVED NONE FEB 0 8 2012 RSDMS FEB 0 8 2 Alaska Oil&Gas Cons. Commission Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Anchorage Submit original only 28. GEOLOGIC MARKERS(List all formations and m. encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑✓ No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1464' 1424' needed,and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: none 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: ry Eller©263-4172 Printed Nam.) L L -1 Ti Title: CTD Engineering Supervisor (-7 / 2-11)12 Signature 1A Ii 1: A IVA. Phone 263-4021 Date 2- Sharon Sharon Allsup-Drake 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 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, February 02, 2012 10:22 AM To: 'Eller, J Gary' I 1 0 45? Cc: Davies, Stephen F (DOA); McMains, Stephen E (DOA) Subject: 2K-08A and 2K-08B(PTD 211-049 and 211-152) Gary, We (Steve, Dave and myself) sat down and discussed the reporting dilemma regarding 2K-08 and have come to a final decision: 2K-08A needs a 407 report with it P &A'd as a final status. (As soon it was sidetracked with CTD for the 2k-08B it was abandoned technically). This closes out this PTD . 2K-08B needs a 407 reporting it as suspended. You have all the drilling reports/directional to us already so just need a redone 407 page. There will be PB1, PB2 and the final failed attempt would be called 2K- 08BPB3 as you have done already. The two other PTDs (2K-08BL1 and 2K-08BL1-01) should be withdrawn (can be done by an email request) since they will never be drilled. When you decide to reenter the well the next wellbore will be 2K- 08C and at that time 2K-08B will be closed out by P &A ing it. I hope this makes sense ... please call me with any questions. This was an unusual well sequence so I apologize for the inconsistency on our part. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 2/2/2012 2K-08A Well Work Summary DATE SUMMARY 6/1/11 Continue to weight up f/ 11 ppg to 12 ppg, monitor well-slight flow-breathing, trip out f/9217'to 7425' (pulling some, pumping some out), circulate bottom's up,trip f/7425'to 3745'-pulling some on elevators, pumping some out due to incorrect hole fill. 6/2/11 Con't to POOH on elevators from 3745', lay down Sperry Sun BHA, clean floor, flush BOP stack, RU to run 4-1/2" 12.6 ppf L-80 SL-HT liner, PJSM, Run liner to 2221', Run liner on 4"drill pipe to the window @ 7434' , CBU, con't to run liner in the open hole to 9424'. 6/3/11 Make up Baker cement head and a single of 4"drill pipe, circulate and condition mud f/cement job, PJSM, cement 4-1/2"liner, set hanger, set packer, test to 1000 psi, PU, circ, cut drilling line, POOH w/liner running tool, Rig up/Run 4-1/2"liner. 6/4/11 Run upper completion. Tag up. Displace to seawater. Space out and land. Test tubing and annulus, shear DCK valve, nipple down BOP stack. 6/5/11 Nipple up and test production tree. Lay down all drill pipe. Freeze protect well, release rig @ 20:00 hrs. 10/24/11 DRIFTED TO 8663' RKB W/3.80 CENT, DRIFT W/2"X 5'DRIVE DOWN BAILER TO 8689' RKB SAMPLE THICK DRILLING MUD TAKE SAMPLE IN 11/27/11 PRE CTD MIT-OA( PASSED ), PT SV, MV,SSV( PASSED) DDT SV, MV, SSV( PASSED) T-POT( PASSED), T-PPPOT( PASSED), IC-POT( PASSED), IC-PPPOT( PASSED ). 12/6/11 GAUGED TBG TO 3.78"TO 7170'SLM. SET SLIP STOP CATCHER @ 7142'SLM. PULLED SHEARED SOV FROM 7114' RKB, REPLACED WITH DV. MITIA 2550 PSI, PASSED. PULLED CATCHER FROM 7142'SLM. READY FOR BPV. 12/13/11 Move from 2K-28 to 2K-08. NUBOP's & hard lines. Begin reel swap. Rig Accept at 22:00 HRS. !i-//7/1( (et ZIP--D O LOAlt 40.4AA ,1-40 wWv- C -vtAtort Page 1of1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, February 02, 2012 10:22 AM To: 'Eller, J Gary' Cc: Stephen F (DOA • cMains, Stephen E (DOA) Subject 2K-08A nd 2K-08B (PTD 211-049 nd 211-152) Gary, We (Steve, Dave and myself) sat down and discussed the reporting dilemma regarding 2K-08 and have come to a final decision: needs a 407 report with it P &A'd as a final status. (As soon it was sidetracked with CTD for the 2k-08B it was abandoned technically). This closes out this PTD . 2K-08B needs a 407 reporting it as suspended. You have all the drilling reports/directional to us already so just need a redone 407 page. There will be PB1, PB2 and the final failed attempt would be called 2K- 08BPB3 as you have done already. The two other PTDs (2K-08BL1 and 2K-08BL1-01) should be withdrawn (can be done by an email request) since they will never be drilled. When you decide to reenter the well the next wellbore will be 2K- 08C and at that time 2K-08B will be closed out by P &A ing it. I hope this makes sense ... please call me with any questions. This was an unusual well sequence so I apologize for the inconsistency on our part. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 2/2/2012 L 7 SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Gary Eller CTD Engineer ConocoPhillips Alaska, Inc. aW 0 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K-08A Sundry Number: 311-363 Dear Mr. Eller: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel . Seamount, Jr. Chair DATED this.j60 dayof November, 2011. 3 Encl. `° " 'TATE OF ALASKA RECEIVED' ALA OIL AN \S CONSERVATION COMMI: V APPLICATION FOR SUNDRY APPROVALS " 7 . il PH( 20 AAC 25.280 1.Type of Request: Abandon 1'�Plu for Redrill A��b�( ®Ig pro e o Ct]1( ItSSIQn yp q g Perforate New Pool Repair w ell j"" ange prove ogram t Suspend r Aug Perforations r Perforate r Pull Tubing f A nAhlowsion r Operational Shutdown E Re-enter Susp.Well Stimulate r Alter casing Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 T. Exploratory r 211-049 • 3.Address: Stratigraphic r Service 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20111-01 • 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r 2K-08A , 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25588,25589 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9441 6098 9441' 6098' 7452' none Casing Length Size MD TVD Burst Collapse Conductor 74' 16" 115 115' Surface 3729' 9.625" 3770' 2905' Intermediate Production 7393' 7" 7434' 5227' Liner 2222' 4.5" 9441' 6098' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none none 4.5 L-80 7222 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-LINER TOP PACKER MD=7222 TVD=5089 NO SSSV 12.Attachments: Description Summary of Proposal 13. Well Class after proposed work: r Detailed Operations Program r BOP Sketch Exploratory r Development Service 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/1/2011 Oil r Gas r WDSPL r Suspended 'I 16.Verbal Approval: Date: WINJ fl GINJ r WAG r Abandoned 49 J i- Commission Representative: GSTOR SPLUG r '� 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Gary Eller @ 263-4172 Printed Name Gary Ell r Title: CTD Engineer Signature (j\‘.1 Phone:263-4172 Date \\lk.,(9\� Commission Use Only lllt Sundry Numbe13l I -NO3 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test 114Aechanical Integrity Test r Location Clearance Other ...J.-is-doPsz_ zoe GSi' 11 I A( „-K .n P/tti ff' � ..,. t .. .,,J 4C 2.500 COs:- ,BO,� 11-"e7-5l R..,orrovc 1-i.-- zO AAA_ ZS.in—CZ) Subsequent Form Required: /o.-zi C-7 110 APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: /1/ 30 1 I 74 /izp•� ?DMS NOV 3 01 11 17 "'( Form 10-403 Revised 1/2010 R I G I A t A L Submit in Duplicate I( e a • L. UP 2K-08A " Well Max Angie&MD TD �OI�OC(�P�tl��lj35 nP.I)N9, _ A;a0a,Inc Wellbore AP 5V Fjeld-Name Well Status Ind() MD(NKB) Act Btm(NKB) r,Ixxx0FTIA :, 50103261 1 1 KUPARUK RIVER UNIT PROD 66.81 8,891.69 9,4410 Cment H25(ppm) iDate Annotation End Date _KB-Card(ft) Rig Rebase Date SSSV:NIPPLE ... 11 -I _. ---I - r- NJe4SRglg;.r.,.gl)A 7!3?Yi,U„11;3s 30 AM _. 0 1/13/2009 Last WO: 40.191 9/2/1989 ai A - _ 9 Depth(NKB) IEnd Date Annotation Last Mod._End Date Last Tag: I. 8,205.0::: ( 4/13/2011 Rev Reason:ADD SIDETRACK nmam 6/18/2011 HANGER.24- Casing Strings Casing Description 0scd tion 'String 0... I StrinID...To NKB) Set Depth(l...ISat Depth(TVD) String WI. StnngTp1 hrd • LINER 3.958 7,222.0 9,443.5 i .60 String SLHT li diner Details Top Depth (TVD) Top Incl Nomi... Top:1103) (11KB) (1 Item Description Comment ID(in) 7,222.0 5,088.9 56.01 PACKER Baker"HRD"ZXPN liner top packer 5"x 7"26 ppf L-80 5"BTC(/TKC pin 5.250 (10'PBR) 7,241.8 5,101.7 56.27 NIPPLE "RS Packoff Seal Nipple w/TKC couping on top and bottom 4.250 7,245.4 5,104.1 56.31 HANGER Baker"OG"Flex-Lock liner hanger 5"x 7"23-26#L-80 Flex Lock 5"BTC 4.380 for TKC pin x pin CONDUCT35-115 OR, 7,255.6 5,110.6 56.45 SBE Baker 80-40 Seal Bore Extension 5"TKC pin x pin 4.000 Tu b i ng_Stri nes____. Tubing Description __..I Str4ing1/02...1 Str3n95ID8..Top(2(2f7518)) !Set Depth(f...!Set Depth(TVD) String Wt Strng...String ITBoTpM T hrd IIP TUBING Completion Details 7,229.7 5,093.9 12.60 I L80I - _ Top Depth i GAS LIFT a-. (TVD) Top Incl Nomi... 3,098 - Top(NKB) MB) (7 Item Description Comment 118( ) n RW 24.5 -800.5 -36.73 HANGER FMC Gen IV 4-1/2"tubing hanger(EUE 8rd top and bottom) 4.500 05 r_.. 5.2 -84__-.-._.-.__ _- 507.0 -30.53 NIPPLE 4-1/2""X"Nipple w/3.813"profile,IBT-m 3.813 .j::. 7,168.0 5,053.2 55.32 NIPPLE 4-112""X"Nipple w/3.813"profile,IBT-m 3.813 7,219.2 5,087.1 55.98 LOCATOR Baker Bullet assembly Locator 4.350 IL 7,220.2 5,087.7 55.99 SEAL ASSY Baker Bullet Seal assembly 4.350 SURFACE35.3,771. A 7,229.1 5,093.5 56.10 MULE SHOE Baker 1/2 Mule Shoe 4.350 �aawr GAS LIFT, 4,733 lit GAS LIFT,._--_ D�f f} 17P-e/ /elt4rGY ry f,e/t- 5.830 C ohc d. . 2,(4- r!, tl.q s /Wye, 4(0(141 r'y t0 �cbloe,,e�4 GAS LIFT. ��� ^ 6,558 4 rsfai 'Aft ft iefe ,10 /'PSPNAJ 4'1/1e4/ , GAS LIFT. ` 4 fr(`irlif 7.115 1' kr 1 NIPPLE,7,168 �J. • LOCAT7,219OR,__ SEAL ASSY, 7,220 MULE SHOE, 7,229 j 1 Top Depth Top Port PRODUCTION, (TVD) Incl OD Valva Latch Size TRO Run 27.9,423 Stn Top_RIJEA_(NKR) (1 Make_ Model (in) Sery TYM TYR. (in) (Pail Run Date Can_. 1 3,098.0 751.1 2.87 Cameo KBG-2 1R 1 GAS LIFT DMY BKS 0.000 0.0 6/4/2011 2 4,732.5 2,636.7 23.94 Cameo KBG-2 1R 1 GAS LIFT DMY BK-5 0.000 0.0 6/4/2011 3 5,829.9 3,879.4 38.08 Cameo KBG-21R 1 GAS LIFT DMY BK-5 0.000 0.06/4/2011 4 6,598.1 4,616.2 47.97 Cameo KBG-21R 1 GAS LIFT DMY BKS 0.000 0.0 6/4/2011 5 7,114.5 5T016.8 54.63 Cameo KBG-2 1R 1 GAS LIFT SOV BEK 0.000 0.06/4/2011 TO(2K-08A), 9,441 LINER,_ 7,222-9.444 KRU 2K-08B, BL1, & BL1-01 — Coiled Tubing Drilling Summary of Operations: Well KRU 2K-08A is a suspended well equipped with 4'/2"tubing and 4'/2"production liner. In June 2011, it was TD'd and cased in the Kalubik shale short of the originally targeted Kuparuk C and A sands. A CTD sidetrack out of the 41/4" liner will be drilled and cased across the Kuparuk C and A sands.'Two A-sand CTD horizontal laterals will then exit this cased section and be drilled west to increase reservoir exposure. Initially the BOPE for Nabors CDR2-AC will be equipped for`bighole' CTD operations(i.e. 3"BHA). Our first operation will be to drill cement out of the 4'/2"shoe track from 9348' to 9440' MD. The 2K-08B sidetrack will ultimately exit the 4'/2" liner at 9425' MD from a mechanical whipstock,rendering the cased / interval below 9425' effectively abandoned in 2K-08A. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to abandon 2K-08A in this manner. J N,4 "ba .. Caret . After setting the whipstock and milling a window in the 4'/2"liner,we will drill through the Kalubik shale and the C-sand into the A-sand with a 41/4"bi-center bit to a depth of 9780' MD. We will then run 580' of 31/4", 6.6 ppf,L-80 liner with TC-II connections from 9200' to 9780'. The 31/4"liner will be cemented in place with 7 bbl of 15.8 ppg cement,which will isolate the Kuparuk sands and the Kalubik shale behind pipe. After reconfiguring our BOPE for slimhole operations(i.e. 2%"BHA),we will set a whipstock in the 31/4"liner at 9650' MD and then make a window exit at that depth. The 2K-08BL1 lateral will be drilled with a 3"bi- v center bit targeting the A4 sand west of 2K-08B with a 2920' lateral. The lateral will be completed with 23/8" slotted liner to the TD of 12,570' MD with an aluminum billet at 10,100' MD. The 2K-08BL1-01 lateral will kick off from the aluminum billet at 10,100' MD and will likewise target the A4 sand west of 2K-08B well with a 2045' lateral. The hole will be completed with a 2W slotted liner to the TD of 12,145' MD with the liner top inside the 31/4"liner at 9640' MD. After completing the 2K-08BL1-01 lateral, as a contingency we will possibly run a 31/4"x 4'/2" liner-top packer at 9200' to provide further isolation to the C-sand formation that is behind the 31/4"cemented liner. The decision to run a liner-top packer will be based upon the thickness and reservoir quality that we find in the C- sand as well as success of the 31/4"liner cement job. Drilling Program - 20 AAC 25.005(c)(13) Pre-CTD Work 1. Positive pressure and drawdown tests on master valve&swab valve 2. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2%"coiled tubing. NU 7-1/16"BOPE,test. BOPE will be configured for`bighole' CTD operations. 2. 2K-08B Sidetrack(Intermediate Hole Section) Pg a. Drill out the 41/2"shoe track to a depth of 9440'. h. b. Set whipstock in 4%2"liner at 9425' MD ? 2K-" c. Mill 3.80"window with high-side orientation at 9425' MD d. Drill 3.70"x 4'/8"bi-center lateral to TD of 9780' MD ✓ e. Lay in over-balanced fluid prior to running liner f. Run 31/4"blank liner with TC-II connections from TD up to 9200'inside the 4%2"liner g. Cement 31/4"liner in place with 7 bbl of 15.8 ppg cement using 2%e-coil November 16, 2011, FINAL I G I f\ Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, October 13, 2011 10:57 AM I n) Z!/—O`'f °1 To: 'Eller, J Gary' Cc: Davies, Stephen F (DOA) Subject: RE: 2K-08A Proposed Drawing Gary, I see your point. We are ok either way but you would have to P &A the 2K-08A lateral first(at least on paper) so a 403 requesting P &A for that leg would be needed. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Thursday, October 13, 2011 9:37 AM To: Schwartz, Guy L (DOA) Subject: 2K-08A Proposed Drawing Guy—Let's discuss again, this time with you have the benefit of a schematic. After thinking it through some more, I think it would be much less confusing to give the CTD intermediate section (9300'—9731') the designation of 2K-08B. At this point, months after rotary has drilled and suspended 2K-08A, it will create much added confusion to rename part of that hole as a plugback. We'd have to rename directional databases, log databases, etc to accommodate the interval from 9300'—9444' as a plugback. Major confusion with a good possibility of screwing it up. It seems much simpler at this point to have CTD start fresh with the B designation, and then the slimhole CTD laterals would be 2K-08BL1 and 2K-08BL1-01. Does that make sense? Let's talk. 3. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1158 10/13/2011 11411. I w » $ e % = Ey § G k7 ¥. - ¥ \ /# & -G - k { \ \ o \ k §- 0iri- f* 555 �/ .2 § E \ � � 2 § $ » CO u � ID_ / - / \ e` i 13 § \ ��CO-0 . 2 . . :�I IJI m co- r- . O. . ' } ` , ; n \9 CA j I —I / 6 , ( ( \ , ! - 1 ! 1 ! 1 ! 1 ! o \ 1ri a SW EU % CO n c£ \ ! X 3 - e P \ g _ \\ Q. \ CO .6 � m 3= 2 5ED x H m -n r = d ¥ � ƒ \ x o f x & E � { g = \ $ & f = - p E § \ § _ o k \C) % / § \ } / G \ \ & � 3z � bo / 7 •- CO \ � -' \ » { N \ / \ $ § � S -..-. _ � co _ - m22 (Dm � gm 6 5c) 7:1 \ 0 / » k . co _ Et) » m - s » - @ J* CO cn - _ _ 9 a § { \ \ ' tet ® - a o_ \ % / \ Q ( ' � a) 0_ \\ \ § j \ /_ \ § � § \ ® b * G �¥ _ - / C § /\ / _, § \ / \ /I) 2 9 k - / 0 0 WELL LOG TRANSMITTAL To: State of Alaska June 9, 2011 Alaska Oil and Gas Conservation Commission Attn.: Howard Okland 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501-3539 RE: LWD Formation Evaluation Logs: 2K-08A+PB2+PB3 AK-MW-0008099838 2K-08A+PB2+PB3 50-103-20111-01: -71: -72 2"x 5" MD GAMMA RAY/RESISTIVITY Logs: 1 Color Log for each wellbore 2"x 5"TVD GAMMA RAY/RESISTIVITY Logs: 1 Color Log for each wellbore Digital Log Images&LDWG-formatted LIS Data w/verification listing; 1 CD Rom lq " ‘ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Buster Bryant 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3539 Fax: 907-273-3535 Buster.Bryant@halliburton.com Date: ` 3 J vi Signed: ,® •.-�0 RECEIVE Pr' STATE OF ALASKA ALASKA` AND GAS CONSERVATION COMMISSIC__ JUN 1. 3 2011 REPORT OF SUNDRY WELL OPERATIONS Alaska Gil 4Ax finrt Remission 1.Operations Abandon U Repair Well U Plug Perforations U Stimulate H Other} Performed: Alter Casing ❑ Pull Tubing❑ Perforate New Pool ❑ Waiver ❑ Time Extension ' ' `'f t�gtz Change Approved Program ❑ Operat.Shutdown Q Perforate ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska,Inc. Development Q Exploratory ❑ PTD:211-049&Sundry:311-155,311-192 3.Address: Stratigraphic El Service ❑ 6.API umber: P.O.Box 100360,Anchorage,AK 99510 50-'113640111-01-00(i 11 t�8� ic11 1' rMt' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25588,25589 2K-08A .. 9.Field/Pool(s): Kuparuk River Field I Kuparuk River Oil Pool 10.Present Well Condition Summary: Total Depth measured 9441 feet Plugs measured None feet true vertical 6097.7 feet Junk measured None feet Effective Depth measured 9441 feet Packer measured 7221.9 feet LINER TOP true vertical 6097.7 feet true vertical 5096.6 feet Casing Length Size MD ND Burst Collapse Structural Conductor 74' 16" 115' 115' Surface 3729' 9-5/8" 3770' 2905' 3520 psi 2020 psi Intermediate Production 7393' 7" 7434' 5227' 4980 psi 4330 psi Liner 2221.6' 4-1/2" 9443.5' 6099' 8430 psi 7500 psi TOP Sj r k t.!P.AKu(C Perforation depth Measured depth None feet > c z-c.„ True Vertical depth None feet .2%., Tubing(size,grade,measured and true vertical depth) 4-1/2" L-80 7221.9'MD 5096.6'TVD Packers and SSSV(type,measured and true vertical depth) Liner Top Packer 7221.9'MD 5096.6'TVD 11.Stimulation or cement squeeze summary: Intervals treated(measured): None Treatment descriptions including volumes used and final pressure: None 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 Subsequent to operation: 0 0 0 13.Attachments: 14.Well Class after work: Copies of Logs and Surveys Run Surveys&Tubing Test Exploratory Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations Daily Drilling 15.Well Status after work: Oil ❑ Gas ❑ WDSPL U GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑✓ SPLUG❑ 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: 311-192 Contact: Elmo CecchettieaG 263-4249 Printed Name:Chip Alvord Title: Drilling Manager Signature: Af_ aok Phone: 265-6120 Date: 6(to(tot( RBDMS my 13 20iidt143. 6 •zZ'// Form 10-404 Revised 10/2010 Lot,hdpor( Submit Original Only 2K-08A Top Set Rotary Sidetrack — CTD Setup Upper Completion Top MD/TVD 16"62.5#H-40 1) 4-1/2"12.6#L-80 "X"Nipple 3.813"ID 505.1'/505.0' 115'/ 115' 2) 4-'h"X 1"KBG-2-1R GLM 3.833"ID 3097.9'/2503.3' Arctic Pack 60 bbls-2222' original 11 3) 4-''/z"X I"KBG-2-1R GLM 3.833"ID 4732.5'/3506.8' 4) 4-/a"X 1"KBG-2-IR GLM 3.833"ID 5829.9'/4202.6' • 5) 4-'h"X 1"KBG-2-1R GLM 3.833"ID 6598.1'/4700.7' D6) 4-'h"X 1"KBG-2-1 R GLM 3.833"ID with SOV 7114.5'/5027.0' • 7) 4-1/2"12.6#L-80 IBT-M li Arctic Set I 8) 4-1/2"12.6#L-80 "X"Nipple 3.813"ID 7167.9'/5061.4' 29 bbls-1072' ' 9) 4-1/2"12.6#L-80 IBT-M Tubing Pup 10) Cross Over 4-1/2"IBT-M box X 5"BTC pin 9-5/8"36.0#J-55 11) Tie Back Seal Assembly Locator 7219.2'/5094.8' Mli 3,770'/2,905' Original RKB 11) Tie Back Seal Assembly with 1/2 mule shoe 7229.7'(Bottom) IV Lower Completion Top MD/TVD 4-1/2"12.6#L-80 1) *Baker 5"X 7"L-80 HRD ZXP Liner Top Packer 7,221.9'/5096.6' IBT-M SCC 4.92" 2) *Baker 5"X 7"L-80 DG Flexlock Liner Hanger 7,245.4/5111.9 4-1/2"Liner Top r TOL-Surface 3) *80-40 Seal Bore Extension BTC with TKC couplings 7,255.5'/5118.4 7,221.9'/5096.6' ' 4) Coupling 5"TKC 4) Cross Over 5"BTC-M pin X SLHT pin Sidetrack KOP 5) 4-1/2"12.6#L-80 SLHT pup joint thru window in 7" 6) 4-'h"12.6#L-80 SLHT casing 7) Cross Over SLHT box X Hydril 521 pin 7,434'/5,227' 8) Landing Collar Hydril 521 9,348.1'/6056.6' L. MI6. 9) **Cross Over Hydril 521 box X BTC-M pin 10) **4-%"12.6#L-80 BTC-M casing(1 joint) ,- , : i ,,t 11) **4-1/2"Float Collar BTC-M 9,380.9'/6071.0 12) **4-1/2" 12.6#L-80 BTC-M casing(2 joints) 13) **4-1/2" EZReam Float Shoe BTC-M box 9,443.5'(Bottom) *BTC pins have been modified for TKC couplings to allow higher torque. 7"Cement Retainer i i **Torque rings are to be installed in BTC couplings(shoe track) 7,452'/5,238' I I ***Liner shoe setting depth is 2.5'deeper than drilled TD depth. .'1-IRZ 8,671.6'/5775.5' Sidetrack KOP Upper Kalubik 9,292.2'/6032.5' thru window in 7" , 7,512'/5,274' tai._ Fault#1 9,354.4'/6059.5' Lower Kalubik—Faulted Out 7"Cement Retainer riiiiiiiiiiiiiiimm 7,531'/5,286' '.�= 6-1/8"Open Hole TD _ - 7"Perforations ' 9,441.0'/6,097.7' Tubing Cut - 7,539'-7,549' . 7,668/5,369' ' Original RKB , P&A TOC 3-'/="CIBP , 7,722'Annulus ./ 7 4-1/2"12.6#L-80 SLHT liner 7,800'/5,448' P 8,254'Tubing ' Original RKB ;! (2,221.6') 9,443.5'/6099.0' To 7 SE.r M Open 8-%:"x 7"TOC C Sand 9,493'!5,981' doJ� K;�' •8,24848''//5,722' 8,300'/5,756' `� Original RKB • Original RKB Estimate Baker HB Packer 8,872'/6,096' 1::: Origaai RKB / 3-%s"CIBP0 i5 1 8,905'/6,114' Original RKB �. ."— Perforations -maiNB"- 9,012'-9,044' 1 —al No- 9,022'-9,032' -oil t .- 9,100'-9,140' Pi3Z- Revised by: ////// 7"26#J-55 casing Elmo Cecchetti 9,423'MD/6,378'TVD June 8, 2011 Original RKB (Actual Depths) r X00 t 12 :::: ../ r.:.: , . 4011 iisiii, . =01E-- 1 • - IJP .1111110„64 ap ..... f "rea4 4/00, �9 o '.6 • O 00 O *V.S.� OO ,' \. ..\. . ` v • . O W f • 1 11/44 f • .s • s bra. /�� \' 4�( + ,000•,irao ' 4 ', '\ '. • /Ili , 00� , . . ... .,,, .. • • :,.., ;:i:000 `,.• . Yj • • 1000 - i _.� -- = '~- .WSJ ConocoPhillips Time Log & Summary Wel!view Web Reporting Report Well Name: 2K-08 Rig Name: DOYON 141 Job Type: DRILLING SIDETRACK Rig Accept: 4/20/2011 5:00:00 PM Rig Release: 6/5/2011 8:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 34/18/2011 24 hr Summary Completing rig work on CD4-210. Rig release. 16:00 00:00 8.00 0 0 MIRU MOVE MOB P Clean pits, blow down sub base and rockwasher. Disassemble handy berm and herculite from sewer plant. Prep and move Doyon rig camp to 2K-08A. Camp moving from CD4-210 -to 2K-08A @ 22:30 hrs. 34/19/2011 Moved all rig complexes off of CD4-210. Stage complexes on 2K pad. Moving substructure 00:00 00:00 24.00 0 0 MIRU MOVE MOB P Moving Doyon 141 to 2K-08A. Prepping location. 34/20/2011 Completed pad preparation. Spotted sub over well. Spotted all rig complexes. Rig accepted @ 17:00 hrs. Rig up to circulate out diesel freeze protect. Pressure tested lines. Pulled BPV. Drill site maintenance notified to pull VR plug. 00:00 03:30 3.50 0 0 MIRU MOVE MOB P Move sub base from mile 8 of ice road to 2K pad. Spot pipesheds on 2H-pad. 03:30 04:00 0.50 0 0 MIRU MOVE MOB P Stage sub base and rockwasher on 2K pad. 04:00 05:30 1.50 0 0 MIRU MOVE MOB P Roads and pads prepping and leveling location. 05:30 09:30 4.00 0 0 MIRU MOVE PSIT P Set matting boards and lay herculite. Spot cellar tank and tree in cellar area. Spot sub over well. 09:30 12:00 2.50 0 0 MIRU MOVE PSIT P Set mats on 2K for modules. Hook up sows to pits and pump complexes. Move complexes from 2H to 2K pad and spot. 12:00 16:30 4.50 0 0 MIRU MOVE PSIT P Spot motor, boiler complexes. Set mats for pipeshed and rockwasher. 16:30 19:00 2.50 0 0 MIRU MOVE RURD P Work on items associated with rig acceptance checklist. Calibrate gas alarms, Level pipeshed, Hook up Glycol,steam,water and air. Rig accepted @ 17:00 hrs. 19:00 23:30 4.50 0 0 SLOT WHDBO RURD P Run hardline to tiger tank, Pull BPV, Rig up to circulate diesel freeze protect out of well. Blow air through lines to verify clear. Pressure test lines 250 psi low and 3,500 psi high. Outer annulus pressure= 500 psi. 23:30 00:00 0.50 0 0 SLOT WHDBO CIRC T Attempted to pump down annulus VR plug set. Drill site maintenance notified to retreive VR plug.** Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 34/21/2011 24 hr Summary Pull VR plug, Rig up and circulate out diesel freeze protect and inhibited seawater with clean seawater. Pumped at 3.2 bpm final circulating rate. Final circulating pressure 2,300 psi. Set BPV and test under BPV to 1,000 psi. Nipple down tree, Nipple up BOPE.Test BOPE.Test witnessed by AOGCC rep John Crisp. Rig down from BOPE test. Pull blanking plug and BPV. Make up spear, Spear into hanger. Back out lock downs. Pull hanger free 95K up wt. Release spear and lay down. Break out hanger from string, Make up headpin to tubing string. Circulate bottoms up at 5 bpm-650 psi. 00:00 02:15 2.25 0 0 SLOT WHDBO NUND T Attempted to circulate down tubing. VR plug set, Remove 2nd Inner annulus valve from tree, Drill site maintenance rigged up lubricator pulled VR plug. Rigged down lubricator, Made 2nd inner annulus valve back up to tree. Rigged up to circulate down inner annulus. 02:15 05:15 3.00 0 0 SLOT WHDBO CIRC P Rig up to pump down inner annulus. Take 24 bbl's returns up tubing. Swap over to pump down tubing. Pumped 73 bbl's seawater down tubing displacing diesel freeze protect from inner annulus. Erratic pressure while pumping 600 psi to 2,000 psi at 3 bpm. Shut down suck diesel out of tiger tank. Continue pumping seawater down tubing taking returns out inner annulus to tiger tank. Pumping discontinued once clean seawater at surface. Final circulating pressure 2,300 psi at 3.2 bpm. 05:15 06:15 1.00 0 0 SLOT WHDBO CIRC P Observed well for flow. Observed diesel at surface, Pumped additional 30 bbl's down tubing taking returns up inner annulus to tiger tank. Verified fluid contained no diesel. Shut down monitored well. (Static) 06:15 07:30 1.25 0 0 SLOT WHDBO NUND P Set BPV and test through inner annulus below BPV to 1,000 psi. Rigged down circulating equipment. 07:30 08:45 1.25 0 0 SLOT WHDBO NUND P PJSM, Nipple down tree and adaptor spool. Install FMC blanking plug with left handed ACME thread. 08:45 12:00 3.25 0 0 SLOT WHDBO NUND P PJSM, Nipple up adaptor flange and BOP stack. Rig on Hi-Line power @ 10:45 hrs. 12:00 15:00 3.00 0 0 SLOT WHDBO PULD P Set Riser, Pick up and rack back 30 stands drillpipe using mousehole. 15:00 16:00 1.00 0 0 SLOT WHDBO BOPE P Rig up to test BOPE. Page 2 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 20:00 4.00 0 0 SLOT WHDBO BOPE P Test BOPE,with 3-1/2"test joint, 250 psi low and 4,000 psi high, 3-1/2"X 6"VBR rams, blind rams, floor valve, upper and lower IBOP valves, Manual and HCR choke and kill line valves,4"demco kill line valve, Choke manifold valves# 1-14. !~ Annular tested 250 psi low-2,500 psi high,All tests 5 minutes.Test recorded and charted.Accumulator test start pressure 3,000 psi after close pressure 1,800 psi, 200 psi increase 43 seconds. Full pressure attained 3 min 24 sec. 5 bottle average 2,100 psi.Test witnessed by AOGCC rep John Crisp. Rig down from BOPE test. 20:00 21:30 1.50 0 0 SLOT WHDBO NUND P Pull Blanking plug and BPV, Clear and Clean floor 21:30 23:30 2.00 0 0 SLOT DRILL PULL P Make up Baker spear assembly, Drain stack, Spear hanger setting down 4k. Spear not seated until 8k down wt applied. Back out lock downs, Pull hanger moved free at 95k up wt. Pulled hanger to floor released and laid down spear. Rig up double stack hyd tongs. Break hanger from string and lay down. (2 control line bands laid down)Rig up to circulate bottoms up using head pin. 23:30 00:00 0.50 7,668 7,668 SLOT DRILL CIRC P Circulate bottoms up at 5 bpm-650 psi. X4/22/2011 Circulate bottoms up at 5 bpm-650 psi. Pull out of hole laying down 3-1/2"J55 9.3 ppf tubing and related jewelry.All equipment recovered from hole. Rig up to test lower rams. Not enough spacing between test plug and rams to test.Wait on Storm packer. Set storm packer. Nipple down BOP stack.Add 3'spacer spool. Nipple up BOP stack.Test rams with 3-1/2"and 4"test joints. Rig down from test.Trip in unseat storm packer and pull from hole. Set 6-3/8"wear bushing. 00:00 00:30 0.50 7,668 7,640 SLOT DRILL CIRC P Circulate bottoms up @ 5 bpm-650 psi. Rig down circulating equipment, _Blow down lines 00:30 08:45 8.25 7,640 0 SLOT DRILL PULL P Trip out laying down 3-1/2"tubing. Spool control line and recovered all 31 control line bands. laid down SSSV. Rigged down control line spooler.Continued tripping out with tubing lay down gas lift mandrels, Total tubing joints recovered 234 plus cut joint 14.95'with 4.25 flared cut. All tubing, Gas lift mandrels, SSSV, Control line and control line clamps recovered 08:45 10:00 1.25 0 0 SLOT DRILL PULL P Rig down hyd tongs, Clear and Clean floor. Pick up test plug,Wear bushing and Baker tools from Beaver slide. Page 3 of 62 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 10:00 10:45 0.75 0 0 SLOT WHDBO BOPE T Rig up to test lower pipe rams with 3-1/2"Test joint.Test joint with crossover to long to test lower rams. 10:45 13:00 2.25 0 0 SLOT WHDBO BOPE P Rig up and test with 4"test joint upper rams 3-1/2"X 6"variable bore rams.250 psi low-4,000 psi high. Test Annular with 4"test joint 250 psi low-2,500 psi high. lay down 4" test joint pick up 5-1/2"test joint and test upper 3-1/2"X 6"variable bore rams 250 psi low-4,000 psi high. Use 5-1/2"test joint and test Annular 250 psi low-2,500 psi high. 5 minute per test all tests charted. Rig down test equipment, Pull test plug and lay down test joint. 13:00 15:00 2.00 0 0 SLOT WHDBO EQRP T Stage 3'Adaptor spool in cellar, Prep to nipple down BOP stack while waiting on storm packer 15:00 16:30 1.50 0 0 SLOT WHDBO MPSP T PJSM, Run 10 stands in hole, Pick up wt 45k, Down wt 45k. Make up storm packer and run in hole on stand of drillpipe. Set storm packer at 74'per baker rep. release from packer and rack back stand.Close blind rams test packer pumping through kill line.Applied 1,000 psi and recorded pressure test on chart. 16:30 19:15 2.75 0 0 SLOT WHDBO NUND T PJSM-Nipple down BOP stack, Install 3'spool adapter, Nipple up BOP stack 19:15 21:30 2.25 0 0 SLOT WHDBO BOPE T Make up 3-1/2"test joint and test plug. Set test plug and test lower 2-7/8"X 5"variable bore rams. Lay down 3-1/2"test joint pick up 4"test joint.Test lower 2-7/8"X 5"variable bore rams. Both test done 250 psi low-4,000 psi high. 5 minute per test.Tests charted and recorded. Pull test plug and test joint, Rig down from test. 21:30 23:15 1.75 0 0 SLOT WHDBO MPSP T Make up top drive to stand of drillpipe, Run in hole and make up to storm packer with IBOP closed. Open IBOP monitor returns(Static) Line up on trip tank. Release storm packer.Trip out of hole with storm packer. Lay down storm packer,Trip out 10 stands of drillpipe. 23:15 00:00 0.75 0 0 SLOT WHDBO NUND P Set 6-3/8"ID wear bushing 34/23/2011 Make up scraper BHA. Single in 4"drillpipe,trip in from derrick to 7,651' MD.Tag tubing stump with 7k. Circulate 30 bbl hi-vis sweep. Continue circulating until returns clean at 8.3 bpm-1,300 psi.Trip out to surface. Lay down scraper assembly. Nipple down riser, Install shooting flange.Test flange-Test failed. Nipple down shooting flange inspect, Install new API ring.Test to 1,000 psi(Good test) Rig up lubricator. Make up wireline gyro and run in hole. — — —_--- __ -- Page 4 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 0 0 SLOT DRILL PULD P Make up 7"Casing scraper assembly 01:00 07:30 6.50 0 7,651 SLOT DRILL TRIP P Trip in hole singling in 4"drillpipe, Pick up 210 joints 4"Trip in from derrick and tag tubing stump at 7,651' MD with 7k. Set down on stump twice. 07:30 08:30 1.00 7,651 7,649 SLOT DRILL CIRC P Circulate at 8.3 bpm- 1,300 psi. Pumped 30 bbl hi-vis sweep continued circulating until returns clean. 08:30 09:00 0.50 7,649 7,562 SLOT DRILL TRIP P Rack back stand, Blow down topdrive and lines. Monitor well (Static) 09:00 12:00 3.00 7,562 15 SLOT DRILL TRIP P Trip out with 7"casing scraper assembly 12:00 12:15 0.25 15 0 SLOT DRILL PULD P Lay down 7"casing scraper assembly 12:15 14:15 2.00 0 0 SLOT WHDBO NUND P Drain stack, Close blind rams, Nipple down riser, Nipple up shooting flange. 14:15 18:30 4.25 0 0 SLOT WHDBO NUND T Pick up wireline equipment and lubricator.Attempt test to 1,000 psi. Test failed. Nipple down lubricator, Pull shooting flange and inspect, Clean and inspect flange ring groove and API ring. Install new API ring. Nipple equipment back up and test to 1,000 psi for 10 min.Witnessed by rig supervisor. 18:30 21:00 2.50 0 0 SLOT DRILL ELOG P Make up Gyro on wireline, Make up lubricator extensions. Check inner annulus for pressure, Open kill line, Fill BOPE stack. 21:00 00:00 3.00 0 7,600 SLOT DRILL ELOG P Run gyro in hole on wireline to 7,600' MD. Note** Rig Safety audit performed with Tourpusher and Doyon HSE. Crews working on correcting any items listed as deficient during walk through. Rig was found to be in very good condition** Outer Annulus Pressure 340 psi 34/24/2011 Pull gyro out of hole on wireline, Make up caliper logging tool, Run in hole perform caliper log F/7,650' MD to surface, Rig down caliper logging tool, Make up 10'perforating gun and run in hole. locate casing collar© 7,535'MD. Perforate casing top shot 7,539'MD Bottom shot 7,549'MD. Pull out perfgun on wireline. Monitor well, Lay down shot pert guns. Drain stack, Close blinds, Rig down shooting flange, Rig up lubricator, Make up Baker 7"K-1 cement retainer, Run retainer in hole on wireline, Set cement retainer @ 7,531'MD. Pull out of hole with wireline, Test cement retainer and casing 3,500 psi(Shear assembly found intact did not shear-reason for pressure test)Rig down wireline, Make up cement retainer stinger and run in hole on 4" drillpipe. Sting into retainer, Est injection rate Final circulating rate 2 BPm- 1,900 psi. Shut in pressure 1,500 psi. 00:00 01:45 1.75 7,600 0 SLOT DRILL ELOG P Pull gyro out of hole with wireline F/7,600'MD to surface. Rig down gyro tool from wireline. L_-_ Page 5 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:45 02:45 1.00 0 0 SLOT DRILL ELOG P Make up wireline run#2 Caliper logging tool. **Sim-ops. Load pipeshed with 16 joints 4"HWDP and 3 joints Non Mag Flex Drill Collars for upcoming whipstock run.** 02:45 06:45 4.00 0 0 SLOT DRILL ELOG P Run in with caliper logging tool on wireline to 7,650' MD, Pull caliper tool out of hole and lay down same. 06:45 08:15 1.50 0 0 SLOT DRILL PERF P Rig up Wireline to 10'perf guns (Wireline run#3) 08:15 09:15 1.00 0 7,549 SLOT DRILL PERF P Run in hole with pen`guns on wireline, Locate casing collar @ 7,535'MD. Shoot perf guns top shot _Jat 7,539-MD=Rottnm shot at 7.549' MD. 09:15 10:30 1.25 7,549 0 SLOT DRILL PERF P Pull out of the hole with perf guns, Monitor well(Static)Lay down perf gun assembly. 10:30 11:15 0.75 0 0 SLOT WHDBO NUND P Drain stack,Close blind rams and kill line,Change out shooting flange, Rig up lubricator. 11:15 14:30 3.25 0 7,531 SLOT DRILL PACK P Rig up wireline to K-1 cement retainer. Run in_hole_andLset retainer r at 7,531'wiraline-measurement_ 14:30 15:45 1.25 7,531 0 SLOT DRILL PACK P Pull wireline out of hole with K1 cement retainer running tool. 15:45 16:15 0.50 0 0 SLOT DRILL PRTS P Close blind rams. Rig down lubricator, Inspect K1 running tool. Found shear assembly did not shear was still intact for this reason quick 3,500 psi test applied to test casing and retainer. 5 minute test witnessed by rig supervisor. 16:15 17:15 1.00 0 0 SLOT DRILL RURD P Rig down wireline equipment and sheaves. Nipple down lubricator riser and mousehole. 17:15 19:00 1.75 0 0 SLOT WHDBO NUND P Nipple down shooting flange, Nipple up bell nipple and stack riser to BOP stack. Blow down kill line. 19:00 22:00 3.00 0 7,440 SLOT DRILL TRIP P Make up cement retainer stinger and crossover to drillpie.Trip in hole to 7,440' MD. Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 7,531 7,531 SLOT DRILL CIRC P Make up top drive, Up wt 127k down wt 90k, Break circulation at 3 bpm- 150 psi, Shut down pumps,Slack off and tag retainer on depth at 7,530' MD,Sting into retainer 15k down weight. Pull out of retainer with 5k overpull. Pull up break off single, Blow down top drive, Make up head pin and cement hose to single. Make single back up to string. Break circulation to fill cement lines.Shut down pump,Slack off and sting into retainer with 15k down weight. Establish infection rate Initial rate 1/2 born-1,730 psi, 1 bpm-1,840 bpm, 1-1/2 bpm-1,900 psi Final circulating rate 2 bpm-1,950 psi. Shut in pressure 1,500 psi.Total 15 bbl's pumped. Returned 1 barrel when pressure bled off. No change to OA pressure during injectivity test. OA pressure 430 psi,. 04/25/2011 Est injection rate,2 bpm-1,900 psi, Unsting from K1 cement retainer, Pump 5 bbl's mudpush, 15 bbl's cement,5 bbl's water holding 270 psi back pressure with choke, pump 635 strokes(54 bbl's)seawater bringing mudpush to stinger. Shut down pump,close choke, Slack off and sting into K1 cement retainer(15k down)Open choke, bleed off annulus pressure,open annular while squeezing cement at 2 bpm 1,850 psi. Shut down after 235 strokes 5 bbl's mudpush and 15 bbl's cement squeezed. Pull stinger out of K1 cement retainer.Cement in place 02:00.Circulate bottoms up.Shut down break off single, Rig down head pin and cement hose. Install ball wiper(Nerf ball)into drill string. Make single up to topdrive.Circulate surface to surface. Hold PJSM, Displace to 9.8 ppg milling fluid, Shut down, Rig up and test 7"casing and k1 Cement retainer to 3,500 psi. 30 min. (Test charted)Trip out to 939'MD, Pick up storm packer,Trip in with storm packer at 75'below surface attempt to set with out success. Pull out of hole lay down storm packer,Continue trip out lay down cement retainer stinger, Service rig, Run in hole 10 stands, Pick up new storm packer and set 75'below surface,Test packer 1,000 psi 5 min. Nipple down stack, Rig up hydra tight equipment to tubing spool, Let OA complete venting, Release 7"casing from compression with hydra tight equipment, Casing up 16-3/4"remove tubing spool. Begin taking off packoff. 00:00 01:00 1.00 7,531 7,531 SLOT CEMEN-CIRC P Unsting from K1 cement retainer, Close annular fill choke and gas buster.Circulate at 2 BPm establishing choke position to hold 250 psi back pressure.Adjust annular preventer for good seal on drillpipe. Page 7 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:00 1.00 7,531 7,528 SLOT CEMEN-SQEZ P Pump cement squeeze per plan, Pump 5 bbl mudpush, 15 bbl's cement, 5 bbl's water holding 270 psi back pressure with choke. Switch to rig for displacement, Pump 635 strokes(54bb1's)Mudpushrat retainer. Shut down pump, Close choke, Slack off stinger into K1 cement retainer with 15k downweight. Open choke, blled off pressure, Open annular.Squeeze cement at 2 bpm-1,850 psi. Pump 235 strokes to clear 5 bbl's mudpush and 15 bbl's cement from stinger. Shut down pump. Final circulating pressure 1,700 psi. Pull stinger out of K1 cement retainer(3')Cement in place 02:00. 02:00 03:30 1.50 7,528 7,528 SLOT CEMEN-CIRC P Circulate bottoms up at top of K1 cement retainer(7,528'MD)9 bpm- 1,100 psi. Rig down cement lines. Shut down pumps, Break off single, Rig down circulating headpin. Load wiper ball into drillpipe(nerf ball) Make up to topdrive, Circulate surface to surface. 03:30 04:15 0.75 7,528 7,528 SLOT DRILL CIRC P Displace well F/seawater to 9.8 ppg milling fluid. Pump 35 bbl Hi-Vis spacer, Chase with 290 bbl's 9.8 ppg KAL shield milling fluid 04:15 06:00 1.75 7,528 7,528 SLOT DRILL PRTS P Rig up and test 7"casing and K1 cement retainer to 3,500 psi for 30 minutes.Test recorded and charted. Rig down from casing test, Blow down Choke and Kill lines, Pump dry job, Blow down topdrive and mud lines 06:00 08:45 2.75 7,528 939 SLOT DRILL TRIP P Blow down Choke and Kill lines, Pump dry job, Blow down topdrive and mud lines.Trip out F/7,528'MD- T/939' MD. up wt 120K 08:45 10:45 2.00 939 939 SLOT DRILL TRIP T Make up storm packer, Run in hole attempt to set packer 75'below surface without success, Pull out of hole inspect storm packer, Check screws. Run packer back in hole attempt to set with same negative results. Pull storm packer out of hole tape friction blocks, Run in hole to 60'made 3rd attempt to set again with negligible results. Pull out of hole and lay down storm packer. 10:45 12:00 1.25 939 0 SLOT DRILL TRIP T Trip out of hole lay down cement retainer stinger, Clear and clean rig floor 12:00 13:15 1.25 0 0 SLOT RIGMNTSVRG P Service draworks, Lube and re-align clutch spline gear on dynamatic, Rebuild 4"demco on standpipe o: 6'' Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:15 15:00 1.75 939 0 SLOT DRILL TRIP T Run 10 stands 4"drillpipe in hole, Pick up New storm packer, Run storm packer 75'below surface. Set storm packer, Release from packer pull stand out of hole. Close blind rams,Test packer 1,000 psi for 5 min.Test recorded and charted. 15:00 16:00 1.00 0 0 SLOT WHDBO RURD P Drain stack, Blow down kill line, Make up stack washer and flush stack with water. Blow down topdrive, Drain stack. Bleed OA pressure of 500 psi to 0 psi using bleed tank. OA left open venting small amount of vapors. 16:00 17:30 1.50 0 0 SLOT WHDBO NUND P Nipple down BOP stack and adaptor spool. 17:30 18:30 1.00 0 0 SLOT WHDBO RURD P Prep tubing spool for hydra tight procedure. Stage Hydra tight equipment. 18:30 19:30 1.00 0 0 SLOT DRILL OWFF P Monitor OA as venting off with minimal pressure. Use gas detector and monitor until vapors completely vented off prior to using hydra tight equipment to release compression in casing. 19:30 22:30 3.00 0 0 SLOT DRILL NUND P Use hydra tight equipment to allow 7"casing to rplpace from • compression.Total of 60 cycles used to back off nuts on tubing spool controlling expansion of compressed casing. Each cycle allowed 3/8"of casing movement Casing compression released allowed casing movement of 16-3/4" 22:30 23:00 0.50 0 0 SLOT WHDBO NUND P Remove tubing spool 23:00 00:00 1.00 0 0 SLOT WHDBO NUND P Remove old packoff from 7"casing. Sim-ops Make up casing spear to 4" drillpipe 34/26/2011 Remove 7'Casing packoff, Spear casing pull to reset in casing slips with 50k tension. (Pulled 151k to achieve 50k overpull) Release spear, Rig up to cut excess 7'casing.Wachs cutter did not function.Wait on new cutter. Use new cutter cut excess 7"casing.Cut piece=32", Install new packoff and tubing spool, Nipple up BOPE and test breaks, Set wear bushing, Retrieve storm packer, Do 15 min 3,500 psi csg test, make up whipstock BHA, trip in hole, Orient whipstock, Set @ 19° LHS, Take SPR's. 00:00 00:30 0.50 0 0 SLOT WHDBO NUND P Complete removal of old 7"packoff 00:30 01:00 0.50 0 0 SLOT WHDBOCUTP P Spear 7"casing and pull 151k on weight indicator to set casing in slips with 50k tension. Reset casing slips, Slack off and release spear. Lay down spear. • 01:00 04:15 3.25 0 0 SLOT WHDBO CUTP T Rig up WACHS cutter to cut excess 7"casing. Casing cutter drive motor did not function,Attempted to rebuild drive assembly while waiting on new one. Could not get drive motor to function. **Rig serviced equipment while waiting on tool. Page 9 of 62 Time Logs J Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 04:45 0.50 0 0 SLOT WHDBO CUTP P Cut 32"excess 7"casing after releasing casing from compression and pulling with spear to achieve 50k tension. Rig down WACHS cutter, Dress stub for packoff installation. 04:45 06:15 1.50 0 0 SLOT WHDBO NUND P Install new 7"packoff and Gen IV 11"3M X 7-1/16"5M tubing spool. Test to 3,000 psi for 10 Min. (Test witnessed by ConocoPhillips rig supervisor) 06:15 09:30 3.25 0 0 SLOT WHDBO NUND P Nipple up adaptor flange, 3'Adaptor spool, BOP stack. 09:30 10:30 1.00 0 0 SLOT WHDBO BOPE P Rig up BOPE test equipment. Test top pipe rams,Tubing adaptor flange, 3'adaptor spool, Choke and Kill lines. 250 psi low-4,000 psi high. 5 Minute per test(All tests charted and recorded) 10:30 11:00 0.50 0 0 SLOT WHDBO NUND P Install 6-3/8"ID wear bushing. 11:00 13:00 2.00 73 0 SLOT DRILL TRIP P Pick up Storm packer retreival tool, Run in hole 73'Open valve on storm packer and flow check,Well Static, Release storm packer and trip out of hole, Lay down storm packer. 13:00 14:00 1.00 0 0 SLOT DRILL PRTS P Close blind rams, Line up to kill line, Test casing and K1 cement retainer to 3,500 psi for 15 min.Test recorded and charted, Bleed off pressure, Blow down kill line 14:00 22:15 8.25 0 7,429 SLOT WHPST TRIP P Make up whipstock assembly,Orient MWD to whipstock, Pulse test MWD,Trip whipstock in hole to 7,429'MD. 22:15 00:00 1.75 7,429 7,512 SLOT WHPST WPST P At 7,429' MD make up topdrive to stand, Obtain up 127k down 95k weights, Break circulation at 6.5 bpm, Orient whipstock to 13° Left of highside. Lay down top single off of stand, Make connection on full stand, Circulate and verify toolface, Toolface setting 19° left of highside when pumps down,Tag K1 cement retainer at 7,529' MD, Set bottom anchor with 12k down wt, Pick up 7k over to verify anchor set,Slack off and shear lug with 32k down weight. Pick up 12' up wt 127k verifying mills free of whipstock.Take SPR's.TOW =7,512' MD. 34/27/2011 Mill window F/7,512' MD to 7,545' MD.TOW=7,512' MD BOW=7,525'MD. Circulate sweeps.. Perform LOT T/15.5 ppg EMW.Add 13 ppg spike fluid to increase mud wt F/9.8 ppg-T/11.0 ppg.Trip out of hole with mills T/2,885'MD. Level rig over hole(Centering pipe in rotary table better)Trip out to surface. Lay down mills, Upper mill full gauge. Pull wear bushing, Flush stack, Install Wear bushing, Slip and cut drill line, Service topdrive. Make up Bi-Center bit BHA. Page 10 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 05:00 5.00 7,512 7,545 SLOT WHPST WPST P Mill window F/7,512' MD-T/7,525'__ MD. Drill additional 20'of new hole ( , with mills T/7,545'MD. 70 rpm,270 gpm- 1,600 psi,torque 5-8k. Pumped Hi-Vis sweep at halfway point of window approximately 7,518' MD. _ 05:00 06:45 1.75 7,545 7,440 SLOT DRILL CIRC P Pump 2 Hi-vis sweeps back to back while working window area with mills, Observed drag at 7,520' MD.Worked area with mills until satisfied. Racked back stand in derrick. 06:45 08:00 1.25 7,440 7,440 SLOT DRILL FIT P Monitor well(Static)Rig up and '') perform LOT to 15.5 ppg EMW. Rig down from test, Blow down test , equipment and kill line. r I 08:00 11:00 3.00 7,440 7,440 SLOT DRILL CIRC P Take on 13.0 ppg spike fluid into pits and blend with 9.8 ppg milling fluid, Circulate 11.0 ppg blended mud surface to surface.Weight up ( S remaining pit volume to 11.0 ppg Il mud. 11:00 13:30 2.50 7,440 2,885 SLOT DRILL TRIP P Trip out of hole with mills T/2,885'. W�LJ Good hole fill. ))116' 13:30 14:00 0.50 2,885 2,885 SLOT DRILL PSIT P Level rig over hole. Centering pipe better in rotary table. 14:00 16:30 2.50 2,885 20 SLOT DRILL TRIP P Trip out to BHA, Lay down 6 joints HWDP, Rack back 3 stands HWDP and flex collars. 16:30 17:30 1.00 20 0 SLOT DRILL PULD P Lay down mills, Inspect and gauge. Upper mill full gauge, Clear and clean rig floor. 17:30 19:15 1.75 0 0 SLOT WHDBOOTHR P Pull wear bushing, Pick up stack washer, Make up to topdrive. Flush stack at 340 gpm, lay down stack washer, Blow down topdrive, Set wear bushing. 19:15 20:45 1.50 0 0 SLOT RIGMNT SLPC P Slip and cut drill line, Service topdrive 20:45 00:00 3.25 0 INTRM1 DRILL PULD P Make up 6"X 7" Bi center bit drilling assembly. Pick up Motor, MWD, Make up to topdrive. Upload MWD tools, Pulse test MWD. 34/28/2011 Complete making up drilling assembly,Trip in hole, Pass through window at 7,512'MD with no problems, Bring on pumps slowly in open hole. Obtain SPR's. Drill F/7,545' MD-T/7,581' MD. Evident BHA tracking casing.Trip out of hole racking back BHA. Pick up 3-1/2"Muleshoe and 30 joints 3-1/2"EUE tubing for balance cement plug job, Run in hole on 4"drillpipe T/5,659'MD 00:00 02:00 2.00 0 457 INTRM1 DRILL PULD P Complete loading MWD data to tool, Shallow pulse test 250 gpm-750 psi, Make up remaining BHA. total length 457.12' 02:00 06:00 4.00 457 7,545 INTRM1 DRILL TRIP P Trip in to window, Pass assembly through window with out orienting toolface.to 7,545'MD. (No problems encountered passing through window) Page 11 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 06:45 0.75 7,545 7,545 INTRM1 DRILL CIRC P Fill pipe with bit in open hole, Obtain SPR's both pumps. Stage pumps up slowly to 230 gpm- 1,950 psi. SPR's @ 7,540 MD 5,296'TVD MW 11.0# 1 pump 25 spm-840 psi, 35 spm- 1050 psi.#2 pump 25 spm-860 psi 35 spm- 1080 psi. 06:45 12:00 5.25 7,545 7,565 INTRM1 DRILL DDRL P Drill F/7,545'MD-T/7,565' MD. 5,311'TVD Sliding with highside toolface, Erratic pressure with motor stalling. Flow rate 260 gpm-2,150 psi, No rotary used. bit wt 2-5k, Up wt 120k down 90k, ECD's 12.59 ppg, Bit and jar hrs 2.25.ADT/AST 2.25 ART 0.0 12:00 13:30 1.50 7,565 7,581 INTRM1 DRILL DDRL P Drill F/7,545' MD-T/7 581'MD._, 5,316'TVD Sliding W/highside toolface. Pump pressure still erratic. Possibilty tracking casing with BHA Flow rate 260 gpm-2,150 psi, No rotary used. bit wt 1-3k, Up wt 120k down 90k, ECD's 12.59 ppg, Flow out 37% Bit and jar hrs 3.27. ADT/AST 1.02 ART 0.0 13:30 14:00 0.50 7,581 7,476 INTRM1 DRILL OWFF T Evident BHA tracking casing,__ Decision made to trip out of hole, Rack back stand and blow down topdrive and mudline. Monitor well (Static) 14:00 20:00 6.00 7,476 0 INTRM1 DRILL TRIP T Trip out of hole with no difficulty pulling up through window. Download MWD. Rack back all BHA in derrick. Bit inspected and graded = 0-3-BT-S-X-I-CT-H P. 20:00 21:00 1.00 0 0 INTRM1 DRILL RURD T Rig up 3-1/2"tubing handling equipment. Elevators,double stack hydraulic tongs. 21:00 22:15 1.25 0 947 INTRM1 DRILL PUTB T Pick up 3-1/2"EUE mule shoe and 30 joints 3-1/2" EUE tubing.Total length 947.16' 22:15 22:45 0.50 947 947 INTRM1 DRILL TRIP T Pick up 3-1/2 EUE crossover to 4" drillpipe, Rig down double stack hyd tongs,Change elevators. 22:45 00:00 1.25 947 5,659 INTRM1 DRILL TRIP T Trip in hole with 3-1/2"Muleshoe and tubing on 4"drillpie T/5,659'MD 04/29/2011 Trip to bottom,Tag bottom, Pull up circulate bottoms up at 7 bpm, Rack back stand pick up single, Muleshoe 5'off bottom, Hold PJSM with cementers, Batch mudpush, Pressure test lines to 3,000 psi. Pump 7 bbl's 13.0 ppg mudpush, 11 bbl's 17.0 ppg cement, 2 bbl's 13.0 mudpush, Displace with rig, Pull out of cement slowly, Circulate drillstring clean-Drop pipe ball wiper at 6,760 MD.Circulate and condition mud. Pull out of hole to 3-1/2 EUE tubing cement work string, Lay down tubing, Make up drilling assembly,Trip in hole,Tag good cement at 7,370' MD. Confirm cement hard above window at 7,511'MD. Orient highside clean out cement across whipstock slide. Slide Highside to 7,555'MD.Assembly packed off and was jarred free. 00:00 01:00 1.00 5,659 7,452 INTRM1 DRILL TRIP T Trip in hole F/5,659'MD-T/7,452' MD I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:00 1.00 7,452 7,581 INTRM1 DRILL CIRC T Wash down F/7,452'MD to bottom 7,581'MD.Tag bottom with 4-5k, Circulate bottoms up at 290 gpm- 1,500 psi. 02:00 02:30 0.50 7,581 7,576 INTRM1 DRILL TRIP T Rack back 1 stand, Pick up single of 4"drillpipe. Position muleshoe 5'off bottom. Rig up cement lines, Break circulation 02:30 03:00 0.50 7,576 7,576 INTRM1 CEMEN-SFTY T Hold PJSM with Dowell cementers, Go over cement balanced plug procedure. Identify hazards. 03:00 04:30 1.50 7,576 7,576 INTRM1 CEMEN-CMNT T Batch mudpush, Pressure test lines to 3,000 psi, Pump balanced cement plug per plan. 7 bbl's 13.0 ppg mudpush II, 11 bbl's 17.0 ppg Class G cement, 2 bbl's mudpush, Displace with 72 bbl's 11.0 ppg Kla -shield mud. 04:30 05:30 1.00 7,576 6,749 INTRM1 CEMEN-TRIP T Flow check(Static) Rig down cement lines and valves, Blow down cement line, Lay down single. Pull out of cement slow to 6,749'MD. 05:30 07:00 1.50 6,749 6,749 INTRM1 DRILL CIRC T Load pipe wipe ball(Nerf Ball) Circulate bottoms up X 2.230 gpm -870 psi. Blow down top drive, Monitor well(Static) 07:00 12:00 5.00 6,749 0 INTRM1 DRILL TRIP T Trip out of hole F/6,749'MD-T/946' MD at cement work string (3-1/2" EUE tubing) Rig up double stack hyd tongs, Change elevators, Lay down cement work string. Rig down tubing handling equipment. Clear and clean floor. 12:00 14:00 2.00 0 0 INTRM1 DRILL WOC T Change out joint of 4"HWDP with bad hardbanding OD worn down to 4.75". Service rig,While waiting on new bit and cement to cure. 14:00 19:30 5.50 0 7,232 INTRM1 DRILL TRIP T Make up bit, Upload MWD, Run in with remaining BHA from derrick.Trip in hole with BHA#6, Fill pipe every 20 stands to 7,232',Assembly took weight. (Cement stringer)Decision to stop at 7,232' MD and displace. 19:30 21:30 2.00 7,232 7,232 INTRM1 DRILL CIRC T PJSM, Pump 35 bbl's steel lube Ep pill as spacer, Displace F/11.0 Kla Shield mud-T/9.8 ppg Power vis polymer mud at 4 bpm-1,300 psi. Reciprocate string during displacement. Obtain SPR's, Up wt 170k, Down 87k. 21:30 21:45 0.25 7,232 7,232 INTRM1 DRILL OWFF T Monitor well(Static) 21:45 23:00 1.25 7,232 7,370 INTRM1 DRILL REAM T Make connection wash and ream F/7,232' MD-T/7,370'MD.At 7,370' MD tagged good cement taking 10-15k bit weight. Flow rate 200 gpm - 1,000 psi, rotary 20 rpm,torque 3,500 ft/lbs. 1 tr: 1: c' 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 23:30 0.50 7,370 7,545 INTRM1 CEMEN-REAM T Clean out cement T/7,500'MD at 200 gpm-980 psi,20 rpm,5-10k bit weight.Confirm hard cement at 7,511' MD just above TOW @ 7,512' MD. Orient to Highside and clean out across whipstock slide. 23:30 00:00 0.50 7,545 7,555 INTRM1 DRILL DDRL T Sliding highside with Bit off of whipstock slide, Bit weight dropped, Increased penetration rate gradually until 15k on bit, 980 psi off bottom at 7,555' MD pump increased to 2,000 psi. Shut pumps down with no pressure decrease. Pressure bled off. Picked up jars went off at 200k. Attempted to circulate at 2 bpm pressure increased to 1,000 psi. Bled pressure off. Pulled up 200k on weight indicator. Up weight 165k, down wt 94k, Pulled 235k setting off jars.Jarred 3 times assembly free. ** Note max overpull on motor 87K. 34/30/2011 Make several attempts to pass through window with out success. Circulate, Pump dry job,Trip out, Inspect BHA, Make up cement retainer,Trip in and set retainer at 7,452'MD._Circulate, Sting into retainer and perform injectivity test. Rig up and pump 15 bbl's 12.5 ppg mudpush and 25 bbl's 15.8 ppg cement. Chase with 43 bbl's 9.8 mud. Shut down sting into retainer and squeeze away cement. Unsting from retainer, reverse circulate pipe vol plus 15 bbl's. Rig down cement equipment. Circulate 2 X bottoms up. 00:00 01:30 1.50 17,555 7,510 INTRM1 DRILL CIRC T Pull up 1 stand F/7,555'MD. Rack back stand to 7,521'MD. Pull above window at 7,512' MD to 7,510'MD. Make up topdrive to string and establish circulation.200 gpm-980 psi. Orient highside attempt to lower bit to window depth.Took weight and 300 psi increase. Several attempts made no good. Shut down pump and slack off setting 10k weight, Pick up with no overpull. Continue setting down staging weight up to 30k. Assembly unable to pass into window area. 01:30 02:45 1.25 7,510 7,510 INTRM1 DRILL CIRC T Circulate bottoms up while mixing dry job. Pump dry job, Blow down, Monitor well(Static) 02:45 06:00 3.25 7,510 457 INTRM1 DRILL TRIP T Trip out of hole F/7,510'MD-T/457' MD(BHA)Calculated hole fill 46.5 bbl's,Actual hole fill 49 bbl's. (**Spill drill held 1.5 min response time**) 06:00 08:30 2.50 457 0 INTRM1 DRILL PULD T Monitor well(Static) Rack back, HWDP,Jars and Flex collars, Pull to bit, Break off bit and inspect, Bit grade=3-3-BT-A-X-I-WT-HP, Download MWD, Lay down MWD tools, Stabilizer, float sub and motor. Clear and clean floor 08:30 09:00 0.50 0 0 INTRM1 CEMEN-PULDT PJSM with baker rep, Mobilize cement retainer to floor, Make up cement retainer per Baker. Page 14 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 13:30 4.50 0 7,452 INTRM1 CEMEN-TRIP T Trip in hole with cement retainer,Add 5'pup to string, Pick up additional __ stand positioning cement retainer at _ 7,452'MD.Set retainer per Baker rep. Confirm retainer set and unsting from retainer. 13:30 14:00 0.50 7,452 7,452 INTRM1 CEMEN-LOT T Pump to verify stinger clear and good circulation possible. Shut down pump sting into retainer, Perform injectivity test at 10 spm formation took fluid with 1,880 psi, 15 spm = 1990 psi,20 spm=2130 psi, 25 spm=2200 psi, 30 spm=2440 psi. Shut in pressure= 1,500 psi. Pressure held for 10 minutes, Charted and recorded. Bleed off pressure, Unsting from retainer. 14:00 14:45 0.75 7,452 7,447 INTRM1 CEMEN-CIRC T Pick up F/7,452'MD-T/7,447'MD (5')Circulate bottoms up at 4 bpm- 400 psi. 14:45 19:00 4.25 7,447 7,447 INTRM1 CEMEN"RURD T Blow down topdrive, Rig up cement line, Lo-torque valve, chicksen swing and headpin to drillstring for cement job. Bring up mills and baker equipment for future whipstock run. Wait on cementers. 19:00 21:30 2.50 7,447 7,452 INTRM1 CEMEN-CMNT T PJSM, rig up dowell cementers, Close annular and open choke, Fill gas buster, Establish circulating rate 30 spm while holding 750 psi back pressure with choke. Drill pipe pressure 1,250 psi. Shut down pump. Obtain pick up 137k down 77k with annular closed, Sting into retainer and re-establish injection rate at 30 spm-2,120 psi, Shut in pump, Pressure stabilized @ 1,550 psi. bleed off pressure, unsting from retainer.turn over to cementers. Dowell pumped 15 bbl's-12.5 ppg-_ mudpush II, 750 psi back pressure held through out cement operation with choke. Shut down test lines 3,500 psi. Pump 25 bbl's of 15.8 ppg cement. Shut down close choke. Line up to take 5 bbl's water flush through bleeder. Dowell lines flushed turn over to rig for displacement. Open choke slightly to hold backpressure. Pump 43 bbl's 9.8 ppg mud. Shut down pump, close choke. Sting into retainer and squeeze 10 bbl's 12.5 mudpush II and 25 bbl's 15.8 ppg cement. ICP= 1,800 psi, FCP=2,050 psi. Stabilized shut in pressure= 1,550 psi. CIP 21:35 Page 15 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 22:30 1.00 7,452 7,449 INTRM1 CEMEN-CIRC ;T Unsting from retainer, Reverse out drillpipe capacity plus 15 bbl's. Bleed off all pressure, open annular. Rig down cement lines. Blow down all surface lines. 22:30 00:00 1.50 7,449 7,449 INTRM1 CEMEN-CIRC T Make up topdrive to string and circulate 2 X bottoms up. 35/01/2011 Trip out with cement retainer stinger, Slip and cut drill line, Service rig, Change out jars, Pick up whipstock and mills,Trip in hole,Orient Whipstock 40° LHS. Set anchor, Shear lug, Mill Window.TOW=7,434' MD BOW 7,447' MD. Milling formation at changeout 7,456'md. **No cement visible in cuttings** 00:00 03:00 3.00 7,449 0 INTRM1 CEMEN-TRIPT Monitor well(Static)Trip out of hole from 7,452'MD, lay down cement retainer stinger.Calculated hole fill 42.12 bbl's,Actual hole fill 46.5 bbl's 03:00 04:00 1.00 0 0 INTRM1 RIGMNTSLPC T Clear and clean floor, PJSM, Slip and cut drill line. 04:00 04:30 0.50 0 0 INTRM1 RIGMNTSVRG T Service rig,Topdrive, Draworks, Traveling blocks, Crown 04:30 05:00 0.50 0 0 INTRM1 DRILL PULD T Change out jars in derrick 05:00 08:00 3.00 0 150 INTRM1 WHPST PULD T PJSM with Baker rep, Make up mills and whipstock. 08:00 09:30 1.50 150 1,554 INTRM1 WHPST TRIP T Trip in hole slowly with whipstock / assembly T/1,554'MD 09:30 10:00 0.50 1,554 1,554 INTRM1 WHPST CIRC T Pulse test MWD with 200 gpm-900 psi. Erratic pump pressure unable to get good pulse test. Decision to continue in hole 10:00 11:30 1.50 1,554 3,051 INTRM1 WHPST TRIP T Trip in hole F/1,554'MD-T/3,051' MD. Up wt 75k, Down wt 65k 11:30 14:30 3.00 3,051 7,301 INTRM1 WHPST TRIP T Trip in hole F/3,051' MD-T/7,301' MD. (Stand#71) 14:30 15:30 1.00 7,301 7,395 INTRM1 WHPST PRTS T Orient to 45° LHS,with 5.5 bpm- 1,300 psi,Wash down, Shut down mudpump. perform 15 min 3,500 psi casing test.test results favorable. (Test recorded and charted) Bleed off pressure, Open rams, Blow down kill line 15:30 16:30 1.00 7,395 7,440 INTRM1 WHPST WPST T Make connection verify toolface, Shut down pump,tag cement retainer at 7,452' MD. Set anchor with 12k down weight, Pick up 6k overpull confirm anchor set. Slack off 26k and shear lug. Pick up 5'obtain SPR's.7,440' MD, 5,304'TVD, 9.8 MW# 1 mudpump 25 spm-420 psi, 35 spm-520 psi.#2 mudpump 25 spm-460 psi, 35 spm-560psi. t, 16:30 00:00 7.50 7,440 7,456 INTRM1 WHPST WPST T Mill window per baker rep, 6 bpm- 1,700 psi, 70-100 rpm,Torque 8-10k, Up wt 138k,do wt 86k, Rot wt 112k. TOW=7,434' MD, BOW=7,447' MD. Milled depth @ 24:00 hrs= 7,456' MD, 5,304'TVD.**No 5/ j Cement visible in cuttings** �{ L4 L. Page 16 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/02/2011 24 hr Summary Complete milling window, Drill with mills F/7,447' MD-T/7,482' MD. Pump sweeps, Displace to 11.0 ppg Kla Shield. Perform LOT,Trip out of hole. Lay down mills. Pull wear bushing inspected and found damaged, Flush stack, Install new wear bushing, Make up 3-1/2 EUE tubing cement work string(30 jts plus Muleshoe- 950.04')Trip in tubing on 4"drillpipe.Tag bottom 7,482' MD. Circulate bottoms up 4 bpm-800 psi. 00:00 00:30 0.50 7,456 7,456 INTRMI WHPST WPST T Polish window area. Shut down rotary and work through window with no difficulties and minimal drag. 00:30 01:30 1.00 7,456 7,482 INTRM1 WHPST WPST T Drill new formation with milling assembly F/7,447 MD-7,482'MD. 100 rpm, 300 gpm-2,000 psi, Torque 7,000 ft/lbs. Up wt 138k down wt 86k. 01:30 03:30 2.00 7,482 7,482 INTRM1 WHPST CIRC T pump Hi-Vis sweeps(2)2nd sweep used as spacer for displacing back to 11.0 ppg Kla Shield. Displacement rate 77 spm-2,000 psi 03:30 04:30 1.00 7,482 7,374 INTRMI DRILL LOT T Take SPR's, Lay down single, Rack back stand, Rig up for LOT. Circulate through drillpipe and kill line,Close rams. Pump at 4 spm recording pressure each stroke.With 14 strokes pumped pressure dropped from 590 psi to 570 psi. Shut down pumps.Conferred with town enq due to low LOT. SPR's at 7,374'MD, 5256 TVD, 11.0 MW. Pump#1 w/25 spm-420 psi 35 spm-570 psi, Pump#2 w/25 spm-470 psi, 35 spm-600 psi. 04:30 14:30 10.00 7,374 0 INTRM1 DRILL TRIP T Monitor well, (Static)Trip out F/7,374'MD-T/6,923'MD. Incorrect hole fill, Flow check(Static) Pump out of hole at 2 bpm-250 psi. F/6,923'MD-T/1,998'MD. Line up to trip tank pull out of hole to BHA. Lay down 5 joints HWDP, rack back 3 stands HWDP and 1 stand flex collars, Lay down mills. 14:30 15:30 1.00 0 0 INTRM1 DRILL RURD T Remove baker milling equipment from floor, Pull wear bushing.Wear bushing damaged and taken out of service. 15:30 16:00 0.50 0 0 INTRM1 DRILL CIRC T make up stack washer and flush stack, Rig down and blow down. 16:00 17:15 1.25 0 0 INTRM1 DRILL RURD T Clear and clean floor, Pick up 3.5" tubing handling equipment. Prep for cement work string. PJSM on picking up tubing while waiting on wear bushing. 17:15 17:30 0.25 0 0 INTRM1 DRILL RURD T Drain stack install new wear bushing 17:30 23:00 5.50 0 7,482 INTRM1 CEMEN-TRIPT Pick up 3-1/2"EUE mule shoe and 30 joints 3-1/2"EUE tubing (950.04') Run in hole. Change out handling equipment to 4" Run in hole F/950' MD-T/7,482' MD(tagged bottom) Up wt 113k down wt 87k —-- -- -- --- — -- Page 17 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 `7,482 7,472 INTRM1 CEMEN-CIRC T Make up top drive to string, Pick up 10'and circulate bottoms up at 4 bpm-800 psi. 35/03/2011 Displace well f/11 ppg KlaShield to 9.9 ppg PowerVis @ 7472', monitor well-static, RU f/balanced cement plug job @ 7479'. Dowell pump 2 bbls MudPush II © 13 ppg, test lines to 3500 psi-OK, pump another 5 bbls for a total of 7 bbls MudPushll, batch mix then pump 25 bbls of 17 ppg cement,follow w/3 bbls MudPush II © 13 ppg, flush lines, rig displace with 9.9 ppg mud. Rig displace 48 bbls @ 3bpm w/210 psi, slow to 1 bpm for another 18 bbls(total mud displacement 65.73 bbls). ICP 90 psi, final 640 psi. RD cementing equip. POOH slow(2-3 min/stand)f/7479'to 6320'. Rev circ 1-1/2 pipe volumes(101.5 bbls)@ 7bpm w/1200 psi. Mud push was observed at the shakers, no cement at shakers. Shut annular,then squeeze 10 bbls of cement @.846 bpm w/1000 psi. Hold f/10 minutes,squeeze another 5 bbls @.846 bpm w/1150 psi, hold f/ 10 minutes. Squeeze another 5 bbls @ .846 bpm w/1000 psi..Total cement squeezed away was 20 bbls. Hold pressure on cement squeeze f/2 hours. Bleed off press, blow down choke and kill lines. Rev circe a pipe volume by pumping 4.65 bpm w/750 psi(Pumped 64.7 bbls).Then pump down string to circ a bottom's up, pumping 9.3 bpm w/1500 psi. RD circulating equipment, BD kill line. Monitor well-static. POOH f/6320' to 950'. PJSM, LD 30 joints of 3-1/2"tubing. Clear floor, RD 3-1/2"equipment. PJSM, RU to test BOPE. Witness of test waived by AOGCC inspector Lou Grimaldi.Tested to 250 psi low and 4000 psi high. Hold each test f/5 min.Test annular to 250 psi low and 2500 psi high. Hold each test 5 minutes.Tested with 3-1/2"and 4"test joints.Tested all valves in choke manifold,floor safety valve and IBOP.Tested manual and automatic TD IBOP.Top pipe rams(3-1/2"x 6")and bottom pipe rams(2-7/8"x 5").Tested accumulator, full charge 3000 psi, after closure 1850 psi,200 psi build up in 38 seconds,full charge 177 seconds. RD testing equipment, blow down lines, install wear bushing, PJSM, PU mtr, install 6"lower sleeve, MU 6-1/8"bit. 00:00 01:00 1.00 7,472 7,472 INTRM1 DRILL CIRC T PJSM, Displace well F/11.0 Kla shield mud-T/9.9 ppg Power vis mud. Pumping 273 gpm (6.5 bpm)w/ 1200 psi.Shut down, Clean shaker trays. 01:00 01:30 0.50 7,472 7,472 INTRM1 DRILL OWFF T Monitorwell-static. 01:30 03:30 2.00 7,472 7,479 INTRM1 DRILL CMNT T Rig up for balanced cement plug lobes PJSM with Dowell, Batch 7 bbl's 13.0 ppg mudpush II. Pump 2 bbl's mudpush, shut down and pressure test surface lines to 3,500 psi. Pump remaining 5 bbl's 13.0 ppg mudpush II. Shut down batch 25 bbl's 17.0 ppg cement. Pump cement, Shut down and batch mix 3 bbl's 13.0 ppg mudpush. Pump mudpush, Shut down and flush lines. Displace mudpush and cement with rig. Pump 565 strokes(48 bbls)of 9.8ppg Power Vis mud @ 3bpm w/210 psi- mudpush around corner, Slow pump rate from 3 bpm to 1 bpm and displace 18 bbl's cement out of tubing. Mud volume to displace 66 bbl's. ICP 90 psi FCP 640 psi.Total strokes pumped to displace 777. Rigged down from cement job. Pipe was not on vacuum. 03:30 04:45 1.25 7,479 6,320 INTRM1 DRILL TRIP T Pull out of cement F/7,479' MD-T/ 6,320' MD Pulling slow 2-3 minutes per stand. Page 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:45 05:00 0.25 6,320 6,320 INTRM1 DRILL CIRC T Reverse circulate 1-1/2 pipe volumes (101.5 bbls)at 7 bpm 1,200 psi. Total strokes 1,200. Mudpush seen at shakers. No cement seen during circulation. 05:00 06:00 1.00 6,320 6,320 INTRM1 DRILL CMNT T Shut annular,squeeze 10 bbls of cement @ 10 spm(.846 bpm)w/ 1000 psi. Hold f/10 minutes,then squeeze 5 bbls of cement @ 10 spm (.846 bpm)w/1150 psi. Hold f/10 minutes. Squeeze another 5 bbls of cement @ 10 spm(.846 bpm)w! 1000 psi.A total of 20 bbls squeezed away. 06:00 08:00 2.00 6,320 6,320 INTRM1 DRILL CMNT T Hold pressure on cement squeeze for 2 hours. 08:00 08:30 0.50 6,320 6,320 INTRM1 DRILL OTHR T Bleed off pressure. Blow down choke and kill lines. 08:30 09:30 1.00 6,320 6,320 INTRM1 DRILL CIRC T Attempt to circulate.While pumping down drill pipe, pressured up to 375 psi. Decision to reverse circulate. Broke circulation with 500 psi. Pumped pipe volume, pumping 4.65 bpm w/750 psi. Pumped 64.7 bbls. Then pumped down drill string one bottom's up, pumping 9.3 bpm w/ 1500 psi. 09:30 10:00 0.50 6,320 6,320 INTRM1 DRILL RURD T Rig down circulating equipment. Blow down kill line. 10:00 10:15 0.25 6,320 6,320 INTRM1 DRILL OWFF T Monitorwell-static. 10:15 12:00 1.75 6,320 950 INTRM1 DRILL TRIP T Trip out of the hole f/6320'to 950'. Monitor well on the trip tank. Calculated 30.78 bbls, actual 33.5 bbls. 12:00 12:15 0.25 950 950 INTRM1 DRILL SFTY T Pre job safety meeting. 12:15 13:45 1.50 950 0 INTRM1 DRILL PULD T Pull out of the hole/lay down 3.5" tubing (30 jts). Monitor on trip tank. Calculated 3.12 bbls, actual 3.15 bbls. 13:45 14:30 0.75 0 0 INTRM1 DRILL RURD T Clear and clean rig floor. Rig down 3-1/2"handling equipment. 14:30 14:45 0.25 0 0 INTRM1 DRILL SFTY T Pre job safety meeting. 14:45 15:30 0.75 0 0 INTRM1 WHDBO RURD P Rig up to test w/3-1/2"test joint. Witness of test waived by AOGCC inspector Lou Grimaldi. f i-pje 19 of C2 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 21:00 5.50 0 0 INTRM1 WHDBO BOPE P Test to 250 psi low and 4000 psi high. Hold each test 5 minutes.Test annular to 250 psi low and 2500 psi high. Hold tests f/5 minutes each. Tested accumulator.Tested all valves in choke manifold and demco mud line.Tested kill and choke valves, top(3-1/2"x 6")and bottom pipe rams(2-7/8"x 5").Test top drive IBOP valves.Tested blind rams. Tested top(3-1/2"x 6")and bottom rams(2-7/8"x 5")and annular with 4"test joint. 21:00 21:30 0.50 0 0 INTRM1 WHDBO RURD P Rig down testing equipment. Blow down kill and choke lines. 21:30 22:00 0.50 0 0 INTRM1 DRILL OTHR T Install FMC wear bushing w/6-3/8" ID. 22:00 22:15 0.25 0 0 INTRM1 DRILL SFTY T Pre job safety meeting on picking up/ make up BHA#10. 22:15 23:45 1.50 0 0 ,INTRM1 DRILL PULD T PU SperryDrill motor ser#475-998 (1.5 deg bend), remove sleeve, install and shim 6"stabilizer on lower end of motor.Torque to 10000 ft lbs. 23:45 00:00 0.25 0 29 INTRM1 DRILL PULD T Make up Bit#3: Baker Hughes, 6-1/8",ATJ-4, ser#5175510 w/(3) 14's. Run in the hole w/motor. Note: OA pressure=zero at midnight. 35/04/2011 Con't to MU BHA#10, RIH w/4"drill pipe.Wash&ream cement stringers f/6979'to 7431',Orient and drill cement across window f/7434'to bottom of window @ 7447'',directional drill to 7505', circ, peform FIT to 16.1. ppg,displace mud to 11 Mpg Kla-Shield, continue to directional drill 6-1/8"hole to 7581'. 00:00 01:15 1.25 29 93 INTRM1 DRILL PULD T Continue to Make up BHA#10: non mag float sub, 5.88"OD stab, DM collar, Slim Phase 4 collar, PWD, TM collar,to 93'. Orient motor to MWD. Pick up to upload Sperry Sun MWD. 01:15 02:00 0.75 93 93 INTRM1 DRILL PULD T Pick up to upload Sperry Sun MWD. Upload MWD. RIH to 93'. 02:00 02:45 0.75 93 462 INTRM1 DRILL PULD T Run a stand of NM flex collars,x-o, then a stand of 4"HWDP, pickup and install jars, run a stand of 4" HWDP, lay down top single, make up another stand of 4" HWDP to 462'. 02:45 03:15 0.50 462 462 INTRM1 DRILL DHEQ T Shallow pulse test MWD tools. Pumping 62 spm(220 gpm)w/800 psi. Good Test. 03:15 07:00 3.75 462 6,979 INTRM1 DRILL TRIP T Trip in the w/4"XT39 drill pipe. RIH to 6979'. Hit cement stringers. Fill every 20 stands. Monitor well on the trip tank. Calculated displacment 44 bbls, actual 44 bbls. Page 20 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 08:30 1.50 6,965 7,431 INTRMI DRILL REAM T Make a top drive connection.Wash and ream f/6979'to 7431'. Pumping 220 gpm w/1400 psi-38%Totco flow out. Rotate 20 rpm w/4000 ft lbs of torque. PU wt 135k, SO wt 85k. Note:Top of window @ 7434'. 08:30 11:00 2.50 7,431 7,447 INTRM1 DRILL DDRL T Orient 40 deg left. Obtain parameters: PU wt 126k, SO wt 82k. Slide f/7431'to 7442',stalled motor, picked up,went back down to 7442', stalled motor again. Picked up, shut down pumps,tried to slide down 45 deg left and 90 deg left, setting down 15k(no go). Picked up oriented 40 deg left, slide back down to 7442' and time drilled to 7447'. Note: Bottom of window @ 7447'. 11:00 12:00 1.00 7,447 7,464 INTRM1 DRILL DDRL T Slide 45 deg left f/7447'to 7464'. Pumping 220 gpm w/1700 psi. Running 15k weight on bit. 12:00 13:00 1.00 7,464 7,482 INTRM1 DRILL DDRL T Continue to slide f/7464'to 7482'. Note:TD of hole prior to cementing was 7482'. 13:00 15:00 2.00 7,482 7,505 INTRM1 DRILL DDRL T Kick off @ 7482'. Drill f/7482'to 7490'. Pick up to 7455',wash back to within 3'of bottom, rotate @ 20 rpm.Wash down and drill w/20k WOB, pumping 220 gpm w/1850 psi. Drill to 7505'(5269'TVD).ADT 1.78 hrs. 15:00 15:45 0.75 7,505 7,430 INTRM1 DRILL CIRC T Backream 10', shut down rotary, orient 45 left, PU to 7455'. Reciprocate below window,while circulating bottom's up. Pull bit above windoww/pumps off to 7430'. Set back a stand. 15:45 16:00 0.25 7,430 7,430 INTRM1 DRILL RURD T Blow down the top drive. Rig up f/ leak off test. 16:00 16:30 0.50 7,430 7,430 INTRM1 DRILL FIT T Perform FIT to 16.1 ppg. MW is 10 ppg,TVD of top of window is 5227', applied pressure of 1650 psi= 16.1 ppg. Pumped 2.1 bbls, bleed down to 1000 psi after 10 minutes. Recorded on chart recorder. Bleed off pressure and returned 1.42 bbls to the pits. Opened rams and rig down testing equipment. 16:30 16:45 0.25 7,430 7,430 INTRM1 DRILL OWFF T Monitor well. Blow down lines. 16:45 17:00 0.25 7,430 7,505 INTRM1 DRILL WASH T Make a top drive connecction, slide bit through window w/pumps off to 7455'. Break circulation, pumping 220 gpm w/1800 psi,wash to bottom @ 7505'. 17:00 18:00 1.00 7,505 7,505 INTRM1 DRILL CIRC T Displace drilling fluid f/10 ppg PowerVis to 11 ppg Kla-Shield. Page 21 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 7,505 7,581 INTRM1 DRILL DDRL T Continue to drill w/1.5 deg motor and 6-1/8"mill tooth bit f/7505'to 7581'.ADT=5.79 hrs, sliding 4.28 hrs of this time. Drill w/20k WOB, Pumping 238 gpm w/2025 psi. Rotate 35 rpm w/5k ft lbs of torque on bottom,4.5k off bottom. PU wt 138k, SO wt 85k, Rot wt 100k. Note: OA pressure 400 psi @ midnight. 35/05/2011 Cont to directional drill 6-1/8"hole f/7581'to 7764', CBU, Bit trip, MU BHA#11, RIH to 4700'. 00:00 11:30 11.50 7,581 7,764 INTRM1 DRILL DDRL P Continue to drill w/1.5 deg motor and 6-1/8"mill tooth bit f/7581'to 7764'(5391'TVD).ADT= 10.51 hrs, ART=5.56 hrs, sliding 4.95 hrs of this time,total hrs on bit 18.08,jar hrs=21.4. Drill w/20k WOB, Pumping 238 gpm w/2025-2150 psi. Rotate 35-80 rpm w/5-6k ft lbs of torque on bottom,4.5-5k off bottom. PU wt 138-132k, SO wt 85-88k, Rot wt 100-110k. Note:Jars are through the window, slow ROP,will pull and change out bit. 11:30 12:00 0.50 7,764 7,764 INTRM1 DRILL CIRC P Circulate bottom's up @ 239 gpm w/ 200 psi-37%Totco flow out. 12:00 12:45 0.75 7,764 7,430 INTRM1 DRILL TRIP P Pump out of the hole f/7764'to 7455', shut down pumps, pull through window(7447'-7434')to 7430'. 12:45 13:15 0.50 7,430 7,430 INTRM1 DRILL OWFF P Pick up 30'to observe hole taking fluid-good. Blow down the top drive. Line up on the trip tank. 13:15 14:00 0.75 7,430 6,114 INTRM1 DRILL TRIP P Pull out of the hole 15 stands f/7430' to 6114' 14:00 14:30 0.50 6,114 6,114 INTRM1 DRILL CIRC P Monitor well-static. Pump a dry job. Blow down the top drive. 14:30 16:45 2.25 6,114 460 INTRM1 DRILL TRIP P Pull out of the hole f/6114'to BHA @ 460'. Monitor well on the trip tank. Calculated fill f/trip was 46.16 bbls, actual 46.25 bbls. 16:45 17:00 0.25 460 460 INTRM1 DRILL OWFF P Monitorwell-static. 17:00 18:00 1.00 460 0 INTRM1 DRILL TRIP P Continue to pull out and stand back BHA#10. Break and change out bit. 18:00 18:30 0.50 0 50 INTRM1 DRILL PULD P RIH to download MWD @-50'. Download tools. 18:30 19:00 0.50 50 93 INTRM1 DRILL PULD P Change out Sperry TM collar. New ser# 11152204. 19:00 20:15 1.25 93 50 INTRM1 DRILL PULD P RIH to upload MWD @-50'. Upload tools. 20:15 20:45 0.50 50 0 INTRM1 DRILL PULD T POOH to break bit, remove 6" stabilizer on the motor and install 5-1/2"OD sleeve protector, make 6-1/8"Reed Hycolog MSF513D bit back up. (Ser# 130126). 20:45 21:30 0.75 0 460 INTRM1 DRILL TRIP P Make up BHA#11 to 460'. Page 22 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 22:15 0.75 460 2,340 INTRM1 DRILL TRIP P Trip in the hole w/BHA#11 f/460'to 2340'. 20 stands of Weatherford 4" drill pipe in the hole. Monitor well on trip tank. 22:15 23:15 1.00 2,340 4,228 INTRM1 DRILL TRIP P Trip in the hole w/BHA#11 f/2340' to 4228'.40 stands of Weatherford 4" drill pipe in the hole. Monitor on pit #6. 23:15 23:30 0.25 4,228 4,228 INTRM1 DRILL CIRC P Fill pipe. Pumping 62 spm w/1500 psi-41%TOTCO flow out. Pulsar working. Obtain survey. 23:30 00:00 0.50 4,228 4,700 INTRM1 DRILL TRIP P Trip in the hole w/BHA#11 f/4228' to 4700'.45 stands of Weatherford 4" drill pipe in the hole. Monitor on pit #6.Calculated displacement is 27.8 bbls, actual 30.25 due to aired up mud. Crew Change. Note: OA pressure at midnight is 40 psi 35/06/2011 RIH f/4700'to 7764', drill 6-1/8"hole f/7764'to 7810',Trip out, change motor,trip in,drill 7810'to 7824'. 00:00 00:15 0.25 4,700 4,700 INTRM1 DRILL SFTY P Pre job safety meeting/crew chnage. 00:15 00:45 0.50 4,700 6,114 INTRM1 DRILL TRIP P Continue trip in the hole f/4700'to 6114'. 00:45 01:00 0.25 6,114 6,114 INTRM1 DRILL CIRC P Fill pipe. 01:00 01:15 0.25 6,114 7,341 INTRM1 DRILL TRIP P Continue trip in the hole f/6114'to 7341'. 01:15 01:30 0.25 7,341 7,433 INTRM1 DRILL CIRC P Make a top drive connection on stand#74. Fill pipe, orient 60 degree left,while 30'above window. 01:30 01:45 0.25 7,433 7,715 INTRM1 DRILL TRIP P Latch up stand#75 and slack off through window(7434'-7447'), continue to 7526'.Trip f/7526'to 7715'. Note: Observed 3-4k drag while going through window w/bit.Then with the stiffer BHA, saw as much as 7k reduction in weight while slacking off through window. 01:45 02:00 0.25 7,715 7,764 INTRM1 DRILL WASH P Make a top drive connection on stand#78.Wash/Ream from 7717' to TD @ 7764'. 02:00 07:00 5.00 7,764 7,810 INTRM1 DRILL DDRL P Directional drill 6-1/8"hole w/Reed Hycolog bit and SperryDrill mtr(1.5 deg bend f/7764'to 7810'.Actual drilling time 2.84 hrs,sliding 2.04 of this time. Drill w/20k WOB. Pumping 275 gpm w/2500 psi-37% TOTCO flow out. Rotate 80 rpm w/ 5k ftlbs on and off bottom. PU wt 138k, SO wt 90k, Rot wt 107k. 07:00 07:15 0.25 7,810 7,810 INTRM1 DRILL OWFF T Pre job safety meeting. Monitor well- static. 07:15 07:45 0.50 7,810 7,435 INTRM1 DRILL TRIP T Decision to POOH due to poor ROP. Pump out f/7810'to 7435'. Pumping 139 gpm w/1650 psi-38%TOTCO ( flow. PU wt 135k, SO wt 90k. Page23of62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 08:00 0.25 7,435 7,435 INTRM1 DRILL OWFF T Monitor well @ the top of window- static. 08:00 08:45 0.75 7,435 6,586 INTRM1 DRILL TRIP T Pull out of the hole f/7435'to 6586' (10 stands). Monitor well on the trip tank. 08:45 09:00 0.25 6,586 6,586 INTRM1 DRILL CIRC T Pump a dry job. Blow down the top drive. 09:00 11:45 2.75 6,586 462 INTRM1 DRILL TRIP T Trip out f/6586'to 462'(BHA). Monitor well on the trip tank. 11:45 12:00 0.25 462 462 INTRM1 DRILL OWFF T Monitor well at the HWDP-static. Calculated fill 39.96 bbls, actual 41.25 bbls. 12:00 12:15 0.25 462 462 INTRM1 DRILL SFTY T Pre job safety meeting w/new crew. 12:15 13:00 0.75 462 0 INTRM1 DRILL TRIP T Stand back 4"HWDP,stand of nm flex drill collars. Inspect bit and mtr. Break bit and motor and lay both down. 13:00 14:00 1.00 0 0 INTRM1 DRILL PULD T Sperry download MWD tools. Clean and clear rig floor. 14:00 16:15 2.25 0 0 INTRM1 RIGMNT SVRG P Service top drive and rig. Blow down choke manifold. Inspect iron roughneck drive motors.Working on MP2's while waiting on new motor f/ Sperry Sun shop in Deadhorse. 16:15 17:00 0.75 0 456 INTRM1 DRILL TRIP T Make up new motor f/BHA#12. Using same bit(Reed Hycolog MSF513D, ser#130126). Orient MWD. Run BHA f/derick to 456' 17:00 17:30 0.50 456 2,333 INTRM1 DRILL TRIP T Run BHA#12 f/456'to 2333'. (20 stands of 4"drill pipe). Monitor well on the trip tank. 17:30 17:45 0.25 2,333 2,333 INTRM1 DRILL CIRC T Fill pipe. Blow down the top drive. 17:45 18:30 0.75 2,333 4,220 INTRM1 DRILL TRIP T Run BHA#12 f/2333'to 4220'. (40 stands of 4"drill pipe). Monitor well on the trip tank. 18:30 18:45 0.25 4,220 4,220 INTRM1 DRILL CIRC T Fill pipe. Blow down the top drive. 18:45 19:15 0.50 4,220 6,108 INTRM1 DRILL TRIP T Run BHA#12 f/4220'to 6108'. (60 stands of 4"drill pipe). Monitor well on the trip tank. 19:15 19:30 0.25 6,108 6,108 INTRM1 DRILL CIRC T Fill pipe. Blow down the top drive. 19:30 20:00 0.50 6,108 7,333 INTRM1 DRILL TRIP T Run BHA#12 f/6108'to 7333'. (73 stands of 4"drill pipe). Monitor well on the trip tank. 20:00 20:15 0.25 7,333 7,428 INTRM1 DRILL CIRC T Make a top drive connection on stand#74. RIH f/7333'to 7397'. Fill pipe, orient to 40 deg left. Shut down pumps. RIH to 7428'. 20:15 20:30 0.25 7,428 7,692 INTRM1 DRILL TRIP T Run stand#75,#76,then run stand #77 to 7692'.Tag up at 7692'. 20:30 20:45 0.25 7,692 7,712 INTRM1 DRILL REAM T Make a connection @ 7692'. Pump and work through 7692'to 7712'. Page 24 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 21:30 0.75 7,712 7,810 INTRM1 DRILL REAM T Make a connection on stand#78, run in 40'to 7752',then ream f/7752'to TD @ 7810'. Calculated displacement 49 bbls, actual 54.8 bbls. Note:Top of jars below bottom of window @ 7752'. 21:30 00:00 2.50 7,810 7,824 INTRM1 DRILL DDRL P Directional drill 6-1/8"hole w/Reed Hycolog bit and SperryDrill motor (1.5 deg bend)f/7810'to 7824'. Actual drilling time 1.45 hrs, sliding zero of this time.Weatherford jar hrs 25.69. Drill w/5-15k WOB. Pumping 200-240 gpm w/1600 to 2050 psi- 37-39%TOTCO flow out. ECD's 12.58 ppg. Rotate 80 rpm w/6k ftlbs on and 4k ftlbs off bottom. PU wt 135k, SO wt 86k, Rot wt 106k. Note: Pumped a 28 bbl medium nut plug sweep(10ppb nut plug) while drilling @ 7822'. Increase of ECD's f/ 12.6 to 12.9 ppg while coming back to surface. Note: OA pressure 250 psi @ midnight. 35/07/2011 Continue to directional drill 6-1/8"hole f/7824'to 8426'. 00:00 04:30 4.50 7,824 7,897 INTRM1 DRILL DDRL P Directional drill 6-1/8"hole w/Reed Hycolog bit and SperryDrill motor (1.5 deg bend)f/7824'to 7897'. Actual drilling time 4.06 hrs, sliding zero of this time.Weatherford jar hrs 29.75. Drill w/5-15k WOB. Pumping 240 gpm w/2050 psi-39%TOTCO flow out. ECD's 12.6 ppg. Rotate 80 rpm w/6k ftlbs on and 4k ftlbs off bottom. PU wt 135k, SO wt 86k, Rot wt 106k. Note: Pumped a 28 bbl medium nut plug sweep(10ppb nut plug) while drilling @ 7900'. Increase of ECD's f/ 12.6 to 12.9 ppg while coming back to surface. 04:30 12:00 7.50 7,897 7,994 INTRM1 DRILL DDRL P Directional drill 6-1/8"hole w/Reed Hycolog bit and SperryDrill motor (1.5 deg bend)f/7897'to 7994' 5490'TVD).Actual drilling time 5.25 hrs, sliding .87 of this time. Weatherford jar hrs 35. Drill w/5-15k WOB. Pumping 240 gpm w/2050 psi-39%TOTCO flow out. ECD's 11.79 ppg. Rotate 80 rpm w/6k ftlbs on and 5k ftlbs off bottom. PU wt 133k, SO wt 92k, Rot wt 110k. Note: Reduced mud wt f/11 ppg to 10.3 ppg by 11 am. Page 25 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 7,994 8,426 INTRM1 DRILL DDRL P Directional drill 6-1/8"hole w/Reed Hycolog bit and SperryDrill motor (1.5 deg bend)f/7994'to 8426' 5668'TVD).Actual drilling time 9.81 hrs, sliding 2.52 of this time. Weatherford jar hrs 44.81. Drill w/ 10-15k WOB. Pumping 240 gpm w/ 2175 psi-38%TOTCO flow out. ECD's 11.99 ppg. Rotate 80 rpm w/ 6k ftlbs on and 5k ftlbs off bottom. PU wt 135k, SO wt 94k, Rot wt 113k. Note: Reduced mud wt f/11 ppg to 10.3 ppg by 11 am. Note: Pumped a 28 bbl medium nut plug sweep(10ppb nut plug) while drilling @ 7820'. Increase of ECD's f/ 12.6 to 12.9 ppg while coming back to surface. Note: OA pressure 820 psi at midnight. 35/08/2011 Continue to directional drill 6-1/8"hole f/8426'to 9310'(6031'TVD). 00:00 06:00 6.00 8,426 8,647 INTRM1 DRILL DDRL P Directional drill 6-1/8"hole w/Reed Hycolog bit and SperryDrill motor (1.5 deg bend)f/8426'to 8647' 5763.8'TVD).Actual drilling time 4.97 hrs, sliding .65 of this time. Weatherford jar hrs 49.78. Drill w/ 10-13k WOB. Pumping 240 gpm w/ 2200-2250 psi-38%TOTCO flow out. ECD's 11.93 ppg. Rotate 80 rpm w/ 6k ftlbs on and 5.5k ftlbs off bottom. PU wt 135k, SO wt 95k, Rot wt 115k. Note: Pumped a 28 bbl medium nut plug sweep(10ppb nut plug) while drilling @ 8571'. 06:00 12:00 6.00 8,647 8,836 INTRM1 DRILL DDRL P Directional drill 6-1/8"hole w/Reed Hycolog bit and SperryDrill motor (1.5 deg bend)f/8647'to 8836' 5839'TVD).Actual drilling time 3.94 hrs,sliding 1.35 of this time. Weatherford jar hrs 53.72. Drill w/ 8-13k WOB. Pumping 240 gpm w/ 2250-2325 psi-38-37%TOTCO flow out. ECD's 12.15 ppg. Rotate 80 rpm w/6k ftlbs on and 5.5k ftlbs off bottom. PU wt 137k, SO wt 96k, Rot wt 116k. Note: Pumped a 28 bbl medium nut plug sweep(10ppb nut plug) while drilling @ 8668'. -- — — --. — Page 26 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 8,836 9,310 INTRM1 DRILL DDRL P Directional drill 6-1/8"hole w/Reed Hycolog bit and SperryDrill motor (1.5 deg bend)f/8836'to 9310' 6031'TVD).Actual drilling time 9.6 hrs, sliding 1.31 of this time. Weatherford jar hrs 63.32. Drill w/ 10-15k WOB. Pumping 240 gpm w/ 2325-2450 psi-38-37%TOTCO flow out. ECD's 12.07 ppg. Rotate 80 rpm w/6k ftlbs on and 5k ftlbs off bottom. PU wt 140k, SO wt 97k, Rot wt 116k. Note: Pumped a 28 bbl medium nut plug sweep(10ppb nut plug) while drilling©8951'. Note: OA pressure at midnight 950 psi. 05/09/2011 Drill f/9310'to 9434'. BROOH to 8600', hole packed off,slack off to 8650',establish circ, increase rate to drilling rate w/full returns, CBU, pump out f/8650'to 7429', perform LOT, POOH, lay down bit and motor, slip and cut drill line, change saver sub on TD, PU/MU BHA#13. 00:00 04:30 4.50 9,310 9,434 INTRM1 DRILL DDRL P Directional drill 6-1/8"hole w/Reed Hycolog bit and SperryDrill motor (1.5 deg bend)f/9310'to 9434' 6080 TVD).Actual drilling time 3.98 hrs, sliding 0 of this time.Total bit hrs this run =43.07.Weatherford jar hrs 67.3. Drill w/8-13k WOB. Pumping 240 gpm w/2550-2450 psi- 38-37%TOTCO flow out. ECD's 12.04 ppg. Rotate 80 rpm w/6k ftlbs on and 5k ftlbs off bottom. PU wt 144k, SO wt 97k, Rot wt 118k. 04:30 04:45 0.25 9,434 9,434 INTRM1 DRILL CIRC P Obtain final survey. Circulate 240 gpm w/2450 psi-37-38%Totco flow out.. 04:45 05:00 0.25 9,434 9,434 INTRM1 DRILL OWFF P Monitor well-static 05:00 06:45 1.75 9,434 8,600 INTRM1 DRILL TRIP P Back ream out of the hole f/9434'to 8600'. Pumping 175 gpm ft/min. 06:45 07:30 0.75 8,600 8,600 INTRM1 DRILL CIRC T While back reaming @ 8600', hole packed off. Rotation stopped w/limit set© 10k ft lbs. Pressured up to 1728 psi.Worked string to find a spot to circulate.Worked down to 8650', able to rotate. Establish circulation, pumping 71 gpm w/700 psi, 89 gpm-28%TOTCO flow out. 07:30 09:00 1.50 8,600 8,600 INTRM1 DRILL CIRC T Increase pump rate every 5 minutes by 18 gpm until reaching drilling rate of 240 gpm w/2100 psi-37 to 38% TOTCO flow out. 09:00 10:00 1.00 8,600 8,600 INTRM1 DRILL CIRC T Circulate bottom's up, pumping 240 gpm w/2100 psi-37 to 39%TOTCO flow out. 10:00 12:30 2.50 8,600 7,429 INTRM1 DRILL TRIP P Pump out of the hole f/8600'to 7429'. Pumping 71 gpm w/500 psi-13%TOTCO flow out. Page 27 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 12:45 0.25 7,429 7,429 INTRM1 DRILL RURD P Blow down the top drive. Rig up f/ FIT/LOT. 12:45 13:45 1.00 7,429 7,429 INTRM1 DRILL LOT P Perform LOT to 13.4 ppg at the window and 12.99 ppg at TD(9434' MD/6080'TVD).With 10.3 ppg mud weight and leak off at 850 psi. Re-test to confirm. 13:45 14:00 0.25 7,429 7,429 INTRM1 DRILL RURD P Rig down testing equipment. Blow down lines. 14:00 14:15 0.25 7,429 7,429 INTRM1 DRILL OWFF P Monitorwell-static. 14:15 14:30 0.25 7,429 6,960 INTRM1 DRILL TRIP P Pull out of the hole on elevators f/ 7429'to 6960'. Hole fill correct. 14:30 14:45 0.25 6,960 6,960 INTRM1 DRILL CIRC P Pump a dry job. 14:45 16:30 1.75 6,960 456 INTRM1 DRILL TRIP P Continue to pull out of the hole f/ 6960'to 456'(BHA). 16:30 16:45 0.25 456 456 INTRM1 DRILL OWFF P Monitor well @ the HWDP-static. 16:45 17:30 0.75 456 53 INTRM1 DRILL TRIP P Continue to pull out of the hole f/456' to 53'. 17:30 18:00 0.50 53 53 INTRM1 DRILL PULD P Download Sperry Sun MWD. 18:00 19:00 1.00 53 0 INTRM1 DRILL PULD P Break bit, lay down MWD and motor. 19:00 19:15 0.25 0 0 INTRM1 DRILL SFTY P Pre job safety meeting on slip and cut drilling line. 19:15 20:15 1.00 0 0 INTRM1 RIGMNTSLPC P Slip and cut 62'of 1-1/4"drilling line. Service rig, inspect brakes. 20:15 20:30 0.25 0 0 INTRM1 RIGMNT SFTY P Pre job safety meeting on changing saver sub on the top drive. 20:30 22:00 1.50 0 0 INTRM1 RIGMNT SVRG P Change out the XT-39 saver sub on the top drive. 22:00 22:15 0.25 0 0 INTRM1 DRILL PULD P Mobilize tools to the rig floor f/7" underreamer run. 22:15 22:30 0.25 0 0 INTRM1 DRILL SFTY P Pre job safety meeting on makeing up BHA#13(Weatherford Rip Tide underreamer). 22:30 00:00 1.50 0 114 INTRM1 DRILL PULD P Make up BHA#13 to 114':4-1/4" Bull nose, bit sub, 7"RipTide underreamer(ser#RT603), 5.88"OD stabilizer, a stand of 4-3/4"flex drill collars. Note: OA pressure @ midnight=80 psi. 35/10/2011 MU BHA#13(7"under reamer), RIH, start reaming 7"f/7468', ream to 7919', monitor well-breathing, CBU, monitor well-breathing, ream f/7919'to 8240'. 00:00 00:15 0.25 114 114 INTRM1 DRILL SFTY P Pre job safety meeting. Page 28 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:15 00:30 0.25 114 476 INTRM1 DRILL TRIP P Continue to make up BHA#13 f/114' to 481.84' :4-1/4"Bull nose, bit sub, 7"RipTide underreamer(ser# RT603), 5.88"OD stabilizer, a stand of 4-3/4"flex drill collars,x-o, a stand of 4-3/4"steel drill collars, a stand of 4"HWDP,jar, 1-2/3"stand of 4" HWDP=total of 481.84'. Cutters are 5.74'above bull nose.Will track depth of cutters. BHA length: cutters to top of HWDP=467.1'. 00:30 04:00 3.50 476 7,468 INTRM1 DRILL TRIP P RIH w/BHA#13 on 4"drill pipe f/ 476'to 7468' PDC cutters depth. Fill pipe every 20 stands. Calculated fill 47.89 bbls, actual 45.85 bbls. 04:00 09:30 5.50 7,468 7,845 INTRM1 DRILL REAM P Start reaming 6-1/8"hole to 7"w/ cutters at 7468'(5.88"OD Stabilizer 5'below window). Ream w/2-6k weight on cutters, pumping 300 gpm w/2200 psi. Rotate 70 rpm w/6k ft lbs of torque on bottom, 5k off bottom. PU wt 126k, SO wt 92k, Rot wt 105k.While reaming to 7"OD, hole started taking mud @ 7845'. 09:30 11:00 1.50 7,845 7,919 INTRM1 DRILL REAM P Continue to under ream f/7845'to 7919'w/Weatherford RipTide reamer. Ream w/5-8k weight on cutters, pumping 300 gpm w/2100 psi. Rotate 80 rpm w/6k ft lbs of torque on bottom,4-5k off bottom. PU wt 127k, SO wt 90k, Rot wt 109k. Losing some mud to the hole. Lost a total of 60 bbls while reaming, pumped a 30 bl nut plug fine(10 ppb) while reaming @ 7875'. No increase in loss rate. 11:00 11:15 0.25 7,919 7,919 INTRM1 DRILL OWFF P Monitor well-flowing w/pumps off-breathing. 11:15 12:30 1.25 7,919 7,919 INTRM1 DRILL CIRC P Circulate bottom's up, pumping 148 gpm w/750-800 psi-38%TOTCO flow out. PU wt 127k, SO wt 90k. Note:Total losses f/tour up to noon =44 bbls. 12:30 12:45 0.25 7,919 7,919 INTRM1 DRILL OWFF P Monitor well-Slight flow,decreasing with time. Decision to continue reaming. Page 29 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:45 00:00 11.25 7,919 8,240 INTRM1 DRILL REAM P Continue to under ream f/7919'to 8240'w/Weatherford RipTide reamer. Losing some mud to the hole. Ream w/6-8k weight on cutters, pumping 260 gpm w/1750 psi. Rotate 80 rpm w/6-8k ft lbs of torque on bottom,4-4.5k off bottom. PU wt 125k, SO wt 90k, Rot wt 107k. Note: Reduced mud weight f/11 ppg to 10.8 ppg while reaming @ 8180'. Note: : Lost a total of 47.5 bbls while reaming this tour.Total fluid lost today=91.5 bbls. 35/11/2011 Ream f/7240'to 8838', packed off, regain circ, con't reaming f/8838'to 9236'(6000'TVD)©midnight. 00:00 12:00 12.00 8,240 8,808 INTRM1 DRILL REAM P Continue to under ream f/8240'to 8808'(5828'TVD)w/Weatherford RipTide reamer. Ream w/3-5k weight on cutters, pumping 260 gpm w/1750-1800 psi. Rotate 80-90 rpm w/8-5.5k ft lbs of torque on bottom, 4-5k off bottom. PU wt 135k, SO wt 88k, Rot wt 112k. Note: Pumped 30 bbl sweeps(10.8 ppg mud w/10%drill zone, 10%fine nut lug)while reaming @ 8294', 8555', 8655'. Note: no mud losses this tour. 12:00 12:15 0.25 8,808 8,838 INTRM1 DRILL REAM P Continue to under ream f/8808'to 8838'(5829'TVD)w/Weatherford RipTide reamer. Ream w/3-5k weight on cutters, pumping 260 gpm w/1650 psi. Rotate 80 rpm w/6k ft lbs of torque on bottom, 5k off bottom. PU wt 135k, SO wt 88k, Rot wt 112k. 12:15 13:30 1.25 8,838 8,838 INTRM1 DRILL CIRC T Hole packed off while reaming © 8838'. Shut down pump and rotary. Pick up f/8838'to 8764'. Establish circulation, staging pumps up to 260 gpm,then ream back down f/8764' to 8838'. Increased rpm f/90 to 120 rpm. Increased flow rate f/260 gpm to 265 gpm. Page 30 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 00:00 10.50 8,838 9,236 INTRM1 DRILL REAM P Continue to under ream f/8838'to 9236'(6000.08'TVD)w/Weatherford RipTide reamer. Ream w/3-12k weight on cutters, pumping 270 gpm w/1900 psi. Rotate 120 rpm w/ 6-6.5k ft lbs of torque on bottom, 5k off bottom. PU wt 137k, SO wt 88k, Rot wt 114k. Note: Pumped 30 bbl sweeps(10.8 ppg mud w/10%drill zone, 10%fine nut lug)while reaming @ 8930, 9120'. Note: No mud losses this tour.Total losses to the well 92 bbls. Note: OA pressure @ midnight 1220 psi. 05/12/2011 Ream f/9236'to 9428', circ, increase MW f/10.8 to 11 ppg, monitor well, CBU,trip out w/7"underreamer, L/D same. 00:00 05:45 5.75 9,236 9,428 INTRM1 DRILL REAM P Continue to under ream f/9236'to 99428'(6079'TVD)w/Weatherford RipTide reamer. Ream w/3-10k weight on cutters, pumping 270 gpm w/2000 psi. Rotate 120 rpm w/7k ft lbs of torque on bottom, 6k off bottom. PU wt 141k, SO wt 85k, Rot wt 116k. 05:45 08:00 2.25 9,428 9,428 INTRM1 DRILL CIRC P Pumped a 30 bbl sweep(10.8 ppg mud w/10%drill zone, 10%fine nut lug)while circulating to clean up hole @ bull nose depth of 9434'(Cutter depth 9428'). Pumping 270 gpm w/ 2000 psi-38%TOTCO flow out. PU wt 141k, SO wt 85k, Rot wt 116k. Note:While circulating, lost 250 psi of pump pressure. 08:00 10:30 2.50 9,428 9,428 INTRM1 DRILL CIRC P Increase mud weight f/trip marging f/ 10.8 ppg to 11 ppg. Pumping 200 gpm w/1100 psi-38%flow out. 10:30 11:15 0.75 9,428 9,428 INTRM1 DRILL OWFF P Monitor well.Total gain of 9.85 bbls to the trip tank while pumps are off (Breathing). 11:15 12:00 0.75 9,428 9,428 INTRM1 DRILL CIRC P Circulate bottom's up, pumping 200 gpm w/1100 psi-38%flow out. Rotate 70 rpm WI 6k ft lbs of torque. Rotating wt 110k. 12:00 12:45 0.75 9,428 9,428 INTRM1 DRILL OWFF P Monitor well-slight flow, diminishing with time. Lay down a single of 4" drill pipe. Blow down the top drive. Drop a 2.38"OD rabbit w/100'wire tail. 12:45 14:00 1.25 9,428 8,480 INTRM1 DRILL TRIP P Pull out of the hole(slow)to maintain EMW of 10.5 ppg while tripping, from 9428'to 8480'. 14:00 14:15 0.25 8,480 8,480 INTRM1 DRILL OWFF P Monitor well. Page 31 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 15:30 1.25 8,480 7,350 INTRM1 DRILL TRIP P Pull out of the hole(slow)to maintain EMW of 10.5 ppg while tripping, from 8480'to 7350'. Pulled through window with no problems. PU wt 125k. Calculated displacement 14.3 bbls, actual 11.6 bbls. 15:30 16:00 0.50 7,350 7,350 INTRM1 DRILL OWFF P Monitor well while inside of 7" casing.Observed fluid level dropping in riser. 16:00 17:00 1.00 7,350 7,350 INTRM1 RIGMNT RGRP T Repair hose on the iron roughneck. 17:00 19:15 2.25 7,350 4,525 INTRM1 DRILL TRIP P Pull out of the hole(slow)to maintain EMW of 10.5 ppg while tripping, from 7350'to 4525'. Pulling pipe wet. 19:15 19:30 0.25 4,525 4,525 INTRM1 DRILL CIRC P Pump a dry job. 19:30 21:00 1.50 4,525 1,711 INTRM1 DRILL TRIP P Pull out of the hole(slow)to maintain EMW of 10.5 ppg while tripping, from 4525'to 476'. 21:00 21:15 0.25 1,711 1,711 INTRM1 DRILL SFTY P Pre job safety meeting/crew change 21:15 22:00 0.75 1,711 476 INTRM1 DRILL TRIP P Pull out of the hole(slow)to maintain EMW of 10.5 ppg while tripping, from 1711'to 476'. 22:00 22:15 0.25 476 476 INTRM1 DRILL OWFF P Monitorwell-static. 22:15 23:15 1.00 476 52 INTRM1 DRILL PULD P Lay down BHA#13(7"Weatherford under reamer)f/476'to 52'. Note: Retrieve rabbit f/top of jars. 23:15 00:00 0.75 52 0 INTRM1 DRILL PULD P Pick up, inspect under reamer cutters(Good condition), check bullnose.22/32"Jet in bullnose is missing; explains 250 psi pump pressure lost after reaming to TD. Finish laying down BHA. NOTE: OA pressure 350 psi at midnight 05/13/2011 Test top rams and annular w/5-1/2"test joint,RU/Rem/5-1/2"liner, MU hanger,circ, RIH on 4"dp to 7390', circ, con't RIH to 8712'. 00:00 00:15 0.25 0 INTRM1 WHDBOSFTY P Pre job safety meeting. 00:15 00:30 0.25 0 0 INTRM1 WHDBO CIRC P Make up stack washing tool,then wash f/28'(below wear bushing). 00:30 01:00 0.50 0 INTRM1 WHDBOOTHR P Drain stack, Pull FMC 6-3/8"wear bushing. 01:00 01:30 0.50 INTRM1 WHDBO RURD P Rig up to test top pipe and annular with 5-1/2"test joint. 01:30 03:15 1.75 INTRM1 WHDBO BOPE P Test top pipe rams(3-1/2"x 6" variables)to 250 psi low and 4000 psi high. Hold each test 5 minutes. Test Annular to 250 psi low and 2500 psi high. Hold each test 5 minutes. Chart tests.Witness of tests waived by AOGCC inspector John Crisp. Notified 1915 hrs 5/11/2011. 03:15 03:30 0.25 INTRM1 WHDBO RURD P Rig down testing equipment. Set FMC 6-3/8"wear bushing. Page 32 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:30 1.00 INTRM1 CASING RURD P Rig up casing equipment. Make up floor safety valve. Clean 5-1/2" 15.5 ppf L-80 Hydril 511 boxes and pin connections to remove road dirt. 04:30 04:45 0.25 INTRM1 CASING SFTY P Pre job safety meeting on running 5-1/2"liner. 04:45 05:15 0.50 0 165 INTRM1 CASING RUNL P Pick up/Make up to 4400 ft lbs: Rays silver bullet baker locked to a joint of casing, bakerlock jt#2,then bakerlock Weatherford model 402 float collar, baker locked to jt#3, then baker lock jt#4(Jt#4 has a Baker insert landing ring installed 1' above the pin end). 05:15 05:30 0.25 165 165 INTRM1 CASING CIRC P Make up crossover and headpin. Rig up circulating hose.Circulate 10 bbls through float equipment, pumping 50 spm w/120 psi. Floats are good. 05:30 06:00 0.50 165 386 INTRM1 CASING RUNL P Continue to run 5-1/2" 15.5 ppf L-80 Hyd 511 casing f/165'to 386'. 06:00 06:30 0.50 386 426 INTRM1 CASING PULD T Change out jt# 10(damaged box while running to the floor f/the pipe shed)(original 43.57'with joint#54 (42.98'). Make up to 4400 ft lbs, RIH. 06:30 07:00 0.50 426 685 INTRM1 CASING RUNL P Continue to run 5-1/2" 15.5 ppf L-80 Hyd 511 casing f/426'to 685'. 07:00 07:15 0.25 685 685 INTRM1 CASING SFTY P Pre job safety meeting/crew change. 07:15 09:30 2.25 685 2,175 INTRM1 CASING RUNL P Continue to run 5-1/2" 15.5 ppf L-80 Hyd 511 casing f/685'to 2175'. 09:30 10:15 0.75 2,175 2,203 INTRM1 CASING RUNL P Change elevators, make up Baker liner hanger and packer assembly. Mix pal mix, pour in top of liner, allow to set. Rig down casing equipment. Calculated displacement 11.9 bbls, actual 10.25 bbls. 10:15 10:45 0.50 2,203 2,296 INTRM1 CASING RUNL P Run liner on a stand of 4"drill pipe f/ 2203'to 2296'. 10:45 11:30 0.75 2,296 2,296 INTRM1 CASING RUNL P Circulate liner capacity @ 2296'. Pumping 200 gpm w/500 psi. Pumped 78 bbls. PU wt after fill 52k, SO wt 49k. Sim ops: Make up cement head, crossovers and a pup joint. 11:30 12:00 0.50 2,296 2,772 INTRM1 CASING RUNL P Run liner in the hole on 4"drill pipe f/ 2296'to 2772'. Fill every 10 stands. PU wt 64k, SO wt 52k. 12:00 17:15 5.25 2,772 7,390 INTRM1 CASING RUNL P Continue to run liner in the hole on 4" drill pipe f/2772'to 7390'. Fill every 10 stands. PU wt 112k, SO wt 80k. Calculated displacement 26.85 bbls, actual 18.5 bbls. Paye 33 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 19:30 2.25 7,390 7,390 INTRM1 CASING CIRC P Circulate at the top of window (Window 7434'-7447'). Stage pumps up to 4 bpm w/875 psi-34%TOTCO flow out.Observed increase in losses. Reduce rate to 3.5 bpm w/ 800 psi-32%TOTCO flow out, 3 bpm w/790 psi-30%TOTCO flow, 2 bpm w/650 psi. Pumped a toal of 357 bbls. 19:30 21:00 1.50 7,390 7,390 INTRM1 CASING OWFF P Monitor well w/pumps off,taking returns to the trip tank. Flow decreasing with time.Total bbl flowed back 32.25 bbls. 21:00 00:00 3.00 7,390 8,712 INTRM1 CASING RUNL P Continue to run liner in the hole on 4" drill pipe f/7390'to 8712'. Run stands 56-59©25'/min,60-63 @ 20'/min,64-65 @ 10-15'/min. PU wt 130k, SO wt 80k. Run stands 66-69 @ 8-10'/min. PU wt 140k, SO wt 84k. Note:After midnight, while running stand#74 @ 9164', hole took weight.Tried to go down,then picked up after breaking free to 9147', screwed into string to circulate and wash through, initiate circ w/.87 bpm, staging up to 2.5 bpm-packing off. Cleaned hole up, still could not go down easily.Worked down to 9135'. Still not going down. Circulated a total of 427 bbls. Note: OA pressure 100 psi @ midnight. 05/14/2011 Con't RIH w/5-1/2"liner f/8712'to 9164'_ took wt,work to get deeper, no-go,pump&,pull liner out of the hole, lay down damaged Baker hanger, PJSM, laying down 5-1/2"liner. 00:00 01:00 1.00 8,712 9,164 INTRM1 CASING RUNL P Continue to run liner in the hole on 4" drill pipe f/8712'to 9164'. Run stands 70-73 plus part of stand#74 @ 8-10'/min. Hole took weight @ 9164'. PU wt 140k, SO wt 84k. Calculated displacement 37.1 bbls, actual 51 bbls. -- Page 34 of 621 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:00 1.00 9,164 9,120 INTRM1 CASING CIRC P Tried to go down,then picked up after breaking free to 9147'(Pulled to 170k,then 180k, pulled free w/ 190k), screwed into string to circulate and wash through, initiate circ w/.87 bpm w/450 to 510 psi, 1.27 bpm w/580 to 600 psi.While pumping the SO wt was 82k. Increase pump rate to 1.7 bpm w/ 680 psi.While pumping the PU wt was 135k. Increase pump rate to 2 bpm w/710 psi-15%increasing to 26%Totco flow out.While pumping the SO wt was 82k. Packed off @ 9135'to 1500 psi, re gained circulation. Picked up to 9120'to try and go deeper,taking weight/packing off. 02:00 05:00 3.00 9,120 9,085 INTRM1 CASING CIRC T Washing f/9120'to 9135'. Quit going down. Pumping 2 bpm w/710 gpm. Work up hole f/9120'to 9085'. Picks up ok,when slacking off-takes weight. Slack off to 45k. Stage pumps up to 3.5 bpm w/850 psi. Observed sand over the shakers. Circulated to clean up. Pressure dropped 100 psi and quit packing off, but still takes weight when slacking off. Continuing to lose ground going down-depth 9085'. 05:00 05:45 0.75 9,085 9,085 INTRM1 CASING DHEQ T Attempt to test and verify if hanger was set. Pressure up on the annulus to 200 psi.Attempt to slack off-no go. 05:45 08:15 2.50 9,085 8,522 INTRM1 CASING TRIP T Pump out of the hole f/9085'to 8522', pumping 2 bpm w/575 psi. Several attempts to RIH.Took weight after slacking off 5-10'. Calculated displacement 5.4 bbls,actual 8.5 bbls. 08:15 09:15 1.00 8,522 7,390 INTRM1 CASING TRIP T Pull out of the hole on elevators f/ 8522'to 7390'(Window @ 7434-7447'). 09:15 09:30 0.25 7,390 7,390 INTRM1 CASING OWFF T Monitor well-static. 09:30 12:00 2.50 7,390 5,599 INTRM1 CASING TRIP T Continue to pull liner out of the hole on elevators f/7390'to 5599'. Calculated displacement 14 bbls, actual 14 bbls. 12:00 12:45 0.75 5,599 5,352 INTRM1 CASING TRIP T Continue to pull liner out of the hole on elevators f/5599'to 5352'. Experienced 20k overpull at 5470'. Slacked off and took 20k several times.Work until free. 12:45 13:30 0.75 5,352 5,352 INTRM1 CASING CIRC T Circulate, staging pumps up to 3 bpm w/650 psi.After two attempts, able to pull pipe, continue to circulate. Page 35 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 21:30 8.00 5,352 2,200 INTRM1 CASING TRIP T Pump liner out of the hole 2.75 to 3 bpm. Pumped out f/5352'to the Baker liner hanger. Pulled tight(20k over)several times @ shoe depths of 4080', 3856', 3233', 2906', 2896'. Circulated a while to move solids away f/hanger top each time,then able to pull again. 21:30 22:00 0.50 2,200 2,176 INTRM1 CASING PULD T Install lift sub, pull hanger to floor, observing a slip segment missing and a half of another slip missing. PU wt 52k. Lay down hanger and packer assembly. Damage to hanger, iron imbedded into packer rubber, iron in dust cover slot. Pictures taken,will post to the "S"drive well folder. 22:00 22:30 0.50 2,176 2,176 INTRM1 CASING RURD T Change elevators to 5-1/2". Blow down the top drive. 22:30 23:00 0.50 2,176 2,176 INTRM1 CASING CIRC T Pump a dry job, blow down the 2" cement line. Clean and clear rig floor. 23:00 23:30 0.50 2,176 2,176 INTRM1 CASING SFTY T Pre job safety meeting on laying down the 5-1/2" 15.5 ppf L-80 Hydril 511 casing. 23:30 00:00 0.50 2,176 2,045 INTRM1 CASING PULD T Lay down 3 joints of liner f/2176'to 2045'. 05/15/2011 Lay down 5-1/2"liner, flush stack, pull wear bushing,test BOPE.Witness of test waived by AOGCC inspector Jeff Jones. MU BHA#14, RIH to 7430', circulate 2-1/2 BU. 00:00 01:00 1.00 2,045 1,323 INTRM1 CASING PULD T Lay down joints#4 through#20 from 2045'to 1323'. 01:00 01:30 0.50 1,323 1,323 INTRM1 CASING OWFF T Monitor well-slight flow to static. 01:30 04:15 2.75 1,323 126 INTRM1 CASING PULD T Lay down joints#21 through#5 of liner f/1323'. 04:15 04:30 0.25 126 126 INTRM1 CASING SFTY T Pre job safety meeting.Acquire Hot work permit. 04:30 05:45 1.25 126 0 INTRM1 CASING PULD T Lay down last 4 joints of 5-1/2"liner f/126'..Welder acquired a hot work permit,then heated up connections w/torch(approx 500 degrees). 05:45 06:00 0.25 0 0 INTRM1 CASING RURD T Rig down casing equipment. 06:00 06:15 0.25 0 0 INTRM1 CASING OWFF T Monitor well-slight flow to static. 06:15 06:30 0.25 0 0 INTRM1 WHDBO CIRC P Rig up,then flush stack w/stack washing tool. Pumping 670 gpm w/ 80 psi. 06:30 06:45 0.25 0 0 INTRM1 WHDBO BOPE P Pull FMC 6-3/8"ID wear bushing. 06:45 07:30 0.75 0 0 INTRM1 WHDBO BOPE P Rig up to test BOPE. 07:30 07:45 0.25 0 0 INTRM1 WHDBO RURD P Pre job safety meeting on testing BOPE. Page 36 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 15:00 7.25 0 0 INTRM1 WHDBO BOPE P Test BOPE equipment(BI-Weekly test).Witness of test waived by AOGCC inspector Jeff Jones.Test w/ 3-1/2",4", and 5-1/2"test joints.Test to 250 psi low and test rams to 4000 psi high(lower 2-7/8"x 5",top 3-1/2" x 6"), annular to 2500 psi.Test all valves to 250 psi and 4000 psi. Hold each test f/5 minutes. Chart tests. Perform accumulator test: System pressure 3000 psi, after closure 1700 psi. @00 psi build up in 32 seconds,full charge 3 minutes 1 second. Nitrogen bottle(5)average pressure of 2150 psi.4"Demco valve on mud line f/kill line failed, repaired and retested. 15:00 15:30 0.50 0 0 INTRM1 WHDBO RURD P Rig down testing equipment. Blow down choke manifold, kill and choke lines. 15:30 15:45 0.25 0 INTRM1 WHDBOOTHR P Install FMC 6-3/8"ID wear bushing. 15:45 16:15 0.50 INTRM1 DRILL PULD T Bring Baker tools to the rig floor. 16:15 16:30 0.25 INTRM1 DRILL SFTY T Pre job safety meeting on making up BHA. 16:30 17:00 0.50 0 25 INTRM1 DRILL PULD T Make up BHA#14(bit, boot baskets, magnet)(cleanout assembly). 17:00 17:30 0.50 25 298 INTRM1 DRILL PULD T PU/MU jars and 4"HWDP to 298' 17:30 22:00 4.50 298 7,364 INTRM1 DRILL TRIP T Trip in the hole with BHA#14 on 4" drill pipe f/298'to 7364'. Fill pipe every 20 stands. 22:00 22:15 0.25 7,364 7,430 INTRM1 DRILL CIRC T Make a top drive connection on stand#76 RIH f/7364'to 7430',fill pipe, break circulation. PU wt 125k, SO wt 87k. Calculated displacment 34.8 bbls, actual 36.9 bbls. 22:15 00:00 1.75 7,430 7,430 INTRM1 DRILL CIRC T Work string f/7430'to 7364'while circulating bottom's up x 2-1/2. Stage pumps up f/2 bpm w/410 psi-25%Totco flow out, 3 bpm w/ 600 psi-31%Totco flow out,4 bpm w/780 psi-43%Totco flow out, 5 bpm w/1050 psi-39-40%Totco flow out, slow back to 4.5 bpm w/1030 psi until a bottom's up,then increase to 5 bpm w/1080 psi-39%Totco flow until almost 2 BU, increase to 5.5 bpm w/1260 psi-38%Totco flow, then 6 bpm w/1400 psi-38%Totco flow out. Circulated 2-1/2 bottom's up (431 bbls). Note: OA pressure at midnight= 150 psi. 05/16/2011 POOH w/cleanout BHA#14, clean magnet and boot baskets, MU/RIH w/ BHA# 15, RIH to 7452', circ, POOH, clean off magnets, PJSM, MU/RIH w/BHA#16(open hole cleanout assembly)to 8374'@ midnight. - —— -- -- _- -- Page 37 of 62 — Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:15 0.25 7,430 7,366 INTRM1 DRILL OWFF T Pre job safety meeting. Stand back a stand f/7430'to 7366'. Blow down the top drive. Monitor well-slight breathing, decreasing w/time. PU wt 125k, SO wt 85k. 00:15 05:15 5.00 7,366 298 INTRM1 DRILL TRIP T POOH on elevators f/7366'to 298'. Monitor well on the trip tank. Calculated fill 43.5 bbls, actual 43.25 bbls. 05:15 05:30 0.25 298 298 INTRM1 DRILL OWFF T Monitor well @ HWDP-static. 05:30 05:45 0.25 298 26 INTRM1 DRILL TRIP T Stand back the HWDP and jars. 05:45 06:45 1.00 26 0 INTRM1 DRILL PULD T Lay down Baker boot baskets and magnet. Clean and inspect same. Note: Recovered window shavings and pieces f/broken hanger on magnet. Recovered hanger pieces f/ upper Boot Basket. Pictures posted to the"S"drive well folder. 06:45 07:30 0.75 0 0 INTRM1 DRILL PULD T Clean and clear rig floor. 07:30 07:45 0.25 0 22 INTRM1 DRILL PULD T Make up cleanout run#2(BHA# 15) 07:45 12:00 4.25 22 7,368 INTRMI DRILL TRIP T Run in the hole w/BHA#15 f/2200' to 7300. Fill pipe every 20 stands. PU wt 122k, SO wt 86k. 12:00 12:15 0.25 7,368 7,435 INTRM1 DRILL CIRC T Make a top drive connection on stand#76 RIH f/7368'to 7450',fill pipe, break circulation. PU wt 125k, SO wt 87k. 12:15 13:15 1.00 7,435 7,452 INTRM1 DRILL CIRC T Work string f/7435'to 7452'while circulating bottom's up.Work down in 2'increments. Stage pumps up f/ 3 bpm w/600 psi-40%Totco flow out,4 bpm w/780 psi-40%Totco flow out. 13:15 14:00 0.75 7,452 7,357 INTRM1 DRILL CIRC T Circulate bottom's up.Work pipe f/ 7434'to 7357'. Pumping 5 bpm w/ 1000 psi-39%TOTCO flow out. 14:00 14:15 0.25 7,357 7,357 INTRM1 DRILL OWFF T Monitor well-slight flow-breathing. 14:15 15:45 1.50 7,357 4,060 INTRM1 DRILL TRIP T Trip out of the hole f/7357'to 4060'. Monitor well ont he trip tank. 15:45 16:00 0.25 4,060 4,060 INTRM1 DRILL CIRC T Pump a dry job. 16:00 17:15 1.25 4,060 20 INTRM1 DRILL TRIP T Continue trip out of the hole f/4060' to 20'. Monitor well on the trip tank. Calculated fill 39.8 bbls, actual 43.5 bbls. 17:15 17:30 0.25 20 0 INTRM1 DRILL TRIP T Break bit, clean magnet, empty Boot Basket. Recovered 6 small slip segment pieces f/Baker Hanger on the magnet. Recovered some metal shavings in the junk basket. 17:30 18:15 0.75 0 0 INTRM1 DRILL PULD T Lay down Baker tools. Pick up a 6" stabilizer from the beaver slide. 18:15 18:30 0.25 0 0 INTRM1 DRILL SFTY T Pre job safety meeting on picking up BHA#15(Open hole cleanout w/ 6-1/8"bit and(2)stabs). Page 38 of 62 Time Logs Date From To Dur S. Deoth E. Depth Phase Code Subcode T Comment 18:30 19:15 0.75 0 106 INTRM1 DRILL PULD T Make up BHA#15:6-1/8"PDC bit, near bit stabilizer, NM flex collar, stabilizer, (2)nm flex drill collars, X-O, (3 jts)4"HWDP,jars, (5 jts)4" HWDP=379.35'. 19:15 19:30 0.25 106 379 INTRM1 DRILL TRIP T Continue trip w/BHA#15 f/106'to total BHA length of 379.35'.X-O, (3 jts)4" HWDP,jars, (5 jts)4" HWDP=379.35'. 19:30 23:00 3.50 379 7,352 INTRM1 DRILL TRIP T Continue trip in w/BHA#15 on 4" drill pipe f/379'to 7352'. Fill pipe every 20 stands. 23:00 23:15 0.25 7,352 7,352 INTRM1 DRILL CIRC T Break circulation @ 7352'. PU wt 127k, SO wt 87k. Circulate 20 bbls. Pumping 3 bpm(35spm) w/650 psi-31%Totco flow out. Pumping 4 bpm(48 spm)w/820 psi-41-42% Totco flow out. Pumping 5 bpm(59 spm)w/1080 psi-40-39%Totco flow out. 23:15 23:30 0.25 7,352 7,914 INTRM1 DRILL TRIP T Continue trip in w/BHA#15 on 4" drill pipe f/7352'to 7914'. 23:30 23:45 0.25 7,914 7,914 INTRM1 DRILL CIRC T Break circulation @ 7914'. PU wt 135k, SO wt 88k. Circulate 20 bbls. Pumping 3 bpm(35spm) w/650 psi-31%Totco flow out. Pumping 4 bpm(48 spm)w/820 psi-41-42% Totco flow out. Pumping 5 bpm(59 spm)w/1080 psi-40-39%Totco flow out. 23:45 00:00 0.25 7,914 8,374 INTRM1 DRILL TRIP T Continue trip in w/BHA#15 on 4" drill pipe f/7914'to 8374'. PU wt 135k, So wt 85k. Calculated displacement 49.3 bbls, actual 40.8 bbls. Note: OA pressure 75 psi @ midnight. 05/17/2011 Trip in hole with BHA#15 T/8,567'MD.Assembly took weight. Hole packing off.Work free and continue reaming in hole slowly.Washed e nd reamed to 8,860' MD. Several instances of hole packing off occurring.At 8,860'MD hole packed off and a$sembly had to be jarred free. Decision made to trip out. Confirmed with town engineer.OA @ 24:00 hrs=500 Psi 00:00 03:00 3.00 8,374 8,456 INTRM1 DRILL TRIP T PJSM(Crew Change)continue tripping in hole @ 8,384'MD break circulation staging pumps up from 34 spm 650 psi to 4 bpm-860 psi. Continue tripping in F/8,384'MD- T/8,567'MD.Took 15k weight. Make up topdrive and break circulation 3 bpm-700 psi.Attempted to wash down with stand taking weight. Worked stand up and racked back stand. Made up topdrive and worked pipe F/8,537'MD-8,479'MD. Rack back 2nd stand make up to topdrive. Worked pipe jarred pipe fee with 190k up and jars firing. Established rotation and circulation @ 8,456' MD Page 39 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 04:00 1.00 8,456 8,454 INTRM1 DRILL CIRC T Establish circulation at 8,456' MD rotary at 80 rpm,stage pumps up from 22 spm-600 psi to 60 spm- 1,250 psi attempt to ream up assembly packed off at 8,450'MD. Slacked off to 8,454' MD and regained circulation and rotation. Staged pumps up to 250 gpm-70 spm- 1,500 psi. 04:00 08:00 4.00 8,454 8,384 INTRM1 DRILL REAM T Back ream pulling slowly F/8,454' MD-T/8,384'MD.Assembly encountered several instances of hole trying to packoff. 70 spm-1,500 psi,45 rpm,torque 5k. 08:00 12:30 4.50 8,384 8,553 INTRM1 DRILL REAM T Pull out of hole on elevators F/8,384' MD-T/8,290'MD. Up wt 140k- 148k.Trip back in on elevators F/8,290'MD-T/8,384'MD.Wash F/8,384' MD-T/8,475'MD. Wash coming up F/8,475'MD-T 8,384' MD. Start washing down F/8,384' MD.Assembly packed off at 8,440' MD worked area to regain circulation. Continued washing down F/8,440' MD-T/8,569' MD.250 gpm-1,450 psi. Prior to making connection backreamed with 250 gpm-1,450 psi. F/8,569' MD-T/8,553'MD when assembly packed off. 12:30 13:00 0.50 8,553 8,290 INTRM1 DRILL JAR T Worked stuck pipe until free 185k up 55k dn.Jars fired on downstroke. Continued jarring down worked 10k torque into string and held torque. in string. 300 psi-400 psi pressure in string.Worked pipe up with 180k and down 55k. Pipe freed with rotation and flow re-established continued to backream F/8,495'MD-T/8,290' MD. Pump rate staged from 1 bpm- 300 psi up to 6.5 bpm-1,700 psi. Rotary staged up from 50 rpm to 120 rpm. 13:00 00:00 11.00 8,290 8,762 INTRM1 DRILL REAM T Ream F/8,290'MD-T/8,552'MD hole began packing off. Picked up above pack off area T/8,479' MD. Establish circulation and rotary staged up from 1 bpm to 6.5 bpm 1,700 psi 120 rpm torq 7k.Work string down to 8,550'MD circulate and clean area. Continue reaming in hole F/8,550' MD to 8,860'MD. Hole packed off after connection. Rack back stand, pick up single to work packoff area. Establish rotary with no pump @ 8,762' MD. OA @ 24:00 hrs =500 psi. Page 40 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/18/2011 24 hr summary Trip out of hole. Cut drill line, service rig.Test lower rams and annular with 2-7/8"test joint 250 psi low-4,000 psi high. Pick up Baker ECP and 32 joints 2-7/8"EUE tubing Cement work string.Trip in hole to TOW(7,434' MD)break circulation pumping at 18 spm 500 psi. Pumped 46 bbl's. Continue in hole to 8,481' MD pick up pup joint and 1 single, Make up cement head position ECP at 8,531' MD. Pump down drillpipe dart pressure up to 550 psi. Shut in pressure. Pressure test cement line to 4,500 psi. Bleed down pressure to 550 psi, open TIW valve pump down dart and inflate ECP per baker rep. 00:00 01:00 1.00 8,762 8,762 INTRM1 DRILL JAR T Work pipe F/8,762'MD-T/8,788'MD packing off. Regain rotation, Not able to circulate. Pull up to 8,762'MD. Lay down single.Worked pipe free. Decision made to come out of hole. (Confirmed decision with town engineer) 01:00 03:00 2.00 8,762 7,352 INTRM1 DRILL TRIP T Pull out of hole F/8,762'MD- T/7,352' MD. No problems 10k overpull was noted @ 8,744'MD and 8,724'MD. 03:00 03:30 0.50 7,352 7,352 INTRM1 DRILL OWFF T Monitor well(Static)Pump dry job. 03:30 07:30 4.00 7,352 379 INTRM1 DRILL TRIP T Trip out of hole F/7,352' MD-T/379' MD 07:30 08:00 0.50 379 0 INTRM1 DRILL PULD T Rack back BHA, Lay down stabilizer _ and bit. 08:00 09:30 1.50 0 0 INTRM1 RIGMNTSLPC T Slip and cut 60'of drill line 09:30 10:00 0.50 0 0 INTRM1 RIGMNT SVRG T Service rig draworks,topdrive and traveling blocks. 10:00 12:15 2.25 0 0 INTRM1 WHDBO BOPE T Test BOPE lower pipe rams 2-7/8"X 5"Variables 250 psi low-4,000 psi high.Test annular 2,500 psi. 5 minute per test all test charted and recorded. 12:15 13:00 0.75 0 0 INTRM1 WHDBO BOPE T Rig down test equipment, Inspect drill line, Set wear ring, Rig up casing equipment. 13:00 15:45 2.75 0 998 INTRM1 CEMEN-PUTB T PJSM, Pick up 32 joints 2-7/8"EUE 6.5#ppf tubing with Baker ECP. Change out handling equipment to 4". Rig down casing equipment. 15:45 19:30 3.75 998 7,430 INTRM1 CEMEN-TRIPT Run 2-7/8"Tubing and Baker ECP in hole on 4"drillpipe F/998' MD- T/7,430' MD(TOW @ 7,434'MD)fill pipe every 15 stands. Calculated displacement 39.2 bbl's Actual displacement 39.5 bbl's 19:30 20:00 0.50 7,430 7,430 INTRM1 CEMEN-CIRC T Break circulation at TOW 18 spm- 500 psi. Pumped 46 bbl's. Up wt 110k dn wt 82k 20:00 21:15 1.25 7,430 8,531 INTRM1 CEMEN-TRIP T Trip in hole F/7,430' MD-T/8,481' MD. Pick up 14.3'pup joint and 1 single joint 31.35'from pipeshed, Make up cement head, Blow down topdrive, Run in hole and position ECP at 8,531'MD. Up wt 124k, do 87k Page 41 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:15 23:00 1.75 8,531 8,531 INTRM1 CEMEN"CIRC T Break circulation @ 1 bpm-500 psi, Pumped 9 bbl's. Drop drop drillpipe dart and pump down at 1.5 bpm- 550 psi-600 psi per Baker rep. Slow rate to 1 bpm bump dart with 1,067 strokes. Pressure up to 550 psi and shut in pressure. 23:00 00:00 1.00 8,531 8,531 INTRM1 CEMEN-PACK T PJSM, Pressure test cement lines 500 psi low 4,500 psi high. Bleed pressure down to 550 psi open TIW valve and pump.3 bbl's mud pushing dart down to seat inflate packer element per Baker rep.OA @ 24:00 =75 psi 35/19/2011 Release from ECP(Packer)Cement per plan, Pull 9 stands slowly, Circulate bottoms up. Load pipe wiper ball, Circulate surface to surface. Monitor well (Static)trip out of hole to 2-7/8"tubing. Lay down tubing. Rig down casing equip. Clear and clean floor. Pick up Bi-center bit drilling assembly.Trip in hole.Tag cement 7,884' MD.Wash down with toolface 90°to 135° right of highside to 7,979' MD. (Soft or contaminated cement) 00:00 01:15 1.25 8,531 8,529 INTRM1 CEMEN CIRC T Release from Baker ECP(Packer) Pick up 2'and circulate bottoms up staging pumps up to 60 spm. 01:15 01:30 0.25 8,529 8,529 INTRM1 CEMEN-SFTY T PJSM with Dowell cementers on pumping cement balanced plug. 01:30 02:45 1.25 8,529 8,529 INTRM1 CEMEN-CMNT T Cement per plan. Pump 9.8 bbl's 13 ppg mudpush II, Pump 35.1 bbfs 17__ ppg cement,pump 1.04 bbl's 13 ppg mudpush II. Displace cement with 11 ppg mud using Dowell to displace. With 40.3 bbl's mud away mudpush at shoe,49.9 bbl's of mud away cement at shoe. Total mud pumped 80.8 bbl's for cement displacement. CIP 02:45 02:45 03:15 0.50 8,529 8,480 INTRM1 CEMEN-PULD T Lay down cement head, single joint 4"drillpipe, 14'pup joint. Flush cement lines. 03:15 04:00 0.75 8,480 7,600 INTRM1 DRILL TRIP T Pull out of cement F/8,500' MD-T/ 7,900' MD pulling slowly. Continue to pull out of hole to 7,600'MD. Up wt _125k 04:00 05:45 1.75 7,600 7,600 INTRM1 DRILL CIRC T Monitor well(Static)Circulate bottoms up at 84 spm-1,450 psi, Shut down load pipe wiper ball. Circulate surface to surface 72 spm- 1,200 psi. 05:45 06:30 0.75 7,600 7,600 INTRM1 DRILL CIRC T Monitor well 20 minutes(Static) Pump dry job, Blow down topdrive and mud lines. 06:30 09:15 2.75 7,600 1,037 INTRM1 DRILL TRIP T Trip out of hole F/7,600' MD-T/ ,1,037' MD. Hole taking correct fill. 09:15 09:45 0.50 1,037 1,037 INTRM1 DRILL OWFF T Monitor well at 2-7/8"tubing(static) Break crossovers, Make up floor safety valve. -- Page 42 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 11:15 1.50 1,037 0 INTRM1 DRILL TRIP T PJSM, Change handling equipment to 2-7/8". Rig up hydraulic tongs, Lay down 32 joints 2-7/8"EUE tubing and ECP running tool. 11:15 14:00 2.75 0 0 INTRM1 DRILL RURD T Rig down hydraulic tongs, Clear and clean floor. Remove excess equipment from floor. Bring small drilling BHA components to rig floor via beaver slide. 14:00 17:00 3.00 0 460 INTRM1 DRILL PULD T PJSM, Make up BHA, Download MWD, Change out nozzle in Bi-center bit. Swap out jars,Trip in hole with remaining BHA to 460'. Shallow pulse test MWD 200 gpm- 800 psi. 17:00 20:30 3.50 460 7,716 INTRM1 DRILL TRIP T Trip in hole F/460' MD-T/7,716' MD. Filled pipe every 20 stands. Calculated displacement 39.75 bbl's, Actual displacement 43.37 bbl's. 20:30 21:45 1.25 7,716 7,770 INTRM1 DRILL CIRC T Circulate staging pumps up to 250 gpm, Bottoms up 11.7 ppg mud with mudpush at surface.At 7,770'with jars out of window obtained PWD baseline varying rotary and flow rates.Take SPR's at 7,805'MD 5,405'TVD MW- 11.0 ppg#1 pump 25 spm-570 psi, 35 spm-810 psi. #2 pump 25 spm-660 psi, 35 spm- 870 psi. 21:45 00:00 2.25 7,770 7,970 INTRM1 DRILL REAM T Ream F/7,770' MD-T/7,884' MD. Tagged soft or contaminated cement at this depth. Continued washing down holding toolface at 90°to 135° right of highside to 7,970' MD. 1�` (Calculated top of cement was 7,900' �J MD) Parameters 220 gpm- 1,700 psi. up wt 138k do wt 87k rot wt 105k. D5/20/2011 Wash down on cement plug with toolface oriented @ 90°- 135° right of highside F/7,974'MD-T/8,024'MD. 8,024' MD confirmed sidetrack point. Drilled F/8,024'MD-T/8,390'MD-5655'TVD. 13.7 actual drilling hrs. 00:00 03:45 3.75 7,970 8,024 INTRM1 DRILL COCF T Wash down with 90°-135° right of highside F/7,974'MD-T/8,024'MD. I� 220 gpm- 1,750 psi, Bit wt 5-20k. J Up wt 140k do wt 85k, rot 105k. ECD- 11.95 ppg. Confirmed sidetrack with survey @ 8,088' MD showing 1.96°change in inclination and 3° change in direction. Sample at shakers showed minimal cement. 03:45 12:00 8.25 8,024 8,072 INTRM1 DRILL DDRL T Drill F/8,024' MD-T/8,072'MD TVD 5,024'AST-5.53/ART-0.0/ADT -5.53. Bit and Jar hrs-5.53. Rot 60 rpm, flow rate 220 gpm-1,750 psi, Torq on 7k off 5k, Up wt 140k, Dn wt 85k, Rot wt 105k. ECD- 11.95 ppg. Page 43 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 8,072 8,390 INTRM1 DRILL DDRL T Drill F/8,072'MD-T/8,390'MD TVD 5,655'AST-3.24/ART-4.93/ADT- 8.17. Bit and Jar hrs-13.7. Rot 80 rpm,flow rate 265 gpm-2,450 psi, Torq on 7.5k off 6k, Up wt 144k, Dn wt 88k, Rot wt 112k. ECD-12.43 ppg. SPR's at 8,087' MD, 5,529' TVD, MW- 10.6 ppg# 1 pump 25 spm-620 psi, 35 spm-790 psi.#2 mudpump 25 spm-650 psi, 35 spm -810 psi 35/21/2011 Drill F/8,390' MD-8,934'MD 5.31 AST/13.86 ART/ADT 19.17 hrs. 00:00 12:00 12.00 8,390 8,725 INTRM1 DRILL DDRL T Drill F/8,390'MD-T/8,725'MD TVD- 5784' AST-1.39/ART-8.67/ADT- 10.06. Bit and Jar hrs-23.76. Rot 80 rpm,flow rate 265 gpm-2,450 psi, Bit wt 10k-15k,Torq on 8k off 7k, Up wt 145k, Dn wt 88k, Rot wt 110k. ECD-12.0 ppg. SPR's at 8,463'MD, 5,684'TVD, MW- 10.6+ppg#1 pump 25 spm-680 psi, 35 spm- 880 psi.#2 mudpump 25 spm-680 psi, 35 spm-850 psi 12:00 00:00 12.00 8,725 8,934 INTRM1 DRILL DDRL T Drill F/8,725' MD-T/8,934'MD TVD- 5863' AST-3.92/ART-5.19/ADT- 9.11. Bit and Jar hrs-32.87. Rot 80 rpm, flow rate 265 gpm-2,450 psi, Bit wt 10k-12k,Torq on 8k off 7k, Up wt 148k, Dn wt 87k, Rot wt 112k. ECD-12.33 ppg. Flow out 38% SPR's at 8,934' MD, 5,863'TVD, MW- 10.6 ppg# 1 pump 25 spm- 630 psi, 35 spm-870 psi.#2 mudpump 25 spm-690 psi, 35 spm -900 psi 05/22/2011 Drill F/8,934' MD to TD at 9,345' MD. Circulate bottoms up, Monitor well slight flow, Circulate and weight up to 11.0 ppg. Monitor well until static 30 minutes for flow to stop. Circulate bottoms up check for gas on flow check.Well static, Pull on elevators F/9345'MD-T/7,901'MD with no difficulties. 00:00 12:00 12.00 8,934 9,259 INTRM1 DRILL DDRL T Drill F/8,934'MD-T/9,259'MD TVD- 6008' AST-3.68/ART-5.76/ADT- 9.44. Bit and Jar hrs-42.31. Rot 80 rpm,flow rate 265 gpm-2,500 psi, Bit wt 3k-I6k,Torq on 8k off 6k, Up wt 155k, Dn wt 88k, Rot wt 113k. ECD-12.44 ppg. Flow out 38% SPR's at 8,934'MD, 5,863'TVD, MW- 10.6 ppg# 1 pump 25 spm- 680 psi, 35 spm-870 psi.#2 mudpump 25 spm-690 psi, 35 spm -900 psi I Page 44 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:15 2.25 9,259 9,345 INTRM1 DRILL DDRL T Drill F/9,259' MD-T/9,345'MD TVD- 6045' AST-0.0/ART-2.32/ADT- 2.32. Bit and Jar hrs-44.54. Rot 80 rpm, flow rate 265 gpm-2,500 psi, Bit wt 3k-8k,Torq on 8k off 7k, Up wt 156k, Dn wt 90k, Rot wt 112k. ECD- 12.40 ppg. Flow out 38% 14:15 14:30 0.25 9,345 9,345 INTRM1 DRILL CIRC T Shoot survey, Circulate and reciprocate for 10 min @ 260 gpm- 40 rpm, Rack back stand. 14:30 15:00 0.50 9,345 9,345 INTRM1 DRILL OWFF T Monitor well,Well breathing,Verified flow diminishing, Pick up 50'and observe fluid level drop, Slack off 50' monitor well until static. 15:00 17:00 2.00 9,345 9,345 INTRM1 DRILL CIRC T Circulate bottoms up, Increase in flow detected, Shut down and monitor well,Well breathing, flow decreasing, reciprocate 3 times with 30'stroke length. Observed well until static. Circulated bottoms up again noted slight flow increase, Used gas detector no gas readings detected. 17:00 19:45 2.75 9,345 9,345 INTRM1 DRILL CIRC T Weight up from 10.6 ppg to 11.0 ppg with 2 full circulations. 19:45 20:15 0.50 9,345 9,345 INTRM1 DRILL OWFF T Monitor well,Well breathing, Monitor for 20 minutes, Pick up 30'observe fluid level drop. Monitor 10 minutes well Static. 20:15 22:30 2.25 9,345 9,250 INTRM1 DRILL CIRC T Circulate bottoms up, Monitor well still breathing, Monitor for 20 minutes still slight flow, Pick up 30'observe fluid drop(Static)Monitor additional 10 minutes. Obtain SPR's Blow down top drive, Rack back 1 stand observing fluid level drop in well 22:30 00:00 1.50 9,250 7,901 INTRM1 DRILL TRIP T Line up on trip tank,Turn on hole fill pump get good mark on trip tank, Pull out on elevators F/9,220'MD- T/7,901'MD. Hole fill incorrect by .85 bbl due to well breathing. OA @ 24:00 hrs=980 psi. 05/23/2011 Trip in hole F/7,340'MD to bottom @ 9,345'MD with no problems, Circulate hole clean(2 bottoms up plus- 5,637 strokes)trip out to window 7,434'MD. Monitor well(Static) Trip out, Lay down BHA, Pull wear bushing, Flush BOP stack, Install wear bushing. Rig up casing equipment. Run 49 joints 5-1/2"casing, Make up hanger fill with pal mix. Pick up 1 stand drillpipe and crossover, Circulate liner volume 3 bpm-600 psi. 00:00 00:30 0.50 7,901 7,340 INTRM1 DRILL TRIP T Pull out of hole on elevators F/7,901' MD-T/7,340'MD. Up wt 145K Dn wt 86k. Monitor well at window. Fluid level dropped 1/2" 00:30 02:00 1.50 7,340 9,345 INTRM1 DRILL TRIP T Trip in hole F/7,340'MD-T/9,345' MD(Bottom) No problems evident. Page 45 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 04:00 2.00 9,345 9,250 INTRM1 DRILL CIRC T Circulate bottoms up staging pumps up slowly(Reached 60 spm at bottoms up) ECD 12.59. Checked LEL level at bottoms up with hand held monitor. LEL level peaked at 28% Flow increase shown on flow out percentage up from 40%to 48%. No large increase of cuttings visible at shakers. Continue to circulate at surface to surface flow increase from 41%to 50%. Continue to circulate. No gain in mud volume. Initial circulating rate 160 gpm-1,550 psi. ECD's 12.59 ppg. Final circulating rate 211 gpm-2,050 psi ECD's 12.57 ppg.Total strokes pumped 5,637. Rack back stand prior to monitoring well. 04:00 04:30 0.50 9,250 9,250 INTRM1 DRILL OWFF T Monitor well until static. Fluid dropped below flow line 1" 04:30 06:30 2.00 9,250 7,340 INTRM1 DRILL TRIP T Trip out of hole F/9,250'MD- T/7,340'MD(Window)With no problems. 06:30 07:30 1.00 7,340 7,340 INTRM1 DRILL OWFF T Monitor well at window.Well static with fluid dropping slightly 07:30 15:00 7.50 7,340 0 INTRM1 DRILL TRIP T Trip out from window 7,340'MD- T/406' MD-BHA. Lay down BHA. Calculated hole fill 56.64 bbl's actual hole fill 57 bbl's. 15:00 16:15 1.25 0 0 INTRM1 DRILL RURD T Clear and clean floor. Pull wear bushing, Pick up stack washer and flush stack, Lay down stack washer, Install wear bushing. 16:15 00:00 7.75 0 2,000 INTRM1 CASING RUNL T Rig up casing equipment, PJSM, Run in hole with 5-1/2" 15.5 ppf, L-80 Hydrill 511 casing per detail. Check float equipment(OK)run 49 joints 5-1/2"casing filling every 10 joints. Make up hanger and fill with pal-mix, Wait 30 minutes for gel to set. Pick up 1 stand drillpipe with crossover. Break circulation and pump liner volume @ 3.5 bpm 650 psi,Well taking fluid rate slowed to 3 bpm. Shut down pump, blow down topdrive. 05/24/2011 Circulate liner volume, Run 5-1/2"liner T/7,410' MD. Break circulation, Run liner through window at 7,434' MD. Run liner to 8,545'MD began taking weight.Worked liner down to 8,950'MD.Worked liner from 8,905' MD- 8,950'MD with great difficulty. Could not get liner past 8,950'MD. Racked back stand attempted circulation with out success. Decision made to pull liner out of hole.Worked liner to window encountering overpull and swabbing. Pumped at 1/2 bpm to offset swabbing effect. Page 46 01'62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 2,000 2,600 INTRM1 DRILL RUNL T Circulated liner volume with well taking fluid.Well began giving back mud.20 bbl's lost while pumping liner volume. Monitored flow until flow declined. Ran 4 stands in hole. Monitored and well breathing. Circulated 11.0 ppg mud in hole with returning mud at 10.8 ppg. Monitored well for 30 minutes flow back gained 12.5 bbl's. Flow diminished with very slight return of fluid. Decision made to continue in hole monitoring pit volume closely. (Apparent well bore breathing) 02:00 12:00 10.00 2,600 7,410 INTRM1 DRILL RUNL T Continue running 5-1/2"Liner in hole on 4"drillpipe F/2,600'MD-7,410' MD. Filling every stand and topping off every 5 stands using fill up hose. Up wt 125k, Dn wt 82k.Actual displacement for trip 32 bbl's calculated displacement 29.7 bbl's. 12:00 12:45 0.75 7,410 7,410 INTRM1 DRILL CIRC T Break circulation above window @ 7,410'MD. Flow rate 1 bpm-500 psi. pumped 25 bbl's. Shut down bleed off pressure taking returns to trip tank. 2.06 bbl loss 12:45 16:45 4.00 7,410 8,905 INTRM1 DRILL RUNL T Run 5-1/2"liner in hole F/7,410'MD- 8,255' MD. Make up topdrive and break circulation @ 1 bpm-550 psi. Pumped 10 bbl's shut down pump, take returns to trip tank. 2.6 bbl loss. Continue in hole with liner F/8,255' MD-8,545'MD Liner took 10k weight at this depth.Worked area with liner taking 20k weight down and 15k overpull.Worked area until satisfied. Continued working liner down to 8,905' MD. Liner was worked down taking weight and reciprocated without pump until reaching 8,905' MD. 16:45 20:30 3.75 8,905 8,905 INTRM1 DRILL RUNL T Worked liner attempting to get past 8,905' MD without success. Slacked off to neutral weight 35k picked up pulling 75k overpull. (Up weight 165k pulled 240k)discussed options with town engineer and decision to rack back stand and attempt to circulate. Page 47 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 22:00 1.50 8,905 8,730 INTRM1 DRILL RUNL T Rack back stand, Make up topdrive and attempt to circulate at 1/2 bpm. No returns pressure built to 1,000 psi. Bled off pressure attempted to work casing down F/8,822'MD without success. Pulled up in 30' intervals then attempted to work casing down. Could not get casing down. Continued attempts were unsuccessful. Discusion with town personnel with decision made to trip out of hole with 5-1/2"liner. Liner at 8,730' MD. 22:00 00:00 2.00 8,730 7,879 INTRM1 DRILL TRIP T Attempted to pull out of hole without pumping. Hole swabbing. Pumped at 1/2 bpm while pulling at 25 fpm to counter hole swabbing. Pulling tight with 50k overpull between 8,730' MD -8,575'MD.Areas worked until overpull minimzed(25k)8,575'pulled 225k worked string down, pulled 250k worked string down. Pulled to 275k before freeing string. (Overpull 110k)Casing pulled F/8,575'MD- T/7,879'with overpull not over 20k. Calculated fill for trip 4.86 bbl's actual fill 3.82 bbl's. Hole took 1.04 bbl's. 35/25/2011 Pull out of hole with 5-1/2"liner to window @ 7,434' MD pumping at 1/2 bpm due to swabbing. Monitor well with liner in window @ 7,410'MD 1/2 hr well static with fluid level dropping slightly. Pull F/7,410'MD-6,937' MD on elevators hole swabbing, Pump out of hole to 2,200'MD pumping 6 spm-150 psi, pulling speed 25 fpm. Monitor well, Lay down 5-1/2"liner.All 5-1/2 liner in good condition, Hanger OK silver bullet shoe OK. Clear and clean floor, Cut drill line, Service rig, Remove excess tubulars F/pipeshed, Pick up Baker ECP and 25 joints 2-7/8"EUE tubing. 00:00 00:30 0.50 7,879 7,410 INTRM1 DRILL TRIP T PJSM,Trip out of hole with 5-1/2" liner F/7,879' MD-T/7,410'MD. 00:30 01:00 0.50 7,410 7,410 INTRM1 DRILL OWFF T Monitor well-Static with fluid dropping slightly. 01:00 02:00 1.00 7,410 6,937 INTRM1 DRILL TRIP T Trip out F/7,410'MD-T/6,937' MD pulling on elevators slowly to avoid swabbing. Hole still swabbing gained 1 bbl. 02:00 09:30 7.50 6,937 2,200 INTRM1 DRILL TRIP T Trip out F/6,937'MD-T/2,200'MD. pumping at 6 spm- 150 psi, Pulling speed 25 fpm.To offset swabbing hole. 09:30 09:45 0.25 2,200 2,200 INTRM1 DRILL OWFF T Monitor well(Static) 09:45 10:45 1.00 2,200 2,134 INTRM1 DRILL TRIP T Pull last stand drillpipe and rack back, 2,134'MD. Rig up double stack hydraulic tongs, Pull hanger to floor and lay down. Change out elevators for laying down 5-1/2"liner. Page 48 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:45 15:00 4.25 2,134 0 INTRM1 DRILL PULD T Lay down 5-1/2"liner. Layed down 4 joints before hole began taking proper fill. Pulled out to Baker lok joints heated connections with torch to break out. Inspect silver bullet shoe found no damage. Calculated hole fill 11.76 bbl's actual hole fill 11.75 bbl's. 15:00 16:30 1.50 0 0 INTRM1 DRILL RURD T Rig down casing equipment, Clear and clean floor. Sim-op strap 2-7/8" EUE tubing in pipeshed(35 joints) 16:30 17:30 1.00 0 0 INTRM1 RIGMNTSLPC T PJSM, Slip and cut 15 wraps 98'of drill line. Service draworks, brakes and linkage, Service and inspect top drive. 17:30 19:00 1.50 0 0 INTRM1 DRILL RURD T PJSM, Change out saver sub on topdrive. 19:00 21:30 2.50 0 0 INTRM1 DRILL RURD T Remove excess tubulars from pipeshed, Stage 2-7/8"EUE tubing cement work string in position in pipeshed. Rig up 2-7/8"running tools. 21:30 00:00 2.50 0 782 INTRM1 DRILL PULD T Make up Baker ECP(expandable casing packer)to 2-7/8"EUE tubing, Picked up 25 joints 2-7/8"EUE tubing(782') 35/26/2011 Pick up remaining 2-7/8 tubing cement work string, Make up crossovers, Run in hole on 4"drillpipe, Fill pipe every 20 stands, Ran in hole slow to avoid pushing away fluid(mud)Set Baker ECP at 8,354' MD, Pump down dart and latch up, Dowell pump dart down and inflate packer, Release from ECP, Circulate bottoms up, Cement pump 10 bbl's 13.0 ppg mudpush, 35 bbl's 17.0 ppg cement, 1 bbl 13.0 ppg mudpush, Displace using Dowell 74 bbl's mud, Pull 9 stands to 7,475'MD slowly pulling pipe out of cement plug, Circulate to clean drill string, pump dry job,Trip out, Lay down tubing, Rig up and Test BOPE.Test waived by AOGCC rep Bob Noble 2-26-2011 @ 21:30. 00:00 01:00 1.00 782 998 INTRM1 DRILL PULD T PJSM, Crew change, Pick up fi remaining 7 joints 2-7/8"EUE tubing cement work string. Rig down double stack hydraulic tongs, Make up crossovers, latch stand from derrick, Make up topdrive, Fill pipe, break circulation 24 spm-175 psi. 01:00 07:00 6.00 998 8,357 INTRM1 DRILL TRIP T RIH with ECP on 2-7/8"tubing stinger and 4"drill pipe. Fill every 20 stands. RIH to 8357' MD. P/U = 135k,s/O=75K. Trip displacement 48.45 bbl act berus 44.47 bbl calc. 07:00 09:15 2.25 8,357 8,357 INTRM1 DRILL CIRC T Drop setting dart and pump down at 14 spm @ 500 psi. Dart seated at 1298 stx. 09:15 10:45 1.50 8,357 8,351 INTRM1 CEMEN-PACK T Rig up cement lines and test to 4300 psi. Inflate ECP per Baker. Release ,from ECP w/3000 psi 10:45 11:30 0.75 8,351 8,351 INTRM1 CEMEN CIRC T Circulate bottoms up at 8351 at 4 bpm @ 1000 psi. Hold PJSM on ,cementing Page 49 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:30 1.00 8,351 8,351 INTRM1 CEMEN-CMNT T Batch and pump 10.1 bbl's 13.0 ppg Mudpush II, Batch and pump 36 bbl's 17.0 ppg Type G cement, Pump 1 bbl 13.0 mudpush II, Displace with dowell pumping 74 bbl's 11.0 ppg mud. 12:30 13:30 1.00 8,351 7,475 INTRM1 CEMEN-TRIPT Rig down cement line, Line up on trip tank, Pull out of hole at 2 min per stand F/8,351'MD-T/7,475' MD. Pulled 2-7/8"EUE tubing clear of cement. (9 stands) 13:30 15:30 2.00 7,475 7,475 INTRM1 CEMEN-CIRC T Install wiper ball into topdrive quill and make up top drive to string. Pump surface to surface volume plus additional bottoms up at 5 bpm- 1,010 psi. 15:30 16:00 0.50 7,475 7,414 INTRM1 CEMEN-OWFF T Monitor well(Static)pick up 40' check for swabbing, Fluid level dropped, Pump 20 bbl 12.3 ppg dry job, Blow down topdrive, Line up on trip tank 16:00 19:00 3.00 7,414 998 INTRM1 DRILL TRIP T Trip out of hole on elevators F/7,414' MD to 2-7/8"EUE tubing(1,004') Break out crossovers, Make up floor safety valve. Kick while tripping drill 2 minute response time. Calculated hole fill 36.72 bbl's Actual hole fill 38 bbl's 19:00 21:00 2.00 998 0 INTRM1 DRILL PULD T Rig up double stack hydraulic tongs. Lay down 2-7/8"EUE tubing cement work string 21:00 22:00 1.00 0 0 INTRM1 DRILL RURD T Rig down double stacked hydraulic tongs and 2-7/8 tubing elevators, Clear un-necessary equipment from floor. Clean rig floor 22:00 22:45 0.75 0 0 INTRM1 WHDBO BOPE T Pull wear bushing, Rig up BOPE test equipment. 22:45 00:00 1.25 0 0 INTRM1 WHDBO BOPE T PJSM, Test BOPE 250 psi low- 4,000 psi high.Test 3-1/2"X 6" variable top pipe rams with 4"test joint,Test choke valves 1,12,13,14. Manual kill valve,Test Upper IBOP, HCR Kill, Choke valves 9-11.All tests 5 minute low 5 minute high, Tests recorded and charted.Witness of BOPE waved by AOGCC rep Bob Noble 5-26-2011 @ 21:30 05/27/2011 Test BOPE, Make up drilling bha and rack back in derrick, Run in hole with bullnose on 4"drillpipe, Circulate and condition lowering mud weight F/11.0 ppg-T/10.5 ppg,Trip out to pick up BHA. Page 50 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 05:45 5.75 0 0 INTRM1 WHDBO BOPE T BOPE test, 250 psi low-4,000 psi high test recorded and charted.test Lower IBOP, Choke valves#5,8,10, Test Dart valve, Choke valves#4,6,7, Test floor valve, Choke valve#2.Test manual choke, HCR kill,Test annular 250 psi low-2,500 psi high, Accumaulator test system pressure 3,000 psi pressure after closed 1,800 psi,200 psi attained 34 seconds full pressure attained 193 seconds. 5 bottle nitrogen average 2,100 psi. Test upper and lower rams, annular with 4-1/2"and 3-1/2"test joints. Test blind rams and choke valve#2. 05:45 07:00 1.25 0 0 INTRM1 WHDBO BOPE T Pull test plug, Rig down test equipment, Blow down choke, Install wear bushing, Change out 2 bad joints of 4"drillpipe. 07:00 10:30 3.50 0 300 INTRM1 DRILL PULD T Make up directional BHA, Orient motor/MWD,Upload MWD data, Pick up remaining BHA, Shallow pulse test. Blow down top drive. 10:30 12:00 1.50 300 300 INTRM1 RIGMNT SVRG T Kuparuk bridge out due to water over road.Waiting on mud products, Service rig tools and equipment. 12:00 13:15 1.25 300 0 INTRM1 DRILL TRIP T Pull BHA out of hole, Drain motor, Run back in fill fill water, Pull out drain and rack back BHA in derrick. 13:15 17:30 4.25 0 7,433 INTRM1 DRILL TRIP T Make up mule shoe and run in hole with 4"drillpipe T/7,433'MD. Calculated displacement 42.66 bbl's Actual displacement 42.5 bbl's 17:30 20:45 3.25 7,433 7,433 INTRM1 DRILL CIRC T Circulate and condition mud, Lower mud weight using centrifuge F/11.0 ppg-T/10.5 ppg. Pumping at 5 bpm -900 psi. Rotating at 20 rpm while reciprocating string. Sim-ops stage new mud pump manifold parts in pump room and prep for changing out manifold. 20:45 21:15 0.50 7,433 7,346 INTRM1 DRILL OWFF T Rack back stand, Install floor safety valve, Pump across top of hole, Monitor well with trip tank 21:15 00:00 2.75 7,346 2,538 INTRM1 DRILL TRIP T PJSM,Trip out of hole on elevators F/7,346' MD-T/2,538'MD. Hole took correct fill. 35/28/2011 Completed trip out of hole, Picked up BHA, Tripped to window,Washed and reamed once past bottom of window, Hole packed off,Worked pipe free. Continued having problems with hole packing off.Worked area until good circulation and rotation at low rpm acquired.Slide assembly to kick off cement plug. 00:00 01:00 1.00 2,538 0 INTRM1 DRILL TRIP T Trip out of hole F/2,538' MD to surface. Calculated hole fill 42 bbl's Actual hole fill 43.75 bbl's 01:00 02:30 1.50 0 457 INTRM1 DRILL PULD T PJSM, Pick up BHA racked in derrick, Upload MWD, Pick up remaining BHA. Pulse test(good) Page 51 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 05:45 3.25 457 7,434 INTRM1 DRILL TRIP T Trip in hole with drilling assembly to TOW @ 7,434'MD. Pipe filled every 20 stands. SPR's taken# 1 mudpump at 7,334'MD. SPR's=# 1 pump 7,334'MD 5,166 TVD 10.5 ppg mud wt.25 spm-680 psi, 35 spm- 900 psi. Up wt 127k down wt 83k. 05:45 08:00 2.25 7,434 7,503 INTRM1 DRILL REAM T Wash and ream F/7,466'MD. Hole packed off at 7,503'MD with 200 gpm-1,550 psi. Pipe hung up at this depth. Regained rotary and flow. Worked area until unrestricted pipe movement. 08:00 11:30 3.50 7,503 7,645 INTRM1 DRILL REAM T Continue to wash and ream F/7,503' MD-T/7,645'MD with 40 rpm, 70 spm-2,250 psi, 5k torque. packing off problems re-occurring.Area worked slowly. Worked string down to 7,645'MD. 11:30 15:15 3.75 7,645 7,400 INTRM1 DRILL REAM T Ream @ 7,645' MD 6 bpm-2,400 psi hole packed off,Worked pipe free attempted to ream ahead with hole still packing off. Reamed and washed down through cement to 7,660'MD again hole packed off.Worked pipe jarring to free string. Established circulation and rotary attempted to continue reaming with hole packing off again at 7,705' MD.Worked pipe repeatedly until able to rack back stand. Picked up single continued to work string until free, Established circulation. Reciprocated string, Layed down single and pulled BHA into window @ 7,434' MD.With string above window circualtion undertaken. 15:15 16:15 1.00 7,400 7,400 INTRM1 DRILL CIRC T Circulate bottoms up X 2 at 6 bpm- 2,750 psi.This was 500 psi over normal off bottom pressure. Pressure dropped back to 2,250 psi after 1-1/2 bottoms up. 16:15 18:30 2.25 7,400 7,700 INTRM1 DRILL REAM T Wash from bottom of window 7,447' MD to 7,625' MD at 6 bpm-2,250 psi.Assembly took weight, Picked up and initiated rotary at 30 rpm, Reamed down F/7,600'MD-7,700' MD at this depth rotary stalled and packing off occurring. SHut down pump, released torque and worked string free.Worked pipe with 6 bpm- 2,250 psi and 30 rpm down to 7,707' MD. Reciprocated entire stand length,Took survey, Orient toolface to 45° LHS. Made connection. Page 52 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 20:30 2.00 7,605 7,605 INTRM1 DRILL CIRC T Attempt to slide with toolface 45° left of highside. Motor stalling with light 5k bit weight. Rack back stand, pump hi-vis sweep while rotating and reciprocating. No increase of cuttings seen at shakers on return of sweep. 20:30 21:45 1.25 7,605 7,707 INTRM1 DRILL TRIP T Pull to window from 7,707' MD pumping 2 bpm-650 psi. Shut down pump and pull through window,Took 5k overpull at window.Trip back to 7,707"MD with no problems. Break circulation, Orient toolface to 45° left of highside. Shut down pumps, Make connection. 21:45 00:00 2.25 7,707 7,732 INTRM1 DRILL DDRL T With toolface set @ 45° left of highside wash F/7,707'MD-7,724' MD. Continue sliding to sidetrack off cement plug F/7,724' MD-T/7,732' MD. Sidetrack not confirmed. �f Sidetrack initiated at 7,724' MD.6 bpm-2,450 psi, up wt 145k down wt 85k,flow percentage out 39%. ECD's 12.21 ppg 05/29/2011 Drill F/7,732'MD-T/8,215'MD with 250 gpm-2,750 psi. Rotary 60-80 rpm, Bit wt 5-15k.Torque on 7k off 6k. 00:00 12:00 12.00 7,732 7,899 INTRM1 DRILL DDRL T Drill F/7,732'MD-T/7,899' MD 5447' TVD. 250 gpm-2,500 psi, 60 rpm, Bit wt 5-10k,Torque on 7k off 6k, ECD's 12.16 ppg Flow out percentage 39% Up wt 145k Down wt 84k Rot wt 109k.ADT 9.28 AST 3.18 ART 6.10. Jar hrs 53.82 Bit hrs 9.28. SPR's @ 7,893'MD 5,443'TVD 10.5 ppg mw#1 pump 25 spm-620 psi 35 spm 890 psi 12:00 00:00 12.00 7,899 8,215 INTRM1 DRILL DDRL T Drill F/7,899'MD-T/8,8215'MD 5486'TVD. 252 gpm-2,750 psi, 80 rpm, Bit wt 10-15k,Torque on 7k off 6k, ECD's 12.44 ppg Flow out percentage 39%Up wt 145k Down wt 87k Rot wt 111k.ADT 9.37 AST 1.54 ART 7.83. Jar hrs 63.19 Bit hrs 18.65. SPR's @ 7,989' MD 5,486' TVD 10.5 ppg mw# 1 pump 25 spm -620 psi 35 spm 860 psi.#2 pump 25 spm-680 psi 35 spm 860 psi. 05/30/2011 Drill F/8,215' MD-T/8,929 MD with 250 gpm-2,750 psi. Rotary 60-80 rpm, Bit wt 10-17k.Torque on 7k off 6.5k. C � - --- ---- ---- �- Page 53 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 8,215 8,590 INTRM1 DRILL DDRL T Drill F/8,215'MD-T/8,590'MD 5741' TVD.249 gpm-2,500 psi, 80 rpm, Bit wt 10-15k,Torque on 7k off 5k, ECD's 12.39 ppg Flow out percentage 39% Up wt 148k Down wt 89k Rot wt 113k.ADT 9.96 AST 1.68 ART 8.28 Jar hrs 73.15 Bit hrs 28.61. SPR's @ 8,551'MD 5,726' TVD 10.5 ppg mw# 1 pump 25 spm -680 psi 35 spm 910 psi.#2 pump 25 spm-710 psi 35 spm 960 psi. 12:00 00:00 12.00 8,590 8,929 INTRM1 DRILL DDRL T Drill F/8,590' MD-T/8,929' MD 5879' TVD. 247 gpm-2,900 psi, 80 rpm, Bit wt 12-17k,Torque on 7k off 6.5k, ECD's 12.43 ppg Flow out percentage 39% Up wt 150k Down wt 91k Rot wt 114k.ADT 10.15 AST 1.24 ART 8.91 Jar hrs 83.30 Bit hrs 38.76. SPR's @ 8,833' MD 5,846' TVD 10.5 ppg mw# 1 pump 25 spm -680 psi 35 spm 940 psi.#2 pump 25 spm-700 psi 35 spm 980 psi. 35/31/2011 Drill 6-1/8"hole from 8,929' MD-to TD @ 9441'MD(6097.7'TVD), circulate 3 bottom's up to clean hole, weight up f/10.5 ppg to 11 ppg. 00:00 12:00 12.00 8,929 9,240 INTRM1 DRILL DDRL T Drill F/8,929'MD-T/9240'MD(6010' TVD). Pumping 249 gpm-2650 psi, 80 rpm, Bit wt 10-15k,Torque on 7.5k off 6k, ECD's 12.39 ppg Flow out percentage 39%. Up wt 155k Down wt 91k Rot wt 115k.ADT 9.44 AST.64 ART 8.80 Jar hrs 92.74 Bit hrs 48.2. SPR's @ 9213' MD 5,999' TVD 10.5 ppg mw# 1 pump 25 spm -650 psi 35 spm 890 psi.#2 pump 25 spm-670 psi 35 spm 940 psi. 12:00 20:30 8.50 9,240 9,441 INTRM1 DRILL DDRL T Drill F/9240' MD-T/94410' MD (6097.7'TVD). Pumping 249 gpm- 3000 psi, 80 rpm, Bit wt 10-15k, Torque on 7.0k off 7k, ECD's 12.26 ppg Flow out percentage 39%. Up wt 157k Down wt 91k Rot wt 117k. ADT 7.89 AST 0 ART 7.89 Jar hrs 100.63 Bit hrs 56.09. SPR's @ 9441' MD 6097'TVD 10.5 ppg mw#1 pump 25 spm-680 psi 35 spm 900 psi.#2 pump 25 spm-690 psi 35 spm 990 psi. 20:30 22:30 2.00 9,441 9,406 INTRM1 DRILL CIRC T Circulate 3 bottom's up, pumping 250 gpm w/2650 psi, ECD's 12.26 ppg. Reciprocate and rotate 80 rpm w/7k ft lbs of torque.Work pipe f/9441'to 9406'. Page 54 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 9,406 9,311 INTRM1 DRILL CIRC T Increase mud weight f/10.5 ppg to 11 ppg. Pumping 250 gpm w/2675 psi. Reciprocate and rotate f/9406' to 9311'. Rotate 80 rpm w/7k ft lbs of torque. Note: OA pressure @ midnight 1500 psi. 06/01/2011 Continue to weight up f/11 ppg to 12 ppg, monitor well-slight flow-breathing,trip out f/9217'to 7425'(pulling some, pumping some out), circulate bottom's up,trip f/7425'to 3745'-pulling some on elevators, pumping some out due to incorrect hole fill. 00:00 01:30 1.50 9,311 9,120 INTRM1 DRILL CIRC T Increase mud weight f/10.5 ppg to 11 ppg. Pumping 250 gpm w/2700 psi. Reciprocate and rotate f/9311' to 9120'. Rotate 80 rpm w/7k ft lbs of torque. 01:30 01:45 0.25 9,120 9,120 INTRM1 DRILL OWFF T Monitorwell-slightflow-breathing. 01:45 02:00 0.25 9,120 9,441 INTRM1 DRILL TRIP T Trip in the hole f/9120'to 9441'. No problems. 02:00 06:00 4.00 9,441 9,217 INTRM1 DRILL CIRC T Continue to weight up f/11 ppg to 11.6 ppg. Reducing pump rate as mud weight increases to mantain maximun of 13 ppg ECD's. Rotate 80 rpm w/7k ft lbs of torque. While increasing weight f/11 to 11.3 ppg: pumping 65 spm(230 gpm)w/ 2500 psi-39%flow out,60 spm(213 gpm)w/2230 psi-39%flow out. While increasing weight f/11.3 to 11.6 ppg: pumping 55 spm(195 gpm)w/2000 psi-38 to 39%flow out, 50 spm(177 gpm)w/1730 psi-38 to 39%flow out, with 11.6 ppg mud:45 spm(159 gpm)w/1540 psi-38%flow out,40 spm(145 gpm)w/1400 psi-38%flow out. PU wt 105k, SO wt 90k. 06:00 06:15 0.25 9,217 9,217 INTRM1 DRILL OWFF T Monitor well-slight flow-breathing. 06:15 06:30 0.25 9,217 9,441 INTRM1 DRILL TRIP T Trip in the hole f/9217'to 9441'. No problems. 06:30 10:00 3.50 9,441 9,217 INTRM1 DRILL CIRC T Continue to weight up f/11.6 ppg to 12 ppg. Reducing pump rate as mud weight increases to mantain maximun of 13 ppg ECD's. Note: No PWD detection at this pump rate. Rotate 80 rpm w/7k ft lbs of torque. While increasing weight from 11.6 ppg to 12 ppg mud: 35 spm(124 gpm)w/1180 psi-38%flow out, 30 spm(107 gpm)w/1050 psi-34-36% flow out. PU wt 105k, SO wt 90k. 10:00 11:00 1.00 9,217 9,217 INTRM1 DRILL OWFF T Monitor well on trip tank-slight flow-decreasing—breathing. 11:00 12:00 1.00 9,217 9,027 INTRM1 DRILL TRIP T Pull out of the hole on elevators f/ 9217'to 9027'. PU wt 155k, SO wt 85k. Page 55 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:15 1.25 9,027 8,272 INTRM1 DRILL TRIP T Crew change, PJSM. Continue to pull out of the hole on elevators f/ 9027'to 8552'. Did not get correct fill due to breathing. Pull a stand f/8552' to 8457'-had good fill. Shut down trip tank pump. Monitor well-static. Continue to pull out of hole. Pulling tight.Worked string to 8272'.. Did not get correct fill-swabbing. 13:15 15:15 2.00 8,272 7,519 INTRM1 DRILL TRIP T Pump out of hte hole, pumping 1 bpm w/500 psi. Pulling 15'/minute f/ 8272'to 7519'. 15:15 15:30 0.25 7,519 7,425 INTRM1 DRILL TRIP T Pull stand#75 without pumpsing. Pull BHA through window to 7425'. Rack back in the derrick. Observed fluid drop in well. Monitor well-static. 15:30 17:30 2.00 7,425 7,425 INTRM1 DRILL CIRC T Circulate bottom's up @ 7425'. Stagged pumps up to 2 bpm w/800 psi. Rotate 2 rpm while reciprocating string. 17:30 17:45 0.25 7,425 7,331 INTRM1 DRILL OWFF T Pull a stand f/7425'to 7331', observe fluid drop in stack. Rack back stand. Monitor well-static. 17:45 20:30 2.75 7,331 5,820 INTRM1 DRILL TRIP T Mud out of balance-pump out of the hole f/7331'to 6482'. Pumping 1 bpm w/500 psi. Pulling 25'/minute. Monitor well-static.Attempt to pull out of the hole on elevators f/6482'to 5820', not taking correct fill. 20:30 20:45 0.25 5,820 5,820 INTRM1 DRILL OWFF T Monitorwell-static. 20:45 22:45 2.00 5,820 4,218 INTRM1 DRILL TRIP T Continue to pump out of the hole f/ 5820'to 4218'. Pumping 1 bpm w/ 400 psi. Pulling 25'/minute. 22:45 23:15 0.50 4,218 4,218 INTRM1 DRILL OWFF T PU 40', observe fluid drop in stack. RIH, monitor well-static. 23:15 00:00 0.75 4,218 3,745 INTRM1 DRILL TRIP T Pull out of the hole on elevators f/ 4218'to 3745', monitoring well on the trip tank. PU wt 81k, SO wt 69k. Note:Calculated displacement f/trip 32.4 bbls, actual 31.75 bbls-due to breathing. Note: OA pressure @ midnight was 440 psi. 36/02/2011 Con't to POOH on elevators from 3745', lay down Sperry Sun BHA, clean floor, flush BOP stack, RU to run 4-1/2" 12.6 ppf L-80 SL-HT liner, PJSM, Run liner to 2221', Run liner on 4"drill pipe to the window @ 7434' , CBU, con't to run liner in the open hole to 9424'. 00:00 01:15 1.25 3,745 454 INTRM1 DRILL TRIP T Pull out of the hole on elevators f/ 3745'to 454', monitoring well on the trip tank. 01:15 01:30 0.25 454 454 INTRM1 DRILL OWFF T Monitorwell-static. 01:30 01:45 0.25 454 175 INTRM1 DRILL TRIP T Stand back 3 stands of 4"HWDP. Note: Retrieved 2.40"rabbit-landed on the jars. 01:45 02:30 0.75 175 82 INTRM1 DRILL PULD T Lay down 3 NM flex drill collars. Page 56 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:00 0.50 82 82 INTRM1 DRILL PULD T Download Sperry Sun MWD. 03:00 04:00 1.00 82 0 INTRM1 DRILL PULD T Break bit, Lay down BHA. Calculated displacement 28.01 bbls, actual 27.5 bbls 04:00 04:30 0.50 0 0 INTRM1 DRILL PULD T Clean and clear rig floor. 04:30 05:15 0.75 0 0 INTRM1 DRILL CIRC T Make up stack washing tool to wash BOP stack. Pumping 640 gpm w/ 150 psi, roate 2 rpm while picking up slow. Make two passes from wear bushing to top of BOP stack. Blow down the top drive. 05:15 07:00 1.75 0 0 INTRM1 CASING RURD T Rig up to run 4-1/2" 12.6 ppf, L-80 SL-HT liner. 07:00 07:30 0.50 0 0 INTRM1 CASING SFTY T Pre job safety meeting on running liner. 07:30 12:00 4.50 0 1,891 INTRM1 CASING RUNL T Make up 4-1/2"liner per detail. Baker lock to the pin of first joint of SLHT liner(pin end of joint screwed into crossover pup above landing collar). Torque 4-1/2"BTC w/torque rings to 5000 ft lbs.Torque 4-1/2"Hyd 521 to 4900 ft lbs. 12:00 12:15 0.25 1,891 1,891 INTRM1 CASING SFTY T Pre job safety meeting, crew change. 12:15 13:00 0.75 1,891 2,163 INTRM1 CASING RUNL T Continue to PU/MU/RIH w/4-1/2" 12.6 ppf L-80 SL-HT liner f/1891'to 2163'(shoe track+67 joints of 4-1/2" 12.6 ppf L-80 SL-HT liner in the hole). 13:00 13:15 0.25 2,163 2,221 INTRM1 CASING RUNL T Make up Baker liner hanger assembly to 2221'. Check slips, pins and element.Torque 5" BTC f/TKC to 7700 ft lbs. 13:15 13:45 0.50 2,221 2,221 INTRM1 CASING RUNL T Mix and install Pal mix in liner top. Allow to set 30 minutes 13:45 14:00 0.25 2,221 2,221 INTRM1 CASING RUNL T Make up a single of 4"drill pipe on top of liner running tool. 14:00 14:30 0.50 2,221 2,221 INTRM1 CASING CIRC T Make a top drive connection. Circulate the liner volume, pumping 4 bpm w/430 psi. Circulate 34 bbls. 14:30 19:15 4.75 2,221 7,430 INTRM1 CASING RUNL T Run liner in the hole on 4"drill pipe f/ the derrick f/2221'to 7430'. Fill every 5 stands w/fillup line. Obtain PU and SO wt's every 10 stands. RIH with liner @ 60'/minutes. Note: PU wt 118k, SO wt 80k. Page 57 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:15 21:15 2.00 7,430 7,430 INTRM1 CASING CIRC T Circulate bottom's up. Stage pumps up f/1 bpm w/425 psi.After 30 bbls increase rate to 1.5 bpm w/500 psi-8 to 11%Totco flow out.After a total of 50 bbls pumped increase rate to 2 bpm w/550 psi-15 to 17%Totco flow out.After pumping 93 bbls go to 2.5 bpm w/620 psi-initial 25%Totco flow out, final 33%Totco flow out. Pumped a total of 195 bbls; Bottom's up calculated 160 bbls. PU wt 115k, SO wt 78k, Rot wt 96k. Rotate 40 rpm w/4.5k ft lbs of torque. 21:15 00:00 2.75 7,430 9,424 INTRM1 CASING RUNL T Continue to run liner on 4"drill pipe f/ 7430'to 9424'. Running speed 30'-50'/minute. Obtain PU and SO wt's every 5 stands in the open hole. Rotating weight's every 10 stands. Fill every 5 stands. Hole took 10k @ these depths, picked up and went through-OK. : 8060', 8163', 8386', 8470', 8541', 8840', 9410'. 76 stands of 4"drill pipe in the hole. Displacement f/trip 39.5 bbls, calculated 40.5 bbls. Note: OA pressure 220 psi at midnight. 36/03/2011 Make up Baker cement head and a single of 4"drill pipe,circulate and condition mud f/cement job,_PJSM, cement 4-1/2"liner,set hanger,set packer,test to 1000 psi, PU, circ, cut drilling line, POOH w/liner running tool, Rig up/Run 4-1/2"liner. 00:00 00:30 0.50 9,424 9,441 INTRM1 CASING RUNL P Crew change, PJSM. Pick up Baker cement head, make up to a single of 4"drill pipe f/the pipe shed. Make a top drive connection,then 5'in the hole to tag bottom @ 9441'. 00:30 01:30 1.00 9,441 9,441 INTRM1 CEMEN-CIRC P Break circulation, pumping 1 bpm w/ 600 psi-11%Totco flow out.After pumping 30 bbls increase rate to 1.5 bpm w/720 psi-12%Totco flow out. Appear to be having slight losses. Slow pumps back to 1 bpm w/610 psi-13%Totco flow out.After pumping 88 bbls of mud, start cutting weight back f/12 ppg,continue to circulate at 1 bpm. 01:30 03:30 2.00 9,441 9,441 INTRM1 CEMEN-CIRC P Continue to circulate and condition mud-reducing mud weight f/12 ppg, pumping 1 bpm w/610 psi-13% Totco flow out. Reciprocate slow f/ 9441'to 9429'. PU wt 140k, SO wt 80k. Pumped a bottom's up. Page 58 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:00 0.50 9,441 9,441 INTRM1 CEMEN-CIRC P Continue to circulate and condition mud-reducing mud weight f/12 ppg, pumping 1.5 bpm w/730 to 760 psi-14%Totco flow out. Reciprocate slow f/9441'to 9429'. PU wt 140k, SO wt 80k. 04:00 04:45 0.75 9,441 9,441 INTRM1 CEMEN-CIRC P Continue to circulate and condition mud-reducing mud weight f/12 ppg, pumping 2 bpm w/850 psi-15% initial to 25%Totco flow out. Reciprocate slow f/9441'to 9429'. PU wt 140k, SO wt 80k. 04:45 05:30 0.75 9,441 9,441 INTRM1 CEMEN-CIRC P Continue to circulate and condition mud-reducing mud weight f/12 ppg, pumping 2.5 bpm w/970 psi-34% initial to 38%Totco flow out. Reciprocate slow f/9441'to 9429'. PU wt 140k, SO wt 80k. 05:30 06:00 0.50 9,441 9,441 INTRM1 CEMEN-CIRC P Continue to circulate and condition mud-reducing mud weight f/12 ppg, pumping 3 bpm w/924 psi-42% Totco flow out. Reciprocate slow f/ 9441'to 9429'. PU wt 140k, SO wt 80k. 06:00 07:00 1.00 9,441 9,441 INTRM1 CEMEN-CIRC P Continue to circulate and condition mud-reducing mud weight f/12 ppg, pumping 3.38 bpm w/920-880 psi-42%Totco flow out. Reciprocate slow f/9441'to 9429'. PU wt 140k, SO wt 80k. 07:00 07:45 0.75 9,441 9,441 INTRM1 CEMEN-CIRC P Continue to circulate and condition mud-reducing mud weight f/12 ppg, pumping 3.8 bpm w/1020 psi-41% Totco flow out. Reciprocate slow f/ 9441'to 9429'. PU wt 140k, SO wt 80k. 07:45 09:00 1.25 9,441 9,441 INTRM1 CEMEN-CIRC P Continue to circulate and condition mud-reducing mud weight f/12 ppg, pumping 4.1 bpm w/1060 to 1010 psi-41-39%Totco flow out. Reciprocate slow f/9441'to 9429'. PU wt 140k, SO wt 80k. 09:00 09:45 0.75 9,441 9,441 INTRM1 CEMEN-CMNT P Mix and pump 5 bbl of CW100. Pressure test lines to 4500 psi. Mix and pump 15 bbl CW100 and 21 bbl ,1 1/1.- MudPush II spacer at 13.0 ppg. Mix and pump61.7 bbl Class G w/ f `yt additives at 15.8 ppg. Shut down l•�"' and drop plug. 09:45 10:30 0.75 9,441 9,441 INTRM1 CEMEN-DISP P Displace cement with 10 bbl fresh water with Schlumberger and 89 bbl mud with rig pump. At 773 stx of displacement caught liner wiper plug. Bumped plug with at 1135 stx with 2800 psi. CIP @ 10:21 hrs 6/3/2011. Set hanger and liner top packer with 4000 psi. Slack off 50 k to verify liner hanger set. . Page 59 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 10:45 0.25 9,441 9,441 INTRM1 CEMEN-PACK P Break off cement line and pick up 5 feet. Set down 65k and rotate to verify liner top packer set. 10:45 11:00 0.25 9,441 9,441 INTRM1 CEMEN-PRTS P Close annular and pressure test annulus and top of liner to 1000 psi for 10 minutes--OK 11:00 12:00 1.00 9,441 9,441 INTRM1 CEMEN-CIRC P Bleed off pressure and open annular. Pressure up on drill pipe to 500 psi and pull setting tool out of top of liner. Circulate out cement at 12 bpm @ 3038 psi(got 66 bbl contaminated cement back). 12:00 13:00 1.00 9,441 9,441 INTRM1 CEMEN-CIRC P Rig down cement head, 2 singles, rack back one stand, blow down kill line, remove MWD stand pipe pressure transducer. 13:00 14:00 1.00 7,134 7,134 INTRM1 CEMEN-CIRC P CBU 3 times @ 7134'MD, @ 500 GPM, 3000 psi. 14:00 15:45 1.75 7,134 7,134 INTRM1 RIGMNT SLPC P Slip and cut drill line. 325'. 50 wraps. 15:45 18:45 3.00 7,134 60 INTRM1 CEMEN-TRIPP PJSM, POOH to liner running tool, Calculated fill=39.75 bbls.Actual fill =41.5 bbls. 18:45 19:15 0.50 60 0 INTRM1 CEMEN-TRIP P Service break running tool and lay down. 19:15 20:00 0.75 0 0 INTRM1 CASING RCST P Clear and clean rig floor, pull wear ring. 20:00 21:45 1.75 0 0 INTRM1 CASING RCST P PJSM, Rig up and run upper completion string. 21:45 00:00 2.25 0 491 INTRM1 CASING RCST P Run 4'/z' 12.6 ppf, L-80, IBTm tubing. as per details. Note: OA pressure 200 psi @ midnight. 06/04/2011 Run upper completion.Tag up. Displace to seawater. Space out and land. Test tubing and annulus, shear DCK valve, nipple down BOP stack. 00:00 04:30 4.50 491 3,432 INTRM1 CASING RCST P PJSM, continue to run 4'/z'Tubing to joint 110. 04:30 05:30 1.00 3,432 3,432 INTRM1 CASING RCST P Circulate one full bottoms up volume due to mud over flowing. Pumped an 11.8 ppg slug, and continued to run tubing. 05:30 10:45 5.25 3,432 7,228 INTRM1 CASING RCST P PJSM, continue to run 4'%"Tubing from joint 110 to joint 229. Calculated displacement=31.8 bbls.Actual displacement=30.75 bbls. 10:45 11:15 0.50 7,228 7,228 INTRM1 CASING RCST P Change out short bails with long bails. 11:15 12:00 0.75 7,228 7,228 INTRM1 CASING RCST P PJSM, rig up to test seals and displace to 8.5 ppg brine. Pick up joint#230. Crew change. 12:00 12:15 0.25 7,228 7,228 INTRM1 CASING RCST P PJSM,sting into tie back extension. Pressure up to 500 psi to confirm seal effectiveness, pull out,verify pressure drop. P/U weight 105k, S/O weight 73K. Good seal assembly. Page 60 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:15 14:15 2.00 7,228 7,228 INTRM1 CASING RCST P PJSM, Displace to 8.5 ppg sea water. 1100 psi initial pump pressure, 700 psi final pump pressure.Spot 30 bbls inhibited seawater. 14:15 15:30 1.25 7,228 7,228 INTRM1 CASING RCST P L/D Joints 230/229/228, M/U space out pups. P/U joint#228, M/U tubing hanger, landing joint, and cross overs,drain stack down. 15:30 16:30 1.00 7,228 7,228 INTRM1 CASING RCST P Land tubing hanger, run in lock down screws, R/U to test tubing and annulus. 16:30 18:30 2.00 7,228 7,228 INTRM1 CASING RCST P Test tubing to 3500 psi, 30 mins charted, bleed off to 3000 psi.Test annulus to 3500 psi, 30 mins charted. Bleed tubing to zero, observed DCK-2 valve shear, confirmed by pumping both ways @ 2 BPM. 725-800 psi. 18:30 19:45 1.25 7,228 7,228 INTRM1 CASING RCST P R/D landing joint, break XO's, clean and clear rig floor. 19:45 20:30 0.75 7,228 7,228 INTRM1 CASING RCST P Set BPV,test to 1000 psi, charted 10 mins, Simops clean pits. 20:30 21:00 0.50 7,228 7,228 INTRM1 CASING RCST P Blow down choke and kill lines, lay down tubing equipment. 21:00 22:30 1.50 7,228 7,228 INTRM1 CASING RCST P PJSM, C/O upper rams to 2 7/8"x 5". remove choke line on BOP stack, SIMOPS lay down long bails, P/U short bails, pull riser and install boot protector, pull long and short mouse holes. 22:30 00:00 1.50 7,228 7,228 INTRM1 MOVE BOPE P PJSM, Remove choke side valves, HCR and manual valves. Note: OA pressure 100 psi @ midnight. 06/05/2011 Nipple up and test production tree. Lay down all drill pipe. Freeze protect well, release rig @ 20:00 hrs. 00:00 03:00 3.00 7,228 7,228 INTRM1 MOVE NUND P PJSM, Change out HCR/Manual choke valves. SIMOPS lay down long bails, and pick up short bails. Blow down pumps, clean pits. 03:00 04:30 1.50 7,228 7,228 INTRM1 MOVE NUND P Nipple down BOPE, SIMOPS prepare for rig move, rig down glycol lines. 04:30 07:30 3.00 7,228 7,228 INTRM1 MOVE NUND P Nipple up adaptor flange and tree, test adapator flange to 250 psi low/ 5000 psi high. 10 mins charted. Good test. 07:30 08:00 0.50 7,228 7,228 INTRM1 MOVE BOPE P Pull BPV, Install test plug. 08:00 09:45 1.75 7,228 7,228 INTRM1 MOVE BOPE P Fill tree with diesel and test to 250 psi low/5000 psi high. 15 mins, charted. Good test. Rig down and pull test plug. Page 61 of 62 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 11:45 2.00 7,228 7,228 INTRM1 MOVE FRZP P PJSM, SIMOPS meeting. Freeze protection and laying down drill pipe in the mouse hole. Rig up to freeze protect well with Hot Oil. Pressure test lines to Hot Oil to 2500 psi. Pump 95 bbls diesel downhole(7"x 4-1/2"tbg)@ 1BPM intial 300 psi, final 600 psi. Shut down pumping, with 350 psi on IA. L/D 30 Joints of DP. 11:45 12:00 0.25 7,228 7,228 INTRM1 MOVE FRZP P PJSM. Crew change. Freeze protection and SIMOPS of laying down drill pipe via mouse hole. 12:00 13:00 1.00 7,228 7,228 INTRM1 MOVE FRZP P Rig up and allow well to U-tube. Release Hot Oil. Continue to lay down drill pipe. 13:00 14:00 1.00 7,228 7,228 INTRM1 MOVE RURD P Rig down hoses and valves, set BPV. Record pressures. SITP=0& Inner annulus=0. 14:00 20:00 6.00 7,228 7,228 INTRM1 MOVE RURD P Continue to lay down drill pipe. Clean pits and rock washer. Switch to rig generator power. (Off high line electricity @ 14:50 hrs.)Lay down mouse hole. Rig release @ 20:00 hrs. Begin rig move to 3 I Pad.Well 31-08 WO. 22 mile rig move. Note: OA pressure at 0. IA pressure 0.Tbg is zero psi as well. Page 62 of 62 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K-08A 501032011101 Sperry Drilling Definitive Survey Report 06 June, 2011 HALLIBURTON Sperry Drilling ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2K-08 Project: Kuparuk River Unit TVD Reference: 2K-08A @ 146.33ft(D141) Site: Kuparuk 2K Pad MD Reference: 2K-08A @ 146.33ft(D141) Well: 2K-08 North Reference: True Wellbore: 2K-08A Survey Calculation Method: Minimum Curvature Design: 2K-08A Database: CPAI EDM Production 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 Well 2K-08 Well Position +N/-S 0.00 ft Northing: 5,938,425.30 ft Latitude: 70°14'34.799 N +E/-W 0.00 ft Easting: 498,310.18 ft Longitude: 150°0'49.132 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 118.50 ft Wellbore 2K-08A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2010 4/25/2011 20.99 80.81 57,612 Design 2K-08A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,669.60 Vertical Section: Depth From(TVD) +NI-S +E/-W Direction (ft) (ft) (ft) (°) 27.83 0.00 0.00 277.06 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 32.33 7,432.33 2K-08 GyroData(2K-08) GYD-CT-CMS Gyrodata cont.casing m/s 11/8/2010 12:C 7,434.00 7,669.60 2K-08A MWD(R500)(2K-08APB2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/23/2011 12:C 7,720.00 9,403.48 2K-08A(R1000)(2K-08A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/29/2011 12:C Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (°) (ft) (ft) (ft) (ft) . (ft) (ft) (°1100') (ft) Survey Tool Name 27.83 0.00 0.00 27.83 -118.50 0.00 0.00 5,938,425.30 498,310.18 0.00 0.00 UNDEFINED 32.33 1.87 105.12 32.33 -114.00 -0.02 0.07 5,938,425.28 498,310.25 41.55 -0.07 GYD-CT-CMS(1) 52.33 1.15 114.40 52.32 -94.01 -0.19 0.57 5,938,425.11 498,310.75 3.79 -0.59 GYD-CT-CMS(1) 72.33 0.54 87.58 72.32 -74.01 -0.27 0.85 5,938,425.03 498,311.03 3.56 -0.87 GYD-CT-CMS(1) 92.33 0.34 48.18 92.32 -54.01 -0.22 0.98 5,938,425.08 498,311.16 1.76 -1.00 GYD-CT-CMS(1) 112.33 0.20 45.40 112.32 -34.01 -0.16 1.05 5,938,425.14 498,311.23 0.70 -1.06 GYD-CT-CMS(1) 132.33 0.33 35.11 132.32 -14.01 -0.09 1.11 5,938,425.21 498,311.29 0.69 -1.11 GYD-CT-CMS(1) 152.33 0.48 40.36 152.32 5.99 0.02 1.20 5,938,425.32 498,311.38 0.77 -1.19 GYD-CT-CMS(1) 172.33 0.42 21.83 172.32 25.99 0.16 1.28 5,938,425.45 498,311.46 0.78 -1.25 GYD-CT-CMS(1) 192.33 0.31 23.89 192.32 45.99 0.27 1.33 5,938,425.57 498,311.51 0.55 -1.29 GYD-CT-CMS(1) 212.33 0.24 65.09 212.32 65.99 0.34 1.39 5,938,425.64 498,311.57 1.02 -1.34 GYD-CT-CMS(1) 232.33 0.26 78.58 232.32 85.99 0.37 1.47 5,938,425.67 498,311.65 0.31 -1.42 GYD-CT-CMS(1) 6/6/2011 8:08:11 AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2K-08 Project: Kuparuk River Unit TVD Reference: 2K-08A @ 146.33ft(D141) Site: Kuparuk 2K Pad MD Reference: 2K-08A @ 146.33ft(D141) Well: 2K-08 North Reference: True Wellbore: 2K-08A Survey Calculation Method: Minimum Curvature Design: 2K-08A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (') (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 252.33 0.32 88.21 252.32 105.99 0.38 1.57 5,938,425.68 498,311.75 0.39 -1.51 GYD-CT-CMS(1) 272.33 0.37 77.30 272.32 125.99 0.39 1.69 5,938,425.69 498,311.87 0.41 -1.63 GYD-CT-CMS(1) 292.33 0.45 69.59 292.32 145.99 0.44 1.83 5,938,425.73 498,312.01 0.49 -1.76 GYD-CT-CMS(1) 312.33 0.44 54.26 312.32 165.99 0.51 1.96 5,938,425.81 498,312.14 0.60 -1.89 GYD-CT-CMS(1) 332.33 0.38 47.18 332.32 185.99 0.60 2.07 5,938,425.90 498,312.25 0.39 -1.99 GYD-CT-CMS(1) 352.33 0.25 50.31 352.31 205.98 0.67 2.16 5,938,425.97 498,312.34 0.66 -2.06 GYD-CT-CMS(1) 372.33 0.30 37.83 372.31 225.98 0.74 2.22 5,938,426.04 498,312.40 0.39 -2.11 GYD-CT-CMS(1) 392.33 0.36 25.05 392.31 245.98 0.84 2.28 5,938,426.14 498,312.46 0.47 -2.16 GYD-CT-CMS(1) 412.33 0.28 19.57 412.31 265.98 0.94 2.32 5,938,426.24 498,312.50 0.43 -2.19 GYD-CT-CMS(1) 432.33 0.17 16.24 432.31 285.98 1.02 2.35 5,938,426.31 498,312.53 0.55 -2.21 GYD-CT-CMS(1) 452.33 0.38 341.19 452.31 305.98 1.11 2.34 5,938,426.41 498,312.52 1.30 -2.18 GYD-CT-CMS(1) 472.33 0.25 305.50 472.31 325.98 1.19 2.28 5,938,426.49 498,312.46 1.15 -2.11 GYD-CT-CMS(1) 492.33 0.32 309.26 492.31 345.98 1.26 2.20 5,938,426.55 498,312.38 0.36 -2.03 GYD-CT-CMS(1) 512.33 0.71 297.93 512.31 365.98 1.35 2.05 5,938,426.65 498,312.23 2.01 -1.87 GYD-CT-CMS(1) 532.33 0.86 292.26 532.31 385.98 1.46 1.80 5,938,426.76 498,311.98 0.84 -1.61 GYD-CT-CMS(1) 552.33 1.60 289.11 552.31 405.98 1.61 1.40 5,938,426.91 498,311.58 3.71 -1.19 GYD-CT-CMS(1) 572.33 2.21 283.78 572.29 425.96 1.80 0.76 5,938,427.09 498,310.94 3.17 -0.53 GYD-CT-CMS(1) 592.33 2.56 284.83 592.28 445.95 2.00 -0.05 5,938,427.30 498,310.13 1.76 0.29 GYD-CT-CMS(1) 612.33 3.54 284.07 612.25 465.92 2.27 -1.08 5,938,427.57 498,309.10 4.90 1.35 GYD-CT-CMS(1) 632.33 4.66 285.38 632.20 485.87 2.63 -2.46 5,938,427.93 498,307.72 5.62 2.77 GYD-CT-CMS(1) 652.33 5.19 286.66 652.12 505.79 3.11 -4.11 5,938,428.41 498,306.07 2.71 4.46 GYD-CT-CMS(1) 672.33 5.77 287.86 672.03 525.70 3.67 -5.94 5,938,428.97 498,304.25 2.96 6.34 GYD-CT-CMS(1) 692.33 6.41 289.04 691.92 545.59 4.35 -7.95 5,938,429.65 498,302.23 3.26 8.42 GYD-CT-CMS(1) 712.33 6.26 291.38 711.80 565.47 5.11 -10.02 5,938,430.41 498,300.16 1.49 10.57 GYD-CT-CMS(1) 732.33 7.02 289.07 731.66 585.33 5.91 -12.19 5,938,431.21 498,297.99 4.03 12.82 GYD-CT-CMS(1) 752.33 8.11 290.30 751.49 605.16 6.79 -14.67 5,938,432.10 498,295.52 5.51 15.39 GYD-CT-CMS(1) 772.33 8.75 293.39 771.27 624.94 7.89 -17.39 5,938,433.19 498,292.80 3.92 18.22 GYD-CT-CMS(1) 792.33 9.30 294.23 791.02 644.69 9.15 -20.26 5,938,434.46 498,289.93 2.83 21.23 GYD-CT-CMS(1) 812.33 9.86 296.03 810.75 664.42 10.57 -23.27 5,938,435.87 498,286.92 3.18 24.39 GYD-CT-CMS(1) 832.33 10.31 297.78 830.44 684.11 12.15 -26.39 5,938,437.46 498,283.79 2.72 27.68 GYD-CT-CMS(1) 852.33 10.90 297.36 850.09 703.76 13.86 -29.65 5,938,439.16 498,280.53 2.98 31.13 GYD-CT-CMS(1) 872.33 11.47 297.46 869.71 723.38 15.64 -33.10 5,938,440.95 498,277.09 2.85 34.77 GYD-CT-CMS(1) 892.33 11.91 297.59 889.30 742.97 17.52 -36.69 5,938,442.82 498,273.50 2.20 38.57 GYD-CT-CMS(1) 912.33 12.46 297.58 908.85 762.52 19.47 -40.43 5,938,444.78 498,269.76 2.75 42.52 GYD-CT-CMS(1) 932.33 13.10 297.34 928.35 782.02 21.51 -44.36 5,938,446.82 498,265.83 3.21 46.67 GYD-CT-CMS(1) 952.33 13.88 296.97 947.80 801.47 23.64 -48.51 5,938,448.95 498,261.68 3.92 51.05 GYD-CT-CMS(1) 972.33 14.66 296.47 967.18 820.85 25.86 -52.91 5,938,451.17 498,257.28 3.95 55.69 GYD-CT-CMS(1) 992.33 15.61 295.96 986.49 840.16 28.16 -57.60 5,938,453.47 498,252.59 4.80 60.62 GYD-CT-CMS(1) 1,012.33 16.27 295.66 1,005.72 859.39 30.55 -62.54 5,938,455.86 498,247.65 3.33 65.82 GYD-CT-CMS(1) 1,032.33 16.75 295.08 1,024.90 878.57 32.99 -67.68 5,938,458.30 498,242.51 2.54 71.22 GYD-CT-CMS(1) 6/6/2011 8:08:11 AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2K-08 Project: Kuparuk River Unit TVD Reference: 2K-08A @ 146.33ft(D141) Site: Kuparuk 2K Pad MD Reference: 2K-08A @ 146.33ft(D141) Well: 2K-08 North Reference: True Wellbore: 2K-08A Survey Calculation Method: Minimum Curvature Design: 2K-08A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,052.33 17.25 294.29 1,044.02 897.69 35.43 -72.99 5,938,460.74 498,237.20 2.75 76.79 GYD-CT-CMS(1) 1,072.33 17.70 293.68 1,063.10 916.77 37.87 -78.48 5,938,463.18 498,231.72 2.43 82.54 GYD-CT-CMS(1) 1,092.33 18.30 292.76 1,082.12 935.79 40.31 -84.16 5,938,465.62 498,226.04 3.32 88.47 GYD-CT-CMS(1) 1,112.33 18.86 291.62 1,101.08 954.75 42.71 -90.06 5,938,468.03 498,220.14 3.34 94.62 GYD-CT-CMS(1) 1,132.33 19.40 289.97 1,119.97 973.64 45.04 -96.19 5,938,470.35 498,214.01 3.82 100.99 GYD-CT-CMS(1) 1,152.33 20.17 288.56 1,138.79 992.46 47.27 -102.58 5,938,472.59 498,207.62 4.53 107.61 GYD-CT-CMS(1) 1,172.33 20.73 287.58 1,157.53 1,011.20 49.44 -109.22 5,938,474.76 498,200.98 3.28 114.47 GYD-CT-CMS(1) 1,192.33 21.41 287.11 1,176.20 1,029.87 51.58 -116.08 5,938,476.90 498,194.12 3.50 121.54 GYD-CT-CMS(1) 1,212.33 22.08 286.73 1,194.77 1,048.44 53.74 -123.17 5,938,479.06 498,187.03 3.42 128.84 GYD-CT-CMS(1) 1,232.33 22.76 286.34 1,213.26 1,066.93 55.91 -130.49 5,938,481.23 498,179.72 3.48 136.36 GYD-CT-CMS(1) 1,252.33 23.51 285.73 1,231.65 1,085.32 58.08 -138.04 5,938,483.40 498,172.17 3.94 144.13 GYD-CT-CMS(1) 1,272.33 24.00 284.83 1,249.96 1,103.63 60.20 -145.81 5,938,485.52 498,164.40 3.05 152.10 GYD-CT-CMS(1) 1,292.33 24.61 283.87 1,268.18 1,121.85 62.24 -153.78 5,938,487.57 498,156.42 3.63 160.26 GYD-CT-CMS(1) 1,312.33 25.32 283.45 1,286.32 1,139.99 64.23 -161.99 5,938,489.56 498,148.22 3.66 168.65 GYD-CT-CMS(1) 1,332.33 25.72 283.44 1,304.36 1,158.03 66.23 -170.37 5,938,491.57 498,139.84 2.00 177.21 GYD-CT-CMS(1) 1,352.33 26.40 283.31 1,322.33 1,176.00 68.27 -178.92 5,938,493.60 498,131.30 3.41 185.95 GYD-CT-CMS(1) 1,372.33 27.28 283.16 1,340.18 1,193.85 70.33 -187.71 5,938,495.67 498,122.51 4.41 194.92 GYD-CT-CMS(1) 1,392.33 27.74 282.85 1,357.91 1,211.58 72.41 -196.71 5,938,497.75 498,113.51 2.41 204.11 GYD-CT-CMS(1) 1,412.33 28.70 282.78 1,375.54 1,229.21 74.51 -205.93 5,938,499.85 498,104.29 4.80 213.52 GYD-CT-CMS(1) 1,432.33 29.14 282.77 1,393.04 1,246.71 76.65 -215.36 5,938,501.99 498,094.86 2.20 223.14 GYD-CT-CMS(1) 1,452.33 29.74 282.84 1,410.46 1,264.13 78.83 -224.95 5,938,504.17 498,085.27 3.00 232.93 GYD-CT-CMS(1) 1,472.33 30.42 283.07 1,427.77 1,281.44 81.08 -234.71 5,938,506.42 498,075.51 3.45 242.90 GYD-CT-CMS(1) 1,492.33 30.49 283.04 1,445.01 1,298.68 83.37 -244.59 5,938,508.71 498,065.63 0.36 252.98 GYD-CT-CMS(1) 1,512.33 31.39 282.87 1,462.16 1,315.83 85.67 -254.61 5,938,511.02 498,055.61 4.52 263.21 GYD-CT-CMS(1) 1,532.33 32.11 282.80 1,479.17 1,332.84 88.01 -264.87 5,938,513.36 498,045.35 3.60 273.68 GYD-CT-CMS(1) 1,552.33 32.55 282.91 1,496.07 1,349.74 90.39 -275.30 5,938,515.74 498,034.93 2.22 284.32 GYD-CT-CMS(1) 1,572.33 33.49 283.01 1,512.84 1,366.51 92.83 -285.92 5,938,518.19 498,024.31 4.71 295.16 GYD-CT-CMS(1) 1,592.33 33.81 282.64 1,529.49 1,383.16 95.29 -296.73 5,938,520.65 498,013.50 1.90 306.19 GYD-CT-CMS(1) 1,612.33 34.37 282.31 1,546.05 1,399.72 97.71 -307.67 5,938,523.07 498,002.56 2.95 317.34 GYD-CT-CMS(1) 1,632.33 35.02 282.15 1,562.49 1,416.16 100.12 -318.80 5,938,525.49 497,991.44 3.28 328.68 GYD-CT-CMS(1) 1,652.33 35.45 281.84 1,578.83 1,432.50 102.52 -330.08 5,938,527.89 497,980.15 2.33 340.18 GYD-CT-CMS(1) 1,672.33 36.26 281.61 1,595.04 1,448.71 104.90 -341.55 5,938,530.27 497,968.68 4.11 351.85 GYD-CT-CMS(1) 1,692.33 36.78 281.75 1,611.11 1,464.78 107.31 -353.21 5,938,532.68 497,957.03 2.63 363.72 GYD-CT-CMS(1) 1,712.33 37.50 281.32 1,627.06 1,480.73 109.73 -365.04 5,938,535.10 497,945.20 3.83 375.76 GYD-CT-CMS(1) 1,732.33 38.11 280.97 1,642.86 1,496.53 112.10 -377.07 5,938,537.47 497,933.17 3.23 387.98 GYD-CT-CMS(1) 1,752.33 38.41 280.45 1,658.56 1,512.23 114.40 -389.24 5,938,539.77 497,921.01 2.20 400.34 GYD-CT-CMS(1) 1,772.33 38.96 280.24 1,674.17 1,527.84 116.64 -401.54 5,938,542.02 497,908.71 2.83 412.82 GYD-CT-CMS(1) 1,792.33 39.58 279.79 1,689.66 1,543.33 118.84 -414.00 5,938,544.22 497,896.24 3.41 425.47 GYD-CT-CMS(1) 1,812.33 40.50 279.84 1,704.97 1,558.64 121.04 -426.68 5,938,546.42 497,883.57 4.60 438.32 GYD-CT-CMS(1) 1,832.33 40.54 280.05 1,720.17 1,573.84 123.28 -439.48 5,938,548.67 497,870.77 0.71 451.29 GYD-CT-CMS(1) 6/6/2011 8:08:11AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2K-08 Project: Kuparuk River Unit TVD Reference: 2K-08A @ 146.33ft(D141) Site: Kuparuk 2K Pad MD Reference: 2K-08A @ 146.33ft(D141) Well: 2K-08 North Reference: True Wellbore: 2K-08A Survey Calculation Method: Minimum Curvature Design: 2K-08A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,852.33 41.42 279.95 1,735.27 1,588.94 125.56 -452.40 5,938,550.95 497,857.86 4.41 464.39 GYD-CT-CMS(1) 1,872.33 41.96 279.53 1,750.21 1,603.88 127.81 -465.51 5,938,553.20 497,844.75 3.04 477.68 GYD-CT-CMS(1) 1,892.33 42.40 279.14 1,765.03 1,618.70 129.99 -478.76 5,938,555.38 497,831.50 2.56 491.10 GYD-CT-CMS(1) 1,912.33 43.37 278.57 1,779.68 1,633.35 132.08 -492.21 5,938,557.48 497,818.05 5.22 504.70 GYD-CT-CMS(1) 1,932.33 43.43 278.55 1,794.21 1,647.88 134.13 -505.79 5,938,559.53 497,804.47 0.31 518.44 GYD-CT-CMS(1) 1,952.33 44.14 278.74 1,808.65 1,662.32 136.21 -519.48 5,938,561.61 497,790.79 3.61 532.27 GYD-CT-CMS(1) 1,972.33 44.30 278.54 1,822.98 1,676.65 138.30 -533.27 5,938,563.71 497,777.00 1.06 546.22 GYD-CT-CMS(1) 1,992.33 44.48 278.74 1,837.28 1,690.95 140.40 -547.10 5,938,565.81 497,763.17 1.14 560.20 GYD-CT-CMS(1) 2,012.33 45.48 278.26 1,851.42 1,705.09 142.49 -561.08 5,938,567.90 497,749.19 5.28 574.33 GYD-CT-CMS(1) 2,032.33 45.83 278.44 1,865.40 1,719.07 144.57 -575.23 5,938,569.98 497,735.04 1.86 588.63 GYD-CT-CMS(1) 2,052.33 46.59 278.63 1,879.24 1,732.91 146.71 -589.51 5,938,572.13 497,720.76 3.86 603.07 GYD-CT-CMS(1) 2,072.33 47.65 278.86 1,892.85 1,746.52 148.94 -603.99 5,938,574.36 497,706.28 5.37 617.72 GYD-CT-CMS(1) 2,092.33 47.81 279.02 1,906.30 1,759.97 151.24 -618.61 5,938,576.66 497,691.66 1.00 632.51 GYD-CT-CMS(1) 2,112.33 48.42 278.75 1,919.66 1,773.33 153.54 -633.32 5,938,578.97 497,676.95 3.21 647.39 GYD-CT-CMS(1) 2,132.33 48.97 278.71 1,932.86 1,786.53 155.82 -648.17 5,938,581.25 497,662.10 2.75 662.41 GYD-CT-CMS(1) 2,152.33 49.17 278.39 1,945.96 1,799.63 158.07 -663.12 5,938,583.50 497,647.16 1.57 677.51 GYD-CT-CMS(1) 2,172.33 49.95 278.00 1,958.93 1,812.60 160.24 -678.18 5,938,585.67 497,632.10 4.17 692.73 GYD-CT-CMS(1) 2,192.33 49.95 277.98 1,971.80 1,825.47 162.36 -693.34 5,938,587.80 497,616.94 0.08 708.04 GYD-CT-CMS(1) 2,212.33 50.43 277.87 1,984.61 1,838.28 164.48 -708.56 5,938,589.92 497,601.73 2.44 723.40 GYD-CT-CMS(1) 2,232.33 50.81 278.33 1,997.30 1,850.97 166.66 -723.87 5,938,592.11 497,586.42 2.60 738.86 GYD-CT-CMS(1) 2,252.33 50.81 278.79 2,009.94 1,863.61 168.97 -739.19 5,938,594.42 497,571.10 1.78 754.35 GYD-CT-CMS(1) 2,272.33 51.24 278.83 2,022.51 1,876.18 171.35 -754.56 5,938,596.80 497,555.73 2.16 769.89 GYD-CT-CMS(1) 2,292.33 51.40 278.93 2,035.01 1,888.68 173.76 -769.98 5,938,599.21 497,540.31 0.89 785.50 GYD-CT-CMS(1) 2,312.33 51.95 279.03 2,047.42 1,901.09 176.21 -785.48 5,938,601.67 497,524.82 2.78 801.18 GYD-CT-CMS(1) 2,332.33 52.87 279.34 2,059.62 1,913.29 178.74 -801.13 5,938,604.20 497,509.17 4.76 817.02 GYD-CT-CMS(1) 2,352.33 53.04 279.33 2,071.67 1,925.34 181.33 -816.88 5,938,606.79 497,493.42 0.85 832.97 GYD-CT-CMS(1) 2,372.33 53.70 279.43 2,083.60 1,937.27 183.94 -832.71 5,938,609.41 497,477.59 3.32 849.00 GYD-CT-CMS(1) 2,392.33 53.78 279.46 2,095.43 1,949.10 186.59 -848.62 5,938,612.06 497,461.68 0.42 865.12 GYD-CT-CMS(1) 2,412.33 53.63 279.57 2,107.27 1,960.94 189.26 -864.52 5,938,614.73 497,445.79 0.87 881.22 GYD-CT-CMS(1) 2,432.33 53.95 279.40 2,119.08 1,972.75 191.91 -880.44 5,938,617.39 497,429.87 1.74 897.34 GYD-CT-CMS(1) 2,452.33 53.68 279.57 2,130.89 1,984.56 194.57 -896.36 5,938,620.06 497,413.95 1.51 913.47 GYD-CT-CMS(1) 2,472.33 53.80 279.75 2,142.72 1,996.39 197.28 -912.26 5,938,622.77 497,398.06 0.94 929.58 GYD-CT-CMS(1) 2,492.33 54.04 279.64 2,154.50 2,008.17 200.00 -928.19 5,938,625.49 497,382.13 1.28 945.73 GYD-CT-CMS(1) 2,512.33 53.81 279.44 2,166.27 2,019.94 202.68 -944.13 5,938,628.17 497,366.19 1.41 961.88 GYD-CT-CMS(1) 2,532.33 54.18 279.83 2,178.03 2,031.70 205.39 -960.08 5,938,630.88 497,350.24 2.43 978.04 GYD-CT-CMS(1) 2,552.33 54.14 279.75 2,189.74 2,043.41 208.15 -976.06 5,938,633.64 497,334.27 0.38 994.23 GYD-CT-CMS(1) 2,572.33 54.16 279.49 2,201.45 2,055.12 210.86 -992.04 5,938,636.36 497,318.28 1.06 1,010.43 GYD-CT-CMS(1) 2,592.33 54.47 279.73 2,213.12 2,066.79 213.57 -1,008.06 5,938,639.07 497,302.27 1.83 1,026.66 GYD-CT-CMS(1) 2,612.33 54.28 279.73 2,224.77 2,078.44 216.32 -1,024.08 5,938,641.82 497,286.25 0.95 1,042.90 GYD-CT-CMS(1) 2,632.33 54.50 279.53 2,236.42 2,090.09 219.04 -1,040.11 5,938,644.55 497,270.22 1.37 1,059.14 GYD-CT-CMS(1) 6/6/2011 8:08:11AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2K-08 Project: Kuparuk River Unit TVD Reference: 2K-08A @ 146.33ft(D141) Site: Kuparuk 2K Pad MD Reference: 2K-08A @ 146.33ft(D141) Well: 2K-08 North Reference: True Wellbore: 2K-08A Survey Calculation Method: Minimum Curvature Design: 2K-08A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (0/100) (ft) Survey Tool Name 2,652.33 54.62 279.72 2,248.01 2,101.68 221.76 -1,056.18 5,938,647.27 497,254.16 0.98 1,075.42 GYD-CT-CMS(1) 2,672.33 54.31 279.70 2,259.64 2,113.31 224.51 -1,072.22 5,938,650.02 497,238.12 1.55 1,091.68 GYD-CT-CMS(1) 2,692.33 54.54 280.16 2,271.27 2,124.94 227.31 -1,088.24 5,938,652.83 497,222.10 2.20 1,107.92 GYD-CT-CMS(1) 2,712.33 54.43 280.08 2,282.89 2,136.56 230.17 -1,104.27 5,938,655.69 497,206.07 0.64 1,124.18 GYD-CT-CMS(1) 2,732.33 54.44 280.04 2,294.52 2,148.19 233.01 -1,120.29 5,938,658.54 497,190.06 0.17 1,140.43 GYD-CT-CMS(1) 2,752.33 54.82 280.19 2,306.10 2,159.77 235.88 -1,136.34 5,938,661.41 497,174.00 2.00 1,156.71 GYD-CT-CMS(1) 2,772.33 54.49 280.51 2,317.67 2,171.34 238.81 -1,152.39 5,938,664.34 497,157.96 2.10 1,173.00 GYD-CT-CMS(1) 2,792.33 54.98 280.52 2,329.22 2,182.89 241.79 -1,168.45 5,938,667.32 497,141.90 2.45 1,189.30 GYD-CT-CMS(1) 2,812.33 54.71 280.51 2,340.73 2,194.40 244.77 -1,184.52 5,938,670.31 497,125.83 1.35 1,205.62 GYD-CT-CMS(1) 2,832.33 55.04 280.66 2,352.24 2,205.91 247.78 -1,200.60 5,938,673.32 497,109.75 1.76 1,221.95 GYD-CT-CMS(1) 2,852.33 55.22 280.64 2,363.67 2,217.34 250.81 -1,216.73 5,938,676.36 497,093.63 0.90 1,238.32 GYD-CT-CMS(1) 2,872.33 55.11 280.86 2,375.10 2,228.77 253.87 -1,232.86 5,938,679.42 497,077.50 1.06 1,254.71 GYD-CT-CMS(1) 2,892.33 55.62 280.78 2,386.47 2,240.14 256.96 -1,249.02 5,938,682.51 497,061.34 2.57 1,271.13 GYD-CT-CMS(1) 2,912.33 55.52 280.81 2,397.77 2,251.44 260.05 -1,265.23 5,938,685.61 497,045.14 0.52 1,287.59 GYD-CT-CMS(1) 2,932.33 55.57 281.02 2,409.09 2,262.76 263.17 -1,281.42 5,938,688.73 497,028.95 0.90 1,304.04 GYD-CT-CMS(1) 2,952.33 55.48 280.21 2,420.41 2,274.08 266.21 -1,297.62 5,938,691.77 497,012.75 3.37 1,320.50 GYD-CT-CMS(1) 2,972.33 55.21 280.44 2,431.78 2,285.45 269.16 -1,313.81 5,938,694.73 496,996.56 1.65 1,336.92 GYD-CT-CMS(1) 2,992.33 55.55 279.95 2,443.15 2,296.82 272.07 -1,330.01 5,938,697.64 496,980.37 2.64 1,353.36 GYD-CT-CMS(1) 3,012.33 55.52 280.30 2,454.46 2,308.13 274.97 -1,346.24 5,938,700.54 496,964.14 1.45 1,369.82 GYD-CT-CMS(1) 3,032.33 55.39 280.61 2,465.80 2,319.47 277.96 -1,362.44 5,938,703.54 496,947.94 1.43 1,386.27 GYD-CT-CMS(1) 3,052.33 55.48 279.91 2,477.15 2,330.82 280.89 -1,378.65 5,938,706.47 496,931.73 2.92 1,402.71 GYD-CT-CMS(1) 3,072.33 54.94 279.68 2,488.56 2,342.23 283.69 -1,394.83 5,938,709.27 496,915.55 2.86 1,419.12 GYD-CT-CMS(1) 3,092.33 54.85 279.98 2,500.06 2,353.73 286.48 -1,410.95 5,938,712.07 496,899.43 1.31 1,435.46 GYD-CT-CMS(1) 3,112.33 54.00 278.80 2,511.70 2,365.37 289.14 -1,427.00 5,938,714.73 496,883.38 6.41 1,451.71 GYD-CT-CMS(1) 3,132.33 53.52 278.20 2,523.52 2,377.19 291.52 -1,442.96 5,938,717.11 496,867.43 3.41 1,467.84 GYD-CT-CMS(1) 3,152.33 53.46 278.28 2,535.42 2,389.09 293.82 -1,458.86 5,938,719.42 496,851.53 0.44 1,483.91 GYD-CT-CMS(1) 3,172.33 53.33 277.75 2,547.35 2,401.02 296.06 -1,474.76 5,938,721.66 496,835.63 2.22 1,499.96 GYD-CT-CMS(1) 3,192.33 53.37 277.58 2,559.29 2,412.96 298.20 -1,490.67 5,938,723.81 496,819.73 0.71 1,516.01 GYD-CT-CMS(1) 3,212.33 53.86 277.79 2,571.15 2,424.82 300.36 -1,506.62 5,938,725.96 496,803.78 2.59 1,532.11 GYD-CT-CMS(1) 3,232.33 53.68 277.56 2,582.97 2,436.64 302.51 -1,522.61 5,938,728.12 496,787.79 1.29 1,548.24 GYD-CT-CMS(1) 3,252.33 53.55 278.27 2,594.84 2,448.51 304.73 -1,538.56 5,938,730.34 496,771.84 2.93 1,564.34 GYD-CT-CMS(1) 3,272.33 53.25 277.54 2,606.76 2,460.43 306.94 -1,554.46 5,938,732.55 496,755.94 3.29 1,580.39 GYD-CT-CMS(1) 3,292.33 53.04 277.46 2,618.76 2,472.43 309.03 -1,570.33 5,938,734.65 496,740.08 1.10 1,596.39 GYD-CT-CMS(1) 3,312.33 53.33 277.92 2,630.74 2,484.41 311.17 -1,586.20 5,938,736.79 496,724.21 2.34 1,612.41 GYD-CT-CMS(1) 3,332.33 53.36 277.73 2,642.68 2,496.35 313.35 -1,602.09 5,938,738.98 496,708.32 0.78 1,628.45 GYD-CT-CMS(1) 3,352.33 53.50 278.00 2,654.60 2,508.27 315.55 -1,618.00 5,938,741.18 496,692.41 1.29 1,644.51 GYD-CT-CMS(1) 3,372.33 53.88 278.03 2,666.44 2,520.11 317.80 -1,633.96 5,938,743.43 496,676.45 1.90 1,660.62 GYD-CT-CMS(1) 3,392.33 53.75 277.90 2,678.25 2,531.92 320.03 -1,649.95 5,938,745.67 496,660.47 0.84 1,676.76 GYD-CT-CMS(1) 3,412.33 54.13 278.42 2,690.02 2,543.69 322.33 -1,665.95 5,938,747.97 496,644.47 2.83 1,692.93 GYD-CT-CMS(1) 3,432.33 54.28 278.14 2,701.72 2,555.39 324.67 -1,682.01 5,938,750.31 496,628.42 1.36 1,709.15 GYD-CT-CMS(1) 6/6/2011 8:08:11AM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2K-08 Project: Kuparuk River Unit TVD Reference: 2K-08A @ 146.33ft(D141) Site: Kuparuk 2K Pad MD Reference: 2K-08A @ 146.33ft(D141) Well: 2K-08 North Reference: True Wellbore: 2K-08A Survey Calculation Method: Minimum Curvature Design: 2K-08A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (1) (1) (ft) (ft) (ft) (ft) (ft) (ft) (1100') (ft) Survey Tool Name 3,452.33 54.25 278.39 2,713.40 2,567.07 327.00 -1,698.07 5,938,752.65 496,612.35 1.03 1,725.38 GYD-CT-CMS(1) 3,472.33 54.65 278.64 2,725.03 2,578.70 329.41 -1,714.16 5,938,755.06 496,596.26 2.24 1,741.65 GYD-CT-CMS(1) 3,492.33 54.64 278.49 2,736.60 2,590.27 331.84 -1,730.29 5,938,757.49 496,580.13 0.61 1,757.95 GYD-CT-CMS(1) 3,512.33 54.85 279.03 2,748.14 2,601.81 334.33 -1,746.43 5,938,759.98 496,563.99 2.44 1,774.28 GYD-CT-CMS(1) 3,532.33 54.79 278.71 2,759.67 2,613.34 336.85 -1,762.59 5,938,762.51 496,547.85 1.34 1,790.61 GYD-CT-CMS(1) 3,552.33 54.67 278.57 2,771.22 2,624.89 339.30 -1,778.73 5,938,764.96 496,531.70 0.83 1,806.94 GYD-CT-CMS(1) 3,572.33 54.57 279.38 2,782.80 2,636.47 341.84 -1,794.84 5,938,767.51 496,515.60 3.34 1,823.23 GYD-CT-CMS(1) 3,592.33 54.00 278.84 2,794.47 2,648.14 344.41 -1,810.87 5,938,770.08 496,499.57 3.60 1,839.46 GYD-CT-CMS(1) 3,612.33 53.14 277.98 2,806.35 2,660.02 346.77 -1,826.79 5,938,772.44 496,483.65 5.52 1,855.55 GYD-CT-CMS(1) 3,632.33 52.96 278.69 2,818.37 2,672.04 349.08 -1,842.60 5,938,774.76 496,467.84 2.98 1,871.53 GYD-CT-CMS(1) 3,652.33 52.18 278.07 2,830.53 2,684.20 351.40 -1,858.31 5,938,777.08 496,452.13 4.61 1,887.41 GYD-CT-CMS(1) 3,672.33 52.20 277.32 2,842.79 2,696.46 353.52 -1,873.97 5,938,779.20 496,436.47 2.96 1,903.21 GYD-CT-CMS(1) 3,692.33 52.32 277.70 2,855.03 2,708.70 355.58 -1,889.65 5,938,781.27 496,420.80 1.62 1,919.02 GYD-CT-CMS(1) 3,712.33 52.35 277.93 2,867.25 2,720.92 357.74 -1,905.34 5,938,783.43 496,405.11 0.92 1,934.85 GYD-CT-CMS(1) 3,732.33 52.86 277.39 2,879.40 2,733.07 359.85 -1,921.09 5,938,785.55 496,389.37 3.33 1,950.74 GYD-CT-CMS(1) 3,752.33 52.65 277.57 2,891.50 2,745.17 361.93 -1,936.87 5,938,787.62 496,373.58 1.27 1,966.66 GYD-CT-CMS(1) 3,772.33 52.33 277.60 2,903.68 2,757.35 364.02 -1,952.60 5,938,789.72 496,357.86 1.60 1,982.52 GYD-CT-CMS(1) 3,792.33 52.21 276.80 2,915.92 2,769.59 366.00 -1,968.29 5,938,791.71 496,342.17 3.22 1,998.34 GYD-CT-CMS(1) 3,812.33 51.95 276.73 2,928.21 2,781.88 367.86 -1,983.96 5,938,793.57 496,326.50 1.33 2,014.12 GYD-CT-CMS(1) 3,832.33 51.83 277.80 2,940.55 2,794.22 369.85 -1,999.57 5,938,795.56 496,310.90 4.25 2,029.86 GYD-CT-CMS(1) 3,852.33 51.49 277.03 2,952.96 2,806.63 371.88 -2,015.12 5,938,797.59 496,295.34 3.47 2,045.54 GYD-CT-CMS(1) 3,872.33 51.14 276.85 2,965.46 2,819.13 373.76 -2,030.62 5,938,799.48 496,279.85 1.89 2,061.15 GYD-CT-CMS(1) 3,892.33 51.23 277.46 2,978.00 2,831.67 375.70 -2,046.08 5,938,801.42 496,264.39 2.42 2,076.74 GYD-CT-CMS(1) 3,912.33 50.92 277.39 2,990.56 2,844.23 377.71 -2,061.51 5,938,803.44 496,248.96 1.57 2,092.30 GYD-CT-CMS(1) 3,932.33 50.95 276.48 3,003.17 2,856.84 379.59 -2,076.93 5,938,805.32 496,233.55 3.54 2,107.82 GYD-CT-CMS(1) 3,952.33 50.99 277.21 3,015.76 2,869.43 381.44 -2,092.35 5,938,807.17 496,218.12 2.84 2,123.36 GYD-CT-CMS(1) 3,972.33 50.77 277.18 3,028.38 2,882.05 383.38 -2,107.75 5,938,809.12 496,202.73 1.11 2,138.88 GYD-CT-CMS(1) 3,992.33 51.08 276.68 3,040.99 2,894.66 385.26 -2,123.16 5,938,810.99 496,187.32 2.48 2,154.40 GYD-CT-CMS(1) 4,012.33 50.66 276.57 3,053.61 2,907.28 387.05 -2,138.57 5,938,812.79 496,171.91 2.14 2,169.92 GYD-CT-CMS(1) 4,032.33 50.48 276.06 3,066.31 2,919.98 388.75 -2,153.92 5,938,814.49 496,156.56 2.17 2,185.36 GYD-CT-CMS(1) 4,052.33 50.50 276.65 3,079.04 2,932.71 390.45 -2,169.26 5,938,816.20 496,141.23 2.28 2,200.79 GYD-CT-CMS(1) 4,072.33 50.50 276.70 3,091.76 2,945.43 392.25 -2,184.59 5,938,818.00 496,125.90 0.19 2,216.22 GYD-CT-CMS(1) 4,092.33 50.36 275.62 3,104.50 2,958.17 393.90 -2,199.91 5,938,819.66 496,110.57 4.22 2,231.64 GYD-CT-CMS(1) 4,112.33 50.31 276.15 3,117.26 2,970.93 395.48 -2,215.23 5,938,821.24 496,095.26 2.06 2,247.03 GYD-CT-CMS(1) 4,132.33 50.13 276.55 3,130.06 2,983.73 397.18 -2,230.50 5,938,822.94 496,079.99 1.78 2,262.40 GYD-CT-CMS(1) 4,152.33 50.11 275.40 3,142.88 2,996.55 398.78 -2,245.77 5,938,824.54 496,064.73 4.41 2,277.75 GYD-CT-CMS(1) 4,172.33 50.13 275.62 3,155.71 3,009.38 400.25 -2,261.05 5,938,826.02 496,049.45 0.85 2,293.09 GYD-CT-CMS(1) 4,192.33 50.25 276.42 3,168.51 3,022.18 401.86 -2,276.32 5,938,827.63 496,034.17 3.13 2,308.45 GYD-CT-CMS(1) 4,212.33 50.29 275.36 3,181.30 3,034.97 403.44 -2,291.62 5,938,829.21 496,018.88 4.08 2,323.83 GYD-CT-CMS(1) 4,232.33 50.08 275.38 3,194.10 3,047.77 404.88 -2,306.92 5,938,830.66 496,003.58 1.05 2,339.18 GYD-CT-CMS(1) 6/6/2011 8.08.11AM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2K-08 Project: Kuparuk River Unit TVD Reference: 2K-08A @ 146.33ft(D141) Site: Kuparuk 2K Pad MD Reference: 2K-08A @ 146.33ft(D141) Well: 2K-08 North Reference: True Wellbore: 2K-08A Survey Calculation Method: Minimum Curvature Design: 2K-08A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/100') (ft) Survey Tool Name 4,252.33 50.29 275.72 3,206.91 3,060.58 406.37 -2,322.21 5,938,832.14 495,988.29 1.68 2,354.54 GYD-CT-CMS(1) 4,272.33 50.25 275.69 3,219.69 3,073.36 407.89 -2,337.51 5,938,833.68 495,972.99 0.23 2,369.92 GYD-CT-CMS(1) 4,292.33 50.44 275.32 3,232.46 3,086.13 409.37 -2,352.84 5,938,835.16 495,957.67 1.71 2,385.31 GYD-CT-CMS(1) 4,312.33 51.20 276.02 3,245.09 3,098.76 410.90 -2,368.27 5,938,836.69 495,942.24 4.67 2,400.81 GYD-CT-CMS(1) 4,332.33 51.32 276.03 3,257.61 3,111.28 412.54 -2,383.78 5,938,838.33 495,926.73 0.60 2,416.40 GYD-CT-CMS(1) 4,352.33 51.78 275.31 3,270.04 3,123.71 414.09 -2,399.37 5,938,839.88 495,911.14 3.64 2,432.06 GYD-CT-CMS(1) 4,372.33 51.42 276.16 3,282.47 3,136.14 415.65 -2,414.96 5,938,841.45 495,895.55 3.79 2,447.73 GYD-CT-CMS(1) 4,392.33 51.37 276.13 3,294.95 3,148.62 417.33 -2,430.50 5,938,843.13 495,880.01 0.28 2,463.36 GYD-CT-CMS(1) 4,412.33 51.70 275.27 3,307.39 3,161.06 418.88 -2,446.08 5,938,844.69 495,864.43 3.75 2,479.01 GYD-CT-CMS(1) 4,432.33 51.70 275.63 3,319.78 3,173.45 420.37 -2,461.71 5,938,846.18 495,848.81 1.41 2,494.70 GYD-CT-CMS(1) 4,452.33 51.26 276.10 3,332.24 3,185.91 421.97 -2,477.27 5,938,847.78 495,833.25 2.87 2,510.35 GYD-CT-CMS(1) 4,472.33 51.53 275.18 3,344.72 3,198.39 423.51 -2,492.83 5,938,849.32 495,817.70 3.84 2,525.97 GYD-CT-CMS(1) 4,492.33 51.46 275.11 3,357.17 3,210.84 424.91 -2,508.42 5,938,850.73 495,802.11 0.44 2,541.61 GYD-CT-CMS(1) 4,512.33 51.39 275.87 3,369.64 3,223.31 426.41 -2,523.98 5,938,852.23 495,786.55 2.99 2,557.24 GYD-CT-CMS(1) 4,532.33 51.49 275.22 3,382.11 3,235.78 427.92 -2,539.55 5,938,853.74 495,770.98 2.59 2,572.88 GYD-CT-CMS(1) 4,552.33 51.37 274.75 3,394.58 3,248.25 429.28 -2,555.12 5,938,855.11 495,755.41 1.93 2,588.50 GYD-CT-CMS(1) 4,572.33 51.52 275.65 3,407.04 3,260.71 430.69 -2,570.70 5,938,856.53 495,739.83 3.60 2,604.14 GYD-CT-CMS(1) 4,592.33 51.50 275.24 3,419.49 3,273.16 432.18 -2,586.28 5,938,858.02 495,724.25 1.61 2,619.78 GYD-CT-CMS(1) 4,612.33 51.42 274.63 3,431.95 3,285.62 433.53 -2,601.87 5,938,859.36 495,708.67 2.42 2,635.42 GYD-CT-CMS(1) 4,632.33 51.51 275.34 3,444.41 3,298.08 434.88 -2,617.45 5,938,860.73 495,693.09 2.81 2,651.05 GYD-CT-CMS(1) 4,652.33 51.43 275.52 3,456.87 3,310.54 436.37 -2,633.03 5,938,862.21 495,677.51 0.81 2,666.69 GYD-CT-CMS(1) 4,672.33 51.46 274.56 3,469.33 3,323.00 437.74 -2,648.61 5,938,863.59 495,661.93 3.76 2,682.32 GYD-CT-CMS(1) 4,692.33 51.42 275.15 3,481.80 3,335.47 439.06 -2,664.19 5,938,864.92 495,646.35 2.32 2,697.95 GYD-CT-CMS(1) 4,712.33 51.42 275.57 3,494.27 3,347.94 440.52 -2,679.76 5,938,866.38 495,630.79 1.64 2,713.58 GYD-CT-CMS(1) 4,732.33 51.34 274.51 3,506.76 3,360.43 441.90 -2,695.32 5,938,867.76 495,615.23 4.16 2,729.19 GYD-CT-CMS(1) 4,752.33 51.35 274.95 3,519.25 3,372.92 443.18 -2,710.89 5,938,869.05 495,599.66 1.72 2,744.80 GYD-CT-CMS(1) 4,772.33 51.39 275.49 3,531.73 3,385.40 444.61 -2,726.45 5,938,870.47 495,584.11 2.12 2,760.41 GYD-CT-CMS(1) 4,792.33 51.37 274.78 3,544.22 3,397.89 446.00 -2,742.01 5,938,871.87 495,568.54 2.78 2,776.03 GYD-CT-CMS(1) 4,812.33 51.29 274.75 3,556.71 3,410.38 447.30 -2,757.57 5,938,873.17 495,552.98 0.42 2,791.63 GYD-CT-CMS(1) 4,832.33 51.41 275.51 3,569.21 3,422.88 448.70 -2,773.13 5,938,874.57 495,537.43 3.03 2,807.24 GYD-CT-CMS(1) 4,852.33 51.44 274.92 3,581.68 3,435.35 450.12 -2,788.70 5,938,876.00 495,521.86 2.31 2,822.87 GYD-CT-CMS(1) 4,872.33 51.16 274.58 3,594.18 3,447.85 451.41 -2,804.25 5,938,877.29 495,506.31 1.93 2,838.47 GYD-CT-CMS(1) 4,892.33 51.34 275.19 3,606.70 3,460.37 452.74 -2,819.79 5,938,878.63 495,490.77 2.54 2,854.05 GYD-CT-CMS(1) 4,912.33 51.20 274.88 3,619.21 3,472.88 454.11 -2,835.34 5,938,880.00 495,475.23 1.40 2,869.65 GYD-CT-CMS(1) 4,932.33 51.16 274.05 3,631.75 3,485.42 455.32 -2,850.87 5,938,881.22 495,459.70 3.24 2,885.21 GYD-CT-CMS(1) 4,952.33 51.21 274.94 3,644.29 3,497.96 456.54 -2,866.41 5,938,882.44 495,444.16 3.48 2,900.78 GYD-CT-CMS(1) 4,972.33 50.93 274.74 3,656.85 3,510.52 457.86 -2,881.91 5,938,883.76 495,428.66 1.60 2,916.33 GYD-CT-CMS(1) 4,992.33 51.13 274.30 3,669.43 3,523.10 459.08 -2,897.41 5,938,884.98 495,413.16 1.98 2,931.86 GYD-CT-CMS(1) 5,012.33 50.93 274.71 3,682.01 3,535.68 460.30 -2,912.91 5,938,886.21 495,397.66 1.88 2,947.39 GYD-CT-CMS(1) 5,032.33 51.14 274.09 3,694.59 3,548.26 461.50 -2,928.42 5,938,887.41 495,382.16 2.63 2,962.93 GYD-CT-CMS(1) 6/6/2011 8:08:11AM Page 8 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2K-08 Project: Kuparuk River Unit TVD Reference: 2K-08A @ 146.33ft(D141) Site: Kuparuk 2K Pad MD Reference: 2K-08A @ 146.33ft(D141) Well: 2K-08 North Reference: True Wellbore: 2K-08A Survey Calculation Method: Minimum Curvature Design: 2K-08A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,052.33 50.93 274.41 3,707.16 3,560.83 462.65 -2,943.92 5,938,888.56 495,366.65 1.63 2,978.46 GYD-CT-CMS(1) 5,072.33 50.95 274.93 3,719.77 3,573.44 463.91 -2,959.40 5,938,889.83 495,351.18 2.02 2,993.98 GYD-CT-CMS(1) 5,092.33 51.02 273.83 3,732.36 3,586.03 465.10 -2,974.90 5,938,891.02 495,335.69 4.29 3,009.50 GYD-CT-CMS(1) 5,112.33 51.08 274.49 3,744.93 3,598.60 466.23 -2,990.41 5,938,892.15 495,320.17 2.58 3,025.03 GYD-CT-CMS(1) 5,132.33 49.86 275.67 3,757.66 3,611.33 467.59 -3,005.77 5,938,893.52 495,304.81 7.61 3,040.45 GYD-CT-CMS(1) 5,152.33 50.31 276.39 3,770.49 3,624.16 469.20 -3,021.03 5,938,895.13 495,289.56 3.56 3,055.78 GYD-CT-CMS(1) 5,172.33 50.17 276.10 3,783.28 3,636.95 470.88 -3,036.31 5,938,896.81 495,274.28 1.32 3,071.16 GYD-CT-CMS(1) 5,192.33 50.28 277.12 3,796.08 3,649.75 472.65 -3,051.58 5,938,898.58 495,259.01 3.96 3,086.53 GYD-CT-CMS(1) 5,212.33 50.19 276.47 3,808.87 3,662.54 474.47 -3,066.85 5,938,900.40 495,243.75 2.54 3,101.90 GYD-CT-CMS(1) 5,232.33 50.08 275.95 3,821.69 3,675.36 476.13 -3,082.11 5,938,902.07 495,228.49 2.07 3,117.25 GYD-CT-CMS(1) 5,252.33 50.35 276.94 3,834.49 3,688.16 477.85 -3,097.38 5,938,903.80 495,213.22 4.04 3,132.62 GYD-CT-CMS(1) 5,272.33 50.01 276.08 3,847.30 3,700.97 479.59 -3,112.64 5,938,905.54 495,197.96 3.71 3,147.98 GYD-CT-CMS(1) 5,292.33 50.39 276.79 3,860.10 3,713.77 481.32 -3,127.91 5,938,907.27 495,182.69 3.32 3,163.34 GYD-CT-CMS(1) 5,312.33 50.29 276.51 3,872.87 3,726.54 483.10 -3,143.20 5,938,909.05 495,167.40 1.19 3,178.74 GYD-CT-CMS(1) 5,332.33 50.26 275.81 3,885.65 3,739.32 484.75 -3,158.50 5,938,910.71 495,152.11 2.70 3,194.12 GYD-CT-CMS(1) 5,352.33 50.38 276.82 3,898.42 3,752.09 486.44 -3,173.79 5,938,912.40 495,136.81 3.93 3,209.51 GYD-CT-CMS(1) 5,372.33 50.34 276.47 3,911.18 3,764.85 488.22 -3,189.09 5,938,914.19 495,121.52 1.36 3,224.91 GYD-CT-CMS(1) 5,392.33 50.39 275.67 3,923.94 3,777.61 489.85 -3,204.41 5,938,915.82 495,106.20 3.09 3,240.31 GYD-CT-CMS(1) 5,412.33 50.30 276.60 3,936.70 3,790.37 491.50 -3,219.72 5,938,917.47 495,090.89 3.61 3,255.71 GYD-CT-CMS(1) 5,432.33 50.25 276.44 3,949.48 3,803.15 493.25 -3,235.00 5,938,919.22 495,075.61 0.66 3,271.09 GYD-CT-CMS(1) 5,452.33 50.57 275.76 3,962.23 3,815.90 494.88 -3,250.33 5,938,920.86 495,060.29 3.07 3,286.50 GYD-CT-CMS(1) 5,472.33 50.28 277.24 3,974.97 3,828.64 496.63 -3,265.64 5,938,922.61 495,044.98 5.89 3,301.91 GYD-CT-CMS(1) 5,492.33 50.81 277.77 3,987.68 3,841.35 498.64 -3,280.95 5,938,924.63 495,029.67 3.35 3,317.36 GYD-CT-CMS(1) 5,512.33 50.41 279.69 4,000.37 3,854.04 500.99 -3,296.23 5,938,926.98 495,014.39 7.68 3,332.80 GYD-CT-CMS(1) 5,532.33 50.35 280.34 4,013.13 3,866.80 503.67 -3,311.40 5,938,929.66 494,999.23 2.52 3,348.19 GYD-CT-CMS(1) 5,552.33 50.55 281.42 4,025.86 3,879.53 506.58 -3,326.54 5,938,932.57 494,984.08 4.28 3,363.58 GYD-CT-CMS(1) 5,572.33 50.41 280.34 4,038.59 3,892.26 509.49 -3,341.69 5,938,935.49 494,968.94 4.22 3,378.97 GYD-CT-CMS(1) 5,592.33 50.49 280.57 4,051.32 3,904.99 512.29 -3,356.86 5,938,938.29 494,953.77 0.97 3,394.36 GYD-CT-CMS(1) 5,612.33 50.68 281.15 4,064.02 3,917.69 515.20 -3,372.03 5,938,941.21 494,938.60 2.43 3,409.78 GYD-CT-CMS(1) 5,632.33 50.60 280.66 4,076.71 3,930.38 518.13 -3,387.22 5,938,944.13 494,923.42 1.94 3,425.21 GYD-CT-CMS(1) 5,652.33 50.38 279.77 4,089.43 3,943.10 520.86 -3,402.40 5,938,946.87 494,908.23 3.61 3,440.62 GYD-CT-CMS(1) 5,672.33 50.49 280.72 4,102.17 3,955.84 523.61 -3,417.57 5,938,949.62 494,893.06 3.70 3,456.01 GYD-CT-CMS(1) 5,692.33 50.57 280.56 4,114.88 3,968.55 526.46 -3,432.75 5,938,952.47 494,877.89 0.74 3,471.42 GYD-CT-CMS(1) 5,712.33 50.24 279.66 4,127.63 3,981.30 529.16 -3,447.92 5,938,955.18 494,862.72 3.84 3,486.81 GYD-CT-CMS(1) 5,732.33 50.80 280.84 4,140.35 3,994.02 531.91 -3,463.11 5,938,957.93 494,847.54 5.35 3,502.22 GYD-CT-CMS(1) 5,752.33 50.32 279.21 4,153.05 4,006.72 534.60 -3,478.32 5,938,960.62 494,832.33 6.74 3,517.64 GYD-CT-CMS(1) 5,772.33 50.33 280.87 4,165.82 4,019.49 537.28 -3,493.48 5,938,963.31 494,817.17 6.39 3,533.02 GYD-CT-CMS(1) 5,792.33 50.34 280.12 4,178.59 4,032.26 540.09 -3,508.61 5,938,966.12 494,802.04 2.89 3,548.38 GYD-CT-CMS(1) 5,812.33 50.38 279.27 4,191.35 4,045.02 542.68 -3,523.79 5,938,968.71 494,786.86 3.28 3,563.77 GYD-CT-CMS(1) 5,832.33 50.36 280.84 4,204.10 4,057.77 545.37 -3,538.96 5,938,971.41 494,771.70 6.05 3,579.15 GYD-CT-CMS(1) 6/6/2011 8:08:11AM Page 9 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2K-08 Project: Kuparuk River Unit TVD Reference: 2K-08A @ 146.33ft(D141) Site: Kuparuk 2K Pad MD Reference: 2K-08A @ 146.33ft(D141) Well: 2K-08 North Reference: True Wellbore: 2K-08A Survey Calculation Method: Minimum Curvature Design: 2K-08A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (n) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,852.33 49.70 279.72 4,216.95 4,070.62 548.11 -3,554.04 5,938,974.15 494,756.62 5.41 3,594.45 GYD-CT-CMS(1) 5,872.33 50.70 279.72 4,229.75 4,083.42 550.70 -3,569.19 5,938,976.74 494,741.47 5.00 3,609.80 GYD-CT-CMS(1) 5,892.33 49.55 280.36 4,242.58 4,096.25 553.37 -3,584.30 5,938,979.42 494,726.36 6.25 3,625.13 GYD-CT-CMS(1) 5,912.33 49.74 278.98 4,255.53 4,109.20 555.93 -3,599.32 5,938,981.98 494,711.34 5.34 3,640.35 GYD-CT-CMS(1) 5,932.33 49.91 280.09 4,268.43 4,122.10 558.47 -3,614.39 5,938,984.52 494,696.27 4.32 3,655.62 GYD-CT-CMS(1) 5,952.33 49.95 279.79 4,281.30 4,134.97 561.11 -3,629.47 5,938,987.16 494,681.20 1.17 3,670.91 GYD-CT-CMS(1) 5,972.33 49.61 278.73 4,294.22 4,147.89 563.57 -3,644.54 5,938,989.63 494,666.13 4.39 3,686.17 GYD-CT-CMS(1) 5,992.33 49.83 280.06 4,307.15 4,160.82 566.06 -3,659.59 5,938,992.12 494,651.08 5.19 3,701.41 GYD-CT-CMS(1) 6,012.33 49.37 278.99 4,320.11 4,173.78 568.58 -3,674.61 5,938,994.64 494,636.06 4.68 3,716.63 GYD-CT-CMS(1) 6,032.33 49.72 279.55 4,333.09 4,186.76 571.03 -3,689.63 5,938,997.10 494,621.04 2.76 3,731.83 GYD-CT-CMS(1) 6,052.33 49.66 279.68 4,346.03 4,199.70 573.58 -3,704.67 5,938,999.65 494,606.01 0.58 3,747.07 GYD-CT-CMS(1) 6,072.33 49.77 278.53 4,358.96 4,212.63 575.99 -3,719.73 5,939,002.07 494,590.95 4.42 3,762.32 GYD-CT-CMS(1) 6,092.33 49.71 279.09 4,371.88 4,225.55 578.33 -3,734.82 5,939,004.41 494,575.87 2.16 3,777.57 GYD-CT-CMS(1) 6,112.33 49.37 279.65 4,384.86 4,238.53 580.80 -3,749.83 5,939,006.89 494,560.85 2.73 3,792.78 GYD-CT-CMS(1) 6,132.33 49.63 278.16 4,397.85 4,251.52 583.16 -3,764.85 5,939,009.24 494,545.83 5.81 3,807.98 GYD-CT-CMS(1) 6,152.33 48.63 278.60 4,410.94 4,264.61 585.36 -3,779.82 5,939,011.45 494,530.87 5.27 3,823.10 GYD-CT-CMS(1) 6,172.33 49.42 279.32 4,424.05 4,277.72 587.71 -3,794.73 5,939,013.81 494,515.96 4.79 3,838.19 GYD-CT-CMS(1) 6,192.33 48.75 278.32 4,437.15 4,290.82 590.03 -3,809.67 5,939,016.13 494,501.03 5.05 3,853.29 GYD-CT-CMS(1) 6,212.33 49.36 277.94 4,450.26 4,303.93 592.17 -3,824.62 5,939,018.27 494,486.07 3.37 3,868.40 GYD-CT-CMS(1) 6,232.33 48.72 279.20 4,463.37 4,317.04 594.42 -3,839.56 5,939,020.52 494,471.14 5.73 3,883.49 GYD-CT-CMS(1) 6,252.33 49.15 278.56 4,476.51 4,330.18 596.75 -3,854.45 5,939,022.85 494,456.25 3.23 3,898.57 GYD-CT-CMS(1) 6,272.33 48.79 277.59 4,489.64 4,343.31 598.87 -3,869.39 5,939,024.97 494,441.31 4.08 3,913.65 GYD-CT-CMS(1) 6,292.33 48.99 278.97 4,502.79 4,356.46 601.04 -3,884.30 5,939,027.15 494,426.40 5.29 3,928.71 GYD-CT-CMS(1) 6,312.33 48.49 279.90 4,515.98 4,369.65 603.50 -3,899.13 5,939,029.61 494,411.57 4.30 3,943.74 GYD-CT-CMS(1) 6,332.33 49.02 280.59 4,529.16 4,382.83 606.17 -3,913.93 5,939,032.29 494,396.78 3.71 3,958.75 GYD-CT-CMS(1) 6,352.33 48.92 281.46 4,542.29 4,395.96 609.06 -3,928.74 5,939,035.18 494,381.97 3.32 3,973.80 GYD-CT-CMS(1) 6,372.33 49.33 282.19 4,555.38 4,409.05 612.16 -3,943.54 5,939,038.28 494,367.17 3.44 3,988.87 GYD-CT-CMS(1) 6,392.33 49.92 281.96 4,568.34 4,422.01 615.35 -3,958.44 5,939,041.47 494,352.27 3.08 4,004.05 GYD-CT-CMS(1) 6,412.33 49.98 282.53 4,581.21 4,434.88 618.59 -3,973.40 5,939,044.72 494,337.31 2.20 4,019.30 GYD-CT-CMS(1) 6,432.33 49.72 281.44 4,594.10 4,447.77 621.77 -3,988.36 5,939,047.90 494,322.36 4.36 4,034.53 GYD-CT-CMS(1) 6,452.33 50.02 282.53 4,606.99 4,460.66 624.94 -4,003.31 5,939,051.08 494,307.41 4.43 4,049.76 GYD-CT-CMS(1) 6,472.33 49.93 282.56 4,619.85 4,473.52 628.27 -4,018.26 5,939,054.41 494,292.46 0.46 4,065.01 GYD-CT-CMS(1) 6,492.33 49.80 281.51 4,632.75 4,486.42 631.46 -4,033.22 5,939,057.60 494,277.51 4.07 4,080.24 GYD-CT-CMS(1) 6,512.33 50.45 282.56 4,645.57 4,499.24 634.66 -4,048.23 5,939,060.80 494,262.50 5.18 4,095.53 GYD-CT-CMS(1) 6,532.33 49.36 282.34 4,658.45 4,512.12 637.96 -4,063.17 5,939,064.10 494,247.56 5.51 4,110.76 GYD-CT-CMS(1) 6,552.33 50.11 282.34 4,671.38 4,525.05 641.22 -4,078.08 5,939,067.37 494,232.66 3.75 4,125.96 GYD-CT-CMS(1) 6,572.33 49.71 282.40 4,684.26 4,537.93 644.50 -4,093.02 5,939,070.65 494,217.71 2.01 4,141.19 GYD-CT-CMS(1) 6,592.33 50.44 282.25 4,697.09 4,550.76 647.77 -4,108.01 5,939,073.93 494,202.73 3.70 4,156.46 GYD-CT-CMS(1) 6,612.33 49.89 282.88 4,709.90 4,563.57 651.11 -4,123.00 5,939,077.27 494,187.74 3.66 4,171.75 GYD-CT-CMS(1) 6,632.33 50.33 281.55 4,722.73 4,576.40 654.36 -4,137.99 5,939,080.52 494,172.75 5.56 4,187.03 GYD-CT-CMS(1) 6/6/2011 8:08:11AM Page 10 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2K-08 Project: Kuparuk River Unit TVD Reference: 2K-08A @ 146.33ft(D141) Site: Kuparuk 2K Pad MD Reference: 2K-08A @ 146.33ft(D141) Well: 2K-08 North Reference: True Wellbore: 2K-08A Survey Calculation Method: Minimum Curvature Design: 2K-08A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 6,652.33 50.24 282.84 4,735.51 4,589.18 657.61 -4,153.03 5,939,083.77 494,157.71 4.98 4,202.36 GYD-CT-CMS(1) 6,672.33 50.50 283.22 4,748.27 4,601.94 661.08 -4,168.04 5,939,087.25 494,142.71 1.96 4,217.68 GYD-CT-CMS(1) 6,692.33 50.47 282.19 4,760.99 4,614.66 664.47 -4,183.09 5,939,090.64 494,127.66 3.98 4,233.03 GYD-CT-CMS(1) 6,712.33 50.63 282.81 4,773.70 4,627.37 667.82 -4,198.16 5,939,093.99 494,112.58 2.52 4,248.40 GYD-CT-CMS(1) 6,732.33 50.80 283.53 4,786.36 4,640.03 671.34 -4,213.24 5,939,097.52 494,097.51 2.91 4,263.80 GYD-CT-CMS(1) 6,752.33 50.64 282.41 4,799.03 4,652.70 674.82 -4,228.32 5,939,101.00 494,082.43 4.41 4,279.19 GYD-CT-CMS(1) 6,772.33 50.82 282.54 4,811.69 4,665.36 678.16 -4,243.44 5,939,104.35 494,067.31 1.03 4,294.61 GYD-CT-CMS(1) 6,792.33 50.95 283.56 4,824.30 4,677.97 681.67 -4,258.56 5,939,107.85 494,052.20 4.01 4,310.04 GYD-CT-CMS(1) 6,812.33 50.89 282.67 4,836.91 4,690.58 685.19 -4,273.68 5,939,111.38 494,037.08 3.47 4,325.48 GYD-CT-CMS(1) 6,832.33 50.82 282.20 4,849.54 4,703.21 688.53 -4,288.82 5,939,114.72 494,021.94 1.86 4,340.92 GYD-CT-CMS(1) 6,852.33 50.83 283.27 4,862.17 4,715.84 691.95 -4,303.95 5,939,118.14 494,006.82 4.15 4,356.35 GYD-CT-CMS(1) 6,872.33 51.14 283.04 4,874.76 4,728.43 695.48 -4,319.08 5,939,121.68 493,991.69 1.79 4,371.80 GYD-CT-CMS(1) 6,892.33 51.07 281.82 4,887.32 4,740.99 698.83 -4,334.28 5,939,125.04 493,976.49 4.76 4,387.30 GYD-CT-CMS(1) 6,912.33 51.21 283.44 4,899.87 4,753.54 702.24 -4,349.48 5,939,128.44 493,961.30 6.35 4,402.80 GYD-CT-CMS(1) 6,932.33 50.87 282.30 4,912.45 4,766.12 705.70 -4,364.64 5,939,131.91 493,946.14 4.75 4,418.27 GYD-CT-CMS(1) 6,952.33 51.49 282.85 4,924.98 4,778.65 709.10 -4,379.84 5,939,135.31 493,930.93 3.77 4,433.78 GYD-CT-CMS(1) 6,972.33 51.62 283.14 4,937.42 4,791.09 712.62 -4,395.11 5,939,138.83 493,915.67 1.31 4,449.36 GYD-CT-CMS(1) 6,992.33 51.24 281.74 4,949.89 4,803.56 715.99 -4,410.38 5,939,142.20 493,900.41 5.79 4,464.93 GYD-CT-CMS(1) 7,012.33 51.26 283.19 4,962.41 4,816.08 719.35 -4,425.61 5,939,145.57 493,885.18 5.65 4,480.45 GYD-CT-CMS(1) 7,032.33 51.05 282.25 4,974.95 4,828.62 722.78 -4,440.80 5,939,149.01 493,869.99 3.81 4,495.95 GYD-CT-CMS(1) 7,052.33 51.73 282.33 4,987.43 4,841.10 726.11 -4,456.07 5,939,152.34 493,854.72 3.41 4,511.52 GYD-CT-CMS(1) 7,072.33 50.33 281.55 5,000.01 4,853.68 729.33 -4,471.28 5,939,155.56 493,839.51 7.63 4,527.01 GYD-CT-CMS(1) 7,092.33 50.23 282.53 5,012.79 4,866.46 732.54 -4,486.33 5,939,158.77 493,824.47 3.80 4,542.33 GYD-CT-CMS(1) 7,112.33 50.26 281.44 5,025.58 4,879.25 735.73 -4,501.37 5,939,161.96 493,809.43 4.19 4,557.65 GYD-CT-CMS(1) 7,132.33 50.37 281.33 5,038.35 4,892.02 738.77 -4,516.46 5,939,165.01 493,794.34 0.69 4,573.00 GYD-CT-CMS(1) 7,152.33 48.99 281.92 5,051.29 4,904.96 741.84 -4,531.39 5,939,168.08 493,779.41 7.26 4,588.20 GYD-CT-CMS(1) 7,172.33 50.00 281.24 5,064.28 4,917.95 744.89 -4,546.29 5,939,171.14 493,764.51 5.67 4,603.36 GYD-CT-CMS(1) 7,192.33 48.75 280.25 5,077.31 4,930.98 747.72 -4,561.20 5,939,173.97 493,749.60 7.29 4,618.51 GYD-CT-CMS(1) 7,212.33 49.54 281.30 5,090.39 4,944.06 750.55 -4,576.06 5,939,176.80 493,734.74 5.60 4,633.60 GYD-CT-CMS(1) 7,232.33 49.23 279.87 5,103.41 4,957.08 753.34 -4,590.98 5,939,179.59 493,719.82 5.64 4,648.75 GYD-CT-CMS(1) 7,252.33 49.75 281.44 5,116.40 4,970.07 756.15 -4,605.93 5,939,182.41 493,704.88 6.51 4,663.93 GYD-CT-CMS(1) 7,272.33 51.31 280.73 5,129.11 4,982.78 759.12 -4,621.08 5,939,185.38 493,689.73 8.27 4,679.33 GYD-CT-CMS(1) 7,292.33 52.25 280.88 5,141.49 4,995.16 762.07 -4,636.51 5,939,188.33 493,674.30 4.74 4,695.01 GYD-CT-CMS(1) 7,312.33 53.15 280.95 5,153.61 5,007.28 765.08 -4,652.13 5,939,191.34 493,658.68 4.51 4,710.88 GYD-CT-CMS(1) 7,332.33 53.21 280.72 5,165.59 5,019.26 768.09 -4,667.86 5,939,194.36 493,642.96 0.97 4,726.86 GYD-CT-CMS(1) 7,352.33 52.91 279.93 5,177.61 5,031.28 770.95 -4,683.58 5,939,197.23 493,627.24 3.50 4,742.82 GYD-CT-CMS(1) 7,372.33 53.18 280.94 5,189.64 5,043.31 773.85 -4,699.30 5,939,200.12 493,611.52 4.26 4,758.77 GYD-CT-CMS(1) 7,392.33 52.43 280.41 5,201.73 5,055.40 776.80 -4,714.96 5,939,203.08 493,595.87 4.30 4,774.67 GYD-CT-CMS(1) 7,412.33 52.65 279.54 5,213.89 5,067.56 779.55 -4,730.59 5,939,205.83 493,580.24 3.62 4,790.52 GYD-CT-CMS(1) 7,432.33 52.30 280.79 5,226.07 5,079.74 782.35 -4,746.20 5,939,208.63 493,564.62 5.26 4,806.36 GYD-CT-CMS(1) 6/6/2011 8 08 11AM Page 11 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2K-08 Project: Kuparuk River Unit TVD Reference: 2K-08A @ 146.33ft(D141) Site: Kuparuk 2K Pad MD Reference: 2K-08A @ 146.33ft(0141) Well: 2K-08 North Reference: True Wellbore: 2K-08A Survey Calculation Method: Minimum Curvature Design: 2K-08A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,434.00 52.36 280.77 5,227.09 5,080.76 782.60 -4,747.50 5,939,208.88 493,563.33 3.72 4,807.68 MWD+IFR-AK-CAZ-SC(2) 7,485.49 60.96 277.89 5,255.37 5,109.04 789.51 -4,789.91 5,939,215.80 493,520.92 17.34 4,850.62 MWD+IFR-AK-CAZ-SC(2) 7,538.34 62.13 275.20 5,280.56 5,134.23 794.80 -4,836.07 5,939,221.10 493,474.77 4.99 4,897.07 MWD+IFR-AK-CAZ-SC(2) 7,626.99 61.37 277.06 5,322.52 5,176.19 803.13 -4,913.71 5,939,229.45 493,397.14 2.04 4,975.15 MWD+IFR-AK-CAZ-SC(2) 7,669.60 60.52 275.37 5,343.21 5,196.88 807.17 -4,950.73 5,939,233.50 493,360.12 4.00 5,012.39 MWD+IFR-AK-CAZ-SC(2) 7,720.00 62.43 278.69 5,367.28 5,220.95 812.60 -4,994.67 5,939,238.93 493,316.19 6.92 5,056.66 MWD+IFR-AK-CAZ-SC(3) 7,763.46 62.99 275.11 5,387.22 5,240.89 817.23 -5,033.00 5,939,243.58 493,277.86 7.43 5,095.27 MWD+IFR-AK-CAZ-SC(3) 7,808.27 63.83 274.08 5,407.27 5,260.94 820.44 -5,072.95 5,939,246.80 493,237.93 2.78 5,135.31 MWD+IFR-AK-CAZ-SC(3) 7,856.31 63.95 274.64 5,428.42 5,282.09 823.72 -5,115.96 5,939,250.08 493,194.92 1.08 5,178.40 MWD+IFR-AK-CAZ-SC(3) 7,951.31 65.14 273.54 5,469.25 5,322.92 829.83 -5,201.51 5,939,256.22 493,109.37 1.63 5,264.06 MWD+IFR-AK-CAZ-SC(3) 8,045.38 64.32 272.61 5,509.40 5,363.07 834.40 -5,286.46 5,939,260.80 493,024.44 1.25 5,348.92 MWD+IFR-AK-CAZ-SC(3) 8,139.81 65.00 273.20 5,549.82 5,403.49 838.73 -5,371.69 5,939,265.15 492,939.21 0.92 5,434.04 MWD+IFR-AK-CAZ-SC(3) 8,232.21 64.60 272.54 5,589,16 5,442.83 842.91 -5,455.19 5,939,269.35 492,855.72 0.78 5,517.42 MWD+IFR-AK-CAZ-SC(3) 8,325.67 64.10 272.61 5,629.62 5,483.29 846.70 -5,539.36 5,939,273.15 492,771.57 0.54 5,601.41 MWD+IFR-AK-CAZ-SC(3) 8,415.77 64.60 272.20 5,668.62 5,522.29 850.11 -5,620.51 5,939,276.58 492,690.43 0.69 5,682.36 MWD+IFR-AK-CAZ-SC(3) 8,514.02 65.31 269.88 5,710.22 5,563.89 851.72 -5,709.49 5,939,278.21 492,601.45 2.26 5,770.88 MWD+IFR-AK-CAZ-SC(3) 8,608.83 65.88 267.75 5,749.39 5,603.06 849.93 -5,795.81 5,939,276.44 492,515.14 2.13 5,856.32 MWD+IFR-AK-CAZ-SC(3) 8,703.23 64.80 266.61 5,788.78 5,642.45 845.71 -5,881.49 5,939,272.24 492,429.47 1.59 5,940.83 MWD+IFR-AK-CAZ-SC(3) 8,796.98 65.58 266.83 5,828.12 5,681.79 840.84 -5,966.45 5,939,267.39 492,344.52 0.86 6,024.55 MWD+IFR-AK-CAZ-SC(3) 8,891.69 66.81 267.95 5,866.35 5,720.02 836.90 -6,053.01 5,939,263.47 492,257.97 1.69 6,109.97 MWD+IFR-AK-CAZ-SC(3) 8,986.77 65.83 267.45 5,904.53 5,758.20 833.41 -6,140.01 5,939,260.00 492,170.97 1.14 6,195.88 MWD+IFR-AK-CAZ-SC(3) 9,081.56 65.49 266.83 5,943.60 5,797.27 829.10 -6,226.27 5,939,255.71 492,084.72 0.70 6,280.96 MWD+IFR-AK-CAZ-SC(3) 9,175.08 65.27 267.46 5,982.56 5,836.23 824.86 -6,311.18 5,939,251.50 491,999.82 0.66 6,364.71 MWD+IFR-AK-CAZ-SC(3) 9,270.17 64.53 266.67 6,022.90 5,876.57 820.46 -6,397.17 5,939,247.11 491,913.83 1.08 6,449.51 MWD+IFR-AK-CAZ-SC(3) 9,366.65 64.06 266.42 6,064.75 5,918.42 815.22 -6,483.95 5,939,241.89 491,827.06 0.54 6,534.98 MWD+IFR-AK-CAZ-SC(3) 9,403.48 63.56 266.08 6,081.00 5,934.67 813.06 -6,516.93 5,939,239.74 491,794.09 1.59 6,567.45 MWD+IFR-AK-CAZ-SC(3) 9,441.00 63.56 266.08 6,097.71 5,951.38 810.76 -6,550.44 5,939,237.45 491,760.57 0.00 6,600.43 PROJECTED to TD 6/6/2011 8:08:11 AM Page 12 COMPASS 2003.16 Build 69 SlfAlfE CHF SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Chip Alvord Drilling Engineer ConocoPhillips Alaska, Inc. v ' I P.O. Box 100360 f I Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K-08A Sundry Number: 311-192 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this day of June, 2011. Encl. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 June 1st,2011 Alaska Oil and Gas Conservation Commission p•. �� 333 West 7th Avenue, Suite 100 Rr_-� Anchorage,Alaska 99501 JUN 0 2 201 Re: SundryPermit,Change of Approved Plan PP Matta Ott& Crag Cork. Commission • Dear Commissioner: , riCII>>In ConocoPhillips Alaska,Inc.hereby applies for a Sundry to change approved program for 2K-08A.The modification will be to Sundry#311-155 defining casing program and cement quantity. On May 10,2011 verbal approval from the Commission was received for a change approved program to PTD#211-049. The change requested was to top set the Kuparuk due to an open hole leak off below the required minimum. Several attempts to run a 5-1/2"liner to the top of the Kuparuk were unsuccessful. The failed liner runs have resulted in the request to change approved program for Sundry#311-155. CPAI is seeking approval to run a 4-1/2"liner in place of the 5-1/2". CPAI is proposing the following plan: 1. Drill 6-1/8"hole from top of window at 7434' MD to 9444' MD(50' MD from top of Kuparuk) 2. Run 4-1/2"liner and cement to liner top. TOL: 7234' MD/5104' TVD and shoe: 9434' MD/6102' TVD 3. Run 4-1/2"gas lift completion and sting into tie back seal assembly in 4-1/2"liner top. 4. Rig down and move off. Note:the rotary sidetrack will not penetrate the Kuparuk reservoir. • Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-403 2. Proposed 4-1/2"liner plan forward. 3. Proposed 2K-08A schematic Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035(a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Elmo Cecchetti at 263-4249 or Chip Alvord at 265-6120. Si cerely, 6Aelift Elmo Cecchetti Drilling Engineer STATE OF ALASKA �,� (g RECEIVECV ALASKA AND GAS CONSERVATION COMMISSIG._ ' APPLICATION FOR SUNDRY APPROVALS sfl AJV 0 2 ?Uhl 20 AAC 25.280 '! P 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well F-AI�i81R a4li ,�} 'gbi ogINI ISS,On Suspend r Rug Perforations r Perforate r Pull Tubing r AFIC,Plefai(tnsion r Operational Shutdown F7 , Re-enter Susp.Well r Stimulate r Alter casing r r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r' Exploratory r - 211-049 • 3.Address: Stratigraphic r Service r 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 s 50-103-20111-01-00 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes:KPA:23800' Spacing Exception Required? Yes r No r .• 2K-08A • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25588,25589 ' Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9444 6106 I Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 16" 115' 115' Surface 3729' 9-5/8" 3770' 2905' 3520 psi 2020 psi Intermediate 7411' 7" 7452' 5238' 4980 psi 4330 psi Production /j;n lea Liner 6-6-14 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): None None Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) None None 12.Attachments: Description Summary of Proposal F7 13. Well Class after proposed work: Detailed Operator's Program r BOP Sketch r Exploratory r Development Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Drill to top of Kuparuk and run 4-1/2"liner-6-1-2011 Oil — P. - Gas r WDSPL r Suspended r 16.Verbal Approval: Yes Date:6.1.2011 WINJ r GINJ r WAG r Abandoned r Commission Representative: Guy Schwartz GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Elmo Cecchetti Printed Name Chip AlvordlvTitle: Drilling Engineer Signature 4,_t. �rd\ Phone:263-4249 Date:6.1.2011, Commission Use Only Sundry Number:3 ( Ho 9. Conditions of approval: Notify Commission so that a representative may witness Plug Integrity,�r BOP Test I� Mechanical Integrity Test r Location Clearance r Other: NO /- 5 C.,r.,,:Ss;el, 642_?'s--a.— re S l e)rGrc—ifie-s1.,..r` br j5ihi Pre) Sf:p&t.t +*c^s a.p,4. Subsequent Form Required: /D- q 047 (o tha) kidtr I1Gpa,rf) / r APPROVED BY / /'J� r /1 Approved by: / COMMISSIONER THE COMMISSION Date: (0 / 1 ppppm� A e,- !r Foriniv�a11l1�evi 11 120 4.‘,// ORIGINAL Submit in D p ice �Q440 !/ y Change Approved Program from Sundry 311-155 Procedure for top setting the Kuparuk with 4-1/2" 1. Directionally drill 6-1/8"hole from top of window at 7,434'MD/5,226'TVD to 9,444'MD/6,106'TVD(50'MD/21' TVD from top of Kuparuk) 2. At total depth,circulate hole clean and weight mud system up from 10.5 ppg to 12.0 ppg. 3. Pull out of hole on elevators and rack back drill pipe and BHA. Pull wear bushing. 4. Pick up and run 71 joints of 4-1/2" 12.6#L-80 SLHT liner on 4"drill pipe. The top of liner will be placed at 7,234'MD/ 5,104'TVD allowing for 200'of overlap. 5. Cement liner to top with 15.8 ppg Class G slurry and 35%excess. Displace with drilling mud and set liner hanger. Slackoff and set liner top packer. Circulate out excess cement above liner. 6. Monitor well then pull out of hole.Lay down 4"drill pipe. 7. Run upper completion as per procedure below. Upper Completion Procedure 1. Rig up 4-1/2"tubing handling equipment. 2. Run 4-1/2"gas lift completion stinging tie-back seal assembly into the tie back extension at 7,245'MD/5,082'TVD. 3. Land tubing for space out.Un-sting and displace well to seawater. 4. Sting back into the tie back assembly and land tubing hanger.Run in lock down screws. 5. Pressure test annulus to 1000 psi to confirm TBE seals are stabbed in. Bleed down annulus. 6. With annulus open,pressure test 4-1/2"tubing to 3,500 psi for 30 minutes monitoring annulus for returns. Bleed down pressure in tubing to 3,000 psi. Pressure test 4-1/2"X 7"annulus to 3,500 psi for 30 minutes. 7. Bleed down tubing pressure to zero. With tubing open,annulus pressure should shear dump valve located at 7,100'MD/ 5,015'TVD. 8. Set BPV and test through inner annulus to 1,000 psi.Nipple down BOPE.Nipple up tree and pull BPV. Install test plug. Test tree to 250 psi low and 5,000 psi high,then test packoff to same. Pull test plug. 9. Freeze protect well by pumping a minimum of 95 bbls diesel down the 4-1/2"tubing x 7"casing annulus taking returns from tubing. Allow diesel to equalize at approximately 2,240'MD/2,000'TVD. 10. Shut in well. Monitor and record SICP and SITP. Set BPV and RDMO. Turn well over to Production via Handover Form. M Casing and Tubing Program Hole Section Hole Casing Weight Grade Connection Length Top Btm Size OD (lb/ft) MD/TVD MD/TVD Conductor 16" 62.5 H-40 Weld 80' Surface 35' 115'/ 115' Surface 12-1/4" 9-5/8" 36 J-55 BTC 3735' Surface 35' 3770'/2905' 1 Production 8-1/2" 7" 26 J-55 BTC 9396' Surface==27' 9423'/6378' Interm.#1 6-1/8" 4-1/2"Liner 12.6 L-80 SLHT 2200' 7234'/5104' 9434'/6102' o. o «, F',n Completion Tubing 4-1/2" 12.6 L-80 IBT-M 7206' Surface=28' 7234'/5104' Cementing Programs 4-1/2"Liner Uni-Slurry Cement System Preflush 20.0 bbls 8.4 ppg Chemical Wash Spacer 20.0 bbls 13 ppg MudPush II Lead Slurry 271.4 sacks 15.8 ppg Class G Cement+0.5%bwoc D167+0.2%bwoc D46,0.3%bwoc D65+0.01 gals/sx D177+ 0.2%bwoc D153 Displacement 109.9 bbls(Drill pipe is 78.4 bbls and liner displacement is 31.5 bbls=109.9 bbls) Lead Slurry Volumes Length Capacity Excess Total Total Total Mix Water (ft) (ft) (ft3) (sacks) (bbls) (bbls) Liner Cap 200 25.5 0% 25.5 22.0 4.5 2.7 6.276"X 4"DP Liner Lap 200 20.9 0% 20.9 18.0 3.8 2.2 I 6.276"x 4.50" Open Hole x Liner OD 2000 188.4 35% 254.3 219.3 45.3 26.6 6.125"x 4.50" Shoe Track ID 130 11.1 0% 11.1 9.6 2.0 1.2 3.958" Open Hole Below Shoe 10 2.0 35% 2.8 2.5 0.5 0.3 6.125" Total 314.6 271.4 56.1 33.0 Top of liner set at 7234'MD,liner shoe set at 9434'MD. Yield=1.16 ft3/sx Mix Water=5.093 gal/sx 2K-08A Top Set Rotary Sidetrack- CTD Setup Upper Completion Top MD/TVD 16"62.5#H-40 1) 4-Y2"X 1"KBG-2 GLM 3.833"ID TBD Arctic Pack 115'/ 115' 2) 4-'/2"X 1"KBG-2 GLM 3.833ID TBD 60 bbls-2222' Ors/ Rk6 3) 4-/2' X I"KBG-2 GLM 3.833"ID TBD 4) 4-%2"X I"KBG-2 GLM 3.833"ID TBD • 5) 4-%2"X 1"KBG-2 GLM 3.833"ID with SOV TBD • GL 6) 41/4"12.6#L-80 IBT-M • • 7) 4-'/2"12.6#L-80 "X"Nipple 3.813"ID Arctic Set I GL 8) 4-'/2"12.6#L-80 IBT-M Tubing Pup 29 bbls-1072' 9) Cross Over 4-%2"IBT-M box X 5"BTC pin 10) Tie Back Seal Assembly Bullet 5"BTC box X''/2 mule shoe GL • 9-5/8"36.0#J-55 3,770'/2,905' Lower Completion Top MD/TVD Original RKB 1) *Baker 5"X 7"L-80 HRD ZXP Liner Top Packer 7,234'/5,104' GL 2) *Baker 5"X 7"L-80 DG Flexlock Liner Hanger 4-1/2" 12.6#L-80 3) *80-40 Seal Bore Extension BTC with TKC couplings 4-Y2"Liner Top IBT-M SCC 4.92" 4) Coupling 5"TKC 7,234'/5 104' ...-.:5:: TOL-Surface 4) Cross Over 5"BTC-M pin X SLHT pin i 5) 4-'/2"12.6#L-80 SLHT pup joint 6) 4-Y2"12.6#L-80 SLHT casing 7) Cross Over SLHT box X Hydril 521 pin 8) Landing Collar Hydril 521 9) **Cross Over Hydril 521 box X BTC-M pin Sidetrack KOP10) **4-'/2"12.6#L-80 BTC-M casing(1 joint) thru window in 7" i 11) **4-'/2"Float Collar BTC-M 7,434'/5,226' 12) **4-'/2"12.6#L-80 BTC-M casing(2 joints) 13) **4-'/2" EZReam Float Shoe BTC-M box 9,434'/6,102' 111 *BTC pins have been modified for TKC couplings to allow higher torque. **Torque rings are to be installed in BTC couplings(shoe track) 7"Cement Retainer 7,452'/5,242' ,�,'' HRZ 8,665'/5,776' Sidetrack KOP Upper Kalubik 9,234'/6,017' thru window in 7" 7,512'/5,279' j Fault#1 9,279'/6,036' IiIIh Lower Kalubik 9,303'/6,046' MOM MINE , 7"Cement Retainer t 7,531'/5,294' • ......i6-1/8" Open Hole TD 7"Perforations 9,444'/6,106' Tubing Cut 7,526'-7,536' 40 7,668/5,370' ' Original RKB P&A TOC 3-%2"CIBP 7,720'Annulus -' 4-1/2" 12.6#L-80 SLHT liner 7,800'/5,449' 0 1/ `� :' Original RKB 8,248'Tubing 1-I Z (2,200') 9,434' MD/6,102'TVD MMG-2 Open D 8_'V"X 7"TOC L`"�� 8,248'/5,725' -y' s3oo'/5 756' C-Sand 9,493'/5,981' Original RKB 'Original RKB Baker HB Packer 8,8727 6,096' Original RKB 3-%2"CIBP 0 8,905'/6,114' Original RKB ....1. .� Perforations -, 9,012'9,012'-9,044' -40 Lira"- 9,022'-9,032' --411111 t...- 9,100'-9140' Driginal RKE Revised by: / 7"26#J-55 casing Elmo Cecchetti r1����/ 9,423'MD/6,378'TVD May 30, 2011 Original RF.' (Well PIan11) Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, June 01, 2011 10:13 AM To: 'Cecchetti, Elmo B' Cc: DOA AOGCC Prudhoe Bay Subject: RE: 2K-08A Request for Change Approved Program to Sundry#311-155 Elmo, You have verbal approval to change the casing program as outlined in the attached document. Please note that the original PTD will need to be updated to include the new CT drilling segment before drilling can recommence again with the CTD unit. Additionally, the well will be in an "Operational Shutdown"status once the 4 '/z" liner is set and you move off with the rotary rig. That request should also be indicated on the sundry form. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Cecchetti, Elmo B [mailto:Elmo.B.Cecchetti@conocophillips.com] Sent: Tuesday, May 31, 2011 4:42 PM To: Schwartz, Guy L (DOA) Subject: 2K-08A Request for Change Approved Program to Sundry #311-155 Mr. Schwartz, CPAI is requesting verbal approval to change approved program to Sundry#311-155. The request is to run a 4- 1/2" liner in place of the 5-1/2"due to numerous failed attempts to land the liner on bottom. Please see attached Sundry. The official hard copy will be mailed. Thank you, Elmo Cecchetti Drilling Engineer Conoco Phillips Alaska Inc. ATO 1564 Work (907)263-4249 Cell (907)903-3141 Fax (907)265-6916 6/1/2011 S1TAITE DEF ALASAA SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Chip Alvord Drilling Engineer69,1 O `� ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K-08A Sundry Number: 311-155 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 1° day of May, 2011. Encl. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 May 10th,2011 Alaska Oil and Gas Conservation Commission RECEIVED 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 AAA'Y 701' Re: Sundry Permit,Change of Approved Planr0� pjssl0n Alaska Q1� & Dear Commissioner: r7i11f1y881Ndri X11118-d ConocoPhillips Alaska,Inc.hereby applies for a sundry to change approved plan for 2K-08A Permit to Drill#211049. The modification will be to Section 18 defining casing program and cement quantity. ✓ On May 1,2011 the 2K-08 wellbore was sidetracked from the 7"casing at 7434' MD/5226' TVD and drilled to a total depth of 9434' MD/6079' TVD approximately 100' MD/40' TVD from top of Kuparuk. An open hole leak off was performed to 13.4 ppg EMW. The open hole test pressure leaked off below the minimum required of 15.0 ppg to penetrate the Kuparuk reservoir. With the unsuccessful LOT,top setting the Kuparuk with a 5-1/2"liner is needed. To top set the Kuparuk and continue drilling into the 12.0 ppg EMW reservoir,ConocoPhillips is proposing the ✓ following plan: 1. Run 5-1/2"liner and cement to liner top. TOL: 7234' MD,TOW: 7434'MD,& shoe:9424'MD 2. Drill 4-3/4"intermediate#2 to 9857' MD/6253'TVD. 3. Run 3-1/2"liner and cement to 9042'MD(500'MD above Kuparuk).TOL: 7144' MD&shoe: 9847' MD. 4. Run 3-1/2"gas lift completion and sting into seal bore assembly in 3-1/2"liner top. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-403 2. Proposed top setting procedure. 3. Proposed 2K-08A schematic Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Elmo Cecchetti at 263-4249 or Chip Alvord at 265-6120. Sincerely, 640 4eekth• Elmo Cecchetti Drilling Engineer ti A RECEIVED �tb MA2 STATE OF ALASKA Y 0 �. �' ALASKA OIL AND GAS CONSERVATION COMMISSION • APPLICATION FOR SUNDRY APPROVAL#a2ka Oil&688 Cans.GommissiOR 20 AAC 25.280 i'2.tf c t'•raga 1 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program p . Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Development F7, Bcpbratory r 211-049 • 3.Address: Stratigraphic r Service r 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20111-01-00 • 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes:KPA:23800' Spacing Exception Required? Yes r No F7 . 2K-08A • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25588;25589• Kuparuk River Field/Kuparuk River Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9434.4 6079.9 Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 16" 115' 115' Surface 3729' 9-5/8" 3770' 2905' 3520 psi 2020 psi Intermediate 7411' 7" 7452' 5238' 4980 psi 4330 psi Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): None None Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) None None 12.Attachments: Description Summary of Proposal ri 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development 17 Service r 14.Estimated Date for Commencing Operations: ✓ 15. Well Status after proposed work: Topsetting Kuparuk with 5-1/2"liner&cement-5-11-2011 Oil rI - Gas r WDSPL r Suspended r 16.Verbal Approval: Date: S•/o• N vow r GINJ r WAG r Abandoned r Commission Representative: 6711 .rc.i..«1 4!1 - GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Elmo Cecchetti Printed Name Chip Alvord Title: Drilling Engineer Signature At , Phone:263-4249 Date:5.10.2011 Commission Use Only Sundry Numbe ' I ,155 Conditions of approval: Notify Commission so that a representative may witness ✓✓ Plug Integrity r BOP Test It Mechanical Integrity Test r Location Clearance r /O-6U s.: act- 'TS-� Other: O j— k2S' es,: /4r....-4J - (t$7' Subsequent Form Required: /b_Yat:h.1 o7 co►++,o46"ft, I`tl•a l—/ 0 t• APPROVED BY / I Approved by: COMMISSIONER THE COMMISSION Date: S/ t. S•/7•// - S./(. // Form 10-40 pS O y 1•8101t-f Submit in Duplicate RIGINA % L I Change Approved Program for PTD 211-049 PP g Procedure for top setting the Kuparuk 1. With leak off at less than 15 ppg EMW at top of Kuparuk,pull out of hole with 6-1/8"bit and pick up under reamer. 2. Ream hole from 6-1/8"to 7"to assist with 5-1/2"liner running. Once on bottom,circulate until hole is clean. Pull out of hole and rack back drill pipe and BHA. Pull wear bushing. 3. Pick up and run 54 joints of 5-1/2"15.5#L-80 Hydril 511 liner on 4"drill pipe. The top of liner will be placed at 7,234'MD allowing for 200'of overlap. • 4. Cement liner to top with 15.8 ppg Class G slurry and 35%excess. Displace with drilling mud and set liner hanger.Slackoff and set liner top packer. Circulate out excess cement above liner. • 5. Monitor well then pull out of hole.Lay down enough drill pipe to leave 7,234'of 4"in the derrick. 6. Install 2-7/8"X 5"rams and test per drilling permit. ' 7. P/U 2-7/8"HT PAC drill pipe with 4-3/4"bit and production hole BHA. . 8. Run in hole and drill out shoe track and 20'of new hole(do not drill into C-sand). 9. Weight mud system up to 12.5 ppg and perform LOT. 10. Directionally drill the 4-3/4"hole to TD of 9857'MD/6253'TVD 11. At total depth,circulate hole clean and wiper trip to inside 5-1/2". Once back on bottom,circulate until hole is clean. Pull out of hole and lay down 2-7/8"and BHA. Pull wear bushing. 12. Pick up and run 88 joints of 3-1/2"9.3#L-80 Hydril 511 liner on 4"drill pipe. The top of liner will be placed at 7,144'MD,90'above 5-1/2"liner top. • 13. Cement liner to 9042'MD(500'MD above the Kuparuk)with 15.8 ppg Class G slurry and 35%excess. Displace with 12.5 ppg fluid and set liner hanger.Slackoff and set liner top packer. Circulate out excess cement above liner then displace wellbore to seawater. 14. Monitor well then pull out of hole,laying down drill pipe. 15. Run upper completion as per procedure below. Upper Completion Procedure 1. Rig up 3-1/2"tubing handling and SSSV equipment. 2. Run 3-1/2"gas lift completion stinging 80-40 seals into the seal bore extension at 7,196'MD/5,078'TVD and placing SSSV at 1,820' MD/1,712'TVD. , 3. Displace well to corrosion inhibited brine and land tubing for space out. , 4. After space out,sting back into the SBE and land tubing hanger.Run in lock down screws. . 5. Pressure test annulus to 1000 psi to confirm SBE seals are stabbed in. Bleed down annulus. 6. With annulus open,pressure test 3-1/2"tubing to 3,500 psi for 30 minutes monitoring annulus for returns. Bleed down pressure in tubing to 3,000 psi. Pressure test 3-1/2"X 7"annulus to 3,500 psi for 30 minutes. 7. Bleed down tubing pressure to zero. With tubing open,annulus pressure should shear dump valve located at 7,100'MD/5,015'TVD. • 8. Set BPV and test through inner annulus to 1,000 psi.Nipple down BOPE.Nipple up tree and pull BPV. Install test plug. Test tree to, 250 psi low and 5,000 psi high,then test packoff to same. Pull test plug. 9. Freeze protect well by pumping a minimum of 80 bbls diesel down the 3-1/2"tubing x 7"casing annulus taking returns from tubing. Allow diesel to equalize at approximately 2,240'MD/2,000'TVD. • 10. Shut in well. Monitor and record SICP and SITP. Set BPV and RDMO. Turn well over to Production via Handover Form. Casing and Tubing Program Hole Casing Weight Top Btm Hole Section Size OD (lb/ft) Grade Connection Length MD/TVD MD/TVD Conductor 16" 62.5 11-40 Weld 80' Surface;,35' 115'/ 115' Surface 12-1/4" 9-5/8" 36 J-55 BTC 3735' Surface=35' 3770'/2905' Production 8-1/2- 7- 26 J-55 BTC 9396' Surface,27' 9423'/6378' Interm.#1 7" 5-1/2"Liner 15.5 L-80 Hydril 511 2190' 7234'/5104' 9424'/6075' cn Interm.#2 4-3/4" 3-1/2"Liner 9.3 L-80 Hydril 511 2703' 7144'/5047' 9847'/6249' g., 1-" Completion Tubing 3-1/2" 9.3 L-80 EUE-M 7172' Surface=28' 7144'/5047' Cementing Programs 5-1/2"Liner Uni-Slurry Cement System Preflush 30.0 bbls 8.4 ppg Chemical Wash Spacer 30.0 bbls 13 ppg MudPush II Lead Slurry 285.7 sacks 15.8 ppg Class G Cement+0.5%bwoc D167+0.2%bwoc D46,0.3%bwoc D65+0.02 gals/sx D177+ 0.2%bwoc D153 Displacement 127.4 bbls(Drill pipe is 78.4 bbls and liner displacement is 49.0 bbls=127.4 bbls) Lead Slurry Volumes Length Capacity Excess Total Total Total Mix Water (ft) (ft) (ft) (sacks) (bbls) (bbls) Liner Cap 200 25.5 0% 25.5 22.0 4.5 2.7 6.276"X 4"DP Liner Lap 200 10.0 0% 10.0 8.7 1.8 1.1 6.276"x 5.50" Open Hole x Liner OD 1990 203.6 35% 274.8 236.9 49.0 28.7 7"x 5.50" Shoe Track ID 130 17.4 0% 17.4 15.0 3.1 1.8 4.95" Open Hole Below Shoe 10 2.7 35% 3.6 3.1 0.6 0.4 7" Total 331.3 285.7 59.0 34.7 Top of liner set at 7234'MD,liner shoe set at 9424'MD. Yield=1.16 ft3/sx Mix Water=5.074 gaUsx 3-1/2"Liner Gas BLOK Cement System Preflush None Spacer 10.0 bbls 14.0 ppg MudPush II Lead Slurry 54.7sacks 15.8 ppg Class G Cement+2 gal/sx D600G+0.4%bwoc D065+0.4%bwoc D047+0.02 gals/sx D177 Displacement 100.1 bbls(Drill pipe is 77.4 bbls and liner displacement is 22.7 bbls=100.1 bbls) Length Capacity Total Total Total Mix Water Lead Slurry Volumes (ft) (ft) Excess (ft) (sacks) (bbls) (bbls) Liner Lap 382 25.4 0% 25.4 21.7 4.6 1.5 4.95"x 3.50" Open Hole x Liner OD 423 23.8 35% 32.2 27.6 5.8 1.8 4-3/4"x 3.50" Shoe Track ID 95 4.6 0% 4.6 4.0 0.8 0.3 2.992" Open Hole Below Shoe 10 1.2 35% 1.6 1.4 0.3 0.1 4-3/4" Total 63.8 54.7 11.5 3.7 Top of liner set at 7144'MD,liner shoe set at 9847'MD,top of cement at 9042'MD(500'MD above Kuparuk) Yield=1.17 ft3/sx Mix Water=2.749 gaUsx 2K-08A Top Set Rotary Sidetrack - CTD Setup Il 16"62.5#H-40 Upper Completion Top MD/TVD Arctic Pack 115'/ 115' 1) 3-%z"TRMAXX-5-CMT SSSV 2.813"ID"X" 1,820'/ 1,712' 60 bbls-2222' _ Original R1,8 2) 3-%2'X 1-'/z"MMG GLM 2.867" ID TBD 3) 3-1/4"X 1-1/4"MMG GLM 2.867" ID TBD iill I 3-1/2"9.3#L-80 EUE-M 4) 3-V2"X 1-1/4"MMG GLM 2.867" ID TBD TOL-Surface 5) 3-%2"X 1-'/2"MMG GLM 2.867" ID TBD Arctic Set I • 6) 3-V2"X 1-1/4"MMG GLM 2.867" ID with SOV 7,100'/5,015' 29 bbls-1072' 7) 3-1/2"9.3#L-80 EUE-M I 8) 3-1/4"9.3#L-80 "X"Nipple 2.813" ID 9-5/8" 36.0#J-55 9) 3-'h"9.3#L-80 EUE Tubing Pup 3-'h"Liner Top O. �, 3,770'/2,905' 9)80-40 Bonded Seal Assembly with %2 mule shoe 7,196'/5,078' 7,144'/5,047' I I Lower Completion Top MD/TVD 1) Baker 5"X 7"L-80 C-2 ZXP Liner Top Packer 7,144'/5,087' 5-1/4"Liner Top 0 0 2) Baker 5"X 7"L-80 Flexlock Liner Hanger 7,234'/5,104' 3) Seal Bore Extension with TKC couplings 4) Cross Over SLHT pin X 5"TKC box 5) Cross Over 3-1/4"Hydril 511 Pin X SLHT Box 6) 3-1/4"9.3#L-80 Hydril 511 casing Sidetrack KOP 7) Cross Over IBT pin X Hydril 511 box thru window in 7" gm ,. 8) Landing Collar IBT 7,434'/5,226' EXi. 9) 3-1/4"Float Collar Hydril IBT 12LIEa 10) 3-1/4"9.3#L-80 IBT casing(2 joints) I 11) 3-1/4" Float Shoe IBT 9,847/6,249' CarrItt=1 t''r.t 1.-et: e t m j � i. HRZ 8,660'!5,767' 7"Cement Retainer , , 7,452'/5,242' :I. I. Sidetrack KOP Upper Kalubik 9,288'/6,022' thru window in 7" 7,512'/5,279' Fault#1 9,335'/6,041' MUM ii` Lower Kalubik 9,359'/6,051' 1011111k. , , 7"Cement Retainer Timimme 7,531'/5,294' I ! --- I I - 7" Perforations C-Sand 9,542'/6,125' Tubing Cut 7,526' 7,536' 7,668/5,370' Original RKB , P&A TOC 3-'/2 CIBP 7iii ,720'Annulus A-Sand 9,611'/6,153' 7,800'/5,449' 8,248'Tubing . Original RKB BI- _. j"' MMG-2 Open , „ " , A4-Sand 9,670'/6,177' 8,248'/5,725' s-/� 'X 7 TOC 5-1/2" 15.5#L-80 Hydril 511 liner ' Original RKB 8300nas,KE (2,190') 9,424' MD/6,075'TVD .. Landing Collar 9,752' 1 " Baker HB Packer 8,8727 6,096' A Original RKB 3-1/2"CP 3-1/2"9.3#L-80 Hydril 511 liner 4-3/4"Open Hole TD 8,905'/6,114' `< (2,703') 9,847' MD/6,249'TVD Original RKB ."- Perforations ' ' ' 9,857'MD/6,253'TVD -..10 IMIB► 9,012'-9,044' -.N P► 9,022'-9,032' -.all `► 9,100'-9,140' ,riginal RKB 7"26#J-55 casing Revised by: !!!!!� 9,423'MD/6,378'TVD Elmo Cecchetti May 9, 2011 Page l of l Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, May 10, 2011 9:09 AM To: 'Cecchetti, Elmo B' Subject: RE: Verbal Approval Request for Sundry to PTD#211049 Elmo, You have verbal approval to proceed with the change in program(top set 5 1/2" Liner) as submitted by email earlier. As per our conversation have the 403 sundry delivered to our office later today. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Cecchetti, Elmo B [mailto:Elmo.B.Cecchetti@conocophillips.com] Sent: Tuesday, May 10, 2011 8:59 AM To: Schwartz, Guy L (DOA) Subject: Verbal Approval Request for Sundry to PTD #211049 Mr. Schwartz, CPAI is requesting verbal approval to the attached Sundry for Change Approved Program to PTD#211049. The change in scope is for an open hole leak off test failing to meet required minimum pressure. As a result of the low leak off pressure, the Kuparuk reservoir will be top set with 5-1/2" liner. Please see Sundry for more details. Thank you, Elmo Cecchetti Drilling Engineer Conoco Phillips Alaska Inc. ATO 1564 Work (907)263-4249 Cell (907)903-3141 Fax (907)265-6916 5/17/2011 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, May 10, 2011 9:09 AM To: 'Cecchetti, Elmo B' Subject: RE: Verbal Approval Request for Sundry to PTD#211049 Elmo, You have verbal approval to proceed with the change in program(top set 51/2" Liner) as submitted by email earlier. As per our conversation have the 403 sundry delivered to our office later today. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Cecchetti, Elmo B [mailto:Elmo.B.Cecchetti@conocophillips.com] Sent: Tuesday, May 10, 2011 8:59 AM To: Schwartz, Guy L(DOA) Subject: Verbal Approval Request for Sundry to PTD #211049 Mr. Schwartz, CPAI is requesting verbal approval to the attached Sundry for Change Approved Program to PTD#211049. The change in scope is for an open hole leak off test failing to meet required minimum pressure. As a result of the low leak off pressure, the Kuparuk reservoir will be top set with 5-1/2" liner. Please see Sundry for more details. Thank you, Elmo Cecchetti Drilling Engineer Conoco Phillips Alaska Inc. ATO 1564 Work (907)263-4249 Cell (907)903-3141 Fax (907)265-6916 5/10/2011 Page l of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, April 12, 2011 9:42 AM To: 'Cecchetti, Elmo B' Subject: RE: 2K-08A Rotary Sidetrack Change in Whipstock Setting Depth (PTD 211-049) Elmo, As long as the well path stays within 500' radius of the permitted path no sundry change of program will be needed. Your casing length and cement will change marginally... Thanks for the update. This email notification is sufficient. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Cecchetti, Elmo B [mailto:Elmo.B.Cecchetti@conocophillips.com] Sent: Tuesday, April 12, 2011 9:21 AM To: Schwartz, Guy L(DOA) Subject: 2K-08A Rotary Sidetrack Change in Whipstock Setting Depth Mr. Schwartz, CPAI desires to change the top of the 7"window from 7966' MD to 7497' MD (469' MD). Would you like a sundry for change of approved program for the PTD 211-049? The cement volumes will be adjusted with the increase in hole length. Thank you, Elmo 4/12/2011 SICAITEE OT ALAMA SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K-08A ConocoPhillips Alaska, Inc. Permit No: 211-049 Surface Location: 121' FSL, 94' FEL, SEC. 02, T1ON, R8E Bottomhole Location: 1214' FSL, 1778' FEL, SEC. 03, T1ON, R8E Dear Mr. Alvord: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Chair DATED this U day of April, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVE W . W r STATE OF ALASKA AL ,KA OIL AND GAS CONSERVATION COMf4.._3ION APR 0 4 2011 PERMIT TO DRILL 20 AAC 25.005 Masks COI&bias Cons.Commission la.Type of Work: lb.Proposed Well Class: Development-Oil 2 • Service- Winj ❑ Single Zone Q • lc.Specify ipgesed for: Drill ❑ Redrill 2 Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp 0 Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑✓ Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc. Bond No. 59-52-180 • 2K-08AJ D uP.q,#' 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage AK 99510-0360 MD: 9920.0' • TVD: 6254.1' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 121'FSL, 94'FEL, Sec 2, T10N,R8E ADL 25588,25589 Kuparuk River Oil Pool Top of Productive Horizon(A-Sand): 8.Land Use Permit: 13.Approximate Spud Date: 1175'FSL,1494'FEL,Sec 3,T10N,R8E ALK 2674,2675 4/25/2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1214'FSL, 1778'FEL, Sec 3,T10N,R8E 2560 >1 Mile 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above I 146.5 , feet 15.Distance to Nearest Well Open Surface x-498,310.18''y- 5,938,425.3' • Zone-4 GL Elevation above! 118.5 feet to Same Pool: 2K-08,406' 16.Deviated wells: Kickoff depth: 7966 . feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 70.6 degrees Downhole: 4,008 • Surface: 3,395 • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 7" 3-1/2" 9.3# L-80 SLHT 2,150 7,760 5,427 9,910 6,250 486 sx Class"G" Tubing 3-1/2" 9.3# L-80 EUE-M 7,732 28 28 7,760 5,427 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 9,423 6,378 410 8,500 5,878 Casing Length Size Cement Volume MD TVD Conductor/Structural 74 16" 115 115 Surface 3,729 9-5/8" 2133 sx ASIII,595 sx Class"G" 3,770 2,905 Intermediate Production 9,382 7" 230 sx Class"G" 9,423 6,378 Liner Perforation Depth MD(ft; Perforation Depth TVD(ft): Plugged Plugged 20. Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis 0 Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Elmo Cecchetti 263-4249 el(„ Printed Name Chip Alvord Title Alaska Drilling Manager Signature / ' f .O k_. Phone 265-6120 Date ktt(2 ct f Commission Use Only Permit to Drill / / y�y, API Number: �� // ��/ M Permit Approv I See cover letter for other Number: Z/ ` / 50- U / D -c%c� Date: R I requirements. Conditions of approval: If box is checked,well maynot be used to explore for,test,orproduce coafb d methane, as hydrates,orgas contained in shales: �f PP .-� PY IJ Other: * 1-b oo �S` 5oP re-3 Samples req'd: Yes❑ o[ Mud log req'd: Yes ❑ No sr CF,�,�,,,,. H2S measures: Yes No Directional svy req'd: Yes [I�No 0 Am Ida, fr3 41 Zspp ps /--- 4- 7 / DATE:4.- APPROVED BY THE COMMISSION ,COMMISSIONER Y 7 it 1���/ Yb U Iui ' tL 1 Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate 2K-08A Rotary Sidetrack - CTD Setup El 16"62.5#H-40 Upper Completion Top MD/TVD Arctic Pack 115'MD/ 115'TVD 1) 3-'/2"TRMAXX-CMT SSSV 2.813" ID"X" 1,952/ 1,808' 60 bbls-2222' 2) 3-'/2"X 1-'/2"MMG GLM 2.867"ID 2,904'/2,400' 3) 3-'/z"X 1-%z"MMG GLM 2.867"ID 4,717'/3,500' 4) 3 'h"X 1-%2"MMG GLM 2.867"ID 5,982'/4,300' Arctic Set I 5) 3-'/2"X 1-%2"MMG GLM 2.867"ID 6,971'/4,900' 29 bbls-1072' 6) 3-'/2"X 1-%2"MMG GLM 2.867"ID with SOV 7,670'/5,363' 1 7) 3-'/2"9.3#L-80 EUE-M 9-5/8"36.0#J-55 8) 3-'/2"9.3#L-80 "X"Nipple 2.813"ID 7,700' 9) 3-'/2"9.3#L-80 EUE Tubing Pup 3,770'MD/2,905'TVD 9)80-40 Bonded Seal Assembly with'/2 mule shoe I Lower Completion Top MD/TVD 3-%2"Liner Top = �= 3-1/2"9.3#L-80 EUE-M 1) Baker 5"X 7" L-80 C-2 ZXP Liner Top Packer 7,760'/5,427' I 7,760'/5,427' 3`g % ConocoPhillips Alaska, Inc. y, Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 RECEIVED'ECc I\ ED April 1st 2011 APR 0 4 2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Atoka Qd &gas Cons. Commission Anchorage,Alaska 99501 Re: Application for Permit to Drill Rotary Sidetrack CTD Setup 2K-08A Producer Dear Commissioner: ConocoPhillips Alaska, Inc.hereby applies for a Permit to Drill/Sidetrack an onshore producer well from the 2K pad for CTD setup. The expected spud date for this well is April 25th,2011 conducting opera___ns with Doyon Rig 141. The 2K-08 wellbore is temporarily abandoned as per approved Sundry 311-064 with 13.4 bbls of cement placed inside att.-- the tubing and annulus from 8,500' to 8,873' MD. The proposed plan is to pull the un-cemented tubing and set a 7" --1 aL retainer at 7,984' MD with a permanent whipstock on top at 7,966' MD/5,549' TVD. Next, a 6-1/8"window will be 9 cut plus 20' of new formation. A formation integrity test will be performed to 16.0 ppg EMW,with a required minimum 0zi leak-off of 13.0 ppg EMW. r 144"" The intermediate section will then be drilled with a 6"by 7"bi-center bit to 9.431' MD/6,092' TVD(100' MD above �?•�� top of Kuparuk). An open hole formation integrity test will be performed with a minimum leak off of 15.0 ppg EMW. After a successful LOT,drilling will continue through the Kuparuk C and A sands landing in the A3 for a total depth of 9,920'MD/6,254' TVD. The intermediate section will be lined from 7,760' MD to 9,910' MD with 3-1/2"9.3#L-80. A 3-1/2"tubing completion will be landed in a seal bore receptacle at the liner top packer at 7,760' MD/5,427' TVD. Doyon 141 will then rig down and move off for, TD;to sidetrack in the A-sands. If the minimum open hole leak off of 15.0 ppg EMW is not obtained, a 10-403 Sundry will be submitted for"change approved program"to top set the Kuparuk. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Elmo Cecchetti at 263-4249 or Chip Alvord at 265-6120. Sipcere Elm4iji; o Cecchetti Drilling Engineer Application for Permit to Drill Document Kuparuk Well 2K-08A Well Name -rn 6"4" Requirements of 20 AAC 25.005(fl The well for which this application is submitted will be designated as 2K-08A. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identdying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 121'FSL, 94'FEL, Sec 2, T1ON,R8E,UM NGS Coordinates RKB Elevation 146.5'AMSL • Northings: 5,938,425.300' Eastings: 498,310..18' Pad Elevation 118.5'AMSL Location at Top of 1175'FSL, 1494'FEL,Sec 3,T1ON,R8E,UM Productive Interval (Kuparuk A Sand) NGS Coordinates Measured Depth, RKB: 9,616.2' Northings: 5,939,483.3' Eastings:491,630.1' Total Vertical Depth,RKB: 6,153.5' Total Vertical Depth, SS: 6,007.0' Location at Total Depth 1214'FSL, 1778'FEL, Sec 3,T1ON,R8E,UM NGS Coordinates Measured Depth, RKB: 9,920.0' Northings: 5,939,523.0' Eastings:491,346.4' Total Vertical Depth, RKB: 6,254.1' Total Vertical Depth, SS: 6,107.6' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan No close approach issues exist. Separation factors are above 1.5 once the sidetrack is greater than 100' MD beyond the window and continue to increase with depth. The 1/4"mile pool scan of the top of Kuparuk A6 sands show the closest approach to be the original 2K-08 wellbore 406'away at 9,445' MD. And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. JGINAL Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Doyon 141. III Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; 2K-08 commingled SIBHP(shut in 1800 hrs)was recorded for AC-sand in January 2011 at 4,008 psi, 12.5 ppg EMW(Top perforation of C-sand at 6171' TVD). Well has been shut in since year 2006 due to suspected casing and tubing collapse. The maximum potential surface pressure(MPSP)while drilling 2K-08A is calculated using above maximum reservoir pressure,a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk C sand at 6,125' TVD (WP6): AC-sand SIBHP =4,008 psi C-sand estimated depth(WP06) =6,125' TVD Gas Gradient =0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column =612.5 psi (6,125' TVD * 0.10 psi/ft) MPSP= SIBHP—gas column =3,395.5 psi (4,008 psi—612.5 psi) (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. And (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; See attached 2K-08A Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.0300; A procedure is on file with the commission for performing LOT's. For 2K-08A the formation integrity test will occur after milling the window and 20' of new formation. The formation at the window depth will be pressured until leak-off occurs or to 16.0 ppg EMW is reached,which ever comes first.A required minimum leak off of 13.0 ppg EMW must be obtained. After drilling the 7" intermediate to 9,431' MD/ ✓ 6,092' TVD (100' MD above top of Kuparuk) an open hole LOT/FIT will be performed. A minimum leak off of 15.0 ppg EMW is required to continue drilling to TD. If required leak off of 15 ppg EMW is not achieved, a 10-403 Sundry will be submitted for"change approved program"to top set the Kuparuk. ORIGINAL Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed Casing Program Casing Hole Weight Top Btm OD Size (lb/ft) Grade Connection Length MD/TVD MD/TVD 16" Conductor 62.5 H-40 Weld 80' Surface= 35' 115'/ 115' Original 9-5/8" 12-1/4" 36 J-55 BTC 3735' Surface z 35' 3770'/2905' Wellbore 7'(*) 8-1/2" 26 J-55 BTC 9396' Surface=27' 9423'/6378' Sidetrack 3-1/2"Liner 7" 9.3 L-80 SLHT 2150' 7760'/5427' 9910'/6250' Out of 7" Casing 3-1/2" Tubing 9.3 L-80 EUE-M 7732' Surface z'28' 7760'/5427' * Estimated top of cement behind 7"production casing at 8,300' MD. Single Stage Cement Program Cement will be placed from TD at 9,920' MD to top of liner. The liner shoe will be at 9,910' MD and the top of liner set at 7,760' MD with 200'of overlap. The slurry consists of 486.0 sacks of Class G cement plus additives at 15.8 ppg with 35%excess yielding 1.16 ft3/sx. Cement System Preflush: 30.0 bbls Chemical Wash Spacer: 30.0 bbls MudPush II Lead Slurry: 486.0 sacks Class G Cement+additives Yield= 1.16 ft3/sx Mix Water=5.073 gal/sx '/ Displacement: 102.0 bbls(Drill pipe is 84.1 bbls and liner displacement is 17.9 bbls= 102.0 bbls) Length Capacity Total Total Total Mix Water Slurry Volumes (ft) (ft3) Excess (ft3) (sacks) (bbls) (bbls) Liner Lap 200 29.6 0% 29.6 25.5 5.3 3.1 6.276"x 3.50" Open Hole x Liner OD 1944 389.7 35% 526.0 453.4 93.6 54.8 7"x 3.50" Shoe Track ID 95 4.6 0% 4.6 4.0 0.8 0.6 2.992" Open Hole Below Shoe 10 2.7 35% 3.6 3.1 0.6 0.4 7" Total 563.8 486.0 100.6 58.9 Diverter System Information Requirements of 20 AAC 25.005(c)(71 An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035,unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); This rotary sidetrack will exit pre-existing 7"casing at 7,966' MD. BOPE will be installed prior to exiting the casing, and therefore no diverter is required. OR1GfttL Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Mud Program Summary Depth MD Mud Wt. Funnel API Fluid (ft) (ppg) Vis(cp) PV YP Loss pH Comments (cc/30min) Milling Fluid 9.8 50-60 15-20 18-25 <12 9.0-9.5 Milling fluid can be reconditioned 7,966'—7,999' for dilling sidetrack LSND 9.8-13.0 • 60-80 25-40 15-20 <5 9.5-10 7,999'-9,920' Milling Fluid: A 9.8 ppg viscosified water based milling fluid consisting of pH control and weighting agents will be used to cut the 6-1/8"window and 20' of new formation. This fluid will maintain good rheology to remove metal fragments from the wellbore and prevent their recirculation. The milling fluid can be reconditioned for use in the sidetrack. Intermediate Sidetrack Fluid: A 9.8 ppg LSND drilling fluid with shale inhibitors will be used to drill to the top of the HRZ. At this depth, fluid weight will be increased to 11 ppg with spike fluid for wellbore stability. Drilling will • continue to the top of the Kuparuk(9,431' MD/6,092' TVD)where fluid weight will be increased to 13 1 ppg. The drilling mud weight is calculated using a commingled C and A-sands EMW of 12.5 ppg plus 0.5 ppg trip margin to result in a 13 ppg.Fluid weight will have sufficient density to overbalance the pressure of uncased formations penetrated. Additional focus will be on minimizing the potential of a hydrostatic pressure surge or swab and good hole cleaning practices. These practices include monitoring tripping speeds and PWD data, controlling ROP, pumping regular sweeps, adjusting rheology, and charting drag weights. Diagram of Doyon 141 Mud System on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A -Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A -Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A-Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska,Inc. is on file with the Commission. n 1GI � L 9'S)3V‘ 2K-08A Rotary Sidetrack(PTD 211-049)Program Outline g Pre Rig Work(Sundry#311-064): a. Slick line set XN plug at 8910'MD and pulled dummy valve from GLM#8. b. Coil tubing pumped 13.4 bbls Class G cement placing cement from XN plug at 8910'to 8500' inside the tubing and from the packer at 8873'to 8500' in the annulus. c. Slick line tag and pressure test cement plug to 2500 psi with AOGCC witness.A drawdown test was performed bleeding the tubing and IA to 0 psi. d. E-line cut tubing at 8274'MD placing cut near the middle of the first full joint below GLM#7. Diesel was pumped down the tubing to verify cut. - Tubing is freeze protected with 24 bbls of diesel(2772'MD). - Inner annulus is freeze protected with 73 bbls of diesel(2772' MD). - BPV and VR plug was set. 1. Move Doyon 141 on 2K-08 and rig up. 2. Pull BPV and VR plugs. Record tubing,IA,and OA pressures. Circulate out freeze protect through tubing cut at 8274' MD and monitor well for pressure. 3. Set BPV and nipple down tree. M/U blanking plug in tubing hanger and nipple up BOPE. • Notify AOGCC field inspector 24 hours prior to BOPE test. • Test BOPE to 250 psi low/4,000 psi high as per drilling permit/ 4. Pull blanking plug and BPV. Pull tubing hanger and lay down 3-1/2"completion. 5. Run 7"casing scraper to 8,274'MD. 6. Rig up E-line and run gyro/caliper in 7"casing to evaluate for subsidence related issues. 7. Using E-line,perforate 7"casing from 7995'-8005'MD(4'below collar)for cement squeeze. 8. With E-line set 7"cement retainer bottom at 7987'MD(4'above collar). 9. With 4"drill pipe squeeze 15 bbls cement(664')into perforations to assist with kickoff and LOT. 10. Test 7"casing and cement retainer to 3,500 psi,chart for 15 minutes. (Per request of AOGCC) 11. Nipple down BOP stack and tubing head using Hydra-tight system. Pull 7"packoff and expect casing growth. 12. Run 7"casing spear and engage 7"casing with overpull. Cut excess casing and reset slips with casing in 8k lbs tension. 13. Install 7"packoff,nipple up tubing head and BOP stack. Retest same. eo 14. Test 7"casing and CIBP to 3,500 psi,chart for 15 minutes. This will be used as a baseline for the FIT/LOT. 15. Pick up 7"whipstock/milling assembly. Run in hole and displace casing to milling fluid. Orient whipstock to 10 degrees left of high side. 16. Set whipstock and mill window in 7"plus 20' of new formation for FIT/LOT. Perform FIT with rig pump as per CPAI procedure to 16 ppg EMW. Minimum acceptable leak off is 13.0 ppg EMW. 17. Pull out of hole whipstock/milling assembly and gauge mills. If greater than 1/8"under,make a new mill run. 18. Pick-up and make up 6"X 7"Reed Hycalog bi-center bit with 4-3/4"L/MWD drilling BHA. 19. Run in hole with drilling BHA to top of window and displace to 9.8 ppg drilling mud. e! 20. Drill 7"hole from 7,966'MD to 9,431'MD(stop at 100'MD above C-sand). • Weight up to 11 ppg before top of HRZ at 8,451'MD/5,767' TVD. 21. Perform open hole leak off to 16.0 ppg EMW. Minimum acceptable leak off is 15.0 ppg EMW. • If pressure leaks off at greater than 15.0 EMW,weight up mud system to 13 ppg and continue drilling 7" intermediate#1 to TD of 9,920' MD/6,254'TVD. • If pressure leaks off at less than 15.0 EMW,a�104�1,5undry will be submitted for"change approved program" to top set the Kuparuk. 22. At total depth,circulate hole clean and wiper trip to window. Once back on bottom,circulate until hole is clean. Pull out of hole and rack back drill pipe and BHA. Pull wear bushing. 23. Pick up and run 70 joints of 3-1/2"9.3#L-80 SLHT liner on 4"drill pipe. The top of liner will be placed at 7,760'MD allowing for 200'of overlap. 24. Cement liner to top with 15.8 ppg Class G slurry and 35%excess. Displace with 13.0 ppg fluid and set liner hanger. Slackoff and set liner top packer. Circulate out excess cement above liner. • If there are signs of lost circulation prior to running casing,mix cello-flakes into cement slurry. 25. Monitor well then pull out of hole laying down drill pipe. 26. Run upper completion as per procedure below. Upper Completion Procedure 1. Rig up 3-1/2"tubing handling and SSSV equipment. 2. Run 3-1/2"gas lift completion stinging 80-40 seals into the seal bore extension at 7,780'MD/5,432'TVD and placing SSSV at 1,952'MD/1,808'TVD. 3. Displace well to corrosion inhibited brine and land tubing for space out. 4. Un-sting from SBE. Mix and spot 20 bbls corrosion inhibited seawater with 2%CRW-132 in the 3-1/2"X 7"annulus between the seal bore assembly and the bottom GLM(spot with sea water). 5. Sting back into the SBE and land tubing hanger.Run in lock down screws. 6. Pressure test annulus to 1000 psi to confirm SBE seals are stabbed in. Bleed down annulus. (L/ 7. With annulus open,pressure test 3-1/2"tubing to 2,500 psi for 30 minutes monitoring annulus for returns. Bleed down pressure in tubing to 2,000 psi. Pressure test 3-1/2"X 7"annulus to 2,500 psi for 30 minutes. 8. Bleed down tubing pressure to zero. With tubing open,annulus pressure should shear dump valve located at 7,670' MD /5,363' TVD. 9. Set BPV and test through inner annulus to 1,000 psi.Nipple down BOPE.Nipple up tree and pull BPV. Install test plug. Test tree to 250 psi low and 5,000 psi high,then test packoff to same. Pull test plug. 10. Freeze protect well by pumping a minimum of 80 bbls diesel down the 3-1/2"tubing x 7"casing annulus taking returns from tubing. Allow diesel to equalize at approximately 2,240' MD/2,000' TVD. 11. Shut in well. Monitor and record SICP and SITP. Set BPV and RDMO. Turn well over to Production via Handover Form. Proposed Drilling Program4/p: Requirements of 20 AAC 25.005(c)(13) sr l An application for a Permit to Drill must be accompanied by each of the following items,except for an item alrearn7inrwith the commission and identified in the application: 2K-08A Pre Rig Work(Sundry#311-064): a. Slick line set XN plug at 8910'MD and pulled dummy valve from GLM#8. b. Coil tubing pumped 13.4 bbls Class G cement placing cement from XN plug at 8910'to 8500'inside the tubing and from the packer at 8873'to 8500'in the annulus. c. Slick line tag and pressure test cement plug to 2500 psi with AOGCC witness.A drawdown test was performed bleeding the tubing and IA to 0 psi. d. E-line cut tubing at 8274'MD placing cut near the middle of the first full joint below GLM#7. Diesel was pumped down the tubing to verify cut. - Tubing is freeze protected with 24 bbls of diesel(2772'MD). - Inner annulus is freeze protected with 73 bbls of diesel(2772'MD). - BPV and VR plug was set. 1. Move Dovon 141 on 2K-08 and rig up. 2. Pull BPV and VR plugs. Record tubing,IA,and OA pressures. Circulate out freeze protect through tubing cut at 8274' MD and monitor well for pressure. 3. Set BPV and nipple down tree. M/U blanking plug in tubing hanger and nipple up BOPE. • Notify AOGCC field inspector 24 hours prior to BOPS test. m;000 psi �,`i • Test BOPE to 250 psi low/--37590-psi high as per drilling permit. 4. Pull blanking plug and BPV. Pull tubing hanger and lay down 3-1/2"completion. 5. Run 7"casing scraper to 8,274'MD. • Spot a weighted pill with corrosion inhibitor between tubing stub and cement retainer. 6. Rig up E-line and run gyro/caliper in 7"casing to evaluate for subsidence related issues. 7. Using E-line,perforate 7"casing from 7995'-8005'MD(4'below collar)for cement squeeze. • 8. Set 7"cement retainer bottom at 7987'MD(4'above collar)with 4"drill pipe. a cr>3P 9. Squeeze 15 bbls cement(664')into perforations to assist with kickoff and LOT. re"' 10. Nipple down BOP stack and tubing head using Hydra-tight system. Pull 7"packoff and expect casing growth. 11. Run 7"casing spear and engage 7"casing with overpull. Cut excess casing and reset slips with casing in 8k lbs tension. P Q 12. Install 7"packoff,nipple up tubing head and BOP stack. Retest same. ! E/ 13. Test 7"casing and CIBP to 3,500 psi,chart for 15 minutes. This will be used as a baseline for the FIT/LOT. 14. Pick up 7"whipstock/milling assembly. Run in hole and displace casing to milling fluid. Orient whipstock to 10 degrees - left of high side. 15. Set whipstock and mill window in 7"plus 20'of new formation for FIT/LOT. Perform FIT with rig pump as per CPAI procedure to 16 ppg EMW. Minimum acceptable leak off is 13.0 ppg EMW._ 16. Pull out of hole whipstock/milling assembly and gauge mills. If greater than 1/8"under,make another mill run with new mills. 77•S ( t D 17. Pick-up and make up 6"X 7"Reed Hycalog bi-center bit with 4-3/4"L/MWD drilling BHA. 18. Run in hole with drilling BHA to top of window and displace to 9.8 ppg drilling mud. 19. Drill 7"hole from 7,966'MD to 9,431'MD(stop at 100'MD above C-sand). • • Weight up to 11 ppg before top of HRZ at 8,451'MD/5,767'TVD. • 20. Perform open hole leak off to 16.0 ppg EMW. Minimum acceptable leak off is 15.0 ppg EMW. • If pressure leaks off at greater than 15.0 EMW,weight up mud system to 13 ppg and continue drilling 7" intermediate#1 to TD of 9,920'MD/6,254'TVD. • If pressure leaks off at less than 15.0 EMW,a 10-403 sundry will be submitted for"change approved program"to top set the Kuparuk. o 21. At total depth,circulate hole clean and wiper trip to window. Once back on bottom,circulate until hole is clean. Pull out of hole and rack back drill pipe and BHA. Pull wear bushing. 22. Pick up and run 70 joints of 3-1/2"9.3#L-80 SLHT liner on 4"drill pipe. The top of liner will be placed at 7,760'MD T' n�-•' r p ' it A SUPEt-eL,IEDED y.p.rt allowing for 200'of overlap. 23. Cement liner to top with 15.8 ppg Class G slurry and 35%excess. Displace with 13.0 ppg fluid and set liner hanger. . Slackoff and set liner top packer. Circulate out excess cement above liner. • Reciprocate liner with 30'stroke lengths for as long as possible to enhance the cement bond. • If there are signs of lost circulation prior to running casing,mix cello-flakes into cement slurry. 24. Monitor well then pull out of hole laying down drill pipe. n 25. Run upper completion as per procedure with SSSV and 5 MMG GLMs. JGQ' Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a . KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored,tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 2K-08A Drilling Hazards Summary . (to be posted in Rig Floor Doghouse Prior to Spud) 7" Hole with 3-1/2" Liner Interval* Event Risk Mitigation Strategy Level Window/Open Hole leak Hi h Squeeze 7"casing near window before milling. Top set off less than required g Kuparuk if necessary. Hole instability while High Utilize a mud weight to stabilize Kalubik without drilling shale section sustaining losses Placement of KOP and bottom hole location to allow for Directional control Moderate 4.5° DLS. Complete all directional work above the HRZ and use a bi-center bit with successful past performance. Drill 6"X 7"hole with proper mud weight for hole Run liner to bottom Moderate stability, directional plan with 4.5° DLS and a tangent from HRZ to TD, and run 3-1/2" liner. Reduced trip speeds,real time equivalent circulating Hole swabbing/surging Moderate density(ECD)monitoring, mud rheology, and proper hole filling. Pump and rotate out of hole as necessary. BOPE drills, keep mud weight above 13 ppg, check for Abnormal Reservoir Moderate flow during connections and if needed increase mud Pressure weight. Area injectors have been shut in to reduce reservoir pressure. Reduced pump rates,real time equivalent circulating Lost Circulation Moderate density(ECD) monitoring, mud rheology, and LCM. Use GKA LC decision tree as needed. Tracking along 7"casing Perforate 7"casing and squeeze cement in 7"X 8-1/2" during window milling Moderate annulus. Original TOC is at 8,300' MD Cement Bonding Moderate Run liner with centralization for standoff. Reciprocate during circulation and pump 35%excess cement. Hydrogen Sulfide Gas Low H2S drills,detection systems, alarms, and standard well .� control practices. *See Well Plan for more detailed risk information and offset data. ORI IN L ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2K Pad 2K-08 Plan: 2K-08A Plan: 2K-08A (wp06) Standard Proposal Report 30 March, 2011 Iftermener HALLIBURTON Sperry Drilling Services ORIGINAL HALLI BU RTO N Project: Kuparuk River Unit WELL DETAILS: 2K-08 Site: Kuparuk 2K Pad Ground Leel: 118.50 Well: 2K-08 +N/-S +E/-W Northing Easting Latinude Longitude Slot Sperry Grilling Wellbore: Plan: 2K-08A 0.00 0.00 5938425.30 498310.18 70°14'34.799 N 150°0'49.132 W Plan: 2K-08A(wp06) REFERENCE INFORMATION Co-ordnate(WE)Reference:Wel 2K-08,True North Whichl(TVD)Reference:2K-OSA 141) 144.508 141(28+118.5)) Measured Depth Reference:2K•08A 141) 146.504 141(26+114.5)) Calculation Method:Minimum Curvature 4500 - CASING DETAILS 4750 MD TVD TVDSS Name Size Hole Size mgr 3763.50 2898.36 2751.86 9 5/8" 9-5/8 12-1/4 -- SUM 7966.02 5549.87 5403.37 7"TOW 7 8-1/2 . 9500.00 6114.94 5968.44 5 1/2" 5-1/2 7 5000— 9920.00 6254.03 6107.53 3 1/2" 3-1/2 4-3/4 I I I Tie on @ 7966'MD,5550'TVD:971'FSL,22'FWL-Sect-TION-ROSE DDI = 6.459 5250 J'`' c_ _ • a - ' • g 5500 - ,e r - 7"TOW - D Top A Sand @ 9616'MD,6154'TVD:1175'FSL,1494'FEL-Sec3-TION-ROSE G] r 11I ' Is 5750-,.=-__K-2 HKZ - i o I- / / TD at 9920'MD,6254'TVD:1214'FSL,1778'FEL I r Leper Knlubik`= ^� r ' • i H 6000 _=1-6.1/1;1=1'(1-om Mn 1/ - x : ,--('a--- - - 5 1/2"° —1 , � r 6250 ,° - A6 ' - v ` ` "�h_ns\(,gri161 14 , - t ` .4 i 3 1/2" 2K-08A(wpO6) /, 'T.. 1r - A3 / 6500 - Se ti� 6750 -- I 1111 1 1 1 1 1 1 1 1 1 1 1 1 1111 1111 1111 1111 1111 1111 1111 1111 1 1 1 1 4500 4750 5000 5250 5500 5750 6000 6250 6500 6750 7000 7250 7500 7750 8000 Vertical Section at 278.63°(500 ft/in) 1750 - I , I , I I I I Top A Sand @ 9616'MD,6154'TVD:1175'FSL,1494'FEL-Sec3-TION-RO8E I I r - TD at 9920'MD,6254'TVD:1214'FSL,1778'FEL r 1500 I I I I \ t- t I Tie on @ 7966'MD,5550'TVD:971'FSL,22'FWL-Sec2-TION-ROSE _ t t - t t - 1 i I 1 1 1250 I r - ,- 44 1 ;--- . _ 2K-08A(wp06)--- ' r1 _ I --- ' - 1 1000 r o I. - 31/2" I - 4 I 8 , ` - ` - 51/2" r h yo _ 9,°o conf '. p 750 12I,-ei ("06)AI 1 to - Macnetic North:'6.63° 7"TOW - Magnetic Field - St'ength:57332.1 snT 500 :79.77° Date: 4/2t/2011 Model:BGGM2010 I r 1 1 1 1 1 1 1 1 r r r r r r r r -1-r-r-T- r r r r r r r r 1111 1111 r r r r 1 1 1 1 1111 1111 1 1 1 1 -8000 -7750 -7500 -7250 -7000 -6750 -6500 -6250 -6000 -5750 -5500 -5250 -5000 -4750 -450( West(-)/East(+)(500 ft/in) C011000P'11llIP5 Alaska ORIGINAL. Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 2K-08 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) . Project: Kuparuk River Unit MD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5 Site: Kuparuk 2K Pad North Reference: True Well: 2K-08 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2K-08A Design: 2K-08A(wp06) Project Kuparuk River Unit,North Slope Alaska,United States 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 2K Pad Site Position: Northing: 5,938,600.18ft Latitude: 70°14'36.519 N From: Map Easting: 498,310.17ft Longitude: 150°0'49.133 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -0.01 ° Well 2K-08 Well Position +NI-S 0.00 ft Northing: 5,938,425.30 ft • Latitude: 70°14'34.799 N +E/-W 0.00 ft Easting: 498,310.18 ft . Longitude: 150°0'49.132 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 118.50 ft Wellbore Plan:2K-08A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 4/25/2011 16.63 79.77 57,334 Design 2K-08A(wp06) Audit Notes: Version: Phase: PLAN Tie On Depth: 7,966.00 Vertical Section: Depth From(TVD) +N/-5 +E/-W Direction (ft) (ft) (ft) (°) 28.00 0.00 0.00 278.63 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (^) 7,966.00 52.19 276.33 5,549.86 5,403.36 851.33 -5,164.54 0.00 0.00 0.00 0.00 7,978.60 54.08 275.92 5,557.41 5,410.91 852.41 -5,174.56 15.24 15.01 -3.27 -10.00 7,998.60 54.08 275.92 5,569.15 5,422.65 854.08 -5,190.67 0.00 0.00 0.00 0.00 8,369.23 70.66 277.94 5,740.46 5,593.96 894.01 -5,515.42 4.50 4.47 0.55 6.67 9,682.88 70.66 277.94 6,175.50 6,029.00 1,065.33 -6,743.05 0.00 0.00 0.00 0.00 9,920.21 70.66 277.94 6,254.10 6,107.60 1,096.28 -6,964.84 0.00 0.00 0.00 0.00 3/30/2011 9:08:52AM Page 2 COMPASS 2003.16 Build 69 ORIGINAL Halliburton -Sperry -IALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 2K-08 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Project: Kuparuk River Unit MD Reference: 2K-08A(D141)©146.50ft(D141(28+118.5)) Site: Kuparuk 2K Pad North Reference: True Well: 2K-08 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2K-08A Design: 2K-08A(wp06) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) -118.50 28.00 0.00 0.00 28.00 -118.50 0.00 0.00 5,938,425.30 498,310.18 0.00 0.00 32.50 1.87 105.12 32.50 -114.00 -0.02 0.07 5,938,425.28 498,310.25 41.55 -0.07 52.50 1.15 114.40 52.49 -94.01 -0.19 0.57 5,938,425.11 498,310.75 3.79 -0.59 72.50 0.54 87.58 72.49 -74.01 -0.27 0.85 5,938,425.03 498,311.03 3.56 -0.88 92.50 0.34 48.18 92.49 -54.01 -0.22 0.98 5,938,425.08 498,311.16 1.76 -1.01 112.50 0.20 45.40 112.49 -34.01 -0.16 1.05 5,938,425.14 498,311.23 0.70 -1.06 132.50 0.33 35.11 132.49 -14.01 -0.09 1.11 5,938,425.21 498,311.29 0.69 -1.11 152.50 0.48 40.36 152.49 5.99 0.02 1.20 5,938,425.32 498,311.38 0.77 -1.18 172.50 0.42 21.83 172.49 25.99 0.16 1.28 5,938,425.45 498,311.46 0.78 -1.24 192.50 0.31 23.89 192.49 45.99 0.27 1.33 5,938,425.57 498,311.51 0.55 -1.27 212.50 0.24 65.09 212.49 65.99 0.34 1.39 5,938,425.64 498,311.57 1.02 -1.32 232.50 0.26 78.58 232.49 85.99 0.37 1.47 5,938,425.67 498,311.65 0.31 -1.40 252.50 0.32 88.21 252.49 105.99 0.38 1.57 5,938,425.68 498,311.75 0.39 -1.50 272.50 0.37 77.30 272.49 125.99 0.39 1.69 5,938,425.69 498,311.87 0.41 -1.61 292.50 0.45 69.59 292.49 145.99 0.44 1.83 5,938,425.73 498,312.01 0.49 -1.74 312.50 0.44 54.26 312.49 165.99 0.51 1.96 5,938,425.81 498,312.14 0.60 -1.86 332.50 0.38 47.18 332.49 185.99 0.60 2.07 5,938,425.90 498,312.25 0.39 -1.96 352.50 0.25 50.31 352.48 205.98 0.67 2.16 5,938,425.97 498,312.34 0.66 -2.03 372.50 0.30 37.83 372.48 225.98 0.74 2.22 5,938,426.04 498,312.40 0.39 -2.09 392.50 0.36 25.05 392.48 245.98 0.84 2.28 5,938,426.14 498,312.46 0.47 -2.13 412.50 0.28 19.57 412.48 265.98 0.94 2.32 5,938,426.24 498,312.50 0.43 -2.16 432.50 0.17 16.24 432.48 285.98 1.02 2.35 5,938,426.31 498,312.53 0.55 -2.17 452.50 0.38 341.19 452.48 305.98 1.11 2.34 5,938,426.41 498,312.52 1.30 -2.14 472.50 0.25 305.50 472.48 325.98 1.19 2.28 5,938,426.49 498,312.46 1.15 -2.07 492.50 0.32 309.26 492.48 345.98 1.26 2.20 5,938,426.55 498,312.38 0.36 -1.99 512.50 0.71 297.93 512.48 365.98 1.35 2.05 5,938,426.65 498,312.23 2.01 -1.82 532.50 0.86 292.26 532.48 385.98 1.46 1.80 5,938,426.76 498,311.98 0.84 -1.56 552.50 1.60 289.11 552.48 405.98 1.61 1.40 5,938,426.91 498,311.58 3.71 -1.14 572.50 2.21 283.78 572.46 425.96 1.80 0.76 5,938,427.09 498,310.94 3.17 -0.48 592.50 2.56 284.83 592.45 445.95 2.00 -0.05 5,938,427.30 498,310.13 1.76 0.35 612.50 3.54 284.07 612.42 465.92 2.27 -1.08 5,938,427.57 498,309.10 4.90 1.41 632.50 4.66 285.38 632.37 485.87 2.63 -2.46 5,938,427.93 498,307.72 5.62 2.83 652.50 5.19 286.66 652.29 505.79 3.11 -4.11 5,938,428.41 498,306.07 2.71 4.53 672.50 5.77 287.86 672.20 525.70 3.67 -5.94 5,938,428.97 498,304.25 2.96 6.42 692.50 6.41 289.04 692.09 545.59 4.35 -7.95 5,938,429.65 498,302.23 3.26 8.51 712.50 6.26 291.38 711.97 565.47 5.11 -10.02 5,938,430.41 498,300.16 1.49 10.67 732.50 7.02 289.07 731.83 585.33 5.91 -12.19 5,938,431.21 498,297.99 4.03 12.94 752.50 8.11 290.30 751.66 605.16 6.79 -14.67 5,938,432.10 498,295.52 5.51 15.52 772.50 8.75 293.39 771.44 624.94 7.89 -17.39 5,938,433.19 498,292.80 3.92 18.37 792.50 9.30 294.23 791.19 644.69 9.15 -20.26 5,938,434.46 498,289.93 2.83 21.40 812.50 9.86 296.03 810.92 664.42 10.57 -23.27 5,938,435.87 498,286.92 3.18 24.59 832.50 10.31 297.78 830.61 684.11 12.15 -26.39 5,938,437.46 498,283.79 2.72 27.92 852.50 10.90 297.36 850.26 703.76 13.86 -29.65 5,938,439.16 498,280.53 2.98 31.40 872.50 11.47 297.46 869.88 723.38 15.64 -33.10 5,938,440.95 498,277.09 2.85 35.07 892.50 11.91 297.59 889.47 742.97 17.52 -36.69 5,938,442.82 498,273.50 2.20 38.90 3/30/2011 9:08:52AM Page 3 COMPASS 2003.16 Build 69 ORIGINAL Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 2K-08 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Project: Kuparuk River Unit MD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Site: Kuparuk 2K Pad North Reference: True Well: 2K-08 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2K-08A Design: 2K-08A(wp06) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-5 +E/-W Northing Easting DLS Vert Section (ft) (°) (') (ft) ft (ft) (ft) (ft) (ft) 762.52 912.50 12.46 297.58 909.02 762.52 19.47 -40.43 5,938,444.78 498,269.76 2.75 42.90 932.50 13.10 297.34 928.52 782.02 21.51 -44.36 5,938,446.82 498,265.83 3.21 47.08 952.50 13.88 296.97 947.97 801.47 23.64 -48.51 5,938,448.95 498,261.68 3.92 51.51 972.50 14.66 296.47 967.35 820.85 25.86 -52.91 5,938,451.17 498,257.28 3.95 56.19 992.50 15.61 295.96 986.66 840.16 28.16 -57.60 5,938,453.47 498,252.59 4.80 61.17 1,012.50 16.27 295.66 1,005.89 859.39 30.55 -62.54 5,938,455.86 498,247.65 3.33 66.42 1,032.50 16.75 295.08 1,025.07 878.57 32.99 -67.68 5,938,458.30 498,242.51 2.54 71.86 1,052.50 17.25 294.29 1,044.19 897.69 35.43 -72.99 5,938,460.74 498,237.20 2.75 77.48 1,072.50 17.70 293.68 1,063.27 916.77 37.87 -78.48 5,938,463.18 498,231.72 2.43 83.27 1,092.50 18.30 292.76 1,082.29 935.79 40.31 -84.16 5,938,465.62 498,226.04 3.32 89.25 1,112.50 18.86 291.62 1,101.25 954.75 42.71 -90.06 5,938,468.03 498,220.14 3.34 95.45 1,132.50 19.40 289.97 1,120.14 973.64 45.04 -96.19 5,938,470.35 498,214.01 3.82 101.86 1,152.50 20.17 288.56 1,138.96 992.46 47.27 -102.58 5,938,472.59 498,207.62 4.53 108.51 1,172.50 20.73 287.58 1,157.70 1,011.20 49.44 -109.22 5,938,474.76 498,200.98 3.28 115.40 1,192.50 21.41 287.11 1,176.37 1,029.87 51.58 -116.08 5,938,476.90 498,194.12 3.50 122.51 1,212.50 22.08 286.73 1,194.94 1,048.44 53.74 -123.17 5,938,479.06 498,187.03 3.42 129.84 1,232.50 22.76 286.34 1,213.43 1,066.93 55.91 -130.49 5,938,481.23 498,179.72 3.48 137.40 1,252.50 23.51 285.73 1,231.82 1,085.32 58.08 -138.04 5,938,483.40 498,172.17 3.94 145.19 1,272.50 24.00 284.83 1,250.13 1,103.63 60.20 -145.81 5,938,485.52 498,164.40 3.05 153.19 1,292.50 24.61 283.87 1,268.35 1,121.85 62.24 -153.78 5,938,487.57 498,156.42 3.63 161.38 1,312.50 25.32 283.45 1,286.49 1,139.99 64.23 -161.99 5,938,489.56 498,148.22 3.66 169.79 1,332.50 25.72 283.44 1,304.53 1,158.03 66.23 -170.37 5,938,491.57 498,139.84 2.00 178.38 1,352.50 26.40 283.31 1,322.50 1,176.00 68.27 -178.92 5,938,493.60 498,131.30 3.41 187.13 1,372.50 27.28 283.16 1,340.35 1,193.85 70.33 -187.71 5,938,495.67 498,122.51 4.41 196.13 1,392.50 27.74 282.85 1,358.08 1,211.58 72.41 -196.71 5,938,497.75 498,113.51 2.41 205.34 1,412.50 28.70 282.78 1,375.71 1,229.21 74.51 -205.93 5,938,499.85 498,104.29 4.80 214.78 1,432.50 29.14 282.77 1,393.21 1,246.71 76.65 -215.36 5,938,501.99 498,094.86 2.20 224.42 1,452.50 29.74 282.84 1,410.63 1,264.13 78.83 -224.95 5,938,504.17 498,085.27 3.00 234.23 1,472.50 30.42 283.07 1,427.94 1,281.44 81.08 -234.71 5,938,506.42 498,075.51 3.45 244.22 1,492.50 30.49 283.04 1,445.18 1,298.68 83.37 -244.59 5,938,508.71 498,065.63 0.36 254.33 1,512.50 31.39 282.87 1,462.33 1,315.83 85.67 -254.61 5,938,511.02 498,055.61 4.52 264.58 1,532.50 32.11 282.80 1,479.34 1,332.84 88.01 -264.87 5,938,513.36 498,045.35 3.60 275.08 1,552.50 32.55 282.91 1,496.24 1,349.74 90.39 -275.30 5,938,515.74 498,034.93 2.22 285.75 1,572.50 33.49 283.01 1,513.01 1,366.51 92.83 -285.92 5,938,518.19 498,024.31 4.71 296.61 1,592.50 33.81 282.64 1,529.66 1,383.16 95.29 -296.73 5,938,520.65 498,013.50 1.90 307.67 1,612.50 34.37 282.31 1,546.22 1,399.72 97.71 -307.67 5,938,523.07 498,002.56 2.95 318.85 1,632.50 35.02 282.15 1,562.66 1,416.16 100.12 -318.80 5,938,525.49 497,991.44 3.28 330.21 1,652.50 35.45 281.84 1,579.00 1,432.50 102.52 -330.08 5,938,527.89 497,980.15 2.33 341.73 1,672.50 36.26 281.61 1,595.21 1,448.71 104.90 -341.55 5,938,530.27 497,968.68 4.11 353.43 1,692.50 36.78 281.75 1,611.28 1,464.78 107.31 -353.21 5,938,532.68 497,957.03 2.63 365.31 1,712.50 37.50 281.32 1,627.23 1,480.73 109.73 -365.04 5,938,535.10 497,945.20 3.83 377.37 1,732.50 38.11 280.97 1,643.03 1,496.53 112.10 -377.07 5,938,537.47 497,933.17 3.23 389.62 1,752.50 38.41 280.45 1,658.73 1,512.23 114.40 -389.24 5,938,539.77 497,921.01 2.20 402.00 1,772.50 38.96 280.24 1,674.34 1,527.84 116.64 -401.54 5,938,542.02 497,908.71 2.83 414.49 1,792.50 39.58 279.79 1,689.83 1,543.33 118.84 -414.00 5,938,544.22 497,896.24 3.41 427.15 3/30/2011 9:08:52AM Page 4 COMPASS 2003.16 Build 69 ORtGINAL Halliburton -Sperry I-IALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 2K-08 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Project: Kuparuk River Unit MD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Site: Kuparuk 2K Pad North Reference: True Well: 2K-08 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2K-08A Design: 2K-08A(wp06) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +EI-W Northing Easting DLS Vert Section (ft) C) C) (ft) ft (ft) (ft) (ft) (ft) 1,558.64 1,812.50 40.50 279.84 1,705.14 1,558.64 121.04 -426.68 5,938,546.42 497,883.57 4.60 440.01 1,832.50 40.54 280.05 1,720.34 1,573.84 123.28 -439.48 5,938,548.67 497,870.77 0.71 453.00 1,852.50 41.42 279.95 1,735.44 1,588.94 125.56 -452.40 5,938,550.95 497,857.86 4.41 466.11 1,872.50 41.96 279.53 1,750.38 1,603.88 127.81 -465.51 5,938,553.20 497,844.75 3.04 479.41 1,892.50 42.40 279.14 1,765.20 1,618.70 129.99 -478.76 5,938,555.38 497,831.50 2.56 492.84 1,912.50 43.37 278.57 1,779.85 1,633.35 132.08 -492.21 5,938,557.48 497,818.05 5.22 506.45 1,932.50 43.43 278.55 1,794.38 1,647.88 134.13 -505.79 5,938,559.53 497,804.47 0.31 520.19 1,952.50 44.14 278.74 1,808.82 1,662.32 136.21 -519.48 5,938,561.61 497,790.79 3.61 534.03 1,972.50 44.30 278.54 1,823.15 1,676.65 138.30 -533.27 5,938,563.71 497,777.00 1.06 547.98 1,992.50 44.48 278.74 1,837.45 1,690.95 140.40 -547.10 5,938,565.81 497,763.17 1.14 561.97 2,012.50 45.48 278.26 1,851.59 1,705.09 142.49 -561.08 5,938,567.90 497,749.19 5.28 576.11 2,032.50 45.83 278.44 1,865.57 1,719.07 144.57 -575.23 5,938,569.98 497,735.04 1.86 590.41 2,052.50 46.59 278.63 1,879.41 1,732.91 146.71 -589.51 5,938,572.13 497,720.76 3.86 604.85 2,072.50 47.65 278.86 1,893.02 1,746.52 148.94 -603.99 5,938,574.36 497,706.28 5.37 619.50 2,092.50 47.81 279.02 1,906.47 1,759.97 151.24 -618.61 5,938,576.66 497,691.66 1.00 634.30 2,112.50 48.42 278.75 1,919.83 1,773.33 153.54 -633.32 5,938,578.97 497,676.95 3.21 649.19 2,132.50 48.97 278.71 1,933.03 1,786.53 155.82 -648.17 5,938,581.25 497,662.10 2.75 664.22 2,152.50 49.17 278.39 1,946.13 1,799.63 158.07 -663.12 5,938,583.50 497,647.16 1.57 679.33 2,172.50 49.95 278.00 1,959.10 1,812.60 160.24 -678.18 5,938,585.67 497,632.10 4.17 694.55 2,192.50 49.95 277.98 1,971.97 1,825.47 162.36 -693.34 5,938,587.80 497,616.94 0.08 709.86 2,212.50 50.43 277.87 1,984.78 1,838.28 164.48 -708.56 5,938,589.92 497,601.73 2.44 725.22 2,232.50 50.81 278.33 1,997.47 1,850.97 166.66 -723.87 5,938,592.11 497,586.42 2.60 740.68 2,252.50 50.81 278.79 2,010.11 1,863.61 168.97 -739.19 5,938,594.42 497,571.10 1.78 756.18 2,272.50 51.24 278.83 2,022.68 1,876.18 171.35 -754.56 5,938,596.80 497,555.73 2.16 771.73 2,292.50 51.40 278.93 2,035.18 1,888.68 173.76 -769.98 5,938,599.21 497,540.31 0.89 787.34 2,312.50 51.95 279.03 2,047.59 1,901.09 176.21 -785.48 5,938,601.67 497,524.82 2.78 803.03 2,332.50 52.87 279.34 2,059.79 1,913.29 178.74 -801.13 5,938,604.20 497,509.17 4.76 818.88 2,352.50 53.04 279.33 2,071.84 1,925.34 181.33 -816.88 5,938,606.79 497,493.42 0.85 834.84 2,372.50 53.70 279.43 2,083.77 1,937.27 183.94 -832.71 5,938,609.41 497,477.59 3.32 850.89 2,392.50 53.78 279.46 2,095.60 1,949.10 186.59 -848.62 5,938,612.06 497,461.68 0.42 867.01 2,412.50 53.63 279.57 2,107.44 1,960.94 189.26 -864.52 5,938,614.73 497,445.79 0.87 883.13 2,432.50 53.95 279.40 2,119.25 1,972.75 191.91 -880.44 5,938,617.39 497,429.87 1.74 899.26 2,452.50 53.68 279.57 2,131.06 1,984.56 194.57 -896.36 5,938,620.06 497,413.95 1.51 915.41 2,472.50 53.80 279.75 2,142.89 1,996.39 197.28 -912.26 5,938,622.77 497,398.06 0.94 931.53 2,492.50 54.04 279.64 2,154.67 2,008.17 200.00 -928.19 5,938,625.49 497,382.13 1.28 947.69 2,512.50 53.81 279.44 2,166.44 2,019.94 202.68 -944.13 5,938,628.17 497,366.19 1.41 963.85 2,532.50 54.18 279.83 2,178.20 2,031.70 205.39 -960.08 5,938,630.88 497,350.24 2.43 980.03 2,552.50 54.14 279.75 2,189.91 2,043.41 208.15 -976.06 5,938,633.64 497,334.27 0.38 996.24 2,572.50 54.16 279.49 2,201.62 2,055.12 210.86 -992.04 5,938,636.36 497,318.28 1.06 1,012.45 2,592.50 54.47 279.73 2,213.29 2,066.79 213.57 -1,008.06 5,938,639.07 497,302.27 1.83 1,028.69 2,612.50 54.28 279.73 2,224.94 2,078.44 216.32 -1,024.08 5,938,641.82 497,286.25 0.95 1,044.94 2,632.50 54.50 279.53 2,236.59 2,090.09 219.04 -1,040.11 5,938,644.55 497,270.22 1.37 1,061.20 2,652.50 54.62 279.72 2,248.18 2,101.68 221.76 -1,056.18 5,938,647.27 497,254.16 0.98 1,077.49 2,672.50 54.31 279.70 2,259.81 2,113.31 224.51 -1,072.22 5,938,650.02 497,238.12 1.55 1,093.77 2,692.50 54.54 280.16 2,271.44 2,124.94 227.31 -1,088.24 5,938,652.83 497,222.10 2.20 1,110.03 3/30/2011 9:08:52AM Page 5 COMPASS 2003.16 Build 69 ORIGINAL Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 2K-08 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Project: Kuparuk River Unit MD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Site: Kuparuk 2K Pad North Reference: True Well: 2K-08 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2K-08A Design: 2K-08A(wp06) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +El-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 2,136.56 2,712.50 54.43 280.08 2,283.06 2,136.56 230.17 -1,104.27 5,938,655.69 497,206.07 0.64 1,126.30 2,732.50 54.44 280.04 2,294.69 2,148.19 233.01 -1,120.29 5,938,658.54 497,190.06 0.17 1,142.57 2,752.50 54.82 280.19 2,306.27 2,159.77 235.88 -1,136.34 5,938,661.41 497,174.00 2.00 1,158.87 2,772.50 54.49 280.51 2,317.84 2,171.34 238.81 -1,152.39 5,938,664.34 497,157.96 2.10 1,175.18 2,792.50 54.98 280.52 2,329.39 2,182.89 241.79 -1,168.45 5,938,667.32 497,141.90 2.45 1,191.50 2,812.50 54.71 280.51 2,340.90 2,194.40 244.77 -1,184.52 5,938,670.31 497,125.83 1.35 1,207.84 2,832.50 55.04 280.66 2,352.41 2,205.91 247.78 -1,200.60 5,938,673.32 497,109.75 1.76 1,224.19 2,852.50 55.22 280.64 2,363.84 2,217.34 250.81 -1,216.73 5,938,676.36 497,093.63 0.90 1,240.59 2,872.50 55.11 280.86 2,375.27 2,228.77 253.87 -1,232.86 5,938,679.42 497,077.50 1.06 1,256.99 2,892.50 55.62 280.78 2,386.64 2,240.14 256.96 -1,249.02 5,938,682.51 497,061.34 2.57 1,273.44 2,912.50 55.52 280.81 2,397.94 2,251.44 260.05 -1,265.23 5,938,685.61 497,045.14 0.52 1,289.92 2,932.50 55.57 281.02 2,409.26 2,262.76 263.17 -1,281.42 5,938,688.73 497,028.95 0.90 1,306.40 2,952.50 55.48 280.21 2,420.58 2,274.08 266.21 -1,297.62 5,938,691.77 497,012.75 3.37 1,322.88 2,972.50 55.21 280.44 2,431.95 2,285.45 269.16 -1,313.81 5,938,694.73 496,996.56 1.65 1,339.32 2,992.50 55.55 279.95 2,443.32 2,296.82 272.07 -1,330.01 5,938,697.64 496,980.37 2.64 1,355.77 3,012.50 55.52 280.30 2,454.63 2,308.13 274.97 -1,346.24 5,938,700.54 496,964.14 1.45 1,372.26 3,032.50 55.39 280.61 2,465.97 2,319.47 277.96 -1,362.44 5,938,703.54 496,947.94 1.43 1,388.72 3,052.50 55.48 279.91 2,477.32 2,330.82 280.89 -1,378.65 5,938,706.47 496,931.73 2.92 1,405.19 3,072.50 54.94 279.68 2,488.73 2,342.23 283.69 -1,394.83 5,938,709.27 496,915.55 2.86 1,421.61 3,092.50 54.85 279.98 2,500.23 2,353.73 286.48 -1,410.95 5,938,712.07 496,899.43 1.31 1,437.97 3,112.50 54.00 278.80 2,511.87 2,365.37 289.14 -1,427.00 5,938,714.73 496,883.38 6.41 1,454.23 3,132.50 53.52 278.20 2,523.69 2,377.19 291.52 -1,442.96 5,938,717.11 496,867.43 3.41 1,470.36 3,152.50 53.46 278.28 2,535.59 2,389.09 293.82 -1,458.86 5,938,719.42 496,851.53 0.44 1,486.44 3,172.50 53.33 277.75 2,547.52 2,401.02 296.06 -1,474.76 5,938,721.66 496,835.63 2.22 1,502.49 3,192.50 53.37 277.58 2,559.46 2,412.96 298.20 -1,490.67 5,938,723.81 496,819.73 0.71 1,518.53 3,212.50 53.86 277.79 2,571.32 2,424.82 300.36 -1,506.62 5,938,725.96 496,803.78 2.59 1,534.63 3,232.50 53.68 277.56 2,583.14 2,436.64 302.51 -1,522.61 5,938,728.12 496,787.79 1.29 1,550.76 3,252.50 53.55 278.27 2,595.01 2,448.51 304.73 -1,538.56 5,938,730.34 496,771.84 2.93 1,566.86 3,272.50 53.25 277.54 2,606.93 2,460.43 306.94 -1,554.46 5,938,732.55 496,755.94 3.29 1,582.92 3,292.50 53.04 277.46 2,618.93 2,472.43 309.03 -1,570.33 5,938,734.65 496,740.08 1.10 1,598.92 3,312.50 53.33 277.92 2,630.91 2,484.41 311.17 -1,586.20 5,938,736.79 496,724.21 2.34 1,614.93 3,332.50 53.36 277.73 2,642.85 2,496.35 313.35 -1,602.09 5,938,738.98 496,708.32 0.78 1,630.97 3,352.50 53.50 278.00 2,654.77 2,508.27 315.55 -1,618.00 5,938,741.18 496,692.41 1.29 1,647.03 3,372.50 53.88 278.03 2,666.61 2,520.11 317.80 -1,633.96 5,938,743.43 496,676.45 1.90 1,663.15 3,392.50 53.75 277.90 2,678.42 2,531.92 320.03 -1,649.95 5,938,745.67 496,660.47 0.84 1,679.29 3,412.50 54.13 278.42 2,690.19 2,543.69 322.33 -1,665.95 5,938,747.97 496,644.47 2.83 1,695.46 3,432.50 54.28 278.14 2,701.89 2,555.39 324.67 -1,682.01 5,938,750.31 496,628.42 1.36 1,711.68 3,452.50 54.25 278.39 2,713.57 2,567.07 327.00 -1,698.07 5,938,752.65 496,612.35 1.03 1,727.91 3,472.50 54.65 278.64 2,725.20 2,578.70 329.41 -1,714.16 5,938,755.06 496,596.26 2.24 1,744.18 3,492.50 54.64 278.49 2,736.77 2,590.27 331.84 -1,730.29 5,938,757.49 496,580.13 0.61 1,760.50 3,512.50 54.85 279.03 2,748.31 2,601.81 334.33 -1,746.43 5,938,759.98 496,563.99 2.44 1,776.83 3,532.50 54.79 278.71 2,759.84 2,613.34 336.85 -1,762.59 5,938,762.51 496,547.85 1.34 1,793.17 3,552.50 54.67 278.57 2,771.39 2,624.89 339.30 -1,778.73 5,938,764.96 496,531.70 0.83 1,809.50 3,572.50 54.57 279.38 2,782.97 2,636.47 341.84 -1,794.84 5,938,767.51 496,515.60 3.34 1,825.81 3,592.50 54.00 278.84 2,794.64 2,648.14 344.41 -1,810.87 5,938,770.08 496,499.57 3.60 1,842.05 3/30/2011 9:08:52AM Page 6 COMPASS 2003.16 Build 69 ORIGINAL Halliburton -Sperry HALLIBURTOI J Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 2K-08 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Project: Kuparuk River Unit MD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Site: Kuparuk 2K Pad North Reference: True Well: 2K-08 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2K-08A Design: 2K-08A(wp06) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 2,660.02 3,612.50 53.14 277.98 2,806.52 2,660.02 346.77 -1,826.79 5,938,772.44 496,483.65 5.52 1,858.14 3,632.50 52.96 278.69 2,818.54 2,672.04 349.08 -1,842.60 5,938,774.76 496,467.84 2.98 1,874.12 3,652.50 52.18 278.07 2,830.70 2,684.20 351.40 -1,858.31 5,938,777.08 496,452.13 4.61 1,890.00 3,672.50 52.20 277.32 2,842.96 2,696.46 353.52 -1,873.97 5,938,779.20 496,436.47 2.96 1,905.80 3,692.50 52.32 277.70 2,855.20 2,708.70 355.58 -1,889.65 5,938,781.27 496,420.80 1.62 1,921.61 3,712.50 52.35 277.93 2,867.42 2,720.92 357.74 -1,905.34 5,938,783.43 496,405.11 0.92 1,937.44 3,732.50 52.86 277.39 2,879.57 2,733.07 359.85 -1,921.09 5,938,785.55 496,389.37 3.33 1,953.33 3,752.50 52.65 277.57 2,891.67 2,745.17 361.93 -1,936.87 5,938,787.62 496,373.58 1.27 1,969.25 3,763.50 52.47 277.59 2,898.36 2,751.86 363.08 -1,945.53 5,938,788.78 496,364.93 1.60 1,977.98 9 5/8" 3,772.50 52.33 277.60 2,903.85 2,757.35 364.02 -1,952.60 5,938,789.72 496,357.86 1.60 1,985.11 3,792.50 52.21 276.80 2,916.09 2,769.59 366.00 -1,968.29 5,938,791.71 496,342.17 3.22 2,000.92 3,812.50 51.95 276.73 2,928.38 2,781.88 367.86 -1,983.96 5,938,793.57 496,326.50 1.33 2,016.69 3,832.50 51.83 277.80 2,940.72 2,794.22 369.85 -1,999.57 5,938,795.56 496,310.90 4.25 2,032.42 3,852.50 51.49 277.03 2,953.13 2,806.63 371.88 -2,015.12 5,938,797.59 496,295.34 3.47 2,048.11 3,872.50 51.14 276.85 2,965.63 2,819.13 373.76 -2,030.62 5,938,799.48 496,279.85 1.89 2,063.71 3,892.50 51.23 277.46 2,978.17 2,831.67 375.70 -2,046.08 5,938,801.42 496,264.39 2.42 2,079.29 3,912.50 50.92 277.39 2,990.73 2,844.23 377.71 -2,061.51 5,938,803.44 496,248.96 1.57 2,094.85 3,932.50 50.95 276.48 3,003.34 2,856.84 379.59 -2,076.93 5,938,805.32 496,233.55 3.54 2,110.37 3,952.50 50.99 277.21 3,015.93 2,869.43 381.44 -2,092.35 5,938,807.17 496,218.12 2.84 2,125.90 3,972.50 50.77 277.18 3,028.55 2,882.05 383.38 -2,107.75 5,938,809.12 496,202.73 1.11 2,141.41 3,992.50 51.08 276.68 3,041.16 2,894.66 385.26 -2,123.16 5,938,810.99 496,187.32 2.48 2,156.93 4,012.50 50.66 276.57 3,053.78 2,907.28 387.05 -2,138.57 5,938,812.79 496,171.91 2.14 2,172.43 4,032.50 50.48 276.06 3,066.48 2,919.98 388.75 -2,153.92 5,938,814.49 496,156.56 2.17 2,187.87 4,052.50 50.50 276.65 3,079.21 2,932.71 390.45 -2,169.26 5,938,816.20 496,141.23 2.28 2,203.29 4,072.50 50.50 276.70 3,091.93 2,945.43 392.25 -2,184.59 5,938,818.00 496,125.90 0.19 2,218.71 4,092.50 50.36 275.62 3,104.67 2,958.17 393.90 -2,199.91 5,938,819.66 496,110.57 4.22 2,234.11 4,112.50 50.31 276.15 3,117.43 2,970.93 395.48 -2,215.23 5,938,821.24 496,095.26 2.06 2,249.49 4,132.50 50.13 276.55 3,130.23 2,983.73 397.18 -2,230.50 5,938,822.94 496,079.99 1.78 2,264.85 4,152.50 50.11 275.40 3,143.05 2,996.55 398.78 -2,245.77 5,938,824.54 496,064.73 4.41 2,280.18 4,172.50 50.13 275.62 3,155.88 3,009.38 400.25 -2,261.05 5,938,826.02 496,049.45 0.85 2,295.50 4,192.50 50.25 276.42 3,168.68 3,022.18 401.86 -2,276.32 5,938,827.63 496,034.17 3,13 2,310.85 4,212.50 50.29 275.36 3,181.47 3,034.97 403.44 -2,291.62 5,938,829.21 496,018.88 4.08 2,326.21 4,232.50 50.08 275.38 3,194.27 3,047.77 404.88 -2,306.92 5,938,830.66 496,003.58 1.05 2,341.55 4,252.50 50.29 275.72 3,207.08 3,060.58 406.37 -2,322.21 5,938,832.14 495,988.29 1.68 2,356.89 4,272.50 50.25 275.69 3,219.86 3,073.36 407.89 -2,337.51 5,938,833.68 495,972.99 0.23 2,372.25 4,292.50 50.44 275.32 3,232.63 3,086.13 409.37 -2,352.84 5,938,835.16 495,957.67 1.71 2,387.63 4,312.50 51.20 276.02 3,245.26 3,098.76 410.90 -2,368.27 5,938,836.69 495,942.24 4.67 2,403.11 4,332.50 51.32 276.03 3,257.78 3,111.28 412.54 -2,383.78 5,938,838.33 495,926.73 0.60 2,418.69 4,352.50 51.78 275.31 3,270.21 3,123.71 414.09 -2,399.37 5,938,839.88 495,911.14 3.64 2,434.34 4,372.50 51.42 276.16 3,282.64 3,136.14 415.65 -2,414.96 5,938,841.45 495,895.55 3.79 2,449.99 4,392.50 51.37 276.13 3,295.12 3,148.62 417.33 -2,430.50 5,938,843.13 495,880.01 0.28 2,465.60 4,412.50 51.70 275.27 3,307.56 3,161.06 418.88 -2,446.08 5,938,844.69 495,864.43 3.75 2,481.24 4,432.50 51.70 275.63 3,319.95 3,173.45 420.37 -2,461.71 5,938,846.18 495,848.81 1.41 2,496.91 4,452.50 51.26 276.10 3,332.41 3,185.91 421.97 -2,477.27 5,938,847.78 495,833.25 2.87 2,512.54 3/30/2011 9:08:52AM Page 7 COMPASS 2003.16 Build 69 ORIGINAL Halliburton -Sperry HALLIBURTOIV Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 2K-08 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Project: Kuparuk River Unit MD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Site: Kuparuk 2K Pad North Reference: True Well: 2K-08 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2K-08A Design: 2K-08A(wp06) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (0) (ft) ft (ft) (ft) (ft) (ft) 3,198.39 4,472.50 51.53 275.18 3,344.89 3,198.39 423.51 -2,492.83 5,938,849.32 495,817.70 3.84 2,528.15 4,492.50 51.46 275.11 3,357.34 3,210.84 424.91 -2,508.42 5,938,850.73 495,802.11 0.44 2,543.77 4,512.50 51.39 275.87 3,369.81 3,223.31 426.41 -2,523.98 5,938,852.23 495,786.55 2.99 2,559.39 4,532.50 51.49 275.22 3,382.28 3,235.78 427.92 -2,539.55 5,938,853.74 495,770.98 2.59 2,575.00 4,552.50 51.37 274.75 3,394.75 3,248.25 429.28 -2,555.12 5,938,855.11 495,755.41 1.93 2,590.61 4,572.50 51.52 275.65 3,407.21 3,260.71 430.69 -2,570.70 5,938,856.53 495,739.83 3.60 2,606.22 4,592.50 51.50 275.24 3,419.66 3,273.16 432.18 -2,586.28 5,938,858.02 495,724.25 1.61 2,621.85 4,612.50 51.42 274.63 3,432.12 3,285.62 433.53 -2,601.87 5,938,859.36 495,708.67 2.42 2,637.46 4,632.50 51.51 275.34 3,444.58 3,298.08 434.88 -2,617.45 5,938,860.73 495,693.09 2.81 2,653.07 4,652.50 51.43 275.52 3,457.04 3,310.54 436.37 -2,633.03 5,938,862.21 495,677.51 0.81 2,668.69 4,672.50 51.46 274.56 3,469.50 3,323.00 437.74 -2,648.61 5,938,863.59 495,661.93 3.76 2,684.30 4,692.50 51.42 275.15 3,481.97 3,335.47 439.06 -2,664.19 5,938,864.92 495,646.35 2.32 2,699.91 4,712.50 51.42 275.57 3,494.44 3,347.94 440.52 -2,679.76 5,938,866.38 495,630.79 1.64 2,715.52 4,732.50 51.34 274.51 3,506.93 3,360.43 441.90 -2,695.32 5,938,867.76 495,615.23 4.16 2,731.11 4,752.50 51.35 274.95 3,519.42 3,372.92 443.18 -2,710.89 5,938,869.05 495,599.66 1.72 2,746.70 4,772.50 51.39 275.49 3,531.90 3,385.40 444.61 -2,726.45 5,938,870.47 495,584.11 2.12 2,762.29 4,792.50 51.37 274.78 3,544.39 3,397.89 446.00 -2,742.01 5,938,871.87 495,568.54 2.78 2,777.89 4,812.50 51.29 274.75 3,556.88 3,410.38 447.30 -2,757.57 5,938,873.17 495,552.98 0.42 2,793.47 4,832.50 51.41 275.51 3,569.38 3,422.88 448.70 -2,773.13 5,938,874.57 495,537.43 3.03 2,809.06 4,852.50 51.44 274.92 3,581.85 3,435.35 450.12 -2,788.70 5,938,876.00 495,521.86 2.31 2,824.67 4,872.50 51.16 274.58 3,594.35 3,447.85 451.41 -2,804.25 5,938,877.29 495,506.31 1.93 2,840.24 4,892.50 51.34 275.19 3,606.87 3,460.37 452.74 -2,819.79 5,938,878.63 495,490.77 2.54 2,855.80 4,912.50 51.20 274.88 3,619.38 3,472.88 454.11 -2,835.34 5,938,880.00 495,475.23 1.40 2,871.37 4,932.50 51.16 274.05 3,631.92 3,485.42 455.32 -2,850.87 5,938,881.22 495,459.70 3.24 2,886.92 4,952.50 51.21 274.94 3,644.46 3,497.96 456.54 -2,866.41 5,938,882.44 495,444.16 3.48 2,902.46 4,972.50 50.93 274.74 3,657.02 3,510.52 457.86 -2,881.91 5,938,883.76 495,428.66 1.60 2,917.98 4,992.50 51.13 274.30 3,669.60 3,523.10 459.08 -2,897.41 5,938,884.98 495,413.16 1.98 2,933.49 5,012.50 50.93 274.71 3,682.18 3,535.68 460.30 -2,912.91 5,938,886.21 495,397.66 1.88 2,949.00 5,032.50 51.14 274.09 3,694.76 3,548.26 461.50 -2,928.42 5,938,887.41 495,382.16 2.63 2,964.51 5,052.50 50.93 274.41 3,707.33 3,560.83 462.65 -2,943.92 5,938,888.56 495,366.65 1.63 2,980.01 5,072.50 50.95 274.93 3,719.94 3,573.44 463.91 -2,959.40 5,938,889.83 495,351.18 2.02 2,995.51 5,092.50 51.02 273.83 3,732.53 3,586.03 465.10 -2,974.90 5,938,891.02 495,335.69 4.29 3,011.00 5,112.50 51.08 274.49 3,745.10 3,598.60 466.23 -2,990.41 5,938,892.15 495,320.17 2.58 3,026.51 5,132.50 49.86 275.67 3,757.83 3,611.33 467.59 -3,005.77 5,938,893.52 495,304.81 7.61 3,041.91 5,152.50 50.31 276.39 3,770.66 3,624.16 469.20 -3,021.03 5,938,895.13 495,289.56 3.56 3,057.23 5,172.50 50.17 276.10 3,783.45 3,636.95 470.88 -3,036.31 5,938,896.81 495,274.28 1.32 3,072.59 5,192.50 50.28 277.12 3,796.25 3,649.75 472.65 -3,051.58 5,938,898.58 495,259.01 3.96 3,087.95 5,212.50 50.19 276.47 3,809.04 3,662.54 474.47 -3,066.85 5,938,900.40 495,243.75 2.54 3,103.32 5,232.50 50.08 275.95 3,821.86 3,675.36 476.13 -3,082.11 5,938,902.07 495,228.49 2.07 3,118.65 5,252.50 50.35 276.94 3,834.66 3,688.16 477.85 -3,097.38 5,938,903.80 495,213.22 4.04 3,134.01 5,272.50 50.01 276.08 3,847.47 3,700.97 479.59 -3,112.64 5,938,905.54 495,197.96 3.71 3,149.36 5,292.50 50.39 276.79 3,860.27 3,713.77 481.32 -3,127.91 5,938,907.27 495,182.69 3.32 3,164.72 5,312.50 50.29 276.51 3,873.04 3,726.54 483.10 -3,143.20 5,938,909.05 495,167.40 1.19 3,180.10 5,332.50 50.26 275.81 3,885.82 3,739.32 484.75 -3,158.50 5,938,910.71 495,152.11 2.70 3,195.47 5,352.50 50.38 276.82 3,898.59 3,752.09 486.44 -3,173.79 5,938,912.40 495,136.81 3.93 3,210.85 3/30/2011 9:08:52AM Page 8 COMPASS 2003.16 Build 69 ORIGINAL Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 2K-08 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Project: Kuparuk River Unit MD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Site: Kuparuk 2K Pad North Reference: True Well: 2K-08 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2K-08A Design: 2K-08A(wp06) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) C) (°) (ft) ft (ft) (ft) (ft) (ft) 3,764.85 5,372.50 50.34 276.47 3,911.35 3,764.85 488.22 -3,189.09 5,938,914.19 495,121.52 1.36 3,226.24 5,392.50 50.39 275.67 3,924.11 3,777.61 489.85 -3,204.41 5,938,915.82 495,106.20 3.09 3,241.63 5,412.50 50.30 276.60 3,936.87 3,790.37 491.50 -3,219.72 5,938,917.47 495,090.89 3.61 3,257.01 5,432.50 50.25 276.44 3,949.65 3,803.15 493.25 -3,235.00 5,938,919.22 495,075.61 0.66 3,272.39 5,452.50 50.57 275.76 3,962.40 3,815.90 494.88 -3,250.33 5,938,920.86 495,060.29 3.07 3,287.78 5,472.50 50.28 277.24 3,975.14 3,828.64 496.63 -3,265.64 5,938,922.61 495,044.98 5.89 3,303.19 5,492.50 50.81 277.77 3,987.85 3,841.35 498.64 -3,280.95 5,938,924.63 495,029.67 3.35 3,318.63 5,512.50 50.41 279.69 4,000.54 3,854.04 500.99 -3,296.23 5,938,926.98 495,014.39 7.68 3,334.08 5,532.50 50.35 280.34 4,013.30 3,866.80 503.67 -3,311.40 5,938,929.66 494,999.23 2.52 3,349.48 5,552.50 50.55 281.42 4,026.03 3,879.53 506.58 -3,326.54 5,938,932.57 494,984.08 4.28 3,364.89 5,572.50 50.41 280.34 4,038.76 3,892.26 509.49 -3,341.69 5,938,935.49 494,968.94 4.22 3,380.31 5,592.50 50.49 280.57 4,051.49 3,904.99 512.29 -3,356.86 5,938,938.29 494,953.77 0.97 3,395.72 5,612.50 50.68 281.15 4,064.19 3,917.69 515.20 -3,372.03 5,938,941.21 494,938.60 2.43 3,411.16 5,632.50 50.60 280.66 4,076.88 3,930.38 518.13 -3,387.22 5,938,944.13 494,923.42 1.94 3,426.61 5,652.50 50.38 279.77 4,089.60 3,943.10 520.86 -3,402.40 5,938,946.87 494,908.23 3.61 3,442.04 5,672.50 50.49 280.72 4,102.34 3,955.84 523.61 -3,417.57 5,938,949.62 494,893.06 3.70 3,457.45 5,692.50 50.57 280.56 4,115.05 3,968.55 526.46 -3,432.75 5,938,952.47 494,877.89 0.74 3,472.88 5,712.50 50.24 279.66 4,127.80 3,981.30 529.16 -3,447.92 5,938,955.18 494,862.72 3.84 3,488.28 5,732.50 50.80 280.84 4,140.52 3,994.02 531.91 -3,463.11 5,938,957.93 494,847.54 5.35 3,503.71 5,752.50 50.32 279.21 4,153.22 4,006.72 534.60 -3,478.32 5,938,960.62 494,832.33 6.74 3,519.15 5,772.50 50.33 280.87 4,165.99 4,019.49 537.28 -3,493.48 5,938,963.31 494,817.17 6.39 3,534.54 5,792.50 50.34 280.12 4,178.76 4,032.26 540.09 -3,508.61 5,938,966.12 494,802.04 2.89 3,549.93 5,812.50 50.38 279.27 4,191.52 4,045.02 542.68 -3,523.79 5,938,968.71 494,786.86 3.28 3,565.33 5,832.50 50.36 280.84 4,204.27 4,057.77 545.37 -3,538.96 5,938,971.41 494,771.70 6.05 3,580.73 5,852.50 49.70 279.72 4,217.12 4,070.62 548.11 -3,554.04 5,938,974.15 494,756.62 5.41 3,596.05 5,872.50 50.70 279.72 4,229.92 4,083.42 550.70 -3,569.19 5,938,976.74 494,741.47 5.00 3,611.41 5,892.50 49.55 280.36 4,242.75 4,096.25 553.37 -3,584.30 5,938,979.42 494,726.36 6.25 3,626.75 5,912.50 49.74 278.98 4,255.70 4,109.20 555.93 -3,599.32 5,938,981.98 494,711.34 5.34 3,641.99 5,932.50 49.91 280.09 4,268.60 4,122.10 558.47 -3,614.39 5,938,984.52 494,696.27 4.32 3,657.27 5,952.50 49.95 279.79 4,281.47 4,134.97 561.11 -3,629.47 5,938,987.16 494,681.20 1.17 3,672.57 5,972.50 49.61 278.73 4,294.39 4,147.89 563.57 -3,644.54 5,938,989.63 494,666.13 4.39 3,687.84 5,992.50 49.83 280.06 4,307.32 4,160.82 566.06 -3,659.59 5,938,992.12 494,651.08 5.19 3,703.10 6,012.50 49.37 278.99 4,320.28 4,173.78 568.58 -3,674.61 5,938,994.64 494,636.06 4.68 3,718.33 6,032.50 49.72 279.55 4,333.26 4,186.76 571.03 -3,689.63 5,938,997.10 494,621.04 2.76 3,733.54 6,052.50 49.66 279.68 4,346.20 4,199.70 573.58 -3,704.67 5,938,999.65 494,606.01 0.58 3,748.79 6,072.50 49.77 278.53 4,359.13 4,212.63 575.99 -3,719.73 5,939,002.07 494,590.95 4.42 3,764.05 6,092.50 49.71 279.09 4,372.05 4,225.55 578.33 -3,734.82 5,939,004.41 494,575.87 2.16 3,779.31 6,112.50 49.37 279.65 4,385.03 4,238.53 580.80 -3,749.83 5,939,006.89 494,560.85 2.73 3,794.53 6,132.50 49.63 278.16 4,398.02 4,251.52 583.16 -3,764.85 5,939,009.24 494,545.83 5.81 3,809.73 6,152.50 48.63 278.60 4,411.11 4,264.61 585.36 -3,779.82 5,939,011.45 494,530.87 5.27 3,824.86 6,172.50 49.42 279.32 4,424.22 4,277.72 587.71 -3,794.73 5,939,013.81 494,515.96 4.79 3,839.96 6,192.50 48.75 278.32 4,437.32 4,290.82 590.03 -3,809.67 5,939,016.13 494,501.03 5.05 3,855.07 6,212.50 49.36 277.94 4,450.43 4,303.93 592.17 -3,824.62 5,939,018.27 494,486.07 3.37 3,870.17 6,232.50 48.72 279.20 4,463.54 4,317.04 594.42 -3,839.56 5,939,020.52 494,471.14 5.73 3,885.28 6,252.50 49.15 278.56 4,476.68 4,330.18 596.75 -3,854.45 5,939,022.85 494,456.25 3.23 3,900.36 3/30/2011 9:08:52AM Page 9 COMPASS 2003.16 Build 69 Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 2K-08 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Project: Kuparuk River Unit MD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Site: Kuparuk 2K Pad North Reference: True Well: 2K-08 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2K-08A Design: 2K-08A(wp06) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (') (°) (ft) ft (ft) (ft) (ft) (ft) 4,343.31 6,272.50 48.79 277.59 4,489.81 4,343.31 598.87 -3,869.39 5,939,024.97 494,441.31 4.08 3,915.44 6,292.50 48.99 278.97 4,502.96 4,356.46 601.04 -3,884.30 5,939,027.15 494,426.40 5.29 3,930.51 6,312.50 48.49 279.90 4,516.15 4,369.65 603.50 -3,899.13 5,939,029.61 494,411.57 4.30 3,945.54 6,332.50 49.02 280.59 4,529.33 4,382.83 606.17 -3,913.93 5,939,032.29 494,396.78 3.71 3,960.58 6,352.50 48.92 281.46 4,542.46 4,395.96 609.06 -3,928.74 5,939,035.18 494,381.97 3.32 3,975.65 6,372.50 49.33 282.19 4,555.55 4,409.05 612.16 -3,943.54 5,939,038.28 494,367.17 3.44 3,990.75 6,392.50 49.92 281.96 4,568.51 4,422.01 615.35 -3,958.44 5,939,041.47 494,352.27 3.08 4,005.96 6,412.50 49.98 282.53 4,581.38 4,434.88 618.59 -3,973.40 5,939,044.72 494,337.31 2.20 4,021.24 6,432.50 49.72 281.44 4,594.27 4,447.77 621.77 -3,988.36 5,939,047.90 494,322.36 4.36 4,036.50 6,452.50 50.02 282.53 4,607.16 4,460.66 624.94 -4,003.31 5,939,051.08 494,307.41 4.43 4,051.76 6,472.50 49.93 282.56 4,620.02 4,473.52 628.27 -4,018.26 5,939,054.41 494,292.46 0.46 4,067.04 6,492.50 49.80 281.51 4,632.92 4,486.42 631.46 -4,033.22 5,939,057.60 494,277.51 4.07 4,082.30 6,512.50 50.45 282.56 4,645.74 4,499.24 634.66 -4,048.23 5,939,060.80 494,262.50 5.18 4,097.63 6,532.50 49.36 282.34 4,658.62 4,512.12 637.96 -4,063.17 5,939,064.10 494,247.56 5.51 4,112.89 6,552.50 50.11 282.34 4,671.55 4,525.05 641.22 -4,078.08 5,939,067.37 494,232.66 3.75 4,128.12 6,572.50 49.71 282.40 4,684.43 4,537.93 644.50 -4,093.02 5,939,070.65 494,217.71 2.01 4,143.39 6,592.50 50.44 282.25 4,697.26 4,550.76 647.77 -4,108.01 5,939,073.93 494,202.73 3.70 4,158.69 6,612.50 49.89 282.88 4,710.07 4,563.57 651.11 -4,123.00 5,939,077.27 494,187.74 3.66 4,174.02 6,632.50 50.33 281.55 4,722.90 4,576.40 654.36 -4,137.99 5,939,080.52 494,172.75 5.56 4,189.33 6,652.50 50.24 282.84 4,735.68 4,589.18 657.61 -4,153.03 5,939,083.77 494,157.71 4.98 4,204.68 6,672.50 50.50 283.22 4,748.44 4,601.94 661.08 -4,168.04 5,939,087.25 494,142.71 1.96 4,220.04 6,692.50 50.47 282.19 4,761.16 4,614.66 664.47 -4,183.09 5,939,090.64 494,127.66 3.98 4,235.43 6,712.50 50.63 282.81 4,773.87 4,627.37 667.82 -4,198.16 5,939,093.99 494,112.58 2.52 4,250.84 6,732.50 50.80 283.53 4,786.53 4,640.03 671.34 -4,213.24 5,939,097.52 494,097.51 2.91 4,266.27 6,752.50 50.64 282.41 4,799.20 4,652.70 674.82 -4,228.32 5,939,101.00 494,082.43 4.41 4,281.71 6,772.50 50.82 282.54 4,811.86 4,665.36 678.16 -4,243.44 5,939,104.35 494,067.31 1.03 4,297.16 6,792.50 50.95 283.56 4,824.47 4,677.97 681.67 -4,258.56 5,939,107.85 494,052.20 4.01 4,312.63 6,812.50 50.89 282.67 4,837.08 4,690.58 685.19 -4,273.68 5,939,111.38 494,037.08 3.47 4,328.11 6,832.50 50.82 282.20 4,849.71 4,703.21 688.53 -4,288.82 5,939,114.72 494,021.94 1.86 4,343.58 6,852.50 50.83 283.27 4,862.34 4,715.84 691.95 -4,303.95 5,939,118.14 494,006.82 4.15 4,359.05 6,872.50 51.14 283.04 4,874.93 4,728.43 695.48 -4,319.08 5,939,121.68 493,991.69 1.79 4,374.54 6,892.50 51.07 281.82 4,887.49 4,740.99 698.83 -4,334.28 5,939,125.04 493,976.49 4.76 4,390.07 6,912.50 51.21 283.44 4,900.04 4,753.54 702.24 -4,349.48 5,939,128.44 493,961.30 6.35 4,405.60 6,932.50 50.87 282.30 4,912.62 4,766.12 705.70 -4,364.64 5,939,131.91 493,946.14 4.75 4,421.11 6,952.50 51.49 282.85 4,925.15 4,778.65 709.10 -4,379.84 5,939,135.31 493,930.93 3.77 4,436.66 6,972.50 51.62 283.14 4,937.59 4,791.09 712.62 -4,395.11 5,939,138.83 493,915.67 1.31 4,452.28 6,992.50 51.24 281.74 4,950.06 4,803.56 715.99 -4,410.38 5,939,142.20 493,900.41 5.79 4,467.88 7,012.50 51.26 283.19 4,962.58 4,816.08 719.35 -4,425.61 5,939,145.57 493,885.18 5.65 4,483.44 7,032.50 51.05 282.25 4,975.12 4,828.62 722.78 -4,440.80 5,939,149.01 493,869.99 3.81 4,498.98 7,052.50 51.73 282.33 4,987.60 4,841.10 726.11 -4,456.07 5,939,152.34 493,854.72 3.41 4,514.57 7,072.50 50.33 281.55 5,000.18 4,853.68 729.33 -4,471.28 5,939,155.56 493,839.51 7.63 4,530.10 7,092.50 50.23 282.53 5,012.96 4,866.46 732.54 -4,486.33 5,939,158.77 493,824.47 3.80 4,545.45 7,112.50 50.26 281.44 5,025.75 4,879.25 735.73 -4,501.37 5,939,161.96 493,809.43 4.19 4,560.80 7,132.50 50.37 281.33 5,038.52 4,892.02 738.77 -4,516.46 5,939,165.01 493,794.34 0.69 4,576.17 7,152.50 48.99 281.92 5,051.46 4,904.96 741.84 -4,531.39 5,939,168.08 493,779.41 7.26 4,591.40 3/30/2011 9:08:52AM Page 10 COMPASS 2003.16 Build 69 ORIGINAL Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 2K-08 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Project: Kuparuk River Unit MD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Site: Kuparuk 2K Pad North Reference: True Well: 2K-08 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2K-08A Design: 2K-08A(wp06) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 4,917.95 7,172.50 50.00 281.24 5,064.45 4,917.95 744.89 -4,546.29 5,939,171.14 493,764.51 5.67 4,606.59 7,192.50 48.75 280.25 5,077.48 4,930.98 747.72 -4,561.20 5,939,173.97 493,749.60 7.29 4,621.76 7,212.50 49.54 281.30 5,090.56 4,944.06 750.55 -4,576.06 5,939,176.80 493,734.74 5.60 4,636.87 7,232.50 49.23 279.87 5,103.58 4,957.08 753.34 -4,590.98 5,939,179.59 493,719.82 5.64 4,652.05 7,252.50 49.75 281.44 5,116.57 4,970.07 756.15 -4,605.93 5,939,182.41 493,704.88 6.51 4,667.24 7,272.50 51.31 280.73 5,129.28 4,982.78 759.12 -4,621.08 5,939,185.38 493,689.73 8.27 4,682.66 7,292.50 52.25 280.88 5,141.66 4,995.16 762.07 -4,636.51 5,939,188.33 493,674.30 4.74 4,698.37 7,312.50 53.15 280.95 5,153.78 5,007.28 765.08 -4,652.13 5,939,191.34 493,658.68 4.51 4,714.26 7,332.50 53.21 280.72 5,165.76 5,019.26 768.09 -4,667.86 5,939,194.36 493,642.96 0.97 4,730.26 7,352.50 52.91 279.93 5,177.78 5,031.28 770.95 -4,683.58 5,939,197.23 493,627.24 3.50 4,746.24 7,372.50 53.18 280.94 5,189.81 5,043.31 773.85 -4,699.30 5,939,200.12 493,611.52 4.26 4,762.21 7,392.50 52.43 280.41 5,201.90 5,055.40 776.80 -4,714.96 5,939,203.08 493,595.87 4.30 4,778.13 7,412.50 52.65 279.54 5,214.06 5,067.56 779.55 -4,730.59 5,939,205.83 493,580.24 3.62 4,794.01 7,432.50 52.30 280.79 5,226.24 5,079.74 782.35 -4,746.20 5,939,208.63 493,564.62 5.26 4,809.86 7,452.50 52.98 280.59 5,238.38 5,091.88 785.30 -4,761.83 5,939,211.59 493,549.01 3.49 4,825.75 7,472.50 51.65 279.91 5,250.61 5,104.11 788.11 -4,777.40 5,939,214.41 493,533.43 7.17 4,841.57 7,492.50 52.40 279.88 5,262.91 5,116.41 790.82 -4,792.93 5,939,217.12 493,517.91 3.75 4,857.33 7,512.50 52.49 281.00 5,275.10 5,128.60 793.70 -4,808.52 5,939,219.99 493,502.32 4.46 4,873.18 7,532.50 52.38 279.81 5,287.30 5,140.80 796.56 -4,824.12 5,939,222.86 493,486.73 4.75 4,889.02 7,552.50 52.74 279.84 5,299.46 5,152.96 799.27 -4,839.76 5,939,225.57 493,471.08 1.80 4,904.90 7,572.50 52.37 280.90 5,311.62 5,165.12 802.13 -4,855.38 5,939,228.43 493,455.46 4.60 4,920.77 7,592.50 52.98 280.29 5,323.74 5,177.24 805.05 -4,871.01 5,939,231.36 493,439.83 3.90 4,936.66 7,612.50 52.76 279.38 5,335.81 5,189.31 807.77 -4,886.72 5,939,234.09 493,424.12 3.79 4,952.61 7,632.50 52.54 280.45 5,347.95 5,201.45 810.51 -4,902.39 5,939,236.83 493,408.47 4.39 4,968.50 7,652.50 53.02 280.62 5,360.05 5,213.55 813.42 -4,918.04 5,939,239.74 493,392.81 2.49 4,984.42 7,672.50 52.73 279.65 5,372.12 5,225.62 816.23 -4,933.74 5,939,242.55 493,377.12 4.13 5,000.36 7,692.50 53.04 280.34 5,384.19 5,237.69 819.00 -4,949.45 5,939,245.33 493,361.41 3.16 5,016.30 7,712.50 53.24 280.81 5,396.18 5,249.68 821.94 -4,965.18 5,939,248.27 493,345.68 2.13 5,032.29 7,732.50 53.36 279.47 5,408.14 5,261.64 824.76 -4,980.96 5,939,251.09 493,329.90 5.41 5,048.32 7,752.50 52.79 280.12 5,420.15 5,273.65 827.48 -4,996.72 5,939,253.81 493,314.15 3.86 5,064.31 7,772.50 53.20 281.02 5,432.19 5,285.69 830.41 -5,012.42 5,939,256.75 493,298.45 4.14 5,080.27 7,792.50 53.60 279.78 5,444.11 5,297.61 833.31 -5,028.21 5,939,259.65 493,282.66 5.36 5,096.32 7,812.50 52.26 279.77 5,456.17 5,309.67 836.02 -5,043.94 5,939,262.36 493,266.94 6.70 5,112.27 7,832.50 52.93 278.52 5,468.32 5,321.82 838.54 -5,059.62 5,939,264.89 493,251.25 5.99 5,128.16 7,852.50 52.16 277.58 5,480.48 5,333.98 840.76 -5,075.34 5,939,267.12 493,235.54 5.36 5,144.03 7,872.50 52.23 276.23 5,492.74 5,346.24 842.66 -5,091.03 5,939,269.02 493,219.85 5.34 5,159.83 7,892.50 52.46 276.99 5,504.96 5,358.46 844.49 -5,106.76 5,939,270.85 493,204.12 3.22 5,175.65 7,912.50 52.77 277.08 5,517.10 5,370.60 846.43 -5,122.53 5,939,272.80 493,188.35 1.59 5,191.54 7,932.50 51.69 275.86 5,529.35 5,382.85 848.21 -5,138.24 5,939,274.58 493,172.65 7.24 5,207.34 7,952.50 52.64 277.45 5,541.62 5,395.12 850.05 -5,153.92 5,939,276.42 493,156.96 7.87 5,223.12 7,966.00 52.19 276.33 5,549.86 5,403.36 851.33 -5,164.54 5,939,277.70 493,146.34 7.37 5,233.81 et.., i �� � Tie on @ 7966'MD,5550'TVD:971'FSL,22'FWL-Sec2-T10N-R08E 7,966.02 52.19 276.33 5,549.87 5,403.37 851.33 -5,164.56 5,939,277.70 493,146.33 0.00 5,233.83 �Lf 7"TOW 7,975.00 53.54 276.04 5,555.29 5,408.79 852.10 -5,171.68 5,939,278.48 493,139.21 15.27 5,240.98 3/30/2011 9 08:52AM Page 11 COMPASS 2003.16 Build 69 JR I Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 2K-08 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Project: Kuparuk River Unit MD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Site: Kuparuk 2K Pad North Reference: True Well: 2K-08 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2K-08A Design: 2K-08A(wp06) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 5,410.91 7,978.60 54.08 275.92 5,557.41 5,410.91 852.41 -5,174.56 5,939,278.78 493,136.32 15.24 5,243.88 7,998.60 54.08 275.92 5,569.15 5,422.65 854.08 -5,190.67 5,939,280.45 493,120.22 0.00 5,260.06 8,000.00 54.14 275.93 5,569.97 5,423.47 854.19 -5,191.80 5,939,280.57 493,119.09 4.50 5,261.19 8,100.00 58.61 276.54 5,625.33 5,478.83 863.25 -5,274.56 5,939,289.64 493,036.35 4.50 5,344.37 8,200.00 63.08 277.10 5,674.03 5,527.53 873.62 -5,361.25 5,939,300.04 492,949.66 4.50 5,431.64 8,300.00 67.56 277.61 5,715.77 5,569.27 885.25 -5,451.34 5,939,311.69 492,859.58 4.50 5,522.46 8,369.23 70.66 277.94 5,740.46 5,593.96 894.01 -5,515.42 5,939,320.45 492,795.51 4.50 5,587.12 8,400.00 70.66 277.94 5,750.65 5,604.15 898.02 -5,544.17 5,939,324.47 492,766.76 0.00 5,616.15 8,450.89 70.66 277.94 5,767.50 5,621.00 904.66 -5,591.73 5,939,331.12 492,719.21 0.00 5,664.17 K-2/HRZ 8,500.00 70.66 277.94 5,783.76 5,637.26 911.06 -5,637.63 5,939,337.53 492,673.32 0.00 5,710.50 8,600.00 70.66 277.94 5,816.88 5,670.38 924.10 -5,731.08 5,939,350.59 492,579.88 0.00 5,804.85 8,700.00 70.66 277.94 5,850.00 5,703.50 937.14 -5,824.53 5,939,363.66 492,486.44 0.00 5,899.20 8,800.00 70.66 277.94 5,883.11 5,736.61 950.19 -5,917.98 5,939,376.72 492,393.00 0.00 5,993.55 8,900.00 70.66 277.94 5,916.23 5,769.73 963.23 -6,011.43 5,939,389.78 492,299.57 0.00 6,087.90 9,000.00 70.66 277.94 5,949.35 5,802.85 976.27 -6,104.88 5,939,402.84 492,206.13 0.00 6,182.25 9,100.00 70.66 277.94 5,982.47 5,835.97 989.31 -6,198.33 5,939,415.90 492,112.69 0.00 6,276.60 9,200.00 70.66 277.94 6,015.58 5,869.08 1,002.35 -6,291.79 5,939,428.96 492,019.25 0.00 6,370.95 9,220.88 70.66 277.94 6,022.50 5,876.00 1,005.07 -6,311.30 5,939,431.69 491,999.73 0.00 6,390.66 Upper Kalubik 9,278.26 70.66 277.94 6,041.50 5,895.00 1,012.56 -6,364.92 5,939,439.18 491,946.13 0.00 6,444.79 Fault#1(From Model) 9,300.00 70.66 277.94 6,048.70 5,902.20 1,015.39 -6,385.24 5,939,442.02 491,925.81 0.00 6,465.31 9,308.45 70.66 277.94 6,051.50 5,905.00 1,016.49 -6,393.14 5,939,443.13 491,917.91 0.00 6,473.28 Lower Kalubik 9,400.00 70.66 277.94 6,081.82 5,935.32 1,028.43 -6,478.69 5,939,455.08 491,832.37 0.00 6,559.66 9,500.00 70.66 277.94 6,114.94 5,968.44 1,041.48 -6,572.14 5,939,468.14 491,738.93 0.00 6,654.01 5 1/2" 9,531.90 70.66 277.94 6,125.50 5,979.00 1,045.64 -6,601.95 5,939,472.31 491,709.12 0.00 6,684.10 C4 9,600.00 70.66 277.94 6,148.05 6,001.55 1,054.52 -6,665.59 5,939,481.20 491,645.49 0.00 6,748.36 9,616.45 70.66 277.94 6,153.50 6,007.00 1,056.66 -6,680.96 5,939,483.35 491,630.12 0.00 6,763.88 Top A Sand @ 9616'MD,6154'ND:1175'FSL,1494'FEL-Sec3-110N-R08E-A6 9,631.55 70.66 277.94 6,158.50 6,012.00 1,058.63 -6,695.07 5,939,485.32 491,616.01 0.00 6,778.12 A5 9,682.88 70.66 277.94 6,175.50 6,029.00 1,065.33 -6,743.05 5,939,492.03 491,568.05 0.00 6,826.55 2K-08A(wp06)A4 9,688.92 70.66 277.94 6,177.50 6,031.00 1,066.11 -6,748.69 5,939,492.82 491,562.41 0.00 6,832.25 A4 9,700.00 70.66 277.94 6,181.17 6,034.67 1,067.56 -6,759.04 5,939,494.27 491,552.05 0.00 6,842.71 9,800.00 70.66 277.94 6,214.29 6,067.79 1,080.60 -6,852.49 5,939,507.33 491,458.61 0.00 6,937.06 9,827.82 70.66 277.94 6,223.50 6,077.00 1,084.23 -6,878.49 5,939,510.96 491,432.62 0.00 6,963.30 A3 9,900.00 70.66 277.94 6,247.40 6,100.90 1,093.64 -6,945.95 5,939,520.39 491,365.17 0.00 7,031.41 3/30/2011 9:08:52AM Page 12 COMPASS 2003.16 Build 69 SII -- _ \ L Halliburton -Sperry I-IALLI B U RTO N Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 2K-08 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Project: Kuparuk River Unit MD Reference: 2K-08A(D141)@ 146.50ft(D141(28+118.5)) Slte: Kuparuk 2K Pad North Reference: True Well: 2K-08 Survey Calculation Method: Minimum Curvature Wellbore: Plan:2K-08A Design: 2K-08A(wp06) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (') (ft) ft (ft) (ft) (ft) (ft) 6,107.53 9,920.00 70.66 277.94 6,254.03 6,107.53 1,096.25 -6,964.64 5,939,523.00 491,346.49 0.00 7,050.28 3 1/2" 9,920.07 70.66 277.94 6,254.05 6,107.55 1,096.26 -6,964.70 5,939,523.01 491,346.42 0.00 7,050.34 TD at 9920'MD,6254'TVD:1214'FSL,1778'FEL • 9,920.21 70.66 277.94 6,254.10 • 6,107.60 1,096.28 . -6,964.84 • 5,939,523.03 491,346.29 0.00 7,050.48 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) 2K-08A(wp06)A4 0.00 0.00 6,175.50 1,065.33 -6,743.05 5,939,492.03 491,568.05 -plan hits target center -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 9,500.00 6,114.94 5 1/2" 5-1/2 7 9,920.00 6,254.03 3 1/2" 3-1/2 4-3/4 3,763.50 2,898.36 9 5/8" 9-5/8 12-1/4 7,966.02 5,549.87 7"TOW 7 8-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (°) (°) 9,827.82 6,223.50 A3 9,631.55 6,158.50 A5 8,450.89 5,767.50 K-2/HRZ SHALE 0.00 9,531.90 6,125.50 C4 9,688.92 6,177.50 A4 9,278.26 6,041.50 Fault#1(From Model) 0.00 9,616.45 6,153.50 A6 9,220.88 6,022.50 Upper Kalubik SAND 0.00 9,308.45 6,051.50 Lower Kalubik Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 7,966.00 5,549.86 851.33 -5,164.54 Tie on @ 7966'MD,5550'TVD:971'FSL,22'FWL-Sec2-T1ON-R08E 9,616.45 6,153.50 1,056.66 -6,680.96 Top A Sand @ 9616'MD,6154'TVD:1175'FSL,1494'FEL-Sec3-T1ON-R08E 9,920.07 6,254.05 1,096.26 -6,964.70 TD at 9920'MD,6254'TVD:1214'FSL,1778'FEL 3/30/2011 9:08:52AM Page 13 COMPASS 2003.16 Build 69 ORIGINAL N to 0 c to LL 01 c M 0 c c f' a) ▪ Q ▪ N CSI go 13. w r rrrr 1 y Co a o C cc 2 co N d d p N 5 fin U O N O �� d t• 0 G - O O �/ rd-. a.°O0 TiW O . • 3 m U) Y w z o o 00 z Y d N N M .-. 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Thanks, Elmo From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, April 07, 2011 1:41 PM To: Cecchetti, Elmo B Subject: FW: 2K-08A Rotary Sidetrack Drilling Permit(PTD 211-049) My error below... Well class= Development Status = Suspended Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L (DOA) Sent: Thursday, April 07, 2011 1:23 PM To: 'Cecchetti, Elmo B' Subject: RE: 2K-08A Rotary Sidetrack Drilling Permit(PTD 211-049) Elmo, • I changed BOP test pressure to 4000 psi based on your provided MASP. • On step 9 after squeezing the cement through the retainer you will need to PT again before nippling down the BOP to cut 7" casing. • Also, I need more detailed steps for running the tubing completion... you can provide this in an email. Once the well is completed, submit 10-407 as if the well is suspended. Well class= Service Status= suspended. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 4/7/2011 Page 2 of 2 t From: Cecchetti, Elmo B [mailto:Elmo.B.Cecchetti@conocophillips.com] Sent: Thursday, April 07, 2011 12:10 PM To: Schwartz, Guy L (DOA) Subject: RE: 2K-08A Rotary Sidetrack Drilling Permit Thank you. From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, April 07, 2011 11:48 AM To: Cecchetti, Elmo B Subject: RE: 2K-08A Rotary Sidetrack Drilling Permit Working on it today... you should be ok. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Cecchetti, Elmo B [mailto:Elmo.B.Cecchetti@conocophillips.com] Sent: Thursday, April 07, 2011 11:34 AM To: Schwartz, Guy L(DOA) Subject: 2K-08A Rotary Sidetrack Drilling Permit Mr. Schwartz, A rig schedule change has moved the spud date up for 2K-08A from April 25th to April 18th. If possible, could the drilling permit be reviewed by April 15th? Thank you, Elmo 263-4249 4/7/2011 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, March 29, 2011 9:51 AM To: 'Cecchetti, Elmo B' , 7�'� �(� 4:)`15Subject: RE: 2K-08A Rotary Sidetrack 1 ' Elmo, 1) The PTD application should reflect the base (most likely ) liner running option. You can describe the contingency in the program and include all the details for it as an alternate pathway. That way you wouldn't have to submit a 403 sundry for a "change of approved program". It would have to have the same detail though as the base plan ( cement plan etc.). 2)The P &A sundry (311-064) already included these steps so another sundry is not needed. Still include all the rig steps in your PTD application. You should arrive on location with the tubing already jet cut. The actual sidetrack operation starts when you begin milling a window... everything before that is part of the P &A operation. Call me if you have any more clarification. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Cecchetti, Elmo B [mailto:Elmo.B.Cecchetti@conocophillips.com] Sent: Tuesday, March 29, 2011 8:15 AM To: Schwartz, Guy L (DOA) Subject: 2K-08A Rotary Sidetrack Mr. Schwartz, I am preparing the permit to drill for the rotary sidetrack of 2K-08A(CTD setup)and have 2 short questions: 1) The drilling program is designed to run a 3-1/2" liner from the 7"window to TD in the A-sand. Due to reservoir pressure, the Kuparuk may require top setting with a 5-1/2" liner. The drilling program will include top setting as a contingency. With this contingency included in the drilling program, does the permit to drill need to reflect running a long string of 3-1/2" liner or the top setting design? I believe the answer is to complete the permit to drill with running the long string and if top setting is required a 10-403 would be submitted for"change of approved program"? 2) The pre-rig work approved with the 10-403 sundry number 311-064 consists of cementing the tubing and annulus at 8500' MD. The tubing will be cut and decompleted on rig. Do I need to submit a 10-403 to pull the completion or can these steps be included in the permit to drill? Thank you, Elmo Cecchetti Drilling Engineer Conoco Phillips Alaska Inc. ATO 1564 Work (907)263-4249 Cell (907)903-3141 Fax (907)265-6916 3/29/2011 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 4ea2k-05* PTD# //0 Development Service Exploratory Stratigraphic Test Non-Conventional Well • FIELD:k (,Q/L ,e�-l". POOL: krt,VAL /01,-Cl'` 6/7 Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL Theermit is for a new wellbore segment of existing g well (If last two digits in API number are Permit No. ,API No. 50- - - . 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 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. 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