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210-174
Image Project Well History File Cover Page XHVZE This pageidentifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. aL a - L '7rLf Well History File Identifier Organizing(done) ❑ Two-sided II 111111 III 1 III ❑ Rescan Needed III 1111111111111111 RES AN DIGITAL DATA OVERSIZED (Scannable) 111 Co r Items: ❑ Diskettes, No. ❑ Maps: Greyscale Items: ❑ Other, No/Type: , they Items Scannable by - a Large Scanner •01 S ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: E Logs of various kinds: NOTES: ❑ Other:: BY: _f. Date: (Pi aliti. isi VII p Project Proofing IIIIIIIIIIIIIIIIII BY: Date: (041 i /s/ PIP Scanning Preparation 5 x 30 = 150 + a,7 = TOTAL PAGES i 7 7 (Count does not include cover sheet) pi BY: CD Date: Ii� /s/ Production Scanning 111111111011111 Stage 1 Page Count from Scanned File: / 7 (Count does include c er sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: AIM Date: /a4... � /s/ 1 ' 1p 1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III 1111IIII II 11111 ReScanned II IIIIIIIIIJ 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked 111111111II11111Ill o c 'D a � 2 - o` O CL 0_a N - C D) O N U J N N ea m O O o J c� • 2 rnCL CO Z 1 CV o as a2 w w o J o _0 o J co c o J c N = Ct� Q'2� 0 CZ J C - J c >., 0 0- '_ 4 U NI > c c'Q'S rew= O a UO.,.. 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Iii eg O O 0 0 0 0 0 0 0 0 N c ZI J 2 0 0 U U U U U U U U C o O a) N m O a a) 0, La 1 Ln Lr) E O. 0 fn N cV N N N N N N N N V N U o rN M J N m Ni M mce Ln IIS v/ Q p 0. Q M c Yo a Q p ZI 0 w w a ce z E o w > •> 0 m U cm o -- c N N Z 7 I 0 co N N c Rii C co to c) LL LL a) 1 t= C C O OJJ C IQ Q ffJJJ J 0 0 Z c) 7 CO u) a V V cp > > > 3 > > > > a) a) a a) co y J c c c X 2 2 2 2 2 2 2 2 IX v) •ztZO J � U) a 03 rn rn i- p E o v v 0 ! Z at+ C W O Z N N 0 co O .= _ O < ° E E 6 M , Z V w aLL J J cnJ O u c rn� NI- r-- LI- o) \U \ UaZW E a \ 0 d - --! 0. 0 0°) cm rn rn rn rn m rn 0 a 03 >, Et J 0 FW J aJ J J W W c 9 0 co v, -- a N Z ZI o N H->1 F. QT r--1 C.) (/) S I I qZ C - Cl) coE o 16 �/ • (n m o U O LL Q O d a) .. � Z d\ Q. a E a CJ J a) J_ (n NW = in z' LI d U -a W za a m V 0 d a co Zd o Q c co Z H to N �O C y 7 o O J Y = CL 0 T E C N c a) o G g N o CD 1 O 5'1a Ur. N I J M Q N N rp r «. r H 1 5 0 G = N d M w CO re to C I D a a p N I1 0 II' QL D o r Y a) Q o a E CI 15 0 as z I M 0 N y R1 Z F.- 'LC 1.-LO t m 1 lii o c I N- m p y N • E E z l co 0 C7 V)r. Z Q �• .> a) V N Z U c r c O o a y a) a) <o 13. E -7; 8 0 ° m c8i E I E a 2 < 0 < C j 0 ! U - f- • w\�� � � s9 THE STATE Alaska Oil and Gas �' °fALASK1l Conservation Commission *h - GOVERNOR SEAN PARNELL 333 West Seventh Avenue OFA�F- Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Steve Shultz Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 o 179 Re: Kuparuk River Field, Tarn Oil Pool, 2L-322 Sundry Number: 313-552 Dear Mr. Shultz: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair, Commissioner DATED this dc"-lay of October, 2013. Encl. • 0 �r1 •- • STATE OF ALASKA 9W"=�'7 D E E I E D A OIL AND GAS CONSERVATION COMM& )N UU 51/3 APPLICATION FOR SUNDRY APPROVALS ke OCT 1 7 O 3 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Apra•6 see-- Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well Stimulate r Alter casing r Other: 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r. 210-174-0 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20628-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No fes. 2L-322 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 380052,380054 Kuparuk River Field/Tarn 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): 7473 • 5319 - 2481' ' 2256' • 2481',4630',5500',6500' Casing Length Size MD TVD Burst Collapse CONDUCTOR 103 16 146' 146' SURFACE 2571 10.75 2613' 2358' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none none 4.5 L-80 1826 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) no packer no SSSV 12.Attachments: Description Summary of Proposal • f;E 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development f;., Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/1/2013 Oil r Gas r WDSPL r Suspended F. • 16.Verbal Approval: Date: WINJ r GINJ r WAG E Abandoned r Commission Representative: GSTOR f! SPLUG r 17. I hereby certify that the foregoing is true and correct to th- •-st•f my knowledge. Contact: Steve Shultz @ 263-4297 Email: Steve.Shultz@contractor.cop.com Printed Name Steve Shultz t Title: Drilling Engineer Signature ' Phone:263-4297 Date /67 &./.26.e Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness -3\3- 5-S2 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No Q Subsequent Form Required: // — 4--e)7.f � APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: l/D–2-8— /3 Approved applicationG is v II to 3. months trom the date of approval. Form 10-403(Revised 10/2012) I I H Submit Fond AttrlplicOv _ 1 i3 ���►I I 1o/�14, �,j�M KUP 2L-322 ConocoPhillips f Well Attributes Max Angle&MD TD • Wellbore APWWI Field Name Well Status Incl('') MD(ftKB) Act Btm(ftKB) AlaskaInc. ' 501032062800 TARN PARTICIPATING AREA EXPEND 81.32 7,358.27 7,473.0 """" Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ' SSSV:NONE Last WO: 5/32011 WeII Contip-2L-322.7/18/2012 2:2016 PM Schematic-Actual - --_ -Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WELL REVIEW osborl 7/182012 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WE..String... String Top Thrd CONDUCTOR 16 15.250 43.0 146.0 146.0 62.50 H40 Welded 7.,,,,,,...",..,,,ps � Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 10 3/4 9.950 42.2 2,613.3 2,357.5 45.50 L-80 BTC HANGER,37 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(WD)...String WE..String... String Top Thrd OPEN HOLE 10 2,712.0 7,473.0 11 Tubing Strings —ng Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd TUBING Kill String 4 1/2 3.980 37.0 1,826.0 1,733.1 12.60 L-80 IBTM Completion Details Top Depth (WD) Top Inc! Nomi... Top(ftKB) (ftKB) ri Item Description Comment ID(in) • 2, 37.0 37. 0 -0.01 HANGER Tbg Hanger&Pup 3.980 „r Cement Squeezes Top Depth Btm Depth (WD) (TVD) Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Description Start Date Comment r 2,481.0 2,900.0 2,254.7 2,580.4 Squeeze Cement 5/1/2011 Blow down Top drive&lines.Make up Head pin and with Retainer cement lines.RU Schlumberger.Pick up out of ,... retainer.Circulate at 5 BPM-260 PSI.Observed 900 wt units of gas.Sting into retainer.Establish injection rate at 3 BPM-650 PSI.Turn over to Schlumberger. Ct Pump 5 BBLS of 12.5 PPG Mud Push.Pressure test lines to 3000 PSI.Pump 45 BBLS of cement,and 4 BBLS of H2O.With Rig Displace with 36 BBLS of 11.8 PPG mud.Pull stinger and pump to leave 5 BBLS of cement above reatiner.POOH to 2315'MD. a;' Circulate bottoms up at 6 BPM-230 PSI,observing ;; no cement returns.Mix&pump 15 BBLS dry job.CIP @ 1640 HRS CONDUCTOR, ! 4,630.0 5,630.0 3,962.1 4,725.1 Second Plug 4/30/2011 With rig-Pump 50 BBL LCM pill,and 20 BBLS of 43-14611.9 mud.Turn over to Schlumberger&continue with ur,+.'' 15 BBLS of 12.5 Mud Push II.Test lines to 3000 PSI. ,: Good test.Pump 95 BBLS of 15.8 PPG cement,and 4 BBLS of H2O.Drop Drill pipe wiper ball.With rig, displace cement with 70 BBLS,Observed 47 BBLS pumped before catching cement.Observed 1 for 1 returns during job.Max Gas observed=3800 units. CIP at 20:45 HRS. POOH slow from 5630'-4250'MD,observing no flow on annulus from well,allowing cement to fall out of DP until annulus staying static.UP WT-165K,SO WT-140K. 5,500.0 6,225.0 4,636.3 5,046.2 First Plug 4/29/2011 -With rig-Pump 50 BBL LCM pill,and 20 BBLS of 11.9 mud.Turn over to Schlumberger&continue with 15 BBLS of 12.5 Mud Push II.Test lines to 3500 PSI. Good test.Pump 89 BBLS of 16 PPG cement,and 2 BBLS of H2O.Drop Drill pipe wiper ball.With rig, displace cement with 75 BBLS,keeping 1400 ft of cement in DP.Observed 47 BBLS pumped before cathing cement.Observed only 33 BBLS of returns during job.Max Gas observed=1250 units.CIP at 22:15 HRS. 6,500.0 7,473.0 5,139.6 Cement BHA in 4/29/2011 Line up,and batch mix.Pump 15 BBLS of 12.5 PPG Place Mud Push II.Test lines to 3500 PSI.Continue pump 66.71 BBLS of 15.9 PPG GasBlok cement chase with 2 EELS H2O.Continue displace with 11.9 PPG Mud SURFACE,_ . for 115 BBLS,cementing drill string in place at 7473' 42-2,613 MD.Observed only 37 BBL returns during job.Max gas-985 units.Shut Down.CIP @ 0130 HRS. RD € Lines.Stab Valve. £mi Notes:General&Safety End Date Annotation • -- 5/4/2011 NOTE:WELL SUSPENDED DUE TO EXCESSIVE GAS Squeeze„ Cement with Retainer,2,481 ',ii Ilit 111 3 Second Plug. /1$ ' 4,630 First Plug, 5,500 Cement BHA \ m .... Place,6,500 OPEN HOLE, 2,712-7,473 TD,7,473 .. Planning for 2L-322 This well was drilled in 2011 and experienced difficulties when the Bermuda Formation was reached. High gas concentrations were observed and once weighing the mud up mud losses were also an issue. The well exhibited indications of breathing and as a result of continually weighting up, the well reached its limit for a 11.8 ppg mud weight. It was deemed prudent to plug back for a temporary abandonment and drill the well at a later date. The well was plugged with four different cement plugs(see attached) and a cement retainer was placed in the 10 3/"surface casing and cement squeeze below this to isolate the 10 3/" shoe. Once the last plug was pumped a kill string of 4 %2" tubing was run in the well and hung off at 1,733'. The well was then freeze protected with diesel and secured. This was all conveyed to the AOGCC with a 10-403 dated April 28, 2011. Now the well is to be re-entered and cleaned out for drilling to the original targets. The intermediate 7 5/8" casing is to be top set above the higher pressured Bermuda prior to drilling the horizontal section. A 10-401 "Permit to Drill"Amill be issued prior to any drilling operations for this well. Ferguson, Victoria L (DOA) From: Schwartz,Guy L(DOA) Sent: Wednesday, October 16,2013 9:04 AM To: Shultz, Steve(Orbis Engineering,Inc.) Cc: Ferguson,Victoria L(DOA) Subject: RE:2L-322 (Tarn Well) Steve, Nope still need a new sundry to reenter the suspended well and P &A the well. Even though no work is done besides kicking off the existing cement plug we need a sundry. You would check" re-enter suspended well" and " plug for redrill". Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Shultz, Steve(Orbis Engineering, Inc.) [mailto:Steve.ShultzCacontractor.conocophillips.com] Sent: Wednesday, October 16, 2013 8:47 AM To: Schwartz, Guy L(DOA) Subject: RE: 2L-322(Tarn Well) Guy, This is the 10-403 we submitted in 2011. Will this suffice and all I need now is a new PTD? Thanks, Steve From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@)alaska.gov] Sent:Tuesday, October 15, 2013 3:32 PM To: Shultz, Steve (Orbis Engineering, Inc.) Cc: Ferguson, Victoria L(DOA) Subject: [EXTERNAL]RE: 2L-322 (Tarn Well) Steve, The well is suspended right now. The PTD has most likely expired for the well since it is well over 2 yrs old. I think the cleanest way to approach this well is to start a new PTD and call the well 2L-322A. You would have to submit paper work to abandon the original well... ( a 10-403 with "plug for redrill" ...) and then submit a new 10-401 with the well plan for 2L-322A. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office 1 From: Shultz, Steve (Orbis Engineering, Inc.) [mailto:Steve.Shultz@contractor.conocophillins.com] Sent: Tuesday, October 15, 2013 8:26 AM To: Schwartz, Guy L(DOA) Subject: 2L-322 (Tam Well) Guy, I have a question. We attempted to drill 2L-322(Tarn)in 2011 and had problems with gas and mud loses after we drilled into the Bermuda Formation.It was decided to temporarily plug back the well and drill it at a later date.We ended up plugging back with several plugs to the 10 W surface casing and set a retainer in the shoe and squeezed away cement. Now we would like to drill this in well February using that original surface casing. Can we use the original numbering of the well(21-322)or does AOGCC require some other numbering to be applied? Thanks, Steve 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/07/11 Inspector: Lou Grimaldi Operator: Conoco Phillips Alaska Inc. Well Name: KRU 2L-322 - Oper.Rep: Martin Walters PTD No.: 210-174 Oper.Phone: 659-7043 Location Verified? Yes Oper.Email: N1787@Conocophillips.com If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 05/03/11 Date AOGCC Notified: 09/05/11 Sundry No.: Well Completion Rpt • Type of Inspection: Initial Wellbore Diagram Avail.? yes , Well Pressures(psi): Tubing N/A Photos Taken? yes IA N/A - OA -0.7 Condition of Wellhead: No wellhouse,Weathered(OK),valves cycled and OK,Gauges(OK),No oil in cellar.Evidence of red dye from surface cement lead spacer in cellar and red mud in 4"conductor port.Also gas bubbling through mud in 4"conductor port.Questionable surf casing cement job. ✓ Condition of Surrounding Surface Established pad in good shape.All wells getting new cellar boxes built. Location: Follow Up Actions Address bubbling in conductor. Needed: Location verified by pad map. Attachments: Photos(2) REVIEWED BY: r Insp.Supry J 41(2 Comm PLB 09/2010 2011-0907_Suspend_KRU_2L-322_Ig F It. tr k :- ticotl, 4..0-4*e-c: . , ''','-'4. ---*")...:".* A 14 .),1 �(j .y .l � � 5 t r.. o 4.7s ➢ k. I �" esi N '4 . € 1 :1 - aha+ g� " 'i 4,• 1 a -T c‘ C7 0 _ J o O c. 1 400,0:I':1 44;I''"''''I w ami •• ✓ . • 0.0• U , ��� � g r � °¢ � _ I V S y �▪ N1 0 O Cm .-. N ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 September 10, 2011 RECEIVE SEP 14 2011 Commissioner Dan Seamount Alaska Oil&Gas Cons.Commission Alaska Oil and Gas Conservation Commission Anchorage 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Re: Suspended Well Inspection 10-404 Sundry Kuparuk River Unit 2L-322 (PTD 210-174-0) Dear Commissioner Seamount: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 2L- 322 (PTD 210-174-0). The following documents are attached: - 10-404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs Please call MJ Loveland or me at 659-7043 if you have any questions. Sincerely, flafr77 a)a Martin Walters ConocoPhillips Well Integrity Projects Supervisor Enclosures STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Stimulate rOther Suspended Well Alter CasingPull TubingPerforate New Pool WaiverInspection r r r r lime Extension r Change Approved Program r Operat.Shutdown r Perforate r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r . 210-174-0 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20628-00•- g 00 7.Property Designation(Lease umber):p Y 9 b ) „ 8.Well Name and Number: ADL380052,ADL380054 + 2L-322 9.Field/Pool(s): Kuparuk River Field/Tarn Oil Pool 10.Present Well Condition Summary: Total Depth measured 7473 feet Plugs(measured) None true vertical 5319 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 0 true vertical 0 feet (true vertucal) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 105 16 146 146 SURFACE 2571 10.75 2613 2358 p EGE VED' Perforation depth: Measured depth: NA SEp 1 4 2011 True Vertical Depth: NA Alaska Oil&Gas Cons.Co�11j=sion ' Tubing(size,grade, MD,and TVD) NA Anchorage Packers&SSSV(type,MD,and TVD) NA 11.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA ' 13.Attachments 14.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r— Service r Stratigraphic r 15.Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations X GSTOR r VVINJ r WAG r GINJ r SUSP. ,r, SPLUG r 16.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: NA Contact MJ Loveland/Martin Walters Printed Name Martin Walters Title: Well Integrity Project Supervisor Signature`!/i /i>de / °— Phone:907-659-7043 Date: 09-10-11 RRDMS SEP 14 2011 T•zs 1, ph, Form 10-404 Revised 10/2010 Submit Original Only Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Kuparuk River Unit 2L-322 Field/Pool: Kuparuk River/Tarn Oil Pool Permit#(PTD): 210-174-0 API Number: 50103206280000 Operator: ConocoPhillips Date Suspended: 5/3/2011 Surface Location: Section: 209'FNL,821'FEL,Sec 22 Twsp: T10N Range: R7E UM Nearest active pad or road: KRU DS2L Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good. Gravel work in progress Location cleanup needed: No Pits condition: N/A Surrounding area condition:Good Water/fluids on pad: No Discoloration, Sheens on pad, pits or water: No sheen Samples taken: None Access road condition: Good Photographs taken (#and description): None Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: New wellhead. Clean red dye evident, no cement to surface evident, bubbling in conductor. No tubing or production casing in well Cellar description, condition, fluids: No oil. Padwide cellar box installation in progress Rat Hole: No Wellhouse or protective barriers: Wellhouse removed at time of inspection Well identification sign: Stenciled on wellhead and wellhouse Tubing Pressure(or casing if no tubing): NA Annulus pressures: IA=OA=-7 psi Wellhead Photos taken (#and description): 2 of wellhead and cellar Work Required: Address bubbling in conductor Operator Rep(name and signature): Martin Walters /���X AOGCC Inspector: Lou Grimaldi Other Observers: Carney/Mouser Inspection Date: 9/7/2011 AOGCC Notice Date: 9/1/2011 Time of arrival: 12:30 Time of Departure: 13:00 Site access method: Highway vehicle �,, KUP 2L-322 Cofocophiii s i.- Well Attributes Max Angle&MD TD Alaska.hc. Wellbore API/UWI Field Name Well Status Incl(') MD(ftK8) Act Btm(ftKB) ua,omPewups 501032062800 TARN PARTICIPATING AREA SUSP 81.32 7,358.27 7,473.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:NONE Last WO: 5/3/2011 Well Conae -2LJ22 5I1120114'.49'51 PM Schematic•Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date i Last Tag: _ Rev Reason:NEW WELL SUSPENDED Imosbor 5/13/2011 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd CONDUCTOR 16 15.250 41.0 146.0 146.0 62.50 H-40 Welded 1 "- r Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt..String... String Top Thrd HANGER.37 SURFACE 103/4 9.950 42.2 2,613.3 2,357.5 45.50 L-80 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd OPEN HOLE 97/8 2,613.0 7,374.0 5,303.6 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd TUBING Kill String 4 1/2 3.980 37.0 1,826.0 1,733.1 12.60 L-80 IBTM • • Completion Details Top Depth (ND) Top Incl Noml... Top(Rice) MB) (0 Item Description Comment ID(in) 37.0 37.0 -0.01 HANGER Tbg Hanger&Pup 3.980 I Cement Squeezes Top Depth Btm Depth (ND) (ND) Top(ftKB) Btm(ftKB) (ftKB) MO) Description Start Date Comment 2,481.0 2,900.0 2,254.7 2,580.4 Squeeze Cement 5/1/2011 Blow down Top drive 8 lines.Make up Head pin and with Retainer cement lines.RU Schlumberger.Pick up out of retainer.Circulate at 5 BPM-260 PSI.Observed 900 units of gas.Sting into retainer.Establish injection rate at 3 BPM-650 PSI.Tum over to Schlumberger. Pump 5 BBLS of 12.5 PPG Mud Push.Pressure test lines to 3000 PSI.Pump 45 BBLS of cement,and 4 BBLS of H2O.With Rig Displace with 36 BBLS of 11.8 PPG mud.Pull stinger and pump to leave 5 BBLS of cement above reatiner.POOH to 2315'MD. Circulate bottoms up at 6 BPM-230 PSI,observing no cement returns.Mix&pump 15 BBLS dry job.CIP @ 1640 HRS CONDUCTOR, 41-146 4,630.0 5,630.0 3,962.1 4,725.1 Second Plug 4/30/2011 Wirig- BLC 11.9th mud.Turn Pump over50 toBL SchMlumbergerpill,and 20 8 continueBBLSof with 15 BBLS of 12.5 Mud Push II.Test lines to 3000 PSI. Good test.Pump 95 BBLS of 15.8 PPG cement,and 4 BBLS of H20.Drop Drill pipe wiper ball.With rig, displace cement with 70 BBLS,Observed 47 BBLS pumped before catching cement.Observed 1 for 1 returns during job.Max Gas observed=3800 units. CIP at 20:45 HRS. POOH slow from 5630'-4250'MD,observing no flow on annulus from well,allowing cement to fall out of DP until annulus staying static.UP WT-165K,SO WT-140K. 5,500.0 6,225.0 4,636.3 5,046.2 First Plug 4/29/2011 With rig-Pump 50 BBL LCM pill,and 20 BBLS of 11.9 mud.Turn over to Schlumberger 8 continue with 15 BBLS of 12.5 Mud Push II.Test lines to 3500 PSI. Good test.Pump 89 BBLS of 16 PPG cement,and 2 I BBLS of H2O.Drop Drill pipe wiper ball.With rig, displace cement with 75 BBLS,keeping 1400 ft of cement in DP.Observed 47 BBLS pumped before cathing cement.Observed only 33 BBLS of returns during job.Max Gas observed=1250 units.CIP at 22:15 HRS. • 6,500.0 7,473.0 5,139.6 Cement BHA in 4/29/2011 Line up,and batch mix.Pump 15 BBLS of 12.5 PPG Place Mud Push II.Test lines to 3500 PSI.Continue pump 66.71 BBLS of 15.9 PPG GasBlok cement chase with 2 BBLS H20.Continue displace with 11.9 PPG Mud for 115 BBLS,cementing drill string in place at 7473' suRFAE. MD.Observed only 37 BBL returns during job.Max 42-2,13_, gas-985 units.Shut Down.CIP @ 0130 HRS. RD Lines.Stab Valve. Squeeze Notes:General&Safety Cement with End Date Annotation Retainer,2,481 5/4/2011 NOTE:WELL SUSPENDED DUE TO EXCESSIVE GAS Second 4,630 Plug, First Plug, 5,500 OPEN HOLE, 2,613-7,374 Cement BHA In Place,6,500 TD,7,473 N - 0 I- 0 0 Z �CO w C U D O LI z .- C-) 05c O 0 o u etQ OU Z w zz G w Q< Z a Z 7c, w U d z JWCC U 0 0 c,U o U -, p � L O J W< W z w2 2 H F < 2 ¢ c) ce J . . o¢ m z < o = I—" D SNS w w Ua a w a m X >< L W W C� ,-0a ct ta• - o Ja( ® O O W _ lid J F— o o • V o o V- • • o -uo• •l� M ti)W WN o U o� u o X W •�• S m N O C • Q CV N m d ~ o u u N ao e- u g a' ..... Q NLIN o.$ VI ti 'LIJI o la, l-1 n s a v 1° J v la MC O • 'z o 30f \ ♦a a • s 30.3we 301 o •••\ GX 305 LI03 306 O s 307 N Z \ C.) \ �£j 309 a 5 310 \ 0 r �2 311 0 cu W tx Q 312 i c �.�, 373 z S 9 315113 Q r § iiw a DL mki. 2 321 \�\ it ¢ ce Z Z a 322 \ W a s a rt 3 • 323 z w o a = `\ a o v1 vai a IU11 j oY. cn z® 325 a a o 0 oz ,, z m Q O•:; 328 D `,' o �" F u < F z °"5 ^sem 327 o z . N y w o O 328 uUi m vl cn a 2 ce a O G C 329 \ ' v� v o w m rz R O OX JJD V) \ U ,GB N ` O O 7 O 9-_ _ ID s < z o U= < I ww 0 u0 0 \`♦ U� w < v E a\ N \ rS < Z2 z ;< 3r O L 9:33 U z v0 0 1;1 Z o o z v CA '45 \\\\\\\\\\\\\ w z oo z o a •O o U w a® IA z \ zI 1 1 1 I cn \ 1, () C 121 0 i 0 a a%U O cm � a =z 1 • 2L-322 (PTD# 210-174-0) , © ConocoPhillips Alaska, Inc. ( This photo is copyrighted by ConocoPhillips Alaska, Inc. f- and cannot be released or published without express written consent of '`' '" ConocoPhillips Alaska f 1 it,..-7,- -- oliv p it4'i ,16,, E a ' fl'aI•i lift) t ,,,,,, r i t 4. i 04,111.1r ( 1 * k , 0 k . 4161.4. .....Q.d..4,,,—4' 1111 V Ilik a 4 r , , A J * * * i, "4.;0 4.i. , *.4". , , ,,- ..4‘..j.1 '1.•,,,;'''''' ..... 4 '14 1 . d 2L-322 (PTD# 210-174-0) ' © ConocoPhillips Alaska, Inc. This photo is copyrighted by ConocoPhillips Alaska, Inc. --,toi,of,Fk-- and cannot be released or lz published without express Ili 40 written consent of ConocoPhillips Alaska WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 5, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Drill Collar Cutting Record: 2L-322 Run Date: 4/29/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2L-322 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20628-00 f C,/ t l PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: X l j Signed: I/ad/4i lirPage 1 of 2 Schwartz, Guy L (DOA) From: Nugent, David (Swift Technical Services LLC) [David.Nugent@contractor.conocophillips.com] Sent: Tuesday, June 28, 2011 8:55 AM To: Schwartz, Guy L(DOA) Subject: RE: 2L-322 (PTD 210-174) It was an interesting test. I think we should have stopped the LOT when it first broke off the straight line (I thought that was around 1050 psi - 18 ppg), but for whatever reason, they continued the test. Really high leak off for such a shallow depth. We did not repeat the test since it was holding around 12.7 ppg. David From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, June 28, 2011 8:35 AM To: Nugent, David (Swift Technical Services LLC) Subject: RE: 2L-322 (PTD 210-174) Looked at the LOT... it is interesting. Looks to me like the real leak off is at 17.6 ppg. ( chart showed 20.2 ppg) But it sure breaks hard when the formation fractures . Did you happen to repeat the LOT?? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Nugent, David (Swift Technical Services LLC) [mailto:David.Nugent@contractor.conocophillips.com] Sent: Monday,June 27, 2011 3:04 PM To: Schwartz, Guy L (DOA) Subject: RE: 2L-322 (PTD 210-174) Guy, I made a pdf of the surface LOT results. Is that what you needed? As far as when we will get back to redrilling this well - I don't think anyone here has an idea at this time. David From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday,June 20, 2011 11:27 AM To: Nugent, David (Swift Technical Services LLC) Subject: 2L-322 (PTD 210-174) David, Can you provide the LOT results for the surface casing? They were not included in the 407 report( daily drilling Page 2 of 2 log)for some reason. Any thoughts or updates as to when you will get back to drilling this target?? Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433(cell) B PRESSURE XI 9' Z N N W W �� N (Q d 8 X N -I o o B N m0 n ppm cn CD �? o 0 0 0 o 0 o g q „z, , H , N m a C CD • 3 7,- _ 7 , I I o 1 . 0 nNcs N ''O -wN C Oa- CD 0�(Q0 iiii n -1 ai N �. 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CA) CO C.) C.) A ? �. _ CT CT 01 CT CT CT CT CT CT 01 01 CT CT 01 CT CT CT CT V CO 0 -. _.'. 0 0 0 0 0 0 0 0 0 0 Cl 0 0 0 0 0 0 0 0 0 0 0 4 • 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 a . lb.Well Class: 20AAC 25.105 20AAC 25.110 Development D • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number ConocoPhillips Alaska, Inc. orAband.: May 3,2011 . 210-174/311-149 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 April 11,2011 50-103-20628-00 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 209'FNL,821'FEL,Sec.22,T1ON, R7E,UM April 19,2011 2L-322 . Top of Productive Horizon: 8.KB(ft above MSL): 40'RKB 15.Field/Pool(s): 1572'FSL, 1479'FEL,Sec.22,T1ON,R7E,UM GL(ft above MSL): 114.8'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+ND): 720'FSL, 1264'FEL,Sec.22,T1ON, R7E,UM 2481'MD/2256'TVD Tarn Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x-460829 • y- 5927638 • Zone-4 ` 7473'MD/5319'TVD - ADL 380052,380054 TPI: x-460159 y- 5924142 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-460371 y- 5923289 Zone-4 none 4600,4602 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) 1415'MD/1383'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 not applicable 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" 164# B-35 41' 146' 41' 146' 24" Driven 10.75" 45.5# L-80 42' 2613' ! 42' 2358' 13.5" 970 sx AS LiteCrete,395 sx LiteCrete 24.Open to production or injection? Yes ❑ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MDITVD) 4.5"kill string 1826' none none iOMPL t 6. ACID,FRACTURE,CEMENT SQUEEZE,ETC. ,j ; s DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED Y • plug#1:6500'-7473' .: f ;�t 315 sx Class G 74 ' r' plug#2:5500'-6225' 427 sx Class G plug#3:4630'5630' 456 sx Class G retainer:2481'-2900' 218 sx Class G 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) not applicable plugged 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 0 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. RECEIVED NONE lUN 0 3 2-011 RBDMS JUN 0 31011 Maska 31iGe ier s} �issian Form 10-407 Revised 12/2009 CONTINUED ON REVERSE n� yrO�� Submit original f only 'T? -k( ...v�, ?.8. GEOLOGIC MARKERS(List all formations and markers er, ,tered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 2 No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1415' 1383' needed,and submit detailed test information per 20 AAC 25.071. Top Bermuda 6580'MD 5160' Base Bermuda 7089'MD 5258' N/A Formation at total depth: Bermuda 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Nugent @ 263-4228 Printed Name G. L.Alvord Title: Alaska Drilling Manager Signature /4£ O- Phone 265-6120 Date 6(2(2-4,1 I Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 KUP 2L-322 ConocoPhillipsWell AttributesMax Annle&MD TD - - Alaska.i, P' *egg wellbore APW WI Freta Name well status Incl(•) ND(ftKB) Act Bbn(ftKB) rkr><r�, cr • 501032062800 TARN PARTICIPATING AREA SUSP 81.32 7,358.27 7,473.0 Comment H2S(ppm) Date Annotation 'End Date KBGrd(ft) Rig Release Date SSSV:NONE _ cast WO: 5/3/2011 _Well Configt-2L-322,013/20114:4951 PM _ --- -----_..— _: Schema.-Actual "- Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason: NEW WELL SUSPENDED Imosbor 5/13/2011 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(ND)...String Wt...String...String Top Thrd -- ----- CONDUCTOR 16 15.250 41.0 146.0 146.0 62.50 H-40Welded. Casing Description String 0... String ID...Top(ftlCB) Set Depth(1...Set Depth(71/D)..String W/ String String Top Thrd HANDER.37 SURFACE 10 3/4 9.950 42.2 2,6113 2,357.5 45.50 L-80 BTC Casing Description String 0... Sting ID Top(HOB) Set Depth(L.Set Depth(TVD)...String Wt...String...String Top Thrd OPEN HOLE 9 7/8 2,613.0 7,374 0 5,303 6 Tubing Strings Tubing Description String 0... String ID...Top(HKB) Set Depth(i...Set Depth(TVD)...String Wt String... Siring Top Thrd — <4 TUBING Kill Strang 41/2 3.980 37.0 I 1,826.0 I 1,733-1 12.60 L-70 IBTM Completion Details Top Depth (TVD) Top Incl Nomi... Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 37.0 37.0 -0.01 HANGER TbgHanger&Pup 3.980 I Cement Squeezes Top Depth Btm Depth (TVD) (TVO) Top(ftKB) Btm(ftKB) (8KB) (8KB) Description Start Data Comment 2,481.0 2,900.0 2,254.7 2,580.4 Squeeze Cement 5/1/2011 Blow down Top drive&lines.Make up Head pin and with Retainer cement lines.RU Schlumberger.Pick up out of retainer.Circulate at 5 BPM-260 PSI.Observed 900 units of gas.Sting into retainer.Establish injection rate at 3 BPM-650 PSI.Turn over to Schlumberger. Pump 5 BBLS of 12.5 PPG Mud Push.Pressure test lines to 3000 PSI.Pump 45 BBLS of cement,and 4 BBLS of H2O.With Rig Displace with 36 BBLS of 11.8 PPG mud.Pull stinger and pump to leave 5 BBLS of cement above reatiner.POOH to 2315'MD. Circulate bottoms up at 6 BPM-230 PSI,observing no cement returns.Mix&pump 15 BBLS dry job.CIP 1640 HRS CONDUCTOR, 41-146 a 4,630.0 5,630.0 3,962.1 4,725.1 Second Plug 4/30/2011 With rig-Pump 50 BBL LCM pill,and 20 BBLS of 11.9 mud.Tum over to Schlumberger&continue with 15 BBLS of 12.5 Mud Push II.Test lines to 3000 PSI. Good test.Pump 95 BBLS of 15.8 PPG cement,and 4 BBLS of H2O.Drop Drill pipe wiper ball.With rig, 1'ZG r displace cement with 70 BBLS,Observed 47 BBLS pumped before catching cement.Observed 1 for 1 returns during job.Max Gas observed=3800 units. CIP at 20:45 HRS. POOH slow from 5630'-4250'MD,observing no flow on annulus from well,allowing cement to fall out of DP until annulus staying static.UP WT-165K,SO WT-140K. 5,500.0 6,225.0 4,636.3 5,046.2 First Plug 4/29/2011 With rig-Pump 50 BBL LCM pill,and 20 BBLS of 11.9 mud.Turn over to Schlumberger&continue with 15 BBLS of 12.5 Mud Push II.Test lines to 3500 PSI. Good test.Pump 89 BBLS of 16 PPG cement,and 2 BBLS of H2O.Drop Drill pipe wiper ball.With rig, displace cement with 75 BBLS,keeping 1400 ft of cement in DP.Observed 47 BBLS pumped before cathing cement.Observed only 33 BBLS of returns during job.Max Gas observed=1250 units.CIP at 22:15 HRS. 6,500.0 7,473.0 5,139.6 Cement BHA in 4/29/2011 Line up,and batch mix.Pump 15 BBLS of 12.5 PPG Place Mud Push II.Test lines to 3500 PSI.Continue pump 66.71 BBLS of 15.9 PPG GasBlok cement chase with 2 BBLS H2O.Continue displace with 11.9 PPG Mud for 115 BBLS,cementing drill string in place at 7473' SURFACE, MD.Observed only 37 BBL returns during job.Max 42-2,613 gas-985 units.Shut Down.CIP @ 0130 HRS. RD Lines.Stab Valve. Notes:General Squeeze &Safety Cement with End Date Annotation • Retainer,2,481 5l4/2011 NO I E WELL SUSPENDED DUE TO EXCESSIVE GAS Second Plug, 4,630 First Plug, 5,500 OPEN HOLE, V) 2,613-7,374 dV\\\\ Cement BHA in Pince,6,500 TD,7,473 0 I h M S f I 1 4 P 0 u I 4 UI ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2L Pad 12L-322PB1 I1501032062870 u % elf. k fl M Sperry Drilling g l'sa ps Definitive Survey Report 4 g. 1 04 May, 2011 gray UI U e v�, I 4 M k6 k it 4 . HALLIBURTON J Sperry Drilling M i:e ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-322(North) Project: Kuparuk River Unit TVD Reference: Rig:2L-322 @ 154.80ft(D15(40.05+114.80)) Site: Kuparuk 2L Pad MD Reference: Rig:2L-322 @ 154.80ft(D15(40.05+114.80)) Well: 2L-322(North) North Reference: True Wellbore: 2L-322PB1 Survey Calculation Method: Minimum Curvature Design: 2L-322PB1 Database: CPAI EDM Production Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2L-322(North) Well Position +N/-S 0.00 ft Northing: 5,927,637.77 ft Latitude: 70°12'47.695 N +EI-W 0.00 ft Easting: 460,829.38 ft Longitude: 150°18'57.255 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 114.80ft Wellbore 2L-322PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2010 4/20/2011 20.85 80.75 57,601 Design 2L-322PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 40.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction ` 4 z (ft) (ft) (ft) (0) ,; _k„ ,. - 40.00 0.00 0.00 177.38 Survey Program Date i' From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 100.00 1,005.00 2L-322 Gyro(R100)(2L-322PB1) CB-GYRO-SS Camera based gyro single shot 4/11/2011 12:C 1,052.23 2,571.43 2L-322 MWD(R100)(2L-322PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/12/2011 12:C 2,619.19 7,358.26 2L-322 MWD(R200)(2L-322PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/16/2011 12:C Survey 4# , rys Map Map Vertical D Inc Azi TVD' TVDSS " +N/-S +E/-W Northing Easting DLS Section (ft) (0) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 40.00 0.00 0.00 40.00 -114.80 0.00 0.00 5,927,637.77 460,829.38 0.00 0.00 UNDEFINED 100.00 0.14 43.59 100.00 -54.80 0.05 0.05 5,927,637.83 460,829.43 0.23 -0.05 CB-GYRO-SS(1) 165.00 0.26 31.97 165.00 10.20 0.24 0.18 5,927,638.01 460,829.56 0.19 -0.23 CB-GYRO-SS(1) 254.00 0.90 144.93 254.00 99.20 -0.17 0.69 5,927,637.61 460,830.07 1.16 0.20 CB-GYRO-SS(1) 346.00 2.30 165.91 345.96 191.16 -2.55 1.56 5,927,635.22 460,830.92 1.62 2.62 CB-GYRO-SS(1) 435.00 2.99 170.63 434.86 280.06 -6.57 2.37 5,927,631.19 460,831.71 0.81 6.67 CB-GYRO-SS(1) 530.00 3.59 167.65 529.71 374.91 -11.92 3.41 5,927,625.84 460,832.73 0.66 12.06 CB-GYRO-SS(1) 625.00 4.64 166.22 624.46 469.66 -18.56 4.96 5,927,619.19 460,834.24 1.11 18.76 CB-GYRO-SS(1) 721.00 6.42 166.79 720.01 565.21 -27.55 7.11 5,927,610.19 460,836.35 1.86 27.85 CB-GYRO-SS(1) 815.00 8.26 174.49 813.24 658.44 -39.39 8.96 5,927,598.34 460,838.14 2.22 39.76 CB-GYRO-SS(1) 910.00 11.33 183.95 906.85 752.05 -55.50 8.97 5,927,582.23 460,838.06 3.64 55.85 CB-GYRO-SS(1) 1,005.00 14.41 193.77 999.46 844.66 -76.30 5.52 5,927,561.46 460,834.50 3.97 76.47 CB-GYRO-SS(1) 5/4/2011 2:46:54PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-322(North) Project: Kuparuk River Unit TVD Reference: Rig:2L-322 @ 154.8Oft(D15(40.05+114.80)) Site: Kuparuk 2L Pad MD Reference: Rig:2L-322 @ 154.8 Oft(D15(40.05+114.80)) Well: 2L-322(North) North Reference: True Wellbore: 2L-322PB1 Survey Calculation Method: Minimum Curvature Design: 2L-322PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (0) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,052.23 15.71 192.60 1,045.07 890.27 -88.25 2.72 5,927,549.52 460,831.64 2.83 88.28 MWD+IFR-AK-CAZ-SC(2) 1,146.38 17.39 195.56 1,135.32 980.52 -114.24 -3.83 5,927,523.56 460,824.95 2.00 113.95 MWD+IFR-AK-CAZ-SC(2) 1,242.97 20.89 193.44 1,226.55 1,071.75 -144.91 -11.71 5,927,492.94 460,816.92 3.69 144.22 MWD+IFR-AK-CAZ-SC(2) 1,332.61 23.80 196.25 1,309.46 1,154.66 -177.82 -20.49 5,927,460.08 460,807.97 3.46 176.70 MWD+IFR-AK-CAZ-SC(2) 1,426.54 25.91 194.57 1,394.68 1,239.88 -215.88 -30.96 5,927,422.07 460,797.31 2.37 214.24 MWD+IFR-AK-CAZ-SC(2) 1,526.06 29.23 194.49 1,482.89 1,328.09 -260.47 -42.51 5,927,377.56 460,785.53 3.34 258.25 MWD+IFR-AK-CAZ-SC(2) 1,623.24 32.24 195.82 1,566.41 1,411.61 -308.39 -55.51 5,927,329.71 460,772.27 3.18 305.53 MWD+IFR-AK-CAZ-SC(2) 1,719.13 35.34 194.17 1,646.09 1,491.29 -359.90 -69.28 5,927,278.27 460,758.24 3.37 356.36 MWD+IFR-AK-CAZ-SC(2) 1,812.38 35.56 194.98 1,722.06 1,567.26 -412.24 -82.89 5,927,226.01 460,744.36 0.56 408.02 MWD+IFR-AK-CAZ-SC(2) 1,906.64 36.34 197.62 1,798.37 1,643.57 -465.34 -98.43 5,927,172.99 460,728.55 1.84 460.36 MWD+I FR-AK-CAZ-SC(2) 2,003.99 36.52 197.81 1,876.69 1,721.89 -520.41 -116.02 5,927,118.02 460,710.67 0.22 514.56 MWD+IFR-AK-CAZ-SC(2) 2,098.42 3729 196.42 1,952.20 1,797.40 -574.60 -132.70 5,927,063.92 460,693.71 1.20 567.94 MWD+IFR-AK-CAZ-SC(2) 2,187.04 37.26 196.84 2,022.72 1,867.92 -626.03 -148.06 5,927,012.58 460,678.09 0.29 618.61 MWD+IFR-AK-CAZ-SC(2) 2,285.86 37.60 196.50 2,101.20 1,946.40 -683.57 -165.29 5,926,955.14 460,660.56 0.40 675.30 MWD+IFR-AK-CAZ-SC(2) 2,377.64 38.15 196.60 2,173.64 2,018.84 -737.58 -181.34 5,926,901.22 460,644.23 0.60 728.52 MWD+IFR-AK-CAZ-SC(2) 2,473.58 38.70 196.53 2,248.80 2,094.00 -794.73 -198.34 5,926,844.16 460,626.94 0.58 784.83 MWD+IFR-AK-CAZ-SC(2) 2,571.43 39.02 197.16 2,325.00 2,170.20 -853.49 -216.13 5,926,785.50 460,608.84 0.52 842.72 MWD+IFR-AK-CAZ-SC(2) 2,619.19 39.05 197.33 2,362.10 2,207.30 -882.22 -225.05 5,926,756.82 460,599.78 0.23 871.01 MWD+IFR-AK-CAZ-SC(3) 2,715.09 39.13 197.93 2,436.53 2,281.73 -939.84 -243.36 5,926,699.30 460,581.17 0.40 927.74 MWD+I FR-AK-CAZ-SC(3) 2,809.01 39.34 197.57 2,509.28 2,354.48 -996.42 -261.47 5,926,642.82 460,562.77 0.33 983.43 MWD+IFR-AK-CAZ-SC(3) 2,902.49 37.70 197.93 2,582.41 2,427.61 -1,051.87 -279.22 5,926,587.47 460,544.74 1.77 1,038.00 MWD+IFR-AK-CAZ-SC(3) 2,947.73 37.79 197.49 2,618.18 2,463.38 -1,078.25 -287.64 5,926,561.14 460,536.18 0.63 1,063.97 MWD+IFR-AK-CAZ-SC(3) 2,997.03 37.89 197.01 2,657.12 2,502.32 -1,107.13 -296.61 5,926,532.31 460,527.06 0.63 1,092.41 MWD+IFR-AK-CAZ-SC(3) 3,091.12 36.46 197.20 2,732.09 2,577.29 -1,161.47 -313.33 5,926,478.06 460,510.06 1.52 1,145.93 MWD+IFR-AK-CAZ-SC(3) 3,187.35 36.59 198.00 2,809.42 2,654.62 -1,216.06 -330.65 5,926,423.57 460,492.46 0.51 1,199.67 MWD+IFR-AK-CAZ-SC(3) 3,280.81 36.39 198.27 2,884.56 2,729.76 -1,268.88 -347.95 5,926,370.84 460,474.89 0.27 1,251.65 MWD+IFR-AK-CAZ-SC(3) 3,375.54 36.35 198.21 2,960.83 2,806.03 -1,322.23 -365.53 5,926,317.59 460,457.03 0.06 1,304.14 MWD+IFR-AK-CAZ-SC(3) 3,469.71 36.68 198.04 3,036.52 2,881.72 -1,375.48 -382.96 5,926,264.43 460,439.32 0.37 1,356.54 MWD+IFR-AK-CAZ-SC(3) 3,565.55 36.81 198.14 3,113.31 2,958.51 -1,429.99 -400.77 5,926,210.03 460,421.24 0.15 1,410.17 MWD+IFR-AK-CAZ-SC(3) 3,658.22 36.93 198.06 3,187.45 3,032.65 -1,482.84 -418.04 5,926,157.27 460,403.69 0.14 1,462.18 MWD+IFR-AK-CAZ-SC(3) 3,756.04 36.83 197.64 3,265.70 3,110.90 -1,538.72 -436.04 5,926,101.49 460,385.41 0.28 1,517.18 MWD+IFR-AK-CAZ-SC(3) 3,848.71 36.89 197.52 3,339.84 3,185.04 -1,591.71 -452.83 5,926,048.59 460,368.35 0.10 1,569.35 MWD+IFR-AK-CAZ-SC(3) 3,945.11 36.93 197.64 3,416.92 3,262.12 -1,646.90 -470.31 5,925,993.50 460,350.58 0.09 1,623.68 MWD+IFR-AK-CAZ-SC(3) 4,040.33 37.33 195.73 3,492.84 3,338.04 -1,701.95 -486.81 5,925,938.54 460,333.80 1.28 1,677.92 MWD+IFR-AK-CAZ-SC(3) 4,052.93 37.31 195.66 3,502.86 3,348.06 -1,709.31 -488.87 5,925,931.20 460,331.69 0.37 1,685.17 MWD+IFR-AK-CAZ-SC(3) 4,131.52 37.19 195.25 3,565.42 3,410.62 -1,755.16 -501.55 5,925,885.42 460,318.78 0.35 1,730.39 MWD+IFR-AK-CAZ-SC(3) 4,227.69 37.20 195.41 3,642.02 3,487.22 -1,811.23 -516.92 5,925,829.43 460,303.12 0.10 1,785.70 MWD+IFR-AK-CAZ-SC(3) 4,323.39 37.16 195.23 3,718.27 3,563.47 -1,867.00 -532.20 5,925,773.74 460,287.55 0.12 1,840.72 MWD+IFR-AK-CAZ-SC(3) 4,418.52 37.06 195.51 3,794.14 3,639.34 -1,922.35 -547.41 5,925,718.48 460,272.05 0.21 1,895.31 MWD+IFR-AK-CAZ-SC(3) 4,513.61 37.14 195.44 3,869.98 3,715.18 -1,977.63 -562.72 5,925,663.29 460,256.46 0.10 1,949.84 MWD+IFR-AK-CAZ-SC(3) 5/4/2011 2:46:54PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-322(North) Project: Kuparuk River Unit TVD Reference: Rig:2L-322 @ 154.80ft(D15(40.05+114.80)) Site: Kuparuk 2L Pad MD Reference: Rig:2L-322 @ 154.80ft(D15(40.05+114.80)) Well: 2L-322(North) North Reference: True Wellbore: 2L-322PB1 Survey Calculation Method: Minimum Curvature Design: 2L-322PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/100') (ft) Survey Tool Name 4,607.65 37.71 194.88 3,944.66 3,789.86 -2,032.79 -577.66 5,925,608.21 460,241.24 0.71 2,004.26 MWD+IFR-AK-CAZ-SC(3) 4,703.13 37.69 195.57 4,020.21 3,865.41 -2,089.13 -593.00 5,925,551.96 460,225.61 0.44 2,059.84 MWD+IFR-AK-CAZ-SC(3) 4,794.31 38.08 194.95 4,092.17 3,937.37 -2,143.14 -607.73 5,925,498.02 460,210.60 0.60 2,113.12 MWD+IFR-AK-CAZ-SC(3) 4,891.89 38.18 195.03 4,168.93 4,014.13 -2,201.34 -623.31 5,925,439.91 460,194.71 0.11 2,170.55 MWD+IFR-AK-CAZ-SC(3) 4,987.22 38.50 194.58 4,243.70 4,088.90 -2,258.52 -638.42 5,925,382.82 460,179.31 0.45 2,226.97 MWD+IFR-AK-CAZ-SC(3) 5,080.09 38.60 195.69 4,316.33 4,161.53 -2,314.38 -653.54 5,925,327.04 460,163.91 0.75 2,282.09 MWD+IFR-AK-CAZ-SC(3) 5,178.01 38.69 195.55 4,392.81 4,238.01 -2,373.27 -670.00 5,925,268.24 460,147.14 0.13 2,340.17 MWD+IFR-AK-CAZ-SC(3) 5,268.44 38.55 195.70 4,463.46 4,308.66 -2,427.63 -685.20 5,925,213.97 460,131.66 0.19 2,393.77 MWD+IFR-AK-CAZ-SC(3) 5,367.51 41.09 191.51 4,539.56 4,384.76 -2,489.27 -700.06 5,925,152.41 460,116.49 3.73 2,454.67 MWD+IFR-AK-CAZ-SC(3) 5,463.37 43.90 189.86 4,610.24 4,455.44 -2,552.90 -712.04 5,925,088.85 460,104.18 3.15 2,517.68 MWD+IFR-AK-CAZ-SC(3) 5,557.77 47.00 186.81 4,676.46 4,521.66 -2,619.45 -721.74 5,925,022.37 460,094.13 4.01 2,583.72 MWD+IFR-AK-CAZ-SC(3) 5,649.77 48.56 184.10 4,738.29 4,583.49 -2,687.26 -728.19 5,924,954.60 460,087.33 2.76 2,651.16 MWD+IFR-AK-CAZ-SC(3) 5,745.62 50.89 180.24 4,800.26 4,645.46 -2,760.30 -730.92 5,924,881.57 460,084.22 3.92 2,724.01 MWD+IFR-AK-CAZSC(3) 5,837.10 53.05 177.97 4,856.62 4,701.82 -2,832.34 -729.77 5,924,809.54 460,084.99 3.06 2,796.02 MWD+IFR-AK-CAZ-SC(3) 5,935.07 56.62 177.48 4,913.04 4,758.24 -2,912.35 -726.59 5,924,729.52 460,087.77 3.67 2,876.10 MWD+IFR-AK-CAZ-SC(3) 6,029.28 60.80 175.17 4,961.96 4,807.16 -2,992.67 -721.39 5,924,649.18 460,092.54 4.91 2,956.56 MWD+IFR-AK-CAZ-SC(3) 6,120.78 64.37 174.26 5,004.08 4,849.28 -3,073.53 -713.90 5,924,568.29 460,099.61 4.00 3,037.68 MWD+IFR-AK-CAZ-SC(3) 6,212.88 66.60 173.55 5,042.30 4,887.50 -3,156.85 -705.00 5,924,484.94 460,108.08 2.52 3,121.32 MWD+IFR-AK-CAZ-SC(3) 6,308.30 69.14 172.90 5,078.24 4,923.44 -3,244.61 -694.57 5,924,397.13 460,118.06 2.74 3,209.47 MWD+IFR-AK-CAZ-SC(3) 6,407.73 71.21 171.84 5,111.96 4,957.16 -3,337.31 -682.15 5,924,304.37 460,130.00 2.31 3,302.64 MWD+IFR-AK-CAZ-SC(3) 6,498.26 73.93 169.56 5,139.08 4,984.28 -3,422.54 -668.18 5,924,219.09 460,143.52 3.85 3,388.41 MWD+IFR-AK-CAZ-SC(3) 6,589.99 76.73 167.59 5,162.31 5,007.51 -3,509.50 -650.59 5,924,132.04 460,160.65 3.69 3,476.09 MWD+IFR-AK-CAZ-SC(3) 6,598.15 76.98 167.42 5,164.16 5,009.36 -3,517.26 -648.87 5,924,124.27 460,162.33 3.67 3,483.92 MWD+IFR-AK-CAZ-SC(3) 6,692.21 80.04 166.34 5,182.90 5,028.10 -3,607.01 -627.95 5,924,034.42 460,182.79 3.44 3,574.54 MWD+IFR-AK-CAZ-SC(3) 6,787.21 79.82 166.67 5,199.51 5,044.71 -3,697.97 -606.12 5,923,943.36 460,204.14 0.41 3,666.40 MWD+IFR-AK-CAZ-SC(3) 6,881.53 78.83 167.58 5,216.98 5,062.18 -3,788.32 -585.47 5,923,852.91 460,224.33 1.41 3,757.60 MWD+IFR-AK-CAZ-SC(3) 6,945.86 78.76 167.12 5,229.48 5,074.68 -3,849.90 -571.65 5,923,791.27 460,237.82 0.71 3,819.74 MWD+IFR-AK-CAZ-SC(3) 6,976.54 78.72 166.90 5,235.47 5,080.67 -3,879.21 -564.88 5,923,761.92 460,244.43 0.72 3,849.34 MWD+IFR-AK-CAZ-SC(3) 7,073.10 78.10 166.21 5,254.87 5,100.07 -3,971.21 -542.89 5,923,669.82 460,265.95 0.95 3,942.24 MWD+IFR-AK-CAZ-SC(3) 7,165.99 80.94 163.67 5,271.77 5,116.97 -4,059.40 -519.15 5,923,581.52 460,289.22 4.07 4,031.42 MWD+IFR-AK-CAZ-SC(3) 7,262.27 81.27 163.86 5,286.66 5,131.86 -4,150.73 -492.56 5,923,490.07 460,315.34 0.39 4,123.87 MWD+IFR-AK-CAZ-SC(3) 7,358.26 81.32 164.29 5,301.19 5,146.39 -4,241.97 -466.53 5,923,398.70 460,340.90 0.45 4,216.21 MWD+IFR-AK-CAZ-SC(3) • 7,473.00 81.32 164.29 5,318.50 , 5,163.70 -4,351.16 -435.81 5,923,289.36 460,371.04 0.00 4,326.69 PROJECTED to TD 5/412011 2:46:54PM Page 4 COMPASS 2003.16 Build 69 3 0 4, or St kti 41 ConocoPhillips(Alaska) Inc. O 0, Kuparuk River Unit q Kuparuk 2L Pad x 2L-322 I 501032062800 Pi NI A 1 N al Sperry Drilling 0 A Definitive Survey Report 11 41 0 4 04 12 May, 2011 • 0 • a mi61P Ix o A at • rte, • tb • r 111 11 HALLIBURTON 1• 1 Sperry Drilling f-4 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-322(North) Project: Kuparuk River Unit TVD Reference: Rig:2L-322 @ 154.80ft(D15(40.05+114.80)) Site: Kuparuk 2L Pad MD Reference: Rig:2L-322 @ 154.80ft(D15(40.05+114.80)) Well: 2L-322(North) North Reference: True Wellbore 2L-322 Survey Calculation Method Minimum Curvature Design: 2L-322 Database: CPAI EDM Production Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2L-322(North) Well Position +N/-S 0.00 ft Northing: 5,927,637.77 ft Latitude: 70°12'47.695 N +El-W 0.00 ft Easting: 460,829.38 ft Longitude: 150°18'57.255 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 114.80ft Wellbore 2L-322 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 4/20/2011 20.85 80.75 57,601 Design 2L-322 Audit Notes: 'Version: 1.0 Phase: ACTUAL Tie On Depth: 40.00 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (ft) (ft) (ft) (°) 40.00 0.00 0.00 177.38 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 100.00 1,005.00 2L-322 Gyro(R100)(2L-322) CB-GYRO-SS Camera based gyro single shot 4/11/2011 12:C 1,052.23 2,571.43 2L-322 MWD(R100)(2L-322) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/12/2011 12:C 2,619.19 7,358.26 2L-322 MWD(R200)(2L-322) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/16/2011 12:C Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/100') (ft) Survey Tool Name 40.00 0.00 0.00 40.00 -114.80 0.00 0.00 5,927,637.77 460,829.38 0.00 0.00 UNDEFINED 100.00 0.14 43.59 100.00 -54.80 0.05 0.05 5,927,637.83 460,829.43 0.23 -0.05 CB-GYRO-SS(1) 165.00 0.26 31.97 165.00 10.20 0.24 0.18 5,927,638.01 460,829.56 0.19 -0.23 CB-GYRO-SS(1) 254.00 0.90 144.93 254.00 99.20 -0.17 0.69 5,927,637.61 460,830.07 1.16 0.20 CB-GYRO-SS(1) 346.00 2.30 165.91 345.96 191.16 -2.55 1.56 5,927,635.22 460,830.92 1.62 2.62 CB-GYRO-SS(1) 435.00 2.99 170.63 434.86 280.06 -6.57 2.37 5,927,631.19 460,831.71 0.81 6.67 CB-GYRO-SS(1) 530.00 3.59 167.65 529.71 374.91 -11.92 3.41 5,927,625.84 460,832.73 0.66 12.06 CB-GYRO-SS(1) 625.00 4.64 166.22 624.46 469.66 -18.56 4.96 5,927,619.19 460,834.24 1.11 18.76 CB-GYRO-SS(1) 721.00 6.42 166.79 720.01 565.21 -27.55 7.11 5,927,610.19 460,836.35 1.86 27.85 CB-GYRO-SS(1) 815.00 8.26 174.49 813.24 658.44 -39.39 8.96 5,927,598.34 460,838.14 2.22 39.76 CB-GYRO-SS(1) 910.00 11.33 183.95 906.85 752.05 -55.50 8.97 5,927,582.23 460,838.06 3.64 55.85 CB-GYRO-SS(1) 1,005.00 14.41 193.77 999.46 844.66 -76.30 5.52 5,927,561.46 460,834.50 3.97 76.47 CB-GYRO-SS(1) 5/12/2011 9:30:18AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-322(North) Project: Kuparuk River Unit TVD Reference: Rig:2L-322 @ 154.80ft(D15(40.05+114.80)) Site: Kuparuk 2L Pad MD Reference: Rig:2L-322 @ 154.80ft(D15(40.05+114.80)) Well: 2L-322(North) North Reference: True Wellbore: 2L-322 Survey Calculation Method: Minimum Curvature Design: 2L-322 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,052.23 15.71 192.60 1,045.07 890.27 -88.25 2.72 5,927,549.52 460,831.64 2.83 88.28 MWD+IFR-AK-CAZ-SC(2) 1,146.38 17.39 195.56 1,135.32 980.52 -114.24 -3.83 5,927,523.56 460,824.95 2.00 113.95 MWD+IFR-AK-CAZ-SC(2) 1,242.97 20.89 193.44 1,226.55 1,071.75 -144.91 -11.71 5,927,492.94 460,816.92 3.69 144.22 MWD+IFR-AK-CAZ-SC(2) 1,332.61 23.80 196.25 1,309.46 1,154.66 -177.82 -20.49 5,927,460.08 460,807.97 3.46 176.70 MWD+IFR-AK-CAZ-SC(2) 1,426.54 25.91 194.57 1,394.68 1,239.88 -215.88 -30.96 5,927,422.07 460,797.31 2.37 214.24 MWD+IFR-AK-CAZ-SC(2) 1,526.06 29.23 194.49 1,482.89 1,328.09 -260.47 -42.51 5,927,377.56 460,785.53 3.34 258.25 MWD+IFR-AK-CAZ-SC(2) 1,623.24 32.24 195.82 1,566.41 1,411.61 -308.39 -55.51 5,927,329.71 460,772.27 3.18 305.53 MWD+IFR-AK-CAZ-SC(2) 1,719.13 35.34 194.17 1,646.09 1,491.29 -359.90 -69.28 5,927,278.27 460,758.24 3.37 356.36 MWD+IFR-AK-CAZ-SC(2) 1,812.38 35.56 194.98 1,722.06 1,567.26 -412.24 -82.89 5,927,226.01 460,744.36 0.56 408.02 MWD+IFR-AK-CAZ-SC(2) 1,906.64 36.34 197.62 1,798.37 1,643.57 -465.34 -98.43 5,927,172.99 460,728.55 1.84 460.36 MWD+IFR-AK-CAZ-SC(2) 2,003.99 36.52 197.81 1,876.69 1,721.89 -520.41 -116.02 5,927,118.02 460,710.67 0.22 514.56 MWD+IFR-AK-CAZ-SC(2) 2,098.42 37.29 196.42 1,952.20 1,797.40 -574.60 -132.70 5,927,063.92 460,693.71 1.20 567.94 MWD+IFR-AK-CAZ-SC(2) 2,187.04 37.26 196.84 2,022.72 1,867.92 -626.03 -148.06 5,927,012.58 460,678.09 0.29 618.61 MWD+IFR-AK-CAZ-SC(2) 2,285.86 37.60 196.50 2,101.20 1,946.40 -683.57 -165.29 5,926,955.14 460,660.56 0.40 675.30 MWD+IFR-AK-CAZ-SC(2) 2,377.64 38.15 196.60 2,173.64 2,018.84 -737.58 -181.34 5,926,901.22 460,644.23 0.60 728.52 MWD+IFR-AK-CAZ-SC(2) 2,473.58 38.70 196.53 2,248.80 2,094.00 -794.73 -198.34 5,926,844.16 460,626.94 0.58 784.83 MWD+IFR-AK-CAZ-SC(2) 2,571.43 39.02 197.16 2,325.00 2,170.20 -853.49 -216.13 5,926,785.50 460,608.84 0.52 842.72 MWD+IFR-AK-CAZ-SC(2) 2,619.19 39.05 197.33 2,362.10 2,207.30 -882.22 -225.05 5,926,756.82 460,599.78 0.23 871.01 MWD+IFR-AK-CAZ-SC(3) 2,715.09 39.13 197.93 2,436.53 2,281.73 -939.84 -243.36 5,926,699.30 460,581.17 0.40 927.74 MWD+IFR-AK-CAZ-SC(3) 2,809.01 39.34 197.57 2,509.28 2,354.48 -996.42 -261.47 5,926,642.82 460,562.77 0.33 983.43 MWD+IFR-AK-CAZ-SC(3) 2,902.49 37.70 197.93 2,582.41 2,427.61 -1,051.87 -279.22 5,926,587.47 460,544.74 1.77 1,038.00 MWD+IFR-AK-CAZ-SC(3) 2,947.73 37.79 197.49 2,618.18 2,463.38 -1,078.25 -287.64 5,926,561.14 460,536.18 0.63 1,063.97 MWD+IFR-AK-CAZ-SC(3) 2,997.03 37.89 197.01 2,657.12 2,502.32 -1,107.13 -296.61 5,926,532.31 460,527.06 0.63 1,092.41 MWD+IFR-AK-CAZ-SC(3) 3,091.12 36.46 197.20 2,732.09 2,577.29 -1,161.47 -313.33 5,926,478.06 460,510.06 1.52 1,145.93 MWD+IFR-AK-CAZ-SC(3) 3,187.35 36.59 198.00 2,809.42 2,654.62 -1,216.06 -330.65 5,926,423.57 460,492.46 0.51 1,199.67 MWD+IFR-AK-CAZ-SC(3) 3,280.81 36.39 198.27 2,884.56 2,729.76 -1,268.88 -347.95 5,926,370.84 460,474.89 0.27 1,251.65 MWD+IFR-AK-CAZ-SC(3) 3,375.54 36.35 198.21 2,960.83 2,806.03 -1,322.23 -365.53 5,926,317.59 460,457.03 0.06 1,304.14 MWD+IFR-AK-CAZ-SC(3) 3,469.71 36.68 198.04 3,036.52 2,881.72 -1,375.48 -382.96 5,926,264.43 460,439.32 0.37 1,356.54 MWD+IFR-AK-CAZ-SC(3) 3,565.55 36.81 198.14 3,113.31 2,958.51 -1,429.99 -400.77 5,926,210.03 460,421.24 0.15 1,410.17 MWD+IFR-AK-CAZ-SC(3) 3,658.22 36.93 198.06 3,187.45 3,032.65 -1,482.84 -418.04 5,926,157.27 460,403.69 0.14 1,462.18 MWD+IFR-AK-CAZ-SC(3) 3,756.04 36.83 197.64 3,265.70 3,110.90 -1,538.72 -436.04 5,926,101.49 460,385.41 0.28 1,517.18 MWD+IFR-AK-CAZ-SC(3) 3,848.71 36.89 197.52 3,339.84 3,185.04 -1,591.71 -452.83 5,926,048.59 460,368.35 0.10 1,569.35 MWD+IFR-AK-CAZ-SC(3) 3,945.11 36.93 197.64 3,416.92 3,262.12 -1,646.90 -470.31 5,925,993.50 460,350.58 0.09 1,623.68 MWD+IFR-AK-CAZ-SC(3) 4,040.33 37.33 195.73 3,492.84 3,338.04 -1,701.95 -486.81 5,925,938.54 460,333.80 1.28 1,677.92 MWD+IFR-AK-CAZ-SC(3) 4,052.93 37.31 195.66 3,502.86 3,348.06 -1,709.31 -488.87 5,925,931.20 460,331.69 0.37 1,685.17 MWD+IFR-AK-CAZ-SC(3) 4,131.52 37.19 195.25 3,565.42 3,410.62 -1,755.16 -501.55 5,925,885.42 460,318.78 0.35 1,730.39 MWD+IFR-AK-CAZ-SC(3) 4,227.69 37.20 195.41 3,642.02 3,487.22 -1,811.23 -516.92 5,925,829.43 460,303.12 0.10 1,785.70 MWD+IFR-AK-CAZ-SC(3) 4,323.39 37.16 195.23 3,718.27 3,563.47 -1,867.00 -532.20 5,925,773.74 460,287.55 0.12 1,840.72 MWD+IFR-AK-CAZ-SC(3) 4,418.52 37.06 195.51 3,794.14 3,639.34 -1,922.35 -547.41 5,925,718.48 460,272.05 0.21 1,895.31 MWD+IFR-AK-CAZ-SC(3) 4,513.61 37.14 195.44 3,869.98 3,715.18 -1,977.63 -562.72 5,925,663.29 460,256.46 0.10 1,949.84 MWD+IFR-AK-CAZ-SC(3) 5/12/2011 9:30:18AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-322(North) Project: Kuparuk River Unit TVD Reference: Rig:2L-322 @ 154.80ft(D15(40.05+114.80)) Site: Kuparuk 2L Pad MD Reference: Rig:2L-322 @ 154.80ft(D15(40.05+114.80)) Well: 2L-322(North) North Reference: True Wellbore: 2L-322 Survey Calculation Method: Minimum Curvature Design: 2L-322 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/-W Northing Easting DLS Section (ft) (°) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,607.65 37.71 194.88 3,944.66 3,789.86 -2,032.79 -577.66 5,925,608.21 460,241.24 0.71 2,004.26 MWD+IFR-AK-CAZ-SC(3) 4,703.13 37.69 195.57 4,020.21 3,865.41 -2,089.13 -593.00 5,925,551.96 460,225.61 0.44 2,059.84 MWD+IFR-AK-CAZ-SC(3) 4,794.31 38.08 194.95 4,092.17 3,937.37 -2,143.14 -607.73 5,925,498.02 460,210.60 0.60 2,113.12 MWD+IFR-AK-CAZ-SC(3) 4,891.89 38.18 195.03 4,168.93 4,014.13 -2,201.34 -623.31 5,925,439.91 460,194.71 0.11 2,170.55 MWD+IFR-AK-CAZ-SC(3) 4,987.22 38.50 194.58 4,243.70 4,088.90 -2,258.52 -638.42 5,925,382.82 460,179.31 0.45 2,226.97 MWD+IFR-AK-CAZ-SC(3) 5,080.09 38.60 195.69 4,316.33 4,161.53 -2,314.38 -653.54 5,925,327.04 460,163.91 0.75 2,282.09 MWD+IFR-AK-CAZ-SC(3) 5,178.01 38.69 195.55 4,392.81 4,238.01 -2,373.27 -670.00 5,925,268.24 460,147.14 0.13 2,340.17 MWD+IFR-AK-CAZ-SC(3) 5,268.44 38.55 195.70 4,463.46 4,308.66 -2,427.63 -685.20 5,925,213.97 460,131.66 0.19 2,393.77 MWD+IFR-AK-CAZ-SC(3) 5,367.51 41.09 191.51 4,539.56 4,384.76 -2,489.27 -700.06 5,925,152.41 460,116.49 3.73 2,454.67 MWD+IFR-AK-CAZ-SC(3) 5,463.37 43.90 189.86 4,610.24 4,455.44 -2,552.90 -712.04 5,925,088.85 460,104.18 3.15 2,517.68 MWD+IFR-AK-CAZ-SC(3) 5,557.77 47.00 186.81 4,676.46 4,521.66 -2,619.45 -721.74 5,925,022.37 460,094.13 4.01 2,583.72 MWD+IFR-AK-CAZ-SC(3) 5,649.77 48.56 184.10 4,738.29 4,583.49 -2,687.26 -728.19 5,924,954.60 460,087.33 2.76 2,651.16 MWD+IFR-AK-CAZ-SC(3) 5,745.62 50.89 180.24 4,800.26 4,645.46 -2,760.30 -730.92 5,924,881.57 460,084.22 3.92 2,724.01 MWD+IFR-AK-CAZ-SC(3) 5,837.10 53.05 177.97 4,856.62 4,701.82 -2,832.34 -729.77 5,924,809.54 460,084.99 3.06 2,796.02 MWD+IFR-AK-CAZ-SC(3) 5,935.07 56.62 177.48 4,913.04 4,758.24 -2,912.35 -726.59 5,924,729.52 460,087.77 3.67 2,876.10 MWD+IFR-AK-CAZ-SC(3) 6,029.28 60.80 175.17 4,961.96 4,807.16 -2,992.67 -721.39 5,924,649.18 460,092.54 4.91 2,956.56 MWD+IFR-AK-CAZ-SC(3) 6,120.78 64.37 174.26 5,004.08 4,849.28 -3,073.53 -713.90 5,924,568.29 460,099.61 4.00 3,037.68 MWD+IFR-AK-CAZ-SC(3) 6,212.88 66.60 173.55 5,042.30 4,887.50 -3,156.85 -705.00 5,924,444.94 460,108.08 2.52 3,121.32 MWD+IFR-AK-CAZ-SC(3) 6,308.30 69.14 172.90 5,078.24 4,923.44 -3,244.61 -694.57 5,924,397.13 460,118.06 2.74 3,209.47 MWD+IFR-AK-CAZ-SC(3) 6,407.73 71.21 171.84 5,111.96 4,957.16 -3,337.31 -682.15 5,924,304.37 460,130.00 2.31 3,302.64 MWD+IFR-AK-CAZ-SC(3) 6,498.26 73.93 169.56 5,139.08 4,984.28 -3,422.54 -668.18 5,924,219.09 460,143.52 3.85 3,388.41 MWD+IFR-AK-CAZ-SC(3) 6,589.99 76.73 167.59 5,162.31 5,007.51 -3,509.50 -650.59 5,924,132.04 460,160.65 3.69 3,476.09 MWD+IFR-AK-CAZ-SC(3) 6,598.15 76.98 167.42 5,164.16 5,009.36 -3,517.26 -648.87 5,924,124.27 460,162.33 3.67 3,483.92 MWD+IFR-AK-CAZ-SC(3) 6,692.21 80.04 166.34 5,182.90 5,028.10 -3,607.01 -627.95 5,924,034.42 460,182.79 3.44 3,574.54 MWD+IFR-AK-CAZ-SC(3) 6,787.21 79.82 166.67 5,199.51 5,044.71 -3,697.97 -606.12 5,923,943.36 460,204.14 0.41 3,666.40 MWD+IFR-AK-CAZ-SC(3) 6,881.53 78.83 167.58 5,216.98 5,062.18 -3,788.32 -585.47 5,923,852.91 460,224.33 1.41 3,757.60 MWD+IFR-AK-CAZ-SC(3) 6,945.86 78.76 167.12 5,229.48 5,074.68 -3,849.90 -571.65 5,923,791.27 460,237.82 0.71 3,819.74 MWD+IFR-AK-CAZ-SC(3) 6,976.54 78.72 166.90 5,235.47 5,080.67 -3,879.21 -564.88 5,923,761.92 460,244.43 0.72 3,849.34 MWD+IFR-AK-CAZ-SC(3) 7,073.10 78.10 166.21 5,254.87 5,100.07 -3,971.21 -542.89 5,923,669.82 460,265.95 0.95 3,942.24 MWD+IFR-AK-CAZ-SC(3) 7,165.99 80.94 163.67 5,271.77 5,116.97 -4,059.40 -519.15 5,923,581.52 460,289.22 4.07 4,031.42 MWD+IFR-AK-CAZ-SC(3) 7,262.27 81.27 163.86 5,286.66 5,131.86 -4,150.73 -492.56 5,923,490.07 460,315.34 0.39 4,123.87 MWD+IFR-AK-CAZ-SC(3) 7,358.26 81.32 164.29 5,301.19 5,146.39 -4,241.97 -466.53 5,923,398.70 460,340.90 0.45 4,216.21 MWD+IFR-AK-CAZ-SC(3) 7,473.00 81.32 164.29 5,318.50 5,163.70 -4,351.16 -435.81 5,923,289.36 460,371.04 0.00 4,326.69 PROJECTED to TD 5/12/2011 9:30:18AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips Time Log & Summary Weliview Web Reporting Report Well Name: 2L-322 Rig Name: DOYON 15 Job Type: DRILLING ORIGINAL Rig Accept: 4/10/2011 11:00:00 AM Rig Release: 5/3/2011 11:59:00 PM Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 04/09/2011 24 hr Summary Moved and positioned rig over well, 11:00 12:00 1.00 MIRU MOVE MOB P PJSM.and Rig down. 12:00 15:00 3.00 MIRU MOVE DMOB P Pull Back off well and move to 2L-322. 15:00 21:00 6.00 MIRU MOVE PSIT P Pull in and position rig over 322.Over well @ 2100 Hrs. 21:00 00:00 3.00 MIRU MOVE PSIT P Move and position Pit Module. 04/10/2011 Complete nipple up of diverter system. Diverter test Annular closed 40 sec,.Knife valve opened 8 seconds. Continue rigging up all areas of rig,Change out saver sub,Cut 96'drill line.Service rig,Transfer pipe in derrick from Drillers side to off drillers side. Pick up 5 stands 5"drillpipe from shed. rig up Gyro. Hold Pre-spud with crew.Make up conductor cleanout BHA. Rig accepted at 11:00 Notice of Diverter test given 4-8-11 @ 17:05 hrs.AOGCC Chuck Sheive waived witness of test 4-8-11 @ 18:30 hrs. 00:00 02:00 2.00 0 0 MIRU MOVE PSIT P Complete spotting Pit and Pump complex. 02:00 03:30 1.50 0 0 MIRU DRILL MOB P Skid rig floor to drilling position.Spot rockwasher, Hook up service lines. 03:30 07:15 3.75 0 0 MIRU DRILL RURD P Rig up Steam Lines,Water and air lines. Prep pits to take on spud mud. Load pipeshed with BHA components and drillpipe,change out clamp on choke line. 07:15 10:30 3.25 0 0 MIRU DRILL RURD P Rig up cellar.Chink gaps in cellar area. Fill void in windwall with herculite. Rig up beaver slide. 10:30 13:30 3.00 0 0 MIRU WHDBO NUND P Nipple up Surface Diverter system. Instal riser on top of annular. Rig accepted at 11:00 hrs. 13:30 14:00 0.50 0 0 MIRU WHDBO BOPE P Function test surface diverter system.Annular fully closed-40 sec. Knife valve fully opened 8 seconds. 14:00 17:00 3.00 0 0 MIRU DRILL RURD P Continue rigging up for Spud.Change Saver sub, Rig up equipment on rig fllor, Pipe shed,pits. 17:00 18:00 1.00 0 0 MIRU RIGMN1SLPC P Slip and cut 96'of drill line 18:00 18:30 0.50 0 0 MIRU RIGMNT SVRG P Service rig topdrive, Draworks, Traveling blocks. (Spill drill in cellar) 18:30 21:00 2.50 0 0 MIRU DRILL PULD P Transfer drillpipe in derrick from drillers side to off drillers side. Pick up and rack back 5"HWDP and 5" Drillpipe. 3 Stands HWDP-27 stands 5"drillpipe total in derrick. 21:00 22:00 1.00 0 0 MIRU DRILL RURD P Rig up Sperry Gyro. Sheaves and line. Hang Gyro. Page 1 of 29 T ` Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 22:00 22:30 0.50 0 0 MIRU DRILL SFTY P Hold Pre-Spud meeting with rig crew and service personnel. Discuss well profile for surface section, Hazards involved and mitigation.Followed with pre job on picking up BHA. 22:30 00:00 1.50 0 0 SURFA( DRILL PULD P Make up BHA to clean out conductor. 13-1/2"Hughes MXL-1X, 8"Sperry motor, Float sub,Stabilizer 12"Gauge, UBHO sub,Crossover. Orient UBHO to motor. 04/11/2011 1 Make up Cleanout BHA. Fill hole check for leaks, Pressure test mud lines-No leaks.Tag up ice at 72'MD. Cleanout conductor to 146'MD. Drill F/146'MD-T/309'MD.Trip out and pick up remaining BHA. Make up BHA, Load MWD data, Pulse test. Drill F/309'MD-T/1,294'Gyro surveys taken to 1,005'MD.Gyro released at 22:30 hrs.Max Gas units observed 1,245. 00:00 00:45 0.75 0 0 SURFA( DRILL PULD P Complete pick up of conductor cleanout BHA. 1 stand HWDP, Fill hole check for leaks. Pressure test surface lines to 3,500 psi checking mud lines for leaks.Good test no leaks. 00:45 01:45 1.00 0 0 SURFA( DRILL REAM P Clean out conductor from 43'MD to 146'MD. Ice encountered at 72'MD. 01:45 05:00 3.25 0 309 SURFA( DRILL DDRL P Drill F/146'MD-T/309'MD.309' TVD.500 gpm-590 psi,70 rpm, Bit wt 2k-8k,Torq on 4k off 3k. Up wt 90k,down 88k,rot wt 88k. AST-.4/ ART-.73/ADT= 1.13. Bit hrs= 1.13,Jar hrs 25.45.Gyro surveys taken 219'MD&306'MD. 05:00 05:45 0.75 309 35 SURFA( DRILL TRIP P Trip out of hole for remaining BHA. Lay down UBHO and crossover. 05:45 09:45 4.00 35 269 SURFA( DRILL PULD P Pick up remaining BHA components WR TM, Pulser, Upload EI user, p MWD data. Pick up 3 non mag flex collars,Jars,2 joints 5"HWDP from pipeshed. (269')Pulse test MWD tools 500 gpm-860 psi. 09:45 10:00 0.25 269 309 SURFA( DRILL REAM P Make topdrive connection.Wash and ream F/269'MD-T/309'MD 500 gpm-860 psi,70 rpm,torque 4k. 10:00 12:00 2.00 309 445 SURFA( DRILL DDRL P Drill F/309'MD-T/445'MD.445' TVD. 500 gpm-960 psi,70 rpm, Bit wt 4k-8k,Torq on 4k off 4k. Up wt 105k,down 100k, rot wt 102k. AST- .14/ART-.46/ADT=.8/ Bithrs= 1.93,Jar hrs 26.25.Gyro survey taken @ 355 MD. *Note calibrated and tested rig gas alarms* 12:00 00:00 12.00 445 1,294 SURFA( DRILL DDRL P Drill F/445'MD-T/1,294'MD. 1,274' ND.500 gpm-980 psi,70 rpm, Bit wt 10k-20k,Torq on 5-6k off 2-3k. Up wt 118k,down 120k, rot wt 118k. AST-1.83/ART-1.71 /ADT=3.54/ Bit hrs=7.70,Jar hrs 32.08. (Gyro survey taken to 1,005'MD. Gyro released at 22:30)Max gas units observed 1,245. Page 2 of 29 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 04/12/2011 24 hr Summary Drilled F/1,294'MD-T2,620'MD(TD for surface interval)Circulate 3 X bottoms up, Flow check, Backream to BHA @ 600 gpm-50 rpm,Trip to bottom on elevators with out difficulty.Circulate hole clean.Trip out on elevators taking good fill with no problems to 1,098'MD 00:00 06:00 6.00 1,294 1,798 SURFA( DRILL DDRL P Drill F/1,294'MD-T/1,798'MD. 1,686'TVD.650 gpm-1830 psi,80 rpm, Bit wt 10k-20k,Torq on 5k off 4k. Up wt 135k,down 130k, rot wt 132k. AST-1.49/ART-2.29/ ADT=3.78/ Bit hrs=11.48,Jar hrs 35.80. 06:00 12:00 6.00 1,798 2,241 SURFA( DRILL DDRL P Drill F/1,798'MD-T/2,241'MD. 2,064'TVD.675 gpm-2150 psi,80 rpm, Bit wt 10k-20k,Torq on 6k off 5k. Up wt 142k,down 135k, rot wt 140k. AST-.42/ART-3.14/ADT= 3.56/ Bit hrs= 15.04,Jar hrs 39.36. Max gas units 1,540 �� 12:00 15:15 3.25 2,241 2,620 SURFA( DRILL DDRL P Drill F/2.241'MD-T/2620'MD. '/f 2,362'TVD.2,620'MD is TD for S� surface interval.675 gpm-2150 psi, 80 rpm, Bit wt 10k-20k,Torq on 6k off 5k. Up wt 150k,down 135k, rot wt 140k. AST-0.0/ART-2.82/ADT= 2.82/ Bit hrs= 17.86,Jar hrs 42.32. Total slide time for section-5.55 hrs. Total rotate time for interval 12.31. Max gas units 1,540 15:15 16:30 1.25 2,620 2,620 SURFA( DRILL CIRC P Circulate 3 X bottoms up.700 gpm- 2,350 psi.80 rpm,torq 6-7k. 16:30 16:45 0.25 2,620 2,620 SURFA( DRILL OWFF P Flow Check(Static) 16:45 19:45 3.00 2,620 538 SURFA( DRILL TRIP P Backream F/2,620'MD-T/538'MD. (BHA)650 gpm-1,850 psi. Slow pump rate to 500 gpm through perma frost 1,250 psi.All backreaming done at 50 rpm per Sperry Directional Driller. 19:45 20:00 0.25 538 538 SURFA( DRILL OWFF P Flow Check(Static) 20:00 21:00 1.00 538 2,528 SURFA( DRILL TRIP P Trip in hole on elevators with no evidence of hole problems. F/538' MD-T/2,528'MD. 21:00 22:00 1.00 2,528 2,620 SURFA( DRILL CIRC P Wash last stand to bottom.Circulate hole clean with 600 gpm-1,850 psi. 80 rpm torque 6-7k. 22:00 22:15 0.25 2,620 2,620 SURFA( DRILL OWFF P Monitor well(Static) 22:15 00:00 1.75 2,620 1,098 SURFA( DRILL TRIP P Trip out of hole F/2,620'MD-T/ 1,098'MD. Pulled on elevators with hole taking good fill. No problems encountered. 04/13/2011 Continue to POOH f/1,098-ft to BHA. POOH laying down BHA#1,change over to CSG equipment. RIH w/ 10 3/4"Surface CSG string to 2,613-ft. RU and Cement in place, RD cement equipment and pull landing jt. RD CSG equipment. Blow down and flush all surface pumping equipment. 00:00 00:30 0.50 1,098 538 SURFA( DRILL ]TRIP P Continue to POOH to 538-ft. Page 3 of 29 T • Time Logs Date From To Dur S.Death E. Depth Phase Code Subcode T Comment 00:30 03:00 2.50 538 0 SURFA( DRILL PULD P Continue to POOH standing back 4 stands of HWDP and laying down BHA#1 03:00 06:00 3.00 0 0 SURFA(CASING PULD P Change over to CSG equipment 06:00 06:30 0.50 0 0 SURFA( CASING SFTY P Held PJSM with Rig and CSG Crew on PU and RIH w/CSG 06:30 14:45 8.25 0 2,613 SURFA( CASING RNCS P PU and MU 10.75",45.5#, L-80 BTC CSG and RIH as per run order to 2,613-ft. PUW=200k,SOW= 120k. 14:45 21:30 6.75 2,613 2,613 SURFA( CEMEN"CMNT P RU CMT head and lines. Break circulation at 2 bpm at 190 psig and increase to 6 bpm at 260 psig with CW-100,stall pumps and check trips at 500 psig. PT lines at 3,000 psig- good test. Continue to pump 40 bbls of 80°F CW-100 at 5 bpm at 144 psig ICP and 311 FCP. SD and Batch up r. 50 bbls of 10.5 ppg Mud push with C red dye and pump at 5.5 bpm at 265 psig ICP and 124 FCP. Drop bottom plug, Batch up and pump 319 bbls of 11.0 ppg Lead slurry at 6 bpm at 450 psig. Batch and pump 113.5 bbls of 12.0 ppg Tail slurry at 5 bpm at 335 psig ICP and 505 psig FCP. (Seen mud push at surface with 510 bbls pumped.) Follow with 10 bbls of fresh water and drop top plug in process. Switch over to rig pumps and displace at 6 bpm at 400 psig ICP-seen slight returns at 65 bbls away of displacement,slowed PR to 4 bpm at 400 psi at 86 bbls away, slowed PR to 3 bpm at 400 psig at 111 bbls away,seen cmt at surface at 151 bbls away,seen 12.0#cmt at 211 bbls away, bumped plug at 234 bbls away. Pressure up to 1,500 psig and held for 10 minutes. Bled back and verify floats holding. CMT in place at 21:30 hrs. Recovered a total of 83 bbls of cement. 21:30 00:00 2.50 2,613 42 SURFA( CEMEN-RURD P Back out 10.75"Landing jt., RD CSG equipment,blow down lines and flush surface equipment. 04/14/2011 ND Diverter system, Install CSG head and NU BOP system and test same. 00:00 01:15 1.25 42 0 SURFA( CEMEN"RURD P Clear rig floor of all cement equipment, 10 3/4 casing equipment and lay down mouse hole. Clean and clear rig floor. 01:15 04:30 3.25 0 0 SURFA(WHDBO NUND P Held PJSM on ND Diverter. Nipple down Diverter system and clean cement from all components. Page 4 of 29 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 04:30 06:30 2.00 0 0 SURFA(WHDBO NUND P Held PJSM on NU of Casing head as per FMC Service hand. Test LWR CSG seal to 1,000 psi for 10 minutes. 06:30 16:30 10.00 0 0 SURFA(WHDBO NUND P Held PJSM on NU of 13 5/8"5M BOPE. NU DSA, High Pressure Riser, NU 13 5/8"5M Class 3 Stack. Install kill and choke lines. Hook up choke and flare lines. Install turn buckles, Flow line and Double gate on annulas. Set riser. Inspect and service Top drive. Change out Koomey hoses. Change LPR's to 5" Solids. RU test equipment. 16:30 21:30 5.00 0 0 SURFA(WHDBO BOPE P Test 13 5/8 5M BOPE w/5"Test it at 250/3,500 psi and annular at 250/2,500 psi. Tested all alarms and sensors-good test. Starting Pressures: 1,500,3,000 and 860 psi. 200 psi increase-37 seconds 6v Full pressure-195 seconds v 5 N2 Bottles at 2,375 psi. 24 hr notice was given to AOGCC at 18:24 hrs on 4-12-11 and Lou Grimaldi with AOGCC witnessed test. 21:30 23:15 1.75 0 0 SURFA(WHDBO OTHR P RD BOP Test BOP equipment and Pull test Plug. Install wear ring. 23:15 00:00 0.75 0 0 SURFA( DRILL PULD P Held PJSM with MWD service hand. Load current hole section MWD tools into the pipe shed to be prepped for next run. 04/15/2011 PU and stand back 5,500 ft±of 5"DP. MU and RIH w/DrIg BHA#2, Drill out 10 3/4"Shoe track and 50-ft of 9 7/8"Open hole. Conduct LOT. 00:00 00:30 0.50 0 0 SURFA( DRILL PULD P Continue to load current hole section MWD tools into the pipe shed to be prepped for next run. 00:30 07:45 7.25 0 0 SURFA( DRILL PULD P Held PJSM with crew on picking and standing back 5"DP. PU,MU 165 jts of 5"DP and and stand back in Derrick for a total of 82 stands. 07:45 08:30 0.75 0 0 SURFA( RIGMNT SVRG P Lubricate rig and change out belt on draw works oiler pump. 08:30 08:45 0.25 0 0 SURFA( DRILL SFTY P Held PJSM with DD and MWD on picking up BHA#2 08:45 14:30 5.75 0 673 SURFA( DRILL PULD P Pick up BHA#2 as per DD and upload MWD tools. Continue to PU remaining BHA to 672-ft. Shallow test MWD and Blow down TOP Drive. Held PJSM with crew on loading sources and load same. Continue to RIH w/ Page 5 of 29 1 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 14:30 15:30 1.00 673 2,504 SURFA( DRILL TRIP P RIH with DrIg BHA#2 on 5"DP from 627.66-ft to 2,507-ft. Tag TOC at 2,504-ft. 15:30 16:00 0.50 2,504 2,504 SURFA( DRILL CIRC P Circulate and condition mud at 2,504-ft at 550 gpm at 1,850 psi, rotating at 40 rpm at 7k free torque. increase PR to 630 gpm at 2,250 psi. ROT wt 140k, PU wt 150k,and SO wt 140k. 16:00 19:00 3.00 2,504 2,504 SURFA( DRILL PRTS P Held PJSM on testing CSG. RU for CSG test, Pressure up to 3,000 psi and held for 30 minutes on chart. Bleed back pressure and recovered 1.5 bbls returns. RD testing equipment. 19:00 22:00 3.00 2,504 2,620 SURFA( CEMEN'DRLG P Drill out cmt from .507-ft to Float collar at 2.528-ft.drilled wiper plug. Contiue to drill out cmt thru shoe track to shoe at 2,613-ft. 22:00 22:30 0.50 2,620 2,640 SURFA( DRILL DDRL P Drill formation to 2640. Pull back i(,(‘ V inside shoe to 2,545 ft for LOT. Ir` 22:30 23:30 1.00 2,640 2,640 SURFA( DRILL LOT P RU and Preform Leak off test,3.2 fE. bbls pumped to leak off,pump an additional 3 bbls into formation as per plan. Bled off pressure and recovered 1 bbl. RD testing equipment. 23:30 00:00 0.50 2,640 2,660 INTRM1 DRILL DDRL P RIH to 2,640-ft and begin drlg intermediate hole to 2,660-ft MD 2,394-ft ND. AST=0.0, ART=.26 hrs, ADT=.26 hrs, JAR=71.09 hrs. 04/16/2011 Continue to drill 9 7/8"intermediate hole from 2,660-ft MD 2,394-ft ND.to 4,486-ft MD, 3,848-ft ND. 00:00 15:00 15.00 2,660 4,081 INTRM1 DRILL DDRL P Continue to drill intermediate hole from 2,660-ft MD 2,394-ft ND. Drill thru Campanion sands from 2,823-ft MD,2,520-ft ND to 2,831-ft MD, 2,526-ft ND-conduct flow check at 2,850-ft MD-No flow. Continue to drill 9 7/8"Intermediate section to 4,081-ft MD 3,526-ft ND PU wt=172k,SO wt=145k and ROT wt=158k, RPM=100,TQ on=9k off=6k WOB=5-12k,Circulating at 750 gpm,2,400 psi. Max Gas=55 units ECD=10.15 SPR at 3,608-ft MD 3,147-ft ND MW=9.5 ppg #1 at 30 spm=210 psi #1 at 40 spm=240 psi #2 at 30 spm=210 psi #2 at 40 spm=270 psi Page 6 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:00 1.00 4,081 4,081 INTRMI DRILL CIRC P Circulate and condition mud at 4,081-ft at 740 gpm at 2,170 psi, Rotating at 50 RPM with TQ Off=6-7k, PU wt=185k,SO wt=140k, Check for flow-static. 16:00 17:30 1.50 4,081 2,561 INTRMI DRILL WPRT P Held PJSM on POOH. POOH f/ 4,081-ft MD to the shoe at 2,561-ft. MD. Highest wt=185k,Slack off wt=140k. 17:30 17:45 0.25 2,561 2,561 INTRMI DRILL OWFF P Flow Check-No flow. 17:45 18:15 0.50 2,561 2,561 INTRM1 RIGMNTSVRG P Service rig 18:15 19:15 1.00 2,561 4,081 INTRM1 DRILL TRIP P RIH from 2,561-ft MD to 3,986-ft MD, fill pipe and wash to 4,081-ft.MD 19:15 23:45 4.50 4,081 4,486 INTRMI DRILL DDRL P Begin drla at 4,081-ft.MD to 4.486-ft MD,3,848-ft TVD. at 750 gpm at 2,500 psi, Rotating at 100 rpm with TQ On=10k,TQ Off=8k and WOB=5-15k. PU wt=190k,SO wt=140k, ROT wt=170k. ECD's=9.8 ppg, Max Gas=65,AST=.09, ART=5.33,ADT=5.42,TST=.43, TRT=12.56, Bit hrs=12.99 and Jar hrs=83.82 SPR at 4,460-ft MD 3,827-ft TVD MW=9.5 ppg #1 at 30 stks=240 psi #1 at 40 stks=300 psi #2 at 30 stks=250 psi #2 at 40 stks=310 psi 23:45 00:00 0.25 4,486 4,486 INTRM1 DRILL OTHR T Standback Kelly and blow down Top drive. Check for leak on connections, hoses and Top drive. Remove stand#4lfrom drill string. Solved leakage. 04/17/2011 Continue to drill 9 7/8"Intermediate hole from 4,486-ft to 6,072-ft MD, Short out to 4,000-ft 00:00 16:30 16.50 4,486 5,821 INTRMI DRILL DDRL P Continue to drill out from 4,486-ft MD,3,848-ft TVD.to 5,821-ft. MD, 4,847-ft TVD.at 750 gpm at 2,750 psi, Rotating at 100 rpm with TQ On=10k,TQ Off=9k and WOB=5k. PU wt=220k,SO wt=170k, ROT wt=189k ECD's 10.3 ppg,Max Gas =790 units at 5,730-ft MD 16:30 18:00 1.50 5,821 5,821 INTRM1 RIGMNT RGRP T Work string from 5,821-ft to 5,695-ft MD while changing out Liner gasket on Pump#1. Circulating at 367 gpm at 870 psi,rotating at 50 rpm's with 10-12k torque. HST=220k,SLK= 170k,and ROT wt= 189k. Page 7 of 29 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 18:00 21:45 3.75 5,821 6,072 INTRMI DRILL DDRL P Continue to drill from 5,821-ft MD, 4,847-ft ND.to 6,072-ft. MD, 4,982-ft ND.at 750 gpm at 2,750 psi, Rotating at 100 rpm with TQ On=12k,TQ Off=9k and WOB=5k. PU wt=220k,SO wt=170k, ROT wt=189k ECD's 10.3 ppg,Max Gas =790 units at 5,730-ft MD AST=2.3,ART=2.99,ADT=5.34, Bit hrs=25.44,Jar Hrs=96.27 SPR at 6,070-ft MD 4,982-ft ND #1 at 30 spm=260 psi #1 at 40 spm=320 psi #2 at 30 spm=240 psi #2 at 40 spm=310 psi 21:45 22:00 0.25 6,072 6,072 INTRM1 DRILL OWFF P Flow check=Static, Blow down Top drive 22:00 00:00 2.00 6,072 4,000 INTRM1 DRILL WPRT P Short trip out on elevators from 6,072-ft MD to 4,000-ft MD. HST=220k,SLK=170k. Had no swabbing and no overpull. 04/18/2011 Observe well for flow, RIH from 4,000-ft.and Continue to drill 9 7/8"Hole from 6,072-ft MD to 7,067-ft MD, 5,252-ft ND 00:00 00:15 0.25 4,000 4,000 INTRMI DRILL OWFF P Flow check=Static 00:15 01:30 1.25 4,000 5,979 INTRM1 DRILL TRIP P RIH from 4,000-ft MD to 5,979-ft MD PU wt=218k,SO wt= 160k. Calculated displacement=15.75 bbls and actual displacement=15 ✓ bbls. 01:30 02:00 0.50 5,979 6,089 INTRM1 DRILL WASH P Wash and ream down from 5,979-ft to 6,089-ft. at 50 rpm's with 10k torque. Stage pumps to 430 gpm at 1,500 psi. 02:00 02:30 0.50 6,089 6,089 INTRM1 DRILL CIRC P CBU at 550 gpm at 1,800 psi, rotating at 50 rpm's with 10k torque, reciprocating DP from 6,089-ft to 5,995-ft. Circulated a total of 463 bbls. PU wt=218k,SO wt=163k. Max. BU gas=144 units. No significant increase in cuttings on shakers. Page 8 of 29 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 02:30 12:00 9.50 6,089 6,641 INTRMI DRILL DDRL P Continue to drill from 6,089-ft. MD, 4,982-ft TVD.to 6,641-ft. MD, 5,173-ft TVD.at 750 gpm at 2,750 psi, Rotating at 100 rpm with TQ On=12k,TQ Off=11 k and WOB=5k. PU wt=225k,SO wt=171k, ROT wt=197k ECD=10.41 SPR at 6,646-ft. 5,173-ft ND MW=9.7 ppg at 11:00 am. #1 at 30 spm=270 psi #1 at 40 spm=340 psi #2 at 30 spm=280 psi #2 at 40 spm=350 psi 12:00 00:00 12.00 6,641 7,067 INTRMI DRILL DDRL P Continue to drill from 6,641-ft. MD, 5,173-ft ND.to 7,067-ft MD,5,252-ft ND at 740 gpm at 2,800 psi, Rotating at 100 rpm with TQ On=15k,TQ Off=10k and WOB=5k. PU wt=230k,SO wt=165k, ROT wt=190k ECD=10.3 Max gas=3,584 Units AST=.87,ART=6.34,ADT=7.21, Bits Hrs=38.32 Jar Hrs=109.15 SPR at 7,078-ft. 5,255-ft ND MW=9.9 ppg at 23:15 am. #1 at 30 spm=270 psi #1 at 40 spm=340 psi #2 at 30 spm=280 psi #2 at 40 spm=350 psi 04/19/2011 Continue to drill 9 7/8"Hole from 7,067-ft MD,5,252-ft ND to TD at 7,473-ft MD,5,318-ft. Pump out of the hole to 5,591-ft.MD,4,699-ft.ND. Increase mud system from 10.1 ppg to 11.1 ppg 00:00 01:30 1.50 7,067 7,130 INTRM1 DRILL DDRL P Continue to drill from 7.067-ft MD, 5,252-ft ND to 7,130 at 740 gpm at 2,800 psi, Rotating at 100 rpm with TQ On=15k,TQ Off=10k and WOB=5k. PU wt=230k,SO wt=165k, ROT wt=190k ECD=10.3 Max gas=3,584 Units 01:30 02:00 0.50 7,130 7 0 INTRM1 DRILL CIRC P Increase MW from 9.9 ppg to 10.0 ppg 'C� 02:00 08:30 6.50 7,130 7,47 INTRM1 DRILL DDRL P Continue to drill from 7,130 to TD at 7,473-ft MD,5,318-ft ND at 740 gpm at 3,250 psi, Rotating at 100 rpm with TQ On=15k,TQ Off=10k and WOB=5k. PU wt=230k,SO wt=162k, ROT wt=192k ECD=11.23 Max gas=4,630 Units-From 7,420-ft MD,slowed ROP to 50 fph to manage ECD of 11.0 ppg at 700 gpm at 3,360 psi Page 9 of 29 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 08:30 16:00 7.50 7,473 7,473 INTRM1 DRILL CIRC P Increased mud weight in mud system from 10.2 ppg to 10.8 ppg, while Circulating at 700 gpm at 2,800 psi, rotating and reciprocating at 50 rpm's with 13k torque from 7,473-ft MD to 7,401-ft MD. PU wt=230k, SO wt=165k, ROT wt=195k. 16:00 19:45 3.75 7,473 5,591 INTRMI DRILL REAM P Pump out of the hole from 7,473-ft MD to 5,591-ft MD,4,699-ft ND at 550 gpm at 2,300 psi,rotating at 70 rpm's with 10k torque. UP wt at 230k, SO wt at 165k and ROT wt at 195k. 19:45 20:00 0.25 5,676 5,676 INTRM1 DRILL OWFF P Check for flow at 5,676-ft MD 20:00 21:45 1.75 5,591 5,591 INTRM1 DRILL CIRC P Increased mud weight in mud p system from 10.8 ppq to 11.1 ppg, I l•1 (1 r while Circulating at 750 gpm at 3,300 psi, rotating and reciprocating at 70 rpm's with 10k torque from 5,591-ft MD to 5,676-ft MD. PU wt=200k, SO wt=170k, ROT wt=185k. 21:45 22:00 0.25 5,676 5,676 INTRM1 DRILL OWFF P Check for flow at 5,676-ft MD Flowed back 2 bbls in 15 minutes. 22:00 00:00 2.00 5,591 5,591 INTRM1 DRILL CIRC P Continue to Increase mud weight in mud system from 11.0+ppg to 11.1 ppg,while Circulating at 750 gpm at 3,300 psi, rotating and reciprocating at 70 rpm's with 10k torque from 5,591-ft MD to 5,676-ft MD.4,740-ft ND. PU wt=200k,SO wt=170k, ROT wt= 185k. At 23:30 hrs slowed PR to 550 gpm at 2,200 psi and continued to weight up Mud system. 04/20/2011 Continue to Reciprocate at 5,591-ft. MD,4,699-ft.ND. Increase mud wt in system 11.0 ppg to 11.4 ppg, Trip back in hole to 7,473-ft MD.Continue to increase mud wt from 11.4 ppg to 11.7 ppg.with max gas= 5,948 units. Lost circulation and pumped 50 bbl 12.0 ppg LCM pill. Had no losses at 135 gpm Total losses as of midnight=206 bbls. 00:00 07:30 7.50 5,591 5,591 INTRM1 DRILL CIRC P Stand back 1 stand and Continue to Increase mud weight in mud system i i,`i Pr) from 11.0+ppg to 11.4 ppq,while Circulating at 555 gpm at 2,100 psi, rotating and reciprocating at 70 rpm's with 10k torque from 5,591-ft MD to 5,500-ft MD.4,640-ft ND. PU wt= 180k,SO wt=170k, ROT wt= 185k. Max Gas=5,800 units Decision was made to RIH to Bottom -Conducted a 5 minute flow check- slight drop in fluid level. 07:30 09:00 1.50 5,591 7,401 INTRM1 DRILL TRIP P Trip in hole from 5,591-ft MD to 7,401-ft MD-Calculated displacement=15.75 bbls-Actual= 15.0 bbls. Page 10of29 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 09:00 09:30 0.50 7,401 7,473 INTRM1 DRILL WASH P Wash last stand in hole from 7,401-ft MD to 7,473-ft MD. PU wt=230k, SO wt=160k. 09:30 13:00 3.50 7,473 7,473 INTRM1 DRILL CIRC P CBU at 252 gpm at 730 psi, rotating and reciprocating at 60 rpm's with 12k torque from 7,473-ft MD to 7,401-ft MD. Observed increase in out flow 16%to 25%, reduced PR to 126 gpm at 200 psi and finish total circulation of 553 bbls with 11.4 ppg MW in and 11.2 ppg MW out. Continue to weight up system to 11.4 ppg surface to surface. 13:00 14:15 1.25 7,473 7,473 INTRMI DRILL CIRC T Circulate through choke manifold,fill lines and Poor boy with 13.3 bbls volume. Close well in to test drill pipe and csg pressures. SIDP=50 psi,SICP=50 psi. Open choke and mud manifold bleeder. Blow down Choke manifold and choke line. Drain Poor boy. 14:15 21:00 6.75 7,473 7,473 INTRMI DRILL CIRC T Continue to circulate and reciprocate from 7,463-ft MD to 7,390-ft MD, 5,318-ft TVD. PR at 350 gpm at 11,220 psi. 70 RPM's with 14k Torque with return flow of 18%while weighting up system from 11.4 ppg IL 1 ffr to 12.7 ppq in.10 increments. Increased PR to 400 gpm at 1,550 psi while circulating with 11.4 ppg and 1,650 psi with MW at 11.7 ppg. Max gas=5,948 units 21:00 00:00 3.00 7,473 7,473 INTRM1 DRILL CIRC T Started loosing fluid,slowed pump rate to 300 GPM at 1,020 psi. Lost 29 bbls in 10 minutes. Pumped 50 BBL 12.0 ppg LCM pill,continued to have losses,slowed PR to 200, 175, 150 and 135 gpm. Had no losses at 135 gpm. Continue to circulate and reciprocate from 7,463-ft to 7,390-ft MD,5,318-ft TVD. 70 RPM with 15k max torque. UP wt=190k,SO wt= 170k and ROT wt=185k. Max Gas =5,948 units. ECD's=12.28 at 550 gpm with 11.7 ppg MW. Total Losses from 12:00 hrs to 24:00 hrs= 206 BBLS. SPR at 7,470-ft MD,5,318-ft ND with 11.7 WBM. Pump#1 at 30 spm at 360 psi Pump#1 at 40 spm at 470 psi Pump#2 at 30 spm at 360 psi Pump#2 at 40 spm at 480 psi Page 11 of 29 ' T Time Logs Date From To Dur S.Death E. Depth Phase Code Subcode T Comment 04/21/2011 24 hr Summary Continue to attempt to heal lost circulation, Back ream out from 7,473-ft.MD to 6,833-ft.MD,Continue to attempt to heal lost circulation, Pump out of the hole to 5,601-ft MD. Continue to attempt to heal lost circulation, 00:00 01:00 1.00 7,473 7,473 INTRM1 DRILL CIRC T Continue to circulate at 250 gpm at 700 psi, rotating at 60 rpm with 11k torque while reciprocating from 7,473-ft MD to 7,401-ft MD PU wt= 193k,Mud wt=11.7 ppg.and Monitoring losses while building surface mud. 01:00 03:00 2.00 7,473 7,473 INTRM1 DRILL CIRC T Slow rate to 147 gpm at 400 psi and monitor losses while continuing to reciprocate. Average losses at 60 BPH. Pump 60 bbl 35 ppb LCM pill #2 and spot at 5,500-ft MD at 135 gpm at 500 psi,while circulating at same parameters. 03:00 07:30 4.50 7,473 7,473 INTRM1 DRILL CIRC T With pill in place,shut down pumping operations,monitor well on trip tank. let pill soak for 10 minutes, establish circulation at 147 gpm at 400 psi,pumping 11.7 ppg mud and continue to weight up mud system to 11.7 ppg in and out. Losses seen at 15-20 bph. 07:30 09:30 2.00 7,473 6,833 INTRMI DRILL REAM T Back ream out from 7,473-ft MD to 6,833-ft MD at 126 gpm at 450 psi with return flow of 10%,rotating at 60 rpm's with 13k max torque. Gas units ranging from 2,300 to 2,800. PU wt=190k 09:30 12:00 2.50 6,833 6,833 INTRM1 DRILL CIRC T Circulate and condition mud at 126 gpm at 350 psi, Rotating at 60 rpm's with 10k torque, reciprocating from 6,833-ft MD to 6,738-ft MD. MW in= 11.7 ppg and MW out=11.65 ppg. PU wt=185k. Max Gas=2,050 units. Building LCM pill on location. 12:00 15:00 3.00 6,833 5,601 INTRM1 DRILL TRIP T Pump out of the hole from 6,833-ft. MD to 5,601-ft. MD at 137 gpm at 390 psi. RPM's at 50k with 12k torque. UP wt= 190k,SO wt=170k 15:00 19:30 4.50 5,601 5,601 INTRMI DRILL CIRC T Circulate and reciprocate from 5,695-ft.MD to 5,601-ft. MD at 126 gpm at 390 psi at 50 rpm's with 10k torque. Mud wt in 11.7 ppg/mud wt. out 11.65 ppg. PU wt= 185k. Stage pumps up to 550 gpm at 2,450 psi, then slowed PR to 200 gpm at 580 psi, rotating at 50 rpm's with 12k torque. 19:30 20:00 0.50 5,601 5,601 INTRM1 RIGMNT SVRG T Service rig while continuing to circulate. Page 12 of 29 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 20:00 00:00 4.00 5,601 5,601 INTRM1 DRILL CIRC T Circulate and reciprocate from 5,695-ft. MD to 5,601-ft.MD at 550 gpm at 2450 psi at 50 rpm's with 10k torque. Mud wt in 11.7 ppg/mud wt. out 11.65 ppg. PU wt=185k. Slowed PR to 200 gpm at 580 psi Rotating at 49 rpm's at 12k torque. Cycled pumps for MWD and increased PR back to 550 gpm at 2,450 psi. Then at 22:30 hrs we began staging PR down at 100 gpm increments to 200 gpm at 580 psi. 273 bbl 24 hr loss to Formation 479 bbl accumulated losses to formation SPR at 5,600-ft MD,4,745-ft ND Pump#1 at 30 spm at 340 psi Pump#1 at 40 spm at 450 psi. Pump#2 at 30 spm at 330 psi Pump#2 at 40 spm at 430 psi. 04/22/2011 Continue to attempt to heal lost circulation, Build and pump 80 bbl Form-a-Block, Pump out of hole f/5,694-ft MD U 4,620-ft. 00:00 01:30 1.50 5,601 5,601 INTRMI DRILL CIRC T Circulate and reciprocate from 5,695-ft.MD to 5,601-ft.MD at 200 gpm at 480 psi at 60 rpm's with 10k torque. Mud wt in 11.7 ppg/mud wt. out 11.65 ppg. PU wt= 193k. while preparing to wt up mud system to 11.8 ppg. Increase pump rate to 475 gpm at 1850 psi. 01:30 05:00 3.50 5,601 5,601 INTRMI DRILL CIRC T Observed losses of 32 bph,Shut down with pill out of the bit. Wait for 5 minutes,pump at 30 spm at 300 psi for 5 minutes. Increase rate to 475 gpm at 1,900 psi.and begin weighting up mud system to 11.8 ppg. MW in=11.8 ppg and Mud wt out 11.7+ppg at 04:00 hrs. 05:00 08:00 3.00 5,601 5,601 INTRMI DRILL CIRC T Loosing circulation, 100 bph losses. Slow pump rate down to 144 gpm at 323 psi. Begin building 50 bbl, 35 ppb LCM pill,pump and spot at 5,656-ft. Close annular and attempt of squeeze LCM pill at 5 bbl increments at 3 bpm at 120 psi with 5 minute soak with 11.8 ppg MW per each interval. Total of 20 bbls squeezed. Open Annular and monitor well-slight flow back. Continue to Reciprocate and Circulate at 126 gpm at 370 psi with 7-8%flow back,maintaining mud wt with 2,600 Gas units. Losses at 24 bph. Begin building Form-a-block LCM pill. PU wt= 190k Page 13 of 29 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 08:00 20:30 12.50 5,601 5,601 INTRM1 DRILL CIRC T Increase PR to 230 gpm at 530 psi while rotating at 65 rpm's with 10k torque while reciprocating. While increasing MW from 11.7+ppg to 11.8+ppg. Max gas 3,000 units. With MW in and out at 11.8 ppg, with Max gas units observed=2,200 -2,500. Slowed PR to 126 gpm at 320 psi with 5%flow and Losses at 50-60 bph. Max gas units=4,293. Continue mixing 80 bbl Form-a- Block pill. PU wt=183k SO wt= 183k 20:30 00:00 3.50 5,601 4,620 INTRM1 DRILL CIRC T As of 21:00 hrs we pumped 78 bbl form a block pill,followed by 16 bbls KWF to spot at bit. We then proceeded to pump out of the hole from 5,694-ft to 4,620-ft.at 2.6 bpm pulling at 27 fpm. Most pressure seen was 470 psi then dropping to 230 psi once pill left string. 04/23/2011 Close annular and Squeeze away 80 bbls and stage pumps to 675 gpm to perform ECD squeezes with an add! 131 bbls. Build 2nd Form a Block pill. Squeeze away 95 bbl 12.5 ppg form a pill and attempt to ECD squeeze at 654 gpm w/25 bbl loss. SD and monitor well-gain back 17 bbls. 00:00 05:30 5.50 4,620 4,620 INTRM1 DRILL CIRC T Closed annular and pumped 80 bbls of KWF down DP and IA simutaineously at 80 to 110 psi. SWI for 30 minutes and pressure dropped from 110 psi to 35 psi. Kelly up top drive and establish circulation at 450 gpm at 01:50 hrs, increase PR to 605 gpm and seen losses. Stage pumps down to 124 gpm then back to 648 gpm with 12.10 ECD,then back to 132 gpm, up to 652 gpm w/ECD at 12.10, back down to 84 gpm, up to 675 gpm w/ECD at 12.28,then back down to 253 gpm, up to 674 gpm w/ ECD at 12.28,then back down to 400 gpm w/ECD at 12.08,then back up to 670 gpm w/ECD at 12.28,then back to 405 gpm w/ECD at 12.08, then back to 675 gpm w/ECD at 12.28,then back to 400 gpm w/ECD at 12.08,with 131 bbl losses since midnight. Bring rate to 450 gpm and establish loss rate of 36 bph,slowed PR to 350 gpm at 859 psi w/11.95 ECD,Zero losses. Min gas units seen 620 units and Max gas rates at 4,500 units. Page 14 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 14:00 8.50 4,620 4,620 INTRMI DRILL CIRC T Circulate and condition mud while building 2nd Form-a-block pill. Circulating 11.6+ppg mud at 350 gpm at 950 psi while rotating and reciprocating at 4,620-ft MD with 14-15%outflow with minimum losses. ECD's=11.94 Max gas= 3,000 units. 14:00 16:30 2.50 4,620 5,885 INTRM1 DRILL REAM T Wash and ream back down from 4,620-ft MD to 5,885-ft MD at 211 gpm at 510 psi with 8%outflow while rotating at 50 rpm's with 8k torque. PU wt=210k,SO wt= 170k. Pumped a total of 4,000 stks,max gas units observed= 1,600 units. 16:30 18:00 1.50 5,885 5,885 INTRMI DRILL CIRC T Rotate and reciprocate at 50 rpms with 8k torque.from 5,885-ft MD to 5,790-ft MD while CBU at 256 gpm at 620 psi with 12%outflow PU wt= 210k SO wt= 170k. Pumped a total of 4,500 stks and Max gas=3,000 units. 18:00 23:00 5.00 5,885 4,650 INTRM1 DRILL CIRC T With bit at 5,885-ft MD, Pump 95 bbl 12.5 ppg Form-a-pill and chase with 9 bbls of 11.6 ppg Mud and spot at bit at 109 gpm at 130 psi w/4%out flow. UP wt=210k DN wt=170k. Pump out of the hole from 5,885-ft MD to 4,650-ft MD at 109 gpm at 190 psi w/4%out flow UP wt=190k, DN wt=160K. RU head pin,blow down top drive. Down squeeze 95 bbls,pumping down IA and DP. Shut down. SICP=135 psi,SIDP= 50 psi. Monitor pressure for 30 minutes, SICP=60 psi,SIDP=40 psi. Bleed off pressure, RD squeezing equipment. 23:00 00:00 1.00 4,650 4,650 INTRMI DRILL CIRC T Circulate at 654 gpm at 2,740 psi for 5 minutes with 22%outflow with 12.01 ppg ECD's. Lost 25 bbls and monitor well for 15 minutes. recovered 17 bbls. CBU staging up in 50 gpm increments 04/24/2011 CBU staging up pumps in 50 gpm increments, recovered 15 bbls of form a pill. increase MW from 11.6 to 11.8 and attempt to heal losses with ECD squeezes. WO orders from town.Continue to circulate in attempt to heal losses. Slip and cut 130-ft of drill line. Held PJSM with crew on stripping in hole with DP. Wash and ream from 4,650-ft MD to 5,895-ft.MD. Page 15 of 29 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 19:00 19.00 4,650 4,650 INTRM1 DRILL CIRC T Continue to CBU staging up in 50 gpm increments up to 675 gpm at 2,800 psi with 32 bbl loss. Recovered 15 bbls of perform-a-pill with Mud wt in 11.6 ppg mud wt out 11.6 ppg. Slow PR to 350 gpm at 900 psi with a 11.96 ECD while increasing MW to 11.8 ppg, Began loosing fluid at 03:00 hrs,Slow pump rate to 275 gpm at 580 psi,continue to loose fluid, lower PR to 200 gpm at 337 psi. Building 60 bbl of 55 ppb LCM pill. 280 bbls loss as of 05:00 hrs. Pump LCM pill at 162 gpm at 300 psi chasing with 11.8 ppg MW- after pill was recovered -losses slowed to 10-25 bph. Raise circulating rate to 250 gpm at 500 psi, rotating and reciprocating at 40 rpm's from 4,650-ft MD to 4,557-ft MD-monitoring losses of 50-65 bph. Reduce rate back to 150 gpm at 300 psi. Begin building another LCM pill and waiting on orders. Well began giving back fluid, increase PR to 316 gpm at 710 psi w/15%outflow. Rotating and reciprocating at 65 rpm's w/7k max torque. ROT wt= 170k. Began taking losses again and slowed pump as needed. Max Gas=2,500 units 19:00 20:30 1.50 4,650 4,650 INTRM1 RIGMN1SLPC T Slip and cut 130-ft.of drill line while circulating at 168 gpm at 300 psi with 7%outflow. UP wt=180k,SO wt.=160k. Losses at 40-50 bph, max gas=2,000 units. 20:30 21:30 1.00 4,650 4,650 INTRM1 DRILL SFTY T Held PJSM with crew on tour on stripping in the hole with drill pipe though Annular. Blow down choke. Simulate stripping in the hole with DP with out closing the annular. 21:30 00:00 2.50 4,650 5,895 INTRM1 DRILL REAM T Wash and ream from 4,650-ft MD to 5,895-ft MD at 174 gpm at 430 psi with 7%outflow. Rotating and reciprocating at 50 rpm w/7k torque. PU wt=200k,SO wt 160k with losses 50 bph. max gas=2,000 units. SPR 4,650-ft MD Pump#1 at 30 spm at 210 psi Pump#1 at 40 spm at 300 psi Pump#2 at 30 spm at 200 psi Pump#2 at 40 spm at 300 psi Page 16 of 29 Time Logs Date From To Dur S. Deoth E.Depth Phase Code Subcode T Comment 04/25/2011 24 hr Summary CBU f/5,895 at 175 gpm at 325 psi.with 11.9+MW in and out,wash down to 6,180-ft MD,fluid loss=80 bbls. CBU at 175 gpm at 325 psi with 11.8 MW in and out. Fluid loss=34 bbls. Wash down to 6,454-ft MD. CBU at 170 gpm at 450 psi with 11.7 MW in and out. Ave. Fluid loss= 15 bph. Wash down to 6,925-ft MD. CBU at 170 gpm at 470 psi with 11.7+in and out. Ave.fluid loss=31 bph. Wash down to TD at 7,473-ft MD;5,318-ft TVD.CBU at 174 gpm at 490 psi with 11.8 MW in and out. Ave.fluid loss=25 bph. Max gas=2,200 units. With bit at 7,462-ft MD close annular and spot 180 bbls of 16.0 ppg mud in three 624-ft stages at 128 gpm at 340 psi with 35 psi back pressure held on choke. Pump out of the hole at 2.6 bpm pulling at 27 fpm.to 5,601-ft MD with 11.7 ppg displacement Mud. 00:00 03:30 3.50 5,895 5,895 INTRM1 DRILL CIRC T CBU at 175 gpm at 325 psi while rotating and reciprocating at 40 rpm's at 8k torque. Lost 80 bbls in 3 1/2 hrs. MW in 11.9+, MW out 11.9+ during circulation. 03:30 04:00 0.50 5,895 6,180 INTRM1 DRILL REAM T Wash and ream in the hole at to 6,180-ft MD at 175 gpm at 325 psi. 04:00 06:30 2.50 6,180 6,180 INTRM1 DRILL CIRC T CBU at 175 gpm at 325 psi while rotating and reciprocating at 40 rpm's at 8k torque. Lost 34 bbls in 2 1/2 hrs as 06:30 hrs. MW in 11.8,MW out 11.8 during circulation. 06:30 07:00 0.50 6,180 6,454 INTRM1 DRILL REAM T Wash and ream the hole from 6,180-ft to 6,454-ft at same parameters. 07:00 09:00 2.00 6,454 6,454 INTRMI DRILL CIRC T Continue to CBU at 170 GPM at 450 psi, rotating and reciprocating the same with 10%out flow. Loss rate of 15 bph with 11.7 ppg MW. 09:00 10:30 1.50 6,454 6,925 INTRM1 DRILL REAM T Wash and ream the hole from 6,454-ft to 6,925-ft at same parameters. Max gas=2,200 units. 10:30 13:00 2.50 6,925 6,925 INTRMI DRILL CIRC T Continue to CBU at 170 GPM at 470 psi, rotating and reciprocating from 6,925-ft MD to 6,833-ft MD at 50 rpm's with 7k torque with 10%out flow. Loss rate of 22/36 bph with 11.7+ppg MW. and Max gas at 2,200 units. ROT wt= 183k 13:00 14:30 1.50 6,925 7,473 INTRM1 DRILL REAM T Wash and ream the hole from 6,925-ft to 7,473-ft circulating at 174 gpm at 490 psi with 9%out flow. Rotating at 50 rpm with 11 k torque. UP wt=220k SO wt=150k with 25 bph losses. 14:30 18:30 4.00 7,473 7,473 INTRM1 DRILL CIRC T CBU while rotating and reciprocating at 50 rpm's with 11 k torque from 7,473-ft MD to 7,401-ft MD, circulating at 144 gpm at 430 psi with 8%out flow. Losses at 50 bph with 1,800 units of gas. ROT wt= 185k, PU wt=220k and SO wt= 150k. Page 17 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 00:00 5.50 7,473 5,601 INTRM1 DRILL CIRC T Close annular with bit at 7,462-ft MD and open HCR Choke holding 35 psi back pressure and pump 180 bbls of 16.0 ppg mud in three 60 bbl stages at 128 gpm at 340 psi and displace to bit each stage. Each stage pump out of the hole with 624-ft of DP f/ 7,462-ft MD to 5,601 -ft MD at 2.6 bpm while POOH at 27 fpm. SPR at 7,473-ft MD 5,318-ft ND MW=11.7 ppg Pump#1 at 30 spm at 380 psi Pump#1 at 40 spm at 480 psi Pump#2 at 30 spm at 390 psi Pump#2 at 40 spm at 490 psi 04/26/2011 Pump 30 bbls of 16.0 ppg mud and displace to bit w/69 bbls of 11.8 ppg mud with annular closed, holding 35 psi back pressure with choke at 128 gpm at 340 psi. Pump out out of the hole f/5,601-ft MD to 4,937-ft MD. Close annular and establish inj. rate at 5 bpm at 520 psi w/SICP of 60 psi. Pump out of the hole to 4,747-ft MD and CBU. Conduct exhale test and start staging in the hole 190-ft intervals and CBU from 4,747-ft MD 00:00 02:15 2.25 5,601 4,937 INTRM1 DRILL CIRC T Pump 30 bbls of 16.0 ppg mud and displace to bit w/69 bbls of 11.8 ppg mud with annular closed, holding 35 psi back pressure with choke at 128 gpm at 340 psi. Pump out out of the hole f/5,601-ft MD to 4,937-ft MD. 02:15 02:30 0.25 4,937 4,937 INTRM1 DRILL CIRC T Close annular and establish inj. rate at 5 bpm at 520 SPP and 60 SICP for 30 bbls with 11.9 ppg MW. bbls SSP SICP 5 500 45 10 500 50 15 520 50 20 510 55 25 520 55 30 520 60 02:30 05:00 2.50 4,937 4,747 INTRM1 DRILL CIRC T Pump out of the hole with 2 stds.to 4,747-ft MD;4,055-ft ND. Rotate and reciprocate at 50 rpm's with 8k torque from 4,747-ft MD to 4,652-ft MD while CBU at 168 gpm at 430 psi,checking for 16.0 ppg mud returns.-Never seen ave.MW= 11.8 with Max Gas at 1,600 units. Continue to Circulate at 126 gpm at 300 psi. Rotating and reciprocating at 50 rpm's with 8k torque. Lost 184 bbls in 2.5 hrs, Prepare to pump 50 bbls of 55 ppb LCM pill. 05:00 07:00 2.00 4,747 4,747 INTRM1 DRILL CIRC T Pumping 50 bbl(35 ppb)LCM pill at 142 gpm at 317 psi, rotating and reciprocating. MW in=11.8 ppg, MW out=12.01 ppg. Losses up to 95 bph. Also adding nut plug and LCM to active system. Page 18 of 29 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 07:00 14:00 7.00 4,747 4,747 INTRM1 DRILL CIRC T Reduce circulation rate to 123 gpm at 300 psi with 6%flow out while rotating and reciprocating at 50 rpm's with 7k torque. After LCM pill was circulated losses decreased to 66 bph with gas units at 200 to 300. Continue to circulate and condition mud system for losses. At 11:20 hrs flow check for 10 minutes, monitoring returns to trip tank-5 bbl gain with gas units at 200. Contninue to circulate and condition mud system for losses at 212 gpm at 460 psi with 10%outfklow. Max gas was at 800 units. Had zero losses from 13:00 to 14:00 hrs. 14:00 18:00 4.00 4,747 4,747 INTRM1 DRILL OWFF T Conduct exhale test-shut bag and open HCR choke=monitor well. (50 psi SIDP 50 psi SICP),After 30 minutes(30 psi SIDP 47 psi SICP) Open super choke and monitor gains every 10 minutes. 5.75 bbls gain after 3 hrs. Open annular and monitor well -Breathing. 18:00 21:30 3.50 4,747 4,747 INTRM1 DRILL CIRC T Circulate bottoms up at 128 gpm at 310 psi with 6%out flow while rotating and reciprocating at 50 rpm's with 7k torque. Max gas=2,200 units. Losses at 50 bph. 21:30 00:00 2.50 4,747 4,936 INTRM1 DRILL TRIP T Stage in the hole 2 stands at a time from 4,747-ft MD to 4,936-ft MD while circulating out 16.0 ppg mud at 123 gpm at 330 psi with 6%flow return. Rotating and reciprocating at 50 rpm's with 7k torque with 50 bph losses and Max gas=298 units. SPR at 4,747-ft MD,4,055-ft ND with 11.8 ppg MW VVV Pump#1 at 30 spm at 270 psi Pump#1 at 40 spm at 350 Pump#2 at 30 spm at 280 psi Pump#2 at 40 spm at 360 04/27/2011 Continue to staging in the hole 190-ft intervals circulating out 16 ppg from 4,747-ft MD to 5,693-ft MD, Losses increased to 185 bph. Pump LCM pill. Circulate across the top with zero losses. Pump 85 bbl form a pill and spot from 5,221-ft to 4,295-ft MD. Attempt to squeeze to max allowable pressure of 100 psi with only 7 bbls pumped. Lost 60 psi in 1 hr. 00:00 02:00 2.00 4,936 5,125 INTRM1 DRILL TRIP T Continue to stage in the hole 2 stands(190-ft)at a time from 4,936-ft MD to 5,125-ft MD while circulating out 16.0 ppg mud at 126 gpm at 330 psi with 6%flow return. Rotating and reciprocating at 50 rpm's with 7k torque with 41 bph losses and Max gas=325 units. Page 19 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 04:30 2.50 5,125 5,315 INTRM1 DRILL TRIP T Continue to stage in the hole 2 stands(190-ft)at a time from 5,125-ft MD to 5,315-ft MD while circulating out 16.0 ppg mud at 128 gpm at 330 psi with 6%flow return. Rotating and reciprocating at 50 rpm's with 7k torque with 30 bph losses and Max gas=1,248 units. 04:30 07:30 3.00 5,315 5,505 INTRM1 DRILL TRIP T Continue to stage in the hole 2 stands(190-ft)at a time from 5,315-ft MD to 5,505-ft MD while circulating out 16.0 ppg mud at 128 gpm at 380 psi with 4%flow return. Rotating and reciprocating at 50 rpm's with 7k torque with 120 bph losses and Max gas=1,250 units. 07:30 09:00 1.50 5,505 5,693 INTRM1 DRILL TRIP T Continue to stage in the hole 2 stands(190-ft)at a time from 5,505-ft MD to 5,693-ft MD while circulating out 16.0 ppg mud at 123 gpm at 330 psi with 1%flow return. Rotating and reciprocating at 50 rpm's with 7k torque with 185 bph losses and Max gas=900 units. 09:00 11:00 2.00 5,693 5,693 INTRM1 DRILL CIRC T Pump 50 bbl of 50 ppb LCM pill while continuing to CBU at 123 gpm at 330 psi with losses at 156 bph with ave. gas units=900+. Build 2nd LCM Pill on location,flow began to increase to 3%with LCM pill in annulus then fell back to 1%-losses not improving. 11:00 12:00 1.00 5,693 5,693 INTRM1 DRILL OWFF T Blow down top drive and monitor hole volume on trip tank for loss rate. 12:00 12:30 0.50 5,693 5,693 INTRM1 DRILL CIRC T Establish loss rate at 84 gpm at 330 psi with 1%out flow while rotating at 50 rpm with 7k torque. UP wt= 210k,SO wt=165k with losses of 110 bph. 12:30 14:00 1.50 5,693 5,693 INTRM1 DRILL CIRC T Circulate across top of hole and monitor static losses of 6 bph. 14:00 15:00 1.00 5,693 5,221 INTRM1 DRILL TRIP T Pump out of the hole from 5,695-ft MD to 5,221-ft MD at 84 gpm at 330 psi with 1%out flow while rotating at 50 rpm's with 7k torque. UP wt= 205k,SO wt=160k and ROT wt= 183k. Lost 21 bbls. 15:00 19:00 4.00 5,221 5,221 INTRM1 DRILL CIRC T Circulate across top of hole and monitor static losses of 0 bph. Page 20 of 29 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 19:00 22:00 3.00 5,221 4,295 INTRM1 DRILL CIRC T Held PJSM and pump 85 bbls of 11.8 ppg Form-a-block and chase with 6 bbls of 11.8 ppg mud.at 105 gpm at 360 psi with 1%flow back rotating at 30 rpm's with 9k torque. ROT wt= 180k and spot pill at bit. Pump out of the hole laying pill from 5,221-ft MD to 4,295-ft. Pumping at 109 gpm pulling speed of 30 ft.min. With max gas=200 units. 22:00 00:00 2.00 4,295 4,295 INTRM1 DRILL OTHR T Blow down top drive and RU squeeze equipment. Perfom squeeze as per procedure-squeeze until SICP= 100 psi, SIDPP=90 psi with 7 bbls away. Shut down pumping ops. Monitor SI pressures of 60 psi SICP and 40 psi SIDPP for 2 hrs. Recording pressures every 5 minutes. 15 minutes=30 psi SIDDP and 45 psi SICP 30 minutes=30 psi SIDDP and 40 psi SICP 45 minutes=30 psi SIDDP and 40 psi SICP 60 minutes=30 psi SIDDP and 40 psi SICP 04/28/2011 Continue Form a block squeeze @ 4925'MD.Total of 45 BBLS. Pull back to 4203'.Attempt to establish circulation,staging pumps at 3 BPM.Minimal returns. Pull back to 4194'MD.Observed 38 BBLS gain. Pump 50 BBLS LCM pill,4600 strokes,with 40-50 BBL/HR losses.Monitor well-Breathing.TIH on elevators to 6165'MD.Circulate with losses up to 100 BBLS.Shut down monitor well.Continue TIH on eleavtors to 7473' MD. RU Schlumberger cementers,build Biozan pill,and load same on truck. Held PJSM for cemeting job. 00:00 01:30 1.50 4,295 4,295 INTRM1 DRILL OTHR T Continue to last hr of monitoring squeeze pressure. Perfom squeeze as per procedure-squeeze until SICP= 100 psi,SIDPP=90 psi with 7 bbls away. Shut down pumping ops. Monitor SI pressures of 60 psi SICP and 40 psi SIDPP for 2 hrs. Recording pressures every 5 minutes. 75 minutes=30 psi SIDDP and 35 psi SICP 90 minutes=30 psi SIDDP and 35 psi SICP 105 minutes=30 psi SIDDP and 35 psi SICP 120 minutes=30 psi SIDDP and 35 psi SICP Page 21 of 29 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 01:30 02:30 1.00 4,295 4,295 INTRM1 DRILL OTHR T Perform squeeze as per procedure- squeeze until SICP=95 psi,SIDPP =80 psi with 15 bbls away. Shut down pumping ops. Monitor SI pressures of 65 psi SICP and 30 psi SIDPP for 1/2 hrs. Recording pressures every 5 minutes. 5 minutes=30 psi SIDDP and 65 psi SICP 10 minutes=30 psi SIDDP and 45 psi SICP 15 minutes=30 psi SIDDP and 40 psi SICP 20 minutes=30 psi SIDDP and 40 psi SICP 25 minutes=30 psi SIDDP and 40 psi SICP 30 minutes=30 psi SIDDP and 40 psi SICP 02:30 03:30 1.00 4,295 4,295 INTRM1 DRILL OTHR T Perform squeeze as per procedure- squeeze until SICP=65 psi, SIDPP =0 psi(possible plug)with 15 bbls away. Shut down pumping ops. Monitor SI pressures of 65 psi SICP and 0 psi SIDPP for 1/2 hrs. Recording pressures every 5 minutes. 5 minutes=0 psi SIDDP and 50 psi SICP 10 minutes=0 psi SIDDP and 45 psi SICP 15 minutes=0 psi SIDDP and 45 psi SICP 20 minutes=0 psi SIDDP and 40 psi SICP 25 minutes=0 psi SIDDP and 40 psi SICP 30 minutes=0 psi SIDDP and 40 psi SICP Page 22 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:30 1.00 4,295 4,295 INTRMI DRILL OTHR T Perform squeeze as per procedure- squeeze until SICP=50 psi,SIDPP =210psi(cleared plug)with 15 bbls away. Shut down pumping ops. Monitor SI pressures of 65 psi SICP and 75 psi SIDPP for 1/2 hrs. Recording pressures every 5 minutes. 5 minutes=75 psi SIDDP and 50 psi SICP 10 minutes=75 psi SIDDP and 45 psi SICP 15 minutes=75 psi SIDDP and 45 psi SICP 20 minutes=75 psi SIDDP and 40 psi SICP 25 minutes=65 psi SIDDP and 40 psi SICP 30 minutes=60 psi SIDDP and 35 psi SICP 04:30 05:00 0.50 4,295 4,203 INTRM1 DRILL OTHR T Decision to Rig down pumping equipment. Rack back 1 stand. Bit depth=4203'. 05:00 06:00 1.00 4,203 4,194 INTRMI DRILL CIRC T Attempt to establish circulation, staging pumps to 3 BPM with minimal returns. 17 BBLS pumped away.Shut down. Blow down Top Drive&lines. Pull back to 4194'. 06:00 11:30 5.50 4,194 4,194 INTRM1 DRILL OWFF T Monitor well on Trip Tank.Observed 38 BBLS gained. 11:30 12:00 0.50 4,194 4,194 INTRM1 DRILL CIRC T Pumped 50 BBLS of 35 PPB LCM pill @ 123 GPM's-400 PSI. Fluid loss= 100 BPH.Crew Change. 12:00 14:00 2.00 4,194 4,194 INTRM1 DRILL CIRC T Continue pump 50 BBLS of 35 PPB pill. Reciprocate&rotate drill string with 40 RPM's. Pumps at 123 GPM's -400 PSI. Pumped a total of 4600 strokes with losses now at 40-50 BPH. 14:00 15:00 1.00 4,194 4,194 INTRMI DRILL OWFF T Monitor well. Observed breathing with pit gains of 11 BBLS. 15:00 16:00 1.00 4,194 6,165 INTRM1 DRILL TRIP T Trip in hole on elevators from 4194'- 6165'MD. UP WT-210K,SO WT- 155K. No issues on TIH. 16:00 18:00 2.00 6,165 6,165 INTRM1 DRILL CIRC T Establish circulation rate with 50 BBLS LCM pill, @ 84 SPM-380 PSI. Reciproccate&rotate drill string. MAx gas observed-1100 units. Lost 100 BBLS. Shut down pumps. 18:00 18:30 0.50 6,165 6,165 INTRM1 DRILL OWFF T Monitor well.Static. 18:30 21:00 2.50 6,165 7,473 INTRM1 DRILL TRIP T Trip in hole to 7473'MD,slow string speed. UP WT-210K,SO WT- 155K. No issues going in hole. Page 23 of 29 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 21:00 22:00 1.00 7,473 7,473 INTRMI CEMEN-CMNT T Lay down single. Pick up pup for space out to set bit on bottom. Rig up cementing lines. RU •Schlumberger Cementers. 22:00 22:30 0.50 7,473 7,473 INTRM1 CEMEN"SFTY T Held PJSM with crew&cementers. Discuss safety&hazard recognition issues. Discuss proceduure to pump cement job. 22:30 00:00 1.50 7,473 INTRMI CEMEN"CMNT T Build BIOZAN pill and load same on truck. Prep pits and trucks for job. 04/29/2011 Line up,and batch mix. Pump 15 BBLS of 12.5 PPG Mud Push II.Test lines.Continue pump 66.71 BBLS of 15.9 PPG GasBlok cement chase with 2 BBLS H2O. Continue displace with 11.9 PPG Mud for 115 BBLS, cementing drill string in place at 7473'MD.Shut Down. RD Lines.Stab Valve.WOC. RU HES E-Line.Make up&run Cutter to 6225'.Cut DP. Rotate 7 turns to left to release&verify DP free.Attempt to establish circulation with no returns. POOH to 6160'MD. Monitor well-Build 50 BBLS of LCM pill.Circulate over top of hole monitoring well.Static-no losses. RU Schlumberger. RIH to position DP end at 6220'MD. Mix&pump 50 BBL LCM pill.20 BBLS of mud, 15 BBLS od mud push,and 89 BBLS of 16.0PPG Cement. Drop DP wiper ball&chase cement with 75 BBLS of mud.Catch cement after 47 BBLS pumped away. Observed returns only 33 BBLS while pumping job. 00:00 01:30 1.50 7,473 7,473 INTRMI CEMEN'CMNT T Line up,and batch mix. Pump 15 BBLS of 12.5 PPG Mud Push II.Test lines to 3500 PSI. Continue pump 66.71 BBLS of 15.9 PPG GasBlok cement chase with 2 BBLS H2O. Continue displace with 11.9 PPG Mud for 115 BBLS,cementing drill string in place at 7473'MD. Observed only 37 BBL returns during job.Max gas-985 units.Shut Down. CIP @ 0130 HRS. RD Lines.Stab Valve. 01:30 10:00 8.50 7,473 7,473 INTRM1 CEMEN"WOC T Wait on Cement.Circulate over top of hole to monitor well.. Load&strap 3 1/2"PH-6 tbg in pipe shed. 10:00 11:30 1.50 7,473 7,473 INTRM1 DRILL ELNE T Rig up Halliburton E-line Service. Hang sheaves. Held PJSM with crew &HES reps. Discuss saefty& hazard recognition issues. Discuss precdure to make up cutting assembly and Wireline ops. 11:30 12:00 0.50 7,473 7,473 INTRM1 DRILL ELNE T Wireline in hole with DP cutter assembly. Monitor well circulating over top of hole.Crew Change 12:00 13:00 1.00 7,473 7,473 INTRMI DRILL ELNE T Conitnue wireline in hole to Iodate cutter on a tool joint at 6225'. Pull drill string to 20%of upweight as per HES reps. Close annular. Fire cutter. Check for trapped pressure, and open bleeder valves. 13:00 14:15 1.25 7,473 7,473 INTRM1 DRILL ELNE T Wireline out of hole. Check cutter assembly verifying good fire. 14:15 15:00 0.75 7,473 7,473 INTRM1 DRILL ELNE T Rig down sheaves and HES wireline crew. Page 24 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 15:30 0.50 6,225 6,160 INTRMI DRILL OTHR T Pick up drill string to 220K,and slack off to 180K. Repeat numerous times. Drill pipe not free. Rotate 7 left hand turns in string to pull free at 230K. Drill pipe free.with new up weight at 195K,SO weight=155K. Continue POOH to 6160'. 15:30 16:00 0.50 6,160 6,160 INTRMI DRILL CIRC T Attempt to break circulation pumping at 2 BPM-no returns. Blow down Top Drive&lines. 16:00 17:15 1.25 6,160 6,160 INTRM1 DRILL OWFF T Circulate over top of hole monitoring well. No losses-static. Build 50 BBLS of LCM pill. 17:15 18:30 1.25 6,160 6,160 INTRM1 DRILL CIRC T Pump down Drill string attempting to establish returns with none observed at 2 BPM-330 PSI. UP WT 195K, SO WT-155K. Pumped 100 BBLS. Schlumberger Cementers on Location. 18:30 19:15 0.75 6,160 6,225 INTRM1 CEMEN'CMNT T TIH with 2 joints to position DP end at 6225. Rig up cementers and lines to DP. Blow down Top Drive. 19:15 19:30 0.25 6,225 6,225 INTRM1 CEMEN"CMNT T Monitor well.Continue RU cementers. 19:30 20:00 0.50 6,225 6,225 INTRM1 CEMEN'SFTY T Held PJSM with crew&cementers. Discuss safety&hazard recognition issues. Discuss proceduure to pump cement job. 20:00 22:00 2.00 6,225 6,225 INTRM1 CEMEN-CMNT T With rig-Pump 50 BBL LCM pill, and 20 BBLS of 11.9 mud.Turn over to Schlumberger&continue with 15 BBLS of 12.5 Mud Push II.Test lines to 3500 PSI.Good test. Pump 89 BBLS of 16 PPG cement, and 2 BBLS of H2O. Drop Drill pipe wiper ball.With rig,displace cement with 75 BBLS,keeping 1400 ft of cement in DP.Observed 47 BBLS pumped before cathing cement.Observed only 33 BBLS of returns during job. Max Gas observed=1250 units.CIP at 22:15 HRS. 22:00 22:30 0.50 6,225 6,225 INTRM1 CEMENT CMNT T Rig down cement lines,and head pin.Observed DP on a strong vacuum. 22:30 00:00 1.50 6,225 4,991 INTRM1 DRILL TRIP T POOH slow from 6225'-4991'MD, observing flow on annulus from well, and possible swabbing from DP cut, allowing cement to fall out of DP until annulus staying static. UP WT- 178K, SO WT-148K.Crew Change Page 25 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/30/2011 24 hr Summary At 4991'MD,Circulate at 2 BPM-200 PSI,with no returns to clear DP. Reciprocate DP to ensure free of cement. Monitor well circulating over top of hole-static losses.WOC-RIH to tga hard cement after 14 hrs. Set down 15K.Tag witnessed by AOGCC rep Chuck Sheve.Circulate while wait on cementers. RU Schlumberger. RIH to position DP end at 5630'MD.Mix&pump 50 BBL LCM pill.20 BBLS of mud, 15 BBLS od mud push,and 95 BBLS of 15.8 PPG Cement. Drop DP wiper ball&chase cement with 70 BBLS of mud. Catch cement after 47 BBLS pumped away.Observed returns almost 1 for 1 while pumping job.Observed 3800 max gas units while pumping. POOH on elevators at 25 ft/min. back to 4250'MD>Circulate bottoms up at 3 BPM-240 PSI. No losses/gains.Observed cement contaminated fluid at surface on bottoms up. 00:00 01:00 1.00 4,991 4,991 INTRM1 DRILL CIRC T At 4991'MD,Circulate at 2 BPM- 200 PSI,with no returns to clear DP. Reciprocate DP to ensure free of cement. 01:00 07:30 6.50 4,991 4,991 INTRM1 DRILL WOC T Monitor well circulating over top of hole-static losses. 07:30 07:45 0.25 4,991 4,991 INTRM1 DRILL CIRC T Condtion mud, pumping a slug to balance mud system. 07:45 08:45 1.00 4,991 4,991 INTRM1 DRILL TRIP T RIH from 4991'-5686'.Tagged soft green cement. POOH to 4991'.Tag witnessed by AOGCC rep Chuck Sheve. 08:45 12:00 3.25 4,991 4,991 INTRM1 DRILL WOC T WOC.Take on 100 BBLS of mud. Crew Change 12:00 13:00 1.00 4,991 5,630 INTRM1 DRILL TRIP T Trip in hole to tag hard cement at 5630',after wahing down from 5576 in soft green cement.Set down wt= 15K.Tag witnessed by AOGCC rep Chuck Sheve. 13:00 13:30 0.50 5,630 5,207 INTRM1 DRILL TRIP T Pump out from 5630'-5207',at 2 BPM-240 PSI. 13:30 17:30 4.00 5,207 5,207 INTRM1 DRILL CIRC T Circulate at 2 BPM-240 PSI.Max gas observed-2150 units. 17:30 18:00 0.50 5,207 5,207 INTRM1 DRILL OWFF T MOnitor well-observed 6 BBL gain in pits. 18:00 18:30 0.50 5,207 5,630 INTRM1 DRILL TRIP T Trip in hole back to 5630'. 18:30 19:00 0.50 5,630 5,630 INTRMI CEMEN"RURD T RU Schlumberger cementers. RU lines and valves to DP for cement job. 19:00 19:15 0.25 5,630 5,630 INTRM1 CEMEN"SFTY T Held PJSM with crew&cementers. Discuss safety&hazard recognition issues. Discuss proceduure to pump cement job. 19:15 20:45 1.50 5,630 5,630 INTRM1 CEMEN"CMNT T With rig-Pump 50 BBL LCM pill, and 20 BBLS of 11.9 mud.Turn over to Schlumberger&continue with 15 BBLS of 12.5 Mud Push II.Test lines to 3000 PSI.Good test. Pump 95 BBLS of 15.8 PPG cement,and 4 BBLS of H2O. Drop Drill pipe wiper ball.With rig,displace cement with 70 BBLS,Observed 47 BBLS pumped before catching cement. Observed 1 for 1 returns during job. Max Gas observed=3800 units.CIP at 20:45 HRS. Page 26 of 29 Time Logs Date From To Dur S. Death E.Death Phase Code Subcode T Comment 20:45 21:00 0.25 5,630 5,630 INTRM1 CEMENT RURD T Rig down cement lines,and head pin. Observed DP on a strong vacuum. 21:00 22:30 1.50 5,630 4,250 INTRM1 DRILL TRIP T POOH slow from 5630'-4250'MD, observing no flow on annulus from well,allowing cement to fall out of DP until annulus staying static. UP WT-165K,SO WT-140K. 22:30 00:00 1.50 4,250 4,250 INTRM1 DRILL CIRC T Circulate bottoms up,at 3.5 BPM- 240 PSI. MAx gas observed-1800 units. No losses. Observed cement contaiminated fluid at surface on bottoms up.Crew change 05/01/2011 POOH,pumping out. Lay down Cut Joint. RU&test BOP's. Install Test plug.Test BOP's.Observed slight flow on annulus. Rig down testing equipment.TIH with cement retainer. Set same at 2531'. RU Schlumberger. Pump 45 BBLS of cement squeezing 15.8 ppg cement below retainer,and leave 5 BBLS above. POOH, lay down DP. RU&test upper pipe rams&annular with 4 1/2"test joint.Witness of test waived by AOGCC rep. Rig down equipnment. RU to run 4 1/2"Kill string. 00:00 00:15 0.25 4,250 4,250 INTRM1 DRILL CIRC T Continue criculate at 3.5 BPM-220 PSI.Observed cement coaminated fluid on bottoms up. 00:15 01:00 0.75 4,250 4,074 INTRMI DRILL TRIP T POOH on elevators,observing swabbing conditions,and improper hole fill. 01:00 05:00 4.00 4,074 1,420 INTRMI DRILL TRIP T Continue pump out of hole from 4074' -1420'.with pumps at 2 BPM-210 PSI. 05:00 06:30 1.50 1,420 0 INTRMI DRILL TRIP T POOH on eleavtors observing proper displacement. 06:30 08:00 1.50 0 0 INTRM1 DRILL OWFF T Observed slight flow in well. Pull WB. Monitor well on trip tank. Drain stack. Install test plug. 08:00 09:00 1.00 0 0 INTRM1 WHDBO SFTY T Held PJSM. Discuss safety&hazard recognition issues. Discuws procedure to RU&test BOP's. Continue monitor annulus. 09:00 10:30 1.50 0 0 INTRM1 WHDBO BOPE T test Annular to 250/2500 PSI. Observed continual flow from annulus. 10:30 11:15 0.75 0 0 INTRM1 WHDBO RURD T Rig down test equipment. Pull test plug. 11:15 11:45 0.50 0 0 INTRM1 CEMENT PULD T Make up BOt 10 3/4"Cement retainer and crossover. 11:45 12:00 0.25 0 481 INTRM1 CEMENT TRIP T Trip in hole with cement retainer. Slight flow in well bore.Crew Change 12:00 13:00 1.00 481 2,531 INTRM1 CEMENT TRIP T Continue trip in hole with cement retainer to 2531'MD. UP WT= 125K,SO WT= 120K. 13:00 14:00 1.00 2,531 2,531 INTRM1 CEMENT CMNT T Locate&set retainer at 2531'MD. Pull up 1'. Pressure test casing to 2500 PSI for 10 minutes,on chart- good test. 14:00 15:30 1.50 2,531 2,531 INTRM1 CEMENT CIRC T Blow down Top drive&lines.Make up Head pin and cement lines. RU Schlumberger. Pick up out of retainer.Circulate at 5 BPM-260 PSI. Observed 900 units of gas. Page 27 of 29 Time Logs Date From To Dur S.Death E.Depth Phase Code Subcode T Comment 15:30 17:00 1.50 2,531 2,315 INTRM1 CEMEN'CMNT T Sting into retainer. Establish injection rate at 3 BPM-650 PSI. Turn over to Schlumberger. Pump 5 BBLS of 12.5 PPG Mud Push. Pressure test lines to 3000 PSI. Pump 45 BBLS of cement,and 4 BBLS of H2O.With Rig Displace with 36 BBLS of 11.8 PPG mud. Pull stinger and pump to leave 5 BBLS of `/ cement above reatiner. POOH to 2315'MD.CIP @ 1640 HRS 17:00 17:45 0.75 2,315 2,315 INTRM1 CEMEN"CIRC T Circulate bottoms up at 6 BPM-230 PSI,observing no cement returns. Mix& um 15 BBLS dryjob. P P 17:45 21:00 3.25 2,315 0 INTRM1 DRILL TRIP T Blow down Top drive&lines. POOH laying down 5"DP. Lay down running tools. 21:00 22:00 1.00 0 0 INTRM1 WHDBO BOPE T Pull wear bushing.Set test plug. Rig up to test rams. Install 4 1/2"test joint. 22:00 22:45 0.75 0 0 INTRM1 WHDBO BOPE T Test upper pipe rams and annular with 4 1/2"test joint to 250/3500 PSI.Witness of test waived by AOGCC rep. 22:45 23:30 0.75 0 0 INTRM1 WHDBO BOPE T Pull test joint&plug. Rig down test equipment and lines. Blow down same. 23:30 00:00 0.50 0 0 INTRM1 DRILL RURD T Clean&clear rig floor. Prep rig floor to run 4 1/2"Kill string. 05/02/2011 PJSM-Run 4 1/2"Kill String. Rig up and run 58 Jont 4 1/2"Kill string. Land Tbg hanger. RILDS. Install TWC. ND BOP's. NU Dry Hole tree.Test same. Pull TWC. RU&pump 35 BBLS spacer followed with 175 BBLS of Freeze protect diesel down annulus with returns through the tubing.Continue clean pits and rockwasher,prep for move. Install BPV.Test same with Little Red to 1000 SI.Secure tree and cellar. 00:00 00:30 0.50 0 0 INTRMI DRILL SFTY T Held PJSM with crew and casing rep. Discuss safety&hazard recognition issues. Discuss procedure to rig up and run 4 1/2"tbg kill string. 00:30 01:00 0.50 0 0 INTRM1 DRILL RURD T Rig up tubing running equipment. Install tongs,slips and elevators. 01:00 03:45 2.75 0 1,826 INTRMI DRILL RCST T Pick up 4 1/2"IBTM tbg from shed, and run in hole with 58 joints.Make up TQ=3500 ft/lbs. Install hanger and landing joint. 03:45 04:45 1.00 1,826 1,826 INTRM1 WHDBO RCST T RIH, land tubing hanger. RILDS. Pull &lay down landing joint. Install BPV. 04:45 16:30 11.75 0 0 INTRM1 WHDBO NUND T Nipple down BOP stack,choke&kill lines. Break all bolts on each spool with sweeny wrench.Wasah&clean out BOP stack. 16:30 19:30 3.00 0 0 INTRM1 WHDBO NUND T Prep Dry Hole tree and adapter flange. Install same.Tighten up with sweeny wrench. 19:30 20:30 1.00 0 0 INTRM1 WHDBO PRTS T Rig and test hanger seal to 5000 PSI -10 minutes as per FMC rep. Fill tree with diesel and test same to 2450/5000 PSI. Record on chart. Page 28 of 29 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 20:30 21:00 0.50 0 0 INTRM11DRILL OWFF T Verify no pressure under TWC. Pull _TWC. 21:00 21:30 0.50 0 0 INTRM1 DRILL SFTY T Held PJSM with crew, FMC,and Little Red reps. Discuss safety& hazard recognition issues. Discuss procedure to pump freeze protect diesel in the well. Designate a Spill _Champion. 21:30 00:00 2.50 0 0 INTRM1 DRILL FRZP T With rig,pump 35 BBLS of 11.8 PPG spacer down annulus ar 2 BPM -140 PSI. RU Little Red,and pump 180 BBLS of freeze protect diesel down annulus at 2 BPM-140 PSI. Take returns to cellar and utilize vac truck to pull returns. 05/03/2011 • Install BPV. Use Little Red to pressure to 500 PSI testing BPV. Rig down lines.Secure tree.Clean out cellar box. Lay down 5"DP from derrick.Continue clean pits and rockwasher. Prep rig for Rig Move. Use vrane to off load Sperry Sun MWD shack,Mud Engineers shack,and Gold Room form roof of pit complex. Pull Centrifuge form Pit Room. 00:00 02:30 2.50 INTRM1 DRILL OTHR T Install BPV as per FMC rep. Utilize Little red services toP ressure under BPV 500 PSI for test. RD lines,and secure tree and cellar box. 02:30 08:00 5.50 INTRM1 DRILL PULD T Lay down 5"drill pipe form derrick. Continue clean pits and rockwasher. 08:00 12:00 4.00 INTRM1 DRILL DMOB T Continue clean pits and rockwasher. • 12:00 00:00 12.00 INTRM1 DRILL DMOB T Continue clean pits and rockwasher. Barite had settled out in all pits and had to be dug out. Rig released to move @ 2400 Hrs. Page 29 of 29 Nov ConocoPhillips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke,AT01808 TO: Christine Shartzen ConocoPhillips Alaska, Inc. AOGCC RECEIVED P.O. Box 100360 333 W. 7th Ave, Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501-3539 MAY 2 7 ,, RE: KRU 2L-322 AOGCC permit: 210-174-0 Mgt O& ;o Cans.Corlanission DATE: 5/24/2011 Ancderage Tr. mitt- .: Kuparuk River Unit, North Slope, Alaska 2L-322 CDRO Final Well report, Mud logging report, CANRIG;well 2L-322(501032062800) TOC, Equipment, well data, geological data, pressure/formation strength, drilling data, daily reports,formation logs color prints; !Formation log (MD) Formation log(TVD)` Gas ratio (MD)V/ Gas ratio (TVD)N/ LWD Combo (MD) LWD Combo (TVD) Drilling dynamics (MD)/ Drilling dynamics (TVD)I CDROM contains; daily reports, DML data, final well report, LAS files, mud log PDF files, remarks and tiff files ,Sign,scan and return in .pdf format if applicable to Sandra.D.Lemke i)Conocophillips.com CC: 2L-322 tra s ittal folder, production well files, eSearch Receipt: '� Date: (2 I4 V 1. ►- GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska (Ph: 907.265.6947 alb 17`y WELL LOG TRANSMITTAL To: State of Alaska May 6, 2011 Alaska Oil and Gas Conservation Commission Attn.: Christine Shartzer 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501-3539 RE: LWD Formation Evaluation Logs: 2L-322 AK-MW-0007742777 2L-322 50-103-20628-00 2"x 5" MD TRIPLE COMBO Logs: 1 Color Log 2"x 5" TVD TRIPLE COMBO Logs: 1 Color Log Digital Log Images&LDWG-formatted LIS Data w/verification listing; 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bryan.Burinda@halliburton.com Date: Signed: c90 SIEJE 11 nilASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GA' 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 David Nugent FAX (907)276-7542 Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 ` 0 Re: Kuparuk River Field, Tarn Oil Pool, 2L-322 Sundry Number: 311-149 Dear Mr. Nugent: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / Daniel T. Seamount, Jr. Chair 3 DATED this day of May, 2011. Encl. • STATE OF ALASKA c' -, '�"ECE1V , • ALASKA _AND GAS CONSERVATION COMMISSI .0 \PR 2 8 201) APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Alaska Oil&Gas Cans.Gaairn1SSI0A 1.Type of Request: Abandon r .k Plug for Redrill r Perforate New Pool r Repair w ell r Change Approyed Proggram r Suspend '`'3 11:m s ' G 7^' p � �JPlug Perforations r Perforate r Pull Tubing �"'' �irne��nsion r y14,n Operational Shutdown Re-enter Susp.Well r StimulateAlter casing g r Other:pha..,lsa IQA. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: 004, ConocoPhillips Alaska, Inc. Development 17 . Exploratory r 210-174 • 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20628-00 00 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No jN 2L-322 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 380052,380054 Kuparuk River Field/Tarn 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): 7473 5319 Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 120' 120' Surface 2573' 10.75" 2613' 2358' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none none none - - Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no packer no SSSV 12.Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory E Development r Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: . 4/28/2011 Oil r Gas r WDSPL r Suspended 17 16.Verbal Approval: Date: vb /ii WINJ r GINJ r WAG r Abandoned r Commission Representative: 6 7 ,s c ti,.J t ie.-, GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Nugent @ 263-4228 Printed Name David Nugent/(,,,,, Title: Drilling EngineerWa///( Signature 4,0a ,- Phone:263-4228 Date Commission Use Only /y Sundry Number:3)i..... 1 . y At( Conditions of approval: Notify Commission so that a representative may witness Plug Integrity BOP Test r Mechanical Integrity Test r Location Clearance r Other: N0 4'' / —t-:svegh'r 4.r inJ: e, ,0 Subsequent Form Required: /6_YO7 APPROVED BY / Approved by: f COMMI81 tvSSIONER THE COMMISSION Dates/J// / Form 10-403 Revised 1/ 010 0R1 tAY 0 4 Z0 Y•Zg•// Submit in Dapli J�atL-7-'ii I f g„ ,7 ry Rig Procedure 1. TIH with the drill string to TD (7,473' MD). 9°° 2. Pump cement through the bit. Leave approximately)ieet of cement in the annulus and inside the drill string (approximatelt.25frof cement above the source tool). --'r h!;0 Cock..^ eer 75a 6K" 3. Cut or backoff the drill string at approximately 6 MD. G 3ab 4. Lay balanced plug(s). Cement to be spotted from 6,400' MD to 5,630' MD. 064- 5. Wait on cement and tag plug. ---a IO v 77 r`r /e` kfheSs• 6. Lay balanced plug(s). Cement to be spotted from 5,630' MD to 4,900 MD. Ceo.•-A. J 7. Reduce mud weight to 10.5 ppg. — '-t- 23)'(l) ,v.et.Qj,0. 8. POOH. 9. RIH with retainer. 10. Set retainer at 2,550' MD (approximately 63' above the 10-3/4"casing shoe). 11. Squeeze cement below retainer from 2,900'to 2,550' MD. 12. Set 50' of cement on top retainer. 13. Run kill string in hole. 14. Install dry hole tree 15. Move off well. • • . CoAoc. PA,i ,( - /41 ,,4 _c,.., --LA_c_ -.r.P4-A • .2 tcs-ot fro R.e.4-gt t#..•t e' 2, r3tio-5 A at, A A ik.- /0 - C 3SIA, . .4 A A . C,,E01 E.Ao*C-4, ii. o2)cf°34D.it't 0 4 AA 4 1 4 ro 5 cpo i,•.-q-2. .-F CIL.,,,„,„‘ , - — -- -- , .R,900' ivi i, ,. ( t ( ) ‘ : I \ Ct‘ S c.-s--, ,, . 4 2Fs' MD. t 3 4,,FP' -rtit I 1.1 I \ k, .i i - "roe 0 f C...-40 \ \ • ,, ., • -r ill it,/5 N / N 11/ Si 0 of',1 _ __ -' - - 4, •A? DD .' 4 „.•"' .,; A-c, 4.?.. ' e•th Or '''' , N 4 _--_,‘.c--- A - 6,c pi 0, --7---------• / •,,.._ — — —— # , / #1 • - ,. z 7-"3 i / 8/ fje_ //r ./'" N ''''••,;"`\ l'04 4.4, 0 , ,.., ri a xi' •-ry I -..\ .\----.- 6 -1111111110t ( I._• fitet(-- . . r C=4' ..., .,,, , AA x HALLIBURTDN I Sperry °rifling Length Length (ft) (ft) BHA Schematic ., jY 6 3/4"POS � PULSER 10.01 ConocoPhillips Alaska, Inc 2L-322 rt BHA#: Flex Collar 31.00 Run #: 200 Drillstring: Drillstring 6 Colllarlar BAT , 23.40 MUM BHA Configuration - OD (in) Length (ft) Description 9.75 0.92 PDC 7.00 25.38 7"SperryDrill Lobe 7/8-6.0 stg 6 3/4"CTN 11.88 6.75 2.14 Float Sub .; Collar 4 £' 6.50 6.95 Integral Blade 6.75 8.83 Non-Mag 6 3/4"DM Collar ---.i "" 6.75 12.10 Non-Mag 6 3/4"EWR-P4 Collar Flex Collar 31.00 6.75 6.65 Non-Mag 6 3/4"DGR Collar 6.75 6.39 Non-Mag 6 3/4"PWD 6 3/4"ALD 14.54 6.75 4.97 Non-Mag 6 3/4"HCIM Collar Collar 6.75 14.54 Non-Mag 6 3/4"ALD Collar 6.75 11.88 Non-Mag 6 3/4"CTN Collar 6.75 23.40 Non-Mag 6 3/4"BAT Collar 6 3/4"HCIM 4.97 Wear Band i Collar Wear Band 6.90 10.01 Non-Mag 6 3/4"POS PULSER ._6 3/4"PWD6.39 6.50 31.00 Flex Collar MI 6.50 31.00 Flex Collar 6 3/4"DGR 6.50 31.00 Flex Collar Collar 6.65 5.00 92.00 5"X 3"HWDP#49.3-NC50(IF) Flex Collar i. 31.00 6.25 30.60 Jar t; 5.00 328.00 5"X 3"HWDP#49.3-NC50(IF) 6 3/4"EWR- P4 Collar 12.10 63/4"DM 883 Collar -. Integral Blade4, 6.95 Float Sub IL 2.14 7 SperryDrill Lobe 7/8-6.0 25.38 stg , PDC :. 0.92 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage,Alaska 99510-0360ConocoPhillips Telephone 907-276-1215 April 28, 2011 RECEIVED Alaska Oil and Gas Conservation Commission 1 333 West 7th Avenue, Suite 100 �i' Anchorage, Alaska 99501 Alaska Ott&Gas Gens.&emm'SSwfl Ancl}9raU Re: Sundry Permit: Request to Hole and BHA containing RA Source Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to permanently abandon the 2L-322 hole and drillstring, including a radioactive source contained within the drilling BHA. The proposed abandonment is a result of a well control event beginning April 20th, 2011 and continuing to the present time. After drilling to TD, the well began experiencing gas in the mud stream. The mud weight was raised but gas continued to be encountered in the mud stream. Partial loss of returns were encountered soon after raising the mud weight to approximately 11.7 ppg. Numerous attempts at stopping the lost circulation and reducing the amount of gas seen in the mud stream have been unsuccessful. We are not able to pull the drill sting out of the hole. CPAI proposes to temporarily plug and abandon this well as per the following procedure. The proposed abandonment plan has received approval from the Nuclear Regulatory Commission in regards to abandoning the radioactive source lost in the hole. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-403 2. Proposed abandonment program 3. Proposed abandonment schematic 4. 2L-322 BHA Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact David A. Nugent at 263- 4228 or Chip Alvord at 265-6120. Sincerely, David A. Nugent Drilling Engineer Page 1 of 1 Schwartz, Guy L (DOA) From: Nugent, David (Swift Technical Services LLC)[David.Nugent@contractor.conocophillips.com] Sent: Thursday, April 28, 2011 12:34 PM To: Schwartz, Guy L(DOA) Subject: 2L-322 Guy, I received the approval from the NRC to proceed with abandoning the source. So the cover letter I sent you with the sundry is now valid. David A. Nugent Swift Worldwide Resources ConocoPhillips Alaska ATO 1502 Anchorage, AK 907-263-4228 4/29/2011 Page 1 of 2 Schwartz, Guy L (DOA) Schwartz, L (DOA) GuyDO ( ) Sent: Friday, April 29, 2011 8:11 AM To: 'Nugent, David (Swift Technical Services LLC)' Cc: DOA AOGCC Prudhoe Bay Subject: RE: 2L-322 (PTD 210-174) Dave, Thank you for the explanation below... your abandonment plan is approved. You have verbal approval to proceed as outlined below. I will make the appropriate changes in the submitted sundry and attach the our emails for documentation. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Nugent, David (Swift Technical Services LLC) [mailto:David.Nugent@contractor.conocophillips.com] Sent: Friday, April 29, 2011 6:56 AM To: Schwartz, Guy L (DOA) Subject: RE: 2L-322 (PTD 210-174) Guy, Yes, our requirements from the NRC with the BHA in the hole is to leave a deflection device (drill pipe) above the BHA we cement in the hole. So we will pump enough cement on our first plug to cover the BHA and cover to the top of the Bermuda Sand (top of cement approximately 6,500' MD). Then we will go in with a severing charge and cut the drill pipe as deep as we can get in the string but at least 100 feet above the top of the cement. Because of the angle in the hole, I believe we will probably be able to make our cut 100 - 300 feet above the top of cement. So with the drill pipe stub sticking up above the top of cement, we will not be able to tag the first plug. We will then set our first open hole plug from where we make the cut to the base of the Iceberg Sand. This will put the top of cement at around 5,635' MD. We will then wait on cement and tag the plug. The plan continues as before with an open hole plug through the Iceberg, and a retainer set at the surface casing shoe and cement squeezed below it. Since we are not able to tag the first plug we set through the BHA, we ask for a variance on testing of that plug. We will test the first open hole plug we set (to the base of the Iceberg Sand) by tagging. David A. Nugent From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, April 28, 2011 4:41 PM To: Nugent, David (Swift Technical Services LLC) Subject: RE: 2L-322 (PTD 210-174) Dave, The explanation below is somewhat outdated now that we are planning on pumping cement around the BHA to just above the Bermuda. We won't be able to tag (or pressure test) that first plug so a variance will still be needed based on that fact. The paragraph on the possible mud weight change is still pertinent though. 4/29/2011 Page 2 of 2 Good luck on cementing when you get to that point. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Nugent, David (Swift Technical Services LLC) [mailto:David.Nugent@contractor.conocophillips.com] Sent: Thursday, April 28, 2011 3:19 PM To: Schwartz, Guy L (DOA) Subject: 2L-322 Guy, As per our recent phone conversation, we request a variance from the regulations to set a cement plug in the target Bermuda Sand in this well. Our BHA with the source will be at TD,and we are required by the NRC to place at least 200'of cement above the source and have some type of deflection device above the source tool. We will sever or back off the drill pipe above the BHA to serve as our deflection device in this well. Due to the high angles we have at TD, we have to come up the hole to get to a position where we believe we have a good chance to sever or back off the drill pipe. At 6,400' MD, we have an inclination of about 71 degrees. We believe we have a reasonable chance of being successful in severing our pipe at this point. This is above the top of the Bermuda Sand. We will have a cement plug from that depth to the base of the Iceberg Sand to isolate the two sands. This will be 770 feet of cement isolating the two sands. Another plug will be set through the Iceberg Sand. We also may cut the MW to 10.5 ppg from the 11.8ppg we now have in the hole after setting the plug in the Iceberg Sand. We believe one of our loss zones in this well is up the hole in the Campanian Sand near the 10- 3/4" shoe. If the hole is stable after setting the plug in the Iceberg, we will not reduce the MW. If we are still experiencing losses,we would like to cut the weight to help stabilize the hole. We would like a variance from the regulations to leave KWM in the hole if our hole conditions dictate we need a lower weight mud. We will test BOP's at our first opportunity when we get out of the hole. Let me know if you need anything else. David A. Nugent Swift Worldwide Resources ConocoPhillips Alaska ATO 1502 Anchorage, AK 907-263-4228 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, April 28, 2011 4:36 PM To: 'Nugent, David (Swift Technical Services LLC)' Subject: RE: 2L-322 (210-174) Dave, I agree... I will make the changes to the sundry outline and forward to the slope inspectors so are up to date on the latest. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Nugent, David (Swift Technical Services LLC) [mailto:David.Nugent@contractor.conocophillips.com] Sent: Thursday, April 28, 2011 3:55 PM To: Schwartz, Guy L (DOA) Subject: 2L-322 Guy, As per our conversation, we will revise our procedure and now our first cement plug will be placed through the BHA from TD to approximately 6,500' MD. That should cover the entire Bermuda Sand with cement. Our plans were then to cut the drill string at 6,400' MD. We may move the cut up the hole 100 -300 ft to make sure we get a good cut. We will then continue with our cement plugs from the cut point up like shown on the original procedure with the sundry. I may or may not be in the office tomorrow. You can reach me at 985-768-0247 if I am not*, Thanks. David A. Nugent --*—^-------7 Swift Worldwide Resources ConocoPhillips Alaska ATO 1502 Anchorage, AK 907-263-4228 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, April 21, 2011 8:58 AM To: 'NSK Prod Engr Specialist' Cc: CPF2 Prod Engrs; DOA AOGCC Prudhoe Bay Subject: RE: 2L-322 PTD 210-174 Darrell, Your request is granted. Please verify the set points for the SVS system are re-calibrated for flowback conditions and also that there will be a "24 man-watch" for the duration of the flowback. Report estimated production as you stated with the 404 sundry report. With the short duration of the flowback it is not necessary to change the well status to `oil". Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: NSK Prod Engr Specialist [mailto:n1139@conocophillips.com] Sent: Thursday, April 21, 2011 7:50 AM To: Schwartz, Guy L(DOA) Cc: NSK Prod Engr Specialist; CPF2 Prod Engrs Subject: 2L-322 PTD 210-174 AOGCC Attn: Guy Schwartz Guy, ConocoPhillips is requesting permission to flowback 2L-329A PTD 198-225 for approximately one week, to assist drilling operations currently ongoing on 2L-322. Drilling has encountered elevated gas levels while drilling through the Bermuda zone in this well. As 2L-329A is the closest injector to this well ConocoPhillips would like to flow it back to reduce reservoir formation pressure in the area. We plan to rig up temporary hardline to flow 2L- 329A to production via existing production piping on the pad. 2L-329A is equipped with a surface safety valve. Produced volumes from 2L-329A will be estimated from well tests using the drillsite facility. ConocoPhillips request verbal approval to proceed as drilling operations are currently in progress. A 10-404 Sundry will follow completion of operations. Thank you for your assistance in this matter. Darrell Humphrey / Bob Christensen ConocoPhillips Alaska, Inc. Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager(907) 659-7000 (924) 4/22/2011 sirtzintE o [F SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 / FAX (907)276-7542 G. C. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Tarn Oil Pool, 2L-322 ConocoPhillips Alaska, Inc. Permit No: 210-174 Surface Location: 209' FNL, 821' FEL, SEC. 22, T1ON, R7E, UM Bottomhole Location: 1060' FNL, 512' FEL, SEC. 27, T1ON, R7E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. 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 KRU 2L-322 and API number 50- 103-20628-70 from records, data and logs acquired for well KRU 2L-322. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Chair DATED this I -"day of December, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA DEC 0 3 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska Oil&Gas Cons.Commission 20 AAC 25.005 Anchorage la.Type of Work: lb.Proposed Well Class: Development-Oil Q Service-Winj ❑ Single Zone ❑✓ 1 c.Specify if well is proposed for: Drill ❑✓ Re-drill❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket Li Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • 2L-322 . -r p;/,-i- 3. ;/,fi3.Address: 6.Proposed Depth: 12. Field/Pool(s): h.Le.. P.O. Box 100360 Anchorage,AK 99510-0360 MD:9287' • TVD: 5243' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:209'FNL,821'FEL,Sec.22,T1ON,R7E,UM ADL 380052,380054 Tarn Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1092'FSL, 1120'FEL,Sec.22,T1ON, R7E,UM 4600,4602 2/3/2011 Total Depth: 9.Acres in Property: 14.Distance to 1060'FNL,512'FEL,Sec.27,T1ON, R7E,UM 2560 Nearest Prop: 1.25 mile to CRU boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 155 feet 15.Distance to Nearest Well Open Surface:x- 460829 . y- 5927638 Zone- 4 GL Elevation above MSL: ? 115 feet to Same Pool: 2L-309PB1,2689'©9203' 16.Deviated wells: Kickoff depth: 500 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 75° deg Downhole: 1416 psig . Surface:839 psig • 18.Casing Proc ram: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 24" 16" 164.8# B-35 Welded 120' Surf. Surf 120' 120' Driven 13.5" 10.75" 45.5# L-80 BTC 2625' Surf. Surf 2665' ' 2400' ' 500 sx ASLite,360 sx DeepCRETE 9.875" 7.625" 29.7# L-80 BTCM 7008' Surf. Surf 7048' 5332' 860 sx GasBLOK Class G 6.75" 3.5" 9.3# L-80 SLHT 2239' 6900' 5221' 9287' 5243' Slotted Liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program❑✓ 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: 22. I hereby certify that the foregoing is true and correct. Contact Steve Shultz @ 263-4297 Printed Name G. C. Alvord Title Alaska Drilling Manager Signature La Zf ' Phon 265-6120 Date '&//j/sd- O/ a cH-rP A�( v b Commission Use Only Permit to Drill �7 API Number: ,,,,,,-,_7y.,' Permit Approv I See cover letter Number: �1[�( / 4 5.-/c,,,6,-,...,-„, Date: \ \\05\1 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m ane,gas hydrates,or gas contained in shales: [0 .- 3 SOD ps- J3OP �.5-& Samples req'd: Yes Cl/No, L Mud log req'd: Yes ❑. No [r f Other: .'Z5( es,:, A nn.,q,r -.fj42S measures: Yes [' No ❑ Directional svy req'd: Yes [1� No ❑ P / , Com-:-K /13,/'/" 2 P/ APPROVED BY THE COMMISSION / v DATE: ���I�� ,COMMISSIONER_ Form 10-401 (Revised 7/2009) This permit is valid fora nforf or >i'd t oi�a ov I(20 AAC 25.005(8)) Submit in Duplicate /z•1 /� .,i le, ./1) ( ? % Post Office Box 100360 C onocoPh II lips Anchorage,Alaska 99510-0360 Chip Alvord Phone(907)265-6120 Email: Chip.Alvord@conocophillips.com December 1,2010 Alaska Oil and Gas Conservation Commission D 333 West 7th Avenue, Suite 100 RECEIVED EIVE V Anchorage,Alaska 99501 DEC 0 3 2010 RE: Application for Permit to Drill 2L-322(North) Alaska Oil&Gas Cons.CO lssi0 Dear Commissioners, Anchorage ConocoPhillips Alaska,Inc hereby applies for a Permit to Drill for theasonshore production well 2L-32n2. The well will be drilled and completed using Doyon Rig#15. The planned spud date for 2L-322 is February 3,2011. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information,please contact Steve Shultz 263-4297. Sincerely, iC'tf7 P u e-13 Chip Alvord Drilling Manager ation for Permit to Drill,Well 2L-322 Saved: 1-Dec-10 Permit It — Tarn Well 2L-322 (North) Application for Permit to Drill Document r"i To Te Mpximi " Well VgI1,11 Table of Contents 1. Well Name 3 Requirements of 20 AAC 25.005(I 3 2. Location Summary 3 Requirements of 20 AAC 25.005(c)(2) 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 4 Requirements of 20 AAC 25.005(c)(3) 4 4. Drilling Hazards Information 4 Requirements of 20 AAC 25.005(c)(4) 4 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 AAC 25.005 (c)(5) 4 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 5 7. Diverter System Information 5 Requirements of 20 AAC 25.005(c)(7) 5 8. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 9. Abnormally Pressured Formation Information 6 Requirements of 20 AAC 25.005(c)(9) 6 I'I 10. Seismic Analysis 6 Requirements of 20 AAC 25.005 (c)(10) 6 11. Seabed Condition Analysis 6 Requirements of 20 AAC 25.005(c)(11) 6 12. Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 13. Proposed Drilling Program 6 Requirements of 20 AAC 25.005(c)(13) 6 2L-322 APD Page 1 of 7 3RIGINAL Printed: 1-Dec-10 ation for Permit to Drill,Well 2L-322 Saved: 1-Dec-10 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 15. Attachments 7 Attachment 1 Directional Plan 7 Attachment 2 Drilling Hazards Summary 7 Attachment 3 Well Schematic 7 Attachment 4 Cement Summary 7 2L-322 APD Page 2 of 7 o R I G I N A L Printed:1-Dec-10 i ation for Permit to Drill,Well 2L-322 Saved: 1-Dec-10 1. Well Name Requirements of 20 AAC 25.005(f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission ander 20 AAC 25.040(6).For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 2L-322. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective jbrmation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration: (C)the proposed depth oftile well at the top ofeach objective formation and at total depth: This well is planned for a pilot hole to lock in the top of the S-8 sand(Bermuda)and then plug back and kick off at +/-6350'MD,5098'TVD. Once the well is redrilled to horizontal in the S-8 sand casing will be ran. The horizontal portion of the well will then be drilled to TD. Location at Surface 209' FNL, 821' FEL, Sec 22, T1ON,R7E,UM NAD 1927 RKB Elevation 154.8' AMSL Northings: 5,927,637.8 Eastings: 460,829.4 114.8' AMSL Pad Elevation Location of Pilot HoleTo of S-8) 1,252'FSL, 1,166' FEL,Sec 22,T1ON,R7E,UM Hole(Top Nad 1927 Measured Depth, RKB: 6,888' Northings: 5,923,820.7 Eastings: 460470.9 Total Vertical Depth,RKB: 5,246' Total Vertical Depth, SS: 5,091' Location at Pilot Hole at TD 735'FSL, 1,028'FEL, Sec 22,T1ON,R7E,UM Nad 1927 Measured Depth, RKB: 7,442' Northings: 5,923,302.9 Eastings:460,606.8 Total Vertical Depth,RKB: 5,390' Total Vertical Depth, SS: 5,235' Location at Heal of Horizontal Interval 1092.1'FSL, 1119.6' FEL, Sec 22,T1ON,R7E,UM (Bermuda) Nad 1927 Measured Depth,RKB: 7,048' Northings: 5,923,660.5 Eastings: 460,516.6 Total Vertical Depth,RKB: 5,232' Total Vertical Depth, SS: 5,077' Location at Toe of Horizontal Interval 1,060'FNL, 512'FEL, Sec 27,T1ON,R7E,UM Nad 1927 Measured Depth, RKB: 9,287' Northings: 5,921,504.9 Eastings: 461,116.1 Total Vertical Depth,RKB: 5,243' Total Vertical Depth, SS: 5,088' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(6) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well: Please see Attachment 1: Directional Plan 2L-322 APD Page 3 of 7 Printed:1-Dec-10 OR ! GIN L ration for Permit to Drill,Well 2L-322 Saved: 1-Dec-10 and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been.furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(0(3) An application for a Permit to Drill must he accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPS)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC'25.037, as applicable; Please reference BOP schematics on file for Doyon 15. 4. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each oldie following items,except for an item already on file with the conmmission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and nmxinuun potential surface pressure based on a methane gradient; The bottom hole pressures from the 2L-320's offset wells are: Well Type SBHP MW Distance Direction Shut in Time 2L-309 Producer 1,228 psi 4.6 ppg 2,689' E/NE 148 hrs 2L-325 Producer 1,418 psi 5.1 ppg 3,386' E 920 hrs 2L-327 Producer 1,159 psi 4.0 ppg 3,724' E/NE 69 hrs 2L-329A Injector 3,291 psi 11.4 ppg 4,286' N 32760 hrs Given the above range of pressures for the nearest wells,2L-322 is expected to have a BHP range of 1,200— 1,400 psi at the reservoir depth of 5,246'TVD. This gives a mud weight range of 4.4 ppg—5.1 ppg. Equivalent Mud Weight @ TD= 1,418/(5,246*.052)=5.2 ppg=0.270 psi/ft The maximum potential surface pressure(MPSP)while drilling 2L-322 is calculated using the higher end of the predicted reservoir pressure 1,400 psi,a 0.11 psi/ft gas gradient,and a S-8 sand top TVD of 5,246' (estimated top of reservoir in 2L-322). MPSP =(5,246 ft TVD)*(0.270-0.11 psi/ft) =839 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity/br differential sticking; Please see Attachment 2-Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests \� Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030(/): Drill out surface casing shoe and perform LOT test or FIT in accordance with the Kuparuk LOT/ FIT procedure that ConocoPhillips Alaska has on file with the Commission.Casing and Cementing Program 2L-322 APD Page 4 of 7 Printed:1-Dec-10 ORIGINAL ation for Permit to Drill,Well 2L-322 Saved: 1-Dec-10 Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must he accompanied by each of the following items,except ibr an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre-perforated liner,or screen to be installed; Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (Ib/ft) Grade Conn. (ft) (ft) (ft) Cement Program Driven 16 24 164.8 B-35 Welded 120' Surf 120'/120' Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 BTC 2,625' Surf 2,665'/2,400' 500 sx ASLite Lead 10.7 ppg, 360 sx Tail Slurry 12.0 ppg Cement Top planned @ 4,000'MD/ 7-5/8 9 7/8" 29.7 L-80 BTCM 7,008' Surf 7,048'/5,332' 3452'TVD. Cemented w/ 860 sx GasBLOK Class"G"15.8 ppg 3 1/z" 6 3/4" 9.3 ppf L-80 SLHT 2,239' 6,90075,221' 9,28775,243' Slotted Liner 6. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035,unless this requirement is waived by the commission under 20 AAC 25.035(10)(2); Please reference diverter schematic on file for Doyon 15. 7. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application far a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Drilling will be done using mud systems having the following properties: Surface WBM 120'—2,665 ' Density(ppg) 8.8—9.5 • Funnel Viscosity(seconds) 75 -250 Yield Point(cP) 60—80 pH 9.0—9.5 API Filtrate(cc) NC—8.0 Chlorides(mg/l) <1000 Intermediate/Production OBM 2,665'—9,287" Density(ppg) 9.1 — 10.0 / • Yield Point(cP) 18—28 HTHP Fluid Loss(ml/30min) <5 OWR 75:25—80:20 Electrical Stability(my) >600 Diagram of Doyon 15 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 2L-322 APD Page 5 of 7 r•1 r t n ! NI A I Printed:1-Dec-10 i ation for Permit to Drill,Well 2L-322 Saved: 1-Dec-10 8. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the fallowing items,except fbr an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(1); N/A-Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); N/A-Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application for a Permit to Drill Hurst be accompanied by each of the following items,except fOr an item already on file with the commission and identified in the application: (Hybl-a well drilled from an of)shore platfbrm,mobile bottom founded structure,jack-up rig,or floating drilling vessel,an analysis of seabed conditions as required by 20 AAC 25.061(6); N/A-Application is not for an offshore well. 11. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the,following items,except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska,Inc.is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to Attachment 3:Well Schematic. 1. MIRU Doyon 15 on 2L-322 Conductor. 2. NU and function test diverter system and prepare spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. • 4. Spud and directionally drill 13-1/2"hole to the 10-3/4"surface.casing point(2,665'MD/2,400'TVD) according to the directional plan. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 5. Run and cement 10-3/4"45.5#L-80 BTC casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with oil base mud. Perform top job if required to bring cement to surface. 6. Nipple down diverter and install wellhead and test to 5000 psi. Nipple up BOPE and test to 3,500 psi. Notify — state of BOP test. Record results. 7. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results,- 8. esults✓8. Drill out cement and 20'minimum to 50'maximum of new hole.Perform LOT. 9., Directionally drill 9-7/8"pilot hole to 7,442'MD/5,390'TVD. gun MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 10. Plug back to+/-6350'MD/5,098'TVD and sidetrack well 2L-322 APD 1 Page 6 of 7 0 D I INAL Printed:1-Dec-10 ation for Permit to Drill,Well 2L-322 Saved: 1-Dec-10 11. Drill to 7 5/8"casing point at 7,048'MD/5,232'TVD µ' c Tc s1 12. POOH with DP and rack back. Run 7-5/8"29.7#L-80 BTCM casing and cement. (e- 44.5r c� i 13. Directionally drill 6 3/4"production hole to 9,287'MD/5,243'TVD,POOH 14. Run 3-1/2"production liner to TD.POOH and LD DP. 15. RU and run 3 '/2"completion. 16. ND BOP and rig up tree. Test tree and freeze protect annulus. Rig down and move out rig. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music be accompanied by each of the following items,except.fbr an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling stud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 2 5.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska does intend to request authorization for the use of this well for annular disposal operations at a later date provided the well meets the regulatory requirements. 14. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary 2L-322 APD Page 7 of 7 APrinted: 1-Dec-10 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-322 (North) 2L-322H Pilot Plan: 2L-322 PB1(wp04) Standard Proposal Report 29 November, 2010 HALLIBURTON Sperry Drilling Services ORIGINAL w I I - o TCCI I - rn c v °ci _ Q_ _ w Z I I Lan p' _ y g eq 2 2' h O I I _ J m d V `°ohm O I I 1 ECO„ E coN co .,M o0 3 Z (--M 2 H - O Q I I S*0 W 11(nF N ZC•o, M Nmh� o U I I ^ En oo o c�(n N I I m o tL L�� Nvoo N5 H I I o - O acv N in`"� N 11 - F .,'Z ZZ 2mn ci orn �; vNi o`+'o�d N I I I I a) - o m r$ F LOO ¢ Callo F b�N LL I I H co - C, W NNO, N adv 2 d,-e_ W Loo Q rnoNr -J N I I 21 S = v oN Ca Lo N r C7 (nryrno LU I I I I - N °o 0 >O> O V rnoin v�o�o LL J I I ,' N - 0 a _ moo v�ryo rnNoo O Z �1 1 M —(o N N VI �n R Q LL 0 O - h y+ cC, 11(0N o PNN U D8�m c - I I , J 3 .. 0.4-1"...` N, �0•--.N Z J <O 1 I ' a N - C N N Q O V K N N O o 1 I ' Q >o� Nvi in in NI N ,' a _00 d1 C� F- 0 I 1 o c� rvv`^i N MI 1 // UI N co CD J rM N U) NI I M , 2I - 0c (n V 11 I i �N - N ❑ N i1 I N o o w ‘`� 0 II 'I,' J _ co w N _ FDCSJ Z2 co o w L8Z6' 'IV o - o O 0 ' m 'I �' _ m E o o @) 0006- II - Z N LLNI- \ ❑ 1 o_ - LC)LLI U CV o ` I- I 0 - o o in N 0098, 1 g ----- 21 w - i -y___g NI O _ c_ J 0 y I a- Cl O o LL U_ \• I CO CO 3 Z 0, 1 J O o 0 N ` 0008_ 1 N Cl CO H cD o O N N ` -I---� _ 0 N 0 \ I , 1 N 00 J I 1 / J O 2 U - CO CO Lf) ,\ I i N N1 (n o • o l'- -J J f� 9 -L.' N v) F- LU o \`QOSL- I��` _ N M J - o o \`� ,I ���� _ UI N la- b _- c in o ❑ 000L\,i,i' ,a6- NI o —o ani LL CO 7 I0LI( 8- CN J _ v N co 03 0099 1 3 to - o a) ❑ Oa II I co Ln o I, 1 . U p - LU M 000 1, I 1 o O co a9 1,I 2 - 0 Z N ` 1 'I Nl —o I M M 0 0 0 O p I I, J M - H 2 ‘, N I I, p N a - N �- �O 1 1`, eL _o Lo N co �s I I N (V Cl `5 I I 0 - N to © pp 1 1 • a _ S I I W D) \ I I 21 o LL .N , O(4 1 I NI 0 _ N (0 ` L� I I N Cl 0 , 1 I M - �p I I Cl J U S 1 1 - o (O LZL. M `5 O 1 1 —Li") CD , O0 I I _ N L Cn - I Li p , I I - o CO ��� I 1 —o (2_, I I - LO I - I I 0 1 I o 0 I I N O ! CO 1 Z 0 0 0 I I _ I I O co1 I 1" 1 I N 0 Q I I ��1L ' I I , / W C I 1 / - 0 / 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 I I I I I I I I I I I 11'I 5 I I I I I I I I I I ��YII J I I I I I I I I I I I I I I .J o 0 0 o o 0 0 o 0 0 0 0 0 2. 0 Q o o V V 0o O 0 0 0 0 0 0 0 0 o 0 En 0 0 (0 L N N C) M l() In (0 (0 I m (un 000L)Lgdaa Ieoi10 ORIGIKIAL HALLIBURTON Project: Kuparuk River Unit WELL DETAILS: Plan:2L-322(North) Sperry Drilling ServicesSite: Kuparuk 2L Pad Ground Level: 114.80 Well: Plan: 2L-322 (North) +NI-S +E/-W Northing Easting Latittude Longitude Slot Wellbore: 2L-322 0.00 0.00 5927637.76 460829.39 70°12'47.695 N 150°18'57.255 W Plan: 2L-322 (wp04) REFERENCE INFORMATION Co-ordinate(N/E)Reference:Well Plan:2L-322(North),True North 250— Vertical(TVD)Reference:Plan:2L-322 015 @ 154.809(015(40+114.8)) — Measured Depth Reference:Plan:2L-322 015 154.809(015(40+114.8)) Calculation Method:Minimum Curvature -0— SHL:209'FNL,821'FEL-Sec22-TION-R07E----- 250 1000 CASING DETAILS: 2L-322 PB1(wp04) -250— TVD TVDSS MD Size Name 1500 2400.00 2245.20 2665.22 10-3/4 10 3/4" 5378.84 5224.05 7400.00 9-7/8 9-7/8"Open Hole 1750 -500— CASING DETAILS: 2L-322(wp04) 2000 -750— TVD TVDSS MD Size Name 10 3/4" 2400.00 2245.20 2665.22 10-3/4 10 3/4" �. 5231.72 5076.92 7048.30 7-5/8 7 5/8" -10002500 ---_ 5242.87 5088.07 9286.92 3-1/2 3 1/2" 2750 Surface Casing @ 2665'MD,2400'TVD:1121'FNL,980'FEL-Sec22-110N-R07E -1250— - 3000 -1500- 3250 -1750— 3500 -2000— 3750 - 2L-322 PB1(wp04) DDI = 5.812 4000 -2250 = 4250 2L-322 (wp04) DDI = 6.179 -2500 4500 a = c-2750— 4750 h — l� -3000— 175° Tie-on @ 6350'MD,5098'TVD:1752'FSL,1295'FEL-Sec22-TION-RIOE _ 5000 __ O -3250— -__--- ' Top Bermuda @ 6888'MD,5246'TVD:1252'FSL,1166'FEL-Sec22-TION-R07E - 0-3500- 1650 y -- 165° --- -3750— -- ' - ==5250 Int Csg @ 7048'MD,5232'TVD:1092'FSL,1120'FEL-Sec22-TION-R07E -4000- - 164 2L-322 H_CP1(wp04) -4250— _ -'ID @ 7442'MD,5390'TVD:735'FSL,1028'FEL-Sec22-TION-R07E 9-7/8"Open Hole _-- i6-3?- 2L-322 PB1(wp04) -4500J --_ 12L-322_H_CP2(wp04f- -4750— 164" 12L-322_H_CP3(wp04t---- -5000— 164° -5250- - 2L-322_H_CP4(wp041_____ 5250 -5500— T M AzMagneticimuths toNorth:True North 21.20° -5750_ 2L __322-H-CPS(wp04�- Magnetic Field Strength:57645.1snT Dip Angle:80.71° -6000— 2L-322_H_CP6(wp04) Date: 10/11/2010 5243 Model:BGGM2009 -6250— 2L-322-H-Toe(wp04# TD @ 9287 MD,5243'TVD:1061'FNL,512'FEL-Sec27-TION-R07E ` - 21.-322(wp04) Ill lil 111i11111111 111111111111111111 I 111111111 1111111111111111111111111 III 1111111111 1111111 IIII 11111111111 Ill -2000 -1750 -1500 -1250 -1000 -750 -500 -250 -0 250 500 750 1000 1250 1500 1750 2000 2250 2500 114n anon 1'cn Wes1tM1L -)/Eas -F ( ' Conoco ORIG1 Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-322(North) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-322 D15 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-322 D15 @ 154.80ft(D15(40+114.8)) • Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-322(North) Survey Calculation Method: Minimum Curvature • Wellbore: 2L-322H Pilof Design: 2L-322 PB1(wp04) Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2L Pad Site Position: Northing: 5,927,695.13 ft Latitude: 70°12'48.272 N From: Map Easting: 461,077.91 ft Longitude: 150°18'50.048 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -0.30° Well Plan:2L-322(North) Well Position +NI-S 0.00 ft Northing: 5,927,637.76 ft ' Latitude: 70°12'47.695 N +E/-W 0.00 ft Easting: 460,829.39 ft , Longitude: 150°18'57.255 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 114.80 ft • Wellbore 2L-322H Pilot Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) bggm2007 8/28/2007 22.78 80.67 57,579 Design 2L-322 PB1(wp04) Audit Notes: Version: 2 Phase: PLAN Tie On Depth: 40.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 40.00 0.00 0.00 177.38 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (0) (0) (ft) ft (ft) (ft) (1100ft) (°/100ft) (.1100ft) (°) 40.00 0.00 0.00 40.00 -114.80 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 245.20 0.00 0.00 0.00 0.00 0.00 0.00 700.00 6.00 160.76 699.45 544.65 -14.82 5.17 2.00 2.00 0.00 160.76 1,878.70 37.99 192.34 1,780.11 1,625.31 -439.14 -53.66 2.80 2.71 2.68 36.28 5,304.21 37.99 192.34 4,479.90 4,325.10 -2,498.84 -504.10 0.00 0.00 0.00 0.00 6,530.95 75.00 165.00 5,153.92 4,999.12 -3,486.59 -427.81 3.50 3.02 -2.23 -40.63 6,630.95 75.00 165.00 5,179.80 5,025.00 -3,579.89 -402.81 0.00 0.00 0.00 0.00 7,441.79 75.00 165.00 5,389.66 5,234.86 -4,336.42 -200.10 0.00 0.00 0.00 0.00 11/29/2010 1:07:15PM Page 2 COMPASS 2003.16 Build 69 ORtGINAL Halliburton -Sperry MALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-322(North) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-322 D15 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-322 D15 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-322(North) Survey Calculation Method: Minimum Curvature Wellbore: 2L-322H Pilot Design: 2L-322 PB1(wp04) i Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) -114.80 40.00 0.00 0.00 40.00 -114.80 0.00 0.00 5,927,637.76 460,829.39 0.00 0.00 100.00 0.00 0.00 100.00 -54.80 0.00 0.00 5,927,637.76 460,829.39 0.00 0.00 200.00 0.00 0.00 200.00 45.20 0.00 0.00 5,927,637.76 460,829.39 0.00 0.00 300.00 0.00 0.00 300.00 145.20 0.00 0.00 5,927,637.76 460,829.39 0.00 0.00 400.00 0.00 0.00 400.00 245.20 0.00 0.00 5,927,637.76 460,829.39 0.00 0.00 500.00 2.00 160.76 499.98 345.18 -1.65 0.58 5,927,636.11 460,829.95 2.00 1.67 600.00 4.00 160.76 599.84 445.04 -6.59 2.30 5,927,631.16 460,831.65 2.00 6.69 700.00 6.00 160.76 699.45 544.65 -14.82 5.17 5,927,622.91 460,834.48 2.00 15.04 800.00 8.42 172.14 798.66 643.86 -27.01 7.90 5,927,610.71 460,837.14 2.80 27.34 900.00 11.02 178.34 897.22 742.42 -43.82 9.17 5,927,593.89 460,838.33 2.80 44.19 1,000.00 13.70 182.16 994.89 840.09 -65.22 9.00 5,927,572.50 460,838.05 2.80 65.56 1,100.00 16.42 184.75 1,091.45 936.65 -91.14 7.39 5,927,546.59 460,836.30 2.80 91.38 1,200.00 19.16 186.61 1,186.66 1,031.86 -121.54 4.33 5,927,516.21 460,833.08 2.80 121.61 1,300.00 21.92 188.03 1,280.29 1,125.49 -156.33 -0.17 5,927,481.45 460,828.40 2.80 156.15 1,400.00 24.68 189.14 1,372.13 1,217.33 -195.43 -6.10 5,927,442.38 460,822.28 2.80 194.95 1,500.00 27.46 190.04 1,461.95 1,307.15 -238.75 -13.43 5,927,399.10 460,814.72 2.80 237.89 1,600.00 30.23 190.78 1,549.53 1,394.73 -286.19 -22.16 5,927,351.71 460,805.74 2.80 284.88 1,700.00 33.01 191.41 1,634.67 1,479.88 -337.64 -32.27 5,927,300.32 460,795.37 2.80 335.81 1,800.00 35.80 191.96 1,717.17 1,562.37 -392.96 -43.72 5,927,245.07 460,783.64 2.80 390.55 1,878.70 37.99 192.34 1,780.11 1,625.31 -439.14 -53.66 5,927,198.94 460,773.45 2.80 436.23 1,900.00 37.99 192.34 1,796.90 1,642.10 -451.95 -56.46 5,927,186.15 460,770.59 0.00 448.90 2,000.00 37.99 192.34 1,875.71 1,720.91 -512.08 -69.61 5,927,126.10 460,757.13 0.00 508.36 2,100.00 37.99 192.34 1,954.53 1,799.73 -572.21 -82.76 5,927,066.04 460,743.67 0.00 567.83 2,200.00 37.99 192.34 2,033.34 1,878.54 -632.34 -95.91 5,927,005.99 460,730.21 0.00 627.29 2,300.00 37.99 192.34 2,112.16 1,957.36 -692.46 -109.06 5,926,945.94 460,716.75 0.00 686.75 2,400.00 37.99 192.34 2,190.97 2,036.17 -752.59 -122.21 5,926,885.88 460,703.29 0.00 746.22 2,500.00 37.99 192.34 2,269.79 2,114.99 -812.72 -135.36 5,926,825.83 460,689.83 0.00 805.68 2,600.00 37.99 192.34 2,348.60 2,193.80 -872.85 -148.51 5,926,765.78 460,676.37 0.00 865.15 2,665.22 37.99 192.34 2,400.00 2,245.20 -912.06 -157.09 5,926,726.61 460,667.59 0.00 903.93 Surface Casing @ 2665'MD,2400'TVD:1121'FNL,980'FEL-Sec22-T10N-R07E-10 3/4" 2,700.00 37.99 192.34 2,427.41 2,272.61 -932.98 -161.66 5,926,705.72 460,662.91 0.00 924.61 2,800.00 37.99 192.34 2,506.23 2,351.43 -993.10 -174.81 5,926,645.67 460,649.45 0.00 984.08 2,900.00 37.99 192.34 2,585.04 2,430.24 -1,053.23 -187.96 5,926,585.62 460,635.99 0.00 1,043.54 3,000.00 37.99 192.34 2,663.86 2,509.06 -1,113.36 -201.11 5,926,525.56 460,622.53 0.00 1,103.00 3,100.00 37.99 192.34 2,742.67 2,587.87 -1,173.49 -214.26 5,926,465.51 460,609.06 0.00 1,162.47 3,200.00 37.99 192.34 2,821.49 2,666.69 -1,233.62 -227.41 5,926,405.46 460,595.60 0.00 1,221.93 3,300.00 37.99 192.34 2,900.30 2,745.50 -1,293.75 -240.56 5,926,345.40 460,582.14 0.00 1,281.40 3,400.00 37.99 192.34 2,979.11 2,824.31 -1,353.87 -253.71 5,926,285.35 460,568.68 0.00 1,340.86 3,500.00 37.99 192.34 3,057.93 2,903.13 -1,414.00 -266.86 5,926,225.30 460,555.22 0.00 1,400.32 3,600.00 37.99 192.34 3,136.74 2,981.94 -1,474.13 -280.01 5,926,165.24 460,541.76 0.00 1,459.79 3,700.00 37.99 192.34 3,215.56 3,060.76 -1,534.26 -293.16 5,926,105.19 460,528.30 0.00 1,519.25 3,800.00 37.99 192.34 3,294.37 3,139.57 -1,594.39 -306.31 5,926,045.14 460,514.84 0.00 1,578.72 3,900.00 37.99 192.34 3,373.19 3,218.39 -1,654.51 -319.46 5,925,985.08 460,501.38 0.00 1,638.18 4,000.00 37.99 192.34 3,452.00 3,297.20 -1,714.64 -332.61 5,925,925.03 460,487.92 0.00 1,697.65 4,100.00 37.99 192.34 3,530.81 3,376.01 -1,774.77 -345.76 5,925,864.98 460,474.46 0.00 1,757.11 11/29/2010 1:07:15PM Page 3 COMPASS 2003.16 Build 69 ORIGtNAL Halliburton -Sperry I-IALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-322(North) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-322 D15 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-322 D15 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-322(North) Survey Calculation Method: Minimum Curvature Wellbore: 2L-322HPilot Design: 2L-322 PB1(wp04) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) C) (ft) ft (ft) (ft) (ft) (ft) 3,454.83 4,200.00 37.99 192.34 3,609.63 3,454.83 -1,834.90 -358.91 5,925,804.92 460,461.00 0.00 1,816.57 4,300.00 37.99 192.34 3,688.44 3,533.64 -1,895.03 -372.05 5,925,744.87 460,447.54 0.00 1,876.04 4,400.00 37.99 192.34 3,767.26 3,612.46 -1,955.15 -385.20 5,925,684.82 460,434.08 0.00 1,935.50 4,500.00 37.99 192.34 3,846.07 3,691.27 -2,015.28 -398.35 5,925,624.77 460,420.62 0.00 1,994.97 4,600.00 37.99 192.34 3,924.89 3,770.09 -2,075.41 -411.50 5,925,564.71 460,407.16 0.00 2,054.43 4,700.00 37.99 192.34 4,003.70 3,848.90 -2,135.54 -424.65 5,925,504.66 460,393.70 0.00 2,113.90 4,800.00 37.99 192.34 4,082.51 3,927.71 -2,195.67 -437.80 5,925,444.61 460,380.24 0.00 2,173.36 4,900.00 37.99 192.34 4,161.33 4,006.53 -2,255.80 -450.95 5,925,384.55 460,366.78 0.00 2,232.82 5,000.00 37.99 192.34 4,240.14 4,085.34 -2,315.92 -464.10 5,925,324.50 460,353.32 0.00 2,292.29 5,100.00 37.99 192.34 4,318.96 4,164.16 -2,376.05 -477.25 5,925,264.45 460,339.86 0.00 2,351.75 5,200.00 37.99 192.34 4,397.77 4,242.97 -2,436.18 -490.40 5,925,204.39 460,326.40 0.00 2,411.22 5,300.00 37.99 192.34 4,476.59 4,321.79 -2,496.31 -503.55 5,925,144.34 460,312.94 0.00 2,470.68 5,304.21 37.99 192.34 4,479.90 4,325.10 -2,498.84 -504.10 5,925,141.81 460,312.38 0.00 2,473.18 5,400.00 40.58 188.98 4,554.05 4,399.25 -2,558.43 -515.27 5,925,082.28 460,300.90 3.50 2,532.20 5,500.00 43.38 185.84 4,628.38 4,473.58 -2,624.74 -523.84 5,925,016.02 460,291.99 3.50 2,598.06 5,600.00 46.26 183.02 4,699.31 4,544.51 -2,695.01 -529.24 5,924,945.80 460,286.22 3.50 2,668.00 5,700.00 49.20 180.45 4,766.57 4,611.77 -2,768.96 -531.44 5,924,871.87 460,283.64 3.50 2,741.77 5,800.00 52.20 178.11 4,829.91 4,675.11 -2,846.31 -530.43 5,924,794.51 460,284.25 3.50 2,819.09 5,900.00 55.23 175.95 4,889.09 4,734.29 -2,926.80 -526.22 5,924,714.02 460,288.04 3.50 2,899.68 6,000.00 58.30 173.94 4,943.88 4,789.08 -3,010.10 -518.83 5,924,630.69 460,295.00 3.50 2,983.23 6,100.00 61.41 172.06 4,994.10 4,839.30 -3,095.91 -508.27 5,924,544.83 460,305.11 3.50 3,069.44 6,200.00 64.53 170.29 5,039.54 4,884.74 -3,183.91 -494.59 5,924,456.76 460,318.33 3.50 3,157.98 6,300.00 67.68 168.62 5,080.05 4,925.25 -3,273.78 -477.85 5,924,366.82 460,334.61 3.50 3,248.51 6,400.00 70.84 167.01 5,115.46 4,960.66 -3,365.17 -458.10 5,924,275.34 460,353.88 3.50 3,340.72 6,500.00 74.01 165.47 5,145.65 4,990.85 -3,457.75 -435.42 5,924,182.65 460,376.08 3.50 3,434.23 6,530.95 75.00 165.00 5,153.92 4,999.12 -3,486.59 -427.81 5,924,153.77 460,383.53 3.50 3,463.39 6,600.00 75.00 165.00 5,171.79 5,016.99 -3,551.02 -410.55 5,924,089.27 460,400.46 0.00 3,528.54 6,630.95 75.00 165.00 5,179.80 5,025.00 -3,579.89 -402.81 5,924,060.35 460,408.05 0.00 3,557.74 • 2L-322_H_Pilot(wp04) 6,700.00 75.00 165.00 5,197.67 5,042.87 -3,644.32 -385.55 5,923,995.85 460,424.97 0.00 3,622.88 6,800.00 75.00 165.00 5,223.55 5,068.75 -3,737.62 -360.55 5,923,902.42 460,449.49 0.00 3,717.23 6,887.50 75.00 165.00 5,246.20 5,091.40 -3,819.26 -338.68 5,923,820.68 460,470.94 0.00 3,799.78 Top Bermuda @ 6888'MD,5246'TVD:1252'FSL,1166'FEL-Sec22-T10N-R07E-S-8 6,900.00 75.00 165.00 5,249.44 5,094.64 -3,830.92 -335.55 5,923,809.00 460,474.00 0.00 3,811.58 7,000.00 75.00 165.00 5,275.32 5,120.52 -3,924.22 -310.55 5,923,715.58 460,498.51 0.00 3,905.92 7,100.00 75.00 165.00 5,301.20 5,146.40 -4,017.52 -285.55 5,923,622.16 460,523.03 0.00 4,000.27 7,200.00 75.00 165.00 5,327.08 5,172.28 -4,110.82 -260.55 5,923,528.74 460,547.54 0.00 4,094.62 7,300.00 75.00 165.00 5,352.96 5,198.16 -4,204.13 -235.55 5,923,435.32 460,572.05 0.00 4,188.96 7,374.32 75.00 165.00 5,372.20 5,217.40 -4,273.47 -216.97 5,923,365.89 460,590.27 0.00 4,259.09 T-2 7,400.00 75.00 165.00 5,378.84 5,224.05 -4,297.43 -210.55 5,923,341.90 460,596.57 0.00 4,283.31 9-7/8"Open Hole 7,441.79 75.00 165.00 5,389.66 5,234.86 -4,336.42 -200.10 5,923,302.86 460,606.81 0.00 4,322.74 ` TD @ 7442'MD,5390'TVD:735'FSL,1028'FEL-Sec22-T10N-R07E 11/29/2010 1:07:15PM Page 4 COMPASS 2003.16 Build 69 c,it I G I N AL Halliburton -Sperry I-IALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-322(North) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-322 D15 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-322 D15 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-322(North) Survey Calculation Method: Minimum Curvature Wellbore: 2 L-322 H_Pilot Design: 2L-322 PB1(wp04) Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +EI-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) 2L-322_H. Pil0t(wp04) 0.00 0.00 5,179.80 -3,579.89 -402.81 5,924,060.35 460,408.05 -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 2,665.22 2,400.00 10 3/4" 10-3/4 13-1/2 L 7,400.00 5,378.84 9-7/8"Open Hole 9-7/8 9-7/8 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (0) (0) 6,887.50 5,246.20 S-8 7,374.32 5,372.20 T-2 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +EI-W (ft) (ft) (ft) (ft) Comment 40.00 SHL:209'FNL,821'FEL-Sec22-T1 ON-R07E 2,665.22 2,400.00 -912.06 -157.09 Surface Casing @ 2665'MD,2400'TVD:1121'FNL,980'FEL-Sec22-T1ON-R07E 6,887.50 5,246.20 -3,819.26 -338.68 Top Bermuda @ 6888'MD,5246'TVD:1252'FSL,1166'FEL-Sec22-710N-R07E L - 7,441.79 5,389.66 -4,336.42 -200.10 TD @ 7442'MD,5390'TVD_735'FSL,1028'FEL-Sec22-T1 ON-R07E 11/29/2010 1:07:15PM Page 5 COMPASS 2003.16 Build 69 ¢ . t\ 11 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-322 (North) 2L-322 Plan: 2L-322 (wp04) Standard Proposal Report 30 November, 2010 HALLIBURTON Mon Sperry Drilling Services 1 I M 1 I Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-322(North) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-322 D15 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-322 D15 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-322(North) Survey Calculation Method: Minimum Curvature Wellbore: 2L-322 Design: 2L-322(wp04) Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor ------- ---- Site Kuparuk 2L Pad Site Position: Northing: 5,927,695.13ft Latitude: 70°12'48.272 N From: Map Easting: 461,077.91 ft Longitude: 150°18'50.048 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -0.30 ° Well Plan:2L-322(North) Well Position +N/-S 0.00 ft Northing: 5,927,637.76 ft Latitude: 70°12'47.695 N +E/-W 0.00 ft Easting: 460,829.39 ft Longitude: 150°18'57.255 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 114.80 ft Wellbore 2L-322 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 10/11/2010 21.20 80.71 57,645 Design 2L-322(wp04) Audit Notes: 'Version: Phase: PLAN Tie On Depth: 6,350.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 40.00 0.00 0.00 177.38 11/30/2010 12:57:00PM Page 2 COMPASS 2003.16 Build 69 in t\ I k 1 \ � Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-322(North) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-322 D15 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-322 D15 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-322(North) Survey Calculation Method: Minimum Curvature Wellbore: 2L-322 Design: 2L-322(wp04) Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°I100ft) (°) 6,350.00 69.26 167.81 5,098.40 4,943.60 -3,319.31 -468.35 0.00 0.00 0.00 0.00 6,541.18 78.34 164.75 5,151.69 4,996.89 -3,497.42 -424.73 5.00 4.75 -1.60 -18.36 6,820.30 78.34 164.75 5,208.09 5,053.29 -3,761.15 -352.82 0.00 0.00 0.00 0.00 7,048.30 89.74 164.18 5,231.72 5,076.92 -3,979.27 -292.17 5.00 5.00 -0.25 -2.87 7,278.30 89.74 164.18 5,232.76 5,077.96 -4,200.55 -229.47 0.00 0.00 0.00 0.00 7,340.05 91.59 164.04 5,232.04 5,077.24 -4,259.94 -212.56 3.00 2.99 -0.23 -4.31 7,597.25 91.59 164.04 5,224.92 5,070.12 -4,507.13 -141.87 0.00 0.00 0.00 0.00 7,680.25 89.10 164.21 5,224.42 5,069.62 -4,586.96 -119.17 3.00 -2.99 0.21 176.08 8,012.45 89.10 164.21 5,229.62 5,074.82 -4,906.58 -28.79 0.00 0.00 0.00 0.00 8,054.10 87.85 164.17 5,230.73 5,075.93 -4,946.65 -17.45 3.00 -3.00 -0.10 -178.18 8,505.82 87.85 164.17 5,247.64 5,092.84 -5,380.93 105.67 0.00 0.00 0.00 0.00 8,519.34 88.11 164.09 5,248.12 5,093.32 -5,393.93 109.37 2.00 1.90 -0.62 -17.96 8,814.39 88.11 164.09 5,257.84 5,103.04 -5,677.52 190.22 0.00 0.00 0.00 0.00 8,894.97 90.51 164.35 5,258.81 5,104.01 -5,755.06 212.13 3.00 2.98 0.33 6.29 9,070.62 90.51 164.35 5,257.23 5,102.43 -5,924.19 259.50 0.00 0.00 0.00 0.00 9,151.89 94.57 164.07 5,253.63 5,098.83 -6,002.30 281.58 5.00 4.99 -0.35 -3.99 9,287.10 94.57 164.07 5,242.86 5,088.06 -6,131.90 318.58 0.00 0.00 0.00 0.00 11/30/2010 12:57:00PM Page 3 COMPASS 2003.16 Build 69 Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-322(North) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-322 D15 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-322 D15 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-322(North) Survey Calculation Method: Minimum Curvature Wellbore: 2L-322 Design: 2L-322(wp04) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Veil Section (ft) (') (') (ft) ft (ft) (ft) (ft) (ft) -54.80 100.00 0.00 0.00 100.00 -54.80 0.00 0.00 5,927,637.76 460,829.39 0.00 0.00 200.00 0.00 0.00 200.00 45.20 0.00 0.00 5,927,637.76 460,829.39 0.00 0.00 300.00 0.00 0.00 300.00 145.20 0.00 0.00 5,927,637.76 460,829.39 0.00 0.00 400.00 0.00 0.00 400.00 245.20 0.00 0.00 5,927,637.76 460,829.39 0.00 0.00 500.00 2.00 160.76 499.98 345.18 -1.65 0.58 5,927,636.11 460,829.95 2.00 1.67 600.00 4.00 160.76 599.84 445.04 -6.59 2.30 5,927,631.16 460,831.65 2.00 6.69 700.00 6.00 160.76 699.45 544.65 -14.82 5.17 5,927,622.91 460,834.48 2.00 15.04 800.00 8.42 172.14 798.66 643.86 -27.01 7.90 5,927,610.71 460,837.14 2.80 27.34 900.00 11.02 178.34 897.22 742.42 -43.82 9.17 5,927,593.89 460,838.33 2.80 44.19 1,000.00 13.70 182.16 994.89 840.09 -65.22 9.00 5,927,572.50 460,838.05 2.80 65.56 1,100.00 16.42 184.75 1,091.45 936.65 -91.14 7.39 5,927,546.59 460,836.30 2.80 91.38 1,200.00 19.16 186.61 1,186.66 1,031.86 -121.54 4.33 5,927,516.21 460,833.08 2.80 121.61 1,300.00 21.92 188.03 1,280.29 1,125.49 -156.33 -0.17 5,927,481.45 460,828.40 2.80 156.15 1,400.00 24.68 189.14 1,372.13 1,217.33 -195.43 -6.10 5,927,442.38 460,822.28 2.80 194.95 1,500.00 27.46 190.04 1,461.95 1,307.15 -238.75 -13.43 5,927,399.10 460,814.72 2.80 237.89 1,600.00 30.23 190.78 1,549.53 1,394.73 -286.19 -22.16 5,927,351.71 460,805.74 2.80 284.88 1,700.00 33.01 191.41 1,634.67 1,479.88 -337.64 -32.27 5,927,300.32 460,795.37 2.80 335.81 1,800.00 35.80 191.96 1,717.17 1,562.37 -392.96 -43.72 5,927,245.07 460,783.64 2.80 390.55 1,900.00 37.99 192.34 1,796.90 1,642.10 -451.95 -56.46 5,927,186.15 460,770.59 2.20 448.90 2,000.00 37.99 192.34 1,875.71 1,720.91 -512.08 -69.61 5,927,126.10 460,757.13 0.00 508.36 2,100.00 37.99 192.34 1,954.53 1,799.73 -572.21 -82.76 5,927,066.04 460,743.67 0.00 567.82 2,200.00 37.99 192.34 2,033.34 1,878.54 -632.34 -95.91 5,927,005.99 460,730.21 0.00 627.29 2,300.00 37.99 192.34 2,112.16 1,957.36 -692.46 -109.06 5,926,945.94 460,716.75 0.00 686.75 2,400.00 37.99 192.34 2,190.97 2,036.17 -752.59 -122.21 5,926,885.88 460,703.29 0.00 746.22 2,500.00 37.99 192.34 2,269.79 2,114.99 -812.72 -135.36 5,926,825.83 460,689.83 0.00 805.68 2,600.00 37.99 192.34 2,348.60 2,193.80 -872.85 -148.51 5,926,765.78 460,676.37 0.00 865.14 2,665.22 37.99 192.34 2,400.00 2,245.20 -912.06 -157.09 5,926,726.61 460,667.59 0.00 903.92 10 3/4" 2,700.00 37.99 192.34 2,427.41 2,272.61 -932.98 -161.66 5,926,705.72 460,662.91 0.00 924.61 2,800.00 37.99 192.34 2,506.23 2,351.43 -993.10 -174.81 5,926,645.67 460,649.45 0.00 984.07 2,900.00 37.99 192.34 2,585.04 2,430.24 -1,053.23 -187.96 5,926,585.62 460,635.99 0.00 1,043.53 3,000.00 37.99 192.34 2,663.86 2,509.06 -1,113.36 -201.11 5,926,525.56 460,622.53 0.00 1,103.00 3,100.00 37.99 192.34 2,742.67 2,587.87 -1,173.49 -214.26 5,926,465.51 460,609.06 0.00 1,162.46 3,200.00 37.99 192.34 2,821.49 2,666.69 -1,233.62 -227.41 5,926,405.46 460,595.60 0.00 1,221.93 3,300.00 37.99 192.34 2,900.30 2,745.50 -1,293.75 -240.56 5,926,345.40 460,582.14 0.00 1,281.39 3,400.00 37.99 192.34 2,979.11 2,824.31 -1,353.87 -253.71 5,926,285.35 460,568.68 0.00 1,340.85 3,500.00 37.99 192.34 3,057.93 2,903.13 -1,414.00 -266.86 5,926,225.30 460,555.22 0.00 1,400.32 3,600.00 37.99 192.34 3,136.74 2,981.94 -1,474.13 -280.01 5,926,165.24 460,541.76 0.00 1,459.78 3,700.00 37.99 192.34 3,215.56 3,060.76 -1,534.26 -293.16 5,926,105.19 460,528.30 0.00 1,519.25 3,800.00 37.99 192.34 3,294.37 3,139.57 -1,594.39 -306.31 5,926,045.14 460,514.84 0.00 1,578.71 3,900.00 37.99 192.34 3,373.19 3,218.39 -1,654.51 -319.46 5,925,985.08 460,501.38 0.00 1,638.17 4,000.00 37.99 192.34 3,452.00 3,297.20 -1,714.64 -332.61 5,925,925.03 460,487.92 0.00 1,697.64 4,100.00 37.99 192.34 3,530.81 3,376.01 -1,774.77 -345.76 5,925,864.98 460,474.46 0.00 1,757.10 4,200.00 37.99 192.34 3,609.63 3,454.83 -1,834.90 -358.91 5,925,804.92 460,461.00 0.00 1,816.56 4,300.00 37.99 192.34 3,688.44 3,533.64 -1,895.03 -372.05 5,925,744.87 460,447.54 0.00 1,876.03 ! 11/30/2010 12:57:00PM Page 4 COMPASS 2003.16 Build 69 fpiiMA, i Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-322(North) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-322 D15 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-322 D15 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-322(North) Survey Calculation Method: Minimum Curvature Wellbore: 2L-322 Design: 2L-322(wp04) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 3,612.46 4,400.00 37.99 192.34 3,767.26 3,612.46 -1,955.15 -385.20 5,925,684.82 460,434.08 0.00 1,935.49 4,500.00 37.99 192.34 3,846.07 3,691.27 -2,015.28 -398.35 5,925,624.77 460,420.62 0.00 1,994.96 4,600.00 37.99 192.34 3,924.89 3,770.09 -2,075.41 -411.50 5,925,564.71 460,407.16 0.00 2,054.42 4,700.00 37.99 192.34 4,003.70 3,848.90 -2,135.54 -424.65 5,925,504.66 460,393.70 0.00 2,113.88 4,800.00 37.99 192.34 4,082.51 3,927.71 -2,195.67 -437.80 5,925,444.61 460,380.24 0.00 2,173.35 4,900.00 37.99 192.34 4,161.33 4,006.53 -2,255.80 -450.95 5,925,384.55 460,366.78 0.00 2,232.81 5,000.00 37.99 192.34 4,240.14 4,085.34 -2,315.92 -464.10 5,925,324.50 460,353.32 0.00 2,292.28 5,100.00 37.99 192.34 4,318.96 4,164.16 -2,376.05 -477.25 5,925,264.45 460,339.86 0.00 2,351.74 5,200.00 37.99 192.34 4,397.77 4,242.97 -2,436.18 -490.40 5,925,204.39 460,326.40 0.00 2,411.20 5,300.00 37.99 192.34 4,476.59 4,321.79 -2,496.31 -503.55 5,925,144.34 460,312.94 0.00 2,470.67 5,400.00 40.58 188.98 4,554.05 4,399.25 -2,558.43 -515.27 5,925,082.28 460,300.90 3.35 2,532.19 5,500.00 43.38 185.84 4,628.38 4,473.58 -2,624.74 -523.84 5,925,016.02 460,291.99 3.50 2,598.04 5,600.00 46.26 183.02 4,699.31 4,544.51 -2,695.01 -529.24 5,924,945.80 460,286.22 3.50 2,667.98 5,700.00 49.20 180.45 4,766.57 4,611.77 -2,768.96 -531.44 5,924,871.87 460,283.64 3.50 2,741.75 5,800.00 52.20 178.11 4,829.91 4,675.11 -2,846.31 -530.43 5,924,794.51 460,284.25 3.50 2,819.08 5,900.00 55.23 175.95 4,889.09 4,734.29 -2,926.80 -526.22 5,924,714.02 460,288.04 3.50 2,899.67 6,000.00 58.30 173.94 4,943.88 4,789.08 -3,010.10 -518.83 5,924,630.69 460,295.00 3.50 2,983.22 6,100.00 61.41 172.06 4,994.10 4,839.30 -3,095.91 -508.27 5,924,544.83 460,305.11 3.50 3,069.43 6,200.00 64.53 170.29 5,039.54 4,884.74 -3,183.91 -494.59 5,924,456.76 460,318.33 3.50 3,157.96 6,300.00 67.68 168.62 5,080.05 4,925.25 -3,273.78 -477.85 5,924,366.82 460,334.61 3.50 3,248.50 6,350.00 69.26 167.81 5,098.40 4,943.60 -3,319.31 -468.35 5,924,321.25 460,343.87 3.50 3,294.42 • Tie-on @ 6350'MD,5098'TVD:1752'FSL,1295'FEL-Sec22-T10N-R10E 6,400.00 71.63 166.98 5,115.14 4,960.34 -3,365.28 -458.06 5,924,275.23 460,353.92 5.00 3,340.81 6,500.00 76.39 165.38 5,142.68 4,987.88 -3,458.60 -435.09 5,924,181.80 460,376.41 5.00 3,435.08 6,541.18 78.34 164.75 5,151.69 4,996.89 -3,497.42 -424.73 5,924,142.93 460,386.56 4.98 3,474.33 6,600.00 78.34 164.75 5,163.58 5,008.78 -3,553.00 -409.58 5,924,087.28 460,401.42 0.00 3,530.55 6,612.98 78.34 164.75 5,166.20 5,011.40 -3,565.26 -406.24 5,924,075.01 460,404.70 0.00 3,542.95 S-8 6,700.00 78.34 164.75 5,183.78 5,028.98 -3,647.48 -383.81 5,923,992.67 460,426.70 0.00 3,626.11 6,800.00 78.34 164.75 5,203.99 5,049.19 -3,741.97 -358.05 5,923,898.06 460,451.97 0.00 3,721.68 6,820.30 78.34 164.75 5,208.09 5,053.29 -3,761.15 -352.82 5,923,878.86 460,457.10 0.00 3,741.08 6,900.00 82.32 164.55 5,221.47 5,066.67 -3,836.90 -332.02 5,923,803.01 460,477.50 5.00 3,817.70 7,000.00 87.32 164.30 5,230.49 5,075.69 -3,932.80 -305.28 5,923,706.98 460,503.74 5.00 3,914.73 7,048.30 89.74 164.18 5,231.72 5,076.92 -3,979.27 -292.17 5,923,660.45 460,516.61 5.02 3,961.74 7 5/8" 7,100.00 89.74 164.18 5,231.95 5,077.15 -4,029.01 -278.07 5,923,610.64 460,530.44 0.00 4,012.08 7,200.00 89.74 164.18 5,232.40 5,077.60 -4,125.22 -250.81 5,923,514.30 460,557.20 0.00 4,109.44 7,278.30 89.74 164.18 5,232.76 5,077.96 -4,200.55 -229.47 5,923,438.86 460,578.16 0.00 4,185.67 2L-322_H_CP1(wp04) 7,300.00 90.39 164.13 5,232.74 5,077.94 -4,221.43 -223.54 5,923,417.96 460,583.97 3.00 4,206.79 7,340.05 91.59 164.04 5,232.04 5,077.24 -4,259.94 -212.56 5,923,379.39 460,594.75 3.00 4,245.76 7,400.00 91.59 164.04 5,230.38 5,075.58 -4,317.56 -196.09 5,923,321.70 460,610.93 0.00 4,304.07 7,500.00 91.59 164.04 5,227.61 5,072.81 -4,413.67 -168.60 5,923,225.46 460,637.91 0.00 4,401.34 7,597.25 91.59 164.04 5,224.92 5,070.12 -4,507.13 -141.87 5,923,131.87 460,664.15 0.00 4,495.93 2L-322_H_CP2(wp04) 11/30/2010 12:57:00PM Page 5 COMPASS 2003.16 Build 69 IC ftL_ Halliburton -Sperry HALLIBURTONI Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-322(North) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-322 D15 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-322 D15 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-322(North) Survey Calculation Method: Minimum Curvature Wellbore: 2L-322 Design: 2L-322(wp04) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 5,070.05 7,600.00 91.51 164.05 5,224.85 5,070.05 -4,509.77 -141.12 5,923,129.22 460,664.89 3.00 4,498.60 7,680.25 89.10 164.21 5,224.42 5,069.62 -4,586.96 -119.17 5,923,051.92 460,686.44 3.00 4,576.71 7,700.00 89.10 164.21 5,224.73 5,069.93 -4,605.96 -113.80 5,923,032.90 460,691.71 0.00 4,595.94 7,800.00 89.10 164.21 5,226.29 5,071.49 -4,702.18 -86.59 5,922,936.55 460,718.41 0.00 4,693.30 7,900.00 89.10 164.21 5,227.86 5,073.06 -4,798.39 -59.39 5,922,840.21 460,745.12 0.00 4,790.66 8,000.00 89.10 164.21 5,229.42 5,074.63 -4,894.61 -32.18 5,922,743.86 460,771.82 0.00 4,888.01 8,012.45 89.10 164.21 5,229.62 5,074.82 -4,906.58 -28.79 5,922,731.87 460,775.14 0.00 4,900.13 2L-322_H_CP3(wp04) 8,054.10 87.85 164.17 5,230.73 5,075.93 -4,946.65 -17.45 5,922,691.75 460,786.28 3.00 4,940.67 8,100.00 87.85 164.17 5,232.44 5,077.64 -4,990.77 -4.94 5,922,647.57 460,798.56 0.00 4,985.33 8,200.00 87.85 164.17 5,236.19 5,081.39 -5,086.91 22.32 5,922,551.29 460,825.31 0.00 5,082.61 8,300.00 87.85 164.17 5,239.93 5,085.13 -5,183.06 49.57 5,922,455.02 460,852.07 0.00 5,179.90 8,400.00 87.85 164.17 5,243.68 5,088.88 -5,279.20 76.83 5,922,358.75 460,878.82 0.00 5,277.19 8,500.00 87.85 164.17 5,247.42 5,092.62 -5,375.34 104.09 5,922,262.48 460,905.58 0.00 5,374.47 8,505.82 87.85 164.17 5,247.64 5,092.84 -5,380.93 105.67 5,922,256.88 460,907.13 0.00 5,380.14 2L-322_H_CP4(wp04) 8,519.34 88.11 164.09 5,248.12 5,093.32 -5,393.93 109.37 5,922,243.86 460,910.76 2.00 5,393.29 8,600.00 88.11 164.09 5,250.77 5,095.97 -5,471.46 131.47 5,922,166.23 460,932.46 0.00 5,471.74 8,700.00 88.11 164.09 5,254.07 5,099.27 -5,567.57 158.87 5,922,069.98 460,959.36 0.00 5,569.01 8,800.00 88.11 164.09 5,257.37 5,102.57 -5,663.69 186.27 5,921,973.73 460,986.26 0.00 5,666.28 8,814.39 88.11 164.09 5,257.84 5,103.04 -5,677.52 190.22 5,921,959.88 460,990.13 0.00 5,680.28 j 2L-322_H_CP5(wp04) 8,894.97 90.51 164.35 5,258.81 5,104.01 -5,755.06 212.13 5,921,882.24 461,011.63 3.00 5,758.73 8,900.00 90.51 164.35 5,258.76 5,103.96 -5,759.90 213.48 5,921,877.40 461,012.96 0.00 5,763.63 9,000.00 90.51 164.35 5,257.86 5,103.06 -5,856.19 240.45 5,921,780.98 461,039.43 0.00 5,861.05 9,070.62 90.51 164.35 5,257.23 5,102.43 -5,924.19 259.50 5,921,712.88 461,058.12 0.00 5,929.86 2L322_H_CP6(wp04) 9,100.00 91.98 164.25 5,256.59 5,101.79 -5,952.46 267.45 5,921,684.57 461,065.92 5.00 5,958.47 9,151.89 94.57 164.07 5,253.63 5,098.83 -6,002.30 281.58 5,921,634.67 461,079.80 5.00 6,008.89 9,200.00 94.57 164.07 5,249.80 5,095.00 -6,048.41 294.75 5,921,588.49 461,092.73 0.00 6,055.56 9,286.92 94.57 164.07 5,242.87 5,088.07 -6,131.73 318.53 5,921,505.06 461,116.07 0.00 6,139.88 31/2" 9,287.00 94.57 164.07 5,242.87 5,088.07 -6,131.80 318.55 5,921,504.98 461,116.09 0.00 6,139.96 TD @ 9287'MD,5242.96'TVD:1061'FNL,512'FEL-Sec27-T10N-R07E 9,287.10 94.57 164.07 5,242.86 . 5,088.06 -6,131.90 , 318.58 . 5,921,504.89 461,116.12 0.00 6,140.06 2L-322_H_Toe(wp04) 11/30/2010 12:57:00PM Page 6 COMPASS 2003.16 Build 69 G ( IL Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-322(North) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-322 D15 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-322 D15 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-322(North) Survey Calculation Method: Minimum Curvature Wellbore: 2L-322 Design: 2L-322(wp04) Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +N/-S +E/-W Northing Easting -Shape (°) r) (ft) (ft) (ft) (ft) (ft) 2L-322_H_CP4(wp04) 0.00 0.01 5,247.64 -5,380.93 105.67 5,922,256.88 460,907.13 -plan hits target center -Point 2L-322_H_CP3(wp04) 0.00 0.01 5,229.62 -4,906.58 -28.79 5,922,731.87 460,775.14 -plan hits target center -Point 2L-322_H_Toe(wp04) 0.00 0.00 5,242.86 -6,131.90 318.58 5,921,504.89 461,116.12 -plan hits target center -Point 2L-322_H_CP5(wp04) 0.00 0.01 5,257.84 -5,677.52 190.22 5,921,959.88 460,990.13 -plan hits target center -Point 2L-322_H_CP2(wp04) 0.00 0.01 5,224.92 -4,507.13 -141.87 5,923,131.87 460,664.15 -plan hits target center -Point 2L-322_H CP6(wp04) 0.00 0.01 5,257.23 -5,924.19 259.50 5,921,712.88 461,058.12 -plan hits target center -Point 2L-322_H_CP1(wp04) 0.00 0.01 5,232.76 -4,200.55 -229.47 5,923,438.86 460,578.16 -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (••) (") 7,048.30 5,231.72 7 5/8" 7-5/8 9-7/8 2,665.22 2,400.00 10 3/4" 10-3/4 13-1/2 9,286.92 5,242.87 3 1/2" 3-1/2 6-3/4 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (°) (') 5,372.20 T-2 0.00 6,612.98 5,166.20 S-8 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E1-W (ft) (ft) (ft) (ft) Comment 6,350.00 5,098.40 -3,319.31 -468.35 Tie-on @ 6350'MD,5098'TVD:1752'FSL,1295'FEL-Sec22-T1ON-R1OE 9,287.00 5,242.87 -6,131.80 318.55 TD @ 9287'MD,5242.96'TVD:1061'FNL,512'FEL-Sec27-T1 ON-R07E 11/30/2010 12:57:00PM Page 7 COMPASS 2003.16 Build 69 I '.:3 IN L 1 m 0 am 3 in M 21 o Q m = a N N to M E 1 m OH U . 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O M M N M N N \• CO • • W • N CD d61) ch ;� ' e FM ; J N • N f a. /- -- --- lf) \\ ' J N J •• ..• (V r • N• M• '.•'�r 3 / 2 • N N N J • M , N • J mM N O • • N . . , .. _, : „...., . .. _ • O • N Lj M i ?JN N o O 7 N ih Q g N 7 7NN N • r N N 4; • CCN, l�0 @. • 0 • YYa Li; - �„ dI 2 T. _ N °- N(y aY;X • CO N '2"e C N P. c d 11 • N • J • N Z 1 �. • m c • ;: • J a • ORIGINAL 2L-322 Drilling Hazards Summary 13-1/2" Hole/ 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate If observed-control drill,reduce pump rates,reduce drilling fluid temperatures,Additions of Lecithin. Gravel/Sand Sloughing Moderate Increase mud weight/viscosity,High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill(use of Trips trip sheets),Pumping out of hole as needed. Lost Circulation Low Prevent by keeping hole clean. If losses occur-reduce pump rates and mud rheology,use LCM 9-7/8" Hole/7-5/8" Casing Interval Event Risk Level Mitigation Strategy Campanian Sands Moderate Control with higher MW and proper drilling practices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Follow mud weight schedule and do not fall behind. Stripping Drills,Shut-in Drills,PWD Tools,Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Low • Use PWD to monitor hole cleaning. Reduced pump rates,Mud rheology,LCM. Use GKA LC decision tree. 6 3/4" Hole/3-1/2" Horizontal Liner Interval Event Risk Level Mitigation Strategy High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Follow mud weight schedule and do not fall behind. Stripping Drills,Shut-in Drills,PWD Tools,Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates,Mud rheology,LCM. Use GKA LC decision tree. A. 2L-322 Hazards.doc Prepared by Mike Greener Page 1 of 1 v TUT p : ii !ii1iii 40 CO 01 I I ❑ I 7 X11, m [ I I � CN _ I I I I m 10 ° 0 0 c C c c m a) a) w a) H _ U a) Q) a) a) OD co Q7 a} a? ITD C O O O O 0) g- C C C O _ _ _ _ F CCS a6 0+++ a)) a) al a) M /�•• a) v7 co Cn co c J CoCorr7 in -o 6 til Ls') 05 a) 0 ca 0 0 0 0 a) DI c al DI O C1.L C O O a1 al J CL 11 II to C CLC c C c C c I 15 M J M J LiD s J 15 15 J 15 o H = = CO = =C = =CA = = C0 n -0 o == H F- r F- F- r H H-�H H -- Ha X == J J ,...J J V J J+-J J --=J m ar 47 00 00 Ol m co aF co co aJ CO W a- CO c c V- U.1 == =',., = =U =- = . 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Q UM . . s 01 - II �:' ;?� O c — ' = Iz _ H 6; j a7 �j bi �j 6i mai cru ' 1 s; s; bi cu'n n .4::' .,:,fir' C? 47Qa co I__ 0 �� m - - - -- - tv� N _mo ____ -__<02 a 6]Lo cu ( _ CV CV N CV{V N WN V �N. S6 W :::•:? C a NCS = = �C �C �,c, irTC 03 .- %- r f J :{r I H .1- MMM co M M q7 M M U M MMM f ^^^^ ..-::.:...............................................:........... t, t-� v r[?€o Eo i o cv c i v to cfl rti Qo a7 :'t o > Q o F- d a(,•.4F b' 41 v oPirltd A --,--. 2L-322 (North) Schlumberger CemCADE Preliminary Job Design 10-3/4" Surface Casin• (WP-04) V2 Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Volume Calculations and Cement Systems Location: Tarn Volumes are based on 300% excess in the permafrost and 50% excess below the Client:CPAI Revision Date: 12/1/2010 permafrost. The top of the tail slurry is designed to be at-1665' MD. Prepared by: Steve Shultz Location:Anchorage,AK Lead Slurry Minimum pump time: 255 min. (pump time plus 120 min.) Phone: (907)263-4297 ARCTICSET Lite @ 10.7 ppg-4.51 ft3/sk 0.6381 ft3/ft x (80')x 1.00 (no excess) = 51 ft3 �, 0.3637 ft3/ft x (1545-80')x 4.00 (300% excess) = 2131 ft3 `✓ < TOC at Surface 0.3637 ft3/ft x (1926-1545)x 1.50 (50% excess) = 65 ft 3 �`~ 51 ft3+2131 ft3+208 ft3. 2247 ft 3 / 2247 ft 4.51 IL = 498 sks ✓ Round up to 500 sks Have additional ASL on location for Top Out stage,if necessary. Previous Csg. Tail Slurry Minimum pump time: 185 min. (pump time plus120 min.) < 16",62.6#casing 12.0 ppg DeepCRETE+ additives- 1.64 ft3/sk at 80'MD 0.3637 ft3/ft x (2665-1665)x 1.50 (50% excess) = 546 ft 0.53997 ft3/ft x 80' (Shoe Joint) = 43 ft3 546 ft3+43 ft3= 589 ft3 589 ft3/ 1.64 ft3/sk= 360 sks BHST=77°F, Estimated BHCT = 73°F. < Base of Permafrost at (BHST calculated using a gradient of 2.1°F/100 ft. from surface) 1,545 MD(1,500'TVD) PUMP SCHEDULE Stage Cumulative Stage Pump Rate Volume Stage Time Time f (bpm) (bbl) (min) (min) CW100 5.0 50.0 10.0 10.0 MUDPUSH II 5.0 50.0 10.0 20.0 < Top of Tail at Drop bottom plug 0.0 0.0 5.0 25.0 1,665'MD ASL 6.0 400.0 66.6 91.6 DeepCRETE 6.0 104.9 17.5 109.6 Drop top plug 0.0 0.0 5.0 114.1 Water 5.0 10.0 2.0 116.1 Switch to rig 0.0 0.0 3.0 119.1 MOBM 8.0 254.7 31.8 140.9 Slow&Bump plug 3.0 9.0 3.0 143.9 < 10-3/4",45.5#casing in 13-1/2"OH MUD REMOVAL Expected Mud Properties:9.6 ppg, Pv<25, Ty<35 TD at 2,665 MD (2,400'TVD) Displacement Mud (MOBM): 10.0 ppg, Pv<22, Ty< 12 Spacer Properties: 10.5 ppg MudPUSH* II, Pv 20-25, Ty 30-35 Centralizers: As per CPAi program. *Mark of Schlumberger ORG1NAL 2L-322 North Schlumberger ( ) CemCADE Preliminary Job Design 7-5/8" Longstring (WP-04)V2 -'OBM Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Location: Alpine Client: CPAI Revision Date: 12/1/2010 Volume Calculations and Cement Systems Prepared by: Steve Shultz Volumes are based on 50% excess. The top of the tail slurry is designed to be Location:Anchorage,AK Phone: (907)263-4297 -4,000' MD. Tail Slurry Minimum pump time: -250 min. (pump time plus 120 min.) 15.8 ppg Class G +2.0 gps D600G + 0.2%D46, 0.6%D65, 0.03 gps D177 - 1.17 ft3/sk 0.2148 ft3/ft x (7048 -4000)x 1.50 (50% excess) 982 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 21 ft3 951 ft3+ 21 ft3= 1003 ft 3 Previous Csg. 97 ft3/ 1.17 ft3/sk = 857 sks < 10-3/4",45.5.#casing Round up to 860 sks at 2,926'MD BHST = 139°F, Estimated BHCT = 106°F. (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (min) (bbl) (min) CW101 5.0 40.0 8.0 8.0 MPII-OBMI 5.0 40.0 8.0 16.0 Drop bottom plug 0.0 0.0 5.0 21.0 GasBLOK Slurry 6.0 178.0 29.7 50.7 Drop top plug 0.0 0.0 5.0 55.7 Water 5.0 10.0 2.0 57.7 Switch to rig 0.0 0.0 3.0 60.7 Water 8.0 289 58.9 96.8 < Top of Cement at Slow for ECD 6.0 18.0 3.0 99.8 4,000'MD Bump plug 3.0 9.0 3.0 102.8 MUD REMOVAL < 7-5/8",29.7#casing Expected Oil Based Mud Properties: 10.0 ppg, Pv<22, Ty< 12 in 9-7/8"OH Spacer Properties: 11.5 ppg MudPUSH* II, Pv= 20 -25, Ty= 35 -40 TD at 7,048'MD Centralizers: As per COP program (5,232'TVD) .Mark of Schlumberger r I r 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 / Z- PTD# 7 J ) ' / Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: Kir ( (/ z POOL: kt �� q G� e � 11 41 67 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 ( Lam- 2 2_PH) and API number (50-/05 - 7C) /Zf' - '7D) from records, data and logs acquired for well Kn[.0 2 L. .Z-- SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 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. 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C C) 01 C%i Q N �_. p N O o O ' 0) N CD l0 N r CD a D 0 N 7 A 'O 0 CD Q (O Z 3 - O * Di O CD N O 3 O a CD Q j CD D 7' ' ,z O N 'p * 'NcE d 7' N O co O o 0 3 O < 3 o) -. 7 • C) C) z Q CD D 0 N O O -0 cn I- co m co < O O• 3 n co O 7 D (71J O (D 3 O CD O co O 3 O) N 0 C 7 Cn C Q c -I 1 N 3 7 K D ca a) 1- > s c w = CD m = c 3 Oo ' 8- ii a O CD _ In c a Co m o a cn Vv'ell History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu May 05 12:06:57 2011 Reel Header Service name LISTPE Date 11/05/05 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 11/05/05 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Tarn MWD/MAD LOGS WELL NAME: 2L-322 API NUMBER: 501032062800 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling TAPE CREATION DATE: 04-MAY-11 JOB DATA MWD RUN 1 MWD RUN 2 JOB NUMBER: AKMW0007742777 AKMW0007742777 LOGGING ENGINEER: BENJAMIN SCH JOE GRANADOS OPERATOR WITNESS: LARRY HILL RAY SPRINGER SURFACE LOCATION SECTION: 22 TOWNSHIP: 10N RANGE: 7E FNL: 209 FSL: FEL: 821 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 154.85 GROUND LEVEL: 114 .80 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.500 16.000 120.0 2ND STRING 9.875 10.750 2610.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3. MWD RUNS 1,2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) , AND DRILLSTRING DYNAMICS SENSOR (DDSr) . MWD RUN 2 ALSO INCLUDED AZIMUTHAL LITHO-DENSITY (ALD) , COMPENSATED THERMAL NEUTRON (CTN) , BI-MODAL ACOUSTIC TOOL (BAT) , ACOUSTIC CALIPER (ACAL) , AND PRESSURE-WHILE-DRILLING (PWD) . MAD ALD AND CTN DATA ACQUIRED OVER 3 SLIDE INTERVALS (6639'-6675' ; 7018'-7045' ; 7111'- 7153' , ALL BIT MD DEPTHS) REPLACED MWD DATA. NO OTHER MAD DATA ARE PRESENTED. • 4. INTERMEDIATE TD WAS CALLED EARLY DUE TO WELL CONTROL CONCERNS. WHEN THE INFLOW OF GAS COULD NOT BE SHUT OFF, THE DECISION WAS MADE TO CEMENT THE BHA IN PLACE. BECAUSE OF THIS, ONLY REAL TIME DATA WERE ACQUIRED FOR MWD RUN 2. THE RUN 2 INTERVAL DOES NOT INCLUDE: R09P, R27P, TNFA, TNNA, ADCL, AHSI, APEL, ALRP, AND NO BAT DATA. 5. LWD DATA ARE CONSIDERED PRIMARY DEPTH CONTROL PER E-MAIL FROM LISA WRIGHT (CPAI) TO BRYAN BURINDA (SD) DATED 12 JANUARY 2011. 6. MWD RUNS 1,2 REPRESENT WELL 2L-322 WITH API#: 50-103-20628-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7473'MD/5318'TVD. MNEMONICS CURVE DESCRIPTION ROPA AVERAGE RATE OF PENETRATION DGRC DGR COMBINED GAMMA RAY R09P 9 INCH PHASE RESISTIVITY R15P 15 INCH PHASE RESISTIVITY R27P 27 INCH PHASE RESISTIVITY R39P 39 INCH PHASE RESISTIVITY EWXT EWR FORMATION EXPOSURE TIME TNPS CTN POROSITY - SANDSTONE TNFA CTN FAR AVERAGE COUNT RATE TNNA CTN NEAR AVERAGE COUNT RATE ACHD ACAL HOLE DIAMETER AHSI ALD HOLE-SIZE INDICATOR ACDL ALD LCRB COMPENSATED DENSITY ADCL ALD LCRB DENSITY CORRECTION APEL ALD LCRB Pe FACTOR ALRP ALD RPM (ZERO RPM'S INDICATES SLIDING) BTCS BAT COMPRESSIONAL SLOWNESS BCSS BAT COMBINED SHEAR SLOWNESS BVPS BAT VP/VS RATIO BSFG BAT SHEAR FLAG PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: FIXED HOLE SIZE - 9.875" BIT MUD WEIGHT: 9.5 - 10.8 PPG MUD SALINITY: 600 - 1500 PPM CHLORIDES FORMATION WATER SALINITY: 19149 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2. 65 G/CM3 LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP, AND GAMMA RAY. THESE CURVES ARE SMOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/05/05 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 232.0 7412.5 RPX 242.0 2561.5 RPM 242.0 2561.5 RPD 242.0 7422.5 FET 242.0 7422.5 RPS 242.0 7422.5 ROP 309.5 7473.0 CALA 2529.0 7381.5 RHOB 2600.0 7392.0 NPHI 2600.0 7378.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 232.0 2620.0 MWD 2 2620.0 7473.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWD IN 4 1 68 4 2 RHOB MWD G/CC 4 1 68 8 3 GR MWD API 4 1 68 12 4 FET MWD HR 4 1 68 16 5 RPX MWD OHMM 4 1 68 20 6 RPS MWD OHMM 4 1 68 24 7 RPM MWD OHMM 4 1 68 28 8 RPD MWD OHMM 4 1 68 32 9 ROP MWD FPH 4 1 68 36 10 NPHI MWD PU 4 1 68 40 11 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 232 7473 3852.5 14483 232 7473 CALA MWD IN 8.39 11.24 9.92464 9415 2529 7381.5 RHOB MWD G/CC 1.424 2.794 2.33131 9305 2600 7392 GR MWD API 13.69 207.52 106.288 14238 232 7412.5 FET MWD HR 0.21 80.68 1.13389 13974 242 7422.5 RPX MWD OHMM 1.61 102.79 14.1462 4640 242 2561.5 RPS MWD OHMM 1.19 1572.41 11.1634 13974 242 7422.5 RPM MWD OHMM 1.33 2000 46.7812 4640 242 2561.5 RPD MWD OHMM 0.1 2000 23.7723 13974 242 7422.5 ROP MWD FPH 1.57 647. 91 140.189 14328 309.5 7473 NPHI MWD PU 2.14 60. 11 30.0513 9275 2600 7378.5 First Reading For Entire File 232 Last Reading For Entire File 7473 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/05/05 Maximum Physical Record65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/05/05 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD • Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 232.0 2552.0 R09P 242.0 2561.5 R39P 242.0 2561.5 R27P 242.0 2561.5 R15P 242.0 2561.5 EWXT 242.0 2561.5 ROPA 309.5 2620.0 LOG HEADER DATA DATE LOGGED: 12-APR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 2620.0 TOP LOG INTERVAL (FT) : 232.0 BOTTOM LOG INTERVAL (FT) : 2620.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .3 MAXIMUM ANGLE: 39.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 163685 EWR4 ELECTROMAG. RESIS. 4 129431 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 13.500 DRILLER'S CASING DEPTH (FT) : .0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) : 9.20 MUD VISCOSITY (S) : 246.0 MUD PH: 9.3 MUD CHLORIDES (PPM) : 850 FLUID LOSS (C3) : 601.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 5.000 69.0 MUD AT MAX CIRCULATING TERMPERATURE: 4 .040 88.5 MUD FILTRATE AT MT: 6.250 69.0 MUD CAKE AT MT: 6.250 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet • Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 FET MWDO10 HR 4 1 68 8 3 RPX MWDO10 OHMM 4 1 68 12 4 RPS MWDO10 OHMM 4 1 68 16 5 RPM MWDO10 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 ROP MWD010 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 232 2620 1426 4777 232 2620 GR MWD010 API 13.69 135.02 73.714 4641 232 2552 FET MWD010 HR 0.21 6. 66 0.89134 4640 242 2561.5 RPX MWD010 OHMM 1. 61 102.79 14.1462 4640 242 2561.5 RPS MWD010 OHMM 1.5 1572.41 25.033 4640 242 2561.5 RPM MWD010 OHMM 1.33 2000 46.7812 4640 242 2561.5 RPD MWDO10 OHMM 1.33 2000 60.4297 4640 242 2561.5 ROP MWDO10 FPH 3.03 647.91 164 .379 4622 309.5 2620 First Reading For Entire File 232 Last Reading For Entire File 2620 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/05/05 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/05/05 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ACHD 2529.0 7381.5 DGRC 2552.5 7412.5 ACDL 2600.0 7392.0 R39P 2600.0 7422.5 EWXT 2600.0 7422.5 R15P 2600.0 7422.5 TNPS 2600.0 7378.5 ROPA 2620.5 7473.0 LOG HEADER DATA DATE LOGGED: 19-APR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 7473.0 TOP LOG INTERVAL (FT) : 2620.0 BOTTOM LOG INTERVAL (FT) : 7473.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 36.4 MAXIMUM ANGLE: 81.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 277300 EWR4 ELECTROMAG. RESIS. 4 231951 CTN COMP THERMAL NEUTRON 245542 BAT Bi-modal Acoustic 11462979 ALD Azimuthal Litho-Dens 126974 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 9.875 DRILLER'S CASING DEPTH (FT) : 2610.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.75 MUD VISCOSITY (S) : 43.0 MUD PH: 9.4 MUD CHLORIDES (PPM) : 900 FLUID LOSS (C3) : 6.7 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1.350 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .620 157.2 MUD FILTRATE AT MT: 1. 650 69.0 MUD CAKE AT MT: 1. 600 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined • Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWD020 IN 4 1 68 4 2 RHOB MWD020 G/CC 4 1 68 8 3 GR MWD020 API 4 1 68 12 4 FET MWD020 HR 4 1 68 16 5 RPS MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 NPHI MWD020 PU 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2529 7473 5001 9889 2529 7473 CALA MWD020 IN 8.39 11.24 9. 92464 9415 2529 7381.5 RHOB MWD020 G/CC 1.424 2.794 2.33131 9305 2600 7392 GR MWD020 API 41.79 207 .52 122.04 9598 2552.5 7412.5 FET MWD020 HR 0.27 80. 68 1.25446 9334 2600 7422.5 RPS MWD020 OHMM 1.19 26.15 4.26877 9334 2600 7422.5 RPD MWD020 OHMM 0.1 2000 5.54963 9334 2600 7422.5 ROP MWD020 FPH 1.57 256. 64 128. 67 9706 2620.5 7473 NPHI MWD020 PU 2.14 60. 11 30.0513 9275 2600 7378.5 First Reading For Entire File 2529 Last Reading For Entire File 7473 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/05/05 Maximum Physical Record65535 File Type LO Next File Name STSLIB.004 Physical EOF Tape Trailer Service name LISTPE Date 11/05/05 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 11/05/05 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ConocoPhillips Alaska, Inc. FINAL WELL REPORT MUDLOGGING DATA 2L-322 14.4 • CAI4 a , SIG I.10. Approved by: Lisa Wright Compiled by: Tollef Winslow Zach Beekman Dan Sherwood Larry Resch Distribution: May 9, 2011 Date: April 19, 2011 $;_ k — L -7v( ConocoPhillips Alaska.Inc. 2L-322 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT&CREW 3 1.1 Equipment Summary 3 1.2 Crew 4 2 WELL DATA 5 2.1 Well Summary 5 2.2 Hole Data 5 2.3 Well Synopsis 5 3 GEOLOGICAL DATA 6 3.1 Formation Tops. 6 3.2 Lithologic Descriptions/Stratigraphy 7 3.3 Connection Gas Summary. 12 3.4 Trip/Wiper Gas Summary 12 3.5 Iso-Tube Chromatography 13 3.6 Sampling Program/Sample Dispatch 13 4 PRESSURE/FORMATION STRENGTH DATA 14 4.1 Pore Pressure Gradient Evaluation 14 4.2 Quantitative Methods 15 5 DRILLING DATA 16 5.1 Daily Activity 16 5.2 Survey Data 19 5.3 Bit Record 22 5.4 Mud Record: 23 5.4.1 Surface Hole--MiSwaco Spud Mud 23 5.4.2 Intermediate Hole MiSwaco LSND 24 6 DAILY REPORTS 25 Enclosures: 2"/100' Formation Log (MD and TVD) 2"/100' LWD Combo Log (MD and TVD) 2"/100' Drilling Dynamics Log (MD and TVD) 2"/100'Gas Ratio Log (MD and TVD) Final Well Data on CD ROM 2 CANRIG Conoc Phillips Alaska.Inc. 2L-322 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type/Position Total Comments Downtime QGM agitator and gas trap Ditch gas Flame ionization total gas 0 and chromatography. TOTCO feed Hook Load, Weight on bit TOTCO WITS Feed 1 unreliable throughout well. Derived from Pump Stroke Mud Flow In 1 Rates*and Pump Output Mud Flow Out TOTCO WITS Feed* 1 Mudlogging Unit computer HP Compaq Pentium 4 0 systems (x2: DML&RigWatch) Mudlogging Unit Acromeg In-unit data 0 box collection/distribution center TOTCO feed Pit Volumes, Pit Gain/Loss TOTCO WITS Feed* 1 unreliable throughout well. TOTCO feed Pump Pressure TOTCO WITS Feed* 1 unreliable throughout well. TOTCO feed Pump Strokes TOTCO WITS Feed* 1 unreliable throughout well. TOTCO Well Monitoring TOTCO computer networked TOTCO feed Components in mud logging unit* 1 unreliable throughout well. Derived from TOTCO depth TOTCO feed Rate of Penetration tracking components(block 1 unreliable throughout height*) well. TOTCO feed RPM TOTCO WITS Feed* 1 unreliable throughout well. TOTCO feed Torque TOTCO WITS Feed* 1 unreliable throughout well. 3 CANRIG ConocoPhillips Alaska.Inc. 2L-322 1.2 Crew Unit Number: ML057 Unit Type: Custom/Arctic/Steel Mudloggers Years of Days at Sample Catchers Years of Days at Technician Days at Experience 2L-322 Experience 2L-306 2L-306 Larry Resch 9 8 Doug Acker 1 15 Allan Williams 1 Tollef Winslow 3 21 Zach Beekman 3 15 _ Dan Sherwood 4 14 4 CANRIG ConocoPhillips Alaska.Inc 2L-322 2 WELL DATA 2.1 Well Summary Well: 2L-322 API Index#: 50-103-20628-00-00 Field: Kuparuk River Unit Surface Co-Ordinates: 209' FNL, 821' FEL Tarn Oil Pool Sec. 22, T10N, R7E UM Borough: North Slope Primary Targets: Bermuda Formation State: Alaska Primary Target Depth: 6572'MD/-5006'SSTVD Rig Name/Type: Doyon 15/Arctic/Tripple Primary Actual Depth 11339'MD/-5191'SSTVD Spud Date: April 10, 2011 TD Depth: 7473'MD/5319'TVD TD Date: April 19, 2011 Ground Elevation: 114.8'AMSL Days Drilling: 21 KB Elevation: 154.8'AMSL Completion Status: Plugged and Abandoned TD Formation: Seabee Fm. /equivalent Classification: Conventional Grassroots Days Evaluating: None Producer 2.2 Hole Data Hole Maximum Depth TD Mud Dev. Casing/ Shoe Depth LOT Section MD TVD Formation Weight Liner MD TVD (ppg) (ft) (ft) (ft) (ft) (ppg) (°inc) Conductor Permafrost 0 16" 114 114 13-1/2" 2620 2362 9.5 39 10-3/4" 2613' 2357' 12.6 9-7/8" 7473 5319 Seabee/Eq 10.4 81 P&A 2.3 Well Synopsis KRU Tarn 2L-322 was drilled as a conventional grassroots producer targeting a lateral to distal portion of the 2N Tarn turbidite accumulation. The well incorporates a pilot hole and a subsequent horizontal sidetrack. The pilot hole was designed to define reservoir presence and parameters. The pilot hole encountered 509 feet of gross reservoir thickness at a depth of-5005 TVDSS. The gas cap was encountered as well as possible gas flooding from nearby injector wells. After a week and a half of attempting to control the well while sustaining high total gas readings and massive losses, the well was plugged and abandoned. 5 CANRIG ConocoPhillips Alaska.Inc. 2L-322 3 GEOLOGICAL DATA 3.1 Formation Tops: Zone or Horizon Prognosed Depth (ft) Actual Depth (ft) MD TVD SS MD TVD SS 10-3/4" Casing 2669' 2400' -2245 2613' 2357' -2202 Shoe 9-7/8" Intermediate _Borehole C80 (K10) -- -- -- 2,747' 2,461' -2,306' Camp Sand (Top) 2,820' 2,520' -2,365' 2,823' 2,520' -2,365' C50 4,300' 3,695' -3,540' 4,285' 3,688' -3,533' C40 4,791' 4,085' -3,930' 4,773' 4,075' -3,920' C37 5,093' 4,325' -4,170' 5,081' 4,317' -4,162' Top Resevoir 6,572' 5,161' -5,006' 6,580' 5,160' -5,005' Base Resevoir 7,128' 5,260' -5,105' 7,089' 5,258' -5,103' C35 TD 7,934' 5,400' -5,245' 7,473' 5,318' -5,163' Note: Horizons and Depths provided by wellsite geologist. 6 CANRIG ConocoPhillips Alaska.Inc. 2L-322 3.2 Litholoqic Descriptions/Stratigraphy SURFACE TO TOP OF C-80: (114' MD/41' TVDSS to 2747' MD/-2306' TVDSS) Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 731 3.5 159.2 1530 1 432.5 Gas Peaks Depth(MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 1346' 1530u 385040 0 0 0 0 0 0 2406' 1477u 286165 238 15 14 0 20 18 High background gas levels and peaks were observed from approximately I 300'MD to 2600'MD with the maximum recorded gas of 1530 units at 1346'MD. This interval is comprised of interbedded clays, silty claystones, conglomeratic sands, silty sand with patchy cementation, all in varying proportions, along with minor organic material and sporadic conglomerates. The sand conglomerate is generally composed of transparent and translucent grains with occasional medium light gray to light gray grains; upper medium to upper fine with abundant coarse grains; poor to moderately poor sorted;sub-angular to sub-rounded;moderate to low sphericity;loose unconsolidated quartz grains with no apparent cement. A salt and pepper appearance predominates. The sand is composed of milky white, translucent, transparent, opaque quartz; light gray smoky light gray, moderate yellowish brown lithic fragments; upper medium to upper fine grained; light greenish gray; sub- rounded to sub-angular, angular in places; moderately sorted; highly unconsolidated with no apparent cementation. The claystones in this section are dark medium gray to medium light gray with blackish hues;poor to moderate induration; brittle to crumbly to occasionally tough; irregular to occasionally blocky to rarely planar;tabular to platy cuttings habit;dull to occasionally earthy luster;smooth to clayey texture; pulverized clay is moderately hydrophilic; moderate to good cohesiveness; poor to moderate adhesiveness; pasty to lumpy consistency. C-80 TO TOP OF CAMP SAND: (2747' MD/-2306'TVDSS to 2823' MD/-2365' TVDSS) Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 183 22 147.6 74 24 47.5 Gas Peaks Depth(MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 none Gas is generally low in this formation section with no notable peaks. 7 CANRIG ConocoPhillips Alaska.Inc. 2L-322 The Camp Sand formation is comprised of sandstone, sand, claystone, silty claystone. The sands in this formation are comprised of predominantly white to translucent to transparent quartz; upper very fine to lower fine; very well sorted; sub-rounded to sub-angular; moderate to high sphericity; loose unconsolidated and disaggregated quartz grains with trace amounts of secondary lithics; good apparent permeability and porosity; no hydrocarbon indicators present. The claystones are comprised of yellowish gray to very light grey coloration; soft and very poorly indurated; pulverulent and malleable to sectile tenacity; massive cuttings habit displayed; clayey to smooth texture; earthy to waxy luster; cohesive and adhesive; clumpy to mushy to tacky; thick apparent bedding. CAMP SAND TO TOP OF C50: (2823' MD/-2365'TVDSS to 4285' MD/-3533' TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 329 21 155.1 65 2 42.7 Gas Peaks Depth(MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 none 0 0 0 0 0 0 0 0 Gas is generally low in this formation section with no notable drilled gas peaks. The C-50 formation is composed of sand, siltstones, claystone. The sands in this formation are composed of predominantly translucent grains with white to smoky hues and occasional transparent quartz; medium to lower coarse grains but ranging from upper very fine to lower fine; well to moderately well sorted;sub-angular to sub-rounded with abundant bladed grains and clastics;generally low to very low sphericity with some moderate; trace amounts of grain supported silica cement sandstone fragments; predominantly loose disaggregated and unconsolidated sand grains; approximately 60% quartz and 40% secondary lithics. Claystones in this section appear yellowish gray to very light gray with light brownish hues;soft; non to poorly indurated;cohesive and adhesive;pulverized claystone clumped in mushy cohesive lumps;tacky to somewhat pasty; irregular fracture; massive cuttings habit;waxy to earthy luster;clayey to silty texture;massive bedding structure; silt; very fine to lower fine quartz sand imbedded within claystone matrix; no petroleum indicators. Siltstones are light medium gray to medium gray with occasional olive gray hues; friable to easily friable; moderately to poorly indurated;tabular to nodular cuttings;silty to abrasive texture;tough to crunchy and fairly dense;occasional thin black and brown laminations in fragments under higher magnification;sample does not appear to be fissile along laminations. 8 CANRIG ConocoPhillips Alaska.Inc. 2L-322 C50 TO TOP OF C40: (4285' MD/-3533'TVDSS to 4733' MD/-3920'TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 205 21 137.0 110 1 42.9 Gas Peaks Depth(MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 4733' 110 21122 513 70 Gas is generally low in this formation section with no notable peaks. This interval consists of claystones. The claystones in this section are very light olive gray to yellowish gray with brownish hues;very soft; poor to no induration;good cohesive and adhesive properties;very mushy to slightly pasty;no structure;very smooth texture; non-abrasive; pulverulent; non-calcareous; hydrophobic; contains trace amounts of lower very fine translucent to transparent quartz grains imbedded in the claystone. No petroleum indicators. C40 TO C37: (4733' MD/3920' TVDSS'to 5081' MD/-4162'TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 193 36 147 115 61 88.4 Gas Peaks Depth(MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 _ 4754' 113 22428 570 86 12 12 5 15 4960' 115 20637 698 182 27 25 8 0 Total gas was generally low in this section of the formation. This interval generally consists of primarily clay with some siltstone, sandstone. The clay is medium dark gray to dark gray with light olive gray, soft, cohesive, plasticity and pliable, stiff to mushy consistency,stiff to flexible tenacity,earthy fracture,massive cuttings habit,dull to earthy luster,clayey to silty texture, massive structure, hydrophobic, no hydrocarbons. The sandstones in this section are translucent and transparent quartz with yellowish gray to very pale orange secondary lithics; very fine to lower fine grained; well sorted; sub-rounded to sub-angular; high to moderate sphericity; soft to easily friable; 70-75 % quartz composition. Siltstone in the C-37 unit generally appears medium gray to medium dark gray;firm to firm friable;moderate to poor induration; crumbly to brittle with some pulverulent; irregular fracture; tabular to nodular and equant; earthy to dull luster; silty to gritty to smooth; no hydrocarbon indicators. 9 CANRIG Conoc Phillips Alaska.Inc. 2L-322 C37 TO TOP RESERVOIR: (5081' MD/4162'TVDSS to 6580' MD/-5005'TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 227 21 138 790 22 68 Gas Peaks Depth(MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 5730' 790 103606 _ 6850 5722 1264 2212 681 _ 734 6185' 357 54467 3575 2056 265 646 158 204 This interval is comprised of sandstone, sand, and siltstone. The sand in this section is commonly translucent,medium light gray to medium gray;quartz typically makes up 85% of the sands; predominantly lower very fine to upper very fine grained; sub-angular to sub-rounded to rounded; predominantly well to very well sorted; spherical to sub-discoidal; clay and silt fill common. In the middle part of the section some samples showed 10% patchy golden yellow fluorescence with no cut. The bottom of the section showed trace amounts of dull yellow to golden yellow fluorescence and no cut. The sandstone of this formation is commonly medium gray to light medium gray; lower very fine to lower fine with some upper fine grain sand; well to very well sorted; sub-angular to sub-rounded to trace rounded; moderate to slightly high sphericity; unconsolidated and grain supported in the upper half of the section to trace calcareous cemented grains in the lower half of the section;fluorescence uncommon but was bright yell ow to dull yellowish when observed. The siltstone in this section appear medium gray to medium dark grey with some grayish brown hues in places; induration is predominantly friable to firm friable; very earthy to very dull luster; texture ranges from very silty to slightly gritty; fluorescence is uncommon but occasionally observed as dull golden yellow to yellow. TOP TO BASE OF RESERVOIR: (6580' MD/-5005'TVDSS -7089'MD/-5103'TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 173 22 62 3580 71 1076 Gas Peaks Depth(MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 6957 2028 221752 29581 23819 4295 12147 3960 5190 7013 3580 317693 58046 56536 9905 27790 8451 10906 7042 3379 159743 43704 56923 11779 33952 10751 13762 7077 2288 66160 25625 40892 9180 27859 9031 11627 7111 4510 285377 66841 73389 13283 39314 12277 16477 The reservoir zone is predominantly composed of sandstone and sandy siltstone. The sandstone in the reservoir section is composed of predominantly translucent to transparent quartz grains (90%), lower very fine to upper very fine grained,sub-prismoidal to sub-discoidal,calcareous cement, matrix supported, sub-angular to sub-rounded; moderately to moderately well consolidated,with thin silty lenses of medium gray siltstone and reddish brown laminae; slight oil odor, very slight light brown oil staining visible; streaming bluish white cut; clear visual cut, no residual cut, very faint yellow residual fluorescence, no oil on 10 CANRIG ConocoPhillips Alaska.Inc. 2L-322 shakers; porosity and permeability visually tight. BASE OF RESERVOIR TO TD: (7089' MD/ 5103' TVDSS—7473' MD/-5163'TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 129 7 77 4735 1752 4005 Gas Peaks Depth(MD) TG Cl C2 C3 IC4 nC4 iC5 nC5 7150 4735 311653 69359 72732 14143 41032 13441 18036 7186 4502 299200 64744 67081 13293 38870 12967 17584 7275 4568 333182 63136 63731 12217 33706 12706 16745 7344 4504 386754 33834 59479 11381 33834 11407 15506 At the base of the reservoir, siltstone grading to carbonaceous siltstone is encountered. The siltstone/carbonaceous siltstone is medium dark gray to medium gray with light olive gray sub hue; friable to firm friable, moderate to moderately poor induration, earthy fracture; sub-nodular to sub-equant cuttings habit; silty to gritty texture; laminae structure. As the interval progresses, siltstone becomes carbonaceous siltstone, washout observed between carbonaceous laminations in siltstone. hydrocarbon indicators are: no oil odor, no grain stain; sample fluorescence, dropped from 60%to 30%to 5% as the depth increased, very, very faint blooming white cut fluorescence, no visual cut; no visual residual cut, faint golden yellow residual fluorescence cut. there was no oil at shakers but there was a heavy oil odor at shakers. 11 CANRIG ConocoPhillips Alaska,Inc. 2L-322 3.3 Connection Gas Summary: 1 Unit=200 ppm =0.05% Methane Equivalent Depth (ft) Units MD/TVD Above Background 2340/2144 724 2410/2199 1422 2640/2378 49 6452/5125 173 6457/5151 101 6641/5172 76 6735/5190 237 6830/5207 356 6925/5225 1680 3.4 Trip/Wiper Gas Summary 1 Unit=200 ppm =0.05% Methane Equivalent Depth (ft) Trip to(ft) Max.Gas MD/TVD MD/TVD (Units) Comments 1346/1323 Survey gas 1531 1242 units above background 1381/1353 Survey Gas 1195 616 units above background 1865/1765 Survey Gas 962 359 units above background 2620/2363 659/658 1433 Wiper trip at TD. 4081/3525 2620/2362 118 Wiper trip to shoe. 12 CANRIG iv- Conoco hiiiips Alaska.Inc. 2L-322 3.5 Iso-Tube Chromatography SAMPLE INTERVAL TOTAL GAS C-1 C-2 C-3 iC-4 nC-4 iC-5 nC-5 MD TVD (ft) (ft) (units) (Ppm) (ppm) (ppm) (ppm) (Ppm) (ppm) (ppm) 6970 5234 1800 199942 28304 23036 4139 11594 3799 4978 7000 5240 2087 222734 34738 30278 5159 14408 4369 5637 7030 5246 2580 145076 35400 40787 7906 21847 6938 9022 7060 5252 2300 49277 23164 42170 9931 30749 9692 12088 7090 5258 2006 64796 22265 31915 6843 20341 6786 6786 7120 5263 3850 279164 63742 67592 12905 37214 12006 15945 7150 5269 4725 311653 69359 72732 14143 41032 13441 18036 7180 5274 4345 288255 62526 64813 12843 37489 12466 16894 7250 5284 3745 247599 52400 54241 10651 31848 11037 15034 7310 5294 4289 385163 60097 57515 10427 32469 10938 14717 7355 5301 4364 369031 58535 57301 11148 32674 11019 15027 7400 5307 4049 354141 57677 55587 10360 31311 10823 15204 7450 5315 4427 354531 59749 56801 10265 35453 11211 53242 7471 5318 4482 367997 58762 55707 10098 65806 10977 52445 3.6 Sampling Program/Sample Dispatch Set Type/Purpose Frequency Interval Dispatched To CPAI,ABV 100 50 ft 140'to 6550' MD Bayview Warehouse Washed, screened and dried. 619 E. Ship Creek Ave. A Set Owner: CPAI 10 ft 6550'to 7150' MD Anchorage,AK 99501 50 ft 7150'to 7473' MD Attn: D. Przywojski/M. McCracken (907)263-4859 CPAI,ABV 100 50 ft 140'to 6550' MD Bayview Warehouse Washed, screened and dried. 619 E. Ship Creek Ave. B Set Owner: CPAI/AOGCC 10 ft 6550'to 7150' MD Anchorage,AK 99501 50 ft 7150'to 7473' MD Attn: D. Przywojski/M. McCracken (907)263-4859 Isotech Laboratories, Inc. Geochemical/Isotubes 30ft 6970'to 7180' MD 1308 Parkland Court 50 ft 7250'to 7473'MD Champaign, IL 61821 Attn:Albert Holba, CPAI 13 CANRIG # v) O 13 0 k 2 2 2 2 2 c 0 k m m m m m 2 z z z z 2 & / > � \ > - - t w § 0 u) K § ca # r c m ¥ co J ° / 9 s = 0) a a a \ C § ƒ .c o 0@ 2 » . � £ ¢ 2§ � o c a m In m m w „ -5 _ CL 6 6 a6 a a e c „ " / " g o / f o \ co k $ / % d k $ O CO CO m 0) I- CD > (N ( C 1 L 1-9- I- 6./ C. b e w f B Co Cu : > \ / CO \ � <0 0 N � � c + # a 3 a \ J ~ -- ° co \ 4-, -0 "0 E CI ^ \ $ / / b / / / O e 8 (N00 7 7 7 N ii II I• ii cmoo mn0I- I / / O 2 $ e. R /+ m \ / ? \ % \ co) / C �I ) I- c © -I _1 a m ® / \ n \ m $ 2 o U) U ® U) U r. IX 0 ca w k IX Cu § o \ \ \ S ¥ ) - w ■ 2 _ N- r 0) 0) o o C 2 M CD E 2 2 \ ® F- \ 0 \ 2 •& 2 < 2 / 0 -J 0 o m \ 2 2 # O ƒ ODw o u m = - i � .0 \ ii ii " 0 _ 'B = _1Io2 w o § $ 4 O q = 2 W cu / e £ $ co \ / k o E \ o N. / 0 ■ a o £ CO O. 0. U. 3 » / / 7 ConocoPhillips Alaska.Inc. 2L-322 4.2 Quantitative Methods The primary indicators used for PPG evaluation were gas trends relative to mud weight(MW)and effective circulating density(ECD), including increases in background gas(BG),appearance and trends of connection gas (CG), and magnitudes of trip gas(TG)and wiper gas (WG). Regional pore pressure trends from sonic data, provided by ConocoPhillips, and surface manifestations of hole conditions were also considered. As a reference, PPG is calculated initially with a formula provided by Canrig Drilling Technology LTD,and then modified using the indicators described above, DXC and resistivity(RES)data. The formula uses DX, ECD, and BG as measured by total ditch gas: PPG = ECD—(0.6-((.001*TLGSU) + (0.05*DX))) The formula has certain limitations,such that it does not allow for a PPG more than 1 ppg less than the ECD, and TLGSU must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However,the formula proved useful in helping formulate a PPG range,when estimating trends, as with DXC data, with data points in shale intervals. 15 CANRIG ConocoPhillips Alaska.Inc. 2L-322 5 DRILLING DATA 5.1 Daily Activity April 11, 2011 Preparations to spud well are under way. Make up 43 ft BHA per directional driller. Fill hole and check for leaks: Pressure test lines to 3500 psi. No leaks observed. Wash and ream from 43 ft to 146 ft: Drilled ice plug at 72 ft. Drill ahead from 146 ft to 309 ft. POOH from 309 ft and pick up BHA: Collars and smart iron. Pulse test tools at 269 ft. Wash and ream from 269 ft to 309 ft. Drill ahead from 309 ft to 1300 ft at report time. April 12,2011 Drill ahead from 1300 ft to TD at 2620 ft MD. Circulate bottoms up(x3)at 700 gpm,2350 psi. Check for flow at 2614: Static. Back ream out of hole on wiper trip from 2620 ft to 538 ft with no problems encountered. Check for flow at 538 ft: Static. RIH on elevators from 538 ft to 2528 ft. Fill pipe and wash down from 2528 ft to bottom at 2620 ft at 600 gpm. Canrig records maximum gas of 1433 units and observed gas peak early at 1470 strokes(calculated bottoms up at 2620 ft is 3950 strokes). Circulate hole clean. Background gas levels out to 250-300 units. Flow check well at 2512 ft before POOH: Static. Currently pulling out of hole on elevators from 2620 ft to 1098 ft at report time. April 13,2011 Continue POOH with drill pipe from 1098 ft to top of HWDP at 538 ft. Stand back HWDP;change out jars; lay down flex collars; download MD; lay down balance of BHA. Rig up to run 10-3/4" casing. Run same from surface to 2620 ft with no problems encountered. Pick up and make up cement head and lines. Break circulation at 2 bpm, 190 psi; increase to 6 bpm, 260 psi. Canrig records a maximum of 313 units gas while circulating. Pressure test lines to 3000 psi. Turn rig over to cementers. Pump 40 bbls CWW-100;50 bbl 10.5 ppg mud push; drop bottom plug; pump 315 bbl of 11.0 ppg lead slurry; 107 bbls of 12.0 ppg TRAIL; drop bottom plug followed by 10 bbls fresh water. Use rig pumps and displace with 233 bbls of 9.7 ppg mud at 4 bpm,430 psi for a total of 2318 strokes: Bumped plug at 2318 strokes. Continue to pressure up to 1500 psi and hold for 10 minutes. Bleed off pressure and check floats: OK. Pull landing joint and rig down casing running equipment. Currently flushing and blowing down lines and surface equipment at report time. April 14, 2011 Continue to lay down equipment after cementing 10-3/4" 45# L-80 casing. Nipple down diverter; remove annular and knife valve assembly; clean all components of cement. Install casing head per FMC representative. Test lower casing seal to 1000 psi for 10 minutes. Begin nipple up BOPE;change lower pipe rams to 5"solid. Test BOPE 250 psi low/3500 psi high; test annular 250 psi low, 2500 psi high. Quadco on location to check TOTCO equipment. Test rig PVT alarms,gas sensors and alarms. Currently loading MWD tools in pipe shed at report time. April 15, 2011 Commence picking up and standing back 5" drill pipe in derrick. Service rig. Pick up BHA#2 and RIH per directional driller and MWD hand. Shallow test MWD;blow down top drive; load nukes. Continue to RIH from 224 ft to 2507 ft. Tag cement at 2504 ft. Circulate and condition mud at 2504 ft at 550 gpm, 1850 psi; increased rate to 630 gpm, 2250 psi. Blow down top drive and rig up for casing test. Perform casing test at 3000 psi for 30 minutes. Bleed off pressure and rig down test manifold. After bleed off observe 1.5 bbls return. Drill out float collar, shoe and 20 feet of new formation at 2640 ft, 550 gpm, 1850 psi. Pump 50 bbl spacer and displace with 9.5 ppg LSND mud while drilling new hole. Circulate bottoms up. Rig up and perform LOT. Results of LOT= (unknown at report time). Blow down and rig down test equipment. Drill ahead from 2640 ft to 2707 ft at report time. 16 CANRIG ConocoPhillips Alaska.Inc. 2L-322 April 16, 2011 Drilling ahead continues from 2707 ft to 4081 ft. Circulate and condition mud at 740 gpm,2170 psi. Circulate bottoms up and prepare for short trip. Check well for flow: Static. Wipe hole from 4081 ft to shoe at 2611 ft. Check well for flow at 2561 ft: Static. Run back to bottom from 2561 ft to 3986 ft. Fill pipe and wash to bottom at 4081 ft. Drill ahead from 4081 ft to 4484 at report time. ft. April 17,2011 Found a wash out at 4,486' on stand#41, rack back and removed from pipe talley. Continued drilling from 4,486' MD to 5,821' MD. Work string from 5,785' to 5,695' while changing liner gasket on # 1 mud pump. Drilled from 5,821'MD to 6,089'MD. Flow check well,blow down the top drive then begin a short trip/wiper trip from 6,072' MD to 4,460' MD. April 18, 2011 Pull out of hole to 4,081'MD, monitor well. Trip in hole to 5,979'MD, wash and ream down to 6,089'MD. Circulate bottoms up at 550gpm. Drill ahead from 6,089'MD to 7,067'MD. Max gas seen was 3580u. April 19,2011 Drilled from 7,067' to 7,130'MD. Increased mud weight from 9.9 ppg to 10.0 ppg. Continued to drill and increase mud weight to 10.2 ppg. Drilled to TD at 7,473'MD/5,318'TVD. Circulated and weighted up drilling fluid to 10.8 ppg. Pump out of hole from 7,473'to 5,591'MD. Circulate and reciprocate while weighting up to 11.1 ppg. Flow check well at 5,676'MD. Flow back was 2 bbls/15 minutes. Continue to circulate and reciprocate from 5,591'to 5,680'while conditioning drilling fluid. April 20, 2011 Continue to circulate and condition. Weight up mud system to 11.4 from 11.0. Gas up to 5,800u.Trip in hole from 5,600'MD to 7,401'MD.Wash last stand down to bottom. Circulate bottoms up. Stage pumps to 6 bpm. Circulate and observe increase in flow out at 16% up to 20% then to 25%. Decision was made to slow the pumps down to 3 bpm. Rig up to circulate through the choke.Shut well in:CSG SIDPP=50psi,SICP=40psi. Open choke and bleeder, blow down.Continue to circulate.Weight up to 11.7 ppg.Saw losses/pumped LCM pill. Continue to circulate as of midnight. April 21,2011 Continue to weight up mud system and circulate at 250 gpm.Observed losses,continued to reciprocate.Built LCM pill and flow checked the well for 10 minutes. Weighted up the mud system to 11.7 ppg. Decision was made to back ream out of the hole from 7,473'MD to 6,833'MD.Continued to circulate and condition mud at 3 bpm. Pumped out of hole from 6,833' to 5,601'MD. Circulate and reciprocate from 5,695' to 5,601'MD. Serviced the rig. Cycled the pumps for MWD and continued to pump and observe the well as of midnight. April 22,2011 Circulate and condition drilling fluid. Monitored volumes while staging pumps up to 475 gpm. Pump LCM pill. Continue to circulate and weight up the mud system to 11.8 gpm when hole started taking fluid at 250 BPH. Reduced pump rate and spotted LCM pill. Close bags and squeezed in 5 bbls inc with 5 minute soak time. Opened bag and monitored well(slight flow). Started to build form a block pill. Pumped form a block pill(11.8 ppg)at 2.6 bbls/minute. Pumped out of the hole from 5,650'to 4,620'MD as of midnight. April 23, 2011 At 4,620'MD rig up pumping equipment for Form-A-Block squeeze.Squeeze 80 bbl pill by pumping down drill pipe and annulus. Pump away 80 bbls. Shut down pumping, drill pipe pressure stable at 50psi, hold for 30 minutes, final pressure 50psi and observe pressure and drilling fluid as of midnight April 25, 2011 April 24,2011 At 4,650'MD continue to circulate and adjust flow rate to evaluate loss rate.Slowly weight up with 12 ppg spike fluid. Continue to circulate while adjusting mud weight. Pump 55 bbl Icm pill and continue to circulate.Cut 130' of drill line and repair brakes on draw works. Wash and ream to current depth of 5600' and 17 CANRIG ConocoPhillips Alaska,Inc. 2L-322 April 25, 2011 Circ B/U @ 5885' and continue to wash and ream to 7,743' stopping to circulate B/U @6,170', 6454', and 6,925'. Rotate and reciprocate at 7,473'circ B/U.Close bag and open HCR choke back pressure.Pump#1 pill 60 bbls 16 ppg and chase with 66 bbls 11.8 ppg.Open bag and pump out to 6,830'.Close bag and hold 35 psi back pressure pump#2 pill 60 bbls 16 ppg. Chase with 55 bbls of 11.8 ppg. Pump out to 5,574'. April 26,2011 Close bag and pump 30 bbl 16 ppg through choke manifold@ 5,572'.Chase with 11.8 ppg.Open annular rams and flow check. Slight flow of gas cut mud, BROH from 5,572'to 4,937.Close annular and pump 30 bbls at 5 bbl/min. Monitor DP pressure @ 60 psi. BROH from 4,973'to 4,747'.Cir B/U and cont to circ and reciprocate. Pump 50 bbl Icm pill. Perform well breathing test, shut bag and open HCR choke. Shut in for 30 min. Open choke and record gains every 10 min. Circ btms up Begin RIH to circulate out 16 ppg pill. April 27, 2011 Wash and ream from 4,936' to 5,693 circulating bottoms up @ 5,124',5,314', 5,503',and 5,693'. Losses increase to 185 bbs hr @ 5,693'pump 50 bbl Icm pill. Monitor hole for static loss rates circulating across top of hole. Pump out of hole to 5,221'and circulate across top of hole monitoring loss rates. Pump 85 bbls of form a block pill and chase with 6 bbls of 11.8 ppg. POOH to 4,295'. Close bag and squeeze pill. April 28,2011 Complete squeeze on form a block pill. Rack back one stnd to 4,203'and attempt to establish circ. Pump 17 bbls away POOH to 4,194'and pump 50 bbl Icm pill. RIH to 6,165'pump 50 bbl Icm pill. RIH to 7,743'and R/U to cement April 29, 2011 Cement @ 7472' UD cement equipment and R/U Halliburton E-Line. RIH with E-line to 6,225' and set off charge to sever drill string. POOH with E line. R/D E-line. POOH to 6,160'and circulate with no returns. RIH to 6,225'and R/U cement equipment. Pump 89 bbls of 16 ppg cement and chase with 75 bbls 11.8 ppg. POOH to 4,991'. 18 CANRIG ConocoPhillips Alaska.Inc. 2L-322 5.2 Survey Data Measured Inclination Azimuth True Latitude Departure Vertical Dogleg Depth Vertical N(+)/S(-) E(+)/W(-) Section Rate Depth (feet „_ (degrees)) (degrees) (feet) (feet) (feet) (feet) (°/100ft) 40.05 0.00 0.00 40.05 0.00 0.00 0.00 0.00 100.00 0.14 43.59 100.00 0.05 0.05 -0.05 0.23 165.00 0.26 31.97 165.00 0.24 0.18 -0.23 0.19 254.00 0.90 144.93 254.00 -0.17 0.69 0.20 1.16 346.00 2.30 165.91 345.96 -2.55 1.56 2.62 1.62 435.00 2.99 170.63 434.86 -6.57 2.37 6.67 0.81 530.00 3.59 167.65 529.71 -11.92 3.41 12.06 0.66 625.00 4.64 166.22 624.46 -18.56 4.96 18.76 1.11 721.00 6.42 166.79 720.01 -27.55 7.11 27.85 1.86 815.00 8.26 174.49 813.24 -39.39 8.96 39.76 2.22 910.00 11.33 183.95 906.85 -55.50 8.97 55.85 3.64 1005.00 14.41 193.77 999.46 -76.30 5.52 76.47 3.97 1052.23 15.71 192.60 1045.07 -88.25 2.72 88.28 2.83 1146.38 17.39 195.56 1135.32 -114.24 -3.83 113.95 2.00 1242.97 20.89 193.44 1226.55 -144.91 -11.71 144.22 3.69 1332.61 23.80 196.25 1309.46 -177.82 -20.49 176.70 3.46 1426.54 25.91 194.57 1394.68 -215.89 -30.96 214.24 2.37 1526.06 29.23 194.49 1482.89 -260.47 -42.51 258.25 3.34 1623.24 32.24 195.82 1566.41 -308.39 -55.51 305.53 3.18 1719.13 35.34 194.17 1646.09 -359.90 -69.28 356.36 3.37 1812.38 35.56 194.98 1722.06 -412.24 -82.89 408.02 0.56 1906.64 36.34 197.62 1798.37 -465.34 -98.43 460.36 1.84 2003.99 36.52 197.81 1876.69 -520.41 -116.02 514.56 0.22 2098.42 37.29 196.42 1952.20 -574.60 -132.70 567.94 1.20 2187.04 37.26 196.84 2022.72 -626.03 -148.06 618.61 0.29 2285.86 37.60 196.50 2101.20 -683.57 -165.29 675.30 0.40 2377.64 38.15 196.60 2173.64 -737.58 -181.34 728.52 0.60 2473.58 38.70 196.53 2248.80 -794.73 -198.34 784.83 0.58 2571.43 39.02 197.16 2325.00 -853.49 -216.13 842.72 0.52 2619.19 39.05 197.33 2362.10 -882.22 -225.05 871.01 0.23 2715.09 39.13 197.93 2436.53 -939.84 -243.36 927.74 0.40 2809.01 39.34 197.57 2509.28 -996.42 -261.47 983.43 0.33 2902.49 37.70 197.93 2582.41 -1051.87 -279.22 1038.00 1.77 2997.03 37.89 197.01 2657.12 -1107.13 -296.61 1092.41 0.63 3091.12 36.46 197.20 2732.09 -1161.47 -313.33 1145.93 1.52 19 CANRIG Conoco`Phillips Alaska.Inc. 2L-322 Measured Inclination Azimuth True Latitude Departure Vertical Dogleg Depth Vertical N(+)/S(-) E(+)/W(-) Section Rate Depth (feet) (degrees)) (degrees) (feet) (feet) (feet) (feet) (°/100ft) 3187.35 36.59 198.00 2809.42 -1216.06 -330.65 1199.67 0.51 3280.81 36.39 198.27 2884.56 -1268.88 -347.95 1251.65 0.27 3375.54 36.35 198.21 2960.83 -1322.23 -365.53 1304.14 0.06 3469.71 36.68 198.04 3036.52 -1375.48 -382.96 1356.54 0.37 3565.55 36.81 198.14 3113.31 -1429.99 -400.76 1410.17 0.15 3658.22 36.93 198.06 3187.45 -1482.84 -418.04 1462.18 0.14 3756.04 36.83 197.64 3265.70 -1538.72 -436.03 1517.18 0.28 3848.71 36.89 197.52 3339.84 -1591.71 -452.82 1569.35 0.10 3945.11 36.93 197.64 3416.92 -1646.90 -470.31 1623.68 0.09 4040.33 37.33 195.73 3492.84 -1701.95 -486.81 1677.92 1.28 4131.52 37.19 195.25 3565.42 -1755.16 -501.55 1730.39 0.35 4227.69 37.20 195.41 3642.02 -1811.23 -516.92 1785.70 0.10 4323.39 37.16 195.23 3718.27 -1867.00 -532.20 1840.72 0.12 4418.52 37.06 195.51 3794.14 -1922.35 -547.41 1895.31 0.21 4513.61 37.14 195.44 3869.98 -1977.63 -562.72 1949.84 0.10 4607.65 37.71 194.88 3944.66 -2032.79 -577.66 2004.26 0.71 4703.13 37.69 195.57 4020.21 -2089.13 -593.00 2059.84 0.44 4794.31 38.08 194.95 4092.17 -2143.14 -607.73 2113.12 0.60 4891.89 38.18 195.03 4168.93 -2201.34 -623.31 2170.55 0.11 4987.22 38.50 194.58 4243.70 -2258.52 -638.42 2226.97 0.45 5080.09 38.60 195.69 4316.33 -2314.38 -653.54 2282.09 0.75 5178.01 38.69 195.55 4392.81 -2373.27 -670.00 2340.17 0.13 5268.44 38.55 195.70 4463.46 -2427.63 -685.20 2393.77 0.19 5367.51 41.09 191.51 4539.56 -2489.27 -700.06 2454.67 3.73 5463.37 43.90 189.86 4610.24 -2552.90 -712.04 2517.68 3.15 5557.77 47.00 186.81 4676.46 -2619.45 -721.74 2583.71 4.01 5649.77 48.56 184.10 4738.29 -2687.26 -728.19 2651.16 2.76 5745.62 50.89 180.24 4800.26 -2760.30 -730.92 2724.01 3.92 5837.10 53.05 177.97 4856.62 -2832.34 -729.77 2796.02 3.06 5935.07 56.62 177.48 4913.04 -2912.35 -726.59 2876.10 3.67 6029.28 60.80 175.17 4961.96 -2992.67 -721.39 2956.56 4.91 6120.78 64.37 174.26 5004.08 -3073.53 -713.90 3037.68 4.00 6212.88 66.60 173.55 5042.30 -3156.85 -705.00 3121.32 2.52 6308.30 69.14 172.90 5078.24 -3244.61 -694.57 3209.47 2.74 6407.73 71.21 171.84 5111.96 -3337.31 -682.15 3302.64 2.31 20 CANRIG Iv- ConocoPPhillips Alaska.Inc. 2L-322 Measured Inclination Azimuth True Latitude Departure Vertical Dogleg Depth Vertical N(+)/S(-) E(+)/W(-) Section Rate Depth (feet) (degrees)) (degrees) (feet) (feet) (feet) (feet) (°/100ft) 6498.26 73.93 169.56 5139.08 -3422.54 -668.18 3388.41 3.85 6598.15 76.98 167.42 5164.16 -3517.26 -648.88 3483.92 3.69 6692.21 80.04 166.34 5182.90 -3607.02 -627.95 3574.54 3.44 6787.21 79.82 166.67 5199.51 -3697.97 -606.12 3666.40 0.41 6881.53 78.83 167.58 5216.98 -3788.32 -585.47 3757.60 1.41 6976.54 78.72 166.90 5235.48 -3879.21 -564.89 3849.34 0.71 7073.10 78.10 166.21 5254.88 -3971.21 -542.89 3942.24 0.95 7165.99 80.94 163.67 5271.77 -4059.40 -519.16 4031.42 4.07 7262.27 81.27 163.86 5286.66 -4150.73 -492.56 4123.87 0.39 7358.26 81.32 164.29 5301.19 -4241.97 -466.53 4216.21 0.45 7473.00 81.32 164.29 5318.51 -4351.16 -435.82 4326.69 0.00 21 CANRIG CN % C I- 2 I k k \ % \ 2A 2 I ' \ e � / nr \ a .. \ N- e . c4 N 0 \ b ci £ ^ � • / cc £ c_ =/ ® � � Mw ,- n < ( � � ®\ tO / n co \ �} g N U 2R / a:, 8 . - tE \ \ cnz G k $ © a) , o,_ . = Scc 2 ® Mx= § E N- in ' Ni_ .0 03 § § k k zz ■ m � CO CO II II II 2 ■ 2 ■ 2 2 ■ ■ CL M q tri CO 0 E ? ? § a 0 E Q E \ k :_ / # g2P 88 \ 2 I a. 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Heim Date: 04/12/2011 Time: 00:01 Current Depth (MD): 1300 Current Drilling Ahead Current Depth (TVD): 1280 Operations: 24 hr Footage (MD): 1165 Drilling Parameters ROP: Current: 92 Max: 265 Torque: Current: 1223 Max: 10596 _WOB: Current 19 Max: 28 RPM: Current: 0 Max: 80 _PP: Current: 1453 Max: 1541 Lag: Strokes: 1948 Time: 15.3 Surf to Bit Strokes: 183 Time: 1.4 ECD: Current: - Max: - Mud Pro•erties 1078/1069 MW: 9.1 FV: 246 PV: 35 YP: 49 FL: 6.1 Gels: 34/61/70 Sol: 4.5 pH: 9.3 Cr: 850 Ca" 40 Gas Data Ditch Gas: Current: 96u Max: 1251u Depth (MD/TVD): 1024/1018 I Average: 62u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) None - - - - - - Lithologies: Current: Clay 50%, sand 50% Last 24 hrs: Conglomeratic sand, then sand and clay. Preparations to spud well are under way. Make up 43 ft BHA per directional driller. Fill hole and check for leaks: Pressure test lines to 3500 psi. No leaks observed. Wash Operational Summary: and ream from 43 ft to 146 ft: Drilled ice plug at 72 ft. Drill ahead from 146 ft to 309 ft. POOH from 309 ft and pick up BHA: Collars and smart iron. Pulse test tools at 269 ft. Wash and ream from 269 ft to 309 ft. Drill ahead from 309 ft to 1300 ft at report time. Calibrations: Chromatograph, THA. Failures: TOTCO WITS feed lost several times today. Refer to mud log. Daily Cost: $3370.00 CANRIG U.nii. Tu inns ., Im. ConocoPhillips Alaska,Inc. Daily Report Tarn 2L-322 Report for: L. Hill M. Brouillet Date: 04/13/2011 Time: 00:01 Current Depth (MD): 2620 Current POOH for 10-3/4" Current Depth (TVD): 2363 Operations: casing 24 hr Footage (MD): 1320 Drilling Parameters ROP: Current: - Max: 168 Torque: Current: - Max: 10440 WOB: Current - Max: 60 RPM: Current: - Max: 100 PP: Current: - Max: 2489 Lag: Strokes: 3950 Time: - Surf to Bit Strokes: 416 Time: - ECD: Current: - Max: - Mud Properties 2620/2363 MW: 9.7 FV: 182 PV: 41 YP: 46 FL: 5.8 Gels: ) 19/47/72 Sol: 7 pH: 9.2 Cr: 850 Ca" 40 Gas Data Ditch Gas: Current: - Max: 1530u Depth (MD/TVD): 1346/1310 Average: 803u Gas Events Type Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) _ SG/1242u 1346/1310 385040.360 0 0 0 0 0 0 _ SG/616u 1381/1351 182088.721 0 0 0 0 0 0 SG/349u 1865/1757 117989.480 0 0 0 0 00 CG/724u 2340/2136 171003.910 0 0 0 0 0 0 WTG/1433u Wiper trip 266290.025 0 0 0 0 0 0 Lithologies: Current: 80%sand, 20%siltstone at TD Last 24 hrs: Sand, clay,then sand and siltstone Drill ahead from 1300 ft to TD at 2620 ft MD. Circulate bottoms up(x3)at 700 gpm, 2350 psi. Check for flow at 2614: Static. Back ream out of hole on wiper trip from 2620 ft to 538 ft with no problems encountered. Check for flow at 538 ft: Static. RIH on elevators from 538 ft to 2528 ft. Fill pipe and wash down from 2528 ft to bottom at Operational Summary: 2620 ft at 600 gpm. Canrig records maximum gas of 1433 units and observed gas peak early at 1470 strokes(calculated bottoms up at 2620 ft is 3950 strokes). Circulate hole clean. Background gas levels out to 250-300 units. Flow check well at 2512 ft before POOH: Static. Currently pulling out of hole on elevators from 2620 ft to 1098 ft at report time. Calibrations: Chromatograph,THA. Failures: TOTCO WITS feed lost again today. Refer to mud log. Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report Tarn 2L-322 Report for: R. R. Springer M. Brouillet Date: 04/14/2011 Time: 00:01 Current Depth (MD): 2620 Current Wait on cement. Current Depth (TVD): 2363 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current _ Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf to Bit Strokes: Time: ECD: Current: Max: Mud Properties Cleaning pits MW: FV: PV: YP: FL: Gels: Sol: pH: Cr: Ca" Gas Data Ditch Gas: Current: n/a Max: Depth (MD/TVD): Average: Gas Events Type Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gas/Amount (MD/TVD) TG/313u 26202363 Lithologies: Current: 80% sand, 20%siltstone at TD Last 24 hrs: No new footage drilled this period. Continue POOH with drill pipe from 1098 ft to top of HWDP at 538 ft. Stand back HWDP; change out jars; lay down flex collars;download MD; lay down balance of BHA. Rig up to run 10-3/4"casing. Run same from surface to 2620 ft with no problems encountered. Pick up and make up cement head and lines. Break circulation at 2 bpm, 190 psi; increase to 6 bpm, 260 psi. Canrig records a maximum of 313 units gas while circulating. Pressure test lines to 3000 psi. Turn rig over to cementers. Pump Operational Summary: 40 bbls CWW-100; 50 bbl 10.5 ppg mud push;drop bottom plug; pump 315 bbl of 11.0 ppg lead slurry; 107 bbls of 12.0 ppg TAAIL;drop bottom plug followed by 10 bbls fresh water. Use rig pumps and displace with 233 bbls of 9.7 ppg mud at 4 bpm,430 psi for a total of 2318 strokes: Bumped plug at 2318 strokes. Continue to pressure up to 1500 psi and hold for 10 minutes. Bleed off pressure and check floats: OK. Pull landing joint and rig down casing running equipment. Currently flushing and blowing down lines and surface equipment at report time. Calibrations: Chromatograph, THA. Failures: Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report Tarn 2L-322 Report for: R. R. Springer M. Brouillet Date: 04/15/2011 Time: 00:01 Current Depth (MD): 2620 Current Pick up 5"drill pipe. Current Depth (TVD): 2363 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf to Bit Strokes: Time: ECD: Current: Max: Mud Properties 2620/2363 MW: 9.7 FV: 77 PV: 21 YP: 11 FL: 5.2 Gels: 4/6/8 Sol: 8 pH: 6.4 Cr: 1200 Ca" Gas Data Ditch Gas: Current: n/a Max: Depth (MD/TVD): Average: Gas Events Type Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gas/Amount (MD/TVD) Lithologies: Current: 80%sand, 20%siltstone at TD Last 24 hrs: No new footage drilled this period. Continue to lay down equipment after cementing 10-3/4"45#L-80 casing. Nipple down diverter; remove annular and knife valve assembly;clean all components of cement. Install casing head per FMC representative. Test lower casing seal to 1000 psi for 10 Operational Summary: minutes. Begin nipple up BOPE;change lower pipe rams to 5"solid. Test BOPE 250 psi low/3500 psi high;test annular 250 psi low,2500 psi high. Quadco on location to check TOTCO equipment. Test rig PVT alarms,gas sensors and alarms. Currently loading MWD tools in pipe shed at report time. Calibrations: Chromatograph, THA. Failures: Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report Tarn 2L-322 Report for: R. Springer M. Brouillet Date: 04/16/2011 Time: 00:01 Current Depth (MD): 2707 Current Drilling ahead. Current Depth (TVD): 2430 Operations: 24 hr Footage (MD): 87 Drilling Parameters ROP: Current: 158 Max: 272 Torque: Current: 6174 Max: 7113 WOB: Current 6 Max: 18 RPM: Current: 103 Max: 104 PP: Current: 1548 Max: 2375 Lag: Strokes: 1882 Time: 12 Surf to Bit Strokes: 413 Time: 2.7 ECD: Current: Max: Mud Properties 2620/2363 MW: 9.5 FV: 54 PV: 10 YP: 20 FL: 4.4 Gels: 8/10/12 Sol: 5 pH: 9.4 Cr: 650 Ca" 40 Gas Data Ditch Gas: Current: 57u Max: 735 Depth (MD/TVD): 2620/2363 Average: Gas Events Type Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gas/Amount (MD/TVD) Lithologies: Current: 80% sand, 20%siltstone at TD Last 24 hrs: n/a Commence picking up and standing back 5"drill pipe in derrick. Service rig. Pick up BHA#2 and RIH per directional driller and MWD hand. Shallow test MWD;blow down top drive; load nukes. Continue to RIH from 224 ft to 2507 ft. Tag cement at 2504 ft. Circulate and condition mud at 2504 ft at 550 gpm, 1850 psi; increased rate to 630 gpm, 2250 psi. Blow down top drive and rig up for casing test. Perform casing test at Operational Summary: 3000 psi for 30 minutes. Bleed off pressure and rig down test manifold. After bleed off observe 1.5 bbls return. Drill out float collar, shoe and 20 feet of new formation at 2640 ft, 550 gpm, 1850 psi. Pump 50 bbl spacer and displace with 9.5 ppg LSND mud while drilling new hole. Circulate bottoms up. Rig up and perform LOT. Results of LOT= (unknown at report time). Blow down and rig down test equipment. Drill ahead from 2640 ft to 2707 ft at report time. Calibrations: Chromatograph, THA. Failures: Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report Tarn 2L-322 Report for: R. Springer M. Brouillet Date: 04/17/2011 Time: 00:01 Current Depth (MD): 4484 Current Drilling ahead. Current Depth (TVD): 3847 Operations: 24 hr Footage (MD): 1753 Drilling Parameters ROP: Current: 98 Max: 329 Torque: Current: 7890 Max: 10281 WOB: Current 6 Max: 16 RPM: Current: 98 Max: 107 PP: Current: 2520 Max: 2592 Lag: Strokes: 2828 Time: 16 Surf to Bit Strokes: 413 Time: 3.6 ECD: Current: Max: Mud Properties 4323/3718 MW: 9.5 FV: 48 PV: 15 YP: 26 FL: _ 4 Gels: 10/16/21 Sol: 6 pH: 9.3 Cr: 750 Ca++ 40 Gas Data _ Ditch Gas: Current: 35u Max: 95u Depth (MD/TVD): 2720/2436 Average: 43u Gas Events Type Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gas/Amount (MD/TVD) WTG/118U 4081/3492 13411.312 16.993 0 0 0 0 0 Lithologies: Current: 100%CLAY Last 24 hrs: Clay, Silts, sand Drilling ahead continues from 2707 ft to 4081 ft. Circulate and condition mud at 740 gpm,2170 psi. Circulate bottoms up and prepare for short trip. Check well for flow: Operational Summary: Static. Wipe hole from 4081 ft to shoe at 2611 ft. Check well for flow at 2561 ft: Static. Run back to bottom from 2561 ft to 3986 ft. Fill pipe and wash to bottom at 4081 ft. Drill ahead from 4081 ft to 4484 at report time. ft. Calibrations: Chromatograph, THA. Failures: none Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report Tarn 2L-322 Report for: R. Springer M. Brouillet Date: 04/18/2011 Time: 00:01 Current Depth (MD): 6071 Current Short trip Current Depth (TVD): 4984 Operations: 24 hr Footage (MD): 1587 Drilling Parameters ROP: Current: 98 Max: 227 Torque: Current: 2854 Max: 13099 WOB: Current 10 Max: 23 RPM: Current: 0 Max: 106 PP: Current: 2912 Max: 3345 Lag: Strokes: 4236 Time: 25 Surf to Bit Strokes: 1006 Time: 6 ECD: Current: Max: Mud Properties 6071/4982 MW: 9.6 FV: 42 PV: 12 YP: 18 FL: 4.2 Gels: l 8/11/16 Sol: 8 pH: 9.3 Cr: 750 Ca" 60 Gas Data Ditch Gas: Current: 15u Max: 790u Depth (MD/TVD): 5730/4790 Average: 68u Gas Events Type Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gas/Amount (MD/TVD) _ Lithologies: Current: 60% Sand, 40% Siltstone Last 24 hrs: Sand, Siltstone Found a wash out at 4,486' on stand#41, rack back and removed from pipe talley. Continued drilling from 4,486' MD to 5,821' MD.Work string from 5,785'to 5,695'while Operational Summary: changing liner gasket on#1 mud pump. Drilled from 5,821' MD to 6,089' MD. Flow check well, blow down the top drive then begin a short trip/wiper trip from 6,072' MD to 4,460' MD. Calibrations: Chromatograph, THA. Failures: none Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report Tarn 2L-322 Report for: R. Springer M. Brouillet Date: 04/19/2011 Time: 00:01 Current Depth (MD): 7067 Current Drilling Ahead Current Depth (TVD): 5253 Operations: 24 hr Footage (MD): 996 Drilling Parameters ROP: Current: 73 Max: 200 Torque: Current: 1766 Max: 15647 WOB: Current 6.7 Max: 66 RPM: Current: 44 Max: 102 PP: Current: 3314 Max: 3287 LN: Strokes: 4993 Time: 29 Surf to Bit Strokes: 1197 Time: 7 ECD: Current: Max: Mud Properties 7067/5253 MW: 9.9 FV: 48 PV: 18 YP: 24 FL: 3.6 Gels: 10/13/18 Sol: 8.5 pH: 9.2 Cr: 850 Ca" 60 Gas Data Ditch Gas: Current: 4614u Max: 3580u Depth (MD/TVD): 7013/5242 Average: 2100u Gas Events Type Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gas/Amount (MD/TVD) WP 194u 6071/4982 26,411 1,564 1,257 277 487 149 163 Lithologies: Current: 60% Sandstone, 30%Sand, 10%Siltstone Last 24 hrs: Sandstone, Sand Pull out of hole to 4,081'MD, monitor well. Trip in hole to 5,979'MD,wash and ream Operational Summary: down to 6,089'MD. Circulate bottoms up at 550gpm. Drill ahead from 6,089'MD to 7,067'MD. Max gas seen was 3580u. Calibrations: Chromatograph, THA. Failures: none Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report Tarn 2L-322 Report for: R. Springer M. Brouillet Date: 04/20/2011 Time: 00:01 Current Depth (MD): 7473 Current Circulating Current Depth (TVD): 55318 Operations: 24 hr Footage (MD): 406 Drilling Parameters ROP: Current: 0 Max: 129 Torque: Current: 9765 Max: 15905 WOB: Current 0 Max: 18 RPM: Current: 67 Max: 101 PP: Current: _ 2215 Max: 3438 Lag: Strokes: 5216 Time: 31 Surf to Bit Strokes: 1253 Time: 7.5 ECD: Current: Max: Mud Properties 7473/5318 r-- MW: 11.0 FV: 55 PV: 25 YP: 30 FL: 3.2 Gels: 13/15/19 Sol: 12 pH: 9.1 Cr: 850 Ca++ 60 Gas Data Ditch Gas: Current: 4380u Max: 4735u Depth (MD/TVD): 7150/5269 Average: 3869u Gas Events Type Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gas/Amount (MD/TVD) Lithologies: Current: 50% Siltstone, 50%Carbonaceous Shale Last 24 hrs: Sandstone, Sand Drilled from 7,067'to 7,130'MD. Increased mud weight from 9.9 ppg to 10.0 ppg. Continued to drill and increase mud weight to 10.2 ppg. Drilled to TD at Operational Summary: 7,473'MD/5,318'TVD. Circulated and weighted up drilling fluid to 10.8 ppg. Pump out of hole from 7,473'to 5,591'MD. Circulate and reciprocate while weighting up to 11.1 ppg. Flow check well at 5,676'MD. Flow back was 2 bbls/15 minutes. Continue to circulate and reciprocate from 5,591'to 5,680'while conditioning drilling fluid. Calibrations: Chromatograph,THA. Failures: none Daily Cost: $3370.00 CANRIG Deua. Tnn..i.o rn. ConocoPhillips Alaska,Inc. Daily Report Tarn 2L-322 Report for: R. Springer M. Brouillet Date: 04/21/2011 Time: 00:01 Current Depth (MD): 7473 Current Circulating Current Depth (TVD): 5318 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 12286 Max: 16284 WOB: Current 0 Max: 0 RPM: Current: 62 Max: 72 PP: Current: 380 Max: 2814 Lag: Strokes: 5216 Time: 153 Surf to Bit Strokes: 1254 Time: 37 ECD: Current: Max: Mud Properties 7473/5318 MW: 11.7 FV: 56 PV: 28 YP: 33 FL: 3.2 Gels: 9/14/19 Sol: 15 pH: 9.2 Cr: 750 Ca" 40 Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Average: Gas Events Type Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gas/Amount (MD/TVD) • Lithologies: Current: Last 24 hrs: Continue to circulate and condition. Weight up mud system to 11.4 from 11.0. Gas up to 5,800u. Trip in hole from 5,600'MD to 7,401'MD.Wash last stand down to bottom. Circulate bottoms up. Stage pumps to 6 bpm. Circulate and observe increase in flow Operational Summary: out at 16%up to 20%then to 25%. Decision was made to slow the pumps down to 3 bpm. Rig up to circulate through the choke. Shut well in:CSG SIDPP=50psi, SICP= 40psi.Open choke and bleeder, blow down. Continue to circulate.Weight up to 11.7 ppg. Saw losses/pumped LCM pill. Continue to circulate as of midnight. Calibrations: Chromatograph,THA. Failures: none Daily Cost: $3435.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report Tarn 2L-322 Report for: R. Springer R. Dolcater Date: 04/22/2011 Time: 00:01 Current Depth (MD): 7473 Current Circulating Current Depth (TVD): 5318 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 10688 Max: 13098 WOB: Current 0 Max: 0 RPM: Current: 58 Max: 66 PP: Current: 112 Max: 2218 Lag: Strokes: 3906 Time: 34 Surf to Bit Strokes: 923 Time: 8 ECD: Current: Max: Mud Properties 7473/5318 MW: 11.7 FV: 58 PV: 31 YP: 29 FL: 2.8 Gels: 10/13/16 Sol: 17 pH: 9.1 Cr: 800 Ca" 40 Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Average: Gas Events Type Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gas/Amount (MD/TVD) Lithologies: Current: Last 24 hrs: Continue to weight up mud system and circulate at 250 gpm. Observed losses, continued to reciprocate. Built LCM pill and flow checked the well for 10 minutes. Weighted up the mud system to 11.7 ppg. Decision was made to back ream out of the Operational Summary: hole from 7,473'MD to 6,833' MD.Continued to circulate and condition mud at 3 bpm. Pumped out of hole from 6,833'to 5,601'MD.Circulate and reciprocate from 5,695'to 5,601'MD. Serviced the rig. Cycled the pumps for MWD and continued to pump and observe the well as of midnight. Calibrations: Chromatograph,THA. Failures: none Daily Cost: $3,435.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report Tarn 2L-322 Report for: R. Springer R. Dolcater Date: 04/23/2011 Time: 00:01 Current Depth (MD): 7473 Current Pumping form a block Current Depth (TVD): 5318 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 6688 Max: 12896 WOB: Current 0 Max: 0 RPM: Current: 48 Max: 63 PP: Current: 1115 Max: 2068 Lag: Strokes: 3906 Time: 34 Surf to Bit Strokes: 923 Time: 8 ECD: Current: Max: Mud Properties 7473/5318 MW: 11.7 FV: 54 PV: 21 YP: 29 FL: 8.1 Gels: 9/12/16 Sol: 17 pH: 9.4 Cr: 750 Ca+` Gas Data Ditch Gas: Current: Max: Depth (MDJTVD): Average: Gas Events _ Type Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gas/Amount (MD/TVD) Lithologies: Current: Last 24 hrs: Circulate and condition drilling fluid. Monitored volumes while staging pumps up to 475 gpm. Pump LCM pill. Continue to circulate and weight up the mud system to 11.8 gpm when hole started taking fluid at 250 BPH. Reduced pump rate and spotted LCM pill. Operational Summary: Close bags and squeezed in 5 bbls inc with 5 minute soak time. Opened bag and monitored well(slight flow). Started to build form a block pill. Pumped form a block pill (11.8 ppg) at 2.6 bbls/minute. Pumped out of the hole from 5,650'to 4,620'MD as of midnight. Calibrations: Chromatograph, THA. Failures: none Daily Cost: $3,435.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report Tarn 2L-322 Report for: R. Springer R. Dolcater Date: 04/24/2011 Time: 00:01 Current Depth (MD): 7473 Current Circulating Current Depth (TVD): 5318 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 5985 Max: 13026 WOB: Current 0 Max: 0 RPM: Current: 37 Max: 61 PP: Current: 1046 Max: 2792 Lag: Strokes: 3206 Time: 34 Surf to Bit Strokes: 746 Time: 8 ECD: Current: Max: Mud Properties 7473/5318 MW: 11.7 FV: 46 PV: 22 YP: 23 FL: 3 Gels: 9/11/13 Sol: 17 pH: 9.1 Cr: 750 Ca" 40 Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Average: _Ga s Events Type Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gas/Amount (MD/TVD) Lithologies: Current: Last 24 hrs: At 4,620'MD rig up pumping equipment for Form-A-Block squeeze. Squeeze 80 bbl pill Operational Summary: by pumping down drill pipe and annulus. Pump away 80 bbls. Shut down pumping,drill pipe pressure stable at 50psi, hold for 30 minutes,final pressure 50psi and observe pressure and drilling fluid as of midnight. Calibrations: Chromatograph, THA. Failures: none Daily Cost: $3,435.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report Tarn 2L-322 Report for: R. Springer R. Dolcater Date: 04/25/2011 Time: 00:01 Current Depth (MD): 7473 Current Wash and Ream to Current Depth (TVD): 5318 Operations: Bottom 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 7980 Max: 7980 WOB: Current 0 Max: 0 RPM: Current: 42 Max: 58 PP: Current: 0 Max: 2797 Lag: Strokes: 3906 Time: 106 Surf to Bit Strokes: 923 Time: 25 ECD: Current: Max: Mud Properties 7473/5318 MW: 11.8 FV: 50 PV: 18 YP: 29 FL: 2.9 Gels: 8/10/14 Sol: 14 pH: 9.0 Cr: 750 Ca" 40 Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Average: 2068 3721 Gas Events Type Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gas/Amount (MD/TVD) Lithologies: Current: Last 24 hrs: At 4,650'MD continue to circulate and adjust flow rate to evaluate loss rate. Slowly Operational Summary: weight up with 12 ppg spike fluid. Continue to circulate while adjusting mud weight. Pump 55 bbl Icm pill and continue to circulate. Cut 130' of drill line and repair brakes on draw works.Wash and ream to current depth of 5600' md. Calibrations: Chromatograph, THA. Failures: none Daily Cost: $3,435.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report Tarn 2L-322 Report for: R. Springer R. Dolcater Date: 04/26/2011 Time: 00:01 Current Depth (MD): 7473 Current Circulate and Current Depth (TVD): 5318 Operations: Reciprocate 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 11310 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 58 PP: _ Current: 0 Max: 516 Lag: Strokes: 3888 Time: 108 Surf to Bit Strokes: 919 Time: 25 ECD: Current: Max: Mud Properties 7473/5318 MW: 11.8 FV: 55 PV: 20 YP: 26 FL: 3 Gels: 10/11/14 Sol: 15 pH: 9.3 CF: 750 Ca" 40 Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Average: 360 2385 Gas Events Type Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gas/Amount (MD/TVD) Lithologies: Current: Last 24 hrs: Circ B/U @ 5885' and continue to wash and ream to 7,743' stopping to circulate B/U @ 6,170', 6454', and 6,925'. Rotate and reciprocate at 7,473' circ B/U. Close bag and Operational Summary: open HCR choke back pressure. Pump#1 pill 60 bbls 16 ppg and chase with 66 bbls 11.8 ppg. Open bag and pump out to 6,830'. Close bag and hold 35 psi back pressure pump#2 pill 60 bbls 16 ppg. Chase with 55 bbls of 11.8 ppg. Pump out to 5,574'. Calibrations: Chromatograph,THA. Failures: none Daily Cost: $3,435.00 CANRIG Dcu.i iei Tr2ir,to, Lm. ConocoPhillips Alaska,Inc. Daily Report Tarn 2L-322 Report for: R. Springer R. Dolcater Date: 04/27/2011 Time: 00:01 Current Depth (MD): 7473 Current Circ and Recip Current Depth (TVD): 5318 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 11310 WOB: Current _ 0 Max: _ 0 RPM: Current: 41 Max: 62 PP: Current: 279 Max: 459 Lag: Strokes: 3507 Time: 125 Surf to Bit Strokes: 823 Time: 29 ECD: Current: Max: Mud Properties 7473/5318 MW: 11.8 FV: 57 PV: 20 YP: 30 FL: 3.2 Gels: 12/14/16 Sol: 16 pH: 9.3 CF: 800 Ca" 40 Gas Data Ditch Gas: Current: Max: Depth (MDlTVD): I Average: 298 2169 Gas Events Type Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gas/Amount (MD/TVD) Lithologies: Current: Last 24 hrs: Close bag and pump 30 bbl 16 ppg through choke manifold@ 5,572'.Chase with 11.8 ppg. Open annular rams and flow check. Slight flow of gas cut mud. BROH from 5572' to 4,937. Close annular and pump 30 bbls at 5 bbVmin. Monitor DP pressure @ 60 psi. Operational Summary: BROH from 4,973'to 4,747'. Cir B/U and cont to circ and reciprocate. Pump 50 bbl Icm pill. Perform well breathing test, shut bag and open HCR choke. Shut in for 30 min. Open choke and record gains every 10 min. Circ btms up Begin RIH to circulate out 16 ppg pill. Calibrations: Chromatograph,THA. Failures: none Daily Cost: $3,435.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report Tarn 2L-322 Report for: R. Springer R. Dolcater Date: 04/28/2011 Time: 00:01 Current Depth (MD): 7473 Current Squeeze form a block Current Depth (TVD): 5318 Operations: pill. 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 9278 Max: 11310 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 48 PP: Current: 540 Max: 459 Lag: Strokes: 2993 Time: Surf to Bit Strokes: 693 Time: ECD: Current: Max: Mud Properties 7473/5318 MW: 11.8 FV: 55 _ PV: 20 YP: 26 _ FL: 3.0 Gels: 10/11/14 Sol: 15 pH: 9.3 Cr: 750 Ca" 40 _Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Average: 0 1732 Gas Events Type Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gas/Amount (MD/TVD) Lithologies: Current: Last 24 hrs: Wash and ream from 4,936'to 5,693 circulating bottoms up @ 5,124',5,314', 5,503',and 5,693'. Losses increase to 185 bbs hr @ 5,693'pump 50 bbl Icm pill. Operational Summary: Monitor hole for static loss rates circulating across top of hole. Pump out of hole to 5,221' and circulate across top of hole monitoring loss rates. Pump 85 bbls of form a block pill and chase with 6 bbls of 11.8 ppg. POOH to 4,295'. Close bag and squeeze pill. Calibrations: Chromatograph, THA. Failures: none Daily Cost: $3,435.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report Tarn 2L-322 Report for: R. Springer R. Dolcater Date: 04/29/2011 Time: 00:01 Current Depth (MD): 7473 Current Squeeze form a block Current Depth (TVD): 5318 Operations: pill. 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: Max: 591 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 34 PP: Current: 0 Max: 459 _ Lag: , Strokes: 5216 Time: Surf to Bit Strokes: 1254 Time: ECD: Current: Max: Mud Properties 7473/5318 MW: 11.9 FV: 52 PV: 17 YP: 29 FL: 3.4 Gels: 11/14/15 Sol: 15 pH: 9.3 Cr: 700 Ca" 40 Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Average: 0 1305 Gas Events Type Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gas/Amount (MD/TVD) Lithologies: Current: Last 24 hrs: Complete squeeze on form a block pill. Rack back one stnd to 4,203' and attempt to Operational Summary: establish circ. Pump 17 bbls away POOH to 4,194' and pump 50 bbl Icm pill. RIH to 6,165' pump 50 bbl Icm pill. RIH to 7,743' and R/U to cement. Calibrations: Chromatograph, THA. Failures: none Daily Cost: $3,435.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report Tarn 2L-322 Report for: R. Springer R. Dolcater Date: 04/30/2011 Time: 00:01 Current Depth (MD): 6223 Current POOH Current Depth (TVD): Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 12098 WOB: Current 0 Max: 0 RPM: Current: 0 Max: _ 58 PP: Current: 0 Max: 822 Lag: Strokes: 3529 Time: N/A Surf to Bit Strokes: 880 Time: ECD: Current: Max: Mud Properties 7473/5318 MW: 11.8 FV: 57 PV: 19 YP: 30 FL: 3.6 Gels: 13/15/16 Sol: 16 pH: 9.5 Cr: 800 Ca" 40 Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Average: 0 1369 Gas Events Type Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gas/Amount (MD/TVD) Lithologies: Current: Last 24 hrs: Cement @ 7472' L/D cement equipment and R/U Halliburton E-Line. RIH with E-line to Operational Summary: 6,225'and set off charge to sever drill string. POOH with E line. R/D E-line. POOH to 6,160' and circulate with no returns. RIH to 6,225' and R/U cement equipment. Pump 89 bbls of 16 ppg cement and chase with 75 bbls 11.8 ppg. POOH to 4,991'. Calibrations: Chromatograph,THA. Failures: none Daily Cost: $2,510 CANRIG 0 3 a 0 r 0 co Co Drilling Logs
