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209-057
THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beluga River Field, Undefined Gas Pool, BRU 232-23 Permit to Drill Number: 209-057 Sundry Number: 319-257 LImTi-iw`een'm Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage. Alaska 99501-3572 Main: 907.279.1433 Pax: 907.276.7542 www. a o g c c. a l a s k a. g o v Enclosed is the approved application for the 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, Daniel T. Seamount, Jr. Commissioner r DATED this Z ?day of May, 2019. W)Ms$ r' MAY 2 4 2019 REIN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 17 2019 APPLICATION FOR SUNDRY APPROVALS on AAr. 9r 7An 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Pull Velocity String ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Stratigraphic ❑ Service ❑ 209-057 ' 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-283-20133-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ❑ ❑� Beluga River Unit (BRU) 232-23 Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0021128 Beluga River - Undefined Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7,587' 6,668' 6,875' 5,956' —311 psi 6,124;6,875 N/A Casing Length Size MD TVD Burst collapse Structural Conductor 10T 20" 107' 107' Surface 3,743' 9.625" 3,743' 2,953' 5,750psi 3,090psi Intermediate Production 7,577' 7" 7,577' 6,658' 7,240psi 5,410psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 4.5" 12.6# / C-75 4,597' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 8 Pers; N/A See Attached Schematic 12. Attachments: Proposal Summary Q Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 22, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: So York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerro�hilcoro com Contact Phone. 777-8420 q Authorized Signature: Date: 5�(� COMMISSION USE ONLY Conditions of approval: Notify CqjhmIsAion so that a representative may witness Sundry Number: ^, /"^I Plug Integrity ❑ SOP � 19/ Mechanical Integrity Test ❑ Location Clearance ❑ Other. RB®MS .�S/ MAY 2 4 2019 Post Initial Injection MIT Req'd? Yes El No 11 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: / O 1 Q APPROVED BY 23 0Approved by: COMMISSIONER THE COMMISSION Date: S� 41i�t2"1 Ste- v Z' 1 nO R . Submit Form and Form -003 Revised 4Y2017 Approved applicatio v li 1,61N o date of approval. ��� Attachments i Duplicate U Hilmm Alaska. LL' Well Prognosis Well: BRU 232-23 Date: 5/15/2019 Well Name: BRU 232-23 API Number: 50-283-20133-00 Current Status: SI Gas Producer Leg: N/A Estimated Start Date: 05/22/2019 Rig: CTU Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 209-057 First Call Engineer: Ted Kramer (907) 777-8420 (0) (987) 867-0665 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: Current Surface Pressure: — 42 psi (Flowing) Maximum Expected BHP: — 650 psi @ 3,395' TVD (Offset Well Survey 7-27-12) Max. Predicted Surface Pressure: — 311 psi (Based on .1 psi/ft. gas Grad) Brief Well Summary BRU 232-23 Was Spudded in July 2009. The well was originally completed with a multi -zone gravel pack with all sands A through I of the Beluga being opened. The well initially made water from the start (2.3MMscfd gas and 163 bbls/day water). In June 2015 a 2" coil velocity string was installed. Prior to the installation of the velocity string the well was making 500 mcfd. In April of 2016 when Hilcorp took over operations, the rate had declined to 325 mcfd and 5 BWPD. By July 2017, the well quit bringing up water and it is not possible to drop soap down the velocity string. Currently, the well makes 265 mcfd and zero water. The purpose of this Sundry is to remove the 2" velocity string from the well so that soap sticks can be dropped to unload water. Notes Regarding Wellbore Condition • Coil velocity string has been in the well for 4 years. Pre- Sundry Work 1.) RU Slickline and run 1.6" OD plug in coil string to prevent flow up coil. Coil Procedure: 1. MIRU CTU. 2. NOTE: See attached schematic showing detail of BHA on end of coil tubing. 3. Set 1.6" OD plug at shoulder on top of shear out sub. 4. POOH with a -line and rig down a -line unit. 5. Once well has been killed and plug has been set, pressure test plug from above to 1500 psi to ensure integrity as a barrier. ✓ 6. Rig up coil tubing unit to the well. 7. Perform coil BOP test to,3;060 psi. `foo V111 8. Rig up to pump down tubing by velocity string annulus and perform annulus kill. w jf 9. Pick up injector and 20' of lubricator to be able to lubricate velocity string BHA. 10. M/U fishing BHA. 11. Stab onto well with injector and lubricator. Pressure test connection to 4000 psi. Well Prognosis Well: BRU 232-23 Ifilmra Alaska, u, Date: 5/15/2019 12. Open swab valve and RIH to latch up to hanger assembly. 13. Pull to confirm latch. 14. Slack off to neutral. 15. Back out hanger bolts. 16. P/U 10' and run back in hole a couple of feet to ensure free movement of pipe. a. Ensure accurate pick up weight is recorded 17. Pick up and tag stripper, run back in hole five (6) feet. 18. Close slips and conduct push/pull and manually lock. 19. Close pipes and manually lock. 20. Pump down coil to release from velocity string. 21. Ensure well is Static. 22. Pop off above first 10' lubricator off of the BOPS. 23. Once popped off, swing crane off to the side so end of coil sticking out of lubricator can be dressed for the spoolable CTC (coil tubing connector), while the stub end sticking out of the BOPs is being dressed. 24. M/U spoolable connector to pipe sticking out of BOPs first. 25. Swing crane over and guide pipe onto the spoolable CTC sticking out of the BOPs. 26. Once stabbed on, increase traction and CTC to previously recorded pulling weight of the string. -3 "rs f c.;- 66vo 27. While still holding hanging weight, open pipe ram EQ (equalizing) port, manually unlock and hydraulically open pipe rams. 28. Manually unlock slips and hydraulically open slips. 29. Proceed out of hole. 30. Once the spoolable connector is securely on the reel with a couple of wraps, proceed out of hole with the anticipated velocity string length. 31. Tag up on lower BHA. 32. Close the swab, bleed down and blow down stack. 33. Pop off to break down tools. 34. Since there is a plug in the string, a hot tap will have to be utilized prior to breaking down BHA to check for trapped pressure. 35. Once hot tapped and zero psi is confirmed above the BHA, proceed to breaking down BHA. 36. Stab back on the well and blow Coil Velocity String down. 37. Remove coil unit from well. 38. Set BPV Mv.'Iv,( 39. Remove xmas tree rigged for coil tubing velocity string. 40. Re -install original xmas tree. 41. Pull BPV (optional) ^moi T �rw man 42. Turn well over to Production. leo ZS-uo / s: Attachments: 1. Current Schematic 2. Proposed Schematic 3. Coil BOP Stack 4. Well Head Diagram SAK PROD BRU 232-23 `we�taaMnlr� . •:: en�t�., :. , � _n x 502832013300 BELUGA RIVER UNIT PRDD 5261 2.349.30 7,587.0 Iiik»nv Aleeku, LLC_ SBSV: Cemn.n NONE uzslppA) DAr MngiaPT La311Y0: () AvO Rarue 10711008 9Ava'sl•Brtu a9-a,mBrsau t73R140M MneuNen him") Mlwbibn 7,06 '32012612 Ra. Rsaagb: OL GO, ADD VELOCRY STM NG Lra =imml 0,4Dar 711472015 ..-.�...,., il13NBL fT3 WCIUR Wa All; WA. SErIAD AS6El WA -.. L In lbmnpl- OD(Inl 0W) Top (PXD) 1Ct IN"J 13) ret Orptk 7... YMM ._ ntiv TOPTat tP R,W4 eor4xcrgn; ao4an CONDl7CTOR 20 18.124 23.0 84.0 84.0 153.00 X� BolIod wrn4 a4 wrraNn.t TAAru:nA t' Amilt; aaSryA NquFl;4u4a NMlE.43PIA noma:..WZT FACE on SURFACE 0 (Inl 9518 (m) eP IaKB) 8.835 22fl Deplhl B) Qet Pml •. -80e 3.742.8 2.962.8 40.00 L•80 Tep BTC -Mod ItA Pam D(n ID(In) ToP( 1 ea Deevn( B SN 0.p1t1(P/0�. x,M1_6w0e PRODUCTION 7 627H 19.0 7,8765 6.057.9 26.00 L4 BTC BTC TpbbWSh1ti§9' . n2 vaw.s umoa �alrAAs PAlpmt;4lW.e Twine om"p oo TUBING 1mn9 Mw.. 4I i ID (IN 3.959 aP lteKB) 17.3 3a DePN IA- Sa Ovpta (rVbl I... 4597.1 3,693.3 m flNlll 1200 G:atle C-75 Top CennPvnm IDTAI 4ELL Iiav;.3P,1 � Cqn _ n'CIBWilS aamalaw �enso4 =- Am; vx@3 Tep ) Te TOP 3x1 rora Dov Com nll v4Ot3 WW; 4me 1J.3 17.3 C.00 NANGEP vmo amiyTubing hanger orrENsen Al44A0] 445.5 446A 3. Ca 0 Md_INJE O NWPLE.AV C. 3.920 teal ITSOP/AI'EA;san 407.1 4.21 NI CamCo 3.813' BP MingNippN 3 13 4, 1.9 70,79 Nt 3,813' Nipple 3413 see:aWt.v raa0; 4!11.8 8, 3, 19.31 LOCA ekN LOCaIIN 6omi ntl7 SpiiaI014 3.900 WE;4at1 IX'p191'M, <46) 4, 9,B61S r4316'PBR 3. 1>g:4NAY IPEat4TH.W,T.T.a IPmc4TKP4TWq a • 4,5845 3.678.4 18. ANCHOR •Anchor BlvalAmemMy 9.260 name 4Ttss SEAL IPEAt 4ATa 04,Wq rol]lt 44tpp4p31A 4,585.7 3,6706 f SEAL A96Y r&223w1Ausmbly veib, NaB mab hoe IPI'N, SM404.01]A Tubin00>r[0p: 641np M4..b aP(mta) (a_ffirM (..w(INDI v TOPCen BBE:1Aa7 Is0vvCl�tl;lAirs A17LTf•20NE 5 3.430 4.5.8 5,933.8 S,O15A v 1011 . a rnr SA rn GRAVELPACK ASSEMBLY s1 a1eIwAn .: �C4Ma TOP TP mq)MR)ltopma 1rn Dea Dem MW at 40W4 1 3, 1850 PAC R SC Packd 70810 4. IPmteivao4I" IPE &,A ,,1ma 4,590,0 3,6836 18.39 EXTENSION Mdl olA 4,700 robe 417lZmq IneEDr. flans SUB IPmt aia.a4.JMJ romt4T%TA4saT9 ;609.8 3, 1814 SBE SmlBoro 3.25D IPERI.4A1at w 4, 3,696.6 1 SLAT Sub 3. 5 SiaAva3 1a0=A 11,41or 4,BOa.3 3, 9 2 1 alt lPGetlor Va 3. !a}W! Paq ra l,M.T 4,606.1 3, .6 1 VALVE Kj=koOWWorvelre 2 ra+G a4mq •a<: B,m.7 i 4,608, 3, 012 ION Ion Sub 3 exaslDN 4a4, $Us 1BC1AW2 4,614.6 70'7.0 1 EE) and Screen 6akeoro IPmt4W4Daa3T 4, 7 7 . )7.37 SBE Seal Ba+1, ayAem M2 5250 Gama W4 CONEYIDa; 44WA 8U114to t 4.627.0 1 17. i50 PA KER R TIOT Packer 8 IPmP� opt 4,651.4 17.1 Sea M 1yN 80. 3 6�0.m� 4, 9,775.0 .1 MNSION rExb bw Ws)zam8032 9.870 vgkalB lAa1B aloa; aaa+ i 4,837.9 8 17.01 FRAC PO mcllx0Ars Z 80x1 a�1 4.010 4,641.3 3, /688 SBE 10om MZ "m 3260 84149102 =ACx6a; A6�] 4, ,734$ NSION Loxer Eneniion MZ symm 3. vrer+eax:Affie 4.638.8 b 1808 SBC SE71 Boro ML SYBlNn 8032 9.260 SAK PROD BRU 232-23 ' px SAK PROD BRU 232-23 SAK PROD BRU 232-23 SAK PROPOSED BRU 232-23 knell A, (toes _ _ e are APIIDI Field Name Well Status 502632013300 BELUGA RIVER UNIT PROD 11 tMax Angle & MD Incf(1�H767ffKB) - 52.61 2349.30 t m(nHB) 7,587.0 __ 1.).c fhomme �N2S P(>pm (Date Annotation Lod Date K&fid (tt) '-- SSSV: NIPPLE Last WO: 18.50 �N la fC q Al ZTiT151201IB e 4 s I�nnotehon TDepth lfiKB� End Date notat on at eme c- 1 Rev Reason: NEW WELL Imosbor Last Tag: .. ,,.. CaSin Sg�Pri s — — — _ asn9 escn on Stiln�9 %�Snn91 ... oP 8)—SeTUePt6`[F..�Sel DepfhIND ... n9 .. nn9:.. CONnuCTOR 220 1 19.124 -1.0 640 84.0 15400 X65 g Release Data 10/7/200 nd rate 11/5/2009 _ S1nn9>°1'„rcI Bolted PACK %z \\ i w..eeise�. x�:.eo,asns,. eEs�.n+m.:n+-.. PPt,a a- a.M V M asw ne.Cs'm o,--ao,--a .abLafessue V mur10xos.8"E\\\,\ 95/8 8.835 22.8 3 742.6 2.95Z,f au uu -o0 e n9 ng D—..Top(HK8 e P ... ep ... Sfdng lAN . n9 String L-80 ng - 'St ng76 _. 7oP( KB` Set Depth (I Set Depth TWD) String -Aft... I String.. String 41/2 3.958 17.3 4597.1 3,690.3 12.60 C-75 Ind - - - — - .) gem Deacdotion Comment 5 ID (In) d EEx,4,l17 ]w AC ,>evr...mwa3� SAK corp Alaska. LLC - FGompleuciin etails PROPOSED BRU 232-23 K8-Grd (ft) F� Rig Release Date 1050 10/7/2009 o(boff TVD) Top Incl Noml... Top (11103) (ftKB) (•) Item Description Comment ID (in) i - leelal(on arc er 706=40 40M EXTENSION llbWEXt PlnxPi -4 —S,929A 1.06 549:8 307 --1-.04 SW19tun Snaplatc 260 559. 32. 44 SERI Sam Units 90H -S :260 2 60 -555. 5;038:8 -f1 See Ftl 24-4 520 . -41 LEEV MU-BXProfil 8;128.4-52'tb:7 C SEAL -AS catorSeaMssemb 0 ;129.-7 11:5 :40 t SeatU -2-.400 , 00:0 -3 SLEEVE--CMU-BX-ProfI 3 222:2 -S-.304-.a .3 S vmtorSeal-Assembly . 20 -2 ;305-.3 i -Unit 2:400 -636. ,642-3 . 6 SLEEVE LBMUtBXC Profile 2,39 4. ,646. .-3 -AS 6ocalor5eal-Assembly- 2 -6,565:9 -5-,647-.6 1:3SEALeafHnits 0 6;68. 44-1 —1.3& SLEEVESLSMUSX-Profile- -- 6666!1 --5q4B4 . . 8 SEAL -ASS- L-aeator-S"PAssembly 5,66. 5,-749-0 —1-.38 SEAL SeaWnits-27.40 6,7 9-.2 . B L{ LGMk}B�Profile --- 3 ,7332 69 SEAL -ASSY L-oeaterSeal Assembly- - 2:42 .6 EA eaWnits- - . -6346-..9 5627-6, 4 SHO Half -Mule -Shoe - - -- -- 2.44 Tutting Strings_ �_ u na escnption- IStdfig fdnd[D—Top IHKB] SetUepth(f... et epth(TVD).-String M.�ing... Stang Top LOWER ZONE CK 53/4 I 3.430 5,950.2 6,746.1 5,827.0 13.50 - ASSEMBLY -_ .•_.. _ - ...... . p -tion Details - _ _ _ — _ - -- - 'Nom[... _ TOP Depth (TVD) Top Ind IHKB) 19 Item Description Comment ID (in) ,1532.- �0 ACRE�SC 2Pac70Bd� 35:8 EXTENSIO FracEctensiorr80->(YC1f250 4:8004-1 9?1 BoreTeceptacleBo--0O�K 2 . 00 rp,RK ;0 ALVE ck'OuYlsolatiorrValvse2-Sle :088. .01 VALV k0atlsolalionValve- - 0 -,966:0 - ove --S-.069:15 O hearoot Safety -Joint -.42- iX8 6 1 RE 3me., E luder2B0 . . 6" 2048 ..4 Crossove � 9 5:215: . 0 X ssove . 9 x;934:8 X21 1:48 B SeaFBomareceptad 25- 6-,157:6 5;219. . B ORES en-Exclutler20B d30 A90 SAK PROPOSED BRU 232-23 KBS Rig eas- a 6d1 ••• Hileorp Alaska, LLC 18.50 10/7/2009 _pletion Dpetails •op -� spin Nomi... (TVD) Top Incl Top (ft felts) M Item Description Comment ID (in) COXp1i4A''� B ump ump ac er 4.b510 , 8. 9-fi . .« Packer d�6 "5;82. IREUNE-ENTRY MPeEur -6;740.6' 5;822.4'--1-46'SHOE IMUCE-SHOE- - - - -6 Other In Hole (Wireline retrievable plugs, valves, pumps, ffsh,_etc.) - aaaaK...a� a -Top�ep�t li j (TVD) Topincl asuaa...«a Top fii (MB) 11) Description Comment Run Date I ID (in) x919/2009 6,875 5,956.6- 1.25 PLUG -Bridge Plug - Permanent _ -- _ Perforations & Slots ce,4�,. I. asmal -- �Ao . a„Ea sem. Top(WD) Bon (WD Dens aw :.z'W0m Comment Top(Mif Min(ftKB) (ftKB) (ftKB) Zane Date fish... T are v: v�a,w..°°a, X734 -3,747-3,83T T834.5� - ots -OFmng z� uunO 3.25"/Shot Orifice .5" a� vi'.i'veae os Ire - un r mng �� 3.25"/Shot Orifice S" ea au. m6� ggg o Ire - un er Fming 3.25"/Shot Orifice .5" E o s Ire dun DUAffe-r Irk 325"/Shot Orifice .5" ots Ire - Gu0 OU er mng . «.aa „r 3.25"/Shot Orifice .5" na>&�0.5faa - o s Ire - unmerFirlri9 z �- - 325"/Shot Orifice .5 ,oeNHi«aza.. o F-md- un er Inng 3.25"/Shot Orifice .5" _ 6 RF lf8 o s Ire - un eierrFiririn9 325"/Shot Orifice .5" 6.0 4,448.0 ots ue - un r Inng w.zm.a.a, 3.25"/Shot Orifice la zv,a..><a«.- .5" saa.use-.. - 59.0- 4,469.0' ER os Ire - un (te�mng 3.25"/Shot Orifice .5" ,caa R:au,- - 7.9 4,529.9'i a 2b fS o Ire - un er Inng w�:�m� � � 325"/Shot Orifice .5" zre.zaei� P, MIA 2 4, 1 3. 2B E los rte - u9�fSA Finn9 aw.am, 3.25"/Shat Orifice .5" caeasan - w.zv 9 o ue - un er Inng 3.25" /Shot Orifice .5" o s Ire - �0 er mng .ia `I a.,x 3.26"/Shot Orifioe .5" z 97227290 fSTots FIr�Gu�D er Iring z 3.25"/Shot Orifice .5" o a a _ 7 ots Flre - un ermnc vnwz. a.am �\ 3 25"/Shot Orifice .5" xa Pnr WH PSI 2" 1502 x2 111( Flanged Val, (Manuel) 2-1/16 1 OK x 10K Ranged (Manual Coil Tubing BOP Coiled Tubing HR580 Injector Head 8 Gooseneck Weight = 12,850 lbs 4-1116" 10K Conventional Stripper 5K CO62 Lubricator 5K C062 x 4-1116" 10K Flange 4-1116" 10K Combi BOP Tcp Sec RIM/Shear Sewed Set. R e'Sli 4-1116" 10K Flow Cross Manual 2)c2 Valve 1: T 1502 x 2-1/16" IDK Flange M anPai 2x2 Valve 2: 2-1116" iOK x2-1/16" 10K Flange Manual 2x2 Valve 3: 2-1116" 1OK x 21/16" 10K Range Manual 2x2 Valve 4. 2" 15M x 2-1/16" 10K Range 4.1116" 10K x Wel heead Adapter Flange Wellhead Beluga River 232-23 Current 05/15/2019 Beluga River Unit Tubing hanger, Vetco-230, 11 232-23 x 4 %IBT susp x 4.909 MCA 20 x 9 5/8 x 7 x 4 34 14t threads, 4" type H BPV profile, 2- CCL pats, Flex neck Valve, Sw 41/1651 DE Valve, Ma 41/165 E) Valve, M 41/16 Vetco Gra) M&230 syst 11" SM to SHTA, Otis, 41/165M FE x 91/2 Otis quick union top e, Wing, 55V, A, 41/16 SM FE, v/ 15" operator, DD trim 1,000,000 t 100,000 C 0 v a 10,000 LL V O _ 'a+ (� O O N 1,000 6 Cu (7 LL i V � 3 V 100 C C N 0 O L F 10 HILCORP ALASKA LLC, BELUGA RIV UNIT 232-23 (209-057) BELUGA RIVER, UNDEFINED GAS Monthly Production Rates .. • F: ill: -_ I.IL IIIIIIIIIII SCO ���■ B�B�� l�wri�� __ O�Owl C I Bl•■B!•r �� �■� i�■�e�� m1m 1 a �- Jan-2009 Jan -2011 Jan -2013 Produced Gas (MCFM) GOR Jan -2015 Jan -2017 Jan -2019 o Produced Water (BOPM) --ll— ProducedOil (BOPM) 1,000,000 100,000 10,000 1,000 100 10 1 SPREADSHEET_2090570_BRU_232-23_Prod_Curves_Well_Gas_V120_20190521.xlsx 5/21/2019 STATE OF ALASKA AL :A OIL AND GAS CONSERVATION CON .SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Install velocity string F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc Development 1,7 Exploratory r 209-057 _ 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-283-20133-00 7.Property Designation(Lease Number): 8.Well Name and Number ADL 21128 BRU 232-23 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s) none Beluga River Field/Undefined Gas Pool 11.Present Well Condition Summary: Total Depth measured 7587 feet Plugs(measured) 6124, 6875 true vertical 6668 feet Junk(measured) none Effective Depth measured 6875 feet Packer(measured) 8 packers from 4586-6738 true vertical 5956 feet (true vertical) from 3680-5820 Casing Length Size MD TVD Burst Collapse Conductor 89' 20" 107.5' 107.5' Surface 3720' 9.625" 3743' 2953' Production 7557' 7" 7577' 6658' Perforation depth Measured depth: from 4734'-6706' s E© i LI4 n _' J'''- RECEIVED True Vertical Depth: 3822'-5788' IUL- 09 2015 Tubing(size,grade,MD,and TVD) 4.5, C-75,4597 MD, 3690 TVD AOGCC Packers&SSSV(type,MD,and TVD) 8 packers from 4586-6738 NIPPLE-CAMCO chemical injection nipple @ 446 MD and 445 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0.5 MMSCFD Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25 070,25 071,&25 283) 15 Well Class after work: Daily Report of Well Operations Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas J' VVDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt / 315-339 ✓ Contact Mike Hazen @ 265-1032 Email HazenMC(a�conocophillips.com Printed Name Mike Hazen Title Staff Wells Engineer Signature '' y Phone:265-1032 Date 8 J-1L i15 f II -/./3 i5 RBDMS\ JUL - 9 2015 A 7/�M Form 1ft-dfld Revicerl chf11 5 Siihmit C)riainal Only BRU 232-23 WELL WORK SUMMARY DATE SUMMARY 6/14/2015 SET 2-WAY CHECK VALVE IN TBG HNGR; PRESSURE TEST ALL WH CONNECTIONS &VALVES 250/3500- PASS; SLU DRIFT 3.73"SWEDGE TO 500' KB 6/15/2015 SLU LATCH SSSV @ 500' SLKB; PUH TO 447', TAG @ CHEM INJ MANDREL; UNABLE TO WORK PAST MANDREL; RIH & RELEASE SSSV @ 500' IN POLISH BORE; POOH & SDFN 6/16/2015 PULL SSSV W/PRS, PRONG & OIL JARS; 3.10 OD SWEDGE TO 5993'SLKB; LOCATE GLV MANDREL @ 4477'SLKB W/P4-1/2 DANIELS KO TOOL& PINNED RUNNING TOOL; 2 MISSED RUNS TO SET CATCHER SUB FOR GLV C/O 6/17/2015 STANND BY-WAITING ON CTU MOVE IN, RIG UP 6/18/2015 RU CTU FOR 2"CT VELOCITY STRING INSTALL 6/19/2015 SLU STAND BY; CTU CONTINUES RIG UP; BOP TEST 250/3500; AOGCC WITNESS WAIVED/ 6/20/2015 HANG-OFF 5810' OF 2"CT @ 60' CTKB USING 4-1/2"-ERrA" C<Ei ; BLEED OFF WHP ABOVE PACKER &450 PSI NEGATIVE TEST PACKER- PASS; SDFN; IN PROGRESS 6/21/2015 PT WIDEPAK PACKER = 1000 W/CAT STANDING VALVE - PASS; 14 ATTEMPTS W/FLUID PUMP TO HYDRO-BURST V-STRING BLOW OUT PLUGS, 2000-4500 PSI; UNABLE TO BURST BLOW OUT PLUGS 6/22/2015 BURST DUAL BLOW OUT PLUGS =4600; PUMP N2 VIA IA TO U-TUBE WELLBORE, 150 MSCF PUMPED, IAP= 990; WHP= 0 & NO RETURNS; PUMP 15K, 30K&45K MSCF N2 SLUGS TO TBG, MAX WHP = 975; SURGE TO TANK& FLOW BACK BETWEEN N2 SLUGS; WELL DIES AFTER EACH & NO FLOW 6/23/2015 RIG DOWN CTU; MOB CTU & PUMP TO BARGE LANDING; RU N2 PUMP TO WELL 6/24/2015 PUMP N2 TO TUBING (60K SCF SLUGS)3 TIMES SURGING & FLOWING BACK TO TANK BETWEEN SLUGS; WELL WILL NOT SUSTAIN FLOW TO ATMOSPHERE THROUGH OPEN CHOKE MANIFOLD 6/25/2015 N2 PUMP 60K SCF ATTEMPTING TO U-TUBE WELLBORE; MAX IAP = 975, PUMPING TO FORMATION; SI CHOKE & BULLHEAD 50K SCF N2 TO TUBING, MAX WHP = 975; FLOW BACK FOR 9 HOURS; WELL DIES; IN PROGESS SAK BRU 232-23 Con®Ct)IPhiIIipsm Well Attributes Max Angle&MD TD )l /P Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btrn(ftKB) Cs4wcoH9Pips 502832013300 BELUGA RIVER UNIT PROD 52.61 2,349.30 7,587.0 ------------- Comment H2S(ppm) Date Annotation End Date KB-Ord(It) Rig Release Date Well Contla:DEVIATED-BRU 232-23,2/18/2013 11:16:28 AM SSSV:WRDP Last WO: 10/72009 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date - -- ---Last Tag: 6/3/2012 Rev Reason:SHOW GRAVEL PACK FRACS osborl 2/14/2013 HANGER 11 " : . � Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR Al a CONDUCTOR 20 19.124 23.0 84.0 84.0 154.00 X65 Bolted OCasing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String W..String...String Top Thrd "' SURFACE 9 5/8 8.835 22.8 3,742.6 2,952.7 40.00 L-80 BTC-Mod NIPPLE aas CasingDescription String 0... String ID...Top(MB) Set Depth f...Set Depth ND StringWt...StringString TopThrd EIIMIIIEr P 9 9 1 ) P ( Pt (TVD) 9 NIPPLE 497PRODUCTION 7 6.276 19.0 7,576.5 6,657.9 26.00 L-80 BTC VADP,497 ` mow,: Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f_.Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 77330 - TUBING 4 1/2 3.958 17.3 4,597.1 3,690.3 12.60 C-75 IBTM GAS LIFT,4409 Completion Details NIPPLE,4,502 �- LOCATOR 4,554 I TopDepth h - (ND) Top Incl Nomi...ANa%SEAL 4565 Top(ftKB) ( B) 1°) Rem Description Comment ID(in) SEALA's Y..4.5566 tom. 17.3 17.3 -0.01 HANGER Vetco Gray Tubing hanger 4.500 EXTENSION SUa A.600 445.5 445.4 3.12 NIPPLE Camco CHEMICAL INJECTION NIPPLE with 3/8"C.L. 3.920- SSES 4603 VALVE,4.604 Le,�_ 497.1 496.9 4.21 NIPPLE Camco 3.813"BP-6i Landing Nipple 3.813 VALVE.4,607 EXTENSION sue . 4,501.8 3,600.5 20.79 NIPPLE 3.813"HESX Nipple 3.813 4.609 SCREEN. SSE 4826 4,553.7. 3,649.5 19.57 LOCATOR Baker Locator Seal Assembly w/2'Space out 3.900 ISO PACKER 4.616 SSE 4601 .. FRAC.0.637 ■ ■ 4,556.5 3,652.1 19.49'PBR Baker 43/4"PBR 3.900 SBE 4641 4,584.5 3,678.4 18.63'ANCHOR E-Anchor Seal Assembly3.250 EXTENSION,4,844 _..- SBE 4649 • •- SEAL !PERF,4,730-0,707 e,; 4,585.7 3,679.6 18.59 SEAL ASSY Baker S-22 Seal Assembly with Half mule Shoe 3.250 !PERE,4,760-4.793 ; SCREEN,4n17� _.♦. Tubing Description String 0... String ID...Top(ftKB) Set Depth(L.Set Depth( D1...StringWt..String•••String Top Thrd IPEAR1,t761905 MULTI-ZONE 53/4 3.430 4,585.8 5,933.6 5,015.4 REEF,49704.581 - •- .-..; SBE,5,033 ASSEMBLY ISO PACKER,5.035 591.5,0E T E%TENFSRlAC,5011 Completion Details FRAC PORT,5094 Top Depth SBE.5.048 (TVD) ExTENs�5/616 ' Top(ftKB) (R B) Top) Item Description' Comment ID(in) lPERF,5,a5,,to /�� 4,585.8 3,679.6 18.59 PACKER SC-2 Packer 70B-40 4.000 !PERE,5,15x5,159 - • .•- 4,599.8 3,692.9 18.16 SBE Seal Bore 80-32 3.250 !PERF ElSe-S 191-__. sE Sna5363 . 4,604.3 3,697.2 18.02 VALVE Knock out Isolation Valve C-2 Sleeve 3.320 (PERF.5,3113,366 -- lPERE,5,3774367-- lPERE,54a5.4a6� ;._. 4,606.8 3,699.6 17.95 VALVE Knock out Isolation valve C-2 3.340 SBE 5.6 ISO PACKER,5,460-� SBE 54x4-,:_'- EXTENSION _ 4,614.6 3,707.0 17.71 SCREEN Vent Screen Bakerweld 3.930 5066-_ FRAC PORT 5 70 � ': , 4,625.7 3,717.6 17.37 SBE Seal Bore MZ system 80-32 3.250 FRAC 5 470 SBE,5.0.1 4,627.9 3,719.7 17.30 ISO PACKER SC-1L ISOLATION Packer 7066-40 3.625 EXTENSION 5476 SBE,5 eel =V° 4,631.4 3,723.1 17.19 SBE Seal Bore MZ system 80-32 3.250 REEF,55775642 -yr Not- 4,633.5 3,725.1 17.13 EXENSION Upper Extension MZ system 80-32 3.970 REEF 56695,733 '♦ SCREEN,5,606 i ,�♦� 4,637.3 3,728.7 17.01 FRAC PORT Frac Extension MZ system 80.32 4.010 REEF.5 8695.914 NIPPLE,5.913 S"wlatpb,5,924 'LI.®.A 4,641.3 3,732.5" 16.89 SBE Seal Bore MZ system 80-32 3.250 SEAL,5925 ���.� -_ PACKER,5,925 _ 4,643.7 3,734.8 16.82 EXTENSION Lower Extension MZ system 80-32 3.980 F6HOE,5.033 x'S1 5,029 bII/ s"a�.a�\ � 4,648.8 3,739.7 16.66 SBE Seal Bore MZ system 80-32 3.250 �i PACKER,5.950 4,716.9 3,805.3 14.01 SCREEN Screen Excluder 2000 3.430 EXTENSION.5.854 SEK,5,957 SBR 5956 5,032.7 4,115.6 6.72 SBE Seal Bore MZ system 80-32 3.250 " 5,034.9 4,117.7 6.68 ISO PACKER SC-1 L Packer 7086-40 3.625 VALVE 5.962 5,038.4 4,121.2 6.61 SBE Seal Bore MZ system 80-32 3.250 VALVE. 5� 1r4 c 5,040.5 4,123.2 6.57 EXTENSION Upper Extension MZ system 80-32 3.970 SCREEN.6.003 r1x _ 5,044.3 4,127.0 6.50 FRAC PORT Frac Extension MZ system 80-32 4.010 IPERF 8.0988,110 SLEEVE-0.6.124 3 5,048.3 4,131.0 6.42 SBE Seal Bore MZ system 80-32 3.250 PLUGTUBING,6,124 ���� SEAL cone 6 12 ■ `,1 5,050.7 4,133.3 6.37 EXTENSION Lower Extension MZ system 80-32 3.980 SEAL,a ISO -" _ SBR 6135 q %P 5,055.8 4,138.4 6.27 SBE Seal Bore MZ system 80-32 3.250 !PERFs138.6.1361474:4'.' 5,083.5 4,166.0 5.72 SCREEN Screen Excluder 2000 3.430 !PERF 91445,161 SCREEN. 1606,,95i.10:- PERE, 5,458.2 4,540.1 1.92 SBE Seal Bore MZ system 80-32 3.250 !PERE,616'34193 '_. �5,�,,,, 5,460.4 4,542.3 1.93 ISO PACKER SC-1L Packer 7086-40 3.625 SLEEVE6218 ■Y 5,463.9 4,545.8 3.12 SBE Seal Bore MZ system 80-32 3.250 SEAL ASST,6323 SEAL,6.224 5,465.9 4,547.9 3.07 EXTENSION Upper Extension MZ system 80-32 3.970 SER,6226r _ SCREEN,6231 I s 5,469.7 4,551.7 2.99 FRAC PORT Frac Extension MZ system 80-32 4.010 !PERE,EEE.6.363-6.3911--_. Kill_` , SC�EN.6.IH 5,473.7 4,555.7 2.90 SBE Seal Bore MZ system 80-32 3.250 !PERF,8,4365.477 PERF,6,4364514 � '_ 5,476.1 4,558.1 2.84 EXTENSION Lower Extension MZ system 80-32 3.980 (PERF,6,4924511 A. '` ` 5,481.2 4,563.2 2.73 SBE Seal Bore MZ system 80-32 3.250 SLEEVE,6.561 TUBING,9,556 ■p; 5,607.5 4,689.4 0.61 SCREEN Screen Excluder 2000 3.430 SEK ASSY,6,565 sSAl 6.569 kik' 5,923.1 5,004.9 1.05 NIPPLE R Nipple 3.250 6. i A-ewe510-owe1 1 %` 5,924.1 5,006.0 1.05 Snaplatch Snaplatch 3.270 WERE.6591-6,606 - -- -. SCREEN,6,571 - i /- 5,925.1 5,006.9 1.05 SEAL Seal Units 3.260 SCREEN,6.850 I` 5,933.1 5,014.9 1.05 SHOE Half Mule shoe 52-40 3.260 SLEEc.a Ilii-ti662 . Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd TUBISEK Asst 6666 9 CK LOWER 2.89 2.370 5,925.1 6,746.8 5,828.4 6.40 1-80 2-7/8 Hyd 511 ' EKA368 �_' ISOLATION STRING SBRBBn i PER SCREEN. I►�� Completion Details PERF,e,eee-ala lig' Top Depth SLEEVE 6118 `"-""� (ND) Top Incl Bond... SCREEN,6,727 LL SEK ASSY.5733 (jTop(ftKB) (ftKB) 11 Rem Description Comment ID(In) Snap120811,VA 9' >? 5,925.1 5,006.9 1.05 PACKER SC-2 Isolation Packer 70B-40 4.000 BOT Sump Parker. 8736 a I SEK,8.736 L 41 SEK.6,7E •� WLEG,6 703 . - .Mandrel Details Bottom Sub 60.31 S z2 6745'N ` $" Top Depth Top Port SHOE 6,746 g (ND) Incl OD Valve Latch Size TRO Run SHOE 6,748 p SHOE.6.741 '- N...Top(ftKB) (ftKB) (°) Make Model (in) sere Type Type PM (Psi) Run Date Com... PLUG.0.015 >_ 1 4,448.6 3,551.1 22.36 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 9/20/2009 PRODUCTION. a = To97,577 ,7507 A..,,.. SAK BRU 232-23 Y P 4 ConocoPhillips IR Alaska.Inc, ........ -.... ........ _ CorlocotWtSps °" KB-Ord(ft) Rig Release Date 10/7/2009 Well Config:DEVIATED-BRU 232-23,2/18/2013 11:16:28 AM Schematic-Actual HANGER,17 • • Completion Details Top Depth COhocoroR, (TVD) Top Incl Semi... 84 Top(ftKB) (ft(B) r) Item Description Comment ID(in) m. 5,929.4 5,0112 1.05 EXTENSION Millout Ext.Pin x Pin 4.650 NIPPLE 46 NIPPLE.49] 11:,i„ 5,948.8 5,030.7 1.04 Snaplatch Snaplatch 3.260 em/ant 5,950.2 5,032.0 1.04 SEAL Seal Units 90H Stub 3.260 5,956.8 5,038.6 1.03 SEAL Seal Units 3.260 SURFACE x33,743 6,124.4 5,2062 1.41 SLEEVE-C SLCMU BX Profile 2.313 GAS LIFT,4,449 6,128.4 5,210.1 1.40 SEAL ASSY Locator Seal Assembly 2.420 NIPPLE 4.502fart LOCATOR 4,551 PSR 4,556 6,129.7 5,211.5 1.40 SEAL Seal Units 2.400 PACKER.aces AN010R SEY. 198 6,218.3 5,300.0 1.35 SLEEVE SLCMU BX Profile 2.313 ' SE.Assr 45ee� laS.\\ 6,2222 5,304.0 1.35 SEAL ASSY Locator Seal Assembly 2.420 4.590IA SBE.4fi00 6223.6 5,305.3 1.35 SEAL Seal Units 2.400 Sue.460 VALVE 4.604 VALVE 4697 6,560.6 5,642.3 126 SLEEVE SLCMU BX Profile 2.313 EXTENSION ems\, SCREEN,4,8156,564.5 5,646.2 1.36 SEAL ASSY Locator Seal Assembly 2.420 SBE 4.626 ISO PACKER 4.628 6,565.9 5,647.6 1.36 SEAL Seal Units 2.400 SBE 4031 ■ • 6,662.4 5,744.1 1.38 SLEEVE SLCMU BX Profile 2.313 SBE 4.641 EXTENSIONEE.4,649 ->e 6,666.4 5,748.0 1.38 SEAL ASSY Locator Seal Assembly 2.420 6,667.7 5,749.4 1.38 SEAL Seal Units 2.400 12;1:7344747--- IPESVIEEN-a,793�_ �'♦. 6,717.6 5,799.2 1.50 SLEEVE SLCMU BX Profile 2.313 SCREEN 4,72 IPERR 46]6.4981- --__` ' 6,733.3 5,814.9 1.47 SEAL ASSY Locator Seal Assembly 2.420 PERF,5975-4.961 PERE 5o,55.m3� -�.. 6,734.6 5,816.3 1.47 SEAL Seal Units 2.400 ISO PACKER 5.035 _ SBE 5,e36� 4a`=-'-- 6,745.9 5,827.5 1.46 SHOE Half Mule Shoe 2.440 IXTE eON 5040 C,5,044 NM FRAC PORT,SBE, Tubing Strings EXTENSION.5051 air.. Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)... String Wt...String... String Top Thrd SBE 5956 LOWER ZONE CK 5 3/4 3.430 5,950.2 6,746.1 5,827.8 13.50 IPERF 51005110 - • r_1 ASSEMBLY IPERF 51525159 PERF 51765191 , Completion Details SCEER 5.003 TopDepth IPERF 531366 -4 P IPERF 5377.538] '♦1 (TVD) Top Incl Nomi... IPERF,50.3654461 To (ftKB) (ftKB) rt Item Description Comment ID in 68E5450 �,-� Pl 1 Dti ( ) ISO PACKER.5.460 - SBE5464 --`� 5,950.2 5,032.0 1.04 PACKER SC-2 Packer 70B-40 4.000 EXTENSION.5.466 FR ;oma ® ® 5,953.9 5,035.8 1.04 EXTENSION Frac Extension 80-40 CK 250 4.800 FRAC 5 ExrE s E ie 5,957.6 5,039.4 1.03 SBR Seal Bore receptacle 80-40 CK 250 4.000 SBE 546,-• --_ - a 5,981.7 5,063.5 1.01 VALVE Knock Out Isolation Valve C-2 Sleeve 3.340 IPERF.56295642 ----.-•� 5,984.4 5,066.2 1.01 VALVE Knock Out Isolation Valve C-2 3.310 IPERE5,6mS.7S1 ,.'.: scrs3=N 56m __ L. 5,987.7 5,069.5 1.02 SOS Shear out Safety Joint 3.420 IPERF,5,688-5,91/ NIPPLE 5,923 sn:a4ch 5,924 wi 6,083.5 5,165.3 1.12 SCREEN Screen Excluder 2000 3.430 SE4 5925 P ACNER 5925 6,123.0 5,204.8 1.41 XO Crossover 3.490 SHOE 5,933 EXTENSION 5929 "-- 5 � ...- �' 6,134.1 5,215.9 1.40 XO Crossover 3.490 Snarl PACKER 5..950 6,134.8 5,216.6 1.40 SBR Seal Bore receptacle 3.250 EXTENSION 5.951 _- sSBBRR 5:957� 6,137.6 5,219.3 1.40 SCREEN Screen Excluder 2000 3.430 6,216.3 5,298.0 1.35 XO Crossover 3.490 VALVE,heel 6,227.4 5,3092 1.34 XO Crossover 3.490 VALVE.5965 - -' 6,228.1 5,309.9 1.34 SBR Seal Bore receptacle 3.250 SOS,5966 SCREEN,6 - 065 It r 6,230.9 5,312.6 1.34 SCREEN Screen Baker Weld 140 3.430 IPERP.e0985,16� i$. 1�, SLEEVE .6,124 6,241.4 5,3232 1.33 SCREEN Screen Excluder 2000 3.430 PLuc.6.,24\ � TOBING.6,2a > .- SEN,ASSY.6126 6,557.0 5,638.7 126 XO Crossover 3.470 S6.1331 SBR ,35 -- SBR 66,568.2 5,649.8 1.36 XO Crossover 3.470 P ERF.6135.166 _'���' 6,568.7 5,650.4 1.36 SBR Seal Bore receptacle 3.250 IPERF.6.140.6,104 SCREEN.6138 -' ' 6,571.5 5,653.1 1.36 SCREEN Screen Excluder 2000 3.430 IPERF,6180.6,194 IPERF,6,160.6 193 i®Al •,. ,- 6,650.3 5,732.0 1.37 SCREEN Screen Baker Weld 140 3.430 SLEEVE 6218- 6,660.9 5,742.5 1.38 XO Crossover 3.470 SEAL ASSY.6.222-- S.L.621, it itWi u• 6,672.0 5,753.6 1.38 XO Crossover 3.470 SBR 6228 SCREEN 6231 >m 6,672.6 5,754.2 1.38 SBR Seal Bore receptacle 3.250 !PERGREEN.66:241 - -/ 6,675.3 5,756.9 1.38 SCREEN Screen Excluder 2000 3.430 IPERF 6 466-6 477 IPERF.66-6 48 .514 =, / 6,714.8 5,796A 1.50 XO Crossover 3.470 IPERF,6,492-6 512 - /> ► / 6,725.9 5,807.6 1.48 XO Crossover 3.470 SLEEVE, j SEAL ASSY 6565 ,.:._ 6,726.5 5,808.1 1.48 SCREEN Screen Baker Weld 140 3.430 X6589-\ - 6,737.0 5,818.7 1.47 Snaplatch Snap latch 82-40 3.250 SEAL.6.5Efi DERE,61T65,� '*-.:-- -0 6,738.0 5,819.6 1.47 SEAL Seal Units 82-40 3.250 WESCRE Ni 6,56]16 lell. 6,745.6 5,827.3 1.46 SHOE Half Mule Shoe 82-40 Stub 3.250 11-4 Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WE..String...String Top Thrd S CREEN. 650 TUBING-Sump 51/2 4.930 6,738,0 6,760.3 5,841.9 ueS ASSY:2:43- 3 Packer S.L.6,668 SBR 603---..... 673 ". Completion Details ; ., SCREEN 6.615 -1 Top Depth m-hem-673 ' (TVD) Top Incl Nomi... ▪ERE.66m-6Tm Top(ftKB) (ftKB) r) Item Description Comment ID(In) bLEEVE 6.710 �^-� solSEV.6n7� 6,738.0 5,819.6 1.47 BOT Sump BOT Sump Packer 4.000 SEAL ASSY 6733N ; Packer Bo s mu Pack 6,736 -- 3S. 6EPL,6.736 T• 1B; SEAL.6.]39 . NAE.6,]40 Bottom 6.80-32 S22.6.745 SHOE SHOE el6,]an 46- SHOE.6.]41 PLUG.6.575 ere,e-!'- PRODUCTION , 7� TD,),5871 �� _ SAK BRU 232-23 ' ConocoPhillips ,i ` Pals,a,lr . CA11ocoPtoispa _ _... KB-&d(R) Rig Release Date Well COnDm:DEVIATED•BRU 232-23,2/182013 1116:28 AM _ _ 10/72009 _-- Schemata-Actual HANGER 17 " . Completion Details I Top Depth CONDUCTOR. (TVD) Top Incl Nomi... 23-64 SI Top(ftKB) (RKB) r) Item Description Comment ID(In) 6,740.0 5,821.6 1.47 WLEG WIRELINE ENTRY GUIDE 4.000 NIPPLE 445 '`■■■ NIPPLE 6,740.8 5,822.4 1.46 SHOE MULE SHOE 4.930 .] Other In Hole(Wireline retrievable plugs,valves,'pumps,fish,etc.) 4a> _i' Top Depth SURFACE 233.]41 N.: Top Incl Top(ftKB) (ftKB) (") Description Comment Run Date ID(in) GAS LET.4,449 497.1 496.9 4.22 WRDP WRDP SET IN BP-6i NIPPLE 9/21/2012 NIPPLE.4.502 LOCATOR 4.554 6,124.4 5,206.2 1.41 PLUG IPX PLUG SET IN SLEEVE 9/21/2012 0.000 PER,SEAL. '..4.585 .: ANCH(%i SEK. 6,875.0 5,956.6 1.25 PLUG BridgePlug-Permanent 9/9/2009 0.000 PACKER 4.586 I MIR, SEAL ASSY.4,58 EXTENSION SUR - 4.590� _� Perforations Slots SBE,4600 Shot SUB.4.603 VALVE.4604 I Top(ND) Btm(TVD) Dens VALVE 4 607 h... EXTENSION SUB Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (s Type Comment SCREEN 44',66155 4,734.0 4,747.0 3,821.9 3,834.5 Sterling A,BRU 9/292009 14.0 IPERF All Shots Fired-Gun OD After Firing SBE 4626 232-23 3.25"/Shot Orifice.5" ISO PACKER,4,678 SBE 4691 FRAC:463] IN ■ 4,780.0 4,793.0 3,866.7 3,879.4 Beluga D,BRU 9/29/2009 14.0 IPERF All Shots Fired-Gun OD After Firing SBE 4x41 232-23 325"/Shot Orifice.5" EXTENSION.4� 4,876.0 4,905.0 3,960.7 3,989.3 Beluga D,BRU 9/29/2009 14.0 IPERF All Shots Fired-Gun OD After Firing IPERF 4734.747 "t- 232-23 3.25"/Shot Orifice.5" IPERF.4]8-0.]91 SCREEN 4,717 4,970.0 4,981.0 4,053.4 4,064.3 Beluga D,BRU 9/29/2009 14.0 IPERF All Shots Fired-Gun OD After Firing IPERF.E,6764905 , 232-23 3.25"/Shot Orifice.5" PEFF.49Ia481 A �- IFERF.5,0155,029 IsoPASSE 6'.035 gA® 5,015.0 5,023.0 4,098.0 4,105.9 Beluga E,BRU 9/29/2009 14.0 IPERF All Shots Fired-Gun OD After Firing SSE 50+6 232-23 3.25"/Shot Orifice.5" . EXTENSION.5.040 p°- FRAC PORT.5.044 ® `f� , 5,100.0 5,110.0 4,182.4 4,192.4 Beluga E,BRU 9/29/2009 14.0 IPERF All Shots Fired-Gun OD After Firing SBE 5,046 232-23 3.25"/Shot Orifice.5" IXTENSSEE 5.08 E:ir - 5,152.0 5,159.0 4,234.2 4,2412 Beluga E,BRU 9/29/2009 14.0 IPERF All Shots Fired-Gun OD After Firing IPERF,519o-5,n0 232-23 3.25"/Shot Orifice.5" IPERF,5.152-5,159 - - --- IPERF 5.1765 191 0._ ' 4 5,176.0 5,191.0 4,258.2 4,273.1 Beluga E,BRU 9/29/2009 14.0 IPERF All Shots Fired-Gun OD After Firing SCREEN.50631 ♦♦ 232-23 3.25"/Shot Orifice 5" P.F.5.3545366 ---.- P EP.5,3775,87 P ERF.54365.44B, .` ♦. 5,354.0 5,366.0 4,436.0 4,448.0 Beluga F,BRU 9/29/2009 14.0 IPERF All Shots Fired-Gun OD After Firing 5 80 232-23 3.25"/Shot Orifice.5" Iso PACKERSSE 5,460_ SBE 5464 EXTENSICR,PORT 5466 5,377.0 5,387.0 4,459.0 4,469.0 Beluga F,BRU 9/29/2009 14.0 IPERF All Shots Fired-Gun OD After Firing FRAC PORT 5470 ruseSEE 5.470 ' 232-23 3.25"/Shot Orifice.5" SBE 5,4]3 FXTENS00 5.4]6- sBE 5031 5,436.0 5,448.0 4,517.9 4,529.9 Beluga F,BRU 9/29/2009 14.0 IPERF All Shots Fired-Gun OD After Firing 232-23 3.25"/Shot Orifice.5" IPERF.56H5642 -i,♦�}- 5,629.0 5,642.0 4,710.9 4,723.9 Beluga F,BRU 9/29/2009 14.0 IPERF All Shots Fired-Gun OD After Firing IPERF5.665]03 SCREEN..6336 - - 232-23 3.25"/Shot Orifice 5" IPERF8686914 Ik�1I Smola.,692424 bt0-���' 5,689.0 5,733.0 4,770.9 4,814.9 Beluga F,BRU 9/29/2009 14.0 IPERF All Shots Fired-Gun OD After Firing PACKER 5 232-23 3.25"/Shot Orifice.5" SHOE.5933 EXTENSION.5.929 1® + 5,888.0 5,914.0 4,969.8 4,995.8 Beluga G,BRU 9/29/2009 14.0 IPERF All Shots Fired-Gun OD After Firing S SEAL.5.950 i ,a;, 232-23 3.25"/Shot Orifice.5" PACIION.5054 EXTENSION.5054 5054 '" �5.957 � 6,098.0 6,118.0 5,179.8 5,199.8 Beluga G,BRU 9222009 14.0 IPERF All Shots Fired-Gun OD After Firing 5950 232-23 3.25"/Shot Orifice.5" ri" 6,139.0 6,166.0 5,220.8 5,247.8 Beluga G,BRU 9/22/2009 14.0 IPERF All Shots Fired-Gun OD After Firing 232-23 3.25"/Shot Orifice.5" VALVE 5.982 VALVE 5080 6,144.0 6,164.0 5,225.8 5,245.8 Beluga G,BRU 9/16/2009 6.0 IPERF All Shots Fired-Gun OD After Firing 3-066.6 SCREEN 683 232-23 3.25"/Shot Orifice.5" IPERF 8-6 60118 SLEEVE C 6124 � d 6,180.0 6,194.0 5,261.8 5,275.8 Beluga H,BRU 9/22/2009 14.0 IPERF All Shots Fired-Gun OD After Firing PLUG 6.124 232-23 3.25"/Shot Orifice.5" TUBING 6124 ti SEK ASSY 6126 / SEAL, 0;30 ' 6,183.0 6,193.0 5,264.8 5,274.8 Beluga H,BRU 9/16/2009 6.0 IPERF All Shots Fired-Gun OD After Firing r 1 232-23 3.25"/Shot Orifice.5" PERF.6.136.18 PERE 01.61. -�®'`; 6,388.0 6,398.0 5,469.7 5,479.7 Beluga H,BRU 9/22/2009 14.0 IPERF All Shots Fired-Gun OD After Firing STI 8138 ®i. 232-23 3.25"/Shot Orifice.5" IPERF 5 180-6 1.IPERF 6,1636193 f�, I��•1` 6,466.0 6,477.0 5,547.7 5,558.7 Beluga H,BRU 9/22/2009 14.0 IPERF All Shots Fired-Gun OD After Firing 232-23 3.25"/Shot Orifice.5" SLEEVE,8.218 s - _ SEK Asst 6,222 6,486.0 6,514.0 5,567.7 5,595.7 Beluga H,BRU 9/22/2009 14.0 IPERF All Shots Fired-Gun OD After Firing SBR 6ne �'�* 232-23 3.25"/Shot Orifice.5" 3-4403+6231 t9t `' 6,492.0 6,512.0 5,573.7 5,593.7 Beluga H,BRU 9/15/2009 6.0 IPERF All Shots Fired-Gun OD After Firing PEP.63886.001 Ir4 g SCREEN.6241 i'. '_ 232-23 3.25"/Shot Orifice.5" PERF.6.6664]7 Ale ,I- PERF'6'°92-6514 :®1 441 ' 6,576.0 6,609.0 5,657.7 5,690.7 Beluga H,BRU 9/22/2009 14.0 IPERF All Shots Fired-Gun OD After Firing IPERF.6,4926,512 11;1' SLEEVE 6.561 " 232-23 3.25"/Shot Orifice.5" . TUBING.6.556 SEK ASSY.6565 6,591.0 6,606.0 5,672.7 5,687.7 Beluga H,BRU 9/14/2009 6.0 IPERF All Shots Fired-Gun OD After Firing SSR 6569 LA 232-23 3.25"/Shot Orifice.5" SEAL,6.566 it '►1 6,683.0 6,709.0 5,764.6 5,790.6 Beluga H,BRU 9/22/2009 14.0 IPERF All Shots Fired-Gun OD After Firing P ERF.6.5766.609 -(4 ,1_ 232-23 3.25"/Shot Orifice.5" IPERF.6.5.6006 SCREEN 6.571 I(-� 6,686.0 6,706.0 5,767.6 5,787.6 Beluga H,BRU 9/13/2009 6.0 IPERF All Shots Fired-Gun OD After Firing SCREEN 8.650 AI 232-23 3 25"/Shot Orifice.5" SLEEVE 6662 _ 6EAL AGCY 6668- Stimulations.84 Treatments SBR 6.668 Bottom a. MTop Max Btm Top Depth Depth IPERF. SCREEN.,66.8785 :N", in- Depth Depth (TVD) (ND) PERF.6.6866.706 ", ,. ► (ftKB) (RKB) (RKB) (RKB) Type Date Comment SLffvE.6.716 kW.4' 4,637.0 4,641.0 3,728.4 3,732.2 FRAC 10/6/2009 FRAC EXTENSION SCREEN.6.727 SEAL ASSY.6733 5,044.0 5,048.0 4,126.7 4,130.7 FRAC 10/6/2009 FRAC EXTENSION BOT sumpP'6k� 5,470.0 5,474.0 4,552.0 4,555.9 FRAC 10/6/2009 FRAC EXTENSION SEALSEAL',eias NL 6.743yI' Bottom$508 032 111 E 22,8.745 SHOE.6.746 f ° SHOE.6.746 SHOE.6.741 PLUG.6.675 PRODUCTION, 711,)037 t SAK BRU 232-23 - ` ConocoPhiHips 1a '. Alaska,Inc. conomehoups ., KB-Grd(R) Rig Release Date -Well Costa:DEVIATED-BOO 232-23,2/1812013 11 16 28 AM - 10/7/2009 Schematic-Actual ""GER" Notes:General&Safety I End Date Annotation _-- CONDUCTOR 11/5/2009 NOTE:View Schematic w/Alaska Schematic9.0 2381 111 NIPPLE,145 NIPPLE,49] WRDP,497 itEt..,..!41 SURFACE 23-5143 GAS LIFT.4.448 NIPPLE.4,502 LOCATOR 4,554 PBR 4,558 ANCHOR SEAL. 4.585 PACKER 4,586. SEALASSY.4506 EXTEN8KN1.50 1.550 SUB,4,800 SUE,4,603 VALVE,4,607 VALVE NSION S E -ate EXTENSION 600 4,8051 SCREEN,ne4.2 $EE,4,86286 _ SSE 330 PAC 4.63 SBE 4.8311 -' , ass FRAC.4.631 ■ ■ BBE 4.841 , EXTENSION.4.814 - SBE 4.649 R-... IPERF,4734.4,747—.-- IPE4793_ C SCREEN SCREEN 431]---_„._ IPERF,1,0]64i _: , ♦' AIL f .- - IPERF.5.1005.110 IPE:5,1528.159 : ♦♦ IPERF, 5.191 SCREEN EEN 5083 IPERF.5,]515.%8 •.. IPERF.5377.5367 - IPERF.54385,48--__ 5555.458 — ISO PACKER,5460�- SBE 5.464\_ -C EXTENSION 5,488 - - FRAC We..5470 see 5.4.30- EXTENSION 5.476 SBE 5,481 • PERE 5.629.5642 -. PERF.68895733 SCREEN,5,608 �.:♦ IP ERR 68685914 NIPPLE,5923 6nN001C11,5.924 - SER,5.925 PACKER,OE,5.9933 ---- / EXTENSION,5,929 Snenhk:N,5,649� SEK,5,950 4,' PACKER.5950 _ _ EXTENSION 5854 EK.5.957 SBR,5958-� VALVE.5982 VALVE.5984 SOS,5988 SCREEN,6003 IPERF,6,5968,116 SLEEVED 8124 PLUG6124-- ` TUBING8,124� Ca�.u?� SEAL ASSY.8.126 l4Ei1 BEAR,AL.8.130 A 's SOR.6.135 PE:,6,1398,168- 3 �.fr' PERF.6,148.184 SF,61808.138 PE:,6,1806,194 ; �- PESC 61636,193 SLEEVE 8,218 A REAL ASB).6,222 SEAL 6,224 SBR. BBR.6.220 �'�j SCREEN,8231 �I PERF SCREEN8 388356 6,241 , FERE.8,4886,47] PER;8,4866.514 FERE,64928,512 SLEEVE 6581 TU&NG,6545nal SEAL ASST,8.565 — 60R.6569L_- 7. SEAL 6,588 / , IPERF,8.5788,809-� _, , IPERF,8,5918.808 111 SCREEN,6,571-- ---- - SCREEN,6,650 +�' - BINSLEEVE,6,862 �,- TUG,6,662 i.—j SEAL ASST,8.686 i.,--7 III SEAL 6660� a : sea,6.673 lE' - . FES 8 EEN 867509 IPERF,66684 706 ... ` SLEEVE.8,718 .4 SCREEN,6,7271\ SEAL ASSY,6,733 \ ..... BOT Sump 9073 eta SEAL 6il' rt1 735 i— SEAL 8,735 MEG.8740 Bde1 om Sue 80.32 S.22,8.745 SHOE.6746 SHOE.6746 SHOE,6.741 PLUG.y75 ' PRODUCTION ED DIE 97577 TD,7,567 N ..--- , OF T7.1, s� THE STATE Alaska Oil and Gas of 4AsKAL Conservation Commission ' f u ' t �=_! _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF 4LASIC • '� �� Fax: 907.276.7542 Sopa3/4N� www aogcc alaska.gov Mike Hazen 7^ ©S Staff Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Beluga River Field, Undefined Gas Pool, BRU 232-23 Sundry Number: 315-339 Dear Mr. Hazen: 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, 4/1 Daniel T. Seamount, Jr. c Commissioner DATED this G day of June, 2015 Encl. STATE OF ALASKA ' A ,KA OIL AND GAS CONSERVATION COM, 310N ` `,' z(`6(ci APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Rill Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Ferforate New Pool r Repair Well rRe-enter Sus Well r Other: Install velocity string j✓. 2 Operator Name: 4.Current Well Class. 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. , _ Exploratory r Development p- 209-057 3 Address. Stratigraphicr Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-283-20133-00' 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 17 ✓ BRU 232-23 9.Property Designation(Lease Number): 10.Field/Pool(s): I I I ADL 21128 . Beluga River Field/B2t j -G s-Rnot ()Ad inki /Jx 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): 7587 - 6668 6875' - 5956' ' 6124,6875 none Casing Length Size MD TVD Burst Collapse Conductor 89' 20" 107.5' 107.5' Surface 3720' 9.625" 3743' 2953' Production 7557' 7" 7577' 6658' RECEIVED JUN 02 2015 AOGCC Perforation Depth MD(ft). Perforation Depth TVD(ft): Tubing Size. Tubing Grade: Tubing MD(ft): from 4734'-6706' 3822'-5788' 4.5 C-75 4597 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) 8 packers from 4586'to 6738'MD NIPPLE-CAMCO chemical injection nipple MD=446 TVD=445 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work Detailed Operations Program r BOP Sketch r Exploratory E Stratigraphic r Development J • Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work. 6/8/2015 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r. WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact. Mike Hazen @ 265-1032 Email: HazenMC@conocophillips corn Printed Name ,Mike Hazen Title: Staff Wells Engineer Signature j�/ tic,( '—' Phone:265-1032 Date ( TOk4 1-5-- Commission Commission Use Only Sundry Number. G Conditions of approval: Notify Commission so that a representative may witness -3 S' 2 7 \ Plug Integrity r BOP Test r77.Mechanical Integrity Test r Location Clearance r Other Opp ff51 /c „? SC o p5,. (A' P 5 PP is 3 45 Os:) Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: iG — 4 G 4 1111P APPROVED BY /� Approved by: COMMISSIONER THE COMMISSION Date: ai-Y i Approved application Is valid tor 12 months trpm the date of approval. submit Form and �S- g'�S 1 Form 03 Revised 5/2611 ORIGINAL -pta 413 ,s A t c me b init Duplicate � '4,------ RBDMS JUN 1 0 2015 ConocoPhillips Alaska REDE!VED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 JUN 0 2 2015 June 1, 2015 AOGCC State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to install a coiled tubing (CT)velocity string Beluga River Unit Producer 232-23 (PTD#209-057). Beluga River Unit (BRU) 232-23 was originally drilled and completed in late 2009 as a producer in the Sterling A- and Beluga D- through H-sands. It is constructed with 7" production casing to 7576' and 4- 1/2" tubing to 4597'. The producing zones were perforated then gravel packed utilizing a Baker MZ assembly with Excluder 2000 premium screens. The well is on line and currently producing approximately 0.5-MMSCFD, however is loaded with water below 5000'. The well has potential to produce 1.5-MMSCFD. The objective of this non-rig workover is to utilize CT to hang off a velocity string on a packer from 50' RKB to 5900' RKB to help initiate flow from ✓ the non-producing perforations from 5500'-6500'. If you have any questions or require any further information, please contact me at 265-1032 or hazenmc@conocophillips.com or Jay Maguire at 263-4551 and Jay.C.Maguire@conocophillips.com. Sincerely, Michael C. Hazen Wells Engineer CPAI Drilling and Wells BRU 232-23 Coiled Tubing Velocity Deployment (PTD# 209-057) Current Status: The well is on line and currently produces approximately 0.5-MMSCFD. It is loaded with water below 5000'.The well has potential to 1.5-MMSCFD. Scope of Work: The objective of this procedure is to utilize coiled tubing to hang off a velocity string on a packer from 50' RKB to 5900' RKB.The well is loaded with water below 5000' and the velocity string will help initiate flow from the non-producing perforations from 5500'-6500'.These zones are gravel packed and the 2" coil will allow water to be lifted and increase production rates. General Well info: MASP: 345 psi (using 0.1 psi/ft gas gradient and Sterling A @ 4,734'MD) Max. Reservoir pressures/TVD: From 8/9/2014 FBHPS(w/5000'produced water FL): Sterling A@ 4,600'MD/3,693'TVD= 375 psi Beluga G @ 6,110'MD/5,192'TVD=870 psi • Max Inclination: 53° @ 3,045' KB. Min ID Within Set Depth: 3.250" SBE @ approx. 4600' KB Wellhead type/pressure rating: VetcoGray Multibowl 5,000 psig SLB BOP Configuration: Dual Stack: 1.) Blind-Shear/Blind-Shear/Pipe/Slip; and 2.) Blind-Shear/Slip-Pipe Well Type: Gas Producer Estimated Start Date: June 8, 2015 Wells Engineer: Jay Maguire (263-4551,Jay.C.Maguire@conocophillips.com) Wells Engineer Production Engineer: Tyler Hall (263-4012,Tyler.A.Hall@conocophillips.com) Cook Inlet Production Engineer Proposed Procedure: Slickline: 1. Conduct pre-job safety meeting (PJSM). 2. Pull WRDP insert from @ 497' KB. 3. Drift well with 3.1" OD tool 6,000' RKB. 4. Drift to 100' RKB with 3.7" OD tool. 5. Set a plug in the CAMCO nipple @ 497' KB to be used to pressure test tree connections/valves. 6. Pressure test tree valve and connections. 7. Pull plug @ 497' KB. Coiled Tubing: 8. Conduct pre-job safety meeting (PJSM). 9. Rig up the CTU with Combi-BOP's with redundant rams (pipe/slips) on wellhead and 30ft of lubricator. 10. Mix and fill the pits with 500 bbl of 6% KCI water with 1%corrosion inhibitor. Rig up the pump to✓ the BOPE with 2" 1502 15M iron and rig the suction lines to the tanks,test system to 250-psi low, 3500-psi high. Bleed pressure to zero when finished. Ensuring BOPE's are capped, line up pump to the well at the flowcross/pump-in-sub. 11. Rig up surface lines to pump into BOPE or flow cross.Test the lines and connections. 12. Notify the AOGCC 48-hours in advance of testing BOPE. Rig up the BOPE to well head.Test and chart BOPE. 13. Pump a sufficient volume of fluid through the CT reel to sweep debris from the tubing. 14. Pump 5/8" drift ball through the CT once string is loaded with fluid. 15. Pick up lubricator and run coiled tubing out the end of the stack. 16. Prep the end of the coiled tubing with reamer and install coil connector. 17. MU pull-plate to connector and pull test to 10,000 lbs. 18. Pressure test CT to 500 psi for 5 minutes and 5000 psi for 10 minutes. 19. Break off the pull plate and make blow out plug w/seating nipple (See attached drawing). 20. Make up stack to well and PT lubricator to 1000-psi through flow cross. 21. Bleed down stack. 22. Pressure-test the pump out plug to 1000 psi by pumping down coil. (The pump out plug is set to release at 1800 psi.) 23. Zero depth counter. 24. RIH slowly until BHA passes thru wellhead. Continue run in hole at 50 ft/min and reduce the running speed to 10 ft/min passing through restrictions. 25. Perform weight check every 1000 ft and record weights. 26. At 5820 ft, prepare to cut coil and rig up packer. Check schematics for depths. 27. Record all parameters such as WHP, CT hanging weight, run in-hole weight and pick-up weight. Record hanging weight also for use when setting packer. 28. Close in BOP pipe rams and confirm the slip rams are holding the coil in place; perform pull test and flow test.Test both pipe rams from below against the swab valve. 29. Upon successful (negative) inflow test, bleed off riser pressure to 0 psi. 30. Open coiled tubing at the reel and inflow test the velocity string blow plug-this will ensure barriers from the well on the inside of the coiled tubing. Pressure-test the pump-out plug from above to 1,000 psi differential (down CT). Monitor for 30 minutes to see if any pressures change in the coil string. 31. Open the injector head skates 32. Break the riser and lift injector head - during this process, a coiled tubing operator will monitor the weight indicator to ensure free movement of the injector head over the stationary coiled tubing. Cut Coiled Tubing& Make-Up Packer Assembly 33. Hot tap the coil tubing to ensure there is no gas pressure at surface. 34. Close Injector Head Skates onto coiled tubing. 35. Cut coiled tubing 36. Once cut, pick coiled tubing up out of the way. MU the packer BHA consisting of 2.00" coiled tubing connector with 2-3/8" CS Pin, 3.063" Sealed tubing swivel, and 2.875" cross over 37. Dress coiled tubing in injector head and install coil connector; pull test to 20,000 lbs. 38. MU connector(upper string) to (lower string) and pull test to 10,000 lbs. 39. Pressure test the coil connector and packer connections to 1,000 psi by applying pressure through the pump through sub between the upper pipe rams and riser of the coil unit. 40. Open pipe and slip rams and continue RIH 50 ft to set the packer at"'50' RKB. 41. Slow RIH speed to 10 fpm. 42. Check reel for valve alignment to drop setting ball. 43. PU coiled tubing as required to line up for inserting setting ball into coiled tubing and record all parameters such as WHP, CT hanging weight, run in hole weight and pick up weight. 44. Insert 5/8" setting ball into reel and pump 2 bbls. Shut down pumps. 45. Start pumping and pump ball over the gooseneck. 46. Stop pump and let ball fall to seat in packer setting tool (see attached). 47. Start pump at .5 bpm and monitor pressure. Stop pumps after coil tubing is full and pressured up to 1,000 psi. 48. Pressure up on CT to 2,000 PSI and stack 2,000 lbs weight down on packer. Continue to pressure up to 4,500 psi in 500 psi increments to set and release from packer. Note:4,000 lbs. of downward force is required to properly set the packer. 49. Pressure up on annulus of CT to 500 psi to test packer sealing integrity. 50. Bleed pressure off CT annulus and pick up and POOH with setting tool assembly. 51. POOH Slick line: 52. Conduct pre-job safety meeting (PJSM). 53. RIH with cat standing valve and set in the top of the packer assembly. With the down hole pump, bull head produced water in the hole until it is full. Set the test tool inside the top of the lower packer assembly. Pressure test the production tubing to 1000 psi for 30 minutes, chart record test for future reference and place a copy in the well file. Pull the test tool and POOH. 54. RDMO and put well back on production. Packer Setting Tools OD ID LENGTH A C.T. Connector w/1%" CS Pin 2.060 1.250 1.00 B Dual Flapper Valve w/11/4" CS Box x Pin 2.130 1.050 1.00 C Sealed Tubing Swivel w/11/4" CS Box x Pin 2.130 1.100 1.00 D Hydraulic Disconnect w/1% • I Blind/Shear I Blind/Shear 41(16"BOP I Slip I I I Blind/Shear 4-1/16.BOP I Pipe/slip 1 C 1 004004 ROW MISS 111111111, WV AIL MV CHOKE LINE/KILL LINE 4111. C4 TO RETURN TANK KILL LINE(Secondary) H -, Tbg head ►.'►./ KILL LINE moimmemImmem -, Casingtehead `CJ"lJi adapr IIIMprep -® a- b. TIW valve will be on location to stab into coil connector if necessary. c. The blow out plug will be pressure tested with 1000 psi differential pressure before including it as a barrier in the installation process. d. **If gas is seen to surface when cutting coil, contingencies include shearing coil at the BOP, isolating the well and allowing the string to go downhole.** Olga'onik " Compaany:ny: Jay ocoOPuhfelips Alaska WellRig : T BRU 232-23 Well Type Oilfield Services Contact#: Field: Date: 3/25/2015 LLCLocation: Prepared By: Patrick Grant Contact: 394-4557 OD ID Length Equip BHA Description Connection Fish Neck (in) (in). (ft) Supplier 11 4-1/2"15.1#Paragon II Packer 3.660" 2.00" TTS Acme 4.43' 3.660"OD x 2.00"ID SealI Pac11 11111111111 011111111111 V4.,/ -,,, I . I � Cross Over 2.875" 1.995" 2-3/8"CS x TTS Acme .33' Sealed Tubing Swivel 3.063" 1.995" 2-3/8"CS Box x Pin 1.00' 4 !, 11 I ;.; I 2.00"Coiled Tubing Connector 2.875" 1.995" 2-3/8"CS Pin 1.31' I' - t e' 2"Coiled Tubing 2.00" N/A N/A TBD Special Blow out Plug,Seating Nipple, 2.875" 1.995" N/A 2.10 and CT Connector(1,800 psi)w/ Pump Out Plug 't Max O.D. & Min.I . = 0 0 Total BHA Length: Please note that all OD's&ID's are approximate,and are given as guidance only BHA w/o Coil 9.17 TRADE SECRET AND CONFIDENTIAL All Shear Screw values are+/-15% • BRU 232-23 Grassroots Well ConocoPhillips Planned Completion Schematic Conductor I5LGR Ali 20•,.75"dact API 5L GRB,Full Grvtl,ft3 Driven to Refusal 91'Below Pad Grade 11/16/2009 Chemical infection onr with 3/8'55 control line ---D Surface Cast=; 01-500 MD ; 9-5/8",408,L-80,BTC Set @ 3742 MD $P61 SCSSSV with%55 control inn to surfacese. Production Casino- (d 01-559'MD.Isolation Sleeve Installed �]i . 7',26.004,L-80,BTC-Mod aa� Set @ 7577 MD Tubincr 4-1/2•,12.6#,L-80,IBT-M RA TAG in 7"CSG nc 4416,3'MD 119.9'0000 ioint I a--'/,Cameo KGB-2 GLM w/1"DMY Cd 4464'MD 8 4-'4 X Steele el 3.813"ID Cd 4600'MDill nti•il SC-2 Packer 014585.71 ft MD/MZ system) -. 3.25"ID Seal Bore @ 4599.73 MD I=1 KOIV @ 4606.78'MD 10.54'Bakenneld Vent Screen @ 4614.56'MD 3.25'ID Seal Bore @4625.68 MD i=1 SC-1 L Isolation Pecker®4627.87 ft MD(MZ av6MIDJ 3 25'ID Seal Bore @ 4631.35'MD ftmil 3.25•ID Seal Bore @ 4641.23'MD In Pert Top Perf Base Perf Top Pert Base h Zone RDT Press 3.25"ID Seal Bore @ 4648.74'MDft MD ft.MD ft ND ft.ND ft MD ft ND PSI PPG ---4 fir- 4734 4747 3821.9 3834.5 13 9 D Tight - 4780 4793 3866 7 3879.4 13 8 D 1309.4 6 6 f"- Excluder Screen @ 4716.84-5032.68'MD " -"1. 4876 4905 3960 7 3989.3 29 12 D Tight - 1..,- 4970 4981 4053 4 4064.3 11 4 E 1041.55 5.0 3 25 ID Seal Bore @ 5032.68'MD ( . H. - 5015 5023 4098 0 4105.9 8 4 E Tight - SC-1 L notation Packer&5034.86 ft MD(MZ aystapal 3.25'ID Seal Bore @ 5038.34'MD mim3.25-ID Seal Bore @ 5048.21'MD Pert Top Perf Base Pert Top Pert Base It Zone ROT Press 3.25-ID Seal Bore @ 5055.71'MD r ft MD ft MD ft TVD ft IVO ft.MD It TVD PSI PPG ir:--- 5100 5110 4182 4 4192 4 10 4 E Tight - 5152 5159 4234 2 4241 2 7 3 E No Data - Excluder Screen @ 5083.44-5458.17'MD :----i, Irl 5176 5191 4258.2 4273.1 15 7 E Tight - 5354 5366 4436 0 4448 0 12 4 F 1462.5 6.4 ('._"_ 5377 5387 4459 0 4469 0 10 5 F 1671 35 7 2 - 5436 5448 4517 9 4529.9 12 8 F 895 3.8 3.25'ID Seal Bore @ 5458.17'MD SC-1L Isolation Packer ti2 5460.35 ft MD(MZ system) 3.25"ID Seal Bore @ 5463.83'MD MN 3.25"ID Seal Bore @ 5473.71'MD 3.25•ID Seal Bore @ 5481.20'MD ® Peri Top Perf Base Pert Top Pert Base It Zone ROT Press - ft-MD ft.MD tl ND ft ND ft.MD ft TVD PSI PPG .t--.4- a - 5629 5642 4710.9 4723 9 13 7 F 1807.87 7 4 Extruder Screen @5607.49-5923.12 MD - - 5689 5733 4770 9 4814 9 44 28 F 794 3 2 -=i- �a 5888 5914 4969 8 4995 8 26 23 G 1800 7 0 • l 3.25"ID R-Nipple @ 5923.12'MD SC-2 Pecker(Isolation Strinol 05025.14'MD II' 7-7/6 Hvdrill 511 L-80 fi.4#/6 Isolation String \RA TAG in 7"COG(5 5788 61'MD 119.79'short joint I SC-2 Packer(d 5950.20'MD ICK System) SOSJ @ 5987.71'MD Ped Top Pert Base Ped Top Pert Base It Zone RDT Press Frac r ft.MD ft MD ft TVD ft.TVD ft.MD ft TVD PSI PPG lbs SLCMU w/2.313 B5 Profile @ 6124.45'MD 3*-' - 6098 6118 5179 8 5199 8 20 13 H 1727 05 - Seal Bore Receptacle(d 6134.89'MD Excluder Screen @ 6137.62-6216.49'MD k.-...k 6139 6166 5220 B 5247 5 27 14 H 2437.3 9.0 SLCMU w/2.313 BX Profile @ 6218.30'MD �.. - 6180 6194 5261.8 5275 8 14 10 H 2171.54 8.0 103'289 Seal Bore Receptacle 0 6228.31'MD n I Bakerweld Screen @ 6231.056241.58'MD Eodr,der Screen @ 6241.5843657.IT MD ,M - 6388 6398 5469.7 5479 7 10 5 H 2071.85 7.3 - • - - 6466 6477 5547 7 5558 7 11 6 H 250305 8.7 ` I - 6486 6514 5567.7 5595.7 28 23 H 2520 8.7 102,478 SLCMU 3 BX Profile @ 6560.63'MD 'I Seall Bore Bore Receptacle @ 6568.89'MD • II Excluder Screen @ 6571.61-6650.33'MD Bakerweld Screen @ 6650 33'-6660.86'MD6576 6609 I 5657.7 5690 7 I 33 26 ( H ( 2740 9.4 (25.086 SLCMU wl 2.313 BX Prefile @ 6662.46'MD Beal Bore Receotaele PP 6072.58'MD 1 i Excluder Screen @ 6675.3-6714.78'MD ' •' _ 6683 6709 ( 5764 7 57906 ( 26 18 ( H ( 2798 94 (84,272 SLCMU w!2.313 BX Profile @ 6717.65'MD I1 Bakerweld Screen @ 6726.49-6737.04'MD - \Rik TAG In 7"CSG(d 6631.22'MD 119 78'short ioint I Model FS Sumo Packer®6738 00'MD(CK System) ila Cast Iron Bridge Plug @ 6875'MD r C Short Joints @ 7020.22 MD(9.68 long SJ) Float Shoe @ 7574.38'MD lin T CSG1 7356.90 MD(9.82 long SJ) , Float Collar CO 7490.87 MD • O I U m Ai i � 000 O ,ia o _ ,20 0.0 SN U' W is a d o • II. I g n -I 2if; ?a 4 - . % ''il t'Lg POI 11 iiii ` J iiia \ N \ / M U �\ m, ry N ithhd .0-:"I P _ 11'`‘ i Irco4 m w�a 410 " 8� 8 'ia� a . , O o <Z t a 5 o LL a Al 11 6 1 iN - iko411. i oN.. IIMM � !rC. \410 hl c� = �I ;� ii'iill', pf4 II b If, =i S V m O I U m 1 — Tenaris Shipping WELD LOCATION RECORD Shipping Spool SPOOL TYPE Metal //f/Z74/ /%SOL 150-95-80 :: :: 7485 / //der STRING NUMBER 35994 Weight Meters Feet Gauge Strip Number GRADE HS-90-C BHISG 6,424 780.29 2560 .125 P324446-1 7,001 850.39 2790 .125 P324446-2 SIZE 2.00 6,863 833.63 2735 .125 / P324446-7 SALES ORDER NO 36008464 6,863 833.63 2735 .125 / P324446-8 3,011 365.76 1200 .125 / P324450 1A DATE COMPLETED 12-18-2014 SHIPPED TO Baker Hughes,Alaska P.O. NUMBER 4507555359 TOTAL FOOTAGE 12,020 TOTAL METERS 3,663.70 EST TUBING WT 30,162 EST SPOOL WT 6,700 EST CWR WT EST TOTAL WT 36,862 FITTING LOCATION Outside Wrap FITTING TYPE 2"1502 Wing Half FITTING I.D. NO. 50508,50220,50536 COMMENTS: / Indicates CM(Continuously Milled)type weld Prepared By KW FOR06467/1 Effective Date;3.22.2012 0 A. o BOO L....,ip � ° c, E. U N a L M Q Z E t \ O 'a N Z 4 U N N id, to CIN Q• a, o bi cl (NI F+k 0.. ¢ Q c c CSS °o M ami �i o "' C I o c Z*" v t� .4 .o .cb 6 v, _ CD a iat CO N N w a.N H o 0 U Hrip 0 <,) O o o M M ,. .O N C`1 O v a Q ¢ a ,. , f zl o c L • 'Kr wUXz � � -§- .13 66 o -1 (q .� Q' 00 � U N � U WO ¢ r5 1 C o o Lc) o N a 1O M C,1 a Q wI o O cr. h o c o Z a o vn Q; Z Wil ' Q o V N A � � 110 H N 'C C C U co N C/) w o C H fs] +I o c U1 E.-1 6, 8 H O .0 � � ►� sx _ o 0 r, r" t 1 H rn N ul U� o N UI N N O0 I H P, Gla N s-., A cd C/� o O tu Q E'""i C) d Ol i g Ua> x U Us ti WN H fil PCIM M (S.{ O LU ami ., w w c c v U x 4 2 ° 2 d <t o U H 4.7 1: O H •b , o O E-, c3 "'� vs �� Pe ;U ca °J d o o cn H , o a� O E ',1f o t ai p W o Ca °n " 00.1 0 E.* cm( V M o c s �• ;OpW N � I • °'" w o C/a H o o o c Io c g e' o o H Q Q C CI Uo o Emilc:: oO n ' • WU aao oCI L- 1-'/ Ll \ 73 Cl •61.Cr, rn vmro UI � oc � tl b IO Gt cd., vx o D •-• w8 B ki 6 o E- IL P.( O N m U U y▪ n1 e rn Q Q Q § r W 0 \'1- N 6 V U V E d z o ort.) o - a"i m chi • ri P; C%) E" 0 r� S `O c A W 0 o fi `� ° 1141) x dZ oo • , Q :72CO o !Y1 U oci, co Low ), �r a) � � fo o ff w Z � U t, < o <r • Gr. • Q +U+ 4 a' ,, M cn • U O 1" I 7. P• . 2 as v � � w 6k.LA. Z3-1"-- 23 STATE OF ALASKA 2 o ti — 0 ci ALASKA OIL AND GAS CONSERVATION COMMISSION NOTICE OF APPLICATION DEFICIENCY The attached application is being returned due to the deficiency or deficiencies listed below. Please submit a new application and all required supporting information. _insufficient information to confirm that the casing and cementing program will protect freshwater aquifers _insufficient information to demonstrate that the proposed perforations will be in compliance with applicable spacing provisions _insufficient information to demonstrate that adequate barriers to flow will be maintained _failure to calculate(or to calculate accurately)anticipated pressures _insufficient information to confirm quality of cement and TOC, relative to proposed perforations insufficient or contradictory well location information or coordinates _insufficient ,�orl contradictory geologic prognosis information ther (Vb Fitz) z) 4 .s 7 sr yr ado other /_ -r'�,es � �"'� ��4sPAt5p c other other same 1v1Av 2 9 21)1F, 1Z-t STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMk ,ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well rRe-enter Susp Well r Other: Install velocity string s-• 2.Operator Name: 4.Current Well Class: 5.Permit t Drill Number: ConocoPhillips Alaska, Inc. ' Exploratory r Development r, 20 57 • 3.Address: Stratigraphic r Service r 6.A Number: P.O. Box 100360,Anchorage,Alaska 99510 50-283-20133-00 • 7.If perforating, 8.Well Name and N ber: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception', Yes r No F.7 BRU 232-23/ 9.Property Designation(Lease Number): 10.Field/Pool(s): / ?Kb ADL 21128• Beluga River Field/Beluga Gas Pool 4y �qt (ic 11. PRESENT WELL CONDITION SU , ARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft): Plugs ' easured): Junk(measured): 7587 • 6668 • 6875' • 5956' 6124,6875 none _Casing Length Size MD pp Burst Collapse Conductor 89' 20" 107.5' ('0'.5' Surface 3720' 9.625" 3743' 12953' RECE 1 O EL) Production 7557' 7" 75 1).1) 6658' C ' Lr MAY 21 2(15 A0 GCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): from 4734'-6706' . 3822'-5788' le. 4.5 C-75 4597 Packers and SSSV Type: P: •rs ,•.V MD(ft)and TVD(ft) 8 packers from 4586'to 6738'MDI �- v NIPPLE-CAMCO chemical injection nipple \ D=446','Vr+=445• 12.Attachments: Description Surrrnary of Proposal v. 13. ‘, ell . :ss after proposed work: Detailed Operations Program r BOP Sk: L '' '' -t'ry r Stratigraphic r Development r• Service r 14.Estimated Date for Commencing Operations. 15.(,\ell Status after proposed work: 6/3/21 1 L r VVINJ r WDSPL r Suspended r 16.Verbal Approval: Dat: GAS WAG T GSTOR r SPLUG r Commission Representative: V � GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and cor'-ct to the best of my knowledge. Contact: Mike Hazen @ 265-1032 Email. Jay.0 Maquire@conocophillips com Printed Name if?" Maguire Title: Wells Engineer Signature f,� Phone:263-4551 Date T/? )/1 5 Commission Use Only , Sundry Number Conditions of approval: Notify Com fission so that a representative may witness .- (i -3 t I Plug Integrity r BOP Te•t r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Re. ired? Yes ❑ No I►CJ Subsequent Form Required: /0 - LI Q APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Approved application is valid tor 12 mon h trom the date of approval. submit Form and Form 10-403 Revised 5/2015 ORIGINAL ,pgas/,i�sAttachments in Duplicate ,��r/ '' RBDM� MAY 2 9 2015 rSAK _ BRU 232-23 • Con0CoP li lips Well Attributes Max Angle 8 MD ,TD •I Wellbore APWWI Field Name Well Status Incl(') MD(ftKB) Act Bun MKS) AlaSka. 502832013300 BELUGA RIVER UNIT PROD 52.61 2,349.30 7,587.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date "' SSSV:WRDP Last WO: 10/7/2009 Well Cordip'DEVIATED.BRU 232-23.2/18/2013 1116'.28 AM Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod By End Date ' Last Tag: 6/3/2012 Rev Reason:SHOW GRAVEL PACK FRACS osborl 2/14/2013 • HANGER,11 itr-- ------ o • Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth)TVD)...String Wt...String... String Top Thrd al coNoucz a,� CONDUCTOR 20 19.124 23.0 84.0 84.0 154.00 X65 Bolted Casing Description String 0... String ID...Top(RKB) Set Depth(L.Set Depth(ND)...String WE..String...String Top Thrd SURFACE 95/8 8.835 22.8 3,742.6 2,952.7 40.00 L-80 BTC-. .d NIPPLE'801 Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String... String T •Thrtl NIPPLE PROP.w� PRODUCTION 7 6.276 19.0 7,576.5 6,657.9 26.00 L-80 ;.TC illiiii - Tubing Strings ` Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String... -.ring Top Thrd SURFACE na.T.3 • TUBING 41/2 3.958 17.3 4,597.1 3,690.3 12.60 C-7 IBTM GAS LIFT.4449 Completion Details NIPPLE'44500 -_ p LOCATOR 4.554 Top Depth PEE 4.556 (TVD) Top Incl Nomi... ANCHOR SEAL . Top(RKB) (RKB) (•) Rem Description Comment ID(in) PACKERSEAL ASE.45585 - 1 ,r 17.3 17.3 -0.01 HANGER Vetco Gray Tubing hanger 4588 4.500 EXTENSION SUB \\ see 4.5900 - _ t 445.5 445.4 3.12 NIPPLE Camco CHEMICAL INJECTION NIPPLE with,8"C.L. 3.920 VALE:a6044� -.. 497.1 496.9 421 NIPPLE Camco 3.813"BP-6i Landing Nipple 3.813 VA1VE,46m EITE"sEe1wn 4,501.8 3,600.5 20.79 NIPPLE 3.813"HES X Nipple 3.8134. 1, SCREEN,4.615 360..636 L_. _c 4,553.7 3,649.5 19.57 LOCATOR Baker Locator Seal Assembly w/2"race out 3.900 ISO PACI(ER 536 . SSE 4.631 - - 4,556.5' 3,652.1 19.49 PER Baker 4 3/4"PER 3.900 • • EXTENSION,'I= -_ - 4,584.5 3,678.4 18.63 ANCHOR 'E-Anchor Seal Assembly '3.250 SBE 4.540 SEAL PERE 4.130.A741 A gr. 4,585.7 9 EAL ASSY 'Baker S-22 Seal Assemb with Half hoe '3.250 4717 _-- •..�., Tubing MULTI-ZONE 9.6 Ste'g/080 3.430ID...Top 4 585.8 • Set Depth( .Set Det(ND)..SString WL..String...String Top Thrd !ERF.4760-4.793 5 SUED( ` PEEP,46]64,905 PERK A9704.981 PERF. 15E023 GRAVEL PACK SEE 5.033-, ISO PACKER 505 '. _._._ ASSEMBLY SBE 5.039 EXTENSSIION,5 - Completion Details 5 OM IF FRAC PORT.5.044 I ' Top Depth WE 5,019 EXTENSION,5,051 _ = (TVD) Top Incl Nomi... Top MKS)) (RKB) )°) Item Description Comment ID(in) PERF 5.100.5,110 -_ T' 4,585.8 3,679.6 18.59 PACKER SC-2 P.cker 70B-40 4.000 !PERF 6.145,1594,599.8 3,692.9 18.16 SBE Sea =ore 80-32 3.250 Irene.5,1)63,191___ ••♦• SCREEN,5083_- , 4,604.3 3,697.2 18.02 VALVE Kr.cA out Isolation Valve C-2 Sleeve 3.320 PERF, SCREEN. PERF,5.32)5,36] 41 IPERF.Seaseeml_ ,,♦♦ 4,606.8 3,699.6 17.95 VALVE nock out Isolation valve C-2 3.340 ISO PACKE468 R 5.460 -- SBE5484� 4,614.6 3,707.0 17.71 SCREEN Vent Screen Bakerweld 3.930 EXTENSION,5.66~'- -��, FRAC P517.1:2-',ORT.s.420� - 4,625.7 3,717.6 17.37 SBE Seal Bore MZ system 80-32 3.250 FRAC.5.420- - - .-T.-• , SEE 5E4 4 _ 4,627.9 3,719.7 17.30 ISO PA R SC-1L ISOLATION Packer 7086-40 3.625 EXTENSION.5426 0005,.01 4,631.4 3,723.1 17.19 SBE Seal Bore MZ system 80-32 3.250 •!PERE 5460-DLO/ 1011011i• 4,633.5 3,725.1 17.13EX 'SION Upper Extension MZ system 80-32 3.970 • !PERF 5.6WNa se 50 s.We -�♦� 4,637.3 3,728.7 17.01 F-r•C PORT Frac Extension MZ system 80-32 4.010 !PERF 58865,914 NIPPLE 5,923 s,NaPNs.5924 6..a I,4 4,641.3 3,732.5 16.89•BE Seal Bore MZ system 80-32 3.250 SEAL MGR PASHOE.5933 11.77' 4,643.7 3,734.8 16. EXTENSION Lower Extension MZ system 80-32 3.980 EXTENSION.5929� sPeq .s, � - 4,648.8 3,739.7 1•••SBE Seal Bore MZ system 80-32 3.250 PACKER,69E0 = 4,716.9 3,805.3 4.01 SCREEN Screen Excluder 2000 3.430 EXTENSION.6E91 SEE,s95s52� 5,032.7 4,115.6 6.72 SBE Seal Bore MZ system 80-32 3.250 5,034.9 4,117. 6.68 ISO PACKER SC-1L Packer 7066.40 3.625 VALVE N94-_ 5,038.4 4,12 2 6.61 SBE Seal Bore MZ system 80-32 3.250 • VALVE 5.954 5,040.5 4, '3.2 6.57 EXTENSION Upper Extension MZ system 80-32 3.970 _ SOS 5.969 i 1 SCREEN.6U63-, 5,044.3 ' 27.0 6.50 FRAC PORT Frac Extension MZ system 8032 4.010 !PERE.6.093E115 -- SL C:e;Np = 5,048.3 4,131.0 6.42 SBE Seal Bore MZ system 80-32 3.250 ,1112:e: 4- Q, 'y M SEAL ASSY.5.125 a 5,050.7* 4,133.3 6.37 EXTENSION Lower Extension MZ system 80-32 3.980 SEAL,61301 SBR,8.135 - 5,05.: 4,138.4 627 SBE Seal Bore MZ system 80-32 3.250 ' IPERE,8.1E6.166 , 5,1:4.5 4,166.0 5.72 SCREEN Screen Excluder 2000 --- 3.430 (PERF 8.144E164� • SCREEN,6,36E_ ' ' 5 58.2 4,540.1 1.92 SBE Seal Bore MZ system 80-32 3250 :ERF6,160b.194 , ' y (PERF.6.ikiE.i93� . h. ,,460.4 4,542.3 1.93 ISO PACKER SC-1L Packer 7086-40 3.625 SLEEVE,5218M * 5,463.9 4,545.8 3.12 SBE Seal Bore MZ system 80-32 3.250 SEE ASSY,63n 'ER': 5,465.9 4,547.9 3.07 EXTENSION Upper Extension MZ system 80-32 3.970 1 SBR.,fi,ne .--- SCREEN 5231 5,469.7 4,551.7 2.99 FRAC PORT Frac Extension MZ system 80-32 4.010 IPEP,63696Ir-'-- \ sE£EN 62n - • ' 5,473.7 4,555.7 2.90 SEE Seal Bore MZ system 80-32 3.250 PEFP,assa.m - 1 IPERF,6,4868,514 , , 5,476.1 4,558.1 2.84 EXTENSION Lower Extension MZ system 80.32 3.980 ERE.6.492-6,512 11. k 5,481.2 4,5632 2.73 SBE Seat Bore MZ system 80.32 3.250 SLEEVE, 561 6 SE0ossra � 5,607.5 4,689.4 0.61 SCREEN Screen Excluder 2000 3.430 SEIR.6, -_ 5,923.1 5,004.9 1.05,NIPPLE R Nipple 3.250 6 • PERF.6s26d.W9L_ i 5,924.1 5,006.0 1.05•Snaplatch Snaplatch 3.270 !PEP,65915,8W I SCREEN,6521 - NM/' ' 5,925.1 5,006.9 1.05'SEAL Seal Units 3.260 OWEEN,8650 5,933.1' 5,014.9 1.05 SHOE Half Mule shoe 52-00 3.260 - SLEEVE.5,562 Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt..string...String Top Thrd TUBING,6600 sEU Assr.s.6ss---. - CK LOWER 2.89 2.370 5,925.1 6,746.8 5,828.4 6.40 L-80 2-7/8 Hyd 511 SEAL 6B80-, :i.-- ,,; ISOLATION STRING ER.6.6]3 - SCREEN.6875 Details EPS,8,6616.r _ Completion ' PERE,6,6966.203w - 1 Top Depth SLEEVE,4718 t t (TVD) Top Incl Nomi... • soKsra6n3 IPi ToPIRKB1 RKa) Description(•) Rem Comment ID('ie) ' S,Ket6623 5,925.1 5,006.9 1.05 PACKER SC-2 Isolation Packer 708-40 ' 4.000 BOT Sums Pa , \ 6.238 am i SEAL 6.236 SEAL 6215 NLEG 8.242 >.-. Mandrel Details Bottom SE ,• S.S 5.6 r• y Top Depth Top Port OE.6.144 SH5 - LLr• 5.,. (TVD) Incl OD Valve Latch Site TRO Run SHOE 5141 - N...Top(ftKB) (RKB) 1°) Make Model (k) Sore Type Type (in) (Psi) Run Date Com... PLUG.535- - 1 4,448.6 3,551.1 22.36 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 9/20/2009 PRODUCTION -- L--L 19-25],807 7042 ]-\. ..119,- Ai SAK BRU 232-23 • • ConocoPhillips 4$ Alaska,Inc. i.on..-iT,ll:pc I' ' KB-Grd(ft) Rig Release Date "' 10/7/2009 Well Confar DEVIATED-BRU 232-23,2/1812013 11:16:28 AM - Schematic-Actual HANGER" Completion Details Top Depth CONDucT3oR1A I (ND) Top Incl Nomi... z Top(ftKB) (1tKB) (°) Item Description Comment ID(In) 5,929.4 5,011.2 1.05 EXTENSION Millout Ext.Pin x Pin 4.650 NIPPLE,445 NIPPLE.497 5,948.8 5,030.7 1.04 Snaplatch Snaplatch 3.260 "RDP'°s] 5,950.2 5,032.0 1.04 SEAL Seal Units 901-I Stub 3.260 5,956.8 5,038.6 1.03 SEAL Seal Units 3.260 SURFACE 2e526 - 6,124.4 5,206.2 1.41 SLEEVE-C SLCMU BX Profile 2.313 cAS LPT.416 6,128.4 5,210.1 1.40 SEAL ASSY Locator Seal Assembly 2.420 NIPPLE 4,562 LOCATOR.4554 ' PeR.4.556 6,129.7 5,211.5 1.40 SEAL Seal Units 2.400 ANCHOR SEK 56 6,218.3 5,300.0 1.35 SLEEVE SLCMU BX Profile 2.313 PACKER.4.500 EVI:g1 4586 - EXrensloil sue 6,222.2 5,304.0 1.35 SEAL ASSY Locator Seal Assembly 2.420 4.590 SBE 4.600 - 6,223.6 5,305.3 1.35 SEAL Seal Units 2.400 sub,:243 VAWE460]� 6,560.6 5,642.3 1.26 SLEEVE SLCMU BX Profile 2.313 IXTENSIg4 Aare 7'�+•"� scgeEN.4.66�115 - Si", :.it 6,564.5 5,646.2 1.36 SEAL ASSY Locator Seal Assembly 2.420 SBE ISO PACKER 4.6 - , 6,565.9 5,647.6 1.36 SEAL Seal Units 2.400 SBE 4.31 FRAC 4. B ■ 6,662.4 5,744.1 1.38 SLEEVE SLCMU BX Profile 2.313 SSE 4,641 _ - IXTEN6ION 4,664 SBE 4.649 - .i► 6,666.4 5,748.0 1.38 SEAL ASSY Locator Seal Assembly 2.420 6,667.7 5,749.4 1.38 SEAL Seal Units 2.400 P ERP'47344.]47 - , .♦. 6,717.6 5,799.2 1.50 SLEEVE SLCMU BX Profile 2.313 PEF.4]061.793�_ s4m4.4.n7 PERF..1.9184.995 --- .•A .' PERF,1,9164.981 6,733.3 5,814.9 1.47 SEAL ASSY Locator Seal A _,.y 2.420 PERF.50155.0.� SBE 5.023 6,734.6 5,816.3 1.47 SEAL Seal Units 2.400 ISO PACKER 5.035 _ ._ SBE 5.091--..26,745.9 5,827.5 1.46 SHOE Half Mule Sh.. 2.440 IXTEN�AC,5.1 1 FRAC PORTA. :Tubing Strings SBE 5,646E ' EXTENSION,5051 Tubing Description String 0... String ID...Top(ftKB(, Set Depth(1...Set Depth(ND)... String Wt...String...String Top Thrd 5'�6 •-- I LOWER ZONE CK 5 3/4 3.430 5,950.7 6,746.1 5,827.8 13.50 • Ce ..5100.6n6 - • ASSEMBLY ,� IPISSF61yS15°- IPE • 1 Completion Details SCREEN.5,191`__ SC5.OB3 TopDe th !PERF 53515366 .♦. p PERF 53]15,381 (TVD) Top Mc! Nomi... IPEPF' seL .. . Top MKS) (RKB) (1 Item Descriptio. Comment 113(In) ISO PACKER.5,1dJ� , 5,950.2 5,032.0 1.04 PACKER SC-2 Packer 70B-40 4.000 SBE 5,461 L FRAC EXTENSION. 6 '- ' 5,953.9 5,035.8 1.04 EXTENSI• Frac Extension 80-40 CK 250 4.800 FRAC;y4m\ 1 IXT4BuSBE s„s _ 5,957.6 5,039.4 1.03 SBR Seal Bore receptacle 80-40 CK 250 4.000 seE5�1 5,981.7 5,063.5 1.01 VALV- Knock Out Isolation Valve C-2 Sleeve 3.340 PERF,5,6.6,642 4 5,984.4 5,066.2 1.01 VA ,E -Knock Out Isolation Valve C-2 3.310 P...5,6.5,733 SCREEN.5.606 �.� 5,987.7 5,069.5 1.02 S,.S Shear out Safety Joint 3.420 PERF.5.7.11.11 NIPPLE 59.� - sl,4dmn.59z1�- �4 6,083.5 5,165.3 1.12°GREEN Screen Excluder 2000 3.430 SE 5.925 • PA«ER,59. 6,123.0 5,204.8 L XO Crossover 3.490 SOE.5831 IXTEN81g459.� a SEAL. 1 6,134.1 5,215.9 .40 XO Crossover 3.490 PACKER,5,950-' 4• 6,134.8 5,216.6 1.40 SBR Seal Bore receptacle 3.250 EXTENSION,5.954� �" sse at5]� - � 6,137.6 5,219.3 1.40 SCREEN Screen Excluder2000 3.430 ' 6,216.3 5,298.1 1.35 X0 Crossover 3.490 VALVE,59e2-- 6,227.4 5,30•.2 1.34 XO Crossover 3.490 VALVE.5066 505,S 5,988 -. - 6,228.1 5, 19.9 1.34 SBR Seal Bore receptacle 3.250 - SCR�N 6951 • 6,230.9 -,312.6 1.34 SCREEN Screen Baker Weld 140 3.430 ERF 6098.n8� t 'SLE p E C 6'z• 6,241.4 5,323.2 1.33 SCREEN Screen Excluder 2000 3.430 61i1� 14 is S NG.fi1284-� f.1-1 Px sI 6,557.1 5,638.7 1.26 XO Crossover 3.470 seR,a,,a 45. 6,56; 5,649.8 1.36 XO Crossover 3.470 PERF,61396,166 T 6, ':.7 5,650.4 1.36 SBR Seal Bore receptacle 3.250 IPERS6.144e,164N.6.1B, 6.71.5 5,653.1 1.36 SCREEN Screen Excluder 2000 3.430 IPERF.6,1008,194�IPERF.6,,838.193 . .,650.3 5,732.0 1,37 SCREEN Screen Baker Weld 140 3.430 SLEEVE. _. 6,660.9 5,742.5 1.38 XO Crossover 3.470 SEAL ASSY,6,222 - sEK.6.221 6,672.0 5,753.6 1.38 XO Crossover 3.470 SBR.5228 - SCREEN,6.231 - .a 6,672.6 5,754.2 1.38 SBR Seal Bore receptacle 3250 PERF6,388823,8�- • ; / 6,675.3 5,756.9 1.38 SCREEN Screen Excluder2000 - 3.430 PERF,6 6-6,472-- P�,66663,4 4 6,714.8 5,796.4 1.50 XO Crossover 3.470 P .6492E,512� 4 / 6,725.9 5,807.6 1.48 XO Crossover 3.470 SLEEVE,6.561 6FALne„�",G g�6 ....••.. 6,726.5 5,808.1 1.48 SCREEN Screen Baker Weld 140 3.430 565-. 4`- -i 1Er46569, � I 6,737.0 5,818.7 1.47 Snaplatch Snap latch 82-40 3.250 SEK.6.566 - PERP.65766.809� ,1�' 6,738.0 5,819.6 1.47 SEAL Seal Units 82.40 3250 PERF,S5916,�fi - srnEEN,6,571 . . 4 6,745.6 5,827.3 1.46 SHOE Half Mule Shoe 82-40 Stub 3.250 -„L Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd ORE..a65z -- : TUBING-Sump 51/2 4.930 6,738.0 6,760.3 5,841.9 uetiv,n S2� _ t.--.1 Packer SEAL sew •6 _ _ • R:6 � _Completion Details scveeN,6675 �' Top Depth sase,]m3v / (TVD) Top Incl Semi... W E P,es667LI6 �G" Top(RKB) (RKB) (°) Rem Description Comment ID(M) SCREEN em°� _.,,1 6,738.0 5,819.6 1.47 BOT Sump BOT Sump Packer 4.000 SEK/SSY.6]33 1.''"-4 Packer L.• 8.238 SPL 8.]30 Bottom 5228,745 �_ - SNOE676-� - ..1.11911• SHOE,6.246 a_ SNOE 6.141 - PLUG.6,025 - PROWCTIIX4 F= = • 4]5]] TD.2.5B] • % SAK BRU 232-23 • ConocoPhillips O & Alaska,Inc. 1 i1 ss� KB-Grd(R) Rig Release Date Well Confiq:DEVIATED-BRU 232-23,2118/2013 11:16 28 AM - 10/7/2009 Schematic-Actual ---_- __ RANGER,17 a Completion Details itTop Depth CCROUCTOR, ' (TVD) Top Incl Nomi... 03a Top(ttKB) MKS) (°) Item Deacriphon Comment ID(In) nlPvtE,445 6,740.0 5,821.6 1.47 WLEG 'WIRELINE ENTRY GUIDE 4.000 NIPPLE 497 M a 6,740.8 5,822.4 1.46 SHOE MULE SHOE 4.930 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth SURFACE.03-3,143 ♦ IND) Top Inc! Top(RKB) (RKB) (°) Description Comment Run Date ID(in) ocSHPT.4.449 - 497.1 496.9 4.22 WRDP WRDP SET IN BP-6i NIPPLE 9/21/2012 NIPPLE,4,550 LCCAOOR.4,564 ANCHOR I �,,. 6,124.4 5,206.2 1.41 PLUG PX PLUG SET IN SLEEVE 9/21/2012 0.000 3fl56,875.0 5,956.6 1.25 PLUG BridgePlug-Permanent 9/9/2009 0.000 PACKER.4..5E6 \\ '�" EXTENSION SIB 4.590 _ Perforations&Slots SBE SUB,46031,-,..r.!. Shot VALVE em]N L Top(ND) Btm(TVD) Dens EXTEALVE,NSION SJR Top(RKB)She MKS) (RKB) (RKB( Zone Date (sh-. Ty - Comment SCREEN,4;66115.15 ` 4,734.0 4,747.0 3,821.9 3,834.5 Sterling A,BRU 9/29/2009 14.0 IP•-F All Shots Fired-Gun OD After Firing SBE 4,6x6 = 232-23 3.25"/Shot Orifice.5" ISO PACKER.4,629 SBE,4,631 FRAC.sen • I'4•"`' • 4,780.0 4,793.0 3,866.7 3,879.4 Beluga D,BRU 9/29/2009 1- i IPERF All Shots Fired-Gun OD After Firing SBE 46'1 232-23 3.25"/Shot Orifice.5" ' EXTENSION.4M 8 SBE AM 4,876.0 4,905.0 3,960.7 3,989.3 Beluga D,BRU 9/29/2009 14.0 IPERF 'All Shots Fired-Gun OD After Firing 232-23 3.25"/Shot Orifice.5" (PERF.4,734-4,]4] P.F.sr4.750-4.793 717 4,970.0 4,981.0 4,053.4 4,064.3 Beluga D,BRU • • 0'9 14.0 IPERF All Shots Fired-Gun OD After Firing IPERF.4976d936 232-23 3.25"/Shot Orifice.5" IPERF.4.970-4.961 PERF'see 5:0 5,015.0 5,023.0 4,098.0 4,105.9 Beluga E,BRU • 9/2009 14.0 IPERF All Shots Fired-Gun OD After Firing Iso PACKER 5.035 232-23 3.25"/Shot Orifice.5" EXTENSION.6040 1 I FRAC PORT.6064 I $' I 5,100.0 5,110.0 4,182.4 4,192.4 Beluga E,BR 9/29/2009 14.0 IPERF All Shots Fired-Gun OD After Firing SSE 5.� 232-23 3.25"/Shot Orifice.5" EXTENSIONSSE.5,051 --.. SK°° -.�. 5,152.0 5,159.0 4,234.2 4,241.2 Beluga E ;RU 9292009 14.0)PERF All Shots Fired-Gun OD After Firing 8ERF,5,105.110 lOr. 232-23 3.25"/Shot Orifice.5" IPERF,61523,158 IPERF,8965,191` .♦.; 5,176.0 5,191.0 4,258.2 4,273.1 Be) - E,BRU 9/29/2009 14.0 IPERF All Shots Fired-Gun OD After Firing swEEN.5,w3 23 23 3.25"/Shot Orifice.5" IPErff,53545,366 -- PERF,5,377-5,387--- ERE.54365,4491_ : ..- 5,354.0 5,366.0 4,436.0 4,448.0',-tuga F,BRU 9/29/2009 14.0 IPERF All Shots Fired-Gun OD After Firing WE ISO PACK 5; _-- ,� 232-23 3.25"/Shot Orifice.5" SBE 5,461 rx mN" a � 5,377.0 5,387.0 4,459.0 4,-.:.0 Beluga F,BRU 9/29/2009 14.0 IPERF Al)Shots Fired-Gun OD After Firing FRAFRAC.5,492 , _ , 232-23 3.25"/Shot Orifice.5" SBE 5<74 ,...- EXTENSION.su 5,436.0 5,448.0 4,517.9 529.9 Beluga F,BRU 9/29/2009 14.0 IPERF All Shots Fired-Gun OD After Firing 232-23 3.25"/Shot Orifice.5" ,`,�;57813� 5,629.0 5,642.0 4,710 4,723.9 Beluga F,BRU 9/29/2009 14.0 IPERF All Shots Fired-Gun OD After Firing SCaEO1.5.808 - - �♦� 232-23 3.25"/Shot Orifice.5" PERK 513894.814 NIPPLE S"4Pa,5;924 - `b_� 5,689.0 5,733.0 4 0.9 4,814.9 Beluga F,BRU 9292009 14.0 IPERF All Shots Fired-Gun OD After Firing SEAL.5033\ -- 232-23 3.25"/Shot Orifice.5" PACKER.SSE EXTENSION 5929 "It::::51 5,888.0 5,914.0 4,969.8 4,995.8 Beluga G,BRU 9/29/2009 14.0 IPERF All Shots Fired-Gun OD After Firing PA saw'S �- •,"�•_ 232-23 3.25"/Shot Orifice.5" EX s ,5854-`. - 6EA1,5957 6,098.0 6,11 .0 5,179.8 5,199.8 Beluga G,BRU 9222009 14.0 IPERF All Shots Fired-Gun OD After Firing saT 5856 232-23 3.25"/Shot Orifice.5" 6,139.0 66.0 5,220.8 5,247.8 Beluga G,BRU 9222009 14.0 IPERF All Shots Fired-Gun OD After Firing 232-23 3.25"/Shot Orifice.5" VALVE 5982 6NLVE'6904 6,144.0 6,164.0 5,225.8 5,245.8 Beluga G,BRU 9/16/2009 6.0 IPERF All Shots Fired-Gun 00 After Firing SOS.SSW 232-23 3. 25"/Shot Orifice.5" SCRE..6.063 SFPERF£v6E°Bc�6112°4� 6,1 .0 6,194.0 5,261.8 5,275.8 Beluga H,BRU 9/22/2009 14.0 IPERF All Shots Fired-Gun OD After Firing Tuer4G:a±zi� i•-' 232-23 3.25"/Shot Orifice.5" SEAL ASSY,5138 sFAL613o-\ _- ,183.0 6,193.0 5,264.8 5,274.8 Beluga H,BRU 9/16/2009 6.0 IPERF Al)Shots Fired-Gun OD After Firing sge 6'1� 'I 232-23 3.25"/Shot Orifice.5" PERF 91.5.1 PERF 6,144-5,166 / 1 6,388.0 6,398.0 5,469.7 5,479.7 Beluga H,BRU 9/22/2009 14.0 IPERF Al)Shots Fired-Gun OD After Firing SCREEN.61301-- 1 ' 232-23 3.25"/Shot Orifice.5" :17:1684,191 IPERF 6,1634.193-� 4- 6,466.0 6,477.0 5,547.7 5,558.7 Beluga H,BRU 9/22/2009 14.0 IPERF All Shots Fired-Gun OD After Firing 232-23 3.25"/Shot Orifice.5" SL6VE,6216 - . SEAL ASSY,8222 6,486.0 6,514.0 5,567.7 5,595.7 Beluga H,BRU 9/22/2009 14.0 IPERF All Shots Fired-Gun OD After Firing V.422e�- ' 232-23 3.25"/Shot Orifice.5" SCEEN.6231 6,492.0 6,512.0 .5,573.7 5,593.7 Beluga H,BRU 9/15/2009 6.0 IPERF All Shots Fired-Gun OD After Firing *Elle':211----- 11 % 9 cruse-Sa 1 - 232-23 3.25"/Shot Orifice.5" PERF.64864.40 PERF,6.4864.514 -, / 6,576.0 6,609.0 5,657.7 5,690.7 Beluga H,BRU 9/22/2009 14.0 IPERF Al)Shots Fired-Gun OD After Firing PERF,6,4924.512- - , , 9 .r 232-23 3.25"/Shot Orifice.5" SLEEVE.6061 SEAL ASSY.s5� 3 6,591.0 6,606.0 5,672.7 5,687.7 Beluga H,BRU 9/142009 6.0 IPERF All Shots Fired-Gun OD After Firing MR 6569 232-23 3.25"/Shot Orifice 5" SEAL 6,565-- PERF,6,5766fiW /�/ 6,683.0 6,709.0 5,764.6 5,790.6 Beluga H,BRU 9/22/2009 14.0 IPERF All Shots Fired-Gun OD After Firing PERF,6.5914606-- / 232-23 3.25"/Shot Orifice.5" SORE..6,571-- 441. / 6,686.0 6,706.0 5,767.6 5,787.6 Beluga H,BRU 9/13/2009 6.0 IPERF All Shots Fired-Gun OD After Firing 232-23 3.25"/Shot Orifice &+ S SEAL (380 Bom fi 662 � Stimulations&Treatments�h .5" Xr* Min Top Max Btm Top Depth pt 10000 66.08-O.ma �1673 Depth Depth (TVD) (TVD) IPERF,6,6064.ID6 0 " (RKB) (RKB) (RKB) (MB) Type Date Comment SLEEVE,6719 t P4 4,637.0 4,641.0 3,728.4 3,7322 FRAC 10/6/2009 FRAC EXTENSION SCREEN,6.727 SEAL AS5V,6733 e, -i 5,044.0 5,048.0 4,126.7 4,130.7 FRAC 10/6/2009 FRAC EXTENSION BOTS P \ _ erg 5,470.0' 5,474.0 4,552.0 4,555.9 FRAC 10/6/2009 FRAC EXTENSION 6.735 SEAL 6339 i. I SEAL 6,735 - ¢ A.G.6740-� BM=Su60032 - 9-126,745 III SHOE 6,7461 i SHOE 6,746- .0E,8,741 PLUG,6,675 ----- - PRCOUCTION t® misi 147.57\ TD,].59'7 • t SAK BRU 232-23 • Conoco`Phillips 01111 Alaska.Inc. CmacOPhallps KB-Grd(11) Rig Release Date --- 10/72009 Well Config DEVIATED-BRU 232-23,2/18/2013 11'16.28 AM Schematic-Actual HANGER. R'" - Notes:General&Safety 1 i I 1 End Date Annotation O OIOR_ 1 11/5/2009 NOTE:View Schematic w/Alaska Schematic9.0 236 NIPPLE.415—___— y �/ NIPPLE.. N.P.497 �. fe SURFACE 233,743 GAS LIFT.1,419 NIPPLE,4,502~.__. LOCATOR.0 SU PBR,4,553 ANp1IX23H1.� 4. .... 0.AL. PACKER,4,588 SEALASSY.156. -__;1-t- –r IXTENSIIXJ590 �7 560 S6E150� I SUB 4,603 VALVE,4,60\ _ VALVE,180] EXTENSION SIB, ' 8m\ SCf SBE,1615 - SBE4,828-- ISO PACKER,1.828 E 4.631-- ■_ 17F SBE 4.641� 49 - EXTENSION 4,6 SSE 4,649— 1 IPPERE.1,7344,747 SCREEN,4.717 IPERF,6910-4,905 • IPERF,1.9]64,981 ./., - FERF. 023—, SSE 5. ♦♦ _: SBE 5.033 ISO PACKER 5035 SBE 5.030 EXTENSION.5,010 FRAC,5049 , , 49 FRAC PORT.5.0 SBE 5.014 L_ IXlENS 5.651 see 5.056 --- (PERE,5,1m5.110--5- . ♦ !FERE.5,15.151-- IPERF.51765,191_._ ♦♦- SE.53545.081— !FERE.8351-5.388 •— IPERT,5,3]]-538]-- ` .. IPERF.51]85,418� ISO PACKER 5480 --- SOS S461 EXTENSION,5,468 PRAOPGRTC.5.470 RU5.4 0 S.5.474 EXTENSION 5,478 BE 5.481 , IPERF,5,8H5.1342 - ' .♦... ERF5 � SCREEN.5.005 - !PERE.5 8085.914 TnNE,593 - ._N_,5,925�4 AR5923� SXOE 5.931 AOkN.5,929 SEAA5.959 PACKER.5950 - I y EXTENSION 5,951 - .1•=11.11- SEAL � SEAL 5,95] S.5,958 VALVE.5982--__ VALVE.59.5085.988 - SCREEN 6063 IPERF.S.09... - 1L SLEEVE-C IL. PLUG.8.124� 7 NBING.8124 SEALASSY.8.136 --- :1110 SEAL,8,130-- SBR.8.135-- PRFB,1Dflt. ,PSCREEN 0,138L PERF8,183-6,194 -' IPERF,8.183-0,193 SLEEVE,6214— ;Et' SEAL ASSY,6,222-- SEAL,6./24--„,,,. SER.6.220 *moi SCREEN 6.01 - _'$ SCREEN 8.211 6.348-E -. - PERE 6,01341.477 4 4 PERE 448%.511 PERE 6.4975.512 •••11 /_ SEF/E,8,383 TUBING,8,55. SEAL ASSY.8.585 SBR,8,869 SEAL,8,586 IPERF,B.57.509 06 r' IPERF 13,591$6 --- SCREEN 8.571 � I GREEN,8650 SLEEVE UBING.5562 -" 1 SEAL ASST.SSW -- - SEAL 6.673 SBR.6.8]3 TAW SCREEN.8875 PERE.B.5.5.709 . 7005 ,M,` ', SLEEVE,8.714 ,t-I SCREEN 5)2] SEAL ASSY,6733 BOT Sump P. y�� 8,73. S.L.8]38 e_=..-i ' S.L.5735 - Bottom Sub88.290� 5-228705�__ 9.La : 6,746-6— SHOE.5,741 - SHOE 5,741 PLUG,6.875 _ PROOU.ON. = CX 1&7,5]] ro.LS4] ` ...m........ 232-23 The objective of this procedure is to utilize coiled tubing to hang off a velocity stri on a packer from 50' RKB to 5900' RKB. Hanging the plug will the plug will give us production inc ase from .5 MMscfd to an expected rate of 1MMscfd.An outline of the work is listed below: 232-23 1. Rig up slickline 2. Pull WRDP insert from @ 497' KB. 7 3. RU SL, drift well with 3.1"OD swedge deep to 6,000' RKB. / 4. Drift to 100' RKB with 3.7" OD swedge. 5. Set a plug in the CAMCO nipple @ 497' KB to used to pressure test all the tree connections/valves. / 6. Pressure test tree valve and connections. 7. Pull plug @ 497' KB. 8. Rig up CTU 7 r- GT- 600 JcL pc- 9. Run coil string down to 5900' (right above our to est perfs in the upper completion) 10. Cut coil and set up packer for CTU hangoff at 5 ' RKB. 11. RIH with coil and set packer at 50' RKB. 12. Bring well online producing up the coil stri 23 - 7 The obj_ tive of this procedure is to util z: coiled tubing to hang off a velocity strin• - . packer from 3900' RKB • 5200' RKB. Hanging the p : will the plug will give us produ increase from 3.9 MMscfd to an - pected rate of 4.4 M cfd. An outline of the w• isted below: 233-27 1. Rig up slickline 2. R . '- i 'Nr•�wedge deep to 5,200 R 3. Rig up CTU , 4. Run coil strin: •. n t• 5200' 5. Cut coil . • set up p.,'ker for TU - goff @ 3900' KB. 6. RI , ith coil and se packer • 3900' K:. 7. :ring well back on!' e produci ig through th- oil string. 1 • 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. QD 9- 06 - 7 Well History File Identifier Organizing (done) ❑ Two -sided 111 I11111 ❑ Rescan Needed 111 I 111111 R9SCAN DIGITAL DATA OVERSIZED (Scannable) AI Color Items: ❑ Diskettes, No. ❑ Maps: ❑ Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: 5 i /ill /s/ Project Proofing IUhIIJIIJIIIIIIIII ImP BY: Maria Dater i i I / /s, IT P Scanning Preparation x 30 = 1 13 + = TOTAL PAGES aO c. (Count does not include cover sheet) ill BY: Maria Date: 6// 11 /s/ Production Scanning 111111 1111111111 Stage 1 Page Count from Scanned File: a03 (Count does include cover heet) Pa•e Count Matches Number in Scann'ng Pr paration: include NO BY: Dater 1 I i i /s/ V1/1 4 ( 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. 111 llhlIJIIIII 11 111 ReScanned 111 II1I11I 11 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked I 10/6/2005 Well History File Cover Page.doc • • C onocoPhill ips Transmittal #1022 Detail Date: 5/2/2011 To (External Party): From (PAI Contact): Email: howard.okland @alaska.gov Email: richard .e.elgarico @conocophillips.com First Name: Howard First Name: Ricky Last Name: Okland Last Name: Elgarico Phone Number: (907) 793 -1235 Phone Number: (907) 265 -6580 Company: AOGCC Company: CPAI Address: 333 W. 7th Ave., Ste. 100 Address: 700 G St. ATO -1484 City: Anchorage City: Anchorage State: AK State: AK Zip Code: 99501 Zip Code: 99501 Transmittal Info: Sent Via: email Tracking #: Justification: Compliance Request. Data transmittal approved by R, Levinson Data Detail: Quantity Description Type 1 BRU 232 -23 Core Analysis Data Excel Attachments: Filename: None Filesize: N/A Received By: Signature: ♦,/ / / . _ _ i Date:Agl Approver: Signature: Date: ? 9 -- © S-7 DATA SUBMITTAL COMPLIANCE REPORT 4/27/2011 Permit to Drill 2090570 Well Name /No. BELUGA RIV UNIT 232 -23 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 283 - 20133 -00 -00 MD 7587 TVD 6668 Completion Date 10/7/2009 Completion Status 1 -GAS Current Status 1 -GAS UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: Dipole Sonic, GR / CCL, GR / RES / DEN / POROSITY / MRIL / SBL / (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr • Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments t/ LI Verification 159 7588 Open 10/1/2009 LIS Veri for 18716 "' ^ ED C Lis 1871 Induction /Resistivity 159 7588 Open 10/1/2009 LIS Veri, RPS, RPM, RPX, RPD, FET, GR< ROP, NCNT, NPHI, RHOB, FCNT, DRHO, PEF (Log Induction /Resistivity 25 Col 216 7587 Open 10/1/2009 MD DGR, EWR, ALD, CTN og Induction /Resistivity 25 Col 216 6668 Open 10/1/2009 TVD DGR, EWR, ALD, CTN " pt Report: Final Well R 0 0 Open 10/16/2009 Final Well Report, Tab of Cont, Equip and Crew, Well Data, Geo Data, Pres /Form data, Drill Data, Daily Reps °1 D C Pdf 18775" Report: Final Well R 3601 7600 Open 10/16/2009 Final Well Report, Tab of Cont, Equip and Crew, Well Data, Geo Data, • Pres /Form data, Drill Data, Daily Reps w /PDF graphics f.tog Mud Log 2 Col 3757 7587 Open 10/16/2009 MD Formation log l 'o'g Mud Log 2 Col 3757 7587 Open 10/16/2009 TVD Formation log rLog Mud Log 2 Col 3757 7587 Open 10/16/2009 MD Combo Log g Mud Log 2 Col 3757 7587 Open 10/16/2009 TVD Combo Log Mud Log 2 Col 3757 7587 Open 10/16/2009 MD Drilling Dynamics g Mud Log 2 Col 3757 7587 Open 10/16/2009 TVD Drilling Dynamics Cog Mud Log 2 Col 3757 7587 Open 10/16/2009 MD Gas Ratio Mud Log 2 Col 3757 7587 Open 10/16/2009 TVD Gas Ratio -- - - -- -- - -- DATA SUBMITTAL COMPLIANCE REPORT 4/27/2011 Permit to Drill 2090570 Well Name /No. BELUGA RIV UNIT 232 -23 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 283 - 20133 -00 -00 MD- 7587 TVD 6668 Completion Date 10/7/2009 Completion Status 1 -GAS Current Status 1 -GAS UIC N f✓�D C Las 18978 Notes 0 0 Open 11/25/2009 7 CD's for Well in folder, Corr, Perf, Set Rec, RST, 1 GEL, CSNG in LAS and Tiff format Reservoir Saturation Col Open 11/25/2009 Reservoir Description Tool L Perforation 5 Col 6164 6780 Case 11/25/2009 Perf, GR g Plug 5 Col 6600 6960 Case 11/25/2009 Plug Setting Record, GR t Gamma Ray 5 Col 5580 5944 Case 11/25/2009 TCP Corr, GR . 1±cfg Correlation 5 Col 5740 6720 Case 11/25/2009 Sump Packer Correlation, GR -Leg Cement Evaluation 5 Col 2200 7430 Case 11/25/2009 Advanced Cement Evaluation Le6 Magnetic Resonance 5 Col 4085 7136 Open 11/25/2009 Magnetic Resonance Imaging Analysis NMR Porosities, Perm & Distribution Data tog Sonic 5 Col 3739 7546 Open 11/25/2009 Wavesonic Semblance L g Analysis - Misc 5 Col 3739 7548 Open 11/25/2009 Clay- Typing Anal L-og Analysis - Misc 5 Col 3774 7546 Open 11/25/2009 Anisotropy Magnetic Resonance 5 Col 4080 6828 Open 11/25/2009 Magnetic Resonance Imaging Analysis, TDA Analysis og Production 5 Col 4400 6850 Case 3/23/2010 PPL, MPL, Pres, GR, CCL, ILS, FCAP, Temp, CFJ ED C Las „ ” a rduction 4400 6850 Case • ' Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Core Chips 6412 6499 9/2/2009 1240 Core 1 Core Chips 6844 6947 9/2/2009 1240 Core 2 DATA SUBMITTAL COMPLIANCE REPORT 4/27/2011 Permit to Drill 2090570 Well Name /No. BELUGA RIV UNIT 232 -23 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 283 - 20133 -00 -00 MD 7587 TVD 6668 Completion Date 10/7/2009 Completion Status 1 -GAS Current Status 1 -GAS UIC N ADDITIONAL INFORMATION ATION (� Well Cored? Lr / N Daily History Received? ` )N Chips Received? li)/ Formation Tops 05/ N Analysis Y /!jv Received? 11 Comments: e � • Compliance Reviewed By: —_ Date: r r L t • II . • ` STATE OF ALASKA AL/10 L AND GAS CONSERVATION COM N REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed: Abandon r Repair w ell r Plug Perforations " Stimulate r Other Install Capillary String Alter Casing r Pull Tubing r Perforate New Fbol r Waiv r Time Exten r Change Approved Program r Operat. Shutdow n 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 J7 Exploratory r ' 209 -057 3. Address: 6. API Number: Stratigraphic r S ervice 1 P. O. Box 100360, Anchorage, Alaska 99510 1i. 50 283 - 20133 - 00 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 21128 • BRU 232 -23 9. Field /Pool(s): .5.A7 Beluga River Field / Be s Pool Uyt r� f - i GIs 4 11 p 10. Present Well Condition Summary: Total Depth measured 7587 feet Plugs (measured) 6875 true vertical 6668 feet Junk (measured) None Effective Depth measured 6875 feet Packer (measured) 7 packers true vertical 5956 feet (true vertucal) Casing Length Size MD TVD Burst Collapse Conductor 89' 20" 107.5 107.5 Surface 3720' 9.625" 3743 2952 Production 7557' 7" 7577 6658 Perforation depth: Measured depth: from 4734' ECE True Vertical Depth: 3822' - 5788' NOV 0 3 2010 Tubing (size, grade, MD, and TVD) 4.5, C -75, 4597 MD, 3690 TVD Alaska Off &Gas Cons. Cenenion Anchorage Packers & SSSV (type, MD, and TVD) 7 packers - see schematic Camco landing nipple © 497' MD and 497' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Ave' - _ ; a += or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 13. Attachments 14. Well Class after work: • Copies of Logs and Surveys run Exploratory r Development 1' Service r Stratigraphic r 15. Well Status after work: Oil r • Gas i WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ 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: none Contact T. Senden a 265 -1544 Printed Nam T. _ enden \ Title Staff Wells Engineer Signature 1 , ` , Phone: 265 -1544 Date IO 6 I 10 talk RBDMS t1-3 r o DMS NOV 0 310 Form 10-404 Revised 10/2010 Submit Original Only y y SAK 411/ BRU 232 -23 it 1 W II A r�butes tMax Angle & MD TD " •x. r Wellbore API/UWI Field Name Well Status Incl( °) MD(ft/B) Act Btm(ftKB) ' 502832013300 _ [ BELUGA RIVER UNIT PROD ! 5261 2,349.30 7,587.0 ' Comment H2S (ppm) Date Annotation End Date IKB -Grd (ft) Rig Release Date Well Canty DEVIATED BRU23223, 1,5/26999 39 AM:_: NIPPLE ' Last WO. 1850 10/7/2009 _- __. _ '_ I 1 .- . - Schematic . Actual Annotation (Depth (ftKB) End Date (Annotation Last Mod By End Date Last Tag: _ Rev Rev Reason: NEW WELL Imosbor 11/5/2009 "'" ' Casing Strings - - -- 1=, " 'OV°° Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 20 19.124 - 1.0 84.0 84.0 154.00 X65 Bolted o „e Casing Description String 0... String ID .. Top (91(8) Set Depth (f... Set Depth (TVD) _. String Wt... String ... String Top Thrd "• SURFACE 95/8 8.835 22.8 3,742.6 2,952.7 40.00 L BTC - Mod W.P.M.. Casing Deunption String 0... String ID ... Top (ftKB) Set Depth (1.. Set Depth (TVD) ... String Wt... String ... String Top Thm s PRODUCTION 7 6276 19.0 7,576.5 6.657.9 26.00 L -80 BTC Tubing Strings Tubing Description String 0.. 'String ID ... (Top (ftKB) Set Depth (f_. Set Depth (TVD) ... (String Wt... String ... String Top Thrd TUBING L 41/2 1 3 958 17.3 4,597.1 3,690.3 ' 12.60 C -75 IBTM soxnce.»us Completion Details 0 ,„,,,,,„. -- E Top Depth (TVD) Top Inc' Nomi... yi T op (fg( 0 (°) Item Description Comment ID (in) ,l., ,, �." 17.3 17.3 -0.01 HANGER Vetco Gray Tubing hanger 4.500 DADS .eerrEw� 445.5 445.4 3.12 NIPPLE Camco CHEMICAL INJECTION NIPPLE with 3/8" C.L. 3.920 ......5. $s° 7 . 497.1 496.9 4.21 NIPPLE Camco 3.813" BP-61 Landing Nipple 3.813 suArAn L. - " '+" 4,501.8 3,600.5 20.79 NIPPLE 3.813" HES X Nipple 3.813 way m - 4,553.7 3,649.5 19.57 SEAL ASSY Baker Locator Seal Assembly w/ 2' Space out 3.900 rese - 4,556.5 3,652.1 19.49 PBR Baker43/4 "PBR - -- 3.900 Sae Os p CDEDS., OM u,Easw'v7 1: 4,584.5 3,678.4 18.63 SEAL ASSY E - Anchor Seal Assembly 3.250 DDTEe . 4,585.7 3,679.6 18.59 SEAL ASSY Baker S -22 Seal Assembly with Half mule Shoe 3.250 Tubing Description Strintrip T String 0... String ID ... Top (ftKB) Set Depth (i. Set Depth (TVD) ... String WL.. Siring ... String Top Thrd perm•' "O' "' I. 1 MULTI -ZONE 53/4 3.430 4,585.8 5,933.6 5,015.4 oErs.vea..>.1 ▪ a....7oe -� GRAVEL PACK 7us., I. ASSEMBLY pe I ,ren ac,ss„n - ✓ 5� L Completion_ Details ,tae ` Top Depth son r te ' - (TVD) Top Inc! Nomi... „ _ Top MKS (ftKB) (1 Item Description Comment ID(in) 4,585.8 3,679.6 18.59 PACKER SC -2 Packer 708-40 4.000 lerk 4,599.8 3,692.9 18.16 SBE Seal Bore 80 -32 3.250 pear, DD.-D.9 -- -. -- -._ pears,, 4,604.3 3,697.2 18.02 VALVE Knock out Isolation Valve C -2 Sleeve 3.320 wear. s,9.-.a. ; 4,606.8 3,699.6 17.95 VALVE Knock out Isolation valve C -2 3.340 wee son - ssn reap ,...D.e 4,614.6 3,707.0 17.71 SCREEN Vent Screen Bakerweld 3.930 sec DAD ✓ cea s,iw saE.sw - 4,625.2 3,717.1 17.38 XO Crossover 3.430 exTEnsioi. ,.ro -..- - - '', --.- 4,625.7 3,717.6 17.37 SBE Seal Bore MZ system 80-32 3.250 4,627.9 3,719.7 17.30 PACKER SC 1L Packer 70136-40 3.625 _ r 4,631.4 3,723.1 17.19 SBE Seal Bore MZ system 80 -32 3.250 0 41 n i .� I 4,633.5 3,725.1 17.13 EXENSION Upper Extension MZ system 80-32 3.970 .aon 9 -- ( b�� i 4,637.3 3,728.7 17.01 EXTENSION Frac Extension MZ system 80-32 4.010 ' ' .. =-::::g \ \ _ 4,641.3 3,732.5 16.89 SBE Seal Bore MZ system 80-32 3.250 ' Alf SD, \ \ � 4,643.7 3,734.8 16.82 EXTENSION Lower Extension MZ system 80-32 3.980 • \ �1ttMrTi1 ru0 1 4,648.8 3,739.7 16.66 SBE Seal Bore MZ system 80-32 3.250 tG co, • s , 4,651.6 3,742.4 16.57 XO Crossover 3.470 • a 'a°' c". \ - -- 4716.9 3,805.3 14.01 SCREEN Screen Excluder 2000 3.430 Vg- - - r • ' 5,032.7 4,115.6 6.72 SBE Seal Bore MZ system 80-32 3.250 s. � {,., 5,034.9 4,117.7 6.68 PACKER SC -1L Packer 70136 -40 3.625 ork , �' 11` 5,038.4 4,121.2 6.61 SBE Seal Bore MZ system 80 -32 3.250 ir cmsmear. Man r s. xo. a,a L 5,040.5 4,123.2 6.57 EXTENSION Upper Extension MZ system 80-32 3.970 s °sv $;r1 5,044.3 4,127.0 6.50 EXTENSION Frac Extension MZ system 80-32 4.010 kt 5,048.3 4,131.0 SBE 'Seal Bore MZ system 80 -32 3.250 rI w '� 5,050.7 4,133.3 MI EXTENSION Lower Extension MZ system 80-32 3.980 sOleem 1,13.-- 5,055.8 4,138.4 6.27 SBE Seal Bore MZ system 80 -32 3.250 perm ;�� L .' 5,058.6 4,141.2 6.21 XO Crossover 3.470 ...cr. ;: 5,083.5 4,166.0 5.72 SCREEN Screen Excluder 2000 3.430 • --- 5,458.2 4,540.1 1.92 SBE Seal Bore MZ system 80 -32 3.250 sra, a ar °---'-,., 5,460.4 4,542.3 1.93 PACKER - SC -1L Packer 7086 -40 3.625 - 1 5,463.9 4,545.8 3.12 SBE Seal Bore MZ system 80-32 3.250 ar M e 7 • O 4} 5,465.9 4,547.9 3.07 EXTENSION Upper Extension MZ system 80-32 3.970 =1 1= -.' 4 5,469.7 4,551.7 2.99 EXTENSION Frac Extension MZ system 80-32 4.010 nesn� ▪ v.. S S, 5,473.7 4,555] 2.90 SBE Seal Bore MZ system 80-32 3.250 1 . 5,476.1 4,558.1 2.84 EX TENSION Lower Extension MZ system 80-32 3.980 • ° - -t 5,481.2 4,563.2 2.73 SBE Seal Bore MZ system 80 -32 3.250 Omsk.. fff r arU s_, ' ar '° 5,484.0 4,566.0OM XO Crossover 3.470 - 1 5,607.5 4,689.4 0.61 SCREEN Screen Excluder 2000 3.430 s° soo a rm y_ .. 5,923.1 5,004.9 1.05 NIPPLE R Nipple 3.250 • r Pr 5,924.1 5,006.0 1.05 Snaplatch Snaplatch 3.270 D0. A ' i at " - s r • , 5,925.1 5,006.9 1.05 SEAL Seal Units 3.260 xrxwox a 5,933.1 5,014.9 1.05 SHOE Half Mule shoe 52-40 3.260 i,e Tubing Description String 0... String ID ... Top (9 (8) Set Depth (L. Set Depth (TVD) ... String Wt... String ... String Top Thrd n l'a n L CK LOWER 2.89 2.370 5,925.1 6,746.8 5,828.4 6.40 L-80 2 -7/8 Hyd 511 - ,_, 1 ISOLATION STRING Mandrel Details • x a Top Depth Top -- - Port .a-- - (TVD) Incl OD Valve Latch Sae TRO Run seor.a a Sin Top (ftK81 (ftKB) (1 Make Moda) (in) Sery Type TYpe 110 0441 Run Date Cam... aUI a ?7' 1 4,448.6 3,551.1 22.36 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 9/20/2009 �� m,7se7 • • SAK • BRU 232 -23 C+o in ps ski , Ire.. Ilk -" -- - KB -Grd (ft) ,Rig Release Date 18 50 Wen Ccnfg: DEVIATED BRU .'23„1j /.�WB $„�.,_ 10'7/2009 - ''' } mpletion Details - 111 ADZ - 'C.t Top Depth (TAM) Top Inc! Nomt -. 4 � - , -y T P tN (B (�) dn ID (in) 5,925.1 KB) 5,006 -9 KB) 1.05 PACKER IleD cription SC -2 Isolation Packer 70B40 Comment - - -- 4.000 w 1 «a- 5,929.4 5,011.2 1.05 EXTENSION Millout Ext. Pin x Pin 4.650 wa1 - - - - - -- "' 5,948.8 5,030.7 1.04 Snaplatch Snaplatch 3.260 j t : 5,950.2 5,032.0 1.04 SEAL Seal Units 90H Stub 3.260 suar.c4 vs,7.a 5,956.8 5,038.6 1.03 SEAL Seal Units 3.260 • 6,124.4 5,206.2 1.41 SLEEVE SLCMU BX Profile - -- 2.313 °nSPT''"'" ` 6,128.4 5,210.1 1.40 SEAL ASSY Locator Seal Assembly -_ -- 2.420 _ .s 6,129.7 5,211.5 1.40 SEAL Seal Units 2.400 w sus r '. 6,218.3 5,300.0 1.35 SLEEVE SLCMU BX Profile 2.313 erree: �e -�.- 6,222.2 5,304.0 1.35 SEAL ASSY Locator Seal Assembly 2.420 sue sw� y� .w" ^'` 6,223.6 5,305.3 1.35 SEAL Seal Units 2.400 °`- a i:- 6,560.6 5,642.3 1.26 SLEEVE SLCMU BX Profile 2.313 r.c a 4% --_, 6,564.5 5,646.2 1.36 SEAL ASSY Locator Seal Assembly 2.420 e =- 6,565.9 5,647-6 1.36 SEAL Seal Units 2.400 ,p„ ... W 6,662.4 5,744.1 1.38 SLEEVE SLCMU BX Profile 2.313 6,666.4 5,748.0 1.38 SEAL ASSY Locator Seal Assembly 2.420 Wee .71 7 - -- . 6,667.7 5,749.4 1.38 SEAL Seal Units 2.400 w ear .no d . ' 7- - 6,717.6 5,799.2 1.50 SLEEVE SLCMU BX Profile 2.313 1Pfa °a p" ♦ 6,733.3 5,814.9 1.47 SEAL ASSY Locator Seal Assembly 2.420 ▪ stm v.4.13. S.C. , � . 6,734.6 5,816.3 1.47 SEAL Seal Units 2.400 WM... s - - `--- 6,745.9 5,827.5 1.46 SHOE Half Mule Sloe 2.440 SW, sr. -- Tubing Strings Pelf s m n , Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String String Top Thed wcw ra,w _ . LOWER ZONE CK 5 3/4 3.430 5,950 2 6,746.1 5,827 8 13.50 , 5,4, _ A SSEMBLY 1 e pt7 x 7 Compl Details pee w r. e Pow, s,..16 - • h Top Depth. see SAO (ND) Top loci Nomi... ..1_4.0,1,... ex,c e , M TopiftKB (BKB) (% Item Description Comment ID (in) .i, 5,950.2 5,032.0 1.04 PACKER SC -2 Packer 708-40 4.000 WC ,.d 5,953.9 5,035.8 1.04 EXTENSION Frac Extension 8040 CK 250 4.800 • aa:� -. - �:.� 5,957.6 5,039.4 1.03 SBR Seal Bore receptacle 80-40 CK 250 4.000 7' i :± 5,981.7 5,063.5 1.01 VALVE Knock Out Isolation Valve C -2 Sleeve 3.340 4 5,984.4 5,066.2 1.01 VALVE Knock Out Isolation Valve C -2 3.310 __ _. . . 5,986.2 5,068 -0 1.01 XO Crossover 3.430 yad DM xSittu...5.4 a , 5,987.7 5,069.5 1.02 SOS Shear out Safety Joint 3.420 - 6,0833 5,165.3 1.12 SCREEN Screen Excluder 2000 3.430 ,.3 - . 6,123.0 5,204.8 1.41 XO ' Crossover 3.490 cou x,+7 6,134.1 5,215.9 1.40 XO Crossover 3.490 mr. \� * c 6,134.8 1.40 SBR Seal Bore receptacle 3.250 � _ s 6,137.6 5,219.3 1 40 SCREEN Screen Excluder2000 3.430 • �_ _.. IL A a .� _ _..._ tow. °"" b. " 6,216.3 5,298.0 1.35 XO Crossover 3.490 se ice. 1. - °-�- e 6,227.4 5,309.2 1.34 XO -- I - Crossover 3.490 „ - . - - 6,228-1 5,309.9 1.34 SBR Seal Bore receptacle 3.250 dN . a ::12: t� t om ' : 6,230.9 5,312 -6 1.34 SCREEN w Screen Baker Weld 140 3.430 x ZT. d, - .-- --- - I 6,241.4 5,3232 1.33 SCREEN Screen Excluder 2000 3.430 wlrr.a,..d.,az wear a, »z,a.� � t /�- 6,557.0 5,638.7 1.26 XO Crossover 3.470 .,a 1 ' 6,568-2 5,649.8 1.36 XO Crossover 3.470 sss „ \ "4 6,568.7 5,650.4 1.36 SBR Seal Bore receptacle 3.250 Tuem. 121, e ; �-- __ S I 6,571.5 5,653.1 1.36 SCREEN Screen Excluder 2000 3.430 -- 6,650.3 5,732.0 1.37 SCREEN Screen Baker Weld 140 3.430 ar u.. • am 6,66(19 5,742.5 1.38 XO Crossover 3.470 ▪ x -- 4` 6,672.0 5,753.6 1.38 XO Crossover 3 10. . ..,. ../r. 4 6,672.6 5,754.2 1.38 SBR Seal Bore receptacle 3.250 x laud, "' ; 6,675.3 5,756.9 1.38 SCREEN Screen Excluder 2000 3.430 ▪ °` 6,714.8 5,796 -4 1.50 X0 Crossover 3.470 se, 6 saa 6 ,725.9 5,807.6 1.48 X0 Crossover 3.470 -_ ► -i4 6,726.5 5,808.1 1.48 SCREEN Screen Baker Weld 140 3.430 sekccu, aa» - III' :4 6,737-0 5,818.7 1.47 Snaplatch Snap latch 8240 3.250 6,738.0 5,819.6 1.47 SEAL Seal Units 8240 3.250 `° 62 �_ ,;? 6,745.6 5,827.3 1.46 SHOE Half Mule Shoe 82-40 Stub 3.250 s. Tubing Description String 0... String ID _ Top ((NCB) Set Depth (f_. Set Depth (ND) •.. String WL.. String ... String Top Thdd 4e' °7d r • TUBING - Production 51/2 4.930 6,738.0 - 6,760.3 5,841.9 weir �d uw 4 - . • a ai F0 ../.7s SAK 0 BRU 232 -23 conocoliips KB -Gro (ft) Rig Release Dele •"• 18.50 10/7/2009 _ sdremnuc =Rm+rt , r, xaE; • m • letion Details To Depth Nomi... (N Top Incl .. (ft tcB l Cl Itom Des iption .. _. _._ _ Commem ID (in) 6,738.0 5,819.6 1A7 BOT Sump BOT Sump Packer Packer 4.000 xenc.r.: , 6,7400 5,821,6 1.47 WLEG WIRELINE ENTRY GUIDE 4.000 6,740.8 5,822 -4 1 46 SHOE MULE SHOE 4.930 sK,e,• r5 Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Incl ass urr.c. __..... -, B (ftKB) (' ) Descn (in) T• • option Comment Run Date ID 6,875 5,956.6 1.25 PLUG Bridge Plug - Permanent 9/9/2009 Perforations & Slots xs Shot � -. Top 01/D) Btm(ND) Dens .rvc.3c+ T.. DNB Btm fKCB) ( B) (FWD) Zone Dale (eh - Type Comment "w� •+wry aw...' 4,734 4,747 3,821.9 3,834.5 9/29/2009 14.0 IPERF All Shots Fired - Gun OD After Firing ` .aa - (` a ion ,. : . 325 " /Shot Orifice .5" ""C ' ; 4,780 4,793 3,866.7 3,879.4 9/29/2009 14.0 IPERF All Shots Fired - Gun OD After Firing ao�rx • _ - - -_ -- 3.25" /Shot Orifice .5" bre be,0 bee 0 4,876 4,905 3,960.7 3,989.3 9/29/2009 14.0 IPERF All Shots Fired - Gun OD After Firing 3.25 " /Shan Orifice .5" •rma >•> - 4,970 4,981 4,053.4 4,064.3 9/29/2009 14.0 IPERF All Shots Fired - Gun OD After Firing „m,-- -�. 3.25" /Shot Orifice .5" !Mbebb.e. - 1 ♦, 5,015 5,023 4,098.0 4,105.9 9/29/2009 14.0 IPERF All Shots Fired - Gun OD After Firing Pcxr, rm = :An - -- .♦ 3.25 " /Shot Orifice .5" ,xTe ram, • b`, se _ -" 5,100 5,110 4,182.4 4,192.4 9/29/2009 14.0 IPERF All Shots Fired - Gun OD After Firing :+ 3.25"/Shot Orifice .5" 5,152 5,159 4,234.2 4,241.2 9/29/2009 14.0 IPERF All Shots Fired - Gun OD After Firing i 3.25 " /Shot Orifice .5" Feb, 5,1525,10 -- • 5,176 5,191 4,258.2 4,273.1 9/29/2009 14.0 IPERF All Shots Fired - Gun OD After Firing „eeN. Se._ ' xr 325 " /Shot Orifice .5" .:a ram 5,354 5,366 4,436.0 4,448.0 9/29/2009 14.0 IPERF All Shots Fired - Gun OD After Firing Per, 1,:,b:a8 - - - • Imo 3.25 " /Shot Orifice .5" ▪ b - . - • " • xp ` 5,377 5,387 4,459.0 4,469.0 929/2009 14.0 IPERF All Shots Fired - Gun OD After Firing X34 „______ t` 325" /Shot Orifice .5" cx ...snot - be.540i -- e. t 5,436 5,448 4,517.9 4,529.9 9/29/2009 14.0 IPERF All Shots Fired - Gun OD After Firing ecxr r.r . :am er,x. :A.r�m - 3.25 " /Shot Orifice .5" ��� ,.,n;a - ∎ 4 5, 5,642 4,710.9 4,723.9 929/2009 14.0 IPERF All Shots Fired- Gun OD After Firing e %d I , 3.25" /Shot Orifice .5" s,oc, SAS ea bb, X0, o00 _ - -- �, s °: ▪ _, � " - 5,689 5,733 4,770.9 4,814.9 9/29/2009 14.0 IPERF All Sh ots Fired - Gun OD After F irin g _ 3.25 " /Shot Orifice .5" • xs w x 1-05: 5,888 5,914 4,969.8 4,995.8 9/29/2009 14.0 IPERF All Shots Fired - Gun OD After Firing � 3.25 " /Shot Orifice .5" )88•r .- 6,098 6,118 5,179.8 5,199.8 9/22/2009 14.0 IPERF All Shots Fired - Gun OD After Firing 55e 3.25 " /Shot Orifice .5" e0uPab On P bbbn be bee CH be. b 6,139 6,166 5,220.8 5,247.8 9/22/2009 14.0 IPERF All Shots Fired- Gun OD After Firing �""". s '"'� -. $ '<:. 325 " /Shot Orifice .5" ..-:41 - - -- ` 6,144 6,164 5,225.8 5,245.8 9/16/2009 6.0 IPERF All Shots Fired - Gun OD After Firing 5xaxo, 5,5b - 3.25" /Shot Orifice .5" I ebbe, bee 17e: Pere a'::',21- "". n 6,180 6,194 5,261.8 5,275.8 9/22/2009 14.0 IPERF All Shots Fired - Gun OD After Firing 1x00 N -_. _ i 3.25 " /Shot Orifice .5" 0 - ae~ - "t•' 6,183 6,193 5,264.8 5,274.8 9/16/2009 6.0 IPERF All Shots Fired - Gun OD After Firing ea j . 3.25 " /Shat Orifice .5" ▪ e t � ; 6,388 6,398 5,469.7 5,479.7 922/2009 140 IPERF All Scats Fired - Gun OD After Firing ecrr. a,mim� t� : 3.25 " /Shot Orifice .5" a 4 _ I a A 6,466 6,477 5,5473 5,558.7 9/22/2009 14.0 IPERF All Shots Fired - Gun OD After Firing ,flame r - 3.25" /Shot Orifice .5" • an -- 4 6,486 6,514 5,567.7 5,595.7 9/22/2009 14.0 IPERF All Slats Fired - Gun OD After Firing aaiz`sx'a~- -- _ , 325" /Shot Orrice .5" n 1 :r - .$. - ' . 6,492 6,512 5,573.7 5,593.7 9/15/2009 6.0 IPERF All Shots Fired - Gun OD After Firing Sbare r .re s - I � 41 3.25 " /Shot Orifice .5" venr,:',Ittas,a� . L� � � 6,576 6,609 5,657.7 5,690 7 922/2009 14.0 IPERF All Shots Fired - Gun OD After Firing 4 3.25" /Shot Orifice .5" be " ? • 6,591 6,606 5,672.7 5,687.7 9/14/2009 6.0 IPERF All Shots Fired - Gun OD After Firing i Y_ L *-. 3.25" /Shot Orifice .5" F. 6,683 6 5 5,790.6 9/22/2009 14.0 IPERF All Shots Fired - Gun OD After Firing Peke. a 0. fp ... 41 3.25"/Shot Orifice .5" ,51� I 4 '\ I 6,686 6,706 5,767.6 5,787.6 9/13/2009 6.0 IPERF All Shots Fired Gun OD After Firing ,�a 325 " /Shot Orifice .5" 4 ° .aaaa� - p; i Notes: General & Safety 314- - "-- g _ ' trtr r i- End Date _ -. Annotation U. - 11/5/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 a: t, 1 a Kb 075 ro.sys BRU 232 -23 Well Work Summary DATE SUMMARY 10/8/10 MIRU POLLARD W/L EQUIPMEt ULLED 3.813" WRDP ON DB LOCK @ 'RKB, SECURE WELLHEAD, RDFN, PJSM. 10/10/10 MIRU POLLARD W/L EQUIPMENT, PULLED PR PLUG FROM "R" NIPPLE @ 5,950'RKB, WELLHEAD PRESSURE ROSE FROM 550 TO 600 PSI, SET 3.813" WRDP ON DB LOCK @ 498'RKB, CLOSURE TEST GOOD FROM 600 TO 375 PSI, RDMO POLLARD, RETURN WELL TO PRODUCTION, JOB COMPLETE. 10/16/10 Pull WRDP SSSV (HPS -459), Attempted to set 3.25" PR plug w/ out success. Lock body damaged during retrieval w/ no replacements available. Will return when other plug options are available. 10/20/10 Installed 2 7/8" PX plug w/ 5' prong in 2.313" CMU located at 6131' wlm. 10/23/10 Install 3/8" BJ capillary string from surface to 5675' w/ 2" fluted centrilizer and piston check BHA. String capped at surface, not currently hooked up to Chemical pump. II I II I Conoco Phillips TRANSMITTAL FROM: Sandra D. Lemke, ATO1808 Christine Mahnken ConocoPhillips Alaska AOGCC P.O. Box 100360 333 W. 7 Ave., Suite 100 Anchorage AK 99510 -0360 Anchorage, Alaska 99501 RE: BRU 232 -23 DATE: 03/19/2010 mail Tran i - Beluga River Unit, Alaska 1 BRU 232 -23 NED Log Print and CD digital data MAR 2 3 2010 Production Profile, PDS, log date: Feb. 27 -2010 l:4 Please sign, scan and return transmittal via e-mail promptly CC: BRU232 -23 U Receipt: Date: toon xz� , 1T55- Upstream Applications & Data I ConocoPhi//ips' Anchorage, Alaska I Ph: 907265.6947 Sandra.D.LemkeeConocophillips com 1g41 RECEIVED • STATE OF ALASKA N V 1 9 �OetI RCtooq ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT "A lti y"d Cnnr"issinn la. Well Status: Oil ❑ Gas Q SPLUG ❑ Plu ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: October 7, 2009 209 - 057 / 3. Address: 6. Date Spudded: 13. API Number: P. 0. Box 100360, Anchorage, AK 99510 - 0360 July 31, 2009 50 283 - 20133 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2102' FNL, 51' FWL, Sec. 24, T13N, R1OW, SM August 26, 2009 BRU 232 - 23 Top of Productive Horizon: 8. KB (ft above MSL): 96.5' RKB 15. Field /Pool(s): 2052' FNL, 2324' FEL, Sec. 23, T13N, R1OW, SM GL (ft above MSL): 78' AMSL Beluga River Field Total Depth: 9. Plug Back Depth (MD + ND): LAvtd l..k�.►ti.Gd 1 2076' FNL, 2391' FEL, Sec. 23, T13N, R1OW, SM 6875' MD / 5956' TVD - Balug -.Gas Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 323388 y 2633529 Zone 4 7587' MD / 6668' TVD ADL 21128 TPI: x - 321013 y - 2633615 Zone 4 11. SSSV Depth (MD + ND): 17. Land Use Permit Total Depth: x 320946 y 2633592 Zone 4 nipple @ 497' MD / 497' TVD not applicable 18. Directional Survey: Yes Q No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/ND: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) not applicable 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 Dipole sonic, GR/CCL, GR/Res /Dens /Porosity /MRIL, SP /SBL, NGT, MDT 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 20" 154# X -65 18.5' 107.5' 18.5' 107.5' na driven 9.625" 40# L -80 22.9' 3743' 22.9' 2952' 12.25" 420 bbls 12.0 ppg Class G 7" 26# L -80 20.2' 7577' 20.2' 6658' 8.75" 191 bbls 10.5 ppg Class G 24. Open to production or injection? Yes 0 No ❑ If Yes, list each 25. TUBING RECORD Interval open (MD +ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4.5" 4597' 4586', 4628', 5035', 5460', 5925', 5950' see attached list 6738' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6139'- 6166', 6180' -6194' 103328# 20-40 carbolite proppant 6486-6514' 102478# 20-40 carbolite proppant 6576-6609' 25086# 20 -40 carbolite proppant 6683' -6709' 84272# 20 -40 carbolite proppant 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) October 20, 2009 gas producer Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO 11/1/2009 16.5 hours Test Period --> na 2.3mmscf /d 163 128 Beans not applicable Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 353 psi 75 24 -Hour Rate -> na na na not available 28. CORE DATA Conventional Core(s) Acquired? Yes • No ❑ Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD +ND 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. `, tVa i't.v. E e. :le t "' ' TO BE SENT UNDER SEPARATE COVER f 1 Form 10-407 Revised 7/2009 CONTINUED ON REVERSE it t o A is (/ (i9inal only iotr, l I 28. GEOLOGIC MARKERS (List all formations and markersiountered): 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes EI 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 not applicable not applicable needed, and submit detailed test information per 20 AAC 25.071. Sterling A 4121' 3258' Sterling B 4324' 3437' Sterling C 4486' 3586' Beluga D 4655' 3746' Beluga E 4919' 4003' Beluga F 5298' 4380' Beluga G 5730' 4812' Beluga H 6065' 5147' Beluga I 6784' 5865' Beluga I Base 7357' 6438' N/A Formation at total depth: Beluga I 30. LIST OF ATTACHMENTS Summary of Daily Operations, directional survey, schematic, list of perforations 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: D1Fig @ 265 - 6862 Printed Name L. Alvord Title: Alaska Drilling Manager �� c � y Signature �C - C P hone 2 -6120 D ate /lib ✓—/a?'.200 / prepared by 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 7/2009 °� SAK • BRU 232 -23 Iv , Conoco [p ',,,,,4:„.:,,,, W �Attnbuteg Max Angle & MD TD _., f�14S1iS. Ina, ' W Ilbore API/UWI Field Name Well Ind ( °) MD (ftKB) 'Act Btm (ftKB) r "' 502832013300 I Wll St BELUGA RIVER UNIT PROD 1 52.61 2,349 30 7,587.0 Comment H2S(ppm) End - AnrroW (Date IAn Cation End Date KB -Grd (ft) Rig Release Date "' SSSV: NIPPLE Last WO: 18 50 10/7/2009 _., Wee calm_aEVIAT52 « .4.R. It .2gt= 21.:!.T! 991,_4Sgk8M.__ A notahon - _ te Data - .. G�}�,�g� Anplg � r Ie on Last Mod By End Date Last Tag: I Depth (ftKB) L Rev Reason: NEW WELL Imosbor � ._. 11/5/2009 _ HePR,7 Casin. Strin•s Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 20 .19124 - 1.0 84.0 84.0 154.00 X65 Bolted CONCH,..m,_,.Se t Casing Desc pt String 0... String ID ... Top (ftl(B) Set Depth (f... Set Depth (ND) ... String Wt... String . String Top Thrd SURFACE 9 5/8 8.835 22.8 3,742.6 2,952 7 40.00 L BTC - Mod NNW ,..s >= Casing Description String 0... String ID Top (ftKB) Set Depth (f... Set Depth (TVD) . String Wt... String .. String Top Thrd 1 = PRODUCTION 7 6 276 19 0 7,576.5 6 657 9 26.00 L -80 BTC Tubing Strings - LASS hrd (Tubing Description String 0 (Str g ID ... Top (ftKB) Set Depth (f... Set Depth (ND) . ( String Wt... String .. String Top Thrd sinrce,assrs TUBING 41/2 J__ 3958 I 173 I 4,597.1 3690.3 12.60 C75 IBT Completion Details _ OAS Ur, 4,1a Top Depth E (TVD) Ind D) Top I Nomi... P . + T (11KB) (6K6) (•) hem Description _... Comment ID (in) s� Pat .ssa � -"a 17.3 17.3 -001 HANGER Vetco Gray Tubing hanger 4.500 s ' '0d ea � 445.5 445.4 3.12 NIPPLE Cameo CHEMICAL INJECTION NIPPLE with 3 /8 "C.L 3.920 s _ . swr.. 21 497.1 496.9 4 NIPPLE Cameo 3.813" BP-61 Landing Nipple 3.813 a � . 4,501.8 3,600.5 20 79 NIPPLE 3.813" HES X Nipple 3.813 ex ress.s u - _ _ � _ k'� 4,553.7 3,649.5 19.57 SEAL ASSY Baker Locator Seal Assembly w/ 2' Space out 3.900 ,�, 8 „ 4,556.5 3,652.1 19.49 PBR Baker 4 3/4" PBR 3.900 rmrti4. -.. � P., ._._ - -.LASS___ .-. -_.. as,..am -- 4,584.5 3,678.4 18.63 SEAL ASSY E- Anchor Seal Assembly 3.250 OM ' sec...an L 4,585 7 3,679.6 18.59 SEAL ASSY Baker S -22 Seal Assembly with Half mule Shoe 3.250 wILLedim „, T bing Description String 0... String ID ... Top (ftl(B) Set Depth (f... Set Depth (ND) .. String Wt... String ... Shing Top Thni MULTI-ZONE 53/4 3.430 4,585.8 5,933.6 5,015.4 Prkr, 4,710.4 xeH.ni s • •� GRAVEL PACK PefT,4a7wa, :� ASSEMBLY rxr,.r7w,ae, -- ow �� e � Completion Details DM. 2 `" -`° Top Depth MS..,U. - - C -.--t (TVD) Top Intl Nomi... crte = i41- -. EiT Top (MKB) Cr") p) Item Descfgiwn Comment 10 (in) 4,585.8 3,679.6 18.59 PACKER SC -2 Packer 708-00 4.000 Ti ll 4,599.8 3,692.9 3,692.9 18 16 SBE Seal Bore 80-32 3.250 us•Ettr, 5,51,0 ,., -. , 4,604.3 3,697.2 18.02 VALVE Knock out Isolation Valve C -2 Sleeve 3.320 IPERr 5,3.5,94t _ 4,606.8 3,699.6 17.95 VALVE Knock out Isolation valve C -2 3.340 } a ER , 5.52 Ih. / 4,614.6 3,707.0 17.71 SCREEN Vent Screen Bakerweld 3.930 oacSPR,s,.as 4,625.2 3,717.1 17.38 XO Crossover 3.430 `e r c` ,=.s sss- ---- SeP.s,.7. 4,625.7 3,717.6 17.37 SBE Seal Bore MZ system 80 -32 3.250 `{ sx! 4,627.9 3,719.7 17.30 PACKER SC -1L Packer 7086-40 3.625 °is� asssaa,a.� • •• • 4,631.4 3,723.1 17.19 SBE Seal Bore MZ system 80-32 3.250 seer.ou 11, - *♦� 4,633.5 3,725.1 17 13 EXENSION Upper Extension MZ system 80-32 3.970 S�oe 9 �+"'„ 4 64 4,637.3 3,728.7 17 01 EXTENSION) Frac Extension MZ system 80-32 4.010 SE, S.IKO 4,641.3 3,732.5 16 89 SBE Seal Bore MZ system 80 -32 3.250 EXISNIsa0x, - 2. _ j 4 3,734.8 16 82 EXTENSION Lower Extension MZ system 80-32 3.980 COuP1.1 St. __. * 4,648.8 3,739.7 16.66 SBE Seal Bore MZ system 80 -32 3.250 4,651.6 3,742.4 16 57 X0 Crossover 3.470 �a i 4,716.9 3,805.3 14 01 SCREEN Screen Excluder 2000 3.430 ■"`''- �__ P , 5,032.7 4,115.6 6.72 SBE Seal Bore MZ system 80 -32 3.250 S ::- 5,034.9 4,117.7 6.68 PACKER SC -1L Packer 70B6 -40 3.625 T , ,,,,,,,,,_ _: 5,038.4 4,121.2 6.61 SBE Seal Bore MZ system 80 -32 3.250 wa. x, r< It,. It,. 0.. 5 4,123.2 6.57 EXTENSION Upper Extension MZ system 80 -32 3.970 SLEEK, SC L t;a 5,044.3 4,127.0 6 50 EXTENSION Frac Extension MZ system 80-32 4.010 ;95 5,048.3 4,131.0 6.42 SBE Seal Bore MZ system 80 -32 3.250 SPA i a ,•a I 11 5,050.7 4,133.3 6.37 EXTENSION Lower Extension MZ system 80-32 3.980 S_ 5,055.8 4,138.4 6.27 SBE Seal Bore MZ system 80 -32 3.250 SCREEN, 0_ 1 :4 1► 1 5 ,058.6 4,741.2 621 XO Crossover 3.470 $ , - 5,083.5 4,166.0 572 SCREEN Screen Excluder 2000 3.430 TUB.. = i - 5 4 1.92 SBE Seal Bore MZ system 80 -32 3.250 _ _ �..v.._.._. 100 1,20 F * 5,460.4 4,542.3 1.93 PACKER SC -1L Packer 7086 -40 3.625 Sa rr 5,463.9 4,545.8 3.12 SBE Seal Bore MZ system 80 -32 3.250 SentELN, 6.20 ' - - • 11• 4 5,465.9 4,547.9 3.07 EXTENSION Upper Extension MZ system 80 32 3.970 8,444,3. . 0 4 ' ^ : POW, 644012 644012 I 5,469.7 4,551.7 2.99 EXTENSION Frac Extension MZ system 80-32 4.010 .O ass? lit '4 ..___ ,me ass, „c - -- I 5,473.7 4,555.7 2.90 SBE Seal Bore MZ system 80-32 3.250 a ssS - Lam: 5,476.1 4,558.1 2.84 EXTENSION Lower Extension MZ system 80-32 3.980 Sea ss v.=_ -_ _._. _. i - ii 5,481.2 4,5632 2 73 SBE Seal Bore MZ system 80 -32 3.250 �- s" �� �- 5,484.0 4,566.0 266X0 Crossover 3.470 7, f 4 ' 5,607.5 4,689.4 0.61 SCREEN Screen Excluder 2000 3.430 .2a l -- - f' 5,923.1 5,004.9 1.05 NIPPLE R Nipple 3250 s a F � ^� 5,924.1 5,006.0 1.05 Snaplatch Snaplatch 3.270 212 - 5,925.1 5,006.9 1.05 SEAL Seal Units 3.260 ,74: f _ p 4 5,933.1 5,014.9 1.05 SHOE Half Mule shoe 52-40 _ 3.260 oaa f Tubing Description Siring 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) Str ng Wt... String ... String Top Thrd " sr CK LOWER 2.89 2.370 5,925.1 6,746.8 5,828.4 6.40 L-80 2 -7/8 Hyd 511 a ' \ ISOLATION STRING • "`a D" `� +` M andrel Details 5x3 s7.s 2o { `" To p Depth Top Pork SHOP. a7. " - _ • (TVD) Intl OD Valve Latch Size TRO Run SHOP, .a 3,140E, ,e, a P, a,7., Stn Top (RKej (ftKB) ( °) Make Model (in) Sary Type Type MN (PO Run Date Cont.., aeo, On 1 4,448.6 3,551 1 22.36 CAMCO KBG-2 1 GAS LIFT DMY IBK 0 000 0.0 9/20/2009 ,.�._.- ..LASS. _._. ... ._.._. nisei . SAK • BRU 232 -23 Coe Alps - �& Al .�. - g r.n r.2, II.8 KB -Grd (f0 1 .5 Rig Release Date •• W tiKordel- DEVIATE() 8tte2-23.t) /S1.Qa964g08 AM... -.. _.. 10 "'"'»- " Completion Details Chen. Top Depth (ND) Top Inc! Nomi... onoiCrea, "� T� (ftKB1 ( B) () Item DOSEIVb Comment ID (in) 5,925 -1 5,006.9 1.05 PACKER SC -2 Isolation Packer 70B-40 4.000 arvam 5,929.4 5,011.2 1.05 EXTENSION Millar Ext. Pin x Pin 4.650 ,iu .aaare.w7 -- - - -- 5,948.8 5,030.7 1.04 Snaplatch Snaplatch 3.260 5,950.2 5,032.0 1.04 SEAL Seal Units 90H Stub 3.260 surwACeassl•e = 5,956.8 5,038.6 1.03 SEAL - Seal Units 3.260 6,124.4 5,206.2 1.41 SLEEVE SLCMU BX Profile 2.313 ons„•r7.A.a 6,128.4 5,210.1 1.40 SEAL ASSY Locator Seal Assembly 2.420 am _ _........ ._- ss:4,5. ■ 6,129.7 5,211.5 1A0 SEAL Seal Units 2.400 S EAL °'a1e 6,218.3 5,300.0 1.35 SLEEVE SLCMU BX Profile 2.313 e a \ eVOINSne' \� 6,222.2 5,304.0 1.35 SEAL ASSY Locator Seal Assembly 2.420 9 , a 6`a - - vw§ tl \ 6,223.6 5,305.3 1.35 SEAL Seal Units 2.400 e.,easa>ti � - k 6,560.6 5,642 1.26 SLEEVE SLCMU BX Profile 2.313 acaee7... a2a _ �. - - - . , 6,564.5 5,646.2 1.36 SEAL ASSY Locator Seal Assembly 2.420 aaoKa, fah � . . _. _....°"..... - .... °..�... E.e7.s,w IL . _- VOW 6,565.9 5,647.6 1.36 SEAL Seal Units 2.400 SSE. 041 """ 6,662.4 5,744.1 1.38 SLEEVE SLCMU BX Profile 2.313 w n..a.. e..a.a 6,666.4 5,748.0 1.38 SEAL ASSY Locator Seal Assembly 2.420 is .•79••7.7 - I 1 6,667.7 5,749.4 1.38 SEAL Seal Units 2.400 1aerw SC1f V;01 6,717.6 5,799.2 1.50 SLEEVE SLCMU BX Profile 2.313 - - ��. wear sn,s6 '-. 6,733.3 5,814.9 1.47 SEAL ASSY Locator Seal Assembly 2.420 oac ° ro e � � -- 6,734. 5,816.3 1.47 SEAL Seal Units 2.400 ez,e 6 6 745.9 58275 1.46 SHOE Half Mule Shoe 2.440 e.ieeao7. 7,03, £- -- 1 , , . . -. MEAS. Tubing Strings wear s,,WS.,,u r v Tubing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (11/D) String Wt... String... String Top Thrd w<ar. s.,us,,w LOWER ZONE CK 5 3)4 3.430 5,950.2 j 6,746.1 5.827.8 13.50 w<w a,roa,m * ASSEMBLY >ccee.sw9 � � ' wm`'ae4saaa Completion Details IPeftr, 5.377 5,907 wcar sA9as,« Top Depth see. snw a ,- (ND) Top Inc! Nomi... a.txea.snaa e„easo, SAaa- aae.rAa. = cop (nK6) MSS) ( °) it .„, t)satpaon comment ID (in) eX,eNSbn,rAm " 5,950.2 5 1.04 PACKER SC -2 Packer 706-40 4.000 sae . 5,953.9 5,035.8 1.04 EXTENSION Frac Extension 80-40 CK 250 4.800 c az tea SCREEN acs y .�. 5,957.6 5,039.4 1 03 SBR Seal Bore receptacle 80 -40 CK 250 4.000 a1 p rAPPI.e, 3,413 .' 5,981.7 5,063.5 1 01 VALVE Knock Out Isolation Valve G2 Sleeve 3.340 ''''=== \_, I`I: 5,984.4 5,066.2 1 01 VALVE Knock Out Isolation Valve C -2 3.310 Alb. A s rw k 5, 986.2 5,068.0 1 01 XO Crossover 3.430 Mr rISION. SAN - ' 5,987.7 5,069.5 1 02 SOS Shear out Safety Joint 3.420 _ _ 6,083.5 5,165.3 1 12 SCREEN Screen Excluder 2000 3.430 co.as cm _ _ ., 6,123.0 5,204.8 Crossover 3.490 • cioscsots 1 = 1 1.40 XO Crossover 3.490 r i� i 6,134.8 5,216.6 1.40 SBR Seal Bore receptacle 3.250 x9.: 6,137.6 5,219.3 1.40 SCREEN Screen Excluder 2000 3.430 • aaa,� - It '"' 6,216.3 5,298.0 1.35 XO Crossover 3.490 aea.aa9 - wear. as.o. y 6,227.4 5,309.2 1.34 XO Crossover 3.490 us a; e , . 6,228.1 5,309.9 SBR Seal Bore receptacle - -_ 3.250 V o a a,9 � gre. 6,230.9 5,312.6 134 SCREEN Screen Baker Weld 140 3.430 ♦ - \ 6,241.4 5,323.2 1 33 SCREEN Screen Excluder 2000 3.430 PER` a - �0 /` 6,557.0 5,638.7 1.26 XO Crossover 3.470 09 ' 4' 6,568 6,568.2 5,649.8 1.36 XO Crossover 3.470 IPEkr, 15,110.4, " n a 6L_ 1 Al 6,568.7 5,650.4 1.36 SBR Seal Bore receptacle 3.250 . az ' I + 6,571.5 5,653.1 1.36 SCREEN Screen Excluder 2000 3.430 s it ; 6,650.3 5,732.0 1.37 SCREEN Screen Baker Weld 140 3.430 aca. . Jr r7:.7 ::-, a "\. 6,660.9 5,742.5 1.38 XO Crossover 3.470 '76.1t.:1:1--- _ ..�.....,..- ,,.. -- ▪ fv A A . ' 'f 6 ,672.0 1.38 XO Crossover . 3.470 7 f a: ' 4 . 6,672.6 5,754.2 1 38 SBR Seal Bore receptacle 3.250 IPEfir. kW-6 asa7 _ __ ; " 6,675.3 5,756.9 138 SCREEN S creen Excluder 2000 3.430 SUN, 6,561 a 9 _ , � 6,714.8 5,796.4 1 50 XO Cro 3.470 � ; .5. -- \ 6,725.9 5,807.6 1 48 XO Crossover - 3.470 s - ea : -�' ' 4. 6,726.5 5,808.1 1 48 SCREEN Screen Baker Weld 140 3.430 SCAM, as7 + - ' 4 6,737.0 5,818.7 147 Snaplatch Snap latch 82-40 3.250 SCAM; , ► .. 6,738.0 5,819.6' 1 47 SEAL Seal Units 82-40 3.250 SEAL ASSY. �"%`a ; TUBING Production o 1 xq Str 51 O S I S tri n g I T p 688 Depth D .[Strip Wt... String... String 7 3.250 a 9 _ - Tubing pion g 'String v B) pm 1.9 1 a n g 'v Thrd a X0. 6,713 SLen2, b,718 41 .a s n e a 9< � r s wa7=a - emamN92 46,7 . 66 SH 6i:a xue M7s ,: SAK • BRU 232 -23 ConocoPhi "'' (mstatotsaltio KB -GM (0) Rig Release Date •• 18 . 1 01 /12 00 9 > Completion Details IF Ci�ee•' Top Depth (TVD) Top loci Nomi... „ c ,�., Top (ftKB) MB) C) _ Item Description Comment ID (in) „ 6,738.0 5,819.6 1.47 BOT Sump BOT Sump Packer 4.000 NEPPLE,M5 Packer 11 6,740.0 5,821.6 1.47 WLEG WIRELINE ENTRY GUIDE 4.000 _ 6,740.8 5,822.4 1.46 SHOE MULE SHOE 4.930 a,7>FM 1111 Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Ind av,e* - Top jftKB3 (MKB) (") Description Comment, Run Date ID (in) „r.v,s 6,875 5,956.6 1.25 PLUG Bridge Plug - Permanent 9/9/2009 ex. sea n Perforations & Slots sea _ -- ._ -- - -- Shot sae .waa Top (TVD) Btm (TVD) Dens Z., ': e apw Top (ftKB) Ben (ftKB) (ftKB) (ftKB) - - - Zone Deb (h... Type Comment slows ` dsue s ^,®"ei 4,734 4,747 3,821.9 3,834.5 9/29/2009 14.0 IPERF All Shots Fired - Gun OD After Firing µ .p � - k a- e 3.25"/Shot Orifice .5" e P.ara:'g-- ..__ -- _ _ ... W_._. - 4,780 4,793 3,866.7 3,879.4 9/29/2009 14.0 IPE All Shots Fired - Gun OD After Firing ESE " s,aa :Z. --- - -- - 325 " /Shot Or ce .5" MEN... - _._..�. sae .ne � 4,876 4,905 3,960 7 3,989.3 9/29/2009 14 0 IPERF All Slats Fired - Gun OD After Firing 3.25"/Shot Orifice .5" 7Sa0a li 11 4,970 4,981 4,053.4 4,064.3 9/29/2009 14.0 IPERF All Shots Fired - Gun OD After Firing IPERF 4,7114 SCREEN „ 325 " /Shot Orifice .5" IMRE a PERE ..w+ - • P 5,015 5,023 4,098 0 4,105.9 9/29/2009 14.0 IPERF All Shots Fired - Gun OD After Firing :o S3 Tom• 325" /Shot Orifice .5" R EX,Ens 5,100 5,110 4,182.4 4,192.4 9/29/2009 14.0 IPERF All Shots Fired - Gun OD After Firing s EXTENSION. iw - - 3.25"/Shot Orifice .5" c,c NVw.6n6, saE.6„ ... - 4 _�..- 4 ...__ _.. A)I 5,152 5,159 4,2342 4,2412 9/29/2009 14.0 IPERF All Shots Fi red - Gun OD After Firing ,PELF. s,dns,,,6 - -- . . . - -.. 325 " /Shot Orifice .5" ,v ,very 6a6xs,ee :. 1 ._, _ -_.. .�,. PORE 6,1,8.7,,.. 5,176 5,191 4,258.2 4,273.1 92912009 14.0 IPERF All Shots Fired -Gun OD Alter Firing SCREEN. - � . 3 25" /Shot Orifice .5" Sp" SAE ,._.. -_ __. _.. __- ,o8. 5,354 5,366 4,443636.0 0 4,44$ 0 929/2009 - 14.0 IPERF All Shots Fired -Gun OD After firing 7 - ►�4 325 " /Shot Orifice .5" PACKER: SA ._. _. SSE, SA. EXTENSION, EsES 5 5 4 4 9/29/2009 14.0 IPERF All Scotts Fired - Gun OD After Firing EXTENSION, 6Am _._. .... 3 " /snot orifice .5" WINS., 1,711 P E, ssxe +s '~.1s 5,436 5,448 4,517.9 4,529.9 9/29/2009 14.0 IPERF All Shots Fired - Gun OD After Firing »� 3.25"/Shot Orifice .5" it S� 4�: 1 5,629 5,642 4,710.9 4,723.9 9/29/2009 14.0 IPERF All Shots Fired - Gun OD After Firing It 41 3.25"/Shot Orifice .5" DOER., SS � ..„.e. . 5,689 5,733 4 770 9 4 $14.9 9/29/2009 14.0 IPERF All Shots Fired -Gun OD After Firing ,k ,t2 f _ 3.25"/Shot Orifice .5" �n•on .'"6's -- ill/1 5,888 5,914 4,969.8 4995.8 9/29/2009 14.0 IPERF All Shots Fired - Gun OD After Firing o 1 3.25"/Shot Orifice .5" __ P _ s A 6,098 6,118 5 179.8 5 199.8 9/22/2009 14.0 IPERF All Shots Fired - Gun OD After Firing ,, - 3.25"/Shot Orifice .5" : 6,139 6,166 5,220.8 5,247.8 9/22/2009 14.0 IPERF All Shots Fired - Gun OD After Firing - 325" /Shot Orifice .5" NK" 1a - k, 6 scats, 6,144 6,164 5,225.8 5,245.8 9/16/2009 6.0 IPERF All Shots Fired - Gun OD After Firing ,..„ �: 3.25"/Shot Orifice .5" FEW, 8,DisES,111 6,180 6,194 5,261.8 5,275.8 9/22/2009 14.0 IPERF All Shots Fired - Gun OD After Firing i ctl a d; 1 v i 325 " /Shot Orifice .5" • ; " e _ 6,183 6,193 5,264.8 5,274.8 9/16/2009 6.0 IPERF - All Shots Fired - Gun OD After Firing ( 3.25"/Shot Orifice .5" w ,Pa. 6144.80 SS 6,388 6,398 5,469.7 5,479.7 9/22/2009 14.0 IPERF All Shots Fired - Gun OD After Firing OEwe<,d17a l� ,Pew.a,mas.� I ,�: 3.25 " /Shot Orfice .S" el -- - -_ ,_. 7 -- 6,466 6,477 5,547.7 5,55$.7 9/22/2009 14.0 IPERERF All Shots Fired - Gun OD After Firing e+w �_ " , 3.25"/Shot Orifice .5" a e n �r 6,486 6,514 5,567.7 5,595.7 9/22/2009 14.0 IPERF All Shots Fired - Gun OD After Firing sses. daft ,* � 3.25 " /Shot Orifice .5" 8. 1x8, - '' -- - .,..... --,.. - _`__ - -.--- (; 6,492 6,512 5,573.7 5,593.7 9/15/2009 6.0 IPERF All Shots Fired - Gun OD After Firing PERE 4.3. O w ..__ , 4 1 3 25" /Shot Orifice .5" P ▪ ERE a,, as,z� 1 ' 4.. 6,576 6,609 5,657.7 5,690.7 9/22/2009 14.0 IPERF All Shots Fired - Gun OD After Firing IPERE as asn, L■ ' 3.25"/Shot Orifice .5" Y �""'sot - NESS 6,591 6,606 5,672. 5,687. 9/14/20 6 0 IPERF All Shots Fired - Gun OD After Firing SEAL ASV, LEO Nt: m te t ------ __. l� 325' /Shot Orifice ii .5" s 8.- r - w -- ` 6,683 6,709 5,764.6 5,790.6 9/22/2009 14.0 IPERF All Shots Fired - Gun OD After Firing 8.o !� ' 4 1 3.25" /Shot Orifice .5" PERE. w s sus - 71 I� 6,686 6,706 5,767.6 5,787.6 0 IP 7.6 9/13/2009 6 ERF All Shots Fired - Gun OD After Firing a I� 3.25 " /Shot Orifice .5" ", - Notes: General & Safety i x -+-, End Date Annotation SCREEN pS r $ 11/5/2005 NOTE VIEW SCHEMATIC w /Alaska Schematic9.0 P`�w aSa d, 6 ■ � - %8.dwS wens. Ili „ea.aa;i L. .. scwenei3i s 8... 6,7, Ma OM • • Perf Top Perf Base Perf Top Perf Base ft. MD ft. MD ft TVD ft TVD SPF 4734 4747 3821.9 3834.5 14 4780 4793 3866.7 3879.4 14; - 4876 4905:, 3960.7 _ ;- _3989.3 14 _ 4970 _ 4981 4053.4 4064.3 14 5015= 5023 4098.0 4105.9, 14 5100 5110 4182.4 4192.4 14 5152 5159 4234.2 4241.2 14 5176 5191 4258.2 4273.1 14 5354 5366 4436.0 4448.0 14 5377 5387 4459.0 4469.0 14 5436 5448 4517.9 4529.9 14 5629 5642 4710.9 4723.9 14 5689 5733 4770.9 4814.9 14 5888 5914 4969.8 4995.8 14 6098 6118 5179.8 5199.8 14 6139 6166 5220.8 5247.8 14 6180 6194 5261.8 5275.8 14 6388 6398 5469.7 5479.7 14 6466 6477 5547.7 5558.7 14 6486 6514 5567.7 5595.7 14 6576 6609 5657.7 5690.7 14 6683 6709 5764.7 5790.6 14 6144 6164 5225.8 5245.8 6 6183 6193 5264.8 5274.8 6 6492 6512 5573.7 5593.7 6 6591 6606 5672.7 5687.7 6 6686 6706 5767.7 5787.6 6 I • { 3 I. 3 ConocoPhillips(Alaska) Inc. Beluga River Beluga River BRU 232 -23 502832013300 Sperry Drilling Services ti a _ Definitive Survey Report 09 September, 2009 HALLIBURTON 3. ,2 !f . } } � 7 { * f Sperry Drilling Services 111 III ConocoPhillips • Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well BRU 232 -23 Project Beluga River TVD Reference: BRU 232 -23 (18.5 +78) @ 96.50ft (Arctic Fox) Site: Beluga River MD Reference: BRU 232 -23 (18.5 +78) @ 96.50ft (Arctic Fox) Well: BRU 232 -23 North Reference: True Wellbore: BRU 232 -23 Survey Calculation Method: Minimum Curvature Design: BRU 232 -23 Database: CPAI EDM Production Project Beluga River 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 BRU 232 -23 Well Position +N / -S 0.00 ft Northing: 2,633,528.63ft Latitude: 61° 12' 15.917 N +E/ -W 0.00 ft Easting: 323,387.57 ft Longitude: 151° 0' 5.148 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 78.00ft Wellbore BRU 232 -23 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ( (nT) BGGM2007 7/31/2009 18.74 74.00 55,702 Design BRU 232 -23 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 18.50 Vertical Section: Depth From (TVD) +N/-S +E/ W Direction (ft) (ft) (ft) ( 18.50 0.00 0.00 280.00 Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 163.73 343.30 BRU 232 -23 (INC only) (BRU 232 -23) INC Inclinometer (Totco/Teledrift) 7/31/2009 1; 399.76 7,505.36 BRU 232 -23 MWD (BRU 232 -23) MWD +SCC +SAG MWD + Short Collar correction + BHA SAG Co 7/31/2009 1; Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/ -W Northing Easting DLS Section Survey Tool Name (ft) ( ( (ft) (ft) (ft) (ft) (ft) (ft) l /100•) (ft) 18.50 0.00 0.00 18.50 -78.00 0.00 0.00 2,633,528.63 323,387.57 0.00 0.00 UNDEFINED 163.73 0.64 140.01 163.73 67.23 -0.62 0.52 2,633,528.01 323,388.08 0.44 -0.62 INC (1) 219.00 0.67 140.89 218.99 122.49 -1.10 0.92 2,633,527.52 323,388.47 0.06 -1.09 INC (1) 280.63 0.39 148.42 280.62 184.12 -1.56 1.25 2,633,527.05 323,388.80 0.46 -1.50 INC (1) 343.30 1.20 295.01 343.29 246.79 -1.46 0.77 2,633,527.16 323,388.32 2.46 -1.01 INC (1) 399.76 2.18 291.35 399.72 303.22 -0.82 -0.76 2,633,527.82 323,386.80 1.74 0.61 MWD +SCC +SAG (2) 454.60 3.31 290.99 454.50 358.00 0.12 -3.21 2,633,528.80 323,384.37 2.06 3.18 MWD +SCC +SAG (2) 521.76 4.74 285.43 521.49 424.99 1.56 -7.69 2,633,530.30 323,379.90 2.22 7.85 MWD +SCC +SAG (2) 581.83 5.74 278.06 581.31 484.81 2.64 -13.06 2,633,531.47 323,374.56 2.00 13.32 MWD +SCC +SAG (2) 641.05 7.38 276.16 640.14 543.64 3.46 -19.77 2,633,532.39 323,367.85 2.80 20.08 MWD +SCC +SAG (2) 700.98 8.89 275.69 699.46 602.96 4.33 -28.21 2,633,533.40 323,359.43 2.53 28.54 MWD +SCC +SAG (2) 761.83 10.28 275.52 759.46 662.96 5.32 -38.30 2,633,534.54 323,349.36 2.27 38.64 MWD +SCC +SAG (2) 826.82 11.44 273.95 823.29 726.79 6.32 -50.50 2,633,535.73 323,337.18 1.85 50.83 MWD +SCC +SAG (2) 9/9/2009 1:04:45PM Page 2 COMPASS 2003.16 Build 69 0 • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well BRU 232 -23 Project Beluga River TVD Reference: BRU 232 -23 (18.5 +78) c@ 96.50ft (Arctic Fox) Site: Beluga River MD Reference: BRU 232 -23 (18.5 +78) @ 96.50ft (Arctic Fox) Well: BRU 232 - 23 North Reference: True Weilbore: BRU 232 - 23 Survey Calculation Method: Minimum Curvature Design: BRU 232 - 23 Database: CPAI EDM Production Survey . Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/ -W Northing Easting DLS Section (ft) (1 (1 (ft) (ft) (ft) (ft) (ft) (ft) (1100') (ft) Survey Tool Name 888.71 13.08 273.66 883.76 787.26 7.19 -63.62 2,633,536.80 323,324.08 2.65 63.90 MWD +SCC +SAG (2) 952.07 15.18 272.87 945.20 848.70 8.07 -79.06 2,633,537.91 323,308.65 3.32 79.26 MWD +SCC +SAG (2) 1,016.52 16.82 271.77 1,007.16 910.66 8.78 -96.81 2,633,538.89 323,290.92 2.59 96.86 MWD +SCC +SAG (2) 1,077.46 18.48 270.55 1,065.23 968.73 9.14 - 115.28 2,633,539.54 323,272.46 2.79 115.11 MWD +SCC +SAG (2) 1,144.36 20.43 269.96 1,128.30 1,031.80 9.24 - 137.56 2,633,539.97 323,250.18 2.93 137.07 MWD +SCC +SAG (2) 1,204.74 22.45 270.06 1,184.50 1,088.00 9.24 - 159.63 2,633,540.32 323,228.12 3.35 158.81 MWD +SCC +SAG (2) 1,271.87 24.49 271.22 1,246.08 1,149.58 9.55 - 186.36 2,633,541.03 323,201.39 3.11 185.19 MWD +SCC +SAG (2) 1,335.86 26.50 272.22 1,303.83 1,207.33 10.39 - 213.88 2,633,542.29 323,173.89 3.21 212.44 MWD +SCC +SAG (2) 1,394.88 28.53 272.27 1,356.17 1,259.67 11.46 - 241.13 2,633,543.78 323,146.66 3.46 239.45 MWD +SCC +SAG (2) I 1,459.61 30.47 272.61 1,412.51 1,316.01 12.82 - 272.98 2,633,545.63 323,114.84 3.00 271.05 MWD +SCC +SAG (2) 1,522.29 32.20 272.64 1,466.04 1,369.54 14.31 - 305.54 2,633,547.62 323,082.31 2.76 303.38 MWD +SCC +SAG (2) 1,584.99 33.78 272.25 1,518.63 1,422.13 15.77 - 339.65 2,633,549.60 323,048.23 2.54 337.22 MWD +SCC +SAG (2) 1,649.40 35.35 271.02 1,571.67 1,475.17 16.80 - 376.17 2,633,551.19 323,011.73 2.67 373.37 MWD +SCC +SAG (2) 1,712.74 37.11 271.25 1,622.76 1,526,26 17.54 - 413.60 2,633,552.50 322,974.32 2.79 410.36 MWD +SCC +SAG (2) 1,776.21 38.92 271.42 1,672.76 1,576.26 18.45 - 452.68 2,633,554.01 322,935.26 2.86 449.01 MWD +SCC +SAG (2) 1,839.41 40.59 272.16 1,721.35 1,624.85 19.71 - 493.08 2,633,555.89 322,894.89 2.74 489.01 MWD +SCC +SAG (2) 1,902.96 42.88 272.58 1,768.77 1,672.27 21.47 - 535.34 2,633,558.29 322,852.66 3.62 530.93 MWD +SCC +SAG (2) 1,967.03 45.68 273.08 1,814.64 1,718.14 23.68 - 580.01 2,633,561.19 322,808.03 4.41 575.31 MWD +SCC +SAG (2) 2,030.57 47.45 273.48 1,858.32 1,761.82 26.32 - 626.07 2,633,564.54 322,762.02 2.83 621.13 MWD +SCC +SAG (2) 2,092.23 49.18 272.97 1,899.32 1,802.82 28.91 - 672.05 2,633,567.83 322,716.09 2.87 666.86 MWD +SCC +SAG (2) 2,156.58 50.57 273.31 1,940.79 1,844.29 31.60 - 721.18 2,633,571.27 322,667.01 2.20 715.71 MWD +SCC +SAG (2) 2,218.82 51.25 272.58 1,980.03 1,883.53 34.08 - 769.42 2,633,574.49 322,618.81 1.42 763.65 MWD +SCC +SAG (2) 2,284.19 52.04 271.73 2,020.60 1,924.10 36.00 - 820.65 2,633,577.20 322,567.63 1.57 814.43 MWD +SCC +SAG (2) 2,349.30 52.61 271.66 2,060.39 1,963.89 37.52 - 872.16 2,633,579.51 322,516.15 0.89 865.42 MWD +SCC +SAG (2) 2,406.48 52.45 271.42 2,095.18 1,998.68 38.75 - 917.52 2,633,581.42 322,470.81 0.43 910.31 MWD +SCC +SAG (2) 2,475.03 51.66 271.20 2,137.33 2,040.83 39.98 - 971.57 2,633,583.49 322,416.79 1.19 963.75 MWD +SCC +SAG (2) 2,539.12 51.20 271.57 2,177.29 2,080.79 41.19 - 1,021.66 2,633,585.46 322,366.73 0.85 1,013.29 MWD +SCC +SAG (2) 2,602.20 51.23 271.50 2,216.80 2,120.30 42.51 - 1,070.81 2,633,587.53 322,317.61 0.11 1,061.93 MWD +SCC +SAG (2) 2,666.16 51.74 271.44 2,256.63 2,160.13 43.79 - 1,120.84 2,633,589.58 322,267.60 0.80 1,111.42 MWD +SCC +SAG (2) 2,729.56 52.22 272.50 2,295.68 2,199.18 45.51 - 1,170.76 2,633,592.07 322,217.72 1.52 1,160.88 MWD +SCC +SAG (2) 2,792.01 51.66 271.49 2,334.18 2,237.68 47.23 - 1,219.90 2,633,594.53 322,168.62 1.56 1,209.57 MWD +SCC +SAG (2) 2,854.41 52.43 272.29 2,372.56 2,276.06 48.85 - 1,269.07 2,633,596.91 322,119.48 1.60 1,258.27 MWD +SCC +SAG (2) 2,917.80 51.81 271.85 2,411.48 2,314.98 50.65 - 1,319.07 2,633,599.48 322,069.52 1.11 1,307.83 MWD +SCC +SAG (2) 2,982.11 52.00 271.52 2,451.16 2,354.66 52.14 - 1,369.66 2,633,601.74 322,018.96 0.49 1,357.91 MWD +SCC +SAG (2) 3,045.55 52.48 271.78 2,490.00 2,393.50 53.59 - 1,419.80 2,633,603.96 321,968.86 0.81 1,407.53 MWD +SCC +SAG (2) 3,108.60 52.13 271.52 2,528.56 2,432.06 55.02 - 1,469.67 2,633,606.15 321,919.02 0.64 1,456.89 MWD +SCC +SAG (2) 3,171.34 51.56 270.23 2,567.31 2,470.81 55.78 - 1,519.00 2,633,607.66 321,869.71 1.85 1,505.60 MWD +SCC +SAG (2) 3,235.68 51.16 269.23 2,607.49 2,510.99 55.54 - 1,569.25 2,633,608.20 321,819.46 1.37 1,555.06 MWD +SCC +SAG (2) I 3,299.40 49.88 269.25 2,648.00 2,551.50 54.89 - 1,618.43 2,633,608.30 321,770.28 2.01 1,603.37 MWD +SCC +SAG (2) 3,362.58 50.30 269.68 2,688.53 2,592.03 54.44 - 1,666.89 2,633,608.59 321,721.82 0.84 1,651.02 MWD +SCC +SAG (2) 9/9/2009 1:04:45PM Page 3 COMPASS 2003.16 Build 69 • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well BRU 232 -23 Project Beluga River TVD Reference: BRU 232 -23 (18.5 +78) @ 96.50ft (Arctic Fox) Site: Beluga River MD Reference: BRU 232 -23 (18.5 +78) @ 96.50ft (Arctic Fox) Well: BRU 232 - 23 North Reference: True Wellbore: BRU 232 - 23 Survey Calculation Method: Minimum Curvature Design: BRU 232 - 23 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) 01001 (ft) Survey Tool Name 3,427.18 49.54 269.46 2,730.13 2,633.63 54.07 - 1,716.32 2,633,608.98 321,672.40 1.20 1,699.63 MWD +SCC +SAG (2) 3,489.63 47.23 268.54 2,771.60 2,675.10 53.26 - 1,763.00 2,633,608.88 321,625.71 3.87 1,745.46 MWD +SCC +SAG (2) 3,552.75 45.64 267.75 2,815.10 2,718.60 51.78 - 1,808.71 2,633,608.11 321,579.99 2.67 1,790.22 MWD +SCC +SAG (2) 3,616.54 44.54 268.64 2,860.13 2,763.63 50.36 - 1,853.86 2,633,607.38 321,534.83 1.99 1,834.44 MWD +SCC +SAG (2) 3,677.50 42.72 269.70 2,904.26 2,807.76 49.75 - 1,895.91 2,633,607.41 321,492.77 3.21 1,875.75 MWD +SCC +SAG (2) 3,704.77 42.06 270.47 2,924.40 2,827.90 49.77 - 1,914.29 2,633,607.71 321,474.39 3.09 1,893.85 MWD +SCC +SAG (2) 3,787.20 41.01 269.93 2,986.10 2,889.60 49.97 - 1,968.95 2,633,608.75 321,419.75 1.34 1,947.71 MWD +SCC +SAG (2) 3,851.22 38.91 270.17 3,035.17 2,938.67 50.00 - 2,010.06 2,633,609.41 321,378.64 3.29 1,988.21 MWD +SCC +SAG (2) 3,908.70 36.71 270.40 3,080.58 2,984.08 50.17 - 2,045.30 2,633,610.12 321,343.42 3.84 2,022.94 MWD +SCC +SAG (2) 3,972.05 34.83 270.47 3,131.98 3,035.48 50.46 - 2,082.32 2,633,610.97 321,306.40 2.97 2,059.45 MWD +SCC +SAG (2) 4,027.23 32.55 270.05 3,177.89 3,081.39 50.60 - 2,112.92 2,633,611.58 321,275.81 4.14 2,089.61 MWD +SCC +SAG (2) 4,103.49 30.35 269.61 3,242.95 3,146.45 50.48 - 2,152.71 2,633,612.08 321,236.03 2.90 2,128.77 MWD +SCC +SAG (2) 4,158.46 29.28 269.07 3,290.64 3,194.14 50.17 - 2,180.04 2,633,612.18 321,208.70 2.01 2,155.63 MWD +SCC +SAG (2) 4,227.62 28.02 269.14 3,351.33 3,254.83 49.65 - 2,213.20 2,633,612.17 321,175.54 1.82 2,188.19 MWD +SCC +SAG (2) 4,287.02 26.74 268.66 3,404.07 3,307.57 49.13 - 2,240.51 2,633,612.06 321,148.22 2.19 2,215.00 MWD +SCC +SAG (2) 4,346.64 25.10 269.74 3,457.70 3,361.20 48.75 - 2,266.56 2,633,612.09 321,122.17 2.87 2,240.60 MWD +SCC +SAG (2) 4,414.44 23.31 269.46 3,519.53 3,423.03 48.56 - 2,294.36 2,633,612.33 321,094.37 2.63 2,267.94 MWD +SCC +SAG (2) 4,477.60 21.50 270.95 3,577.92 3,481.42 48.64 - 2,318.43 2,633,612.77 321,070.31 3.00 2,291.66 MWD +SCC +SAG (2) 4,539.27 19.68 271.36 3,635.65 3,539.15 49.07 - 2,340.12 2,633,613.54 321,048.63 2.96 2,313.09 MWD +SCC +SAG (2) 4,603.40 18.05 270.43 3,696.33 3,599.83 49.40 - 2,360.85 2,633,614.18 321,027.91 2.59 2,333.56 MWD +SCC +SAG (2) 4,667.14 16.10 271.42 3,757.26 3,660.76 49.70 - 2,379.56 2,633,614.76 321,009.21 3.09 2,352.04 MWD +SCC +SAG (2) 4,734.72 13.66 269.82 3,822.57 3,726.07 49.90 - 2,396.91 2,633,615.24 320,991.86 3.66 2,369.16 MWD +SCC +SAG (2) 4,767.82 13.01 269.25 3,854.78 3,758.28 49.84 - 2,404.55 2,633,615.29 320,984.23 2.00 2,376.67 MWD +SCC +SAG (2) 4,832.08 11.36 270.73 3,917.59 3,821.09 49.83 - 2,418.11 2,633,615.49 320,970.67 2.61 2,390.02 MWD +SCC +SAG (2) 4,893.46 10.29 268.13 3,977.87 3,881.37 49.73 - 2,429.63 2,633,615.56 320,959.15 1.92 2,401.35 MWD +SCC +SAG (2) 4,956.27 8.82 267.98 4,039.81 3,943.31 49.37 - 2,440.05 2,633,615.37 320,948.72 2.34 2,411.56 MWD +SCC +SAG (2) 5,012.62 7.53 270.54 4,095.59 3,999.09 49.26 - 2,448.06 2,633,615.37 320,940.71 2.38 2,419.42 MWD +SCC +SAG (2) 5,080.06 5.79 274.05 4,162.57 4,066.07 49.54 - 2,455.87 2,633,615.78 320,932.91 2.65 2,427.17 MWD +SCC +SAG (2) 5,145.53 4.50 274.55 4,227.77 4,131.27 49.98 - 2,461.73 2,633,616.30 320,927.06 1.97 2,433.01 MWD +SCC +SAG (2) 5,176.41 3.59 268.85 4,258.58 4,162.08 50.05 - 2,463.90 2,633,616.41 320,924.89 3.22 2,435.16 MWD +SCC +SAG (2) 5,208.59 2.89 267.82 4,290.71 4,194.21 50.00 - 2,465.72 2,633,616.39 320,923.07 2.18 2,436.94 MWD +SCC +SAG (2) 5,270.07 2.72 263.05 4,352.11 4,255.61 49.77 - 2,468.72 2,633,616.20 320,920.07 0.47 2,439.85 MWD +SCC +SAG (2) 5,335.19 2.04 245.71 4,417.18 4,320.68 49.10 - 2,471.31 2,633,615.58 320,917.47 1.51 2,442.29 MWD +SCC +SAG (2) 5,399.00 1.82 238.95 4,480.95 4,384.45 48.11 - 2,473.21 2,633,614.61 320,915.55 0.50 2,443.99 MWD +SCC +SAG (2) 5,461.32 1.93 238.44 4,543.24 4,446.74 47.05 - 2,474.95 2,633,613.58 320,913.79 0.18 2,445.52 MWD +SCC +SAG (2) 5,526.29 1.70 238.45 4,608.17 4,511.67 45.98 - 2,476.71 2,633,612.53 320,912.02 0.35 2,447.06 MWD +SCC +SAG (2) 5,588.69 0.28 223.47 4,670.56 4,574.06 45.38 - 2,477.60 2,633,611.95 320,911.12 2.29 2,447.84 MWD +SCC +SAG (2) 5,650.26 0.76 100.37 4,732.13 4,635.63 45.20 - 2,477.30 2,633,611.76 320,911.41 1.53 2,447.51 MWD +SCC +SAG (2) 5,713.87 0.98 84.08 4,795.73 4,699.23 45.18 - 2,476.35 2,633,611.73 320,912.37 0.52 2,446.57 MWD +SCC +SAG (2) 5,776.30 0.94 88.32 4,858.16 4,761.66 45.25 - 2,475.30 2,633,611.78 320,913.41 0.13 2,445.55 MWD +SCC +SAG (2) 9/9/2009 1:04:45PM Page 4 COMPASS 2003.16 Build 69 • • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well BRU 232 -23 Project Beluga River TVD Reference: BRU 232 -23 (18.5 +78) © 96.50ft (Arctic Fox) Site: Beluga River MD Reference: BRU 232 -23 (18.5 +78) @ 96.50ft (Arctic Fox) Well: BRU 232 - 23 North Reference: True Wellbore: BRU 232 - 23 Survey Calculation Method: Minimum Curvature Design: BRU 232 - 23 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (ft) ( ( (ft) (ft) (ft) (ft) (ft) (ft) (°H00') (ft) Survey Tool Name 5,839.79 1.20 91.64 4,921.63 4,825.13 45.24 - 2,474.12 2,633,611.76 320,914.60 0.42 2,444.39 MWD +SCC +SAG (2) 5,902.95 1.06 89.42 4,984.78 4,888.28 45.23 - 2,472.87 2,633,611.73 320,915.84 0.23 2,443.16 MWD +SCC +SAG (2) 5,965.83 1.03 101.77 5,047.65 4,951.15 45.12 - 2,471.74 2,633,611.60 320,916.98 0.36 2,442.02 MWD +SCC +SAG (2) 6,027.92 1.06 108.94 5,109.73 5,013.23 44.82 - 2,470.65 2,633,611.29 320,918.06 0.22 2,440.90 MWD +SCC +SAG (2) 6,091.19 1.13 113.24 5,172.99 5,076.49 44.39 - 2,469.52 2,633,610.83 320,919.18 0.17 2,439.71 MWD +SCC +SAG (2) 6,155.60 1.39 105.05 5,237.38 5,140.88 43.93 - 2,468.18 2,633,610.36 320,920.51 0.49 2,438.31 MWD +SCC +SAG (2) 6,215.50 1.36 109.75 5,297.27 5,200.77 43.50 - 2,466.81 2,633,609.91 320,921.88 0.19 2,436.89 MWD +SCC +SAG (2) 6,282.47 1.28 114.84 5,364.22 5,267.72 42.92 - 2,465.39 2,633,609.30 320,923.29 0.21 2,435.38 MWD +SCC +SAG (2) 6,372.27 1.18 112.66 5,454.00 5,357.50 42.14 - 2,463.62 2,633,608.50 320,925.04 0.12 2,433.51 MWD +SCC +SAG (2) 6,435.36 1.23 112.33 5,517.07 5,420.57 41.64 - 2,462.40 2,633,607.97 320,926.26 0.08 2,432.22 MWD +SCC +SAG (2) 6,498.16 1.34 119.61 5,579.86 5,483.36 41.02 - 2,461.13 2,633,607.34 320,927.51 0.31 2,430.87 MWD +SCC +SAG (2) 6,547.16 1.25 127.67 5,628.85 5,532.35 40.41 - 2,460.21 2,633,606.71 320,928.43 0.41 2,429.85 MWD +SCC +SAG (2) 6,561.96 1.26 128.59 5,643.64 5,547.14 40.21 - 2,459.96 2,633,606.51 320,928.68 0.15 2,429.57 MWD +SCC +SAG (2) 6,624.71 1.37 128.77 5,706.38 5,609.88 39.31 - 2,458.83 2,633,605.59 320,929.79 0.18 2,428.30 MWD +SCC +SAG (2) 6,687.42 1.38 124.29 5,769.07 5,672.57 38.41 - 2,457.63 2,633,604.68 320,930.98 0.17 2,426.96 MWD +SCC +SAG (2) 6,751.73 1.45 120.02 5,833.36 5,736.86 37.57 - 2,456.28 2,633,603.81 320,932.31 0.20 2,425.49 MWD +SCC +SAG (2) 6,819.05 1.36 117.97 5,900.66 5,804.16 36.77 - 2,454.84 2,633,602.99 320,933.74 0.15 2,423.93 MWD +SCC +SAG (2) 6,876.78 1.25 123.37 5,958.37 5,861.87 36.10 - 2,453.71 2,633,602.31 320,934.86 0.29 2,422.70 MWD +SCC +SAG (2) 6,938.53 1.33 121.71 6,020.11 5,923.61 35.35 - 2,452.54 2,633,601.54 320,936.03 0.14 2,421.41 MWD +SCC +SAG (2) 7,004.25 1.24 120.97 6,085.81 5,989.31 34.59 - 2,451.28 2,633,600.75 320,937.27 0.14 2,420.04 MWD +SCC +SAG (2) 7,061.00 1.16 127.51 6,142.55 6,046.05 33.92 - 2,450.29 2,633,600.07 320,938.24 0.28 2,418.96 MWD +SCC +SAG (2) 7,129.11 1.13 130.06 6,210.65 6,114.15 33.07 - 2,449.23 2,633,599.21 320,939.29 0.09 2,417.77 MWD +SCC +SAG (2) 7,190.94 1.13 138.59 6,272.46 6,175.96 32.22 - 2,448.36 2,633,598.34 320,940.15 0.27 2,416.76 MWD +SCC +SAG (2) 7,254.05 1.20 138.44 6,335.56 6,239.06 31.26 - 2,447.51 2,633,597.37 320,940.98 0.11 2,415.76 MWD +SCC +SAG (2) 7,319.27 1.16 133.39 6,400.77 6,304.27 30.29 - 2,446.58 2,633,596.39 320,941.90 0.17 2,414.67 MWD +SCC +SAG (2) 7,380.36 1.30 133.05 6,461.84 6,365.34 29.40 - 2,445.63 2,633,595.48 320,942.84 0.23 2,413.58 MWD +SCC +SAG (2) 7,444.25 1.37 135.37 6,525.72 6,429.22 28.36 - 2,444.56 2,633,594.42 320,943.89 0.14 2,412.34 MWD +SCC +SAG (2) 7,505.36 1.47 134.53 6,586.81 6,490.31 27.29 - 2,443.49 2,633,593.34 320,944.95 0.17 2,411.10 MWD +SCC +SAG (2) 7,587.00 1.47 134.53 6,668.42 6,571.92 25.82 - 2,441.99 2,633,591.85 320,946.42 0.00 2,409.38 PROJECTED to TD 9/9/2009 1:04:45PM Page 5 COMPASS 2003.16 Build 69 • • Conoco hiIIips Time Log & Summary WeOview Web Reporting Report Well Name: BRU 232 -23 Rig Name: DOYON ARCTIC FOX Job Type: DRILLING ORIGINAL Rig Accept: 7/30/2009 12:01:00 AM Rig Release: 10/7/2009 12:00:00 PM Time Logs Date From To Dur S. Deoth E. Deoth Phase Code Subcode ; T Comment 07/30/2009 Rig accepted 00:00 hrs 7/30/2009. Change out Knife valve. Load & test all mud lines to 2000 PSI. Cleanout conductor to 92'. Perform Diverter function test - witnessed by AOGCC rep Lou Grimaldi. Continue RU calibrate Totco equipment. Function test pipe skate. Held PJSM & pick up, rack back 104 joints 5" DP, and 20 joints of 5" HWDP. Calibrate blocks with Sperry Sun MWD. 00:00 02:30 2.50 0 0 MIRU RISER RURD P Rig accepted 00:00 hrs 7/30/2009. Change out Knife valve. Function test. load riser with water and check for leaks. 02:30 04:30 2.00 0 0 MIRU DRILL RURD P Load & test mud line, and valves to 2000 PSI. Repair leaking valves. 04:30 06:00 1.50 0 92 MIRU DRILL FCO P MU 12 1/4" Bit with 5" DP & Clean out 20" Conductor to 92' from Rotary Table. Displace with water. Crew Change 06:00 10:00 4.00 92 92 MIRU RISER BOPE P Drain stack for test. Calibrate Totco RPM & Torque sensors. Perform diverter function test. Knife valve closed in 3 seconds, with full closure of Annular in 35 Seconds. Starting pressure = 3025 PSI. First 200 PSI - 14 Seconds, and full pressure in 1 min 16 seconds. Nitrogen bottle avg pressure = 2200 PSI. Test witnessed by AOGCC rep Lou Grimaldi. 10:00 13:30 3.50 92 92 MIRU RISER RURD P Add 23' buoy line section to existing line as per AOGCC rep. Total length = 133', considering existing ignition source on PAD. 13:30 14:45 1.25 92 92 MIRU DRILL FCO P Breakout & lay down 12 1/4" Bit. Rack back one stand. Lay down 1 joint. 14:45 16:00 1.25 92 92 MIRU DRILL RURD P Re- calibrate Totco RPM & Torque sensors. Function test pipe skate. Repair Hydraulic leak. Repair Tong torque gauges. 16:00 16:15 0.25 92 92 MIRU DRILL SFTY P Held PJSM. Discuss safety & hazard recognition issues. Discuss procedure to pick up and rack back stands in the derrick. 16:15 17:15 1.00 92 92 MIRU DRILL RURD P Recalibrate Sperry Sun Block Height & Depth. 17:15 18:00 0.75 92 92 MIRU DRILL RURD P Change out rig tong gauge line. Troubleshoot draw works cooling pump gauge. Crew Change Page 1 of 64 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 92 92 MIRU DRILL PULD P Pick up and rack back 104 joints of 5" drill pipe with SLM. 07/31/2009 Load Drill Collars, PU 12 1/4" Spud BHA. Test lines to 2200 PSI after repairs. Cleanout conductor to 92'. Well spudded @ 1200 HRS. Directional drill from 92' to 876' as per plan. Back ream each stand. 00:00 01:45 1.75 92 92 MIRU DRILL PULD P Pick up and rack back 20 joints of 5" HWDP. Obtain SLM in derrick. 01:45 02:45 1.00 92 92 MIRU DRILL PULD P Clean & Clear rig floor area. PU handling equipment for BHA. Load Drill collars in shed. Strap same. 02:45 06:00 3.25 92 92 SURFA( DRILL PULD P Make up BHA, standing back in derrick. Crew Change 06:00 07:00 1.00 92 92 SURFA( DRILL RURD P Perform test on Mud line to 2200 PSI. Repair torque gauges. 07:00 09:30 2.50 92 92 SURFA( DRILL PULD P Continue MU remaining BHA including motor, Stabilizer, with 12 1/4" Hughes MXLIX bit. TFA - .699. 09:30 11:30 2.00 92 92 SURFA( DRILL RGRP T Change out Top Drive grabber dies, while trouble shoot Top Drive Hydraulic system. 11:30 12:00 0.50 92 92 SURFA( DRILL CIRC P Circulate down cleaning out 20" conductor to 92'. 12:00 14:00 2.00 92 220 SURFA( DRILL DRLG P Spud well @ 1200 HRS. Drill from 92' - 220'. ART = 1.71 HRS. 14:00 14 :15 0.25 220 220 SURFA( DRILL CIRC P Circulate hole clean with pumps at 80 SPM - 500 PSI. 14:15 15:00 0.75 220 220 SURFA( DRILL TRIP P POOH from 220' standing back 3 stands HWDP. Breakout & lay down XO, clear floor area. 15:00 15:30 0.50 220 220 SURFA( DRILL SFTY P HELD PJSM. Discuss safety & hazard recognition issues. Discuss procedure to make up MWD assembly. 15:30 16:30 1.00 220 220 SURFA( DRILL PULD P Make up remaining BHA picking up DM, DGR /EWR, TM, & UBHO sub. Orient Mud motor as per DD & MWD reps. 16:30 17:00 0.50 220 220 SURFA( DRILL PULD P Plug in and Upload MWD assembly. 17:00 17:30 0.50 220 220 SURFA( DRILL TRIP P Trip back in hole with BHA & flex DC's. to 220' MD. 17:30 00:00 6.50 220 876 SURFA( DRILL DDRL P Continue drill ahead from 220' - 876'. TVD = 871'. Drill with lower pump rates to begin KO and maintain parameters as per plan. Drill with 15K WOB, 450 GPM's and 500 -1000 PSI. ADT = 4.47 HRS, AST = 1.04 HRS. Bit & Jar HRS - 4.47. UP WT = 75K, SO WT = 69K, ROT WT = 72K. 08/01/2009 Continue directional drill from 876' to 2143' MD. TVD = 1932'. BROOH 6 stands for planned wiper trip, continuing to POOH on elevators. Observed good hole. Service Top Drive & Drawworks. TIH to 1572'. Observed proper hole fill. 00:00 03:15 3.25 876 1,192 SURFA( DRILL DDRL P Continue directional drill from 876' to 1192' MD. ADT = 2.49 HRS, AST = 1.72 HRS. ART = .77 HRS. 50 RPM's, WOB - 15K. Back ream each stand before connection. Page2of64 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 06:00 2.75 1,192 570 SURFA( DRILL WPRT P Circulate bottoms up, and pump out of hole for planned wiper trip to 570'. Observed 15K - 25K overpull when attempting to POOH on elevators. Pump out at 365 GPM's - 1150 PSI. Crew Change 06:00 07:00 1.00 570 570 SURFA( DRILL SVRG P Service Top Drive & Draw works. 07:00 08:00 1.00 570 214 SURFA( DRILL TRIP T POOH from 570' - 214'. Clean rig floor area. Change out Top Drive grabber dies & keeper bolts. 08:00 10:00 2.00 214 1,192 SURFA( DRILL TRIP P Trip in hole from 214' to 1131' . Observed proper displacement & good hole. Wash & ream from 1131' back to bottom @ 1192' MD. 10:00 12:00 2.00 1,192 1,445 SURFA( DRILL DDRL P Continue directional drill surface hole from 1192' - 1445' MD. TVD = 1400'. ADT = .73 HRS, ART = .46 HRS, AST = .27 HRS. 12:00 18:15 6.25 1,445 2,143 SURFA( DRILL DDRL P Continue directional drill surface hole from 1445' - 2143' MD. TVD = 1932'. ADT = 2.89 HRS, ART = 1.96 HRS, AST = .93 HRS. Total Bit & Jar Hrs - 9.58 Crew Change 18:15 22:30 4.25 2,143 825 SURFA( DRILL WPRT P BROOH for wiper trip from 2143' - 1825'. Circulate a bottoms up and POOH on elevators from 1825' - 825'. Pumps at 500 GPM's - 1240 PSI while BROOH. Oberved proper displacement. No Hole issues. 22:30 23:00 0.50 825 825 SURFA( DRILL OTHR P Service rig & Top Drive. 23:00 23:30 0.50 825 825 SURFA( DRILL RGRP T Trouble shoot problems with rig air system. Clean out air lines on Draw works, and in MIND air lines. Observed lines packed with desecant material from air dryer. Function test lines after cleanout. 23:30 00:00 0.50 825 1,572 SURFA( DRILL TRIP P Trip back in hole from 825 - 1572' observing proper displacement. 08/02/2009 directional Continue BROOH ds for planned wiper trip @ 3158' MD, continuing to • Observed .... hole. Total Jar & Bit HRS = 20.85. 00:00 00:30 0.50 1,572 2,143 SURFA( DRILL TRIP P Continue trip back in hole after short trip from 1572' - 2143' MD. Observed proper displacement & clean hole conditions. 00:30 12:00 11.50 2,143 2,396 SURFA( DRILL DDRL P Continue directional drill surface hole from 2143' - 2936' MD. ND = 2421'. AVG ROP = 69 Ft/HR ADT = 5.86 HRS, ART = 4.47 HRS, AST = 1.39 HRS. Total Bit & Jar Hrs - 15.44. PU WT = 115K, SO WT = 70K, ROT WT = 90K. Crew Change @ 0600 HRS Page 3 of 64 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 15:15 3.25 2,396 3,158 SURFA( DRILL DDRL P Continue directional drill surface hole from 2936' - 3158' MD. TVD = 2559'. AVG ROP = 68 Ft/HR ADT = 1.92 HRS, ART = 1.58 HRS, AST = .34 HRS. Total Bit & Jar Hrs - 17.36. PU WT= 118K,SOWT= 71K, ROT WT = 92K. 15:15 16:30 1.25 3,158 2,841 SURFA( DRILL REAM P BROOH from 3158' - 2841' MD with pumps at 550 GPM's - 1600 PSI, for planned wiper trip. 16:30 17:15 0.75 2,841 2,841 SURFA( DRILL CIRC P Circulate bottoms up while reciprocate & rotate drill string. Monitor well - static. 17:15 18:30 1.25 2,841 2,143 SURFA( DRILL TRIP P Trip out of hole on elevators from 2841' - 2143' MD, with no excessive pull. Observed good clean hole conditions. Crew Change @ 1800 HRS. 18:30 19:15 0.75 2,143 3,158 SURFA( DRILL TRIP P Trip back in hole from 2143' - 3158' MD with no issues, observing proper displacement. 19:15 00:00 4.75 3,158 3,349 SURFA( DRILL DDRL P Continue directional drill surface hole from 3158' - 3349' MD. TVD = 2679'. AVG ROP = 40 Ft/HR ADT = 3.28 HRS, ART = 2.40 HRS, AST = .88 HRS. Total Bit & Jar Hrs - 20.85. PU WT= 118K,SOWT =71K, ROT WI = 92K. SIMOPS: Prep 9 5/8" casing for upcoming run. 08/03/2009 Continue directional drill from 3349' - 3755' MD. TVD = 2962 ". Circulate bottoms up 3 times at 550 GPMs- 1850 PSI. Reciprocate & rotate drill string. BROOH from 3755' - 3440' MD. Observed good hole, continue POOH on elevators back to HWDP - 814 ". Work through spots at 3350' - 3249. Monitor well. Trip back in hole to TD. Circulate & condition mud for upcoming casing run. 00:00 12:00 12.00 3,349 3,755 SURFA( DRILL DDRL P Continue directional drill surface hole from 3349' - 3755' MD. TVD = 2962'. AVG ROP = 54 Ft/HR ADT = 7.49 HRS, ART = 5.15 HRS, AST = 2.34 HRS. Total Bit & Jar Hrs - 28.34. PU WT = 125K, SO WT = 85K, ROT WT = 104K. SIMOPS: Prep 9 5/8" casing for upcoming run. 12:00 14:30 2.50 3,755 3,755 SURFA( DRILL CIRC P Obtain Bottom hole surveys as per MWD and CBU 3 times, at 550 GPM - 1850 PSI. reciprocate & rotate drill string. 14:30 15:00 0.50 3,755 3,440 SURFA( DRILL REAM P Flow check well, BROOH from 3755' - 3440" MD. 80 RPM's and 550 PSI. 1850 PSI 15:00 16:00 1.00 3,440 3,440 SURFA( DRILL CIRC P CBU while reciprocate & rotate drill string. 550 GPM -s 1700 PSI. 16:00 19:30 3.50 3,440 814 SURFA( DRILL WPRT P POOH on elevators from 3440' - 814' MD. Observed good clean hole with proper displacement. 19:30 19:45 0.25 814 814 SURFA( DRILL OWFF P Monitor well - static. Page 4 of 64 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:45 22:30 2.75 814 3,755 SURFA( DRILL TRIP P Trip back in hole from 814' - 3755' with no hole issues and proper displacement. 22:30 00:00 1.50 3,755 3,755 SURFA( DRILL CIRC P Circulate & condition mud for running 9 5/8" casing. Pumps at 550 GPM - 1740 PSI. 08/04/2009 Continue Circulate & condition mud for upcoming casing job. Drop an ESS survey tool for JORPS requirements, and obtain surveys @ 2391', 2332' MWD measurements. POOH. Breakout & lay down drilling BHA. 12 1/4" Bit Grade = 2 /4/WT /G /E /4 /CC/TD. Clean & clear rig floor. RU & run 9 5/8" casing to +/- 3200' breaking circulation every 1200' as planned. 00:00 02:00 2.00 3,755 3,755 SURFA( DRILL CIRC P Continue circulate & condition mud at 3755', for upcoming casing run. Reciprocate & rotate drill string. Pumps at 550 GPM's - 1750 PSI. Spot lube pill in the annulus befroe POOH. 02:00 06:00 4.00 3,755 3,755 SURFA( DRILL TRIP P Monitor well - static. Drop and ESS survey tool as planned for JORPS requirments. Obtain surveys at 2391', and 2332' MD MWD depths.POOH with drill string, observing proper displacement. Crew Change 06:00 07:30 1.50 3,755 90 SURFA( DRILL PULD P POOH, racking back 5" HWDP. Hels PJSM with crew and Sperry Sun reps. Discuss safety & hazard recognition issues. Discuss procedure to breakout, and lay down BHA. 07:30 11:00 3.50 90 0 SURFA( DRILL OTHR P Plug in and download MWD assembly. Breakout & lay down BHA. Inspect and grade 12 1/4" Bit to 2 /4MIT /G /E /4 /CC/TD. 11:00 15:00 4.00 0 0 SURFA( CASING RURD P Held PJSM. Discuss procedure to rig up. Rig up Weatherford casing crew & equipment. Install long Bales on Top Drive. 15:00 15:30 0.50 0 0 SURFA( CASING SFTY P Held PJSM with crew, Weatherford reps. Discuss safety & hazard recognition. Discuss procedure to pick up and run 9 5/8" casing. 15:30 00:00 8.50 0 2,100 SURFA( CASING RNCS P Make up Shoe joint with Silver Bullet float shoe, and threadlock joint with FC joint. Baker -loc connections. Fill with mud and check floats. Continue MU 9 5/8" casing with 8500 ft/lbs of torque. Break circulation every 1200'. Depth at midnight = 2100'. 08/05/2009 Continue run 9 5/8" casing to land shoe at 3742' MD. TVD = 2952'. RU & pump 420 BBLS total cement job. Observed 145 BBLS cement to surface. Bumped plug, checked floats. Rig, wash up. ND Diverter system. Cleanout & wash all cement from cellar box. Page 5 of 64 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 05:15 5.25 2,100 3,742 SURFA( CASING RNCS P Continue run 9 5/8" Casing from 2100' to TD, landing shoe at 3742.63' MD. TVD = 2952'. Circulate & condition while RIH at 2400'. Pumps at 4.3 BPM - 380 PSI. Reciprocate casing string. Obtain parameters when PU landing joint & hanger. Up WT = 185K, SO Wt = 65K. MU Vetco Gray casing hanger, and landing joint. Land casing in bowl. 05:15 06:00 0.75 3,742 3,742 SURFA( CASING RNCS P RD Weatherford casing running equipment. MU cement head crossover & cement head with plugs installed. Attach all lines. 06:00 11:00 5.00 3,742 3,742 SURFA( CEMENT CIRC P Circulate & condition mud for desired cementing properties as per plan. PV = 14, YP = 23. Prepare & mix 40 BBLS of nut plug sweep. Reciprocate casing string while circulating, staging pumps to 7 BPM - 458 PSI. Held PJSM with crew, BJ, and MI reps. Discuss safety & hazard recognition issues. Discuss procedure to perform cement job. 11:00 14:30 3.50 3,742 3,742 SURFA( CEMENT CMNT P Pump 40 BBLS nut plug sweep, follow with 24 BBLS of 8.4 ppg Mud Clean II with Red Dye. Flush lines with 2 BBLS of H2O pumping a total of of 12.0 Cement with rates to 6.8 BPM - 350 PSI. Turn over to rig to displace observing nut plug & red dye at / surface @ 350 stks and cement e re ns at 1718 stks with a total of 45,BBLS cement to surface. Bump lug with 3897 StKS from rig ( 253 BBSL). FCP - 680 PSI. Observed plug bumped and pressure to 1180 PSI. Hold 5 minutes. Bleed pressure and check floats. Floats held. CIP @ 14:11 HRS. Flush flowline. 14:30 18:00 3.50 3,742 3,742 SURFA( CEMENT RURD P Held PJSM with crew. Discuss procedure to ND diverter system. Breakout & lay down landing joint. Change out top drive bales. Flush Hydril, starting head and lines.Nipple down Splash pan, bell nipple. Crew Change. 18:00 20:00 2.00 0 0 SURFA( CASING NUND P Held PJSM with new crew. Discuss safety & hazard recognition issues. Doscuuss procedure to ND Diverter system. Nipple down diverter system, including buoy line. 20:00 22:15 2.25 0 0 SURFA( CASING NUND P Remove cellar grating, & support beams. Clean out all cement & fluids in cellar box. Page 6 of 64 • r Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 23:00 0.75 0 0 SURFA( CASING NUND P Make up Vetco Gray wellhead. Test same to 5000 PSI - 5 minutes. Witnessed by driller. Obtain RKB to rig floor from wellhead LDS. - 17.2'. 23:00 00:00 1.00 0 0 SURFA( CASING NUND P Nipple up Annular & double gate BOP's. 08/06/2009 Continune NU BOP's. RU Test equipment & test BOP's with AOGCC rep Bob Noble witnessing. Observed failed tests. Make repairs. 00:00 10:30 10.50 0 0 SURFA( CASING NUND P Continue nipple up Annular & double gate BOP's. NU Mud cross & valves. NU Choke & Kill Lines. Flow nipple & fill up lines. 10:30 12:45 2.25 0 0 SURFA( CASING BOPE P Rig up test equipment for BOP test. Change out saver sub installing HT -38. 12:45 17:45 5.00 0 0 SURFA( CASING BOPE T Change out Blind ram door seals, clean door grooves. Hammer up flange leaks. Trouble shoot failed test. 17:45 19:00 1.25 0 0 SURFA( CASING BOPE P Continue test BOP'S @ 250 Low / 5000 High pressures a_ mit, with AOGCC rep B Nobl witness. Trouble ailed tests. 19:00 00:00 5.00 0 0 SURFA( CASING BOPE T Tighten Flanges, Grease & work valves. Trouble shoot failed tests.Remove upper & lower IBOP's for rebuild of same. 08/07/2009 Continue make repairs, and test BOP'S with AOGCC rep Bob Nobles witnessing. Lay down all 5" DP from derrick. Slip & Cut Drilling line 00:00 05:00 5.00 0 0 SURFA( CASING BOPE P Continue test BOP's @ 250 Low / _- 5000 High pressures as per permit, with AOGCC rep Bob Noble as witness. Perform Koomey test with starting pressure at 3050 PSI. Pressure first 200 PSI in 10 sec, with full recovery in 1 minute, 15 seconds. Avg pressure in 6 nitrogen bottles - 2150 PSI. 05:00 09:00 4.00 0 0 SURFA( CASING BOPE T MU IBOP in Top Drive. 09:00 09:30 0.50 0 0 SURFA( CASING BOPE P Test IBOP to 250/5000 PSI. 09:30 11:30 2.00 0 0 SURFA( CASING BOPE P Rig down all test equipment. Pull test plug, install long wear bushing as per Vetco rep. 11:30 12:00 0.50 0 0 SURFA( CASING TRIP P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to breakout & lay down 5" DP from derrick. TIH with 5" DP to 620' MD. 12:00 13:00 1.00 0 0 SURFA( CASING TRIP P Continue trip in hole from 620' - 1000' MD. 13:00 13:30 0.50 0 0 SURFA( CASING RGRP P Work on Totco system calibrations. 13:30 14:45 1.25 0 0 SURFA( CASING TRIP P Continue tripping 5" DP in hole from 1000' - 2200'. 14:45 22:30 7.75 0 0 SURFA( CASING TRIP P POOH, breakout & lay down 5" DP. Page 7 of 64 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 23:00 0.50 0 0 SURFA( CASING TRIP P Clean & clerar rig floor area. lay down 5" handling tools. 23:00 00:00 1.00 0 0 SURFA( CASING SLPC P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to slip & cut 69' driilling line. 08/08/2009 Continue pick up & rack back 4" DP. MU BHA #2- 8 3/4" drilling assembly, and TIH picking up 4" singles from Pipe shed. 00:00 00:30 0.50 0 SURFA( CASING SLPC P Continue slip & Cut 69' of drilling line. 00:30 01:30 1.00 0 0 SURFA( CASING SVRG P Continue pick up & rack back 4" drill pipe in derrick, with SLM. 01:30 03:00 1.50 0 0 SURFA( CASING RURD P Rig up pipe shed, load and strap 4" DP. 03:00 10:15 7.25 0 0 SURFA( CASING TRIP P Pick up and rack back a atotal of 138 joints in the derrick. 10:15 12:00 1.75 0 0 SURFA( CASING RURD P Load all BHA in the pipe shed as per DD & MWD reps. Pull all handling tools to rig flor for make up of BHA. 12:00 15:15 3.25 0 120 SURFA( CASING PULD P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to make up BHA. MU 8 3/4" bit with 7" Sperry Drill 7/8 - 6.0 stage mud motor. Continue make up MWD assembly as planned, and orient mud motor to MWD. Tool Face offset = 138.8 Deg. 15:15 16:15 1.00 120 120 SURFA( CASING PULD P Plug in and upload MWD assembly. 16:15 16:45 0.50 120 180 SURFA( CASING PULD P Continue make up BHA. RIH with one stand. 16:45 19:00 2.25 180 180 SURFA( CASING PULD P Perfom shallow pulse test with pumps at 417 GPM's - 690 PSI. Pumping new mud down drill pipe observing when interfaced the mud clabbered up in the pitcher nipple and in the mud pumps. Flushed all lines, mud pumps and flow nipple to gain good detection in MWD. 19:00 19:30 0.50 180 180 SURFA( CASING RGRP P Repair air boot in dresser sleeve on flow nipple. Test same - OK. 19:30 20:00 0.50 180 180 SURFA( CASING SFTY P Held PJSM with crew & MWD reps. Discuss safety & hazard recognition issues. Discuss procedure to install nuclear sources in the BHA. Install sources in BHA. 20:00 22:00 2.00 180 655 SURFA( CASING PULD P Continue make up remaining BHA installing non -mag Flex drill collars,and 4" HWDP & drilling Jars. 22:00 00:00 2.00 655 1,895 SURFA( CASING TRIP P Trip in hole with BHA #2 picking up 4" Drill pipe from shed from 655' - 1895' MD. 08/09/2009 Continue RIH with 4" DP singles from shed to 3400' MD. Circulate & condition mud. Perform casing test to 3000 PSI. Good test. Drill Shoe track tagging Cement @ 3628' & FC @ 3657', drilling through Float shoe @ 3740' plus 20 ft of new hole to 3775'. Circulate & perform FIT test to 16.0 PPG with 9.6 PPG Mud. Displace well with 9.6 PPG Klashield mud as planned. Directional drill 8 3/4" hole from 3775' - 4059' MD. TVD = 3204'. Total drilling hours = 4.06. Page 8 of 64 • Time Logs Date From To Dur S. Depth E. Depth Phase Code - Subcode T Comment 00:00 02:30 2.50 1,895 3,400 SURFA( CASING TRIP P Continue Trip in hole with BHA #2 picking up 4" Drill pipe from shed from 1895' - 3400' MD. 02:30 03:30 1.00 3,400 3,400 SURFA( CASING CIRC P Circulate & condition mud with pumps at 400 GPM;s - 1750 PSI. Reciprocate & Rotate drill string. 03:30 06:00 2.50 3,400 3,400 SURFA( CASING PRTS P RU Testing equipment. Calibrate casing test pump, including bucket test. Test the 9 5/8" casing to 3000 PSI - 30 minutes. Record on chart. RD test equipment. Crew Change 06:00 10:30 4.50 3,400 3,755 PROD1 DRILL REAM P Trip in hole to tag cement at 3430'. Drill firm cement from 3430' - tag FC at 3628'. Continue drilling shoe track out from 3628' through float collar at 3740' MD. Pumps at 450 GPM's - 1900 PSI with 70 RPM's - 7K TQ. 10:30 11:00 0.50 3,755 3,775 PROD1 DRILL DRLG P Drill out 20 feet of new hole as planned for LOT, from 3755' - 3775' MD. ND = 2976'. 11:00 11:45 0.75 3,775 3,775 PROD1 DRILL CIRC P CBU at 460 GPM's - 2050 PSI. 11:45 13:00 1.25 3,775 3,775 PROD1 DRILL LOT P Rig up test equipment for LOT. Pump at 1/2 BPM to pressure to EMW of 16 PPG. Pressure held in 10 minutes. Bleed pressure and rig down test equipment. 13:00 15:45 2.75 3,775 3,775 PROD1 DRILL CIRC P Prep mud pits for Klashield displacement. Mix 40 BBL Spacer pill. Displace well with 9.6 PPG Klashield at 450 GPM's - 1900 PSI. Reciprocate & rotate drill string. 15:45 16:00 0.25 3,775 3,775 PROD1 DRILL OWFF P Monitor well - static. 16:00 17:15 1.25 3,775 3,775 PROD1 DRILL CIRC P Continue circulate to buiold volume in pits, mixing mud with Swaco mix unit. 17:15 00:00 6.75 3,775 4,059 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 3775' - 4059' MD. ND = 3204'. ADT = 4.06 HRS, AST = .94 HRS, ART = 3.12 hRS. Bit & Jar hours = 4.06. UP WT = 100K, SO WT = 70K, ROT WT = 75K. TQ on - 6K, TQ off - 5.5K. ECD = 10.0 PPG. MAX gas observed = 67 Units. 08/10/2009 Continue directional drilling 8 3/4" Hole from 4059' - 4748' MD. ND = 3835'. ADT = 9.29 HRS. AVG ROP - 74.5 FT/ HR. Circulate Bottoms up x 3, for planned wiper trip. POOH on elevators observing good clean hole. Pump Dry job, Continuing to POOH for installation of MIRL tool, to 781' Midnight depth. Observed proper displacement. 00:00 12:00 12.00 4,059 4,456 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 4059' - 4456' MD. ND = 3558'. ADT = 5.34 HRS, AST = 2.14 HRS, ART = 3.20 HRS. Bit & Jar hours = 9.40. UPWT= 110K,SOWT= 80K,ROT WT = 93K. TQ on - 6K, TQ off - 6K. ECD = 10.10 PPG. MAX gas observed = 91 Units. Page 9 of 64 • 0 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 4,456 4,748 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 4456" - 4748' MD. TVD = 3835'. ADT = 3.95 HRS, AST = 1.57 HRS, ART = 2.38 HRS. Bit & Jar hours = 13.35. Pumps at 500 GPM's- 2010 PSI. WOB = 2-4K RPM's = 100 UP WT = 108K, SO WT = 80K, ROT WT = 92K. TQ on - 6K, TQ off - 6K. ECD = 10.10 PPG. MAX gas observed = 85 Units. Obtained SPR's at 4456' MD. 18:00 20:00 2.00 4,748 4,748 PROD1 DRILL CIRC P Circulate bottoms up x 3, for wiper trip. Observed clean shakers, and no fluid loss issues. Reciprocate & rotate drill string. 20:00 20:15 0.25 4,748 4,748 PROD1 DRILL OWFF P Monitor well - static. 20:15 00:00 3.75 4,748 781 PROD1 DRILL WPRT P POOH on elevators observing good clean hole with no overpull issues & proper displacement. Pulled 5 stands. Peformed checkshot survey as per MWD. Pumped dry job. Continue POOH on elevators to midnight depth of 781. Prepare Sperry Sun MIRL tool in pipe shed. 08/11/2009 Continue POOH from 781' to MWD BHA @ 120'. Install planned MIRL tool. Test same, RIH with BHA #3. Observed proper displacement. Obtained checkshot surveys @ 4183' MD> Wash & Ream hole from 4727' -4748' - Bottom. Continue Directional drill from 4748' - 5038' MD (290'). AVG ROP = 43.28 FT /HR. ADT = 6.70 HRS. Total Bit & Jar HRS = 28.34. 00:00 00:30 0.50 781 120 PROD1 DRILL TRIP P Continue POOH from 781' to 120' + / -. Pulled to MWD TM assembly. Observed proper displacement. Monitor well at Shoe & at BHA. 00:30 03:00 2.50 120 120 PROD1 DRILL PULD P Install Sperry Sun MIRL tool. Plug in. Download tool. Tool length = 38.18'. Total BHA length = 693.73'. 03:00 03:30 0.50 693 693 PROD1 DRILL PULD P RU & Pulse test MWD. Good test. Pumps @ 400 GPM's- 950 PSI. 03:30 04:00 0.50 120 693 PROD1 DRILL PULD P Make up Remaing BHA. DC's & HWDP. 04:00 06:00 2.00 693 3,800 PROD1 DRILL TRIP P Continue trip in hole with BHA #3 from 693' - 3800' MD. Observed proper displacement. Crew Change 06:00 06:30 0.50 3,800 3,800 PROD1 DRILL SVRG P Service rig, Fill drill string. 06:30 08:30 2.00 3,800 4,183 PROD1 DRILL TRIP P Continue trip in hole from 3800' - 4183' MD. Perform 4 - point Checkshot survey @ 4183'. 08:30 09:30 1.00 4,183 4,748 PROD1 DRILL TRIP P Continue TIH to 4727'. RU, wash & ream back to bottom @ 4748. CBU. Page 10 of 64 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 12:00 2.50 4,748 4,812 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 4748' - 4812' MD. ND = 3836'. ADT = 1.48 HRS, AST = .56 HRS, ART = .92 HRS. Bit & Jar hours = 14.83 Pumps at 500 GPM's- 2060 PSI. WOB = 2-4K RPM's = 100. UP WT = 110K, SO WT = 84K, ROT WT = 92K. TQ on - 7K, TQ off - 6K. ECD = 10.0 PPG. MAX gas observed = 91 Units. Obtained SPR's at 4812' MD. 12:00 18:00 6.00 4,812 4,912 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 4812' - 4912' MD. ND = 3996'. ADT = 2.25 HRS, AST = .53 HRS, ART = 1.72 HRS. Bit & Jar hours = 17.08 Pumps at 500 GPM's- 2060 PSI. WOB = 2-4K RPM's = 100. UP WT = 110K, SO WT =84K, ROT WT= 92K. TQ on - 7K, TQ off - 6K. ECD = 10.0 PPG. MAX gas observed = 102 Units. Obtained SPR's at 4912' MD. Crew Change 18:00 00:00 6.00 4,912 5,038 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 4912' - 5038 MD. ND = 3996'. ADT = 2.97 HRS, AST = 1.78 HRS, ART = 1.19 HRS. Bit & Jar hours = 20.05 Pumps at 500 GPM's- 2060 PSI. WOB = 2-4K RPM's = 100. UP WT = 110K, SO WT = 84K, ROT WT = 92K. TQ on - 7K, TQ off - 6K. ECD = 10.0 PPG. MAX gas observed = 142 Units. Obtained SPR's at 5038' MD. 08/12/2009 Continue directional Drill from 5038' - 5680' MD ND = 4762' Dump & Dilute mud as per program +/- every 300', 100 BBLS. 00:00 06:00 6.00 5,038 5,205 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 5038' - 5205' MD. ND = 3996'. ADT = 2.25 HRS, AST = .53 HRS, ART = 1.72 HRS. Bit & Jar hours = 22.88 Pumps at 500 GPM's- 21300 PSI. WOB = 3 -5K RPM's = 100. UP WT = 115K, SOWT =85K, ROT WT= 100K. TQ on - 7K, TQ off - 6K. ECD = 10.15 PPG. MAX gas observed = 165 Units. Obtained SPR's at 5038' MD. Crew Change 06:00 12:00 6.00 5,205 5,354 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 5205' - 5354' MD. ND = 4436'. ADT = 3.08 HRS, AST = .65 HRS, ART = 2.43 HRS. Bit & Jar hours = 25.96. Pumps at 500 GPM's- 2130 PSI. WOB = 3 -5K RPM's = 100. UP WT = 130K, SO WT = 90K, ROT WT = 105K. TQ on - 8.2K, TQ off - 7K. ECD = 10.01 PPG. MAX gas observed = 165 Units. Obtained SPR's at 4436' MD. Page 11 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 5,354 5,546 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 5354' - 5546' MD. TVD = 4625'. ADT = 3.90 HRS, AST = 1.01 HRS, ART = 2.89 HRS. Bit & Jar hours = 29.86. Pumps at 500 GPM's- 2260 PSI. WOB = 3-5K RPM's = 100 UP WT = 135K, SO WT = 90K, ROT WT = 107K. TQ on - 8K, TQ off - 7K. ECD = 9.92 PPG. MAX gas observed = 142 Units. Crew Change 18:00 00:00 6.00 5,546 5,680 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 5546' - 5680' MD. TVD = 4762'. ADT = 1.97 HRS, AST = 1.13 HRS, ART = .84 HRS. Bit & Jar hours = 31.83. Pumps at 500 GPM's- 2260 PSI. WOB = 3 -5K RPM's = 100 UP WT = 138K, SO WT = 85K, ROT WT = 110K. TQ on - 8.5K, TQ off - 7.5K. ECD = 9.89 PPG. MAX gas observed = 210 Units. Obtained SPR's at 5680 MD. 08/13/2009 Continue driectional Drill from 5680' - 6289 MD TVD = 5382'. Observed MWD pulses off /on throughout the day up to 1800 HRS when MWD failed. Attempt to get pulses again, without success. CBU, and BROOH for planned wiper trip. Obtained pulses again when BROOH. BROOH to 5546' MD. While drilling, dump & dilute mud as per mud engineer, +/- every 300', 100 BBLS. 00:00 06:00 6.00 5,680 5,921 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 5680' - 5921' MD. TVD = 5003'. ADT = 2.88 HRS, AST = 0 HRS, ART = 3.88 HRS. Bit & Jar hours = 34.71. Pumps at 500 GPM's- 2350 PSI. WOB = 5K RPM's = 100. UPWT= 140K, SO WT = 90K, ROT WT = 110K. TQ on - 8.5K, TQ off - 7.5K. ECD = 9.99 PPG. MAX gas observed = 290 Units. Obtained SPR's at 5921' MD.Observed MWD pulses in / out. Troubleshoot same. Gained back each time. 06:00 12:00 6.00 5,921 6,089 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 5921' - 6089' MD. TVD = 5171'. ADT = 2.09 HRS, AST = 0 HRS, ART = 2.09 HRS. Bit & Jar hours = 36.80. Pumps at 500 GPM's- 2350 PSI. WOB = 5K RPM's = 100. UP WT = 147K, SO WT = 90K, ROT WT = 115K. TO on - 9K, TQ off - 8K. ECD = 10.03 PPG. MAX gas observed = 135 Units. Obtained SPR's at 6089 MD. Troubleshoot same. Gained back each time. Page 12of64 S • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 6,089 6,289 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 6089' - 6289' MD. TVD = 5370'. ADT = 3.36 HRS, AST = 0 HRS, ART = 3.36 HRS. Bit & Jar hours = 40.16. Pumps at 500 GPM's- 2350 PSI. WOB = 5K RPM's = 2350 UP WT = 148K, SO WT = 90K, ROT WT = 117K. TQ on - 9K, TQ off - 8K. ECD = 10.01 PPG. MAX gas observed = 627 Units. Obtained SPR's at 6289 MD. Troubleshoot same. Gained back each time. 18:00 20:30 2.50 6,289 6,300 PROD1 DRILL DDRL T Observed MWD pulses failed. Attempt to get back data, while drilling from 6289' - 6300' MD. TVD = 5382'. We had no success in gaining pulses. Geologists discussed plan forward with town as we are +/- 100 feet from our coring depth. Decision to perform planned wiper trip. 20:30 22:00 1.50 6,300 6,300 PROD1 DRILL CIRC P Circulate bottoms up x 2, with pumps at 500 GPM's - 2500 PSI. Reciprocate & rotated rill string. Observed hole unloading cuttings with approx - 25% increase at shakers. 22:00 00:00 2.00 6,300 5,546 PROD1 DRILL REAM P BROOH first 5 stands. to 5900' MD. CBU, attempt to POOH on elevators, no success with up to 25K overpull. Attempt to pump out of hole, no go. Continue BROOH at 20 -25 Ft/Min. with pumps at 500 GPM's - 2300 PSI. 100 RPM's - 7K TQ. NOTE: Observed MWD pulses came on again with good data after 5th stand pulled. Continued to midnight depth of 5546' MD. 08/14/2009 Continue U BROOH U 4600' MD - Circulate Bottoms Up - Observed the Well For Flow (Static) - TIH U 5987' MD - Wash /Ream U 6300' MD taking Surveys Every 60' - DDRL'd U 6412' MD (Core Point) - Circulate and Condition Mud for Coring, Attempting to get the API F/L to <3.0 00:00 03:00 3.00 5,546 4,600 PROD1 DRILL REAM P Continue to BROOH f/ 5546' - 4600' MD; 500 GPM @ 2260 Psi; Torque 6,000 @ 100 RPM Proper Displacement Throughout 03:00 04:00 1.00 4,600 4,600 PROD1 DRILL CIRC P CBU; 500 GPM @ 2170 Psi while Rotating 100 RPM - Gas at Bottoms Up 35 Units 04:00 04:15 0.25 4,600 4,600 PROD1 DRILL OWFF P OWFF (Static) 04:15 05:15 1.00 4,600 5,987 PROD1 DRILL TRIP P TIH f/ 4600' - 5987' MD - Proper Displacement 05:15 06:00 0.75 5,987 6,300 PROD1 DRILL WASH P Wash & Ream f/ 5987' - 6300' MD - Obtained Surveys Every 60' Page 13 of 64 S • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 09:15 3.25 6,300 6,412 PROD1 DRILL DDRL P DDRL 8 3/4" Hole w/ Motor f/ 6300' - 6412' MD (Core Point) ART =1.65 Torque 8 @ 100 RPM 470 GPM @ 2400 Psi P/U 155, S/O 95, Rot 117 09:15 12:00 2.75 6,412 6,412 PROD1 DRILL CIRC P Circ & Condition Mud for Coring; Target API Fluid Loss <3.0 12:00 18:00 6.00 6,412 6,287 PROD1 DRILL CIRC X C &C for Coring - Attempt to Bring API F/L Down to 3.0 or Less by Adding Safe Carb / Pre - Hydrated Gel - Stand Back Two Stands During Circulation U 6287' MD - C &C for Coring - Continue to Rotate and Reciprocate Drill String While Cirulating 18:00 00:00 6.00 6,287 6,211 PROD1 DRILL CIRC X C &C for Coring - Attempt to Bring API F/L Down to 3.0 or Less by Adding Safe Carb / Pre - Hydrated Gel - Continue to Rotate and Reciprocate Drill String While Cirulating 08/15/2009 Continue to Circ & Cond Mud to Lower API F/L to <3.0 - Decision Made to Accept F/L of 4.5 and Proceed w/ Coring - RIH U 6412' MD (Encountered 8' of Soft Fill f/ 6404 - 6412') - Circulate while Adding Deuterium Marker to Mud then Circulating Entire Volume twice More to Disperse Evenly - POOh on Elevators U 3720' MD - String was Differentially Sticky f/ 6412' - 6303' MD then Good for the Remainder of the Trip - Monitor Well at Casing Shoe - Continue to POOH and Begin L/D the BHA U 161' MD 00:00 06:00 6.00 6,211 6,084 PROD1 DRILL CIRC X C &C for Coring - Attempt to Bring API F/L Down to 3.0 or Less by Adding Safe Carb / Pre - Hydrated Gel - Stand Back One Stand & Continue to Rotate and Reciprocate Drill String While Cirulating 06:00 06:30 0.50 6,211 6,412 PROD1 DRILL TRIP X TIH U 6367' MD - Wash /Ream t/ Bottom 6412' MD - Note 8' of Soft Fill f/ 6404' - 6412' MD 430 GPM @ 2150 Psi 06:30 16:30 10.00 6,412 6,412 PROD1 CORING CIRC P Circulate and Condition Mud Adding Deuterium Marker to the Entire System - Then Circulating the Entire System Through Twice to Disperse 16:30 19:30 3.00 6,412 3,720 PROD1 DRILL TRIP P Observe Well For Flow (Static) - POOH on Elevators f/ 6412' - 3720' MD - String was Differentially Sticking - Had to Rotate to Break Friction Before Pulling Up Unitl 6303' MD then Pulled Well for Remainder of Trip 19:30 20:00 0.50 3,720 3,720 PROD1 DRILL OWFF P Monitor Well - Hole Taking Approximately .6 BPH Static 20:00 21:15 1.25 3,720 693 PROD1 DRILL TRIP P Continue to POOH on Elevators U 693' MD 21:15 23:45 2.50 693 161 PROD1 DRILL PULD P L/D BHA per DD and MWD U 161' MD Page 14 of 64 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:45 00:00 0.25 161 161 PROD1 DRILL OTHR P Clean & Clear Rig Floor in Perparation for Laying Down RA Sources and Reading MRIL Tools - P/U Pigs for RA Source Storage 08/16/2009 Attempt to Read MRIUMWD Tools - Unable to Read MRIL Data due to Dead Batteries - L/D Remainder of BHA #3 - Service Top Drive, Crown & Blocks - M/U and RIH w/ Core Barrels - Hold Dry Run Core Shucking Procedure with Crew - RIH w/ Core Barrels on 4" DP to 3695' MD - Slip /Cut Drill Line - Change Swivel Packing - RIH t/ 5328' MD - Swivel packing Leaking - POOH on Elevators t/ 3695' MD - Begin Changing Swivel Packing 00:00 00:15 0.25 161 161 PROD1 DRILL SFTY P PJSM w/ Crew for Downloading MRIL Tool and Nuclear Sources 00:15 01:15 1.00 161 161 PROD1 DRILL DHEQ P Attempt to Read MRIL Tools (Dead Batteries) - Remove Nuclear Sources 01:15 01:45 0.50 161 122 PROD1 DRILL PULD P Continur to UD BHA t/ 122' MD 01:45 02:45 1.00 122 122 PROD1 DRILL DHEQ P Download MWD Data 02:45 04:45 2.00 122 0 PROD1 DRILL PULD P UD Remainder of BHA 04:45 05:00 0.25 0 0 PROD1 DRILL OTHR P Clean / Clear Rig Floor - monitor Well Via Trip Tank 05:00 07:00 2.00 0 0 PROD1 DRILL SVRG P Grease Top Drive, Blocks & Crown Sheaves - Replace Wire Ties on External Pins of Top Drive 07:00 11:30 4.50 0 605 PROD1 CORING PULD P PJSM - M/U Coring Bit and Outer Barrels - M/U Inner Barrels and Space Out 11:30 12:00 0.50 605 605 PROD1 CORING OTHR P Develop and Conduct Dry Run of Core Shucking and Laying Down 12:00 16:00 4.00 605 3,695 PROD1 CORING TRIP P RIH w/ Core Barrels on 4" DP t/ 3695' MD 16:00 17:30 1.50 3,695 3,695 PROD1 CORING SLPC P PJSm - Slip and Cut Drill Line - Calibrate Block Height w/ Sperry - Change Swivel Packing 17:30 19:00 1.50 3,695 3,695 PROD1 RIGMNT RGRP T PJSm - Change Swivel Packing 19:00 21:00 2.00 3,695 5,328 PROD1 CORING TRIP P TIH on Elevators t/ 5328' MD - Displacement Good 21:00 22:45 1.75 5,328 3,695 PROD1 CORING TRIP T POOH on Elevators t/ 3695' MD to Change Swivel Packing 22:45 00:00 1.25 3,695 3,695 PROD1 CORING RGRP T Replace Top Drive Swivel Packing - Monitor Well on Pit 6 08/17/2009 Continue to Change the Swivel Packing - RIH t/ 6211' MD - Wash /Ream U 6412' MD - Space Out Core String - CBU - Core f/ 6412' - 6503' MD Avg ROP 5 FPH, Max Gas 18 Units - Worked Core Off Bottom and Begin to CBU 00:00 02:15 2.25 3,695 3,695 PROD1 CORING RGRP T Continue to Change Swivel Packing - Monitor Well on Pit #6 02:15 03:30 1.25 3,695 5,328 PROD1 CORING TRIP T RIH on Elevators t/ 5328' MD - Fill Pipe Every 25 Stands 03:30 04:30 1.00 5,328 6,211 PROD1 CORING TRIP P RIH on Elevators t/ 6211' MD 04:30 05:00 0.50 6,211 6,412 PROD1 CORING WASH P Wash / Ream t/ 6418' MD - tagged Bottom at 6412' MD 05:00 06:30 1.50 6,412 6,412 PROD1 CORING CIRC P CBU - 210 GPM @ 700 Psi, Torque 7,000 @ 40 RPM Page 15 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 07:00 0.50 6,412 6,412 PROD1 CORING HOSO P Rack Back 1 Stand and P/U 15' 4" DP Pup to Space Out Core String - Drop 1" Ball and M/U 1 Stand and Pump Ball Down @ 130 GPM /400 Psi - Ball on Seat Verified by 60 Psi Pressure Increase - wash Down t/ 6412' MD 07:00 22:15 15.25 6,412 6,503 PROD1 CORING CORE P Core Drilling Formation per Baker Coring Rep f/ 6412' - 6503' MD; 6412' - 6439' MD; Average ROP 8 FPH, Max gas 8 units 6439' - 6456' MD; Breaks w/ ROPs up to16 FPH but Averaging 8 FPH w/ Gas @ 13 Units 6456' - 6460' MD; Average ROP 4 FPH w/ 8 Units of Gas 6460' - 6479' MD; Max ROP increased to 19 FPH but Averaged 9 FPH w/ 5 Units of Gas 6479' - 6502' MD; Max ROP During Interval Peaked at 60 FPH with Average ROP 4 FPH w/ 18 Units of Gas Parameters throughout the operation: WOB 10 -12 RPM 85 230 GPM @ 880 Psi Torque 7,500 22:15 23:15 1.00 6,503 6,403 PROD1 CORING CIRC P Rack Back One Stand and Work Core Off Bottom 120 GPM @ 470 Psi - Continue to Circulate While Pulling 2nd Stand at 200 GPM @ 760 Psi - UD 15' Pup 23:15 00:00 0.75 6,403 6,403 PROD1 CORING CIRC P CBU @ 6403' MD - 220 GPM @ 760 Psi, 25 RPM - Max Gas 10 Units 08/18/2009 Continue to CBU Prior to Pulling the Core - POOh on Elevators t/ 3620' MD Observing Speed Limits in the Well Plan - OWFF - POOh U 101' MD - PJSM - UD Core Barrels and Cores (88' of Core Retrieved) - P/U BHA #5 and RIH t/ 00:00 00:45 0.75 6,403 6,403 PROD1 CORING CIRC P Continue to CBU Prior to Pulling Core 00:45 03:45 3.00 6,403 3,620 PROD1 CORING TRIP P POOH on Elevators t/ 3620' MD - Hole Took Proper Displacement 03:45 04:15 0.50 3,620 3,620 PROD1 CORING OWFF P OWFF (Static) - Pump 18 BBI Dry Job 04:15 11:00 6.75 3,620 101 PROD1 CORING TRIP P Continue to POOH per Drilling Program t/ 101' MD 11:00 12:00 1.00 101 101 PROD1 CORING SFTY P PJSM on UD Coring Barrels and Shucking / Handling the Cores 12:00 14:00 2.00 101 0 PROD1 CORING PULD P UD Inner and Outer Core Barrels 14:00 14:30 0.50 0 0 PROD1 CORING OTHR P Clean / Clear Rig Floor in Preparation for Handling Cores 14:30 15:30 1.00 0 0 PROD1 CORING PULD P Continue to UD Cores (88' of Recovery) 15:30 17:30 2.00 0 109 PROD1 DRILL PULD P PJSM; Begin P/U BHA #5 Page 16 of 64 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 18:30 1.00 109 109 PROD1 DRILL OTHR P Read MWD 18:30 18:45 0.25 109 109 PROD1 DRILL SFTY P PJSM - Load Nuclear Sources 18:45 20:00 1.25 109 641 PROD1 DRILL PULD P Continue to P/U BHA #5 and Shallow Pulse Test MWD 20:00 22:45 2.75 641 4,170 PROD1 DRILL TRIP P RIH w/ BHA #5 on 4" DP f/ 641' - 4170' MD - Displacement Good 22:45 23:30 0.75 4,170 4,170 PROD1 DRILL SRVY P Obtain MWD Check Shots - 455 GPM @ 1890 Psi 23:30 00:00 0.50 4,170 4,960 PROD1 DRILL TRIP P RIH w/ BHA #5 t/ 4960' MD 08/19/2009 Take MWD Check Shots - Continued to RIH /t 6379' MD - Wash /Ream t/ 6503' MD - Drill Production Hole t/ 6615' MD When MWD Density signal was Lost - Attempted to Regain Signal but Unsuccessful - POOH on Elevators and UD MWD Tool - P/U Back Up MWD and RIH t/ 4170' MD 00:00 00:45 0.75 4,960 4,960 PROD1 DRILL OTHR P Obtain MWD Check Shot's @ 4960' MD 00:45 01:30 0.75 4,960 6,379 PROD1 DRILL TRIP P RIH f/ 4960' - 6379' MD 01:30 04:00 2.50 6,379 6,503 PROD1 DRILL WASH P Wash & Ream to Bottom While Conducting MADD Pass - 460 GPM @ 2420 Psi, 100 RPM, Rot Wt. 115K 04:00 09:00 5.00 6,503 6,615 PROD1 DRILL DDRL P Drill 8 3/4" Hole w/ Motor f/ 6503' - 6615' MD RPM - 100 470 GPM @ 2500 Psi WOB 5 -10 Torque 8.5 -10 P/U 165, S/O 98, Rot 118 09:00 09:30 0.50 6,615 6,506 PROD1 DRILL OTHR T Lost MWD Density Signal; Tried Mode Switch (No Help) - OWFF (Static) - POOH t/ 6506' MD - Try Again (bad) 09:30 15:00 5.50 6,506 641 PROD1 DRILL TRIP T POOH on Elevators t/ 641' MD - Hole Fill Good 15:00 16:30 1.50 641 110 PROD1 DRILL PULD T UD BHA #5 to Nukes 16:30 17:00 0.50 110 110 PROD1 DRILL OTHR T PJSM - Unload nuclear Sources 17:00 17:30 0.50 110 83 PROD1 DRILL OTHR T UD 1 NMFDC - Read MWD 17:30 18:00 0.50 83 30 PROD1 DRILL PULD T Change Out MWD 18:00 19:00 1.00 30 83 PROD1 DRILL PULD T P/U DM, ALS, Stab, CTN 19:00 19:30 0.50 83 83 PROD1 DRILL OTHR T PJSM - Read New MWD 19:30 19:45 0.25 83 109 PROD1 DRILL PULD T Continue to P/U BHA #6 & Shallow Pulse Test MWD 19:45 20:15 0.50 109 109 PROD1 DRILL OTHR T Load Nuclear Sources 20:15 21:30 1.25 109 641 PROD1 DRILL PULD T P/U Remainder of BHA #6 t/ 641' MD 21:30 00:00 2.50 641 4,170 PROD1 DRILL TRIP T TIH f/ 641' - 4170' MD on Elevators - Displacement Good 08/20/2009 Acquire MWD Check Shots- PIH f/ 4170' - 6566' MD - Wash /Ream t/ 6615' MD - Drill Production Hole t/ 6839' MD (2nd Core Point) - Circulate One System Volume While Adding Deuterium Tracer to the System - Perform Wiper Trip f/ 6839' - 6506' - Circulate Entire System Volume Twice More to Disperse Deuterium Evenly - POOH t/ 641' MD - S/B HWDP, Jars and NMFDC's t/ 107' MD Page 17 of 64 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 4,170 4,170 PROD1 DRILL OTHR T Obtain MWD Check Shots at 4170' MD 00:30 02:00 1.50 4,170 6,566 PROD1 DRILL TRIP T RIH f/ 4170' - 6566' MD - Fill Pipe Every 25 Stands 02:00 02:30 0.50 6,566 6,615 PROD1 DRILL WASH T Wash /Ream f/ 6566' - 6615' MD - Obtian SPR's 450 GPM @ 2310 Psi / RPM - 10 02:30 09:30 7.00 6,615 6,839 PROD1 DRILL DDRL P Drill Production Hole f/ 6615' - 6839' MD (Core Point) 480 GPM @ 2790 Psi 100 RPM Torque 10,000 ADT - 4.16 09:30 11:30 2.00 6,839 6,839 PROD1 DRILL CIRC P Circulate One Total Volume of Mud While Adding Deuterium Tracer - Rotate and Reciprocate Pipe - 480 GPM @ 2660 Psi, 100 RPM 11:30 13:00 1.50 6,839 6,839 PROD1 DRILL WPRT P Perform Wiper Trip past new hole (6506' - 6839' MD) - 430 GPM @ 2300 Psi, 100 RPM 13:00 17:00 4.00 6,839 6,839 PROD1 DRILL CIRC P Circulate Two Complete System Volumes to Disperse Deuterium Evenly - 450 GPM @ 2350 Psi 17:00 17:15 0.25 6,839 6,839 PROD1 DRILL OWFF P OWFF (Static) 17:15 18:00 0.75 6,839 6,440 PROD1 DRILL TRIP P POOH - Pulled 90K Over - Differentially Stuck - Rotated Pipe to Break Friction t/ 6440' MD 18:00 22:15 4.25 6,440 641 PROD1 DRILL TRIP P POOH on Elevators f/ 6440' - 641' MD 22:15 00:00 1.75 641 107 PROD1 DRILL PULD P POOH w/ BHA #6 - S/B HWDP, Jars and NMFDC's 08/21/2009 Continue to UD BHA #7 - P/U 4" Test Joint and Test BOPE: Annular U 250/3500, Rams, Valves and Manifolds t/ 250/5000 - Troubleshoot and Repair Draw Works Air System - M/U Core Bit, Outer /Inner Barrels and Space Out - Drift PBL Sub w/ Ball and N/U Remainder of BHA #7 - Witenssing of BOPE Test Waived by AOGCC Inspector Jim Regg 00:00 00:30 0.50 107 84 PROD1 DRILL PULD P Continue of UD BHA #6 00:30 01:00 0.50 84 84 PROD1 DRILL OTHR P Read MWD Data 01:00 02:00 1.00 84 0 PROD1 DRILL PULD P UD Remainder of BHA #6 02:00 03:30 1.50 0 0 PROD1 WHDBO RURD P Clear Rig Floor - Set 4" Test Joint and R/U to Test BOPE 03:30 11:00 7.50 0 0 PROD1 WHDBO BOPE P Test BOPE as F. •ws: Annular Preventer t/ 25u/3514 Psi - Upper and Lower Varia• e Rams, Blind Rams, Dart, Upper and Lower IBOP, 4" TIW, HCR / Manual Choke and Kill, 4' Demco Valve, and all Choke Manifold Valves t/ 250/5000 Psi - Accumulator Tested 200 Psi Rise in 12 Seconds - Full Charge in 1:24 - 6 Bottle Average 2100 Psi - Witnessing of Test Waived by AOGCC Inspector Jim Regg Page 18 of 64 . • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 0 0 PROD1 WHDBO OTHR P R/D BOPE Test Equipment and Clear Rig Floor 12:00 12:30 0.50 0 0 PROD1 CORING SFTY P PJSm on making up Core Barrels - Monitor Well Via Trip Tank 12:30 13:30 1.00 0 0 PROD1 CORING SVRG P Service Crown Shieves, Blocks, Top Drive 13:30 20:00 6.50 0 0 PROD1 CORING RGRP T Troubleshoot and Repair Draw Works Air Systems - Monitor Well Via Trip Tank (Losses Avg 1 BPH) 20:00 20:30 0.50 0 0 PROD1 CORING OTHR P Arrange Baker Tools in pipe Shed - Clear Rig Floor 20:30 00:00 3.50 0 107 PROD1 CORING PULD P P/U BHA #7: Coring Bit, Inner and Outer Barrels and Space Out t/ 107' MD 08/22/2009 M/U the Remainder of BHA #7 - RIH on 4" DP t/ 6534' MD then Wash /Ream t/ 6839' MD (Tagged Bottom) - Dropped 1.25' Ball and Drill Core t/ 6897' MD (58 Ft) - ROP Dropped to .5 FPM During the Final Two Feet of Coring - Discussed options with Town - Decision Made to Pull Core - POOH w/ Core at Planned Speeds t/ 6100' MD 00:00 06:15 6.25 107 6,534 PROD1 CORING TRIP P Continue to M/U the Remainder of BHA #7 and RIH on 4" DP t/ 6534' MD 06:15 07:15 1.00 6,534 6,844 PROD1 CORING WASH P Wash / Ream f/ 6534' - 6844' MD (Tagged Bottom) - Take SPR's 07:15 08:15 1.00 6,844 6,844 PROD1 CORING CIRC P CBU - 250 GPM @ 830 Psi 08:15 08:30 0.25 6,844 6,844 PROD1 CORING OTHR P Drop/ Pump 1/25" Ball Down - Ball on Seat - Observed Pressure Increase f/ 420 - 510 Psi @ 126 GPM 08:30 22:00 13.50 6,844 6,902 PROD1 CORING CORE P Drill Core f/ 6844' - 6902' MD; From 6844' - 6875' MD ROP Averaged 5 -7 FPH w/ Breaks to 12 FPH Max; From 6875' - 6886' MD ROP Averaged 26 -31 FPH; 6886' - 6899' MD ROP Averaged 3 FPH w/ No Breaks; 6899' - 6902' MD ROP Dropped to .5 - 1 FPH w/ No Breaks Note: EPOCH Mud Logging Recorded 60 -70% Quartz in Samples Taken from the Lower Three Feet 22:00 00:00 2.00 6,902 6,100 PROD1 CORING TRIP T OWFF (Static) - Break Core and POOH f/ 6902' - 6100' MD Observing the 25 FPM Pulling Rate in the Well Plan 08/23/2009 Continue to POOH w/ Cores at Specified Speeds, Stopping at Predetermined Points for 30 Minutes - Held Core UD Dry Runs at Each Stop - Recovered 58' of Core - P/U 60' of Core Barrels and RIH t/ 6882' MD 00:00 04:00 4.00 6,100 3,741 PROD1 CORING TRIP T Continue to POOH w/ Core Barrels @ 25 FPM t/ 3741' MD 04:00 04:30 0.50 3,741 3,741 PROD1 CORING OWFF T OWFF - Allow Well to Go Static 04:30 08:30 4.00 3,741 800 PROD1 CORING TRIP T Continue to POOH w/ Core Barrels t/ 3,000' MD at 25 FPM then F/ 3,000' MD to 1400' MD at 18 FPM; and f/ 1400' to 800' MD at 10 FPM Page 19 of 64 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 09:15 0.75 800 800 PROD1 CORING OTHR T Predetermined Stop at 800' MD for Gas Expansion - Make Dry Run for UD Core Barrels w/ BOT Rep 09:15 10:00 0.75 800 607 PROD1 CORING TRIP T POOH f/ 800' - 607' MD @ 5 FPM 10:00 10:45 0.75 607 350 PROD1 CORING PULD T UD BHA f/ 607' - 350' MD @ 5 FPM 10:45 11:15 0.50 350 350 PROD1 CORING OTHR T Second Predetermined Stop - Hold Dry Run w/ BOT Rep for UD Core Barrels 11:15 13:00 1.75 350 95 PROD1 CORING PULD T UD Remainder of BHA Except Core Barrels at 5 FPM 13:00 15:00 2.00 95 0 PROD1 CORING PULD T UD Inner Barrels per BOT Rep - Recovered 58' of Core 15:00 18:00 3.00 0 333 PROD1 CORING PULD T Inspect Coring Bit - M/U Bit and 60' Core Barrels and Remaining BHA Components 18:00 23:00 5.00 333 6,568 PROD1 CORING TRIP T RIH w/ Core Barrels t/ 6568' MD 23:00 00:00 1.00 6,568 6,882 PROD1 CORING WASH T Wash & Ream t/ 6882' MD - 256 GPM @ 900 Psi 08/24/2009 Wash / Ream U 6902' MD (Tagged Bottom) - CBU - Drill Core f/ 6902' -6946' MD - CBU - POOH w/ Core t/ 1400' MD 00:00 00:30 0.50 6,882 6,902 PROD1 CORING WASH T Wash & Ream f/ 6882' - 6902' MD (Tagged Bottom) 00:30 02:30 2.00 6,902 6,902 PROD1 CORING CIRC P CBU Prior to Coring - 256 GPM @ 900 Psi 02:30 14:15 11.75 6,902 6,946 PROD1 CORING CORE P Drill Core f/ 6902' - 6946' MD; From 6902' - 6907' MD Average ROP 4.5 w/ Breaks t/ 9 FPH - From 6909' - 6914' MD Average ROP 3 FPH - From 6914' - 6922' MD Average ROP 8 FPH w/ Breaks to 19 FPH - From 6922' - 6936' MD Average ROP 3 FPH w/ Breaks U 8 FPH - From 6936' - 6943' MD Average ROP 6 FPH w/ Breaks to 12 - From 6943' - 6946' MD Average ROP 1.6 FPM w/ Breaks t/ 7.3 FPM WOB 10 -15 265 -315 GPM @ 1010 -1290 Psi RPM -70 Torque 6,000 -9,000 14:15 14:45 0.50 6,946 6,946 PROD1 CORING OTHR P Work to Break Core Free - 250 GPM @ 970 Psi 14:45 15:45 1.00 6,946 6,882 PROD1 CORING CIRC P S/B 4" DP Pup Jts and CBU - 250 Psi @ 970 Psi 15:45 20:30 4.75 6,882 3,603 PROD1 CORING TRIP P POOH w/ Core Barrels t/ 3603' MD 20:30 20:45 0.25 3,603 3,603 PROD1 CORING OWFF P OWFF (Static) 20:45 00:00 3.25 1,400 1,400 PROD1 CORING TRIP P Continue to POOH f/ 3603' -1400' MD 08/25/2009 Continue POOH with Core barrels as per time schedule. Breakout & lay down core and assembly. Service rig. MU BHA #9, 8 3/4" drilling assembly, TIH fill every 20 stands.Obtain Checkshot surveys @ 4186' & 4815'. Perform MAD PASS from 6800' - 6900' MD @ 100 ft/hr. 00:00 01:00 1.00 1,400 800 PROD1 CORING TRIP P Continue to POOH f/ 1400' - 800' MD Page 20 of 64 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 01:30 0.50 800 800 PROD1 CORING TRIP P Allow 30 minutes for decompression as per schedule. Perfrom dry run with core barrel shuck. 01:30 03:30 2.00 800 350 PROD1 CORING TRIP P Continue to POOH f/ 800' - 350' MD 03:30 04:00 0.50 350 350 PROD1 CORING TRIP P Allow 30 minutes for decompression as per schedule. Perfrom second dry run with core barrel shuck. 04:00 06:00 2.00 350 100 PROD1 CORING TRIP P Continue POOH racking back HWDP & DC's. Crew Change 06:00 08:30 2.50 100 0 PROD1 CORING PULD P Held PJSM with crew, BOT reps. Discuss safety & hazard recognition issues. Discuss procedure to breakout & lay down the core & coring assembly. Breakout & lay down #3 core & coring assembly as per BOT rep. Breakout core bit , grade same to 1 /1 /PN /N/X /I /NO /BHA, observing 3 plugged nozzles. 08:30 09:00 0.50 0 0 PROD1 DRILL PULD P Clean & clear rig floor area. Send out all core handling equipment. 09:00 10:00 1.00 0 0 PROD1 DRILL SVRG P Load pipe shed with BHA #9 tools. Calibrate Totco block height. Service Top Drive & crown sheaves. 10:00 11:30 1.50 0 124 PROD1 DRILL PULD P Make up 8 3/4" drilling BHA #9. as per DD, with Hughes HCM506Z bit & 7" Sperry drill motor. MU MWD tools. 11:30 13:00 1.50 124 124 PROD1 DRILL PULD P Plug in and upload MWD assembly. 13:00 14:00 1.00 124 124 PROD1 DRILL PULD T Change out MWD DM HOC tools. Observed voltage issues in tool, decision to chnage out to backup. 14:00 14:45 0.75 124 124 PROD1 DRILL PULD P Plug in and upload MWD assembly. Successful upload. 14:45 15:30 0.75 124 124 PROD1 DRILL PULD P Continue make up remaining BHA with NM Flex DC's . Perform shallow pulse test with pumps at 440 GPM's - 920 PSI. Good test. 15:30 15:45 0.25 124 154 PROD1 DRILL SFTY P Held PJSM with crew & Sperry hands. Discuss safety & hazard recognition, along with procedure to install Nuke sources in the assembly. Install sources. 15:45 16:30 0.75 124 656 PROD1 DRILL PULD P Continue make up 4" HWDP. Total BHA = 656.69' 16:30 18:00 1.50 656 3,491 PROD1 DRILL TRIP P Trip in hole with BHA #9 from 656' - 3491'. Fill drill string every 25 stands. Observed proper displacement. Obtain T & D parameters every 10 stands. Crew Change 18:00 21:30 3.50 3,491 6,647 PROD1 DRILL TRIP P Continue trip in hole with BHA #9 from 3491' - 6647'. Fill drill string every 25 stands. Obtain checkshot surveys @ 4186' & 4815' MD. Observed proper displacement. Obtain T & D parameters every 10 stands. Page 21 of 64 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 00:00 2.50 6,647 6,900 PROD1 DRILL REAM P Continue TIH and then wash & ream in hole from 6800' - 6900' MD performing MAD PASS surveys at 100 ft / hr. Pumps at 456 GPM's - 2770 PSI. 70 RPM's with 9K TQ. 08/26/2009 Continue MAD PASS from 6900' - 6947' MD. Washing & reaming back to bottom. Directional drill 8 3/4" hole from 6947' to TD at 7587' MD . TVD = 6668'. ADT = 10.98 HRS. CBU, BROOH 10 stands. CBU. TIH to TD. CBU x 3 with pumps at 460 GPM's - 2900 PSI. 00:00 00:30 0.50 6,900 6,947 PROD1 DRILL TRIP P Continue wash & ream in hole from 6900' - 6947' MD performing MAD PASS surveys at 100 ft / hr. Pumps at 456 GPM's - 2770 PSI. 70 RPM's with 9K TQ. 00:30 06:00 5.50 6,947 7,147 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 6947' - 7147' MD. TVD = 6229'. ADT = 5.13' HRS, AST = 0 HRS, ART = 5.13 HRS. Bit Hrs - 5.13. & Total Jar hours = 93.62. Pumps at GPM's- 470 - 3000 PSI. WOB = 12K RPM's = 100. UP WT = 165K, SO WT = 100K, ROT WT = 125K. TQ on - 9K, TQ off - 8K. ECD = 10.4 PPG. MAX gas observed = 80 Units. Crew Change 06:00 12:00 6.00 7,147 7,400 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 7147' - 7400' MD. TVD = 6481'. ADT = 3.04 HRS, AST = 0 HRS, ART = 3.04 HRS. Bit HRS = 8.17 & Total Jar hours = 96.66. Pumps at 480 GPM's- 3030 PSI. WOB = 12K RPM's = 100. UP WT = 170K, SO WT = 100K, ROT WT = 128K. TQ on - 9K, TQ off - 8K. ECD = 10.4 PPG. MAX gas observed = 123 Units. Obtained SPR's at MD. 12:00 16:30 4.50 7,400 7,587 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 7400' - 7587' MD. TVD = 6668'. ADT = 2.81 HRS, AST = 0 HRS, ART = 2.81 HRS. Bit Hrs - 10.98 & Total Jar hours = 99.4. Pumps at 480 GPM's- 3000 PSI. WOB = 12K RPM's = 100. UP WT = 175K, SO WT = 103K, ROT WT = 130K. TQ on - 9K,TQoff -8K. ECD =10.2 PPG. MAX gas observed = 152 Units. Obtained SPR's at 7587' MD. 16:30 17:30 1.00 7,587 7,587 PROD1 DRILL CIRC P Circulate bottoms up with pumps at 492 GPM's- 2900 PSI. Rotate & Reciprocate drill string. Max gas obseved = 73 units. 17:30 21:00 3.50 7,587 6,900 PROD1 DRILL REAM P BROOH from 7587' - 6900' MD. Observed no hole issues, with proper displacement. 21:00 21:30 0.50 6,900 6,900 PROD1 DRILL CIRC P CBU with pumps at 480 GPM's - 2800 PSI. Rotate & Reciprocate drill string. Max gas obseved = 60 units. Page 22 of 64 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 22:00 0.50 6,900 7,587 PROD1 DRILL TRIP P Trip back in hole to TD at 7587' MD. Observed proper displacement with no hole issues. 22:00 00:00 2.00 7,587 7,587 PROD1 DRILL CIRC P Circulate bottoms up x 3,a s per plan. Pumps at 460 GPM's - 2900 PSI. Rotate & Reciprocate drill string. 08/27/2009 Continue CBU x 3. POOH on elevators. perform checkshot survey @ 4816' MD. Continue POOH, breakout & lay down BHA #9 Inspect & grade bit to 1 /1/WT /A/X /I /ER/TD. RU Halliburton E -line. WLIH with Dipole Sonic, SPectral Gamma, Spontaneous Potential and 6 -Arm caliper logging suite. Tag at 7,569' WLM. Log from 7,569' to 3,743. Lay down tools. Make up Nuclear magnetic resonance tool assembly. 00:00 00:30 0.50 7,587 7,587 PROD1 DRILL CIRC P Continue circulate bottoms up x 3,a s per plan. Pumps at 460 GPM's - 2900 PSI. Rotate & Reciprocate drill string. 00:30 00:45 0.25 7,587 7,587 PROD1 DRILL OWFF P Monitor well - static. 00:45 08:15 7.50 7,587 656 PROD1 DRILL TRIP P Drop 2 1/2" Drift in DP. POOH on elevators. Obtain SLM. Observed utilizing rotation to break string free each connection for first 1500 ft pulled. Obtained checkshot survey at 4816' DPM. Continue POOH to BHA . Monitor well at the shoe and when at BHA 08:15 09:00 0.75 656 120 PROD1 DRILL PULD P Rack back HWDP & DC "s. Recover drift & wireline from DP. Flush BHA assembly with fresh water. 09:00 10:45 1.75 120 120 PROD1 DRILL PULD P Held PJSM with crew & Sperry reps. Discuss safety & hazard recognition issues. Discuss procedure for removing nukes. remove sources, plug in and download MWD assembly. 10:45 12:00 1.25 120 0 PROD1 DRILL PULD P Continue breakout & lay down remaining BHA. Inspect & grade bit to 1 /1/WT /A/X /I /ER/TD. Observed proper displacement on TOH. 12:00 12:30 0.50 0 0 PROD1 DRILL PULD P Clean & clear rig floor area. Send tools out. 12:30 14:30 2.00 0 90 PROD1 EVALWE RURD P Held PJSM with crew & Halliburton E -Line reps. Discuss safety & hazard recognition issues. Discuss rigging up and running wireline logging tools. MU Dipole Sonic assembly to 90'. Monitor well via trip tank. No losses. 14:30 22:00 7.50 0 0 PROD1 EVALWE ELOG P WLIH with Logging Run #1 - Dipole Sonic, Spectral Gamma -Ray, Spontaneous Potential and 6 -Arm caliper assembly to tag at 7569' WLM. Log from 7569'. WLOH, breakout & lay down assembly. 22:00 00:00 2.00 0 0 PROD1 EVALWE ELOG P Make up logging assembly for Wireline Logging Run #2 - Nuclear magnetic resonance assembly. Page 23 of 64 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/28/2009 24 hr Summary Continue wireline logging operations with MRIL tool assembly. Observed tool failure while logging up at 4,700'MD. Communication issues with tool. WLOH to replace tool. Lay down the swivel. Check tools. WLIH. Perform logs and log up from 4700 to 4300. WLOH, lay down partial tool assembly. While downloading data, a problem was observed with MRIL data from intial MRIL run logging run #2. MU tools assembly to relog the lower section 7150 -4700 . WLIH. 00:00 12:00 12.00 0 0 PROD1 EVALWE ELOG P Continue WLIH with 2nd logging (MRIL tool) run to 7569 WLM. Log up to 4700' WLM. Monitor well via trip tank. Well - static - no losses. 12:00 14:30 2.50 0 0 PROD1 EVALWE ELOG T Observe and troubleshoot electrical communication issue in tool string @ 4,700' MD. WLOH. lay down swivel. 14:30 22:30 8.00 0 0 PROD1 EVALWE ELOG T WLIH with logging run #3, MRIL assembly to 4,700 WLM. WLOH logging back to 4,300' at 3 ft/minute. POOH begin to lay down tools.Monitor well via trip tank. Static. Good hole conditions. 22:30 00:00 1.50 0 0 PROD1 EVALWE ELOG T Problem discovered with data from logging Run #2 (1st MRIL logging run). Data was inadvertently deleted. Discussion with Geologist, Drilling Engineer and Halliburton logging representative to determine path forward. Decision made to relog interval from 7,150 - 4,700'MD. MU tools, and WLIH to 7150' WLM. Begin logging back to 4,700' at 3 ft/minute. Well - static. 08/29/2009 Continue to relog the lower section with MRIL tool - logging run #4. Log from 7150' - 4300'. POOH, lay down MRIL tool assembly. MU E -log tool string for RDT drill pipe conveyed run. Run in hole to shoe @ 3742'. 00:00 13:00 13.00 0 0 PROD1 EVALWE ELOG T Continue logging run #4 - relog the lower section as planned. with the MRIL tool assembly from 7,150' - 4,700'. 13:00 16:00 3.00 0 107 PROD1 EVALWE ELOG P MU RDT wireline tool assembly. Total tool length = 107.14'. 16:00 16:30 0.50 107 107 PROD1 EVALWE SFTY P Held PJSM with crew & Halliburton reps. Discuss safety & hazard recogniiton issues. Discuss procedure to RIH with RDT assembly and MU side door entry sub. 16:30 18:00 1.50 107 507 PROD1 EVALWE ELNE P MU 4" HWDP, with 2.5" drift. Breakout & lay down bottleneck crossover. Crew Change 18:00 00:00 6.00 507 4,129 PROD1 EVALWE ELOG P Trip in hole with 4" drillpipe to 4129' DPM. Running speed 30 ft/min as per Halliburton rep. Fill drill string every 10 stands breaking circulation each time. Observed proper displacement. 08/30/2009 Slip & cut 120' of drilling line at 4100' MD. Make up side door entry sub as per Halliburton rep. Continue trip in hole logging with RDT wireline tool assembly from 4100' - 5498'. Running speed avg 30 ft/min. Obtained 36 samples. Monitor well via trip tank, well taking <1.5 BPH. Page 24 of 64 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 4,100 4,100 PROD1 RIGMNTSLPC P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to slip & cut drilling line. Slip & cut 120' of line. Monitor well - static. 01:30 00:00 22.50 4,100 6,530 PROD1 EVALWE ELOG P Make up side door entry sub as per Halliburton rep. Wireline in hole pumping at 3 BPM - 500 PSI to observed good latch up. Test tools. Continue RIH logging down obtaining samples & pressures Avg running speed 30 ft/minute. Midnight depth = 6530' MD. Monitor well via trip tank with the well taking < 1.5 BBLS /HR. 08/31/2009 Continue RIH logging down obtaining samples & pressures Avg running speed 30 ft/minute. Complete last of 48 total samples taken at 7168' MD. POOH from 7168' - 4166'. Lay down Side door entry sub. Unlatch - WLOH. Rig Down Halliburton E -liner crew. POOH on elevators to surface. Breakout & lay down RDT wireline tools. MU 8 3/4" Bit & BHA for wiper trip. TIH to TD at 7587' MD. CBU x 2, BROOH from 7587' - 7400' starting a 10 stand wiper trip. 00:00 04:00 4.00 6,530 7,168 PROD1 EVALWE ELOG P Continue RIH logging down obtaining samples & pressures Avg running speed 30 ft/minute. Final logging depth = 7168'. Observed the well taking a total of 8 BBLS for the trip. 04:00 07:30 3.50 7,168 4,166 PROD1 EVALWE ELOG P POOH with RDT wire line assembly from 7168' - 4166'. Pulling speed 40 -50 ft/mim with proper displacement. Observed good hole conditions with initial overpulls off bottom from 25 -60K. 07:30 08:30 1.00 4,166 4,166 PROD1 EVALWE ELOG P Breakout & lay down side door entry sub. Unlatch, and WLOH. 08:30 13:00 4.50 4,166 107 PROD1 EVALWE ELOG P Continue POOH on elevators from 4166' - BHA. Observed good hole condition with proper displacement. Monitor well at the shoe. Static. 13:00 15:00 2.00 107 0 PROD1 EVALWE ELOG P Lay down RDT logging tool assembly. Observed all equipment came back. Lay down sheaves. 15:00 15:15 0.25 0 0 PROD1 DRILL SFTY P Held PJSM with crew & DD. Discuss safety & hazard recognition issues. Discuss BHA and make up of same. 15:15 16:30 1.25 0 538 PROD1 DRILL PULD P Make up 8 3/4" bit, and remaining dumb iron BHA for wiper trip assembly. Total BHA length = 537.56'. 16:30 21:00 4.50 538 7,510 PROD1 DRILL TRIP P Trip in hole with BHA # 10. Fill drill string every 25 stands to tag up at 7510'. 21:00 21:45 0.75 7,510 7,587 PROD1 DRILL REAM P Make up Top Drive, wash & ream back to bottom from 7510' - 7587'. Work through spot at 7510' until clean. Pumps at 475 GPM's - 2500 PSI. UP WT 157K, SO WT = 90K, ROT WT = 147K. 120 RPM's with 7K TQ.SPR's taken at 7587'. Page 25 of 64 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 23:15 1.50 7,587 7,587 PROD1 DRILL CIRC P CBU x 2 while reciprocate & rotate drill string. 23:15 00:00 0.75 7,587 7,400 PROD1 DRILL REAM P Begin 10 stand short wiper trip. BROOH from 7587' - 7400'. Pumps at 475 GPM's - 2500 PSI. UP WT 157K, SO WT = 90K, ROT WT = 147K. 120 RPM's with 7K TQ. 09/01/2009 Complete short trip BROOH. Trip back to TD at 7587' CBU x 3. Monitor well - static. POOH on elevators. Breakout & lay down BHA. RU & run 7" casing to 1162' at midnight. 00:00 01:15 1.25 7,587 6,968 PROD1 DRILL REAM P Continue with 10 stand short wiper trip. BROOH from 7400' - 6968'. Pumps at 475 GPM's - 2500 PSI. UP WT 157K, SO WT = 90K, ROT WT = 147K. 120 RPM'S with 7K TQ. 01:15 01:30 0.25 6,968 6,968 PROD1 DRILL OWFF P Monitor well - static. 01:30 02:00 0.50 6,968 7,587 PROD1 DRILL TRIP P Trip back in hole form 6968' - 7587'. Good hole. 02:00 04:15 2.25 7,587 7,587 PROD1 DRILL CIRC P Wash down last stand, circulate & condition mud with pumps at 515 GPM's - 2750 PSI. Reciprocate & rotate drill string. 04:15 04:30 0.25 7,587 7,587 PROD1 DRILL OWFF P Monitor well - static. 04:30 06:00 1.50 7,587 6,529 PROD1 DRILL TRIP P POOH on elevators from 7587' - 6529' MD, observing up to 25K overpull but when broke free, good hole conditions. Crew Change 06:00 11:30 5.50 6,529 538 PROD1 DRILL TRIP P Continue POOH on elevators, monitoring well at the shoe. Pull to BHA. 538' 11:30 14:00 2.50 538 0 PROD1 DRILL PULD P Breakout & lay down BHA including drill collars. 14:00 15:00 1.00 0 0 PROD1 WHDBO BOPE P Clean & clear floor area. Rig up and pull the wear ring. Install test plug. Change top set of pipe rams installing 7" rams. 15:00 16:00 1.00 0 0 PROD1 WHDBO BOPE P Rig up and test 7" rams to 250 / 5000 PSI. Record on chart. Bleed pressures and rig down test equipment, 16:00 16:30 0.50 0 0 PROD1 CASING PULD P Make up 7" casing hanger & landing joint. RIH to land same for dummy run check. 16:30 20:15 3.75 0 0 PROD1 CASING RURD P Rig up to run 7" casing with Weatherford casing crew. Install long bales on top drive, with 150 ton side door elevators. RU power tongs, and power unit. RU fill up line. Pull all centralizer jewelry to rig floor. 20:15 20:45 0.50 0 0 PROD1 CASING SFTY P Held PJSM with crew, & Weatherford casing reps. Discuss safety & hazard recognition issues. Discuss Weatherford casing JSA with crew. Page 26 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 00:00 3.25 0 1,162 PROD1 CASING RNCS P Make up Silver Bullet float collar & joint, threadlock joint installing Weatherford 402 float collar with baker -loc. Fill string, and check floats. Floats good. Continue make up 7" 26# L -80 casing with make up torques @ 7500 - 8000 Ft/lbs. Install centralizers, stop rings, and spiralgliders as per detail. Midnight depth = 1162' MD. Monitor well, with proper displacement. 09/02/2009 Continue run 7" casing from 1126' - 7577' MD. Circulate at the shoe 3742', 5655' and on bottom. No hole issues while running in hole, with proper displacement. MU Hanger, and land casing. RU BJ cement head, and lines. Circulate & condition mud, while reciprocate string. Mix & pump 191 BBLS cement with 40 BBL spacer. Displace with rig pumps, not bumping the plug. Check Floats - held. Rig down all cement equipment & lines. Install casing hanger packoff, test same to 5000 PSI as per Vetco rep. 00:00 05:00 5.00 1,162 3,680 PROD1 CASING RNCS P Continue RIH from 1162' - 3680' MD, making up 7" 26# L -80 casing with make up torques @ 7500 - 8000 Ft/lbs. Install centralizers, stop rings, and spiralgliders as per detail. 05:00 06:00 1.00 3,680 3,680 PROD1 CASING CIRC P At the shoe, circulate bottoms up with pumps at 5 BPM - 420 PSI. No losses. 06:00 10:30 4.50 3,680 5,655 PROD1 CASING RNCS P Continue RIH from 3680' - 5655' MD, making up 7" 26# L -80 casing with make up torques @ 7500 - 8000 Ft/lbs. Install centralizers, stop rings, and spiralgliders as per detail. Obtain T & D parameters. 10:30 11:30 1.00 5,655 5,655 PROD1 CASING CIRC P At the shoe, circulate bottoms up with pumps at 4 BPM - 340 PSI. No losses. Reciprocate casing string. UP WT = 158K, SO WT - 95K. 11:30 15:00 3.50 5,655 7,577 PROD1 CASING RNCS P Continue RIH from 5655' - 7577' MD, making up 7" 26# L -80 casing with make up torques @ 7500 - 8000 Ft/lbs. Install centralizers, stop rings, and spiralgliders as per detail. Obtain T & D parameters. UP WT = 220K, SO WT = 136K. Observed no hole issues while running casing & proper displacement. 15:00 15:30 0.50 7,577 7,577 PROD1 CASING RNCS P Make up casing hanger & landing joint. RIH to land hanger. Make up BJ cement head and all lines & valves. SIMOPS: Cleaning pits, loading water in tiger tanks. 15:30 19:00 3.50 7,577 7,577 PROD1 CEMENT CIRC P Break circulation building to 5 BPM 570 PSI. Reciprocate casing string. UP WT = 220K, SO WT = 136K. 19:00 19:30 0.50 7,577 7,577 PROD1 CEMENT SFTY P Held PJSM with crew, BJ reps, and Peak drivers. Discuss safety & hazard recognition issues. Discuss procedure to mix & pump cement job and all presures expected. Designate Spill Champ. Page 27 of 64 0 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 21:30 2.00 7,577 7,577 PROD1 CEMEN" CMNT P Turn over to BJ. Pump 5 BBLS water. Pressure test lines to 3000 PSI. Held test 5 minutes. Good test. Drop bottom plug, mix & pump 40 BL PPG Spacer. Continue 10.5 n with 91 B LS of 10.5 PPG cement wit es at 6 BPM - 600 PSI. Flush lines. Drop & verify top plug. Full returns and continuous reciprocation of string while pumping. 21:30 22:45 1.25 7,577 7,577 PROD1 CEMEN" DISP P Turn over to rig pump. Displace cement with 8.5 PPG water from pits, at rates from 4 BPM - 785 PSI to 6 BPM - building to 1010 PSI, as we observed lift pressures of cement on the annulus. Full returns and continuous reciprocation of string while pumping. Stopped reciprocation of string at 5600 Strokes pumped (20 BBLS short of calculated bump) with full returns. Slow pumps to 4 BPM - 830 PSI, stabilizing pressure, continuing to pump a total of 6160 total STKS. 284 BBLS).Stepped pumping. Observe no bump plug. Shut in pressur — SI. Held 10 minutes. Bleed pressure & check floats. Held - no flow. CIP at 2220 HRS. Full returns through job. 22:45 00:00 1.25 7,577 7,577 PROD1 CEMEN" RURD P Rig down all cement equipment, lines & valves. Pull & lay down landing joint. Drain BOP stack. Install packoff & RILDS as per Vetco Gray rep. Test same to 5000 PSI. Witnessed by Driller. Rig down long bales on Top Drive installing short bales. 09/03/2009 Continue rig down equipment. Install & Test packoff to 5000 PSI.Change out & install 2 7/8" x 5" Rams. Rig up & test BOP's. Witness of test waived by AOGCC rep Jim Regg. Install wear bushing. RILDS. PJSM. Clean & prep rig and location for completion program. 00:00 00:30 0.50 0 0 PROD1 CASING PRTS P Install & Test 7" packoff to 5000 PSI, as per Vetco Gray rep. 00:30 01:30 1.00 0 0 PROD1 CASING BOPE P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedures to change out rams, & test BOP's. Change out top set of rams, removing 7 ", installing 2 / 7/8" x 5" VBR's. 01:30 02:00 0.50 0 0 PROD1 WHDBO BOPE P Clean & clear rig floor area, prepare for BOP test. Page 28 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 10:30 8.50 0 0 PROD1 WHDBO BOPE P Rig up t equipment. Test BOP's to 250'/ 500Q PSI. Test BOP stack & rams, rrtarfual & HCR valves. Test choke manifold, floor valves including dart valve. Test upper & lower IBOP's in Top Drive. Perform Koomey test with first 200 PSI in 30 secs, and full 3000 PSI in 1 min 40 secs. Performed test with 4" & 4 1/2" test joints. Observed 6 nitrogen bottles with avg 2150 PSI. Witness of test waived by AOGCC rep - Jim Regg. 10:30 11:00 0.50 0 0 PROD1 WHDBO BOPE P Pull test plug insatll wear bushing with a 6.375" ID. RILDS. 11:00 00:00 13.00 0 0 PROD1 WELLPF RURD P Held PJSM. Clean & prepare rig & location for upcoming completion. Held Pre -Spud for completion with engineers. Clean up includes all pit cleaning. Flush BOP stack ,all lines and hoses. Load out all uneeded tools and equipment. Prepare the location for equipment to be moved in. Clean boilers on rig. Load all MI SWACO BHA tools in pipe shed. 09/04/2009 Clean & prep rig and location for completion program. 00:00 12:00 12.00 0 0 PROD1 WELLPF RURD P Held PJSM. Clean & prepare rig & location for upcoming completion. Held Pre -Spud for completion with engineers. Clean up includes all pit cleaning. Flush BOP stack ,all lines and hoses. Load out all uneeded tools and equipment. Prepare the location for equipment to be moved in. Clean boilers on rig. 12:00 00:00 12.00 0 0 PROD1 WELLPF RURD P Continue clean up. includes all pit cleaning. Mix caustic wash for upcoming flush of all lines and hoses. Load out all uneeded tools and equipment. Prepare the location for equipment to be moved in. Clean boilers on rig. Swaco reps installing 3" camlocks replacing aluminum fittings. 09/05/2009 00:00 12:00 12.00 0 0 PROD1 WELLPF RURD P Continue clean up. includes all pit cleaning. Mix caustic wash for upcoming flush of all lines and hoses. Load out all uneeded tools and equipment. Prepare the location for equipment to be moved in. Clean boilers on rig. Swaco reps installing 3" camlocks replacing aluminum fittings. Build berm for upright tanks. Page 29 of 64 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 0 0 PROD1 WELLPF RURD P Continue clean up. includes all pit cleaning. Mix citric, and safe surf wash for flush of all lines and hoses. Load out all uneeded tools and equipment. Prepare the location for equipment to be moved in. Clean boilers on rig. Swaco reps installing 3" camlocks replacing aluminum fittings. Continue building berms for tanks & Swaco equipment. 09/06/2009 Clean & prep rig and location for completion program. MU MI SWACO Ceeanout BHA. TIH with 4" Dp to ? ?? 00:00 12:00 12.00 0 0 PROD1 WELLPF RURD P Continue clean up. includes all pit cleaning. Mix citric wash, and safe surf wash for flush of all lines and hoses. Flush lines with clean rinse water. Clean pits again. Prepare the location for MI SWACO equipment to be moved in. Clean boilers on rig. Swaco reps installing 3" camlocks replacing aluminum fittings. Continue building berms for Tank farm & Swaco equipment. 12:00 20:00 8.00 0 0 PROD1 WELLPF RURD P Continue clean & inspect pits again. Inspect & change out seals on pirt valves, and valve seats. Install rubber flooring over pit grates to prevent debris from entering pits. Work on steam system for heating tanks. Prepare the location for MI SWACO equipment to be moved in. Clean boilers on rig. Swaco reps installing 3" camlocks replacing aluminum fittings. Continue building berms for Tank farm & Swaco equipment. Spot MI Swaco filtration equipment. 20:00 20:30 0.50 0 0 PROD1 WELLPF SFTY P Held PJSM with crew & MI Swaco tool reps. Discuss safety & hazard recognition issues. Discuss procedure to make and run cleanout assembly. 20:30 21:00 0.50 0 60 PROD1 WELLPF PULD P Make up clean out BHA with 6 1/8" Baker mill, 7" Razor back, Stabilizer, magnet & brush assemblies. Simops: Load tiger tanks with water, rig up filtration equipment. Attach electrical panel. Verify equipment running correctly. 21:00 00:00 3.00 60 4,000 PROD1 WELLPF TRIP P Trip in hole with cleanout BHA from 60' - 4000' MD. Observed proper displacement. SIMOPS: Continue Rig up filtration equipment, load tanks with water. Load DE on filtration press for precoat. Page 30 of 64 w • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/07/2009 24 hr Summary Continue trip in hole with MI Swaco cleanout BHA from 4000' - tag at 7466'. Perform wiper trip back top 3900'. Rig up, pump safety pickle at 1 BPM. Reverse out same. Mix & pump well cleanout pills including Flo Visc, caustic, mix, safe floc, and circulate filtered fresh water. Shut down. Clean pits, lines. Discard all fresh water returns. Clean pits. Mix and filter 12% KCL brine. 9.0 PPG, and load rig pits with same. 00:00 03:00 3.00 4,000 7,466 PROD1 WELLPF TRIP P Continue trip in hole with MI Swaco cleanout BHA from 4000' to tag at 7466' DPM. Set down 15K x 3 to verify hard tag. UP WT = 175K, SO WT = 90K 03:00 06:00 3.00 7,466 3,789 PROD1 WELLPFTRIP P Perform wiper trip with MI Swaco BHA from 7466' back to 3789' allowing brushes back to top of casing. Crew Change 06:00 08:00 2.00 3,789 7,445 PROD1 WELLPF TRIP P Trip back in hole from 3789' - 7445' DPM . Avg running speed 150 ft/min as per Swaco rep. 08:00 08:30 0.50 7,445 7,445 PROD1 RIGMN1 SVRG P Service Top Drive, Blocks and draw works. 08:30 15:30 7.00 7,445 7,445 PROD1 WELLPF CIRC P Held PJSM with crew, swaco & MI reps. Discuss safety & hazard recognition issues. Discuss procedure to mix and pump pickle. Check all lines and valves. Pump 20 BBLS of Visc pill, 9.2 BBLS of Safety Pickle continuing with 69 BBLS of filtered fresh water, with pumps at 1 BPM - 50 PSI 15:30 18:30 3.00 7,445 7,445 PROD1 WELLPFCIRC P Held PJSM with crew, swaco & MI reps. Discuss safety & hazard recognition issues. Discuss procedure to mix and pump well cleanout pills. Mix & pump 20 BBLS visc pill, 70 BBLS of caustic wash, 75 BBLS of safe surf, 25 BBLS visc pill, and 110 BBLS of Safe Floc. Continue pump with filtered fresh water at rate of 7.5 BPM. Pumped a total of 420 BBLS. Reciprocate & rotate drill string at 60 RPMs. 18:30 19:00 0.50 7,445 7,445 PROD1 WELLPFCIRC P Observed Filter press packed off. Unable to feed rig pits with clean water. Shut down pumping with clean filtered water at surface. 19:00 00:00 5.00 7,445 7,445 PROD1 WELLPF RURD P Decision made to stop short of planned 790 BBLS as the well was already displaced to clean water. Clean pits, filter press, pods, lines, and hoses. Discard all fluids in pits, and rockwasher. Mix and filter 12% KCL brine, loading rig pits for displacement. 09/08/2009 Continue mix and filter 12% KCL 9.0 PPG brine and load rig pits with same. Displace well with 12% KCL and circulate to verify returns less than 20 NTU's. POOH, breakout & lay down BHA. Page 31 of 64 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:30 3.50 7,445 7,445 PROD1 WELLPF RURD P Continue mix and filter 12% KCL 9.0 PPG brine and load rig pits with same. Discard all fresh water returns in pits. 03:30 17:45 14.25 7,445 7,445 PROD1 WELLPF CIRC P Displae Well to 9 PPG 12% KCL brine at 3 -7.5 BPM. The NTU reading of returns leveled off at 20 -50 range for 7 hours. Made a pilot test by adding 0.2% lnflo 150 surfactant and 0.05% ClayMaster 5C in the 12% KCI brine w/ NTUR =7, NTU reading has no change. Displace 300 bbl 12% KCL brine with 0.2% inflo 150 surfactant and 0.05% ClayMaster 5C to well, the returns NTU =25 -50 range. Treat and Process Thru Filtration Systems Fluids on Surface - 7 BPM @ 1370 Psi 17:45 18:00 0.25 7,445 7,445 PROD1 WELLPF OWFF P OWFF (Static) 18:00 23:00 5.00 7,445 0 PROD1 WELLPF TRIP P POOH on Elevators - UD 7 jts of 4" HT 38 DP - Stand Remainder Back in the Derrick - UD Mi Swaco Clean Out BHA 23:00 00:00 1.00 0 0 PROD1 WELLPF ELOG P Clean & Clear Rig Floor - Service Rig - Prep f/ E -Line 09/09/2009 R/U Halliburton E -Line Sheaves and Logging Tools - RIH and Log Cement f/ 7430' MD t/ TOC 2500' MD - Test 7" Casing t/ 4700 Psi f/ 30 Minutes - R/U and Set Bridge Plug @ 6875' MD - R/D Halliburton E -Line - R/U & Run 4 1/2" 12.6# Work String t/ 3077' MD 00:00 02:00 2.00 0 0 PROD1 EVALWE RURD P PJSM; Rig Up E -Line Sheaves and Equipment for CBL 02:00 09:15 7.25 0 0 PROD1 EVALWE ELOG P RIH w/ E -Line fast Cast CBL - Log Cement f/ 7430' to TOC 2500' MD - POOh w/ CBL Tool String 09:15 09:45 0.50 0 0 PROD1 EVALWE RURD P UD CBL Tool String 09:45 12:00 2.25 0 0 PROD1 RPCOM PRTS P PJSM; R/U and test 7" Casing t/ 4700 Psi f/ 30 Minutes 12:00 16:00 4.00 0 0 COMPZ RPCOM MPSP P PJSM; R/U and RIH w/ Bridge Plug - Set on Depth at 6875' MD 16:00 16:45 0.75 0 0 COMPZ RPCOM PULD P L/D E -Line Tools and Sheaves - Rig Down E -Line Unit and Prepare to Move 16:45 19:00 2.25 0 0 COMPZ RPCOM RURD P Rig Up Weatherford Tools to Run 4 1/2" Work String 19:00 19:30 0.50 0 0 COMPZ RPCOM OTHR P Service Rig 19:30 00:00 4.50 0 3,077 COMPZ RPCOM PUTB P RIH w/ 4 1/2" 12.6 PPF Work String as Follows Mule Shoe & 100 jts of 4.5" Tubing t/ 3077' MD 09/10/2009 Continue to RIH w/ Work String t/ 5906' MD - R/U to Pickle String - Pickle String w/ 18 Bbls of 15% HCL Acid - Reverse Out Pickle - Circ & Cond Mud to Lower NTU to Less than 20 - R/D BJ Circ Head - R/U BJ Frac Head 00:00 03:00 3.00 3,077 5,906 COMPZ RPCOM PUTB P Continue to RIH w/ 4 1/2 ", 12.6# Work String Page32 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 04:30 1.50 5,906 5,906 COMPZ RPCOM RURD P R/D Weatherford Tubing Running Tools - R/U BJ to Pump Tubing Pickle 04:30 14:30 10.00 5,906 5,906 COMPZ RPCOM RURD P R/U BJ Equipment to Pump Pickle; M/U Hard lines, build Containments and Stage Equipment, Prep and Stage materials for Treating Pickle on Surface, Stage Spill kits 14:30 17:15 2.75 5,906 5,906 COMPZ RPCOM CIRC P PJSM on Pumping Pickle - PT Lines to 2500 Psi - Pickle Work Sting as Follows; 20 Bbls Flow Vis, 13.8 Bbls 15% HCL Acid, 74.8 Bbls 12% KCL Brine 17:15 18:00 0.75 5,906 5,906 COMPZ RPCOM CIRC P Reverse Circulate Pickle w/ Rig Pumps Taking Returns to the Cuttings Box - 3 BPM @ 150 Psi 18:00 21:30 3.50 5,906 5,906 COMPZ RPCOM CIRC P R/U to Take Returns to Pits - Continue to Reverse Circulate & Filter 9.0 PPG 12% KCL Brine @ 8 BPM - Brine Foamed Up in Pits - Circulated Normally @ 6 BPM Unitl NTU's Dropped and Stabilized Below 20 - Initial NTU Reading 300. NTU readings gradually dropped to 12 - 7 for the Final 1.75 hrs 9.0 PPG 12% KCL w/ 0.2% In Flow 150 and 0.05% Clay Master 5C 21:30 00:00 2.50 5,906 5,906 COMPZ RPCOM RURD P R/D BJ Circulating Equipment and R/U BJ Frac Head 09/11/2009 Continue Rig Up of Frac Head - Spot BJ Frac Pumps, Sand King, Ops Trailer, Hydrator, Propit, Mix Trailer - R/U BJ Hard Lines - Fill the Sand King w/ Propit - Spot and R/U Halliburton E -Line Equipment - P/U and R/U Pump -In Sub and E -Line BOP - Continue Mixing 6% KCL and Heating w/ Steam to 90 Degrees 00:00 12:00 12.00 5,906 5,906 COMPZ STIM RURD P Continue Rig Up of Frac Head - Spot BJ Frac Pumps, Sand King, Ops Trailer, Hydrator, Propit, Mix Trailer 12:00 00:00 12.00 5,906 5,906 COMPZ PERF RURD P Continue w/ R/U of BJ Hard Lines and Filling the Sand King w/ Crane - Spot and R/U Halliburton E -Line Equipment - P/U and R/U Pump -In Sub and E -Line BOP - Heat Brine Tanks t/ 80 +/- 10 Degrees 09/12/2009 Continue to R/U and Spot BJ Frac Equipment and HES E -Line Unit - Build and Filter 8.6PPG 6% KCL for Frac - Heat KCL uprights to 80 +/- 10 Degrees - PJSM on Perf Gun Handling and Frac Head Pressure Testing - Pressure Test BJ Lines and Frac Head to 6,000 Psi f/ 5 Minutes - Pressure Test FOSV from Annulus to 3500 Psi f/ 5 Minutes - R/U HES Lubricator w/ Guns - Pressure Test t/ 1500 Psi f/ 5 Minutes - RIH w/ HES E -Line Perf Guns 00:00 18:00 18.00 5,906 5,906 COMPZ STIM RURD P Continue to R/U BJ Frac Equipment and Halliburton E -Line Unit - Build 6% Filtered KCL Brine for Frac and Heat to 80 +/- 10 18:00 20:30 2.50 5,906 5,906 COMPZ STIM OTHR P Continue to Heat Upright Tanks of 8.6 PPG 6% KCL Brine w/ Steam Page 33 of 64 1 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 21:00 0.50 5,906 5,906 COMPZ PERF SFTY P PJSM w/ BJ, Hallibruton, CPAI Rep, DDI Crew, Peak Crew & MI Crew on R/U the Lubricator w/ Perf Guns - Gun Safety - Handling Spent Guns - Pressure Testing BJ Equipment, Lines, and Frac Head 21:00 22:00 1.00 5,906 5,906 COMPZ STIM PRTS P Pressure Test BJ 3" Lines f/ Frac Pumps to 3" Valve & Pumps to FOSV w/ BJ Pumps t/ 6,000 Psi f/ 5 Minutes - Pressure Up on Annulus w/ Rig Pumps and Test FSOV to 3500 Psi f/ 5 Minutes 22:00 23:00 1.00 5,906 5,906 COMPZ PERF RURD P R/U HES Lubricator w/ Guns 23:00 23:45 0.75 5,906 5,906 COMPZ PERF PRTS P R/U and Pressure Test HES Lubricator w/ Rig Test Pump t/ 1500 Psi f/ 5 Minutes 23:45 00:00 0.25 5,906 5,906 COMPZ PERF TRIP P RIH w/ HES Perf Guns on E -line - Monitor Well via TT 09/13/2009 Continue to RIH w/ E -Line Perf Guns - Perforate 6686-6706' MD w/ Millenium Charges @ 6 SPF - POOH and R/D Lubricator to inspect Guns - Perform DFIT - Conduct Frac Analysis and Continue to Build and Heat 8.6# 6% Filtered KCL Brine - Perform Mini -Frac - Conduct Frac Analysis and Continue to Build and Heat 8.6# 6% Filtered KCL Brine - Perform Main Frac 00:00 01:00 1.00 5,906 6,706 COMPZ PERF TRIP P Continue to RIH w/ Perf Guns U 6706' MD - Correlate Depth w/ Gamma 01:00 01:15 0.25 6,686 6,706 COMPZ PERF PERF P Close Top Pipe Rams - Open Kill Line and Apply 130 Psi to Wellbore - Fire Perf Guns; Shot Density 6 SPF - Perforated f/ 6686' - 6706' MD - PSI Applied Dropped to 90 After Firing Guns 01:15 02:00 0.75 6,706 0 COMPZ PERF TRIP P POOH w/ Spent Perf Guns 02:00 02:45 0.75 0 0 COMPZ PERF RURD P R/D Lubricator - Inspect Guns - Gun OD 3.25' after Firing - All Shots Fired - Shot Orifice 1/2" 02:45 03:15 0.50 0 0 COMPZ STIM SFTY P PJSM w/ BJ, CPAI, DDI, MI, HES on DFIT Procedures; Discussed High Pressure Ops 03:15 03:30 0.25 0 0 COMPZ STIM PRTS P Flood All Lines - Pressure Test BJ Lines t/ 6,000 Psi 03:30 06:00 2.50 0 0 COMPZ STIM STIM P Pump DFIT as Follows: 90 Bbls of 8.6 Ppg 6% KCL @ 24 BPM w/ 1138 Psi - Close Choke - Stage Pumps Up f/ 4.5 BPM to 7.1 BPM Injected 30 Bbls of 8.6 Ppg KCL Brine Pressures Rose t/ 3190 Psi and Broke Over to 2790 Psi and Slowly Climbed to 3064 Psi as the Rate Reached 7.1 PBM 06:00 15:00 9.00 0 0 COMPZ STIM OTHR P Shut Well in, Conduct Frac Analysis and Monitor Pressure - Pressure On Casing Gauge Dropped f/ 500 - 200 Psi 15:00 15:30 0.50 0 0 COMPZ STIM SFTY P PJSM for Mini -Frac w/ BJ, CPAI, MI, Peak & DDI Page 34 of 64 1 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 18:00 2.50 0 0 COMPZ STIM STIM P Pumped 20 Bbls of 8.6 ppg 6% KCL Brine Followed by 90 Bbl Cross Linked Lightning 2000 Gel @ 20#, Injected 10 Bbl Cross Linked Gel and Flush w/ 120 Bbl 8.6# 6% KCL Brine @ 15 BPM - Initial Shut in Pressure 2375 psi 18:00 21:30 3.50 0 0 COMPZ STIM OTHR P Conduct Mini -Frac Analysis - Build Frac Plan - Continue to Build and Heat 6% Filtered KCL Brine Stored in Uprights 21:30 22:00 0.50 0 0 COMPZ STIM SFTY P PJSM on Main Frac w/ CPAI, DDI, Peak, MI and BJ 22:00 00:00 2.00 0 0 COMPZ STIM STIM P Perform Main Frac as Follows: Pump 90 Bbls Filtered 6% KCL Brine and Take Returns to Pits - Pump 270 Bbl Pad - Pump 558 Bbl Main Frac Ramping Sand Slurry f/ 1 -6# - Hold 72 Bbls 6# Sand Slurry - Flush w/ 108 Bbls Linear Gel - Total Sand Pumped 85,991 lbs; Sand In Formation 84,272 lbs; Left 1700 Ibs Sand in Casing for Plug - Took 5 Cross Linked gel Samples (Good) - Filtered 8.6# KCL Brine Used for Gel @ 80 -90 Deg F - All Numbers From BJ Service Job Master Program - Initial Shut in Pressure 2300 psi 09/14/2009 Monitor Well and wait for Sand Plug to Settle Out - Pressure Test Sand Plug (Failed) - RIH and Tag Top of sand plug @ 6783' MD - Pump 2 - 20 bbl Sand Slurries at 2 PPG Average sand Content, Each Chased by 70 bbls of 8.6 PPG KCL Brine - Allowed Sand to Settle for an Hour After Each Slurry - Attempted to Pressure Test the Plug (X4) - Decision Made to Continue w/ Next Operations - Rlh w/ Live Perforating Guns and Tag Sand Plug @ 6672' MD - Pull Up and Perforate 6591' - 6606' MD - POOH and Verify All Shots Fired - Perform DFIT - Monitor Pressure and Build Main Frac Program - SIMOPS: Continue to Build, Filter and Heat 8.6 PPG 6% KCL Brine NOTE: Glycol Heater Hooked Up to Tanks 1, 2, A & B - 1900 Temperatures 56, 58, 72, 48 - 2100 Temperatures 58, 58, 72, 50 - Brine Temperature Did Not Increase - R/D Glycol Heater f/ Tanks 1 & 2 and Hook Up Rig Steam - Steam Online at 2345 - 0200 Brine Temps 65, 70, 72, 48 F 00:00 01:30 1.50 0 0 COMPZ STIM PLUG P Monitor Pressure & Wait for Sand to Settle Out 01:30 02:00 0.50 0 0 COMPZ STIM PRTS P Pressure Test Sand Plug (Unsuccessful)- Pumped 6.5 Bbls at 3.3 BPM Pressure Stabilized at 2605 Psi while Pumping - Shut Down & Monitor Pressure - Pressure Decreased 1,000 Psi in 3.6 Minutes 02:00 03:15 1.25 0 0 COMPZ STIM RURD P R/U HES Lubricator - Pressure Test t/ 1500 Psi f/ 5 Minutes - Equalized Lubricator to WB Pressure 842 Psi 03:15 05:45 2.50 0 0 COMPZ STIM TRIP P RIH w/ Spent Perf Guns & Gamma on E -Line - Tagged Sand Plug @ 6783' MD (X3) - POOh w/ E -Line & Spent Guns to Lubricator 05:45 06:00 0.25 0 0 COMPZ STIM RURD P R/D HES E -Line Sheaves Page 35 of 64 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 06:30 0.50 0 0 COMPZ STIM PLUG P Pump First Sand Plug w/ BJ Pumps as Follows: 20 Bbl, 2 Ppg Average (1300 Ibs Total), Sand Slurry Chased by 70 Bbl 8.6 Ppg 6% KCL Brine @ 7 BPM w/ 450 Psi 06:30 07:30 1.00 0 0 COMPZ STIM OTHR P Wait for Sand to Settle Out 07:30 08:00 0.50 0 0 COMPZ STIM PLUG P Pump Second Slurry as Follows: 20 Bbl, 2 Ppg Average (1300 Ibs Total), Sand Slurry Chased by 70 Bbl 8.6 Ppg 6% KCL Brine @ 7 BPM w/ 450 Psi 08:00 09:00 1.00 0 0 COMPZ STIM OTHR P Wait for Sand to Settle Out 09:00 09:30 0.50 0 0 COMPZ STIM PRTS P Attempt Pressure Test Sand Plug w/ Rig Pumps t/ 3,000 Psi - Pumped 8 Bbls of Brine @ 3.3 BPM and Pressure Never Exceeded 2730 Psi - Let Pressure Bleed to 1100 Psi (5 Minutes) and Pressure Up again t/ 2730 Psi - Pressure Bled to 1092 Psi in 10 Minutes 09:30 12:00 2.50 0 0 COMPZ STIM TRIP P PJSM - RIH w/ Spent Guns on E -Line - Tagged Top of Sand Plug @ 6669' MD - Decision Made to Allow Sand to Continue to Settle Out 12:00 13:00 1.00 0 0 COMPZ STIM OTHR P Pull Guns Up Into Lubricator and Bleed Pressure - Wait for Sand to Settle Out 13:00 13:30 0.50 0 0 COMPZ STIM PRTS P Attempt to Pressure Test Sand Plug t/ 3,000 Psi - Pressure Bled Off to 1350 Psi in 10 Minutes - Bled Pressure and Shut Well In - SICP 400 Psi 13:30 14:30 1.00 0 0 COMPZ STIM OTHR P Wait for Sand to Settle Out 14:30 18:00 3.50 0 0 COMPZ STIM PRTS P Attempt to Pressure Test Sand Plug t/ 3,000 Psi - Pressured up to 3,000 Psi and Monitor f/ 10 Minutes - Pressure Bled to 1550 Psi - Decision Made to Continue Subsequent Operations 18:00 18:15 0.25 0 0 COMPZ PERF SFTY P PJSM on Handling Frac Guns 18:15 19:15 1.00 0 0 COMPZ PERF RURD P R/D Spent Guns and R/U Live Guns and Sheaves 19:15 21:45 2.50 0 0 COMPZ PERF PERF P RIH w/ Perforating Guns and Gamma on E -Line - Tag Top of Sand @ 6672' MD - Depth Correlated by Gamma - Pull Up to Depth and Perforate 6591' - 6606' MD, Shot Density 6 SPF - Casing PRessure Prior to Shot 400 Psi / after Shot 300 Psi - POOH w/ Spent Guns 21:45 22:15 0.50 0 0 COMPZ PERF RURD P R/D Lubricator and Inspect Gun - R/U Lubricator - R/D E -Line Sheaves SIMOPS: Rig Down Glycol Heater f/ Tanks 1 & 2 and R/U Steam Page 36 of 64 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 22:45 0.50 0 0 COMPZ STIM SFTY P PJSM on Data Frac w/ CPAI, DDI, Peak, MI and BJ 22:45 23:45 1.00 0 0 COMPZ STIM STIM P Prime Frac Pumps & Pressure Test Surface Lines t/ 6000 Psi - Open to Well Head and Commence DFIT; Pumped 23.9 Bbls of 8.6#, 6% KCL Brine @ 2.2 BPM Until Formation Broke Over at 2752 Psi - After Formation Broke Pumped Remainder of DFIT at 6.6 BPM w/ 2830 psi SIMOPS: Steam Online to Tanks 1 & 2 at 2345 23:45 00:00 0.25 0 0 COMPZ STIM OTHR P Monitor Pressure for DFIT 09/15/2009 Monitor Pressure and Analyze DFIT Data While Heating Brine - Perform Main Frac; Pumped 27,190 Ibs of Sand Into Formation - Allow Sand to Settle Out and Pressure Test Plug t/ 3,000 Psi - Tag Sand w/ Spent Perf Guns on E -Line @ 6577' MD - Load Live Guns and Perforate 6492' - 6512' MD @ 6 SPF Density (All Shots Fired) - Pump DFIT, Analyze Data and Build Main Frac Program SIMOPS: Continue to Heat and Build 6% KCL Brine 00:00 09:00 9.00 0 0 COMPZ STIM OTHR P Heat 6% KCL Brine for Frac - Desired Temp 80 F 09:00 09:30 0.50 0 0 COMPZ STIM SFTY P PJSM w/ BJ, MI, DDI, CPAI & Peak for Main Frac 09:30 11:30 2.00 0 0 COMPZ STIM STIM P Perform Main Frac as Follows: Pump 75 Bbl Cross Linked Gel Pad - 25 Bbl, 1 PPG Sand Slurry - 150 Bbls Sand Slurry Ramp Up Sand Content f/ 1 to 6 PPG - 38 Bbl, 6 PPG Sand Slurry - Flush w/ 102 Bbl Linear Gel -- Total Sand Pumped 27,190 Lbs / Sand In Formation 25,086 Lbs / Sand Left in Casing for Plug 2,098 Lbs 11:30 13:30 2.00 0 0 COMPZ STIM OTHR P Wait for Sand to Settle Out 13:30 14:00 0.50 0 0 COMPZ STIM PRTS P Attempt Pressure Test Sand Plug t/ 3,000 Psi - Started Pumping Fluid Away at 2840 Psi - Shut In and Monitor Pressure f/ 10 Minutes Pressure Dropped to 2232 Psi - Pressure Up to 3000 Again - Shut In and Monitor for 10 Minutes - Pressure Dropped 120 Psi to 2880 Psi - Bled Pressure to t/ 1000 Psi 14:00 17:00 3.00 0 0 COMPZ STIM TRIP P PJSM - Pressure Test Lubricator Flange t/ 1800 Psi - RIH w/ Spent Guns on E- Line - Tagged Top of Sand Plug © 6577' MD - POOH & UD Spent Guns 17:00 17:30 0.50 0 0 COMPZ PERF SFTY P PJSM w/ HES, MI, CPAI & DDI on Picking Up Live Perf Guns 17:30 18:00 0.50 0 0 COMPZ PERF PULD P P/U Live Guns and M/U Lubricator - Test Flange Seals t/ 1800 Psi Page 37 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 19:15 1.25 0 0 COMPZ PERF PERF P RIH w/ Live Guns, Gamma and CCL on E -Line t/ 6512' MD - Correlate Depth w/ CCL and Gamma - Perforate f/ 6492' - 6512' MD w/ Millenium Charges at a Shot Density of 6 SPF - POOH w/ Spent Guns - PRessure Before Firing Guns 500 Psi / After 375 Psi 19:15 19:45 0.50 0 0 COMPZ PERF RURD P Break Lubricator at Test Sub Flange and Inspect Guns - All Shot Fired - Gun OD In 3.125" Out 3.25" - R/U Lubricator w/ Spent Gun Inside 19:45 20:15 0.50 0 0 COMPZ STIM OTHR P Monitor Well Bore Pressure & Heat 6% KCL 20:15 20:30 0.25 0 0 COMPZ STIM SFTY P PJSM w/ BJ, DDI, MI, Peak & CPAI on DFIT 20:30 20:45 0.25 0 0 COMPZ STIM STIM P Prime BJ Pump #3 w/ 10 bbls 6% KCL - Pump 3.6 Bbls of 6% KCL Brine at 3.5 BPM - Formation Fractured at 2950 Psi - Increased Rate to 6.3 BPM and Pumped 20.4 Bbls Into Formation w/ Pressure Decreasing f/ 3050 to 2875 Psi - Initial Shut in Pressure 2850 Psi 20:45 00:00 3.25 0 0 COMPZ STIM OTHR P Analyze DFIT Data and Concoct Main Frac Plan - Brine Tank Temps at 2100: 1 -90, 2 -87, A -79, B -54 F 09/16/2009 Troubleshoot BJ Linker Mix Pump - Pump Main Frac Stage #3 - Pressure Test Sand Plug (Good)and Tag w/ E -Line @ 6510' MD - Pressure Up and Bleed Off Annulus Pressure - Tag Sand Plug Again at 6490' MD - Wait on Orders - Pressure Up / Bleed Off Annuls Pressure - Tag Again w/ E -Line @ 6343' MD - RIH w/ 10' Perf Gun and Perf 6183' - 6193' MD at 6 SPF Density - RIH w/ 20' Perf Gun and Perf 6144' - 6164' MD at 6 SPF Density - R/U and Test BJ Equipment Prior to Conducting DFIT 00:00 00:45 0.75 0 0 COMPZ STIM OTHR P Analyze DFIT Data - Continue to Heat 6% KCL 00:45 01:15 0.50 0 0 COMPZ STIM SFTY P PJSM for Main Frac w/ BJ, CPAI, DDI, MI & Peak 01:15 02:30 1.25 0 0 COMPZ STIM STIM T Troubleshoot BJ "Linker" Injector Pump /HoseNalves 02:30 04:00 1.50 0 0 COMPZ STIM STIM P Pump Main Frac as Follows: Pump 175 Bbl Cross Linked Gel Pad Taking 90 Bbls of Returns to the Pits Prior to Closing Choke - 104 Bbl, 1 PPG Sand Hold - 577 Bbl Ramp Increasing Sand Content f/ 1 -6 PPG - 127 Bbl, 6 PPG Sand Hold - 18 Bbl, 8 PPG Sand for Plug - 90 Bbl 6% KCL Flush - Pump Rate 18.5 BPM - Pumped 102,367 Lbs of Sand Into the Formation, Left 4,200 Lbs of Sand in the Casing, Total 106,567 Lbs of Sand Pumped 04:00 06:30 2.50 0 0 COMPZ STIM OTHR P Allow Sand to Settle Out - SIMOPS Begin Building 6% KCL 06:30 07:00 0.50 0 0 COMPZ STIM PRTS P PJSM; Pressure Test Sand Plug t/ 3,000 Psi - Pressure Bled to 2,200 Psi in 10 Minutes (Good Test) Page 38 of 64 • 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 09:00 2.00 0 0 COMPZ STIM TRIP P PJSM; RIH w/ Spent Guns on E -Line - Tag Sand Plug @ 6510' MD - POOH w/ Guns. Sand Plug depth below top pert. 09:00 11:00 2.00 0 0 COMPZ STIM TRIP P Decision Made to RIH Again w/ Spent Guns and Tag Sand Again - Tagged Sand @ 6490' MD - Gun Became Stuck - Bled Pressure f/ Annulus and Gun Became Free - POOH w/ Guns 11:00 11:30 0.50 0 0 COMPZ STIM OTHR P Pressure Up on Annulus to 1500 Psi Twice to Flex the Well - Bled to 0 Psi and Shut In 11:30 12:30 1.00 0 0 COMPZ STIM OTHR P Monitor Pressure - Build and Heat 6% KCL Brine 12:30 13:30 1.00 0 0 COMPZ PERF TRIP P PJSM; Load Live Perf Gun and Test Lubricator Flange t/ 1800 Psi (Good) - RIH w/ 10' Gun t/ 3977' MD - R/U and Test Sand Plug t/ 3000 Psi f/ 10 Minutes - Pressure Bled Down t/ 2330 Psi (Good Test) - Continue to RIH t/ 6193' MD - Tie in Depth w/ CCR and CCL and Prepare to Fire 13:30 15:30 2.00 0 0 COMPZ PERF OTHR T Confer w/ Anchorage Based Engineers while Building and Heating 6% KCL 15:30 17:00 1.50 0 0 COMPZ PERF TRIP T POOH w/ Live Gun and UD 17:00 18:45 1.75 0 0 COMPZ STIM TRIP T P/U Spent Gun and Test Lubricator t/ 1800 Psi - RIH and Tag Sand Plug @ 6343' MD - POOH w/ Spent Guns 18:45 19:15 0.50 0 0 COMPZ STIM RURD T UD Spent Guns - P/U 10' Live Gun and R/U Lubricator - Test Flange t/ 1800 Psi (Good) 19:15 21:00 1.75 0 0 COMPZ PERF PERF P RIH w/ 10' Live Gun on E -Line, Correlate Depth w/ GR and CCL - Perforate 6183' - 6193' MD, Shot Density 6 SPF - POOH w/ Spent Gun - SICP In = 60, SICP Out = 45 - Gun OD in 3.125" Out 3.25" 21:00 21:45 0.75 0 0 COMPZ PERF RURD P R/D Lubricator and UD Spent Gun After Verifying All Shots Fired - Gun OD in 3.125" Out 3.25" - P/U 20' Live Gun and R/U Lubricator - Test Flange t/ 1800 Psi 21:45 23:15 1.50 0 0 COMPZ PERF PERF P RIH w/ 20' Live Gun on E -Line, Correlate Depth w/ GR and CCL - Perforate 6144' - 6164' MD, Shot Density 6 SPF - POOH w/ Spent Gun - SICP In = 40, SICP Out = 5 23:15 23:30 0.25 0 0 COMPZ PERF RURD P R/D Lubricator and Inspect Gun -AII Shots Fired - Gun OD in 3.125" Out 3.25" 23:30 00:00 0.50 0 0 COMPZ STIM RURD P R/U & Test BJ Equipment Prior to DFIT Page 39 of 64 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 09/17/2009 24 hr Summary Perform DFIT - Analyze DFIT Data & Compose Main Frac Plan - Perform Stage #4 Main Frac - Formulate Kill Sheet and Circulate Kill Weight Brine (10.4 PPG) Through the Choke - Monitor Well on TT and Confer w/ Town, Well Losing 6 BPH - Lower Brine Weight to 10.2 PPG While Circulating - Losses Dropped to 3.6 BPH - Set Baker Storm Packer and Begin Testing BOPE 00:00 00:15 0.25 0 0 COMPZ STIM OTHR P Prepare for DFIT 00:15 00:30 0.25 0 0 COMPZ STIM SFTY P PJSM w/ CPAI, Peak, DDI, MI & BJ for DFIT 00:30 01:00 0.50 0 0 COMPZ STIM STIM P Perform DFIT as Follows; Prime Pumps w/ 26 Bbls of 6% KCL taking Returns to the Cuttings Box - Inject 24.1 Bbls of 6% KCL Into Formation at 6.5 BPM, 1800 Psi - Initial SICP 1800 Psi 01:00 04:15 3.25 0 0 COMPZ STIM OTHR P Monitor Wellbore Pressure While Analyzing DFIT Data and Formulating Main Frac Program 04:15 04:30 0.25 0 0 COMPZ STIM SFTY P PJSM for Main Frac w/ BJ, CPAI, DDI, Peak and MI 04:30 06:15 1.75 0 0 COMPZ STIM STIM P Perform Stage 4 Main Frac as Follows: Pump 300 Bbls Crosslinked Pad @ 16 BPM, 105 bbls of 1# Hold at 16 BPM, 577 Bbls of 1 -6# Ramp at 18 BPM, 127 Bbls of 6# Hold at 18 BPM, and 90 Bbls of 8.6% KCI Flush - Pumped 103,653 Ib of Sand Into Formation and Left 722 Ib of Sand in Casing - Total Sand Pumped 104,275 Ibs 06:15 07:30 1.25 0 0 COMPZ STIM OTHR P Monitor Well - SICP Bled from 1800 to 1400 Psi 07:30 11:00 3.50 0 0 COMPZ WELCTI KLWL P PJSM; Formulate Kill Sheet per CPAI Rep - Circualte 277 Bbls of 10.4 PPG Brine Down Tubing taking Returns Through Choke to Kill the well @ 3.3 BPM - Calculated Volume to Kill 200 Bbls - After 1 Full Circulation the Well was Shut In and Monitored - DP /Csg Psi = 0 - Open Choke, No Flow - Open Rams and Observe Well (Static) - Put Hole on TT and Continue to Monitor 11:00 14:00 3.00 0 0 COMPZ STIM RURD P PJSM's: R/D BJ Hard Line, HES E -Line Lubricator, BOPE and Sheaves, R/D Frac Head and UD FOSV 14:00 16:30 2.50 0 0 COMPZ RPCOM CIRC T Losses Steady at 6 BPM - Confer w/ Anchorage Based Team - Orders to Cut MW by .2 PPG - Circulate Until 10.2 PPG Around at 4 BPM w/ 150 psi 16:30 17:00 0.50 0 0 COMPZ RPCOM OWFF P Monitor Well on TT for Losses - Losses Average 3.6 BPH 17:00 19:30 2.50 0 0 COMPZ WHDBO PULD P Monitor Losses - Averarge 3.6 BPH - M/U Storm Packer Assembly Page 40 of 64 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 20:00 0.50 0 5,956 COMPZ WHDBO PACK P Set Packer: Top of Tool 35' MD - Element Center Depth 43' MD - POOH w/ Setting Tool - Tubing Tail Now 5956' MD 20:00 21:00 1.00 0 0 COMPZ WHDBO RURD P Pull Wear Ring, Install Test Plug and R/U to Test BOPE 21:00 00:00 3.00 0 0 COMPZ WHDBO BOPE P Test BOPE as Follows: Test Annular Preventer t/ 250/3500 Psi, Top rams, Demco on Kill Line, NCR Kill, Upper & Lower IBOP, 4" TIW, Manual Choke and Kill Valves, Choke Manifold Valves 1, 3, 4, 5, 7, 8, 9, 11, 12, 13, 14, 15 t/ 250/5000 Psi 09/18/2009 Continue & Complete BOPE Testing - Pull Storm Packer - Monitor Well - Close Bag and Reverse Out Fill f/ 6244' - 6382' MD Witenss of BOPE Test waived by AOGCC Inspector Jim Regg 00:00 08:30 8.50 0 0 COMPZ WHDBO BOPE P Continue to Test BOPE: Test Lower Rams and Valves 2, 6 & 10 w/ 4" Test Joint t/ 250/5000 Psi (Good), Tested Blind Rams to 250/5000 Psi (Good) - Tested Top & Bottom Rams w/ 4 1/2" Test Joint t/ 250/5000 Psi - Tested Annular Preventer w/ 4 1/2" Test Joint t/ 250/3500 Psi (Good) NOTE: During Testing Had to open Lower Ram Cavities and Remove Built Up Frac Sand, Change Out the Test Pump Hose, and Tighten Mud Cross Flange Bolts Witnessing of Test Waived by j AOGCC Inspector Jim Regg 08:30 09:30 1.00 0 0 COMPZ WHDBO RURD P R/D BOPE Test Equipment - Install Wear Bushing - Break Cross Overs f/ Test Joints 09:30 11:00 1.50 5,956 5,906 COMPZ RPCOM PACK P Pull Storm Packer per BOT Rep 11:00 12:00 1.00 5,906 5,906 COMPZ RPCOM CIRC P CBU @ 5 BPM, 220 Psi - No Gas On Bottoms Up 12:00 13:15 1.25 5,906 5,906 COMPZ RPCOM OWFF P Monitor Well While allowing Fluid to U -Tube 13:15 14:30 1.25 5,906 5,906 COMPZ RPCOM CIRC P Circulate 10.2 PPG Brine Around at 4 BPM, 130 Psi 14:30 14:45 0.25 5,906 5,875 COMPZ RPCOM PULD P UD PH -6 Single and Cross Over 14:45 15:30 0.75 5,875 6,244 COMPZ RPCOM TRIP P M/U 4 1/2" IBT to HT -38 Cross Over and TIH on 4" DP to Top of Sand at 6244' MD 15:30 16:45 1.25 6,244 6,229 COMPZ RPCOM OTHR P Pull Up to 6229' MD and Monitor Well While Building Brine - Losses 3.6 BPH 16:45 17:00 0.25 6,229 6,229 COMPZ RPCOM SFTY P PJSM on Reversing Out Sand Operations w/ CPAI, Peak, DDI & MI Page 41 of 64 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 18:00 1.00 6,229 6,270 COMPZ RPCOM FCO P Close Annular Preventer w/ 700 Psi - Strip In Hole & Pump Down Kill Line Reversing Frac Sand Out Through Tubing @ 6 BPM, 400 Psi 18:00 19:30 1.50 6,270 6,250 COMPZ RPCOM OTHR P Pull Off Bottom & Reverse Circulate to Clear DP and Mud Lines of Frac Sand - Shut Down Pumps, Open Bag, and Circulate Over the Top While MI Flushed the DE Filter Press of Solids - Losses 3.6 BPH Static 19:30 00:00 4.50 6,250 6,382 COMPZ RPCOM FCO P Close Bag and Continue to Strip In and Clean Fill f/ 6270' - 6382' MD - Reverse Circulating @ 6 BPM, 380 Psi - Circulating Sand From DP and Mud Lines Every Connection Mud Lost to Formation in Last 24 hrs = 95 bbls 09/19/2009 Continue to Clean Fill f/ 6382' - 6505' MD - Stopped to Flush the Filter Press and Build 10.2 PPG Brine While Circulating Over the Top (Losses 10 BPH) - Continue to Clean Fill f/ 6505' - 6877' MD (Tagged Bridge Plug) - Circulate Until Hole Cleaned Up & NTU's Were Consistently Below 20 Total Brine Lost to Formation in Previous 24 hrs = 446 Bbls 00:00 05:15 5.25 6,382 6,505 COMPZ RPCOM FCO P Continue to Clean Out Fill (Frac Sand) While Reversing at 6 BPM, 380 Psi f/ 6382' - 6505' MD 05:15 16:45 11.50 6,505 6,505 COMPZ RPCOM OTHR P Pull Up, Clear Drill Pipe of FiII, Open Annular, Circulate Over the Top While Cleaning the DE Filter Press and Building 10.2 PPG Brine - Losses 10 BPH 16:45 22:45 6.00 6,505 6,877 COMPZ RPCOM FCO P Continue to Clean Out Fill (Frac Sand) While Reversing at 6 BPM, 450 Psi f/ 6505' - 6877' MD- Tagged Bridge Plug @ 6877' MD 22:45 00:00 1.25 6,877 6,877 COMPZ RPCOM CIRC P Reverse Circulate 4 String Volumes - Shakers Cleaned Up and NTU's Were Stable at 3 Going In and 18 Coming Out - MW In /Out 10.0 PPG P/U 115, S/O 75 Total Losses Previous 24 Hour Period 446 Bbls 09/20/2009 Observe Well (Lost 11 bbls in One hour) - POOH t/ 5872' MD - RIH & Tagged CIBP @ 6877' MD Verifying there is Sufficient Rat Hole for Sump Packer - Circulate and Condition Mud to Lower Mud Weight f/ 10.0 PPG to 9.8 PPG - POOH w/ DP and 4 1/2" Work String - Monitor Well While R/D and R/U Equipment - Hole is taking 2 to 6 BPH (Static) 00:00 00:30 0.50 6,877 6,877 COMPZ RPCOM RURD P Blow Down Kill and Reverse Lines and Rig Down Reverse Line - Fill TT 00:30 01:30 1.00 6,877 6,877 COMPZ RPCOM OWFF P Observe Well for 1 Hour - Lost 11 Bbls (Static) 01:30 02:30 1.00 6,877 5,872 COMPZ RPCOM TRIP P POOH t/ 5872' MD - Displacement 9.9 Bbls Over Calculated Page 42 of 64 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 04:00 1.50 5,872 5,872 COMPZ RPCOM PULD P Monitor Well - P/U Weatherford Casing Tongs - Well Lost 20 bbls in 1 Hour 04:00 05:00 1.00 5,872 6,877 COMPZ RPCOM TRIP P RIH w/o Pumping and Tag CIBP @ 6877' MD (Drill Pipe Measurement) - Lost 11 bbls f/ Trip In 05:00 06:00 1.00 6,877 5,872 COMPZ RPCOM TRIP P POOH w/ 16 Stands of DP t/ 5872' MD - Displacement 7.1 Bbls Over Calculated 06:00 06:45 0.75 5,872 5,872 COMPZ RPCOM RURD P PJSM - R/U Tubing Elevators, Tongs, Slips 06:45 07:00 0.25 5,872 5,751 COMPZ RPCOM PULL P Pull 4 jts of 4 1/2" IBT Tubing and UD 07:00 07:30 0.50 5,751 5,751 COMPZ RPCOM RURD P R/D tubing handling Equipment and R/U DP Handling Equipment 07:30 08:15 0.75 5,751 6,870 COMPZ RPCOM TRIP P RIH t/ 6870' MD on 4' DP 08:15 09:15 1.00 6,870 6,870 COMPZ RPCOM OWFF P Monitor Well Via TT While Building 9.8 PPG Brine 09:15 10:30 1.25 6,870 6,870 COMPZ RPCOM CIRC P Circulate Conventionally to Lower Brine Weight From 10.0 to 9.8 PPG to Slow Losses 10:30 11:00 0.50 6,870 6,870 COMPZ RPCOM OWFF P Monitor Well - Losses Reduced to 5 -6 BPH - Well U- Tubing Flowing f/ Pipe 11:00 11:15 0.25 6,870 6,520 COMPZ RPCOM TRIP P POOH t/ 6520' MD 11:15 12:00 0.75 6,520 6,520 COMPZ RPCOM OWFF P Monitor Well via TT - Losses 5 -6 BPH 12:00 12:30 0.50 6,520 6,520 COMPZ RPCOM CIRC P Circulate 9.8 PPG Brine @ 10 BPM, 930 Psi 12:30 13:00 0.50 6,520 5,751 COMPZ RPCOM TRIP P POOH f/ 6520' -5751' MD 13:00 13:30 0.50 5,751 5,751 COMPZ RPCOM RURD P R/D DP handling Equipment and R/U 4 1/2" Tubing Equipment 13:30 23:00 9.50 5,751 0 COMPZ RPCOM PULL P Pull 4 1/2" IBT Work String f/ Hole (191 Jts Total) - Lost 21.6 bbls More Than Calculated 23:00 23:30 0.50 0 0 COMPZ RPCOM RURD P R/D Weatherford Casing Tongs, Elevators and Cleared the Tig Floor 23:30 00:00 0.50 0 0 COMPZ PERF SFTY P PJSM w/ HES on Handling, Loading and Running TCPG's 09/21/2009 Load TCPG's in Pipe Shed - P/U 28 TCPG's, 2 jts of 2 7/8" Tubing, 7" Champ Packer, Omni Valve and Associated Jewelry and RIH on 4" DP t/ 4217' MD - Noticed Brine Flowing from DP - Consulted w/ Anchorage based Team and HES - Decided to POOH and Check Below Packer Vent, Packet, Annular Pressure XO, and Omni Valve - Tested Omni Valve & Below Packer Vent (Good) - Replaced Champ Packer & Below Packer Vent - RIH w/ TCPG's on 4" DP t/ 6725' MD 00:00 04:00 4.00 0 816 COMPZ PERF PULD P PJSM; TCPG's in Pipe Shed - P/U Handling Tools - P/U 28 4 5/8" TCP Guns, 2 Jts 2 7/8" Tubing, PKR Safety Joint, Champ Packer, Jars, Omni Valve, 1 Std 4" DP & RA Sub 04:00 05:00 1.00 816 816 COMPZ PERF SVRG P Service Rig 05:00 08:45 3.75 816 4,217 COMPZ PERF TRIP P RIH w/ Perf Guns on 4" DP f/ 753' - 4217' MD - Filling Pipe Every 5 Stands Page 43 of 64 llk Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:45 09:15 0.50 4,217 4,217 COMPZ PERF OTHR T After Filling Pipe Noticed Backflow From the DP - Monitored Flow for 30 Minutes and Discussed w/ Halliburton and Town Based Engineers - Decided to POOH due to Possible Disc Failure 09:15 14:15 5.00 4,217 816 COMPZ PERF TRIP T POOH f/ 4217' - 753' MD 14:15 14:45 0.50 816 700 COMPZ PERF PULD T UD Below Below Packer Vent, Packer, Annular Pressure XO, Jars, Omni Valve, XO, 1 Stand of 4" DP and RA Marker 14:45 15:15 0.50 700 700 COMPZ PERF PRTS T Pressure Test Omni Valve & Below Packer Vent to 200 Psi (Good) 15:15 15:45 0.50 700 727 COMPZ PERF PULD T P/U Below Below Packer Vent, Packer, Annular Pressure XO, Jars, Replaced Packer & Below Packer Vent 15:45 16:00 0.25 727 727 COMPZ PERF PRTS T PT Omni Valve t/ 3,000 Psi w/ BOPE Test Pump (Good) 16:00 17:30 1.50 727 816 COMPZ PERF RURD T R/U Test Equipment and M/U Omni Valve, XO, 1 Stand of DP, and RA Sub 17:30 17:45 0.25 816 816 COMPZ PERF OTHR T Clean / Clear the Rig Floor 17:45 21:30 3.75 816 4,217 COMPZ PERF TRIP T RIH w /TCP Guns t /4217' 21:30 00:00 2.50 4,217 6,725 COMPZ PERF TRIP P Continue to RIH w/ TCP Guns t/ 6725' MD - P/U 125, S/O 75 - Displacement 21 Bbls Short of Calculated for Trip 09/22/2009 RU & test Halliburton Lubricator - 1300 PSI. WLIH, correlate perf gun depths. POOH. RD Lubricator. Set packer at 5987' MD. RU - PT lines to 3000 PSI. Close annular. Pressure down annulus to 2500 PSI. Fire guns. Open circulating valve. reverse circulate at 4 BPM - 250 PSI, 3600 stks. Shut in. Monitor pressures. Well static - release packer. Rig down circulating equipment monitoring well observing fluid losses at 2 BPH. POOH. lay down all guns. Observed all guns fired. Slip & cut drilling line. Make up Surge assembly with Halliburton Champ packer. Fluid loss steady at 2 -3 BPH. 24 HR fluid loss at 51 BBLS. 00:00 01:30 1.50 6,725 6,725 COMPZ PERF RURD P PJSM. Make up crossovers and safety valve with adapter flanges. 01:30 06:30 5.00 6,725 6,725 COMPZ PERF ELOG P PJSM. Make up wireline with logging tools & lubricator. Test lubricator to 1300 PSI - 5 minutes. WLIH with assembly, locate RA tags, correlate depths for perf guns. WLOH, RD lubricator & wireline tool assembly. 06:30 09:00 2.50 6,725 6,725 COMPZ PERF PERF P Rig up lines to reverse circulate through choke manifold.PT lines to 3000 PSI - good test. PU 13' for wireline depth correlation. Close annular, and pressure to 2500 PSI to fire guns. Packer set at 5987' MD. Shots from 6098' - 6709'. Up WT = 123K, SO WT = 75K. Observed no pressure increase or fluid loss when guns fired. Page 44 of 64 0 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 09:45 0.75 6,725 6,725 COMPZ PERF CIRC P Reverse circulate at 4 BPM - 250 PSI for 3600 stks, with no gas issues. 09:45 10:45 1.00 6,725 6,725 COMPZ PERF OWFF P Monitor well. Observed 0 PSI. Release PKR, continue monitor well with no gas issues. Observed avg loss = 2 -3 BPH. 10:45 16:30 5.75 6,725 816 COMPZ PERF TRIP P Lay down 15' pup joint. PU single, and POOH with TCP gun assembly. Pulling rates slow at 2 minutes + / stand. 16:30 17:30 1.00 816 816 COMPZ PERF OWFF P Monitor well at the BHA. Allow gas to surface from guns, with well at a 2 -3 BPH loss. Verify well dead. 17:30 21:30 4.00 816 0 COMPZ PERF PULD P Held PJSM. Rig up, pull and lay down all TCP pert gun assembly. Observed all guns fired. No misfires. 21:30 22:00 0.50 0 0 COMPZ PERF PULD P Clean & clear rig floor of all tools.Pull tools to rig floor. 22:00 23:00 1.00 0 0 COMPZ RIGMNT SVRG P Held PJSM. Discuss safety & hazard recognition issues. Discuss procedure to slip & cut drilling line. Slip & cut 105' of line. Inspect brakes, and service Top Drive, and blocks. 23:00 00:00 1.00 0 0 COMPZ RPCOM OTHR P Make up Halliburton surge BHA with Champ packer & Multi - sevice valve. Total fluid loss for 24 HRS - 51 BBLS. 09/23/2009 Continue make up Halliburton Surge assembly. TIH with assembly to locate & set packer at 5868' MD. Set packer. Held PJSM. RU lines, and test same to 3500 PSI. Perform well surge operation as planned with 2000 PSI down annulus. Observed no increase in DP pressure, with minor fluid returns. Shut in. Circulate down anulus at 4 BPM - with full returns, no gas, and little sand returns. Unseat PKR. POOH lay down BHA. MU MI SWACO cleanout BHA with razorback and magnet assembly. TIH to work through perforated zones, run bit to 6850' MD. No tag on sand. Losses at 4 -6 BPH on TIH. Reverse circulate at 4 BPM for NTU's. Losses to 16 BPH. 00:00 05:00 5.00 0 5,945 COMPZ RPCOM OTHR P Continue make up Halliburton surge BHA with Champ packer & multi - service valve. TIH at 1 minute / stand. Allow pipe to run dry for underbalanced operation. Observed fluid losses at 2 -3 BPH. 05:00 06:00 1.00 5,945 5,945 COMPZ RPCOM OTHR P HELD PJSM. Make up top drive. Locate & set 7" Champ packer at 5868' MD as planned. Rig lines and test same to 3500 PSI. 06:00 07:45 1.75 5,945 5,945 COMPZ RPCOM OTHR P Close annular. Pressure down annulus to 2000 PSI to open valve. Observed pressure drop to 500 PSI. PU & open bypass, pressure down to zero. Reverse circulate through choke manifold at 4 BPM - 290 PSI with full returns. Observed 8 BBLS lost in 4640 stks pumped. No gas and very little sand to surface. Release Champ Packer. Page 45 of 64 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 09:00 1.25 5,945 5,945 COMPZ RPCOM OWFF P Monitor well. Losses at 4 -6 BPH. 09:00 14:30 5.50 5,945 0 COMPZ RPCOM TRIP P POOH, breakout & lay down Surge BHA. Avg fluid loss - 4.5 BPH. 14:30 15:30 1.00 0 0 COMPZ RPCOM PULD P Pull 3 1/2" handling equipment to rig floor. Make up MI Swaco cleanout BHA with razorback and magnet assembly. 15:30 19:30 4.00 0 6,034 COMPZ RPCOM TRIP P Trip in hole with BHA to 6034' MD. 19:30 22:00 2.50 6,034 6,724 COMPZ RPCOM FCO P Work assembly, dry reaming through perforated zones cleaning up perfs. 6034' - 6724'. 70 RPM's with 7K torque. 22:00 00:00 2.00 6,724 6,850 COMPZ RPCOM FCO P BROOH through perfs. Ream back to 6724'. Close annular, rig up to reverse circulate, washing down from 6724' - 6850' MD. Observed no hard tag on sand. UP WT = 135K, SO WT = 85K. 09/24/2009 Continue reverse circulate for NTU's less than 20. POOH breakout & lay down cleanout assembly. Recovered 17 LBS of iron on the magnets. MU BOT sump packer assembly and runing tools. RIH with assembly. RU Halliburton E -line. WLIH to correlate sump packer depth. WLOH rig down a -line. Locate sump packer at 6738' DPM. 00:00 06:15 6.25 6,850 6,850 COMPZ RPCOM CIRC P Continue reverse circulate at 4 BPM - 250 PSi for NTU's less than 20. Obtained 3 readings in a row at 18. Total losses while circulating - 58 BBLS. 06:15 07:00 0.75 6,850 6,850 COMPZ RPCOM OWFF P Monitor well. 3.6 BPH losses. 07:00 11:45 4.75 6,850 0 COMPZ RPCOM TRIP P POOH with cleanout assembly. Breakout & lay down scraper, and magnet assembly. Recovered 17 Ibs of iron on magnets. Losses during trip = 4.4 BPH. 11:45 12:00 0.25 0 0 COMPZ RPCOM SFTY P Held PJSm with crew, BOT reps. Discuss safety & hazard recognition issues. Discuss procedure to make up and run the Sump Packer assembly 12:00 13:30 1.50 0 0 COMPZ RPCOM PULD P Make up Sump Packer assembly as per BOT rep. 13:30 21:00 7.50 0 6,750 COMPZ RPCOM TRIP P Trip in hole with sump packer aseembly at 2 minutes / stand as per BOT rep. Drift drill pipe from derrick with a 2.32" drift. Make up space out pups as planned. Run past setting depth, at 6750' and pull drill srtring into tension. UP WT = 136K, SO WT = 85K. Fluid losses on trip 4 BPH, total for trip = 32 BBLS. 21:00 23:30 2.50 6,750 6,750 COMPZ RPCOM RURD P Held PJSM with Halliburton reps and crew. Make up crossovers and sheaves. make up lubricator. test same to 1500 PSI. Page 46 of 64 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 6,750 6,750 COMPZ RPCOM ELNE P WLIH with CCL & Gamma ray assembly to correlate sump packer setting depths. 09/25/2009 Continue wireline with CCL & Gamma to correlate sump packer setting depth. WLOH, RD Halliburton E line. Pull to set packer on depth at 6738' DPM. RU BJ. test lines and set PKR on depth as planned. POOH, breakout & lay down settiong tool assembly. Service rig & top drive. Load screens in pipe shed. MU CK 5" screen assembly, and 2 7/8" inner string, and packer aseembly. RIH at 2 minutes /stand as per BOT rep to 1750'. BHA = 809.75'. 00:00 03:00 3.00 6,750 6,738 COMPZ RPCOM ELNE P Continue wireline with CCL & Gamma to correlate sump packer setting depth. WLOH, RD Halliburton E line. Pull to set packer on depth at 6738' DPM. RD Halliburton E -line. with lubricator. 03:00 03:45 0.75 6,730 6,738 COMPZ RPCOM PACK P Drop 1 7/16" Ball as per BOt rep, allow to fall & seat. 03:45 04:15 0.50 6,738 6,738 COMPZ RPCOM PACK P RU BJ. test lines to 3500 PSI and set PKR on depth as planned with pressure down drill string to 2000 PSI. Observed packwer set at 600 PSI with weight indicator, and a good shear off with 22K overpull. Breakout TIW valve & lines. 04:15 08:30 4.25 6,738 0 COMPZ RPCOM TRIP P POOH, Inspect, breakout & lay down setting tool assembly. 08:30 09:00 0.50 0 0 COMPZ RPCOM SVRG P Service rig draw works, top drive and crown section. 09:00 12:00 3.00 0 0 COMPZ RPCOM RURD P Rig up handling equipment & tools. Rig up Weatherford power tongs. Load pipe shed with screens, and packer assembly. Double check equipment. 12:00 12:30 0.50 0 0 COMPZ RPCOM SFTY P Hels PJSM with crew, BOT, Weatherford and completion engineers. Discuss safety & hazard recognition issues. Discuss procedure to make up gravel pack screens and inner string assembly. 12:30 14:00 1.50 0 150 COMPZ RPCOM SCRN P Make up CK 5" Gravel pack screen assembly. 14:00 17:15 3.25 150 150 COMPZ RPCOM SCRN T Observed a "bad" screen. A hole indicated gauge was .021 in biggest hole. Should be .010 Pictures were taken and sent to town. Call for replacement screen, flown fore Kenai. 17:15 20:15 3.00 150 809 COMPZ RPCOM SCRN P Continue make up CK 5" Gravel pack screen assembly. 809.51' 20:15 22:30 2.25 809 809 COMPZ RPCOM SCRN P Rig up, make up and run 2 7/8" inner string. Make up BOT SC -3 Packer assembly with KOIV valve. Fluid loss avg 5 BPH. 22:30 23:30 1.00 809 809 COMPZ RPCOM RURD P Rig down Weatherford power tongs and equipment. Clean & clear rig floor area. Rig up to run Drill pipe from derrick. Page 47 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 809 1,750 COMPZ RPCOM SCRN P Continue trip in hole with CK gravel pack screen assembly with drill pipe from derrick. Running speed at 2 minutes /stand as per BOP rep. Fluid losses continue at 4 -6 BPH. 09/26/2009 Continue RIH with CK Gravel pack screen assembly to 6674' MD. Latch up to sump packer. UP WT 144K, SO WT = 88K. Install long bales. RU BJ lines and equipment. Drop ball & set packer. Reverse out ball. Verify ball in catcher. Retest lines to 5800 PSI. Pump gravel pack job as planned putting away 16377 Lbs of sand. Observed good screen out. Reverse circulate 5 DP volumes, and verify well is static. Rig down BJ lines & equipment. 00:00 06:00 6.00 1,750 6,674 COMPZ RPCOM SCRN P Continue trip in hole with CK gravel pack screen assembly with drill pipe from derrick to 6674' MD. Running speed at 2 minutes /stand as per BOT rep. Fluid losses continue at 4 -6 BPH. UP WT = 144K, SO WT = 88K. 06:00 07:30 1.50 6,674 6,674 COMPZ RPCOM RURD P Make up pup joint for space out, RIH to 6750' MD. Change out to long bales on top drive. Make up TIW valve. 07:30 13:30 6.00 6,674 6,674 COMPZ RPCOM GRVL P Rig up BJ lines and equipment. Attach COM lines. 13:30 14:00 0.50 6,674 6,674 COMPZ RPCOM SFTY P Held PJSM with crew, BOT reps, and BJ reps. Discuss safety & hazard recognition issues. Discuss procedure to flood lines, pressure test and pump Gravel pack job. 14:00 14:30 0.50 6,674 6,674 COMPZ RPCOM GRVL P Prime up BJ pumps, flood lines, and break circulation. Pressure test lines. 14:30 15:00 0.50 6,674 6,674 COMPZ RPCOM GRVL P Drop 1 3/4" ball as per BOT rep. Allow to fall & seat. 15:00 18:00 3.00 6,674 6,674 COMPZ RPCOM GRVL P Stage BJ pumps up 1900SPI, and then to 3100 PSI, to set packer. Confirm packer set with 20K overpull, and 35K set down weight. Pressure down annulus to 2000 PSI. Release from packer. Reverse circulate ball out. Break apart lines, and verify ball in catcher on the rig floor. Make up lines. and retest same to 5800 PSI / after replacing leaking gasket in chicksan. 18:00 18:30 0.50 6,674 6,674 COMPZ RPCOM SFTY P Crew Change. Held PJSM with crew, BOT reps, and BJ reps. Discuss safety & hazard recognition issues. Discuss procedure to flood lines, pressure test and pump Gravel pack job. Page 48 of 64 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:30 1.00 6,674 6,674 COMPZ RPCOM GRVL P Shift gravel pack tool to circulate position. Set and test pop offs at 4600 PSI . Perform circulating rate test at various rates with choke open. Hold rates until pressure stabilized. Close choke and perform injection test at various rates. ISIP -1625 psi. Analyze results and finalize rates and sand concentrations for gravel pack job. Fluid used for these tests 170 bbls. 19:30 20:30 1.00 6,674 6,674 COMPZ RPCOM GRVL P On line pumping gravel pack at 10 b/m with 0.75 ppg sand concentration. Close choke to maintain returns at 3 b /m. With one tubing volume away increase sand concentration to 1 ppg. Swivel on return line develops drip. Decision to flush sand and replace swivel. Swap to flush. (299 bbls fluid pumped). Pump 70 bbls fluid to clear sand from workstring. Sand in formation 10232 lbs. Dump seals on gravel pack tool with 20k over string weight. Replace swivel. Move GP tool to circulate position. 20:30 22:30 2.00 6,674 6,674 COMPZ RPCOM GRVL P Back on line with gravel pack at 10 b/m with a sand concentration of 1 ppg. With 1 ppg sand at perfs increase sand concentration to 1.5 ppg and returns at 3 b /m. Switch to flush and drop treating rate to 1.5 b /m. Choke returns to 1.5 b/m to induce screen out. Screen out achieved with an additional 6145 Ibs of sand in formation and a final pressure of 3618 psi. Sand in formation: 16377 Ibs (approximately 50 Ibs /ft) Sand left in workstring -1060 Ibs. Total fluid used for this stage of gravel pack- 222 bbls. SD pumping. Pressure up backside to 1000 psi and pick up gravel pack tool to reverse position. Totals: Sand in formation: 16377 Ibs (densitometer) 17726 (skrew) Inflo 150- 63 gal. Claymaster- 17 gal Sand left in tubing -1060 Ibs. Screen out pressure -3618 psi Treating pressures- 2376 -2900 9.8 ppg Brine with additives -761 bbls. Complete 4 workstring volumes to clean pipe and remove sand. Final NTU -8. Page 49 of 64 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 23:30 1.00 6,674 6,674 COMPZ RPCOM GRVL P Observed well flowing, with 1.5 BBL gain in 10 miinutes. Pump 1 1/2 drill pipe volumes, reverse circulating to verify balanced fluid. Continue monitor well, verify flow stopping. 23:30 00:00 0.50 6,674 6,674 COMPZ RPCOM RURD P Rig down all BJ lines, and equipment. 09/27/2009 Continue rig down BJ lines and equipment. POOH slow, observing clean movement, and pull out of KOIV valve observing valve close. Pressure test KOIV to 200 PSI. Good test. Continue POOH, breakout & lay down the gravel pack inner string assembly. Make up Isolation Packer assembly. TIH to locate & snap into CK Screen assembly sump packer. Drop ball & set ISO packer on depth at 5929' MD. Test & release from packer. Displace well with 12% 9.0 PPG brine. 00:00 01:00 1.00 6,674 6,674 COMPZ RPCOM RURD P Continue rig down BJ lines and equipment. 01:00 06:00 5.00 6,674 0 COMPZ RPCOM TRIP P POOH slow with washpipe assembly observing clean movement, and pull out of KOIV valve observing valve close. Pressure test KOIV to 200 PSI. Good test. Continue POOH to Setting tools. Observed proper displacement. 06:00 07:00 1.00 0 0 COMPZ RPCOM RURD P Clean & clear rig floor. Pull tools to floor. Rig up Weatherford power tongs. 07:00 08:00 1.00 0 0 COMPZ RPCOM PUTB P Held PJSM. POOH, breakout & lay down the 23 joints of 2 7/8" gravel pack inner string assembly. 08:00 11:00 3.00 0 0 COMPZ RPCOM PUTB P Held PJSM. Make up 2 7/8" pipe for Isolation packer assembly. Make up Baker SC -3 packer assembly as per BOT reps. 11:00 11:30 0.50 0 0 COMPZ RPCOM RURD P Rig down Weatherford power tongs. 11:30 18:00 6.50 0 5,950 COMPZ RPCOM TRIP P Trip in hole with Isolation Packer assembly to 5950' MD. Observed proper displacement. RIH with stand 82. Tag KOIV at 5988 DP depth. Up weight 100k. Pick up to 5978'. Retag twice and break KOIV. Pick back up and circulate 5 bbls to clear debris from ball seat. Continue to RIH with DP to stand 94 ( 6745') 18:00 19:00 1.00 5,950 5,950 COMPZ RPCOM RURD P Change out bales and rig up TIW with head pin. RIH and snap in. Down wt.is 83K. Tag and set 10k down. Snap out with 140k up weight. Seals are dragging. Sting in and monitor well for 30 minutes. No fluid movement. Drop 1 7/16" stainless steel ball and let fall for 30 minutes. 19:00 19:45 0.75 5,929 5,929 COMPZ RPCOM RURD P Rig up BJ 3" Hardlines bales and valves. Page 50 of 64 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T _ Comment 19:45 21:15 1.50 5,929 5,929 COMPZ RPCOM GRVL P Pressure test lines to 5000. Good. Pressure up in increments and set packer at 5929 DP depth (5929 WLMD). Pull test packer to 160k (20k over up weight). Good Close bag and pressure test backside to 500 psi. Good test. Pressure up on annulus to 2000 and release setting tool. Pressure DP up to 500 psi to test isolation assembly. 21:15 22:30 1.25 5,929 5,929 COMPZ RPCOM RURD P Rig down BJ lines, TIW valve, and head pin. 22:30 23:30 1.00 5,929 5,929 COMPZ RPCOM CIRC P Displace well with 12% 9.0 PPG brine with additives at 8 BPM - 900 PSI. No Losses. 23:30 00:00 0.50 5,929 5,929 COMPZ RPCOM OWFF P Monitor well - static. Drop 2 3/8" drift in Drill string. 09/28/2009 POOH and lay clown the 2 7/8" Isolation packer setting tools. RU & Test BOP's. Observed trouble damaging O -rings on test plug as suspected metal burr in a port on the well head continued to cut the rings. Vetco hand was brought out to inspect. AOGCC rep Bob Noble waived witness of test. BOP testing was completed successfully with 250 / 5000 PSI as per permit. Make up Halliburton TCP pert gun assembly, and TIH with Drill pipe to 1460' MD. 00:00 03:30 3.50 5,929 0 COMPZ RPCOM TRIP P POOH with the Isolation packer setting tool assembly. Observed proper displacement. 03:30 04:00 0.50 0 0 COMPZ RPCOM RURD P Clean & clear rig floor area. 04:00 18:00 14.00 0 0 COMPZ RPCOM BOPE P Rig up. Pull wear bushing. Install test plug and test joint. Test BOP stack, 250 / 5000 PSI. Test rams to 4" and 4 1/2" sizes. Test choke manifold & valves, HCR's and all floor valves. Test upper & lower Top Drive valves. Test Koomey. First 200 PSI in 23 Sec, with full pressure to 3000 PSI in 2 Min- 25 Sec. Nitrogen bottle - 6 with avg PSI of 2050 PSI. AOGCC rep Bob Noble waived witness of test. Observed the test plug had to be pulled and the 0 ring on the test plug had to be changed out numerous times as suspected damage from port valve in wellhead kept cutting the 0 ring. After BOP test, install wear bushing and run in lock down screws. 18:00 19:15 1.25 0 0 COMPZ RPCOM RURD P Pull tools to rig floor. load TCP gun assembly in pipe shed, and double check the count. Rig up hole fill line to fill drill string each stand. Install elevators. 19:15 19:30 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM with crew, BOT and Halliburton reps. Discuss safety & hazard recognition issues. Discuss procedure to pick up TCP gun assembly and RIH. Page 51 of 64 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 23:30 4.00 0 1,327 COMPZ RPCOM PERF P Make up TCP perf gun assembly with packer plug, 7" Champ Packer and OMNI valve. 1327'. 23:30 00:00 0.50 1,327 1,460 COMPZ RPCOM TRIP P Continue TIH with TCP gun assembly to 1460'. Running speed 2 minutes / stand as per Halliburton reps. Fill each stand on TIH up # 24. 09/29/2009 Continue TIH with TCP gun assembly from 1460' - top of isolation packer. Sting in and set plug. Locate perf guns on depth. Set packer @ 4623'. Perf 500 PSI underbalanced. Observed all fired and gas to surface. Shut in pressure = 375 PSI. Circulate out gas , and monitor well until dead. Release packer. POOH, at slow speeds allowing gas to migrate to surface. Observed fluid losses from 8 -16 BPH. Hold PJSM, breakout & lay down perf guns. 00:00 06:00 6.00 1,460 5,935 COMPZ RPCOM TRIP P Continue trip in hole with TCP pert gun assembly from 1460' to tag & land packer plug at 5935' MD. Note: Top of Isolation packer at 5929 DPM. Fill each stand with brine to stand # 24. Continue run with dry drill string. UP WT = 105K, SO WT = 72K. Set down 10K, Pull and shear packer plug tool with 5K. Verify depth. Crew Change 06:00 07:00 1.00 5,935 5,935 COMPZ RPCOM RURD P Make up BJ lines to reverse circulate. Load lines, and test same to 4000 PSI. 07:00 07:30 0.50 5,935 5,935 COMPZ RPCOM SFTY P Held PJSM with crew, BOT, and BJ and Halliburton reps. Discuss safety & hazard recognition issues. Discuss procedure to pressure up and fire guns. 07:30 11:00 3.50 5,935 5,935 COMPZ RPCOM PERF P Pick up 5.5' and position guns with top shot at 4734 and bottom shot at 5914. Pressure up on annulus to 2500 and fire guns. (1.18 bbls used) Online with rig pumps reversing at 3 b /m. Gas bubble on surface. Shut down pumping and close choke. Monitor SIDPP @ 375 PSI. On line with BJ pumps pumping down annulus at 3 b/m taking returns through choke to pits. With 19 bbls away catch fluid. Pump pressure increases from 60 psi to 200 psi. Continue at same rate monitoring pump and DP pressure. With 110 bbls away .SD pumping with BJ. SICP -32 psi. Open choke and continue to reverse surface to surface 162 bbls (3500 strokes) to ensure all gas is out of wellbore. Shut down pumping and monitor well. Release packer and circulate. Observed losses ranging from 10 -16 bbl /hr. Monitor well. 11:00 12:00 1.00 5,935 5,935 COMPZ RPCOM OWFF P Monitor well via trip tank Observed losses at 16 BPH. Page 52 of 64 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:30 0.50 5,935 5,935 COMPZ RPCOM RURD P Rig down all lines, blow down same and the choke manifold. 12:30 16:45 4.25 5,935 1,960 COMPZ RPCOM TRIP P POOH slow, with tripping speeds at 25 -30 Ft/min as per Halliburton reps. Observed gas breaking out at surface. 16:45 18:00 1.25 1,960 1,960 COMPZ RPCOM OWFF P Monitor well, allowing gas to breakout of guns to surface. Crew Change 18:00 19:30 1.50 1,960 1,960 COMPZ RPCOM OWFF P Continue Monitor well, allowing gas to breakout of guns to surface. 19:30 21:30 2.00 1,960 1,337 COMPZ RPCOM TRIP P Continue POOH slow, with tripping speeds at 15 -30 Ft/min as needed allowing gas to breakout at surface. Ensure gas broke out before allowing guns at surface. 21:30 00:00 2.50 1,337 600 COMPZ RPCOM PULD P Breakout & lay down service tools in running assembly including Omni valve & Champ Packer assembly. Held PJSM with crew and Halliburton reps. Discuss safety & hazard recognition issues. Discuss procedure to breakout & lay down spent guns, aware of the trapped gas pressure and well control issues. 09/30/2009 Continue POOH, break out & lay down guns. Observed all fired. Service rig. Mu Mi Swaco clean out assembly with razorback scrapers and magnets. TIH to dress the perfs. Tag fill @ 5919'.(10' above top of isolation packer). BROOH with no 'Dumps to dress perfs. TIH to 5915'. Reverse circulate for NTU's. 00:00 03:15 3.25 600 0 COMPZ RPCOM TRIP P Continue breakout & lay down spent guns, aware of the trapped gas pressure and well control issues. 03:15 04:45 1.50 0 0 COMPZ RPCOM SVRG P Service rig, Top Drive & crown Section. Observe well with static losses at 8.8 BPH. 04:45 06:00 1.25 0 200 COMPZ RPCOM PULD P Hold PJSM with crew & MI Swaco rep. Make up Cleanout BHA with razorback scraper and magnets. 06:00 10:00 4.00 200 4,705 COMPZ RPCOM TRIP P Trip in hole with assembly to 4705' MD. 10:00 13:00 3.00 4,705 5,919 COMPZ RPCOM REAM P Dress pert sections with the assembly from 4705' - to tag fill at 5919' DPM, (10' above top of isolation packer). 13:00 17:30 4.50 5,919 5,915 COMPZ RPCOM REAM P BROOH with no pumps through the perf section to dress off same. Trip back to bottom. UP WT = 110K, SO WT = 85K. Rotating 70 RPM's with 6 -7K TQ. Total loss on trip = 80 BBLS 17:30 20:00 2.50 5,915 5,915 COMPZ RPCOM CIRC P Rig up and reverse circulate @ 3 BPM - 170 PSI. Observed losses of 8 -10 BBLS / HR. Observed NTU's of 55. 20:00 20:30 0.50 5,915 5,915 COMPZ RPCOM TRIP P Rotate & reciprocate drill string from 5915' - 5855'. Page 53 of 64 1 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 21:30 1.00 5,915 5,915 COMPZ RPCOM CIRC P Continue circulating for NTU's. Observed Filter press packing off limiting flow to 3 BPM. NTU readings of 50 -55 stabilizing. 21:30 23:00 1.50 5,915 5,915 COMPZ RPCOM OTHR P Shut down pumps. Clean out filter press screens, and recoat with DE. Fluid looses staic - 6.75 BPH. 23:00 00:00 1.00 5,915 5,915 COMPZ RPCOM CIRC P Continue circulating for NTU's down to 40 -50. Increased pump rate to 4 BPM - 10/01 /2009 Continue circulating for NTU's trend and stabilizing at 40 -50. Pull assembly up above top perfs at 4705'. Continue circulating for NTU's. Trend to 25 readings. POOH, breakout & lay down assembly. Recovered 22 Ibs of iron debris. Slip & cut 88' of drilling line. Inspect brakes. Change out saver sub. Make up Cavins Bailer assembly, and RIH to tag at 5919', wash down reverse circulate to catch packer plug. Observed pulled over 20K, POOH. Breakout assembly observed no fish. recovered 150 Ibs of iron, with overshot packed off. 00:00 01:30 1.50 5,915 5,915 COMPZ RPCOM CIRC P Continue reverse circulating for NTUs @ 4 BPM 260 PSI. Observed NTU readings trending down and stabilizing at 40 -50. Shut down pumps - monitor well. 01:30 02:30 1.00 5,915 4,705 COMPZ RPCOM TRIP P Pull assembly from 5915' to 4705' above top pert section. 02:30 05:30 3.00 4,705 4,705 COMPZ RPCOM CIRC P Continue reverse circulate at 4 BPM for NTU's.Observed trending down stabilizing at 25 NTU's. Monitor well fluid losses 6 -8 BPH. 05:30 09:00 3.50 4,705 0 COMPZ RPCOM TRIP P POOh with clean out assembly from 4705' - BHA. Breakout & lay down assembly recovered 22 Ibs of iron debris. 09:00 10:15 1.25 0 0 COMPZ RPCOM SVRG P Held PJSM. Rig up. Slip & cut 88' of drilling line. Inspect brakes. 10:15 11:30 1.25 0 0 COMPZ RPCOM SVRG P Inspect & change out saver sub. 11:30 12:00 0.50 0 0 COMPZ RPCOM BAIL P Held PJSM with crew, BOT & Cavins reps. Discuss safety & hazard recognition issues. Discuss procedure to make up and run Cavins BHA. 12:00 15:30 3.50 0 5,918 COMPZ RPCOM BAIL P Make up Cavins BHA assembly with 5 3/4" overshot - 2 5/8" grapple, and pump out sub spaced out 6 stands above overshot. TIH with assembly to tag fill at 5918' DPM. 15:30 18:00 2.50 5,918 5,929 COMPZ RPCOM BAIL P Wash down reverse circulating to allow iron debris to wash up into drill string. Repeated attempts tagging packer plug to retrieve same. Observe 20 K overpull suspect recovered packer plug. Observed fluid in wellbore falling with continued losses at 6 -8 BPH. 18:00 19:45 1.75 5,929 5,621 COMPZ RPCOM TRIP P POOH from 5929' to 5621'. Pressure up on drill string to 2500 PSi shearing circulation sub. Observed well unbalanced. Allow fluid to U -tube to balance. Page 54 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:45 23:30 3.75 5,621 0 COMPZ RPCOM TRIP P Continue POOh from 5621' - surface. Observed 50 BBL loss for the trip. 23:30 00:00 0.50 0 0 COMPZ RPCOM PULD P Breakout & lay down overshot assembly. Observed No fish. Assembly packed off with Iron debris. recovered 150 lbs of iron. Inspect tools. 10/02/2009 Mu Cavins assembly #2. TIH with assembly, reverse circulate down to tag at 5929' DPM. Observed pressure increase when OS swallowed fish neck. Pumps off, open annular, pull 40K over to release packer plug. Slack off verify tag higher and observed plug re enter isolation packer. Monitor well - 8 BPH losses. POOH. Breakout & lay down Cavins BHA with packer plug. Rig up and run gravel pack screen assembly. Continue with 2 7/8" inner string. Total BHA = 1361.60'. 00:00 00:30 0.50 0 0 COMPZ RPCOM PULD P Make up Cavins BHA #2. Decision to run same configuration. Install new overshot with 2 5/8" grapple. Redress shear sub. 00:30 03:30 3.00 0 5,929 COMPZ RPCOM TRIP P Trip in hole with Cavins assembly #2. 03:30 04:30 1.00 5,929 5,929 COMPZ RPCOM BAIL P Close annular. reverse circulate down to top of fish at 5929' with 5 BPM - 300 PSI. Wash debris up inside assembly attempting to catch packer plug. Observed pressure in crease when plug into overshot 50 PSI. Pumps off, open annular, pull 40K over to see packer plug pull free. Slack off and observe plug re enter ISO packer. UP WT 104K, SO WT = 83K. 04:30 05:00 0.50 5,929 5,929 COMPZ RPCOM OWFF P Monitor well. Verify fluid losses at 8 BPH. 05:00 09:30 4.50 5,929 0 COMPZ RPCOM TRIP P POOH with Cavins bailer assembly. Breakout & lay down tools recovering packer plug and 10 lbs of iron debris. 09:30 12:00 2.50 0 0 COMPZ RPCOM RURD P Clean & clear rig floor area. Rig up to run gravel pack screen assembly. RU Weatherford power tongs and equipment. Pull all handling tools to floor. Confirm screens in pipe shed, 2 7/8" and 1.90" inner strings in place. Monitor well with consistant 8 BPH fluid loss. 12:00 12:30 0.50 0 0 COMPZ RPCOM SFTY P Held PJSM with crew, BOT, engineers, and Weatherford reps. Discuss safety & hazard recognition issues. Discuss procedure to pick up gravel pack screen assembly with inner string. 12:30 22:30 10.00 0 1,362 COMPZ RPCOM PULD P Make up MZ Gravel pack screen assembly. Total BHA length = 1361.60'. Make up 2 7/8" inner string. SIMOPS: BJ hands running and checking out all equipment for gravel pack. 22:30 23:00 0.50 1,362 1,362 COMPZ RPCOM RURD P Rig down Weatherford power tongs and equipment. Page 55 of 64 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 1,362 1,362 COMPZ RPCOM PULD P Pick up 2 7/8" pups and space out same. 10/03/2009 Continue make up 1.9" inner string. RU & test seals. Space out 2 7/8" & 1.9" tubing. Make up SC -2 Packer assembly & test same. TIH with MZ assembly at 3 min /stand as per BOT reps. Tag top of Isolation packer at 5929' DPM, engage, and set down. Change out top drive bales, and RU BJ hardlines. Load & flush lines. Pressure test same to 4500 PSI. Set stage 3 packer @ 4590'. Rotate & release from packer. Pull up and pressure up to set lower packer. Attempt to activate hydraulic locator. Repeat attempts. observed not set. Held teleconference. Decision to displace well and pump injectivity, reverse and circulation tests. Well displaced with 9.0 ppg HEC Brine at 2.5 BPM - 1940 PSI. Total pumped 15 BBLS. 00:00 01:30 1.50 1,362 1,362 COMPZ RPCOM PULD P Continue make up and run 1.9" inner string to 844'MD . 01:30 05:00 3.50 1,362 1,362 COMPZ RPCOM PRTS P Rig up Baker test pump, and test the 1.90" inner string. Rig down test equipment. 05:00 08:30 3.50 1,362 1,362 COMPZ RPCOM PULD P Space out 2 7/8" & 1.9" inner strings. Install space out pups. Make up BOT SC -2 packer assembly. Perform low test to 250 PSI. Good test. String weight = 27K. 08:30 13:15 4.75 1,362 5,929 COMPZ RPCOM TRIP P Trip in hole with assembly from 1362' - 5929' DPM. Runing speed 3 minutes / stand as per BOT reps. Fluid loss = 6 BPH. Drift DP on TIH - 2.5". 13:15 13:30 0.25 5,929 5,929 COMPZ RPCOM TRIP P Tag top of isolation packer on depth at 5929' DPM. Sting in and set down. UP WT= 117K, SO WT = 90K. 13:30 16:00 2.50 5,929 5,929 COMPZ RPCOM RURD P Change out & install long bales on Top Drive. Install TIW valve & XO. Rig up BJ 3" hardline. 16:00 17:30 1.50 5,929 5,929 COMPZ RPCOM RURD P Load lines with fluid, and test same to 8000 PSI. Good test. 17:30 18:00 0.50 5,929 5,929 COMPZ RPCOM PACK P Set stage 3 packer on depth © 4585.71. 18:00 19:30 1.50 4,585 4,585 COMPZ RPCOM PACK P Rotate 28 right turns to release from SC -2 packer, and pull up to verify free movement. Pull into position and pressure down to set lower SCL -1 packer on depth 5460.35'. Pressure to 2100 PSI, then 3100 PSI. Release pressure, pull free. UP WT 96K, SO WT = 75K. 19:30 22:30 3.00 4,585 4,585 COMPZ RPCOM GRVL T Attempt to activate hydraulic locator. Repeat attempts with pressure from 2500 to 3500 PSI. Unsuccessful. Confer with town. Decision to continue pump tests. Retry. 22:30 23:30 1.00 4,585 4,585 COMPZ RPCOM GRVL P Displace well with 9.0 PPG HEC Brine @ 2.5 BPM - 1940 PSI. Pump a total of 150 BBLS with BJ. 23:30 00:00 0.50 4,585 4,560 COMPZ RPCOM GRVL P Spearhead HEC w/ breaker down annulus with BJ at 4.5 BPM - 2560 PSI. 10/04/2009 Continue pump 9.0 PPG Brine with HEC & Breaker down annulus. perform injectivity , circulating and reversing test in 3 different zones to complete 3 MZ gravel pack intervals. Mix & load fluids as needed in between intervals, dumping more sand into sand king as needed. Top of SC -2 packer at 4585.71'. Page 56 of 64 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 4,585 4,585 COMPZ RPCOM GRVL P Continue pump 9.0 PPG Brine with HEC & Breaker down annulus. 87 BBLS total. Perform reversing test at 1,2,3,4 and 4.7 BPM. At 4.7 BPM, IAP - 3500 PSI. WHP = 239, and return rate = 5 BPM. Move tool to circulation position. Close choke, and perform injectivity test at various rates. At 8 BPM DP pressure = 2729 PSI. IAP = 1222, with no returns. Open choke and perform circulation test at various rates. At 8 BPM the IAP = 73 PSI. The DP pressure = 2581 PSI and the return rate = 2.9 BPM. 02:00 03:30 1.50 4,585 4,585 COMPZ RPCOM GRVL P Attempt to actuate the Hydraulic Locator with 25oo PSI. Failed. repeat attempt and observed success. Set down to 35K. UP WT = 98K, SO WT = 75K. Set BJ Pop off to 7000 PSI. Gravel pack lower intervals of perforations from 4734' - 5023'. HWWP was pumped at 7.5 BPM avg rate, with an avg DPP of 2478 PSI. The returns were choked back to 30 %. 8037 Ibs of sand was pumped at 1 ppg. 1771 Ibs of sand was left in the drill pipe. 6266 lbs of sand left behind the screens, which proves to be 35 Ibs /ft. 230 BBLS of fluid used for the HWWP, and 165 used to flush after screen out. Screen out pressure = 5867 PSI. 03:30 04:30 1.00 4,585 4,585 COMPZ RPCOM RURD P Rig down BJ lines in preparation to move uphole with drill pipe. Initial fluid losses were 32 BPH but slowerd to 16 BPH. 04:30 06:00 1.50 4,585 4,585 COMPZ RPCOM GRVL P POOH with 7 stands as per BOT rep, for next interval. SIMOPS: Haul away all fluid returns for injection, and dump additional sand into sand king. Pick up single joint & pups for space out in interval. Locate seals at 5470'. Crew change 06:00 12:00 6.00 4,585 4,585 COMPZ RPCOM GRVL P Mix & build 9.0 ppg 12% KCL building volume. Monitor well. Fluid losses static. Pull seals to flush same as per BOT rep. Observed 3.25 BBLS loss each time seals repositioned. 12:00 13:30 1.50 4,585 4,585 COMPZ RPCOM RURD P Rig up BJ 3" hard lines to drill pipe with TIW valve & crossover. Test lines to 8000 PSI. Page 57 of 64 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 17:00 3.50 5,034 5,034 COMPZ RPCOM GRVL P Set isolation packer at 5034.86. Pump 5 bbls for reverse test at 1 b /m. IAP -307 psi. On line with injection test at 1, 2, 4, 6, 8 b /m. At 8 b/m DPP -2301 IAP -1060. ISIP -995. Perform circulation test with choke open at various rates. At 7.7 b/m DPP -2122, IAP -68 Rtns -2.8 b /m. Choke returns back to 2.3 b/m and come on line with sand at 1 ppg. Screen out at 2604 psi with 10856 Ibs of sand pumped. 929 Ibs of sand left in pipe. Fluid pumped for gravel pack 402 bbls. Move tool to reverse position and reverse out until clean returns. (65 bbls) Continue to pump 100 bbls to flush drillpipe. 17:00 21:00 4.00 4,627 4,627 COMPZ RPCOM GRVL P Rig down BJ lines and pick up pipe to next position. Mix additional brine and dump 2 more bags of sand. Rig up BJ surface lines on drillpipe and pressure test to 8000 psi. Set isolation packer at 4627.87' Pick up to reverse and confirm tool in proper position. 21:00 00:00 3.00 4,627 4,627 COMPZ RPCOM GRVL P Move tool to circulate position and perform injectivity test with choke closed at various rates. 7.7 b/m DPP -1550 IAP -395. On to circulation test. At various rates. At 6 b/m unable to get good returns so job will be pumped at 4 b/m with 30% returns. Online with sand at 1 ppg. Sand concentration raised to 1.5 ppg. Screen out with 2295 psi with 10850 Ibs sand pumped. 8386 Ibs in formation and 2464 lbs left in pipe. Fluid pumped for gravel pack 295 bbls. Pick up tool and reverse to clean drillpipe. Pump 200 bbls after last sand seen to flush pipe. 10/05/2009 Breakout & lay down all BJ 3" iron from rig floor. Pull 7 stands. Observed pulling through KOIV valve slowly, and valve closing with fluid losses stopping. Continue POOH, lay down 4" drill pipe. Make dummy run with 4 1/2" tbg hanger. RILDS and test same to 5000 PSI. Pull hanger. Rig up for completion. 00:00 01:00 1.00 4,627 4,627 COMPZ RPCOM RURD P Rig down all BJ 3" iron on rig floor. Prep to pull out of hole. 01:00 02:00 1.00 4,627 4,627 COMPZ RPCOM TRIP P Pull 7 stands. Before pulling through KOIV valve, close annular, screw into DP with Top drive. Observed KOIV valve close slowly pulling through it, and fluid losses stopped. 02:00 03:00 1.00 4,627 4,627 COMPZ RPCOM RURD P Breakout & lay down long bales. Breakout TIW valve. Prepare rig floor for laying down DP. 03:00 06:15 3.25 4,627 4,627 COMPZ RPCOM PULD P Pull out of hole laying down 4" drill pipe. Observed proper displacement. Page 58 of 64 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:15 08:30 2.25 4,627 4,627 COMPZ RPCOM PULD P Rig up. POOH lay down 1.9" inner string. 08:30 12:00 3.50 4,627 4,627 COMPZ RPCOM PULD P Rig up. POOH lay down 2 7/8" inner string. 12:00 12:45 0.75 0 0 COMPZ RPCOM RURD P Clean & clear rig floor area. 12:45 14:45 2.00 0 0 COMPZ RPCOM OTHR P Drain BOP stack. Pull wear ring. Make up test plug for dummy run in stack to verify clean bore. Inspect plug for damage to seal ring. All good. Install wear ring and RILDS> 14:45 16:45 2.00 0 0 COMPZ RPCOM PULD P TIH with 1900' of drill pipe from the derrick. POOH laying down same. 16:45 20:00 3.25 0 0 COMPZ RPCOM OTHR P Make up tubing hanger as per Vetco Gray rep. RIH to set for dummy run to ensure clean bore. RILDS. test hanger to 5000 PSI - 10 minutes. Good test. POOH, inspect hanger - no damage. Install wear bushing. RILDS. 20:00 22:00 2.00 0 0 COMPZ RPCOM PULD P TIH with 1900' of drill pipe from the derrick. POOH laying down same. Last of drill pipe from derick. Fluid losses = 0. 22:00 00:00 2.00 0 0 COMPZ RPCOM RURD P BOLDS, Pull wear bushing. Clean & clear floor area. Pull tools to floor. RU Weatherford power tongs and equipment for completion run. 10/06/2009 Continue RU to run Completion. Hold PJSM. MU Baker PBR with E- Anchor assembly. RIH with 4 1/2" Completion string. 00:00 00:30 0.50 0 0 COMPZ RPCOM RURD P Continue rig up to run 4 1/2" Completion string. 00:30 01:00 0.50 0 0 COMPZ RPCOM SFTY P Held PJSM with crew, BOT, and Weatherford reps. Discuss safety & hazard recognition issues. Discuss procedure to make up and run 4 1/2" Completion string. 01:00 07:15 6.25 0 0 COMPZ RPCOM RCST P Make up Baker S -22 Seal assembly with E anchor, and PBR. Continue RIH picking 4 1/2" completion as per detail. Locate into pkr at 4586'. 07:15 07:45 0.50 0 0 COMPZ RPCOM DHEQ P Latch anchor seal assembly. PU and shear PBR at 45k over weight. Close annular and pressure annulus to 500 psi to verfiy seal placement. Pull seals out of PBR and re -land to confirm seal entry. 07:45 08:30 0.75 0 0 COMPZ RPCOM TRIP P POH to 4080'. 08:30 12:00 3.50 0 0 COMPZ RPCOM RCST P MU control lines on landing nipple and CIM. Test 1/4" control line and landing nipple to 6000 psi. Verify proper installation of check valve on CIM. RIH with 4 1/2" completion equipment to 4550'. Attach control lines to pipe with 2 SS bands per jt. Page 59 of 64 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:00 2.00 0 0 COMPZ RPCOM CIRC P Displace well with 40 bbls viscosified spacer followed by 190 bbls inhibited 12% KCL brine. 14:00 17:00 3.00 0 0 COMPZ RPCOM RCST P MU hanger and landing jt. Strip in controls lines. Retest landing nipple line to 5000 psi. Drain stack. Land hanger. RILDS. Test hanger seals to 5000 psi. 17:00 18:00 1.00 0 0 COMPZ RPCOM DHEQ P Pressure annulus to 2500 psi for 5 min. OK. Pressure annulus to 3500 psi for 30 min. OK. Bleed off pressure. 18:00 18:30 0.50 0 0 COMPZ RPCOM OTHR P Set BPV. 18:30 19:30 1.00 0 0 COMPZ RPCOM RURD P Rig down and clear floor of Weatherford and SLB equipment. 19:30 00:00 4.50 0 0 COMPZ RPCOM NUND P ND BOPE. Flush and clean pits. 10/07/2009 Install and test lower tree assembly to 5000 psi. Clean pits and flush lines. Released rig at 12:00 hrs. Rig down and move rig to Cottonwood Creek Camp site. 00:00 04:00 4.00 0 0 COMPZ RPCOM NUND P NU lower tree. Test hanger void to 5000 psi. OK. Install sweep and flanges on annulus valves. Test SSSV connections to 5000 psi. OK. 04:00 05:00 1.00 0 0 COMPZ RPCOM DHEQ P Pull BPV. Install TWC. Test lower tree to 250 / 5000 psi. OK. 05:00 06:00 1.00 0 0 COMPZ RPCOM OTHR P Pull TWC. Install BPV. Secure well. 06:00 12:00 6.00 0 0 COMPZ RPCOM OTHR P Finish clean and flush all pumps, lines and equipment with fresh water. 12:00 18:00 ,6.00 0 0 DEMOB MOVE RURD P Released rig at 12:00 10 -7 -09. Break out floor valve connections and xo's. RD flare line, mud lines, gas buster and rock washer. Blow down all steam lines. Remove centrifuge. Drain boilers. Remove pipe shed. Pull pump seats. Inspect and grease same 18:00 00:00 6.00 0 0 DEMOB MOVE RURD P Pickle all mud line valves in pump room. Break down exhaust stacks on pits, pumps and motor modules. Remove wind walls and doors on pits. Rig down lights and hand rails. Remove auger. Prep degasser and mud cleaner for removal. Empty rig water tank. Page 60 of 64 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 12, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Advanced Cement Evaluation: BRU #232 -23 Run Date: 9/9/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 BRU #232 -23 Digital Data in LAS format, Digital Log Image file 1 CD Rom 283- 20133 -00 Advanced Cement Evaluation 1 Color Log 283- 20133 -00 ** Working on the LDWG format for data, will come at a later date -r.:r•* PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto _ 6900 Arctic Blvd. (;1 '(}�; C . Anchorage, Alaska 99518 / / Office: 907 - 273 -3527 Fax: 907-273-3535 rafael.barreto(`z halliburton.com Date: Stoned: 1 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 12, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Anisotropy / Wave / CSNG: BRU #232 -23 Run Date: 8/27/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Baneto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 BRU #232 -23 Digital Data in LAS format, Digital Log Image file 1 CD Rom 283- 20133 -00 Anisotropy / Wave / CSNG 1 Color Log 283- 20133 -00 ,;_ _ * Working on the LDWG format for data, will come at a later date * * PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Baneto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 -273 -3527 Fax: 907-273-3535 rafael.barreto@hallihurton.com Date: I! ( , / {yp \\ Date: Signed: • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 11, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: BRU #232 -23 Run Date: 9/12/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 BRU #232 -23 Digital Data in LAS format, Digital Log Image file 1 CD Rom 283- 20133 -00 Perforating Record 1 Color Log 283- 20133 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 -273 -3535 rafael.banreto @halliburton.com Date: - Signed: • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 11, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Reservoir Description Tool: BRU #232 -23 Run Date: 8/30/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 BRU #232 -23 Digital Data in LAS format, Digital Log Image file 1 CD Rom 283 - 20133 -00 Reservoir Description Tool 1 Color Log 283 - 20133 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907- 273 -3535 rafaelban Date: Signed: �' • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 11, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Sump Packer Correlation Record: BRU #232 -23 Run Date: 9/25/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 BRU #232 -23 Digital Data in LAS foiinat, Digital Log Image file 1 CD Rom 283 - 20133 -00 Sump Packer Correlation Record 1 Color Log 283 - 20133 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 -273 -3527 Fax: 907 -273 -3535 rafael.ban eto(ci halliburton.com Date: Signed: • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 11, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: TCP Correlation: BRU #232 -23 Run Date: 9/23/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Baneto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 BRU #232 -23 Digital Data in LAS format, Digital Log Image file 1 CD Rom 283- 20133 -00 TCP Correlation 1 Color Log 283- 20133 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907-273-3535 rafael.ban eto(ca'halliburton.com Date: /, • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 11, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plu g Setting Settin Record: BRU #232 -23 Run Date: 9/9/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 BRU #232 -23 Digital Data in LAS format, Digital Log Image file 1 CD Rom 283 - 20133 -00 Plug Setting Record 1 Color Log 283 - 20133 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 -273 -3527 Fax: 907 - 273 -3535 rafael.ban etoi'halliburton. com Date: Signed: • • { onoC1 ► ii ip5 TRANSMITTAL Beluga River Unit development well data FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. State of Alaska P.O. Box 100360 AOGCC Anchorage AK 99510 -0360 333 W. 7 Ave, Suite 100 Anchorage, Alaska 99501 -3539 RE: BRU 232 -23 Permit: 209 -057 DATE: 09/07/2009 mail Tr.n m' .-•: Cook Inlet, Alaska Beluga River Unit 232 -23 5028320133000 Report and CDROM Final Well Report, Mud logging Data, BRU 232 -23; Epoch, report date: 8/28/2009. Contents, equipment and crew, well details, geological data, pressure /formation, drilling data, daily reports, Color log prints 3757 -7587' md: Formation logs MD, Formation Log TVD; LWD Combo MD; LWD COMBO TVD; Gas ratio MD; Gas ratio TVD; Drilling dynamics MD; Drilling dynamics TVD _coon: :1 .',3 V:%7'i'�;� .i�:� > -v.:z va' 32,9,23 2 _fist t3 :'' fr'I Ay -.r :��R..:i� ±� ;x ,.53. %.✓62 — -- CC: Rick Levinson, CPAI Geologist Receipt: Date: � w ... . r '� *9,rP"� � , 3 9 ice' °s sue` �? �' =J;�, .,:e1• ',h 2 5;417 C�.' . , '� � " re'.��° � i. �''�'�.;!'�.,� , �!'r`�,r�;- iki','?J >�..f I �...�.i,�.',w Lw�, 3:�d� >. ✓,� � ,^-�f „ ; . j Sandra .D.Lemice0Conecoolyllips oom ° �q 1 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_ Fleckenstein @admin.state.ak.us; Jim_Regg @admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: ConocoPhillips Alaska FIELD / UNIT / PAD: Beluga DATE: 10/06/09 OPERATOR REP: Donald Lutrick AOGCC REP: Not Witnessed Packer Depth Pretest Initial 15 Min. 30 Min. Well 232 -23 Type Inj. N TVD 3,683' Tubing 0 0 0 0 Interval 1 P.T.D. 209 -057 Type test P Test psi 3500 Casing 0 3,500 3,500 3,500 P/F P Notes: OA 0 0 0 0 Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test _ Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waist M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Waistewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form BFL 9/1/05 MIT 232- 23.xls • 1 WELL LOG TRANSMITTAL To: State of Alaska September 29, 2009 Alaska Oil and Gas Conservation Commission Attn: Christine Mahnken 333 W. 7"' Ave., #100 Anchorage, AK 99501 -3539 RE: MWD Formation Evaluation Logs: BRU 232 -23 AK -MW- 0006503016 BRU 232 -23 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 50- 283 - 20133 -00 2" x 5" TVD TRIPLE COMBO Logs: 1 Color Log 50- 283 - 20133 -00 Digital Log Images & LWDG- formatted LIS Data w /verification listing; 1 CD Rom 50- 283 - 20133 -00 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: Alaska DNR, Division of Oil & Gas '� pct Beluga BRU232-23 Production Casing Cement quality. Page 1 of 2 zol-.9s Aubert, Winton G (DOA) From: Hartwig, Dennis D pennis.D.Hartwig©conocophillips.com] Sent: Thursday, September 10, 2009 11:18 AM To: Aubert, Winton G (DOA) Subject: Beluga BRU232-23 Production Casing Cement quality. Importance: High Winton, Per our brief conversation this morning I have included pertinent details describino the 7" Production cement job and evaluation as well as background info on our surface casing job. 9-5/8" Surface Casing and Cement :lob in 12-1/4" Hole 9-5/8 set at shoe depth of MD -- Total depth 3,755'MD Cemented in place with 12•0ppg cement Pumped 420 bbls cement with 145 bbls returned to surface Full returns throughout cement job. Casing landed on mandrel hanger. 7" Production Casing, and Cement Job in 8-3/4" Hole 7" set at shoe depth of - MD - Total depth 7,588'IMD Cemented in place with I0.5ppg cement Pumped 191 bbls cement or - 20% excess over callipered hole volume. Full returns throughout cement job, 20 reciprocation of casing string until the last 20bbls of displacement. Casing was landed on a mandrel hanger with 20 bbls left to displace Plug did not bump, however the floats held and on a later cleanout nin the plug was tagged just above the float collar. Overall the cement evaluation log looks very good. The - log shows excellent isolation between all of the h),, bearing Beluga and Sterling sands. Our uppermost hydrocarbon, the Sterling A sand is at approximately 4,120'MD, with the CBI: indicating approximately 360' of good cement isolation above the sand. The cement just below the casing shoe, — 3,760'tvlD and up inside the 9-5/8" to approximately 9/10/2009 Beluga BRU232-23 Production Casing Cement quality. Page 2 of 2 • • 3.500'MD indicates poorer coverage and bond and possibly some channeling. Over this interval (3755 — 3500'MD) the cement appears to have channeled to the highside of the wellbore with poorer cement coverage on the sides. In addition, our BRWD injection well, 1.7 miles away is in a zone at approximately 3.800'MD. If need be I can sit down with you and review the log. Our feeling is that any remedial work to provide further isolation at the shoe or inside of the 9-5/8" would most likely not he very successful and may actually end up comprotnising casing integrity over the life of the well. Thanks for your time, Regards...Dennis Dennis Hartwig Drilling Engineer ConocoPhillips Alaska ATO-1592 Office 907-265-6862 Cell : 907-575-7109 Fax : 907-265-1 535 9/10/2009 • Wea therford LABORATORIES State of Alaska Oil and Gas Commision. 333 7 Ave. Anchorage, AK OMNI Laboratories, Inc. 3209 Denali Anchorage, AK 907 - 646 -8605 Chip SamplesConoco- Phillips BRU- 232 -23, Kenai Peninsula, AK Date:9 /1/09 _ e 5 7 Material Shipping Record Depths 6412 -6499 6844- 6902.5 4 Boxes tota14 6902.5 - 6947.5 ` OMNI Contact: Dave Foster (307) 265 -8800 S igned• State of Alaska: 4 ...: / 4 ,/ 6 • ' °` SARAH PALIN, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMAIISSION a/ ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 ( FAX (907) 276 -7542 G.L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 -0360 Re: Beluga River Field, Sterling /Beluga Gas Pool, BRU 232 -23 Well ConocoPhillips Alaska, Inc. Permit No: 209 -057 Surface Location: 2102' FNL, 51' FWL, Sec. 24, T13N, R10W, SM Bottomhole Location: 2037' FNL, 2371' FEL, Sec. 23, T13N, R1 OW, SM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. ConocoPhillips assumes the liability of any protest to the spacing exception that may occur. 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, , 7 7 60.2( A ‘.......„, Cathy . Foerster Com issioner DATED this day of May, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 0,16/Ti O' / 2.1 2-0 21 • • STATE OF ALASKA RECTIVED ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL MAY 2 ! „iii 20 AAC 25.005 Aiask3 Oil & Cap Co. .;: ':(r:° , °:a ;j+ la. Type of Work: 1 b. Current Well Class: Exploratory ❑ Development Oil ❑ lc. Specify if well is pro osed for: Drill 0 Re -drill ❑ Stratigraphic Test El Service ❑ Development Gas 0 Coalbed Methane IO h B r G�s l ydrates ❑ Re-ent ry ❑ Multiple Zone 0 Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: U Blanket 11 Single Well 11. Well Name and Number. ConocoPhillips Alaska, Inc. Bond No. 59 - 52 - 180 BRU 232 - 23 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 7594' TVD: 6665' Beluga River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 2102' FNL, 51' FWL, Sec. 24, T13N, R1OW, SM ADL 21128 Sterling - Beluga Gas Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2039' FNL, 2300' FEL, Sec. 23, T13N, R1OW, SM NA 7/15/2009 Total Depth: 9. Acres in Property: , 14. Distance to 2037' FNL, 2371' FEL, Sec. 23, T13N, R1OW, SM 489 pp, y' ' Nearest Property: 3368.6' from CIRI lease 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 9 a/ Set 15. Distance to Nearest Well Open Surface: x - 323387.57 y - 2633528.6 Zone 4 KB Elevation above GL: '7ir, JAI feet to Same Pool: 212 -24 , 2351' 16. Deviated wells: Kickoff depth: 400 ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 52° deg Downhole: 3466 psig Surface: 2148 psig 18. Casing Program Specifications Setting Depth Quantity of Cement Size Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) na 20" 154.2# X -65 Bolted 84.875 20.6' 20.6' 105.5 105.5 driven 12.25" 9 -5/8" 40# L -80 BTC 3770.4 20.6' 20.6' 3791' 2975' 964 sx 12 ppg Lightweight slurry (BJ) 8.75" 7" 26# L -80 BTCM 7576.3 17.7' 17.7' 7594' 6665' 283 sx 10 ppg Lightweight slurry (BJ) 4.5" 12.6# L -80 IBTM 7279 15 15 7294' 6365' production tubing and sand screens 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: Filing Fee ❑ BOP Sketch o Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat El Diverter Sketch El Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Dennis Hartwig @ 265 - 6862 Printed Name A G. L. Alvord Title Alaska Drilling Manager Signature [%V\ /� , < Phon„ ,� Date ca ((O q Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: 7(.:- /� , 7 50- 2 j .5 5 - / Approval Date: for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed me ane, gas hydrates, or gas contained in shales: d Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No 2` Other: . H2S measures: Yes ❑ No [� Directional svy req'd: Yes [Y No ❑ p.�,, 20 /1--C LS. 035 .k) (0 cit:4 '�`ei v e,�.f [i An.. Zfaha4rt.e,< is i't ypc tfe. 4 m,f - p F f sDOO e jj . APPROV D BY THE COMMISSION DATE: - ?,2 ©11 j 3, '' ` ;', / , COMMISSIONER Form 10 -401 (Revised 1/2009) � ✓ i \IL) 1 1‘ r Submit in Dupligte 1 5 - • . 2 / e-'9 j 4J4 - 05/24hool III • ,, 1 1- C R I' , V F.: p STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 tAiaslc tai i'd5 ~,soft:,:. i:a3 71111 la. Type of Work: 1b. Current Well Class: Exploratory ❑ Development Oil ❑ lc. Specify if well is proposed for: Anchorage Drill 0 . Re -drill ❑ Stratigraphic Test ❑ Service ❑ Development Gas 0 ! Coalbed Methane ❑ Gas Hydrates ❑ Re -ent ry ❑ Multiple Zone El ' Single Zone ❑ Shale Gasp 2. Operator Name: 5. Bond: U Blanket U Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59 52 180 . BRU 232 - 23 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 7594' TVD: •665' Beluga River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 2102' FNL, 51' FWL, Sec 24 T13N R1OW SM ' ADL s 1128 • Sterling - Beluga Gas Pool Top of Productive Horizon: 8. Land Use Perm' . 13. Approximate Spud Date: 2039 FNL 2300' FEL, Sec. 23 T13N R1OW SM NA 7/15/2009 Total Depth: 9. Acres in - roperty: 14. Distance to 2037 FNL 2371' FEL, Sec. 23 T13N R1OW SM 489 Nearest Progerty:3368.6 from CIRI lease 4b. Location of Well (State Base Plane Coordinates): 10. B Elevationbove MSL ei• /(~ L5. Distance to Nearest y - Height above GL): 1 RK feet .O , t Surface: x - 323387.57 • 2633528.6 ' Zone 4 f 4 Well within Pool: 212 -24 , 2351 ft * ' 2i. '`) 16. Deviated wells: Kickoff depth: 400 . 17. Maximum Anticipated Pressure , psig (see 20 AAC 25.035) Maximum Hole Angle: 52° deg Downhole: 3466 psig ' “ Surface: 2148 psig ' 18. Casing Program Specifications Setting Depth Quantity of Cement Size Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling ength MD TVD MD TVD (including stage data) na 20" 154.2# X -65 Bolted 84.875 20.6 20.6 105.5 105.5 driven 12.25" 9 -5/8" 40# L -80 BTC 3770.4 20.6 20.6 3791 • 2975 . 964 sx 12 ppg Lightweight slurry (BJ) ' 8.75" 7" 26# L -80 BT' M 7576.3 17.7 17.7 7594 • 6665 • 283 sx 10 ppg Lightweight slurry (BJ) / 4 -1/2" 12.6# L -80 :TM 7279 15 15 7294 6365 production tubing and sand screens 19 PRESENT WELL C • P■ I *ION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD :: Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 1 Casing Len . h. Sie Cement Volume MD TVD Conductor /Structural pp ,, Surface '. / Intermediate Production / , ` 7 / ' - -F Liner v � 0 , Perforation Depth MD ( : Perforation Depth TVD (ft): 20. Attachments: ding Fee 0 BOP Sketch Ei Drilling Progran>Q Time v. Depth Plot❑ Shallow Hazard Analysis ❑ P operty Plat El Diverter Sketch El Seabed Report El Drilling Fluid Program Ei 20 AAC 25.050 requirements Ei 21. Verbal Approv Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dennis Hartwig Printed Name C. Alvord Title Drilling Team Lead Signature � C Phone 24,6 ;,...6 X20 Date 5'1(G( QS Commission Use Only Permit to Drill API Number:_ Permit Approval See cover letter Number: ,0 -- 6_c 7 50- 2_) - 2133 Date: for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Er Samples req'd: Yes El No u Mud log req'd: YeiJ No[f Other: H2S measures: Yes ❑ No n Directional svy req'd: Yes [ No ❑ p To A-ic Zs CS tit) 0-), CKAIR lf ve ..-+ 1 i h.,c vqtvi e,14. GC , . IP roved , _nest acs pE fo Soar_, "L., . APPROVED BY THE COMMISSION DATE: , COMMISSIONER Q RIGINAL 5' 246" Form 10 -401 Revised 12/2005 Submit in uplicate • • ConocoPhillips Alaska, Inc. Post Office Box 100360 ,.w . Anchorage, Alaska 99510 -0360 COnocoPhillips Telephone 907 - 276 -1215 May 18, 2009 i''`(1 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill BRU 232 -23 Dear Sir or Madam: • ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development gas well from an existing pad in the Beluga River Field, Alaska. / The well is designed to penetrate the Beluga sands, core the lower Beluga H and I intervals, log, evaluate and be completed as a gravel pack gas producer. / • As indicated in the attachments, the drilling program will include drilling 12 -1/4" surface hole to approximately 3794' MD, cement 9 -5/8" surface casing, followed by drilling an 8- 3/4" hole through the Sterling and Beluga sands. Two separate 90 ft coring runs are planned through the lower Beluga H and I intervals. After logging with LWD and electric • line tools, 7" casing will be run and cemented. The completion program will include perforating, fracturing and gravel packing the target zones. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10 -401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program 3. A drilling fluids program summary. 4. Pressure information as required by 20 ACC 25.035 (d)(2). 5. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). 6. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 7. A description of the drilling fluids handling system. • • If you have any questions or require further information, please contact Dennis Hartwig at 265 -6862 or Chip Alvord at 265 -6120. Sincerely, )eril �� Dennis Hartwig Drilling Engineer Attachments cc: BRU 211 -26 Well File Chip Alvord ATO -1570 Mark Chambers ATO -1566 John Braden ATO -1392 Marta Czarneski Kenai LNG plant Greg Noble. BLM Anchorage Field Office • • BRU 232 -23 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) 12 -1/4" Hole / 9 -5/8" Casing Interval Event Risk Level Mitigation Strategy Gas Hydrates Low , Monitor well, increased mud weight, managed fluid rheologies, decreased circulating times, controlled drilling rates, low mud temperatures Clay Balling Medium Maintain planned mud parameters, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP. Abnormal Pressure in Low Diverter drills, increased mud weight. Offset Surface Formations • drilling does not indicate abnormal pressures in the surface hole. Lost Circulation Medium Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries, port collar, controlled running speeds. 8 -3/4" Hole / 7" Casing Interval Event Risk Level Mitigation Strategy Lost circulation High Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, Pre - planned LCM pills, lost circulation material. Hole swabbing on trips Low Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Directional Control Medium BHA design, geologic review and advisement of potential slump blocks. Sloughing Shale, Tight High Increased mud density to control the shales and Hole fluid composition according to plan, controlled trip speeds, sweeps, ECD monitoring. Abnormal Reservoir Low Well control drills, increased mud weight, offset Pressure well data does not indicate abnormal pressures in the area. Tight hole in coals Medium Control drilling, mud logs, crew awareness Hydrogen Sulfide gas Low • H drills, detection systems, alarms, standard ,/ well control practices, mud scavengers ORIGINAL • • Beluga : BRU 232 -23 General Procedure: 1. MIRU Doyon's Arctic Fox over pre - installed 20" conductor casing with bolted landing ring on conductor. 2. Install diverter & function test same. Notify regulatory agencies 48 hours prior to test. 3. Spud well and drill 12 1/4" hole to the surface casing point at 3791' MD / 2975' TVD. Run MWD / LWD logging tools (GR /RES) in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 9 5/8" 40# L80 BTC casing string to surface. • Employ lightweight cement lead slurry assure cement returns to the surface in a one -stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify all regulatory agencies 48 hours prior to test 7. Make up 8 3/4" bit and BHA and RIH to top of float equipment. • Pressure test casing to 3000 psi for 30 minutes • Record results and fax to town 8. Drill float equipment and approximately 20' of new hole • Perform LOT (or FIT if gradient reaches 16 ppg equivalent) • Record results and fax to town 9. Drill 8 -3/4" hole to +/- 6074' MD / +/- 5145' TVD Prognosed Top of Beluga H - formation) . Run MWD / LWD (GR /RES /DENS /POROSITY /MRIL) logging tools in drill string as required for directional monitoring and formation data gathering. POOH with drilling assembly. Mud Logging services will also be used in the ✓ production hole for total mud gas monitoring and for chromatography. • Condition hole and mud for upcoming coring operations. 10. Make up 8 3/4" Coring Bit and Coring BHA and RIH to TD. 11. Core with 8 -3/4" coring bit to obtain approximately 90' of 4" diameter core in Beluga H formation. POOH with coring assembly and lay core down. • Condition hole and mud for upcoming drilling operations. 12. Drill 8 -3/4" hole to +/- 6764' MD / +/- 5835' TVD Prognosed Top of Beluga I formation). Run MWD / LWD (GR /RES /DENS /POROSITY /MRIL) logging tools in drill string as required for directional monitoring and formation data gathering. POOH with drilling assembly. • Condition hole and mud for upcoming coring operations. ORIGINAL • • 13. Make up 8 3/4" Coring Bit and Coring BHA and RIH to TD. 14. Core with 8 -3/4" coring bit to obtain approximately 90' of 4" diameter core in Beluga I formation. POOH with coring assembly and lay core down. • Condition hole and mud for upcoming drilling operations. 15. Drill 8 -3/4" hole to +/- 7594' MD / +/- 6665' TVD. Run MWD / LWD (GR/RES /DENS /POROSITY /MRIL) logging tools in drill string as required for directional monitoring and formation data gathering. POOH with drilling assembly. • Condition hole and mud for upcoming logging operations. 16. Log 8 -3/4" open hole with Halliburton electric line tools (SP /SBL, Dipole Sonic, NGT, MDT). 17. Run and cement 7" casing per program to TD (est.@ 7594' MD/ 6665' TVD). Cement casing to bring cement +/- 500' above Sterling A sand. • If there are signs of lost circulation prior to running casing, install a Halliburton H ES stage cementing tool at +1- 4500' MD. 18. Run in hole with casing cleanup assembly on drilipipe. 19. Clean casing and pickle drilipipe. 20. Displace well to c filtered brine. 21. Test casing to 000 psi. 22. Rig up Halliburton E -line and run cement bond log GR / CCL. 23. Pick up and run in hole with tubing frac. String (4 -1/2" tubing). 24. Set tubing in slips, close pipe rams, and rig up electric line 25. Perforate with wireline tools 26. Fracture Stimulate 1 zone 27. Sand Back 28. Repeat perforating and fracturing 2 -4 times as needed / 29. Clean out proppant 30. POOH with tubing string 31. Pick up approximately 1200' gross tubing conveyed perforating guns on drilipipe. 32. Perforate with large hole perforations- 4 -5/8" guns / 33. Run Conventional gravel pack equipment with 2 -7/8" inner string to gravel pack lower interval. 34. Pump high rate water pack (HRWP). 35. Run inner string to isolate pack. 36. Pick up approximately 1500' gross 4 -5/8" tubing conveyed perforating guns. Perforate. 37. Run Multizone gravel pack completion, complete with 2 -7/8" and 1.9" inner strings. ORIGINAL • • 38. Set packers, pump three HRWPs, and POOH with inner strings as required. 39. Run Upper completion per completion schematic. (Latch into anchor, shear PBR, space out, etc.) 40. Land tubing and test tubing hanger. 41. Test inner annulus to 2500 psi for 30 minutes. (Note: This will test our tubing / integrity.) 42. Pressure up on IA to shear SOV at 3000 psi. 43. Set BPV and ND BOP. / 44. Nipple up tree and test same. 45. RDMO. Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. BRU 212 -24 is the closest well. Minimum well separation is 100' at 671' MD. Drilling Area Risks: The interbedded layers of the Sterling and Beluga sands may have reservoir pressure that varies from normal (water gradient) to depleted 3.5 - 4 ppg. Sufficient mud weight to control the shale and coal layers could provide very high (1700 psi +) overbalance on the depleted sand layers. Lost circulation is a risk. This will be mitigated by LCM, low fluid Toss mud additives and wellbore strengthening additives. 1 ORIGINAL • • Drilling Fluid Program Surface Interval Fluid Properties Funnel API Fluid Drill Depth MD Mud Wt. Viscosity Yield Point Loss Solids (ft) (lb/gal) (cp) (Ib /100ft (m1/30min) pH ( %) MBT 0 — 3791 8.8 — 9.6/ 80 - 200 40 - 60 NC — <10 +/ 9.0 < 7% <35 Production Interval Fluid Properties API Fluid Depth MD Mud Wt. Funnel Yield Point Loss Solids (ft) (ppg) Viscosity (Ib/100ft (m1 /30min) pH ( %) 3,791' -7594' 9.2 -10.4 42 -55 18 -25 <6 9.0 -9.5 9 -14 Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec /qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: The Beluga Production Interval mud system will be an inhibitive water based mud system. The primary inhibitors are KCI which will be maintained at 6% by wt, and a proprietary shale inhibitor designed to enhance the inhibition of KCL as well as provide inhibition on it own. Other components of the system are Well Bore Strengthening materials designed to prevent lost circulation in low pressure depleted Zones of the upper hole section while drilling to TD for long string casing. The system also includes additives for aiding in the stabilization of coal seams and minimizing fluid invasion to prevent reservoir damage. If well control becomes an issue, enough barite to increase the mud weight by one pound per gallon will be on location at all times, as well as the option to increase KCL concentration for added density. OR!GINAL • • BRU 232 -23 Grassroots Well ConocoPhil lips Completion Schematic Conductor (Driven): 20 ", .75 ", API 5L GRB, Full Grvd, R3 Driven to Refusal 91' Below Pad Grade 1 1 1 11/16/2009 ; I • Chemical injection port with 3/8" SS control line +/- 500' MD f f j TOC 500' BP6i SCSSSV with "A SS control line to surface i TOC +1- 3612' MD / 2845' TVD above top Sterling rag +/- 550' MD i i i i r i Surface Casing: f 9 -5/8 ", 40 #, L -80, BTC Formaton: Estimated TOPS: Pore Pressure Set @ 3791' MD / 2975' TVD (-250' TVD above ' Sterling -A) Halliburton H ES HO stage tool e+/- 4500' MD Sterling A 4112' MD / 3235' TVD -- CONTINGENCY IF THERE ARE LOST CIRCULATION Sterling B 4317' MD / 3415' TVD 3.7 PPG EMW PROBLEMS -- To Sterling A 4-"A" Camco KGB -2 GLM w/ 1" DCK2 shear valve(cD Sterling C 4479' MD / 3565' TVD 4150 ft MD r :I SC -2 Packer w/ Millout Extension a 4334 ft MD - SC-1L Isolation Packer @ 4394 ft MD Formaton: Estimated Tops: Pore Pressure cn O * Beluga D 4648' MD / 3725' TVD 4.6 -4.8 ppg IMEEEEll SC-1L Isolation Packer @ 4904 ft MD c Beluga E 4913' MD / 3985' TVD 3.9 - 5.6 ppg Beluga F 5269' MD / 4340' TVD 4.2 -7.5 ppg SC-1L I Packer @ 5414 ft MD Beluga G 5734' MD / 4870' TVD 8.3 ppg 7 • cn O SC -2 P w/ Millout Extension @ 5924 ft MD Formaton: Estimated Tops: Pore Pressure SC -2 Packer w/ Alternate Bore © 5944 ft MD i — 7 Beluga H 6074' MD / 5145' TVD 6.5 -9.4 ppg ce Beluga H and I will require 4 C-- � : O Fracs followed by HRWP c Beluga I 6764' MD / 5834' TVD 9.8 ppg • — • Beluga I Base 7294' MD / 6365' TVD 9.8 ppg r Model FS Sump Packer (a7 7304 ft MU mii Production Casing: 7 ", 26.00 #, L -80, BTC -Mod Set @ 7594' MD / 6665' TVD , ( +/- 300' MD Below Beluga I Base) ,_ _; BRU 232 -23 prepared by Dennis Hartwig / Rami Jasser 03/03/09 Sperry Drilling Services Directional Plan wp06 ORIGINAL • • BRU 232 -23 PRESSURE INFORMATION AND CASING DESIGN: Maximum Anticipated Surface Pressure and Casing Design: The following information is used for calculation of the maximum anticipated surface pressures for the planned well: Casing Casing Setting Maximum Pore Pore Size Depth Pressure Pressure MASP Gradient Drilling 20" 105.5' MD / 105.5' 8.6 ppg 49 NA TVD 9 -5/8" 3791 MD / 2975' 9.0 ppg 1392 49 psi TVD 7" 7597' MD / 6665', 10 ppg , 3466 4 2148 psi TVD Expected Maximum Mud Weights: • 12 -1/4" surface hole to 3791' MD / 2975' TVD: 9.6 ppg, pore pressures of up to 9.0 ppg may be present. • 8 -3/4" production hole to 7594' MD / 6665' TVD: 10.4 ppg The pore pressure is not expected to be above 10 ppg from offset drilling data and depletion due to production Procedure for Calculating Maximum Anticipated Surface Pressure: MASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) MASP = [(FG x 0.052) — 0.11] x D Where: MASP = Maximum Anticipated Surface Pressure FG = Fracture Gradient at the casing seat in lb/gal 0.0 = Conversion factor from lb/gal to psi /ft 0.= Gas Gradient in psi /ft (above 10,000' TVD) D = True vertical depth to casing seat in ft from RKB OR 2) MASP =FPP — (0.11 x D) Where: FPP = Formation Pore Pressure at the next casing seat MASP Calculations 1. Drilling below 20" Conductor Casing MASP = [(FG x 0.052) — 0.11 x D = [(11.0 x 0.052) — O. 1 x 105.5' = 49 psi OR fTh' 7.) r‘ N AL 1 • MASP = FPP — (0.11 x D) = 1392 — (0.11 x 2975') = 1065 psi 2. Drilling below 9 -5/8" Surface Casing MASP= [(FG x 0.052) — 0.11] x D = [(16x0.052) - 0.11]x2975' = 2148psi ' OR MASP = FPP — (0.11 x D) = 3466 — (0.11 x 6665') = 2733 psi ** See the included BOP schematics, diverter layout for a minimum 3000 psi BOP configuration. It is planned to use a 5000 psi stack due to availability. Casing Design Performance Properties Size Hole Weight Grade Conn. Internal Collapse Tensile Yield Strength Joint Body 20" NA 154.2 X65 Bolted Conductor ppf 9 -5/8" 12.25 40 ppf L -80 BTC 5750 psi 3090 psi 947 916 kips kips 7" 8.75 26 ppf L -80 BTC -M 7240 psi 5410 psi 641 604 kips kips Casing Setting Depth Rational: 20" @ 105.5' MD RKB - Conductor casing driven to provide sufficient anchor for diverter system. 9 -5/8" @ 3791' MD RKB - Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling 8 -3/4" hole to top of reservoir. 7" @ 7594' MD RKB - Production casing is near the bottom of the Beluga sands to provide pressure integrity and zonal isolation. Assumptions a) Use of lightweight cement slurries cement slurries for design purposes b) Temperature deration of pipe properties has not been applied to all strings c) Assume higher than expected mud weight, - conservative for most cases ORIGINAL Cementing Program: 9 5/8" Surface Casing run to 3791' MD / 2975' TVD Cement from 3791' MD to surface with lightweight 12 ppg slurry. Assume 70% excess annular volume. Lead slurry:(3791'- surface') X 0.3132 ft /ft X 1.7 (70% excess) = 2018.5 ft => 964 sx @ 2.095 ft /sk System: 1134 Sx Type I Cement + 0.9% bwoc BA -10A + 0.1% bwoc FL -52 + 0.05% bwoc Static Free + 25% bwoc LW -6 + 0.6% bwoc CD -32 + 1 gals /100 sack FP -6L + 0.4% bwoc Sodium Metasilicate + 5% bwoc MPA -1 + 67.9% Fresh Water , Yielding 2.095 ft3 /sk 7" Production, Casing run to 7594' MD / 6665' TVD Cement from 7594' MD to +/- 3612' MD (minimum 500' MD above top of Sterling formation) with lightweight cement 10 ppg. Assume 40% excess annular volume. Tail: (7594' — 3791') X 0.1503 ft /ft X 1.4 (40% excess) + (3791' — 3612') x .1585 ft /ft = 828.6 ft annular vol. 80' X 0.2148 ft /ft = 17.2 ft shoe joint volume Total volume = 828.6 + 17.2 = 845.8 ft => 283 Sx @ 2.99 ft /sk System: 295 Sx Class G + 22% bwoc LW -7 -6 + 15% bwoc BA -90 + 1% bwoc CD -32 0.6% bwoc Sodium Metasilicate + 1.2 % bwoc FL -52 + 0.05% bwoc static free + 1 gal /100sk FP -6L + fresh water@ 10.0 ppg, yielding 2.99 ft /sk If there are problems with lost circulation during drilling, logging or tripping, consideration will be made to including a hydraulic opening stage tool in the casing string, to help ensure cement coverage of the Sterling formation. `` r ) j r' 1 IN 1,)11\1.i 111 • 0: 0 1 1 :i , 5 1 . : ConocoPhillips(Alaska) Inc. 11 ,iit Beluga River p Beluga River Plan: BRU 232-23 Plan: BRU 232-23 1 1 f i'5' k i•,!: 15 Plan: BRU 232-23wp06 r t t• Standard Proposal Report I N A D 2 71 . t : 09 March, 2009 T ': I V V 6 V El 5 zE IE : [ F i E E 5 5 E E , E , ANAL, HALLIBURTON 411111:11114i Sperry Drilling Services ill z4 k n r% !GINAL • . Beluga River Rive Beluga Plan: BRU 232-23 DDI: 5.537 BRU 232- 23wp06 Plan BRU BRU 232- 23wp06 c 400 — 0 o 7 x 8 -3/4" 9 -5/8" x 12 -1/4" t r — O Z BRU 232- 23wp05 Base Beluga .0 O co - 400 -2400 -2000 -1600 -1200 -800 -400 0 West( -) /East( +) (400 ft/in) g 0— o° c 10 2 O O -�O • V7 4) - 2500 -- - -- h� 9 -5/8" x 12 -1/4" O_ _ p a r >- 0 ' .. - -- 2' ... .. ii 10. Beluga E f Beluga F j 5000 Beluga G a) Beluga H 0` — ----- - - - - -- ' 7" x 8 -3/4" I— Beluga I __ Beluga I -Base - -T BRU 232- 23wp05 Base Beluga BRU 232- 23wpC6 -5000 -2500 0 2500 5000 7500 Vertical Section at 280.00° (2500 ft /in) ORIGINAL • I A ID 2 I ConocoPhillips HALL1BURTON Standard Proposal Report Database: EDM v16 Prod Local Co- ordinate Reference: Well Plan: BRU 232 - 23 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: 232 -23 (16.5 +78) © 94.50ft Project: Beluga River MD Reference: Plan: 232 -23 (16.5 +78) @ 94.50ft Site: Beluga River North Reference: True Well: Plan: BRU 232 -23 Survey Calculation Method: Minimum Curvature Wel!bore: Plan: BRU 232 -23 Design: BRU 232 23wp06 Project Beluga River Map System: US State Plane 11127 (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 Beluga River Site Position: Northing: 244.11ft Latitude: 53° 45' 36.816 N From: Map Easting: - 1,140,020.60ft Longitude: 157° 35' 11.935 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: 0.00 ° Well Plan: BRU 232 - 23 Well Position +N /-S 0.00 ft Northing: 2,633,528.63 ft , Latitude: 61° 12' 15.917 N +E/ -W 0.00 ft Easting: 323,387.57 ft ' Longitude: 151° 0' 5.148 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 78.00ft Wellbore Plan: BRU 232 - 23 Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) r) (nT) BGGM2007 2/23/2009 16.12 72.95 55,016 Design BRU 232- 23wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 16.50 Vertical Section: Depth From (TVD) +W-S +E/-W Direction (ft) (ft) (ft) (°) 16.50 0.00 0.00 280.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N /-S +E/ -W Rate Rate Rate Tool Face (ft} (°) ( (ft) ft (ft) (ft) (°/100ft) (° /100ft) ( ° /100ft} (°) 16.50 0.00 0.00 16.50 -78.00 0.00 0.00 0.00 0.00 0.00 0.00 400.72 . 0.00 0.00 400.72 306.22 0.00 0.00 0.00 0.00 0.00 0.00 700.72 5.25 271.53 700.30 605.80 0.37 -13.73 1.75 1.75 0.00 271.53 1,200.72 20.25 271.53 1,186.58 1,092.08 3.30 - 123.72 3.00 3.00 0.00 0.00 2,107.86 52.00 271.53 1,909.97 1,815.47 17.40 - 651.52 3.50 3.50 0.00 0.00 3,405.46 52.00 271.53 2,708.85 2,614.35 44.70 - 1,673.68 0.00 0.00 0.00 0.00 5,173.99 0.00 329.03 4,244.39 4,149.89 64.76 - 2,422.38 2.94 -2.94 3.25 180.00 7,374.10 0.00 329.03 6,444.50 6,350.00 64.89 - 2,422.46 0.00 0.00 0.00 0.00 7,594.10 0.00 329.03 6,664.50 6,570.00 64.91 - 2,422.47 0.00 0.00 0.00 0.00 3/9/2009 3:26:33PM Page 2 COMPASS 2003.16 Build 42F f 171 1 Al s 4 , 4 • • ConocoPhillips HALLIBURTON Standard Proposal Report Database:.. EDM v16 Prod Local Co- ordinate Reference: Well Plan: BRU 232 -23 Company: ConocoPhillips(Alaska) Inc. ND Reference: Plan: 232 -23 (16.5 +78) @ 94.50ft Project: Beluga River MD Reference: Plan: 232 -23 (16.5 +78) © 94.50ft Site: Beluga River North Reference: True Well: Plan: BRU 232 -23 Survey Calculation Method: Minimum Curvature Welibore: Plan: BRU 232 -23 Design: BRU 232- 23wp06 Planned Surrey Measured Vertical Map Map Depth inclination Azimuth Depth NDss +N1 +E1 - Northing Fasting DLS Vert Section (ft) ( °) ( °) (ft) ft (ft) (ft) (ft) (ft) -78.00 16.50 0.00 0.00 16.50 -78.00 0.00 0.00 2,633,528.63 323,387.57 0.00 0.00 100.00 0.00 0.00 100.00 5.50 0.00 0.00 2,633,528.63 323,387.57 0.00 0.00 200.00 0.00 0.00 200.00 105.50 0.00 0.00 2,633,528.63 323,387.57 0.00 0.00 300.00 0.00 0.00 300.00 205.50 0.00 0.00 2,633,528.63 323,387.57 0.00 0.00 400.00 0.00 0.00 400.00 305.50 0.00 0.00 2,633,528.63 323,387.57 0.00 0.00 400.72 0.00, 0.00 400.72 306.22 0.00 0.00 2,633,528.63 323,387.57 0.00 0.00 Start Build 1.75 500.00 1.74 271.53 499.98 405.48 0.04 -1.50 2,633,528.69 323,386.07 1.75 1.49 600.00 3.49 271.53 599.88 505.38 0.16 -6.06 2,633,528.89 323,381.52 1.75 6.00 700.00 5.24 271.53 699.58 605.08 0.36 -13.66 2,633,529.21 323,373.92 1.75 13.52 700.72 5.25 271.53 700.30 605.80 0.37 -13.73 2,633,529.21 323,373.85 1.75 13.59 Start Build 3.00 800.00 8.23 271.53 798.88 704.38 0.68 -25.38 2,633,529.70 323,362.21 3.00 25.11 900.00 11.23 271.53 897.43 802.93 1.13 -42.26 2,633,530.41 323,345.33 3.00 41.82 1,000.00 14.23 271.53 994.97 900.47 1.72 -64.29 2,633,531.33 323,323.32 3.00 63.61 1,100.00 17.23 271.53 1,091.21 996.71 2.44 -91.38 2,633,532.47 323,296.24 3.00 90.42 1,200.00 20.23 271.53 1,185.90 1,091.40 3.30 - 123.48 2,633,533.82 323,264.17 3.00 122.17 1,200.72 20.25 271.53 1,186.58 1,092.08 3.30 - 123.72 2,633,533.83 323,263.92 3.00 122.42 Start Build 3.50 1,300.00 23.72 271.53 1,278.62 1,184.12 4.30 - 160.88 2,633,535.39 323,226.79 3.50 159.18 1,400.00 27.22 271.53 1,368.89 1,274.39 5.45 - 203.87 2,633,537.20 323,183.83 3.50 201.71 1,500.00 30.72 271.53 1,456.36 1,361.86 6.74 - 252.28 2,633,539.23 323,135.44 3.50 249.62 1,600.00 34.22 271.53 1,540.71 1,446.21 8.17 - 305.95 2,633,541.49 323,081.81 3.50 302.72 1,700.00 37.72 271.53 1,621.62 1,527.12 9.74 - 364.66 2,633,543.95 323,023.13 3.50 360.81 1,800.00 41.22 271.53 1,698.80 1,604.30 11.44 - 428.20 2,633,546.62 322,959.62 3.50 423.68 1,900.00 44.72 271.53 1,771.96 1,677.46 13.26 - 496.34 2,633,549.49 322,891.53 3.50 491.10 2,000.00 48.22 271.53 1,840.81 1,746.31 15.19 - 568.81 2,633,552.53 322,819.10 3.50 562.80 I 2,100.00 51.72 271.53 1,905.11 1,810.61 17.24 - 645.34 2,633,555.75 322,742.61 3.50 638.53 2,107.86 52.00 271.53 1,909.97 1,815.47 17.40 - 651.52 2,633,556.01 322,736.43 3.50 644.65 Start 1297.60 hold at 2107.86 MD 2,200.00 52.00 271.53 1,966.70 1,872.20 19.34 - 724.10 2,633,559.06 322,663.90 0.00 716.46 2,300.00 52.00 271.53 2,028.26 1,933.76 21.44 - 802.88 2,633,562.37 322,585.17 0.00 794.40 2,400.00 52.00 271.53 2,089.83 1,995.33 23.55 - 881.65 2,633,565.68 322,506.44 0.00 872.35 2,500.00 52.00 271.53 2,151.39 2,056.89 25.65 - 960.42 2,633,568.99 322,427.72 0.00 950.29 2,600.00 52.00 271.53 2,212.96 2,118.46 27.76 - 1,039.20 2,633,572.30 322,348.99 0.00 1,028.23 2,700.00 52.00 271.53 2,274.53 2,180.03 29.86 - 1,117.97 2,633,575.61 322,270.26 0.00 1,106.17 2,800.00 52.00 271.53 2,336.09 2,241.59 31.96 - 1,196.74 2,633,578.92 322,191.54 0.00 1,184.11 2,900.00 52.00 271.53 2,397.66 2,303.16 34.07 - 1,275.51 2,633,582.23 322,112.81 0.00 1,262.05 3,000.00 52.00 271.53 2,459.22 2,364.72 36.17 - 1,354.29 2,633,585.54 322,034.09 0.00 1,339.99 3,100.00 52.00 271.53 2,520.79 2,426.29 38.28 - 1,433.06 2,633,588.85 321,955.36 0.00 1,417.94 3,200.00 52.00 271.53 2,582.36 2,487.86 40.38 - 1,511.83 2,633,592.16 321,876.63 0.00 1,495.88 3,300.00 52.00 271.53 2,643.92 2,549.42 42.48 - 1,590.61 2,633,595.47 321,797.91 0.00 1,573.82 3,400.00 52.00 271.53 2,705.49 2,610.99 44.59 - 1,669.38 2,633,598.78 321,719.18 0.00 1,651.76 3,405.46 52.00 271.53 2,708.85 2,614.35 44.70 - 1,673.68 2,633,598.96 321,714.88 0.00 1,656.02 Start DLS 2.94 TFO 180.00 3/9/2009 3:26:33PM Page 3 COMPASS 2003.16 Build 42F 0 R1G A , . • ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co- ordinate Reference: Well Plan: BRU 232 -23 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: 232 -23 (16.5 +78) © 94.50ft Project: Beluga River MD Reference: Plan: 232 -23 (16.5 +78) © 94.50ft Site: Beluga River North Reference: True Welk Plan: BRU 232 -23 Survey Calculation Method: Minimum Curvature Welibore: Plan: BRU 232 -23 Design: BRU 232- 23wp06 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +EI-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 2,674.34 3,500.00 49.22 271.53 2,768.84 2,674.34 46.65 - 1,746.71 2,633,602.03 321,641.89 2.94 1,728.28 3,600.00 46.28 271.53 2,836.07 2,741.57 48.63 - 1,820.70 2,633,605.14 321,567.95 2.94 1,801.48 3,700.00 43.34 271.53 2,907.00 2,812.50 50.51 - 1,891.14 2,633,608.10 321,497.55 2.94 1,871.18 3,790.84 40.67 271.53 2,974.50 2,880.00 52.14 - 1,951.90 2,633,610.66 321,436.82 2.94 1,931.30 9-518" x 12 -1/4" 3,800.00 40.40 271.53 2,981.46 2,886.96 52.30 - 1,957.86 2,633,610.91 321,430.87 2.94 1,937.19 3,900.00 37.46 271.53 3,059.25 2,964.75 53.98 - 2,020.66 2,633,613.55 321,368.10 2.94 1,999.34 4,000.00 34.52 271.53 3,140.15 3,045.65 55.55 - 2,079.40 2,633,616.02 321,309.40 2.94 2,057.46 4,100.00 31.58 271.53 3,223.96 3,129.46 57.01 - 2,133.91 2,633,618.31 321,254.92 2.94 2,111.39 4,112.35 31.22 271.53 3,234.50 3,140.00 57.18 - 2,140.34 2,633,618.58 321,248.50 2.94 2,117.75 Sterling A 4,200.00 28.64 271.53 3,310.46 3,215.96 58.35 - 2,184.05 2,633,620.42 321,204.81 2.94 2,161.00 4,300.00 25.70 271.53 3,399.41 3,304.91 59.57 - 2,229.69 2,633,622.34 321,159.20 2.94 2,206.16 4,316.71 25.21 271.53 3,414.50 3,320.00 59.76 - 2,236.87 2,633,622.64 321,152.02 2.94 2,213.27 Sterling B 4,400.00 22.76 271.54 3,490.59 3,396.09 60.67 - 2,270.71 2,633,624.07 321,118.20 2.94 2,246.75 4,479.49 20.42 271.54 3,564.50 3,470.00 61.45 - 2,299.95 2,633,625.30 321,088.98 2.94 2,275.68 Sterling C 4,500.00 19.82 271.54 3,583.76 3,489.26 61.64 - 2,307.00 2,633,625.60 321,081.93 2.94 2,282.66 4,600.00 16.88 271.54 3,678.67 3,584.17 62.49 - 2,338.47 2,633,626.92 321,050.49 2.94 2,313.79 4,647.72 15.48 271.54 3,724.50 3,630.00 62.84 - 2,351.76 2,633,627.48 321,037.20 2.94 2,326.94 Beluga D 4,700.00 13.94 271.54 3,775.06 3,680.56 63.20 - 2,365.02 2,633,628.04 321,023.95 2.94 2,340.07 4,800.00 11.00 271.55 3,872.69 3,778.19 63.78 - 2,386.60 2,633,628.96 321,002.38 2.94 2,361.42 4,900.00 8.06 271.55 3,971.30 3,876.80 64.23 - 2,403.15 2,633,629.66 320,985.84 2.94 2,377.79 4,913.32 7.67 271.55 3,984.50 3,890.00 64.28 - 2,404.97 2,633,629.73 320,984.02 2.94 2,379.60 Beluga E 5,000.00 5.12 271.57 4,070.63 3,976.13 64.54 - 2,414.62 2,633,630.14 320,974.38 2.94 2,389.14 5,100.00 2.18 271.62 4,170.42 4,075.92 64.72 - 2,420.98 2,633,630.42 320,968.03 2.94 2,395.43 5,173.99 0.00 328.09 4,244.39 4,149.89 64.76 - 2,422.38 2,633,630.48 320,966.62 2.94 2,396.83 Start 2200.11 hold at 5173.99 MD 5,200.00 0.00 329.03 4,270.40 4,175.90 64.76 - 2,422.38 2,633,630.48 320,966.62 0.00 2,396.83 5,269.10 0.00 329.03 4,339.50 4,245.00 64.76 - 2,422.39 2,633,630.49 320,966.62 0.00 2,396.83 Beluga F 5,300.00 0.00 329.03 4,370.40 4,275.90 64.77 - 2,422.39 2,633,630.49 320,966.62 0.00 2,396.83 5,400.00 0.00 329.03 4,470.40 4,375.90 64.77 - 2,422.39 2,633,630.49 320,966.61 0.00 2,396.84 5,500.00 0.00 329.03 4,570.40 4,475.90 64.78 - 2,422.39 2,633,630.50 320,966.61 0.00 2,396.84 5,600.00 0.00 329.03 4,670.40 4,575.90 64.78 - 2,422.40 2,633,630.51 320,966.61 0.00 2,396.85 5,700.00 0.00 329.03 4,770.40 4,675.90 64.79 - 2,422.40 2,633,630.51 320,966.60 0.00 2,396.85 5,734.10 0.00 329.03 4,804.50 4,710.00 64.79 - 2,422.40 2,633,630.51 320,966.60 0.00 2,396.85 Beluga G 5,800.00 0.00 329.03 4,870.40 4,775.90 64.80 - 2,422.41 2,633,630.52 320,966.60 0.00 2,396.86 5,900.00 0.00 329.03 4,970.40 4,875.90 64.80 - 2,422.41 2,633,630.52 320,966.60 0.00 2,396.86 6,000.00 0.00 329.03 5,070.40 4,975.90 64.81 - 2,422.41 2,633,630.53 320,966.59 0.00 2,396.87 3/9/2009 3:26:33PM Page 4 COMPASS 2003.16 Build 42F ORIGINAL 0 • ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan: BRU 232 - 23 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: 232 -23 (16.5 +78) © 94.50ft Project: Beluga River MD Reference: Plan: 232 -23 (16.5 +78) © 94.50ft Site: Beluga River North Reference: True Well: Plan: BRU 232 -23 Survey Calculation Method: Minimum Curvature Welibore: Plan: BRU 232 -23 Design: BRU 232- 23wp06 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/ -W Northing Fasting DLS Vert Section (ft} (°) (°) (ft) ft (ft) (ft) (ft) (ft) 5,050.00 6,074.10 0.00 329.03 5,144.50 5,050.00 64.81 - 2,422.42 2,633,630.54 320,966.59 0.00 2,396.87 Beluga H 6,100.00 0.00 329.03 5,170.40 5,075.90 64.82 - 2,422.42 2,633,630.54 320,966.59 0.00 2,396.87 6,200.00 0.00 329.03 5,270.40 5,175.90 64.82 - 2,422.42 2,633,630.54 320,966.59 0.00 2,396.87 6,300.00 0.00 329.03 5,370.40 5,275.90 64.83 - 2,422.42 2,633,630.55 320,966.58 0.00 2,396.88 6,400.00 0.00 329.03 5,470.40 5,375.90 64.83 - 2,422.43 2,633,630.56 320,966.58 0.00 2,396.88 6,500.00 0.00 329.03 5,570.40 5,475.90 64.84 - 2,422.43 2,633,630.56 320,966.58 0.00 2,396.89 6,600.00 0.00 329.03 5,670.40 5,575.90 64.85 - 2,422.44 2,633,630.57 320,966.57 0.00 2,396.89 6,700.00 0.00 329.03 5,770.40 5,675.90 64.85 - 2,422.44 2,633,630.57 320,966.57 0.00 2,396.90 6,764.10 0.00 329.03 5,834.50 5,740.00 64.86 - 2,422.44 2,633,630.58 320,966.57 0.00 2,396.90 Beluga 1 6,800.00 0.00 329.03 5,870.40 5,775.90 64.86 - 2,422.44 2,633,630.58 320,966.56 0.00 2,396.90 6,900.00 0.00 329.03 5,970.40 5,875.90 64.86 - 2,422.45 2,633,630.59 320,966.56 0.00 2,396.91 7,000.00 0.00 329.03 6,070.40 5,975.90 64.87 - 2,422.45 2,633,630.59 320,966.56 0.00 2,396.91 7,100.00 0.00 329.03 6,170.40 6,075.90 64.88 - 2,422.45 2,633,630.60 320,966.55 0.00 2,396.92 7,200.00 0.00 329.03 6,270.40 6,175.90 64.88 - 2,422.46 2,633,630.60 320,966.55 0.00 2,396.92 7,294.10 0.00 329.03 6,364.50 6,270.00 64.89 - 2,422.46 2,633,630.61 320,966.55 0.00 2,396.93 Beluga 1 - Base 7,300.00 0.00 329.03 6,370.40 6,275.90 64.89 - 2,422.46 2,633,630.61 320,966.55 0.00 2,396.93 7,374.10 0.00 329.03 6,444.50 6,350.00 64.89 - 2,422.46 2,633,630.62 320,966.54 0.00 2,396.93 Start 220.00 hold at 7374.10 MD - BRU 232 23wp05 Base Beluga 7,400.00 0.00 329.03 6,470.40 6,375.90 64.90 - 2,422.46 2,633,630.62 320,966.54 0.00 2,396.93 7,500.00 0.00 329.03 6,570.40 6,475.90 64.90 - 2,422.47 2,633,630.62 320,966.54 0.00 2,396.94 • 7,594.10 0.00 329.03 6,664.50, 6,570.00 64.91 - 2,422.47 2,633,630.63 320,966.54 0.00 2,396.94 TD at 7594.10 Targets Target Name - hlttmiss target Dip Angle Dip Dir. TVD +NI-S +EI-W Northing Fasting .Shape C) C) (ft) (ft) (ft) (ft) (ft) BRU 232- 23wp05 Base Beluga 0.00 0.00 6,444.50 64.89 - 2,422.46 2,633,630.62 320,966.54 - plan hits target - Point Casing Points Measured Vertical Casing Hole Depth Depth Demeter Diameter (ft) (ft) Name ( ") ( ") 3,790.84 2,974.50 9 -5/8" x 12 -1/4" 9 -5/8 12 -1/4 7,594.10 6,664.50 7" x 8 -3/4" 7 8 -3/4 3/9/2009 3 :26 :33PM Page 5 COMPASS 2003.16 Build 42F . • ConocoPhillips HALL1BURTON Standard Proposal Report Database: EDM v16 Prod Local Co- ordinate Reference: Well Plan: BRU 232 -23 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: 232 -23 (16.5 +78) @ 94.50ft Project: Beluga River MD Reference: Plan: 232 -23 (16.5 +78) @ 94.50ft Site: Beluga River North Reference: - True Well: Plan: BRU 232 -23 Survey Calculation Method: Minimum Curvature Wellbore: Plan: BRU 232 -23 Design: BRU 232- 23wp06 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft} ft Name Lithology ( °) (°) 5,734.10 4,804.50 Beluga G 0.00 4,316.71 3,414.50 Sterling B 0.00 6,764.10 5,834.50 Beluga I 0.00 5,269.10 4,339.50 Beluga F 0.00 6,074.10 5,144.50 Beluga H 0.00 4,913.32 3,984.50 Beluga E 0.00 7,294.10 6,364.50 Beluga I -Base 0.00 4,112.35 3,234.50 Sterling A 0.00 4,647.72 3,724.50 Beluga D 0.00 4,479.49 3,564.50 Sterling C 0.00 F Pian Annotations Measured Vertical Local Coordinates Depth Depth +N /-S +E/ -W (ft) (ft) (ft) (ft) Comment 400.72 400.72 0.00 0.00 Start Build 1.75 700.72 700.30 0.37 -13.73 Start Build 3.00 1,200.72 1,186.58 3.30 - 123.72 Start Build 3.50 2,107.86 1,909.97 17.40 - 651.52 Start 1297.60 hold at 2107.86 MD 3,405.46 2,708.85 44.70 - 1,673.68 Start DLS 2.94 TFO 180.00 5,173.99 4,244.39 64.76 - 2,422.38 Start 2200.11 hold at 5173.99 MD 7,374.10 6,444.50 64.89 - 2,422.46 Start 220.00 hold at 7374.10 MD 7,594.10 6,664.50 64.91 - 2,422.47 TD at 7594.10 3/9/2009 3 :26 :33PM Pag COMPASS 2003.16 Build 42F ootWA I Y 'k 1 : wT ,, a 4 ConocoPhillips (Alaska) Inc. -Expl , ` Beluga River _> , Beluga River - Plan: BRU 232 -23 Plan: BRU 232 -23 E BRU 232- 23wp06 40 „/ Sperry Drilling Services -6 n Clearance Summary Anticollision Report 30 April, 2009 g Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) , ' I Reference Design: Beluga River - Plan: BRU 232 -23 - Plan: BRU 232 -23 - BRU 232- 23wp06 • Well Coordinates: 2,633,289.00 N, 1,463,415.00 E (61° 12' 13.91” N, 151° 00' 13.17" W) 5 Datum Height: Plan: 232 -23 (16.5 +78) @ 94.50ft g Scan Range: 0.00 to 7,600.00 ft. Measured Depth. g Scan Radius is 957.76 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Ai Geodetic Scale Factor Applied 0 1 Version: 2003.16 Build: 42F 3 i7 Scan Type: GLOBAL FILTER All wellpaths within 200'+ 100/1000 of reference ; a Scan Type: WM HALLIBURTC3N Sperry °rHMl s Berviksss I GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference BRU 232- 23wpO6 Ellipsoid Color 16.50 To 7600.00 17 " ' °' "' 251 1751 2001 5001 6001 14001 16001 251 501 2001 2501 6001 7001 16001 18001 501 751 2501 3001 7001 8001 18001 20001 751 1001 3001 3501 8001 9001 20001 25001 0/360 1001 1251 3501 4001 9001 10001 1251 1501 4001 4501 10001 12001 30/330 30 1501 `" 1751 4501 5001 12001 14001 20* • 0 / 360 50 CD -60 / 300 60 -30 / 330 30 Al . - " - ' BRU 212 -24 G +'^) 60 / 300 60 -90 / 270 90 Y Ali -90 / 270 90 -120 / 240 120 -120 / 240 120 200 -150 /210 150 - 150/210 150 50 - 180 / 180 - 180 / 180 Travelling Cylinder Azimuth (TFO +AZI) [1 vs Centre to Centre Separation [100 ft/in] Travelling Cylinder Azimuth (TFO+AZI) [ vs Centre to Centre Separation [25 ft/in] ConocoPhillips (Alaska) Inc. -Expl HALLIBURTON Beluga River Anticollision Report for Plan: BRU 232 -23 - BRU 232- 23wp06 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Beluga River - Plan: BRU 232 -23 - Plan: BRU 232 -23 - BRU 232- 23wp06 Scan Range: 0.00 to 7,600.00 ft. Measured Depth. Scan Radius is 957.76 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft • Beluga River BRU 212 -24 - BRU 212 -24 - BRU 212 -24 671.13 99.84 671.13 88.78 675.00 9.027 Centre Distance Pass - Major Risk -I BRU 212 -24 - BRU 212 -24 - BRU 212 -24 770.04 100.43 770.04 87.79 775.00 7.945 Clearance Factor Pass - Major Risk , (5 Survey tool program From To Survey /Plan Survey Tool ...04- (ft) (ft) .�. 16.50 7,594.10 BRU 232- 23wp06 MWD +SCC +SAG Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 30 April, 2009 - 16.•07 Page 2 of 4 COMPASS p Project: Beluga River BRU 232- 23wp06 Conoco P hilii S Site: Beluga River Well: Plan: BRU 232 -23 Wellbore: BRU 232 23wp06 -23 Quarter Mile View 1500 i 1000 I 1 c_ 17 500 06 cp 0 - I BRU 212 -241 ' 0 0 i I Z j c i c o n - 500 -1000 1 i -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 West( -) /East( +) (500 ft/in) Operator: Cacc9Pl6>0E(AtY9)hc. -Expel GridCareetn: -OAS .tbNa 9N /A Reid Beluga River 11409n.1tO.a ltn: 1609 ° AR Na 6N /A Wet 11RU212- 250006 DC 7420 • ArINa 6N /A RID yN /A D4000w 100 It System DVD)ReYlelee Mem Sea level Sabo lxattn Original VS Plane: 280.00 Pawl yel Pw1:BRU212d1 X 146341500 ft View VS Plane: 280.00 • Rl(B mot. 04.50 It Y : 263329900 It **System. APIBaeO /WS Seatlm (VS) ReleereR Ste Comments: POOL: P In View & & & R BRU 232- 23wp06 Plan: 3630' to 6270' TVDss 1 2635000 BRU 212 -24: 3630' to 6270' TVDss s 2634000 • 73 21Y -24 2633000 �..... Section View' — BRU 232- 23wp06 Plan —8— BRU 212 -24 �_. r -- - : 2632000 •2631000 L • a East ( +) / West ( -) O 3000 1 I k\b‘..\‘‘'''........‘..%..1*........\\ ' I I - 4000 V. N .1000 21 7003 Vertical Section along' View VS Plane' Combo Preview Page 1 of 1 (BRU 232-23%06 Todboxids) 3/9/2009 3:09 PM Closest in POOL Ilk Closest Approach: Reference Well: BRU 232- 23wp06 Plan Offset Well: BRU 212 -24 Coords. - words. - ASP ASP 3 -D ctr -ctr - ... Meas. Incl. TRUE Subsea N( +)/S( -) View VS Meas. Incl. TRUE Subsea N( + )/S( -) View VS ..a -.,� Distance. ._ ' = Depth Angle Azi. TVD E( +)/W(- (280) comments Depth Angle Azi. TVD E( +) /W(- (280) :omments .,, POOL Mn Uwtance (L3b1.04 Distance (2351.04 ft) In POOL (3630 - # ft) in POOL (3630 - 6270 TVDss) to 6270 TVDss) to BRU 232- 23wp06 BRU 212 -24 (3630 - Plan ( 3630 - 6270 2351 • . 4647.72 15.47 271.54 3630.03 2633388 1461065 2326.914 6270 TVDs0 3727 0 0 3629 2633391 1463416 0 TVDss) PcolSummaryl 3/9/2009 3:13 PM • BRU232-23 Surface Location - - - _ - - - LPA1 Coordinate Converter J _10j " Datunx 1NAD Region ralaska J Datum INAD j Region: 1.w C Latitude/Lonaltude 'Decimal Degrees j r Lattude/Lorgitude !Decimal Degrees C UTM Zone: 1 r South r UTM Zone: T r South State Plane Zone: [J Links: us17:3 C State Plane Zone: True j Units uF C 67 Legal Description (NAD27 only) Starting Coordinates: Legal Description X. 11463415 Township: 1013 Range: fiFF 1 Y: 12633289 Meriden: 11 Section:124 IFNL ml 12102.0014 0! j 51.413446 / Transform 1 Quit 1 He 1 BRU 232 Top of Productive Zone CPA! Coordinate Converter • 25-1 Fran: Tnt Datum: FIAD83 Region: lalaska J Datum 11:4AD27 Region: lalaska C Latitude/Longitude 'Decimal Degrees zi r Latitude/Longitude [Decimal Degrees C UTM Zone: r South C UTM Zone: 1True r South ( State Plane Zone: 14 Units: us.fri r State Plane Zane: 1 4 zi Urat lus4t r Decripton ft only t Legal Desaiption 4AD27 only) Starting Coordinates. Legal Description X: 11461275.95277458 Township: Ran 1010 FE Y: 1 2633376%22253 Madam Is Section:123 1FNL zi• 12045.0029 1FEL 2:1 12%8.8958 Transform 11 Quk 1 Help I BRU 232 Total Depth CPA! Coordinate Converter From: er: Datum. 1NAD83 j Regal lalaska J Datum 1NAD j Regier lalaska C Latitude/Longitude 'Decimal Degrees 11 Latitude/Longitude 1Decinal Degrees J UTM Zone: r --- r South r UTM Zone: r South a State Plane Zone: Units: us4nt C' State Plane Zone True j Units. ur7f7E 6' Legal Description (NAD27 only) Stating Coordinates: Legal Description X: 11460993.99 Township: roT3 Range: FIE- FE Y: 12633391.01 Meridian: is' j Section:fr3 fit'] 12037.3362 hilt 12371.0280 Transfam Quit I Hee) I ORIGINAL • REV DATE BY CK I APP DESCRIPTION REV DATE BY CK APP DESCRIPTION T13N 15 /14 \ 13/ NOTES / ) THIS 1 . COORDINATES SHOWN ARE NAD 83 ALASKA I SURVEY STATE PLANE, ZONE 4 IN SURVEY FEET. 22 21 2. VERTICAL BENCHMARK IS WELL 221 -23 rc REFERENCE ASBUILT DATE, 1976. W 24 c 3 o .-I ON 3. SURVEY CONTROL POINTS 18 AND 19 ARE 0 5/8' REBAR SET FLUSH 111111 G SURVEY 27 25 CONTROL POINT 20 IS SET 6' SPIKE FLUSH WITH GRAVEL PAD. cReF, 4. ELEVATION AT TOP OF CONDUCTOR = 88.90' TS3 MOW OS o EP 0 LEGEND ) SEC. s+ BELUGA 35 040 RUNWAY / �� •ts SURVEY CONTROL `�, • DOSING WELL 34 O p `� u BOLLARD T13N G POWER ME T12N —OH U— OVERHEAD UTILITY SCALE: 1 "=1OO' VICINITY MAP - 1" = I MILE N 90'00'00" E 400.00' --- 0 o TANKDEHYDRATOR � , 77- -`` — 77-'' .- t/ VAI—I BU DING j�' BRU 212 -24 0 3 ., J • 20 of • s t CCVV 1. 0 150 <sr� w Z ,r) / BRU . '\ HEATER 232 -23 ° T BUILDING 78^. DGE OF ° --- 19 • • EXISTING o o OHU % ''f GRAVEL PAD o GENERATOR S 90'00'00" W ¶ N BUILDING 111.00 � 289.00' BRU 232 -23 N 0'00'00" W47.00' S 90'00'00" W DGE OF PROPOSED LOCATED WITHIN PROTRACTED SEC. 24, -,� ` O F ` 4 1, , GRAVEL PAD T. 13 N., R. 10 W., SEWARD MERIDIAN. = p .. • S r i 2102' F.N.L, 51' F.W.L c ' � � y / ',ii LAT. = 6192'13.9059' N /\ L = 15100'131737' W : * . 4 9 T" • i Y = 2,633,289' i i X = 1,463,415' i �n '. Kenneth W. �� ‘: Ayers: LS - 8535 .. SURVEYOR'S CERTIFICATE / i , `f• � ; • . • Jam I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO i rr .p F 4 p • • • . - - .. • • • • � - PRACTICE LAND SURVEYING IN THE STATE CF ALASKA AND THAT NS r r r �'P ESSI ONp REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION LOUNSBURY AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF & ASSOCIATES. INC. JANUARY 26, 2009. SURVEYORS ONCINEIRS PLANNERS 1. 4% 00?) m -swi ARE MODULE: UNIT: Conoc P hilli S BRU 232 -23 WELL CONDUCTOR AS BUILT WITH p PAD CONFIGURATION INCLUDING CONTOURS Alaska, Inc. CADD FILE NO. DRAWING NO: PART: REV: BRU2I2- 24ASBUILT.dwq BRU2I2- 24ASBUILT.dwg I OF I O n D I r ! N! A ! • 0 I I ADLO588 4 41C-j:i 10 11 ' ADL391271 • 11ADL058815 ADL391352 J _' * 8R0012 dd 1 13 , aRtJSrtvo t 18 300062 — 3000'radius ADL058820 eaur�� - +s .� : 1 ■ DLO58831 : ' 32 -23 BRU ` 2- ADL39O572 B H! ' 6 %t./ Surff. . F- 33 wn 34' 20 ADLO. 128 j d ADL02112E ! // ADL02i 127 �e IADLO1 • 8 • L3RU _ 28 J as -017658 4 .J 30 29 A L021123" 4' ,'` r % S sitna Flats / 1 Stat Game Refuge 33 36 31 32 ' A 029657 H Frvs�v h ADL017599 ADLO17599 i j I R ERTS. E BELUGA z 1 —I RIVER 02965 UNIT I ADL017592 ADL39O38 l - ADL017592 ADL391122 ConocoPhillips Alaska Inc. Exhibit A BRU 232 -23 1 2 Beluga River Unit — Well Spacing Exception LE ILES 2 27 09 08052001E01 ORIGINAL i II 0 K411. I VALVE LEGEND • t o e I a a I 1 BYPASS - 1 .E©T. ©�0• ©�Q7O� 2 KILL I I i _� U I I I 3 CHOKE - t' -- 'T 4 BOTTOM RAMS le II', 5000 PSI. HYORIL ANNULAR BOP 5 BLIND RAMS STUDDED TOP/FLANGED BOTTOM I P 6 TOP PIPE RAMS R s ACCUMULATOR; OILCO, 6 STATION 7 ANNULAR TRIPLEX PUMP: 2/575 VAC, 25 HP -- - - - - -- FLANGE BOTTOM /FLANGE TOP B% 160 NR PUMP; 2/40:1, 8GPM, 3,000 PSI Fl LAID RESERVOIR: 450 GALLON , : 411 II W - 11', SO P51 SHAFFER L %T DOUBLE PIPE RAM • O O O �........ STUWF�O BOM/FI.ANGE TOP 88 160 ®® 1111 ■... 3 I/8 5000 OTT PSI HER VALVE 3' CHOKE UNE .11° d'I■ . AIII ''111 II► 411110.111. - 2' KILL LINE : I I 1 I I I : I I .y , W PSI VKVf OPEN CLOSE 3 I/8' •: e1:r :- 3 SO 1/8 5000 HCR PSI GATE VALVE a 3 1/8' 5000 PSI GATE VALVE C S O O O O O O -4I . 11' ILA . 5000 0 P D TOP P% LXT PIPE RAM C - - - ,'.� . �� •� . ;mwc.a.t , 5(1(1(1 PSI IUFFER W �� MIR STUDDED BOTTOM / FLANGE TOP B% 160 - ppEN — CLT5E' '°+r 80P STACK O .... ADAPTER SPOOL O O WELLHEAD T O O a. .... FLANGE /FLANGE KII1. 1 1.. -1{--..a --'!F ..il- 4 .. �- � n 'TF ,1 I T 0 0 i - PDSIT - & - 14605 - :, 0 . I ... F ,... qo. - f ACCUMULATOR MANIFOLD 0 0 0 1 � 12 BOT TLES, 15 GALLONS EACH TO OPERATE P0611 "" ,' i -- e 0 0 f BOP STACK ELEVATION - REMOTE PANEL IN DOGHOUSF AND UTILITY MODULE ill --- . .1)1. boil i lC `It' if if V lF wr" OPERATED KNIFE TE VALVE AOTTES r 1 /�' 2000 P5. 6 BOTTLES BCKUP , 337 C FT. L MOP HYORIL 80P /OVERTER STUDDED TOP/FLANGED BOTTOM -- 13' FLU'S VENT UNE I Rra 8 iN X &T I�1111101OEDI IOMC F ONILOt I Mvyon PROJECT ARCTIC FOX RIG 1 SURFACE DIVFRTER CONFIGURATION VILE BOP SYSTEM AND CONTROL 11 -28 -98 I .1111 LEA MN MN TO 11900* 8/02/07 'a4RPR00 %PFAOTm m LEA 9[v. 1 in . - OTTE 2. V. '7 O[9TO1101 SflL[ NTS ML NTH I orG IR 9rt. 1 ( ayafl DIVERTER BOP STACK ARCTIC FOX c ) 5 :),,,,: z • To Open ' ft? ? t')� i Accumulator U 1 1" 5K Shaffer Annular From I Close 21-1/4" Hydril Annular Accumulator "' ,. "' ` Close - / 11" 5K Shaffer Double Gate t u•ui ui of uiom Upper Pipe Rams �+'+' - °A Blind Rams ��'�� III 0 �. Q III I �» Open 4P ,...�., ,.� ,.� �....: • J � 1 � / t� _ _ le- lap �IIIIo; oIIR ANIMINorr 1 1" 5K Drilling Spool 1.111111111110111 1 w/ 2ea. 3 -1/8" outlets C ��yy ■■ V r • 7 11 1 O )I1 '��}%' i ' • �Ir l 0 I[O ,� 12" Diverter Line CD lea. 3 -1/8" 5K Manual & Hydraulic Valve — Programed to open when Annual or � '■• "L�'.� Rams are closed 3 [IIII ° ti ci 12" Hydraulic Knife Valve lea. 3" 5K Choke Hose `sJ Q iIIili �'' ".�. • L,J lea. 3 -1/8" 5K Manual, lea. 3 -1/8" Hydraulic Valves, 11" 5K Shaffer Single Gate T . lea. 3 -1/8" Check Valve Le Lower Pipe Rams '• lea. 2" Kill Line - ..:-a, ■ ~ ts,„ I II ii ...., (-. DIVERTER LINE RUN 100'+ b_ BYOND SUBSTRUCTURE. __: -- ma=r= - , i DIVERTER LINE - 8 @ 21' EA. - - _ - - `� _ • __-- _ "_ - " " h TOTAL DIVERTER LINE 168' i'''-..,„'- ic? 21' -0" I 21' -0" I 21'-0" I-10" 0" l ■ .,. e...a u.., .. I _ I I 1 V OYON � P !1 I I 1"." (.1 (.1 A AKITA DRILLING LTD. Z302 Rh Slre"1. Nlsk "N5"n� inliMININ J '9E ]ZT Tel (]d01955£] cy • 1 T • I __ 1 1 JJ.. 11 k property of Doyon AKITA JV. Any ^.� —. ".._ — - - - - -- - t t nrohibited e Am •• _ •• I j.„,_ tT..� m _ _ m AKITA JV la or r prohibited. written consent of Doyon is t _! 1 3'-0 ' y + ' .1. ± 4 �'' � ` 4/22/09 s } w -. .......... x D zomdmener Arctic Fox - Beluga 21i" 2000 psi Diverter Assembly General Layout i LEDGEND Wily le)." A KI TA JV , .. lc White Handle Valves .� Normally Open B , /� . Red Handle Valves 4 ► / Normally Closed E TO F s ` /` � • r ,,. ,� F R4M 0 p P STA CD -10 __� G) Ty, f` �.� 6 I .F 1 . 3' �� , 'mil TO PATS . a� m.: GSPNERIG • TM MATERIAL LIST DEGAS Item Description A ' 3- 1/16" 10M Remote Operated Choke B 3 -1/8" 5M Adjustable Choke t i ►. , ismo 1 2- 1/16" 5M Manual Gate Valve 2 -14 3-1/8" 5M Manual Gate Valve ARC= FOX e .N...WS 9 PMN lI&oJd atx8ae M ` ." 7 s« ru. ....PS .4 IOO fl ` _ 0 V SIN 6WLJE r' aro n ' p..4oad .1 "AS ViIMV . y i uoSOa to mos.. uo... ^ ,, .ct c di aswd80.....e+ Led �o 1 f: -t. ' 1 i� • ^d apy.r NI uoy po∎d Ruy T —iiii Ar v1 ,, uoI0 p to /NadaM ex s ds+=,,ee otos Nu e 6u 64p 8 141 • ul peuleIu0a uolleu 10JUI ayl ,€ _ T i : , vae ' '1 1,. , = t 880./v ^sW ....Nli Mall, I ! #& - i `J N11h11:10 ny a , al 1 .Y — "1 fl vpxe M C dH /Me arerre 7,— .1;,::;* a X . .. t . 9 .� it (al 'gym u ry . ettttttttt_ E Y rn C N ' 1 • E a a.a 1 !'' : Jj/ f T3nota k ■ i WWII. '413.V liiir 44...9 OW =.wavev3),wa>waw i 401346 m i UNDERFLOW FROM TO WEIR BOX 1001 Barrels NET SHAKERS TOTAL TANK CAPACITY = TO FLOW NIPPLE MUD GUN 1145 Barrels GROSS v 233 Barrels NET 132 Barrels NET 6" 128 Barrels NET 6 "2 Q LAYERS 6"Q 6 „Q . LOW PRESSURE SYS. !3 " 3" 3 ” O1Mr. (_ ry SUCTION TANK OUTLINE ® 52 barrels (8.2)m NET ■ TROUGH DIE" DIE" k (� 75 HP ■j. ; ;3" $4" 3" ;3 ;3" IIegass> OVER -FLOW > TO 10 CONE (--) MUD CLEANER N MIX HOPPER N.r'• s.,:.. e... 111•• ■" <. EN ,....„-------A1, ow.— R" 4. I 6., 6" 0 0 104SO4.1 Ilv., t 3 "3 !3" .( 6" QD 0 � wla l"t 5.� 6" er 6 "� 6 "I 6" C,,, • i 6 x 5 x 14 ` ... � w 60 HP ' NE The information contained In 7.5 HP this drawing is the sole 7 HP 7.5 HP property of AKITAJV. pe y o yon „Q f - 7 6 x 5 x 14 Any reproduction In whole 6 o r part without the express written cosent of Doyon 6. 6 6 „ 6 "Q w160 HP AKITA JVn Is prohibited. 6 ( QA 8,„ g 8 "Q 8",--, g "� , / �4 �nlos urs `. r DDI F Mud Schematic • I 172 Barrels NET 214 Barrels NET 70 Barrels NET MIX HOPPER ••• Beluga Project V V TO MUD PUMPS � • Mud Tank - slmpnnad Schematic LAYERS . LOW PRESSURE SYS. SUCTION SuMI> • TANK OUTLINE TROUGH IP� v v u II k %.". a:a.. o.u si s . k � OYON a ® 7 .5 zr HP 7.5 sHP DRILLING E i AKITA MILLING LTD. '�.' zoz 3" 3" 3" roe z n Tet pool essaneo 7.5 HP I The Information contained In C GALAGHER r\ GALAGHER this drawing In the sofa PUMP t PUMP property of Doyon AKITA JV. Any reproduction In whole or part without the express written consent of Doyon oyon • AKITA JV. Is prohibited. 3" GI' _. ____. A. 1 6) 3" 3 "� 3^ 3/7/09 ns r rev • re.. DIN 4F Mud Schematk Y. Beluga Project Rock Washer Schematic \ l ... — N 144 M3 92m) AMOR II TWO TANK MUD SYSTEM THREE SHAKERS, TWO MIX PUMPS, TWO MIX HOPPERS DETROIT 60 SERIES ,..,-............ 180 gal 6 STATION -\, I I , I I FOUR AGITATORS, DEGASSER, 400 kW 600 V GENS ACCUMULATOR I I 10 CONE MUD CLEANER A, ill= I NOW 11111•111111 MINIMS. J/INNIA 4•111111111. .1■1111111. 7 I--- 7 . ' 111011911 =VA 1111111._ : • -- i 1 __ " i : 0 FUEL TANK WATER TANK , 1 7'-- 6500 gal. ".2 490 BBLS * I ;4+ / , IF ' I "" : I J : t" * ..". ii ' ." ".. I , 7.1 , LO l 0,4'4001 'Owl ' , Ir k :1 ' ril 7111 ' 1 ANI . r oT I • : 1 i FUEL & WATER I I .,....• i -----1 gI, 1 f„Ii 4 ,t,' 1 ' I . ' - 1 , I , r , ......_ - II ,1 WM ' al „„." 7....--; PUMP ROOM t..'..' iii: r. I I I- II is [:I; I ' zit I . a .-. k _ ',Ir. ,."' i b - , ---,..2.-- - .;rf —;;,....ii#,- ,,,,-. I .... , , i ' 4 41, 4' , 11 ■ a , t I e n , , . . , k . .,,,,.....-- HOT WELL TANK DOGHOUSE or/ SLIDE , L. ° * L' --- ,. :. ,i,' m''''•"'''' '. 6 Barrels , .r OM ' ' lial • - ' allE 1 I' OUT - 1 I I - T LUNCH ROOM AND I t-silk,III I.. --- ' I " ' , iiilliff IMAMS , TONG ROOM ON END ' 4 ,,, , , :. , „ 'num", . ilmiwr , .. 111111 . I P _. [ , C3 0. 3 asi L I ,•■••••1 , .. / TWO 100 HP BOILERS lit .1 ....• WORK BENCH, AIR COMPRESSORS BOP HANDLING TROLLEY --///.......... /MEI 11.177 ' IIMI CREW CHANGE ROOM DRILLING 1 4g 4 I _om , 1" THREE GARDNER DENVER PZ-8 .0 i DRILLING LTD, ,- MUD PUMPS POWERED e'S II , ..., RIGMASTER P-750 en I ;;; ONE PIECE SUB wi BY 3412 E CAT MOTORS, b -- TELESCOPIC DOUBLE N NOV CASING TEST PUMP G MAST AND TSM-700011 • co DRAW WORKS The Informabon contented in I PROPOSED CENTRIFUGE HOUSE this drawing is the Joint ON TOP OF CUTTINGS PROCESSOR p rp r r t y 4 o f f i zo n n A n if w h i T A . .1J . or part without the °serene CUTTINGS PROCESSOR written consent of Mayon AKITA JV is prohibited. 11117 e.... BMW NTS —' CATWALK WITH TWO , 1 — E ..- 1 , SHEDS AND ONE '''' 001 AF GA i !MIME III' ENCLOSED PIPE TUB .... _ Beluga Ness, "ftIMmtlfill•1111.111 ........... ■ 1111111111111• General Arrangement Ns / AIR HEATER \*,.... NMI • • TRANSMITTAL LETTER CHECKLIST r i WELL NAME JO/.: 2-5 L - PTD# C , 9 L ' / Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD. - 7(3'( i c . <., -�� POOL: F 4� i`�� <'(j �c��_ �7a < e s--- 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(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to f ; , pliance with 20 AAC EXCEPTION 25.055. Approval to perforate an .roduc; / in'ect is contingent upon issuanc 7 of a consetion. = approving a spacing exception. t ' $ assumes the liability of any protest to the spacing xception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 Field & Pool BELUGA RIVER, UNDEFINED GAS - 92500 >�,�,,, �ER�1T ���' Well Name: BELUGA RIV UNIT 232 -23 Program DEV Well bore sag [] PTD#: 2090570 Con_a_ CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / PEND GeoArea 820 Unit 50220 On /Off Shore On Annular Disposal [] Administration 1 Permit fee_attached NA 2 _Lease number appropriate Yes 3 _Unique well name and number Yes 4 Well Jocated in a defined pool No BELUGA RIVER, UNDEFINED GAS- 92500 5 Well Jocated proper distance from drilling unit_boundary Yes Conforms with20 AAC 25.055 _(a)(2) 6 Well _located proper distance from other wells No SPACING EXCEPTION REQUIRED; less than 3000' from offset wells 7 Sutflcient acreage available indrillingunit No SPACING EXCEPTION REQUIRED; will be third gas producerin SectIon_23 8 if deviated, Is wellbore plat included Yes Public hearing notice published 4/18 /2009 and vacated 5/7/2009._ Orderin progress._ SFAS/21 /2009 9 _Operator only affected party Yes 10 _operator has appropriate bond in_force Yes 11 Permit can be issued without conservation order No Appr Date 12 Permitcan be issued without adrninistrativeapprovel Yes SFD 5/21/2009 13 Can permit be approved before 15- day_walt Yes 14 .Well located within.area and strata authorized.by Injection Order # (put IO# In_comments) £For sere NA 15 All wells within 1/4 mile area of review identified_(For service well only) NA 16 Pre- produced_injector:. duration of preproduction less than 3months (For. service wellonly). NA 17 .Nonconven._gas conforms. to AS31,05,030(l.1_.A),(j.2A -D). NA 18 Conductor string provided Yes Driven to 106'. Engineering 19 Surface casing protecte all known USDW$ Yes Set at 3791'. 20 CMT_vol adequate to circulate on conductor_& surf csg Yes 70% excess. 21 CMT_vol_adequate toile-in. long string to surf oeg Yes 22 CMT_will over ell known productive horizons Yes 23 Casing designs_adequate for C. T, B_& permafrost Yes Std csg. design. 24 Adequate tankage or.reserve pit Yes Arotic Fox rig. 25 if a_re- drill, has s 10 - 403 for_abandonment been approved NA New well. 26 Adequate welibore separation_proposed Yes 27 itdlverter requlred,_does.itroeet regulations Yes 12' vent line variance, Appr Date 28 _ DriUingftuld _program_sohematic&equlpJist _adequate Yes MaxMW 10.4 ppg. WGA 5/21/2009 29 _BOPEs,_do they meat regulation Yes Three_ ram stack. III"` 30 _BOPE.press rating_appropriate,_ test to_(put psig in comments) Yes MASP 2148 psi,_test BOPE to_5000 psi . 31 _Chokemanifoldcomplies w /API RP -53 (May 84) Yes 32 Work will occurwithout operation shutdown Yes 33 Js presence of 17.12$ gas probable No 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be Issued w/o hydrogen sulfide measures Yes Production interval will be mudiogged, Sensors will be employed Geology 36 Datapresented on potential overpressure zones Yes Offset drilling data indicate 10.0 ppg gradient; will be drilled using 10.4 ppg mud, Appr Date 37 Seismic analysis of shallow gas zones NA Offset well BRU 212 -24 was.drilled nearby, and three_other wells have been drilled within_1_ mile, SFD 5/21/2009 38 Seabed oondition.survey (if off - shore) NA 39 Contest namelphone_for_w.eekly_progress reports.1exploratory only] NA Geologic Date: Engineering Date Public Date Comsioner: Commissioner: Commissioner k5 ri91 5A2A i r • • Well 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 simplrfy 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. • . bru 232- 23.tapx Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Sep 18 14:48:05 2009 Reel Header Service name LISTPE Date 09/09/18 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 09/09/18 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 Beluga MWD /MAD LOGS WELL NAME: BRU 232 -23 API NUMBER: 502832013300 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 18- SEP -09 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: w- 0006503016 W- 0006503016 W- 0006503016 LOGGING ENGINEER: S. LATZ S. LATZ S. LATZ OPERATOR WITNESS: L. HILL D. LUTRICK D. LUTRICK MWD RUN 4 MWD RUN 5 MWD RUN 6 JOB NUMBER: W- 0006503016 w- 0006503016 w- 0006503016 LOGGING ENGINEER: S. LATZ S. LATZ P. WALKER OPERATOR WITNESS: L. HILL L. HILL L. HILL SURFACE LOCATION SECTION: 24 TOWNSHIP: 13N RANGE: 10W FNL: 2102 FSL: FEL: FWL: 51 ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 96.50 GROUND LEVEL: 78.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 20.000 106.0 2ND STRING 8.750 9.625 3741.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD), UNLESS OTHERWISE NOTED. Page 1 bru 232- 23.tapx 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 - COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER - MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR -P4), AND DRILLSTRING DYNAMICS SENSOR (DDSr). MWD RUNS 2 - ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO- DENSITY (ALD), AND PRESSURE WHILE DRILLING (PWD). DENSLIDE DATA ARE ONLY PRESENTED FOR MWD RUN 2, SINCE THESE INTERVALS WERE NOT INCLUDED IN SUBSEQUENT ROTATED MAD PASSES. 4. DATA GAPS OVER 3 CORED INTERVALS ( 6412 'MD /5494'TVD- 6503'MD/5584'TVD; 6839 'MD /5920'rvD -6901' MD /5983'TVD; 6901 'MD /5983'TVD- 6946'MD/6027'TVD) WERE FILLED IN BY ROTATED MAD PASSES - NO SEPARATE MAD PRESENTATION IS INCLUDED. 5. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED TO A HALLIBURTON CASED -HOLE GAMMA RAY LOG RUN IN BRU 232 - ON 9 SEPTEMBER 2009. THESE PDC DATA WERE PROVIDED BY RAPHAEL BARRETO (HES) ON 15 SEPTEMBER 2009, AS AUTHORIZED BY WAYNE CAMPAIGN (CPAI). ALL LOG HEADER AND ANNOTATION DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1 - REPRESENT WELL BRU 232 - WITH API #50 283 - 20133 - 00. THIS WELL REACHED A TOTAL DEPTH OF 7587'MD/6668'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT- DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT- DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED (LOW -COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW -COUNT BIN). SNP2 = SMOOTHED NEAR - DETECTOR -ONLY PHOTOELECTRIC ABSORPTION FACTOR COUNT BIN). DENSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT -TO- SENSOR DISTANCE. PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: FIXED, 8.75" BIT MUD WEIGHT: 9.60 - 9.90 PPG WHOLE MUD CHLORIDES: 49000 - 72000 PPM FORMATION WATER SALINITY 345.0 - PPM CL FLUID DENSITY: 1.0 G /CC MATRIX DENSITY 2.65 G /CC 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 SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. } File Header Page 2 111 1 11 0 bru 232- 23.tapx service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/09/18 Maximum Physical Record 65535 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 RPS 159.0 7533.0 RPM 159.0 7533.0 RPX 159.0 7533.0 RPD 159.0 7533.0 FET 159.0 7533.0 GR 165.0 7523.0 ROP 223.0 7588.0 NCNT 3732.0 7479.0 NPHI 3732.0 7479.0 RHOB 3732.0 7492.5 FCNT 3732.0 7479.0 DRHO 3732.0 7492.5 PEF 3732.0 7492.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 2234.0 2227.5 2248.0 2244.0 2258.0 2253.5 2272.0 2267.0 2403.5 2396.5 2776.5 2767.0 3285.0 3278.5 3312.0 3306.5 3377.0 3370.5 3392.5 3386.0 3453.5 3449.0 3500.5 3495.5 3515.5 3508.5 3596.0 3589.5 3642.5 3637.5 3648.5 3642.0 3697.0 3691.0 3743.0 3742.0 3759.5 3757.5 3770.0 3768.0 3780.0 3778.0 3793.0 3790.5 3797.0 3793.0 3801.0 3797.5 3894.0 3890.5 3930.0 3926.5 3940.5 3938.0 4020.5 4017.0 4024.5 4020.5 4126.0 4123.5 4159.0 4156.0 4160.5 4158.0 4162.5 4159.5 4164.0 4160.5 4179.5 4175.5 4181.5 4178.5 4183.0 4180.0 4198.5 4194.5 4212.0 4208.5 4250.5 4247.5 4291.0 4289.5 4323.5 4322.0 4326.5 4325.0 Page 3 • bru 232- 23.tapx 4330.0 4328.0 4358.0 4356.5 4368.5 4366.5 4435.5 4432.0 4466.0 4462.0 4481.5 4478.5 4490.5 4486.5 4507.0 4502.5 4524.0 4520.5 4537.5 4533.0 4584.0 4580.0 4593.0 4588.5 4607.5 4603.5 4655.5 4651.5 4711.0 4708.5 4713.0 4710.0 4721.0 4718.5 4753.0 4750.0 4760.5 4756.5 4805.5 4801.5 4814.0 4808.0 4822.5 4818.5 4832.0 4828.5 4866.5 4862.5 4912.0 4910.5 4923.5 4921.5 4929.0 4926.5 4931.5 4929.0 4937.5 4935.5 4978.5 4975.5 5002.5 5000.0 5010.5 5008.5 5027.0 5024.5 5046.0 5043.5 5078.5 5075.0 5088.5 5085.5 5114.0 5112.0 5124.5 5122.0 5136.5 5134.5 5185.5 5184.5 5208.5 5206.5 5217.5 5215.5 5226.0 5223.5 5240.5 5238.0 5243.5 5240.0 5264.5 5262.5 5273.0 5271.0 5281.5 5279.5 5301.5 5299.5 5304.0 5302.0 5318.0 5315.5 5322.0 5320.5 5326.0 5323.5 5329.5 5327.5 5331.0 5329.0 5351.0 5349.0 5359.5 5357.5 5386.0 5384.0 5397.5 5396.0 5405.0 5403.5 5408.0 5406.0 5411.5 5410.0 5417.5 5416.0 5427.5 5424.5 5436.0 5434.0 5439.0 5436.5 5464.0 5462.5 5488.0 5485.0 5509.0 5508.0 5520.0 5519.0 5540.0 5539.0 5546.5 5545.0 5552.5 5551.5 5576.5 5575.0 5612.5 5611.0 5640.0 5639.0 5643.5 5642.5 5650.0 5649.5 5653.5 5653.0 Page 4 410 4110 bru 232- 23.tapx 5658.5 5657.5 5660.5 5660.0 5667.5 5666.5 5694.0 5692.5 5708.0 5706.0 5724.5 5723.0 5735.0 5733.0 5746.5 5744.5 5752.5 5751.0 5759.5 5758.0 5764.5 5762.5 5767.5 5766.0 5777.0 5775.0 5792.5 5790.0 5828.5 5826.5 5830.0 5829.0 5855.0 5854.5 5861.5 5860.0 5880.0 5878.5 5925.0 5923.5 5933.5 5932.5 5940.0 5938.5 5951.5 5950.5 6067.0 6065.5 6070.5 6069.0 6121.5 6120.0 6128.0 6126.5 6154.0 6152.5 6167.5 6166.5 6211.0 6210.0 6279.5 6279.0 6295.5 6295.0 6307.0 6306.0 6310.0 6308.5 6311.0 6310.0 6402.5 6402.0 6411.5 6411.5 6438.5 6438.0 6472.0 6471.5 6475.5 6475.0 6498.5 6497.5 6507.5 6506.5 6515.0 6514.5 6536.0 6534.5 6587.5 6587.0 6601.0 6601.0 6607.0 6607.0 6610.0 6610.0 6631.5 6629.0 6686.5 6687.5 6702.5 6704.0 6710.5 6712.0 6790.5 6791.5 6793.0 6794.0 6831.5 6833.0 6835.5 6836.5 6843.5 6845.0 6858.0 6859.5 6866.5 6868.0 6906.0 6906.5 6920.0 6920.0 6936.0 6937.0 6938.0 6939.0 6955.5 6957.0 6964.5 6964.5 6976.0 6977.5 6996.5 6998.5 7001.5 7003.0 7008.5 7010.5 7031.5 7033.5 7050.5 7052.0 7065.5 7066.5 7074.5 7075.5 7078.5 7080.5 7081.0 7081.5 7086.5 7087.0 7105.0 7105.0 7124.5 7125.5 7128.5 7130.5 Page 5 S bru 232- 23.tapx 7133.5 7135.0 7142.0 7143.0 7158.5 7159.0 7167.5 7168.5 7194.0 7196.5 7207.5 7209.5 7209.5 7211.0 7217.0 7217.0 7230.0 7230.5 7235.0 7235.5 7256.0 7257.0 7260.5 7261.5 7269.0 7270.5 7282.5 7283.0 7294.0 7294.5 7303.0 7302.0 7309.5 7309.5 7326.0 7328.0 7345.0 7344.5 7357.5 7356.5 7360.0 7360.0 7375.0 7374.5 7377.5 7376.5 $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 152.5 3755.0 MWD 2 3692.0 4748.0 MWD 3 4640.0 6412.0 MWD 4 6412.0 6615.0 MWD 5 6615.0 6839.0 MWD 6 6839.0 7587.0 $ # 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 1 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 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G /CC 4 1 68 12 4 DRHO MWD G /CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 NPHI MWD PU 4 1 68 52 14 Fi rst Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 159 7588 3873.5 14859 159 7588 FCNT MWD CP30 568.23 2793.81 1008.87 7495 3732 7479 NCNT MWD CP30 132999 235299 170501 7495 3732 7479 RHOB MWD G /CC 0.684 2.873 2.2238 7522 3732 7492.5 DRHO MWD G /CC -2.229 0.354 0.0868167 7522 3732 7492.5 RPD MWD OHMM 1.44 2000 66.4193 14678 159 7533 RPM MWD OHMM 0.1 2000 48.8798 14678 159 7533 RPS MWD OHMM 0.09 2000 43.7203 14678 159 7533 RPx MWD OHMM 0.09 1884.13 24.1745 14678 159 7533 Page 6 1 I 1 1/ 1 bru 232- 23.tapx FET MWD HR 0.18 150.61 5.23763 14678 159 7533 GR MWD API 15.83 107.95 62.6069 14717 165 7523 PEF MWD B/E 0.37 12.25 2.4133 7522 3732 7492.5 ROP MWD FPH 0.09 998.53 154.781 14731 223 7588 NPHI MWD PU 17.08 113.68 45.7935 7495 3732 7479 First Reading For Entire File 159 Last Reading For Entire File 7588 File Trailer Service name STSLIB.001 Service Sub Level Name version Number 1 0 0 Date of Generation 09/09/18 Maximum Physical Record 65535 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 09/09/18 Maximum Physical Record 65535 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 SEDP 152.5 3691.5 SEMP 152.5 3691.5 SFXE 152.5 3691.5 SESP 152.5 3691.5 SEXP 152.5 3691.5 SGRC 158.5 3697.5 SROP 216.5 3755.0 LOG HEADER DATA DATE LOGGED: 03- AUG -09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 3755.0 TOP LOG INTERVAL (FT): 156.0 BOTTOM LOG INTERVAL (FT): 3755.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 52.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 076571 EWR4 ELECTROMAG. RESIS. 4 77613 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): .0 BOREHOLE CONDITIONS MUD TYPE: Native /Spud Mud MUD DENSITY (LB /G): 9.20 Page 7 III/ 1 10 bru 232- 23.tapx MUD VISCOSITY (S): 243.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 100 FLUID LOSS (C3): 6.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 7.000 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 4.230 112.0 MUD FILTRATE AT MT: 5.000 68.0 MUD CAKE AT MT: 9.000 67.0 # 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 RPD MWD010 OHMM 4 1 68 4 2 RPM MWD010 OHMM 4 1 68 8 3 RPS MWD010 OHMM 4 1 68 12 4 RPX MWD010 OHMM 4 1 68 16 5 FET MWD010 HR 4 1 68 20 6 GR MWD010 API 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 152.5 3755 1953.75 7206 152.5 3755 RPD MWD010 OHMM 3.91 2000 103.806 7079 152.5 3691.5 RPM MWD010 OHMM 2.35 444.32 67.8686 7079 152.5 3691.5 RPS MWD010 OHMM 2.02 307.92 58.0739 7079 152.5 3691.5 RPX MWD010 OHMM 1.85 145.74 39.6825 7079 152.5 3691.5 FET MWD010 HR 0.18 7.09 1.17603 7079 152.5 3691.5 GR MWD010 API 23.05 84.34 50.009 7079 158.5 3697.5 ROP MWD010 FPH 0.26 998.53 246.13 7078 216.5 3755 First Reading For Entire File 152.5 Last Reading For Entire File 3755 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/09/18 Maximum Physical Record 65535 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 09/09/18 Page 8 bru 232- 23.tapx Maximum Physical Record 65535 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 SESP 3692.0 4693.0 SEDP 3692.0 4693.0 SFXE 3692.0 4693.0 SEXP 3692.0 4693.0 SEMP 3692.0 4693.0 SGRC 3698.0 4683.5 SNP2 3730.0 4653.0 TNPS 3730.0 4639.5 CTNA 3730.0 4639.5 SBD2 3730.0 4653.0 SCO2 3730.0 4653.0 CTFA 3730.0 4639.5 SROP 3755.5 4748.0 LOG HEADER DATA DATE LOGGED: 11- AUG -09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 4748.0 TOP LOG INTERVAL (FT): 3755.0 BOTTOM LOG INTERVAL (FT): 4748.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 16.1 MAXIMUM ANGLE: 42.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 252384 EWR4 ELECTROMAG. RESIS. 4 216787 CTN COMP THERMAL NEUTRON 231173 ALD Azimuthal Litho -Dens 144855 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 3741.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB /G): 9.65 MUD VISCOSITY (5): 56.0 MUD PH: 10.0 MUD CHLORIDES (PPM): 71081 FLUID LOSS (C3): 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .080 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .050 117.7 MUD FILTRATE AT MT: .090 70.0 MUD CAKE AT MT: .090 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Page 9 111/ 1 10 bru 232- 23.tapx 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 FCNT MWD020 CP30 4 1 68 4 2 NCNT MWD020 CP30 4 1 68 8 3 RHOB MWD020 G /CC 4 1 68 12 4 DRHO MWD020 G /CC 4 1 68 16 5 RPD MWD020 OHMM 4 1 68 20 6 RPM MWD020 OHMM 4 1 68 24 7 RPS MWD020 OHMM 4 1 68 28 8 RPX MWD020 OHMM 4 1 68 32 9 FET MWD020 HR 4 1 68 36 10 GR MWD020 API 4 1 68 40 11 PEF MWD020 B/E 4 1 68 44 12 ROP MWD020 FPH 4 1 68 48 13 NPHI MWD020 PU 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3692 4748 4220 2113 3692 4748 FCNT MWD020 CP30 568.23 1840.78 915.212 1820 3730 4639.5 NCNT MWD020 CP30 132999 196118 162491 1820 3730 4639.5 RHOB MWD020 G /CC 0.684 2.574 2.06123 1847 3730 4653 DRHO MWD020 G /CC -2.229 0.286 0.0441597 1847 3730 4653 RPD MWD020 OHMM 2.94 2000 88.2159 1924 3692 4693 RPM MWD020 OHMM 0.1 2000 80.9252 1924 3692 4693 RPS MWD020 OHMM 0.09 2000 67.9651 1924 3692 4693 RPx MWD020 OHMM 0.09 1394.72 12.8117 1924 3692 4693 FET MWD020 HR 0.62 150.61 5.52443 1924 3692 4693 GR MWD020 API 15.83 91.27 68.5565 1972 3698 4683.5 PEF MWD020 B/E 0.37 12.25 2.21897 1847 3730 4653 ROP MWD020 FPH 0.12 260.93 86.6734 1986 3755.5 4748 NPHI MWD020 Pu 17.08 110.39 48.053 1820 3730 4639.5 First Reading For Entire File 3692 Last Reading For Entire File 4748 File Trailer Service name STSLIB.003 Service Sub Level Name version Number 1 0 0 Date of Generation 09/09/18 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.004 Physical EOF File Header Service name STSLIB.004 service sub Level Name version Number 1 0 0 Date of Generation 09/09/18 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. Page 10 I 110 bru 232- 23.tapx BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CTNA 4640.0 6303.0 TNPS 4640.0 6303.0 CTFA 4640.0 6303.0 SNP2 4653.5 6316.5 SBD2 4653.5 6316.5 SCO2 4653.5 6316.5 SGRC 4684.0 6347.0 SEXP 4693.5 6356.5 SESP 4693.5 6356.5 SFXE 4693.5 6356.5 SEMP 4693.5 6356.5 SEDP 4693.5 6356.5 SROP 4748.5 6412.0 LOG HEADER DATA DATE LOGGED: 16- AUG -09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 6412.0 TOP LOG INTERVAL (FT): 4748.0 BOTTOM LOG INTERVAL (FT): 6412.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .3 MAXIMUM ANGLE: 13.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 252384 EWR4 ELECTROMAG. RESIS. 4 216787 CTN COMP THERMAL NEUTRON 231173 ALD Azimuthal Litho -Dens 144855 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 3741.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB /G): 9.60 MUD VISCOSITY (S): 60.0 MUD PH: 10.1 MUD CHLORIDES (PPM): 70000 FLUID LOSS (C3): 4.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .090 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .050 135.5 MUD FILTRATE AT MT: .120 70.0 MUD CAKE AT MT: .080 70.0 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 Page 11 S 11 1/ 1 bru 232- 23.tapx 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 FCNT MWD030 CP30 4 1 68 4 2 NCNT MWD030 CP30 4 1 68 8 3 RHOB MWD030 G /CC 4 1 68 12 4 DRHO MWD030 G /CC 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 B/E 4 1 68 44 12 ROP MWD030 FPH 4 1 68 48 13 NPHI MWD030 PU 4 1 68 52 14 Fi rst Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4640 6412 5526 3545 4640 6412 FCNT MWD030 CP30 589.93 1693.45 949.775 3327 4640 6303 NCNT MWD030 CP30 140795 208203 168346 3327 4640 6303 RHOB MWD030 G /CC 1.286 2.873 2.20107 3327 4653.5 6316.5 DRHO MWD030 G /CC -0.047 0.354 0.101137 3327 4653.5 6316.5 RPD MWD030 OHMM 1.44 1564.4 14.8555 3327 4693.5 6356.5 RPM MWD030 OHMM 1.3 1778.02 17.4779 3327 4693.5 6356.5 RPS MWD030 OHMM 1.25 1950.34 23.1591 3327 4693.5 6356.5 RPX MWD030 OHMM 1.12 1884.13 9.35052 3327 4693.5 6356.5 FET MWD030 HR 0.65 18.2 2.91313 3327 4693.5 6356.5 GR MWD030 API 17.32 107.95 72.8015 3327 4684 6347 PEF MWD030 B/E 0.4 7.26 2.39909 3327 4653.5 6316.5 ROP MWD030 FPH 0.09 217.57 68.681 3328 4748.5 6412 NPHI MWD030 Pu 27.73 113.68 49.9512 3327 4640 6303 First Reading For Entire File 4640 Last Reading For Entire File 6412 File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/09/18 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.005 Physical EOF File Header Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/09/18 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CTNA 6303.5 6520.5 TNPS 6303.5 6520.5 CTFA 6303.5 6520.5 SNP2 6317.0 6534.5 Page 12 III II/ . bru 232- 23.tapx SBD2 6317.0 6534.5 SCO2 6317.0 6534.5 SGRC 6347.5 6565.0 SEXP 6357.0 6575.0 SEMP 6357.0 6575.0 SEDP 6357.0 6575.0 SESP 6357.0 6575.0 SFXE 6357.0 6575.0 SROP 6412.5 6615.0 $ # LOG HEADER DATA DATE LOGGED: 19- AUG -09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 6615.0 TOP LOG INTERVAL (FT): 6412.0 BOTTOM LOG INTERVAL (FT): 6615.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 1.2 MAXIMUM ANGLE: 1.3 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 121210 CTN COMP THERMAL NEUTRON 245542 ALD Azimuthal Litho -Dens 146830 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 3741.0 # BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB /G): 9.80 MUD VISCOSITY (S): 120.0 MUD PH: 9 . 8 MUD CHLORIDES (PPM): 55000 FLUID LOSS (C3): 3.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .200 74.0 MUD AT MAX CIRCULATING TERMPERATURE: .130 114.0 MUD FILTRATE AT MT: .080 74.0 MUD CAKE AT MT: .140 74.0 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 Loggin 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 FCNT MWD040 CP30 4 1 68 4 2 NCNT MWD040 CP30 4 1 68 8 3 RHOB MWD040 G /CC 4 1 68 12 4 DRHO MWD040 G /CC 4 1 68 16 5 Page 13 411/ III/ bru 232- 23.tapx RPD MWD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MWD040 OHMM 4 1 68 28 8 RPx MWD040 OHMM 4 1 68 32 9 FET MWD040 HR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 PEF MWD040 B/E 4 1 68 44 12 ROP MWD040 FPH 4 1 68 48 13 NPHI MWD040 PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6303.5 6615 6459.25 624 6303.5 6615 FCNT MWD040 CP30 642.86 2793.81 1098.16 435 6303.5 6520.5 NCNT MWD040 CP30 146712 235299 177070 435 6303.5 6520.5 RHOB MWD040 G /CC 1.497 2.666 2.35254 436 6317 6534.5 DRHO MWD040 G /CC -0.029 0.277 0.120883 436 6317 6534.5 RPD MWD040 OHMM 4.43 63.9 10.8099 437 6357 6575 RPM MWD040 OHMM 3.98 117.68 10.8598 437 6357 6575 RPS MWD040 OHMM 3.14 756.6 11.9343 437 6357 6575 RPX MWD040 OHMM 1.85 123.4 7.28119 437 6357 6575 FET MWD040 HR 0.64 114.08 44.9814 437 6357 6575 GR MWD040 API 46.17 95.32 78.3911 436 6347.5 6565 PEF MWD040 B/E 0.94 4.25 2.63835 436 6317 6534.5 ROP MWD040 FPH 1.21 118.38 39.4166 406 6412.5 6615 NPHI MWD040 PU 18.36 84.8 41.5154 435 6303.5 6520.5 First Reading For Entire File 6303.5 Last Reading For Entire File 6615 File Trailer Service name STSLIB.005 Service Sub Level Name version Number 1 0 0 Date of Generation 09/09/18 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.006 Physical EOF File Header Service name STSLIB.006 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/09/18 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TNPS 6521.0 6744.0 CTFA 6521.0 6744.0 CTNA 6521.0 6744.0 SNP2 6535.0 6757.5 SBD2 6535.0 6757.5 sCO2 6535.0 6757.5 SGRC 6565.5 6788.0 SFXE 6575.5 6798.0 SEXP 6575.5 6798.0 SESP 6575.5 6798.0 SEMP 6575.5 6798.0 SEDP 6575.5 6798.0 SROP 6615.5 6839.0 Page 14 III/ 411 bru 232- 23.tapx $ # LOG HEADER DATA DATE LOGGED: 20- AUG -09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 6839.0 TOP LOG INTERVAL (FT): 6615.0 BOTTOM LOG INTERVAL (FT): 6839.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 1.3 MAXIMUM ANGLE: 1.5 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 121210 CTN COMP THERMAL NEUTRON 11068806 ALD Azimuthal Litho -Dens 151843 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 3741.0 # BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB /G): 9.80 MUD VISCOSITY (5): 75.0 MUD PH: 9 . 9 MUD CHLORIDES (PPM): 52000 FLUID LOSS (C3): 4.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .190 72.0 MUD AT MAX CIRCULATING TERMPERATURE: .110 125.6 MUD FILTRATE AT MT: .090 72.0 MUD CAKE AT MT: .130 72.0 # 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 FCNT MWD050 CP30 4 1 68 4 2 NCNT MWD050 CP30 4 1 68 8 3 RHOB MWD050 G /CC 4 1 68 12 4 DRHO MWD050 G /CC 4 1 68 16 5 RPD MWD050 OHMM 4 1 68 20 6 RPM MWD050 OHMM 4 1 68 24 7 RPS MWD050 OHMM 4 1 68 28 8 RPX MWD050 OHMM 4 1 68 32 9 FET MWD050 HR 4 1 68 36 10 GR MWD050 API 4 1 68 40 11 PEF MWD050 B/E 4 1 68 44 12 ROP MWD050 FPH 4 1 68 48 13 NPHI MWD050 PU 4 1 68 52 14 Page 15 i bru 232- 23.tapx Fi rst Last Name service Unit Min Max Mean Nsam Reading Reading DEPT FT 6521 6839 6680 637 6521 6839 FCNT MWD050 CP30 763.28 2669.27 1160.38 447 6521 6744 NCNT MWD050 CP30 154042 233694 182117 447 6521 6744 RHOB MWD050 G /CC 1.774 2.676 2.36704 446 6535 6757.5 DRHO MWD050 G /CC 0.03 0.224 0.111823 446 6535 6757.5 RPD MWD050 OHMM 4.8 34.25 11.5642 446 6575.5 6798 RPM MWD050 OHMM 4.3 37.62 11.4759 446 6575.5 6798 RP5 MWD050 OHMM 4.04 31.87 11.0385 446 6575.5 6798 RPX MWD050 OHMM 3.15 29.02 8.58435 446 6575.5 6798 FET MWD050 HR 0.55 20.35 4.71397 446 6575.5 6798 GR MWD050 API 48.28 106.38 77.2302 446 6565.5 6788 PEF MWD050 B/E 1.36 4.11 2.82354 446 6535 6757.5 ROP MWD050 FPH 3.95 131.08 64.7424 448 6615.5 6839 NPHI MWD050 PU 19.53 62.12 37.8232 447 6521 6744 First Reading For Entire File 6521 Last Reading For Entire File 6839 File Trailer Service name STSLIB.006 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/09/18 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.007 Physical EOF File Header Service name STSLIB.007 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/09/18 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CTNA 6744.5 7478.0 CTFA 6744.5 7478.0 TNPS 6744.5 7478.0 SBD2 6758.0 7491.5 SCO2 6758.0 7491.5 SNP2 6758.0 7491.5 SGRC 6788.5 7522.0 SEDP 6798.5 7532.0 SEMP 6798.5 7532.0 SEXP 6798.5 7532.0 SFXE 6798.5 7532.0 SESP 6798.5 7532.0 SROP 6839.5 7587.0 $ # LOG HEADER DATA DATE LOGGED: 26- AUG -09 SOFTWARE SURFACE SOFTWARE VERSION: incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 7587.0 Page 16 III 11/ bru 232- 23.tapx TOP LOG INTERVAL (FT): 6839.0 BOTTOM LOG INTERVAL (FT): 7587.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 1.1 MAXIMUM ANGLE: 1.5 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 121210 CTN COMP THERMAL NEUTRON 179954 ALD Azimuthal Litho -Dens 146098 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 3741.0 # BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB /G): 9.80 MUD VISCOSITY (5): 90.0 MUD PH: 10.0 MUD CHLORIDES (PPM): 52000 FLUID LOSS (C3): 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .200 72.0 MUD AT MAX CIRCULATING TERMPERATURE: .120 129.0 MUD FILTRATE AT MT: .120 72.0 MUD CAKE AT MT: .200 72.0 # 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 Lowing 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 FCNT MWD060 CP30 4 1 68 4 2 NCNT MWD060 CP30 4 1 68 8 3 RHOB MWD060 G /CC 4 1 68 12 4 DRHO MWD060 G /CC 4 1 68 16 5 RPD MWD060 OHMM 4 1 68 20 6 RPM MWD060 OHMM 4 1 68 24 7 RPS MWD060 OHMM 4 1 68 28 8 RPX MWD060 OHMM 4 1 68 32 9 FET MWD060 HR 4 1 68 36 10 GR MWD060 API 4 1 68 40 11 PEF MWD060 B/E 4 1 68 44 12 ROP MWD060 FPH 4 1 68 48 13 NPHI MWD060 PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6744.5 7587 7165.75 1686 6744.5 7587 FCNT MWD060 CP30 678.34 2583.98 1186.31 1468 6744.5 7478 NCNT MWD060 CP30 142999 224131 179863 1468 6744.5 7478 RHOB MWD060 G /CC 1.541 2.734 2.39739 1468 6758 7491.5 Page 17 • . bru 232- 23.tapx DRHO MWD060 G /CC -0.021 0.237 0.0897718 1468 6758 7491.5 RPD MWD060 OHMM 5.12 23.72 9.83031 1468 6798.5 7532 RPM MWD060 OHMM 4.48 32 9.7209 1468 6798.5 7532 RPS MWD060 OHMM 3.87 42.83 9.51366 1468 6798.5 7532 RPX MWD060 OHMM 1.64 40.68 7.9883 1468 6798.5 7532 FET MWD060 HR 0.69 135.1 18.0441 1468 6798.5 7532 GR MWD060 API 49.99 106.97 83.0225 1468 6788.5 7522 PEF MWD060 B/E 1.05 4.64 2.51034 1468 6758 7491.5 ROP MWD060 FPH 0.62 163.45 62.7186 1496 6839.5 7587 NPHI MWD060 Pu 19.6 77.25 37.1387 1468 6744.5 7478 First Reading For Entire File 6744.5 Last Reading For Entire File 7587 File Trailer Service name STSLIB.007 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/09/18 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.008 Physical EOF Tape Trailer service name LISTPE Date 09/09/18 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 09/09/18 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 LI5 File I Page 18 s Aoae.e 7 0.wwit . Nov C onocoPhil li s Alaska, Inc. FINAL WELL REPORT MUDLOGGING DATA BRU 232 -23 • Provided by: CAN RIG Approved by: Rick A. Levinson Compiled by: John Lundy Steven Pike Date: 08/28/2009 Distribution:09 /15/09 Conoc P hillips Alaska, Inc. BRU- 232-23 23 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW 2 1.1 Equipment Summary 2 1.2 Crew 2 2 WELL DETAILS 3 2.1 Well Summary 3 2.2 Hole Data 3 2.3 Daily Activity Summary 4 3 GEOLOGICAL DATA 6 3.1 Lithostratigraphy 6 3.2 Mudlog Summary 7 3.3 Connection Gases 15 3.4 Trip (Wiper) Gases 15 3.5 Sampling Program / Sample Dispatch 16 4 PRESSURE / FORMATION STRENGTH DATA 17 4.1 Pore Pressure Gradient Evaluation 17 4.2 Quantitative Methods 18 5 DRILLING DATA 1 9 5.1 Survey Data 1 9 5.2 Bit Record 22 5.3 Mud Record 23 6 DAILY REPORTS 24 • Enclosures: 2 "/100' Formation Log (MD and TVD) 2 "/100' Combination MWD / Lithology Log (MD and TVD) 2 "/100' Drilling Dynamics Log (MD and TVD) 2 "/100' Gas Ratio Log (MD and TVD) • CANRIG Conoc Alaska, Inc 410 BRU- 232 -23 -23 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment T Total ype /Position Downtime Comments QGM Agitator (Mounted in possum belly) Ditch gas .5 Flame ionization total gas & chromatography. Hook Load / Weight on bit From TOTCO via WITS 18 See Note Mud Flow In From TOTCO via WITS 18 See Note Mud Flow Out From TOTCO via WITS 18 See Note Mudlogging unit computer HP Compaq Pentium 4 (X2, DML & 0 See Note system Rigwatch) Mudlogging unit DAC box In -unit data collection /distribution 0 See Note center Pit Volumes, Pit Gain /Loss From TOTCO via WITS 18 See Note Pump Pressure From TOTCO via WITS 18 See Note Pump stroke counters From TOTCO via WITS 18 See Note Totco Well Monitoring WITS Feed 18 See Note Components Rate of penetration RigWatch Calculated from TOTCO 2 See Note pulses via WITS RPM From TOTCO via WITS 18 See Note Torque From TOTCO via WITS 18 See Note 1 0 Note: Totco computer and network failures contributed a total of 18 hours without WITS feed information to Canrig Rigwatch system, however, only 2 hours of this occurred while actively drilling. Canrig DML personnel manually entered gas and ROP data during outages while drilling, all other data lost. 1.2 Crew Unit Type • Arctic Steel Unit Number : ML030 Years Days Mudloggers •1 =2 Sample Catchers Years Days Technician Days John Lundy 17 24 Tollef Winslow 1 20 Allan 2 Williams Steven Pike 7 24 Jeff McBeth 1 20 *1 Years experience as Mudlogger *2 Days at wellsite between spud and total depth of well 2 • CANRIG Conoc Phillips Alaska, Inc BRU- 232 -23 • 2 WELL DETAILS 2.1 Well Summary Well: BRU- 232 -23 API Index #: 50- 283 - 20133 -00 Field: Beluga River Unit Surface Co- Ordinates: 2102' FNL, 51' FWL Sec 24, T13N, R10W SM Borough: Kenai Primary Target Depth: 6074 State: Alaska TD Depth: 7587 Rig Name / Type: Doyon, Arctic Fox #1, Suspension Date: N/A g yp Double Prima Tar et: Sterling A, B, C and License: N/A g Beluga D thru 1 Spud Date: 7/27/2009 Ground Elevation: 78.00' Above MSL Completion Date: N/A RT Elevation: 96.50' Above MSL Completion Status: Going into completion at Secondary Target: N/A rig down Depth: Classification: Gas Well TD Date: 8/26/2008 TD Formation: Below Beluga I Days Testing: NA Days Drilling: 30 2.2 Hole Data • Maximum Depth Mud Shoe Depth LOT Hole TD Dev. Casing/ TVDS Section MD TVDSS Formation Weight (oinc) Coring tops Liner MD S (PPg (ft) (ft) (Ppg) (ft) (ft) ) 12.25" 3756.41' 2841' Sterling 9.7 19.5 NA 10.625" 304 2855' 16.0 8.5" 7587 6668 Beluga I 9.8 1.47 6412, 6844 7" Additional Comments; 3 cores were taken; 6412' to 6503', 6844' to 6902.5' and 6902.5' to 5947.5' I 3 • C NR!G Conocillips Alaska, Inc. BRU- 232 -23 • 2.3 Daily Activity Summary 8/04/2009: Rig up Canrig logging unit. 8/05/2009: Canrig continue rigging up. Rig crew rigging up to test cement lines and cement casing.. 8/06/2009: Canrig rigged up, TOTCO WITS issues are only outstanding item. Continue rig up and test cement lines. Pump cement as per plan. Clean and flush cement equipment and stack. Clear cellar and remove excess cement. Nipple down BOPs. Nipple up new BOP stack. Rig up to test BOPs.. 8/07/2009 Continue to test BOPs. 8/08/2009 Lay down 5' drill pipe. 8/09/2009 Pick up BHA and single in with 4" drill pipe. 8/10/2009 Single in with 4" drill pipe to 3456', conduct casing pressure test, continue to trip to bottom, condition mud, drill out cement and shoe, drill 20' feet of new formation, perform FIT test @3775' 16.0 PPG, drill ahead 8/11/2009 Drill ahead to 4750', circulate bottoms up. P.O.O.H. to 3867', spot pill, P.O.O.H for BHA. 8/12/2009 Pick up new BHA with MRIL tool, trip in hole to bottom, circulate bottoms up, 36 units trip gas, drill ahead. 8/13/2009 Drill and slide ahead from 5045' to 5705' 8/14/2009 Drill ahead from 5705' to 6301', circulate bottoms up, conduct short trip from 6301' to 4750'. 8/15/2009 Conduct short trip from 6301' to 4750', circulate bottoms up, trip back to bottom, circulate bottoms up, max gas 60u, drill ahead from 6301' to 6412, circulate and condition mud. 8/16/2009 Circulate and condition mud, pull five stands, circulate, go back to bottom, circulate, max gas 24u, add core tracer to mud, circulate 2.5 surface to surface, P.O.O.H, lay down BHA. 8/17/2009 Lay down BHA, pick up core barrel BHA assembly, trip in hole to 5380', pull back out to 3690', work on top drive swivel. 8/18/2009 Work on top drive swivel, trip back to bottom 6412' MD, circulate bottoms up, commence coring from 6412' MD to 6503' MD, circulate bottoms up, P.O.O.H. with core barrel. 8/19/2009 P.O.O.H. with core barrel, lay down core barrel BHA and remove core, pick up MWD directional BHA, trip in hole to 6412' MD. 8/20/2009 Trip in hole to 6412' MD, circulate bottoms up max gas 29 units, drill ahead from 6503' MD to 6620' MD, P.O.O.H. for directional BHA. 8/21/2009 Pick up directional BHA, trip in hole to 6620' MD, circulate bottoms up, max gas 89 units, drill ahead fro 6620' MD to 6844' MD, circulate bottoms up, short trip, circulate 3X bottoms up and add tracer, circulate 2X bottoms up, P.O.O.H. for core run. 8/22/2009 P.O.O.H. for core run, test BOPs, work on draw works, pick up core barrel, trip in hole. 4 • CANRIG ConocoPhillips Alaska. Inc. BRU- 232 -23 8/23/2009 Trip in hole with core barrel, core from 6844' MD to 6902.5' MD, circulate bottoms up, P.O.O.H. with the core barrel. 8/24/2009 P.O.O.H. with the core barrel, lay down core barrel and remove core, put together new core barrel, and trip in hole. 8/25/2009 Put together new core barrel, trip in hole, circulate bottoms up, max gas 16 units, core ahead from 6902.5' MD to 6947.5' MD, circulate bottoms up, P.O.O.H. 826/2009 Lay down core barrel and remove core, pick up directional BHA, trip in hole, mad pass to bottom of well. 8/27/2009 MAD Pass to bottom of well, circulate bottoms up, max gas 26 units, drill ahead from 6947' MD to 7587' MD, circulate 3x bottoms up, wiper trip, trip back to bottom, circulate bottoms up, max gas 100 units. 8/28/2009 P.O.O.H., lay down BHA, rig up for wireline, run wireline sonic tool, run wireline nuclear resonance. Epoch /Canrig released 10:00 Hrs. • 5 • C:AANRIG ConocoPhillips Alaska, Inc. BRU- 232 -23 0 3 GEOLOGICAL DATA 3.1 Lithostratigraphv LWD tops refer to provisional picks by the ConocoPhillips Alaska, Inc. (CPAI) well site geologist. FORMATION PROGNOSED LWD PICK MD SSTVD MD SSTVD (ft) (ft) (ft) (ft) Injection Zone No Pick 3795 2895 Sterling A 4112 3140 4121 3163 Sterling B 4317 3320 4324 3341 Sterling C 4479 3470 4486 3489 Beluga D 4648 3630 4655 3649 Beluga E 4913 3890 4919 3906 Beluga F 5269 4245 5298 4284 Beluga G 5734 4710 5730 4716 IIII Beluga H 6074 5050 6065 5050 Beluga I 6764 5740 6784 5770 TD 7594 6570 7587 6572' 410 6 CANRIG Conoc Phillips Alaska, Inc. BRU- 232 -23 • 3.2 Mudloq Summary Overburden (3755 to 3795'MD; 2865' to 2895' SSTVD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 279 26 104 52 1 15 This interval consists of alternating sequences of sand, siltstone and shale with very thin beds of coal dispersed throughout. No oil indicators were noted in this section. Carbonaceous Shale : dark gray to dark gray brown, dark brown and black; moderately hard; brittle; slight friable; angular irregular to splintery fragments; abundant poorly developed; interbedded with very thin coal and siltstone beds. Sand : light gray to white with some clear to translucent; mostly quartz sand; upper fine to lower to upper medium grain sand; moderate to well sorted throughout; very well rounded to sub - rounded with some slightly sub - angular to slightly angular; moderate sphericity; some sand grains appeared to be slightly frosted to somewhat polished in places; fair to good apparent porosity. Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 3795 53 9354 NA NA NA , NA NA NA • Injection Zone (3795" to 4121' MD; 2895' to 3163' SSTVD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 145 17 89 72 9 23 This interval is typified by massive sands with thin siltstone and occasional coaly interbeds in the upper portion. As depth increases in the section coals make up a more significant part of the lithology and the siltstone changes character becoming dominantly tuffaceous, occurring in thicker interbeds with similar tuffaceous claystone in the dominant sand. No oil indicators were noted in this section. Sand = light gray to white with some clear to translucent; mostly quartz grain sand matrix; upper fine to lower to upper medium grain sand; moderate to well sorted throughout; very well rounded to sub - rounded with some slightly sub - angular to slightly angular; moderate sphericity; some sand grains appeared to be slightly frosted to somewhat polished in places; fair to good apparent porosity. Siltstone = light gray to medium gray with some grayish brown to brown hues; firm; crumbly; slightly irregular fracture; amorphous cuttings habit; trace very fine lower sand size clasts interbedded throughout; silty to gritty to slightly sandy texture in places; dull earthy luster; thin beds of carbonaceous material interbedded throughout. Sand = translucent to clear with some light to medium gray to white; predominantly quartz grain sand matrix throughout with abundant dark colored lithic fragments; lower to upper fine to lower to upper medium grain sand; fair to moderately sorted; very well rounded to sub - rounded with some sub - angular to slightly angular; moderate to high sphericity; sand grains were polished to slightly frosted in places. 7 • CANRIG ■ Conoc Alaska. Inc BRU- 232 -23 0 Coal = black with blackish red to very dusky red hues; slightly stiff to very firm; somewhat slightly dense in places; blocky to irregular fracture; massive to somewhat platy cuttings habit. Tuffaceous Claystone = light gray to medium gray with occasional brown hues; mostly friable to moderately hard; poor induration; dense to crumbly; nodular to slightly elongated cuttings habit; silty to clayey to slightly gritty texture; dull earthy luster; clumpy to slightly pasty consistency; interbedded with tuffaceous silt and sand throughout; thin carbonaceous laminae interbedded throughout. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 3796 58 10561 NA NA NA NA NA NA 3900 48 8689 NA NA NA NA NA NA 4019 73 13543 NA NA NA NA NA NA Sterling A Group (4121' to 4324'; 3163' to 3341' SSTVD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 200 11 97 220 8 72 This interval consists of alternating sequences of sand, siltstone and shale with very thin beds of coal dispersed throughout. No oil indicators were noted in this section. Sand = clear to translucent with some white, light gray, light blue green, and grayish red hues; mostly quartz III grain sand with some dark colored lithic fragments; lower to upper fine to lower medium grain sand; moderately well sorted; very well rounded to sub - rounded with some slightly angular to angular; moderate to high sphericity; some sand grains appeared to be slightly polished in places; occasional thin coal interbeds; fair to poor visible porosity; no visible sample fluorescence was observed. Tuffaceous Siltstone = light gray to very light gray with some bluish gray; lumpy to clumpy; very crumbly slightly crunchy; irregular fracture; amorphous cuttings habit; very earthy to slightly dull luster with some vitreous in places; very clayey texture with some slightly gritty in places; thinly interbedded with thick beds of tuffaceous claystone and thick beds of silty tuffaceous sand; occasional thin beds of fine fluffy white ash /tuff. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 4161 220 40995 NA NA NA NA NA NA 4173 175 32788 NA NA NA NA NA NA 4208 192 36832 NA NA NA NA NA NA Sterling B Group (4324' to 4486' MD; 3341' to 3489" SSTVD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 223 11 92 94 13 39 The Sterling B is comprised of alternating beds of shale, claystone, tuffaceous claystone, tuffaceous siltstone and sands, with very thin stringers of intermittent seams of coal and carbonaceous shale. No oil indicators were noted in this section. • 8 CANRIG Conoc Phillips Alaska, Inc. BRU- 232 -23 I Carbonaceous Shale /Coal : dark gray to dark gray brown and black; hard to moderately hard; angular irregular to slightly splintery and blocky cuttings habit; shale is primarily well sorted grading to slightly silty; silty fraction tends to dark gray brown; non to very coarsely fissile; coaly in part; vigorous out gassing over ten minutes diminishes to slight after 20 minutes; common brown surface stain on fractures and partings; trace poor conchoidal fracture; pronounced cleat on some fragments. Sand /Sandstone : medium to medium light gray; firm to hard; sample occurs as disconsolidated loose sand; medium lower to fine upper, medium upper, and coarse; clear to translucent white; sub - rounded to sub spheroidal grains predominate; common angular; quartz sand predominates; trace to common medium and light gray lithics; trace dark mafic mineral grains; trace rose, blue and light orange grains; slightly to very clayey /ashy in part; appears to be primarily matrix supported; interbedded with thin silty claystone and medium gray silty carbonaceous shale; overlies fine grain tuffaceous sandstone below 4400'; trace calcareous. Tuffaceous Siltstone /Claystone : light to medium light gray slight intermittent brownish secondary hue; angular irregular to blocky cutting habit; moderate beds interbedded with and grading to silty tuffaceous sandstone and occasional thin cleaner sands; moderately hydrophilic; slightly to moderately adhesive in clayey sections; slightly cohesive; slightly sandy throughout grades to occasional thin very fine grain slightly silty sandstone occasional sandstone intervals display abundant medium lower to fine upper size white ash /clay blebs; non to trace calcareous. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 4317' 94 16601 NA NA NA NA NA NA 4358 79 15480 NA NA NA NA NA NA 4433 62 12922 NA NA NA NA NA NA • Sterling C Group (4486' to 4655' MD; 3489' to 3649' SSTVD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 280 22 87 230 16 73.8 This section is comprised sandstone and sandstone conglomerate with tuffaceous siltstone and claystone in gradational contact and as thin interbeds with occasional thin to very thin coals. No oil indicators were noted in this section. Tuffaceous Siltstone /Claystone = light to medium light gray slight intermittent brownish secondary hue; angular irregular to blocky cutting habit; moderate beds interbedded with and grading to silty tuffaceous sandstone and occasional thin cleaner sands; moderately hydrophilic; slightly to moderately adhesive in clayey sections; slightly cohesive; slightly sandy throughout grades to occasional thin very fine grain slightly silty sandstone occasional sandstone intervals display abundant medium lower to fine upper size white ash /clay blebs; non to trace calcareous. Sandstone /Sand = light to medium light gray; hard to firm; sample recovered largely as deconsolidated medium to coarse lower loose sand; trace very coarse and small pebble size angular quartz fragments; overall sub spheroidal to sub angular and angular grains; upper portion is grain supported, grain to mixed grain and matrix support in the base of the zone; matrix is a silty/ashy medium to light gray and brownish gray similar to the overlying siltstone; occasional thin coal interbeds; non to very slight trace calcareous. 9 • CANRIG Conoco Alaska, Inc BRU- 232 -23 • Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 4501 102 19955 NA NA NA NA NA NA 4523 117 22203 NA NA NA NA NA NA 4550 88 16700 NA NA NA NA NA NA 4603 231 48030 NA NA NA NA NA NA 4646 153 28564 NA NA NA NA NA NA Beluga D Group (4655' to 4919' MD; 3649' to 3906' SSTVD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 235 9 68 235 5 66 The upper portion of the interval consists of mainly alternating sequences of siltstone and shale with some tuffaceous siltstone and tuffaceous claystone and sand in lesser amounts. Moderate coal beds with associated carbonaceous shale were found at 4700', 4750' and 4800' with thinner coals interbedded throughout the section. In the lower portion of the interval, below 4800', non tuffaceous siltstone and claystone were seen. No oil indicators were noted in this section. Sandstone/Tuffaceous Sandstone = medium light gray with a slight brownish secondary hue; firm to hard; fine lower to fine upper, very fine upper and medium lower grain; coarser material is sub spheroidal to sub angular finer fraction is predominantly sub rounded to rounded; overall poorly sorted; locally moderately sorted; mixed grain and matrix support; fair to poor visible porosity; matrix is silty /ashy clay similar to that found in the adjacent siltstone; material appears to be interbedded with and grading to siltstone; common light gray • claystone interbeds; trace to very slightly calcareous. Tuffaceous Siltstone /Claystone = medium gray to very light gray with grayish brown; clumpy to lumpy; very crunchy slightly crumbly; irregular fracture; amorphous cuttings habit; very earthy to slightly dull luster with some greasy in places; very clayey texture with some slightly gritty in places; thinly interbedded with thick beds of tuffaceous claystone and tuffaceous sand with some very thin lenses of sand; also interbedded with thin layers of volcanic tuff in places. Coal /Carbonaceous Shale = very dark brownish black to black; hard to firm; brittle; splintery in part shaly in part; common brownish stain on fractures and partings; trace white non calcareous fracture fill; conchoidal fracture on larger fragments; generally lignitic; sample at 4800, coal is moderately silty and soft; no to slight outgassing; trace cleat on fracture surfaces; interbedded with very fine to fine grain tuffaceous sand, tuffaceous siltstone and hard brownish gray siltstone /claystone. Siltstone /Claystone = medium light to medium gray; moderate brownish secondary hue in part; firm to very firm and moderately hard; angular irregular to tabular cuttings habit; some cuttings display a slight curl; moderately cohesive; slightly adhesive; generally well sorted; some slightly sandy; thin interbeds of tuffaceous siltstone and sandstone similar to overlying material; trace brownish plant remain stains in part; non to very slight trace calcareous. Peaks Depth TG Cl C2 C3 C41 C4N C51 C5N 4713' 235 51270 NA NA NA NA NA NA 4743 136 22911 NA NA NA NA NA NA 4800 83 19971 NA NA NA NA NA NA 4830 74 16681 NA NA NA NA NA NA 1 4864 74 14555 NA NA NA NA NA NA 4884 67 13335 NA NA NA NA NA NA 10 410 CANRIG ConocoPhillips Alaska, Inc. BRU- 232 -23 1 Beluga E Group (4919' to 5298' MD; 3906' to 4284' SSTVD) Drill Rate ( ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 353 11.8 67 199 5 59 This interval consists of siltstone, sand, sandstone, tuffaceous siltstone, tuffaceous claystone and several thin shaly coals in the base of the section. No oil indicators were noted in this section. Tuffaceous Claystone = light gray with some light medium gray and grayish brown and very brown gray hues; predominantly lumpy to clumpy; mostly crunchy to crumbly; irregular to blocky fracture, mostly amorphous cuttings habit; greasy to slightly waxy luster; smooth to somewhat silty in places; very thin interbedded with tuffaceous siltstone and tuffaceous sandstone, with a small amount of claystone and siltstone; no visible fluorescence. Sand = translucent to clear with some light gray to white; predominantly quartz grain sand with abundant dark colored lithic fragments; upper very fine to upper fine grain; moderately well sorted throughout; very well rounded to sub - rounded with some slightly angular to sub - angular; moderate to high sphericity; abundant volcanic lithics; 20 % -30% multicolored lithics dominated by light bluish green, grayish green, moderate yellow green, and very pale green; no visible sample fluorescence. Tuffaceous Siltstone = medium to light gray with some pale blue to grayish blue hues; mostly clumpy to lumpy with some clotted; some pasty to clumpy; crunchy to somewhat crumbly; irregular fracture; amorphous cuttings habit; very earthy to slightly dull luster with some vitreous in places; very clayey texture with some slightly gritty in places; thinly interbedded with thin beds of coal and thin beds of tuffaceous siltstone and claystone; no visible sample fluorescence was observed. • Carbonaceous Shale = brownish black to reddish black; slightly stiff; very brittle to slightly elastic; irregular fracture; platy to slightly planar cuttings habit; mostly resinous to slightly greasy luster; no visible sample fluorescence. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 4926 148 28266 NA NA NA NA NA NA 5007 172 32592 NA NA NA NA NA NA 5025 130 24739 NA NA NA NA NA NA 5078 90 16901 NA NA NA NA NA NA 5116 199 16752 NA NA NA NA NA NA 5209 87 87 NA NA NA NA NA NA 5241 117 117 NA NA NA NA NA NA 5274 135 135 NA NA NA NA NA NA 5284 130 130 NA NA NA NA NA NA Beluga F Group (5298' to 5730' MD; 4284' to 4716' SSTVD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 219 5.6 74 303 23 111 This section is comprised of siltstone, tuffaceous siltstone, tuffaceous claystone, tuffaceous shale, and intermittent beds of coal and carbonaceous shale. No oil indicators were noted in this section. • 11 CANRIG Conoc Alaska, Inc BRU- 232 -23 0 Sandstone/Tuffaceous Sandstone = light to medium Tight gray with a pervasive slight brownish secondary hue; soft to slightly firm to disconsolidated small irregular fragments of very fine upper to very fine lower grain moderately spheroidal to sub - angular; clear to translucent white quartz sand; trace to common fine upper to fine lower and medium lower, angular quartz grains; primarily matrix supported in light brownish gray ashy matrix; matrix is hydrophilic and is easily lost in sample preparation. locally grain supported coarser material; trace dark to medium gray lithics; interbedded with thin siltstone /clay- stones containing trace to common carbonaceous micro - lamina, coal, and clean non tuffaceous siltstone /claystone interbeds; non calcareous. Tuffaceous Siltstone /Claystone = Very light to medium gray with a pervasive brownish secondary hue becoming bluish with increasing depth; firm to occasionally moderately hard; mushy to pasty; very brittle; clean to slightly sandy; irregular to blocky cuttings habit; micro sparkly luster; dull earthy in part; trace to common carbonaceous micro - lamina; hydrophilic; readily hydrates when in contact with fresh water; interbedded with thin beds of tuffaceous sandstone and tuffaceous siltstone; abundant dark colored Iithic fragments in the lower 100' of section. Coal /Carbonaceous Shale = dark gray brown to black; firm to stiff to hard; dense to brittle; greasy to dull luster; smooth to slightly silty texture; very minor outgassing; Iignitic to sub - bituminous; splintery irregular angular fragments; no notable conchoidal fracture; generally dirty shaly in part; interbedded with thin to moderate beds of tuffaceous sand; sand contains trace to abundant carbonaceous micro - lamina and inclusions; common brownish stain on fractures and partings; some shaly fragments display remnant woody structures. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 5315 304 59288 NA NA NA NA NA NA 5358 140 27339 NA NA NA NA NA NA 5383 231 45192 NA NA NA NA NA NA • 5409 267 52150 NA NA NA NA NA NA 5463 245 47874 NA NA NA NA NA NA 5504 99 19338 NA NA NA NA NA NA 5520 247 48198 NA NA NA NA NA NA 5570 93 18320 NA NA NA NA NA NA 5638 262 51019 NA NA NA NA NA NA 5660 255 49724 NA NA NA NA NA NA 5708 145 28449 NA NA NA NA NA NA Beluga G Group (5730' to 6065' MD 4716' to 5050' SSTVD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 482 15 82 306 17 114 This section displays a gradual transition from massive tuffaceous siltstone /claystone beds with thin interbedded sands and occasional thin coals in the upper portion, sand becoming gradually more dominant with depth. The lower portion is dominantly moderate beds of tuffaceous sandstone with interbedded thin siltstone /claystones. Very thin coals are found throughout. No oil indicators were found in this section. Tuffaceous Sandstone = medium gray to light gray with slight grayish blue and pale blue hues; predominantly poorly sorted becoming moderately to well sorted with depth; sub - rounded to sub - angular; poor to moderate sphericity; mostly fair to moderate cementation; very common white tuffaceous matrix throughout; matrix supported; 50% translucent quartz; 50% multicolored volcanic clasts and carbonaceous fragments; soft to easily friable; no visible sample fluorescence was observed; no solvent cut. 12 • CANRIG ConocoPhillips Alaska, Inc BRU- 232 -23 Coal = reddish black to black, with some blackish red hues; brittle tenacity; blocky to platy to irregular cuttings habit; planar to irregular fracture; earthy luster to occasionally sub vitreous luster; smooth texture; massively bedded; common visible outgassing present. Tuffaceous Siltstone = medium Tight gray with a slight to pronounced brownish secondary hue; soft to firm and occasionally hard; moderately eroded to angular irregular fragments; trace bluish gray non tuffaceous claystone; micro - sparkly to dull earthy luster; slightly sandy texture; trace to common carbonaceous micro- lamina; trace very fine mica; occasional fragments contain abundant medium sand size ash blebs; hydrophilic; slightly to non adhesive; moderately cohesive; grades to and inter bedded with associated tuffaceous sand stone; trace to 10% moderately hard waxy yellowish white ash; some fragments contain moderate amounts of lignite blended with medium sand; occasional thin coal interbeds; non calcareous. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 5760 245 41491 NA NA NA NA NA NA 5907 306 59764 NA NA NA NA NA NA 5978 83 15792 NA NA NA NA NA NA 6003 83 15843 NA NA NA NA NA NA 6042 92 17461 NA NA NA NA NA NA 6065 157 29866 NA NA NA NA NA NA Beluga H Group (6065' to 6784' MD; 5050' to 5770' SSTVD Drill Rate (ft/hr) Total Gas (units • Maximum Minimum Average Maximum Minimum Average 366 *2 65 627 *1 84 *Note: Occurred during coring operations. This section is composed of interbedded sandstone /conglomeratic sand, siltstone, claystone and coals. Material is tuffaceous throughout, with some non tuffaceous intervals. No oil indicators were found in this section. Sand /Sandstone = medium to light gray; firm to disconsolidated; moderately to locally well sorted; medium lower to medium upper and fine lower; locally very fine upper well sorted; angular to sub - angular; 60% white to trans - parent quartz; 40% light to medium gray Iithics; trace dark mafic mineral in the medium grain sand; at 6570 trace to common coarse grain sand and angular dark gray pebble fragments; mixed grain and matrix support; some medium grain suspended in soft ash /clay matrix; interbedded with tuffaceous and non tuffaceous siltstone and claystone; trace medium sand has abundant fine carbonaceous inclusions; siltstone locally has abundant carbonaceous micro - lamina; slightly to moderately calcareous. Tuffaceous Siltstone = dark gray to medium gray with some Tight gray with brownish black and black hues; mostly clotted to very clumpy in places; irregular fracture; mostly massive to amorphous cuttings habit; dull to earthy luster; very silty to gritty texture; interbedded with sand and sandstone and carbonaceous materials and tuffaceous claystone throughout; predominantly thinly to very thinly bedded. Coal = very dark brownish gray to black; firm to hard; brittle; hackly; angular irregular to slightly blocky fragments; sub - bituminous; slightly lignitic in part; common silty carbonaceous material; trace carbonaceous shale; trace sand, siltstone, heavily carbonaceous siltstone, thin fine upper grain angular quartz sand and clay interbeds. 13 • CANRIG ConocoPhillips Alaska, Inc. BRU- 232 -23 • Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 6067 180 34286 NA NA NA NA NA NA 6104 246 46871 NA NA NA NA NA NA 6145 627 119288 NA NA NA NA NA NA 6194 200 38977 NA NA NA NA NA NA 6225 201 38301 NA NA NA NA NA NA 6257 159 29352 NA NA NA NA NA NA 6301 120 23557 NA NA NA NA NA NA 6312 152 28112 NA NA NA NA NA NA 6397 144 26846 NA NA NA NA NA NA 6479 18* 3559 NA NA NA s NA NA NA 6518 87 16703 NA NA NA NA NA NA 6590 113 21164 NA NA NA NA NA NA 6644 70 13623 NA NA NA NA NA NA 6692 91 17027 NA NA NA NA NA NA *Note: Occurred during coring operations. Beluga I Group (6784 to 7587' MD; 5770' to 6668' SSTVD) I Drill Rate (ftlhr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 169 *1.5 60 150 *1 46 *Note: Occurred during coring operations. 0 This section is predominantly massive to moderate beds of sandstone interbedded with thinner claystone, siltstone and coals. Typically the formation is tuffaceous at least in part and locally is dominated by tuffaceous /clayey matrix material. No oil indicators were found in this section. Sand /sandstone = light to medium light gray to gray brown; firm to disconsolidated; friable in part, very fine upper to fine lower to very fine lower grain; occasional trace medium lower and larger grain up to small pebble fragments; predominantly matrix supported with partial grain support; locally displays fair visible porosity, particularly in the finer grain material; angular to sub - angular translucent quartz predominates; trace dark mafic grains; common lithics in the larger grain sizes; interbedded with tuffaceous and non tuff silts and clays; thin to micro lamina of carbonaceous material, and plant remains throughout; occasional thin to moderate coals;; matrix is light gray to brownish gray clay /silt; gray to brownish gray clay /ash; non to trace calcareous; samples contaminated with safe -carb. Tuffaceous claystone = very light gray to gray with occasional brownish gray hues; poor to moderate induration; mostly crumbly to crunchy; irregular fracture; amorphous to slight platy cuttings habit; earthy to dull luster; overall silty texture with an abundant amount of dark colored Iithic fragments throughout; very thick beds of tuffaceous claystone interbedded with moderate to thin beds of sand with some sandstone. Tuffaceous siltstone /claystone (7440 -7480) = light to medium light gray; brownish secondary hue in part; dull earthy to silky luster; smooth to gritty texture occurs as thin to moderate interbeds in associated sandstone; some cuttings display clean non gradational boundary; hydrophilic; trace to common dark gray to black silty carbonaceous shale and thin to micro -thin carbonaceous lamina. Coal = black to brownish black with some reddish black; cuttings are crumbly, with a splintery fracture, resulting in the flaky habit; broken surfaces have a waxy luster and a matte texture; the coal is moderately bedded and contains tougher shaly laminae throughout; interbedded with siltstone and some very thin lenses of sand, containing minor lenses of medium to coarse grained sand. • 14 CAN RIG IV ConocoPhillips Alaska, ln . BRU- 232 -23 • Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 6792 130 25938 21 NA NA NA NA NA 6878 *20 4354 NA NA NA NA NA NA 6920 *16 2939 NA NA NA NA NA NA 6957 74 13786 NA NA NA NA NA NA 6975 81 15301 NA NA NA NA NA NA 7031 84 16249 NA NA NA NA NA NA 7068 70 13629 NA NA NA NA NA NA 7121 76 14495 NA NA NA NA NA NA 7193 40 8389 NA NA NA NA NA NA 7231 77 17521 NA NA NA NA NA NA 7324 112 22187 NA NA NA NA NA NA 7357 123 23888 NA NA NA NA NA NA 7393 150 20644 NA NA NA NA NA NA 7559 134 23177 NA NA NA NA NA NA *Note: Occurred during coring operations. 3.3 Connection Gases lunit = 0.05% Methane Equivalent • Depth Gas over BGG Depth Gas over BGG (feet) (units) (feet) (units) None Noted 3.4 Trip (Wiper) Gases lunit = 0.05% Methane Equivalent Depth Trip to Gas (feet) (feet) (units) 4748' Surface' 36 6503 Surface' 17295 6615 Surface' 69 6897 Surface' 16 WG 7587 3570 94 15 • CANRRIG Conoc Phillips Alaska Inc. BRU- 232 -23 • 3.5 Sampling Program / Sample Dispatch Set Type / Purpose Frequency Interval Dispatched to CPAI Washed Samples 30' 3760' — 4750' Bayview Geologic Facility A 619 owner: CPAI 10' 4760' -7587' 619 East Ship Creek Ave Ste 14 Anchorage, AK 99501 Attn: D. Przywojski 265 -6340 Set Type / Purpose Frequency Interval Dispatched to CPAI Washed Samples 30' 3760' — 4750' Bayview Geologic Facility B Set owner: CPAI 10' 4760' -7587' 619 East Ship Creek Ave Ste 14 Anchorage, AK 99501 Attn: D. Przywojski 265 -6340 7 Sample frequency was locally altered according to drill rate constraints and zones of interest. • • 16 CANRIG •i • ConocoPhillips Alaska. Inc BRU- 232 -23 4 PRESSURE / FORMATION STRENGTH DATA The pore pressure gradient (PPG) is estimated to have varied from 9.5 in the Sterling A Group to 9.6 in the Beluga I Group. The mud weight was raised from 9.2 ppg to 9.6 before drilling the Beluga I formation. 4.1 Pore Pressure Gradient Evaluation Formation Primary Secondary Interval Tops Pore Pressure (EMW) Trend Lithology Lithology MD SSTVD Min Max Interval ( %) ( %) (ft) (ft) (ppg) (ppg) Trend Indicators Sterling A Sltst, Sh Sn, Co 4121 2895 9.4 9.6 Slight FG,CG Increase Sterling B TffSIst, Sn, Co 4324 3163 9.4 9.6 Slight FG,CG,TG TffClyst, Sltst Increase Sterling C TffClyst, Sn, Co 4486 3341 9.4 9.6 Slight FG,CG, TG TffSltst Increase Beluga D TffSIst, TffClyst Sn, Co 4655 3489 9.4 9.6 Slight FG,CG, TG Increase Beluga E TffSlst, Sn, Co 4919 3649 9.3 9.5 Slight FG,CG, TG TffClyst, Sltst Increase TffSIst, Sn, Co Slight Beluga F TffClyst, Sltst, 5298 3906 9.3 9.5 Increase FG,CG, TG Sh Beluga G TffSIst, Sn, Co 5730 4284 9.3 9.5 Slight FG,CG, TG TffClyst, Sltst Increase Beluga H Clyst, Sh, Sltst, Sn, Co 6065 4716 9.3 9.6 Slight FG,CG, TG TffSltst Increase Beluga I Clyst, Sh, Sltst, Sn, Co 6784 5050 9.8 9.6 Slight FG,CG, TG TffSltst, Increase NOTE: TffClyst = Tuffaceous Claystone, TffSltst= Tuffaceous Siltstone, Clyst = Claystone /Clay, Sd = Sand, Sltst = Siltstone, Sh = Shale, Sn = Sand, Coal =Co 17 Comp • . . ConocoPhitllips Alaska. Inc. BRU- 232 -23 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 Epoch, and then modified using the indicators described above, and 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 establish a PPG range, when establishing trends, as with DXC data, with data points in shale intervals. 18 CANRIG Conoc Phillips Alaska, Inc. BRU- 232 -23 0 5 DRILLING DATA 5.1 Survey Data Measured True Latitude Departure Vertical Dogleg Depth Incl. Azom. Vertical (ft) (ft) Section Rate (ft) O O Depth (ft) N( +), S(-) E( +), W(-) (ft) ( ° /100ft) 18.50 0.00 0.00 18.50 0.00 0.00 0.00 TIE -IN 163.73 0.64 140.01 163.73 0.62 0.52 -0.62 0.44 219.00 0.67 140.89 218.99 1.10 0.92 -1.09 0.06 280.63 0.39 148.42 280.62 1.56 1.25 -1.50 0.46 343.30 1.20 295.01 343.29 1.46 0.77 -1.01 2.46 399.76 2.18 291.35 399.72 0.82 0.76 0.61 1.74 454.60 3.30 290.99 454.50 0.12 3.21 3.18 2.06 521.76 4.74 285.43 521.49 1.56 7.69 7.85 2.22 581.83 5.74 278.06 581.31 2.64 13.06 13.32 1.99 641.05 7.38 276.16 640.14 3.46 19.78 20.08 2.80 700.98 8.90 275.69 699.46 4.33 28.21 28.54 2.53 761.83 10.28 275.52 759.46 5.32 38.30 38.64 2.27 826.82 11.44 273.95 823.29 6.32 50.50 50.83 1.85 888.71 13.08 273.66 883.76 7.19 63.62 63.90 2.65 952.07 15.18 272.88 945.20 8.07 79.06 79.26 3.32 1016.52 16.82 271.77 1007.16 8.78 96.81 96.86 2.59 • 1077.46 18.48 270.55 1065.23 9.14 115.28 115.11 2.79 1144.36 20.43 269.96 1128.30 9.24 137.56 137.07 2.93 1204.74 22.45 270.06 1184.50 9.24 159.63 158.81 3.35 1271.87 24.49 271.22 1246.08 9.55 186.36 185.19 3.11 1335.86 26.50 272.22 1303.83 10.39 213.88 212.44 3.21 1394.88 28.53 272.27 1356.17 11.46 241.13 239.45 3.46 1459.61 30.47 272.61 1412.51 12.82 272.98 271.05 3.00 1522.29 32.20 272.64 1466.04 14.31 305.54 303.38 2.76 1584.99 33.78 272.25 1518.63 15.77 339.65 337.22 2.53 1649.40 35.3.5 271.02 1571.67 16.80 376.17 373.37 2.67 1712.74 37.11 271.25 1622.76 17.54 413.60 410.36 2.79 1776.21 38.92 271.42 1672.76 18.45 452.68 449.01 2.86 1839.41 40.59 272.16 1721.35 19.72 493.08 489.01 2.74 1902.96 42.88 272.58 1768.77 21.47 535.34 530.93 3.62 1967.03 45.68 273.08 1814.64 23.68 280.01 575.31 4.41 2030.57 47.45 273.48 1858.32 26.32 626.07 621.13 2.83 2092.23 49.18 272.97 1899.32 28.91 672.04 666.85 2.87 2456.58 50.57 273.31 1940.79 31.60 721.18 715.71 2.20 2218.82 51.25 272.58 1980.03 34.08 769.42 763.65 1.42 2284.19 52.04 271.73 2020.60 36.00 820.65 814.43 1.57 2349.30 52.61 271.66 2060.39 37.53 872.16 865.42 0.89 2406.48 52.46 271.42 2095.18 38.75 917.52 910.31 0.43 2475.03 51.66 271.20 2137.33 39.98 971.57 963.75 1.19 III 19 CANRIG Conoc Phillips Alaska, Inc. BRU- 232 -23 O 2539.12 51.20 271.57 2177.29 41.19 1021.66 1013.29 0.85 2602.20 51.23 271.50 2216.80 42.51 1070.81 1061.93 0.11 2666.16 51.74 271.44 2256.63 43.80 1120.84 1111.42 0.80 2729.56 52.22 272.50 2295.68 45.52 1170.76 1160.88 1.52 2792.01 51.66 271.49 2334.18 47.23 1219.90 1209.57 1.57 2854.41 52.43 272.29 2372.56 48.85 1269.07 1258.27 1.60 2917.80 51.81 271.85 2411.48 50.66 1319.07 1307.83 1.11 2982.11 52.00 271.52 2451.16 52.15 1369.66 1357.91 0.49 3045.55 52.48 271.78 2490.00 53.59 1419.80 1407.53 0.82 3108.60 52.03 271.52 2528.56 55.03 1469.67 1456.89 0.64 3171.34 51.57 270.23 2567.31 55.78 1519.00 1505.60 1.85 3235.68 51.16 269.23 2607.49 55.54 1569.25 1555.06 1.37 3299.40 49.88 269.25 2648.00 54.89 1618.43 1603.37 2.01 3362.58 50.30 269.68 2688.53 54.44 1666.89 1651.02 0.84 3427.18 49.54 269.46 2730.13 54.07 1716.32 1699.63 1.20 3489.63 47.23 268.54 2771.60 53.26 1763.00 1745.46 3.86 3552.75 45.64 267.75 2815.10 51.79 1808.71 1790.22 2.68 3616.54 44.53 268.64 2860.13 50.36 1853.86 1834.44 1.99 3677.50 42.72 269.70 2904.26 49.75 1895.91 1875.75 3.21 3704.77 42.06 270.47 2924.40 49.77 1914.30 1893.86 3.09 3787.20 41.01 269.93 2986.10 49.97 1968.95 1974.71 1.35 3851.22 38.91 270.17 3035.17 50.00 2010.06 1988.21 3.29 3908.70 36.71 270.40 3080.58 50.18 2045.30 2022.94 3.84 • 3972.05 34.83 270.47 3131.98 50.46 2082.32 2059.45 2.97 4027.23 32.55 270.55 3177.89 50.60 2112.93 2089.61 4.14 4103.49 30.35 269.61 3242.95 50.49 2152.71 2128.77 2.90 4158.46 29.28 269.07 3290.64 50.17 2180.04 2155.63 2.01 4227.62 28.02 269.14 3351.33 49.65 2213.20 2188.19 1.82 4287.02 26.72 268.66 3404.07 49.13 2240.51 2215.00 2.19 4346.64 25.10 269.73 3457.69 48.76 2266.57 2240.60 2.87 4414.44 23.31 269.46 3519.53 48.57 2294.36 2267.67 2.63 4477.60 21.50 270.95 3577.92 48.64 2318.43 2291.66 3.00 4539.27 19.68 271.35 3635.65 49.07 2340.12 2313.09 2.96 4603.40 18.05 270.43 3696.33 49.41 2360.85 2333.56 2.59 4667.14 16.10 271.42 3757.26 49.70 2379.56 2352.04 3.09 4734.72 13.66 269.82 3822.57 49.71 2396.91 2369.16 3.66 4767.82 13.01 269.25 3854.77 49.85 2404.55 2376.67 2.00 4832.08 11.36 270.73 3917.59 49.83 2418.11 2390.02 2.62 4956.27 8.82 267.98 4039.81 49.38 2440.04 2411.55 2.32 5012.62 7.53 270.54 4095.59 49.26 2448.06 2419.42 2.38 5080.06 5.79 274.05 4162.57 49.54 2455.87 2427.17 2.65 5145.53 4.50 274.55 4227.77 49.98 2461.73 2433.01 1.97 5176.41 3.59 268.85 4258.58 50.06 2463.90 2435.16 3.22 5208.59 2.89 267.82 4290.70 50.00 2465.72 2436.94 2.18 5270.07 2.72 263.05 4352.11 49.77 2468.72 2439.85 0.74 5335.19 2.04 245.71 4417.18 49.10 2471.31 2442.29 1.51 5461.32 1.93 238.44 4543.24 47.06 2474.95 2445.52 0.18 20 • CANRIG Conoc Phillips Alaska, Inc BRU- 232 -23 O 5526.29 1.70 238.45 4608.17 45.98 2476.71 2447.06 0.35 5588.69 0.28 223.47 4670.56 45.38 2477.60 2447.84 2.29 5650.26 0.76 100.37 4732.13 45.20 2477.30 2447.52 1.53 5713.87 0.98 84.08 4795.73 45.18 2476.35 2446.57 0.52 5776.30 0.94 88.32 4858.15 45.25 2475.30 2445.56 0.13 5839.79 1.20 91.64 4921.63 45.25 2474.12 2444.39 0.42 5902.95 1.06 89.42 4984.78 45.23 2472.87 2443.16 0.23 5965.83 1.03 101.77 5047.65 45.12 2471.74 2442.02 0.36 6027.92 1.06 108.94 5109.73 44.82 2470.65 2440.90 0.22 6091.19 1.13 113.24 5172.99 44.39 2469.52 2439.71 0.17 6155.60 1.39 105.05 5237.38 43.93 2468.18 2438.32 0.49 6215.50 1.36 109.75 5297.27 43.51 2466.81 2436.89 0.19 6282.47 1.28 114.84 5364.22 42.92 2465.39 2435.39 0.21 6372.27 1.18 112.66 5454.00 42.15 2463.62 2433.51 0.12 6435.36 1.23 112.33 5517.07 41.64 2462.40 2432.22 0.08 6498.16 1.34 119.61 5579.86 41.02 2461.14 2430.87 0.31 6547.16 1.25 127.67 5628.85 40.41 2460.21 2429.85 0.41 6561.96 1.26 128.59 5643.64 40.21 2459.96 2429.57 0.15 6624.71 1.37 128.77 5706.38 39.31 2458.84 2428.31 0.18 6687.42 1.38 124.29 5769.07 38.41 2457.63 2426.96 0.17 6751.73 1.45 120.02 5822.36 37.57 2456.28 2425.49 0.20 6819.05 1.36 117.97 5900.66 36.77 2454.84 2423.93 0.15 6876.78 1.25 123.37 5958.37 36.10 2453.71 2422.70 0.29 6938.53 1.33 121.71 6020.11 35.36 2452.54 2421.42 0.14 • 7004.25 1.24 120.97 6085.81 34.59 2451.28 2420.04 0.14 7061.00 1.16 127.51 6142.55 33.92 2450.30 2418.96 0.28 7129.11 1.13 130.06 6210.64 33.07 2449.23 2417.77 0.09 7190.94 1.13 138.59 6272.46 32.22 2448.36 2416.76 0.27 7254.05 1.20 138.44 6335.56 31.26 2447.52 2415.76 0.11 7319.27 1.16 133.39 6400.77 30.30 2446.58 2414.67 0.17 7380.36 1.30 133.05 6461.84 29.40 2445.63 2413.58 0.23 7444.25 1.37 135.37 6525.71 28.36 2444.56 2412.35 0.14 7505.36 1.47 134.53 6586.81 27.29 2443.49 2411.10 0.17 7587.00 1.47 134.53 6668.42 25.82 2442.00 2409.38 0.00 21 O CANRIG II i it S Alaska. Inc. BRU- 232 -23 5.2 Bit Record Depth In Total Bit Aug WOB PP Bit Size Make Type / S# Jets / TFA MD / Footage Hrs (fRt/Ohr) (Klbs) RPM (psi) Wear BHA 2 8.75" Hughes HCM506Z 3x14, 3x13, 3755' 1293' 13.41 90.9 8 =35 185 1936 #2 # 7114472 0.840 RR2 8.75" Hughes HCM506Z 3x14, 3x3 4748' 1664' #3 #7114472 0.840 3 8.75" Hughes BHC406Z 0.780 6412' 91' #4 #7119053 4 8.75" Hughes HCM506Z 3x14, 3x13 6503' 117' #5 #7110224 0.840 4rr1 8.75" Hughes HCM506Z 3x14, 3x13 6620' 219' #6 #7110224 0.840 3rr1 8.75" Hughes 71190 Z 0.780 6839' #7 #7119053 22 CANRIG • It S ConocoPhillips Alaska, Inc. BRU- 232 -23 5.3 Mud Record Contractor: MI SWACO Mud Type: LSND Date Depth MW VIS PV YP Gels FL FC Sols O/W Sd CI Ca (ppg) (s /qt) (cc) ( %) Ratio ( %) pH (m1/1) (m1/1) 08/08/09 3755 9.6 60 14 22 8/11/13 7 2 8 1/92 0.52 8.2 200 80 08/09/09 3755 9.6 65 17 17 4/5/6 4.7 2 8.5 /92 tr 20.0 62000 80 08/10/09 3945 9.6 50 16 16 5/5/6 4.7 2/2 9 /91 1.5 10 72000 100 08/11/09 4749 9.7 54 19 25 11/13/14 4.3 2/2 9 1/91 1.2 10 71000 80 08/12/09 5040 9.7 57 19 30 14/16/17 3.6 1/2 10 2/88 1 10 70000 80 08/13/09 5640 9.6 48 18 24 9/11/12 3.4 1/1 10 1/89 1 9.9 68000 80 08/14/09 6301 9.7 56 22 29 10/12/13 3.7 2/2 10 1/89 0.75 10 60000 80 08/15/09 6412 9.8 66 30 36 9/13/14 4.9 1/1 12 1/87 1.25 9.9 50000 60 08/16/09 6412 9.8 60 28 36 9/11/13 4.3 1/1 11 1/89 1 9.9 48000 60 08/17/09 6412 9.8 76 29 34 9/11/12 4.2 1/1 11 1/89 1 9.9 48000 60 08/18/09 6503 9.8 77 29 34 8/12/13 4.1 1/1 12 1/88 1 10 53000 60 08/19/09 6503 9.8 84 29 34 9/12/13 4.1 1/1 11 1/89 1 9.9 55000 60 08/20/09 6620 9.8 73 27 35 9/11/12 3.9 1/2 11.5 1/88 1.25 9.9 55000 60 08/21/09 6839 9.9 68 31 32 9/11/12 1.0 1/2 11.5 1/88 .75 9.9 55000 60 08/22/09 6897 9.9 84 33 37 10/12/13 5.2 1/2 11.5 1/88 0.75 9.9 53000 80 08/23/09 6897 9.9 84 30 35 10/11/12 5.1 2/2 12 1/88 0.65 9.9 48000 80 08/24/09 6947 10.0 86 35 35 12/13/14 4.2 1/1 12 1/87 1 9.9 52000 60 08/25/09 6947 9.9 91 30 33 9/10/12 4.3 2/1 12 2/87 1 10.0 49000 60 08/26/09 7587 9.8 53 23 26 7/9/10 4.0 2/1 12.5 3/85 0.5 9.9 47000 40 08/27/09 7587 9.8 55 25 21 7// 4.2 1/1 12.5 3/85 0.5 9.9 47000 40 Abbreviations MW = Mud Weight Gels = Gel Strength Sd = Sand content ECD = Effective Circulating Density WL = Water or Filtrate Loss CI = Chlorides VIS = Funnel Viscosity FC = Filter Cake Ca = Hardness Calcium PV = Plastic Viscosity Sols = Solids O/W = Oil to Water ratio YP = Yield Point 23 CANRIG 6 DAILY REPORTS • 24 • CANRIG ConocoPhillips Alaska Inc. BRU 232 -23 • Daily Report Report for: Donny Lutrick Scott Heim Date: 8/05/2009 Time: 0600 Current Depth (MD): 3756 Current Current Depth Operations: Epoch rigging up (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: CI Ca + + : MW Change: Depth: None From: To: Reason: Mud Loss event: Depth: None Volume: Gas Data Ditch Gas: Current: Max: I Depth (MD/TVD): Avg BG • Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection C1 C2 C3 C4I C4N C5I C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Epoch continue rigging up. Rig crew rigging up to test cement lines and cement casing. Calibrations: Chromatograph, THA. Failures: None Daily Cost: 2410.00 E{ EPOCH ConocoPhillips Alaska Inc. • BRU 232 -23 Daily Report Report for: Donny Lutrick Scott Heim Date: 8/06/2009 Time: 0600 Current Depth (MD): 3756 Current Current Depth Operations: Rig up to test BOPs (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: CI Ca + +: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: I Max: I Depth (MD/TVD): • Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection C1 C2 C3 C41 C4N C5I C5N Gases None Gas Samples No. Depth (MD/1VD) TG Cl C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Epoch rigged up, TOTCO WITS issues are only outstanding item. Continue rig up Operational Summary: and test cement lines. Pump cement as per plan. Clean and flush cement equipment and stack. Clear cellar and remove excess cement. Nipple down BOPS. Nipple up new BOP stack. Rig up to test BOPs. Calibrations: Chromatograph, THA. Failures: None • Daily Cost: 2410.00 EI EPOCH ConocoPhillips Alaska Inc. • BRU 232 -23 Daily Report Report for: Donny Lutrick Scott Heim Date: 8/07/2009 Time: 0600 Current Depth (MD): 3756 Current Current Depth Operations: Continue to test BOPs (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl Ca + +: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: I Max: I I Depth (MD/TVD): 1 Ili Avg BG : Gas Events Depth (MD/TVD) Cl C2 C3 C41 C4N C5I C5N Trip Gas Connection Cl C2 C3 C4I C4N C5I C5N Gases None Gas Samples No. Depth (MD/TVD) TG Cl C2 C3 C41 C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Continue to test BOPs. Calibrations: Chromatograph, THA. Failures: None Daily Cost: 3070.00 • El EPOCH ConocoPhillips Alaska Inc. BRU 232 -23 • Daily Report Report for: Donny Lutrick Scott Heim Date: 8/08/2009 Time: 0600 Current Depth (MD): 3756 Current Current Depth Operations: Lay down 5" drill pipe (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl Ca + +: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: I Max: I I Depth (MD/TVD): Avg BG : • Gas Events Depth (MD/TVD) Cl C2 C3 C41 C4N C51 C5N Trip Gas Connection Cl C2 C3 C4I C4N C51 C5N Gases None Gas Samples No. Depth (MD/TVD) TG Cl C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Lay down 5' drill pipe. Calibrations: Chromatograph, THA. Failures: None Daily Cost: 3070.00 III El EPOCH ConocoPhillips Alaska Inc. BRU 232 -23 Daily Report Report for: Donny Lutrick Scott Heim Date: 8/09/2009 Time: 0600 Current Depth (MD): 3756 Current Single in with 4" drill Current Depth Operations: pipe. (TVD): 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf -Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: CI Ca + + MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: I Max: I I Depth ( MD/TVD): • Avg BG : Gas Events Depth (MD/TVD) Cl C2 C3 C4I C4N C5I C5N Trip Gas Connection C1 C2 C3 C41 C4N C51 C5N Gases None Gas Samples No. Depth (MD/TVD) TG Cl C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Pick up BHA and single in with 4" drill pipe. Calibrations: None Failures: None Daily Cost: 3270.00 • HI EPOCH ConocoPhillips Alaska Inc. • BRU 232 -23 Daily Report Report for: Donny Lutrick Scott Heim Date: 8/10/2009 Time: 0600 Current Depth (MD): 4055 Current Current Depth Operations: Drill Ahead (TVD): 24 hr Footage (MD): 298 Drilling Parameters ROP: Current: 55.6 Max: 279.3 Torque: Current: Max: WOB: Current 18.7 Max: 35 RPM: Current: Max: PP: Current: 1855 Max: 2210 Lag: Strokes: 4917 Time: 18:01 Surf -Surf: Strokes: Time: ECD: Current: Max: Mud Pro erties @ 3945' MW: 9.6 FV: 50 PV: 16 YP: 16 FL: 4.7 Gels: Sol: 9 pH: 10 CI 72000 Ca + +: 100 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: I I Depth ( MD/TVD): • Avg BG : 18 72 4019 MD Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C51 C5N Trip Gas NA Connection NA C1 C2 C3 C41 C4N C5I C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Tuffaceous claystone, tuffaceous siltstone, siltstone and sand. Last 24 hrs: Siltstone, coal and sand. Single in with 4" drill pipe to 3456', conduct casing pressure test, continue to trip to Operational Summary: bottom, condition mud, drill out cement and shoe, drill 20' feet of new formation, perform FIT test @3775' 16.0 PPG, drill ahead. Calibrations: None Failures: None Daily Cost: 3270.00 • El EPOCH ConocoPhillips Alaska Inc. BRU 232 -23 • Daily Report Report for: Donny Lutrick Scott Heim Date: 8/11/2009 Time: 0600 Current Depth (MD): 4750 Current Current Depth Operations: P.O.O.H. for BHA. (TVD): 24 hr Footage (MD): 695 Drilling Parameters ROP: Current: NA Max: 280 Torque: Current: NA Max: 0 WOB: Current NA Max: 33 RPM: Current: NA Max: 185 PP: Current: NA Max: 2367 Lag: Strokes: 5804 Time: 21:26 Surf -Surf: Strokes: 7336 Time: 27:27 ECD: Current: Max: Mud Properties @ 4749' MW: 9.7 FV 54 PV 19 YP 25 FL 4.3 Gels: 11/13/14 Sol 9 pH 10 CI 71000 Ca ++ 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: I Max: I Depth ( MD/TVD): Avg BG : 0 235 4713 MD • Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C51 C5N Trip Gas NA Connection NA C1 C2 C3 C41 C4N C51 C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C51 C5N Lithologies: Current: Tuffaceous sandstone, tuffaceous claystone, tuffaceous siltstone. Last 24 hrs: Tuffaceous sandstone, tuffaceous claystone, tuffaceous siltstone. Operational Summary: Drill ahead to 4750', circulate bottoms up. P.O.O.H. to 3867', spot pill, P.O.O.H for BHA. Calibrations: None Failures: None Daily Cost: 3270.00 III HI EPOCH ConocoPhillips Alaska Inc. BRU 232 -23 • Daily Report Report for: Donny Lutrick Scott Heim Date: 8/12/2009 Time: 0600 Current Depth (MD): 5045 Current Current Depth Operations: Drill ahead. (TVD): 24 hr Footage (MD): 295 Drilling Parameters ROP: Current: 89.6 Max: 143.1 Torque: Current: 10227 Max: 12537 WOB: Current 20 Max: 23 RPM: Current: 95 Max: 108 PP: Current: 2290 Max: 2464 Lag: Strokes: 6179 Time: 24:35 Surf -Surf: Strokes: 7786 Time: 30:18 ECD: Current: Max: Mud Properties @ 4749' MW: 9.7 FV 54 PV 19 YP 25 FL 4.3 Gels: l 11/13/14 Sol 9 pH 10 CI 71000 Ca ++ 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 1 Max: 1 1 Depth (MD/TVD): 1 Avg BG : 51 171 • Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C51 C5N Trip Gas 3738' 9045 36U Connection NA C1 C2 C3 C4I C4N C5I C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Sand, siltstone, claystone, shale, tuffaceous claystone, tuffaceous siltstone. Last 24 hrs: Sand, siltstone, claystone, shale, tuffaceous claystone, tuffaceous siltstone. Operational Summary: Pick up new BHA with MRIL tool, trip in hole to bottom, circulate bottoms up, 36 units trip gas, drill ahead. Calibrations: None Failures: None Daily Cost: 3270.00 • EPOCH ConocoPhillips Alaska Inc. BRU 232 -23 • Daily Report Report for: Donny Lutrick Scott Heim Date: 8/13/2009 Time: 0600 Current Depth (MD): 5705 Current Current Depth Operations: Drill ahead. (TVD): 24 hr Footage (MD): 660 Drilling Parameters ROP: Current: 89.6 Max: 352 Torque: Current: 10335 Max: 12868 WOB: Current 12 Max: 24 RPM: Current: 87 Max: 102 PP: Current: 1326 Max: 2502 Lag: Strokes: 6179 Time: 27:22 Surf -Surf: Strokes: 8801 Time: 34:11 ECD: Current: Max: Mud Properties @ 5640' MW: 9.6 FV 48 PV 18 YP 24 FL 3.4 Gels: 9/11/12 Sol 10 pH 9.9 CI 68000 Ca ++ 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 1 Max: 1 1 Depth (MD/TVD): Avg BG : 115 303 5311' Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C5I C5N Trip Gas NA Connection NA C1 C2 C3 C41 C4N C5I C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C51 C5N Lithologies: Current: Tuffaceous sand, tuffaceous claystone, and tuffaceous siltstone. Last 24 hrs: Tuffaceous sand, tuffaceous claystone, and tuffaceous siltstone. Operational Summary: Drill and slide ahead from 5045' to 5705'. Calibrations: None Failures: None Daily Cost: 3270.00 EI EPOCH ConocoPhillips Alaska Inc. BRU 232 -23 • Daily Report Report for: Donny Lutrick Scott Heim Date: 8/14/2009 Time: 0600 Current Depth (MD): 6301 Current Short trip at 6301' to Current Depth Operations: 4750'. (TVD): 24 hr Footage (MD): 596' Drilling Parameters ROP: Current: NA Max: 482 Torque: Current: NA Max: 12423 WOB: Current NA Max: 40 RPM: Current: NA Max: 101 PP: Current: NA Max: 2806 Lag: Strokes: 7782 Time: 32:29 Surf -Surf: Strokes: 9712 Time: 40:30 ECD: Current: Max: Mud Pro erties @ 6301' MW: 9.7 FV 56 PV 22 YP 29 FL 3.7 Gels: 10/12/13 Sol 10 pH 10 CI 60000 Ca ++ 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 1 Max: 1 1 Depth (MD/TVD): Avg BG : 25 627 6145' • Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C51 C5N Trip Gas NA I Connection NA C1 C2 C3 C4I C4N C5I C5N Gases None Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Sandstone, sand, siltstone, tuffaceous claystone, and tuffaceous siltstone, and coals. Last 24 hrs: Sandstone, sand, siltstone, tuffaceous claystone, and tuffaceous siltstone, and coals. Operational Summary: Drill ahead from 5705' to 6301', circulate bottoms up, conduct short trip from 6301' to 4750'. Calibrations: None Failures: None • Daily Cost: 3270.00 PI EPOCH ConocoPhillips Alaska Inc. • BRU 232 -23 Daily Report Report for: Donny Lutrick Scott Heim Date: 8/15/2009 Time: 0600 Current Depth (MD): 6412 Current Circulate and condition Current Depth Operations: mud. (TVD): 24 hr Footage (MD): 111' Drilling Parameters ROP: Current: NA Max: 365 Torque: Current: NA Max: 8978 WOB: Current NA Max: 7 RPM: Current: NA Max: 96 PP: Current: NA Max: 2648 Lag: Strokes: 7924 Time: 33:28 Surf-Surf: Strokes: 9803 Time: 41:41 ECD: Current: Max: Mud Properties @ 6412' MW: 9.8 FV 66 PV 30 YP 36 FL 4.2 Gels: 9/13/14 Sol 12 pH 9.9 CI 50000 Ca ++ 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 1 Max: ] Depth ( MD/TVD): Avg BG : 15 152 6312' 0 Gas Events Depth (MD/TVD) 01 C2 C3 C41 C4N C5I C5N Trip Gas 6301' 35144 60u Connection NA 01 C2 C3 C4I C4N C51 C5N Gases None Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Sandstone, sand, siltstone, tuffaceous claystone, and tuffaceous siltstone, and coals. Last 24 hrs: Sandstone, sand, siltstone, tuffaceous claystone, and tuffaceous siltstone, and coals. Conduct short trip from 6301' to 4750', circulate bottoms up, trip back to bottom, Operational Summary: circulate bottoms up, max gas 60u, drill ahead from 6301' to 6412, circulate and condition mud. Calibrations: None Failures: None • Daily Cost: 3270.00 El EPOCH ConocoPhillips Alaska Inc. BRU 232 -23 0 Daily Report Report for: Donny Lutrick Jeff Browning Date: 8/16/2009 Time: 0600 Current Depth (MD): 6412 Current Current Depth Operations: Lay down BHA. (TVD): 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: NA Max: NA Torque: Current: NA Max: NA WOB: Current NA Max: NA RPM: Current: NA Max: NA PP: Current: NA Max: NA Lag: Strokes: 7924 Time: 33:28 Surf-Surf: Strokes: 9803 Time: 41:41 ECD: Current: Max: Mud Properties @ 6412' MW: 9.8 FV 66 PV 30 YP 36 FL 4.2 Gels: 9/13/14 Sol 12 pH 9.9 CI 50000 Ca ++ 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 1 Max: 1 1 Depth (MD/TVD): 1 Avg BG : NA • Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas 6412' 24u Connection NA C1 C2 C3 C4I C4N C5I C5N Gases None 1 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Sandstone, sand, siltstone, tuffaceous claystone, and tuffaceous siltstone, and coals. Circulate and condition mud, pull five stands, circulate, go back to bottom, Operational Summary: circulate, max gas 24u, add core tracer to mud, circulate 2.5 surface to surface, P.O.O.H, lay down BHA. Calibrations: None Failures: None 0 Daily Cost: 3270.00 U EPOCH ConocoPhillips Alaska Inc. • BRU 232 -23 Daily Report Report for: Donny Lutrick Jeff Browning Date: 8/17/2009 Time: 0600 Current Depth (MD): 6412 Current Work on top drive Current Depth Operations: swivel. (TVD): 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: NA Max: NA Torque: Current: NA Max: NA WOB: Current NA Max: NA RPM: Current: NA Max: NA PP: Current: NA Max: NA Lag: Strokes: 7924 Time: 33:28 Surf -Surf: Strokes: 9803 Time: 41:41 ECD: Current: Max: Mud Properties @ 6412' MW: 9.8 FV 76 PV 29 YP 34 FL 4.1 Gels: 9/11/12 Sol 11 pH 9.9 CI 48000 Ca ++ 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 1 Max: 1 1 Depth (MD/TVD): 1 • Avg BG : NA Gas Events Depth ( MD/TVD) 01 C2 C3 C4I C4N C5I C5N Trip Gas Connection 01 C2 C3 C4I C4N C5I C5N Gases None Gas Samples No. Depth (MD/TVD) TG 01 C2 C3 C41 C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Lay down BHA, pick up core barrel BHA assembly, trip in hole to 5380', pull back out to 3690', work on top drive swivel. Calibrations: None Failures: None Daily Cost: 3270.00 Ei EPOCH ConocoPhiltips Alaska Inc. • BRU 232 -23 Daily Report Report for: Donny Lutrick Jeff Browning Date: 8/18/2009 Time: 0600 Current Depth (MD): 6503' Current Trip out of hole with Current Depth Operations: core barrel. (TVD): 24 hr Footage (MD): 91' Drilling Parameters ROP: Current: NA Max: 59 Torque: Current: NA Max: 11778 WOB: Current NA Max: 13 RPM: Current: NA Max: 94 PP: Current: NA Max: 930 Lag: Strokes: 8036 Time: 68:37 Surf-Surf: Strokes: 9807 Time: 82:41 ECD: Current: Max: Mud Properties @ 6503' MW: 9.8 FV 77 PV 29 YP 34 FL 4.1 Gels: 8/12/13 Sol 12 pH 10 CI 53000 Ca ++ 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 1 Max: 1 1 Depth (MD/TVD): 1 Avg BG : _ NA 18 6479' MD Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C51 C5N Trip Gas 6412' MD 4921 26u Connection NA C1 C2 C3 C41 C4N C51 C5N Gases None Gas Samples No. _ Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: Work on top drive swivel, trip back to bottom 6412' MD, circulate bottoms up, Operational Summary: commence coring from 6412' MD to 6503' MD, circulate bottoms up, P.O.O.H. with core barrel. Calibrations: None Failures: None Daily Cost: 3270.00 • PI EPOCH ConocoPhillips Alaska Inc. • BRU 232 -23 Daily Report Report for: Larry Hill Jeff Browning Date: 8/19/2009 Time: 0600 Current Depth (MD): 6503' Current Trip in hole with MWD Current Depth Operations: directional BHA. (TVD): 24 hr Footage (MD): 91' Drilling Parameters ROP: Current: NA Max: 59 Torque: Current: NA Max: 11778 WOB: Current NA Max: 13 RPM: Current: NA Max: 94 PP: Current: NA Max: 930 Lag: Strokes: 8036 Time: 68:37 Surf -Surf: Strokes: 9807 Time: 82:41 ECD: Current: Max: Mud Pro erties @ 6503' MW: 9.8 FV 84 PV 29 YP 34 FL 4.1 Gels: 9/12/13 Sol 11 pH 9.9 CI 55000 Ca ++ 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 1 Max: 1 Depth (MD/TVD): 1 Avg BG • Gas Events Depth (MD/TVD) 01 C2 C3 C4I C4N C5I C5N Trip Gas NA Connection NA 01 C2 C3 C4I C4N C5I C5N Gases None Gas Samples No. Depth ( MD/TVD) TG 01 C2 C3 041 C4N C5I C5N Lithologies: Current: Last 24 hrs: O erational Summa P.O.O.H. with core barrel, lay down core barrel BHA and remove core, pick up p ry: MWD directional BHA, trip in hole to 6412' MD. Calibrations: None Failures: None Daily Cost: 3270.00 1111 1 Ell EPOCH ConocoPhillips Alaska Inc. BRU 232 -23 Daily Report Report for: Larry Hill Jeff Browning Date: 8/20/2009 Time: 0600 Current Depth (MD): 6620' Current Trip in hole with MWD Current Depth 5701' Operations: directional BHA. (TVD): 24 hr Footage (MD): 117' Drilling Parameters ROP: Current: NA Max: 140 Torque: Current: NA Max: 12847 WOB: Current NA Max: 12 RPM: Current: NA Max: 101 PP: Current: NA Max: 3150 Lag: Strokes: 8036 Time: 68:37 Surf -Surf: Strokes: 9807 Time: 82:41 ECD: Current: Max: Mud Properties @ 6620' MW: 9.8 FV 84 PV 29 YP 34 FL 4.1 Gels: 9/12/13 Sol 11 pH 9.9 CI 55000 Ca ++ 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: 1 Depth ( MD/TVD): 1 • Avg BG : NA 112 6590' MD Gas Events Depth (MD/TVD) 01 C2 C3 C4I C4N C51 C5N Trip Gas 6503' 29u Connection NA 01 C2 C3 C4I C4N C51 C5N Gases None Gas Samples No. Depth ( MD/TVD) TG 01 C2 C3 C41 C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Trip in hole to 6412' MD, circulate bottoms up max gas 29 units, drill ahead from 6503' MD to 6620' MD, P.O.O.H. for directional BHA. Calibrations: None Failures: None Daily Cost: 3270.00 • HI EPOCH ConocoPhillips Alaska Inc. • BRU 232 -23 Daily Report Report for: Larry Hill Jeff Browning Date: 8/21/2009 Time: 0600 Current Depth (MD): 6839' Current Current De 5920' Operations: Lay down BHA. (TVD): 24 hr Footage (MD): 219' Drilling Parameters ROP: Current: NA Max: 126 Torque: Current: NA Max: 6384 WOB: Current NA Max: 10 RPM: Current: NA Max: 103 PP: Current: NA Max: 2923 Lag: Strokes: 8446 Time: 34:32 Surf -Surf: Strokes: 10152 Time: 41:57 ECD: Current: Max: Mud Properties @ 6839' MW: 9.8 FV 84 PV 29 YP 34 FL 4.1 Gels: 9/12/13 Sol 11 pH 9.9 CI 55000 Ca ++ 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: I Max: Depth (MD/TVD): 1 • Avg BG : NA 130 6793' MD Gas Events Depth ( MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection NA C1 C2 C3 C41 C4N C5I C5N Gases None Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 1 Lithologies: Current: Last 24 hrs: Pick up directional BHA, trip in hole to 6620' MD, circulate bottoms up, max gas 89 Operational Summary: units, drill ahead fro 6620' MD to 6839' MD, circulate bottoms up, short trip, circulate 3X bottoms up and add tracer, circulate 2X bottoms up, P.O.O.H. for core run. Calibrations: None Failures: None • Daily Cost: 3270.00 El EPOCH ConocoPhillips Alaska Inc. • BRU 232 -23 Daily Report Report for: Larry Hill Jeff Browning Date: 8/22/2009 Time: 0600 Current Depth (MD): 6839' Current Current De 5920' Operations: Trip in with core barrel. (TVD): 24 hr Footage (MD): NA Drilling Parameters ROP: Current: NA Max: 126 Torque: Current: NA Max: 6384 WOB: Current NA Max: 10 RPM: Current: NA Max: 103 PP: Current: NA Max: 2923 Lag: Strokes: 8446 Time: 34:32 Surf-Surf: Strokes: 10152 Time: 41:57 ECD: Current: Max: Mud Properties @ 6839' MW: 9.9 FV 68 PV 31 YP 34 FL 1.0 Gels: 9/11/12 Sol 11.5 pH 9.9 CI 55000 Ca ++ 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 1 Max: 1 Depth (MD/TVD): 1 • Avg BG : Gas Events Depth (MD/TVD) 01 C2 C3 C4I C4N C5I C5N Trip Gas NA Connection NA C1 C2 C3 C4I C4N C5I C5N Gases None Gas Samples No. Depth (MD/TVD) TG 01 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: P.O.O.H. for core run, test BOPs, work on draw works, pick up core barrel, trip in hole. Calibrations: None Failures: None Daily Cost: 3270.00 1 IIIIII El EPOCH ConocoPhillips Alaska Inc. BRU 232 -23 • Daily Report Report for: Larry Hill Jeff Browning Date: 8/23/2009 Time: 0600 Current Depth (MD): 6897' Current Current De 5980' Operations: Trip out with core barrel. (TVD): 24 hr Footage (MD): 60' Drilling Parameters ROP: Current: NA Max: 74 Torque: Current: NA Max: 5903 WOB: Current NA Max: 12 RPM: Current: NA Max: 98 PP: Current: NA Max: 2791 Lag: Strokes: 8650 Time: 66:54 Surf -Surf: Strokes: 10426 Time: 80:54 ECD: Current: Max: Mud Properties @ 6897' MW: 9.9 FV 84 PV 33 YP 37 FL 5.2 Gels: 10/12/13 Sol 11.5 pH 9.9 CI 53000 Ca ++ 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data _ Ditch Gas: Current: 1 Max: 1 Depth ( MD/TVD): 1 • Avg BG : NA 27 6890' Gas Events Depth ( MD/TVD) C1 C2 C3 C4I C4N C51 C5N Trip Gas NA Connection NA C1 C2 C3 C4I C4N C5I C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Trip in hole with core barrel, core from 6837' MD to 6897' MD, circulate bottoms up, P.O.O.H. with the core barrel. Calibrations: None Failures: None Daily Cost: 3270.00 1 0 1 El EPOCH ConocoPhillips Alaska Inc. • BRU 232 -23 Daily Report Report for: Larry Hill Jeff Browning Date: 8/24/2009 Time: 0600 Current Depth (MD): 6897' Current Trip in with the core Current Depth 5980' Operations: barrel. (TVD): 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: NA Max: NA Torque: Current: NA Max: NA WOB: Current NA Max: NA RPM: Current: NA Max: NA PP: Current: NA Max: NA Lag: Strokes: 8650 Time: 63:28 Surf -Surf: Strokes: 10426 Time: 80:54 ECD: Current: Max: Mud Properties @ 6897' MW: 9.9 FV 84 PV 30 YP 35 FL 5.1 Gels: 10/11/12 Sol 12 pH 9.9 CI 48000 Ca ++ 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 1 Max: Depth ( MD/TVD): 1 II Avg BG : Gas Events Depth ( MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas NA Connection NA C1 C2 C3 C4I C4N C5I C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C51 C5N Lithologies: Current: Last 24 hrs: Operational Summary: P.O.O.H. with the core barrel, lay down core barrel and remove core, put together new core barrel, and trip in hole. Calibrations: None Failures: None Daily Cost: 3270.00 • El EPOCH ConocoPhillips Alaska Inc. • BRU 232 -23 Daily Report Report for: Larry Hill Jeff Browning Date: 8/25/2009 Time: 0600 Current Depth (MD): 6947' Current Trip out with the core Current Depth 6028" Operations: barrel. (TVD): 24 hr Footage (MD): 50' Drilling Parameters ROP: Current: NA Max: 18 Torque: Current: NA Max: 10772 WOB: Current NA Max: 16 RPM: Current: NA Max: 92 PP: Current: NA Max: 1326 Lag: Strokes: 8732 Time: 64:14 Surf -Surf: Strokes: 10510 Time: 77:12 ECD: Current: Max: Mud Pro erties @ 6947' MW: 10.0 FV 86 PV 35 YP 35 FL 4.2 Gels: 12/13/14 Sol 12 pH 9.9 CI 52000 Ca ++ 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 1 Max: 1 1 Depth ( MD/TVD): 1 • Avg BG : NA 30 6944" Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas 6897' 5963 16u Connection NA C1 C2 C3 C41 C4N C5I C5N Gases None Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: 40% Tuffaceous siltstone, 20% tuffaceous claystone, 10% sandstone, 10% sand, 20% carbonaceous shale Operational Summary: Put together new core barrel, trip in hole, circulate bottoms up, max gas 16 units, core ahead from 6897' MD to 6947' MD, circulate bottoms up, P.O.O.H. Calibrations: None Failures: None Daily Cost: 3270.00 • LI EPOCH ConocoPhillips Alaska Inc. BRU 232 -23 • Daily Report Report for: Larry Hill Scott Heim Date: 8/26/2009 Time: 0600 Current Depth (MD): 6947' Current Mad pass to bottom of Current Depth 6028" Operations: well. (TVD): 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: NA Max: NA Torque: Current: NA Max: NA WOB: Current NA Max: NA RPM: Current: NA Max: NA PP: Current: NA Max: NA Lag: Strokes: 8732 Time: 64:14 Surf -Surf: Strokes: 10510 Time: 77:12 ECD: Current: Max: Mud Properties @ 6947' MW: 9.9 FV 91 PV 30 YP 33 FL 4.3 Gels: 9/10/12 Sol 12 pH 10.0 CI 49000 Ca ++ 60 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: 1 1 Depth (MD/TVD): 1 • Avg BG : NA Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas 6947' 9698 26u Connection NA C1 C2 C3 C4I C4N C5I C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Lay down core barrel and remove core, pick up directional BHA, trip in hole, mad pass to bottom of well. Calibrations: None Failures: None Daily Cost: 3270.00 • PI EPOCH ConocoPhillips Alaska Inc. BRU 232 -23 • Daily Report Report for: Larry Hill Scott Heim Date: 8/27/2009 Time: 0600 Current Depth (MD): 7587' Current Current De 6675' Operations: Circulate bottoms up. (TVD): 24 hr Footage (MD): 640' Drilling Parameters ROP: Current: NA Max: 169 Torque: Current: NA Max: 13958 WOB: Current NA Max: 15 RPM: Current: NA Max: 106 PP: Current: NA Max: 3167 Lag: Strokes: 9482 Time: 69:21 Surf -Surf: Strokes: 11349 Time: 83:21 ECD: Current: Max: Mud Properties @ 7587' MW: 9.9 FV 53 PV 23 YP 26 FL 4.0 Gels: 7/9/10 Sol 12.5 pH 9.9 CI 47000 Ca ++ 40 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 1 Max: 1 1 Depth ( MD/TVD): Avg BG : NA 150 7430' • Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas 7587' 11230 100u Connection NA C1 C2 C3 C4I C4N C5I C5N Gases None Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C4I C4N C51 C5N Lithologies: Current: Last 24 hrs: Mad pass to bottom of well, circulate bottoms up, max gas 26 units, drill ahead Operational Summary: from 6947' MD to 7587' MD, circulate 3x bottoms up, wiper trip, trip back to bottom, circulate bottoms up, max gas 100 units. Calibrations: None Failures: None Daily Cost: 3270.00 • Ell EPOCH ConocoPhillips Alaska Inc. BRU 232 -23 • Daily Report Report for: Larry Hill Scott Heim Date: 8/28/2009 Time: 0600 Current Depth (MD): 7587' Current Current De 6675' Operations: Wireline logging. (TVD): 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: NA Max: NA Torque: Current: NA Max: NA WOB: Current NA Max: NA RPM: Current: NA Max: NA PP: Current: NA Max: NA Lag: Strokes: 9482 Time: 69:21 Surf-Surf: Strokes: 11349 Time: 83:21 ECD: Current: Max: Mud Properties @ 7587' MW: 9.8 FV 55 PV 25 YP 21 FL 4.2 Gels: 7// Sol 12.5 pH 9.9 CI 47000 Ca ++ 40 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 1 Max: 1 Depth (MD/TVD): 1 Avg BG : NA • Gas Events Depth ( MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas NA Connection NA C1 C2 C3 C4I C4N C5I C5N Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: P.O.O.H., lay down BHA, rig up for wireline, run wireline sonic tool, run wireline nuclear resonance. Calibrations: None Failures: None Daily Cost: 3470.00 411 El I EPOCH
