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HomeMy WebLinkAbout211-133New Plugback Esets 7/18/2024 Well Name API Number PTD Number ESet Number Date 1J-162 PB2 50-029-23360-71-00 207-080 T39224 5-21-2009 CD3-125 PB1 50-103-20632-70-00 210-189 T39225 4-15-2011 CD3-301A PB1 50-103-20543-71-00 210-017 T39226 4-13-2010 KIGUN 1 PB1 50-629-23239-70-00 205-025 T39227 9-26-2005 1J-105 PB1 50-029-23346-70-00 207-027 T39228 4-23-2009 2K-28A PB1 50-103-20385-70-00 211-133 T39229 2-6-2012 2L-306 PB1 50-103-20630-70-00 210-182 T39230 4-15-2011 3A-17AL1 PB1 50-029-22691-70-00 210-114 T39231 11-24-2010 3G-22AL2 PB1 50-103-20147-70-00 212-047 T39232 7-24-2012 3H-34L1 PB1 50-103-20643-70-00 211-162 T39233 2-28-2012 3N-16AL1 PB1 50-029-21593-73-00 210-107 T39234 11-24-2010 C-12A PB1 50-029-21373-70-00 199-091 T39235 1-17-2002 ODSN-01 PB1 50-703-20648-70-00 211-166 T39236 5-3-2012 ODST-39 PB1 50-703-20572-70-00 208-040 T39237 3-22-2012 OI06-05 PB1 50-029-23437-70-00 210-165 T39238 11-3-2011 OP17-02 PB1 50-029-23431-70-00 210-125 T39239 1-3-2011 2K-28A PB1 50-103-20385-70-00 211-133 T39229 2-6-2012 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2K-28A KUPARUK RIV UNIT 2K-28A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 2K-28A 50-103-20385-01-00 211-133-0 W SPT 6109 2111330 1527 2544 2545 2555 2553 750 750 750 750 4YRTST P Kam StJohn 6/20/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2K-28A Inspection Date: Tubing OA Packer Depth 380 2030 1980 1975IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS230621134748 BBL Pumped:0.7 BBL Returned:0.7 Thursday, July 27, 2023 Page 1 of 1          MEMORANDUM TO: Pim Rper P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 26, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2K -28A KUPARUK RIV UNIT 2K -28A Src: Inspector Reviewed By: P.I. Supry l5 _ NON -CONFIDENTIAL Comm rR ame KUPARUK RIV UNIT 2K -28A API Well Number 50-103-20385-01-00 Inspector Name: Lou Laubenstein Permit Number: 211-133-0 Inspection Date: 61812019um:mitLOL190611075419 sp Num: Wednesday, June 26, 2019 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well, 2K -28A T.Npe III "TVI) b109 Tubing "' 3775 T 3775 3775 - PTD 2111330 TN pe Test s"I Test psi 1527 IA oo 7100 z060 2060 BBL Pumped: 1.7 1311L Returned: 1.3 - OA 670 - 670 - 670 J 670 Interval - aversr P/F P Notes: Wednesday, June 26, 2019 Page 1 of 1 • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Jim DATE: Tuesday,July 14,2015 TO: Regg 7 I l Z��S SUBJECT: Mechanical Integrity Tests P.I.Supervisor CONOCOPHILLIPS ALASKA INC 2K-28A FROM: Chuck Scheve KUPARUK RIV UNIT 2K-28A Petroleum Inspector NN S e ED 14.it1�1 U. 0 5 Src: Inspector Reviewed By: P.I.Suprva -- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-28AAPI Well Number 50-103-20385-01-00 Inspector Name: Chuck Scheve Permit Number: 211-133-0 Inspection Date: 7/10/2015 Insp Num: mitCS150713095644 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well -2K 28A Type Inl W 'TVD i 6109 - Tubing 2600 2600 - 2600 ' 2600 - 2111330 SPT' 1527 680 1990 - 1970 " 1970 PTD Type Test, Test psi IA OA ; Interval4YRTST P/F P .,/ 500 = 500 500 1 500 _I_ i Notes: Tuesday,July 14,2015 Page 1 of 1 • o c o 1 I I o '-.7.•° m C� ,n a ° m • 'n coo i a > O (-) O To'aiI w • co c �} 'III O IaE 0'N a+ co a a a aE M U 1, wi °� Yl;d m •ate 0 O a m _ m a 0, d m o 5 IlI c, oO = c m ate- a o coo a o oO m E •CD i° --> �'�� a)aco co co oF a .ate I Lc) H ii)m E! = N cn p E _�otS m.E E m E = N I, '', 02.N 0 o E m M LL a N 0 m a@ N 1 Z = O 10 N f0 C N O 0 o > o) 0 o O o cn H Iia - O iirna �a ~a 2a 2a II Q o yi CD i I I 00 > IN N N N N N N 0 I a m Z N ti 1 U) y 1 N N N N N N N > o Ce 1� CO co co (o f0 to il Z - I 0 1 J I N N N N N N N 2 E c o 2 C C C C C C C d = w • E a c 2 =; Q a a a a a w N co a) OU'i0 0 0 0 0 0 0 o N Q � -co co U rot Cl) '5 C'lo N-co N N `m z Z U to co o rn m rn o a y a aII 2 i c y = J M o M M M VI Z • 0 a W z d >• _ Z V U 1 y 8 « R=' ZCD Z` I- Q N N = I O 1 J a ii I 10 ., O o .08 o 0 0 0 0 o c ,. E CL N c ZI J 2 U 0 0 U 0 0 y m o E � o LL N w d ' a a� rn� O HCl E d O V N Ln N Lo LU LO UN U0 • E -I CD a QCON Y 0 N .- O H r o co 5� Z N o H G > N CO • • W C II �,/=A D N C II V/ d 0 III I,• N H a Y C o f ZI Lu w . w .> . . w • Z E w •,..,0-5 > > > > > > 1 o d U O u) co u) N 'in-- M • E J N N N in 'f) 'N 'U) RO a a a w o a a'o o a' z = g c c c c c c c y d o O o 0 0 0 0 3 _ _ > C 0 r z c C c c c c c r I .. 0 II CD I M `- QZ N } LO Z 0 N O O J m O • E E i v 0 a O € _ 0? w €6 (h 1 w OLL . fyZ QZy 2 to u. co p d I, 1 \dU O OOCL Z•, \ �) N \ VV ..g.N> E Q y Jy aI _ 0 U) oI0 _ 0 u ' E" a ca 0 0 O 0 0 o w O co g Ili Q >, o >. O H 5 J O F- bJ J w J J J J Cr U QCe I o 0 .- 9 0 N o el o } - N M U «(���ZZZCCCIII o 0 I p z Q z z_ co Y2m m J Ce Q 2 O U a a :,- U J_ W D a 0 U W Z z U § Z Q y J o w A N C • NN O El a E O N 0 O) J Q 1 aco Cl j I— N 1- H. p E N COS N re 1 CO CL 4 as Q Yg m Q o a Q Z o E U m z d • to r a a> O 13 N e 3 N a) i a' C Lo C C « N- y iv E B. a U U STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM„BION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon Repair w ell Augbrforations Perforate Other Convert WINJ to r p r 9 r r WAG After Casing r Rill Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program r Operat.Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r ” 211-133 3.Address: 6.API Number: 00 P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-103-20385-01 ` 7.Property Designation(Lease Number): 8.Well Name and Number: - ADL25588 " 2K-28A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10073 feet Plugs(measured) None true vertical 6261 feet Junk(measured) None Effective Depth measured 7320 feet Packer(measured) 7240 and true vertical 6274 feet (true vertical) 6216 tvd Casing Length Size MD TVD Burst Collapse CONDUCTOR 190 16 220' 220' SURFACE 3242 7 5/8 3,272' 2,956' PRODUCTION 7511 5 1/2 7,536' 6,287' RECEIVED���' LINER A 2753 2 3/8 10,073' 6,261' , OCT 0 9 2012 Perforation depth: Measured depth: 7222-7228; 7330-7891; 7906-8170;8172-10073 AOGCC True Vertical Depth: 6203-6208; 6278-6285;6285-6295;6295-6261 Tubing(size,grade,MD,and ND) 3.5, L-80, 7108 MD,6109 TVD Packers&SSSV(type,MD,and ND) CAMCO DS NIPPLE (WHIPSTOCK WHIPSTOCK ON KB PACKER \ 497.3(md)497(ND) " 7,240(md)6,216.2(TVD) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 _ 1561 580 2553 Subsequent to operation 1166 0 350 3531 14.Attachments 1 - Copies of Logs and Surveys run Exploratory r Development r Service J Stratigraphic r 16.Well Status after work: _ Oil [ Gas r WDSPL r Daily Report of Well Operations X GSTOR r WINJ r WAG 17 GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: None Contact Darrell Humphrey/Bob Christen: Email N1139©conocophillips.com Printed Name Darrell Humphrey Title NSK Production Engineering Specialist Signature Phone:907-659-7535 Date /u•7• Jz_ RBDMS OCT 10 20TZ R8DMS OCT 0 9 21:112&-.A)--(, /0.7-t L Form 10-404 Revised 11/2011Submit Original Only 2K-28A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/12/12 Convert on Sept 12 from WINJ to WAG , . , i KUP 2K-28A ConocoPhillips /8 Well Attributes Max Angle&MD TD Wellbore API/UWI Field Name raw- mel rt MD(111(8) Act Btm(11KB) carnaoetrepe 501032038501 KUPARUK RIVER UNIT INJ 96.34 8,410.60 10,073.0 "" Comment H25(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date • Well Confie.-2K- A,4Z22 :50 PM SSSV:NIPPLE Last WO: 34.59 8/26/2001 scne28matK-A0ctu012al 3:43Annotation 'Depth(FMB) 'End Date Annotation Last Mod...End Date Last Tag:WLM 7,280.0 10/24/2011 Rev Reason:ADD PERFS ninam 4/20/2012 Casing Strings Casing Description String 0... String ID...Top MKS) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 30.0 220.0 220.0 62.58 H-40 WELDED HANGER,25-111M11111.'' Caning Description String 0... String ID...Top(ttKB) Set Depth(f...Set Depth(TVD)...String Wt...-String...String Top Thrd j SURFACE 7 5/8 6.875 29.9 3,272.0 2,955.8 29.70 L-80 BTCM '1 Casing Description String 0... String ID...Top(61KB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 5.5'x3.5"@ 7129' 51/2 4.950 25.0 7,536.3 6,287.0 15.50 L-80 LTCM Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd LINER A 2 3/8 1.992 7,320.5 10,073.0 4.70 L-80 STL Liner Details Top Depth (TVD) Top Incl Need... Top MKS) (RKB) 11 item Description Comment ID(in) 7,320.5 6,274.6 62.74 BILLET LINER TOP BILLET 1.992 8,171.3 6,294.6 88.09 DEPLOY SHORTY DEPLOYMENT SLEEVE ' 1.900 CONDUCTOR, 30.220 Tubing Strings Tubing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd NIPPLE.497 TUBING 31/2 2.992 25.0 7,109.5 6,110.1 9.30 L-80 EUE-8rd Completion Details Top Depth (TVD) Top Incl Nomi... Top(18(B) (RKB) (°) Item Description Comment ID(In) 25.0 25.0 -0.01 HANGER FMC GEN V TUBING HANGER 3.500 497.3 497.0 4.20 NIPPLE CAMCO DS NIPPLE 2.875 7,063.2 6,072.2 35.41 NIPPLE CAMCO DS NIPPLE 2.812 SURFACE _-_- - L 7,107.7 6,108.6 34.51 LOCATOR BAKER NO GO SUB 3.000 30-3 2] 7,108.5 6,109.3 34.49 SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBLY STABBED INTO CSG SBR 3.000 Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) Top Depth GAS LIFT, 1 1 (ND) Top Mei 7.014 Top(61KB) (SK8) (°) Description Comment Run Date ID(In) 7,240 6,216.2 26.15 WHIPSTOCK WHIPSTOCK ON KB PACKER 10/31/2011 0.000 s--Perforations&Slots Shot r< Top(TVD) Btm)TVD) Dens Top MKS)Btm(RKB) (RKB) (RKB) Zone Date (oh... Type Comment 7,222 7,228 6,203.4 6,208.8 C-4,2K-28 4/19/2004 6.0 APERF 2.5"HSD,60 deg ph,random orient NIPPLE,7,063 - 7,330 7,891 6,277.5 6,284.7 A-4,2K-28A 11/27/2011 32.0 SLOTS 7,906 8,170 6,284.5 6,294.6 A-4,2K-28A 11/27/2011 32.0 SLOTS 8,172 10,073 6,294.7 A-4,2K-28A 11/27/2011 32.0 SLOTS Notes:General&Safety End Date Annotation 11/5/2010 NOTE:View Schematic w/Alaska Schematic9.0 11/15/2011 NOTE:WELL SIDETRACKED TO'A'8 AL1(AL1 COMES OFF MAIN WELLBORE) LOCATOR. 7,108 SEAL ASSY. 7,109 APERF. 7,222-7,225 -- WHIPSTOCK, 7,240 PRODUCTION 7129' 5.,255^;3-7,536.5-e SLOTS, 7,330-7,891 Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run SLOTS. Stn Top(RKB) IRKS) P) Make Model (in) Sery Typo Type (In) (pall Run Date Com... 7,906A.170 1 7,013.6 6,032.6 36.42 CAMCO KBG 2-9 1 GAS LIFT DMY BTM 0.000 0.012/7/2001 SLOTS, 9,172-10.073- LINER A, II II 7.320-10,073 II.i TD(2K-28A), 10,073 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday,April 04,2012 TO: Jim Regg P.I.Supervisor ' ' 414 _ SUBJECT:Mechanical Integrity Tests ( t CONOCOPHILLIPS ALASKA INC 2K-28A FROM: Lou Grimaldi KUPARUK RIV UNIT 2K-28A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-28A API Well Number 50-103-20385-01-00 Inspector Name: Lou Grimaldi Permit Number: 211-133-0 Inspection Date: 4/1/2012 Insp Num: mitLG120402095712 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2K-28A - Type Inj W TVD 1 6109 IA 60 3025 '� 2992 T 2988- - — PTD 2111330 - Type Test SPT Test psil 1527 " OA j 420 430 430 430 _ Interval INITAL - P/F - P Tubing 2400 2400 - 2400 2400 1 Notes: 1.8 Bbl's diesel pumped 1.2 returned.Bled gas cap on IA prior to pumping.Good solid post workover initial test. Wednesday,April 04,2012 Page 1 of 1 t rim z4go BAKER PRINT DISTRIBUTION LIST HUGHES COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes (mandatory) WELL NAME 2K-28APB1 RUN NUMBER (mandatory) FIELD Kuparuk BH SALESMAN Woods,Jim (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: 11/22/2011 TODAYS DATE: 3/2/2012 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY CD FIELD FINAL (digital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Oh F'HIN i 5 #OF COPIES #OF COPIES 1 ConocoPhillips Alaska,Inc. I 1 NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC I 1 I 1 Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3 BP 1 1 Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP 1 1 Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 Brandon Tucker,NRT I I 1 I State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 4 4 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 I/! Zit 6 0 BAKER PRINT DISTRIBUTION LIST HUGHES COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes (mandate WELL NAME 2K-28A RUN NUMBER (mandate FIELD Kuparuk BH SALESMAN Woods,Jim (mandatory) ;,10pr% 'VE e _ . (mandatory) COUNTY North Slope Borough DISTRICT Alaska (mandatory) FEB 0 6 (mandatory) STATE Alaska 2012 PAGE OF (mandatory) Gas COA$ LOG DATE: 11/26/2011 CLQ TODAYS DATE: 3/2/2012 (mandatory) Arleh8f8 E DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY FIELD FINAL (digital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #UN THIN IS #OF COPIES #OF COPIES 1 ConocoPhillips Alaska,Inc. 1 NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 3BP I 1 I 1 I I Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP 1 I 1 I I Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 Brandon Tucker,NRT 1 State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 4 4 0 0 - 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 Letter of Transmittal ViII Date: BAKER December 15, 2011 HUGHES To: From: Corazon Manaois Carl Ulrich/Sachin Gandra State of Alaska; DNR, Div. of Oil and Gas Baker Hughes INTEQ 550 W. 7th Ave., Suite 800 795 East 94th Avenue Anchorage, Alaska 99501-3510 Anchorage,Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2K-28A 2,1\•1.3 2K-28APB1 2K-28AL1PB1 2K-28AL1PB2 2K-28AL1 2,1 •l, - • - - (5) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Sachin Gandra, Baker Hughes, Project Engineer Sachin.Gandra@BakerHughes.com Carl.Ulrich, Baker Hughes, Survey Manager Carl.Ulrich@BakerHughes.com • • 0 c' 14 W malt,mt, moigtz 0- 0 m .< II L0QVI .2 A 0' 2. u) Z CD . 47tCL a � � 0 0) m r kJ 0 ,> lo A' I • N O N N ■� 2 -Ne E O O ii=�O 1 N CO o 6'` V0 NLt CO CI r 6' 6 • 0 Z (ill co tri= s 1161 14� • o r r r t m �W� co M O O O N V C 11) >�•0+ O O Q=gth : d M d R N N H o 'CZ C (r 3 CD N CO 0 N N O a N C r r N O W co ii 0 0 O O C) " o >,69 0) 0 0 0 2^ = 60 0 O O N N _ N N tm N 0 3 m CO to 7. c.,' d co a. N N > Cl) 6) O) r r O O d 13 6 0 a. C '-01 . 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W O 0t M) M nM M 6nM 6 N JcZd0 W$ N N N N N (i. 01- o o + o 0 m CO co o m cn u o Ln rn Ln M vi co 2 of co rn ono `9 ro m n r i + i co oo o co o n rn p 0 0 0 0 0 0 0 �” co CO co m CO co m u) M () Cc V n u) M D 0. 0 ▪ M M M M N N N li C > co O co co• N N N N N N N gg co co co cO ;i coco Ca la "' Q c , '07, O ' M Nr O v c/) co , 11 j 00 co co 00 of 6 ai MY 0- ' a -- c� O j j /c� U0 CZ CZ Z CO CO CO /y C Q. Q. N N N ( x. V.. C° o C a U) o o \Ct. U Y Y N N N C" rn Lc; rn m rn m el I CO CO t O O M N N a) M O ,--- "-- C C (a [1O O O N U) W N O d 2 :., a) a) d z �'� oc) o—o) c) cs) J.G.Eller • Staff CTD Engineer Drilling&Wells P.0.Box 100360 NOV Anchorage,AK 99510-0360 ConocoPhiHips Phone: 907-263-4172 RECEIVED April 20, 2012 MAY 0 1 2012 Commissioner AOGCC State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Correction to Completion Reports 2K-28A and 2K-28 a(1— ' 33 Dear Commissioner: Attached are corrected completion reports for wells KRU 2K-28 and 2K-28A. The 2K- 28A was a coiled tubing sidetrack from 2K-28 that was performed in November/December 2011. The original 2K-28 completion should now be considered Abandoned, not Suspended as was reported on the original 10-407. The 2K-28A completion report has been amended to include open perforations in the C-sand (7222'- 7228' MD) that we were unsuccessful in squeezing with cement prior to the 2K-28A sidetrack. If you have any questions regarding this matter, please contact J. Gary Eller at 263- ' 4172. Sincerely, J. . Iler Staff D Engineer CPAI Wells JGE/skad- STATE OF ALASKA • ALF ,OIL AND GAS CONSERVATION COM, 310N REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Frforations r Perforate r Other (v repCorrectort completion Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension (— Change Change Approved R-ogram r Operat.Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r — 211-133 _ 3.Address: 6.API Number: Stratigraphic r Service P. O. Box 100360,Anchorage,Alaska 99510 50-103-20385-01 0 0 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25588 ' 2K-28A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): _ none Kuparuk River Field/Kuparuk River Oil Pool P P 11.Present Well Condition Summary: Total Depth measured 10073 feet Plugs(measured) None true vertical 6261 feet Junk(measured) None Effective Depth measured 7320 feet Packer(measured) no packer true vertical 6274 feet (true vertucal) Casing Length Size MD TVD Burst Collapse CONDUCTOR 190 16 220 220' SURFACE 3242 7.625 3272 2956' PRODUCTION 7104 5.5 7129 6126' LINER A 407 3.5 7536 6470' LINER A> 2753 2.375 10073 6261 Perforation depth: Measured depth: 7222'-7228' (c - 5i4-N 0 REcE True Vertical Depth: 6203'-6209' 1 VED MAY 412012 Tubing(size,grade, MD,and TVD) 3.5, L-80, 7110 MD,6110 TVD AOGCC Packers&SSSV(type,MD,and TVD) no packer nipple @ 497'MD and 497'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1718 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil r Gas r- WDSPL r Daily Report of Well Operations GSTOR r WIND p" WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Gary Ell @ 263-4172 Printed Name ,`Gary Ell -` Title Wells Engineer Signature Phone:263-4172 Date kkci 1\2_ , Alia 4411 RBDMS MAY 012012 " S---1-.1 L- Form 10-404 Rein. -• 11/2011 ' Submit Original Only ' 2' —. ` t KUP 2K-28A ConocoPhiliips •W.. Well Attributes Max Angle&MD TD Wellbore APIIUWI Field Name Well Status Incl(") MD(ftKB) Act Btm(ftKB) Alaska.Inc. 501032038501 KUPARUK RIVER UNIT INJ 96.34 ( 8410.60 10,073.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date Well Coned:-20-28A,4202012 343-.50 PM -SSSV:NIPPLE Last WO: 34.59 8/26/2001 Schematk-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:WLM 7,280.0 10/24/2011 Rev Reason:ADD PERFS ninam 4/20/2012 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd __. CONDUCTOR 16 15.062 30.0 220.0 220.0 62.58 H-40 WELDED HANGER,25 Casing Description String 0... String ID...Top MKS) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 75/8 6.875 29.9 3,272.0 2,955.8 29.70 L-80 BTCM iCasing Description String 0... •String ID...Top(MB) Set Depth(1...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 51/2 4.950 25.0 7,536.3 6,287.0 15.50 L-80 LTCM 5.5"x3.5"@ 7129' Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd NILINER A 2 3/8 1.992 7,320.5 10,073.0 4.70 L-80 STL Liner Details Top Depth ...1 (TVD) Top Incl Need... Top(RKB) (RKB) (°) Item Description Comment ID(In) 7,320.5 6,274.6 62.74 BILLET LINER TOP BILLET 1.992 8,171.3 6,294.6 88.09 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.900 CONDUCTOR,_ "' 30.220 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd NIPPLE,497 'fr TUBING 31/2 2.992 25.0 7,109.5 6,110.1 9.30 L-80 EUE-8rd Completion Details Top Depth (TVD) Top Incl Nomi... Top(ftKB) (MB) (°) Item Description Comment ID(In) 25.0 25.0 -0.01 HANGER FMC GEN V TUBING HANGER 3.500 497.3 497.0 4.20 NIPPLE CAMCO DS NIPPLE 2.875 7,063.2 6,072.2 35.41 NIPPLE CAMCO DS NIPPLE 2,812 SURFACE. � 7,107.7 6,108.6 34.51 LOCATOR BAKER NO GO SUB 3.000 30-3.272 7,108.5 6,109.3 34.49 SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBLY STABBED INTO CSG SBR 3.000 I. Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth GAS LIFT, E ND) Top Incl 7,014 ( Top(ftKB) (ftKB) (°) ' Description Comment Run Date _ID(in) 7,240 6,216.2 26.15 WHIPSTOCK WHIPSTOCK ON KB PACKER 10/31/2011 0.000 Perforations&Slots Shot - Top(TVD) Btm)ND) Dens Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone _ Date )eh•.• Type Comment in 7,222 7,228 6,203.4 6,208.8 C-4,2K-28 7,330 7,891 6,277.5 6,284.7 A-4,2K-28A 4/19/211/27/2010041 32.0 6.0 APERFSLOTS 2.5"HSD,60 deg ph,random orient NIPP_E 7.0E3 7,906 8,170 6,284.5 6,294.6 A-4,2K-28A 11/27/2011 32.0 SLOTS `•1 8,172 10,073 6,294.7 A-4,2K-28A 11/27/2011 32.0 SLOTS Notes:General&Safety End Date Annotation 11/5/2010 NOTE:View Schematic w/Alaska Schematic9.0 11/15/2011 NOTE:WELL SIDETRACKED TO'A'8 AL1(AL1 COMES OFF MAIN WELLBORE) .-.A LOCATOR. 7,108 _- _ SEAL ASSY, 4. 4 7,109 APERF, 7.222-7.228 WHIPSTOCK 7.240 hit I PRODUCTION 5.5"x3.5" 7129'.25-7.536 SLOTS. 7,330.7.891 Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run SLOTS. Stn Top)ftKB) (ftKB) (') Make Model (in) Sery Type Type lie) (psi) Run Date Corn... 7.908.6.170 1 7,013.6 6,032.6 36.42 CAMCO KBG 2-9 1 GAS LIFT DMY BTM 0.000 0.0 12/7/2001 1 SLOTS, 8,172-10,073 LINER A, 7,320-10,073 ili TD(2K-28A), 10,073 Ati ' j 1 SEAN PARNELL, GOVERNOR t�T ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Martin Walters Well Integrity Project Supervisor 33 ConocoPhillips Alaska, Inc. O.\\ l P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 2K-28A Sundry Number: 312-081 Dear Mr. Walters: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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, a Daniel T. Seamount, Jr. Chair fi DATED this•2-g day of February, 2012. Encl. STATE OF ALASKA.. (A A ALAS. ..OIL AND GAS CONSERVATION COMMIS. .J (�Q��,11� 11111,1 • . APPLICATION FOR SUNDRY APPROVALS i ti 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operational Shutdown ❑ Re-enter Susp.Well [j Stimulate ❑ Alter casing E Other:Conductor Extension g- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development❑ Exploratory r y./('( 1 , Z, 3.Address: 6.API Number: / % '��!+ Stratigraphic 17 Service (] P. O. Box 100360,Anchorage,Alaska 99510 50-103-20385;9C • 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 C No r 2K-28f r- A 1.Z,-/ l" 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025588- 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): 7543 - 6476 Casing Length Size MD TVD Burst Collapse CONDUCTOR 190 16 220' 220' 1640 630 SURFACE 3242 7-5/8 3272' 2956' 6890 4790 PRODUCTION 7100 5-1/2 7130' 6127' 7000 4990 PRODUCTION 406 3-1/2 7536' 6470' 10540 10160 FIVED RFC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7222-7320 6204-6287 3.5 L Q 2 7108 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) d 2012 PACKER=SBE-BAKER 80-40 GBH-22 SEAL ASS. MD=7109,ND=6109 SSSV=CAMCO"DS"NIPPLE MD=497,ND=497 Alaska Oil R Gas Pons. COfnmi33ion 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Anchorage Detailed Operations Program ❑ BOP Sketch Exploratory ❑ Develo• - 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/1/2012 Oil r Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: i WIND r GINJ r WAG r Abandoned ❑ Commission Representative: GSTOR r1 SPLUG f j 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Martin Walters Printed Name /Martin Walters Title: Well Integrity Project Supervisor Signature /Gei 2 / 4,/&...- Phone:659-7043 Date:02/21/12 Commission Use Only Sundry Number: 31 7.7(.3? Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ❑ BOP Test r Mechanical Integrity Test [ Location Clearance ❑ Other: *. FA 04b dO G4_•y.t ..0 % b'^ 1 r(79 4.44_ Subsequent Form Required: / O -Y c illAPPROVED BY Appro / COMMISSIONER THE COMMISSION Date: 2 I Z9 1) 2 � ' AR 0 2 201471 Form 10-403 Revised 1/ 4-y/�0 R I G I N A L Submit in D,upl' ate �• •l�AL- , 1 . . ConocoPhillips Alaska P.O. BOX 100360 • ANCHORAGE,ALASKA 99510-0360 February 21, 2012 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well P D 2 4 surface casing inspection and repair. 2K- , 21/ (534,29( Please contact MJ Loveland or me at 659-7043 if you have any questions. Sincerely, AA77k(Z/&- Martin Walters ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska,Inc. Kuparuk Well 2K-28(PTD 7AIAP i,r SUNDRY NOTICE 10-403 APPROVAL REQUEST February 21, 2012 This application for Sundry approval for Kuparuk well 2K-28 is to extend the conductor to original height so as to prevent any further corrosion to SC. This well is a Kuparuk water injector • that is currently injecting seawater. At some point during normal operations the conductor subsided about six inches. With approval,the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. If possible, install anti-corrosion coating on SC as specified by CPAI Corrosion Engineer. 4. Extend the conductor to starter head and fill the void with cement and top off with sealant. 5. File 10-404 with the AOGCC post repair. NSK Problem Well Supervisor 05/07/05 • p1. _ KUP 2K-28 COn000f I lliPS AWeas Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Well Status Incl(°) MD(RKB) Act Btm(RKB) �„•Ko.,, 501032038500 KUPARUK RIVER UNIT PROD 36.93 3,495.41 7,543.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(R) Rig Release Date °°° SSSV:NIPPLE Last WO: 34.59 8/26/2001 Well Conficr.2K-28 12/28/2011 8 28:58 AM --- ---- Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag:WLM 7280.0 10/24/2011 Rev Reason:ADD SIDETRACKS ninam 12/28/2011 Casing Strings Casing Description String 0... String ID...Top)RKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd CONDUCTOR 16 15.062 30.0 220.0 220.0 62,58 H-40 WELDED HANGER,25 s! Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 75/8 6.875 29.9 3,272.0 2,955.8 29.70 L-80 BTCM Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 51/2 4.950 25.0 7,536.3 6,470.0 15.50 L-80 LTCM 5.5"x3.5" Tubing Strings Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd TUBING 31/2 2.992 25.0 7,109.5 6,109.5 9.30 L-80 EUE-8rd Completion Details 111.1 Top Depth (ND) Top Incl Mont.. Top(RKB) (RKB) ("1 Item Description Comment ID(In) CONDUCTOR, 25.0 25.0 -0.15 HANGER FMC GEN V TUBING HANGER 3.500 30-220 497.3 497.0 4.20 NIPPLE CAMCO DS NIPPLE 2.875 NIPPLE,497 ft 7,063.2 6,072.0 34.68 NIPPLE CAMCO DS NIPPLE 2.812 7,107.7 6,107.9 32.92 LOCATOR BAKER NO GO SUB 3.000 7,108.5 6,108.6 32.92 SBE BAKER 80-40 GBH-22 Seal Assembly 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (ND) Top Incl --• Top(RKB) (RKB) (') Description Comment Run Date ID(in) 7,240 6,219.0 32.79 WHIPSTOCK 35 KB PACKER WHIPSTOCK 10/31/2011 0.000 SURFACE, 30.3,2]2 Perforations&Slots Shot Top(ND) Btm(ND) Dens Top(RKB) Btm(RKB) (RKB) (RKB) Zone Date Oh- Type Comment GAS LIFT. 7,222 7,228 6,203.9 6,208.9 C-4,2K-28 4/19/2004 6.0 APERF 2.5"HSD,60 deg ph,random orient ]014 III 7,268 7,284 6,242.6 6,258.0 A-5,2K-28 4/19/2004 6.0 APERF 2.5"HSD,60 deg ph,random orient 7,300 7,320 6,270.8 6,287.0 A-4,2K-28 12/16/2001 6.0 IPERF 2.5"HSD,60 deg phase Notes:General&Safety End Date Annotation 11/5/2010 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE 7,063 - LOCATOR, 7,108 SBE,7.109 • APERF, 7,222-7,228 WHIPSTOCK. 7,240 APERF, 7,288-7,284 IPERF, 7,300-7,320 PRODUCTION 5.5'x3.5', Mandrel Details 25-7.538 Top Depth Top Port TO(2K-28). (TVD) Ind OD Valve Latch Size TRO Run 7. SLOTS Stn Top(RKB) (RKB) C) Make Model (in) Sere Type Type (in) (psi) Run Date Com... 7,330-7,1391 1 7,013.6 6,031.1 34.46 CAMCO KBG 2-9 1 GAS LIFT i DMY BTM 0.000 0.0 12/7/2001 SLOTS, 7,906-10,073 4 LINER A. 7,320-10,073 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 ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ 2 WAG ❑ WDSPL ❑ No.of Completions: Service ❑✓ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: December 12,2011 211-133/ 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 November 18,2011 50-103-20385-01 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 3'FNL,94'FEL,Sec. 11,T10N,RO8E,UM November 25,2011 2K-28A/2K-28APB1 Top of Productive Horizon: 8. KB(ft above MSL): 30'RKB 15.Field/Pool(s): 1928'FNL,2403'FWL,Sec. 11,T10N,RO8E,UM GL(ft above MSL): 148.7'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 40'FSL,2096'FEL,Sec.2,T1 ON, RO8E,UM 7320'MD/6274'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- 5938301 Zone-4 10073'MD/6261'TVD ADL 25588 TPI: x-495528 y- 5936378 Zone-4 11,SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-496309 y- 5938345 Zone-4 nipple @ 497'MD/497'TVD 2674 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) 1515'MD/1489'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 7238'MD/6217'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 30' 220' 30' 220' 24" 5.5 sx High Early 7.625" 29.7# L-80 30' 3272' 30' 2956' 9.875" 290 sx AS Lite,200 sx LiteCRETE 5.5" 15.5# L-80 25' 7129' 25' 6126' 6.75" 215 sx GasBLOK 3.5" 9.3# L-80 7129' 7536' 6126' 6470' 6.75" included above 2.375" 4.7# L-80 7320' 10073' 6274' 6261' 3" slotted liner 24.Open to production or injection? Yes ❑ No Q If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 7110' none slotted liner: 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. _.��:4.^,..t-h..:(1; 7329'-10073'MD 6278'-6261'TVD # "" ., 1 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED -vim 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting for facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 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 summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE RECEIVED RBDMS JAN 0 6_12L\ 31,,N 0 6 2012 .c01� Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 14�31R8 Q &Gas Com•G original only 2•Z'/Lpent!!Iye 28. GEOLOGIC MARKERS(List all formations and markers ,untered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes E No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1515' 1489' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk A6 7255' 6230' Kuparuk A5 7266' 6243' Kuparuk A4 7300' 6264' Kuparuk A5 7826' 6284' Kuparuk A4 7934' 6285' 2K-28APB1 N/A KOP-Kuparuk A4 8411' 6285' Kuparuk A5 8687' 6263' Kuparuk A6 9079' 6234' total depth 9237' 6225' Formation at total depth: Kuparuk A4 30. LIST OF ATTACHMENTS I Summary of Daily Operations,schematic,final directional survey f k Ist Zo►L 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Winfree @ 265-6820 Printed Nam L.Gantt+ Title: en ltd.=Supervisor Signature Q1tNQR �7 ' �'w"'�` Phone 263-4021 Date J/r/z /Z INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 `. „° KUP 2K-28A ConocoPhillips Well Attributes max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) ,naxamnhpz 501032038501 KUPARUK RIVER UNIT PROD 10,073.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Well Cont.:-2K-28.12/2812011 8'317.18 AM SSSV,NIPPLE Last WO: 34.598/26/2001 Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag:WLM 7,280.0 10/24/2011 .Rev Reason.ADD SIDETRACKS ninam 12/28/2011 Casing Strings Casing Description String 0... String ID,..Top(ftKB) Set Depth(8...Set Depth(TVD)...String Wt...String,.. String Top Thrd LINER A 23/8 1.992 7,320.5 10,073.0 4.70 L-80 STL Liner Details HANGER,25 Top Depth • (TVD) Top Incl Noon... Top(ftKB) IRKS) (°) Item Description Comment ID(in) 7,320.5 BILLET LINER TOP BILLET 1.992 8,171.3 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.900 Jri Perforations&Slots Shot Top(TVD) Btm(TVD) Dens Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (sh-• Type Comment 7,330 7,891 A-4,2K-28 11/27/2011 32.0 SLOTS 7,906 10,073 A-4,2K-28 11/27/2011 32.0 SLOTS CONDUCTOR. 30-220 NIPPLE,497 l Gns LIo,FT a _.-H NIPPLE 7,063 { I L LOCATOR, 7,108 SBE.7,109 APERF,___41 \\\: 7,222-7,228 WHIPSTOCK 7,240 Il APERF, Mandrel Details 7.768-7,204 Top Depth Top Port (TVD) In OD Valve Latch Size TRO Rue Ste Top(ftKB) (ftKB) (°l Make Model (in) Sery Type Type lin) (ps1) Run Date Corn... 1 7,013.6 6,031.1 34.46 CAMCO KBG 2-9 1 GAS LIFT DMY BTM 0.000 0.0 12/7/2001 PERF. 7.300-7.320 111 PRODUCTION 5.51[35", 25-7,538 TD(26-213), • A 7,543 11 M 0111 z `Wo bm Q= m d a ca 0 Q co cc VI 1 Q 1- >% Q. 2 Z a) = Q 0. s — •— = V) .� 0- s = O 0. 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U Y Y N N N P- .11 m 1/ r0-/' m m m (c) (n criY ` O O 5., 6 to N NCDONO O N1 N N O) CO O Y C 0 C '� ON co N O O r r 0 : _ 0 Coof Di of oai ai 2 Q V 0 : d d Lo 00. U)) 0 Cl) 2K-28 Pre and Post Rig Work Summary DATE SUMMARY 9/21/11 DRIFT TBG W/ 8' X 2.25" DD BLL. .S+ BLR OAL= 36') TO TAG @ 7427' SLM .,)B COMPLETE. 10/5/11 PERFORMED HOISTING OPERATIONS FOR GYRO DATA. GYRO DATA LOGGED CONTINUOUS SURVEY FROM SURFACE TO A DEPTH OF 7109'AT THE SBE. GYRO DATA LOGGED REPEAT PASS FORM 7109' TO SURFACE. RIGGED DOWN TURNED WELL OVER TO DSO. 10/24/11 DRIFT W/ 17' 10 1/2"X 2.78" DUMMY WHIP STOCK TO 7280' WLM NO PROBLEMS , PRE E-LINE 10/30/11 SET BAKER 35 KB PACKER WHIPSTOCK AT 7240' ORIENTED 18 DEGREES FROM HIGHSIDE LOOKING DOWNHOLE. PULL UPHOLE AFTER SET AND PERFORM 30 MINUTE TEMP/ PRESS STATION LOG AT 7200'. 147 DEGF / 3870 PSIG. PRESSURE FELL OF FROM INITIAL 3884 PSIG. PIP TAG SET AT 7246.5'. (2 PIPS = 2uCi OF Co-60). PIP TAG DATA SHEET ATTACHED IN WSR. 10/31/11 RIG IN HOLE WITH MIT 24 ARM CALIPER TO VERIFY THE ORIENTATION OF WHIPSTOCK SET/AFTER 3 LOG PASSES ACROSS THE WHIPSTOCK IT WAS VERIFIED THAT IT WAS SET 20 DEGREES RIGHT OF HIGH SIDE IN HOLE/ LITTLE RED CONNECT TO LUBRICATOR AND PUMP .10 BPM INTO TUBING AND PRESSURE INCREASED TO 3000 PSI /COULD NOT GET RATE INTO THE C SAND/ PERFORM BOTTOM HOLE PRESSURE SURVEY ( PRESSURE © 7230' WAS 3958 PSI AT END OF 45 MINUTE STATION ) 12/21/11 ATTEMPT TO DRIFT FOR BHPS, MAX DEPTH ACHIEVED 2620' SLM WITH TOOLS FALLING 10' FPM DUE TO BRINE, CALL COMPANY MAN, JOB CALLED OFF. 12/28/11 TAGGED TOP OF LINER @ 7238' RKB WITH 2" LIB. MEASURED BHP @ 7233' RKB ( 3939 psi max ). JOB COMPLETE. ConocoPhillips Time Log & Summary We/v,ew Web Reporting Report Well Name: 2K-28 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 11/15/2011 8:00:00 PM Rig Release: Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11/15/2011 24 hr Summary Rig move. Spot rig over well,fix tree valves and flanges.Weld on reel. NUBOP's. Rig Accept at 20:00 HRS 06:00 20:00 14.00 MIRU MOVE MOB P Move rig from 2K-22 to 2K-28.***Rig accept at 20:00 hrs*** 20:00 23:00 3.00 MIRU SURFEC NUND T Call out valve crew tree problems- SSV External Seal/spacer ring out of place, inner OA valve leaking. Inpsect/grease to determine if replacement valves needed Prior to NUBOP stack.Cannot install valve on MP line. Rig up to continue with BOP test. 23:00 00:00 1.00 MIRU WHDBO NUND P Start NUBOP's 11/16/2011 Complete BOP test,pressure test tiger tank line and lubricator. Pull BPV SITP 1400 psi.Start cutting coil. Hold Safety Stand up&pre-spud meeting. 00:00 02:30 2.50 0 0 MIRU WHDBO NUND P Rig up and prepare for BOP testing. 02:30 12:30 10.00 0 0 MIRU WHDBO BOPE P Begin BOP testing High 4500psi/Low 250psi.State test Witnessed by John Crisp.Test Gas alarms Hi/Low. 0 Fails 12:30 14:30 2.00 0 0 MIRU WHDBO NUND T Reposition outer MP valve(T2)on stack. Unable to install valve handle to open/close valve due to it hitting on platform. PT(4000psi)good on MP line 14:30 14:36 0.10 0 0 MIRU WHDBO BOPE P Pressure test Inner reel valve.Good 14:36 15:36 1.00 0 0 SURPRI WELLPF CTOP P Lift injector off well. Cut CTC off, install boot on E-line 15:36 16:36 1.00 0 0 SURPRI WELLPF SLPC P MU injector head to welll, Reverse Circulate SW 20bbrls at 2.3 BPM for slack management, lift off well. 16:36 18:06 1.50 0 0 SURPRI WELLPF SLPC P PJSM, Set up rig floor for BPV removal and CT cutting. 18:06 19:36 1.50 0 0 PROD1 WELLPF SFTY P Safety Stand up with both crews 19:36 21:06 1.50 0 0 PROD1 WELLPF PRTS P Pressure test Lubricator and tiger tank line.Two small leaks in line. Blow down, hammer up. Re-test to 2000 psi. 21:06 22:36 1.50 0 0 PROD1 WELLPF MPSP P Pressure 1500psi, Equalize above BPV-Pull BPV. Bleed down WHP to zero-increase over 5 minutes. Shut in and bleed down lines. Rig down Lubricator. 22:36 23:36 1.00 0 0 PROD1 WELLPF SFTY P Pre-spud meeting with Maddy crew. PJSM for cutting pipe Page 1 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:36 00:00 0.40 0 0 PROD1 WELLPF CTOP P Start cutting 1400'of CT. 11/17/2011 Cut 1400ft of CT. Pump slack&cut back 18'to find cable. Re-head, pressure&pull test. Deploy BHA#1 with 2.80"mill/string mill. RIH and circ out well fluid with used flo-pro.Tag TOWS 7238.3'. Start milling window. 00:00 04:30 4.50 0 0 PROD1 WELLPF CTOP P Continue cutting 1400ft of CT. Re-tighten reel bolt. 04:30 06:00 1.50 0 0 PROD1 WELLPF CTOP P Reverse circ.CT to pump slack back. 06:00 06:15 0.25 0 0 PROD1 WELLPF SFTY P Crew change, PJSM 06:15 07:15 1.00 0 0 PROD1 WELLPF SLPC P Cut CT to find cable. 18'cut.Total CT cut entered into Cerberus-1420'. 07:15 08:45 1.50 0 0 PROD1 WELLPF SLPC P MU CTC, pull test 35K 08:45 10:00 1.25 0 0 PROD1 WELLPF SLPC P MU BHI drilling head,pressure test CTC 4000psi. 10:00 11:30 1.50 0 0 PROD1 WELLPF PRTS P Pressure test both PDL's 1500psi. Well Head pressure 1400 psi. Bleed down to 220psi out to tiger tank. Pressure build back up 360psi in 5 minutes.Shut in well. 11:30 11:45 0.25 0 0 PROD1 WHPST SFTY P PJSM, Deploy BHA 11:45 12:30 0.75 0 0 PROD1 WHPST PULD P Start to deploy BHA#1. (.6K AKO) 12:30 13:15 0.75 0 0 PROD1 WHPST SFTY P BHA made up in PDL and made up to well.Well shut in. Hold Pre-Spud meeting 13:15 14:15 1.00 0 0 PROD1 WHPST PULD P Continue to Deploy BHA#1.WHP 1125psi 14:15 18:15 4.00 73 7,239 PROD1 WHPST TRIP P RIH, Pumping slack forward,taking returns to tiger tank. Circ out SW with used Flo-pro. 18:15 00:00 5.75 7,239 7,241 PROD1 WHPST MILL P Dry tag TOWS=7239'Start pumping-tag TOW 7238.3' . Start milling window. 1.50 bpm, 3500, BHP 3624, ECD 11.5,WHP 0, WOB 1 -2.5K,Ct weight 17K.Auto drill-light medal returns after.5 ft c milled. 11/18/2011 Complete milling window.TOW=7238' BOW=7243'. P/U build assembly with 2.5 AKO. Drilled to 7320'. Pull BHA for less motor AKO due to 50+doglegs. 00:00 04:00 4.00 7,241 7,245 PROD1 WHPST MILL P Mid-Point-Continue milling window- 1.50 bpm, 3490, BHP 3630,WHP 0, ECD 11.6, ROP 1-2 fph,WOB 2.3K, I , CT weight 17.6K. Exit window 7243' ��L'�IA Formation returns in surface. Continue following milling procedure. No-stalls. TOW=7238/BOW=7243'. 04:00 08:00 4.00 7,245 7,259 PROD1 WHPST MILL P Increase to 4-7 fph.Continue milling additional 15ft. Start holding WHP for ECD of 12.5 08:00 08:45 0.75 7,259 7,236 PROD1 WHPST MILL P Pick up backreaming window up, down, up 08:45 09:15 0.50 7,236 7,236 PROD1 WHPST MILL P Drift window. Good Page 2 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 11:00 1.75 7,236 0 PROD1 WHPST TRIP P Open EDC, POOH following 9.1ppg MP schedule 11:00 11:30 0.50 0 0 PROD1 WHPST SFTY P At surface,Crew change. PTM 11:30 11:45 0.25 0 0 PROD1 WHPST SFTY P PJSM, 11:45 14:15 2.50 0 0 PROD1 WHPST PULD P Undeploy BHA 1,Gauge mills, (2.80 No-Go mill,2.79 No-Go string mill). Service injector head and reel. Change stripper rubber 14:15 15:30 1.25 0 0 PROD1 DRILL PULD P Deploy BHA 2(2.5 AKO) 15:30 18:30 3.00 62 7,260 PROD1 DRILL TRIP P RIH with EDC open following MPD. Tie in correction+2.Circulate new mud at bottom. 18:30 20:00 1.50 7,260 7,270 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm, 3730, BHP 3975, ECD 12.6,WHP 0, ROP 8, WOB 1.1K, Ct weight 15K.Tool orientation problems starting out. P/U and check orientator-works drill ahead slowly due to interference. 20:00 21:00 1.00 7,270 7,295 PROD1 DRILL DRLG P Drilling ahead normal-1.40 bpm, 3770, BHP 3940, ECD 12.5,WOB 2.1K,Ct weight 15K, ROP 40. 21:00 22:00 1.00 7,295 7,320 PROD1 DRILL WPRT P Wiper trip&Tie into K1 zero correction&pip tag @ 7245'.TOW= 7238'/BOW 7243'. Doglegs are showing 47-55 degrees.Average is 51 degrees. Drill to 7310'with lighter WOB for a few more data points-AVG 47 degrees. Call town. 22:00 00:00 2.00 7,320 2,500 PROD1 DRILL TRIP P Pull BHA to lower motor AKO. P/U weight 30K-Open EDC&follow MPD. 11/19/2011 P/U BHA#3 with 2.3 AKO&drill build section to TD of 7585'with 46-60 degree doglegs. POOH&P/U BHA #4 with RSM and bi-center. 00:00 01:00 1.00 2,500 72 PROD1 DRILL TRIP P POOH following MPD 01:00 02:30 1.50 72 0 PROD1 DRILL PULD P PJSM-Undeploy BHA 02:30 03:30 1.00 0 72 PROD1 DRILL PULD T Change to 2.3 AKO. Deploy BHA.#3 03:30 06:30 3.00 72 7,145 PROD1 DRILL TRIP T RIH with EDC open pumping .5 bpm. 06:30 06:45 0.25 7,145 7,145 PROD1 DRILL DLOG T Tie in depth+3'correction 06:45 10:00 3.25 7,320 7,470 PROD1 DRILL DRLG P Drill ahead 1.4 BPM, 3350 CTP, 4000 BHP, 1.7K WOB 10:00 10:30 0.50 7,470 7,470 PROD1 DRILL WPRT P Wiper trip to window.30K PUW 10:30 11:30 1.00 7,470 7,500 PROD1 DRILL DRLG P Drill ahead 1.4 BPM,3350 CTP, 4000 BHP, 1.7K WOB 11:30 12:00 0.50 0 PROD1 DRILL WPRT PUH Getting 51, Discuss with town 12:00 14:45 2.75 7,500 7,585 PROD1 DRILL DRLG P Drill ahead next surveys 48 DLS. Control drill minimizing WOB. 1-1.5K WOB. 14:45 18:15 3.50 7,585 72 PROD1 DRILL TRIP P TD build section. Last 2 surveys 60+ DLS. POOH Page 3 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:15 20:15 2.00 72 0 PROD1 DRILL PULD P PJSM Undeploy BHA#3.Service injector and reel. 20:15 22:45 2.50 0 68 PROD1 DRILL PULD P PJSM Start P/U BHA#4 RSM with rebuild Bi-center.Auto choke WHP pressure reading not functioning.Still .have secondary WHP reading. 22:45 00:00 1.25 68 5,500 PROD1 DRILL TRIP P RIH with EDC open following MPD running the choke on manual. Fix WHP while tripping in hole. 11/20/2011 Drilling ahead with RSM.Slow pump rate through higher Doglegs in build.Mud swap with 1210ft on system .8%solids. 00:00 01:30 1.50 5,500 7,583 PROD1 DRILL TRIP P RIH following MPD. +3 ft correction. Close EDC-RIH slowly through window,slight weight gain bottom of window. RIH min rate through build weight gain to 3K WOB @ 7275 with minimal CT weight change.WOB back down to 1K @ 7350'.Good down to 7572'WOB increase to 2K, dropped off 7578'. 01:30 03:30 2.00 7,583 7,645 PROD1 DRILL DRLG P Bring pumps up to drilling rate,zero WOB-Motor work @ 7585'. BHA& pressures look normal. 1.40 bpm, 3680, BHP 4010,WOB 1.5K,CT weight 12k, ECD 12.6, WHP 80, ROP 50.Control drill for the first 60'. 03:30 05:00 1.50 7,645 7,735 PROD1 DRILL DRLG P Drill ahead normal-1.45 bpm,3800, BHP 4030,WHP 100, ECD 12.6, WOB 2.6K, Ct weight 14K, ROP 60. 05:00 05:18 0.30 7,735 7,735 PROD1 DRILL WPRT P Wiper trip to window,29K PUW 05:18 06:18 1.00 7,735 7,735 PROD1 DRILL DLOG P MADD pass build section 7590-7260 06:18 06:36 0.30 7,735 7,735 PROD1 DRILL WPRT P RBIH 06:36 11:00 4.40 7,735 7,885 PROD1 DRILL DRLG P Drill ahead 1.4 BPM,4016 BHP, 3616 CTP, holding 87 psi MP choke 11:00 11:30 0.50 7,885 7,885 PROD1 DRILL WPRT P Wiper trip to window, 30K PUW. While PUH through 60 DLS 7600', Bore pressure increase 275psi, surface psi increase 230 psi. Continue wiper trip. 11:30 12:00 0.50 7,885 7,885 PROD1 DRILL WPRT P RBIH 12:00 14:45 2.75 7,885 8,035 PROD1 DRILL DRLG P Drill ahead 1.4 BPM,4052 BHP, 3854 CTP, holding 87 psi MP choke. Drilling pressures 200+psi higher on bottom after wiper trip. Drill ahead closely monitoring RSM. Discuss possible damage of RSM pulling through high DLS.Currently working fine. 14:45 15:30 0.75 8,035 8,035 PROD1 DRILL WPRT P Wiper trip to window. 30K PUW. Lower pump rate and POOH speed when pulling RSM thru high DLS area. .75 BPM at 10-15 FPM Page 4 of 21 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 15:30 15:42 0.20 8,035 8,035 PROD1 DRILL DLOG P Tie in depth to RA marker+.5' correction. RBIH 15:42 17:12 1.50 8,035 8,185 PROD1 DRILL DRLG P Drill Ahead 1.44 BPM,4057 CTP, 4071 BHP, 10K CTW, 70 psi MP choke. 17:12 18:42 1.50 8,185 8,185 PROD1 DRILL WPRT P Wiper trip slow pump rate and speed down through higher DLG. 18:42 20:30 1.80 8,185 8,335 PROD1 DRILL DRLG P Drilling ahead 1.45 bpm,4080, BHP 4144,WHP 70,WOB 1.8K,Ct weight 13K. 8230'-annular pressure increasing slowly, open choke fully. BHP 4080psi. Run mud property check. .8%solids.Call out vac trucks. 20:30 22:00 1.50 8,335 8,335 PROD1 DRILL WPRT P Wiper trip-P/U weight 30K. Slow pump rates through DGL in build. Clean through build. 22:00 00:00 2.00 8,335 8,485 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,4150, BHP 4100,WHP 0,WOB 2K, ROP 80,Ct weight 12K. Start pumping new mud 8450'-1230ft on system.8%solids. 11/21/2011 Continue drilling ahead A Lateral utilizing RSM BHA, increase claystop to 2.5%in mud system. 00:00 02:00 2.00 8,485 8,485 PROD1 DRILL WPRT P Wiper trip P/U weight 30K.Tie in =+4ft. lincrease in cutting over shaker during top of wiper trip with new mud around.Oil saturated samples/cuttings. 02:00 03:30 1.50 8,485 8,635 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,3790, BHP 4090,WHP 130, ECD 12.7, ROP 120,WOB 1.7K, CT weight 13K. 03:30 05:30 2.00 8,635 8,635 PROD1 DRILL WPRT P Wiper trip-P/U weight 30K. Drop pump rate to.75 BPM and slow down to 10-15 FPM thru high DLS ✓ 05:30 08:00 2.50 8,635 8,785 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm, 3654 CTP, BHP 4080,WHP 120, ECD 12.7, ROP 120,WOB 1.7K,CT weight 11K. 08:00 10:00 2.00 8,785 8,785 PROD1 DRILL WPRT P Wiper trip to window 30K PUW. Drop pump rate to.75 BPM and slow down to 10-15 FPM thru high DLS 10:00 12:30 2.50 8,785 8,935 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm, 3756, BHP 4108,WHP 120, ECD 12.7,WOB 2-3K, CT weight 10K. 12:30 14:30 2.00 8,935 8,935 PROD1 DRILL WPRT P Wiper trip to window 30K PUW.Tie in depth to RA marker+4' corrrection. Drop pump rate to.75 BPM and slow down to 10-15 FPM thru high DLS 14:30 17:00 2.50 8,935 9,085 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,3904, BHP 4117,WHP 130, ECD 13, ROP 120, WOB 2K,CT weight 10K. 17:00 20:00 3.00 9,085 9,085 PROD1 DRILL WPRT P Wiper trip to window 30K PUW.Tie in depth to RA marker+4' corrrection. Drop pump rate to.75 BPM and slow down to 10-15 FPM thru high DLS Page 5 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 23:00 3.00 9,085 9,174 PROD1 DRILL DRLG P Drilling ahead-1.45 bpm,3800, BHP 4095,WHP 70, ROP 25,WOB 1.4K, Ct weight 12.3K. Poor shale/clay formation from 9050', increase claystop from 1.5%to 2.5%. @ 9100ft.Control drilling trying to get tool to drop. 23:00 00:00 1.00 9,174 9,190 PROD1 DRILL DRLG P BHA wiper P/U weight 30K. Drilling ahead. 11/22/2011 Drill into A6, POOH Set Anchored Billet @ 8410 00:00 02:00 2.00 9,190 9,237 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3900, BHP 4130, ECD 13,WOB.8K, CT weight 12K, ROP 25-40. Hard time turning down with RSM.Tried WOB/Less WOB no changes. Geo steering-samples 100% silt/claystone. 02:00 03:30 1.50 9,237 7,200 PROD1 DRILL WPRT T Wiper trip-P/U weight 30K Call town to discuss BHA change&Geo out.= . le.a @ rough window Determined sand drilled was non target A5 sand. Made decision to POOH and PU anchored billet for geologic ST in the A4. 03:30 06:00 2.50 7,200 0 PROD1 DRILL TRIP POOH following MPD. 06:00 06:30 0.50 0 0 PROD1 DRILL SFTY T A surface. rew change, PJSM 06:30 08:00 1.50 0 0 PROD1 DRILL PULD T Undeploy BHA 08:00 10:00 2.00 0 0 PROD1 DRILL SVRG T Service injector head and reel, repair PDL heat line. (waiting on BOT) 10:00 12:45 2.75 0 0 PROD1 DRILL PULD T Conduct TGSM. Deploy BHA. 12:45 15:45 3.00 0 8,410 PROD1 DRILL TRIP T RIH W/Anchored billet BHA,tie in for a+2'correction. stop at setting depth 15:45 16:00 0.25 8,410 8,410 PROD1 DRILL ANCR T Set anchor billet,top @ 8410' 16:00 18:15 2.25 8,410 73 PROD1 DRILL TRIP T TOOH 18:15 21:45 3.50 73 72 PROD1 STK PULD T PUD BHA#5 Billet Run, PD BHA#6, Drill by BHA with .7 degree motor and Bi-Center bit, Make up to Coil track and surface test tool,Tag up 1 and set counters e� 1 21:45 23:30 1.75 72 7,155 PROD1 STK TRIP T RIH EDC Open 23:30 23:36 0.10 7,155 7,175 PROD1 STK DLOG T Log tie in for+3',Close EDC 23:36 00:00 0.40 7,175 8,031 PROD1 STK TRIP T Trip in to dry tag billet 11/23/2011 Drill past Billet @ 8410, Drill ahead to 9129 00:00 00:12 0.20 8,031 8,412 PROD1 STK TRIP T Continue in well to dry tag billet 00:12 03:42 3.50 8,412 8,440 PROD1 STK KOST T Tag TOB @ 8410.6 with pumps on, Start time milling,stalled @ 8410.7 )K'zIA and 8411.12, 1.4 BPM @ 3980 PSI FS, BHP=4070,WO Choke Page 6 of 21 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 03:42 03:54 0.20 8,440 8,440 PROD1 STK WPRT T Drill by down to 8440, PUW=30K, Drift past billet looks good 03:54 05:30 1.60 8,440 8,570 IPROD1 DRILL DRLG T 8440', Drill Ahead 1.4 BPM @ 3910 PSI FS, RIW=15.3K,Wide Open Choke, BHP=4080 05:30 07:15 1.75 8,570 8,570 PROD1 DRILL WPRT T Pull wiper 30k off BTM, pull wiper to 7250'. RBIH 07:15 09:30 2.25 8,570 8,720 PROD1 DRILL DRLG T Drill ahead, 1.40 BPM 4330 PSI, ECD 12.91.Wide open choke 4115 BHP drill to 8720'. Had one stall @ 8708'. 09:30 10:45 1.25 8,720 8,000 PROD1 DRILL WPRT T Pull wiper, 30k off btm. 10:45 11:15 0.50 8,000 8,260 PROD1 DRILL DLOG T Perform MAD pass from 8006'to 8260@10FPM 11:15 11:30 0.25 8,260 8,720 PROD1 DRILL TRIP T RBIH 11:30 14:45 3.25 8,720 8,870 PROD1 DRILL DRLG T Drill ahead. 1.40 BPM,4182 psi. ECD 12.92 4112 BHP 14:45 16:45 2.00 8,870 8,870 PROD1 DRILL WPRT T Pull wiper,31k Off BTM. RBIH,tie in for a+1'correction. Drill solids upto .65 Return trucks are on the way. 16:45 20:00 3.25 8,870 9,020 PROD1 DRILL DRLG T Drill ahead. Swap to new mud system.2 dirty trucks on location. 20:00 22:12 2.20 9,020 9,020 PROD1 DRILL WPRT T Wiper trip to window, PUW=30K, BHP=4110 22:12 00:00 1.80 9,020 9,129 PROD1 DRILL DRLG T 9020', Drill Ahead, 1.45 BPM @ 3950 PSI FS, BHP=4120, RIW=10.3K with DHWOB=1.6K Midnight Depth 9129 11/24/2011 Drill Ahead to 9465, POOH for HOT Failure 00:00 01:15 1.25 9,129 9,170 PROD1 DRILL DRLG T 9129 Midnight depth, Drill ahead, 1.48 BPM @3950 PSI FS, BHP=4120, ECD=12.9 01:15 03:39 2.40 9,170 9,170 PROD1 DRILL WPRT T Wiper to window, PUW=31K, BHP=4110, ECD=12.9 03:39 05:45 2.10 9,170 9,237 PROD1 DRILL DRLG T 9170', Drill Ahead, 1.46 BPM @ 3850 PSI FS, BHP=4155,Clean trip in and out, ECD=12.9 05:45 07:00 1.25 9,237 9,320 PROD1 DRILL DRLG P Drilled back to 9237',end troubled time. continue drilling. 07:00 09:30 2.50 9,320 9,320 PROD1 DRILL DRLG P Wiper to Window 09:30 11:45 2.25 9,320 9,465 PROD1 DRILL DRLG P Drill ahead, 1.46 BPM @ 3880 PSI. 12.96 ECD,4122 BHP. Directional driller having some tool issues.Call town to discuss. Stall out @ 9465', over pull to 35k-puh.wiper up,get call to TOOH to swap out HOT. 11:45 13:45 2.00 9,465 7,215 PROD1 DRILL WPRT P Wiper to window 13:45 15:15 1.50 7,215 72 PROD1 DRILL TRIP T Trip out to replace HOT Begin BHI NPT Page 7 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:15 18:45 3.50 72 72 PROD1 DRILL PULD T Tagged up&spaced out.Conduct PJSM. Undeploy BHA#6, PD BHA #7 with .7 degree motor and Hycalog Bi Center, Make uo to coil and surface test 18:45 19:15 0.50 72 1,704 PROD1 DRILL TRIP T RIH, EDC open .6 BPM 19:15 20:00 0.75 1,704 72 PROD1 DRILL TRIP T Communication lost with BHA. POOH to troubleshoot 20:00 21:30 1.50 72 72 PROD1 DRILL PULD T Tag up and space out, PJSM Strip off well maintaining MP.Trouble shoot problem to UQC and LQC. Change out and retest.Make up to coil and surface test. Strip on well 21:30 23:12 1.70 72 7,155 PROD1 DRILL TRIP T Trip in well with BHA#8, .7 degree motor and Bi center to TD"A"Lateral 23:12 23:15 0.06 7,155 7,171 PROD1 DRILL DLOG T 7155'Log tie in for a+3'correction, close EDC, PUW=30K End BHI NPT, 9.5 HRS 23:15 23:59 0.74 7,171 8,411 PROD1 DRILL TRIP P Trip in to drill,clean pass through window Midnight 8411 11/25/2011 Driill Ahead from 9465 to 10017' 00:00 00:30 0.50 8,411 9,465 PROD1 DRILL TRIP P Tripping in to Drill(cont) 00:30 00:42 0.20 9,465 9,467 PROD1 DRILL DRLG P 9465', Drill ahead, 1.45 BPM @ 3766 PSI FS, BHP=4165, RIW=9.6K DHWOB=2.6K 00:42 01:12 0.50 9,467 9,467 PROD1 DRILL WPRT P DD wiper to reboot computers, PUW=28K 01:12 01:48 0.60 9,467 9,474 PROD1 DRILL DRLG P 9467', Drill ahead, 1.48 BPM @ 3777 PSI FS, BHP=4139 01:48 03:18 1.50 9,474 9,474 PROD1 DRILL WPRT T 9474,Tool not holding tool face, PUH to re image CTK Computer 1.5 HRS BHI NPT 03:18 05:45 2.46 9,474 9,620 PROD1 DRILL DRLG P 9474', 1.45 BPM @ 3800 PSI FS, BHP=4170, ECD=13.1 Tool still acting up 05:45 09:45 4.00 9,620 9,620 PROD1 DRILL WPRT P Wiper up to window. RBIH,tie in for a+5'correction. 09:45 14:00 4.25 9,620 9,770 PROD1 DRILL DRLG P Drill ahead 1.45 BPM 4014 PSI, 4149 BHP 13.07 ECD 14:00 17:15 3.25 9,770 9,770 PROD1 DRILL WPRT P Wiper to the window,29k off BTM. 17:15 19:03 1.80 9,770 9,920 PROD1 DRILL DRLG P Drill ahead, 1.47 BPM 4113 PSI, 4214 BHP, 13.29 ECD 19:03 22:33 3.50 9,920 9,220 PROD1 DRILL WPRT P Wiper to window, PUW=28.5k 22:33 23:59 1.44 9,220 10,017 PROD1 DRILL DRLG P 9220', Drill Ahead, 1.45 BPM @ 3860 PSI FS, BHP=4223 Midnight 10117' 11/26/2011 Condition hole-Kill well,M/U 58 Jts lower liner segmet, RIH Page 8 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 10,017 10,070 PROD1 DRILL DRLG P Drilling ahead 1.45 BPM @ 3860 PSI FS, RIW=7.6K DHWOB=1.6K, BHP=4223 01:00 02:18 1.30 10,070 8,170 PROD1 DRILL WPRT P Wiper to window with tie in, PUW=30K 02:18 03:24 1.10 8,170 10,065 PROD1 DRILL WPRT P Coming up on wiper Geo's called TD, Turn around to pull. - -'es and �) chase to swa•,TD=10070' 03:24 07:45 4.36 10,065 0 PROD1 DRILL WPRT P 10065,sweep- _-• g out, PUW=27K,wipe to swab 07:45 11:15 3.50 0 10,073 PROD1 DRILL TRIP P Wiper to swab complete. RBIH. Note: Called state to give 24 hour BOP test notice(07:40)Test waived by Chuck Scheve.Tie in for+3. RIH to TD @ 10073' 11:15 14:45 3.50 10,073 0 PROD1 DRILL KLWL P Start laying in 9.8 PPG bead pill from TD to 7600'. 12.5 KWL to surface 14:45 15:15 0.50 0 0 PROD1 DRILL SFTY P Watch for no flow for 30 minutes while PJSM for laying down BHA. Well is on a vac. 15:15 16:30 1.25 0 0 PROD1 DRILL PULD P Lay down BHA.Service injectior. 16:30 21:00 4.50 0 1,900 COMPZ CASING PUTB P Run liner,(segment#1)Non-ported bullnose,58 jts slotted liner,& Shorty deployment Sleeve. 21:00 22:00 1.00 1,900 1,946 COMPZ CASING PULD P PJSM,M/U Coil track to liner,strip on well,surface test tool.Tag up and set counters 22:00 23:24 1.40 1,946 7,045 COMPZ CASING TRIP P Trip in hole with"A"later lower section. Non Ported bull nose, 58 Jts (1900.49'),shorty deployment sleeve, EDC Closed 23:24 23:30 0.10 7,045 7,055 COMPZ CASING DLOG P Tie into flag for a+1.2'correction. 23:30 23:59 0.49 7,055 7,711 COMPZ CASING TRIP P Trip in with liner, Get PUW @ 7200 @ 30K Midnight Depth 7711' 11/27/2011 Ran"A"Lateral in two runs, 10073 to 7320,Start BOP Test.Witness waived by Chuck Sheve,AOGCC 00:00 00:42 0.70 7,711 9,035 COMPZ CASING TRIP P Continue in well with liner 00:42 00:48 0.10 9,035 9,057 COMPZ CASING DLOG P Log gamma tie in for+2'(+3'total correction with flag) 00:48 01:30 0.70 9,057 10,073 COMPZ CASING TRIP P Trip in liner,set down @ 10073, PUW=33K,Set back on bottom, Pump off liner PUW=28K TOL=8147 01:30 03:45 2.25 10,073 49 COMPZ CASING TRIP P PUH to 10057, remove liner length from counters 8156'.Continue out of well pumping 12.5 completion fluid across the top. Paint EOP flags @ 7200&6200' 03:45 04:45 1.00 49 0 COMPZ CASING PULD P PJSM,conduct 10 min no flow test. Lay down liner running BHA 04:45 05:15 0.50 0 0 COMPZ CASING RURD P Rig up floor to run liner/Service Injector Page 9 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 07:15 2.00 0 0 COMPZ CASING PUTB P PJSM, P/U A Lateral upper section 07:15 07:45 0.50 0 895 COMPZ CASING SFTY P PJSM, load up billet&BHI BHA. 07:45 11:45 4.00 895 8,173 COMPZ CASING TRIP P RIH w/lateral"A"upper section,stop @ flag-.05.Get pu wt,33k. Set liner @ 8169'. Pump off liner, 30k pu wt. 11:45 13:45 2.00 8,173 0 COMPZ CASING TRIP P PUH,tie into Gamma, +5' correction. Puts top of liner @ 7323'. x TOOH to surface. 13:45 18:00 4.25 0 0 COMPZ CASING PULD P Tagged up. Lay down BHA. Cicurlate out 12.5 out of coil with water to prep for BOP test.Valve crew on location to service tree. Remove checks from UQC.Test inner reel valve 18:00 18:30 0.50 0 0 COMPZ WHDBO SFTY P Crew change, PJSM,Valve alignment, 18:30 00:00 5.50 0 0 COMPZ WHDBO BOPE P Perform Bi Weekly BOPE Test,Test witness waived by Chuck Scheve, AOGCC 11/28/2011 Complete BOPE Test, Drill By Billet @ 7323',TD Build/Turn to 7503',TOOH 00:00 03:00 3.00 0 0 COMPZ WHDBO BOPE P Continue BOPE Test,Complete test @ 0300 03:00 04:00 1.00 0 0 PROD2 STK CTOP P Skid cart forward and install check valves in UQC, Prep to circulate coil back to 12.5 KWF 04:00 05:00 1.00 0 0 PROD2 STK CIRC P Circ coil, Initialy looked like ice plug in putz? Take returns to TT,Open up well fill and check for flow 05:00 07:30 2.50 0 0 PROD2 STK PULD P Change out& PJSM. Load up/Deploy BHA 07:30 10:15 2.75 62 7,165 PROD2 STK TRIP P RIH W/BHA#11, had to slow speed down,counting collars on the way down.Start sending 15 bbls spacer &flo pro down coil to time out to bit Y/ @ window depth,Tie for a+3' correction. 10:15 11:45 1.50 7,165 7,323 PROD2 STK CIRC P Tie for a+3'correction. @ 7182'On like down coil w/9.8 flo-pro.Get flow pro all around,shut down to close EDC. RIH Tag TOB @ 7323'. 11:45 15:45 4.00 7,323 7,375 PROD2 STK KOST P PUH, Pumps up 3700 PSI FS. Ease down see light motor work @ 7322.3' Let it drill off,start time drilling 1 k��n�L FPH,follow KO procedure. Drill down 62 to 7375' PUH and drift past billet clean. Continue drilling 1.42 BPM @ 3974 PSI,wide open choke,0 WHP. 12.43 ECD,4054 BHP 15:45 17:30 1.75 7,375 7,503 PROD2 DRILL DRLG P 7375', Drill Ahead, 1.4 BPM @ 4190 PSI FS, BHP=4090 17:30 20:15 2.75 7,503 64 PROD2 DRILL TRIP P 7503,Call End Of Build,Trip out for RSM following MP schedule, PUW=31K 20:15 21:45 1.50 64 0 PROD2 DRILL PULD P At Surface, PJSM, PUD BHA#11 Build/turn BHA 21:45 22:30 0.75 0 0 PROD2 DRILL PULD P Configure BHA/Make up RSM/ load into PDL Page 10 of 21 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 0 68 PROD2 DRILL PULD P PD BHA#12,AL-1 lateral BHA with RSM and rebuild Hughs Bi Center, make up to coil track and surface test tool,strip on,tag up and set counter 11/29/2011 RIH with RSM and Drill, 7503 to 8560 00:00 00:30 0.50 68 68 PROD2 DRILL PULD P prepare to run in hole 00:30 02:18 1.80 68 7,145 PROD2 DRILL TRIP P RIH W/BHA#12, RSM for AL1 lateral section, EDC Open 02:18 03:06 0.80 7,145 7,174 PROD2 DRILL DLOG P Log tie in for+9'correction, Inspect and adjust BHI counter on goose neck,Close EDC, PUW=28K 03:06 03:24 0.30 7,174 7,503 PROD2 DRILL TRIP P RIH to drill,clean pass through window 03:24 05:12 1.80 7,503 7,660 PROD2 DRILL DRLG P 7503', Drill ahead, 1.35 BPH @ 3723 PSI FS, BHP=4130, RIW=11.7K, DHWOB=1.9K 05:12 06:30 1.31 7,660 7,660 PROD2 DRILL WPRT P 7650',Wiper to window with MAD Pass, PUW=29K. RBIH 06:30 08:45 2.25 7,660 7,810 PROD2 DRILL DRLG P 7660, Drill ahead 1.35 BPM @ 3887 PSI,4091 BHP 08:45 09:30 0.75 7,810 7,810 PROD2 DRILL WPRT P 7810',Wiper up 28k PU WT.wipe up to 7242' 09:30 10:45 1.25 7,810 7,960 PROD2 DRILL DRLG P 7810', Drill ahead. 1.37 BPM @ 3860 psi,4129 BHP. ROP 120. 10:45 11:45 1.00 7,960 7,960 PROD2 DRILL WPRT P 7960',Wiper up to window. RBIH,tie in for 0 coreection. 11:45 13:15 1.50 7,960 8,110 PROD2 DRILL DRLG P 7960', Drill ahead 1.37 BPM @ 3850 PSI, 12.84 ECD,4110 BHP. ROP @ 130 FPH 13:15 14:15 1.00 8,110 8,110 PROD2 DRILL WPRT P Wiper up 30k PU WT.to window. RBIH. 14:15 16:15 2.00 8,110 8,260 PROD2 DRILL DRLG P Drill ahead. 1.39 BPM 3950 PSI, 4128 BHP, 12.90 ECD 16:15 17:15 1.00 8,260 8,260 PROD2 DRILL WPRT P 8260',Wiper up 30k 17:15 20:03 2.80 8,260 8,410 PROD2 DRILL DRLG P Drill ahead, 1.37 @ 3800 PSI, 20:03 21:48 1.75 8,410 8,410 PROD2 DRILL WPRT P Wiper to window with tie in, PUW=31 K,Corrrect-1' Swap Mud 21:48 23:42 1.90 8,410 8,560 PROD2 DRILL DRLG P 8410', Drill ahead, 1.41 @ 3660 PSI FS, RIW=13K, BHP=4180 23:42 23:59 0.29 8,560 8,322 PROD2 DRILL WPRT P 8560'Wiper to window, PUW=30.5K 11/30/2011 Drilled Ahead to 8860,Out of zone,Set Anchored Billet @ 8120 00:00 01:30 1.50 8,322 8,560 PROD2 DRILL WPRT P Wiper to window, PUW=30.5K 01:30 06:00 4.50 8,560 8,710 PROD2 DRILL DRLG P 8560', Drill Ahead, 1.42 BPM @ 3500PSI FS, BHP=4090, ECD=12.7 06:00 08:00 2.00 8,710 8,710 PROD2 DRILL WPRT P 8710',Wiper up to window 08:00 12:15 4.25 8,710 8,860 PROD2 DRILL DRLG P 8710', Drill ahead. Slow going. continue to drill to identifiy zone. 12:15 15:30 3.25 8,860 91 PROD2 DRILL TRIP T Trip OOH Page 11 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 18:30 3.00 91 0 PROD2 DRILL PULD T Tagged up&spaced out. PJSM, PUD BHA Rig steer BHA#12. 18:30 20:00 1.50 0 73 PROD2 DRILL PULD T PD BHA#13 Aluminum Billet, make up coil track amd surface test tool 20:00 22:15 2.25 73 7,150 PROD2 DRILL TRIP T Trip in with billet, EDC Open 22:15 22:21 0.10 7,150 7,179 PROD2 DRILL DLOG T Log Tie in for+12, PUW=27K, Shut EDC 22:21 23:09 0.80 7,179 8,132 PROD2 DRILL TRIP T Trip into set billet p0 23:09 23:54 0.75 8,132 5,490 PROD2 DRILL TRIP T 8131.92 Set Billet TOB=8120 Set @ 180 degrees,Tool shift @ 4450 PSI,Set down 1K,TOOH for drill by I I BHA. 12/01/2011 Drill by Billet @ 8120, Drill to 8760, BHA Stuck at billet on wiper trip 00:00 01:15 1.25 5,490 69 PROD2 DRILL TRIP T Continue out of well after setting anchored billet 01:15 04:39 3.40 69 72 PROD2 STK PULD T PJSM,at surface, PUD BHA#13 �� Billet running tools, M/U BHA#14 `� Drill by and continue to TD. .8 degree motor and bi center bit. PD,make up to coil track and surface test,Strip on.tag up and set counters 04:39 07:15 2.60 72 8,121 PROD2 STK TRIP T Trip in with BHA#14,tie in for a+20'. Rih tag TOB @ 8120.5' 07:15 11:30 4.25 8,121 8,150 PROD2 STK KOST T Pumps up, 1.42 BPM @ 3500 PSI FS. Ease down until slight motor work is noticed,time drill per procedure. Had little to no progress right off the billet. Pick-up&ease back inti it. Had a caouple stalls and had a couple pressure spikes without stalls. Clean up and started to look good,drill down to 8150'. Puh and drift clean. 11:30 13:45 2.25 8,150 8,310 PROD2 DRILL DRLG T 8150',continue drilling, 1.45 BPM @ 3900 PSI, BHP @ 4126. 13:45 15:00 1.25 8,310 8,310 PROD2 DRILL WPRT T Pull wiper,29k pu wt. Pulled a little heavier just below billet @ 8125' otherwise clean. RBIH 15:00 16:15 1.25 8,310 8,460 PROD2 DRILL DRLG T 8310', Drill ahead. 1.39 BPM @ 3754 PSI, 12.54 ECD, BHP 4104 16:15 17:30 1.25 8,460 8,460 PROD2 DRILL WPRT T 8460.0, pull wiper,34k off btm. RBIH 17:30 19:24 1.90 8,460 8,610 PROD2 DRILL DRLG T Drill ahead, 1.4 BPM @ 3600 PSI FS, BHP=4120 19:24 21:24 2.00 8,610 8,610 PROD2 DRILL WPRT T Wiper to window with tie, PUW=31K, tie in correction-5' 21:24 22:36 1.20 8,610 8,760 PROD2 DRILL DRLG T 8606', Drill Ahead, 1.4 BPM @ 3625PS1 FS, BHP=4103, ECD=12.7 22:36 23:06 0.50 8,760 8,125 PROD2 DRILL WPRT T 8760',Wiper to window, PUW=31K 23:06 00:00 0.90 8,125 8,125 PROD2 DRILL WPRT T Coming up hole past billet,22 FPM Min pump rate pulled 4 K over. RBIH, unable to run past 8125, Unable to orient. motor stalled.Attemp to work down then up. Consult with town. Page 12 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/02/2011 24 hr Summary RIH With Fishing BHA, Latch fish @ 8072, No jars down,Jar up 28 times, Release fish and POOH,Cut 540' coil rehead 00:00 02:00 2.00 8,125 8,125 PROD2 DRILL WPRT T Stuck at Billet, consult with town, work pipe,consult,work pipe to orienter limit--19k / 02:00 02:15 0.25 8,125 8,125 PROD2 DRILL CTOP T Release from BHA. Left 56.27'fish in '" •i5k hole, Estimate TOF @ 8068.7, PUW=30K 02:15 02:45 0.50 8,125 7,189 PROD2 DRILL TRIP T PUH to above window, Remove length of fish left in well from counters. Prep pits to kill well 02:45 04:15 1.50 7,189 7,189 PROD2 DRILL KLWL T Trucks here empty pits for swap, 04:15 07:00 2.75 7,189 0 PROD2 DRILL CIRC T Pump 5 BBI Hi vis spacer/12.5 PPG KWF 07:00 07:30 0.50 0 0 PROD2 DRILL SFTY T Tagged up. PJSM and no flow check. Well dead. 07:30 08:45 1.25 0 0 PROD2 DRILL PULD T Lay down BHA. PJSM. Pick-up fishing BHA 08:45 12:30 3.75 0 7,950 PROD2 DRILL TRIP T RIH pumping 12.5 @ min rate. Tie in for a+22' 12:30 15:45 3.25 7,950 8,072 PROD2 DRILL FISH T 7950'Pick-up wt @ 33k. RBIH tag fish @ 8072'. Pull up 6k over, appear to be latched. Cycle 4 diferent times to Stack 6k WOB. Jars not going off down. Discuss options with town. Decided to jar up. Hit 28 up licks, starting @-7k WOB to-15 WOB. No movement. Pump off easily @ 1.3 BPM. 15:45 18:00 2.25 8,072 8,072 PROD2 DRILL TRIP T Trip OOH, keeping hole full of KWF across the top until above the window. Pump down coil for pipe displacement. 18:00 18:30 0.50 8,072 117 PROD2 DRILL SFTY T Crew change out/valve checklist 18:30 20:00 1.50 117 0 PROD2 DRILL PULD T At surface,flo check, PJSM Lay down BHA Fishing tools 20:00 23:24 3.40 0 0 PROD2 DRILL CTOP T PJSM. R/U and cut 500'pipe, Pump slack and cut 40'to find wire 23:24 00:00 0.60 0 0 PROD2 DRILL CTOP P Prep pipe and install CTC 12/03/2011 M/U Hip Tripper, RIH,Jar down/Up. Pump lube pill,Jar down/Up,trip out, POOH Make up Jars, RIH 00:00 00:30 0.50 0 0 PROD2 DRILL CTOP T continue install Coil connector, pull test to 35K 00:30 01:30 1.00 0 0 PROD2 DRILL CTOP T Install UQC ✓ 01:30 02:06 0.60 0 0 PROD2 DRILL CTOP T Pressure test CTC and upper quick connect. Roll coil back to 12.5 KWF, unstab injector, move off of floor 02:06 03:06 1.00 0 74 PROD2 DRILL PULD T M/U BHA#16,2 1/2 GS Spear, Hip Tripper,Accelorator,3 weight bars, coiltrack 03:06 04:06 1.00 74 74 PROD2 DRILL PULD T Complete Injector maintenance, Make up coil to coil trak,surface test tool,tag up and set counters,Adjust gooseneck counter Page 13 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:06 06:30 2.40 75 7,218 PROD2 DRILL TRIP T RIH,pumping, EDC open. 06:30 07:45 1.25 7,218 7,218 PROD2 DRILL CIRC T Getting 9.8 drilling mud to the bit, continue circulating well from 12.5 to 9.8 drilling mud. 07:45 13:00 5.25 7,218 8,072 PROD2 DRILL FISH T RIH Pu Wt 30k. Latch fish @ 8072'. Get Hipp tripper dialed in. 1.4 WOB .96 BPM @ 3860 PSI.See hammer working on display.Work hammer down for 1.25 hrs.Work hammer up for about an hour.Alternate back and forth a couple times. Pump 20 bbl lube pill.Sqeeze in the choke to try to get the lubes across the fish. Work down/up again, no movement. Pump off fish. PUH to the window. 13:00 16:30 3.50 8,072 7,220 PROD2 DRILL CIRC T Open EDC, had to wait for spacer& mud to be waited up.Get 12.5 KWF above us-Trip out laying 12.5 KWF. 16:30 18:00 1.50 7,220 0 PROD2 DRILL TRIP T Trip out 18:00 21:00 3.00 0 68 PROD2 DRILL PULD T Crew change,At Surface, Flow check well, PJSM, Pull BHA#16 Hip triper,M/U and run BHA#17 Fishing string with up/down jars 21:00 22:30 1.50 68 7,160 PROD2 DRILL TRIP T Trip in hole, EDC Open 22:30 00:00 1.50 7,160 8,050 PROD2 DRILL TRIP T Stop and shut EDC, PUW=31K, Continue in hole,to TOF,Work on injector hydraulics to obtain traction pressure 12/04/2011 Latch fish, unable to jar down,Jar up 21 hits, POOH with fish,WOW Phase 3 00:00 00:30 0.50 8,050 8,050 PROD2 DRILL FISH T Working with hydraulics to get traction pressure up 00:30 02:06 1.60 8,050 8,040 PROD2 DRILL FISH T Start jarring,Attempting to get jars to fire going down for 6 cycles. No hits, Jar up 21 times then pulled free. Discussed risks of running back in hole. POOH without trying to set back down 02:06 04:18 2.20 8,040 86 PROD2 DRILL TRIP T Trip out fill accross top with 12.5 PPG 04:18 04:48 0.50 86 0 PROD2 DRILL PULD T At surface, No Flow check, PJSM Lay down fishing BHA 04:48 07:00 2.21 0 0 PROD2 DRILL PULD T Lay down recovered fish, Left bottom of orienter,2 3/8 extreme motor and bi center bit in hole. Get crews changed out, Phase 2 weather. 07:00 21:00 14.00 0 0 PROD2 DRILL CTOP T Stand by for weather, Phase 3 21:00 21:30 0.50 0 0 PROD2 DRILL SFTY T PT Meeting,formulate plan forward 21:30 23:30 2.00 0 0 PROD2 DRILL RGRP T Repair leaking hose fitting feeding B5 on stack/Prep billet to run 23:30 23:59 0.49 0 PROD2 DRILL SFTY P PJSM, M/U Billet BHA 12/05/2011 RIH with Anchored Billet,Set down @ 7343, Pick up, orient,set down 2'lower, POOH Run FCO BHA, POOH for Billet Page 14 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 0 72 PROD2 DRILL PULD T Continue making up billet BHA, Make up to coil track,Make up injector,tag up and set counters 01:30 03:30 2.00 72 7,135 PROD2 DRILL TRIP T RIH, EDC open 03:30 03:36 0.10 7,135 7,174 PROD2 DRILL DLOG T Log tie in for+20'correction, PUW=32K, Close EDC 03:36 04:00 0.40 7,174 7,343 PROD2 DRILL TRIP T RIH to set Billet, Set down at 7343', Pick up @ 32K,Orient 90 degrees to move slips, RBIH and set down @ 7345.Overpull to 35K, PUH to above window 04:00 05:30 1.50 7,343 102 PROD2 DRILL TRIP T Consult with town, POOH for clean out BHA 05:30 06:30 1.00 102 102 PROD2 DRILL TRIP T Suspend ops for PHASE 3 06:30 10:15 3.75 0 0 PROD2 DRILL PULD T Access now phase 2, Lay down anchored billet. Change out crew on their way from camp. Do change out, do handover with crew in the dog house, PJSM on picking up BHA. Pick-up BHA#19 10:15 13:00 2.75 62 7,214 PROD2 DRILL TRIP T RIH,send down spacer,tie in for a+ 21'correction.Stop @ 7214' 13:00 14:30 1.50 7,214 7,214 PROD2 DRILL CIRC T 7214',continue circulating 9.8 Flo Pro, recovering 12.5 KWF. 14:30 17:54 3.40 7,214 62 PROD2 DRILL FCO T RIH @ min rate to 7900', no problem. Kick up rate to 1.25 BPM, POOH @ 22 FPM,clean open hole up into the window,chase to surface. Get a good slug of formate to surface and light crude. 17:54 18:54 1.00 62 62 PROD2 DRILL FCO T Crew Change,valve check list, PJSM to clear choke lines. Heavy mung/ aluminum shavings in choke. Get squared away before PUD BHA#19 18:54 20:24 1.50 62 0 PROD2 DRILL PULD T PJSM, PUD BHA#19, FCO BHA 20:24 22:24 2.00 0 73 PROD2 DRILL PULD T PJSM, PD BHA#20 Anchored Aluminum billet 22:24 00:00 1.60 73 6,750 PROD2 DRILL TRIP T Trip in hole BHA#20- Midnight depth 6750 12/06/2011 RIH with anchored billet to setting depth. Set anchor @ 7861.95', single slip 180 TF. POOH.TOB 7850'. Deploy drilling BHA.(.8 AKO, Hycalog Bi-Center).Tag TOB 7850.5', sidetrack for AL1 lateral with a 140 LOHS TF. Mulitple stalls from 7851.1', adjust TF 110 LOHS to 7852.8'.adjust TF back to 140 LOHS by 7853.1'cont. milling. Clean drift through sidetrack,drill ahead AU Lateral performing wiper trips every 150'. 00:00 00:12 0.20 6,750 7,140 PROD2 DRILL TRIP T Continue in hole 00:12 00:18 0.10 7,140 7,175 PROD2 DRILL DLOG T Tie in to K1 for+20', PUW=27K, Close EDC 00:18 00:54 0.60 7,175 7,862 PROD2 DRILL TRIP T RIH to Billet set depth @ 7861.95, orient to 180 degrees. Pumps on and see tool shift @ 4200 PSI,Set down 4K Top Of Billet=7850' 00:54 02:54 2.00 7,862 100 PROD2 DRILL TRIP T POOH after billet set 02:54 03:12 0.30 100 0 PROD2 DRILL SFTY T At surface, PJSM, PUD BHA#20 Billet running tools Page 15 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:12 05:54 2.70 0 0 PROD2 DRILL PULD T Undeploy BHA#20, Deploy BHA# 21 05:54 06:12 0.30 0 0 PROD2 DRILL SFTY T Crew changeout 06:12 06:30 0.30 0 0 PROD2 STK PULD T finish deploy BHA 06:30 08:12 1.70 0 7,140 PROD2 STK TRIP T RIH 08:12 08:24 0.20 7,140 7,179 PROD2 STK DLOG T Tie in to RA, +20' 08:24 08:48 0.40 7,179 7,851 PROD2 STK TRIP T Continue RIH to billet 08:48 11:24 2.60 7,851 7,852 PROD2 STK KOST T Tag billet,start time milling at 7850.5, 1.4 BPM, 3500 CTP,4035 BHP, 18K RIW, 220(140 LOHS)TF Stalled at 7851.1 restart 11:24 14:24 3.00 7,852 7,852 PROD2 STK KOST T Stalled after stacking some weight. 7 Stalls at this depth. 14:24 16:24 2.00 7,852 7,880 PROD2 STK KOST T 250(110 LOHS)TF allowed continued time miling,adjusted TF back from 7852.8'to 220 by 7853.1. Continue milling and drilling,dry drift accross billet clean 16:24 17:54 1.50 7,880 8,010 PROD2 DRILL DRLG T Drilling ahead, 1.4 BPM,3500 CTP, 4050 BHP, 17:54 18:54 1.00 8,010 8,010 PROD2 DRILL WPRT T Wiper trip back to window,30K PUW 18:54 20:24 1.50 8,010 8,160 PROD2 DRILL DRLG T Drill ahead, 1.4 BPM,3770 CTP on bottom,4088 BHP, 15K CTW, 1-1.5K WOB 20:24 21:54 1.50 8,160 8,160 PROD2 DRILL WPRT T Wiper trip back to window 7270',30K PUW 21:54 23:15 1.35 8,160 8,310 PROD2 DRILL DRLG T Drill Ahead, 1.4 BPM, 3871 CTP on bottom,4106 BHP, 13K CTW, 1-2K WOB 23:15 00:00 0.75 8,310 8,310 PROD2 DRILL WPRT T Wiper trip back to window, 30K PUW. Log RA marker 7265-7283',-2' correction 12/07/2011 Drill AU lateral performing wiper trips back to window every 150'drilled, lowering pump rates in the higher CT fatigue area. 3K overpulls on wiper trips at 9093'. 00:00 00:48 0.80 8,310 8,310 PROD2 DRILL WPRT T RBIH to drill 00:48 02:12 1.40 8,310 8,460 PROD2 DRILL DRLG T Drill Ahead 1.4 BPM, 3915 CTP on bottom, 3554 CTP off bottom,4112 BHP, 12K CTW, 1-1.5K DHWOB 02:12 03:42 1.50 8,460 8,460 PROD2 DRILL WPRT T Wiper trip back to window 7285', 30K PUW 03:42 05:12 1.50 8,460 8,610 PROD2 DRILL DRLG T Drill Ahead 1.4 BPM,3854 CTP on bottom,3554 CTP off bottom,4108 BHP, 10K CTW, 1-2K DHWOB 05:12 06:54 1.70 8,610 8,610 PROD2 DRILL WPRT T Wiper trip to window, 30K PUW 06:54 08:12 1.30 8,610 8,760 PROD2 DRILL DRLG T Continue drilling, 1.4 BPM, 3550 CTP,4100 BHP, 14K RIW 08:12 09:24 1.20 8,760 7,260 PROD2 DRILL WPRT T Wiper to window, 31K PUW,slight over pull and motor work at 8510' 09:24 09:42 0.30 7,260 7,290 PROD2 DRILL DLOG T Tie in to RA,-3' 09:42 10:36 0.90 7,290 8,760 PROD2 DRILL WPRT T Wiper back in hole, 17K RIW. Start mud swap while RIH Page 16 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:36 11:36 1.00 8,760 8,860 PROD2 DRILL DRLG T Continue drilling, 1.4 BPM, 3500 CTP,4120 BHP, 14K RIW 11:36 12:06 0.50 8,860 8,910 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3500 CTP,4120 BHP, 14K RIW 12:06 14:12 2.10 8,910 8,910 PROD2 DRILL WPRT P Wiper to window, 32K PUW 14:12 15:36 1.40 8,910 9,060 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3500 CTP,4120 BHP, 14K RIW 15:36 17:51 2.25 9,060 9,060 PROD2 DRILL WPRT P Wiper to the window, 33K PUW 17:51 19:36 1.75 9,060 9,210 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM, 3873 CTP on bottom, 3526 CTP off bottom,4162 BHP, 10K CTW, 1-2K DHWOB 19:36 22:21 2.75 9,210 9,210 PROD2 DRILL WPRT P Wiper trip back to window, 32K PUW. 3K overpull at 9093'. Lower pump rates thru high CT fatigue areas. Log RA marker for depth correlation. -3'correction. RBIH had 500lbs set down at 9093' on DHWOB, 3K CT surface wt. 22:21 00:00 1.65 9,210 9,360 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM, 3760 CTP on bottom,3426 CTP off bottom,4188 BHP, 7-8K CTW, 1-2K DHWOB 12/08/2011 Drill AL1 lateral performing wiper trips every 150'drilled, lowering pump rates thru higher CT fatigue areas. Overpull/Setdowns at 9093'.Over pull 1k thru billet at 7850'.As precautionary,shut pumps down while pulling thru billet during wiper trips. 00:00 02:45 2.75 9,360 9,360 PROD2 DRILL WPRT P Wiper trip to window 33K PUW. 3K overpull at 9093'-9086'. Lower pump rates.75 BPM while cycling CT through high fatigue area. 7700-7635'. (bit depth) Lower pump rate to minimum rate at 9093'.Still see 5001bs set down on DHWOB. 02:45 05:06 2.35 9,360 9,510 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM,3730 CTP on bottom, 3366 CTP off bottom,4202 BHP, 10K CTW, 1-2K DHWOB 05:06 06:54 1.80 9,510 7,260 PROD2 DRILL WPRT P Wiper trip back to window,-1K overpull on WOB at the billet at 7851' 06:54 07:12 0.30 7,260 7,290 PROD2 DRILL DLOG P Tie in to RA,-2' 07:12 08:36 1.40 7,290 9,510 PROD2 DRILL WPRT P Wiper back in hole,dry drift bilet down and up were clean. 08:36 10:24 1.80 9,510 9,660 PROD2 DRILL DRLG P Resume drilling, 1.4 BPM,3550 CTP,4200 BHP, 9K RIW 10:24 13:42 3.30 9,660 9,660 PROD2 DRILL WPRT P Wiper to window, 32K PUW,offline with pump while pulling past billet at 7851', no overpull. 13:42 16:06 2.40 9,660 9,810 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM, 3500 CTP,4200 BHP, 11K RIW 16:06 19:21 3.25 9,810 9,810 PROD2 DRILL WPRT P Wiper to window, 32K PUW,off-line with pump while pulling past billet at 7851', 19:21 21:21 2.00 9,810 9,960 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM, 3880 CTP on bottom,3466 CTP off bottom,4297 BHP, 10K CTW, 1-2K DHWOB Page 17 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:21 23:06 1.75 9,960 9,960 PROD2 DRILL WPRT P Wiper trip to window, 32K PUW 23:06 00:00 0.90 9,960 9,960 PROD2 DRILL WPRT P RBIH at 7875'(jog) 100'. POOH cont wiper trip PUH thru billet w/o pumps. Did not see billet. Cont wiper trip. Log RA marker for depth correlation. -5'correction. 12/09/2011 Drill AL1 lateral performing wiper trips every 150'drilled. Lower pump rates thru high CT fatigued areas. Perform 100'jog below billet(7850'). PUH thru billet w/o pumps, not seeing any weight bobbles. Perform mud swap at 10125'. 00:00 01:30 1.50 9,960 9,960 PROD2 DRILL WPRT P RBIH, 500Ibs set down on DHWOB at 9093'and 9730' 01:30 03:00 1.50 9,960 10,052 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM, 3774 CTP,7K CTW, 1-2K WOB,4280 BHP 03:00 07:00 4.00 10,052 10,052 PROD2 DRILL WPRT P PUH,34K Swab leaking on mud pump 2. Pump 1 air locked. Cont to PUH repairing pump. 07:00 07:54 0.90 10,052 10,125 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM, 3774 CTP,7K CTW, 1-2K WOB,4280 BHP 07:54 11:42 3.80 10,125 10,125 PROD2 DRILL WPRT P Wiper to window,32K PUW 11:42 16:00 4.30 10,125 10,290 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3500 CTP,4270 BHP. Start new mud down coil. 16:00 20:15 4.25 10,290 10,290 PROD2 DRILL WPRT P Wiper to the window, 32K PUW. Log RA marker for depth correction.-7' correction 20:15 22:15 2.00 10,290 10,440 PROD2 DRILL DRLG P Drill Ahead, 1.4 BPM,3700 CTP, 4293 BHP, 1-2K WOB,220 MP choke 22:15 00:00 1.75 10,440 10,440 PROD2 DRILL WPRT P Wiper trip to window,32K PUW. 12/10/2011 / Drill AL1 Lateral to TD 10810' 00:00 02:15 2.25 10,440 10,440 PROD2 DRILL WPRT P Cont Wiper trip 02:15 02:30 0.25 10,440 10,456 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM, 3519 CTP, 8K CTW,220 MP choke 02:30 02:45 0.25 10,456 10,456 PROD2 DRILL WPRT P PU orient TF for end stop placement, Unable to RIH stacking. PUH/RIH 30 FPM in order to pipe to slide 02:45 04:36 1.85 10,456 10,567 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM, 3750 CTP,5K CTW,200 MP choke 04:36 08:48 4.20 10,567 10,567 PROD2 DRILL WPRT P Wiper to window, 33K PUW 08:48 12:36 3.80 10,567 10,603 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM, 3500 CTP,4330 BHP, 10K RIW. In Ankerite... 12:36 15:30 2.90 10,603 10,715 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3500 CTP,4330 BHP, 10K RIW. Through Ankerite, 0 to-5K surface weight for 1-2K WOB Pumped low/high vis sweeps Page 18 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 20:15 4.75 10,715 10,715 PROD2 DRILL WPRT P Wiper trip to window, 36K PUW. Perform 100'jog below billet, PUH thru billet w/o pumps. Lower pump rates cycling CT thru high fatigue area. Log RA marker for depth correlation. -6'correction 20:15 22:15 2.00 10,715 10,800 PROD2 DRILL DRLG P Drill ahead 1.5 BPM, 3830 CTP, 4363 BHP,4.5K CTW, 1-2K DHWOB. 22:15 00:00 1.75 10,800 8,100 PROD2 DRILL WPRT P TD AL1 lateral at 10810'. Pump 10brls low/high sweeps 119 POOH to swab valves 12/11/2011 Perform wiper trip to swab valves, RBIH to 10811'. Lay in liner running pill(9.8ppg FP)to window, KWF (12.5ppg K-formate)to surface. PU/MU/RIH AL1 liner(67 slotted jnts). Release liner on bottom. BOL 10817', TOL 8612'. POOH 00:00 02:30 2.50 8,100 0 PROD2 DRILL WPRT P Cont.wiper trip to swab valves 02:30 05:00 2.50 0 7,140 PROD2 DRILL WPRT P RBIH, large amounts of cuttings all the way to surface and RBIH to 5000'. 05:00 05:15 0.25 7,140 7,140 PROD2 DRILL DLOG P Tie in depth to K1.-11'correction 05:15 07:06 1.85 7,140 10,811 PROD2 DRILL WPRT P Cont RIH 07:06 11:06 4.00 10,811 0 PROD2 DRILL DISP P Tag TD at 10811', lay in 9.8 ppg liner running pill in open hole, 12.5 ppg KWF from window to surface 11:06 11:30 0.40 0 0 PROD2 DRILL SFTY P Check well for flow, PJSM for lay down drilling BHA 11:30 12:18 0.80 0 0 PROD2 DRILL PULD P Lay down drilling BHA 12:18 12:42 0.40 0 0 COMPZ CASING SFTY P PJSM for liner operations 12:42 16:12 3.50 0 2,204 COMPZ CASING PUTB P RU floor for liner operations. PU 67 joints slotted liner for lower section of AL1 liner. Kick while tripping drill after joint#5. 16:12 17:12 1.00 2,248 2,248 COMPZ CASING PUTB P MU coiltrack tools and injector 17:12 18:27 1.25 2,248 7,123 COMPZ CASING RUNL P RIH 18:27 19:48 1.35 7,123 10,814 COMPZ CASING RUNL P Tie into first EOP flag. +25' correction. Record up in down weights. 33K up, 17K down. RIH to TD 19:48 20:48 1.00 10,814 7,135 COMPZ CASING RUNL P Depth-1.5'passing second EOP flag.Tag bottom 10814.3'CTES counter. (BHI counter quit working at 10811'due to software issue, problem corrected, adjusted BHI depth 10826'). Release liner at max pump rate 4350 psi CTP. Liner released 33K PUW. DHWOB 0. Line up to pump across top in order keep liner running pill displaced in OH. Remove liner length from bit depth. POOH to K1 for tie in. Page 19 of 21 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 20:48 21:03 0.25 7,135 7,135 COMPZ CASINGRUNL P Log K1 for depth correclation.-9' correction. 21:03 23:03 2.00 7,135 0 COMPZ CASING RUNL P POOH 23:03 23:18 0.25 0 0 COMPZ CASING SFTY P At surface,Monitor well for flow, PJSM 23:18 00:00 0.70 0 0 COMPZ CASING PUTB P LD BHA#22 12/12/2011 PU AL1 upper liner.On Joint 17 well smarted flowing. PU 2 3/8"safety joint with TIW valve. shut in well with both 2 3/8"P/S rams. Bullhead 90brls 12.5ppg(P.Formate)down annulus.Confirm well dead.Cont. PU/MU/RIH AL1 upper liner. Release upper liner BOL 8612'.TOL 7238'. Swap well to seawater,freeze protect well. Undeploy BHA 23.Set BPV. Blow down rig and CT, prepare to move rig. 00:00 00:15 0.25 0 0 COMPZ,CASING PUTB Prep floor to PU liner 00:15 01:00 0.75 0 0 COMPZ CASING PUTB P PU 17jnts AL1 liner 01:00 01:15 0.25 0 0 COMPZ CASING OWFF T Fluid level rising, Monitor well 01:15 02:45 1.50 0 0 COMPZ CASING OWFF T Well flowing, pick up safety joint, spaceout across both 2 3/8"P/S rams and shut in well.Monitor well for psi against MP choke. 1 hour shut in-48psi 02:45 04:00 1.25 0 0 COMPZ CASING CIRC T PJSM,WHP 67psi/rising slowly. bullhead 90bbrls KWF down Kill line. 04:00 04:45 0.75 0 0 COMPZ CASING OWFF T Offline with pumps. Monitor well for flow. No flow. 04:45 05:00 0.25 0 0 COMPZ CASING SFTY T PJSM,to pu liner 05:00 08:06 3.10 0 1,418 COMPZ CASING PUTB P PU AL1 upper liner and coiltrack tools 08:06 09:30 1.40 1,418 7,118 COMPZ CASING RUNL P RIH with liner 09:30 10:00 0.50 7,118 8,615 COMPZ CASINGRUNL P Correct to flag-21', 33K PUW, 16K RIW. Contiinue RIH 10:00 10:18 0.30 8,615 7,140 COMPZ CASING RUNL P Tag lower liner at 8613', relaease liner, open EDC, start SW down coil. 10:18 10:36 0.30 7,140 7,200 COMPZ CASING DLOG P Tie in to foramation,-2', Corrected liner top at 7238' 10:36 14:12 3.60 7,200 0 DEMOB WELLPF DISP P Swap well over to SW, POOH. FP with 25 BBIs diesel 14:12 14:30 0.30 0 0 DEMOB WELLPF SFTY P PJSM for undeploy 14:30 16:18 1.80 0 0 DEMOB WELLPF PULD P Undeploy BHA 16:18 16:48 0.50 0 0 DEMOB WHDBO SFTY P PJSM for BPV 16:48 20:00 3.20 0 0 DEMOB WHDBO NUND P Set BPV 20:00 20:15 0.25 0 0 DEMOB WHDBO SFTY P PJSM 20:15 00:00 3.75 0 0 DEMOB WHDBO NUND P Flush rig with inhibitor, blow down rig and CT with N2 12/13/2011 ND BOP's, Move rig 00:00 00:45 0.75 0 0 DEMOB WHDBO CTOP P RU to unstab CT, RD tiger tank hardline from rig 00:45 01:00 0.25 0 0 DEMOB WHDBO SFTY P PJSM 01:00 02:45 1.75 0 0 DEMOB WHDBO CTOP P Unstab CT from inj. head, secure CT to drum out of horseshead Page 20 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:45 03:00 0.25 0 0 DEMOB WHDBO NUND P PJSM 03:00 06:00 3.00 0 0 DEMOB WHDBO NUND P ND stack, interconnect, RDMO Rig released at 0600 Page 21 of 21 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, November 22, 2011 7:06 PM To: Winfree, Michael Alex(Jr.) Cc: Schwartz, Guy L(DOA) Subject: RE: 2K-28A CTD Lateral (PTD 211 133) Mike, You are correct. The lost hole section will become 2K-28APB1. Good luck with the new penetration. Tom Maunder, PE AOGCC From: Winfree, Michael Alex (Jr.) [mailto:Michael.A.Winfree@conocophillips.com] Sent: Tue 11/22/2011 5:04 PM To: Maunder, Thomas E (DOA) Cc: Schwartz, Guy L (DOA) Subject: 2K-28A CTD Lateral (PTD 211 133) Tom, While drilling the 2K-28A CTD lateral, the geologic interpretation of the fault system at the time seemed to indicate we were drilling in the targeted A4 sand. After exiting the top of the sand, indications were we had drilled into the A6 which means we had been drilling in the A5 sand. Per our conversation, our plan forward is to set an anchored aluminum billet in the A4 sand, approximately 700' up hole from the end of the lateral, to kick off of and continue drilling the A4 sand. No liner will be run in the A5 section. The purpose of this e-mail is to confirm that the AOGCC requires no additional information for the operations listed above. Thank you, -Mike Mike A. Winfree Drilling Engineer 907.265.6820 Direct 907.242.0246 Cell 11/23/2011 LILAS [(A SEAN PARNELL,GOVERNOR O ALASKA OIL A1VI) GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMNIISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Lamar Gantt CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K-28A ConocoPhillips Alaska, Inc. Permit No: 211-133 Surface Location: 3' FNL, 94' FEL, SEC. 11, T1ON, R8E, UM Bottomhole Location: 204' FSL, 2331' FEL, SEC. 2, T1ON, R8E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sin -'It Comsoner DATED this 7 day of November, 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) � s ConocoPhilli RECEIVED' ConocoPhillips Alaska )CT ) 211 l P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 Alaska Oil& Gas Cons. Coffin Ancharago October 6, 2011 Commissioner-State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Permit to Drill applications for two coiled tubing drilling (CTD) laterals out of Kuparuk well 2K-28 (PTD#201-154) using the Nabors CDR2-AC coiled tubing drilling rig. The objective is to drill two injection A-sand laterals: 2K-28A, and 2K-28AL1. Work is scheduled to begin in November 2011. A sundry has been submitted and is pending approval for 2K-28 pre-rig well work. Attached to this application are the following documents that explain the proposed job operations: — Permit to Drill Application Forms for 2K-28A and 2K-28AL1 — Proposed &Current Wellbore Schematic — Summary of Operations — Directional Plans If you have any questions or require additional information regarding the 2K-28A and 2K-28AL1 Application for Permit to Drill, please call 907-265-6820. Sincerel Mike A. W free ConocoPhi '•s Alaska CTD Drilling ngineer STATE OF ALASKA RECEIVE ALASKA OIL AND GAS CONSERVATION COMM.-610N (J(T 0 1 PERMIT TO DRILL 211 20 MC 25.005 Alaska Oil 2 Als la.Type of Work: • lb.Proposed Well Class: Development-Oil El Service- Winj 2. Single Zone 0 • lc.Specify i a she Drill ❑ Redrill ❑., Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gaskitheapdrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑ Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 . 2K-28A . 3.Address: 6.Proposed Depth: , 12.Field/Pool(s): P.O.Box 100360 Anchorage AK 99510-0360 MD: 10,200 TVD: 6090 Kuparuk River Field 4a. Location f Well Governmental S,ction): 7.Property Designation(Lease Number): Kuparuk River Oil Pool ' Surface: ,94'FEL,Secy2;T10N,RO8E,UM ADL 25588 ALK 2674 Top of Productive Horizon: ,A- /0•/L'°// 8.Land Use Permit: 13.Approximate Spud Date: �FNL,2655'FEL,Sec 11,T10N,RO8E,UM 2674,2679 11/1/2011 Total Depth: ,�n/d'/6"-/I 9.Acres in Property: 14.Distance to Nearest Property: 204'FSL,2331'FEL,Sec 2,T10N,RO8E,UM 2560 7,750'to KPA Boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above P 154 feet 15.Distance to Nearest Well Open Surface x- 498,310 ' y- 5,938,300 ' Zone-4 GL Elevation above I 40 feet to Same Pool: 2K-21, 1,500' 16.Deviated wells: Kickoff depth: 7,240 feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035)7 Maximum Hole Angle: 95.9 degrees Downhole: 4025 • Surface: a?9 --3:- re,5.: 77 F2 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2-3/8 4.7 ppf L-80 STL 2,815 7380 6142 10195 6090 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): 6800 6550 6377 6265 Casing Length Size Cement Volume MD TVD Conductor/Structural 190 16 Pre-Installed 220 220 Surface 3,242 7-5/8 290 sx AS III,200 sx LiteCrete 3272 2956 Production 7104 5-1/2 215 sx GasBLOK 7129 6128 Production 407 3-1/2 included above 7536 4980 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): (7222-7228)(7268-7284)(7300-7320) (6204-6209)(6243-6256)(6269-6286) 20. Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program E Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑, 20 AAC 25.050 requirements❑., 21. Verbal Approval: Commission Representative: Date 8/6/2011 22. I hereby certify that the foregoing is true and correct. Contact Mike A.Winfree Printed Name Lamar Gantt Title CTD Engineering Supervisor Signature AOjYI. QI\ -i . irk Vl/`k. Phone 263-4021 Date 1/6!2071 10/7/1 Commission Use Only Permit to Drill z J / API Number: f�• �V ermit Approval See cover letter for other Number: I / I 50-/L/'� L�). O'D C--1 te: 1\� /� t' requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,g s hydrates,or gas contained in shales: Other: A IMO o tp5v a dip •T-f 61.1./...-.' / 1 Samples req'd: Yes❑ No[." Mud log req'd: Yes ❑ o [✓� i- -S2 /93 Ann w�-,t Ic=s.� `N-i.•�+ I H2S measures: Yes j 'No, Directional svy req'd: Yes Q No ❑ c,Z l t i n, - oto, .--i c.- i" ei-cc,c3,^S 6_;/ Al o Z — MIT % -wc--P / DATE: //'91 l APPROVED BY THE COMMISSION ,COMMISSIONER / 17 \ Form 10-401(Revised 7/2009) This permit is vale rlos�fri thelid of approval(20 AAC 25.005(g)) Submit in Duplicate,07 Proposed 2K-28 CTD Laterals 3-12'Camco DS nipple @497'RKB(2.875"min ID) 3-12'9.3#L-80 EU E8rd Tubing to surface 6.12"15.5#L- 3-1/2 Camco 113G 2-9 gas lift mandrel @ 7014'RKB 80 XD to 312" �_,�_�,_„a @7129'RKB 1 3-12'Cameo DS landing nipple @7063 RKB(2.812"min ID) Baker 3.12'GBH-22 seal assembly @7109'RKB(3"ID) Liner too Baker 80-40 seal receptacle @ 7109 RKB(4"ID seal bore) 5-12'x 3-12'crossover @ 7129'RKB C4-s and pert 7222•7728'MD KOP C.7240 MD 2K-28 AU (iAihh. 2K-28Swp03) 10900'TD sand perfs 268'-7284'MD 300'-7320'MD // _,... t4DP 6 Y3A0 MD 2K-28 A 2/428 WNwp08) 10200'TD 3-12"9.3*L-80 shoe @7536'RKB ....rilli riler—_ ORIGINAL KUP 2K-28 ConocoPhilli wen Well Attributes Max Angle&MD TD AlaskaWellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act atm(ftKB) 501032038500 KUPARUK RIVER UNIT INJ 36.93 3,495.41 7,543.0 Comment H2S(ppm) Data Annotation End Date KB-Ord(It) Rig Release Date ••• Well Confip:-2K-2B,4/3/!0117:47:25 AM SSSV:NIPPLE Last WO: 34.59 8/26/2001 Schematic-Actual Annotation - Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 7,330.0 4/2/2011 Rev Reason:TAG Imosbor 4/32011 Casing Strings Casing Description String 0... 'String ID...Top(ftKB) Set Depth(f...'Set Depth(TVD)...String Wt...String... String Top Thrd SURFACE 75/8 6.875 29.9 3,272.0 2,955.8 29.70 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(TVD)...String Wt...String... String Top Thrd HANGER,zs PRODUCTION 51/2 4.950 25.0 7,536.3 6,470.0 15.50 L-80 LTCM 5.5"x3.5" Tubing Strings Tubing Description String 0... String ID...Top(11613) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd TUBING 31/2 2.992 25.0 7,109.5 6,109.5 9.30 L-80 EUE-8rd Completion Details Top Depth Fr (TVD) Top not Noma... Top(18(B) (ftKB) P) Item Description Comment ID(in) 25.0 25.0 -0.15 HANGER FMC GEN V TUBING HANGER 3.500 497.3 497.0 4.20 NIPPLE CAMCO DS NIPPLE 2.875 I 7,063.2 6,072.0 34.68 NIPPLE CAMCO DS NIPPLE 2.812 7,107.7 6,107.9 32.92 LOCATOR BAKER NO GO SUB 3.000 7,108.5 6,108.6 32.92 SBE BAKER 80-40 GBH-22 Seal Assembly 3.000 CONDUCTOR, 30.22 0 Perforations&Slots Shot Top(TVD) Btm(TVD) Dens NIPPLE,497 II Top(ftKB)Bent(RKB) (ftKB) (ftKB) Zone Date (oh... Type Comment 7,222.0 7,228.0 6,203.9 6,208.9 C-4,2K-28 4/19/2004 6.0 APERF 2.5"HSD,60 deg ph,random orient 7,268.0 7,284.0 6,242.6 6,258.0 A-5,2K-28 4/19/2004 6.0 APERF 2.5"HSD,60 deg ph,random orient 7,300.0 7,320.0 6,270.8 6,287.0 A-4,2K-28 12/16/2001 6.0 IPERF 2.5"HSD,60 deg phase Notes:General&Safety End Date Annotation . 11/52010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE. / l 30-3.272 GAS LIT. 7,0F14 I NIPPLE,7,063— ," LOCATOR,_ 7,108 SEE.7.108 _.... .-_.._.-_ APERF, 7,222-7.228 5, 7,268-7.284 Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Sloe TRO Run Ste Top(IRKS) (ftKB) (I Make Model (le) Sery Type Type (in) (psi) Run Date Com... 1 7,013.6 6,031.1 34.46 CAMCO KBG 2-9 1 GAS LIFT-DMY BTM '0.000 0.0 12/7/2001 7,300 IPERF, 320 PRODUCTION SS'k3,Sl ORIGINAL 257,536 \ TD,7,543 gli m El .T. „,1 °O' M — Y s 0 • M 8 N N N_ 2 ei r c°°�gC�e ee - ._. _s , N Fl U L'3 t'-2 'EL-' g g m m m 1mm 3 z ; 0 _ g> mI I- - g l I Ico 2 III1111111:1111” () NV- .e „ 4 � d 0 .-'1= El _ d i < _101 . 8 N i . %. Y t.:,-..kr' '_ Aki Ak .- 1 IViig ' 4 ii„ ii .., : , ,,,,, , A, ,,,,..„-... laliklui,4 11111M � oo I �I'� �`''' tx 8 (c ■ Iwo M 11Prar 1 M En 7 Tk on I 8 11 ir Y Y Y QQ N I Y cd N ' - ' - O li oN3a°¢ l u . N �,, 17 ,u g kW ,1 o 5s ''.. rJ 0 l '. O 1 lil ''i 1 �� 4n YL Ia i ( it'A I 9 _ 1 1 r " "&; C r �� co s ii 1 U : o00 $ - o - _ - = d $ _ o § os oy N V O f- M O NNN fP , Y 7 V � . \P KRU 2K-28A and 2K-28AL1 — Coiled Tubing Drilling Summary of Operations: Well 2K-28 is a Kuparuk A/C-sand injection well equipped with 31/2"tubing and 5-1/2"x 3-1/2"tapered production casing. Two proposed A-sand CTD laterals will increase reservoir exposure and support existing i producer 2K-11 and the future CTD laterals 2K-22A and 2K-22AL1. The existing A-Sand perfs will be ✓ isolated below a CIBP and the C sand perfs will be squeezed with cement prior to drilling. After setting a CIBP to isolate the A sand perfs, a mechanical whipstock will be placed in the 3-1/2"tubing at the planned kick off point. With the whipstock in place,the C sand perfs will be isolated with a cement sqeeze. The 2K-28A sidetrack will exit the 3-1/2" casing at 7,240' MD and will target the A4 sand north of the existing well with a 2,960' lateral. The hole will be completed with a 2%" slotted liner from the TD of 10,200' MD with an anchored aluminum billet at 7,380' MD. The 2K-28AL1 lateral will kick off from the aluminum billet at 7,380' MD and will target the A4 sand south of the existing well with a 3,520' lateral. The hole will be completed with a 2%" slotted liner from the TD of 10,900' MD with the final liner top located just inside the 31/2"casing at 7,230' MD. CTD Drill and Complete 2K-28 Laterals Pre-CTD Work(Sundry Pending AOGCC Approval) The pre-rig operations are only listed here for reference 1. Positive pressure and drawdown tests on master valve& swab valve 2. RU e-line. Set CIBP above A sand perfs, drift then run and set whipstock. Obtain static BHP on C-sand, RD e-line. 3. Rig up Little Red Services and perform injectivity test into C sand perfs 4. RU service coil and pump 15.8 ppg cement for hesitation squeeze into the C sand perfs. 5. After squeeze, clean out to top of whipstock at 7,240' MD 6. RDMO service coil 7. Prep site for Nabors CDR2-AC, including setting BPV Sundry Work Ends Here New PTD work begins here Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 2K-28A Sidetrack(A4 sand,north) a. Mill 2.80"window with high-side orientation at 7,240' MD. - b. Drill 2.70"x 3"bi-center lateral to TD of 10,200' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 7,380' MD 3. 2K-28AL1 Lateral(A4 sand, south) a. Kick off of the aluminum billet at 7,380' MD b. Drill 2.70"x 3"bi-center lateral to TD of 10,900' MD c. Run 2%" slotted liner from TD up to 7,230' MD, 10' inside the 31/2"casing 4. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP 3. Put well on production (Niri \ loIL \ KRU 2K-28A and 2K-28AL1 — Coiled Tubing Drilling Mud Program: 1 • Will use chloride-based Biozan brine or used drilling mud(9.8 ppg)for milling operations, and chloride- based Flo-Pro mud(10.0 ppg)for drilling operations. We will have to kill the well with weighted brine in order to deploy 2%" slotted liner in the two laterals. Disposal: • This well will not be used for annular injection • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind&Inject at PBU Drill site 4 • Class I wastes willo to Pad 3 for disposal. g p Casing Program: • 2K-28A: 2%",4.7#, L-80, ST-L slotted/solid liner from 7,380' MD to 10,190' MD • 2K-28A-L1: 2%",4.7#,L-80, ST-L slotted/solid liner from 7,230' MD to 10,890' MD Existing Casing/Liner Information String Size Weight Grade Burst Collapse Surface 7-5/8" 29.7 ppf L-80 6890 psi 4790 psi Production 5-1/2" 15.5 ppf L-80 7000 psi 4990 psi Production 3-1/2" 9.3 ppf L-80 4980 psi 4320 psi Logging • MWD directional,resistivity, and gamma ray will be run over the entire open hole section. Reservoir Pressure • The most recent static BHP survey in well 2K-27 was taken August 18th,2011. The A/C-sand reservoir pressure was measured at 4,025 psi at 7,252' MD, 6,240' TVD,which is 12.4 ppg EMW. Well Control: • Two well bore volumes(-190 bbl)of KWF will be available to the rig during drilling operations. The kill ' weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is on file for operations with 2"coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4500 psi. Maximum potential surface pressure in 2K-28 is 962-psi assuming a gas gradient to surface and maximum potential formation pressure. Maximum potential formation pressure is based on a pressure measurement of 4,025 • psi at 6,240' TVD taken August 18th 2011, corresponding to 12.4 ppg EMW formation pressure. The BHP will be taken again by e-line after the A sand is isolated by a CIBP and the whipstock is set. In this configuaration,the pressure will be C sand only. • The annular preventer will be tested to 250 psi and 2500 psi. • �' _ 1{DZj p3: � `�v ` p5�/�) ; EVOI Ps.; /e -II -I 1 KRU 2K-28A and 2K-28AL1 — Coiled Tubing Drilling Directional: • See attached directional plans: 1. 2K-28Awp06 2. 2K-28A-L 1 wp03 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 2K-28 CTD laterals A and A-L1 are 7,750' and 9,800' respectively to KPA boundary Hazards • Shale stability is the most significant problem expected. It will be mitigated by directional planning to ✓ minimize exposure to the worst shales and by applying MPD pressure to maintain hole stability. • There has not been gas in the vicinityof 2K-28 location in 15+years, so it is unlikelythat an - injection influx will yield significant quantities of gas. • Well 2K-28 is located in the middle of the well row on 2K pad and 24' south of the offset well 2K-12 and 65' North of well 2K-13 surface locations. The closest well with measured H2S is 2K-11 which is 50' to the North and measured 25 ppm on 1/10/2010. The maximum H25 level on the pad is 220 ppm from well 2K-08 (11/05/05)The original 2K-08 well was P&A'd . All H2S monitoring equipment will be operational. Managed Pressure Drilling g Managed pressure drilling(MPD)techniques will be employed to provide constant bottom hole pressure by v' using 10 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be used to reduce pressure fluctuations to help with hole stability. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%"BHA will be accomplished utilizing the 2%"pipe rams and slip rams. The annular preventer will act as a secondary isolation during deployment and not as a stripper. Well 2K-28 will have to be killed prior to deploying slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Expected reservoir pressure is 4,025 psi at 6,240' TVD, or 12.4 ppg EMW. • Expected annular friction losses while circulating: 1,090 psi(assuming annular friction of 100 psi/1000 ft due to the 3'/2"tubing) • Planned mud density of 10.0 ppg equates to 3,245 psi hydrostatic bottom hole pressure at 6,240' TVD. • While circulating 10 ppg mud, bottom hole circulating pressure is estimated to be 4,335 psi or 13.3 ppg EMW without holding any additional surface pressure. This is sufficient to overbalance expected formation pressure in 2K-28. If increased formation pressure is encountered,mud weight or choke pressure will be increased to maintain overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability,but not necessarily for well control. • When circulation is stopped, 1,090 psi of surface pressure would have to be applied to maintain the same borehole pressure as during drilling operations. y _ y ^. A KRU 2K-28A and 2K-28AL1 — Coiled Tubing Drilling Quarter-Mile Injection Review The following wells lay within one-quarter mile of the proposed 2K-28 CTD laterals in zone. 2K-14(Producer) Currently online producing 115 bopd with gas lift. / F , . J c Q _ t 4 —�,. La) co i.co�_ 4 8 -.._f U O i . i 'f- t C Ste+ i • _1ini .�. a I •- ❑ :�_ N __ ■ T-- 11' N _ - 0,1 - o NM C7 _ I I 1 - 0 Q _ N ///114M. i - N t r';' \ 0 co 1 N c) r1 i." ___ — i i ' t iffimgriaw , , Q - N f , ith - N - • gf. ' _.H. ____. a _ - _ 0 , 13 _ � CD o —� _ o if ' 1 t ,333, `—. - 0 I _ , 1 I i , \ : i _ . 1 1 1 l r i i 1 , . . f i r s i i i a i i i a m ,1 1 ! i i t 1 1 1 1 ' T 1 1 1 1 1 1 1 1 1 1 1 1 7. 00101 / [ 1(+)uuoN/(-)tilnos \. e 3 „, ConocoPhilli s p Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2K Pad 2K-28 2K-28A Plan: 2K-28A_wp06 Standard Planning Report 04 October, 2011 BAKER HUGHES ORIGINAL ✓ ConocoPhillips or its affiliates Fa' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-28 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level ° Project: Kuparuk River Unit MD Reference: 2K-28@ @ 148.65ft(2K-28@) a Site: Kuparuk 2K Pad North Reference: True Well: 2K-28 Survey Calculation Method: Minimum Curvature Wellbore: 2K-28A Design: 2K-28A_wp06 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 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: " Grid Convergence: -0.01 ° Well 2K-28 Well Position +N/-S 0.00 ft Northing: 5,938,300.61 ft Latitude: 70° 14'33.573 N +E/-W 0.00 ft Easting: 498,310.32 ft , Longitude: 150°0'49.127 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore 2K-28A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 11/11/2011 16.37 79.80 57,352 Design 2K-28A_wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,187.69 Vertical Section: Depth From(ND) +N//-S +El-W Direction (ft) (ft) (ft) (0) -118.50 0.00 0.00 10.00 Plan Sections Measured ND Below Dogleg Build Turn Depth Inclination Azimuth System +NI-S +E/-W Rate Rate Rate TFO (ft) (0) (0) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 7,187.69 32.89 226.85 6,026.46 -2,263.72 -2,507.99 0.00 0.00 0.00 0.00 7,240.00 32.87 227.37 6,070.39 -2,283.05 -2,528.80 0.54 -0.04 0.99 94.27 7,261.00 35.65 229.09 6,087.74 -2,290.92 -2,537.62 14.00 13.22 8.21 20.00 7,385.50 90.00 245.57 6,142.79 -2,344.78 -2,629.12 45.00 43.66 13.23 20.00 7,485.00 92.82 290.28 6,140.21 -2,348.31 -2,726.01 45.00 2.83 44.93 86.00 7,585.00 90.23 335.22 6,137.41 -2,282.18 -2,797.52 45.00 -2.59 44.95 92.50 7,635.00 90.21 357.72 6,137.22 -2,233.87 -2,809.14 45.00 -0.03 45.00 90.00 7,835.00 90.21 7.72 6,136.49 -2,034.35 -2,799.65 5.00 0.00 5.00 90.00 8,385.00 93.70 29.46 6,117.54 -1,516.53 -2,625.58 4.00 0.64 3.95 80.60 8,635.00 95.88 19.67 6,096.61 -1,290.26 -2,522.13 4.00 0.87 -3.92 283.00 8,935.00 90.55 30.44 6,079.73 -1,019.44 -2,395.46 4.00 -1.78 3.59 116.00 9,135.00 90.13 22.45 6,078.55 -840.51 -2,306.47 4.00 -0.21 -3.99 267.00 9,735.00 89.30 358.46 6,081.57 -254.79 -2,198.38 4.00 -0.14 -4.00 268.00 9,935.00 88.75 350.48 6,084.97 -55.91 -2,217.63 4.00 -0.27 -3.99 266.00 10,200.00 88.77 1.08 6,090.70 207.93 -2,237.09 4.00 0.01 4.00 90.00 10/4/2011 1:30:28PM Ple COMPASS 2003.16 Build 69 Nes-' ConocoPhillips or its affiliates FI r: ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-28 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-28@ @ 148.65ft(2K-28@) Site: Kuparuk 2K Pad North Reference: True Well: 2K-28 Survey Calculation Method: Minimum Curvature Wellbore: 2K-28A Design: 2K-28A_wp06 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 7,187.69 32.89 226.85 6,026.46 -2,263.72 -2,507.99 -2,664.84 0.00 0.00 5,936,037.67 495,802.07 TIP 7,200.00 32.89 226.97 6,036.79 -2,268.29 -2,512.87 -2,670.19 0.54 94.27 5,936,033.11 495,797.19 7,240.00 32.87 227.37 6,070.39 -2,283.05 -2,528.80 -2,687.49 0.54 94.17 5,936,018.35 495,781.26 KOP 7,261.00 35.65 229.09 6,087.74 -2,290.92 -2,537.62 -2,696.77 14.00 20.00 5,936,010.49 495,772.44 3 7,300.00 52.43 236.57 6,115.70 -2,307.00 -2,559.28 -2,716.37 45.00 20.00 5,935,994.41 495,750.78 7,385.50 90.00 245.57 6,142.79 -2,344.78 -2,629.12 -2,765.70 45.00 14.56 5,935,956.65 495,680.93 Start of 45DLS 7,400.00 90.45 252.08 6,142.73 -2,350.01 -2,642.64 -2,773.20 45.00 86.00 5,935,951.42 495,667.42 7,485.00 92.82 290.28 6,140.21 -2,348.31 -2,726.01 -2,786.01 45.00 86.03 5,935,953.14 495,584.05 5 7,500.00 92.50 297.03 6,139.51 -2,342.31 -2,739.73 -2,782.47 45.00 92.50 5,935,959.15 495,570.34 7,585.00 90.23 335.22 6,137.41 -2,282.18 -2,797.52 -2,733.29 45.00 92.81 5,936,019.29 495,512.56 6 7,600.00 90.22 341.97 6,137.35 -2,268.22 -2,803.00 -2,720.49 45.00 90.00 5,936,033.25 495,507.10 7,635.00 90.21 357.72 6,137.22 -2,233.87 -2,809.14 -2,687.74 45.00 90.03 5,936,067.59 495,500.96 7 7,700.00 90.21 0.97 6,136.98 -2,168.89 -2,809.88 -2,623.87 5.00 90.00 5,936,132.57 495,500.23 7,800.00 90.21 5.97 6,136.62 -2,069.10 -2,803.83 -2,524.55 5.00 90.01 5,936,232.34 495,506.31 7,835.00 90.21 7.72 6,136.49 -2,034.35 -2,799.65 -2,489.60 5.00 90.03 5,936,267.09 495,510.49 Ribsteer 7,900.00 90.63 10.29 6,136.02 -1,970.16 -2,789.48 -2,424.62 4.00 80.60 5,936,331.27 495,520.68 8,000.00 91.28 14.24 6,134.36 -1,872.48 -2,768.25 -2,324.73 4.00 80.62 5,936,428.94 495,541.93 8,100.00 91.92 18.19 6,131.56 -1,776.51 -2,740.35 -2,225.38 4.00 80.68 5,936,524.89 495,569.85 8,200.00 92.56 22.14 6,127.65 -1,682.73 -2,705.92 -2,127.04 4.00 80.79 5,936,618.66 495,604.30 8,300.00 93.18 26.09 6,122.64 -1,591.59 -2,665.12 -2,030.20 4.00 80.95 5,936,709.78 495,645.11 8,385.00 93.70 29.46 6,117.54 -1,516.53 -2,625.58 -1,949.42 4.00 81.15 5,936,784.82 495,684.66 9 8,400.00 93.83 28.87 6,116.55 -1,503.46 -2,618.29 -1,935.28 4.00 -77.00 5,936,797.89 495,691.95 8,500.00 94.72 24.96 6,109.09 -1,414.56 -2,573.15 -1,839.90 4.00 -77.04 5,936,886.76 495,737.11 8,600.00 95.59 21.04 6,100.11 -1,322.91 -2,534.24 -1,742.87 4.00 -77.33 5,936,978.40 495,776.04 8,635.00 95.88 19.67 6,096.61 -1,290.26 -2,522.13 -1,708.62 4.00 -77.68 5,937,011.05 495,788.16 10 8,700.00 94.74 22.01 6,090.59 -1,229.78 -2,499.10 -1,645.06 4.00 116.00 5,937,071.52 495,811.19 i 8,800.00 92.96 25.60 6,083.87 -1,138.51 -2,458.83 -1,548.19 4.00 116.22 5,937,162.76 495,851.48 8,900.00 91.18 29.19 6,080.26 -1,049.80 -2,412.86 -1,452.84 4.00 116.46 5,937,251.45 495,897.47 1 8,935.00 90.55 30.44 6,079.73 -1,019.44 -2,395.46 -1,419.92 4.00 116.59 5,937,281.81 495,914.87 11 9,000.00 90.41 27.84 6,079.19 -962.67 -2,363.81 -1,358.52 4.00 -93.00 5,937,338.56 495 946.53 9,100.00 90.20 23.85 6,078.65 -872.69 -2,320.23 -1,262.34 4.00 -93.02 5,937,428.52 495,990.13 9,135.00 90.13 22.45 6,078.55 -840.51 -2,306.47 -1,228.26 4.00 -93.04 5,937,460.70 496,003.89 12 9,200.00 90.04 19.85 6,078.46 -779.90 -2,283.02 -1,164.49 4.00 -92.00 5,937,521.30 496,027.35 9,300.00 89.90 15.85 6,078.51 -684.73 -2,252.37 -1,065.45 4.00 -92.00 5,937,616.45 496,058.02 9,400.00 89.76 11.86 6,078.82 -587.66 -2,228.43 -965.69 4.00 -92.00 5,937,713.51 496,081.98 9,500.00 89.62 7.86 6,079.36 -489.16 -2,211.32 -865.72 4.00 -91.99 5,937,812.00 496,099.11 9,600.00 89.48 3.86 6,080.14 -389.70 -2,201.11 -766.00 4.00 -91.97 5,937,911.44 496,109.34 9,700.00 89.35 359.86 6,081.16 -289.78 -2,197.87 -667.03 4.00 -91.94 5,938,011.35 496,112.61 9,735.00 89.30 358.46 6,081.57 -254.79 -2,198.38 -632.66 4.00 -91.90 5,938,046.34 496,112.11 13 10/4/2011 1:30:28PM Page 3 I A I COMPASS 2003.16 Build 69 r,•' ConocoPhillips or its affiliates 13" ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-28 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-28@ @ 148.65ft(2K-28@) Site: Kuparuk 2K Pad North Reference: True Well: 2K-28 Survey Calculation Method: Minimum Curvature Wellbore: 2K-28A Design: 2K-28A_wp06 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (0) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 9,800.00 89.12 355.87 6,082.47 -189.88 -2,201.59 -569.30 4.00 -94.00 5,938,111.24 496,108.91 9,900.00 88.85 351.88 6,084.24 -90.49 -2,212.26 -473.27 4.00 -93.96 5,938,210.63 496,098.26 9,935.00 88.75 350.48 6,084.97 -55.91 -2,217.63 -440.15 4.00 -93.89 5,938,245.20 496,092.90 14 10,000.00 88.75 353.08 6,086.39 8.40 -2,226.92 -378.42 4.00 90.00 5,938,309.51 496,083.63 10,100.00 88.76 357.08 6,088.55 107.99 -2,235.49 -281.84 4.00 89.94 5,938,409.09 496,075.08 10,200.00 88.77 1.08 6,090.70 207.93 . -2,237.09 - -183.69 4.00 89.86 5,938,509.02 496,073.50 TD Targets Target Name 1 -hit/miss target Dip Angle Dip Dir. ND +NI-S +E/-W Northing Easting 1 -Shape (0) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2K-28A_T1 0.00 0.00 6,143.00 -2,342.39 -2,623.94 5,935,959.04 495,686.12 70°14'10.531 N 150°2'5.386 W -plan hits target center -Point 2K-28A_T4 0.00 0.00 6,090.00 205.89 -2,227.44 5,938,506.97 496,083.15 70°14'35.594 N 150° 1'53.885 W -plan misses target center by 9.71ft at 10197.78ft MD(6090.66 TVD,205.72 N,-2237.13 E) -Point 1 2K-28A_Polygon 0.00 0.00 0.00 -2,367.45 -2,922.97 5,935,934.05 495,387.11 70°14'10.283 N 150°2'14.076 W -plan misses target center by 6041.62ft at 7187.69ft MD(6026.46 TVD,-2263.72 N,-2507.99 E) -Polygon Point 1 0.00 -2,367.45 -2,922.97 5,935,934.05 495,387.11 Point 2 0.00 -880.22 -2,642.35 5,937,421.07 495,668.03 Point 3 0.00 342.93 -2,526.68 5,938,644.07 495,783.97 Point4 0.00 95.08 -1,898.54 5,938,396.10 496,411.99 Point 5 0.00 -2,516.34 -2,459.88 5,935,785.07 495,850.12 Point 6 0.00 -2,367.45 -2,922.97 5,935,934.05 495,387.11 2K-28A_T3 0.00 0.00 6,080.00 -1,051.25 -2,408.19 5,937,250.01 495,902.13 70°14'23.230 N 150° 1'59.128 W -plan misses target center by 4.78ft at 8901.07ft MD(6080.24 TVD,-1048.87 N,-2412.33 E) -Point 2K-28A_Fault 1 0.00 0.00 6,113.00 -1,426.37 -2,857.17 5,936,875.03 495,453.12 70°14'19.539 N 150°2'12.174 W -plan misses target center by 246.45ft at 8357.17ft MD(6119.29 TVD,-1540.84 N,-2639.01 E) -Polygon Point 1 6,113.00 -1,426.37 -2,857.17 5,936,875.03 495,453.12 Point2 6,113.00 -1,468.30 -2,597.13 5,936,833.04 495,713.12 Point 3 6,113.00 -1,690.24 -2,279.04 5,936,611.05 496,031.13 Point 4 6,113.00 -1,468.30 -2,597.13 5,936,833.04 495,713.12 2K-28A_T2 0.00 0.00 6,113.00 -1,468.32 -2,597.13 5,936,833.02 495,713.12 70°14'19.127 N 150°2'4.615 W -plan misses target center by 2.24ft at 8441.08ft MD(6113.68 TVD,-1467.31 N,-2599.01 E) -Point 10/4/2011 1:30:28PM Page 4 COMPASS 2003.16 Build 69 ,,,, I 01N L N.-- ConocoPhillips or its affiliates Ire rli ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-28 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-28@ @ 148.65ft(2K-28@) Site: Kuparuk 2K Pad North Reference: True Well: 2K-28 Survey Calculation Method: Minimum Curvature Wellbore: 2K-28A Design: 2K-28A_wp06 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 3,282.03 2,815.20 9 5/8" 9-5/8 12-1/4 7,240.00 6,070.39 7" 7 8-1/2 10,200.00 6,090.70 2-3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 7,187.69 6,026.46 -2,263.72 -2,507.99 TIP 7,240.00 6,070.39 -2,283.05 -2,528.80 KOP 7,261.00 6,087.74 -2,290.92 -2,537.62 3 7,385.50 6,142.79 -2,344.78 -2,629.12 Start of 45DLS 7,485.00 6,140.21 -2,348.31 -2,726.01 5 7,585.00 6,137.41 -2,282.18 -2,797.52 6 7,635.00 6,137.22 -2,233.87 -2,809.14 7 7,835.00 6,136.49 -2,034.35 -2,799.65 Ribsteer 8,385.00 6,117.54 -1,516.53 -2,625.58 9 8,635.00 6,096.61 -1,290.26 -2,522.13 10 8,935.00 6,079.73 -1,019.44 -2,395.46 11 9,135.00 6,078.55 -840.51 -2,306.47 12 9,735.00 6,081.57 -254.79 -2,198.38 13 9,935.00 6,084.97 -55.91 -2,217.63 14 10,200.00 6,090.70 207.93 -2,237.09 TD 10/4/2011 1:30:28PM Page 5 COMPASS 2003.16 Build 69 i\ L) 1 1 v. t L ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2K Pad 2K-28 2K-28A 2K-28A_wp06 Travelling Cylinder Report 06 October, 2011 BAKER HUGHES ORIGINAL ConocoPhillips or its affiliates Irf, ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-28 Project: Kuparuk River Unit TVD Reference: 2K-28@ @ 148.65ft(2K-28(g) Reference Site: Kuparuk 2K Pad MD Reference: 2K-28@ @ 148.65ft(2K-28@) Site Error: 0.00ft North Reference: True Reference Well: 2K-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-28A Database: EDM Alaska Prod v16 Reference Design: 2K-28A_wp06 Offset TVD Reference: Offset Datum Reference 2K-28A_wp06 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of referE Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 7,187.69 to 10,200.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,216.98ft Error Surface: Elliptical Conic Survey Tool Program Date 10/4/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 130.00 582.10 2K-28 Gyro(2K-28) CB-GYRO-SS Camera based gyro single shot 665.41 7,187.69 2K-28 MWD(2K-28) MWD MWD-Standard 7,187.69 10,199.50 2K-28A_wp06(2K-28A) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 3,282.03 2,963.85 9 5/8" 9-5/8 12-1/4 7,240.00 6,219.04 7" 7 8-1/2 10,200.00 6,239.35 2-3/8" 2-3/8 3 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/6/2011 8:11:07AM Page 2 of 9 COMPASS 2003.16 Build 69 ORIGINi 'iL ConocoPhillips or its affiliates Ir1� ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-28 Project: Kuparuk River Unit TVD Reference: 2K-28@ @ 148.65ft(2K-28©) Reference Site: Kuparuk 2K Pad MD Reference: 2K-28©©148.65ft(2K-28©) Site Error: 0.00ft North Reference: True Reference Well: 2K-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-28A Database: EDM Alaska Prod v16 Reference Design: 2K-28A_wp06 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 2K Pad 2K-04-2K-04-2K-04 Out of range 2K-05-2K-05-2K-05 Out of range 2K-06-2K-06-2K-06 Out of range 2K-07-2K-07-2K-07 Out of range 2K-08-2K-08-2K-08 Out of range 2K-08-2K-08A-2K-08A Out of range 2K-08-2K-08APB1 -2K-08APB1 Out of range 2K-08-2K-08APB2-2K-08APB2 Out of range 2K-08-2K-08APB3-2K-08APB3 Out of range 2K-09-2K-09-2K-09 Out of range 2K-10-2K-10-2K-10 Out of range 2K-11 -2K-11 -2K-11 Out of range 2K-12-2K-12-2K-12 Out of range 2K-13-2K-13-2K-13 Out of range 2K-13-2K-13A-2K-13A Out of range 2K-13-2K-13AL1 -2K-13AL1 Out of range 2K-13-2K-13AL2-2K-13AL2 Out of range 2K-14-2K-14-2K-14 8,332.30 7,125.00 957.81 196.13 784.04 Pass-Major Risk 2K-15-2K-15-2K-15 Out of range 2K-16-2K-16-2K-16 Out of range 2K-17-2K-17-2K-17 Out of range 2K-18-2K-18-2K-18 Out of range 2K-19-2K-19-2K-19 Out of range 2K-19-2K-19A-2K-19A Out of range 2K-19-2K-19AL1 -2K-19AL1 Out of range 2K-20-2K-20-2K-20 Out of range 2K-27-2K-27-2K-27 Out of range 2K-28-2K-28-2K-28 7,250.00 7,250.00 0.12 2.33 -1.04 FAIL-Minor 1/10 2K-28-2K-28AL1 -2K-28AL1_wp03 7,399.83 7,400.00 1.68 0.83 0.86 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/6/2011 8:11:07AM Page 3 of 9 A COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates rin ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-28 Project: Kuparuk River Unit TVD Reference: 2K-28@ @ 148.65ft(2K-28@) Reference Site: Kuparuk 2K Pad MD Reference: 2K-28©@ 148.65ft(2K-28@) Site Error: 0.00ft North Reference: True Reference Well: 2K-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-28A Database: EDM Alaska Prod v16 Reference Design: 2K-28A_wp06 Offset TVD Reference: Offset Datum Offset Design Kuparuk 2K Pad- 2K-14-2K-14-2K-14 Offset Site Error: 0.00 ft Survey Program: 50-GYD-CT-CMS,7900-BOSS-GYRO Rule Assigned:Major Risk Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (1 (ft) (ft) (ft) (ff) (ft) (ft) 8,100.00 6,280.21 7,925.00 6,370.20 42.63 27.60 -75.87 -1,360.32 -3,878.32 0.42 1,214.64 189.67 1,027.91 Pass-Major Risk 8,123.88 6,279.38 7,900.00 6,349.26 42.45 27.60 -73.95 -1,358.78 -3,864.76 0.42 1,200.75 190.86 1,012.52 Pass-Major Risk 8,127.70 6,279.24 7,875.00 6,328.49 42.42 27.55 -72.84 -1,357.00 -3,850.95 0.42 1,187.38 191.25 998.81 Pass-Major Risk 8,131.71 6,279.09 7,850.00 6,307.92 42.39 27.49 -71.71 -1,355.02 -3,836.88 0.42 1,174.19 191.73 985.31 Pass-Major Risk 8,135.91 6,278.93 7,825.00 6,287.55 42.36 27.44 -70.56 -1,352.84 -3,822.56 0.42 1,161.19 192.28 972.03 Pass-Major Risk 8,140.32 6,278.77 7,800.00 6,267.37 42.33 27.39 -69.39 -1,350.46 -3,808.00 0.42 1,148.40 192.83 958.99 Pass-Major Risk 8,144.86 6,278.59 7,775.00 6,247.35 42.30 27.28 -68.19 -1,347.98 -3,793.23 0.42 1,135.81 192.90 946.28 Pass-Major Risk 8,149.50 6,278.41 7,750.00 6,227.40 42.26 27.17 -66.98 -1,345.46 -3,778.38 0.42 1,123.55 192.98 933.92 Pass-Major Risk 8,154.30 6,278.22 7,725.00 6,207.58 42.23 27.07 -65.75 -1,342.81 -3,763.36 0.42 1,111.56 193.05 921.89 Pass-Major Risk 8,159.26 6,278.02 7,700.00 6,187.95 42.19 26.96 -64.49 -1,340.05 -3,748.14 0.42 1,099.79 193.13 910.12 Pass-Major Risk 8,164.33 6,277.82 7,675.00 6,168.37 42.15 26.85 -63.21 -1,337.22 -3,732.86 0.42 1,088.40 193.21 898.78 Pass-Major Risk 8,169.58 6,277.60 7,650.00 6,148.87 42.11 26.73 -61.91 -1,334.19 -3,717.51 0.42 1,077.42 193.30 887.90 Pass-Major Risk 8,175.00 6,277.38 7,625.00 6,129.41 42.07 26.62 -60.58 -1,331.01 -3,702.13 0.42 1,066.89 193.38 877.53 Pass-Major Risk 8,200.00 6,276.30 7,475.00 6,014.67 41.89 25.94 -52.63 -1,306.05 -3,608.86 0.42 1,014.14 193.40 827.39 Pass-Major Risk 8,200.00 6,276.30 7,500.00 6,033.50 41.89 26.06 -53.81 -1,310.92 -3,624.56 0.42 1,021.63 193.61 834.12 Pass-Major Risk 8,200.00 6,276.30 7,525.00 6,052.48 41.89 26.17 -54.98 -1,315.58 -3,640.15 0.42 1,029.62 193.82 841.41 Pass-Major Risk 8,200.00 6,276.30 7,550.00 6,071.50 41.89 26.29 -56.14 -1,319.92 -3,655.79 0.42 1,038.29 194.02 849.45 Pass-Major Risk 8,200.00 6,276.30 7,575.00 6,090.73 41.89 26.40 -57.29 -1,323.70 -3,671.31 0.42 1,047.54 194.22 858.12 Pass-Major Risk 8,200.00 6,276.30 7,600.00 6,110.02 41.89 26.51 -58.43 -1,327.44 -3,686.76 0.42 1,057.24 194.41 867.30 Pass-Major Risk 8,219.62 6,275.40 7,450.00 5,996.01 41.74 25.82 -50.64 -1,300.95 -3,593.02 0.42 1,006.81 194.13 820.16 Pass-Major Risk 8,227.07 6,275.05 7,425.00 5,977.50 41.69 25.70 -49.14 -1,295.46 -3,577.15 0.42 1,000.17 194.26 814.14 Pass-Major Risk 8,234.80 6,274.68 7,400.00 5,959.10 41.63 25.58 -47.63 -1,289.64 -3,561.25 0.42 994.08 194.39 808.74 Pass-Major Risk 8,242.71 6,274.29 7,375.00 5,940.82 41.57 25.46 -46.10 -1,283.72 -3,545.26 0.42 988.40 194.53 803.81 Pass-Major Risk 8,250.98 6,273.88 7,350.00 5,922.79 41.51 25.34 -44.56 -1,277.40 -3,529.13 0.42 983.17 194.66 799.39 Pass-Major Risk 8,259.47 6,273.45 7,325.00 5,904.88 41.45 25.22 -43.01 -1,270.89 -3,512.96 0.42 978.41 194.80 795.51 Pass-Major Risk 8,268.14 6,273.00 7,300.00 5,887.00 41.38 25.10 -41.45 -1,264.25 -3,496.79 0.42 974.19 194.94 792.24 Pass-Major Risk 8,277.01 6,272.54 7,275.00 5,869.19 41.32 24.98 -39.87 -1,257.47 -3,480.61 0.42 970.49 195.08 789.54 Pass-Major Risk 8,300.00 6,271.29 7,175.00 5,797.67 41.15 24.49 -34.03 -1,230.72 -3,416.04 0.65 961.00 195.29 784.85 Pass-Major Risk 8,300.00 6,271.29 7,200.00 5,815.54 41.15 24.61 -35.26 -1,237.44 -3,432.19 0.65 962.52 195.54 784.87 Pass-Major Risk 8,300.00 6,271.29 7,225.00 5,833.33 41.15 24.73 -36.48 -1,244.13 -3,448.43 0.65 964.79 195.79 785.71 Pass-Major Risk 8,300.00 6,271.29 7,250.00 5,851.30 41.15 24.86 -37.70 -1,250.76 -3,464.49 0.42 967.51 195.80 787.27 Pass-Major Risk 8,322.71 6,270.00 7,150.00 5,779.92 40.98 24.37 -31.86 -1,224.24 -3,399.68 0.65 959.42 195.99 784.27 Pass-Major Risk 8,332.30 6,269.44 7,125.00 5,762.67 40.90 24.24 -30.24 -1,217.76 -3,382.79 0.65 957.81 196.13 784.04 Pass-Major Risk,ES,SF 8,342.08 6,268.86 7,100.00 5,745.54 40.83 24.12 -28.62 -1,211.22 -3,365.79 0.65 956.58 196.26 784.25 Pass-Major Risk 8,351.93 6,268 26 7,075.00 5,728.43 40.76 23.99 -27.00 -1,204.82 -3,348.73 0.65 955.75 196.39 784.91 Pass-Major Risk 8,361.95 6,267.65 7,050.00 5,711.33 40.68 23.86 -25.37 -1,198.36 -3,331.67 0.65 955.42 196.52 786.13 Pass-Major Risk,CC 8,385.00 6,266.19 7,000.00 5,677.41 40.51 23.61 -21.99 -1,185.56 -3,297.24 0.65 955.85 196.86 789.75 Pass-Major Risk 8,385.00 6,266.19 7,025.00 5,694.27 40.51 23.74 -23.19 -1,191.95 -3,314.56 0.65 955.66 197.12 787.76 Pass-Major Risk 8,413.28 6,264.30 6,975.00 5,660.45 40.27 23.48 -21.98 -1,179.08 -3,280.06 0.65 956.72 194.38 794.03 Pass-Major Risk 8,449.77 6,261.68 6,950.00 5,643.52 39.94 23.36 -22.31 -1,172.71 -3,262.80 0.65 957.57 191.14 798.77 Pass-Major Risk 8,485.43 6,258.93 6,925.00 5,626.66 39.62 23.23 -22.60 -1,166.24 -3,245.51 0.65 958.49 187.92 803.51 Pass-Major Risk 8,519.88 6,256.08 6,900.00 5,609.78 39.33 23.10 -22.84 -1,159.84 -3,228.22 0.65 959.50 184.77 808.22 Pass-Major Risk 8,553.10 6,253.16 6,875.00 5,592.82 39.05 22.98 -23.03 -1,153.50 -3,210.98 0.65 960.75 181.69 813.03 Pass-Major Risk 8,585.34 6,250.17 6,850.00 5,575.86 38.78 22.85 -23.18 -1,147.14 -3,193.75 0.65 962.17 178.67 817.91 Pass-Major Risk 8,616.56 6,247.12 6,825.00 5,559.03 38.53 22.72 -23.28 -1,140.82 -3,176.38 0.65 963.59 175.72 822.64 Pass-Major Risk 8,635.00 6,245.26 6,775.00 5,525.22 38.39 22.47 -21.60 -1,128.05 -3,141.82 0.65 967.74 173.66 831.11 Pass-Major Risk 8,635.00 6,245.26 6,800.00 5,542.15 38.39 22.60 -22.84 -1,134.41 -3,159.09 0.65 965.37 173.88 827.02 Pass-Major Risk 8,654.84 6,243.29 6,750.00 5,508.09 38.24 22.35 -19.57 -1,121.86 -3,124.70 0.65 970.64 174.18 835.20 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/6/2011 8:11.07AMtl , ij P COMPASS 2003.16 Build 69 'ad 0. tIN i..1L ConocoPhillips or its affiliates VA' ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-28 Project: Kuparuk River Unit ND Reference: 2K-28@ @ 148.65ft(2K-28@) Reference Site: Kuparuk 2K Pad MD Reference: 2K-28@ @ 148.65ft(2K-28@) Site Error: O.00ft North Reference: True Reference Well: 2K-28 Survey Calculation Method: Minimum Curvature Well Error: O.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-28A Database: EDM Alaska Prod v16 Reference Design: 2K-28A_wp06 Offset ND Reference: Offset Datum Offset Design Kuparuk 2K Pad- 2K-14-2K-14-2K-14 Offset Site Error: 0.00 ft Survey Program: 50-GYD-CT-CMS,7900-BOSS-GYRO Rule Assigned:Major Risk Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +Ni-S +EI-W Hole Size Centre Distance Deviation (ff) (ff) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) (N) (ff) (ft) 8,662.93 6,242.52 6,725.00 5,490.55 38.18 22.22 -18.02 -1,115.90 -3,107.91 0.65 974.67 174.26 840.76 Pass-Major Risk 8,670.94 6,241.77 6,700.00 5,472.75 38.12 22.10 -16.48 -1,110.08 -3,091.35 0.65 979.52 174.33 847.16 Pass-Major Risk 8,678.89 6,241.05 6,675.00 5,454.76 38.06 21.98 -14.96 -1,104.37 -3,074.97 0.65 985.12 174.40 854.32 Pass-Major Risk 8,686.88 6,240.35 6,650.00 5,436.82 38.00 21.86 -13.46 -1,098.66 -3,058.52 0.65 991.14 174.46 861.90 Pass-Major Risk 8,700.00 6,239.24 6,575.00 5,383.05 37.91 21.50 -9.47 -1,081.39 -3,009.17 0.65 1,012.15 174.25 887.77 Pass-Major Risk 8,700.00 6,239.24 6,600.00 5,400.93 37.91 21.62 -10.61 -1,087.08 -3,025.69 0.65 1,004.70 174.47 878.62 Pass-Major Risk 8,700.00 6,239.24 6,625.00 5,418.87 37.91 21.74 -11.77 -1,092.85 -3,042.11 0.65 997.71 174.69 869.90 Pass-Major Risk 8,719.14 6,237.72 6,550.00 5,365.00 37.78 21.38 -7.61 -1,075.81 -2,992.79 0.65 1,020.06 174.75 896.95 Pass-Major Risk 8,727.27 6,237.10 6,525.00 5,347.04 37.72 21.26 -6.19 -1,070.12 -2,976.36 0.65 1,028.44 174.83 906.82 Pass-Major Risk 8,735.44 6,236.51 6,500.00 5,329.12 37.66 21.15 -4.79 -1,064.42 -2,959.89 0.65 1,037.19 174.91 917.06 Pass-Major Risk 8,743.47 6,235.94 6,475.00 5,311.00 37.61 21.03 -3.42 -1,058.97 -2,943.54 0.65 1,046.56 174.97 927.90 Pass-Major Risk 8,751.57 6,235.39 6,450.00 5,292.94 37.55 20.91 -2.07 -1,053.46 -2,927.16 0.65 1,056.29 175.04 939.07 Pass-Major Risk 8,759.74 6,234.86 6,425.00 5,274.92 37.50 20.79 -0.74 -1,047.89 -2,910.75 0.65 1,066.38 175.10 950.57 Pass-Major Risk 8,767.99 6,234.34 6,400.00 5,256.94 37.44 20.67 0.57 -1,042.22 -2,894.35 0.65 1,076.83 175.15 962.41 Pass-Major Risk 8,776.22 6,233.84 6,375.00 5,239.06 37.38 20.55 1.87 -1,036.69 -2,877.76 0.65 1,087.48 175.21 974.42 Pass-Major Risk 8,800.00 6,232.52 6,250.00 5,149.92 37.22 19.95 7.35 -1,008.97 -2,794.64 0.65 1,145.94 174.85 1,039.42 Pass-Major Risk 8,800.00 6,232.52 6,275.00 5,167.64 37.22 20.07 6.47 -1,014.49 -2,811.39 0.65 1,133.61 175.07 1,025.80 Pass-Major Risk 8,800.00 6,232.52 6,300.00 5,185.48 37.22 20.19 5.58 -1,020.11 -2,827.98 0.65 1,121.53 175.30 1,012.39 Pass-Major Risk 8,800.00 6,232.52 6,325.00 5,203.29 37.22 20.31 4.66 -1,025.60 -2,844.64 0.65 1,109.93 175.53 999.42 Pass-Major Risk 8,800.00 6,232.52 6,350.00 5,221.17 37.22 20.43 3.73 -1,031.19 -2,861.19 0.65 1,098.68 175.76 986.75 Pass-Major Risk 8,826.40 6,231.27 6,225.00 5,132.28 37.04 19.83 9.19 -1,003.39 -2,777.82 0.65 1,158.13 175.48 1,052.57 Pass-Major Risk 8,834.87 6,230.91 6,200.00 5,114.61 36.98 19.71 10.34 -997.88 -2,761.03 0.65 1,170.87 175.52 1,066.45 Pass-Major Risk 8,843.33 6,230.58 6,175.00 5,097.02 36.92 19.59 11.48 -992.49 -2,744.09 0.65 1,183.77 175.56 1,080.46 Pass-Major Risk 8,851.87 6,230.26 6,150.00 5,079.36 36.86 19.47 12.59 -986.95 -2,727.29 0.65 1,197.08 175.59 1,094.82 Pass-Major Risk 8,860.37 6,229.97 6,125.00 5,061.74 36.80 19.35 13.68 -981.58 -2,710.39 0.65 1,210.60 175.61 1,109.37 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/6/2011 8:11:07AM Page 5 of 9 COMPASS 2003.16 Build 69 y ConocoPhillips or its affiliates Fab ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-28 Project: Kuparuk River Unit TVD Reference: 2K-28@ @ 148.65ft(2K-28@) Reference Site: Kuparuk 2K Pad MD Reference: 2K-28@ @ 148.65ft(2K-28@) Site Error: O.00ft North Reference: True Reference Well: 2K-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-28A Database: EDM Alaska Prod v16 Reference Design: 2K-28A_wp06 Offset TVD Reference: Offset Datum Offset Design Kuparuk 2K Pad- 2K-28-2K-28-2K-28 Offset Site Error: 0 00 ft Survey Program: 130-CB-GYRO-SS,665-MWD Rule Assigned:Minor 1/10 Offset Well Error: O.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (1 (ft) (ft) (ft) (ft) (ft) (ft) 7,200.00 6,185.44 7,200.00 6,185.44 0.08 0.08 30.06 -2,268.29 -2,512.87 0.65 0.00 1.82 -0.79 FAIL-Minor 1/10,CC 7,225.00 6,206.44 7,225.00 6,206.44 0.21 0.25 30.25 -2,277.53 -2,522.81 0.65 0.00 2.28 -0.98 FAIL-Minor 1/10 7,250.00 6,227.37 7,250.00 6,227.44 0.35 0.42 64.80 -2,286.72 -2,532.79 0.42 0.12 2.33 -1.04 FAIL-Minor 1/10,ES,SF 7,274.77 6,247.16 7,275.00 6,248.44 0.50 0.59 67.24 -2,295.87 -2,542.81 0.22 2.00 2.10 0.92 Pass-Minor 1/10 7,298.10 6,263.18 7,300.00 6,269.44 0.67 0.76 69.51 -2,304.98 -2,552.86 0.22 8.21 2.20 7.02 Pass-Minor 1/10 7,318.77 6,274.69 7,325.00 6,290.43 0.85 0.93 71.10 -2,314.08 -2,562.93 0.22 18.47 2.20 17.24 Pass-Minor 1/10 7,336.33 6,282.25 7,350.00 6,311.41 1.01 1.11 72.40 -2,323.18 -2,573.02 0.22 32.02 2.10 30.78 Pass-Minor 1/10 7,350.00 6,286.62 7,375.00 6,332.39 1.14 1.28 73.44 -2,332.28 -2,583.14 0.22 48.10 2.01 46.88 Pass-Minor 1/10 7,362.91 6,289.48 7,400.00 6,353.41 1.27 1.45 74.43 -2,341.31 -2,593.21 0.22 66.11 1.97 64.92 Pass-Minor 1/10 7,372.67 6,290.80 7,425.00 6,374.57 1.37 1.62 75.16 -2,350.19 -2,603.13 0.22 85.68 1.95 84.53 Pass-Minor 1/10 7,380.00 6,291.32 7,450.00 6,395.86 1.45 1.79 75.71 -2,358.93 -2,612.91 0.22 106.42 1.92 105.32 Pass-Minor 1/10 7,388.22 6,291.43 7,475.00 6,417.27 1.53 1.95 77.35 -2,367.51 -2,622.54 0.22 128.01 1.94 126.95 Pass-Minor 1/10 7,397.56 6,291.40 7,500.00 6,438.73 1.63 2.12 81.75 -2,376.04 -2,632.11 0.22 149.98 1.94 148.90 Pass-Minor 1/10 7,406.20 6,291.32 7,525.00 6,460.20 1.72 2.28 86.07 -2,384.57 -2,641.68 0.22 172.17 1.92 171.06 Pass-Minor 1/10 7,411.99 6,291.24 7,543.00 6,475.65 1.78 2.40 89.07 -2,390.71 -2,648.57 0.22 188.27 1.91 187.15 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/6/2011 8:11:07AM Page 6 of 9 COMPASS 2003.16 Build 69 I N A L ConocoPhillips or its affiliates I/.r ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-28 Project: Kuparuk River Unit TVD Reference: 2K-28@ @ 148.65ft(2K-28@) Reference Site: Kuparuk 2K Pad MD Reference: 2K-28@ @ 148.65ft(2K-28@) Site Error: 0.00ft North Reference: True Reference Well: 2K-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-28A Database: EDM Alaska Prod v16 Reference Design: 2K-28A_wp06 Offset ND Reference: Offset Datum Offset Design Kuparuk 2K Pad- 2K-28-2K-28AL1 -2K-28AL1_wp03 Offset Site Error: 0.00 ft Survey Program: 130-CB-GYRO-SS,665-MWD,7188-MWD,7380-MWD Rule Assigned:Minor 1/10 Offset Well Error: 0.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (It) (ft) (ft) (1 (ft) (ft) (ft) (ft) (ft) (ft) 7,399.83 6,291.38 7,400.00 6,292.16 0.21 0.21 134.12 -2,351.37 -2,642.02 0.22 1.68 0.83 0.86 Pass-Minor 1/10,CC,ES, 7,422.79 6,291.06 7,425.00 6,293.22 0.45 0.46 158.51 -2,363.79 -2,663.69 0.22 9.07 1.19 7.87 Pass-Minor 1/10 7,442.05 6,290.57 7,450.00 6,294.26 0.66 0.72 171.18 -2,377.59 -2,684.50 0.22 21.73 1.37 20.35 Pass-Minor 1/10 7,450.00 6,290.32 8,450.00 6,302.25 0.74 11.28 -176.24 -3,316.93 -2,803.35 0.22 967.63 2.42 967.41 Pass-Minor 1/10 7,450.00 6,290.32 8,475.00 6,302.74 0.74 11.53 -176.23 -3,340.99 -2,796.57 0.22 990.80 2.42 990.35 Pass-Minor 1/10 7,450.00 6,290.32 8,500.00 6,303.23 0.74 11.79 -176.23 -3,365.16 -2,790.21 0.22 1,014.21 2.39 1,013.58 Pass-Minor 1/10 7,450.00 6,290.32 8,525.00 6,303.72 0.74 12.03 -176.22 -3,389.44 -2,784.27 0.22 1,037.83 2.35 1,037.08 Pass-Minor 1/10 7,450.00 6,290.32 8,550.00 6,304.21 0.74 12.27 -176.22 -3,413.82 -2,778.76 0.22 1,061.66 2.29 1,060.81 Pass-Minor 1/10 7,450.00 6,290.32 8,575.00 6,304.70 0.74 12.51 -176.21 -3,438.29 -2,773.67 0.22 1,085.66 2.24 1,084.74 Pass-Minor 1/10 7,450.00 6,290.32 8,600.00 6,305.18 0.74 12.76 -176.21 -3,462.85 -2,769.01 0.22 1,109.82 2.17 1,108.84 Pass-Minor 1/10 7,450.00 6,290.32 8,625.00 6,305.67 0.74 13.01 -176.21 -3,487.48 -2,764.78 0.22 1,134.12 2.11 1,133.08 Pass-Minor 1/10 7,450.00 6,290.32 8,650.00 6,306.16 0.74 13.26 -176.21 -3,512.18 -2,760.99 0.22 1,158.55 2.02 1,157.46 Pass-Minor 1/10 7,450.00 6,290.32 8,675.00 6,306.64 0.74 13.52 -176.21 -3,536.95 -2,757.62 0.22 1,183.08 1.95 1,181.97 Pass-Minor 1/10 7,450.00 6,290.32 8,700.00 6,307.13 0.74 13.77 -176.21 -3,561.77 -2,754.69 0.22 1,207.72 1.86 1,206.58 Pass-Minor 1/10 7,455.17 6,290.14 8,425.00 6,301.76 0.80 11.01 -173.84 -3,292.95 -2,810.40 0.22 944.55 2.12 943.94 Pass-Minor 1/10 7,457.14 6,290.07 7,475.00 6,295.16 0.82 0.98 -179.89 -2,392.72 -2,704.38 0.22 38.39 1.45 36.95 Pass-Minor 1/10 7,460.00 6,289.96 8,250.00 6,298.30 0.85 9.09 -171.65 -3,122.26 -2,848.37 0.22 781.54 2.07 780.68 Pass-Minor 1/10 7,460.00 6,289.96 8,275.00 6,298.80 0.85 9.36 -171.64 -3,146.91 -2,844.23 0.22 805.02 2.06 804.22 Pass-Minor 1/10 7,460.00 6,289.96 8,300.00 6,299.29 0.85 9.64 -171.63 -3,171.49 -2,839.66 0.22 828.45 2.04 827.68 Pass-Minor 1/10 7,460.00 6,289.96 8,325.00 6,299.79 0.85 9.91 -171.63 -3,195.98 -2,834.66 0.22 851.82 2.03 851.07 Pass-Minor 1/10 7,460.00 6,289.96 8,350.00 6,300.28 0.85 10.19 -171.62 -3,220.37 -2,829.23 0.22 875.13 2.01 874.38 Pass-Minor 1/10 7,460.00 6,289.96 8,375.00 6,300.77 0.85 10.46 -171.61 -3,244.67 -2,823.37 0.22 898.37 1.98 897.59 Pass-Minor 1/10 7,460.00 6,289.96 8,400.00 6,301.27 0.85 10.74 -171.60 -3,268.87 -2,817.10 0.22 921.55 1.97 920.72 Pass-Minor 1/10 7,464.52 6,289.78 8,225.00 6,297.82 0.89 8.82 -169.54 -3,097.55 -2,852.09 0.22 757.90 1.96 756.86 Pass-Minor 1/10 7,465.70 6,289.73 8,200.00 6,297.39 0.90 8.54 -169.00 -3,072.77 -2,855.37 0.22 734.25 1.94 733.15 Pass-Minor 1/10 7,470.00 6,289.55 7,500.00 6,295.77 0.95 1.23 -172.55 -2,409.10 -2,723.25 0.22 57.94 1.50 56.48 Pass-Minor 1/10 7,470.00 6,289.55 8,050.00 6,296.13 0.95 6.91 -167.18 -2,923.22 -2,866.06 0.22 591.11 1.74 589.80 Pass-Minor 1/10 7,470.00 6,289.55 8,075.00 6,296.18 0.95 7.18 -167.13 -2,948.21 -2,865.35 0.22 615.09 1.81 613.79 Pass-Minor 1/10 7,470.00 6,289.55 8,100.00 6,296.30 0.95 7.45 -167.09 -2,973.19 -2,864.22 0.22 639.03 1.84 637.74 Pass-Minor 1/10 7,470.00 6,289.55 8,125.00 6,296.48 0.95 7.72 -167.05 -2,998.14 -2,862.65 0.22 662.92 1.86 661.66 Pass-Minor 1/10 7,470.00 6,289.55 8,150.00 6,296.72 0.95 7.99 -167.03 -3,023.05 -2,860.65 0.22 686.78 1.87 685.54 Pass-Minor 1/10 7,470.00 6,289.55 8,175.00 6,297.02 0.95 8.27 -167.00 -3,047.93 -2,858.23 0.22 710.58 1.86 709.37 Pass-Minor 1/10 7,474.12 6,289.37 8,025.00 6,296.12 0.99 6.64 -165.30 -2,898.22 -2,866.33 0.22 567.01 1.71 565.72 Pass-Minor 1/10 7,475.34 6,289.31 8,000.00 6,296.12 1.00 6.37 -164.79 -2,873.22 -2,866.16 0.22 542.90 1.64 541.65 Pass-Minor 1/10 7,476.73 6,289.25 7,525.00 6,296.09 1.02 1.49 -168.39 -2,426.67 -2,741.02 0.22 79.41 1.50 77.96 Pass-Minor 1/10 7,480.00 6,289.10 7,875.00 6,296.13 1.05 5.04 -162.97 -2,748.48 -2,858.80 0.22 421.64 1.48 420.60 Pass-Minor 1/10 7,480.00 6,289.10 7,900.00 6,296.13 1.05 5.30 -162.89 -2,773.37 -2,861.14 0.22 445.97 1.44 445.07 Pass-Minor 1/10 7,480.00 6,289.10 7,925.00 6,296.13 1.05 5.57 -162.81 -2,798.30 -2,863.05 0.22 470.27 1.40 469.97 Pass-Minor 1/10 7,480.00 6,289.10 7,950.00 6,296.13 1.05 5.83 -162.73 -2,823.25 -2,864.52 0.22 494.55 1.50 493.65 Pass-Minor 1/10 7,480.00 6,289.10 7,975.00 6,296.12 1.05 6.10 -162.66 -2,848.23 -2,865.56 0.22 518.79 1.60 517.73 Pass-Minor 1/10 7,482.60 6,288.97 7,550.00 6,296.14 1.07 1.75 -164.83 -2,445.35 -2,757.63 0.22 102.27 1.51 100.82 Pass-Minor 1/10 7,482.94 6,288.96 7,850.00 6,296.13 1.08 4.78 -161.68 -2,723.64 -2,856.02 0.22 397.25 1.44 396.05 Pass-Minor 1/10 7,485.00 6,288.86 7,800.00 6,296.13 1.10 4.27 -160.94 -2,674.11 -2,849.17 0.22 348.37 1.42 347.09 Pass-Minor 1/10 7,485.00 6,288.86 7,825.00 6,296.13 1.10 4.52 -160.82 -2,698.84 -2,852.81 0.22 372.83 1.42 371.56 Pass-Minor 1/10 7,486.63 6,288.78 7,575.00 6,296.14 1.11 2.00 -162.34 -2,465.07 -2,772.99 0.22 126.05 1.51 124.61 Pass-Minor 1/10 7,486.97 6,288.76 7,775.00 6,296,13 1.12 4.01 -160.14 -2,649.45 -2,845.10 0.22 323.88 1.40 322.58 Pass-Minor 1/10 7,490.00 6,288.62 7,600.00 6,296.14 1.15 2.26 -160.31 -2,485.76 -2,787.02 0.22 150.43 1.51 149.00 Pass-Minor 1/10 7,490.00 6,288.62 7,625.00 6,296.14 1.15 2.51 -159.96 -2,507.32 -2,799.67 0.22 175.17 1.49 173.75 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/6/2011 8:11:07AM Page 7 ofCOMPASS 2003.16 Build 69 ' r? 1 GINAL y ConocoPhillips or its affiliates Mit ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-28 Project: Kuparuk River Unit TVD Reference: 2K-28@ @ 148.65ft(2K-28@) Reference Site: Kuparuk 2K Pad MD Reference: 2K-28@ @ 148.65ft(2K-28@) Site Error: 0.00ft North Reference: True Reference Well: 2K-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-28A Database: EDM Alaska Prod v16 Reference Design: 2K-28A_wp06 Offset TVD Reference: Offset Datum Offset Design Kuparuk 2K Pad- 2K-28-2K-28AL1 -2K-28AL1_wp03 Offset Site Error: 0.00ft Survey Program: 130-CB-GYRO-SS,665-MWD,7188-MWD,7380-MWD Rule Assigned:Minor 1/10 Offset Well Error: O.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) (ft) (ft) (ft) 7,490.00 6,288.62 7,650.00 6,296.14 1.15 2.77 -159.68 -2,529.66 -2,810.88 0.22 200.10 1.47 198.70 Pass-Minor 1/10 7,490.00 6,288.62 7,675.00 6,296.14 1.15 3.02 -159.43 -2,552.68 -2,820.61 0.22 225.08 1.45 223.69 Pass-Minor 1/10 7,490.00 6,288.62 7,700.00 6,296.14 1.15 3.27 -159.22 -2,576.29 -2,828.81 0.22 250.00 1.43 248.62 Pass-Minor 1/10 7,490.00 6,288.62 7,725.00 6,296.13 1.15 3.52 -159.03 -2,600.39 -2,835.45 0.22 274.78 1.40 273.42 Pass-Minor 1/10 7,490.00 6,288.62 7,750.00 6,296.13 1.15 3.76 -158.86 -2,624.85 -2,840.59 0.22 299.38 1.36 298.04 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/6/2011 8:11:07AM eaqq,,8jof 9 COMPASS 2003.16 Build 69 ConocoPhillips or its affiliates ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2K-28 Project: Kuparuk River Unit TVD Reference: 2K-28©@ 148.65ft(2K-28@) Reference Site: Kuparuk 2K Pad MD Reference: 2K-28@ @ 148.65ft(2K-28(g) Site Error: 0.00ft North Reference: True Reference Well: 2K-28 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2K-28A Database: EDM Alaska Prod v16 Reference Design: 2K-28A_wp06 Offset TVD Reference: Offset Datum Reference Depths are relative to 2K-28@ @ 148.65ft(2K-28@) Coordinates are relative to:2K-28 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:-0.02° Ladder Plot 1200 I I I I I I I I I I I I I I I I I I I I I I I 0 I I I I I 1 I I I I I I I I I I I I I I I I" 900 ' C I I I I I I I I I I I 1 I I I I I I w I I I I I t I I I I I I I I I I I I I I I I I I I I I I I I s 600 V I I I I I I I I I I I I I I I I I I I 1 I I I I J J J J {t 1 t I I I I V I 1 I I I I I 1 I I I I 300 1 1 I I I I I 1 I I I I I I I I I I 1 t I I I I 1 I I I I I I I I I I I I 1 I I I I 0 1500 3000 4500 6000 7500 9000 Measured Depth LEGEND -4-- 2K-14.2K-14,2K-14 V0 —4—2K-28.2K-28.2K-28 Vl5 -e- 2 K-28.2 K-28 ALI.2 K-28AL1 wp03VOl CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/6/2011 8:11:07AM Page 9 of 9 COMPASS 2003.16 Build 69 4 G1 NAL Davies, Stephen F (DOA) From: Winfree, Michael Alex (Jr.) [Michael.A.Winfree@conocophillips.com] Sent: Monday, October 10, 2011 3:58 PM To: Davies, Stephen F (DOA) Subject: 2K-28 CTD APD Coordinate Revision (Original PTD#201-154) Mr. Davies, Per our conversation regarding the surface coordinates for well 2K-28. The coordinates from the original PTD are correct with the surface location in Section 11. I recalculated the surface coordinates and matched the original permit as well. The Application for the Permit to Drill 2K-28A and 2K-28AL1 should read: Surface Coordinates for Both Laterals: Legal Description I Township: 010 N Range: 008 E ( Meridian: p-7E, Section:lj j FIT13.2507134 FEL 194.167277 � Top of Productive Horizon For 2K-28A ral: 11 i Legal Description - i i Township: 1010 FE Range: .ram 008 E Meridian U J Section: ll FNL j 12310.6875 FETE 1.2655.0915 Top of Productive Horizon for 2K-28AL1 Lateral: :Legal Description- Township: escription Township: I010 IFE Range: 008 IFE. Meridian u j Section:l11 FEE 12346.1940 1.-F\:#—FE; WL 12560.0337 Total Depth for 2K-28A Lateral is Correct Total Depth for 2K-28AL1 Lateral: 1 --Legal Description — — Township: 010 NITE Range: 008 E Meridian: `N Section-114 FNL 420.85446 F ciL : 2028.2990 After further investigation, I found my error was inputting the site location coordinates rather than the surface coordinates into the conversion program. After reviewing the remaining coordinates I found, and fixed, some cut and paste errors. The correct coordinates are listed above. Please let me know if you need additional information regarding the 2K-28 CTD Application for a Permit to Drill. Thank you, -Mike Mike A. Winfree Drilling Engirt::or 907.265.6820 Direct 907.242.0246 Cell 2 rage I or z Schwartz, Guy L (DOA) From: Winfree, Michael Alex (Jr.) [Michael.A.Winfree@conocophillips.com] Sent: Wednesday, November 09, 2011 8:23 AM To: Schwartz, Guy L (DOA) Cc: Gantt, Lamar L; Kanady, Randall B Subject: 2K-28 CTD 10-401 Response to Request for more Information Guy, Per the AOGCC's request, please find the information below regarding the Application for the Permit to Drill 2K-28A and 2K-28AL1: Slotted Liner Running Procedure • A SSSV is not present in the 2K-28 well, so the well will be displaced to a completion fluid that maintains overbalance on the formation prior to running the liner. • Confirm appropriate liner sized rams are in place in the BOP stack. • The pipe rams must be capable of sealing on the OD of the blank joint. • Have a TIW valve made up to a Range 2 length joint(safety joint) of blank liner ready for well control during running of the slotted liner • Monitor well bore fluid level and keep hole full at all times while making up liner. • RIH with 2%"slotted liner assembly to TD using 2"coil. • Release from liner running tools and pull out of the hole. Pressure Deploy BHA The double swab valves, double deployment rams, double ball valves and one set of double check valves in the BHA, and a slick line lubricator are used to deploy/undeploy the BHA under pressure. The Managed Pressure Drilling technique is used to maintain an overbalance on the formation, pumping below the swab valve, during the deployment procedure. The pressure control equipment listed ensures there are always two barriers to reservoir pressure during the BHA deploy/undeploy process. When the lubricator is installed and the BHA is spaced out above the tree, the double swab valves are closed and provide isolation to reservoir pressure. When the BHA is spaced out for access to the double ball valves, the set of double check valves and the double ball valves in the bottom hole assembly are preventing wellbore pressure communication up the BHA. The double deployment rams and lubricator are annular barriers to reservoir pressure with the BHA in this position. The lubricator can be removed once pressure is bled off above the deployment rams. Two barriers are still maintained with the double deployment rams on the annulus and the double check valves and double ball valves in the BHA. With the coil made up to the BHA, the double ball valves open in the BHA, and the riser installed, the BHA can continue to be safely run in the hole. Permit Application Clarification for Mud Weight In the permit application under the"Mud Program"and "Managed Pressure Drilling"sections, it states we intend to use a 10.0 ppg mud system for CT drilling operations on 2K-28. The mud weight in this section should be listed as a range between a 9.5 ppg and 10.5 ppg chloride based Flo-Pro mud system since the density of the fluid we choose to drill with depends on reservoir pressure and acceptable choke pressures for MPD operations. 11/9/2011 Page 2 of 2 Please let me know if you need additional information to process the 10-401 form for 2K-28A and 2K-28AL1. Thank you, -Mike Mike A. Winfree From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, November 03, 2011 1:51 PM To: Kanady, Randall B Cc: Gantt, Lamar L; Winfree, Michael Alex (Jr.) Subject: CTD PTD Randy, I am reviewing the regulation requirements and cross-referencing what is submitted in the CTD permit applications. Everything that is required by 20 AAC 25.005 seems to be in order. It still comes down to the procedural steps provided being detailed enough to allow me to ascertain that the equipment and processes are in place to safely drill and complete the well. Two items needed area a detailed procedure for running the slotted liners and more information on deploying the BHA tools under pressure.As we talked about in the meeting, if you were a new operator on the slope I would want to see your contingencies and SOP for both of these operations. A detailed bullet paragraph for both of these operations would be a great start. They could be added to the well control section of the application. You could reference the slotted liner paragraph in the procedure step itself. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 11/9/2011 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 a'/ / ,,4q PTD# 2--l C5 Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: �(� � c,� POOL: 4Ld,-r',_A- 4 e r ( Circle Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 co m CI ,��, D I o 0 Q., › 0 -0 _ rc7...g. 7 5. m 0 iv , . o o 0 3• o m - . O\ yN yO Ot 7 O N D -,.,-3- 0 N CDo o O n CO CO V O CA A W N 0 C0 Co V 0) 01 A CO N -.• 0 CO 01 _ __.. - co W W W W W c.---5----ca W W N N N N N N N N N N CO Co V 0) 01 A G) N ° COCA 01 A W N 0 V 0) 0 'fn Co '0 b K ;y * C) co 00 0 -« 'D D 0 'C) 'C) 'C) '(n C) - D .* C) b b 'p 'p a. 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