Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
208-081
X8031 31197 WELL LOG TRANSMITTAL #905855686 To: Alaska Oil and Gas Conservation Comm. September 9, 2019 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 3C -15A Run Date: 7/24/2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3C -15A Digital Data in LAS format, Digital Log Image file 50-029-21426-01 RECEIVE® SEP 12 2019 AOGCC 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Date: t klzlw l Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate U Pull Tubing Li Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: Tubing Patch ❑✓ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑r Exploratory ❑ Stratigraphic ❑ Service [-]6. 208-081 3. Address: API Number: P.O.Box 100360, Anchorage, Alaska 99510 50-029-21426-01 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025629[ADL0025634 KRU 3C -15A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9324 feet Plugs measured N/A feet true vertical 6617 feet Junk measured N/A feet Effective Depth measured 9061 feet Packer measured 2526 & 8242 feet true vertical 6404 feet true vertical 2525 & 5924 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 116' 116' Surface 3805' 9-5/8" 3840' 3680' Prod Post SfF 2727' 7" 2760' 2755' Liner 6200' 5-1/2" 8725' 6128' Perforation depth Measured depth 9015'-9115' feet True Vertical depth 6367'-6448' feet Tubing (size, grade, measured and true vertical depth) 3.5" L-80 8482' MD 5924' TVD Packers and SSSV (type, measured and true vertical depth) Upper Patch Packer High Expansion 8,164' MD 5,714' TVD Lower Patch Packer High Expansion 8,196' MD 5,731' TVD 5.5" x 7" Liner Top Packer BAKER CPH 2,526' MD 2,525' TVD 3.5" x 5.5" Prod. Packer BAKER FAB -1 8,242' NO 5,924' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-McfWater-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A N/A N/A Subsequent to operation:N/A N/A N/A N/A N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑' Exploratory ❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Authorized Name: Rachel Kautz Contact Name: Rachel Kautz/Sara Carlisle Authorized Title: Well Integrity and Compliance Specialist Contact Email: N2549 ,conocoohillios.com Authorized Signature: / Dale: 8/5/19 Contact Phone: 659-7126 v77- g/-f/i 9 Form 10-404 Revised 4/2017 fk / Submit Original Only RBDMSAO� 0 8 2019 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 5, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the permanent tubing patch set across a known tubing leak in producer KRU 3C-15 (PTD 208-081). Please contact Sara Carlisle or me at 659-7126 if you have any questions. Sincerely, Rachel Kautz Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Executive Summary 08/12/18 3C -15A DESCRIPTION OF WORK COMPLETED SUMMARY After in a new gas -lift design in 2017 there have been recurring challenges installing a gas -lift ,valve in the station at 8169' MD in 3C-15. Attempts with extended packing valves and multiple setting tools were unsuccessful, so the decision was made to install a permanent patch over the mandrel. A permanent patch was set and tested with a passing CMIT-TxIA against the lower packer and MIT -T against the uDDer Dacker PERFORM LDL W/ PONY TAIL FOUND OV (C-0 8170' RKB W/ EXTENDED PACKING & HIGH SEALING FREUDENBERG PACKING TO BE LEAK POINT. 2.31 CA -2 PLUG & 2 1/2 AVA CATCHER @ 8293' RKB PUMP 125 BBLS INHIBITED SEAWATER FOLLOWED BY 90 BBLS DSL DOWN TBG AND 07/21/19 THE IA, U -TUBE FOR FREEZE PROTECT JOB COMPI FTF 07/23/19 07/24/19 07/25/19 07/27/19 07/28/19 PULLED 2 1/2 AVA HER @ 8292' RKB, PULLED 2.25 CA -2 PLUG @ 8292' RKB, TAG @ 9032' RKB. MEASURED BHP @ 9058' RKB. BRUSHED AND TLUSHED TBG FROM 8128' TO 8228' RKB. IN PROGRESS. DRIFT TO 8228' RKB W/ 2.30" x 35.9' DMY PATCH. SET 2.19" HI -EXPANSION NON - RETRIEVABLE PKR MID-ELEM @ 8196' RKB. SET SPECIAL CLEARANCE TTS TEST TOOL IN PKR; ATTEMPT 3000psi CMIT, FAILS W/ 2.8gpm LEAK OFF RATE. REPEAT CMIT, FAILS W/ 1.319pm LEAK OFF RATE. Urvu i i t) ;s000 (PASS ON 3rd ATTEMPT) W/ SPECIAL CLEARANCE TTS TEST TOOL SET IN PKR @ 8196' RKB. SET 2.19" HI -EXPANSION NON -RETRIEVABLE PKR, TELESCOPING JOINT, SPACER PIPE, BOW SPRING CENT, ANCHOR LATCH, MID-ELEM @ 8164' RKB. SET BAITED SPECIAL CLEARANCE TTS TEST TOOL IN PKR @ 8164' RKB. LRS ON LOCATION TO MIT TBG. IN PROGRESS. MIT TBG POST EXPANSION PACKER, (FAIL) CMIT TBG X IA (PASS) COMBO MIT TBGXIA .5BBLS DSL TO PUMP UP PRE START 15M 30M TBG 2400 3000 2900 2875 IA 2500 3025 2975 2960 OA 0 0 n n ATTEMPT MITT TO 3000; PUMPED 8 BBLS @ 0.6 BPM &PSI CAMP UP 50 PSI. PULLED & RE- RAN TEST TOOL TO PKR @ 8164' RKB. OBTAIN GOOD COMBO T x IA P.T. LRS ON LOCATION TO ESTABLISH LEAK RATE of 0.56 BPM. rtKt-VKM LUL: LOG BASELINE TO TEST TOOL IN PKR @ 8164' RKB. BRING PUMP ON WHILI OPENING IA; NO PSI CHANGE ON TBG. MITT TO 3000 (PASS). PULLED GLV @ 7605' RKB & SET OV. OBTAIN GOOD P.T. ON TBG & DDT ON IA. PULLED TEST TOOL F/ PKR @ 8164' RKB. JOB COMPLETE. MITT TO 3000. PRE T/1/0= 2625/160/0. PSI UP W/ 0.4 BBLS START= 3025/160/0, 15 MIN= 3010/175/0, 30 MIN= 3010/17F KUP PROD WELLNAME 3C -15A Conoa;Phillips 4 Well Attributes MaxAngleBMD TD welmor<aplmwl weaa-Sta,ue ne �' mopnK'8., as atm nMe Alaska. na, NUPARUK RIVER UNIT 560292142601 PROD a s e o avv n LastTag ___... _. ___._ ..... ........ .w,.,,,,,. AK All Wellbores Schem n< Deptn (ana)URIal Iamod a, VIctor< ogn45' Las1Ta9: HK0 Es154' v,dIALeav el OF -.Perls. 9,061.0 ]/25/2016 embae 11C -IIA Last Rev Reason CEVIATE0. 3G1Sy ?..a, 17:38PM M^otafion Ena om< Last end By weunure wmal=aMmtled'Suep Rev Reason: SelH expansion PalcM1, UO GLV ]2912619 /amaj Notes: General8. Safety Eno Hale 4nnotallon Welloole ....... wr9en 374 CONDUCTOR 3A 06 a nae cony UFi: 2460.5 WINDOW A, 1]736 2]Sa0 PRODUCTION PGa arn.yed2,nelt watine edrah xo Re4u<:1a rt.5'.,p): 5.,36.4 SURFACE: 3523,910)- GAS LIFT. 5.0212 GAS.1, GARGG GAa UFU TURNS - Packer: areao LEARpreen- peen LIFT; eta.) ap.a, Plce: e.me.o P<a.r: enar. Leulw: 9,353 PER. aFa.T SEALASSY:a2423 A<Mr, 8.232) Xlp1le-Oa,.. Da, O: e.2as GwrXla: e.N23 MPPLE;0,106,6 a4M2 SfA AsSai a 4824 vLLx;; esvo SCIS LINER TOP: a M50 MERF: 8did GUU. med.aGaB.0 (PERF:ea39.DaW5D- MERE, BEER .0B,M,0- MER1:a.0)aGfli150� tIIYER BTM: e./61.& 9.32e5� ....,. ...... -III 111 10/23'2616 I NOTE: Polycore Ultraeube,estalleb. Minimize wellbore entries sad use of sharp eiges 3C -15A Casing Strings - se: oepin 111) ILea Cap Ges OO (in) IO (in) Topiri Sel Deptn lM1Ka) Inxa) hand, Grade Top TFreaG yadur re CONDUCTOR i6 1506 36.0 1160 II60 62.50 H-00 WELDED 3C-1574 BURFACE 998 8.]6 35.2 3,840.] 1 3.680.83600 J-55 BTC 3C-1574 9 8.00 2,749.0 2,754.0 2.740.9 3C -15A ';DOWA PRODUCTION POST 7 5.28 380 2,760.0 2,754.6 26,00 7-55 BTC 3C -15A 5? LINER TOP 51/22.525.8 885.6 6,12]] 15.50 L -BO HydUt 511 3C -15A LINER BTM 31/2 299 6.481.9 9,323.5 6,61).2 9.20 L-80 hydel 511 3C 15A Tubing Strings Slnnp Max Nominal Sel Depth Set Depin lTW Oes 009n) IO lin) Top InXB) (Itl(6) (RKB) WIIIWn) GfaCo Top Thread W¢IlGore TUBING original (Below S? 2)IB 2.46 8]00.0 'Undid0 84136 6.50 JSS 3C-05 wnaGw) Upper Cpmp'etion3112 2.67 3).4 8242) 5,7G 1, 10,13 L-80 EUEeM 36154 Tub'm8 - Pmtloction 31/2 299 44.6 8,500.0 5,9390 9.30 L-90 'BTM 3C -15A Stacked Packer 31/2 2W 0,242] 8.349.1 5,824.8 10.13 L-80 EUEBrd 3C-i5A Completion Details ",.Ne TOP (ivG Topmn ONominal (nx0) °1 ItemSortCam ID(in) Weroare 37.4 374 0.00 Hanger CIW 3-1I2EUE 8Mx]-i/16"TBG Holger w/3'Tyra H 8 5 2.9503C -15A profile $2283 5,748.9 55.42 1 Locator Baker PER East Lodater 2990 3C -15A 8,228.] 5,]49.1 55411 PBR Baker 80.M PER pXspace Gut) 2.6)0 3C -15A 8,242.3 5,756.9 54.51 SEAL ASSY Baker 'KBH-22' Anchor Sea' Assm ebly 2.990 3C -15A 8242.] 5-7572 S4AB Paler Baker FAB -1 Pead ion Packer 3.000 3C -15R 8,2924 5,787A 50.74 XO Reducing Crossover 3-112'EUE-Mod box 12-7/8"EVE-Motl pin 2,366 3C -15A -7292-9 5,7e7.7 SOJO S. -DB, XN, 2-]/0"x2.312 0. D " DS Nipple with POS RHC plus 2313 3C -15A R 83423 58281 47,09 Overshot Baker Poor Bey OYers601(6iow) 31'sked 3.625 3C -15A 8008.) 5,8659 42NI .19 PPLE DNIPPLEw/2.777 GO 2.750 3C -15A 8481.2 5923.7 313.13 LOCATOR BAKER LOCATOR 3,990 3G 15A --F482 8,482.4 5,924) 36.ID SEAL ASSY BAKER PO -40 PBR wI SEALASSEMBLY 2.990 M-1SAGAS Other In Hale (Whaline retrievable plugs, valves, pumps, fish, ate.) Top nvDI raPlnna) pse) Top lnG p) Bed Cam Run ooh to (in) welleare 8164.0 5.)1474 5984 Packer Oui 2,19"Hi-Expansion Packer with )/252019 1.O60 3G15A telesceping joint, spear¢, pipe, centralizer, and.Shorlatch. OAL32'. Mm OD249" 8.168.0 5,716.4 59.50 1 Spacer Pipe 24'M1.66'NU spacer pipe 7292019 1.190 3G15A 8.169.0 51716.9 59.42 LEAK L0GLOL... LEAKFOUNDATGLM46AT 32012019 0 m 3C-1574 8169' 8,196.0 5,]31.1 5]74tico 5 Packer 0ua2.19'Ni-Expansion Packer. 3.9T )242019 1.060 3G15A DAL 8511.0 5,94]9 35.34 PWG PUMPED CEMENT ON TOP OF PLUG, 4/3-2016 BC -15A CEMENT NOT TESTED Liner Details Top DV0 Namina,. Tap(1(1la) lnl(Df Taprislnal0 Item Oei lin) Weffade 35,2 35.2 000 HANGER 8.785 3C-1574 36.0 360 0.00 CONDUCTORLOCATOR: 15.062 3C -15A 2.5258 2.5251 646 PACKER BAKER"CPH" LINER TOP PACKER C-2 4.9M 3C -15A PROFILE ••2500 Psi MAX"' 2,5367 2,535.9 5.89 HANGER BAKER HMC LINER HANGER 4,960 3C -15A 2,7490 2,]44.0 14.99 WINDOWA 8.000 3C -15A, 2,760.0 2,]54.6 1544 ECP].000 3G15A 2,]60.0 2,754.6 i5A" ECP TODD 3G15A 8.481.9 5,9243 36.11 SBE ZXP EXTENSION 4.120 3C -45A 8,506A 5.944.2 35.46 PACKER BAKER HE ZXP LINER TOP PACKER 3,000 3C -15A 8°5148 5.951.0 35.24 HANGER BAKER HMC LINER HANGER 2940 3C-1574 92233 6536.8 35.96 BAFFLE BOT BAFFLE SUB 2.9]0 SG15A Perforations 6 Slots rop(nxB etm /nice rop jNO) etmlrv0) ) (nNBj (XRa) Unked Zone Shot Gens (:noRlit Date ) Type Co. Wel'Wre 8015,0 9,0370 6,367.4 6,385.1 A-3, 3C -15A 10252008 6.0 1 APERF 12.5- PJ HBO suns, 60° 3C-1574 evved. 803ee9058.0 5305.9 6.402.1 A-3.3G15A 81262008 5.0 -PERE 2.6 Hypei 60- PH 3C -15A 9,059.0 9,062.0 6,402.9 6.4053 A -3.3C-1574 10252008 6.0 APERF 25"PJ HBDg90 60° 3C-1574 ,and]T 9A)80 91150 6,418.2 64484 A23C-i5A 10/25/2008 6D APERF TE Pi HED Awes 3C -15A random ),3460 ),3fi2.0 6,322.9 6,335.171UNITB, 3G 5 1111/1985 12.o'pERF 5"Csg Gun HJII; 120 rag. 30-15 p 4,3E-15 11/1/1985 4.0 (PERF 4'Csg onHJ 11; 90 deg. 3C-15 ph ),Sfi).0 7,5820 6,490.7 6,502D A -3,3C-15 11/111985 407PERF T Csg Gun HJ'1; 90" ph 3C-15 KUP PROD ConocoPhillips Aaska, In, Run O.A WELLNAME 3C -15A AK All Wellbores Schem .n.A MODNCIn 5/F ill GIS LIR x0 RMucmS SVRFgCE: 3v.] GPS LIFT: GFS LIFT: G434FT'. L. GFS LIFT:I Spettr Plp.;l VacMrl L.u,w PBRt SEAL ASSY;F PoCM: E MW -DB. AN,i B 0 ERF, OversM1m:B RIPPLE: B, Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: j f AOGCC -+ ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 ^•-As Anchorage, AK 99501 i r TRANSMITTAL DATE TRANSMITTAL # �L Schlumberger -Private TE OF ALASKA A KA OIL AND GAS CONSERVATION COMA/SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon fl Plug Perforations 1 Fracture Stimulate E"' Pull Tubing F Operations Shutdown E Performed: Suspend r Perforate Other Stimulate p Alter Casing ra Change Approved Program ra Plug for Redrill E Perforate New Pool 1 a Repair Well F Re-enter Susp Well E r- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory f 208-081 3.Address: 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-21426-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL25634,ADL 25629 KRU 3C-15A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9327 feet Plugs(measured) 8511, 8547 true vertical 6620 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 2526,8506, 8243 true vertical 0 feet (true vertical) 2525, 5944, 5757 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 116 116 SURFACE 3805 9 5/8 3841 3681 PRODUCTION 7793 7 2760 2755 LINER 6199 51/2 9324 6617 RECEIVED NOV 0 4 2016 Perforation depth: Measured depth: 9015-9037, 9038-9058, 9059-9062,9078-9115 True Vertical Depth: 6367-6385, 6386-6402,6403-6405,6418-6448 AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 8482 MD, 5924 TVD Packers&SSSV(type,MD,and ND) PACKER=BAKER CPH Liner Top Packer @ 2526 MD and 2525 TVD PACKER=BAKER HR ZXP Liner Top Packer @ 8506 MD and 5944 ND PACKER=BAKER FAB-1 PRODUCTION PACKER @ 8243 MD and 5757 ND SSSV: = NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): NONE } Treatment descriptions including volumes used and final pressure: sc16*E0 h!lP\.!°) 3 -L 1:- I. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-In 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 F Exploratory E Development F Service f a Stratigraphic E Copies of Logs and Surveys Run 1 16.Well Status after work: Oil F Gas fa WDSPL Printed and Electronic Fracture Stimulation Data r GSTOR fa WINJ WAG E GINJ E SUSP 1 a SPLUG f a- 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Diana Guzman (a.265-6318 Email Diana.Guzmanaconocoohillips.com Printed Name Diana Guzman Title Sr. Drilling Supervisor Signature 4A 94_1,) gem-Phone:263-4612at loft- (,v�rn�V 11/1( 0 Form 10-404 Revised 5/2015 V77— Z/l G 7/7 RBDMS t SOY - 7 2016 Submit Original Only 7/ I, • i Operations Summary (with Timelog Depths) A 3C-15 +ConocaPhiillips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code. Time P-T-X Operation (ftKB)' End Depth(ftKB), 9/24/2016 9/24/2016 3.50 MIRU MOVE RURD P Continue prepping for rig move, 00:00 03:30 staging and positioning rig modules. 9/24/2016 9/24/2016 2.00 MIRU MOVE MOB P Move shop,office, Boiler,Motor Pump 03:30 05:30 and Pit complex's from 2X-Pad to 3C Pad 9/24/2016 9/24/2016 2.50 MIRU MOVE MOB P Spot Office Complex and Shop 05:30 08:00 9/24/2016 9/24/2016 3.00 MIRU MOVE MOB P Travel back to 2X Pad and latch up to 08:00 11:00 Sub base,2 pipe shed complex's and rock washer. 9/24/2016 9/24/2016 0.50 MIRU MOVE MOB P Make field wide announcement and 11:00 11:30 move the Sub base,2 pipe shed complex's and rock washer from 2X- Pad to spine road and 2X Access road. 9/24/2016 9/24/2016 0.50 MIRU MOVE MOB P Move the Sub base,2 pipe shed 11:30 12:00 complex's and rock washer from 2X- Pad to Oliktok Road intersection 9/24/2016 9/24/2016 1.25 MIRU MOVE MOB P Move the Sub base,2 pipe shed 12:00 13:15 complex's and rock washer from Oliktok Road intersection to 3C Pad access. 9/24/2016 9/24/2016 0.25 MIRU MOVE MOB P Move the Sub base,2 pipe shed 13:15 13:30 complex's and rock washer from 3C Pad access to 3C Pad. 9/24/2016 9/24/2016 2.50 MIRU MOVE MOB P Spot sub over well 3C-15 and set 13:30 16:00 down 9/24/2016 9/24/2016 1.00 MIRU MOVE MOB P Move Boiler,Motor and pump 16:00 17:00 modules forward. Spot and set down Pit Module after marrying up with sub base. 9/24/2016 9/24/2016 1.00 MIRU MOVE MOB P Spot and set down pump module after 17:00 18:00 marrying up with Pit Module. 9/24/2016 9/24/2016 0.50 MIRU MOVE MOB P Spot and set down Motor Complex 18:00 18:30 after marrying up with Pit Module. 9/24/2016 9/24/2016 0.50 MIRU MOVE MOB P Spot and set down Boiler Room 18:30 19:00 Complex after marrying up with Motor Room Complex. 9/24/2016 9/24/2016 0.50 MIRU MOVE MOB P Spot and set down Pipe Skate module 19:00 19:30 after marrying up with the Sub Base. 9/24/2016 9/24/2016 1.50 MIRU MOVE MOB P Spot and set down Pipe Rack module 19:30 21:00 after marrying up with the Pipe Skate Module. 9/24/2016 9/25/2016 3.00 MIRU MOVE RURD P Tie in interconnects Plug in 21:00 00:00 interconnects switch to rig generator power,work on acceptance check list, Rig up skate rail, Finish berming take on first load of mud,Rig accepted at 2400 hrs 9/25/2016 9/25/2016 1.00 MIRU WELCTL RURD P Continue taking on mud screen up 0.0 0.0 00:00 01:00 shakers,and rig up rock washer. 9/25/2016 9/25/2016 1.50 MIRU WELCTL MPSP P R/U Lubricator and test t/1500 psi Pull 0.0 0.0 01:00 02:30 BPV R/D Lubricator,Tubing psi 825, IA psi 800,OA Psi 50 9/25/2016 9/25/2016 2.50 MIRU WELCTL RURD P R/U to Circulating line to kill well,Test 0.0 0.0 02:30 05:00 lines. Page 1/10 Report Printed: 10/20/2016 -44,?::,„. . • Operations Summary (with Timelog Depths) 0 3C-15 Conocc ehittips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation {ftKEj End Depth{ftKE) 9/25/2016 9/25/2016 4.00 MIRU WELCTL KLWL P Bleed IA and Tubing to Zero,Pump 30 0.0 0.0 05:00 09:00 bbl Hi Vls 13.8ppg spacer,Followed by 230 bbls Warp 13.8 ppg down tubing taking returns to tiger tank,shut down monitor well slight flow on tubing 9/25/2016 9/25/2016 4.00 MIRU WELCTL CIRC T Circulate back to pits @ 1.5 bpm 680 0.0 0.0 09:00 13:00 psi conditioning fluid.Shut down after surface to surfcace. 9/25/2016 9/25/2016 0.50 MIRU WELCTL OWFF T I Observe well for flow,slight flow on 0.0 0.0 13:00 13:30 'tubing,pressure buid to 4 psi. 9/25/2016 9/25/2016 4.50 MIRU WELCTL CIRC T Reverse circulate 1.5 times hole 0.0 0.0 13:30 18:00 volume @ 1.5 bpm 700 psi Shut down 9/25/2016 9/25/2016 0.50 MIRU WELCTL OWFF P Observe well for flow well static. 0.0 0.0 18:00 18:30 9/25/2016 9/25/2016 0.50 MIRU WHDBOP MPSP P Set TWC as per Cameron test to 1000 0.0 0.0 18:30 19:00 psi in direction of flow. 9/25/2016 9/25/2016 2.00 MIRU WHDBOP NUND P Nipple down Tree and adaptor, 0.0 0.0 19:00 21:00 Function LD,Install test dart 9/25/2016 9/25/2016 2.50 MIRU WHDBOP NUND P I N/U BOP Stack and adaptor,hook up 0.0 0.0 21:00 23:30 I turn buckles and riser. 9/25/2016 9/26/2016 0.50 MIRU WHDBOP RURD P R/U to test BOP's Fill stack and choke 0.0 0.0 23:30 00:00 with water. 9/26/2016 9/26/2016 1.50 MIRU WHDBOP RURD P PJSM,Continue to RU testing 0.0 0.0 00:00 01:30 equipment. 9/26/2016 9/26/2016 5.75 MIRU WHDBOP BOPE T Perform body test @ 250/5,000 psi 0.0 0.0 01:30 07:15 with upper VBR's and 3-1/2 test joint. Found door seals to be leaking on the UPR's and Blind Ram doors-Attempt to tighten. Re-test,failed. Blow down BOP stack Open doors and replace door seal rings.Change API ring in Choke hose. Recharge Koomey and refill choke and stack-good body test at 250/5,000 psi. Page 2/10 Report Printed: 10/20/2016 ! ! Operations Summary (with Timelog Depths) 3C-15 +ConocoPhinips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Cade Activity Code Time P-T X Operation (ftKB) End Depth(ftKB) 9/26/2016 9/26/2016 7.75 MIRU WHDBOP BOPE P Conduct initial BOP Test @ 250/ 0.0 0.0 07:15 15:00 5,000 psi on rams,choke and kill manifold. 250/3,500 psi on the Annular with 3-1/2 test joint. 24 hr notice was given on 9-23-16 @ 8:29 am and waived by Chuck Scheve @ 18:00 hrs on 9-25-16. Test# #1 Upr VBR's,3-1/2 8rd FOSV,CM 12,13, 14 and Manual kill #2 upper IBOP, HCR Kill,CM 1,9, 11. #3 Lower IBOP,CM 5,8, 10 #4 Dart Valve,CM 4,6,7 #5 XT-39 FOSV,CM 2 #6 Choke HCR,Kill ManualDemco #7 Choke Manual,Kill HCR #8 Annular @ 250/3,500 psi #9 LPR @ 250/5,000 psi #10 Blind Rams and CM 3 Koomey Test Sys Psi=3,000 After closure=1875 psi 200 PSI obtained=46 sec. Full Psi= 180 sec. 5-N2 Bottles w/2,000 psi ave 9/26/2016 9/26/2016 1.00 MIRU WHDBOP RURD P Rig down test equipment,blow down 0.0 0.0 15:00 16:00 lines Drain BOP stack 9/26/2016 9/26/2016 0.50 MIRU WHDBOP MPSP P Pull Test Dart and BPV(Well Static) 0.0 0.0 16:00 16:30 9/26/2016 9/26/2016 1.00 COMPZN RPCOMP RURD P M/U landing jt to hanger and top drive, 0.0 0.0 16:30 17:30 BOLDS 9/26/2016 9/27/2016 6.50 COMPZN RPCOMP WAIT T Unseat tubing hanger w/80 k Block 0.0 0.0 17:30 00:00 weight,attempt to pull seals free, stage pumps to 2 bpm straight pull to 200k unable to pull free,continue working string while Waiting on Eline for chemical cut. 9/27/2016 9/27/2016 6.75 COMPZN RPCOMP WAIT T Continue to work string in attempt to 0.0 0.0 00:00 06:45 pull seals from SBE @ 8,487-ft to 8,506-ft from 100 k est.string to 100k over pull.while circulating @ 2 bpm @ 780 psi. 9/27/2016 9/27/2016 1.00 COMPZN RPCOMP RURD P PJSM,w/rig and wireline crew. Land 0.0 0.0 06:45 07:45 tubing in slips @ 30k osw. 9/27/2016 9/27/2016 3.25 COMPZN RPCOMP ELNE P Mobe SLB wireline tools to rig floor. 0.0 0.0 07:45 11:00 Rug up e-line w/pump in sub and pack off.Test to 1500 psi.Make up chemical cutter and weight bars. 9/27/2016 9/27/2016 1.00 COMPZN RPCOMP ELNE P RIH w/chemical cutter to 5090'WLM. 0.0 0.0 11:00 12:00 Tagging up solid.Discuss options with WO engineer. 9/27/2016 9/27/2016 6.00 COMPZN RPCOMP ELNE P Attempt to pump cutter down w/1 bpm, 0.0 0.0 12:00 18:00 510 psi.Still tagging up at 5090'WLM. Pull up to 5055'WLM and make cut. POOH w/e-line to surface.Anchor on chemical cutter hanging up requiring to hold 1650 psi.on tubing. Page 3/10 Report Printed: 10/20/2016 • • 14°,t 6i4K Operations Summary (with Timelog Depths) ',,; 3C-15 ConacoPhiili s Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (RKB) End Depth MKS) 9/27/2016 9/27/2016 5.00 COMPZN RPCOMP ELNE T PJSM on handling cutter on surface. 0.0 0.0 18:00 23:00 Anchor hanging up just below tubing hanger.Reconfigure lubricator by adding 30'section and work cutter into lubricator holding 1650 psi.Lay down cutter assy.and rig down wireline tools. 9/27/2016 9/28/2016 1.00 COMPZN RPCOMP ELNE P Lay down cutter assy.and rig down 0.0 0.0 23:00 00:00 wireline tools. 9/28/2016 9/28/2016 1.00 COMPZN RPCOMP PULL P Back out and lay down landing joint. 5,055.0 5,055.0 00:00 01:00 Rig up to circulate 9/28/2016 9/28/2016 1.25 COMPZN RPCOMP CIRC P Circulate surface to surface two times 5,055.0 5,055.0 01:00 02:15 at 6 bpm at 1320 psi 9/28/2016 9/28/2016 0.50 COMPZN RPCOMP OWFF P Observe well for flow. Simultaneously 5,055.0 5,055.0 02:15 02:45 rig down circulating equipment,install stripping rubber and air slips 9/28/2016 9/28/2016 3.25 COMPZN RPCOMP PULL P Lay down 3-1/2"completion tubing 5,055.0 3,055.0 02:45 06:00 from 5055'to 3055' 9/28/2016 9/28/2016 0.50 COMPZN RPCOMP PULD P Lay down SSSV and rig down spooler. 3,055.0 3,055.0 06:00 06:30 Recover 62 out of 68 stainless steel bands off of control line 9/28/2016 9/28/2016 0.25 COMPZN RPCOMP SFT( P Kick while tripping drill 3,055.0 3,055.0 06:30 06:45 9/28/2016 9/28/2016 3.00 COMPZN RPCOMP PULL P Continue laying down tubing from 3,055.0 0.0 06:45 09:45 3055 to surface. Recovered a total of 159 joints of tubing,one cut joint @ 16.85',one SSSV and two GLM's with associated pups,tubing hanger. Total recovered(5020.03')+original RKB (37.40')=Top of fish @ 5057.43' tubing measurement. 9/28/2016 9/28/2016 2.25 COMPZN RPCOMP BHAH P Clear and clean rig floor. Install wear 0.0 0.0 09:45 12:00 ring(6-1/2"I.D.) Bring BHA tools to the floor.Load pipe shed and strap 3- 1/2"PH-6 work string 9/28/2016 9/28/2016 5.00 COMPZN RPCOMP BHAH T Attempt to make up BHA. Not able to 0.0 0.0 12:00 17:00 get power tongs to bite on BHA components.Expedite heads and dies from GBR Prudhoe Shop. 9/28/2016 9/28/2016 2.00 COMPZN RPCOMP BHAH P Make up overshot fishing BHA#1. 0.0 306.0 17:00 19:00 9/28/2016 9/28/2016 4.50 COMPZN RPCOMP PULD P PU 152 jts of 3 1/2"PH-6 workstring 306.0 5,026.0 19:00 23:30 from pipe shed to 5026'MD.No indication of entering liner top. Calc disp=23.18 bbls Act disp=22.78 bbls 9/28/2016 9/29/2016 0.50 COMPZN RPCOMP CIRC P MU top drive and establish 5,026.0 5,026.0 23:30 00:00 parameters.67K SO,78K PU, 70K Rot,20 rpm, 1.5K tq.Circ at 5 bpm/2530 psi. 9/29/2016 9/29/2016 0.50 COMPZN RPCOMP CIRC P Circ and cond mud 5 bpm,2160 psi 5,026.0 5,026.0 00:00 00:30 9/29/2016 9/29/2016 0.50 COMPZN RPCOMP FISH P RIH and tag top of fish at 5057' 5,026.0 5,061.0 00:30 01:00 original RKB and work over stump and no-go at 5061'original RKB. SPR/MP#2-20 spm=680 psi 30 spm=850 psi at 5026'MD. Page 4/10 Report Printed: 10/20/2016 • • Operations Summary (with Timelog Depths) oz 3C-15 ConocoPhillips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time Cod Time Our(hr) Phase Op Code Activity Code Time P-T-X Operabos (ftKB) Erd',Depth(ftKB)', 9/29/2016 9/29/2016 8.25 COMPZN RPCOMP JAR P Stage up jarring operation and over 5,061.0 5,061.0 01:00 09:15 pull to max limits.Jar at 135K wt and pull to 240K wt.Attempt with pump on and off.Pumping at 2 bpm/680 psi.Hit jar 400+times.No progress made. 9/29/2016 9/29/2016 2.50 COMPZN RPCOMP OTHR T Attempt to release from fish.Work 5,061.0 5,026.0 09:15 11:45 strimg weight down w/torque limit set at 5K,stall out several times while attempting to release.Trap torque and work down.PU to neutral weight. Rotate off fish at 20 rpm with no additional torque or grapple drag. 9/29/2016 9/29/2016 0.75 COMPZN RPCOMP CIRC T CBU.3.5 bph, 1200 psi.Monitor well. 5,026.0 5,026.0 11:45 12:30 Static. OA=680 psi 9/29/2016 9/29/2016 4.50 COMPZN RPCOMP TRIP T POOH from 5026'MD to 306'MD. 5,026.0 306.0 12:30 17:00 Monitor well.Static. Calc disp=22.18 bbls Act disp=36.75 bbls 9/29/2016 9/29/2016 3.00 COMPZN RPCOMP BHAH T Back out and lay down DC's and 306.0 0.0 17:00 20:00 Fishing BHA#1.Clean and clear rig floor. 9/29/2016 9/29/2016 2.00 COMPZN RPCOMP SLPC T Slip and cut 60'drilling line. 0.0 0.0 20:00 22:00 9/29/2016 9/29/2016 0.50 COMPZN RPCOMP SVRG T Service top drive and drawworks 0.0 0.0 22:00 22:30 9/29/2016 9/30/2016 1.50 COMPZN RPCOMP WAIT T Wait on SLB E-line and Welltec. 0.0 0.0 22:30 00:00 Perform MP2's,light maintenance and housekeeping. OA=160 psi 9/30/2016 9/30/2016 6.75 COMPZN RPCOMP WAIT T Wait on SLB E-line and Welltec. 0.0 0.0 00:00 06:45 Perform MP2's,light maintenance and housekeeping. 9/30/2016 9/30/2016 6.25 COMPZN RPCOMP ELNE T PJSM-Rig up SLB wireline with 0.0 0.0 06:45 13:00 Welltec tractor.Make up grease head/60'lubricator,tractor and chemical cutter. OA=90 psi 9/30/2016 9/30/2016 4.25 COMPZN RPCOMP ELNE T RIH w/tractor and chemical cutter on 0.0 0.0 13:00 17:15 SLB e-line to 8350'WLM.Cut tubing at 8350'WLM. 9/30/2016 9/30/2016 2.00 COMPZN RPCOMP ELNE T POOH w/wireline 0.0 0.0 17:15 19:15 9/30/2016 9/30/2016 3.00 COMPZN RPCOMP ELNE T PJSM on rigging down chemical cutter 0.0 0.0 19:15 22:15 and tractor.Rig down e-line tools and equipment. 9/30/2016 9/30/2016 1.00 COMPZN RPCOMP BHAH P PJSM-Mobilize Baker overshot tools 0.0 0.0 22:15 23:15 to rig floor.Rig up GBR tongs. 9/30/2016 10/1/2016 0.75 COMPZN RPCOMP BHAH P Make up overshot.(Tong operator 0.0 0.0 23:15 00:00 was struck by power tongs resulting in a laceration on his nose) 10/1/2016 10/1/2016 0.50 COMPZN RPCOMP SFTY P Discuss with crew and investigate 0.0 0.0 00:00 00:30 tong operator injury. 10/1/2016 10/1/2016 0.50 COMPZN RPCOMP BHAH P PJSM-Make up Fishing overshot BHA 0.0 7.0 00:30 01:00 #2 as per BOT. 10/1/2016 10/1/2016 3.00 COMPZN RPCOMP TRIP P RIH w/3 1/2"PH-6 workstring to 4693' 7.0 4,693.0 01:00 04:00 MD. Page 5/10 Report Printed: 10/20/2016 • • Operations Summary (with Timelog Depths) '.� Cc V 3C-15 : _ itgps . Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/1/2016 10/1/2016 1.25 COMPZN RPCOMP PULD P Pick up 12 jts 3 1/2"PH-6 workstring 4,693.0 5,042.0 04:00 05:15 from pipe shed.Make up two space out pup joints. PU=76K SO=67K Rot=72K. 10 rpm, 1.5K tq. Calc disp=23.1 bbls Act disp=23.8 bbls 10/1/2016 10/1/2016 0.75 COMPZN RPCOMP CIRC P Make up top drive.Stage pump to 5 5,042.0 5,042.0 05:15 06:00 bpm, 1240 psi ICP, 1163 psi FCP, 21%FO, 13.8 ppg MW in/out.Circulate surface to surface 10/1/2016 10/1/2016 0.25 COMPZN RPCOMP FISH P RIH and engage fish at 5045'MD 5,042.0 8,350.0 06:00 06:15 (5057'OKB).Verify w/25K overpull 10/1/2016 10/1/2016 0.75 COMPZN RPCOMP CIRC P Stage pump to 5 bpm,ICP=1840 psi, 8,350.0 8,350.0 06:15 07:00 22%FO,FCP=1460 psi, 13.8 ppg MW in/out. 10/1/2016 10/1/2016 0.50 COMPZN RPCOMP OWFF P Blow down top drive.Monitor well. 8,350.0 8,350.0 07:00 07:30 Static. 10/1/2016 10/1/2016 3.50 COMPZN RPCOMP TRIP P Lay down space out pups and 3 joints 8,350.0 3,302.0 07:30 11:00 of PH-6 workstring.POOH w/fish f/8350'MD t/3302'MD.Total of 53 std's of PH-6 stood back in derrick. Calc disp=23.1 bbls Act disp=29.8 bbls. 10/1/2016 10/1/2016 0.25 COMPZN RPCOMP OWFF P Monitor well.Static. 3,302.0 3,302.0 11:00 11:15 10/1/2016 10/1/2016 0.75 COMPZN RPCOMP PULL P PJSM-Lay down overshot assy w/cut 3,302.0 3,129.0 11:15 12:00 joint to pipe shed.Lay down 3 1/2" completion tubing fish f/3302'MD t/3129'MD. OA=140 psi 10/1/2016 10/1/2016 3.75 COMPZN RPCOMP PULL P PJSM-Con't to lay down 3 1/2" 3,129.0 0.0 12:00 15:45 completion tubing.Recover 103 full jts tubing,2 cut jts tubing and 3 GLM's. Total footage recovered=3296'. 10/1/2016 10/1/2016 0.25 COMPZN RPCOMP PULL P Clean and clear rig floor. 0.0 0.0 15:45 16:00 10/1/2016 10/1/2016 0.75 COMPZN RPCOMP BHAH P PJSM-Pick up and service break 0.0 0.0 16:00 16:45 overshot assy.Lay down cut joint. 10/1/2016 10/1/2016 0.25 COMPZN RPCOMP SVRG P Adjust drawworks brakes 0.0 0.0 16:45 17:00 10/1/2016 10/1/2016 0.50 COMPZN RPCOMP BHAH P PJSM-Mobilize Overshot BHA#3 tools 0.0 0.0 17:00 17:30 to rig floor. 10/1/2016 10/1/2016 3.25 COMPZN RPCOMP BHAH P PJSM-Make up Overshot BHA#3 as 0.0 304.0 17:30 20:45 per Baker Fishing. 10/1/2016 10/1/2016 2.75 COMPZN RPCOMP TRIP P PJSM-RIH w/overshot assy on 3 1/2" 304.0 5,274.0 20:45 23:30 PH-6 workstring to 5274'MD. 10/1/2016 10/2/2016 0.50 COMPZN RPCOMP PULD P PU and break out XO from working 5,274.0 5,462.0 23:30 00:00 single. RIH picking up PH-6 workstring from pipeshed to 5462'MD.PU=83K 50=66K Calc disp=25.43 bbls Act disp=25.55 bbls Page 6/10 Report Printed: 10/20/2016 • Operations Summary (with Timelog Depths) 0. '0wa Amt 5, r 3C-15 ConocoPhiliips #S.ack� Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code. Time P-T-X Operation {ftK6) End Depth MKS) 10/2/2016 10/2/2016 5.75 COMPZN RPCOMP PULD T Con't RIH picking up 3 1/2"PH-6 5,462.0 8,327.0 00:00 05:45 workstring from pipe shed f/5460'MD t/8327'MD. Pick up total of 99 jts. PU=115K SO=75K Calc disp=12.6 bbls Act disp=12 bbls. 10/2/2016 10/2/2016 1.00 COMPZN RPCOMP CIRC T Circ and cond mud surface to surface. 8,327.0 8,327.0 05:45 06:45 Stage pump up to 5 bpm,21%FO. ICP=2500 psi,FCP=2450 psi. 10/2/2016 10/2/2016 1.00 COMPZN RPCOMP JAR T Obtain parameters.PU=115K 8,327.0 8,343.0 06:45 07:45 50=75K Rot=83K, 15 rpm,4K tq.RIH and tag top of fish at 8343'MD. Engage overshot and jar on fish working up to jarring at 175K and overpull to 250K. Fire jar 4 times and observe weight drop off to free travel of 115K. 10/2/2016 10/2/2016 0.75 COMPZN RPCOMP CIRC T Pull up to 8313'MD.CBU stage pump 8,343.0 8,313.0 07:45 08:30 up to 5 bpm,2830 psi,22%FO. Obtain SPR's. SPR/MP#1/#2-20 spm=820/880 psi 30 spm=1180/1180 psi at 8300'MD. 13.8 ppg MW 10/2/2016 10/2/2016 0.25 COMPZN RPCOMP OWFF T Monitor well.Static, 8,313.0 8,313.0 08:30 08:45 10/2/2016 10/2/2016 3.25 COMPZN RPCOMP TRIP T Blow down TD.Lay down 3 jts PH-6 8,313.0 2,180.0 08:45 12:00 pipe. POOH f/8313'MD t/2180'MD. Calc disp=27.3 bbls Act disp=26.2 bbls. OA=220 psi. 10/2/2016 10/2/2016 1.25 COMPZN RPCOMP TRIP T PJSM-Con't to POOH f/2180'MD 2,180.0 364.0 12:00 13:15 t/364'MD. 10/2/2016 10/2/2016 2.00 COMPZN RPCOMP BHAH T PJSM-Lay down overshot fishing BHA 364.0 0.0 13:15 15:15 #3.No fish recovery. 10/2/2016 10/2/2016 0.50 COMPZN RPCOMP BHAH T Clear and clean rig floor.Lay down 2 0.0 0.0 15:15 15:45 7/8"tools. 10/2/2016 10/2/2016 1.50 COMPZN RPCOMP RURD T Change out GBR power tongs. 0.0 0.0 15:45 17:15 Mobilize Baker completion tools to rig floor. 10/2/2016 10/2/2016 2.00 COMPZN RPCOMP BHAH P PJSM-Make up poorboy overshot 0.0 142.0 17:15 19:15 packer assy to 142'MD. 10/2/2016 10/3/2016 4.75 COMPZN RPCOMP RCST P RIH w/poorboy overshot packer assy 142.0 5,300.0 19:15 00:00 on PH-6 workstring to 5300'MD. Calc disp=23.4 bbls Act disp=24.15 bbls OA=100 psi. 10/3/2016 10/3/2016 3.00 COMPZN RPCOMP RCST P RIH w/poorboy overshot packer assy 5,300.0 8,109.0 00:00 03:00 on PH-6 workstring f/5300'MD t/8109'MD. 10/3/2016 10/3/2016 0.50 COMPZN RPCOMP PULD P PU 8 jts of PH-6 work string from pipe 8,109.0 8,326.0 03:00 03:30 shed to 8326'MD. Calc disp=14.6 bbls Act disp= 14 bbls.PU=120K SO=70K Page 7/10 Report Printed: 10/20/2016 Xi • • Operations Summary (with Timelog Depths) 3C-15 Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (fEE) End Depth(ftKB) 10/3/2016 10/3/2016 0.50 COMPZN RPCOMP PACK P RIH to no-go at 8349'MD.Swallow 6' 8,326.0 8,349.0 03:30 04:00 stump with overshot. Pick up to 8327' MD and break connetion.Drop 1.375 phenolic ball.RIH to 8349'MD Pump ball down at 3 bpm, 1230 psi, 18% FO.At 400 stks reduce rate to 2 bpm, 860 psi 19%FO.Ball on seat at 500 stks. Pressure up to 4000 psi and observe packer set and release. 10/3/2016 10/3/2016 1.25 COMPZN RPCOMP PRTS P PJSM-Blow down top drive.Pull up to 8,349.0 8,327.0 04:00 05:15 8327'MD and lay down jt#263.Rig up to test casing. Fluid pack test lines and test casing to 1800 psi/30 min. charted. 10/3/2016 10/3/2016 1.00 COMPZN RPCOMP CIRC P Drop 1.87"Baker dart to open circ 8,327.0 8,327.0 05:15 06:15 sub.Pump down at 2 bpm,980 psi, 19%FO. Dart on seat at 295 stks. Pressure up to 2500 psi and open circ sub.CBU at 7 bpm,3271 psi,28% FO. 10/3/2016 10/3/2016 0.75 COMPZN RPCOMP RURD P Offload pits 1 and 5 to vac truck. 8,327.0 8,327.0 06:15 07:00 10/3/2016 10/3/2016 2.00 COMPZN RPCOMP DISP P PJSM-Displace well from 13.8 ppg 8,327.0 8,327.0 07:00 09:00 WARP mud to 8.4 ppg seawater. Pump 75 bbls of 11.5 ppg deep clean pill,35 bbls of 11.5 ppg hi vis spacer and 206 bbls of 8.4 ppg seawater.7 bpm, ICP=3230 psi,FCP=2702 psi, 30%FO.Obtain SPR's.Rig down and blow down circ equip. SPR/MP#1/#2-20 spm=200/200 psi 30 spm=450/420 psi at 8300'MD.8.4 ppg MW 10/3/2016 10/3/2016 0.25 COMPZN RPCOMP OWFF P Monitor well.Static. 8,327.0 8,327.0 09:00 09:15 10/3/2016 10/3/2016 2.75 COMPZN RPCOMP PULD P POOH laying down 3 1/2"PH-6 8,327.0 6,409.0 09:15 12:00 workstring f/8327'MD t/6409'MD. Calc disp=6.3 bbls Act disp=6.1 bbls OA=250 psi 10/3/2016 10/3/2016 8.00 COMPZN RPCOMP PULD P PJSM-Con't to lay down 3 1/2"PH-6 6,409.0 36.0 12:00 20:00 workstring. Calc disp=36.54 bbls Act disp=38.91 bbls. 10/3/2016 10/3/2016 0.25 COMPZN RPCOMP BHAH P Lay down Baker running tools. 36.0 0.0 20:00 20:15 10/3/2016 10/3/2016 0.50 COMPZN RPCOMP BHAH P Clean and clear rig floor 0.0 0.0 20:15 20:45 10/3/2016 10/3/2016 0.75 COMPZN RPCOMP RURD P Pull wear ring.Rig up to run upper 0.0 0.0 20:45 21:30 completion. 10/3/2016 10/4/2016 2.50 COMPZN RPCOMP PUTB P PJSM-PU and RIH w/3 1/2"L-80, 0.0 1,057.0 21:30 00:00 9.3#Polycoated tubing as per running order to 1057'MD. 10/4/2016 10/4/2016 6.00 COMPZN RPCOMP PUTB P Con't to PU and RIH w/3 1/2"L-80, 1,057.0 4,490.0 00:00 06:00 9.3#Polycoated tubing as per running order f/1057'MD t/4490'MD. Page 8/10 Report Printed: 10/20/2016 • a Operations Summary (with Timelog Depths) 3C-15 ConocoPhittlps Rig: DOYON 141 Job: RECOMPLETION Time Log ?. Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code: Time P-T-X Operation (EKE) End Depth MKS) 10/4/2016 10/4/2016 6.00 COMPZN RPCOMP PUTB P Cont to PU and RIH w/3 1/2"L-80, 4,490.0 8,235.0 06:00 12:00 9.3#Polycoated tubing as per running order f/4490'MD t/8235'MD.Make up circ equipment on jt#257. Calc disp=30.06 bbls Act disp=37.72 bbls. OA=150 psi 10/4/2016 10/4/2016 1.00 COMPZN RPCOMP OTHR P Make up top drive.Slack off and latch 8,235.0 8,242.0 12:00 13:00 anchor at 8242'MD(Doyon 141 KB). Set down 30K wt.PU 30K overpull and confirm latch up.Slack off to 65K. Pressure up to 1500 psi on tubing.PU to 125K and observe shear out of PBR with 300 psi pressure drop.Bleed off pressure. 10/4/2016 10/4/2016 1.00 COMPZN RPCOMP HOSO P PU and space out.Lay down jts 257, 8,242.0 8,215.0 13:00 14:00 256,and 255.Make up 6.12'pup and pick up jt#255. Ran a total of 255 jts 3 1/2"L-80,9.3# EUE 8rd Mod Polycoated tubing, 1 space out pup,6 ea 2 7/8"x 1"GLM's, PBR and anchor assy. No remakes,no rejects 10/4/2016 10/4/2016 1.00 COMPZN RPCOMP THGR P Make up tubing hanger and landing 8,215.0 8,215.0 14:00 15:00 joint. 10/4/2016 10/4/2016 1.50 COMPZN RPCOMP CRIH P PJSM-Displace well with 110 bbls of 8,215.0 8,215.0 15:00 16:30 8.4 ppg inhibited seawater followed by 18 bbls seawater at 3 bpm. ICP=390 psi FCP=350 psi. 10/4/2016 10/4/2016 0.50 COMPZN RPCOMP HOSO P Land tubing 7'from fully located. 8,215.0 8,235.0 16:30 17:00 RILDS. PU=103K SO=63K. 10/4/2016 10/4/2016 1.50 COMPZN RPCOMP PRTS P Test tubing to 3000 psi/30 min 8,235.0 8,235.0 17:00 18:30 charted.Bleed tubing down to 1000 psi.Test IA to 2500 psi/30 min charted.Bleed off tubing pressure and shear SOV. 10/4/2016 10/4/2016 0.25 COMPZN RPCOMP OWFF P Monitor well.Static. 8,235.0 8,235.0 18:30 18:45 10/4/2016 10/4/2016 1.00 COMPZN WHDBOP MPSP P Lay down landing joint.Set BPV and 8,235.0 0.0 18:45 19:45 test in direction of flow to 1000 psi/10 min charted. 10/4/2016 10/4/2016 1.50 COMPZN WHDBOP NUND P PJSM-ND BOPE.Sim-ops/Clean pits 0.0 0.0 19:45 21:15 and drip pan.Disassemble mud pumps 10/4/2016 10/5/2016 2.75 COMPZN WHDBOP NUND P PJSM-Prep wellhead,NU adapter 0.0 0.0 21:15 00:00 flange and tree.Test hanger seals and adapter to 250/5000 psi/10 min. 10/5/2016 10/5/2016 1.00 COMPZN WHDBOP NUND P NU tree 0.0 0.0 00:00 01:00 10/5/2016 10/5/2016 1.50 COMPZN WHDBOP PRTS P Fill tree and test with diesel.250/5000 0.0 0.0 01:00 02:30 psi. 10/5/2016 10/5/2016 0.50 COMPZN WHDBOP MPSP P Pull BPV 0.0 0.0 02:30 03:00 Page 9/10 Report Printed: 10/20/2016 • • 0 Operations Summary (with Timelog Depths) a 3C-15 Ccochilii ss Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKE) V 10/5/2016 10/5/2016 1.50 COMPZN WHDBOP FRZP P R/U and freeze protect well with 70 0.0 0.0 03:00 04:30 bbls of Diesel. PUmped @ 2 bpm/ 700 psi. 10/5/2016 10/5/2016 1.00 COMPZN WHDBOP FRZP P Let well equalize.Continue with 0.0 0.0 04:30 05:30 emptying pits and rigging down equipment. 10/5/2016 10/5/2016 0.50 COMPZN WHDBOP MPSP P Set BPV 0.0 0.0 05:30 06:00 10/5/2016 10/5/2016 1.00 DEMOB MOVE RURD P 'Clean cellar,clean wellhead,Empty 0.0 0.0 06:00 07:00 pits and prep for rig move. ***Rig Release @ 07:00 hrs*** Page 10/10 Report Printed: 10/20/2016 y ;: KUPD 3C-15A ConocoPhiHips & 0 a Well Attribut Max Angle TD • I Wellbore APVUWI Field Name Wellbore Status ncl r) MD(RKB) Act Btm(ftKB) Alaska,Inc, h ''''r 500292142601 KUPARUK RIVER UNIT PROD 69.38 7,584.28 9,327.0 Csxwcohhil..,. ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date DEVIATED-3C-15A,11/2/20163:54:28 PM SSSV:NONE 120 11/28/2013 Last WO: 9/23/2016 37.30 10/9/1985 Verbpl schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 8,511.0 4/5/2016 Rev Reason:WORKOVER,SEE NOTES pproven 11/1/2016 Casing btnngs 01.11.1141.1.1•101111.111•1 u, )l''. ,,...Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Hanger;37.4 -l3 t J'. CONDUCTOR 16 15.062 36.0 116.0 116.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.765 35.2 3,840.7 3,680.8 36.00 J-55 BTC Casing Description OD(in) ID(in) Top MKS) Set Depth(RKB) Set Depth(TVD)...WVLen(I...Grade Top Thread WINDOW A 9 8.000 2,749.0. 2,754.0 2,748.9 Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I.,.Grade Top Thread CONDUCTOR;36.0-116.0-4 PRODUCTION POST 7 6.276 33.0 2,760.0 2,754.6 26.00 J-55 BTC SIT Casing Description .OD(in) ID(in) Top(ftKB) Set Depth)ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread air LINER LINER TOP 51/2 4.950 2,525.8 8,725.0 6,127.7 15.50 L-80 Hydril 511 GAS LIFT;2,484.5 [ Liner Details Nominal ID Top(ftKB) Top(TVD)(RKB) Top Incl 0 Item Des Com (in) 2,525.8 2,525.1 6.46 PACKER BAKER"CPH"LINER TOP PACKER C-2 PROFILE 4.940 "2500 psi MAX"' 2,536.7 2,535.9 6.89 HANGER BAKER HMC LINER HANGER 4.960 Casing Description OD On) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread LINER BTM 31/2 2.992 8,481.9 9,323.5 6,617.2 9.20 L-80 hydril 511 Liner Details WINDOW A;2,749.04,754.0`_411 PRODUCTION POST SIT; Nominal ID 33.0-2,760.0 Top(RKB) Top(ND)(kKB) Top Incl C) Item Des Com (in) * 8,481.9 5,924.3 36.11 SBE ZXP EXTENSION 4.120 GAS LIFT;3,729.4 i 8,506.4 5,944.2 35.46 PACKER BAKER HR ZXP LINER TOP PACKER 3.000 XO Reducing(Tubing);3,735.4 7 _ JK 8,514.8 5,951.0 35.24 HANGER BAKER HMC LINER HANGER 2.940 9223.3 6,536.8 35.96 BAFFLE BOT BAFFLE SUB 2.970 SURFACE;35.23,840.7-.- I k Tubing Strings Tubing Description String Ma...ID(in) Top(RKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection Upper Completion 3 1/2 2.670 37.4 8,242.7 5,757.2 10.13 L-80 EUE 8rd Completion Details 111. Nominal ID GAS LIFT;5,021.2 S Top(kl(B) Top(ND)(ftKB) Top Incl C) Item Des Com (in) s 37.4 37.4 0.00 Hanger CIW 3-1/2 EUE 8rd x 7-1/16"TBG Hanger w/3"Type H 2.950 Nil BPV profile I 8,228.3 5,748.9 55.42 Locator Baker PBR Seal Locater 2.990 8,228.7 5,749.1 55.40 PBR Baker 80-40 PBR(7 ft space out) 2.670 8,242.3 5,756.9 54.51 SEAL ASSY Baker"KBH-22"Anchor Seal Assembly 2.990 IF GAS LIFT;6,443.2 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection w Tubing-Production 3 1/2 2.992 44.6 8,500.0 5,939.0 9.30 L-80 IBTM NI Completion Details Top(RKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) Nominal ID 8,406.7 5,865.9 42.19 NIPPLE D NIPPLE w/2.75"NO GO l. 2.750 IMF 8,481.2 5,923.7 36.13 LOCATOR BAKER LOCATOR 3.990 GAS LIFT;7,604.6 - l 8,482.4 5,924.7 36,10 SEAL ASSY BAKER 80-40 PBR w/SEAL ASSEMBLY 2.990 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection lail Stacked Packer 31/2 2.670 8,242.7 8,349.1 5,824.8 10.13 L-80 EUE 8rd GAS LIFT;8,169.7 y Completion Details Nominal ID Top(ftKB) Top(ND)(kKB) Top Incl C) Item Des Corn (in) ! 8,292.9 5,787.7 50.70 Nipple-DB, 2-7/8"x 2.312"DS Nipple with POS RHC plug 2.313 Locator,8,228.3- XN,DS,D PBR,8,228.7.. I= _ SEAL ASSY;0,242.3- I- 8,342.3 5,820.1 47.09 Overshot Baker Poor Boy Overshot(6.31'Swallow) 3.625 Packer(Tubing);8,242.7 - -_ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 7 Top(ND) Top Incl 1r Top(ftKB) (ftKB) C) Des Corn Run Date ID(in) Nipple-DB,XN,DS,D;8,292.9 - 8,511.0 5,947.9 35.34 PLUG PUMPED CEMENT ON TOP OF PLUG,CEMENT 4/3/2016 1 NOT TESTED 8,547.0 5,977.5 34.36 PLUG EXTENDED REACH WFD CBO(1.43'DAL) 10/4/2015 I Perforations&Slots Overshot;8,342.3 'T Shot Mt Dens `kTop(ND) Btm(ND) (shots) NIPPLE;8,406.6 _ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type COB Itt 9,015.0 9,037.0 6,367.4 6,385.1 A-3,3C-15A 10/25/2008 6.0 APERF 2.5"PJ HSD guns,60 LOCATOR;8,481.2 lEt deg random 9,038.0 9,058.0 6,385.9 6,402.1 A-3,3C-15A 8/26/2008 6.0 IPERF 2.5"HyperJet,60 deg pH SEAL ASSY;8,482.4 - I I 9,059.0 9,062.0 6,402.9 6,405.3 A-3,3C-15A 10/25/2008 6.0 APERF 2.5"PJ HSD guns,60 deg random 9,078.0 9,115.0 6,418.2 6,448.4 A-2,3C-15A 10/25/2008 6.0 APERF 2.5"PJ HSD guns,60 PLUG;0,511.0 deg random PLUG;8,547.0 Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Btm(ND) I (ftKB) (RKB) (ftKB) (ftKB) Stg# Type Date Com 9,038.0 9,058.0 6,385.9 6,402.1 1 FRAC 9/1/2008 Pumped A-Sand FRAC using YF150D w/total LINER TOP;2525.0-8,725.0 193991#of 16/20 Carbolite pumped;172981# APERF;9,015.0-9,037.0 behind pipe;85%of design;10 ppa on formation IPERF;9,038.09,058.0 FRAC;9,038.0\ , , Mandrel Inserts APERF;9,059.0-9,062.0 SI ati APERF;9,078.0-8115.0 N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com ( 1 2,484.5 2,483.9 Camco KBMM 43/4-PROD GLV BK 0.156 1,340.0 10/14/2016 a 2 3,729.4 3,597.8 Camco KBMM 4 3/4 PROD GLV BK 0.156 1,288.0 10/15/2016 LINER BTM;8,46199,323.5 KUP gifD 3C-15A r Conoco Phillips vz,6.„� Alaska,Inc. J CxWcoPhillips .° ••• DEVIATED-3C-15A,11/2/20163:5429 PM Vertical echematic(actual) „_ Mandrel Inserts _ I( st ir Hanger,37.4 +. ati N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn IN 3 5,021.2 4,461.0 Camco KBMM 43/4 GAS LIFT GLV BK 0.188 1,268.0 10/14/2016 III CONDUCTOR;3s.a11s.o---1 "-4 6,443.2 5,042.3 Camco KBMM 4 3/4 PROD OV BK 0.250 0.0 10/14/2016 5 7,604.6 5,498.6 Camco KBMM 4 3/4 PROD DMY BK 1.000 10/5/2016 6 81169.7 5,717.2 Camco KBMM 43/4 PROD DMY BK 1.000 10/5/2016 NNE 7 Notes:General&Safety GAS LIFT;2,484.5 End Date Annotation 8/1/2008 NOTE:WELL SIDETRACKED 8/14/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 10/17/2012 NOTE:RIGS'DIFFERENT RKBs ACCOUNT FOR CSG/TUBING TOPS 3/27/2014 NOTE:SET BTM INT DGLV W/EXTENDED PACKING,GLM#3(5447'RKB) 2/19/2015 NOTE:MAINTAIN 3700 PSI OVER TBG PSI ON CONTROL LINE 10/23/2016 NOTE:Polycore Ultratube installed.Minimize wellbore entries and use of sharp edges WINDOW A;2,749.0-2,754.0, . PRODUCTION POST S/T; 330-2,760.0 GAS LIFT;3,729.4 I XO Reducing(Tubing);3,736.4 7 IV SURFACE;35.2-3,840.7 i MK 7 GAS LIFT;5,021.2 K 7 it I ME 7 GAS LIFT;6,443.2 S 7 ilt ii 7 GAS LIFT;7,604.6 F 1 rE V GAS LIFT;8,169.7 a `r Locator;8,228.3_ cm, WM PBR;8,228,7_ SEAL ASSY;8,242.3. Packer(Tubing);8,242.7 — 11 W 7 Nipple-DB,XN,DS,D;8,292.9 I- Oco48ot; 8,342.3 P' VIL NIPPLE;8,406.6 LOCATOR;8,4812 SEAL ASSY;8,482.4 iiii iiii PLUG;8,511.0 PLUG;8,547 0 LINER TOP;2,525.8-8,725.0 APERF;9,015.0-9,037.0 (PERE;9,0380-9,058.0 FRAC;9,038.0, C ] APERF;9,059.0-9,062.0 APERF;9,078.0-9,115.0 — ItiAi LINER BTM;8,481.9-9,323.5 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, February 15, 2015 6:12 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: 3C-15A(PTD# 208-081) Report of sustained inner casing pressure Attachments: image001.png Chris- This is an email regarding the 10-403 that was originally intended to be submitted for the remainder of the well work to secure the well in preparations for a rig work over on 3C-15A. Because the remaining work to pull the lower patch assembly and re-set the WRP is not intended to be corrective action but intended to secure the well properly for a rig work over a 10-403 will not be submitted. The actual repair work requiring a 10-403 will occur during the RWO. The appropriate paper work for the repairs will be submitted at that time. Please let me know if you disagree. Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 AWELLS TEAM conocahmior SCANNED iv* if 4 ,? From: NSK Problem Well Supv Sent: Friday, February 13, 2015 1:56 PM To: Wallace, Chris D (DOA) • Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: 3C-15A(PTD# 208-081) Report of sustained inner casing pressure Chris- Kuparuk producer 3C-15A(PTD#208-081) has recently been reported for SCP of the IA. The well was previously secured with a WRP above the existing tubing patch for tubing by IA communication. The WRP was pulled so the existing tubing patch could be removed and the WRP could be re-set below the seal assembly in preparation for a RWO. Due to complications pulling the lower section of the patch,the WRP has not been re-set and the IA pressure has climbed to 2550 psi. The well has 7" 26 ppf J-55 casing from surface to a liner top packer at 2526'. The pipe from the liner top to the seal assembly is 5.5" 15.5 ppf L-80. The current pressure exceeds forty five percent of the J-55's burst pressure which is 4980 psi. It is CPAI's intentions to pump a heavier fluid down the tubing to help maintain a manageable pressure until the remaining well work can be scheduled and completed. A 10-403 will be submitted for the remainder of the well work to remove the lower section of the patch and re-set a WRP below the seal assembly. Please let us know if you have any questions or disagree with this plan. Attached is a 90 day TIO plot and well bore schematic. Dusty Freeborn /Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907)943-0450 1 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday, February 13, 2015 1:56 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: 3C-15A (PTD# 208-081) Report of sustained inner casing pressure Attachments: image001.png; 3C-15A.pdf; 3C-15A 90 day TIO plot.JPG Chris- Kuparuk producer 3C-15A(PTD#208-081) has recently been reported for SCP of the IA. The well was previously secured with a WRP above the existing tubing patch for tubing by IA communication. The WRP was pulled so the existing tubing patch could be removed and the WRP could be re-set below the seal assembly in preparation for a RWO. Due to complications pulling the lower section of the patch,the WRP has not been re-set and the IA pressure has climbed to 2550 psi. The well has 7" 26 ppf J-55 casing from surface to a liner top packer at 2526'. The pipe from the liner top to the seal assembly is 5.5" 15.5 ppf L-80. The current pressure exceeds forty five percent of the J-55's burst pressure which is 4980 psi. It is CPAI's intentions to pump a heavier fluid down the tubing to help maintain a manageable pressure until the remaining well work can be scheduled and completed. A 10-403 will be submitted for the remainder of the well work to remove the lower section of the patch and re-set a WRP below the seal assembly. Please let us know if you have any questions or disagree with this plan. Attached is a 90 day TIO plot and well bore schematic. Dusty Freeborn/Jan Byrne Problem Wells Supervisor SCA$ED ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907)943-0450 WELLS TEAM Conocatilllips1 u 5 S O N O 8 ✓ x u W (O y a oc 2 5 Ibap N N r O V� O�' P f f f Q O 11 LL 0 Inu, 1/5 r i as as o � ` z c • J v o v C yr, l C O O N N d G r t30x I v E _ I A A o 0 0 o Q o0 0 0 00 0000000 0 0 Z arw trsa^ +�® R R C r▪7 ry CJ sd 3 H d W KUP PROD 3C-15A Conor P fillips ; Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status �ncl(") MD(ftKB) Act Btm(ftKB) Ly,,kyiki" 500292142601 KUPARUK RIVER UNIT PROD 69.38 7,58428 9,327.0 -.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date DEVIATED-3C-15A,5/25/201410.3048 AM SSSV:TRDP 120 11/28/2013 Last WO: 8/1/2008 37.30 10/9/1985 Vertical schematic(actual) Annotation Depth OMB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,0420 2/9/2014 Rev Reason:SET PLUG lehallf 5/25/2014 Casing Strings kI y,y Casing Ducription OD(in) ID(in) Top(ftKB) Set Depth(NM Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 116.0 116.0 62,50 H-40 WELDED HANGER 37.4 ■ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WOLen(I...Grade Top Thread SURFACE 95/8 8.765 35.2 3,840.7 3,680.8 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth IftKBI Set Depth(TVD)... Wt/Len 0...Grade Top Thread CONDUCTOR,38.0-116.0 k WINDOW A 9 8.000 2,749.0 2,754.0 2,748.9 Casing Description OD(in) ID(in) Top(MB) Set Depth(NK131 Set Depth(TVD)... WVLen(I...Grade Top Thread - PRODUCTION POST 7 6276 330 2,760.0 2,754.6 26.00 J-55 BTC CR SAFETY VLV;1,999.0Aill Casing Description OD(in) ID(in) Top(MO) Set Depth(ftKB) 'Set Depth(TVD)...WVLen(I...Grade Top Thread LINER TOP 51/2 4.950 2,525.8 8,725.0. 6,127.7 15.50 L-80 Hydril 511 Liner Details Nominal ID Top(ftKB) Top(TVD)INKB) Top Incl F) Item Des Com (in) GAS LIFT,2,510.9rf 2,525.8 2,525.1 6.46 PACKER BAKER"CPH"LINER TOP PACKER C-2 PROFILE 4.940 "2500 psi MAX- 1 2,536.7 2,535,9 6.89`HANGER BAKER HMC LINER HANGER 4.960 1I Casing Description IOD(in) IID(in) Top(NKB) IS t Depth(ftKB) 'Set Depth(TVD)...'WtlLen(I...I Grade 'Top Thread LINER BTM 31/2 2.992 8.481.9 9,323.5 6,6172 9.201L-80 hydril 511 Liner Details Nominal ID r ' Top INKB) Top(TVD)(ftKB) Top Incl(°) Item Des _ Com (in) WINDOW A,2,749.0-2,754.0 8,481.9 5,924.3 36.11 SBE ZXP EXTENSION 4.120 PRODUCTION POST SIT; 33.0-2,780.0 8,506.4 5,944.2 35.46 PACKER BAKER HR ZXP LINER TOP PACKER 3000 8,514.8 5,951.0 35.24'HANGER BAKER HMC LINER HANGER 2.940 9,223.3 6,536.8 35.96 BAFFLE BOT BAFFLE SUB 2.970 SURFACE,35.2-3,840.7-. .. Tubing Strings Tubing Description 'String Ma...IID(in) I Top(ftKB) 'Set Depth(#..'Set Depth(ND)(...I Wt(113/ft) (Grade 'Top Connection TUBING WO 1 31/2 2.992 374 8,5009 5,939.7 9.301L-80 IBTM GAS LIFT,3,887.5 Completion Details Nominal ID 1-- Top(NKB) Top(TVD)(MB) Top Incl(") Item Des Corn (in) 37.4 37.4 0.00 HANGER GEN V TUBING HANGER 3.030 GAS LIFT;5,447.86 1,999.0" 1,998.9 1.68 SAFETY VLV 'TRMAXX-5E SAFETY VALVE w/2.812'X PROFILE 2.812 8,407.5" 5,866.5 42.11 NIPPLE '0 NIPPLE w/2.75"NO GO 2.750 1---, 8,482.1 5,924,4 36.11 LOCATOR "BAKER LOCATOR 3.990 8,483.3 5,925,4 36.08 SEAL ASSY 'BAKER 80-40 PBR w/SEAL ASSEMBLY 2.990 GAS LIFT;7,277.1- ' Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (") Den Com Run Date ID(in) �, 8,331.0 5,812.5 47.93 PLUG "Vi/RP SET ATMID ELE 8333' 5/21/2014 GAS LIFT;8,322.4 8,341,0 5,819.3' 47.18"PACKER 'WEATHERFORD ER PACKER ER TEST TOOL 1/7/2011 1.750 3/18/14 PLUG;8,331.0 8,343.0' 5,820.6 47.03"PATCH 'SPACER PIPE/SLICK STICK OD 3.75"ID 1/6/2011 ' 1.750 1.992/SPACER PIPE/SLICK SITCK/SPACER PIPE i- (OAL=67') PACKER.8,34108,350.0 5,825.4 46.51 FISH BOTTOM 5"OF OV FROM 8322' 10/4/2010 0.000 8,406.0 5,865.4' 42.24 SEAL Bottom of Patch Assy:D NIPPLE SEALS w/NO GO 1/6/2011 1.700 FISH;8,3500 &• PATCH;8,3430 li Perforations Slots ,I Shot SEAL;8,408.0 Dens Top)TVD) Ben(ND) (shots# NIPPLE;8,407.5 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 9,015.0 9,037.0 6,367.4 6,385.1 A-3,3C-15A 10/25/2008 6.0'APERF 2.5"PJ HSD guns,60 deg random LOCATOR;8,482.0 9,038.0 01 9,058.0 6,385.9 6,402.1 A-3,3C-15A 8/26/2008 6.0 IPERF 2.5"HyperJet,60 deg SEAL ASSY;8,483.3 pH 9,059.0 9,062.0 6,402.9 6,405.3.A-3,3C-15A 10/25/2008 6.0 APERF "2.5"PJ HSD guns,60 deg random 9,078.0 9.115.0 6,418.2 6,448.4'A-2,3C-15A 10/25/2008 6.0 APERF '2.5"PJ HSD guns,60 deg random Stimulations 8 Treatments Min Top Men Ben Depth Depth Top(TVD) Ben(TVD) IRKS) (MB) (ftKB) (NCB) Type Date Com 9,038.0 9,058.0 6,385.9 6,402.1 FRAC 9/1/2008 Pumped A-Sand FRAC using YF150D wdotal 193991#of 16/20 Carbolite pumped;172981#behind pipe;85%of design;10 ppa on formation LINER TOP;2525.8-8,725.0 Mandrel Inserts St APERF;9,015.0-8,0370 all on N Top)TVD) Valve Latch Port SW TRO Run - -1 Top(ftKB) INKB) Make Model OD(in) Sete Type Type (In) (psi) Run Date _ Corn (PERF;9,03AC;9,8.0-9,03858.00 { 2,510.9 2,510.2 Camco KBG-2- 1 GAS LIFT DMY BTM ' 0.000 0.0 3/18/2014 FR , 9 - - 2 3,867.5 3,700.8Camco KBG-2- 1 GAS LIFT DMY BTM ' 0.000 0.0'3/20/2014 APERF;9059.0-9,082.0 9 _ _ 3 5,447.7 4,653.1'Camco KBG-2- 1 GAS LIFT DMY INT 0000 0.0 3/27/2014 APERF:9,078.0-9,1150 - 9 4 7,277.2 5,374.4 Camco KBG-2- 1 GAS LIFT DMY INT 0.000 0.0:3/20/2014 in9 - 5 8,322.4 5,806.8.Camco KBG-2- ' 1 GAS LIFT 'DMY INT 0.000 0.0 3/19/2014 9 Notes:General&Safety End Date Annotation 8/1/2008 NOTE:WELL SIDETRACKED 8/14/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 LINER BTM;8,481.99,323.5 KUP PROD 3C-15A • ConocoPhillips t Alaska.Inc. DEVIATED-3C-15A,5/25/2014 10:30:48 AM Vertical schematic(actual) I I Notes:General&Safety 1 na. End Date Annotation HANGER.37 a ■_ �`1 10/17/2012 NOTE:RIGS'DIFFERENT RKBS ACCOUNT FOR CSG/TUBING TOPS 32712014 NOTE:SET BTM INT DGLV W/EXTENDED PACKING,GLM#3(5447'RKB) CONDUCTOR;36.0-115.0 SAFETY VLV,1.989.0 - GAS LIFT;2,510.0 • WINDOW A;2.749.0-2,754.0 PRODUCTION POST S/T; 33.0.2,760.0 SURFACE;35.2-3.840.7— GAS LIFT;3.867.5 — I GAS LIFT;5.447.8 GAS LIFT;7,277.1 GAS LIFT;8,321.4 PLUG;8.331.0 ri PACKER;8,341.0 FISH;8,350.0 I . PATCH;8,343.0 SEAL;8,406.0 NIPPLE;8,407.5 LOCATOR;8,482.0 II SEAL ASSY;8,483.3 1s( LINER TOP;2.525.8-0,725.0 APERF;0,015.0-0,037.0 (PERF;0,038.0-0,058.0 C 1 FRAC;0.038.0 0 APERF;9,0580-9.0620 APERF;0,078.0-0,116.0 I LINER BTM,8,4810-0,323.5 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. ~~~ - ~~~ Well History File Identifier II I I I' I II (I II ( ~ (II I O anizin (done) r9 9- Two-sided II I II'I II II II I II III ^ Rescan Needed RES N DIGITAL DATA OVERSIZED (Scannable) Color Items: ^ Diskettes, No. ^ Maps: /T N Oth e: G~ ~ ~ ~ Other Items Scannable by ^ Greyscale Items: yp er, o ` V a Lar a Scanner S g j.,, o G ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ` /® /s/ Pro -ect Proofing II I II II II I I III I I III ,(~ " BY: Maria Date: /s/ ~ ~ ~ ~ ~ =TOTAL PAGES ~~ Scannin Pre aration 9 x 30 = + (Count does not include cover sheet) BY: _ Maria Date: ~' ~ `7 II ~ l sl Production Scanning Stage 1 Page Count from Scanned File: ~O (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ,~ YES BY: Maria Date: Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO /s/ NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II ~I II I II II I I III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III I'll! III II'I III 10/6!2005 Well History File Cover Page.doc STATE OF ALASKA ALASKA APAND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Repair well J Plug Perforations 0 Stimulate ❑ Other ® Install Patch - After Casing o Pull Tubing ❑ Perforate New Pool [ Waiver [ Time &tension ❑ Change Approved Program 0 Operat. Shutdow n ® Perforate [ Re -enter Suspended Well 0 2. Operator Name: 4. Well Class Before Work: • 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ . '` 208 -081 3. Address: 6. API Number. Stratigraphic ❑ Service [ P. O. Box 100360, Anchorage, Alaska 99510 50 - 029 - 21426 - — 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025634 / ADL0025629 + 3C - 15A 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 9327 feet Plugs (measured) None true vertical 6620 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 8341 true vertical - 0 feet (true vertucal) - 5819 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 116 116 0 0 SURFACE 3805 9.625 3841 3681 3520 2020 PRODUCTION 7793 7 7826 5578 4980 4330 . Perforation depth: Measured depth: 9018 -9037, 9038 -9058, 9059 -9062, 9078 -9115 True Vertical Depth: 6368 -6385, 6386 -6402, 6403 - 6405, 6418 -6448 f - n, ` iOfiSs e. „ S all R m age Tubing (size, grade, MD, and TVD) 3.5, L -80, 8501 MD, 5940 TVD, WFT 1.750" ID ER PATCH FROM 8339 - 8408 Packers & SSSV (type, MD, and TVD) PACKER - Baker "HR" ZXP Liner Top Packer @ 8506 MD and 5944 TVD SAFETY VLV - 3.5" TRMAXX -5E SCSSV w/ 2.812" X Profile IBTM @ 1999 MD and 1999 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data , r Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after work: .. Copies of Logs and Surveys run Exploratory 0 Development ® Service [ Stratigraphic 15. Well Status after work: .• Oil El Gas 0 WDSPL a Daily Report of Well Operations x GSTOR ® WINJ 0 WAG 0 GINJ ❑ SUSP ❑ SPLUG [ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt • N/A Contact Martin Walters / Brent Rogers Printed Name Martin Walters Title: Problem Wells Supervisor Signature Phone: 907- 659 -7224 Date: 02/01/11 RBDMS FEB 04 MN ? �� -7 - 1/ Form 10 -404 Revised 10/2010 �/ Submit Original Only • • 3C -15A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 1/31/2011 IRE -TIFL (PASSED) 1/26/2011 SET SLIP STOP CATCHER. REPLACED GLV @ 2510' RKB WITH 1/4" OV. PULLED CATCHER. COMPLETE. 1/7/2011 SET 2.724 ER PACKER, SPACER PIPE, AND JJ SLICK STICK (17' OAL, MIN ID 1.75 ") @ 8339' RKB. BLED 1350 PSI OFF IA, CONFIRM SET. COMPLETE. PULLED CA -2 PLUG @ 8407' RKB. SET LOWER SECTION @ 8381' RKB (JJ TIE BACK RECEPTACLE, SPACER PIPE, NO -GO SEAL ASSEMBLY, 26' 5.5" OAL, MAX OD 2.80 ", 1/6/2011 MIN ID 1.875 "). SET MIDDLE SECTION @ 8355' RKB (SAME AS ABOVE, 26' 11" OAL, MAX OD 2.735" , MIN ID 1.75 "). COMBO TESTED TBG x IA AGAINST PATCH SECTIONS IN HOLE, GOOD IN PROGRESS. LEAK DETECTION LOG/ CALIPER - PUMPED 1BPM DOWN TUBING, TOOK RETURNS UP IA JUMPERED TO FLOWLINE. SUSPECTED LARGER LEAK ZONE AT 8370', SMALLER LEAK ZONES AT 8381', AND 8388'. DURING JOB PLUG BEGAN TO LEAK. STOPPED 10/30/2010 PUMPING, BUILDING PRESSURE OBSERVED IN IA, OPENED IA TO FLOWLINE, SPINNER DATA SHOWED PRODUCTION PAST PLUG EXITING TUBING THROUGH LARGER LEAK ZONE @8370'. LOGGED CALIPER FROM 8396' TO SURFACE- DATA SENT TO PDS FOR PROCESSING. STATE OF ALASKA ALASKP� AND GAS CONSERVATION COMMIS* REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell fl Rug Perforations r Stimulate r Other Install Patch Alter Casing r Rill Tubing E Perforate New Pool r Waiver ' Time Extension Change Approved Program r Operat. Shutdow n Perforate [ Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory r r 208 - 081 3. Address: 6. API Number: Stratigraphic r Service ' "" P. O. Box 100360, Anchorage, Alaska 99510 50 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25634, 25629 . 3C - 15A 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 9327 feet Plugs (measured) None true vertical 6620 feet Junk (measured) 8350' Effective Depth measured 9221 feet Packer (measured) 2526, 8506, 8341 true vertical 6535 feet (true vertucal) 2525, 5944, 5820 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 116 116 SURFACE 3805 9 -5/8" 3841 3681 PRODUCTION 7793 7" 7826 5578 LINER TOP 6199 5.5 8725 6127' LINER BOTTOM 842' 3.5 9324 6617' RFC '! 'kw. °.twu. Perforation depth: Measured depth: 9016- 9062', 9078' -9115' r 0 " - 1011 True Vertical Depth: 6368'- 6405', 6418' -6448' FEB `" o 20fi i x , Coos. �s�:i: fission Tubing (size, grade, MD, and TVD) 3.5, L -80, 8500 MD, 5940 TVD 1 ''?'1 , 0 6 Packers & SSSV (type, MD, and TVD) PACKER - BAKER 'CPH' PACKER @ 2526 MD and 2525 TVD PACKER - BAKER 'HR' ZAP LINER TOP PACKER @ 8506 MD and 5944 TVD PACKER - WEATHERFORD ER PACKER @ 8341 MD and 5820 TVD SAFETY VLV - 3.5" TRMAXX -5E SCSSV @ 1999 MD and 1999 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 290 849 566 -- 116 Subsequent to operation 317 15 219 -- 105 13. Attachments 14. Well Class after work: - Copies of Logs and Surveys run Exploratory r Development'; Service r Stratigraphic 15. Well Status after work: ■ Oil WI Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ J '" SUSP r SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce ae 265 -6471 Printed Name John Peirce Title Wells Engineer Signature r _ Phone: 265-6471 Date z /2 /.L 1. R M5 FEB 4 2111 Subm Original Only Form 10 -404 Revised 10/2010 � � ,�Z• /( 9 Y ,,, ,-,4( 3C -15A Well Work Summary DATE SUMMARY 1/6/11 PULLED CA -2 PLUG @ 8407' RKOSET LOWER SECTION @ 8381' RKB (JJ. BACK RECEPTACLE, SPACER PIPE, NO -GO SEAL ASSEMBLY, 26' 5.5" OAL, MAX OD 2.80 ", MIN ID 1.875 "). SET MIDDLE SECTION @ 8355' RKB (SAME AS ABOVE, 26' 11" OAL, MAX OD 2.735" , MIN ID 1.75 "). COMBO TESTED TBG x IA AGAINST PATCH SECTIONS IN HOLE, GOOD. IN PROGRESS. 1/7/11 SET 2.724 ER PACKER, SPACER PIPE, AND JJ SLICK STICK (17' OAL, MIN ID 1.75 ") @ 8339' RKB. BLED 1350 PSI OFF IA, CONFIRM SET. COMPLETE. 1/26/11 SET SLIP STOP CATCHER. REPLACED GLV @ 2510' RKB WITH 1/4" OV. PULLED CATCHER. COMPLETE. 1/31/11 RE -TIFL (PASSED) KU P • 3C -15A ConocoPhillips 1 1 Well Attributes Max Angle & MD TD sii.3 {r'aC. { . .' y Wellbore API,UWI Field Name Well Status Ind ( MO (ftKB) Act Btm (MKS/ acgF#h7kps 5016292142601 KUPARUK RIVER UNIT PROD 69 38 7,584.28 9,32/ 0 {,crfe -�- - -_ C ent I H2S (ppm) Date (Annotation End Date KB (ft) Rig Release Date SSSV TRDP 120 12/24/2009 'Last WO: 8/1/2008 37 30 10/9/1985 ws: Co PE.Y.V TER .e..C,159.72U. /N13,#Z.`.RA4., -_ Annotat on Depth OMB) End Date Annotation [Last ... (End Date Last Tag: SLM 9,180.0 , 12/1/2010 Rev Reason: Pull Plug, Set Patch GLV C/O Imosbor 1/27/2011 Casing Strings ,,,- �- C C g D UC TOR pt Str g 16 0... Str 15 g 062 ID Top (ft36 KB) 0 Set D 11 pth 6 0 11 (f Set D pth 6 (TV . 0 D) ... Strg Wt...'Str -4g 0 'St trig W ELDED Top Thrd 62 m H -... _._ Casing Description String 0... String ID .. Top (itK6) Set Depth (f Set Depth (WD)... String V✓1... String String Top Thrd FI „ SURFACE 9 5/8 8.765 35.2 3,840.7 3,680.8 36.00 J-55 BTC ' - - -� -- Casing Description String 0... String ID ._ Top (ftKB) Set Depth (f... Set Depth (WD)... String Wt... String ... String Top Thid HANGER, 37 F t PRODUCTION 7 6.151 33.1 7,8258 8 S 578.2 26.00 J - 55 BTC � Casing Description String 0... String ID ._ Top (ftKB) Set Depth (5... Set Depth (ND) ... String Wt... String .. String Top Thrd LINER TOP 5 1/2 4.950 2,525.8 8,725.0 6,1277 15.50 L Hydril 511 CONDUCTOR, 36 -116 ,Liner Details Top Depth (ftKB) _ , .. (ND) Top Ind Norni... SAFETY VLV, _ 0tKB), (`) Item Descripti ID (in) Olt on Comment ).BBB Toe 6.41 _.�... ._. _.. _ 2,525.8 2,524.8 6.41 PACKER Baker "CPH" 5.5" x 7" Liner Top Packer C -2 profile * *2500 psi MAX * ** 4.940 2,536.7 2,535.7 6.85 HANGER Baker HMC Liner Hanger 5.5 Vam Pin x Pin 4.960 1 GAS LIFT, ;„ Casing Description String 0... String ID ..ITOp (ftKB) ISet Depth ff...I Set Depth (ND)... String Wt... String String Top Thrd 2,511 LINER BTM 3 1/2 2.992 8,481 9 9,323.5 6,617.2 9.20 L-80 hydrl 511 Illif Liner Details t43I : -. ( TOP Depth 2 (ND) Top Inc! Nomt... 1 I f :1 Tpp7HKB) (ftKB) (") Item Description Comment ID (in) 8,481.9 5 924.6 36.15 SBE ZXP extension (4.80" OD / 4.12" ID) 4.120 8,506.4 5,944.2 35.48 PACKER Baker "HR" ZXP Liner Top Packer (4.67OD 13.00ID) 3.000 8,514.8 5,951.0 35 25((ANGER Baker HMC Liner Hanger (4 51' OD 12.94" ID) 2940 9,2233 6 5368 35 95 BAFFLE BOT Baffle Sub 3 1/2 ", 9 3 ppf 3 1/2" IBT Box x Pin 2 970 SURFACE, 363.841 Tubing Strings ( Tubing Description String 0 String ID ... Top (ftKB) Set Depth )f... Set Depth (ND) . String Wt... String String Top Thrd GAS LIFT„__.. 1 I UBINC 31/2 2992 I 37.4 I 8,500.8 I 59398 I 9.30 I L80 I IBTM 3.888 p (TVD) Depth To ftKB) ( r 'ncl 5.448 p,r 37.4 To KB Top _._ N .). Completion Details GAS LIFT,_ ) ftKB Rein Description Comment ID (n) HANGER 3.5" Gen V Tubing Hanger alb 8rd (XO Pup jt 3.18' EUE 8rd Up x IBT 3.030 51/2 liner top, Dn) 2,546 -.-.._ 1,999.0 1,998.9 1.68 SAFETY VLV 3.5' TRMAXX -5E SCSSV w/ 2.812" X Profile IBTM 2.812 GAS LIFT, 8,407.5 5,866.8 41.97 NIPPLE 3.5" D Nipple w/ 2.75" NOGG profile 2.750 Ur 8,482.1 5,924.7 36.15 LOCATOR Baker 3 5" Locator 0.0.4.54" I D. 3.99" 3.990 $4813 5,925.7 36 12 SEAL ASSY Baker 80 -40 PBR w /Seal Assembly O.D. 4.01' I . 2 99 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (ND) Top In0l !' Top (ftKB) (ftKB) ( 1 ) Description_,. Comment Run Date ID (in) 8,341.0 5,819.7 47.21 PACKER WEATHERFORD ER PACKER 1/7/2011 1.750 8,343.0 5,821.0 47.06 PATCH SPACER PIPE/SUCK STICK OD 3.75" ID 1.992/SPACER 1/6/2011 1.750 PIPE /SLICK SITCK/SPACER PIPE (OAL =67') PRODUCTION, ` 33 - 7,826 8,350.0 5,825.6 46.53 FISH BOTTOM 5" OF OV FROM 8322' 10/4/2010 0.000 8,406.0 5 865 0 42 09 SEAL Bottom of Patch Assy: D NIPPLE SEALS wINO GO 1/62011 1.700 GAS LIFT, 8,322 ` Perforations & Slots IOU Top (TVD) Bim (TVD)' Shot I Dens PACKER, 8,341 - Top (fIKB) Ban (MB) (ftKB) (ftKB) Zone Date (sit_ Type Comment I ! 9,015.0 9,037.0 6,367.5 6,385.1 A-3, 3C-15A 10/25/2008 6.0 APERF 2.5" PJ HSD guns, 60 deg random FISH, 8,350 - - - 9,038.0 9,058.0 6,385.9 6,402 1 A -3, 3C -15A 8/26/2008 6.0 IPERF 2.5" HyperJet, 60 deg pH PATCH,8,343 - '-` --` - - ^ 8,059.0 9,062.0 6,402.9 6,405.3 A -3, 3C -15A 10/25/2008 6.0 APERF 2.5" PJ HSD guns, 60 deg random SEAL, e,406 - - - -- 9,078.0 9,115 0 6,418.2 6,448.4 A -2, 3C-15A 10/25/2008 6.0 APERF 2 5" PJ HSD guns, 60 deg random NIPPLE, 8,488 `__- litr Stimulations & Treatments 11111, Bottom Min Top Max Ben Top Depth Depth LOCATOR, 1 - Depth Depth (TVD) (TVD) 8,482 ` (ftKB) (8113) MKS) (ft913) Type Data Comment SEAL ASSY, z : 9,038.0 9,058.0 6,385.9 6,402.1 FRAC 9/1/2008 Pumped ASand FRAC using YF1500 w /total 8,483 193991# of 16/20 Carbolite pumped; 172981# behind pipe; 85% of design 10 ppa on formation Cemen Top Depth Btm Depth (TVD) (TVD) Top (0118) BOn((nKB1 (ftKB) (ftKB) Description Start Date Comment 2,546.0 5,800.0 2,545.0 4,789.11 SQUEEZE 7/17/2008 Liner Top was clown squeezed from top with 48 bble 15.8 ppg cement. 8,500.0 8,725.0 5,939.1 6,127.7 SQUEEZE 7/19/2008 Squeezed thru landing collar and floats Via stab in retainer. Shoe sot, 8,500 LINER TOP, 2,526 -8,725 APERF, 9,015 -9.037 K _ ' MERE, . ,Mandrel _ 4etails ..W ,. i " 3.2 FRAC. 9, 5.0 B _ . _ - -! (TVD) Inc! OD Valve Latch Sae TRO Run APERF, _ Ste Top_(HKB) (998) ( ") Make Model (in) ) Sery Type Type (in) (psi) Run Date Com. 9.0599.002 1 2,510.9 2,509.9 5.80 Camco KBG -2 -9 1 GAS LIFT OV INT 0.250 0.01262011 APERF, 2 3,867.5 3700.7 41.70 Camco KBG -2 -9 1 GAS LIFT GLV INT 0.156 1,372.0 10/7/2010 9,078 - 9,115 3 5,447.8 4,653 .0 64.23 Camco KBG -2 -9 1 GAS LIFT GLV (NT 0.156 1,346.0 10/26/2010 4 7,277.2 5,374.4 66.97 Cameo KBG -2 -9 1 GAS LIFT GLV INT 0.188 1,362.0 10/10/2008 r° 5 8,322.4 5,806.9 48.58 Camco KBG -2 -9 1 GAS LIFT OV INT 0.250 0.0 10/27/2010 LINER BTM, Q482 -9,324 TD (3P150), 9,327 • • 7 WELL LOG TRANSMITTAL PROAci wE D SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing lnspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey WOWED FEB 01 2011 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Caliper Report 30-Oct-10 3C -15A 1 Report / EDE 50-029 - 21426 -01 2) ao , _ 65 1 ( -p 4 t oLo Signed : Date : .a a1 ... Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -88952 EMAIL : odsanch oraoearnemorvioa.COm WEBSITE : `+oNVJ.memorvtog.iz rn ,,) _ C:\Documents and Settings\Diane WilliamsSDesictop\Tn ns n t Cmwco docx I • • Memory Multi - Finger Caliper iip Log Results Summary 1 1 1 , I Company: ConocoPhillips Alaska, Inc. Well: 3C -15A Log Date: October 30, 2010 Field: Kuparuk Log No.: SO# 7741976 State: Alaska Run No.: 1 API No.: 50 -029- 21426 -01 I Pipel Desc.: 3.5" 9.3 lb. L -80 IBTM Top Log Intvl: Surface Pipet Use: Tubing Bot. Log Intvl: 8,396 Ft. (MD) I Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : I This caliper data is correlated to the tubing detail dated July 30, 2008. This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. I The caliper recordings indicate the 3.5" tubing logged appears to be in good to poor condition, with a probable hole recorded in joint 265 (8,380'). A 3 -D log plot of the caliper recordings across the probable hole is included in this report. Wall penetrations ranging from 40% to 89% wall thickness are recorded in 26 of the 279 joints logged. Recorded damage appears as isolated pitting and a deep line of pits from 5,070' to I 8,396' (EOL). No significant areas of cross - sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. I This summary report is interpretation of data provided by Halliburton Well Services. MAXIMUM RECORDED WALL PENETRATIONS : I Probable Holes ( 89 %) Jt. 265 © 8,380 Ft. (MD) Line of pits ( 64 %) Jt. 264 © 8,366 Ft. (MD) Line of pits ( 58 %) Jt. 184 © 5,829 Ft. (MD) I Line of pits Line of pits ( 57 %) Jt. 191 © 6,043 Ft. (MD) (57 %) Jt. 198 @ 6,264 Ft. (MD) MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : I No significant areas of cross - sectional wall loss (> 7 %) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS : I No significant la restrictions are recorded throughout the tubing logged. I I I Field Engineer: J. Conrad Analyst: C. Waldrop Witness: B. Boehme I I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS @memorylog.com I Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 • • PDS Multifinger Caliper 3D Log Plot 1 VS Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3C -15A Date : Octo ber 30, 2010 I Description : Detail of Caliper Recordings Across Probable Hole Reco rded in 3.5" Tu bing. Comments Depth Max. Pen. ( %) Maximum I.D. 3 -D Log Image Map I 1 in 116 1ft200ft 0 1002.5 inches 3.5 92° 0° 90° 180° 270° 0° I I Minimum I.D. I 2.5 inches 3.5 Nominal I.D. • 2.5 inches 3.5 Joint 262 I I t = _ C 1 8290 1 II ' I If hill 1111111111111111 1111111111111111 Joint 263 830 1 IIIIIMMUll 11111 1 I 8310 t #� LIM ill INN MI Ism _ 1 Pup Jt. 8320 •ii. JIIIU. GLM 5 , — .■iNIU – I IIII 8 330 'ammo Pup Jt. jl NI AMIN 4 1111 _ 1 MIME 8340 ■1MINI= NI =•M Joint 264 -2I ` � �. _ Line of pits 8350 1 : :: 1111•• 64% Wall 111111111111 1 Penetration i� is.. `• 1141 _` M ill• _ _ • p. I -Woo -1.-- _ 8370 Joint 265 swam Mill I Line of pits $3$0 �� Mi ���� FIFI•-• P s— – 1 flE I, _ Probable Hole l ( 8,380') Br- . �� I Ii fi. - Ilrill 8390 _ #' 1 End of Log Ii 11111111•M 1111■11111111 1 1 ' of Recorded Damage to Borehole profile Correlation g 1 • Pipe 1 3.5 in (53.9' - 8366.3') Well: 3C -15A Field: Kuparuk Company: ConocoPhillips Alaska, Inc. I Country: USA Survey Date: October 30, 2010 1 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 58 I 25 802 1 50 1574 I 1 75 2364 GLM 1 - _� I 100 it, 3156 Q I GLM2 °' E 125 3953 c Z _ J a I ° 150 _ Z 4731 0 GLM 3 175 –i ~ 5530 I 200 — 1 6306 225 7085 ::: 265 8366 I 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) 1 Bottom of Survey = 265 1 1 • • I PDS Report Overview Body Region Analysis I Well: 3C -15A Survey Date: October 30, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. Hal. Company: ConocoPhillips Alaska, Inc Tool Size: 1.69 Country: USA No. of Fingers: 24 I Analyst: C. Tubing: Nom.OD Weight Grade &Thread Nom.ID Nom. Upset Waldrop Upper len. Lower len. 3.5 ins 9.3 ppf L -80 IBTM 2.992 ins 3.5 ins 6.0 ins 6.0 ins 1 Penetration and Metal Loss (% wall) Damage Profile (% wall) I penetration body metal loss body im penetration body i metal loss body 0 50 100 250 0 1 200 150 100 1 50 , • El I/ 49 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% _1 1 Number of joints analysed (total = 279) GLM 1 pene. 0 186 39 28 25 1 95 loss 50 229 0 0 0 0 I GLM 2 Damage Configuration ( body) -3 143 80 I 60 GLM 3 i er∎xxew . 40 191 --_._ .. 20 0 GLM 4 =- isolated general line ring hole /poss 239 7:: I pitting corrosion corrosion corrosion ible hole -- Number of joints damaged (total = 77) GLM 5 1 76 0 0 0 1 Bottom of Survey = 265 1 Analysis Overview page 2 1 1 1 • PDS REPORT 1 OINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L -80 IBTM Well: 3C -15A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: October 30, 2010 I Joint Jt Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) % ) Upset Body Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 • .1 54 0 0.02 9 1 2.88 PUP I 1 58 0 0.01 2 1 2.95 1.1 88 0 0.01 4 0 3.00 PUP 1 2 92 0 0.01 5 2 2.94 3 123 0 0.01 2 2 2.96 I 4 153 0 0.02 9 2 2.95 5 184 0 0.01 4 2 2.96 • 6 214 0 0.02 9 3 2.94 r 7 245 0 0.01 4 1 2.94 8 276 0 0.01 2 1 2.95 9 307 0 0.01 5 1 2.95 10 338 0 0.01 5 2 2.95 1 11 370 0 0.01 6 2 2.96 12 401 0 0.01 2 2 2.94 ' 13 432 0 0.01 2 2 2.95 14 461 0 0.01 5 1 2.96 15 492 0 0.01 2 1 2.94 16 523 0 0.01 2 2 2.95 I 17 554 0 0.01 4 2 2.94 18 586 0 0.01 4 2 2.95 • 19 617 0 0.02 9 2 2.95 20 647 0 0.01 2 2 2.95 i I 21 22 678 0 0.01 4 2 2.94 709 0 0.01 2 2 2.96 23 740 0 0.01 2 2 2.95 24 771 0 0.01 3 1 2.93 I 25 802 0 0.01 5 2 2.95 i 26 834 0 0.01 5 2 2.94 27 865 0 0.01 4 1 2.95 1 28 895 0 0.01 4 2 2.96 1 I 29 926 0 0.01 5 2 2.96 30 958 0 0.01 2 1 2.96 t 31 988 0 0.01 4 2 2.96 32 1019 0 0.01 2 1 2.93 33 1049 0 0.01 4 1 2.95 i I 34 1080 0 0.02 9 2 2.95 35 1110 0 0.01 2 2 2.96 • 36 1141 0 0.01 4 1 2.96 i 37 1172 0 0.01 6 2 2.96 I 38 1203 39 1235 0 0.01 5 2 2.94 0 0.01 2 2 2.95 40 1266 0 0.01 5 1 2.96 41 1297 0 0.01 4 2 2.95 1 I 42 1328 0 0.01 2 2 2.95 43 1360 0 0.01 5 2 2.94 44 1391 0 0.03 11 3 2.94 4 i 5 1422 0 0.01 4 2 2.94 46 1453 0 0.02 8 2 2.96 r I 47 1482 0 0.01 2 1 2.94 48 1513 0 0.01 5 2 2.96 Penetration Body 1 Metal Loss Body Page 1 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 IBTM Well: 3C -15A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: October 30, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) To (Ins.) 0 50 100 49 1544 0 0.01 2 1 2.97 50 1574 0 0.01 2 2 2.95 51 1606 0 0.01 2 2 2.96 52 1636 0 0.01 4 2 2.96 1 53 1668 0 0.01 2 2 2.96 54 1700 0 0.01 4 2 2.93 55 1731 0 0.01 4 2 2.95 56 1762 0 0.01 5 2 2.95 57 1793 0 0.01 2 2 2.95 ` 58 1824 0 0.01 4 3 2.94 59 1854 0 0.01 2 2 2.95 60 1886 0 0.01 2 2 2.95 1 61 1916 0 0.01 2 2 2.94 1 1 62 1947 0 0.01 2 2 2.95 63 1979 0 0.01 2 2 2.96 1 63.1 2009 0 0.01 2 0 2.98 PUP 1 63.2 2014 0 0 0 0 2.81 3.5" TRMAXX -5E SCSSV 63.3 2019 0 0.01 6 0 _ 2.99 PUP 1I I 64 2025 0 0.01 2 2 2.96 1 65 2057 0 0.01 5 1 2.94 11 66 2086 0 0.01 5 1 2.95 1 67 2117 0 0.01 2 2 2.94 i I 68 2149 0 0.01 4 2 2.95 69 2179 0 0.01 5 3 2.95 ' 70 2208 0 0.00 2 1 2.95 71 2239 0 0.01 4 2 2.95 1 72 2270 0 0.01 2 1 2.97 II ' I 73 2302 0 0.01 4 2 2.95 1 t 74 2333 0 0.01 2 2 2.94 I 75 2364 0 0.02 9 2 2.93 • 76 2394 0 0.01 4 1 2.95 77 2425 0 0.01 4 0 2.94 78 2456 0 0.01 5 2 2.96 79 2487 0 0.03 10 2 2.95 I 79.1 2519 0 0.00 2 1 2.95 PUP 79.2 2524 0 0 0 0 N/A GLM 1 (No Deviation) 79.3 2531 0 0.03 10 2 2.94 PUP 80 2537 0 0.01 6 2 2.97 81 2568 0 0.02 9 2 2.94 • 82 2599 0 0.01 4 2 2.95 83 2631 0 0.02 8 2 2.96 • 84 2661 0 0.03 12 2 2.95 85 2693 0 0.01 3 2 2.93 1 86 2725 0 0.02 9 2 2.95 ' 87 2756 0 0.01 4 2 2.94 88 2785 0 0.01 4 1 2.97 89 2816 0 0.01 2 1 2.95 1 90 2848 0 0.01 4 2 2.95 ' 91 2879 0 0.00 2 1 2.96 92 2910 0 0.01 4 1 2.93 Metal Penetration Loss Bo dy II ' Page 2 IN TABULATION SHE PDS REPORT JOINT l Pipe: 3.5 in 9.3 ppf L -80 IBTM Well: 3C -15A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: October 30, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 93 2939 0 0.01 2 2 2.95 I 94 2971 95 3002 0 0.01 4 2 2.92 0 0.02 9 2 2.95 1 • 9 • 6 3033 0 0.02 9 2 2.93 97 3064 0 0.01 4 2 2.95 I 98 3095 99 3125 0 0.01 4 2 2.97 0 0.01 4 2 2.93 100 3156 0 0.01 5 1 2.95 1 • 101 3186 0 0.02 9 2 2.95 I 102 3218 0 0.01 4 1 2.95 t 103 3249 0 0.01 3 2 2.95 104 3279 0 0.00 2 1 2.96 105 3311 0 0.03 10 2 2.94 • • 106 3342 0 0.02 9 2 2.96 I 107 3373 0 0.03 10 2 2.94 • 108 3405 0 0.02 9 2 2.94 • 109 3435 0 0.02 9 2 2.95 • 110 3467 0 0.03 10 2 2.93 I 111 3498 0 0.01 4 2 2.93 112 3530 0 0.01 2 2 2.94 1 • 113 3561 0 0.03 10 1 2.95 114 3593 0 0.01 2 2 2.95 1 I 115 3624 0 0.02 9 2 2.94 il 116 3655 0 0.02 8 2 2.95 117 3686 0 0.02 9 2 2.95 118 3716 0 0.02 9 2 2.94 I 119 3748 0 0.01 4 2 2.96 120 3778 0 0.03 10 2 2.93 • 121 3808 0 0.03 10 2 2.95 • • 122 3839 0 0.03 10 2 2.96 I 122.1 3870 0 0.01 2 1 2.98 PUP 122.2 3878 0 0 0 0 N/A GLM 2 (Latch @ 10:30) 122.3 3884 0 0.03 11 1 2.94 PUP • 123 3892 0 0.03 11 3 2.93 C 124 3924 0 0.02 9 2 2.93 r 1 125 3953 0 0.01 2 2 2.94 126 3981 0 0.04 15 2 2.94 Shallow pitting. 127 4013 0 0.02 9 2 2.94 • 128 4044 0 0.02 9 1 2.94 • I 129 4075 0 0.03 10 2 2.96 • 130 4107 0 0.04 14 2 2.96 Shallow pitting. •• • 131 4138 0 0.03 12 1 2.96 132 4169 0 0.01 2 2 2.95 1 I 133 4201 0 0.04 16 4 2.94 Shallow pitting. C 134 4231 0 0.02 9 2 2.93 135 4262 0 0.03 13 2 2.94 Shallow pitting. 136 4294 0 0.02 8 3 2.93 C I 137 4326 0 0.02 9 2 2.94 138 4355 0 0.03 11 1 2.92 139 4387 0 _ 0.03 10 2 2.95 • 1 Penetration Metal Loss Body Page 3 1 1 • • PDS REPORT JOINT TABULATION SHEET l Pipe: 3.5 in 9.3 ppf L -80 IBTM Well: 3C -15A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal LD.: 2.992 in Country: USA Survey Date: October 30, 2010 joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 140 4418 0 0.01 4 2 2.96 I 141 4450 0 0.01 4 2 2.94 142 4480 0 0.03 10 2 2.94 143 4512 0 0.01 5 _ 2 2.95 144 4542 0 0.01 4 2 2.94 I 145 4573 0 0.01 2 1 2.96 146 4605 0 0.02 9 1 2.95 147 4637 0 0.01 4 3 2.95 148 4669 0 0.03 11 2 2.94 • I 149 4700 0 0.03 12 3 2.95 • 150 4731 0 0.04 14 2 2.95 Shallow pitting. ■ 151 4762 0 0.03 11 2 2.95 • 152 4793 0 0.05 19 2 2.94 Shallow pitting. • 153 4825 0 0.04 18 2 2.94 Shallow pitting. • I 154 4855 0 0.04 16 3 2.95 Shallow pitting. 155 4889 0 0.01 5 2 2.94 156 4919 0 0.03 12 2 2.94 • 157 4950 0 0.04 14 2 2.93 Shallow pitting. ■ I 158 4980 0 0.03 13 2 2.95 Shallow pitting. ■ 159 5012 0 0.05 19 2 2.93 Shallow pitting. o 160 5042 0 0.02 9 2 2.94 161 5075 0 0.04 16 2 2.95 Shallow line of pits. ■ I 162 5105 0 0.04 16 2 2.95 Shallow line of pits. • 163 5136 0 0.05 19 2 2.96 Shallow line of pits. • 164 5167 0 0.07 28 2 2.94 Line of pits. ■ 165 5198 0 0.05 21 2 2.94 Line of pits. ■ I 166 5228 0 0.07 26 2 2.93 Line of pits. • 167 5260 0 0.06 24 2 2.96 Line of pits. au 168 5291 0 0.07 29 2 2.93 Line of pits. • 169 5323 0 0.07 28 2 2.95 Line of pits. • I 170 5354 0 0.07 29 2 2.95 Line of pits. • 171 5384 0 0.07 29 4 2.93 Line of pits. Lt. Deposits. ■ 172 5415 0.05 0.08 31 4 2.96 Line of pits. 172.1 5449 0 0.01 4 1 2.97 PUP 172.2 5456 0 0 0 0 N/A GLM 3 (Latch @ 4:00) I 172.3 5463 0 0.01 2 1 2.98 PUP 173 5469 0 0.09 36 2 2.94 Line of pits. ■ 174 5501 0 0.08 31 2 2.92 Line of pits. - 175 5530 0 0.11 44 3 2.93 Line of pits. • I 176 5562 0 0.07 26 2 2.95 Line of pits. - 177 5593 0 0.11 42 3 2.94 Line of pits. ■ 178 5624 0 0.09 37 2 2.92 Line of pits. • 179 5654 0 0.11 43 3 2.94 Line of pits. • I 180 5686 0 0.13 52 2 2.95 Line of pits. • 181 5718 0 0.11 43 2 2.96 Line of pits. • 182 5750 0 0.09 34 2 2.94 Line of pits. • 183 5780 0 0.01 5 2 2.93 I 184 5810 0 0.15 58 4 2.94 Line of pits. ■ 185 5840 0 0.09 37 2 2.93 Line of pits. ■ 186 5874 0 0.09 37 2 2.94 Line of pits. • Body I 'Penetration Metal Loss Body Page 4 1 1 • PDS REPORT 1 OINT TABULATION SHE! 1 Pipe: 3.5 in 9.3 ppf L -80 IBTM Well: 3C -15A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: October 30, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments Damage (Ins.) (Ins.) % (Ins.) 0 50 100 187 5904 0 0.11 43 2 2.93 Line of pits. I 188 5937 0 0.11 42 3 2.94 Line of pits. 189 5968 0 0.03 11 3 2.95 190 6000 0 0.12 49 2 2.94 Line of pits. 191 6028 0 0.15 57 2 2.94 Line of pits. I 192 6061 0 0.06 24 1 2.94 Line of pits. 193 6091 0 0.11 45 2 2.93 Line of pits. 194 6122 0 0.05 20 2 2.94 Shallow line of pits. 195 6152 0 0.11 42 2 2.95 Line of pits. I 196 6183 0 0.09 35 3 2.93 Line of pits. 197 6214 0 0.09 35 3 2.93 Line of pits. 198 6245 0 0.15 57 3 2.93 Line of pits. 199 6276 0 0.09 35 6 2.94 Line of pits. I 200 6306 0 0.01 4 2 2.94 201 6338 0 0.10 37 2 2.95 Line of pits. 202 6369 0 0.09 37 2 2.93 Line of pits. 203 6399 0 0.13 53 7 2.93 Line of pits. 204 6433 0 0.02 9 2 2.94 I 205 6464 0 0.08 31 2 2.95 Line of pits. 206 6495 0 0.14 56 2 2.93 Line of pits. 207 6525 0 0.11 42 3 2.92 Line of pits. 208 6556 0 0.12 49 2 2.95 Line of pits. I 209 6587 0 0.13 52 3 2.94 Line of pits. 210 6618 0 0.01 4 2 2.94 211 6649 0 0.02 9 3 2.93 212 6679 0 0.03 10 2 2.93 I 213 6711 0 0.04 15 2 2.91 Shallow line of pits. 214 6741 0 0.04 14 2 2.92 Shallow line of pits. 215 6773 0 0.02 9 2 2.93 NI • 216 6805 0 0.04 14 2 2.93 Shallow line of pits. IN 217 6836 0 0.02 9 2 2.93 I 218 6866 0 0.12 48 3 2.92 Line of pits. 219 6896 0 0.03 11 2 2.93 • 220 6928 0 0.02 9 2 2.93 221 6958 0 0.02 9 2 2.93 • I 222 6992 223 7022 0 0.02 9 1 2.93 • 0 0.02 9 2 2.92 i 224 7053 0 0.02 9 2 2.94 225 7085 0 0.02 8 2 2.93 I 226 7116 0 0.09 35 2 2.91 Line of pits. Lt. Deposits. 227 7147 0 0.02 9 2 2.93 MOIR • • 228 7180 0 0.03 11 2 2.92 229 7211 0 0.05 20 2 2.93 Shallow line of pits. MI 1 230 7242 0 0.09 33 2 2.93 Line of pits. 230.1 7274 0 0.02 7 1 2.96 PUP 230.2 7282 0 0 0 0 N/A GLM 4 (Latch @ 3:30) INS 230.3 7287 0 0.01 5 1 2.96 PUP I 231 7295 0 0.03 10 2 2.92 232 7326 0 0.02 9 2 2.92 • 233 7357 0 0.02 9 2 2.93 r Penetration I Metal Loss Body Page 5 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 IBTM Well: 3C -15A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: October 30, 2010 1 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) To (Ins.) 0 50 100 234 7390 0 0.14 54 6 2.93 Line of pits. i I 235 7420 0 0.02 9 2 2.94 236 7450 0 0.03 10 1 2.93 NI 237 7482 0 0.00 2 1 2.92 238 7514 0 0.04 17 2 2.93 Shallow line of pits. • I 239 7545 0 0.04 14 2 2.94 Shallow line of pits. 240 7575 0 0.01 5 2 2.94 241 7607 0 0.03 10 2 2.93 • 242 7638 0 0.03 11 3 2.91 • I 243 7669 0 0.03 12 2 2.93 244 7701 0 0.01 2 2 2.94 1 245 7732 0 0.03 11 2 2.93 246 7762 0 0.02 9 2 2.92 I 247 7794 0 0.02 9 2 2.95 248 7823 0 0.00 2 1 2.94 249 7854 0 0.01 4 2 2.92 250 7885 0 0.03 10 2 2.93 251 7917 0 0.01 2 2 2.93 I 252 7949 0 0.02 9 2 2.93 253 7979 0 0.02 9 2 2.93 r 254 8009 0 0.07 28 3 2.92 Line of pits. • 255 8041 0 0.13 50 3 2.92 Line of pits. • I 256 8071 0 0.12 48 3 2.93 Line of pits. • 8103 0.12 0.13 50 3 2.94 Line of its. • ■ 257 p 258 8132 0 0.14 55 3 2.92 Line of pits. • 259 8163 0 0.09 37 3 2.93 Line of pits. • I 260 8193 0 0.07 28 2 2.94 Line of pits. II 8226 0 0.03 13 2 2.91 Shallow line of pits. oil 8255 0 0.03 10 2 2.95 IN 263 8287 0 0.03 10 2 2.92 I 263.1 8316 0 0.01 2 2 2.98 PUP 263.2 8322 0 0 0 0 N/A GLM 5 (Latch @ 4:30) 263.3 8327 0 0.04 17 2 2.96 PUP Shallow line of pits. • 264 8335 0 0.16 64 3 2.92 Line of pits. • 265 _ 8366 0.08 0.23 89 6 2.93 Probable Hole! Penetration Body Metal Loss Body 1 1 1 1 Page 6 1 1 1 • • 1 PDS Report Cross Sections ____„Sk_ ib I Well: 3C -15A Kuparuk Survey Date: October 30, 2010 Field: Tool Type: UW MFC 24 No. Hal. Company: ConocoPhillips Alaska, Inc Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf L-80 IBTM Analyst: C. Waldrop 1 I Cross Section for Joint 265 at depth 8380.05 ft Tool speed = 43 Nominal ID = 2.992 I Nominal OD = 3.500 Remaining wall area = 96 % Tool deviation = 46 ° 1 1 1 1 1 1 1 ■ I Finger 3 Penetration = 0.225 ins Probable Hole 0.23 ins = 89% Wall Penetration HIGH SIDE = UP 1 1 1 Cross Sections page 1 1 1 1 • • 1 PDS Report Cross Sections I Well: 3C -15A Kuparuk Survey Date: October 30, 2010 Field: Tool Type: UW MFC 24 No. Hal. Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf L-80 IBTM Analyst: C. Waldrop 1 1 I Cross Section for Joint 264 at depth 8365.89 ft Tool speed = 43 Nominal ID = 2.992 I Nominal OD = 3.500 Remaining wall area = 97 % Tool deviation = 48 ° 1 1 1 1 1 I Finger 7 Penetration = 0.162 ins Line of pits 0.16 ins = 64% Wall Penetration HIGH SIDE = UP I 1 1 1 Cross Sections page 2 1 1 1.-- KU P 3C -15A • I Co 1.-- r & Attributes ngle &MD TD Al:iskit, (Ix:. I re APW WI Field Name Well Status MD p6® Act Ben MKS) ConocoFtwtpr 500292142601 KUPARUK RIVER UNIT PRODUCING 69.38 7,584.28 9,327.0 Comment 1128 (ppm) Date AmotaBon taxi Date IBdird (11) Rig Release Date - SSSV: TRDP 120 12/24/2009 Last WO: 8/1/2008 37.30 10/9/1986 I well Co n1 4. DEVIATED - 3ci5A, 10/9/2010 844:26 AM - - _ - - -- - -- - - -- /9 schematic - Actual Annotation Depth MKS) BW Doe Annotation Last Tag: SLM 9,012.0 10/8/2010 Rev Reason: TAG, GLV C /O, PULL CATCHER lmosbor 10/9/2010 Casing Strings Last Mod._ End Date _ Casing Description String 0... String ID... Top (11148) Set Depth (f -. Set Depth 1TVD) ... String Wt.. String ... Meng Top Tnrd CONDUCTOR 16 15.062 36.0 116.0 116.0 62.50 H -00 WELDED L - i - - - - - - casing Desalpflan 91 9 5 0.,. 84i11W 10._ Top (a1B 8'43D840.1- epth Set D epth (ND) ... 0-11169 WL.. SMng... String Top TAtd SURFACE 95/8 8.765 35.2 , 3,680.8 36.00 J-55 BTC Casing Description String o_ String ID._ Top MKS) Set Depth (f_ Set Depth (TVD).- String Wt.. String... String Top Tlvd wwGER, 37 PRODUCTION 7 6.151 33.1 7,825.8 5,578.2 26.00 J-55 BTC w ing Description String 0... String ID - Top (RPM) Set Depth (L.. Set Depth (ND) ... String WL.. String... String Top Thrd LINER TOP 51/2 4.950 2,525.8 8,725.0 6,127.7 15.50 L-80 Hydril 511 Liner Details Top Depth ' Depth 1 Top owl ID (In) T ( 1116 ) n item Description Comment sAFE TV1799 0 8 2,524.8 6.41 PACKER Baker "CPH" 5.5" x 7 Liner Top Packer C -2 profile "'2500 psi MAX 4.940 2,536.7 2,535.7 6.85 HANGER Baker HMC Liner Hanger 5.5 Vam Pin x Pin 4.960 Casing Description ating0... St . glD ... To8(�) �De ntDepth (NW ._ Sting .. 8(ing... Smap TMd OM 1 GAS LIFT. UNER BTM I 3 1/2 I 2.992 I 8,481.9 9 323.5 , S 6 61 I 9.20 L 80 hyd 5 2s11 Liner Details � Top Depth (ND) Top Inc! Nomi... Top ROM) Pixel 19 item oesaipe , conmat D M) 8,481.9 5,924.6 36.15 SBE ZXP extension (4.80" OD / 4.12" ID) 4.120 I 8,506.4 5,944.2 35.48 PACKER Baker "HR" ZXP Liner Top Packer (4.67 OD / 3.00` ID) 3.000 8,514.8 5,951.0 35.25 HANGER Baker HMC Liner Hanger (4.51" OD / 2.94" ID) 2.940 9,223.3 6,636.8 35.9516AFFLE BOT Baffle Sub 3-1/2", 9.3 ppf. 3-1/2" IBT Box Pin 2.970 ■ SU Tubin ! Sarin I 353 eat .. Description , , . 0... Sting l • ... Top (, c ) Set Depth sat • oath T •) ._ string .. string... string op Turd 1 TUBING 31/2 2.992 37.4 8,500.8 5,939.8 9.30 L-80 IBTM GAS 3e , -- Completion Details I - Top Depth (TVD) Top Inc' Noml... Top MKS) 1. 0 Rem Description Comment ID MI I GAS LET, NW 37.4 37.4 0.00 HANGER 3.5' Gen V Tubing Hanger EUE 8rd (X0 Pup it 3.18' EUE 8rd Upx IBT 3.030 Dn) 5,448 5ln liner top. 1,999.0 1,998.9 1.68 SAFETY VLV 3.5" TRMAXX -5E SCSSV w/ 2.812" X Profile IBTM 2.812 z.548 8,407.5 5,866.8 41.97 NIPPLE 3.5" D Nipple w/ 2.75" NOGG profile 2.750 GAS LIFT, .277 8,482.1 5,924.7 36.15 LOCATOR Baker 3.5" Locator O.D. 4.54 „ I. D. 3.99" 3.990 7 8,483.31 5,925.71 36.12ISEAL ASSY 'Baker 80-40 PBR w /Seal Assembly O.D. 4.01" I.D. 2.99 1 2.990 ' Other In Hole (reline retrievable plugs, valves, pumps, fish, etc.) V Top Depth (TAD) Top Ines LI Top (18(s) ( C) Description Perfo Coronsnot et Run Date ID en) 8,350rations .0 5,825.6 & Slots 46.53 FISH BOTTOM 5" OF OV FROM 8322' 10/4/2010 0.000 1 1 :[ Top (1VD) atm (ND) Dens PRODUCTION. T op ), onin PIKE) PEN MEIN Zone Date OK- Type Comment 33 9,015.0 9,037.0 6,367.5 6,385.1 A-3, 3C -15A 10/25/2008 6.0 APERF 2.5" PJ HSD gums, 60 deg random ' 9,038.0 9,058.0 6,385.9 6,402.1 A-3, 3C-15A 8/26/2008 6.0 IPERF 2.5" HyperJet, 60 deg pH GAS ,322 FT, 9,059.0 9,062.0 6,402.9 6,405.3 A - 3, 3C - 15A 10/25/2008 6.0 APERF 2.5" PJ HSD guns, 60 deg random IN 8 ` 9,078.0 9,115.0 6,418.2 6,448.4 A-2, 3C -15A 10/25/2008 6.0 APERF 2.5" PJ HSD guns, 60 deg random FISH, 8,350 Stimulations & Treatments i IR Bottom Mn Top Max aim Top Depth Depth Depth Depth (TVD) (TAD) NIPPLE. 8.408 lel MKS) P MB) ) Type Date Comment W. 9,038.0 9,058.0 6,385.9 6,402.1 FRAC 9/1/2008 PUMPED A SAND FRAC USING YF150D WITH A TOTAL OF 193991# OF 16/20 CARBOLITE LOCATOR. 11 PUMPED. WITH 172981# BEHIND PIPE, 85% OF I 8.482 ", FRAC CC W TH 10 PPA ON F RBMATI NOMPLETED SEAL ASSY, 8.x83 I Cement Squeezes Top Depth atm Depth (TVD) (Tw) i Top mg Btm (M(B) 1x9) Rag Desaipdcn Start Date Comment 1 2,546.0 5,800.0 2,545.0 4,789.1 SQUEEZE 7/17/2008 Liner Top was down squeezed from top with 48 bbls 15.8 ppg cement. 8,500.0 8,725.0 5,939.1 6,127.7 SQUEEZE 7/19/2008 Squeezed lEn, landing collar and goats Via stab in retainer. Notes: General & Safety Shoe soz. End Date Annotation I 8,500 8/1/2008 NOTE: WELL SIDETRACKED 8/1/2008 LINER 8,500 2,5249,725 8/14/2008 NOTE: VIEW SCHEMATIC sdAlaska Sctematic9.0 APERF. 9,010-8,037 IPERF, 9,038-9,058 ' Mandrel Details FRAC, 9,038 Top Depth Top Port (ND) ma OD Verve Latch Size TRO Run 9,059 Stn Top 98(B) PPM) (7 Make Model ere Sere TYPE TYPE ON Orel) Run Otte Can_ 1 2,510.9 2,509.9 5.80 Camco KBG -2 -9 1 GAS LIFT GLV INT 0.125 1,368.0 10/11/2008 APERF, 9.07,9,1115 15 2 3,867.5 3,700.7 41.70 Cameo KBG-2-9 1 GAS LIFT GLV INT 0.156 1,372.0 10/7/2010 3 5,447.8 4,653.0 64.23 Camco KBG -2 -9 1 GAS LIFT GLV INT 0.156 1,346.0 10/7/2010 1 4 7,277.2 5,374.4 66.97 Cameo KBG -29 5 8,322.4 5,8065 48.58 Cameo KBG-2-9 1 GAS LIFT GLV INT 0.188 1,362.0 10/10/2008 1 GAS UFT OV 0.250 0.0 10/5/2510 Hybrid OV 1 LINER 9TM, 8,482 -9,324 TO (3C -15A), 1 1 9.327 1 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 3, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 3C -15 Run Date: 10/30/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 X -15 . .... ......... . Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21426-01 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. t� Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.woo alliburtoncom Date: Signed: a 1 ~- ;IT ~~~ Transmittal #969 Detail Date: 2/16/2010 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 Phone Number: (907) 793-1235 Company: AOGCC Address: 333 W. 7th Ave., Ste. 100 City: Anchorage State: AK Zip Code: 99501 Last Name: Elgarico Phone Number: (907) 265-6580 Company: CPAI Address: 700 G St. ATO-1484 City: Anchorage State: AK Zip Code: 99501 `, ,- ~ ~ ,_ ;r ~,~ Transmittal Info: Sent Via: Hand Delivery Tracking #: Justification: Compliance Request Data Detail: Quantity Description 1 3C-15A Digital Images in TIFl: format Attachments: Filename: None Filesize: N/A Received By: Signature: Approver: Signature: Date: Date: ~~~ ~ y ~~~ ~~ i ~ ^ ~. :r .J `a6 - - ~ ":; Type CD ~~~~~~ l ~13~5 DATA SUBMITTAL COMPLIANCE REPORT 2/16/2010 Permit to Drill 2080810 Wel! Name/No. KUPARUK RIV UNIT 3C-15A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21426-01-00 MD 9327 TVD 6620 Completion Date 8/27/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/RES, USIT Well Log Information: Log/ Electr Data Digital Dataset (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / mearrrmc rvumner Name Cement Evaluation C Pds 16677 dement Evaluation LIS Verification C Lis 16870 ~ Induction/Resistivity C Pds 16915 perforation Perforation Report: Final Well R C 16938 ~5ee Notes Mud Log scale meaia No Start Stop CH Received Comments 5 Col 2500 5000 Case 7/28/2008 SUIT, CBL, GR, CCL 17- Ju1-2008 2500 5000 Case 7/28/2008 SUIT, CBL, GR, CCL 17- Ju1-2008 2736 9327 Open 9/12/2008 LIS Veri, GR, RPX, RPS, RPM, FET, RPD, ROP 2736 9327 Open 9/12/2008 LIS Veri, GR, RPX, RPS, RPM, FET, RPD, ROP 8790 9102 Case 9/17/2008 Perf w.SBHPS 27-Aug- 2008 5 Blu 8790 9102 Case 9/17/2008 Perf w.SBHPS 27-Aug- 2008 0 0 Open 9/29!2008 End of Well Report Table of Content. Equip and i Crew, Well Data Geo Data, ~, Pres/Form Data, Drill Data, Daily Reports 0 0 Open 9/29/2008 End of WeII Report Table of Content. Equip and !, Crew, Well Data Geo Data, Pres/Form Data, Drill Data, Daily Reports w.PDS graphics for Logs 2 Col 2749 9329 Open 9/28/2008 MD Formation Log C7 [7 DATA SUBMITTAL COMPLIANCE REPORT 2/16/2010 Permit to Drill 2080810 Well Name/No. KUPARUK RIV UNIT 3C-15A Operator CONOCOPHILLIPS ALASKA INC MD 9327 TVD 6620 Completion Date 8/27/2008 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-21426-01-00 UIC N g Mud Log 2 Col 2749 9329 Open 9/28/2008 TVD Formation Log og Mud Log 2 Col 2749 9329 Open 9/28/2008 MD Combo Log og Mud Log 2 Col 2749 9329 Open 9/28/2008 TVD Combo Log ' og Mud Log 2 Col 2749 9329 Open 9/28/2008 MD Gas Ratio og Mud Log 2 Col 2749 9329 Open 9/28/2008 TVD Gas Ratio Mud Log 2 Col 2749 9329 Open 9/28/2008 MD Drilling Dynamics Mud Log 2 Col 2749 9329 Open 9/28/2008 TVD Drilling Dynamics ED C 16961 See Notes 0 0 Open 9/30/2008 PDF, EMF, CGM graphics for EWR togs Induction/Resistivity 25 Col 2749 9327 Open 9/30/2008 MD ROP, DGR, EWR og Induction/Resistivity 25 Col 2749 9327 Open 9/30/2008 TVD DGR, EWR C Asc ~ Directional Survey 0 9327 Open 8/8/2008 ,. ~ Directional Survey _ 0 9327 Open 8/8/2008 ~ _''. JVell Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y Chips Received? ^'f`TI~ Analysis ~-f-N-' Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~ N Formation Tops ~/ N • t Comments: DATA SUBMITTAL COMPLIANCE REPORT 2/16/2010 Permit to Drill 2080810 Well Name/No. KUPARUK RIV UNIT 3C-15A MD 9327 TVD 6620 Completion Date 8/27/2008 Compliance Reviewed By: ___ Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21426-01-00 Completion Status 1-OIL Current Status 1-OIL ~ / UIC N Date: _~~ l ~ `Z t • ~ . ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 3, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7d' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: .~CEIVED ~u~ o ~ Zoo9 r~laska Oil & Gas Cons. Commission Arscl~~rags aog-o~-~ ~~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRIn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As ,per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped June 16~` & 26d`, 2009 and the corrosion inhibitor/sealant was pumped June 23rd & 30d', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at -659-7043, if you have any questions. Sincerely, ~`~~ ~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/3109 3 C PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3C-01 500292141300 1851870 22' 2.3 28" 6/26/2009 5.9 6/30/2009 3C-02 500292141400 1851880 76' 10.0 22" 6/26/2009 5.1 6/30/2009 3C-03 500292141500. 1851890 5' 1.0 21" 6/26/2009 5.1 6/30/2009 3G04A 500292141601 2020570 4' 1.0 23" 6/26/2009 5.1 6/30/2009 3C-05 500292138900 1851540 24" Na 24" n/a 4.25 6/23/2009 3C-06 500292109600 1840420 6" Na 6" Na 7.65 6/23/2009 3C-07 500292139100 1851560 37' 5.00 25" 6/16/2009 5.52 6/23/2009 3C-08 500292139000 1851550 12' 2.00 22" 6/16/2009 3.4 6/23/2009 3C-09 500292135500 1851000 20" n/a 20" n/a 2.55 6/23/2009 3C-10 500292135600 1851010 30' 4.10 24" 6/16/2009 4.25 6/23/2009 3C-12 500292135400 1850990 45' 9.30 26" 6/26/2009 4.3 6/30/2009 3C-13 500292142400 1851980 20" n/a 20" n/a 2.12 6/23/2009 3C-14A 500292142501 2071750 3' n/a 3' Na 8.07 6/23/2009 G15A 500292142601 2080810 31' 4.40 26" 6/16/2009 2.75 6/23/2009 3C-16 500292142700 1852010 20" Na 20" n/a 2.12 6/23/2009 3G17 500292338900 2080590 2'6" Na 2'6" n/a 8.92 6/23/2009 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA~rIONS 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^~ - Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ ~ Exploratory ^ 208-081 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-21426-01' 7. KB Elevation (ft): 9. Well Name and Number: 47.7' AMSL 3C-15A ' 8. Property Designation: 10. Field/Pool(s): ADL 25634,25629 ' Kuparuk River Field /Kuparuk Oil Pool . 11. Present Well Condition Summary: Total Depth measured 9327' ' feet true vertical 6620' ~ feet Plugs (measured) Effective Depth measured 9221' feet Junk (measured) true vertical 6535' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 116' 116' SURFACE 2712' 9-5/8" 2749' 2744' PRODUCTION 2712' 7" 2749' 2744' LINER TOP 6199' 5-1/2" 8725' 6127' LINER TOP 840' 3-1/2" 9327' 6620' Perforation depth: Measured depth: 9015'-9037', 9038'-9058', 9059'-9062', 9078'-9115' true vertical depth: 6368'-6385', 6386'-6402', 6403'-6405', 6418'-6448' Tubing (size, grade, and measured depth) 3.5", L-80, 8500.85' MD. Packers &SSSV (type & measured depth) Baker'CPH' liner top pkr, Baker'HR' ZXP pkr @ 2526', 8506' SSSV @ 1999' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 326 94 531 -- 123 Subsequent to operation 355 ! 1020 611 - 122 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^O ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact John Peirce @ 265-6471 Printed Name John Peirce ~ Title Wells Group Engineer ~~~ ~~wO$ Date Signature A / ~ Phone: 265-6471 W Pre ared b Sharon Allsu D k 263-4612 W ~ ~/.IO.fJ~ ~ ~ ~ ~,f ~ ~ ~ooa ~t~t~ Form 10-404 Revised 04/2006 Submit Ori I I , ,. 3C-15A Well Work Summary DATE SUMMARY 10/20/08 TAGGED @ 9027' SLM. PROPOSED PERF DEPTH: 9115'. READY FOR CTU. 10/23/08 COIL TUBING FCO WITH 2" DOWN JET,WASHED DOWN TO 9173 CTMD WITH SSW AND BIO SWEEPS, HAD GOOD RETURNS THROUGHOUT CLEAN OUT. FREEZE PROTECTED WELL AND FLOW LINE WITH SLICK DIESEL. WELL SHUT IN FOR SLICK LINE TAG. 10/24/08 TAGGED @ 9137' SLM, SAMPLE OBTAINED. DRIFT TBG W/ 20' OF 2.62" TO 9120' SLM, NO RESTRICTIONS. READY FOR PERF. 10/25/08 PERFORATE WITH 2.5" HSD PJ 2506 LOADED 6 SPF, 60 DEG PHASING FROM 9078'-9115x'. BACK IN AM TO CONTINUE PERFORATING. 10/26/08 PERFORATE 2 1/2" HSD PJ 2506 LOADED 6 SPF, 60 DEG PHASE FROM 9015'- 9037' AND FROM 9059'-9062,' -- KUP ~~~ { ~~[{)~~j~~~~~~ ~~ 1 Well Attributes r ... ~~ ~ _a:: - .; ;.:J.l ANGER 37 ' H , __ CONDUCTOR, °~ 0-116 SAFETY VLV, ~ 1,999 .........III GAS LIFT, 2,517 63,Bg1 GAS LIFT, GAS LIFT, 5,448 5 121iraa top, 2,546 GAS LIFT, 7.277 PRODUCTION, a7,az9 GAS LIFT, 8,322 NIPPLE, 8,408 LOCATOR, 8,482 aEALAaSV, 8,483 shoe soz, e.soD LINER TOP, 2,5268,725 APERF, 9.0759.037 FRAC, 9,038 (PERF, 9,03&9,059 APERF, 9.059-9.062 APERF, i 9,078-9,175 i~ ~~ t F I, [[[v 1 3C-15A 7 ..r:,, , ypr: ,.., l r Wellbore APUUr~I Ferd name ..en our „ 500292142601 KUPARUK RIVER UNIT (PROD ax Lr.,~,,,, 69.38 .°. . °...,.. , ,..,..°, 7,584.28 9,327.0" Commerrt H2S (ppm) Dat e Annotation End Date KB-Grd (R) Rig Release Date SSSV:TRDP ( 100 7/1/2008 LastWO: j 8/1/2008 37.30 10/9/1985 Annotation rDepth (RKB) ;End Date Annotation. ----- - (End Date (Last Tag: SLM ( 9,137.0 ~ 10/24(2008 Rev Reason: TAG FILL, PERF 10/30@008 Casing Strings Gaxrng Dex,:rrpLon '.TU,,,g u._ SiNOy ID ... {op ittkB) Sel Depth (r.-Sei Depth iTVD)... Slang l'J i... ,Siang ... Siring TOp Thrcl CONDUCTOR ~ 16 15.062 0.0 116.0 116.0 62.50 I H-00 ~ Casing Descrtpton String 0... String ID ... lop (RKB) Set Depth (L_ Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 9518 8.765 0.0 3,841.0 3,681.0 36.00 J-55 Casing Description String 0... String ID ... Top (RKB) Set Depth (L_ Set Depth (ND) ... String Wt... String ... SRing Top Thrd PRODUCTION 7 6.151 0.0 7,826.0 5,578.3 26.00 J-55 Casing Descriptlon Strng 0... String ID ... Top (RKB) Set Depth (f._ Set Depth (ND) ... String Wt... String ... String Top Thrd LINER TOP 5 1l2 4.950 2 525.8 A725 n R 197 7 15 50 L-RO Hydril 511 Liner Details _ rop Ucpih (ND1 Top ( Top (RKB) (RKB) Incr (°) Item Deudplion Comment ID (in) 2,525.8 2,524.8 6.41 PACKER Baker "CPH" 5.5" x 7" Dner Top Packer G2 protite "2500 psi MAX"' 4.940 2,536.7 2,535.7 6.85 HANGER Baker HMC Liner Hanger 5.5 Vam Pin x Pin 4.960 8,680.7 6,090.3 32.57 COLLAR Davis Lyndl 5-112" Float Collar, Hydri1521 box x pin 14.950 Casing Description String 0... String ID ... ( Top (RKB) Set Deptlr (f....Set Depth (TVD) ... String Wt... String ~~~ String Top Thrd , ( LINER BTM 3 1/2 2.992 i 8.481.9 9.323.5 ~ 6.617.2 9.20 L-80 hydri151 ~ Liner Details Top fiepih INDI Top Top (RKB) (RKB) Incl (°) Item DeseNpdon Comment ID (in) 8,481.9 5,924.6 36.15 SBE ZXP extension (4.80" OD / 4.12" ID) 4.120 8,506.4 5,944.2 35.48 PACKER ~ Baker "HR" ZXP Liner Top Packer (4.67" OD / 3.00" ID) 3.000 8,514.8 5,951.01 35.251 HANGER Baker HMC Liner Hanger (4.51" OD / 2.94" ID) 2.940 9,221.3 6,535.2 35.89 COLLAR BOT Type 1 Landing Collar 3-1/2" Hydril 511 Box x 167 Pin 2.980 9,223.3 6,536.8 35.95 BAFFLE BOT BafOe Sub 3-112", 9.3 ppf. 3-12" IBT Box x Pin 2.970 9,257.4 1 6,564.3 36.85 COLLAR Weathertord Float Collar (OD 3.52") ( 2.992 .Tubing Strings ITub;ng ocs~.r;~r"~R ~Ir ~,l o so-;~a io r~~ (rtRe1 ~s«t [>Pctn lr. ~s«rr rn~ Iwo1 .c.nmr wc. st ng ;arnng rop ram ~.GomDletion Details lop Deyrh 1 (ND) Top Top (RKB) (RKB) Incl (°) ttem Description ~ Comment ID tin) 37.4 37.4 0.00 HANGER ! 3.5" Gen V Tubing Hanger EUE 8rd (XO Pup jt 3.18' EUE Srd Up x IBT Dn) 3.030 1,999.0 1,998.9; 1.68 SAFETY VLV 3.5" TRMAXX-SE SCSSV w/ 2.812" X Profile (BTM 2.812 8,407.5 5,866.8 i 41.97 NIPPLE 3.5" D Nipple w/ 2.75" NOGO profile 2.750 8,482.1 ~ 5,924.7 36.15 LOCATOR Baker 3.5" Loptor O.D. 4.54" I. D. 3.99" 3.990 8,483.31 5,925.7 36.12 SEAL ASSY Baker 80-00 PBR wlSeal Assembly O.D. 4.01" I.D. 2.99 ~ 2.990 Perfora tions 1 Top (ND) Btm (ND) snot Dens Top (RKB) I Btm (RKB) (RKB) (RKB) Zone Date (sh.° Type Comment 9,015.0; 9,037.0 6,367.5 6,385.1 A-3, 3C-15A 10125/2008 6.0 APERF 2.5" PJ HSD guns, 60 deg random 9,038.0 9,058.0 6,385.9 6,402.1 A-3, 3C-15A 8/26/2008 6.0 (PERF 2.5" HyperJet, 60 deg pH 9,059.0 9,062.0 6,402.9 6,405.3 A-3, 3C-15A 10125/2008 6.O~ APERF 2.5" PJ HSD guns, 60 deg random 9,078.0 9,115.0 6,418.2 6,448.4i A-2, 3C-15A 10125/2008 6.OIAPERF 2.5" PJ HSD guns, 60 deg random Stimulations 8 Treatments I Bottom Min Top Max Btm Top Depth Depth Depth Depth (ND) I (ND) 1 '. (itK6) (RKB) (RKB) ~ (RKB) Type Date Comment 9,038.0 9,058.0 6,385.91 6,402.1 FRAC '9112008 PUMPEDASAND FRAC USING YF150D WITHA ~ I ~ TOTAL OF 193991# OF 1620 CARBOLITE I ~ ~ PUMPED. WITH 172981# BEHIND PIPE, 85%OF DESIGN 21010# LEFT IN TUBING. COMPLETED i t FRAC WITH 10 PPA ON FORMATION. Cement Squeezes I op Depth Btm f)eptn ( Top (RKB) KBI ( KBl Descri Btm (flK6) ( pgon Start Date Comment 2,546.0 5,800.0 2,545.0 4,789.1 SQUEEZE 7/172005 Liner Top was down squeezed from top with 48 bbls 15.8 ppg cement. 8,500.0 8,725.0 5,939.1 6,127.7 SQUEEZE 7/1 912 0 0 8 !Squeezed thm landing collar and floats Via stab in jretainer. ENotes: General 8 Safety Eno Dare notation 8(1/2008 iNOTE: WELL SIDETRACKED 8112008 8/142008 NOTE: VIEW SCHEMATIC wlAlaska Schematic9.0 _ i Mandrel Details reP tiepin rop Port (ND) Inel OD Valve ~ Latch Slze TRO RUn StnTOO lfg(B1 (RKB) (°) Make Model (n) Serv Type li Type lint (psi) I Run Date Comm... 4,653.0 LINER BTM, 9,482-9,324 TD (3C-15A), 9,327 -~ J ConocoPhillips G. C. Alvord Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 October 13, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 3C-15A ~~~~~ ~~T ~ ~ C008 Alaska Oil ~ Gay Con ~. Co~t~i~r;;`~i,~r Anc~h~ii"a~o Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 3C-15A. If you have any questions regarding this matter, please contact me at 265-6120 or David Nugent at 263-4674. Sincerely, ~ - ~ G. C. Alvord Kuparuk Drilling Team Leader CPAI Drilling GCA/skad • STATE OF ALASKA ~~' ~.i~~D ALASKA OIL AND GAS CONSERVATION COMM S ION WELL COMPLETION OR RECOMPLETION RE~1~~ ~Q~D LOG 1a. Well Status: Oil ^/ Gas Plugged ^ Abandoned Suspended t•~ 20AAC 25.105 20AAC 25.110 ~~~~k~ V (~ ~ ~ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. (Well Cla Q~{~`~S'~~ v+h~Y~h~ l ~ J Exploratory ^ G~lt>~ ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp.,~~ y? '~.V' orAband.: Sember~2008 2. Permit to Drill Number: 208-081 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: July 6, 2008 13. API Number: 50-029-21426-01 4a. Location of Well (Governmental Section): Surface: 1193' FNL, 1241' FEL, Sec. 14, T12N, R9E, UM' 7. Date TD Reached: July 24, 2008 14. Well Name and Number: 3C-15A Top of Productive Horizon: 572' FSL, 283' FWL, Sec. 11, T12N, R9E, UM 8. KB (ft above MSL): 84.7' RKB Ground (ft MSL): 47.7' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 684' FSL, 149' FWL, Sec. 11, T12N, R9E, UM 9. Plug Back Depth (MD + TVD): 9221' MD / 6535' TVD Kuparuk Oil Pool " 4b. Location of Well (State Base Plane Coordinates): Surface: x- 528333 y- 5995239 Zone- 4 10. Total Depth (MD + TVD): 9327' MD / 6620' TVD 16. Property Designation: ADL 25634, 25629 TPI: x- 524569 y- 5996990 Zone- 4 Total Depth: x- 524435 • - 5997101 Zone- 4 11. SSSV Depth (MD + TVD): 1999' MD / 1999' TVD 17. Land Use Permit: ALK 2567, 2562 18. Directional Survey: Yes Q No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (1VD): 1700' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): ~t~1 /~.,,,foalof window @ 2749' MD GR/RES, USIT ~/iV00 G o?~ %~D ~~-r7 /TyA G ~~ 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE CEMENTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 37' 116' 37' 116' 24" 1 ss sx CSII 9-5/8" 36# J-55 37' 2749' 37' 2744' 12.25" 950 sx PF'E', 36o sx Class G 7" 26# J-55 37' 2749' 37' 2744' 8.5" 40o sx Class G, 175 sx PF 'C' 5.5" 15.5# L-80 2526' 8725' 2526' 6127' 7" 321 sx Class G 3.5" 9.2# L-80 8487' 9327' 5942' 6620' 4.75" 70 sx Class G 23. Open to production or injection? Yes /^ No ^ If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 8500' 2526', 8506' 9038'-9058' MD ~ 6386'-6405' TVD 6 Spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9038'-9058' 193991# of 16/20 carbolite 26. PRODUCTION TEST Date First Production September 29, 2008 Method of Operation (Flowing, gas lift, etc.) gas lift oil Date of Test 10/1/2008 Hours Tested 22.5 hours Production for Test Period --> OIL-BBL 448 ~ GAS-MCF 237 WATER-BBL 1078 CHOKE SIZE 124 Bean GAS-OIL RATIO 605 Flow Tubing press. 127 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 457 GAS-MCF 271 WATER-BBL 1129 OIL GRAVITY -API (corn) 24.4 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No Q - Sidewall Cores Acquired? Yes No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ~p• ~in.ny~f 71-k.~' Vlf .. ~•rv 1 j NONE ~,jFE~ ) Form 10-407 Revised 2/2007 r'"~ (`~ ~ CONTINUED ON REVERSE SIDE A ~p,gps$ r~ r1 28. GEOLOGIC MARKERS (List all formations and ma s encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes 0 No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1700' 1700' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk D 8709' 6114' Kuparuk C 8805' 6195' Kuparuk B 8878' 6256' Kuparuk A 9009' 6363' Kuparuk A3 9030' 6380' Kuparuk A2 9077' 6417' ° N!A Formation at total depth: Kuparuk A3 ' 30. LIST OF ATTACHMENTS (6 !3 og Summary of Daily Operations, Directional Survey p. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Nugent @ 263-4674 Printed Name G. C. Alvord Title: Drillino Team Leader Signature ti ~~ Phone -~ f S ! ~, Z Date `-' C~a INSTRUCTIONS Prepared by:Sharon Allsup-Drake @ 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 2/2007 3C-15A Sidetrack Summary • DATE SUMMARY 4/5/08 T & IC POT/PPPOT -PASSED, LDS CONFIRMED FUNCTIONAL (PRE-RWO/ST) 4/23/08 TAGGED @ 7349' SLM. MEASURED BHP @ 7200' RKB: 3986 psi. JOB SUSPENDED. 4/24/08 PULLED GLVs AND SET DVs @ 2269, 3938, 5177' RKB. PULLED OV @ 5926' RKB. LOCKED OPEN TRDP-1A-SSA FLAPPER @ 1800' RKB. IN PROGRESS. 4/25/08 SET K-2 PLUG ASS'Y @ 6032' WLM. LOAD TBG / IA WITH SW & DSL FREEZE PROTECT. SET DV @ 5926' RKB. TESTED IA 2000 PSI, GOOD. BLED TO 200 PSI. PULLED SLIP STOP AND K-2 PACKER- PLUG @ 6032' WLM. IN PROGRESS. 4/26/08 PULLED LOWER SLIP STOP @ 6026' WLM. MIT IA 2500 PSI, PASSED_ PERFORMED INJECTIVITY TEST ON C SANDS: 1 BPM @ 1925 PSI. TAGGED @ 7315' WLM, BOTTOM CSM INACCESSIBLE. PULLED DV @ 7138' RKB. READY FOR E/L. 4/27/08 SET HALLIBURTON ENERGY SERVICES (HES) 2-7/8" FASTDRILL CEMENT RETAINER WITH MID-ELEMENT AT 7155'. . 4/29/08 Crew Swap, MIRU Ctu 4 4/30/08 PUMPED A TOTAL OF 61 BBLS OF CEMENT WITH 35 BBLS BELOW CEMENT RETAINER (30 BBLS INTO C SANDI UPON STINGING OUT OF RETAINER COIL BECAME DETAINED UNSURE OF HOW MUCH CEMENT WAS PUSHED INTO IA VIA GLM AT 7133' MD, FCO'D DOWN TO 6850' CTMD ALLOW CEMENT TO BALANCE OUT BETWEEN IA AND TBG. 5/2/08 MITIA FAILED. IA LEAKING VIA GLM MITT PASSED TAG CEMENT @ 7091 RKB W/ 2.3" SWAGE. ATTEMPT TO PULL DV IN STA #6. JOB IN PROGRESS. 5/3/08 PULLED 1" BKDV FROM STA #6 @ 6768' RKB. STILL NEEDS COMBO MIT. JOB SUSPENDED. 5/4/08 CMIT TBG X IA TO 1500 PSI PASSED. 5/9/08 JET CUT TUBING AT 6700' WITH 2 1/8" POWERCUTTER. VAVLE CREW TO SET BPV IN AM. 8/20/08 TAGGED DRILLING MUD @ 8527' RKB, OBTAIN SAMPLE. SET CATCHER SUB @ 8407' RKB. PULL SOV @ 8322' RKB. IN PROGRESS 8/21/08 SET DV @ 8322' RKB. MIT IA TO 2400 PSI. GOOD TEST. PULL CATCHER @ 8407' RKB. READY FOR MUD CLEAN OUT. 8/23/08 PERFORM MUD CLEAN OUT TO PBTD @ 9156 CTMD, WELL IS FREEZE PROTECTED, READY FOR S/L. 8/24/08 DRIFT W/ 21' X 2.5" DMY GUN & TAGGED @ 9158' SLM, NO PROBLEMS. COMPLETE. 8/27/08 PERFORATED INTERVAL 9038'-9058' WITH 2.5" HSD HJ2506 CHARGES - WHP FROM y 175 PSI TO 1450 PSI, PRESSURE STOP 9048' MD: 4343.0 PSIA, 157.1 DEGF, GRADIENT STOP 8910' MD: 4294.9 PSIA, 155.2 DEGF, DID NOT TAG TD 8/28/08 DRIFT TREE W/ 2.92" G-RING, SET FRAC SLEEVE @ 1972' SLM. JOB COMPLETE. 8/31/08 Attempted to pump A sand Frac but equipment failures caused us to abort this attempt and restart at a later date. 9/1/08 PUMPED A SAND FRAC USING YF150D WITH A TOTAL OF 193991# OF 16/20 CARBOLITE PUMPED. WITH 172981# BEHIND PIPE, 85% OF DESIGN 21010# LEFT IN TUBING. COMPLETED FRAC WITH 10 PPA ON FORMATION. PUMPED A TOTAL OF 1841 BBLS OF SW @ AN AVERAGE TREATING PRESSURE OF 5982 PSI. FRAC PRESSURED OUT WITH 146 BBLS OF 10 PPA INTO FORMATION AND 8 BBLS OF FLUSH. (WELL IS NOT FREEZE PROTECTED) 9/7/08 CT POST FRAC FCO 1.75" JSN DOWN TO HARD TAG AT 9180' RKB USING SSW AND BIO SWEEPS. GOOD 1:1 RETURNS THROUGHOUT. 122' OF RAT HOLE BELOW PERFS 9038'-9058'. WELL LEFT FREEZE PROTECTED WITH SD. ~ 9/9/08 TAGGED @ 8944' SLM. PULLED FRAC SLEEVE @ 1999' RKB. FUNCTION TESTED SSSV, GOOD. COMPLETE. ~~ u ConoCOPhi~lips Time Log & Summary ~~,~~~ ~e~ Re~p~,~g Report Well Name: 3C-15 Rig Name: DOYON 15 Job Type: DRILLING SIDETRACK Rig Accept: 6/30/2008 6:00:00 PM Rig Release: 8/2/2008 2:00:00 AM Time`~O - - gs --- - - - Date _ From To Dur S. Depth E. Depth Phase Code 5ubcode T Comment 6/30/2008 z4 hr summary Moved rig from well # 3C-17 to well # 3C-15, rig up lines to displace diesel out w/ sea water. pump down IA w/tubing lined up on flow back tank. Pressure up to 1,000 psi. (1 bbl.) bleed down 1"stream, pressure dropped 200 psi. in 10 mins. Pressure up on tubing same flow, 1,000 psi. Called town with results, Shut SC$SV, well flowing out tubing w/ IA on vacuum, pump sea water down tubing to balance, cycled SCSSV, not holdin ,well still out of balance. Note; Acce t ri 18:00 hrs 6/30/08 00:00 18:00 18.00 0 0 MIRU MOVE MOB P Dress location around #3C-15 set matting boards move rig over well # C-15. M!U mud pits U sub complex, skid rig floor, spot rock washer, choke lines, flow lines, berm rig, and prep cellar. Accept rig @ 18:00 hrs 6/30/08 18:00 22:00 4.00 0 0 MIRU MOVE MOB P R/U lines to flow back tanks, prepare tree ca to lurbricate BPV. 22:00 00:00 2.00 0 0 MIRU MOVE MOB P Rig up lubricator to tree cap, lubricate BP Vout, tubing pressure @ 100 psi, IA = 400 psi., UD lubricator, hook u line to tree ca . 7/01 /2008 Made several attempts to displace diesel from tubing and annulus. Unable to circulate. Nipple up and test BOPE. Stopped to tighten bolts between BOP stack and riser. All componets passed test. Witness waived b AOGCC Chuck Scheve. Ri ed u to ull back ressure valve /two wa check. 00:00 01:45 1.75 0 0 MIRU RPCOM CIRC P Attempt to displace diesel from tubing pressuring annulus up to 1000 psi, no circulation, pressure slowly bleeding off. Bleed off pressure, check lines and SSSV. Make second attempt to displace diesel from tubing, no circulation. Bleed off pressure. Line up to pump down tubing, pressure up to 1000 psi. Held for 30 minutes and pressure bled down to 200 si. Bleed off ressure. 01:45 02:45 1.00 0 0 MIRU RPCOM OTHR P Blow down and rig down lines on 7" x 2-7/8"annulus. 02:45 03:30 0.75 0 MIRU RPCOM OWFF P Monitor well, out of balance 03:30 04:30 1.00 0 0 MIRU RPCOM CIRC P Pressure up on tubing to 1000 psi. Let tubing bled down to 500 psi. Pressured back up to 1000 psi. Let tubing bled down to 500 psi. Lined up to pump on annulus and pressure up annulus to 1000 si, no circulation. 04:30 05:30 1.00 0 0 MIRU RPCOM OTHR P Attempt to install back pressure, valve. Well out of balance. Pace 1 of 3U • ~ _J Time Lois -- - --- ,- Date From To Dur S. Depth E Depth Pha-~„e Code Subcode T Comment _ 05:30 06:00 0.50 0 0 MIRU RPCOM CIRC P Pump down tubing. Pressured up to 1000 psi, let tubing bleed down to 500 psi. Repeat four times and bleed off ressure. 06:00 08:00 2.00 0 0 MIRU RPCOM OWFF P Allow tubing and annulus to equalize. 08:00 09:15 1.25 0 0 MIRU RPCOM OTHR P Set back ressure valve with two wa check valve and nipple down tree. Clean and inspect threads on tubing han er. 09:15 12:00 2.75 0 0 MIRU WELCTL NUND P Nipple up ROPE. 12:00 13:15 1.25 0 0 MIRU WELCTL NUND P Change lower rams from 3-1/2" to 2-7/8" 13:15 14:00 0.75 0 0 MIRU WELCTL BOPE P Install test joint. Had trouble seating test joint in hanger. Cameron rep was on location. 14:00 15:15 1.25 0 0 MIRU WELCTL BOPE P Rig up BOPE test equipment. 15:15 18:00 2.75 0 0 MIRU WELCTL BOPE P Testin BOPE 250 psi low, 5000 psi high. Witness waived by AOGCC Chuck Scheve 18:00 19:30 1.50 0 0 MIRU WELCTL BOPE T Tighten flange between BOP stack and riser. 19:30 22:45 3.25 0 0 MIRU WELCTL BOPE P Continue testing BOPE. All components passed. Draw down test starting pressure 3050 psi, function bag and rams. 200 psi increase in 52 seconds, full pressure, 3100 psi, in 3 minutes 23 seconds. 5 bottle nitro en avera a ressure 2400 si. 22:45 23:15 0.50 0 0 MIRU WELCTL BOPE P Rig down BOPE test equipment. Blow down to drive and lines. 23:15 00:00 0.75 0 0 MIRU RPCOM CIRC P Rig up lines for displacement (preparing to pull back pressure valve / two wa check 7/02/2008 Pull back pressure valve and attempt to pull tubing. Tubing not free. Calculate freepoint and discuss with town. Decision made to cut tubing at 5500' MD. Rig up and run in hole with wireline cutter. Stacking out at 175' MD. Observed 700-1400# of overpull and found ice on tool string when pulled out of hole. Run in hole to 270' MD with 1"pipe and wash tubing. Attempt to run in with wireline and stacked out at 800' MD. Pull wire-ine and run back in hole with wash i e. De th at midni ht 820' MD. 00:00 00:15 0.25 0 0 MIRU RPCOM SFTY P PJSM -opening two way check valve to check for ressure. 00:15 00:30 0.25 0 0 MIRU RPCOM RURD P Change elevators and make up cross overs for safe valve. 00:30 01:30 1.00 0 0 MIRU RPCOM OTHR P Ooen two wav check valve.,no_ ressure underneath, well static. Pull back pressure valve /two way check. Pick up and screw into hanger with landing joint with floor safety valve attached. Att~^'nr #n ~ i dl 7J/R" tubing. Calculated tubing wei ht with blo k at 108k. Pulled to 140k. Tubin did not come free. Pulled to 140k several times, no change. Calculated free oint at 5945' MD Page 2 e~f 3fl J _Time Logs_ __ _~ Date From To Dur S. De th E. D~th Phase Code Subcode T Comment 01:30 03:00 1.50 0 0 MIRU RPCOM RURD T Called town. Decision made to cut tubing at 5500' MD. Spotted Schlumberger wireline units outside ri . 03:00 04:00 1.00 0 0 MIRU RIGMNT SVRG P Service rig, iron roughneck, drawworks and to drive. 04:00 04:30 0.50 0 0 MIRU RPCOM SFTY T PJSM -Rigging up wireline and runnin ex losive tubin cutter. 04:30 05:15 0.75 0 0 MIRU RPCOM RURD T Pick up and rig up sheaves and wireline tools. 05:15 06:00 0.75 0 0 MIRU RPCOM RURD T Make up explosive tubing cutter to wireline tool strip . 06:00 10:00 4.00 0 0 MIRU RPCOM OTHR T RIH with tubing cutter on wireline. Stacked out at 175' MD. Observed 700 - 1400# overpull. Made several attempts to get past 175' MD. POOH and found ice on tool string. Begin heating seawater in pits and ordered 1" CS hydril pipe for washing tubing; Ri down wireline sheaves. 10:00 11:00 1.00 0 0 MIRU RIGMNT SVRG Service top drive, blocks, crown and drawworks. 11:00 12:00 1.00 0 0 MIRU RPCOM PULD T Pick up tools for running 1" hydril 12:00 14:30 2.50 0 0 MIRU RPCOM TRIP T RIH with 1"hydril, took weight at 120' MD. Stop and circulate at 1 bpm, 280 psi. RIH to 210' MD and circulated, RIH to 270 and circulated at 2 b m, 710 si. POOH with 1" h dril 14:30 15:00 0.50 0 0 MIRU RPCOM OTHR T Attempt to pull 2-7/8" tubing. Pick up to 140k no movement in tubin . Attempt to circulate thru tubing. Pressured up to 930 psi, stopped and bleed off pressure. Rig down lines. 15:00 18:00 3.00 0 0 MIRU RPCOM RURD T Rig up wireline tools and make up explosive cutter. RIH and stacked out at 294' MD. POOH and laydown cutter assembly. Pick up weight bars and prep to run in hole without tubing cutter. 18:00 18:30 0.50 0 0 MIRU RPCOM RURD T Make up wireline tool string with wei ht bars and no cutter. 18:30 21:00 2.50 0 0 MIRU RPCOM OTHR T R nning in hole with weight bars on wireline work tools down to 800' MD. h v s. 21:00 21:15 0.25 0 0 MIRU RPCOM RURD T Rig up to run in hole with 1" hydril 21:15 21:30 0.25 0 0 MIRU RPCOM SFTY T P SM -runnin in hole with 1" i and circulatin hot water. 21:30 23:00 1.50 0 0 MIRU RPCOM TRIP T Single in hole with 1" pipe. No obstructions found. 23:00 23:30 0.50 0 0 MIRU RPCOM CIRC T Circulate until hot water back at surface. Pumping 2 bpm, 1570 psi. 110 de rees in 98 de rees out. 23:30 00:00 0.50 0 0 MIRU RPCOM OTHR T Washing in hole with "doubles" um in 2 b m. l~ac~~ 3 of 30 l I n -_.J Time Logs ~ ~_ _ To Dur S Depth E. Depth Phase Code Subcode T Comment __ Date From 7/03/2008 _ zahrsummarv in hole with 1" i e to 1496' MD and wash tubing. POOH and run in with tubing cutter on wireline. Cut tubing and POOH. Pull on tubing to confirm successful cut. Circulate diesel from casing and tubing. Pull 5500' of 2-7/8" com letion strip .Chan a rams and test. 00:00 02:00 2.00 0 0 MIRU RPCOM OTHR T Washing in hole with "doubles" um in 2 b m. 02:00 02:15 0.25 0 0 MIRU RPCOM TRIP T Single in hole with 1" pipe. PU wt 73k, SO wt 73k 02:15 03:00 0.75 0 0 MIRU RPCOM CIRC T Circulate hot seawater to clean tubin um in 2 b m, 3200 si. 03:00 04:30 1.50 0 0 MIRU RPCOM TRIP T POOH laying down 1" hydril. 04:30 05:00 0.50 0 0 MIRU RPCOM RURD T Make up 2-7/8" landing joint and rig u wireline sheaves. 05:00 05:15 0.25 0 0 MIRU RPCOM SFTY T PJSM -loading explosive cutter and runnin wireline in hole. 05:15 06:45 1.50 0 0 MIRU RPCOM OTHR T RIH with wireline to cut depth. Confirm de th and cut tubin 06:45 07:30 0.75 0 0 MIRU RPCOM OTHR T wi wire ine oo s 07:30 08:00 0.50 0 0 MIRU RPCOM RURD P Rig down wireline sheaves and tool string. Leave wireline unit spotted on location. 08:00 08:30 0.50 0 0 MIRU RPCOM RURD P Rig up to circulate out remaining diesel in well. Run out lock down screws. 08:30 08:45 0.25 0 0 MIRU RPCOM OTHR P Unseat hanger to confirm tubing is cut. PU wt 105k, SO wt 100k. Reland hanger and run in lock down screws. 08:45 12:15 3.50 0 0 MIRU RPCOM CIRC P Circulate thru tubing a total of 640 bbls. First 170 bbls seawater to displace diesel discharging to open top tanks followed by 290 bbls of safe-surf-o and another 180 bbls of seawater dischar in to rock washer. 12:15 12:45 0.50 0 0 MIRU RPCOM OWFF P Monitor well -static. 12:45 17:00 4.25 0 0 MIRU RPCOM PULD P Pull and lay down 2-7/8" completion strip . 17:00 18:00 1.00 0 0 MIRU RIGMNT SVRG P Service rig, top drive, drawworks and crown 18:00 21:00 3.00 0 0 MIRU RPCOM PULD P Continue to pull 2-7/8" completion 21:00 21:45 0.75 0 0 MIRU RPCOM RURD P Rig down GBR 2-7/8" pipe handling tools 21:45 22:45 1.00 0 0 MIRU WELCTL EQRP P Change out bottom rams to 3" x 6" variable rams. Rig up BOPE test e ui ment. 22:45 23:15 0.50 0 0 MIRU WELCTL BOPE P Set test plug and fill stack with water. 23:15 00:00 0.75 0 0 MIRU WELCTL BOPE P Test bag 250 psi low and 3500 psi high, test upper and lower rams, 250 psi low and 5000 psi high. Having trouble getting low pressure test with ba and rams. ?eye ~ of 3£} ~i r~ U Time Logs _ _ __ _ Subcode T Comment Date From To Dur S. De th E. De th Phase Code 7/04/2008 _ 24 hr Summary Finish testing BOP after changing rams. Run in hole with casing scraper and circulate hole clean. Spot 100 bbl 13 ppg pill from 5500' MD to 2887' MD. Run USIT logs to locate top of cement and casing collars. Run bridge plug on wire line and set top at 2768' MD. Test casing to 3800 psi for 30 minutes, good test. Start ni lin down to than a tubin s ool and 7" ackoff. 00:00 01:15 125 0 0 MIRU WELCTL BOPE P Test bag 250 psi low and 3500 psi high, test upper and lower rams with 4" test joint. 250 psi low and 5000 psi high. Having trouble getting low pressure test with bag and rams. Run in lock down screws on test plug to energize seals and achieved ood low ressure tests. 01:15 01:45 0.50 0 0 MIRU WELCTI BOPE P Pull test plug and rig down test e ui ment. 01:45 02:15 0.50 0 0 MIRU CASING OTHR P Install wear ring and run in lock down screws. 02:15 02:30 0.25 0 0 SURFAC CASING SFTY P PJSM -picking up scraper BHA and runnin in hole. 02:30 04:30 2.00 0 0 SURFA( RPCOM PULD P Pick up and run in hole with scraper BHA (bit, scraper, collars, jars and HWDP 04:30 06:45 2.25 0 0 SURFA( RPCOM TRIP P Singling in hole with 4"drill pipe. PU wt 115k, SO wt 115k. 06:45 08:00 1.25 0 0 SURFA( RPCOM TRIP P TIH with 4"drill pipe from derrick. Tag tubing stub at 5505' MD. Set down 5k. PU wt 167k, SO wt 143k. Hole took ro er dis lacement. 08:00 09:30 1.50 0 0 SURFA( RPCOM CIRC P Pick up and circulate hole clean pumping 600 gpm, 2520 psi, rotating 50 rpm. Spotted 100 bbl 13 ppg balanced ill in casin . 09:30 09:45 0.25 0 0 SURFA( RPCOM OWFF P Monitor well -static 09:45 11:45 2.00 0 0 SURFA( RPCOM TRIP P POOH on elevators to BHA. Hole took ro er fill. 11:45 12:30 0.75 0 0 SURFA( RPCOM TRIP P Stand back HWDP and collars. lay down scra er and bit. 12:30 13:00 0.50 0 0 SURFA( EVALWE RURD P Rig up Schlumberger USIT logging_ tools. 13:00 15:30 2.50 0 0 SURFA( EVALWE ELOG T First run had poor quality logs. 15:30 18:00 2.50 0 0 SURFA( EVALWE ELOG P Adjust centralizers and run back in hole with to in tools. 18:00 19:30 1.50 0 0 SURFA( EVALWE ELOG P POOH with wireline logging tools and la down to in tool. 19:30 20:00 0.50 0 0 SURFA( RPCOM SFTY P PJSM -picking up and running bride lu on wireline. 20:00 21:30 1.50 2,768 2,768 SURFA( RPCOM OTHR P RIH with bridge tug on wireline. Set lu 2768' MD and ull out of hole 21:30 21:45 0.25 0 0 SURFA( RPCOM RURD P Rig down Schlumberger wireline tools. 21:45 22:15 0.50 0 0 SURFA( RPCOM DHEO P Test casing & bridge olug to 3800 psi ressure held,; charted test. 22:15 22:45 0.50 0 0 SURFA( RPCOM RURD P Pull wear ring, pull and lay down mouse hole, drain stack. 22:45 23:15 0.50 0 0 SURFA( RPCOM SFTY P PJSM -changing tubing spool and 7" ack off. Wage b of 3~ • • Time Logs ___ _ Date From To Dur S De th E. De th Ph se Code Subcode T Comment 23:15 00:00 0.75 0 0 SURFA( RPCOM NUND P Nipple down bell nipple, break bottom flan eon tubin s ool. 7!05/2008 Nipple down stack to change out 7" packoff and tubing spool. Nipple back up and test BOPE. All components passed. Witness waived by AOGCC Bob Noble. Pick up and run in hole with whipstock and millin assembl .Orient and set whi stock, be in millin window. 00:00 01:00 1.00 0 0 SURFA( RPCOM NUND P Nipple down bell nipple, break bottom flange on tubing spool. Stand back BOP stack with riser and tubin s ool attached. 01:00 02:00 1.00 0 0 SURFAC RPCOM NUND P Make up tool for pulling pack off to stand of drill. pipe and pull7" packoff. 25k overpull to remove packoff. Make up new packoff to tool and set ackoff. 02:00 02:30 0.50 0 0 SURFA( RPCOM NUND P Install new tubing spool. Break old s ool from bottom of riser. 02:30 03:30 1.00 0 0 SURFA( RPCOM NUND P Set BOP stack on wellhead and make u bolts. 03:30 05:15 1.75 0 0 SURFA( RPCOM DHEQ P Rig up and test packoff to 3000 psi for 30 minutes, pressure held. Sim ops nipple up bell nipple and flow line. 05:15 07:15 2.00 0 0 SURFA( WELCTL BOPE P Install test plug and fill stack with water. Rig up BOPE test equipment and lines. Grease choke manifold. 07:15 13:00 5.75 0 0 SURFA( WELCTI ROPE P Testin BOPE 250 psi low, 5000 psi high. Witness waived by AOGCC Bob Noble. All components passed. Draw down test starting pressure 3050 psi, function bag and rams. 200 psi increase in 32 seconds, full pressure in 3 minutes 6 seconds. 5 bottle nitrogen average pressure 2400 si. 13:00 13:45 0.75 0 0 SURFA( WELCTL BOPE P Rig down test equipment, pull test plug, blow down lines and choke manifold. 13:45 14:00 0.25 0 0 SURFA( STK OTHR P Install wear ring. 14:00 14:15 0.25 0 0 SURFA( STK OTHR P PJSM -Picking up and making up whi sho and millin BHA. 14:15 16:45 2.50 0 0 SURFA( STK PULD P Pick up and make up whipshop and millin BHA. 16:45 17:30 0.75 0 65 SURFA( STK OTHR P Dowload MWD. 17:30 18:30 1.00 65 500 SURFAC STK TRIP P Tripping in hole with whipstock and millin BHA. 18:30 19:00 0.50 500 500 SURFA( STK OTHR P Sha ow pulse test MWD pumping 6 b m, 580 si. 19:00 19:15 0.25 500 870 SURFA( STK TRIP P Continue tripping in hole with whi stock and millin BHA. 19:15 20:45 1.50 870 2,753 SURFA( STK TRIP P TIH with 4"drill pipe. PU wt 125k, SO wt 128k. 20:45 21:15 0.50 2,753 2,753 SURFA( STK CIRC P Displace well over to 9.7 ppg drilling mud at 7 bpm, 1080 psi. Orient whi stock while circulatin . F~age & cif 3(} • • Time Logs _ _ Date From To Dur S De th E. De th Phase Code Subcode T Comment ____ - 21:15 21:30 0.25 2,753 2,749 SURFA( -._ ~_. _ STK WPST P Confirm whipstock orientation and set whipstock. Final orientation 18 degrees right. Pick up to confirm whipstock set and set down 35k to shear off. To of window 2749' MD. ~ 21:30 00:00 2.50 2,749 2,754 SURFA( STK WPST P Mill window thru 7" and 9-5/8" casing per Baker rep. Pump , ~~ MI "Super Sweep" after milling 5' of casing. Observed 1400 psi increase in standpipe pressure as sweep was circulated. 7/06/2008 Milled window and rat hole. Perform Leak Off Test (14.0 ppg EMW). Trip out milling assembly and trip in with drillin BHA. Serviced ri and be an drillin intermediate hole section. 00:00 02:00 2.00 2,754 2,762 SURFA( STK WPST P Continue milling window thru 7" and 9-5/8" casing per Baker rep. Pump 30 bbl, 1/4 ppb MI "Super Sweep" after millin each 5' of casin . 02:00 04:15 2.25 2,762 2,794 SURFA( STK WPST P Work string mill and watermellon mill thru window. Drilled rat hole for LOT. max as 25 units. 04:15 04:30 0.25 2,794 2,747 SURFA( STK WPST P Reciprocate mills thru window. Window appears clean. PU wt 128k, SO wt 125k 04:30 04:45 0.25 2,747 2,747 SURFA( STK OWFF P Monitor well -very slight flow. 04:45 06:00 1.25 2,747 2,747 SURFA( STK CIRC P Circulate bottoms up then pump 35 bbl "super sweep". Circulate until hole clean. 06:00 06:15 0.25 2,747 2,747 SURFA( STK OWFF P Monitor well -static 06:15 07:00 0.75 2,747 2,747 SURFA( DRILL LOT P Perform Leak Off Test. Formation broke at 600 si and started taking fluid at 675 osi. Calculated 14.0 ppq 07:00 07:45 0.75 2,747 870 SURFA( STK TRIP P POOH on elevators to BHA. Hole took ro er fill. 07:45 09:15 1.50 870 0 SURFA( STK TRIP P Handle BHA, stand back HWDP, lay down drill collars, make up flex collars, stabilizers and MWD. 09:15 10:00 0.75 0 0 SURFA( DRILL OTHR P Download MWD 10:00 10:15 0.25 0 0 SURFA( DRILL DHEQ P Shallow test MWD pumping 250 m, 570 si. Good test. 10:15 11:00 0.75 0 0 SURFA( DRILL PULD P Stand back drilling BHA 11:00 11:45 0.75 0 0 SURFA( DRILL CIRC P Flush stack and lines. 11:45 13:00 1.25 0 550 INTRM1 DRILL TRIP P Make up and run in hole with drilling BHA 13:00 15:15 2.25 550 2,717 INTRM1 DRILL TRIP P Single in hole with 4"drill pipe from i e shed. 15:15 15:30 0.25 2,717 2,717 INTRM1 RIGMNT SFTY P PJSM -slip and cut drilling line 15:30 16:30 1.00 2,717 2,717 INTRM1 RIGMNT SVRG P Slip and cut drilling line. 16:30 17:30 1.00 2,717 2,717 INTRM1 RIGMNT SVRG P Grease top drive, blocks and crown. Take pictures of crown and gauge sheaves for line wear. Page ~ of 3fl i • Time Logs _ D e From To Dur S. Depth E. De th Phase Code Subcode T Comment 17:30 18:00 0.50 2,717 2,717 INTRM1 DRILL CIRC P Make top drive connection and obtain drilling parameters per DD and Smith bits, Rhino Reamer re . 18:00 00:00 6.00 2,717 3,070 INTRM1 DRILL DDRL P Drilling intermediate hole with 6-1/8" bit and 7" reamer. 7/07/2008 Drilled intermediate hole to 3286' MD and could not make more hole. Troubleshoot then tripped out of hole. Mud motor failed. Picked up new motor and MWD and tripped back to bottom. Reshot surveys on the way in hole. Resumed drillin at 18:30. 00:00 04:30 4.50 3,070 3,282 INTRM1 DRILL DDRL P Drilling intermediate hole with 6-1l8" bit and 7" reamer. 04:30 09:00 4.50 3,282 3,282 INTRM1 DRILL CIRC T Assembly stopped drilling shortly after making connection. Varied drilling parameters and pumped sweeps trying to get assembly to drill. Decision made to trip and check BHA. 09:00 09:15 0.25 3,286 3,286 INTRM1 DRILL OWFF T Monitor well -static 09:15 11:00 1.75 3,286 550 INTRM1 DRILL TRIP T POOH on elevators to BHA. Hole took ro er fill. 11:00 12:00 1.00 550 0 INTRM1 DRILL TRIP T Rack back HWDP and flex collars. 12:00 12:30 0.50 0 0 INTRM1 DRILL PULD T Download MWD 12:30 13:30 1.00 0 0 INTRM1 DRILL PULD T Lay down MWD and motor. 13:30 14:15 0.75 0 0 INTRM1 DRILL PULD T Pick up backup motor and MWD 14:15 14:45 0.50 0 0 INTRM1 DRILL PULD T Upload MWD 14:45 15:30 0.75 0 88 INTRM1 DRILL TRIP T TIH and shallow pulse test MWD. Pum 300 m, 930 si. Good test. 15:30 16:00 0.50 88 550 INTRM1 DRILL TRIP T TIH with remaining BHA. 16:00 18:00 2.00 550 3,187 INTRM1 DRILL TRIP T TIH stopping to survey at 3064', 3094', 3120', 3151' and 3186'. PU wt 130k, SO wt 125k. 18:00 18:30 0.50 3,187 3,286 INTRMI DRILL REAM T Rotate and wash to TD. Pumping 280 m, 1710 si, rotatin 30 r m. 18:30 00:00 5.50 3,286 3,613 INTRM1 DRILL DDRL P Resume drilling intermediate hole with 6-1/8" bit and 7" under reamer. 7/08/2008 Drilling 6-1/8" x 7" intermediate hole section. 00:00 06:00 6.00 3,613 3,941 INTRM1 DRILL DDRL P Drilling 6-1/8" x 7" intermediate hole. 06:00 12:00 6.00 3,941 4,224 INTRM1 DRILL DDRL P Drilling 6-1/8" x 7" intermediate hole. 12:00 18:00 6.00 4,224 4,447 INTRM1 DRILL DDRL P Drilling 6-118" x 7" intermediate hole. 18:00 00:00 6.00 4,447 4,684 INTRM1 DRILL DDRL P Drilling 6-1/8" x 7" intermediate hole. 7/09/2008 Drilled 6-1/8" x 7" to 5262' MD and made a planned trip to change out motor, reamer and bit. Picked up new motor, reamer and bit. 00:00 12:00 12.00 4,684 5,050 INTRM1 DRILL DDRL P Drilling 6-1/8" x 7" intermediate hole. 12:00 17:15 5.25 5,050 5,262 INTRM1 DRILL DDRL P Drill 6-1/8" x 7" intermediate hole then prepare to trip for bit and reamer er well Ian. I Time Logs. _ _ _ Date From To Dur S. Depth E. De th Phase Code Subcode T Comment _ 17:15 18:30 1.25 5,262 5,262 INTRM1 DRILL CIRC P Pump 45 bbl high viscosity sweep and circulate it out of hole. Pumping 293 gpm, 2290 psi, rotating 60 rpm and reciprocating 90'. Observed 15% increase in cuttings when sweep returned to surface. PU wt 150k, SO wt130k 18:30 18:45 0.25 5,262 5,262 INTRM1 DRILL OWFF P Monitor well -static 18:45 19:45 1.00 5,262 4,980 INTRM1 DRILL TRIP P Pull 5 stands on elevators, monitorin hole fill via tri tank. 19:45 20:00 0.25 4,980 4,980 INTRM1 DRILL CIRC P Pump 30 bbl, 11.8 ppg dry job. 20:00 21:30 1.50 4,980 547 INTRM1 DRILL TRIP P POOH on elevators to BHA. 21:30 22:00 0.50 547 85 INTRM1 DRILL TRIP P Rack back HWDP, jars and flex drill collars. 22:00 22:30 0.50 85 85 INTRM1 DRILL SFTY P PJSM -handling motors, MWD, reamers and bits. Assign 2 crew members to observe handling of BHA operations and plan on discussing in ost ~ob review. 22:30 23:00 .0.50 85 85 INTRM1 DRILL TRIP P Download MWD. Monitoring well via tri tank. 23:00 23:30 0.50 85 0 INTRM1 DRILL PULD P Lay down motor, reamer and bit. 23:30 00:00 0.50 0 85 INTRM1 DRILL PULD P Pick up and make up new motor, reamer and bit to MWD. Change out ulser. 7/10/2008 Finish picking up BHA from planned trip. Trip in hole to window. Service rig and change saver sub. Trip to bottom and resume drilling intermediate hole section. Stop drilling and circulate while holding Safety Standdown. Well started breathin after resumin drillin . 00:00 00:30 0.50 85 85 INTRM1 DRILL PULD P Changing out pulser in MWD. 00:30 01:30 1.00 85 85 INTRM1 DRILL PULD P Upload MWD 01:30 01:45 0.25 85 85 INTRM1 DRILL CIRC P Shallow pulse test MWD pumping 260 m, 750 si. Good test. 01:45 02:30 0.75 85 547 INTRM1 DRILL TRIP P TIH with flex collars, jars and HWDP. Monitorin dis lacement via tri tank 02:30 03:30 1.00 547 2,715 INTRM1 DRILL TRIP P TIH with drill pipe to window. Filled pipe every 20 stands, monitored dis lacement via tri tank. 03:30 04:30 1.00 2,715 2,715 INTRM1 RIGMNT SVRG P Service rig, crown, top drive and travelin a ui ment. 04:30 04:45 0.25 2,715 2,715 INTRM1 RIGMNT SFTY P PJSM -Changing saver sub. 04:45 06:45 2.00 2,715 2,715 INTRM1 RIGMNT SVRG P Change out saver sub. 06:45 08:45 2.00 2,715 5,262 INTRM1 DRILL TRIP P TIH to bottom. Filled pipe every 25 stands. PU wt 150k, SO wt 132k. 08:45 12:15 3.50 5,262 5,545 INTRM1 DRILL DDRL P Drill 6-1/8" x 7" intermediate hole. Observed hole packing off when backreaming stand. Stand pipe pressure 2948 psi, ECDs 16.9 ppg. Reamed down and continued drillin . ~a~e 9 Est 3Q • • Time Logs _ Date From To Dur S De th E, De th Phase Code Subcode T Comment 12:15 16:15 4.00 5,545 5,730 INTRMI DRILL DDRL P Drilling 6-1l8" x 7" hole section. 16:15 18:00 1.75 5,730 5,828 INTRM1 DRILL DDRL P Drilling 6-1/2" x 7" hole section. Pump 30 bbl high vis sweep while drilling. Observed increase in stand pipe pressure, 2800 psi and increase in ECDs 12.5 ppg, while circulating swee . 18:00 19:30 1.50 5,828 5,828 INTRM1 DRILL CIRC P Stop drilling and circulate while holding Safety Stand down. Pumped 15 bbl high viscosity sweep. Observed 25% increase in cuttings when swee returned. 19:30 20:30 1.00 5,828 5,924 INTRM1 DRILL DDRL P Continue drilling intermediate hole section. Hole started taking fluid while backreamin stand. 20:30 21:00 0.50 5,924 5,924 INTRM1 DRILL OWFF P Monitor well -flowing to static, breathin . 21:00 22:30 1.50 5,924 5,924 INTRM1 DRILL CIRC P Stage pumps from 2 bpm, 550 psi to 6 bpm, 1780 psi. Well started taking fluid at 6 b m, loosin about 36 b h. 22:30 23:00 0.50 5,924 5,924 INTRM1 DRILL OWFF P Monitor well -flowing to static. Well ave 20 bbls of fluid back. 23:00 00:00 1.00 5,924 5,924 INTRM1 DRILL CIRC P Stage pumps back up to 6 bpm, re arin to um LCM ill. 7/11 /2008 Drilling 6-1/8" x 7" intermediate hole section. Well breathing and taking fluid. Reduce mud weight from 9.8 ppg to 9.4 ppg, make wiper trip to window. Trip back to bottom and resume drilling. Lost 378 bbls mud to formation toda , cummulative losses 410 bbls. 00:00 00:45 0.75 5,924 5,924 INTRM1 DRILL CIRC P Pump 15 bbl, 20 ppb LCM sweep at 6 bpm, 1750 psi. No change is losses as swee came around. 00:45 06:00 5.25 5,924 6,206 INTRM1 DRILL DDRL P Drill 6-1/8" x 7" intermediate hole. 06:00 09:00 3.00 6,206 6,300 INTRM1 DRILL DDRL P Continue drilling 6-1/8" x 7" intermediate hole. Losses increased to approx 50 bph as ECDs went over 11.4 .Called town to discuss . lowering mud weight and making wi er tri . 09:00 11:45 2.75 6,300 6,300 INTRM1 DRILL CIRC P Pump 10 bbl high vis sweep at 6 bpm, 2180 psi, rotating 60 rpm and reciprocating 90'. Continued to circulate lowering mud weight from 9.8 to 9.5 11:45 12:15 0.50 6,300 6,300 INTRM1 DRILL OWFF P Monitor well -breathing- 12:15 13:00 0.75 6,300 5,359 INTRM1 DRILL TRIP P POOH on elevators, monitoring well via tri tank. Well swabbin . 13:00 15:00 2.00 5,359 3,943 INTRM1 DRILL TRIP P Pump out of hole. Pumping at 6 b m, 1790 si. 15:00 16:15 1.25 3,943 2,700 INTRM1 DRILL TRIP P POOH on elevators, monitoring well via trip tank. Gained 7.3 bbls on trip to window. 16:15 16:45 0.50 2,700 2,700 INTRM1 DRILL OWFF P Monitor well -static. Sim ops - service ri . 16:45 18:00 1.25 2,700 4,792 INTRM1 DRILL TRIP P TIH on elevators. Monitor displacement via trip tank. PU wt 135k, SO wt 123k Rage ip of 3t~ L • • Time Logs _ Date From To Dur 5 De th E. De th Phase Code Sub e T Comment 18:00 19:45 1.75 4,792 6,300 INTRM1 DRILL TRIP P Continue tripping back to bottom. Lost 39 bbls on tri in hole. 19:45 21:00 1.25 6,300 6,300 INTRM1 DRILL CIRC P Stage pumps up to 6 bpm, 1800 psi. Circulating out old heavy mud. Resumed drilling when mud weight was 9.5 ppg in and out. ECDs 10.6 . 472 as units on bottoms u . 21:00 00:00 3.00 6,300 6,404 INTRM1 DRILL DDRL P Drill intermediate hole section. Limit rotating ROP to 80 fph until mud wei ht in = 9.4 7/12/2008 Drilling 6-1/8" x 7" intermediate hole section. Pumping high viscosity sweeps and limiting ROP while rotating to keep ECDs below 11.4 ppg EMW. Dump old mud and build new mud to reduce drill solids in system. No losses to formation toda .Cummulative losses 410 bbls. 00:00 02:45 2.75 6,404 6,585 INTRM1 DRILL DDRL P Drillin 6-1/8" x 7" intermediate hole section. Started swee down hole. 02:45 03:15 0.50 6,585 6,585 INTRM1 DRILL CIRC P Rotate and reciprocate while circulating sweep around. Dumping sweeps and estimatating effectivness by change in ECDs. ECDs before swee 11.2 ,after 10.9 03:15 06:00 2.75 6,585 6,720 INTRMI DRILL DDRL P Drilling intermediate hole. 06:00 12:00 6.00 6,720 6,961 INTRM1 DRILL DDRL P Drilling intermediate hole. Pumped sweeps while drilling @ 06:30 & 10:30. ECDs before sweep 11.2 ppg, after 10.9 12:00 18:00 6.00 6,961 7,230 INTRM1 DRILL DDRL P Drilling intermediate hole. Pumped sweep while drilling @ 16:20. Sto ed addin LCM to mud. 18:00 00:00 6.00 7,230 7,475 INTRM1 DRILL DDRL P Drilling intermediate hole. Pumped sweeps while drilling @ 19:40 & 23:00. 7/13/2008 Drilling 6-1/8" x 7" intermediate hole section. Pumping high viscosity sweeps and limiting ROP while rotating to kee ECDs below 11.4 EMW. No losses to formation toda .Cummulative losses 410 bbls. 00:00 12:00 12.00 7,475 8,011 INTRM1 DRILL DDRL P Drilling intermediate hole. Pumped and dumped sweeps while drilling to clean hole 7625', 7880' 7905' . 12:00 00:00 12.00 8,011 8,262 INTRM1 DRILL DDRL P Drilling intermediate hole. 7/14/2008 Drilling 6-1 /8" x 7" intermediate hole section to TD, 8748' MD, 6147.8' TVD. Backream 5 stands, trip to bottom and be in circulatin hole clean. 00:00 02:45 2.75 8,262 8,308 INTRM1 DRILL DDRL P Drilling 6-1/8" x 7" intermediate hole, sliding. Having trouble holding tool face. 02:45 03:30 0.75 8,308 7,905 INTRM1 DRILL REAM P Backream 5 stands pumping 270 m, 2070 si, rotatin 60 r m. 03:30 03:45 0.25 7,905 8,308 INTRM1 DRILL TRIP P Trip back to bottom. 03:45 05:15 1.50 8,308 8,308 INTRM1 DRILL CIRC P Pump and dump 10 bbl high vis sweep at 265 gpm, 2140 psi, rotating 60 r m. 05:15 06:00 0.75 8,308 8,330 INTRM1 DRILL DDRL P Drilling 6-1 /8" x 7" intermediate hole, slidin . 06:00 18:00 12.00 8,330 8,665 INTRM1 DRILL DDRL P Drilling 6-1/8" x 7" intermediate hole. F~ge 11 rat 3~ • • Time Logs __ __ _. _ Date. From To Dur S. De th E. De th Pha e Code Subcode T Comment 18:00 22:00 4.00 8,665 8,748 INTRMI DRILL DDRL P Drilling 6-1/8" x 7" intermediate hole. TD: 48' MD - 6147.8' TVD. 22:00 23:15 1.25 8,748 8,748 INTRM1 DRILL CIRC P Pump and dump 10 bbl high vis swee . 23:15 00:00 0.75 8,748 8,375 INTRMI DRILL REAM P Backream 5 stands pumping 275 m, 2250 si. 7/15/2008 Short trip and condition hole for 5 1/2, 15.5 # L-80 casing liner, POOH UD BHA #5, run liner. 00:00 00:15 0.25 8,375 8,748 INTRM1 DRILL WPRT P TIH on elevators to TD. Monitoring dis lacement via tri tank. 00:15 02:15 2.00 8,748 8,748 INTRM1 DRILL CIRC P Pump and dump 10 bbl high vis sweep. Continued to circulate and reci rotate until hole was clean. 02:15 02:30 0.25 8,748 8,748 INTRM1 DRILL OWFF P Monitor well -static 02:30 03:00 0.50 8,748 8,183 INTRM1 DRILL WPRT P Pull 5 stands f/ 8,748' MD t/ 8,183' MD, monitor well on tri tank. 03:00 03:15 0.25 8,183 8,183 INTRM1 DRILL OWFF P Monitor well -static, pump dry job 03:15 06:00 2.75 8,183 2,715 INTRM1 DRILL WPRT P POOH on elevators monitoring hole fill via tri tank. 06:00 06:45 0.75 2,715 2,715 INTRM1 RIGMN7 SVRG P Service top drive & traveling e ui ment, monitor hole on tri tank. 06:45 10:15 3.50 2,715 8,660 INTRM1 DRILL WPRT P TIH on elevators f/ 2,715' MD t/ 8,660' MD 10:15 13:15 3.00 8,660 8,748 INTRM1 DRILL CIRC P ROT & Recip. f/ 8,860' t/ 8,748' while circulatin 13:15 13:30 0.25 8,748 8,748 INTRM1 DRILL OWFF P Monitor well (flowing ) 13:30 14:30 1.00 8,748 8,748 INTRM1 DRILL CIRC P Continue to ROT & Recip.f/ 8,660' t/ 8,748' while circulatin . 14:30 15:00 0.50 8,748 8,748 INTRM1 DRILL OWFF P Monitor well (flowing t/ static) 15:00 15:30 0.50 8,748 8,137 INTRM1 DRILL WPRT P POOH on elevators f/ 8,748' MD t/ 8,137' 15:30 15:45 0.25 8,137 8,137 INTRM1 DRILL OWFF P Monitor well (static), pumped a 15 bbl. 11.4 slu . 15:45 17:15 1.50 8,137 2,525 INTRM1 DRILL WPRT P POOH on elevators f/8,137 MD t/ 2,545' MD, monitor hole w/trip tank, record P/U WTS. eve 5 stds. 17:15 17:30 0.25 2,525 2,545 INTRM1 DRILL OWFF P Monitor well (static) drop a 2.25 drift w/ an 80' tail on std. # 22 17:30 18:15 0.75 2,545 550 INTRM1 DRILL TRIP P POOH on elevators f/ 2,545 U 550' MD, monitoring w/ trip tank, recording R/U and S/O WTS. every 10 stds. (SPR @ 8,173 MD #1 pump, 20 SPM =380 psi, 30 SPM = 610 psi./ #2 pump, 20 SPM = 410 si. 30 = 630 si. 18:15 19:30 1.25 550 350 INTRM1 DRILL TRIP P Rack back HWDP, LD jars and replace w/ jt. HWDP, build 5 stands of Hybrid 4 3/4 DC's and 4 "HWDP and rack back in DRK. 19:30 22:00 2.50 350 0 INTRM1 DRILL TRIP P UD BHA #5, 4 314 flex collars, break off bit &Rino reamer, down load MWD, test Rino reamer- OK, UD MWD and motor, clean floor. Page 92 raf 3~ J C~ Time Logs ~ __ _ __ Date From To Dur ST Depth E. De th Ph~,,e Code Subcode T Comment 22:00 22:15 0.25 0 0 INTRM1 DRILL OTHR P P/U test joint and pull wear bushing. 22:15 23:00 0.75 0 0 INTRM1 CASING RUNL P Rig up GBR casing tongs and fill up line. 23:00 23:15 0.25 0 0 INTRM1 CASING SFTY P PJSM w/ casing crew. 23:15 00:00 0.75 0 120 INTRM1 CASING RUNL P Pick up 5 1/2 float joints, Baker lock same, check floats- OK. 7/16/2008 Continue running 5 1/2 liner on DP. t/ 8,747' tag bottom ,while circulating liner became stuck and packed off. Released from liner hanger, Pumped down inside liner for an injection rate, broke @ 1450 psi. @ 1 BPM, went to the back side injection rate was 450 psi @ 1 BPM. POOH for liner contingency squeeze tool, spaced out into liner, set sli son liner han er, ulled u 10' to ex ose orted sub fors ueezin . 00:00 07:00 7.00 120 6,175 INTRM1 CASING RUNL P Continue running 5 1/2" Hydril L-80- 511, 15.5 PPF liner U 6,175' MD 07:00 07:45 0.75 6,175 6,277 INTRM1 CASING RUNL P P/U BOT liner hanger and on stand of drill collars, RIH t/ 6,302', 07:45 10:15 2.50 6,277 6,302 INTRM1 CASING CIRC P Circ. and Recip. f/ 6,277' t/ 6.302' @ 1 BPM= 420 psi. FCP @ 310 psi. P/U WT.= 170K, S/O WT.= 120K 10:15 11:15 1.00 6,302 7,405 INTRM1 CASING RUNL P RIH on elevators w/ 5 1/2 liner f/ 6,302' MD U 7,405', P/U WT. _ 200K, S/O WT. = 125K 11:15 11:45 0.50 7,405 7,405 INTRMI CASING CIRC P Circ. and Recip. f/ 7405' t/ 7380' @ 1 BPM= 420 psi. FCP @ 310 psi. P/U WT.= 200K, S/O WT.= 130K 11:45 13:00 1.25 7,405 8,707 INTRM1 CASING RUNL P RIH on elevators w/ 5 1/2 liner f/ 7380" MD t/ 7503', P/U WT. = 240K, S!O WT. = 128K 13:00 14:00 1.00 8,707 8,727 INTRM1 CASING CIRC P Circ. and Recip. f/ 8727' U 8707' @ 1 BPM= 420 psi. FCP @ 310 psi. P/U WT.= 248K, S/O WT.= 130K 14:00 14:30 0.50 8,727 8,727 INTRM1 CASING RUNL P P/U BOT. cement head 14:30 14:45 0.25 8,727 8,727 INTRM1 CASING CIRC P Establish circulation thru cement head @ 1 BPM. = 550 psi. Tag bottom 8747' w/ 10 K. 14:45 18:30 3.75 8,727 8,727 INTRM1 CASING CIRC P Circ. and Recip. f/ 8748' MD t/ 8727 MD .w/ pump rate @ 1 BPM = 480 psi. P/U WT. = 248K, S/O WT = 130, 792 units of gas (Epoch ) Increase pump rate to 2 BPM, string stuck with returns, ull max of 250 K as per BOT.rep.w/ 2650 strokes pumped, hole packed off w/ no returns, continue to work stuck pipe as per BOT &CPAI REP, well flowing @ 6 BPH, observe flow on tri tank. 18:30 18:45 0.25 8,727 8,727 INTRM1 CASING RUNL T Release from hanger 23' off bottom. Establish an injection rate down inside of liner. Broke down @ 1450 psi. 2.2 bbls. injected. Pump down annulus. Broke down @ 450 psi. @ 1 BPM. 2.7 bbls. um ed. 18:45 19:15 0.50 8,727 8,727 INTRM1 CASING OTHR T Wait on orders U UD cement head F/ CPAI REP. 19:15 19:30 0.25 8,727 8,727 INTRM1 CASING CIRC P CBU @ 2,420' ~'as~e 13 of 30 Time Logs _ Date From To Dur S De th E. De th Phase Code Subcode T Comment 19:30 19:45 0.25 8,727 8,727 INTRM1 DRILL OWFF P Monitor well (flowing) suspect out of balance. 19:45 20:00 0.25 8,727 8,727 INTRM1 CASING CIRC P C / 2,420' 20:00 20:15 0.25 8,727 8,727 INTRM1 DRILL OWFF P Monitor well (static) 20:15 21:15 1.00 8,727 0 INTRM1 CASING RUNL P POH f/ 2,420' MD. w/hanger running tool 21:15 21:30 0.25 0 0 INTRM1 CASING RUNL P Lay down liner running tool as per BOT REP. Top of liner @ 2,525', Bottom of liner 8,725'. 21:30 00:00 2.50 0 0 INTRM1 CASING RUNL P P/U liner squeeze running tool as per BOT REP. RIH t/ 2,520', space out tool into liner, set slips on liner hanger w/ 2800 psi. Pull 10' to ex ose circulatin orted sub. 7/17/2008 Service rig while waiting on cement lab results, squeeze 5 1/2 liner, set BOT packer, POOH UD 4" DP, test BOPE. P/U BHA #6, 4 3/4" bit & scra er, 2 7/8" HWDP and 2 7/8" drill i e. 00:00 02:00 2.00 2,525 2,525 INTRM1 CASING WOEO P Waiting on lab results on squeeze cement (Schlumberger) service rig, to drive and drawworks. 02:00 03:00 1.00 2,525 2,525 INTRM1 CEMEN" SFTY P PJSM for squeeze job, preform injection rates, 1 BPM = 330 psi. 2 BPM = 500 si. 3 BPM =730 si. 03:00 03:45 0.75 2,525 2,525 INTRM1 CEMEN" SQEZ P Close annular squeeze as per Schumberger detail, 48 bbl. of 15.8 class G cement, chase w/ 21 bbls, 9.3 PPG mud leavin 1 bbl. in DP. bleed off ressure. 03:45 04:00 0.25 2,525 2,525 INTRM1 CEMEN" SQEZ P Strip down thru Hydril & set packer as er BOT w/ 30 K down. 04:00 05:30 1.50 2,525 2,525 INTRM1 CEMEN" CIRC P Circulate residual cement out 2x the long way and reverse 2.5 times DP volume, cement to surface (est.1 bbl. 05:30 05:45 0.25 2,525 2,525 INTRM1 CEMEN" PULD P R/D reverse circulating lines and R/U for la in down DP 05:45 06:00 0.25 2,525 1,950 INTRM1 CEMEN" TRIP P UD 4" DP f/ 2,335' MD t/ 1,950' 06:00 06:15 0.25 1,950 0 INTRM1 CEMEN" SFTY P PJSM on laying down DP. 06:15 08:30 2.25 0 0 INTRM1 CEMEN- TRIP P Continue to POOH sideways f/ 1,950' t/ cement stinger, monitor well on trip tank. 08:30 09:15 0.75 0 0 INTRM1 CEMEN" TRIP P PJSM w/ BOT REP. on laying down cement stin er, UD same. 09:15 09:45 0.50 0 0 INTRM1 CEMEN" PULD P Clear floor of cement tools. 09:45 10:15 0.50 0 0 INTRM1 CEMEN" TRIP P P/U 2 7/8 handling equipment & subs. 10:15 10:30 0.25 0 0 INTRM1 DRILL SFTY P PJSM on transfering 4" DP in DRK. 10:30 12:00 1.50 0 0 INTRM1 DRILL RURD P UD & transfer 4" DP w/ blind rams shut. 12:00 13:00 1.00 0 0 INTRM1 WELCTI BOPE P R/U BOPE test equipment Page 1A of 30 • l J Time Logs ~„_ _ __ th E. De th Phase Code Subcode T Comment Date From To Dur S De 13:00 18:00 5.00 _ 0 0 INTRMI WELCTL BOPE P Test BOPE as per AOGCC REP. Chuck Scheve, test Hydril w/ 2 7/8, 3 1 /2 & 4 " test jts. 250 low 3.500 psi.high., test upper pipe rams w/ 2 7/8, 3 1 /2, & 4" test jts. U 250 psi. low & 5000 psi. high. Test lower pipe rams w/ 3 1/2 & 4" test jt. U 250 psi. low & 5000 psi. high, Test blind rams U 250 psi. low & 5000 psi. high, test choke valves 1-18, choke and kill manual & HCR's, & 4" valve on mud line, upper and lower IBOP, XT-39 TIW & dart U 250 psi low & 5000 psi. hi h. 18:00 19:45 1.75 0 0 INTRM1 WELCTL BOPE P Rig down test jt, install wear ring, test floor and dart valve, R/D top drive ca ,and R/D test a ui ment. 19:45 20:15 0.50 0 0 INTRM1 CEMEN" TRIP P R/U GBR tongs, change elevators. 20:15 00:00 3.75 0 1,184 INTRM1 CEMEN" TRIP P P/U BHA # 6, 4 3/4 "bit and scraper, a pin broke on a 2 7/8" DC, UD 3 DC"S, pick up 38 jts. of spiral HWDP instead, sending DC's to be inspected, monitor displacement on tri tank. 7/18/2008 Continue to RIH w/ BHA #6, 4 3/4" scraper, CBU @ landing collar, POOH, Run a USIT. and CBL. log w/ Sclumber er to in unit down 2 hrs. with air line ,USIT tool failed. 00:00 09:15 9.25 1,184 4,696 INTRM1 CEMEN" TRIP P Continue to P/U BHA # 6, f/ 1,184' U 4,696' MD, monitor hole on trip tank w/ proper fill. P/U WT. =110K, S/O WT.=110K 09:15 09:45 0.50 4,696 6,796 INTRM1 CEMEN' TRIP P R!D 2 7/8" handling equipment 09:45 11:00 1.25 6,796 8,638 INTRMI CEMEN" TRIP P TIH w/scraper BHA on 4" DP f/ 6,880' U 8,638' MD, to landin collar. 11:00 12:00 1.00 8,638 8,638 INTRMI CEMEN" CIRC P Curculate surface to surface, GPM = 166, flow = 20 %, si = 2,480 12:00 12:30 0.50 8,638 8,638 INTRM1 WELCTL OWFF P Monitor well (static) and pump and um a 15 bbl. d 'ob. 12:30 13:45 1.25 8,638 6,880 INTRM1 CEMEN" TRIP P POOH on elevators f/ 8,638' U 6,880' MD, P/U WT. = 190K, S/O WT = 120 K 13:45 14:00 0.25 6,880 6,880 INTRM1 CEMEN" TRIP P R/U GBR 2 7/8" handling equipment. 14:00 15:45 1.75 6,880 1,184 INTRM1 CEMEN" TRIP P POOH w/ 2 7/8" DP f/ 6,880' U 1,184' MD 15:45 16:15 0.50 1,184 0 INTRM1 DRILL SFTY P PJSM w/ crew and GBR on laying down 3" HWDP. 16:15 18:45 2.50 0 0 INTRM1 CEMEN" TRIP P Lay down HWDP f/ 1,184' MD, BRK out bit and scaper, clean floor R/D GBR. 18:45 19:00 0.25 0 0 INTRM1 EVALWE SFTY T PJSM w/ Schlumberger crew. 19:00 19:45 0.75 0 0 INTRM1 EVALWE ELOG T P/U wire line tools, hang sheaves. 19:45 22:00 2.25 0 8,595 INTRM1 EVALWE ELOG T RIH w/ USITand CBL log U 8.595' wire line depth, Unit broke down /air line/ brake release. Page 15 of 3€} J Time Lo s ~' Date From To Dur S. Depth E. D pth Ph~e Code Subcode T Comment 22:00 23:00 1.00 8,595 8,595 INTRM1 EVALWE ELOG T Wait on mechanic & repair air line, USIT tool faliure, 23:00 00:00 1.00 8,595 8,595 INTRM1 EVALWE ELOG T Continue to log out w/ CBL tool. 7/19/2008 Finished up w/ USIT logging, RIH w/ Fast drill retainer, set @ 8620, POH for BHA #7. 00:00 01:45 1.75 8,595 8,695 INTRM1 EVALWE ELOG T Continue to log up the hole w/CBL tools found cement f/ 3,400 ' to the liner la 2525'. 01:45 02:15 0.50 8,695 0 INTRM1 EVALWE ELOG T Change out USIT tools. 02:15 06:00 3.75 0 8,595 INTRM1 EVALWE ELOG T RIH w/ new USIT tool U 8,595, attempt to log. tool interminant, trouble shoot 06:00 08:15 2.25 8,595 0 INTRM1 EVALWE ELOG T POOH w/ USIT tools, change out same. 08:15 08:45 0.50 0 8,595 INTRM1 EVALWE ELOG T RIH w/ third set of USIT tools 08:45 09:45 1.00 8,595 0 INTRM1 EVALWE ELOG T Log out w/Schlumberger USIT tool retrieved to 09:45 10:30 0.75 0 0 INTRM1 EVALWE PULD T UD Schlumberger USIT wire line tools. 10:30 11:00 0.50 0 0 INTRMI CEMEN" PULD T R!U 2 7/8" handling equipment w/ GBR. 11:00 11:15 0.25 0 0 INTRMI CEMEN" SFTY T PJSM for squeeze packer w/ Halliburton Rep. PJSM on 2 7/8" handlin a ui ment. 11:15 11:45 0.50 0 0 INTRM1 CEMEN" PULD T M/U Halliburton Fast drill composite retainer as er Re . 11:45 16:00 4.25 0 6 INTRM1 CEMEN" TRIP T RIH w/ fast drill retainer t/ 5,606', monitorin dis lacement on tri tank. 16:00 16:30 0.50 5,606 6,270 INTRM1 CEMEN" TRIP T P/U 2 7/8" DP f/ shed, RIH f/ 5,606' U 6,270' MD, monitor displacement on tri tank 16:30 17:00 0.50 6,270 6,270 INTRM1 CEMEN- TRIP T R/D 2 7!8" handling tools, R/U 4" handlin tools. 17:00 18:15 1.25 6,270 8,625 INTRM1 CEMEN" TRIP T RIH w/ fast drill retainer t/ 8,625', monitor well on trip tank.P/U WT.= 185K, S/O WT.= 125 K. 18:15 18:30 0.25 8,625 8,625 INTRM1 CEMEN" TRIP T Circulate @ 88 GPM, 1010 psi. to clean up retainer, 11%flow, P/U WT. = 185 K S/O WT. =125 K 18:30 20:00 1.50 8,625 8,620 INTRM1 CEMEN" PACK T Set retainer as per Halliburton rep -~ and CPSI. rep.@_8,620' MD (would, not shear) work string f/ 125 K t/ 250 K, shut annular and pressure up to 1000 psi. w/ 250 K on string. bled off and pulled 260 K, sheared. Pulled up 15' and set 20 K on retainer retainer sheared and set @ 8.620_ MD 20:00 20:30 0.50 8,620 8,620 INTRM1 CEMEN" SOEZ T Establish an injection rate, 1 BPM = 1650,,broke down to 1,010' @ 2 20:30 20:45 0.25 8,620 8,620 INTRM1 CEMEN - PULD T R/U cement lines for squeeze. 20:45 21:00 0.25 8,620 8,620 INTRM1 CEMEN " SFTY T PJSM on cement job w/ Schlumberger, Howco, DDI. and CPAI. re s. .....~_....~ gage 9& of 3t~ J Time Logs I Date From To Dur S. De th E. Depth Phase Code Subcode T Comment _ 21:00 21:30 0.50 8,620 8,620 INTRM1 CEMEN" SOEZ T Flush lines with water while hatching u cement. 21:30 21:45 0.25 8,620 8,620 INTRM1 CEMEN" SOEZ T Pressure test lines to 4000 psi. 21:45 22:30 0.75 8,620 8,620 INTRM1 CEMEN' SOEZ T Pump 10 bbls. of 15.8 class (G ) cement w/gas block. Held 200 psi back pressure w/ rig choke, displace cement w/ 38 bbls. of 9.6 mud ,stab into retainer and squeezed 9.5 bbl. of cement thru shoe track, leaving 1/2 bbl. on top of retainer, calculated 500' u back side of liner. 22:30 23:15 0.75 8,620 8,600 INTRM1 CEMEN" CIRC T Circulate surface to surface @ 190 GPM, 22 % flow, 3000 si. 23:15 23:30 0.25 8,600 8,600 INTRM1 WELCTI OWFF T Monitor well (static) 23:30 00:00 0.50 8,600 7,219 INTRM1 CEMEN" TRIP T POOH f/ 8,595' t/ 7,219' Monitor well on tri tank. 7!20/2008 POH w/ retainer running tool , RIH w/ BHA # 7, stop cut drilling line and service rig, cement and retainer, cleanout to 8,725' 00:00 00:15 0.25 7,219 7,219 INTRM1 CEMEN" TRIP T Pump dry job 00:15 00:30 0.25 7,219 6,272 INTRM1 CEMEN" TRIP T Continue to POOH f/ 7,219' t/ 6,272' MD, Monitor well on tri tank. 00:30 00:45 0.25 6,272 6,272 INTRM1 CEMEN" TRIP T R/D 4" equipment, R/U 2 7/8" e ui ment 00:45 03:30 2.75 6,272 0 INTRM1 CEMEN" TRIP T Continue to POOH f/ 6,272' t/ surface, monitor well on tri tank. 03:30 03:45 0.25 0 0 INTRM1 CEMEN" PULD T UD HOWCO retainer tuning tool, clear floor. 03:45 04:00 0.25 0 0 INTRM1 CEMEN' SFTY P PJSM on picking up new BHA #7 04:00 04:45 0.75 0 84 INTRM1 CEMEN" TRIP P P/U BHA, bit- motor- stab, MWD, orient tool face. 04:45 05:30 0.75 84 84 INTRM1 CEMEN" TRIP P P/UMWDtools. 05:30 06:00 0.50 84 84 INTRM1 CEMEN' TRIP P Upload MWD. 06:00 07:30 1.50 84 111 INTRM1 CEMEN- TRIP P Continue t/ M/U BHA # 7, t/ 111', reform a shallow ulse test. 07:30 09:00 1.50 111 410 INTRM1 CEMEN" TRIP P RIH f/111' t/ 400' perform another shallow ulse test. 09:00 09:15 0.25 410 410 INTRM1 CEMEN" SFTY P PJSM for M/U BHA, w/GBR casing crew. 09:15 14:30 5.25 410 7,875 INTRM1 CEMEN" TRIP P Continue to RIH w/ BHA # 7, as per DD.& MWD. rep.w/GBR casing crew . F/ 410' U 7,875' monitoring dis lacement on tri tank. 14:30 15:30 1.00 7,875 7,213 INTRM1 CEMEN" TRIP P POH UD 21 jts. monitor dis lacement on ti tank. 15:30 15:45 0.25 7,213 7,213 INTRM1 CEMEN- PULD P UD 2 7/8 handling equipment, monitor hole on tri tank. 15:45 16:00 0.25 7,213 7,875 INTRM1 CEMEN" TRIP P RIH w/ 4" DP f/ derrick f/ 7,213' t/ 7875' MD monitor hole on tri tank. 16:00 18:00 2.00 7,875 7,875 INTRM1 CEMEN' CIRC P Recip. while CBU f/ 7,754' MD t/ 7,875' MD w/ GPM= 120, psi off = 2630, flow out = 16 %, P!U- WT. =170 K, S/O WT. = 118 K, RT-WT =132 K FT LBS. Page '17 of 3t7 • • Time Logs Date From To Dur S De th E De th Phase Code Subcode T Comment _ 18:00 20:15 2.25 7,875 7,875 INTRM1 RIGMNT SVRG P Cut and slip 139' of drilling line and adjust brakes. Service and inspect travelin a ui ment. 20:15 20:45 0.50 7,875 7,875 INTRM1 CASING RURD P R/U casing test equipment. 20:45 21:45 1.00 7,875 7,875 INTRM1 CASING DHEO P Preform a casing integrity test as per CPAI re 2000 si. or mins. 21:45 22:15 0.50 7,875 7,875 INTRM1 CASING RURD P R/D casing test equipment. 22:15 22:30 0.25 7,875 8,619 INTRM1 CEMEN" TRIP P RIH f/ 7,875' t/ 8,619' tag cement MD. 22:30 00:00 1.50 8,619 8,747 INTRM1 CEMEN" DRLG P Drill out fast drill retainer and float e~uioment to 8747'. Pump rate = 120 GPM, 2580 psi., 16 % flow, 50 RPM, 5 K TO, ON/OFF,2-4 WOB, P/U WT.= 200 K, S/0= 120K, RT WT =140 K. 7/21 /2008 Drilled cement retainer & float equipment, change mud system f/ 9.6 PPG t/ 12 PPG, drilled 20' of new hole, reform a FIT test, drill U 8 795', wei ht u t/ 13.3 PPG, drill ahead U 8,964' 00:00 00:30 0.50 8,748 8,748 INTRM1 CEMEN" DRLG P Continue to drill out to, 8,748'. 00:30 01:15 0.75 8,748 8,748 INTRM1 DRILL CIRC P CBU @ 8,748' MD, 120 GPM, 2680 si., 16% flow, 30 RPM, TQ = 5 K. 01:15 03:00 1.75 8,748 8,748 INTRM1 DRILL CIRC P Displace hole f/ 9.6 PPG LSDN mud U 12 PPG polymer mud, 120 GPM/ OFF, 18% flow, 30 RPM, TO = 5K 03:00 04:00 1.00 8,748 8,768 INTRM1 DRILL DDRL P Drill f/ 8,748' t/ 8,768', MD, 6,163' TVD, 120 GPM, 3,060 si. ON, 04:00 05:15 1.25 8,768 8,768 INTRM1 DRILL CIRC P CBU @ 8722' MD, 120 GPM, 2,980' si., 18% flow, 30 RPM, TQ = 5-6 K. 05:15 05:30 0.25 8,768 8,768 INTRM1 DRILL PULD P R/U test equipment for LOT. 05:30 06:00 0.50 8,768 8,768 INTRM1 DRILL FIT P LOT @ 8,720' MD, 6147' TVD, 12 PPG. polymer mud, bad sensor bled off, re air same. 06:00 07:00 1.00 8,768 8,768 INTRM1 DRILL FIT P LOT 8,720' MD, 6147' TVD, 12 PPG. Perform FIT t/ 16 EMW/ 1,275,. psi. hold for 10 mins. Used test pump on test going down kill kine and DP. 07:00 07:30 0.50 8,768 8,768 PROD1 DRILL PULD P R/D test equipment. 07:30 07:45 0.25 8,768 8,768 PROD1 DRILL REAM P Make a connection, wash in f/ 8,620' MD t 8,768' MD w/ GPM = 120. PSI OFF =2780, RPM = 60, TO OFF = 5K FT LBS., Flow out = 18 %, P/U WT. =200K, S/O WT. = 120 K , RT WT.= 140 K. 07:45 10:30 2.75 8,768 8,795 PROD1 DRILL DDRL P Continue drilling f/ 8,768' t/ 8,795' MD, 6,185' TVD. 10:30 12:00 1.50 8,795 8,795 PROD1 DRILL CIRC P ROR & RECIP. while weighting up entire system f/ 8,795' t/ 8,723' MD. GPM -120, PSI OFF = 3160, RPM = 55, TO = 5 K FT LBS, Flow out = 19 %, 13.3 PPG. IN/OUT 12:00 17:30 5.50 8,795 8,795 PROD1 DRILL CIRC P Continue to weight up system to 13.3 PPG mud P~~e 18 of 3Q ~ J • Time Lo s I Date From To Dur S Depth E. De th Phase Code Subcode T Comment _ 17:30 17:45 0.25 8,795 8,795 PROD1 DRILL CIRC P SPR's @ 8,795' MD 6185' ND, 13.3 PPG, #2 pump 10 SPM/ 660 psi. 20 SPM/ 1980 si. 17:45 18:00 0.25 8,795 8,795 PROD1 DRILL CIRC P Change mode on MWD 18:00 00:00 6.00 8,795 8,856 PROD1 DRILL DDRL P Drilling f/ 8,795' U 8.856' MD 6,236' ND. 7/22/2008 Finished weighting up to 13.7 PPG mud, drilled ahead to 9,006', lost pump pressure, tested surface e ui ment, OK. UD bit, motor, stab, and Jars. Down load MWD, RIH w/ BHA # 8. 00:00 06:00 6.00 8,856 8,964 PROD1 DRILL DDRL P Drilling f/ 8,856' U 8,964' MD, 6,321' ND. 06:00 06:15 0.25 8,964 8,980 PROD1 DRILL DDRL P Drill 4.75" production hole f/ 8,964' U 8,980' MD 6,338' ND' 06:15 08:15 2.00 8,980 8,980 PROD1 DRILL CIRC P Circulate and conditon mud ,weight up f/ 13.3 PPG U 13.7 PPG, 115 GPM, 3,500 psi. OFF, 20 % flow 3,640 si, after wei htin u . 08:15 10:00 1.75 8,980 9,006 PROD1 DRILL DDRL P Continue drilling f/ 8,880' U 9,006' MD, 6,361' ND. 10:00 10:30 0.50 9,006 9,006 PROD1 DRILL CIRC T Lost pump pressure, tested surface equipment, OK, pressure loss down hole. 10:30 11:00 0.50 9,006 8,626 PROD1 DRILL TRIP T POOH f/ 9,006' U 8,626' MD, (above 5 1!2 liner top) monitor on trip tank, lookin for wash out. 11:00 11:15 0.25 8,626 8,626 PROD1 WELCTL OWFF T Monitor well (static ) 11:15 12:00 0.75 8,626 7,213 PROD1 DRILL TRIP T Continue POOH f/ 8,629' U 7,213' MD, monitof fill on trip tank looking for wash out . 12:00 12:30 0.50 7,213 7,213 PROD1 DRILL PULD T R/D GBR & 2 7/8" equipment. 12:30 16:00 3.50 7,213 1,617 PROD1 DRILL TRIP T Continue to POOH f/ 7,213' U 1,617' MD, Monitor hole on trip tank looking for wash out. 16:00 18:00 2.00 1,617 820 PROD1 DRILL TRIP T BHA, UD 2 7/8" spiral HWDP/Jars U 820' MD. SPR @ 8,980'MD 6,338 ND 13.7 PPG. Mud, # 2 pump 10 SPR = 800 si. 20 SPM =2,340 si. 18:00 20:30 2.50 820 820 PROD1 DRILL TRIP T Continue to UD BHA, 2 7/8 spiral HWDP f/ 820' MD 20:30 20:45 0.25 820 820 PROD1 DRILL PULD T Download MWD 20:45 21:15 0.50 400 0 PROD1 DRILL TRIP T Continue to UD BHA # 7, C/O bit ,motor, and stab, no obvious wash out while POOH, found a small errosion in the side of the bit. 21:15 22:00 0.75 0 0 PROD1 DRILL TRIP T M/U bi 22:00 22:30 0.50 0 80 PROD1 DRILL TRIP T Up load MWD 22:30 23:15 0.75 80 200 PROD1 DRILL TRIP T Continue to M!U BHA. 23:15 23:30 0.25 200 200 PROD1 DRILL DHEQ T Shallow test MWD-good. Pump @ 110 GPM 1400 si, 18 % flow 23:30 23:45 0.25. 200 200 PROD1 DRILL TRIP T Test surface equipment -Test good, 3000 si. 23:45 00:00 0.25 200 300 PROD1 DRILL OTHR T Continue to trip in hole w/ BHA # 8 U 300' Page i9 of 3Q • J Time Logs _ ___ bCOde T Comment From To Dur 5 C)epth E. Depth Phase Code Su Date _ 7/23/2008 _ 24 hr summary RIH w/ BHA # 8, watching for possible wash out, testing string on way in. condition mud @ 5 1/2"shoe, Drill f/ 9,006 U 9,211' MD, 6,527' ND. 00:00 01:30 1.50 300 1,130 PROD1 DRILL TRIP T Continue to M/U BHA # 8 f/ 300' U 1,130' 01:30 03:00 1.50 1,130 1,139 PROD1 DRILL TRIP T P/U a new set of jars, found theads rusted and service break loose, UD, P/U old set RIH. 03:00 03:15 0.25 1,139 1,130 PROD1 DRILL TRIP T Shallow test and visually check jars for was out @ surface, pump @ 110 GPM, 2020 psi, 18 % flow out. test ood. 03:15 04:45 1.50 1,130 1,616 PROD1 DRILL TRIP T Continue to RIH w/ BHA # 8 f/ 1,130 ' U 1,616'. Clean and inspect all connections for wash out. 04:45 05:30 0.75 1,616 3,040 PROD1 DRILL TRIP T RIH w/ 2 7/8" DP f/ 1,600' U 3,040' MD 05:30 06:00 0.50 3,040 3,040 PROD1 DRILL TRIP T Shallow test MWD @ 3.040' MD, pump @ 110 GPM, 2330, 18 % flow out. Test ood. 06:00 09:00 3.00 3,040 8,725 PROD1 DRILL TRIP T RIH f/ 3,040' U 8725' MD @ 5 1/2" shoe, monitor displacement on trip tank, fillin i e eve 25 stds. 09:00 10:00 1.00 8,725 8,725 PROD1 DRILL CIRC T Condition mud for (barite sag) 13.7 in/out, 105 GPM, ICP = 3,400 psi. FCP 3,520 psi., flow out = 17 %, RPM=30,TQ=4 K, UPWT.= 190K, S/O WT = 120 K, RT WT. =138 K. 10:00 10:15 0.25 8,725 8,725 PROD1 DRILL CIRC T Slow pump rates @ 8,725' MD, 6,147' MD w/ 13.7 PPG IVIW = #2 pump @ 10 SPM = 950 psi. pump 20 SPM = 2270 si. 10:15 11:15 1.00 8,725 9,006 PROD1 DRILL TRIP T RIH f/ 8,725' U 9,006' MD, Monitor hole on tri tank. 11:15 12:00 0.75 9,006 9,024 PROD1 DRILL DDRL P Drill f/ 9,006' U 9,024' MD 6,374' ND, 105 GPM, 3,800 psi./ on, 3,550' /off, Flow out + 18%, RPM = 55, TQ /on = 4 -5 K, TQ/ off = 4 K, P/U WT.=200 K, S/O WT.= 120 K RT WT. = 140 K 12:00 18:00 6.00 9,024 9,161 PROD1 DRILL DDRL P Continue drilling f/ 9,024' U 9,161' MD, 6,486' ND, 100 GPM, 3,600 psi /on, 3,450 psi./off, Flow out = 17 %, RPM = 55, TO/ on /off = 5 K, P/U WT = 200 K, S/O WT = 120 K, RT WT =140 K. 18:00 00:00 .6.00 9,161 9,211 PROD1 DRILL DDRL P Continue drilling f/ 9,161' U 9„211' MD 6,527' ND, 100 GPM, 3,600 psi /on, 3,450 psi./off, Flow out = 17 %, RPM = 55, TO/ on /off = 5 K, P/U WT = 200 K, S/O WT = 120 K, RT WT =140 K. 39 hrs. on Jars. ECD 15.8 EMW. 7/24/2008 Drill f/ 9,211'- U 9,327' MD (TD) 6,619' ND, monitor well, static. Short trip to 5 1/2" shoe and back. CBU, 500 units gas, circulate gas cut mud out. Monitor well 15 min. (flowing) circulate light spot out, monitor well again static , BROOH to 5 112" shoe to kee from swabbin the hole. • • Time Logs _ __ _ D to From To Dur S. Dew E. De th Ph .e Code Subcode T Comment 00:00 06:00 6.00 9,211 9,248 PROD1 DRILL DDRL P Drill ahead f/ 92,11'- U 9,248' MD, 6,557' TVD, 100 GPM, 3500 psi. ON, 3450 psi. OFF, 23 SPM, 17 % flow out, 25 units of as. 06:00 12:00 6.00 9,248 9,303 PROD1 DRILL DDRL P Continue drill f/ 9,248'- 9,903' MD, 6,600' TVD, 105 GPM, 3,700 PSI ON, 3,600 psi. OFF, 17 % flow out, 55 RPM. SPR @ TD. w/ 13.5 mud = # 2 pump, 10 SPM =1,130 psi. 20 SPM = 2,660 si. 12:00 18:00 6.00 9,303 9,327 PROD1 DRILL DDRL P Continue drill f/ 9,303'- 9,327' MD, 6 600' TVD, 105 GPM, 3,700 PSI ON, 3,600 psi. OFF, 17 % flow out, 55 RPM. 18:00 18:15 0.25 9,327 9,327 PROD1 DRILL OWFF P Monitor hole (static) 18:15 .19:00 0.75. 9,327 8,725 PROD1 DRILL WPRT P Short trip to 5 1/2" shoe, P/U WT.= 215 K, DN WT.= 120 K. 19:00 20:00 1.00 8,725 8,725 PROD1 RIGMNT SVRG P Grease top drive, blocks, crown , blocks, added oil tot drive. 20:00 20:30 0.50 8,725 9,327 PROD1 DRILL WPRT P RIH to 9,327' MD, hole took proper displacement, took 25 K @ 9,230' +/-worked pipe down slowly, no trouble. 20:30 22:15 1.75 9,327 9,327 PROD1 DRILL CIRC P Circulate and condition mud, 28 YP, 13.5 PPG.to balance, 500 units gas @ bottoms up. 100 GPM. 24 SPM, 3,560' psi. 16 % flow out. RPM=55, TQ =5 K 22:15 22:30 0.25 9,327 9,327 PROD1 DRILL OWFF P Observe well 15 mins. (well flowing) 22:30 23:00 0.50 9,327 9,327 PROD1 DRILL CIRC P Circulate to balance, had a light s ot, 23:00 23:15 0.25 9,327 9,327 PROD1 DRILL OWFF P Monitor well for 15 min. (well static) 23:15 00:00 0.75 9,327 8,725 PROD1 DRILL TRIP P BROOH to the shoe @ 8,725' MD,75 GPM. 7/25/2008 POOH & UD BHA # 8, P/U & RIH w/ 3 1/2" Hydril 511, 9.2 ppf. casing liner w/ "HR" ZXP liner hanger, filling and circulatin eve 2,500'. 00:00 00:30 0.50 9,008 8,725 PROD1 DRILL TRIP P Continue BROOH f/ 9,008'- U 8,725' 00:30 01:00 0.50 8,725 8,161 PROD1 DRILL TRIP P POOH on elevators f/ 8725' - U 8,161' MD, same arameters. 01:00 01:30 0.50 8,161 8,161 PROD1 DRILL TRIP P Monitor well (static) Pump dry job. 01:30 02:00 0.50 8,161 7,215 PROD1 DRILL TRIP P Continue to POOH f/ 8,161' - U 7,215' MD, hole took ro er dis lacemerit. 02:00 02:45 0.75 7,215 7,215 PROD1 DRILL TRIP P Attempt to drop 1.32" drift would not fall, retrieve drift, rigged up belly rope for i e rack, ri u GBR. 02:45 05:30 2.75 7,215 1,616 PROD1 DRILL TRIP P POOH on elevators f/ 7,215' -U 1,616' MD. Hole took ro er dis lacement. 05:30 06:00 0.50 1,616 1,616 PROD1 DRILL TRIP P UD HWDP and have a trip drill. 06:00 09:45 3.75 1,616 1,200 PROD1 DRILL TRIP P Continue to UD HWDP, DC's 09:45 10:45 1.00 1,200 0 PROD1 DRILL PULD P Down load MWD, UD same and clean same. 10:45 11:30 0.75 0 0 PROD1 DRILL RURD P UD subs, nubbins, and GBR tongs. Page 2'3 of 3~ • • Time Logs Date From To Dur S. De th E. De th Ph e Code Subcode T Comment 11:30 12:15 0.75 0 0 COMPZ CASING RUNL P R/U to run 3 1/2" Hydril 511, 9.2# I~ er. 12:15 14:15 2.00 0 750 COMPZ CASING RUNL P PJSM run 3 112' liner, monitor hole on tri tank 14:15 15:00 0.75 750 829 COMPZ CASING RUNL P P/U Baker "HR" ZXP liner hanger/ packer, M/U & fill same w/ Gel packer fluid, wait 25 mins., as per BOT.rep. Check PU/WT = 80 K. S/O WT.= 80 K. 15:00 15:15 0.25 829 829 COMPZ CASING CIRC P Fill pipe & circulate 1 pipe volume, @ 133 GPM, 3.1 BPM, 19 % flow out. 15:15 16:45 1.50 829 2,485 COMPZ CASING RUNL P Continue RIH w/liner assembly on 2 7/8" DP, single in from pipe shed f/ 829' - t/ 2,485' MD (5 1/2 liner top 2,525 MD) Monitor displacement om tri tank. 16:45 17:30 0.75 2,485 2,485 COMPZ CASING CIRC P CBU @ liner top @ 3 BPM, 125GPM 820 psi. 18% flow out, P/U WT.= 90 K, S/O WT.= 90 K. 17:30 18:00 0.50 2,485 3,055 COMPZ CASING RUNL P Continue to run 3.1/2" liner assembly, filling & circulating every 2,500' 18:00 18:45 0.75 3,055 3,768 COMPZ CASING RUNL P Continue RIH w! 5 1!2" liner assembly on 2 7/8" DP picking up out of shed, f/ 3,055'- U 3,768' MD. 18:45 20:30 1.75 3,768 5,000 COMPZ CASING RUNL P Continue RIH out of DRK f/ 3,768' - t/ 5,000', no obstructions when packer assembl entered 5 1/2" liner to . 20:30 22:00 1.50 5,000 5,000 COMPZ CASING CIRC P CBU @ 5,002' MD. Stage pumps up - 1 BPM= 480 psi. 4 %, 1.5 BPM= 690 psi, 9 %, 2 BPM = 890 psi. 178 units of as BU 22:00 00:00 2.00 5,000 6,805 COMPZ CASING RUNL P Continue RIH W 3 1/2" liner assembl f/ 5,000 - t/ 6,805' MD. 7/26/2008 RIH w/ 3 1/2" liner on 2 7/8" DP staging in & circulating every 2,500', tagged bottom @ 9,327'. Pumped cement and displaced, dart failed to bump, attempt to release from liner, (would not) POOH w/ string up to 6100' CBU, dart bum ed. POOH wet, broke out landin collar. Std. shoe track in DRK. 00:00 01:30 1.50 6,805 7,564 COMPZ CASING RUNL P Continue RIH w/ 3 1/5" liner assembly f/ 6,805' MD - t/ 7,564' hole took proper displacement. All of the 2 7/8" DP was drifted from DRK oin in the hole w/ 1.34" drift. 01:30. 03:00 1.50 7,564 7,564 COMPZ CASING CIRC P CBU @ 7,564', Pump 2 BPM, 1,380 si. 12% flow out,110 units of as. 03:00 04:45 1.75 7,564 9,327 COMPZ CASING RUNL P IH w/ 3 1/2 "liner assembly t/ 7,564' - U 9,303' MD,_ stage pumps up, 1 BPM =1,160 psi., flow = 5 %, 1.5 BPM = 1,360 psi. flow out = 8%, P/U WT. = 157 K, D/N WT. = 110 K. Hole took proper dis lacement. 04:45 08:00 3.25 9,327 9,327 COMPZ CASING CIRC P Circulate & reciprocate @ 83 GPM, 1,500 psi. flow out = 11 %, P/U WT. = 168 K, S/O WT. =115 K. 08:00 08:45 0.75 9,327 9,327 COMPZ CASING NUND P P/U BOT cementing head. Wage 22 ~a~ 3U • l J Time Logs _ _ _ _ __ _____ Date From To Dur 5 De th E. De th Phase Code Subcode T Comment 08:45 09:00 0.25 9,327 9,327 COMPZ CEMEN" CIRC P Circulate down @ 1 BPM, tag bottom @ 9.327' MD, increase pump rate t/ 2 BPM, 84 GPM, 1,730 psi. flow = 13 %. 09:00 10:00 1.00 9,327 9,327 COMPZ CEMEN" SFTY P PJSM on cement liner, continue circ.& recip. while batch up cement, test lines t/ 4.500, si. - OK. 10:00 11:15 1.25 9,327 9,327 COMPZ CEMEN" CIRC T Cement as per program, 10bbls C 100 @ 8.3 ppg., 20 bbls 15.0 ppg. mud push, followed by 15.0 bbls, 71 sxs GasBLOK .20% D46, .20 gal/sk D47, .40 % D65, 2.0 gal/sk D600G, 0.030 gal/sk D177, Batched mixed @ 15.8ppg. class ( G cement, shut down and wash lines out on cement head, drop wiper dart (indicator tripped) Displace w/ 46 bbls Max 13.5 ppg mud (Calculated to bump 44.5 bbls), Did not bump lu . C.I.P 1125 hrs 7/26/08 11:15 12:00 0.75 9,327 9,327 COMPZ CEMEN" OTHR T Attempted to left hand release liner hanger 3 times, Pipe backed off below rotary table, Screw back into i e. 12:00 12:15 0.25 9,327 9,327 COMPZ CEMEN" CIRC T Attempt bump plug w/ 10 bbls still no bump, No returns up annulus hole ossibl acked off, shut down. 12:15 12:30 0.25 9,327 9,327 COMPZ CEMEN" PULD T UD cement head get ready to POOH. 12:30 15:00 2.50 9,327 6,100 COMPZ CEMEN" TRIP T POOH on elevators f! 9,327' - t/ 6,100' MD, monitor hole on trip tank, hole swabbed on the first 15 jts. pumped as needed to fill hole below han er. 15:00 15:30 0.50 6,100 6,100 COMPZ CEMEN" CIRC T CBU @ 2 BPM. 85 GPM, 1220 psi, flow = 11%, @ 50 bbls (Pipe volume 30 bbls .Dart bum ed w/ 4,200 si. 15:30 17:15 1.75 6,100 2,525 COMPZ CEMEN" TRIP T Continue to POOH f/ 6,100' MD t! 2,525', monitor hole on trip tank, took ro er dis lacement. 17:15 17:30 0.25 2,525 2,525 COMPZ WELCTI OWFF T Monitor well @ top of 5 1/2" liner. 17:30 18:00 0.50 2,525 1,650 COMPZ CEMEN" TRIP T Continue to POOH f /2,525' - t/ 1,650' MD, monitor fill on tri tank. 18:00 19:30 1.50 1,660 860 COMPZ CEMEN" TRIP T Continue to POOH f/ 1660' 2 718" DP, hole took ro er dis lacement. 19:30 21:45 2.25 860 90 COMPZ CEMEN" TRIP T UD 3 1/2 "assembly to the landin collar. 21:45 22:15 0.50 90 90 COMPZ CEMEN" PULD T Clear floor and change handling tools. 22:15 23:15 1.00 90 COMPZ CEMEN" PULD T Sniff area around rotary, OK, hot work permit, heat up landing collar and break out Baker locked joints on collar. 23:15 00:00 0.75 COMPZ CEMEN" PULD T Circulate through shoe track @ 3 BPM, check floats (good) and stand back in the derrick, all centralizers accounted for. PacJa 23 r~~ 3it ~_ J ~ J Time Logs _ Date From To Dur S De th E. De th Phase Code Subcode T Comment 7/27/2008 za hr Summary P/U clean out assembly, RIH staging in, circulating out cement contaminated mud. 2,500' / 5000'/ 6100'/ 8700'/ and 9,231'. Condition mud to a 28 eild oint,13.5 .around. 00:00 03:15 3.25 0 0 COMPZ CEMEN' TRIP T PJSM, M/U clean out assembly as er DD, checkin all connection. 03:15 04:00 0.75 415 415 COMPZ CEMEN' TRIP T Shallow test MWD. Pump @105 BPM, 1,180 psi., flow = 13 %, test ood. 04:00 05:15 1.25 415 2,500 COMPZ CEMEN' TRIP T RIH f/ 415' - t/ 2,500' MD hole took proper displacement. Continue to check for loose connections. 05:15 06:00 0.75 2,500 2,500 COMPZ CEMEN' CIRC T Circulate & condition mud @ 2,500' MD. Pump @ 120 GPM, 2,.000 psi, flow out = 15%, r m = 50, TQ = 2 K. 06:00 07:15 1.25 2,500 5,000 COMPZ CEMEN' TRIP T Continue to RIH f/ 2,500' - t/ 5,000' MD, monitor displacement on trip tank. 07:15 07:45 0.50 5,000 6,100 COMPZ CEMEN' TRIP T Continue to RIH f/ 5,000' - t/ 6,100' MD, monitor displacement on trip tank. 07:45 09:00 1.25 5,000 5,000 COMPZ CEMEN' CIRC T CBU @ 5,000' MD, 111 GPM, 2,600 psi. Flow out = 15 % ,RPM = 30, TQ = 3 K, P/U WT. = 124k S/O WT. =110 K,RTWT.=115K 09:00 10:00 1.00 6,100 6,100 COMPZ CEMEN' CIRC T CBU @ 6,100' MD, 108 GPM, 2,670 psi., Flow out = 14 % ,RPM = 30, TO = 3 K, P/U VV'f. = 132 K, S/O WT.=110 K,RTWT.=115 K. Cement returns bottoms u . 10:00 10:45 0.75 6,100 7,115 COMPZ CEMEN' TRIP T Continue to RIH f/ 6,100' - t/ 7,115' MD, monitor displacement on trip tank. 10:45 11:45 1.00 7,115 7,115 COMPZ CEMEN- CIRC T CBU @ 7,515' MD, 108 GPM, 3,580 psi., Flow out = 14 % ,RPM = 30, TQ = 3 K, P/U WT. = 132 K, S/O WT. = 110 K, RT WT.= 115 K. 11:45 12:45 1.00 7,115 7,789 COMPZ CEMEN- TRIP T Continue to RIH f/ 7,115' - U 7,789' MD, monitor displacement on trip tank. Ta cement strin er 7,720' 12:45 14:15 1.50 7,789 7,789 COMPZ CEMEN' CIRC T CBU @ 7,889' MD, 108 GPM, 3,800 psi., Flow out = 15 % ,RPM = 30, TO = 3 K, P/U WT. = 150 K, S/O WT. = 110 K, RT WT.= 120 K. 14:15 14:45 0.50 7,789 7,789 COMPZ CEMEN- TRIP T Stand back #77 (2 7/8 DP) P/U # 89 & UD 2 singles to get back on even stands, R/U for 4 " DP. 14:45 15:30 0.75 7,789 8,195 COMPZ CEMEN' TRIP T Ream cement f! 7,789' - t/ 8,195'. MD, 118 GPM, 3,770 psi, flow out = 15 %, RPM = 40, TQ = 4 K. 15:30 16:45 1.25 8,195 8,195 COMPZ CEMEN' CIRC T CBU @ 8195' MD, 118 GPM, 3,770 psi., Flow out = 15 % ,RPM = 30, TO = 3 K, P/U WT. = 162 K, S/O WT. = 112 K, RT WT.= 125 K. Final circulatin ressure = 3,640 si. 16:45 18:00 1.25 8,195 8,500 COMPZ CEMEN' TRIP T Ream cement f/ 8,195' - t/ 8.500' MD, 118 GPM, 118 GPM, 3,770 psi, flow out=15%, RPM=50,TQ=4 K. i Pae~~ ~4 of 3fl Time Logs _ __ __ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 18:00 19:15 1.25 8,500 8,500 COMPZ CEMEN CIRC T Wash down f/ 8,500' - t/ 8,725', pump 120 GPM, 3850 psi., flow out = 16%, RPM = 60, TQ = 4-5 K. 19:15 21:15 2.00 8,500 8,725 COMPZ CEMEN- CIRC T CBU @ 8,725' MD, 120 GPM, 3,850 psi.( ICP), Flow out = 15 % ,RPM = 30, TO = 3 K, P/U WT. = 162 K, S/O WT. = 112 K, RT WT.= 125 K. Final circulating pressure = 3,710 psi. 1,000 units of gas (Epoch) circulated as cut mud out. 21:15 00:00 2.75 8,725 9,231 COMPZ CEMEN" CIRC T Continue to wash down f/ 8,725' t/ 9 231' Pump @ 100 GPM, 2850 psi. flow out = 14 %, RPM = 50, TO = 4-5 K. back round as 230 units. 7/28/2008 Finish servicing rig, RIH to TD (9,327') conditon mud, POOH, L/D BHA # 9, P/U 3 1/2" liner w! "HR" hanger and ZXP to acker, RIH to 1,785'. 00:00 01:15 1.25 9,231 9,327 COMPZ CEMEN" TRIP T Continue washing down f// 9.231' - t/ ' MD. Pump @ 100 GPM, 2,850' psi. flow = 14 %, RPM = 50, TO = 4-5 K. 01:15 03:15 2.00 9,327 9,327 COMPZ CEMEN" CIRC T Circulate and condition mud @ 9,327' Pump @ 100 GPM, 2,750' psi. flow out =13 %, RPM = 50, TQ = 4 K. P/U WT. = 208 K, S/O WT. 120 K, 47 units as . 03:15 03:30 0.25 9,327 9,327 COMPZ WELCTI OWFF T Monitor well (static) 03:30 04:15 0.75 9,327 8,667 COMPZ CEMEN" TRIP T POOH f/ 9.327' - t/ 8,667' MD. hole took ro er dis lacement. 04:15 04:30 0.25 8,667 8,667 COMPZ WELCTL OWFF T Monitor well (static) 04:30 07:00 2.50 8,667 8,667 COMPZ RIGMNT SVRG T Cut & slip drilling line, service top drive Drwks. and crown sheaves. 07:00 07:15 0.25 8,667 9,327 COMPZ CEMEN" TRIP T RIH f/ 8,667' - t/ 9,327' MD (TD), wash down last stand @ 104 GPM = 3,140 psi. flow out =14 % RPM = 40, TQ = 4-5 K. 07:15 09:30 2.25 9,327 9,327 COMPZ CEMEN" CIRC T CBU @ 9,327' MD, 104 GPM, 3,140 psi. flow out, RPM =40,T0 =4-5 K. P/U WT. = 120 K, RT WT. = 140 K. 09:30 09:45 0.25 9,327 9,327 COMPZ WELCTL OWFF T Monitor well (static). 09:45 10:45 1.00 9,327 8,725 COMPZ CEMEN- TRIP T Pump out of the hole to 5 1/2 "shoe to kee from swabbin as in. 10:45 11:00 0.25 8,725 8,725 COMPZ WELCTI TRIP T Monitor well (static) 11:00 11:30 0.50 8,725 8 COMPZ CEMEN" TRIP T POOH on elevators t/ 8,100', monitor well on tri tamk. 11:30 11:45 0.25 8,100 8,100 COMPZ CEMEN" CIRC T Pumped a dry job. 11:45 12:00 0.25 8,100 7,721 COMPZ CEMEN" TRIP T POOH to 7,721', monitor well on trip tank. 12:00 12:45 0.75 7,721 7,721 COMPZ CEMEN" TRIP T Break out XO and R/U 2 7!8" handling equipment. Drop rabbit, R/U bell ro a to stand back 2 7/8". 12:45 15:15 2.50 7,721 415 COMPZ CEMEN" TRIP T POOH w/ 2 7!8" DP f/ 7,721' - t/ 415' MD. Retrieved drift from stand #7 when pipe came wet. Still need to drift stands # 1 to # 7 ,for liner'ob. Page 25 cif 3(~ • u Time Logs ~ _ _ _ __ _ __ Date From To Dur S De th E De th Ph e Code Subcode T Comment _ 15:15 16:45 1.50 415 0 COMPZ CEMEN" TRIP T UD BHA # 9 as per DD,MWD. 16:45 17:15 0.50 0 0 COMPZ DRILL PULD T Clean and clear floor 17:15 18:00 0.75 0 0 COMPZ CASING RUNL T R/U to run tinere Change out elevators, remove centralizer from shoe track, P/U Hydril 511 pup, drift w/ 2.88" 9.85 Ion M/U floor valve. 18:00 18:30 0.50 0 0 COMPZ CASING SFTY T PJSM for running 3 1/2" (9.2 ppf, L-80 liner. 18:30 19:00 0.50 0 0 COMPZ CASING RUNL T Change out a hydraulic hose on GBR ton ower unit. 19:00 19:30 0.50 0 126 COMPZ CASING RNCS T P/U 3 1/2" (9.2 PPF, L-80) liner t/ 126' 19:30 20:00 0.50 126 126 COMPZ CASING DHEO T Circulate through float equipment w/ 105 GPM, 220 psi. flow out =14%, checked floats OK 20:00 21:15 1.25 126 800 COMPZ CASING RNCS T Run 3 1/2 liner to 800' MD. 21:15 22:15 1.00 800 800 COMPZ CASING RNCS T P/U hanger w/ " HR" ZXP liner top packer/ mix gel up, let set in tool for 30 mins.as er BOT Re . 22:15 22:45 0.50 800 937 COMPZ CASING RUNL T RIH w/ hanger on 2 7/8" DP, f/ 800' - t/ 937' MD. Drifted stands # 1- #7 stands not drifted on tri out. 22:45 23:00 0.25 937 937 COMPZ CASING RUNL T @ 937' MD circulate liner volume @ 108 GPM, 390 si., flow out = 14 %. 23:00 00:00 1.00 937 1,785 COMPZ CASING RUNL T RIH w/ 2 7/8" DP f/ 937' - U 1,785' MD. 7/29/2008 Run 3-1/2 production liner on 2-7/8"drill pipe to TD. Circulate and condition mud for cement. Drop 3/4" ball to set and release han er. Ball did not seat. Dro second ball and um down. 00:00 00:30 0.50 1,785 2,738 COMPZ CASING RUNL T TIH with 3-1/2" liner on 2-7/8"drill i e. PU wt 92k, SO wt 92k 00:30 01:30 1.00 2,738 2,738 COMPZ CASING CIRC T Circulate bottoms up pumping 105 m, 810 si. Max as 36 units 01:30 04:00 2.50 2,738 5,015 COMPZ CASING RUNL T Tripping in hole with liner on drill i e. 04:00 05:15 1.25 5,015 5,015 COMPZ CASING CIRC T Circulate bottoms up pumping 95 gpm, 1320 psi. PU wt 115k, SO wt 105k. Max as 112 units 05:15 07:45 2.50 5,015 7,483 COMPZ CASING RUNL T Tripping in hole with liner on drill i e. 07:45 09:15 1.50 7,483 7,483 COMPZ CASING CIRC T Circulate bottoms up pumping 70 m, 1240 si. 09:15 10:15 1.00 7,483 8,527 COMPZ CASING RUNL T Tripping in hole with liner on drill i e. 10:15 11:00 0.75 8,527 8,527 COMPZ CASING CIRC T Lost string weight, stop and circulate at 55 m, 1230 si. 11:00 12:45 1.75 8,527 9,011 COMPZ CASING RUNL T Continue tripping in hole with liner on drill i e. 12:45 13:00 0.25 9,011 8,906 COMPZ CASING RUNL T Tagged up on tight stop pick up and circulate. 13:00 14:30 1.50 8,906 8,906 COMPZ CASING CIRC T Circulate bottoms up pumping 50 m, 1250 si. 14:30 17:30 3.00 8,906 9,332 COMPZ CASING RUNL T Wash and ream liner in hole with 4" drill i e from derrick. ~ Page 26 of ~£~ CI Time Logs - ---- - -- -- Date From To Dur S. De th E Depth Phase Code Subcode T _Comment 17:30 18:45 1.25 9,332 9,332 COMPZ CASING CIRC T Circulate and condition mud for cement job. Pumping 57 gpm, 1220 si. PU wt 165k, So wt 112k 18:45 19:15 0.50 9,332 9,000 COMPZ CASING RUNL T POOH standing back 4" drill pipe. 19:15 19:45 0.50 9,000 9,316 COMPZ CASING RUNL T Run liner back in hole with 2-7/8"drill i e. 19:45 20:00 0.25 9,316 9,316 COMPZ CASING CIRC T Circulate 30 bbls at 53 gpm, 1200 si. 20:00 21:00 1.00 9,316 9,327 COMPZ CASING RUNL T Pick up single and make up cement head. 21:00 22:15 1.25 9,327 9,327 COMPZ CASING CIRC T Circulate and reciprocate pipe. Stage um s to 80 m, 1840 si. 22:15 23:30 1.25 9,327 9,327 COMPZ CASING CIRC T Pick up to tool joint, break connection and drop ball. Pump ball down at 79 gpm, 1720 psi. No indication that ball landed on seat. Continue pumping while discussing o tions. 23:30 00:00 0.50 9,327 9,327 COMPZ CASING CIRC T Pick up to tool joint, break connection and drop second ball. Pum down at 82 m, 1780 si. 7/30/2008 Dropped balls to set and release hanger. Balls did not seat and could not confirm release. Cemented liner and attempted to set packer. Circulated hole clean and tested packer. Would not hold pressure. Made several attempts to set and test packer. Pulled out of hole and waited for cement to cure. Casing held 1600 si when retested. Ri ed u and be an runnin 3-1/2" as lift com letion. 00:00 04:30 4.50 9,327 9,327 COMPZ CASING CIRC T Continue ciruclating, attempting to seat ball to release hanger. Discuss options with Baker and CPAI En ineers. 04:30 05:45 1.25 9,327 9,327 COMPZ CEMEN" OTHR P Turn over to Dowell for cement job. Pumped cement. Bumped plug, set hanger and release liner, checked floats -float holdin . 05:45 06:00 0.25 8,487 8,487 COMPZ CEMEN" PACK P Pick up and expose packer setting tool. Set down on liner to set acker. 06:00 07:30 1.50 8,487 8,487 COMPZ CEMEN" CIRC P Circulate out CW100, mud push and cement from liner top at 3 bpm, 3550 si 07:30 08:45 1.25 8,487 8,487 COMPZ CASING DHEQ T Test packer to 1500 psi. Not holding pressure. Set down on liner again to set packer. Attempt to test, not holdin ressure. 08:45 11:15 2.50 8,487 8,487 COMPZ CEMEN" CIRC T Circulate 2 bottoms up at 3 bpm, 3550 si. 11:15 12:15 1.00 8,487 8,487 COMPZ CEMEN- PACK T Continue attem is to set and test liner top packer. Still not holding ressure. 12:1.5 12:30 0.25 8,487 8,487 COMPZ CASING RUNL P Monitor well -static. 12:30 13:30 1.00 8,487 8,487 COMPZ CASING RUNL P Pump dry job, blow down top drive and lines. Rig down lines and cement head. Make service breaks on cement head per Baker rep and la down. 13:30 14:30 1.00 8,487 7,211 COMPZ CASING RUNL P Change out handling equipment and POOH with liner runnin tools. Pa€~e 27 rrf 3€7 Time Logs Date_ From To Dur S. De th E. De th Phase Cade Su6code T Comment 14:30 15:00 0.50 7,211 7,211 COMPZ RIGMNT SVRG P _ Service crown, blocks and top drive. 15:00 17:00 2.00 7,211 0 COMPZ CASING RUNL P POOH with liner running tools. Hole took ro er fill. 17:00 18:00 1.00 0 0 COMPZ CASING RUNL P Inspect liner running tool. Tattle tale sheared indicating weight was transfered to packer setting tool. Make service breaks on liner running tool per Baker rep and lay down tools. 18:00 19:00 1.00 0 0 COMPZ CEMEN' WOC P Waiting on cement to cure before performing casing/packer pressure test. Serviced draw works. 19:00 19:30 0.50 0 0 COMPZ CASING DHEQ P Close blind rams, perform casing test to psi, o o es. Good test. 19:30 21:00 1.50 0 0 COMPZ RPCOM RURD P Clear and clean rig floor, rig up to run 3-1/2" tubin . 21:00 21:30 0.50 0 0 COMPZ RPCOM SFTY P PJSM -running completion. 21:30 22:15 0.75 0 0 COMPZ RPCOM RURD P Pick up test joint and pull wear ring. 22:15 00:00 1.75 0 1,230 COMPZ RPCOM RCST P RIH with 3-1/2" gas lift completion strip . 7/31 /2008 Run 3-1/2" gas lift completion with subsurface safety valve.. Tag up and space out. Test tubing, seals and SSSV. Install back ressure valve and be in ni lip down stack. 00:00 00:45 0.75 1,230 1,230 COMPZ RPCOM RURD P Rig down double stack tongs and rig u ower ton s. 00:45 06:30 5.75 1,230 6,507 COMPZ RPCOM RCST P RIH with 3-1/2" gas lift completion strip . PU wt 120k, So wt 100k 06:30 07:30 1.00 6,507 6,507 COMPZ RPCOM RURD P Pick up and rig up Camco SSSV control line. Make up line to SSSV and test to 6200 psi for 10 minutes, held ressure. 07:30 10:00 2.50 6,507 7,685- COMPZ RPCOM RCST P RIH with 3-1/2" gas lift completion strip . 10:00 11:15 1.25 7,685 7,685 COMPZ RPCOM SFTY P Power tongs blew an o-ring spraying tong operator in the face. Washed tong operators face and eyes using eye wash and sent to medic. Tong operator was ok and released back to work. Approximately 1 pint of hydraulic fluid was released. Security was notified. 11:15 12:00 0.75 7,685 8,504 COMPZ RPCOM RCST P RIH with 3-1/2" gas lift completion string. Pump down last 30' with 200 psi to verify seals engaging. PU wt 140k, SO wt 102k. 12:00 14:00 2.00 8,504 8,500 COMPZ RPCOM RCST P Tagged up and spaced out. Installed bleeder on control line. 14:00 14:45 0.75 8,500 8,500 COMPZ RPCOM DHEQ P Pressure test tubin to 2000 psi and annulus to 2000 psi for 10 minutes, Both held, charted test. 14:45 16:45 2.00 8,500 8,500 COMPZ RPCOM RCST P Pick up out of seal bore and displace well to seawater. Stage pumps to 7 bpm, 1780 psi. Spot 26 bbls of corrosion inhibited brine on top of liner. Page 28 of 3~ • ! Time Logs Date From To Dur S. De th E. De th Ph se Code Subcode T Comment 16:45 18:30 1.75 8,500 8,500 COMPZ RPCOM HOSO P Lay down 3joints, pick up pup and 1 joint and run in hole. Pick up and make up hanger and landing joint. Land tubing and run in lock down screws. Total of 68 bands used to secure SSSV control line. 18:30 19:30 1.00 8,500 8,500 COMPZ RPCOM RCST P Drain stack and blow down lines. Rig u for tubin test. 19:30 21:15 1.75 8,500 8,500 COMPZ RPCOM DHEQ P Pressure u tubing to 2200 psi and hold for 15 minutes, pressure held. Bleed tubing to 1500 psi and shut in. Pressure annulus to 2000 psi for 30 minutes, ressure held. Bleed pressure off of annulus then tubing. Pressure up on annulus to shear out valve. Sheared at 1500 psi. Bleed off pressure and close SSSV. Pressure up on annulus to 2000 psi for 10 minutes. SSSV holding pressure. Open SSSV and let pressure equalize between annulus and tubing. Bleed off pressure and close SSSV. 21:15 21:30 0.25 0 0 COMPZ RPCOM RURD P Rig down test equipment. 21:30 21:45 0.25 0 0 COMPZ RPCOM RCST P Set back pressure valve. 21:45 00:00 2.25 0 0 COMPZ RPCOM NUND P Break bolts on BOP stack, clean drip pan and surface equipment. Nipple down flow line, bell nipple and fill u line. 8/01 /2008 Nipple down BOP stack and break down stack. Nipple up tree and test. Freeze protected well. Lay down 2-7/8" & 4"drill i e from derrick. Cleaned its and rockwasher. 00:00 00:45 0.75 0 0 COMPZ RPCOM NUND P Continue to nipple down flow line, bell ni le and fill u line. 00:45 01:45 1.00 0 0 COMPZ RPCOM RURD P Rig up 2-7/8" handling equipment. Sim ops, cleaning pits, kick top of beaver slide out to gain access to cellar with fork lift. 01:45 02:30 0.75 0 0 COMPZ RPCOM PULD P Lay down 2-7/8"drill pipe from derrick. Sim ops nipple down stack and cleanin its. 02:30 03:30 1.00 0 0 COMPZ RPCOM RURD P Pull mouse hole to move BOP stack to ground using bridge cranes. Nipple down riser and move stack. Cleaning its. 03:30 04:30 1.00 0 0 COMPZ RPCOM PULD P Replace mouse hole and lay down 2-7/8"drill pipe. Break stack apart for ins ection. 04:30 06:00 1.50 0 0 COMPZ RPCOM RURD NP Rig down 2-7/8" doub-e stack tongs due to leaking seals. Rig up power ton sand backu ton s. 06:00 09:30 3.50 0 0 COMPZ RPCOM RURD P Continue breaking down stack and cleanin its. 09:30 10:00 0.50 0 0 COMPZ RPCOM NUND P Nipple up tree per Drill Site Operator and Cameron rep. Pressure test tree to 5000 psi. Pressure held. Continue cleanin its. E~a€te 29 crt 3D Time Lis _ __ Date From To Dur S. Depth E. De th Ph se Code Subcode T Comment 10:00 10:45 0.75 0 0 COMPZ RPCOM PULD T Repair GBRs double stack tongs 10:45 12:00 1.25 0 0 COMPZ RPCOM PULD P Lay down 2-7/8" drill pipe from derrick. Continue cleanin its. 12:00 12:30 0.50 0 0 COMPZ RPCOM FRZP P Pull two way check valve and open SSSV with 6200 psi on control line. Continue cleanin its. 12:30 14:30 2.00 0 0 COMPZ RPCOM PULD P Lay down 2-7/8"drill pipe from derrick. 14:30 17:45 3.25 0 0 COMPZ RPCOM FRZP P Freeze protect well with 90 bbls of diesel. Diesel in place at 16:15, u-tube for 1.5 hours. Sim ops laying down 2-7/8"drill i e. 17:45 18:45 1.00 0 0 COMPZ RPCOM RURD P Set back pressure valve. 18:45 20:00 1.25 0 0 COMPZ RPCOM PULD P Lay down 2-7/8"drill pipe from derrick. 20:00 20:30 0.50 0 0 COMPZ RPCOM RURD P Rig down 2-7/8" handling tools 20:30 00:00 3.50 0 0 COMPZ RPCOM PULD P Lay down 4"drill pipe from derrick. 8/02/2008 Lay down 4"drill pipe, clean pits, rockwasher and cuttings bin. Rig Released at 02:00 (adjusted for 3 hours of ri maintenance com leted before actual release at 05:00 . 00:00 02:45 2.75 0 0 COMPZ RPCOM PULD P Lay down 4"drill pipe from derrick. 02:45 05:00 2.25 0 0 COMPZ RPCOM RURD P Finish cleaning pits, rock washer and cuttin s bin. Ri released. E~~s~e 3Ct cif 3Q • ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3C Pad 3C-15A 50-029-21426-01 DEFINITIVE • ConocoPhillip~ or its affiliates Definitive Survey Report Company.: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: W~113C-15 ~ Project: Kuparuk River Unit ND Reference: 3C-15A @ 84.66ft (Doyan 15) Site: Kuparuk 3C Pad MD Reference: 3C-15A @ 84.66ft{Doyosl 15) Well: 3C-15 North Ftefei•ence: Tree Wellbore: 3C-15A Survey Calculation Method: Minimum Curvature Design: 3C-15A Databaese: . ECM Alaska-Prod v16 Project Kuparuk River Unit _. , Map System: US State Plane 1927 (Exact solution). Systesn Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUSj Using Well Reference Pvint " Map Zone: Alaska Zone 04 Using. geodetic scale factor Well 3C-15 Well Position +N/-S 0.00 ft Northing:. 5,995,238.66ft Latitude: 70° 23' 53.084 N +E/-W 0.00 ft Easting: 528,333.07ft Longitude: 149° 46' 9.956 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 47.70ft -; i We!!hcire 3C-15A _ ~ ~'~9~,7 i~:ic5 PJlode! Name Sam ple Uate Dec: ination Dip ~~r?g!e Field Stren i gi? , BC3GM2GG7 7ii12008 1 r'.~o . ° jy 57,^9p ~' - - - __ - ;.::Design - 3C-15A ~ ~,I A F ~ !_ N~~tes: j `/e„sior:~ i 1.0 Rh ase: ACTUAL Ii i (3n Depth: 2,6`/9•" c' `~ec~ un- De pti~ Frcm (TVD) +N(--1~ +Ic/-1Pv Direction ~ (ftl (ft}) ( :~1 t°) ~0 96 Q0~ 0.0 ~ 346 (iu S~rtiey ~~-ogran~ Date ~ To ,tj ((t) Survey(Wellbo re) Tool Nar-ne Je~,cription ~urv~y D~t~ 99.66 .2,699.66 3C-15 (3C-15) GCT-MS SckJumbergea GCT multishot 1/12/2001 1: 2,749.00 9,290.10 3C-15A MWD+SAG+CA+II FR+MS (3C- 1 MWD+IFER-AK-CAZ-SC MVAID+IFR AK CAZ SCC- - -- -7/5/2008 12:J Survey Map Map Vertical ~ MD Inc Azi TVD TVDSS +N/-S +E/-W Northin 9 Fasting DLS Section ft ( ) (°) ft (°) ( ) ft ( ) ft ( ) ft ( ) ft ( ) ft ( ) °/100' ( ) ft ( ) Survey Tool Name I 3696 0.00 0.00 36.96 -47.70 0.00 O.G~D 5,995,238.66• 528,333.07 .0.00. 0.00 UEJDEFINED 99.66 0.07 337.58 99.66 15.00 0.04 -O.Oa1 5,995,238.70 528,333.06 0.11 0.04 GCT-MS (1) 199.66 0.18 76.84 199.66 115.00 0.13 0.1:;? 5,995,238.79 328,333.18 0.20 0.10 GCT-MS (1) 299.66 0.32 85.57 299.66 215.00 0.18 0.5i~ 5,995,238.85 528,333.62 0.14 0.05 GCT-MS (1) 399:66 0.37 110:87 399.66 315.00 0.09 1.1,3- 5,995,238.76 528,334.20. - 0.16. -0.18 GCT-M$ (1) 499.66 0.27 121.70 499.66 415.00 -0.15 1.~ 5,995,238.52 528,334.70. 0.12 -0.54- .GCT-MS (1} 599.66 0.23 94.40 599.65 514.99 -0.29 2.Q;3 5,995,238.38 528,335.10 0.12 -0.77 GCT-MS (1) 699.66 0.32 139.18 699.65 614.99 -0.51 2.4"-~I 5,995;238.16 528,335.48 0.23 -1.08 GCT-MS (1) 799.66 0.35 163.16 '799.65 714.99 -1.02 2.68 5,995;237.65 528,335.76 0.14 -1.64 GCT-MS (1) ~ 899.66 0.37 172.97 899.65 814.99 -1.63 2:ffs'3 5,995;237:04 528;335.89 0.06 -2.26 GCT-MS (1) I 999:66 0.43 199.86 999.65 914.99 -2.30 2.7~ 5,995,236.37 528,335.80 0.19 -2.89 GCT-MS (1) 1,099.66 0.48 216.94 1,099.64 1,014.98- -2.99 2.~4 5,995,235.68 528;335.42 0.14 -3:47 GCT-MS (1) 1,199.66 0.45 229.74 1,199.64 1,114.98 -3:58 1.T?~ 5,995;235.09 528,334.88 0.11 -3:91 GCT-MS(1) 8/5/2008 11:12:33AM Page 2 COMPASS 2003.16 Burld 42F ~ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: We113C-15 Project: Kuparuk River Unit TVD Reference: 3C-15A @ 84.66f;t (Doyon 15) Site: Kuparuk 3C Pad MD Reference: 3C-15A @ 84.66ft (Doyon 15) Well: 3C-15 North Reference: True Wellbore: 3C-15A Survey Calculation NSethod: Minimum Curvature Design: 3C-15A Database: EDM Alaska Prod v16 Survey ....Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) {°/'1D0') (ft) Survey Tool Naume '1,299.66 0:23 . 234-91 1,299.64 1,214.98 -3.95 1.33 5,995,234.72 528,334.41 0.22 -4.15 GCT-MS (1) 1,399.66 .0.32 180.10 1,399.64 1,314.98 -4.34 1.16 5,995,234.32 528,334:25 0.27 -4.50 GCT-MS (1) 1,499.66 0.88 174.60 1,499.63 1,414.97 -5.39 1.24 5,995,233.28 528,334.33 0.56 -5.53 GCT-MS (1) 1,599.66 1.18 171.30 1,599.62 1,514.96 -7.17 1.46 5,995,23t5t~ .528,334.56 0.31 -7.31 .GCT-MS (1) 1,699.66 1.23 158.54 1,699.59 1,614.93 -9.19 2-01 5,995,229.4&3 528;335.12 0.27 -9.40 GCT-MS (1) ?,799.66 1.23 158.04 1,799.57 1,714.91 -11.18 2.81 5,995,27.7.49 52$,335.92 0.01 -11.53 GC r-M5 (1) 1,899:66 1.25 1.50:57 1,899.55 1,814.89 -13.53 3.74 5,995,225.55 528,336.86 0.16 -"3.64 GCT-MS (i) 1,999.66 1.68 132.31 1,999.52 1,9`4.86 -i5.C6 5.36 5,995,223.62 528,338.49 0.63 -15.91 GGT-i':AS (1) 2,099.66 1.97 134.40 2,099.46 `2,014.30 -17.25 7.68 5,995,221.44} 528,346.81 0.30 -ifs.60 GCT-MS i1) x,199.66 1.68 135.43 2,199.41 2,114.75 -19.50 9.93 5,995,2192 528,343.07 0.29 -21.32 GCT-MS (1) 2,299.66 1.88 122.74 2,299-37 2,214.71 -21.43 12.34 5,995,217.28 528,345.49 0.44 -23.78 GCT-MS (1) 2;399.66 247 125.39 2,399.29 2,314.63 -23.57 15.48 5;995,215.16 528,348.63 0.60 -26.61 GCT-MS (1) 2,499.66 5.42 16772 2,499.66 2,414.40 -29.43 18.24 5,995,209-3® 628,351.42 3.96 -'12.97 G6T-MS (11 2,599.66 8.40 162.12 2,598.21 2,513.55 -42.67 20.79 5,995;196.6 528,354.01 3.98 45.85 GCT-MS (ii 2_,699.66 13,45 169.74 2,69$.21 2,611.55 -61 54 24.70 5,995,17722 528,357.(0 4.05 -fi5:62 :~',?-MS (1) 2.,749.00 14-99 173.98 2,744A° • 2,659.37 -73 53 '%6.119 5,995,1652 528,359.44 3.77 -7'1.66. M'v'JD+fFR-Ar CA.a^:-5~~: t2) 2,402.83 17.17 180.80 _,-"'~.~6 2,711.16 -88.41 26-71 5,995,150.371 528,360.11 5.35 -224 ~nWD+l~=R-AK-Ctsr-;>C(2) 2,847.64 172.6 186.07 2,838.57 2,753.9'1 -101.63 25:92 5,995,137-143 528,359.37 3.49 -54.88 MV~JD+;FR-Ah C..~-C!~ (2j 2,866.19 17.83 188.2'1 2,85625 2,771.59 -107.18 25.22 5,995,131.59 528,358.69 4.64 -11.09 h9WD'~IFR-AK-CAS-SG (2j 2,902.23 18.79 192.16 2,890.47 2,805.81 -118.31 23.21 5,995,120.455 528,356.72 4.35 -120.41 MVJG+iFR-AK-CAS-SC (2) 2,932.01 18.99. 195.29 2,919.21 2,834.55 -127.86 20.67 5,995,110.89 528,354.43 3.40 -129.12 MWD+IFR-AK-CAF SC (2) 2;960:92 19.20 198.14 2,945.97 2,861.31 -136.73 18.21 5,995,102.0'@ 528,351.80 3.38 -137.08 MWD+IFR-AK-GAS'-SC (2) 2,991.61 19.39 201.14 2,974.93 2,890.27 -146.28 14.80 5,995,092.451 .528,348.42 3.29 -145.51 MWD+IFR-AK-CA~°-SC (2) 3,027.43 20.06 204.49 3,008.65. 2,923.99 -157.42 10.11 5,995,081.29 528,343.77 3.70 -155.19 MWD+IFR-AK-CAS SC (2) 3,057.12 21.86 203.50 3,036.37 2,951.71 -167.13 5.79 5,995,07L5~ 528,339.49 6.11 -1F,;3.57 MWD+IFR-AK-CAS SC (2) 3,083.75 23.44 205.59 3,060.95 2,976.29 -176.45 1.53 5,995,062.235 528,335.26 fi.66 -171.58 MWD+IFR-AK-CAZ SC (2) 3,113.94 24.11 211.00 3,088-58 3,003.92 -187.16 -4.24 5,995,051.514 528,329.54 7.55 -15;:0.57 MWD+IFR-AK-CAS SC (2) 3,149.40 24.52 215.01 3,120.90 3,036.24 -199.39 -12.20 5,995,039.245 528,321.63 4.80 -10.52 MWD+IFR-AK-CAS SC (2) 3,193.62 26.11 214.98 3,160.87 3,076.21 -214.88 -23.04 5,995,023.79 528,310.85 3.60 -2®2.92 MWD+IFR-AK-CAZ-SC (2) 3,244.77 28.62 214.50 3,206.29 3,121.63 -234.20 -36.43 5,995,004.345 528,297.53 4.93. -2'Ffi.43 MWD+IFR-AK-GAZ SC (2) 3,293.20. 30.17 214.58 3,248.48 3,163.82 -253.78 -49.91 5,994,984.72 528,284.13. 3.20 -23'4.17. MWD+IFR-AK-CAS SC (2) 3,338.29 30.38 214.29 3,287.42 3,202.76 -272.53 -62.76 5,994,965.92 528,271.34 0.57 -249.25 MWD+IFR-AK-CAS-SC (2) 3,383.15 32.11 217.45 3,325.78 3,241.12 -291.37 -76.41 5,994,947.035 528,257.78.. . 5.31_ -264.23 MWD+IFR-AK-CAS'.-SC (2) 3,432.36. 33.56 222.07 3,367.13 3,282.47 -311.85 -93.48 5,994,926.483 528,240.78 5.88 -27J.98 MWD+IFR-AK-CAS-SC (2) 3,476.60 35.75 222.22 3,403.52 3,318.86 -330.51 -110.36 5,994,907.7P 528,223.98 4.95 -203,99 MWD+IFR-AK-CAS SC (2) 3,527.71 37.54 222.62 3,444.53 3,359.87 -353.02 -130.94 5,994,885.183 528,203.49 3.53 -310.86 ' MWD+IFR-AK-CA2'-SC (2) 3,575.12 38.91 223.62 3,481.77 3,397.11 -374.43 -150.99 5,994,863.76) 528,183.52 3.17 -32fi.78 MWD+IFR-AK-CAS.-SC (2) 3,619.91 40.73 227.18 3,516.18 3,431.52 -394.55 -171.42 5,994,843.50) 528,163.17 6.51 -341.36 MWD+IFR-AK-CAZ'-SC (2) 3,667.47 41.91 227.73 3,551.90 3,467.24 -415.78 -194.55 5,994,822.181 528,140.12 2.60 -356.36 MWD+IFR-AK-CA2'-SC (2) 3,714.81 42.19 229.65 3,587.05 3,502.39 -436.71 -218.37 5,994,801.1 528,116.38 2.78. -370.91'. MWD+IFR-AK-CAS SC (2) 8/5/2008 11:12:33AM Page 3 COMPASS 2003.16 Build 42F •ConocoPhillips or its affiliates • Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Project; Kuparuk River Unit Site: Kuparuk 3C Pad Well: 3C-15 Wellbore: 3C-15A Design: 3C-15A .Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well ~-15 3C-15~ @ 84.66ft (Doyon 15) 3C-15~A @ 84.66ft (Doyon 15) True Minim:~m Curvature EDM Alaska Prod v16 Survey Map Map MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Fasting (ft) (~) (°) (ft) (ft) (ft) (ft) (ft) (ft) 3,764.12 41.87 233.13 3,623.68 3,539.02 - -457.31 -244.15 5,594,780.48 528,090.68 3,809.05 41:78 234.79 3,657.17 3,572.51 -474.93 -268.37. 5,994,762.76 528,066.52 .3,855:59 41.73 239.13 3,691.90 3,607.24 -491.82 -294.34 5,994,745.78 528,040.63 3,903.43 41:93 241.26 3,727.55 3,642.89 -507.67 -322.02. 5,994,729.82 528,013.01 3,948.38 42.22 245.27 3,760.92 3,676.26 -521.21 -348.91 5,994,716.18 527,986.17 3,997.16 42.49 247.98 3,796.97 3,712.31 -534.25 -379:07 5,994,703.03 527,956.06 4,042.39 42.02 250.62 3,830.45 3,745.79 -545.00 -407.52 5,994,692.17 527,927.66 4,091.77 40.60 254.33 3,867.55 3,782.89 -554.83 -433.58 5,994,682.23 527,896.64 4,137.53 41.17 257.04 3,902.15 3,817.49 -562.23 -467.60 5,394,674.??_ 527,867.65 4;186.16 42.78 260.52 3,938.30 3,853.64 -568.54 -49S.50 5,994,668.29 527,835.78 4,227.32 43.77 264.51 3,968.28 3,883.62 -572.20 -527.46 5,994;664.52 527;807.84 4,280.31 44.89 266.14 4,006,18 3,921.52 -575.22 -564:36 5,994,661.37 527,770.95 4,317.33 45;46 269.64 4,032.28 3,947.62 -576.18 -590.59 5,994,660'-0 527,74472 4,;175.11 .45.58 215.00 4,072.78 3,988.12 -574.51 -631.76 5:994,661.82 527;703.56 4,4X.70 46.12 279.55 4, 104.55 4,019.89 -570.36 -664.19 5,994,o6S.84 527;671.17. 4,469.44 45.''1 283.55 4,138.49 4,053.83 -563.37 -698.45 5;994,672.71 527,636.83 'x,511.46 46.89 234.39 4,167.55 4,082.89 -556.64 -727.96 5,994,F,79.92 527,607.3`' 4,563.85 49.08 284.80 4,202.6°: 4,117.95 -546.23 -765.57 5,994,689.5£- 527,569.66 4.609.57 50.87 286.99 4,232.02 4,147.36 -535.63 -799.23 5,994,699.06 527,535.96 4,657.98 53.04 287.82 4,261.85 4,177.19 -525.22 -835.60 5,994,710.32. 527,499.55 4,704.70 53.64 290.54 4,289.75 4,205.09 -512.91 -871.00 5,994,722.50 527,464.11 4,752.98 54.38 293.01 4,318.12 4,233.46 -498.42 -907.27 5,994,736.86 527,427.79 4,801.22 55.88 293.40 4,345.70 4,261.04 -482.82 -943.64 5,994,752.31 527,391.36 4,845.51 57.97 294.71 .4,369:87 4,285.21 -467.69 -977.53 5,994,767.31 527,357.42 4,895.42 58.58 296.94 4,396.12 4,311.46 -449.20 -1,015.73 .5,994,785.66 527,319.15 4,939.74 58.91 298.86 4,419.12 4,334:46 -431.47 -1,049.21 5,994,803.26 527,285.60 4,985.25 59.14 300.68 4,442.54 4,357.88 -412.09 -1,083.08 5,994,822.50 527,251.66 5,034.98 58.96 304.69 4,468.12 4,383.46 -389.07 -1,118.97 5,994,845.39 527,215.70 5,085.48 59.64 308.57 4,493.91 4;409:25 -363.17 -1,153.80 5,994,871.16 527,180.77 5,129.65 61.82 310.32 4,515.51 4,430.85 -338.68. -1,183.55 5,994,895.52 527,150.93 5,175.36 62.94 311.44 4,536.70 4,452.04 -312.18. -1,214.17 5,994,921.91 527,120.21 5,224.01 64.16 311.01 4,558.37 4,473.71 -283.47 -1,246.93 5,994,950.49 527,087:35 5,270.54 65.49 313.26 4,578.16 4,493.50 - -255.22.. -.1,278.15 .5,994,978.62 527,056.02 5,318.27 65.19 313.39 :4,598.08 4,513.42 -225.46 -1,309.70 5,995,008.26 527,024:36 5,365.89 64.92 313.74 4,618.16 4,533.50 -195.70 -1,340.99 5,995,037,89 526,992.96 5,412.57 64.69 313:89 4,638.03 4,553.37 -166.46 -1,371.47 5,995,067.02 526,962.38 5,459.77 64.73 313.02 4,658.20 .4,573.54 -137.11 -1,402.45 5,995,096.25 526,931.29 5,507.05. 66.69 312.37 4,677,65 4,592..99 -107.89 -1,434.12 5,995,125.35 526,899.51 5,556.86 66.79 310.67 4,697.32 4,612.66 -77.56 -1,468.38 5,995;155.55 526,865:14 5,601.62 67:51 309.36 4,714:70 4,630.04 -51.04 -1,499.97 5,995,181.94 526;833.45 Vertical BLS Section (°/~ 00') (ft) Survey Tool Name 4.77 -384.66 MWD+IFR-AK-CAZ-SC (2) 2.48 -395.90 MWD+IFR-AK-CAZ-SC (2) 6.21 -406.00 MWD+IFR-AK-CAZ-SC (2) 3.00 -414.69 MWD+IFR-AK-CAZ-SC (2) i 6.01 -421.32 MWD+IFR-AK-CAZ-SC (2) 3.78 -426.67 MWD+IFR-AK-CAZ-SC (2) 4.06 -430.22 MWD+IFR-AK-CAZ-SC (2) 5.73 -432.24 i MlriVD+IFR-AK-CAZ-SC (2} 4.07 -432.40 ^.1V°s3~'D~IFR-AK-CAZ-SC (2) I i 5.82 -430.81 t MWD+IFR-AK-s'r~Z-SC (2) 7.07 -427.60 MWD+IFR-AK-CAZ-SC (2) ~ 3.01 -421.60 MWD+IFR-AK-CAZ-SC (2) 6.88 -416.19 M{lS/D+IFR-AK-CP.Z-SG(2i ,6.62 -?04.61 M1r@JD+iFR-AK-CAZ-SC (2; 7,26 -392.74 ML'a'D+IFR-AK-CA7-S~~ (2) 5.98 -377.66 M4~U+IFR-AK-CAZ-:SC «) ~~ 3.37 -363.42 I4EWD+±;=R-ABC-Cr~7-Si; (2) ~, 4:22 -344.79 MWU+IFR-AK;;A7_-~? ;2; 5.36 -327.34 ~hWD+IFR-AK=CAZ-SC (2) ' 4.68 -307.47 MWD+IFrz-AK-CAZ-SC (2) 4.84 -286.96 MWD+IFR-AK-CAZ-SC (2) 4.41 -264.12 MWD+IFR-AK-CAZ-SC (2) 3.18 -240.19 ~~ MWD+IFR-AK-CAZ-SC (2) i 5.33 -217.31 MWD+IFR-AK-CAZ-SC (2) ~ 3.99 -190.12 MWD+IFR-AK-CAZ-SC (2) 3.78 -164.82 MWD+IFR-AK-CAZ-SC (2) 3.47 -137.83 MWD+IFR-AK-CAZ-SC (2) 6.92 -106.81 MWD+IFR-AK-CAZ-SC (2) 6.74 -73.25 MWD+IFR-AK-CAZ-SC (2) 6.03 -42.30 MWD+IFR-AK-CAZ-SC (2) 3.27 -9.17 MWD+IFR-AK-CAZ-SC (2) 2.63 26.61 MWD+IFR-AK-CAZ-SC (2) 5.23 61.57 MWD+IFR-AK-CAZ-SC (2) 0.68 98.08 .MWD+IFR-AK-CAZ-SC (2) 0.87 134.53 MWD+IFR-AK-CAZ-SC (2) 0.57 170.27. MWD+IFR-AK-CAZ-SC (2) 1..67 206.25 MWD+IFR-AK-CAZ-SC (2) 4.33 242.26 MWD+IFR-AK-CAZ-SC (2) 3:14 279.98 MWD+IFR-AK-CAZ-SC (2} 3.14. 313.36 MWD+IFR-AK-CAZ-SC {2) L 8/5/2008 11:12:33AM Page 4 COMPASS 2003.16 Build 42F •ConocoPhillips or its affiliates • Definitive Survey Report Company: ConocoPhillips(Alaska) Inc Project: Kuparuk River Unit Site: Kuparuk 3C Pad Well: 3C-15 Wel lbore: 3C-15A Desi n• 3C-15A 9 Survey MD Inc (ft) (~) 5,648.68 67.38 5,696.14 67.49 5,745.50 68.87 5,790.59 68.64 5,836.81 68.31 ~i,?,80.62 68.22 1 5,935.58 67.71 5,980.38 67.';0 6,027.35 67.20 5,074.04 °6.97 ~ 6,120.34 66.65 6,167.95 56.33 6,21=g.~7 .5 95 '~ 5,26228 65.'?0 ~, 119.65 65.58 t.3s--5.79 E5.30 1:~.: '_6.58 6,451.'11 66.78 6,498.29 6u 81 6,545.99 06.51 6,591.78 66.52 6,637.89 66.87 6,686.68 66.68 6,734.18 66.38 6,781.47 65.92 6,828:88 66.47 6,922..89 67.26 7;017,52 66.67. 7,111.79 66.04 7,207.11 65.87 7,300.31- .67:34 ..7;395.97 66.38 7,488.58.. 68.18 7,584.27 69.38 7,678.77 68.99 7,772.67 68.78 7,866.95 68.59 7, 961.62:68.24 8,010..03 67.55 8, 056.20:65.19 Azi TVD TVDSS +N/-S (°) (ft) (ft) (ft) .310.83 4,732.75 .4,648.09 -23.05 309.35 4,750.96 4,666:30 5.18 305.96 4,769.31 4,684.65 33.16 307.41 4,785.65 4,700.99 58.26 307.46 4,802.61 4,717.95 84.40 307.5E 4,1,18.84 4,734.18 109.18 308.G~(3 4,839.46 4,754.80 140.42 308.4~i 4,856.52 4,771.86 166.06 308.07 4,874.61 4,789.95. 192.39 307.75 4,92.79 4,808.13 219.31 307.07 4,911.02 4,826.36 245.17 306.87 4,930:02 4,845.36 271.42 30628 4,943.87 4,864.2 i 296.33 306-82 4,96°.41 4,883.75 3:_7.75 :305.82 4,::'87.95 4;90329 348.32 30620 5.007.'12 4,922.46 37?_,98 367.35 S,Q2619 4,94153 398.55 307.40 5,045.65 4.960.99 425.95 307.64 5,064.00-,979.34 452.62 307.83 5,082.90 4,998.24 478.83 308.17 5,101.15 5,016.49 504.68 310.07 5,119.39 5,034.73 531.40 309.95 5,138.63 5,053.97 560.23 309.89 5,157.55 5,072.89 588.19 309.31 5,176.67 5,092.01 615.76 310.00 5,195.81 5,111.15 ' 643.44 31.0.86 5,232.74 5,148.08 699.50 311.53 5,269.77 5,185.11 756.86 311.13 5,307.58 5,222.92 813.89 311.59 5,346.42 5,261.76 871.41 312.32 5,383.42 5,298.76 928.59.. .311.71 5.,421.02 5,336.36 987.47 311.10 5,456.78 5,372.12 1,043.96 307.76 5,491.43 5,406.77 .1,100.60: 307.70 5,525.01 5,440.35 1,154.65 307.68 5,558.83 5,474.17 1,208.21 308.15 5,593.10 5,508.44 1,262.18 308.22 5,627.93 .5,543.27 1,316.60- 308.42 5,646.15 5,561:49 1,344.41 307.95 5,664.65 5,579.99 1,370.56 Local Co-ordinate Reference:. Well 3C-15 TVD Reference: 3C-15A @ 84.66ft (iDoyon 15) MD Reference: 3C-15A @ 84.66ft (®oyon 15) North Reference: True Survey Calculation Method:. .Minimum Curvature Database: ' EDM Alaska Prod v"I6 Map Map Vertica9 i . I +E!-W Northing Fasting DLS Section (ft) _(ft) (ft) ('/100') (ft) Survey Tool Narrne -1,533.22 5,995,209.80. 526,800.10. 2.90 348.6 MWD+IFR-AK-CAZ-SC (2) -1,56675 5,995,237.90 526,766.47 2.89 384_'05 MWD+IFR-AK-CAc~-SC (2) -1,603.02 5,995,265.74 526,730.09 6.96 419.8 MWD+IFR-AK-CAZ-SC (2) -1,636.72 5,995,290.71 526,696.30 3.04 452.?19 MWD+IFR-AK-CAZ-SC (2) -1,670.86 5,995,316.72 526,6fi2.06 0.72 486_'11 MWD+IFR-AK-CAZ-SC (2) -',703.15 5,995,341.37 526,629.69 0.28 517_C6 MWD+IFR-AK-CAZ~SC (21 f -1,743.39 5,995,372.45 526,589.33 1.30 553_C1 A-1WD+FR„4K-CAS-SG (2) -1,775.92 5,995.397.97 526,556.71 6.31 SaQ~6 t~1WD+IFR--AY.-C,^~-S:",(<) -1,809.97 5,995,424.67 526,522.57 0.92 625_hJ3 MWD+IFR-A{-CA:s=-SL; '2) , -1.843.90 5,995,450.96 526,488.54 0.80 6fi8.38 A MVVD'IFR-AID ~_A.7-SC (2) i -1;877.70 5,995,476.68 526,454.64 1.52 692.114 MWD+IFR-AK-CAZ-SC (2) ~ -1,912.58 5,995,502.80 526,419.66 0.77 726.D6 MWD+IFR-AK-CAZ-SC (2_) -1,946.82 5,995,528.08 525,385.33 1.40 758..39 MWD+IFP,-AK~-CAZ.-SG r~) -1,981.79 5,995,553.86 526.3.50.27 1.17. 792.60 M1NP ~Fl-l.s-CRS--`~;?~; i -2,016.55 5,995,579.29 526,315.40 1.94 825:.2 r,A1:JD+,F;~-cK,`2A~-St (7_) -2,050_SC 5,995;603.83 526,2$1.37 0.96 B57.W7 iv4\V";-1tR-A;~A,~-SQ(L) -2,084.70 .5;995,629.26 5L6,247.08 3.54 891 ?~4 ~:iW'~+IFR-AK-CAi?°SC (2; 1 -2,120.58 5,995,S5S.53 526,211.10 0.42 92':,.31 MWD~IFR-AY.--Cf~-SC!2~ j -2,154.53 5,995,682.47 526,177.05 0.48 Sr59.£~2 MWD+IFR-F ~: CAZ-S~, (2) i I -2,1x9.17 5,995,709.14 526,142.32 0.73 994.21 MWD+IFR-AK-CAS SC (2) -2,22228 5,995,734.87 526,109.13. 0.68 1,027.331 MWD+IFR-AK-GAZ-SC (Z) !i -2,255-11 5,995,761.46 526,076.18 3.86 1,061-.138 MWD+IFR-AK-CAZ-SC (2) -2,289.46 5,995,790.15 526,041.73 0.45 1,097.4k6 MWD+iFR-A':-CA.2~-Si. (2) -2,322-87 5,995,817.98 526,008.22. 0.64 1,132.617 MWD+IFR-AK-CAF SC (2) -2,35620 5,995,845:42 525,974:79 1.48 1,167.418 MWD+IFR-AK-CAFSC (2) -2,389.59 5,995,872.97 525,941.29 1.77 1,202.4L2 .MWD+IFR-AK-CAFSC (2) -2,455-39 5,995,928.78. 525,875.28 1.19 1,272.7°-4 I -MWD+IFR-AK-CAFSC (2) . -2,520-J2 5,995,985:88 525,809.55 0.90 .1,344.24 MWD+IFR-AK-CAZ-SC (2) -2,585.77 5,996,042:66 .525,744.49.. 0.77 1,415.2b MWD+IFR-AK-CAFSC (2) -2,651.11 5,996,099.92 525,678.94 0.48' .1,486.8#9 MWD+IFR-AK-CAFSC (2) -2,714-71 5,996,156.86 525,615.13. 1.73 1,557.7fi MWD+IFR-AK-CAZ-SC (2) -2,780.07 5,996,215.49 525,549:56 1.16 1,630.7A MWD+IFR-AK-CAZ-SC (2) -2,844.14 5,996,271.73_ 525;485.28 .:..:.2.04. 1,701.031 ' MWD+IFR-AK-CAS-SC (2) -2,913.03 5,996,328.10 525,416,18 3.49 1,772.En3 MWD+IFR-AK-CAZ-SC(2) -2,982.89 5,996,381.88 525,346:12 0.42 1,841.8 MWD+IFR-AK-CAZ-SC (2) -3,052.21 5,996,435:17 525;276.61 0.22 1,910.7`1 MWD+IFR-AK-CAZ-SC'(2) ~' : -3,121.50 5,996;488.87 525,207.12: 0.51 1,979.8I3 E MWD+IFR-AK-CAZ-SC (2) i ( -3,190.69 5,996,543.02. 525,137.72 0.38.: 2;049.3; MWD+IFR-AK-GAL-SG (2) ~. -3,225.88 5,996,570.70 525,102.43 1.48 2,084.8x'9-. MWD+IFR-AK-CAZ-SG (2) I~ -3,259.13 .5.,996,596.72 525,069.09 5.20 2,118.3;D MWD+IFR-AK-CAZ-SC (2) f 8/5/2008 11:12:33AM Page 5 COMPASS 2003.16 Build 42F ~ConocoPhillips or its affiliates • Definitive Survey Report Company: GonocoPhillips(Alaska) Inc. Local Co-ordinate Reference: WelI3C-15 Project: Kuparuk River Unit TVD Reference:- 3C-15A @ 84.66ft (Doyon 15) Site: Kuparuk 3C Pad MD Reference: 3C-15A @ 84.66ft (Doyon 15) .Well: 3C-15 North Reference: True Wellbore: 3C-15A Survey Calculation Method: Minimum Curvature Design: 3C-15A Database: EDM Alaska Prod v16 Survey - - - ~ , Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-5N Northing Fasting DLS Section (ft) (~) (°) (ft) (ft) (ft) (ft~ (ft) (ft) - (°/100') (ft) Survey Tool Name 8,086,23 63.62 307.41 5,677.63 .5,592.97 1,387.11 -3,280.56 5,996,613.19. 525.,047.60 5.47. .2,139.55 MWD+IFR-AK-CAS-SC (2) 8,118.24 61.91 307.53 5,692.27 5,607.61 .1,404.43 -3,3®3:15 5,996,630:42. 525,024.95 5.35 2,161.81 MWD+IFR-AK-CAS-SC (2) 8,150.23 . 61.00 307.29 5,707:56 5,622.90 1,421.50 -3,325.47 5,996,647.40 525,002.57 2.92 ,2,183.78 MWD+IFR-AK-CAS-SC (2) 8,183.20 58.22_ 307.02 .5,724.24 5,639.58. 1,438:67 -3,348.13 5,996,664.49 524,979.84 8.46. 2,205.93 MWD+IFR-AK-CAS-SC (2) 8,213.31: 56.40 306.72 5,740.50 5,655.84 1,453.88 -3,368.40 5,996,679.62 524,959.51 6.10 2,225.58 MWD+IFR-AK-CAS-SC (2) 8;245.08 54.33 307.15 5,758.56 5,673.90 1,469.58 -3,369.30 5,996,695.24 524,938.56 6.61 2,245.88 MWD+IFR-AK-CAS-SC (2) 8,275.42 51.90 307.15 5,776.76 5,692.10 1,484.24 -3,408.64 5,996,709.82 524,919.17 8.01 2,264.77 MWD+IFR-AK-CA.7L-SC (2) 8,307.49 49.70 306.94 5,797:03 5,712.37 1,499.21 -3,428.47 5,996,724.71 524,899.28 6.88 2,284.10 MWD+IFR-AK-CAS-SC (2) .8,339.16 47.32 305.97 5,818.01 5,733.35 1,513.31 -3,447.55 5,996,738.74 524,880.15 7.86 2,302.39 MWD+IFR-AK-CAS-SC (?) 8,371.62 44.89 306.36 5,840:52 5,755.86 1,527.11 -3,466.43 5,996,752.47 524,861.22 7.54 2,320.35 MWD+IFR-AK-CA.~!-SC (2) 8,401.44 42.63 307.08 5,862,05 5,777.39 1,539.44 -3,482.97 5,996,764.73 524,844.64 7.76 2,336.32 MWD+IFR-AK=CAc -SC (2) 8,434.34 39.83 308.09 5,886.79 5,802.13 1,552.66 -3,5©0.15 5,996,771.88 524,827.41 8.75 2,353.30 MWD+IFR-AK-CA?-SC !2) 8,480-48 36.15 308.65 5,923.15 5,838.49 1,57028 -3,522.42 5,996,795.42 524,805.08 8.01 2,375.78 MWD+IFR-AK-CAsZ-SC (2) 8,528.50 34.87 308.85 5,962.24 5,877.58 1,587.74 -3,544.17 5,996,812.79 524,783.26 2.68 2,397.99 MWD+IFR-AI<-Ct~-SC (2) 8,575.36 33.58 309.30 6,000.98 5,916.32 1,604.35 -3,564.63 5,996,829.32 .524,762.74 2.81 2,419.05 Iv1`4~'D+IFR-Ah: CArZ-SD ?,' 3,623.31 31.82 309.84 6,041.33 5,956.67 1,620.85 -3,584.60 5,996,845.75 524,742.71 372 2,439.89. M;"JD+IFR-AK.-CAz7-SC (2) I x,669.38 31.44 309.77 6,080.56 5,995.90 1,636.31 -3,6.073.16 5,996,861.14 524,724.09 0.83 2,459.3v P1`AJD+IFR-AK-CAS-SG (Z'. 8,709.11 32.53 310.08 5,114.26 6,029.60 1,649.82 -3,619.30 5,996,874.58 524,707.90 2.77 2,476.40 MWD+!FR-AK-CAS-SC (2) 8,782.74 32.42 31-0.25 6,176.37 6,091.71 1,675.32 -3,649.51 5,996,899.97 524,677.60 0.19 2,508.45 MWD+IFR-AK-CAS-SC (2? 8,804.67 32.81 310.06 6,194:84 6,110.18 1,682.94 -3,658.54 5,996,907.55 524,668.53 1.84 2,518.03 MWD+IFR-AK-CALF-SC (2) I 8,833.79 33.49 309.41 6,219.23 6,134.57 1,693.12 -3,670.79 5,996,917.68 .524,656.25 2.63 2,530.87 MWD+IFR-AK-CAS-SC (2) 8,877.81 33.49 309.18. 6,255.94 6,171.28 1,708.50 -3,689.59 5,996,932.99 524,637.40 0.29 .2,550.34 MWD+IFR-AK-CAS-SC (2) 8,924.57 35.28 310.37 6,294.53 6,209.87 1,725.A0 -3,7D9.88 5,996,949.81 524,617.04 4.09 2,571.65 MWD+IFR-AK-CAS-SC (2) 8,970.47 36.70 .309.79 6,331.66 6,247.00 1,742.76 -3,730:52 5,996,967.10 524,596.34. 3.18. 2,593.49 MWD+IFR-AK-CAZ-SC (2) 9,006:82 36.43 309.59 6;360.86 6,27620 1,756.59 -3,747.18 5,996,980:86 524,579.63 0.81 2,610.94 - MWD+IFR-AK-CAS-SC (2) 9,038:00 36.41 309.48' 6,385.95 6,301.29 1,768.38 -3,761.46 5,996,992.59 524,565.31 0.22 2,625.83 MWD+IFR-AK-CAS-SC (2) - 9,065.54 36.20 309.78 6,408:14 6,323.48 1,778.78 -3,774.02 5,997;002.94 524,552.71 1.00. ..2,638.96 MWD+IFR-AK-CAZ-SC (2) 9,101..04 35.29 309.68 6,436.95 6,352.29 1,792.03 -3,789.97 5,997,016.14 524,536.71 2.57 2,655.68 MWD+IFR-AK-CAS-SCj2) 9,132.63 35.11 310.10 6,462.77 6,378.11 1,803.71 -3,8®3.94 5,997,027:76 524;522.70 0.95 2,670.39 MWD+IFR-AK-CAS-SC (2) 9,160:36 34.88 310.13 6,485.48 6,400.82 1,813.96 -3,896.10 5,997;037:96 524,510.50 0.83 2,683.27 MWD+IFR-AK-CAvZ-SC (2) 9,194.52 35:28 .310.02 6,513.44 6,428:78 1,826.60- -3;831.12 5;997,050.54: `524,495.43 1.19_ 2,699.17 MWD+IFR-AK-CAS-SC (2) ` 9,226:25 36.03 309:76 6,539.22 6,454.56 1,838.46 -3,845.31 .,5,997,062.35 524;481.20 2.41 2;714,11 MWD+IFR-AK-CAS-SC (2) 9;253:.88- 36_82- -.310,88 6,561.45 . 6,476.79- 1,849.07 -3,857.82 .5,997;072.91 524;468.65 _ ....3.74. ..2,727.44 i MWD+IFR-AK-CAS-SC (2) 9,290.19 36.85 309.84 6,590.52 6,505.86. 1;863.17 -3,87.4.41 5,997,086:95 ..524,452.01 -.1.72 .2,745.13 . MWD+IFR-AK-GAS=SC (2) I 9,327.00 36.85 309.84 6,619.97 ~ 6,535.31 1,877.31 -3,891.36 5;997,701.02 ; 524;435.01 ~ -0.00 2,762.95 PROJECTED to T 8/5/2008 11:12:33AM Page 6 COMPASS 2003.1 ~ Build 42F ~~ ~ KUP i ' • 3C-15A CQnaCC hilli s / P ~ Well Attributes ESIac1~. wNllwre API/UWI FiuIJ Ilamc ~' LYell Slalua Inulinalwn T) MD (hKal Tuiai liep[h (hie6) 500292142601 KUPARUK RIVER UNIT i (PROD 69.38 7,584.28 9,327.0 Comment H2S (ppm) Date _ Annotation End Date KB-Grd (R) Rig Release Date - TRDP 100 7/112008 LastWO~~ 37.30 8/1/2008 ~~, r<„~o~..: ,.: ~.,i __Annotation DepM (flKB) End Date Annotation ,End Date ~ Last Taq: 8.944.0 ~ 9/9/2008 Rev Reason: GLV C/O, FRAC, FCO, TAG, PULL FRAC SLV ~ 911712008 Casing Strings - - I HANGER, 37 ~, .. .., .. .. .. ~ ~ ~'. u~ .. CONDUCTOR, 0.118 sssv, GAS LIFT, 2,511 SURFACE, 0.3,807 GAS UFT, 3,868 GA8 LIFT, s,445 s trz amr rop, 2,506 GA8 LIFT, 7,277 TUBING, 7,264 PRODUCTION, a7,e2s GA8 LIFT NIPPLE, 8,405 E) LOCATOR,. 8,482 CC LOCATOR, 8,482 SEAL ASSV, 8,483 I i 72 Ilner ahce back, 5,500 LINER TOP, 2,526A, 725 IPERF, 9,038-9,058 SarM Frac, ~~ 9,038 - amg Deaenptton Mrln. ; t y 1 .. Tup (nRB) ~ JCI Utpih (K.. Jel ueplb ITY6) (iL.. Jlnuy ... slue... SUtny lop I brd CONDUCTOR 16 I._ 062 0.0 116.0 116.0 62.50 H-40 Casing Description Strip. Yung 1.. Top (RNB) Set Depth (R.. Set Depth (ND) (R... String ... Strip... String Top ihrd `SURFACE 95/8 8.765 0.0 3,841.0 3,681.0 36.00 J-55 Casing DescNption Strip... String I... Top (RKB) Set Depth (R.. Set DepM (ND) (R.. 'String ... StNn... String Top Thrd PRODUCTION 7 6.151 0.0 7,826.0 5,578.3 26.00 J-55 Casing Description Strip... String 1... Top (RKB) Set Depth (ft... Set Depth (ND) (ft... String .. Strip... String Top Thrd ILINER TOP .5V2 4.950 2.5258 R?25A 8127] 15.Fq L->s0 14yAri1511 Liner Details Top {tiKU) Item Uesunytron uomment ID (In) 2,525.8 PACKER Baker "CPH" 5.5" x 7" Dner Top Packer C-2 profile "2500 psi MAX"' 4.940 2,536.7 HANGER Baker HMC Dner Hanger 5.5 Vam Pin x Pin 4.960 8,680.7 COLLAR Davis Lynch 5-1/2" Float Collar, Hydril 521 box x pin 4.950 Casing Description Strip... String 1... Top (RKB) Set Depth (R... Set Depth (ND) (R... String ... Strip... String Top Thrd !LINER BTM 31/2 2.992 8.481.9 9323.5 6fi172 9.20 L-RO I hydri1511 Liner Details Top (ttKd) Item Deaunphun ant I Ip (u~) 8,481.9 SBE ZXP extension (4.80" OD 14.12" ID) ~ 4.120, 8,506.4 PACKER Baker "HR" ZXP Liner Top Packer (4.67" OD / 3.00" ID) 3.000 8,514.8 HANGER Baker HMC Dner Hanger (4.51" OD / 2.94" ID) 2.940 9,221.3 COLLAR BOT Type 1 Landing Collar 3-1/2" Hydri1511 Box x IBT Pin 2.980 9,257.4 COLLAR Weatherford Float Collar (OD 3.52") 2.992 Tubing Strings cnptron SiN yUD..,Sinn ID I...i TUp IuWnR In... set Depth lm.... Isar OePth1 ,:; i. ~..:: IRP.A TUE VJG ~ ~ I "A _ nDi(iuce0 enrng vn_ 5Y n_. stung Tnp Tnm Completion Details 37.4 HANGER 3.5" Gen V Tubing Hanger EUE brd (XO Pup jt 3.18' EUE brd Up x IBT Dn) 3.030 1,999.0 SSSV 3.5" TRMAXX-SE SCSSV w/ 2.812" X Profile IBTM 2.812 8,407.5 NIPPLE 3.5" D Nipple w12.75" profile 2.750 8,482.1 LOCATOR Baker 3.5" Locator O.D. 4.54" i. D. 3.99" 3.990 ~ o, waarrt...aar oarcer atwVCOre wiaeal /4ssemDly v.u. g.ur LU. Z.BS Z.99U .Other In HDte (Wireline retnevable,plugs, valves, pumps, fish, etc.) Top IHk AI C e, ri Ntron -- - .~mi~nl hu `C t IC, lip)' 1-_. L ', fCiR B,~ht=~- V _i GO LOCATOR ~ i.JOi Perforations Tup 8lm Dhul~ Top Btm (ND) i (ND) Dens I (RKB) (RKB) (RKB) I (RKB) Type Zone (sho...i Da4 I Commerrt 9,038.0 9,058.0 6,385.9 j 6,402.1 I IPERF ~A-3, 3C-15A 6.0 8/26/2008 2.5" HyperJet, 60 deg phase StlmuldteOns & Treat/»erHa _ I Mm Top Max Btm _~ i ~ get Dcplh Vort Top INDI Valve Latch Size TRO RUn Stn i (RKB) (RKB) Make Model OD lint Type ~ TYPe (l^) (Pail Run Date Comment LINER BTM, 8,482-9,324 TD (3C-15A), 9,327 Depth (RKB) Depth (RKB) Date Type Comment 9,038.0 9,058.0 911/2005 Sand PUMPED A SAND FRAC USING YF150D WITH A TOTAL OF 193991# Frac 16/20 CARBOLITE PUMPED. WITH 172981# BEHIND PIPE, 85%OF DESIGN 21010# LEFT IN TUBING. COMPLETED FRAC WITH 10 PPA ON FORMATION. +~ i WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 3C-15A August 20, 2008 AK-MW-5772142 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3C-15A 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-21426-01 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-21426-01 Digital Log Images 1 CD Rom 50-029-21426-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 9951 &~ `. BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 _~ ~ ~D Date: Signed: ~ _ /~/~A_/ ~a~-ohs ~ ~ /(09~ r ~, ~'~i-~ls TRANSMITTAL Beluga River Unit deve%pment wet! 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: KRU 3C-15A Permit: 208-081 DATE: 09/25/2008 Kuparuk River Unit, Alaska 3C-15A 500292142601 Report and CDROM Final Well Report, Mud logging Data, 3C-15A; Epoch, report date: 07/3112008. Contents, equipment and crew, well details, geological data, pressure/formation strength data, drilling data, daily reports, Color log prints: Formation logs MD Formation Log ND; LWD Combo MD; LWD COMBO TVD; Gas ratio MD; Gas ratio TVD; Drilling dynamics MD; Drilling dynamics TVD 1 o sill ~e?,ra J"~r::~~l.~'f?,~.~: rll/~~~al~ !''~31 yfJt~~~eut~:',it~'i:~.~`~L~ __ ;:~i-~~ _ _ ..., ~?t .r .... ', _ :: ~v'~~~~? ~~° Approver: CPF-3 Pad' ~i~e geologist Date: "..._- ~-~' ~~.J ~~~'~f 5t s~i1 ~~ Y .~f «?,~? fry c'a, ~ r ~ ,.~k ~_ !;.. .. .•'i, ~~~. Esy ~ , ;;'„~r,;~ ; %~';t, s'~ ~,~ ~.r.~, _~~-~ti .Sandra. ~. Lsm,'faCa~Conocoof~Itlip~. com o~'°~ 3~ 2 ~ ~a 09/15/08 • ~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # „~ ,; N0.4871 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD -! Log Description iC-172A 11978478 PRODUCTION PROFILE ~- Q 08/19/08 1 1 1C-172A 12080429 GLS/FBHP 08/19/08 1 1 3M-26 12096533 SBHP SURVEY 08/20/08 1 1 3N-02A 11996652 SBHP SURVEY 08/20/08 1 1 3M-22 11966276 SBHP SURVEY - 08/20/08 1 1 3C-17 11996657 SCMT CYtS - / <n 9 ~L./_ 08/25/08 1 1 3C-15A 11996659 PERF/SBHP SURVEY ~aO~S-Q~~ IloG3~~- 08/27/08 1 1 2U-06 12080428 LDL _p( - 08/29/08 1 1 2V-15 11996661 PRODUCTION PROFILE -p 08/29/08 1 1 2T-19 11996663 PRODUCTION PROFILE 08/31/08 1 1 2D-07 11975790 INJECTION PROFILE - jc.~ Q 09/07/08 1 1 2H-09 11975788 PRODUCTION PROFILE ~ (p 09/05/08 1 1 iC-174 12096539 INJECTION PROFILE - ~ p 09/07/08 1 1 2H-12 12096540 PRODUCTION PROFILE ~ 09/09/08 1 1 30-01 11975792 LDL ^U~ 09/09/08 1 1 3F-10 11975789 LDL ( 09/06/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~ • WELL LOG TRANSMITTAL To: State of Alaska August 15, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 3C-15A AK-MW-5772142 1 LDWG formatted CD Rom with verification listing. API#: 50-029-21426-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ,~, ~- ~~~'~ ~ ;~ a. ~"2m>3 -e. .. .z n... Date: ~;;= ~ y ~'~E y Signed: ~ o~s-O~ ~ ~ ~ ~ ~°~ v • i 07-Aug-08 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3C-15A Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 2,699.66 ' MD Window /Kickoff Survey: 2,749.00 ' MD (if applicable) Projected Survey: 9,327.00 ' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~ ~~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Tim Allen Survey Manager Attachment(s) ~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # // /, J (~=~, NO. 4792 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnke~n 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 07/24/08 1A-O6 12080402 INJECTION PROFILE - ( 07/06/08 1 1 3C-17 11964626 SFRT (~~- 07/12/08 1 1 1Y-04 12096505 INJECTION PROFILE - ~ 07/13/08 1 1 1G-06 12061729 INJECTION PROFILE a d 07/13/08 1 1 i F-06 12096506 PRODUCTION PROFILE - f 07/14/08 1 1 3M-08 12096516 SBHP SURVEY 07/21/08 1 1 3M-09 12096515 SBHP SURVEY (o (p 07/21/08 1 1 3N-13 12096517 SBHP SURVEY C (o - 07/22/08 1 1 2W-01 12096508 PRODUCTION PROFILE ~ "~- 07/16/08 1 1 1 F-06 12096510 PRODUCTION PROFILE / - /C 07/17/08 1 1 2A-02 12096511 INJECTION PROFILE 07/18!08 1 1 3J-17 12096514 SBHP SURVEY g !~($ 07/20/08 1 1 3J-07A 12097409 ~ SBHP SURVEY ~_~~~ ®(~(D'~Cp 07/20/08 1 1 3C-15A 12097406 ® _ USIT / '~ 07/17/08 1 1 2A-05 12096512 SCMT 07/19/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Maunder, Thomas E (DOA) Page 1 of 2 From: Greener, Mike R. [Mike.R.Greener@conocophillips.com] Sent: Monday, July 07, 2008 9:53 AM To: Maunder, Thomas E (DOA) Subject: RE: 3C-15 (185-200) update 7/2/08 Attachments: Greener, Mike R..vcf ao~- O~S~ We cleaned out the ice plug in the tubing, got it cut at +/- 5,500' MD, pulled and our whipstock set at +/- 2,754' MD (based on USIT log information). Window cut good and we are currently in the West Sak "D" drilling ahead. Mike Greener From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, July 07, 2008 9:16 AM To: Greener, Mike R. Subject: RE: 3C-15 (185-200) update 7/2/08 Hi Mike. Any further update on 3C-15? Note, since you have not actually milled the window in the casing by our convention the work is still taking place in 3C-15. Tom Maunder, PE AOGCC From: Greener, Mike R. [mailto:Mike.R.Greener@conocophillips.com] Sent: Thursday, July 03, 2008 8:34 AM To: Maunder, Thomas E (DOA) Subject: RE: 3C-15A update 7/2/08. Ice plugs have been cleared out. Tubing is cut at 5,500'. Will attempt to pull in a couple of hours. Mike Greener From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, July 03, 2008 7:35 AM To: Greener, Mike R. Subject: RE: 3C-15A update 7/2/08 It never ends, eh? From: Greener, Mike R. [mailto:Mike.R.Greener@conocophillips.com] Sent: Wednesday, July 02, 2008 3:06 PM To: Maunder, Thomas E (DOA) Subject: 3C-15A update 7/2/08 7/7/2008 Page 2 of 2 Attempts to pull the tubing were unsuccessful. Did stretch free point calculation which showed free point at 5,900'. Rig up wireline to run jet cutter but tubing has ice plug at +/- 200'. Currently picking up 1-1/16" tubing to wash out ice plug. Mike Greener 7/7/2008 ~. '~_. 4 7 .~. SARAH PALIN, GOVERNOR C01~5E~t~~A,iIOH ~ ~ SIOl~ 333 W. 7th AVENUE, SUITE 100 •s-7 iii e.+~~~1~~•~~~lll~~•iiii ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3C-15A ConocoPhillips Alaska, Inc. Permit No: 208-081 Surface Location: 1193' FNL, 1241' FEL, SEC. 14, T12N, R9E, UM Bottomhole Location: 684' FSL, 143' FWL, SEC. 11, T12N, R9E, UM Dear Mr. Thomas: 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 iri the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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, Daniel T. Seamount, Jr. S Chair DATED this 2 ~ day of May, 2008 cc: Department of ash & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~hillips ~ Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com May 15, 2008 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Rim ~G~~ `i ~ Re: Application for Permit to Drill, Kuparuk Producer 3C-15A ,'~~~ ~~~ ~ ~~` ~ts~op~ Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permit to Drill for an onshore producer well, 3C-15A. Please find attached for the review of the Commission form 10-401 and the information required by 20 ACC 25.005 for this sidetrack of well 3C-15. The expected spud date of 3C-15A is June 2, 2008. If you have any questions or require any further information, please contact David Nugent at 263-4674. Sincerely, Randy Thomas Greater Kuparuk Area Drilling Team Leader FZE~EIV'~D STATE OF ALASKA MAY 1 6 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION ~ j(~~ PERMIT TO DRILL J 20 AAC 25.005 ,~laska Oil 8~ Gas ®onseCommi5s1°-~ finch ~J 1a. Type of Work: Drill ^ Re-drill ^ Re-entry ^/ 1 b. Current Well Class: Exploratory ^ Development Oil 0 ~ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 ~ 11. Well Name and Number: 3C-15A 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 9398' ' ND: 6611' ' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1193' FNL, 1241' FEL, Sec. 14, T12N, R9E, UM 7. Property Designation: ADL 25634, 25629 ~ Kuparuk Oil Pool Top of Productive Horizon: 562' FSL, 288' FWL, Sec. 11, T12N, R9E, UM 8. Land Use Permit: ALK ALK 2567, 2562 13. Approximate Spud Date: 6/2/2008 Total Depth: 684' FSL, 143' FWL, Sec. 11, T12N, R9E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: > 2 miles 4b. Location of Well (State Base Plane Coordinates): Surface: x- 528333 y- 5995239 'Zone- 4 10. KB Elevation (Height above GL): 76' AMSL feet 15. Distance to Nearest Well within Pool: 3C-03 , 1157' @ 8089' 16. Deviated wells: Kickoff depth: 3000' ft.' Maximum Hole Angle: 67° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.oa5) Downhole: 4438 psig Surface: 3740 psig 18. Casing Program if i Setting Depth Quantity of Cement Size icat ons Spec Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 7" 5.5" 15.5# L-80 Hydril 563 5900' 2800' 2793' 8700' 6055' 220 sx LiteCRETE, 70 sx GasBLOK 4.75" 3.5" 9.3# L-80 Hydril 511 898' 8500' 5919' 9398' 6611' 80 sx Class G w/GasBLOK 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): 7840' Total Depth ND (ft): 6695' Plugs (measured) none Effective Depth MD (ft): 7294' Effective Depth ND (ft): Junk (measured) 7397', 7457' Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 188 sx CS II 116' 116' Surface 3801' 9-5/8" 950 sx PF E, 360 sx CI G 3841' 3714' Intermediate Production 7786' 7" 400 sx Class G, 175 sx PF C 7826' 6685' Liner Perforation Depth MD (ft): 7346'-7362', 7542'-7547', 7567'-7582' Perforation Depth ND (ft): 6323'-6335 ; 6472'-6476', 6491'-6502' 20. Attachments: Filing Fee ^ BOP Sketch Drilling Program / Time v. Depth Plot ^ Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Nugent @ 263-4674 Printed Name Randy Thomas Title Drilling Team Leader _ Signature ~ ._ ,~ - Phone Z-6S6z35a Date 5 ~<Sloa h All k Commission Use Only Permit to Dri--ll~~ //~~QQ Number: 6YT,~ ~QS j 1 API Number: 50- DZ,~~ Z~ ~2(p~~~ Permit Approval (~~ Date: ~ ~a.~ ~~/ See cover letter for other requirements f box is checked, well may not be used to explore for, test, or produce Coalbed me hane, gas hydrates, or gas contained in shales: Conditions Of approval : I i~ ` l~ Samples req'd: Yes ^ No Mud log req'd: Yes ^ No [/]~ Other: ~Q ~ Ps t `~~Q -kS""C- v5 ~~~ \ H2S measures: Yes [~ No ^ Directional svy req'd: Yes [' No ^ ED BY THE COMMISSION ~/ ~` DATE: ,COMMISSIONER Submit in Du licate Form 10-401 Revised 12/2005 ~ ~~ ~ v l I • • f ~,,, ~ ~.~U~ f•/r7~a8 Application for Permit to Drill, Well 3C-15A Revision No.O Saved: 12-May-08 .F~~~ Permit It - Kuparuk We113C-15A • ~ ~,, Application for Permit to Drill Document ~i: t~ Mlpximiz¢ +u~ii yo~u~ Table of Contents 1. Well Name .................................................................................................................. 2 q f ~ ............................................................................................................. Re uirements o 20 AAC 25.005 2 2. Location Summary ...................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) .........................................................................................................2 R' .f ~) ............................................................................................... . . Re uirementso 20 AAC 25.050 ••••••••••••2 3. Blowout Prevention Equipment Information ............................................................... 3 Requirements of 20 AAC 25.OOS(c)(3) ......................................................................................................... 3 4. Drilling Hazards Information ...................................................................................... 3 Requirements of 20 AAC 2S. 005 (c)(4) ......................................................................................................... 3 5. Procedure for Conducting Formation Integrity Tests ................................................... 3 Requirements of 20 AAC 2S. 005 (c)(S) ......................................................................................................... 3 6. Casing and Cementing Program .................................................................................. 3 Requirements of 20 AAC 25.005(c)(6) ......................................................................................................... 3 7. Diverter System Information ....................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ......................................................................................................... 4 8. Drilling Fluid Program ............................................................................................... 4 Requirements of 20 AAC 25.005(c)(8) ......................................................................................................... 4 9. Abnormally Pressured Formation Information ............................................................ 4 Requirements of 20 AAC 25.005 (c)(9) ......................................................................................................... 4 10. Seismic Analysis .......................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ...................................................................................................... . 5 11. Seabed Condition Analysis .......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ...................................................................................................... . 5 12. Evidence of Bonding ................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ...................................................................................................... . 5 13. Proposed Drilling Program ......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ...................................................................................................... .5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. 7 ^ ~ ~ ~ A ( A ~ 3N-15A PERMIT IT wp08.DOC [~_,`j 1\,'j H Page 1 of 6 Application for Permit to Drill, Well 3C-15A Revision No.O Saved: 12-May-08 Requirements of 20 AAC 25.005 (c)(14) ....................................................................................................... 7 15. Attachments :............................................................................................................. 7 Attachment 1 Directional Plan .........................:.........................................................................................7 Attachment 2 Drilling Hazards Summary ....................................................................................................7 Attachment 3 Well Schematic .....................................................................................................................7 Attachment 4 Cement Summary ..................................................................................................................7 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 2.i.040(b). For a well with multiple ~+~ell branches, each branch must similarly be identified by a unique name and API number by adding a suffrx to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 3C-15A. 2. Location Summary Requirements of 20 AAC 25.005(c) (2) An application for a Permit to Drill must be accompanied by each of the following items, exceptfor an item already on file kith the commission and identified in the application: (2) a plat identifying the property mid the property's owners cold showing (Ajthe coordnaates of the proposed location of the well at the surface, at the top of each objective formation, mid at total depth, referenced to govermnental section lines. (B) the coordinates of the proposed location of the well at the szErface, referenced to the state plane coordinate system for this state as maintained by the _~~ational Geodetic Survey i~a the National Oceanic and ~4tnsospheric ddnsinisbation; (C) the proposed depth of the well at the top of each objective fornuztion and at total depth; Location at Surface 1193' FNL, 1241' FEL, Sec 14,. T12N, R9E, UM NGSCoordrnates RKB Elevation 76.0' AMSL Northings: 5,995,239 Eastings: 528,333 Pad Elevation 48.0' AMSL Location at Top of 562' FSL, 288' FWL, Sec. 11, T12N, R9E, UM Productive Interval Ku aruk A Sand NGSCoordinates Measured De th, RKB: 9,066' Northings: 5,996,980 Eastings: 524,575 Total Vertical De th, RKB: 6,339' Total Vertical Depth, SS: 6,251' Location at Total De th 684' FSL, 143' FWL, Sec. 11, T12N, R9E, UM NGSCoordinates Measured Depth, RKB: 9,398' Northings: 5,997,101 Eastings: 524,429 Total Vertical Depth, RKB: 6,611' Total Vertical Depth, SS: 6,523' al2d (D) other information required by 20 AAC 25.0~0(b); Requirements of 20 AAC 25.050(b) If a ~a~ell is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a sautable scale, showing the path of the proposed wellbore, including ald adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 2: Directional Plan And (2) for all wells within 200 feet of the proposed wellbore (AJ list the names of the operators of those wells, to the extent that those names are known or discoverable in pztblic records, and show that each named operator has been furnished a copy of the application by certfied mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. ORIGINAL 3N-15A PERMIT IT wp08.DOC Page 2 of 6 3. Blowout Prevention Equipment Information Application for Permit to Drill, Well 3C-15A Revision No.O Saved: 12-May-08 Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the follo~a~ing items, exceptfor an item already on file with the commission and identified in the application: (3) a diagram and description of the blowozst prevention eyuipsnent (BOPS) as required by 20 AAC 25.03.1, 20 AAC 25.036, or 20 AAC 2.1.037, as applicable; Please reference BOP schematics on file for Doyon 141. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4J information on drilling hcr=.ards, including (A) the maximum doN•nhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; BHP data on 3C-02 indicates that the expected reservoir pressure for 3C-15A is 4,413 psi at 6,338' TVD. Equivalent Mud Weight @TD = 4413psi =13.4ppg . 6338'TVD x 0.052 The maximum potential surface pressure (MPSP) while drilling 3C-15A is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk A Sand target at 6,338' TVD. MPSP = ~GradientMua - Gradient~aS )TVD GradientMud =13.4 ppg x 0.052 = 0.70 f t t Gradient~aS = 0.11 f lZ t TVD = 6340 ft MPSP = 0.70 psa - 0.11 psa 6340 ft = 3740 psi ft ft B) data on potential gas -ones; The well bore is not expected to penetrate any gas zones. And (C) data concerning potential causes of hole problems suds as abnornuzlly geo pressured strata, lost circulation =ones, and=ones that have a propensity for d~erential sticking; Please see Attachment 2 -Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(S) An application for a Permit to Drill mtest be accompanied by each of the following items, except for mz item aleady on file with the commission and identified in the applicatiws: (5) a description of the procedure for conducting formation integrity tests. as required under 20 AAC 25.030(fl; A procedure is on file with the commission for performing LOT's. For 3C-15A the procedure will be followed after milling the window in 7" casing and drilling 20'-50' of new formation. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) Asa application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file Frith the commission and identified in the application: (6) a complete proposed casing mad cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre perforated liner, or screen to be installed 3N-15A PERMIT IT wp08.DOC OOOEEE Page 3 of 6 C~ Application for Permit to Drill, Well 3C-15A Revision No.O Saved: 12-May-08 Casin and Cementin Pro ram Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/t) Grade Conn. (ftJ (ft) (ft) Cement Pro am Ori final Wellbore 3C-15 9-5/8" 12-1/4 36 J-55 BTC 3,841 surface 3,841 / 3,714 950 sx Permafrost E & 360 sx Class G 7" 8-1/2 26 J-55 BTC 7,826 surface 7,826 / 6,685 400 sx Class G 2-7/8" 6.5 J-55 EUE 7,465 surface 7,465 / 6,414 Tubing 8rd 3C-15A Sidetrack Plan 7" window 26 J-55 BTC 3,000 surface 3,000 / 2,981 220 sx 11 ppg LiteCRETE, 3.3 5.5" flush jt 7" 15.5 L-80 H563i1 5,900 2,800 / 2,793 8,700 / 6,055 3 0/sx 15.8 GasBLOK w/ Class G, 1.17 ft3/sk „ 3-1/2 flush jt 4.75 9.3 L-80 Hydril 898 8,500 / 5,919 9,398 / 6,611 80 sx 15.8 GasBLOCK w/Class 1 17 ft3/ k G 511 . s , 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) ~n application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file ti+~ith the conznzisston and identified in the application: (7J a diagram mid description of the diverter system as required by 20 AAC 2~.03~, males this requirement is waived by the comnttssion under 20 AAC 25.035(h)(2); This rotary sidetrack will exit pre-existing casing at +/-3,000' MD. BOPE will be installed prior to exiting the casing; therefore, no diverter is required. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid systenv, as required by 20 AAC 25.033; Drilling will be done using a LSND mud systems having the following properties: Sidetrack Hole mud properties Intermediate Interval Production Interval Depth MD 3,000' - 8,700' 8,700' - 9,398' Density (ppg) 9.8 13.7 Yield Point (cP) 25 - 32 25 - 28 pH 9.0 - 9.5 9.0 - 9.5 API Filtrate(cc) <6 <6 Diagram of Doyon 15 Mud System on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following iten2s, exceptfor an item already on file with the commission and ident~ed in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo pressured sh~ata as required by 20 .AAC 2~.033(~; 3N-15A PERMIT IT wp08.DOC Page 4 of 6 N/A -Application is not for an exploratory or stratigraphic test well. • Application for Permit to Drill, Well 3C-15A Revision No.O Saved: 12-May-08 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the follrnving items, except for an item already on file with the commission and ident fled in the application: (10) for an exploratory or stratigraphic test icell, a seismic refractio~z or reflection analysis as required by 20 AAC 25.067(a); N/A -Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill nuESt 6e accompanied by each of the folloiming items, except for an item already on file with the commission and identifred in the application: (11) for a well drilled from an offshore platform, mobile bottom founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); N/A -Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the follrnving items, except for an item already on file with the commission and identified in the application7: (12) evidence showing that the requirements of 20 AAC 2.025 {Bonding}hm~e been ntet,~ Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompm~ied by each of the followi~~g items, except for an item already on file with the commission and identified in the application: Pre-Rig Well Work: Wells Group supervised pre-rig P&A and submitted a separate Sundry and procedure for P&A. Rig Work: 1. Notify the AOGCC field inspector 24 hours before prior to spud and BOP test. MI and RU Doyon 15 2. With BPV installed, remove tree and tubing head adaptor. 3. Install BOP blanking plug and NU BOP on 7-1/16" SK flange. Test BOP to 5,000 psi. 4. Ensure well is dead. Pull blanking plug and BPV. 5. Pull 2-7/8" tubing. t d~~~ 6. PU mill, casing scraper, and DP and RIH to (3,200' MD. POOH. DTI 7. RU wireline set a CIBP inside the 7" casing at (3,017' MD based on casing collar depth. (Note: CIBP must be >_ 2.0' above a casing collar and >_ 20' below a casing collar) POOH, RD SWS. Test 7" casing and CIBP to 3,700 psi and hold for 15 min. 8. PU and RIH with Baker's "WindowMaster" whipstock system & window mill, bottom trip anchor, MWD, and UBHO on drill pipe from the derrick. Whipstock to be set on top of CIBP set at 3,000' MD. 9. Orient whipstock, shear off, and POOH. 10. Displace Brine from hole with 9.8 ppg LSND new mud to mill window. Mill window and dri1120' new formation. Dress ``'' window. Pump super sweep pill. y ` ~l l . Perform FIT/LOT. POOH and LD window mill etc. ~~.-.~ Q ®~ ~ ~' 1 \1 ~ L 3N-15A PERMIT IT wp08.DOC V 1 1f ` , Page 5 of 6 Application for Permit to Drill, Well 3C-15A Revision No.O Saved: 12-May-08 12. PU bit, Rhino Reamer, BHA, DP, and RIH. 13. Drill to casing point (f8,700' MD / 6,055' TVD). MW expected to be 9.8 ppg. 14. PU 5-1/2" hydri1563 liner and RIH. Liner overlap into 7" casing needs to be 1200'. 15. Reciprocate the liner while circulating and cementing. R/U Dowell and cement the liner. 16. Release from liner. Set packer. 17. Pull and lay down DP. Pick up 2-7/8" DP. Change out BOP rams and test to 5,000 psi. 18. Weight up to 12 ppg LSND. 19. Pick up and run 4-3/4" bit, 3-1/8" BHA, and 2-7/8" DP. 20. Tag cement. Drill out and perform an FIT/LOT. 21. Dri114-3/4" Production hole to just above the C Sand. Weight up mud to 13.7 ppg. ~ 22. Dri114-3/4" Production hole to TD @ 9,398' MD / 6,611' TVD. 23. RU and run 3-1/2" hydri1511 liner. Reciprocate the liner while circulating and cementing. R/U Dowell and cement 3-1/2" hydril 511 liner. 24. Release from liner. Set packer. 25. Displace the well above the liner top with seawater until the returns are clean. Check for flow. POOH. LD/DP. 26. RU and RIH with 3-1/2" production tubing. Space out and land. RILD's. 27. Test tubing, PBR and liner to 1,500 psi with the IA open for 15 minutes. Bleed the tubing down to 1,000 psi. Test the IA, PBR and liner top to 1,500 psi for 30 minutes (chart test). Bleed tubing pressure to zero psi. With tubing open, annulus pressure should shear dump kill valve (1,500 psi casing to tubing shear). Bleed pressures to zero. 28. Install BPV and blanking plug. ND BOPE. NU and test the 3-1/8" SK tree to 5,000 psi. 29. Pull the blanking plug and BPV. 30. Displace the well with diesel freeze protect fluid. 31. Install BPV. RD and MO Doyon Rig 15. Post-Rig Well Work: 1. Pull BPV. 2. RU SL. Drift and tag to PBTD. 3. Dummy-off GLM. RD SL. 4. RU E-Line. 5. Perforate the Kuparuk "C" sand as directed. RD E-Line. 6. Fflowback "A" sand producer. - 7. Turn over to Production. ORIGINAL 3N-15A PERMIT IT wp08.DOC Page 6 of 6 L~ Application for Permit to Drill, Well 3C-15A Revision No.O Saved: 12-May-08 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music be accompanied by each of the following items, exceptfor an item already on file with the commission and identified in the application: (1-~) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorisation under 20 AAC 25.080 for an am2ular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary ORIGINAL 3N-15A PERMIT IT wp08.DOC Page 7 of 6 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3C Pad 3C-15 Plan: 3C-15a Plan: 3C-15A (wp08) Standard Proposal Report 05 May, 2008 HALL#BL~RTON Sperry Driliing Services HALLIBLIRTON Sps.rv toMNlrq 8sr.ncss 1 1 2400 c_ 0 0 ~_ t Q N _U N N 23 H - Top West Sak t~ Base west SaIF ~c,~ s O~~ ~^ry? - - o°j~G --- -- ---- _- ~ 24~ ti~ ~~ ~ ,~'~ ~O NN FS\~ 024 ,~'~~' 0~ 0 ~,• ~ 52 ^rL A 5 ~~8i ~~ ^ ;t a~ .Q`'~ o ~ `'24 ~ ~~p~ ~^~ ~a ~ boa .~O ~ ~ ~ p a 5~''L o^^ 0 ~ 00 ~ F ~2 h`O ~ O~O~ ' ~~ ,`rah ~ 4\C,`@J / ^,~O O0 ~O P k Q i ~ ~ °j N ~ Q Vag ~ ~~~ ~ ~O' ~°` - ~ oQ `t-Q`~ ~O0 --- _, , , '~ Qa~J ~O, 51/2'- ...-- ,~oQ @J 3 1/2"' ~ 1yPl~Qp61 3G' -1200 -800 -400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 Vertical Section at 346.00° (800 ft/in) COi1oCOPh1~lIP5 Alaska I~utect: Kuparuk River Unit Site: Kuparuk 3C Pad Well: 3C-15 Wellbore: PIan:3C-15a Plan: 3C-15A (wp08) CASING DETAILS TVD TVDSS MD Size Name 2981.37 2893.67 3000.02 7 7" TOW 6037.70 5950.00 8676.33 5-I/2 5 1/2" 6610.53 6522.83 9397.82 3-1/2 31/2" FORMATION TOP DETAILS TVDFath TVDssPath MDPath Formation 3222.70 3135.00 3265.56 Top West Sak D 3672.70 3585.00 3826.34 Base West Sak 5830.70 5743.00 8354.83 Base HRZITop Kzlubik 5960.70 5873.00 8563.99 K-1 marker 6061.70 5974.00 8710.00 Kuparuk D 6134.70 6047.00 8809.10 Kuparuk C 6196.70 6109.00 8889.86 Kuparuk B 6338.70 6251.00 9065.98 Kuparuk A3 6375.70 6288.00 9111.15 Kuparuk A2 6446.70 6359.00 919282 Base Kuparuk;Miluveach 7" TOW TOW @ 3000' MD, 2981' TVD: 1346' FNL, 1220' FEL - Sec14-T12N-R09E NAD 1927 (NADCON CONUS) Alaska Zone 04 +N/-S +E/-W Northing Fasting Latittu e Longitude Slot 0.00 0.00 5995238.66 528333.07 70° 23' 53.084 N 149° 46' 9.9 REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well 3C-15, True North Vertical (TVD) Reference: 3C-15A @ 87.70ft (D75 (40+47.7)) Measured Depth Reference: 3C-15A @ 87.70ft (Di 5 (40+47.7)) Calculation Methotl: Minimum Curvature i• l U l l ~l r~'1 ~ HALLIBURTOIV Project: Kuparuk River Unit REFERENCE INFORMATION WELL DETAILS: 3C-15 NAD 1927 (NADCON CONUS) Alaska Zone 04 Slte: Kuparuk 3C Pad Co-ordinate(N/E)Reference: We113C-15, True North Ground Level: 47.70 6perry L7rtliing 6ervioaa Vertical (TVD) Reference: 8C-15A 87.70(1 (D15 (40+47.7)) Well: 3C-15 @ +N/-S +E/-W Northing Fasting Latittude Longitude Slot II ~ PI ~ 3C 15 d D th R f 3C-15A @ 87 70ft (D75 (40+47 7)) 1750 tsoo 1250 C w 0 1000 0 s C 750 0 o soo to 250 0 -250 -500 -750 -1000 We bore. an. - a Measure ep a erence. Plan: 3C-15A (wp08) Calculation Method: Minimum Curvature 0.00 0.00 5995238.66 528333.07 70° 23' 53.084 N 149° 4G 9.956 W BHL @ 9398' MD, 6611' TVD: 684' FSL, 143' FWL - Secl 1-T12N-R09E CASING DETAtLs TVD TVDSS MD Size Name ~ To Ku azuk A3 u) 9066' MD, 6339' TVD: 562' FSL, 288' FWL - Secl 1-T12N-R09E 2981.37 zs93.67 3000.02 7 7^ Tow p'~ P P ~ _ 6037.70 5950.00 8676.33 5-1/2 51/2" `y~Q ti~ , ' , - - ' ~ 6610.53 6522.83 9397.82 3-1/2 3 1/2" ~L hP ~ ~ i ~~ , . - - " " Top Kuparuk C @ 8809' MD, 6135' TVD: 462' FSL, 408' FWL -Sec 11-T12N-R09E ' ~ _ - -~~ _ _ _ _ - - - - Top Kupazuk D ~ 8710' MD, 6062' TVD: 419' FSL, 459' FWL - Secl l-T 12N-R09E 31/2" ~ - p0- ------------------ ~_`~ ;4___________________________CasingPomt@8676'MD,6038'TVD: 404'FSL,47TFWL-Secll-T12N-R09E 3GISA(wp07)-T1 r 95'%a cont. 5 1/2" ~,~~~ ~O hh T M Azimuths to True North Magnetic North: 17.85° Magnetic Field Strength:57271.2snT Dip Angle: 79.78° Date: 1/23/2008 Model: BGGM2007 ,,~0 h~ ,1p TOW @ 3000' MD, 2981' TVD: 1346' FNL, 1220' FEL - Secl4-T12N-R09E ^~ ~o h~ ,,0 ~~ a^`~ 2750 ~3Q 7" TOW O~ Gh 0 h -4250 X000 -3750 -3500 -3250 -3000 -2750 -2500 -2250 -2000 -1750 -1500 -1250 -1000 West(-)/East(+) (500 fr/in) `'o -750 -500 -250 9 5/8" -S 0 250 500 GonocoPhillips Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3C Pad Well: 3C-15 Wellbore: Plan: 3C-15a Design: 3C-15A (wp08) • Halliburton -Sperry Standard Proposal Report Local Co-ordinate Reference: Well 3C-15 TVD Reference: 3C-15A @ 87.70ft (D15 (40+47.7)) MD Reference: 3C-15A @ 87.70ft (D15 (40+47.7)) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3C Pad Site Position: Northing: 5,995,835.15ft Latitude: 70° 23' 58.955 N From: Map Easting: 528,205.68ft Longitude: 149° 46' 13.622 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: 0 22 ° Well 3C-15 Well Position +N/-S 0.00 ft Northing: 5,995,238.66 ft Latitude: 70° 23' 53.084 N +E/-W 0.00 ft Easting: 528,333.07 ft Longitude: 149° 46' 9.956 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 47.70ft Wellbore PIan:3C-15a Magnetics Model Name Sample Date BGGM2007 1/23/2008 Design 3C ~ ~A (wp08) Audit Notes: Version: Phase: Vertical Section: Depth From (TVD) (ft) L 40.00 -_ - Plan Sections - __ Measured Vertical TVD Depth Inclination Azimuth Depth System I (ft) (°) (°) (ft) ft 3,000.00 22.63 191.03 2,981.35 2,893.65 3,016.50 24.13 195.24 2,996.50 2,908.80 3,166.50 24.13 195.24 3,133.40 3,045.70 3,666.50 42.04 221.20 3,552.61 3,464.91 5,277.65 67.37 309.81 4,605.11 4,517.41 7,931.93 67.37 309.81 5,626.29 5,538.59 9,011.05 35.00 310.00 6,293.70 6,206.00 9,035.46 35.00 310.00 6,313.70 6,226.00 9,397.82 35.00 310.00 6,610.53 6,522.83 Declination Dip Angle (°) (°) 17.85 79.78 Field Strength (nT) 57,271 PLAN Tie On Depth: 3,000.00 +N/-S +E/-W Direction (ft) (ft) (°) 0.00 0.00 346.00 Dogleg Build Turn +N/-S +E/-W Rate Rate Rate Tool Face (ft} (ft) (°/100ft) (°/100ft) (`'1100ft) (°) -153.73 21.23 0.00 0.00 0.00 0.00 -160.10 19.74 13.60 9.09 25.50 50.00 -219.25 3.62 0.00 0.00 0.00 0.00 -446.76 -135.30 4.50 3.58 5.19 50.00 -365.51 -1,209.10 4.50 1.57 5.50 104.64 1,203.04 -3,091.13 0.00 0.00 0.00 0.00 1,735.05 -3,727.81 3.00 -3.00 0.02 179.80 1,744.05 -3,738.54 0.00 0.00 0.00 0.00 1,877.65 -3,897.76 0.00 0.00 0.00 0.00 5/5/2008 10:11:34AM Page 2 COMPASS 2003.16 Build 42F f ~~ Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup2 ND Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 3C Pad North Reference: Well: 3C-15 Survey Calculation Method: Wellbore: PIan:3C-15a Design: 3C-15A (wp08) Planned Survey Measured Vertical Map Depth Inclination Azimuth Depth NDss +N/-S +E/_yy Northing (ft) (°) (°) (ft) ft (ft) (ft) (ft) 100.00 0.07 337.58 200.00 0.17 76.23 300.00 0.32 85.44 400.00 0.37 110.29 500.00 0.27 121.31 600.00 0.23 95.23 700.00 0.32 138.39 800.00 0.35 162.58 900.00 0.37 172.72 1,000.00 0.43 199.25 1,100.00 0.48 216.53 1,200.00 0.45 229.37 1,300.00 0.24 234.64 1,400.00 0.31 181.02 1,500.00 0.86 174.65 1,600.00 1.17 171.37 1,700.00 1.23 158.87 1,800.00 1.23 158.05 1,900.00 1.25 150.77 2,000.00 1.67 132.67 2,100.00 1.96 134.35 2,200.00 1.69 135.40 2,300.00 1.87 123.04 2,400.00 2.45 125.34 2,500.00 5.32 167.24 2,600.00 9.29 169.10 2,700.00 13.34 169.73 2,800.00 16.54 177.34 2,900.00 19.98 184.75 3,000.00 22.63 191.03 3,000.02 22.63 191.03 TOW @ 3000' MD, 2981' ND: 3,016.50 24.13 195.24 3,100.00 24.13 195.24 3,166.50 24.13 195.24 3,200.00 25.12 197.96 3,265.56 27.19 202.72 Top West Sak D 3,300.00 28.34 204.96 3,400.00 31.85 210.59 3,500.00 35.56 215.18 3,600.00 39.42 218.99 3,666.50 42.04 221.20 3,700.00 41.68 223.39 3,800.00 40.86 230.10 Haltiburton -Sperry Standard Proposal Report Well 3C-15 3C-15A @ 87.70ft (D15 (40+47.7)) 3C-15A @ 87.70ft (D15 (40+47.7)) True Minimum Curvature Map 100.00 12.30 0.03 -0.01 5,995,238.69 200.00 112.30 0.13 0.11 5,995,238.79 300.00 212.30 0.18 0.53 5,995,238.85 400.00 312.30 0.10 1.11 5,995,238.76 500.00 412.30 -0.14 1.62 5,995,238.53 599.99 512.29 -0.29 2.02 5,995,238.38 699.99 612.29 -0.50 2.40 5,995,238.17 799.99 712.29 -1.00 2.68 5,995,237.67 899.99 812.29 -1.61 2.81 5,995,237.06 999.99 912.29 -2.28 2.73 5,995,236.39 1,099.98 1,012.28 -2.97 2.36 5,995,235.70 1,199.98 1,112.28 -3.57 1.81 5,995,235.10 1,299.98 1,212.28 -3.94 1.34 5,995,234.72 1,399.98 1,312.28 -4.33 1.16 5,995,234.34 1,499.97 1,412.27 -5.35 1.23 5,995,233.32 1,599.96 1,512.26 -7.11 1.46 5,995,231.55 1,699.93 1,612.23 -9.13 1.99 5,995,229.54 1,799.91 1,712.21 -11.13 2.78 5,995,227.55 1,899.89 1,812.19 -13.07 3.71 5,995,225.60 1,999.86 1,912.16 -15.01 5.31 5,995,223.67 2,099.81 2,012.11 -17.19 7.61 5,995,221.50 2,199.76 2,112.06 -19.44 9.88 5,995,219.26 2,299.71 2,212.01 -21.38 12.27 5,995,217.33 2,399.64 2,311.94 -23.50 15.38 5,995,215.22 2,499.42 2,411.72 -29.18 18.18 5,995,209.55 2,598.58 2,510.88 -41.64 20.70 5,995,197.10 2,696.62 2,608.92 -60.93 24.29 5,995,177.83 2,793.23 2,705.53 -86.52 27.06 5,995,152.25 2,888.19 2,800.49 -117.78 26.32 5,995,120.99 2,981.35 2,893.65 -153.73 21.23 5,995,085.03 2,981.37 2,893.67 -153.73 21.23 5,995,085.02 1346' FNL, 1220' FEL - Sec14-T12N- R09E - 7" TOW 2,996.50 2,908.80 -160.10 19.74 5,995,078.66 3,072.71 2,985.01 -193.03 10.76 5,995,045.69 3,133.40 3,045.70 -219.25 3.62 5,995,019.44 3,163.85 3,076.15 -232.63 -0.37 5,995,006.06 3,222.70 3,135.00 -259.69 -10.45 5,994,978.96 Fasting DLS Vert Section (ft) 12.30 528,333.06 0.00 0.03 528,333.18 0.20 0.10 528,333.60 0.15 0.05 528,334.18 0.16 -0.17 528,334.69 0.11 -0.53 528,335.09 0.12 -0.77 528,335.47 0.22 -1.07 528,335.75 0.14 -1.62 528,335.88 0.07 -2.24 528,335.81 0.19 -2.88 528,335.44 0.14 -3.45 528,334.89 0.11 -3.90 528,334.42 0.22 -4.15 528,334.25 0.26 -4.48 528,334.32 0.55 -5.49 528,334.55 0.31 -7.26 528,335.10 0.27 -9.34 528,335.90 0.02 -11.47 528,336.83 0.16 -13.58 528,338.43 0.62 -15.85 528,340.74 0.30 -18.52 528,343.02 0.28 -21.25 528,345.42 0.43 -23.71 528,348.54 0.59 -26.52 528,351.36 3.86 -32.72 528,353.93 3.98 -45.41 528,357.59 4.05 -64.99 528,360.46 3.75 -90.50 528,359.84 4.15 -120.65 528,354.88 3.49 -154.30 528,354.88 0.00 -154.30 528,353.41 13.62 -160.11 528,344.57 0.00 -189.90 528,337.52 0.00 -213.62 528,333.58 4.50 -225.63 528,323.60 4.50 -249.45 3,253.17 3,165.47 -274.36 -16.94 5,994,964.27 528,317.17 4.50 -262.11 3,339.70 3,252.00 -318.61 -40.40 5,994,919.93 528,293.89 4.50 -299.38 3,422.88 3,335.18 -365.12 -70.59 5,994,873.31 528,263.87 4.50 -337.20 3,502.22 3,414.52 -413.59 -107.34 5,994,824.71 528,227.31 4.50 -375.34 3,552.61 3,464.91 -446.76 -135.30 5,994,791.43 528,199.48 4.50 -400.76 3,577.56 3,489.86 -463.30 -150.34 5,994,774.84 528,184.50 4.50 -413.17 3,652.76 3,565.06 -508.47 -198.31 5,994,729.49 528,136.71 4.50 -445.39 5/5/2008 10:11:34AM Page 3 COMPASS 2003.16 Build 42F BRIGINAL Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3C Pad Well: 3C-15 Wellbore: PIan:3C-15a Design: 3C-15A (wp08) Planned Survey Measured Depth Inclination Azimuth 3,826.34 40.71 231.90 Base West Sak 3,900.00 40.44 4,000.00 40.44 4,100.00 40.84 4,200.00 41.65 4,300.00 42.83 4,400.00 44.36 4,500.00 46.20 4,600.00 48.31 4,700.00 50.66 4,800.00 53.21 4,900.00 55.94 5,000.00 58.81 5,100.00 61.81 5,200.00 64.91 5,277.65 67.37 5,300.00 67.37 5,400.00 67.37 5,500.00 67.37 5,600.00 67.37 5,700.00 67.37 5,800.00 67.37 5,900.00 67.37 6,000.00 67.37 6,100.00 67.37 6,200.00 67.37 6,300.00 67.37 6,400.00 67.37 6,500.00 67.37 6,600.00 67.37 6,700.00 67.37 6,800.00 67.37 6,900.00 67.37 7,000.00 67.37 7,100.00 67.37 7,200.00 67.37 7,300.00 67.37 7,400.00 67.37 7,500.00 67.37 7,600.00 67.37 7,700.00 67.37 7,800.00 67.37 7,900.00 67.37 7,931.93 67.37 Vertical Depth (ft) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Map TVDss +N/-S +E/-W Northing ft (ft) (ft) (ft) Halliburton -Sperry Standard Proposal Report Well 3C-15 3C-15A @ 87.70ft (D15 (40+47.7)) 3C-15A @ 87.70ft (D15 (40+47.7)) True Minimum Curvature 3,672.70 3,585.00 -519.30 -211.68 5,994,718.61 Map Fasting DLS Vert Section (ft) 3,585.OD 528,123.38 4.50 -452.66 236.98 3,728.66 3,640.96 -547.15 -250.63 5,994,690.62 528,084.54 4.50 -470.26 243.92 3,804.81 3,717.11 -579.10 -306.98 5,994,658.46 528,028.32 4.50 -487.63 250.80 3,880.73 3,793.03 -604.12 -367.02 5,994,633.21 527,968.38 4.50 -497.39 257.52 3,955.96 3,868.26 -622.06 -430.38 5,994,615.03 527,905.10 4.50 -499.47 263.98 4,030.03 3,942.33 -632.81 -496.66 5,994,604.03 527,838.87 4.50 -493.86 270.12 4,102.48 4,014.78 -636.30 -565.45 5,994,600.28 527,770.09 4.50 -480.60 275.90 4,172.87 4,085.17 -632.51 -636.34 5,994,603.80 527,699.19 4.50 -459.78 281.32 4,240.77 4,153.07 -621.47 -708.89 5,994,614.57 527,626.61 4.50 -431.51 286.37 4,305.75 4,218.05 -603.23 -782.64 5,994,632.52 527,552.80 4.50 -395.98 291.08 4,367.42 4,279.72 -577.92 -857.15 5,994,657.55 527,478.20 4.50 -353.39 295.47 4,425.40 4,337.70 -545.69 -931.95 5,994,689.49 527,403.29 4.50 -304.03 299.58 4,479.32 4,391.62 -506.74 -1,006.58 5,994,728.16 527,328.52 4.50 -248.18 303.45 4,528.86 4,441.16 -461.31 -1,080.59 5,994,773.30 527,254.35 4.50 -186.19 307.10 4,573.70 4,486.00 -409.68 -1,153.51 5,994,824.65 527,181.24 4.50 -118.45 309.81 4,605.11 4,517.41 -365.51 -1,209.10 5,994,868.60 527,125.49 4.50 -62.15 309.81 4,613.71 4,526.01 -352.30 -1,224.95 5,994,881.75 527,109.59 0.00 -45.50 309.81 4,652.19 4,564.49 -293.21 -1,295.85 5,994,940.57 527,038.47 0.00 29.00 309.81 4,690.66 4,602.96 -234.11 -1,366.76 5,994,999.39 526,967.34 0.00 103.49 309.81 4,729.13 4,641.43 -175.02 -1,437.66 5,995,058.21 526,896.22 0.00 177.98 309.81 4,767.60 4,679.90 -115.92 -1,508.57 5,995,117.03 526,825.10 0.00 252.48 309.81 4,806.08 4,718.38 -56.83 -1,579.47 5,995,175.85 526,753.98 0.00 326.97 309.81 4,844.55 4,756.85 2.27 -1,650.38 5,995,234.67 526,682.86 0.00 401.46 309.81 4,883.02 4,795.32 61.36 -1,721.29 5,995,293.49 526,611.73 0.00 475.96 309.81 4,921.49 4,833.79 120.46 -1,792.19 5,995,352.31 526,540.61 0.00 550.45 309.81 4,959.97 4,872.27 179.55 -1,863.10 5,995,411.13 526,469.49 0.00 624.94 309.81 4,998.44 4,910.74 238.65 -1,934.00 5,995,469.95 526,398.37 0.00 699.44 309.81 5,036.91 4,949.21 297.74 -2,004.91 5,995,528.77 526,327.25 0.00 773.93 309.81 5,075.39 4,987.69 356.84 -2,075.81 5,995,587.59 526,256.12 0.00 848.42 309.81 5,113.86 5,026.16 415.93 -2,146.72 5,995,646.41 526,185.00 0.00 922.92 309.81 5,152.33 5,064.63 475.03 -2,217.63 5,995,705.23 526,113.88 0.00 997.41 309.81 5,190.80 5,103.10 534.12 -2,288.53 5,995,764.05 526,042.76 0.00 1,071.90 309.81 5,229.28 5,141.58 593.22 -2,359.44 5,995,822.87 525,971.64 0.00 1,146.40 309.81 5,267.75 5,180.05 652.31 -2,430.34 5,995,881.69 525,900.51 0.00 1,220.89 309.81 5,306.22 5,218.52 711.41 -2,501.25 5,995,940.51 525,829.39 0.00 1,295.38 309.81 5,344.69 5,256.99 770.51 -2,572.15 5,995,999.33 525,758.27 0.00 1,369.88 309.81 5,383.17 5,295.47 829.60 -2,643.06 5,996,058.15 525,687.15 0.00 1,444.37 309.81 5,421.64 5,333.94 888.70 -2,713.96 5,996,116.97 525,616.02 0.00 1,518.87 309.81 5,460.11 5,372.41 947.79 -2,784.87 5,996,175.79 525,544.90 0.00 1,593.36 309.81 5,498.58 5,410.88 1,006.89 -2,855.78 5,996,234.61 525,473.78 0.00 1,667.85 309.81 5,537.06 5,449.36 1,065.98 -2,926.68 5,996,293.43 525,402.66 0.00 1,742.35 309.81 5,575.53 5,487.83 1,125.08 -2,997.59 5,996,352.25 525,331.54 0.00 1,816.84 309.81 5,614.00 5,526.30 1,184.17 -3,068.49 5,996,411.07 525,260.41 0.00 1,891.33 309.81 5,626.29 5,538.59 1,203.04 -3,091.13 5,996,429.86 525,237.71 0.00 1,915.12 5/5/2008 10:1 i:34AM Page 4 COMPASS 2003.16 Build 42F ^41G~NAL • Halliburton -Sperry NQ~L~~RT~~ Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 3C-15 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: 3C-15A @ 87.70ft (D15 (40+47.7)) Project: Kuparuk River Unit MD Reference: 3C-15A @ 87.70ft (D15 (40+47.7)) Site: Kuparuk 3C Pad North Reference: True Well: 3C-15 Survey Calculation Method: Minimum Curvature Wellbore: PIan:3C-15a Design: 3C-15A (wp08) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 5,565.89 8,000.00 65.33 309.82 5,653.59 5,565.89 1,242.96 -3,139.03 5,996,469.59 525,189.66 3.00 1,965.44 8,100.00 62.33 309.83 5,697.69 5,609.99 1,300.43 -3,207.95 5,996,526.80 525,120.53 3.00 2,037.88 8,200.00 59.33 309.84 5,746.42 5,658.72 1,356.36 -3,274.99 5,996,582.46 525,053.28 3.00 2,108.37 8,300.00 56.33 309.86 5,799.65 5,711.95 1,410.60 -3,339.97 5,996,636.45 524,988.11 3.00 2,176.71 8,354.83 54.69 309.86 5,830.70 5,743.00 1,439.56 -3,374.66 5,996,665.27 524,953.31 3.00 2,213.20 Base HRZ/Top Kalubik 8,400.00 53.33 309.87 5,857.25 5,769.55 1,462.99 -3,402.71 5,996,688.59 524,925.17 3.00 2,242.72 8,500.00 50.33 309.89 5,919.04 5,831.34 1,513.39 -3,463.04 5,996,738.76 524,864.66 3.00 2,306.22 8,563.99 48.41 309.90 5,960.70 5,873.00 1,544.53 -3,500.29 5,996,769.76 524,827.29 3.00 2,345.45 K-1 marker 8,600.00 47.33 309.90 5,984.86 5,897.16 1,561.67 -3,520.78 5,996,786.81 524,806.74 3.00 2,367.03 8,676.18 45.05 309.92 6,037.59 5,949.89 1,596.93 -3,562.95 5,996,821.92 524,764.45 3.00 2,411.45 Casing Point @ 8676' MD, 603 8' TVD: 404' FSL, 477' FWL - Sec1 1-T12N-R09E 8,676.33 45.04 309.92 6,037.70 5,950.00 1,597.00 -3,563.03 5,996,821.99 524,764.36 3.00 2,411.54 5 112" 8,700.00 44.33 309.92 6,054.53 5,966.83 1,607.68 -3,575.80 5,996,832.62 524,751.56 3.00 2,424.99 8,710.00 44.03 309.93 6,061.70 5,974.00 1,612.16 -3,581.14 5,996,837.07 524,746.20 3.00 2,430.63 Top Kuparuk D @ 8710' MD, 6 062' TVD: 419' FSL, 459' FWL - Sec11-T12N-R09 E -Kuparuk D 8,800.00 41.33 309.95 6,127.85 6,040.15 1,651.32 -3,627.92 5,996,876.05 524,699.28 3.00 2,479.94 8,809.10 41.06 309.95 6,134.70 6,047.00 1,655.16 -3,632.51 5,996,879.88 524,694.67 3.00 2,484.78 Top Kuparuk C @ 8809' MD, 6 135' TVD: 462' FSL, 408' FWL - Se c11-T12N-R09 E -Kuparuk C 8,889.86 38.64 309.97 6,196.70 6,109.00 1,688.39 -3,672.17 5,996,912.96 524,654.89 3.00 2,526.62 Kuparuk B 8,900.00 38.33 309.97 6,204.64 6,116.94 1,692.45 -3,677.01 5,996,916.99 524,650.03 3.00 2,531.73 9,000.00 35.33 310.00 6,284.67 6,196.97 1,730.96 -3,722.94 5,996,955.33 524,603.96 3.00 2,580.21 9,011.05 35.00 310.00 6,293.70 6,206.00 1,735.05 -3,727.81 5,996,959.40 524,599.08 3.00 2,585.35 9,035.46 35.00 310.00 6,313.70 6,226.00 1,744.05 -3,738.54 5,996,968.36 524,588.32 0.00 2,596.68 3C-15A (wp07) - T1 9,065.98 35.00 310.00 6,338.70 6,251.00 1,755.31 -3,751.95 5,996,979.56 524,574.86 0.00 2,610.84 Top Kuparuk ,43 @ 9066' MD, 6339' TVD: 562' FSL, 288' FWL - S ec11-T12N-R0 9E -Kuparuk A3 9,100.00 35.00 310.00 6,366.57 6,278.87 1,767.85 -3,766.90 5,996,992.04 524,559.87 0.00 2,626.63 9,111.15 35.00 310.00 6,375.70 6,288.00 1,771.96 -3,771.80 5,996,996.13 524,554.96 0.00 2,631.80 Kuparuk A2 9,197.82 35.00 310.00 6,446.70 6,359.00 1,803.91 -3,809.88 5,997,027.94 524,516.76 0.00 2,672.02 Base Kuparuk/Miluveach 9,200.00 35.00 310.00 6,448.48 6,360.78 1,804.72 -3,810.84 5,997,028.74 524,515.80 0.00 2,673.03 9,300.00 35.00 310.00 6,530.40 6,442.70 1,841.59 -3,854.78 5,997,065.44 524,471.72 0.00 2,719.44 • 9,397.82 35.00 310.00 6,610.53 , 6,522.83 1,877.65 -3,897.76 5,997,101.34 524,428.61 0.00 2,764.83 BHL @ 9398' Mt3, 6611` TVD: 684' FSL, 143' FWL - Se c11-T12N-R09E 5/5/2008 10:11:34AM Page 5 COMPASS 2003.16 Build 42F Halliburton -Sperry i~AL~~i.~'ro~ Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 3C-15 Company: ConocoPhillips (Alaska) Inc. -Kup2 ND Reference: 3C-15A @ 87.70ft (D15 (40+47.7)) Project: Kuparuk River Unit MD Reference: 3C-15A @ 87.70ft (D15 (40+47.7)) Site: Kuparuk 3C Pad North Reference: True Well: 3C-15 Survey Calculation Method: Minimum Curvature Wellbore: PIan:3C-15a Design: 3C-15A (wp08) Targets Target Name - hitJmiss target Dip Angle Dip Dir. ND +N/-S +E/-W Northing Easting -Shape (°) (') (ft) (ft) (ft) (ft) (ft) 3C-15A (wp07) - T1 0. 00 0.00 6,313.70 1,744.05 -3,738.54 5,996,968.36 524,588.32 - plan hits target - Circle (radius 150.00) Casing Points _- Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (~~) ('7 3,000.02 2,981.37 7" TOW 7 8-1/2 8,676.33 6,037.70 51/2" 5-1/2 6-3/4 9,397.82 6,610.53 31/2" 3-1/2 4-3/4 Formations ', Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (°) (°) 9,065.98 6,338.70 Kuparuk A3 0.00 8,889.86 6,196.70 Kuparuk B 0.00 3,826.34 3,672.70 Base West Sak 0.00 3,265.56 3,222.70 Top West Sak D 0.00 8,563.99 5,960.70 K-1 marker 0.00 8,354.83 5,830.70 Base HR7JTop Kalubik 0.00 9,197.82 6,446.70 Base Kuparuk/Miluveach 0.00 9,111.15 6,375.70 Kuparuk A2 0.00 8,710.00 6,061.70 Kuparuk D 0.00 8,809.10 6,134.70 Kuparuk C 0.00 Plan Annotations ~ Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 3,000.02 2,981.37 -153.73 21.23 TOW @ 3000' MD, 2981' TVD: 1346' FNL, 1220' FEL - Sec14-T12N-R09E 8,676.18 6,037.59 1,596.93 -3,562.95 Casing Point @ 8676' MD, 6038' ND: 404' FSL, 477' FWL - Sec11-T12N-R 8,710.00 6,061.70 1,612.16 -3,581.14 Top Kuparuk D @ 8710' MD, 6062' ND: 419' FSL, 459' FWL - Sec11-T12N 8,809.10 6,134.70 1,655.17 -3,632.51 Top Kuparuk C @ 8809' MD, 6135' ND: 462' FSL, 408' FWL - Sec11-T12N 9,065.98 6,338.70 1,755.31 -3,751.95 Top Kuparuk A3 @ 9066' MD, 6339' ND: 562' FSL, 288' FWL - Sec11-T12t 9,397.82 6,610.53 1,877.65 -3,897.76 BHL @ 9398' MD, 6611' ND: 684' FSL, 143' FWL - Sec11-T12N-R09E 5/5!2008 10:11:34AM Page 6 COMPASS 2003.16 Build 42F ORIGINAL ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3C Pad 3C-15 Plan: 3C-15a 3C-15A (wp08) '~ ; rpNrr L"~rillin~ ~rr~ir Clearance Summary Anticollision Report 01 May, 2008 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3C Pad - 3C-15 -Plan: 3C-15a - 3C-15A (wp08) Well Coordinates: 5,994,990.36 N, 1,668,364.65E (70° 23' 52.03" N, 149° 46' 21.21" W) Datum Height: 3C-15A @ 87.70ft (D15 (40+47.7)) Scan Range: 3,000.00 to 9,397.67 ft. Measured Depth. Scan Radius is 1,135.77 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALL.IBU'RTON Sperry Drilling S®rvica~ SURVEY PROGRAM Date: 2008-04-16700:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 102.70 3000.00 3C-15 (3C-15) CCT-MS 3000.00 9397.67 3C-15A (wp08) (Plan: 3C-ISa) MWD+IFR-Ali-CA~SC 0 3C-1 ConocoPhillips (Alaska) Inc. -Kup2 Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surtace: Elliptical Conic Warning Method: Rules Based ANTI-COLLISION SETTINGS Interpolation Method: MD, interval: 50.00 Depth Range From: 3000.00 To 9397.67 Centre Distance: 1135.77 Reference: Plan: 3C-15A (wp08) (3C-15/Plan: 3C-15a) 0 270 1so Travelling Cylinder Azimuth (TFO+AZI) (°~ vs Centre to Centre Separation [200 ft/in) Details: 3C-15 North American Datum 1983 Alaska Zone 4 Ground Level: 47.70 +N/-S +EI-W Northing Easting Latittude Longitude Slot 0.00 0.00 5994990.39 1668364.85 70° 23' 52.030 N 149° 46' 21.213 W REFERENCE INFORMATION Co-ordinate (NIE) Reference: Well 3C-15, True North Vertical (TVD) Reference: 3G15A @ 87.70ft (015 (40+47.7)) Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: 3C-15A @ 87.70tt (015(40+47.7)) Calculation Method: Minimum Curvature From Colour To MD 3000 3250 3250 3500 3500 4000 4000 --- - - - 5000 5000 6000 6000 7000 7000 9000 9000 ---~- ~ 9400 180 Travelling Cylinder Azimuth (TFO+AZI) ~°( vs Centre to Centre Separation (50 f[/in) SECTION DETAILS Sec MD Inc Azi TVD +N/-S +FJ-W DLeg TFace VSec Targel 1 3000.00 22.63 191.03 2981.35 -153.73 21.23 0.00 0.00 -154.30 2 3016.50 24.13 195.24 2996.50 -160.10 19.74 13.60 50.00 -160.11 3 3166.50 24.13 195.24 3133.40 -219.25 3.62 0.00 0.00 -213.62 4 3666.50 42.04 221.20 3552.61 -446.76 -135.30 4.50 50.00 -400.76 5 5277.58 67.37 309.81 4605.08 -365.56 -1209.06 4.50 104.64 -62.21 6 7931.83 67.37 309.81 5626.30 1202.85 -3091.14 0.00 0.00 1914.93 7 9010.89 35.00 310.00 6293.70 1734.80 -3727.80 3.00 179.79 2585.11 8 9035.31 35.00 310.00 6313.70 1743.81 -3738.53 0.00 0.00 2596.44 3C-1 SA (wp07) - T1 9 9397.67 35.00 310.00 6610.53 1877.40 -3897.74 0.00 0.00 2764.59 HALLIBURTON ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for 3C-15 - 3C-15A (wp08) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3C Pad - 3C-15 -Plan: 3C-15a - 3C-15A (wp08) Scan Range: 3,000.00 to 9,397.67 ft. Measured Depth. Scan Radius is 1,135.77 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 Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft Kuparuk 1C Pad Kuparuk 1 D Pad V ...._ .~~ Kuparuk 1J Pad Kuparuk 3C Pad 3C-01 - 3C-01 - 3C-01 3C-01 - 3C-01 - 3C-01 3C-02 - 3C-02 - 3C-02 3C-02 - 3C-02 - 3C-02 3C-09 - 3C-09 - 3C-09 3C-12 - 3C-12 - 3C-12 3C-14 - 3C-14 - 3C-14 3C-14 - 3C-14A - 3C-14A 3C-15 - 3C-15 - 3C-15 3C-16 - 3C-16 - 3C-16 3C-16 -Plan: 3C-16A - 3C-16A (wp01) Plan: 3C-17 - 3C-17 - 3C-17 (wp08) Plan: 3C-17 - 3C-17 - 3C-17 (wp08) Kuparuk 3F Pad Separation Warning ~~;~~~,x''d}~lsn,.. ,,.4,c .. k {. _~'~_+ : s Te.: , ~~ .~w.~ A.. S'f.~ . -,F.r.n }i'VS b~W. s:F~' s~+H.. ~ .9. r. ,-6r i_ a~w.~ , »:. ~:~5. -~. 5~._~ / \. ~. ., n m ~ ~ ~ y~~.~. .P \. C"~ Sil'x'..N? ~ -'kC h ~.'5~..-~\/.\:3~~. . r r «.~~.F ~ '. .f~~Sr ~~a „ .~~f.~.T=~iS~ 1sew.~CR~: Ptip ~Y . ~ m :. r :k ., .r ) ~. ~. ~~e,~._ _., 41 ~ R n.e ._:.:_~ .,: . ,. -0.~ ,rSfnSC~.±•~'r', .~ .~{K, v.:.; ~. ~..-S~. ,n, .+.. ~ „_a, ! v ~".. ~at...2'~.. .a ,°i~.~a3'aea 3a~, s:. ~:.~s .. ,t,SSlF(;~5'~L'~wF, >SC+.i. .. ~.~sLv:..'8u':~ ,..,. ~ ~.._ '~3`~~h ~ ~_~t. ,. a~ e, „r. ,..cis. n.9 ,,.~ ., ~~.,~X~~ 4,682.65 647.49 4,682.65 527.34 4,475.00 5.389 Centre Distance Pass -Major Risk 4,716.31 648.40 4,716.31 526.17 4,525.00 5.305 Clearance Factor Pass -Major Risk 5,977.57 202.17 5,977.57 60.38 5,475.00 1.426 Clearance Factor Pass -Major Risk 5,992.67 201.24 5,992.67 62.41 5,500.00 1.450 Centre Distance Pass -Major Risk 3,000.00 698.33 3,000.00 603.73 3,250.00 7.382 Clearance Factor Pass -Major Risk 3,007.15 490.96 3,007.15 394.52 3,075.00 5.091 Clearance Factor Pass -Major Risk 3,002.21 317.53 3,002.21 221.68 3,000.00 3.313 Clearance Factor Pass -Major Risk 3,000.00 316.22 3,000.00 220.46 3,000.00 3.302 Clearance Factor Pass -Major Risk ~~i ', 3,010.51 217.61 3,010.51 124.79 3,075.00 2.344 Clearance Factor Pass -Major Risk 3,010.51 217.61 3,010.51 124.79 3,075.00 2.344 Clearance Factor Pass -Major Risk 3,506.41 605.15 3,506.41 529.02 3,425.00 7.948 Centre Distance Pass -Major Risk 3,526.21 605.31 3,526.21 528.71 3,450.00 7.902 Clearance Factor Pass -Major Risk ~I • 01 May, 2008 - 11:32 Page 2 of 5 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 HAL.I.~IBURTC'~N Kuparuk River Unit Anticollision Report for 3C-15 - 3C-15A (wp08) Survev tool proaram From To Survey/Plan (ft) (ft) 102.70 3,000.00 3,000.00 9,397.67 3C-15A (wp08) 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. Survey Tool GCT-MS MWD+IFR-AK-CAZ-SC 01 May, 2008 - 11:32 Page 3 of 5 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 HALLIBURTON Anticollision Report for 3C-15 - 3C-15A (wp08) Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to 3C-15A @ 87.70ft (D15 (40+47.7)). Northing and Easting are relative to 3C-15. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is -150.00°, Grid Convergence at Surtace is: 0.21 °. Ladder Plot ~e ~+ i 1050- 0 lt7 fh c 0 .~ ca 700- ~. tll C N U 0 350- C Q) U 0 0 ---------- ---------- f ---------- ---------- f ---------- -------- , f ~ f f f f f f f$ f f f ' ' ,G- Eq~: ~ ~ ~ I ~ f 1 ~ ~ I ~ 1 1 ~ i f i , f f i -----~----- -----f----- -~F --- --- -f --- ---- f----- ----_f--- i~ k ~ C,~ i f f f f ~ I ~ I 1 1 ~ ~ f f ~ f f f f ~ i ~ .~ f f ~ 1 1 1 1 1 1 1 f t 1 1 ---_f---- - - ---'f---- - - _f-- - ~^ - - - ----f-- - - - - --f----- - ----f-- - - ~ ~ ~ ~ ~ ,as ~ 1 1 1 ~ ~ f ~ ~ 1 t f I ~ f f i ' f f f ~ { f , 1 I I F ~ I J I f t 1 -. 1 .'' ' f 1 1 1 1 1 1 1 1 -----f----- -----f----- -----'----- ` -----f---- -----f----- -----f--- ~ ~ f ~ ~ f f ~ f f f i f i i i f i f i ~ ~ i 1 1 1 1 f 1500 3000 4500 6000 7500 Measured Depth ~ 1500 ftlin) Kuparuk River Unit LEGEND - 1G 74, Plan: 1C•174a, 1C•174a (wp01)V2 - 1 D- 18, 1D•118, Pbn N1 V1 - Pla IJ-124, Plan IJ•124, 1J•124(wpDS)V4 -3C• 1,3C-01,3C•01 V2 - 3C• 2, 3C-02, 3C-D2 V2 - 3C• 9, 3C•09, 3C-09 V2 -3C• 2,3C•12,3C-12 V2 -3C- 3,3C-13,3C•13 V1 - 3 G- 4, 3 C-14, 3C•14 V2 -3C• 4,3C•14A,3C•14AVD •w 3C• 5, 3C-15, 3C•15 V1 -3C- 6,3C•16,3C•16Y1 -3C- 6,PIan:3C•16A,3C•16R(wpDt)V1 -Pla :3C-17,3C•17,3C-17(wpD8)VZ - 3F• Q, Plan 4, 3F•18AU-D 1, Plan A4 VO - 3 F• 6, Plan 4, 3 F•16A11.02, Plan N4 VD - Pla Win star OGktok, Win star OGktok Pt Stau "If N2D"N 1.. -3C• 5A (wp08) 01 May, 2008 - 11:32 Page 4 of 5 COMPASS u HALLIBURTON O ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for 3C-15 - 3C-15A (wp08) Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor io AO 8?,5 7.50 p_~ ~i l .~. 625 0 m Q SAO m c~ Q ~ 3.7 5 2a0 125 OAD ~ ~ - r _ ~- ;_ ~ ~ ; . ; u _.. . t ~ e ., - y; , Y t __ ` k . ,- a A 3 . _: ~. ~ ~ d _ , _.. ~~ ~ ._ . _ r ff ~. a v ~_-~.. s . ~ _ = s _ t r _ ~.,, .. ~_~ . . ,. _, i . _ a_- # -~-~ ._ ~ _. _ .~ ~i ~ _, - - -w - ~. - ,._ ~_ _m ~rt_ . _._. ,-. -, t t a ~ ~ ~ f ~ ? x- .. ~. r t ,- Y ~ ~_ r e _. ~ _ . _.k. ,. ~~ - r r , r >.. ~ -._s a .._. ~_ ...~.~..r.__. ____ e ., r s- ~- ~-.~ r-- ,,.s..~ .t ~. _. .. _. ,.... __ ,~ . _~ g. ., s .. .... ,..,p ~ -fi - b-. _ _ { ;°i i t - ( r -s n u nn ~ sn 3nnn a7 5o 15 00 52 50 60 00 6i 50 75 00 82 80 90 00 Measured Depth (1500 1tAn) LEG END 1 •174, PI an: 1C-174a, 1C•174a(~p01)V2 1 •I16, 1D-118, Plan 91 VI lan 1J•124, Plan IJ-124, 1J-124 (wp05)V4 -01,3C-01,3C•O1 V2 -02, 3C•02, 3C•02 V! -00, 3C•00, 3C•00 V! -12, 3C-11, 3C•12 V2 -13, 3C-13, 3C•13 V1 • 14, 3C-14, 3C•141/2 • 14, 3 C-14A, 3 C•14A 1N •15, 3C-15, 3C•15 VI •10,3C-10, 3G161t1 -10, Plan: 3C-tOf~ 3C•t0A(wp01) V1 Ian:3C•17, 3C•17,3C-17 (~p08)V2 -10, Plan 4, 3F•t0AL1.O1, Plan N41.0 •10, Plan 4, 3F•t0A11-02, Plan N4 W lan Winstar Ofiktok, 1Alinstar Oliktok Pt State '7f H20'~tfi ONkt~ • 15 A (~ p06) 01 May, 2008 - 11:32 Page 5 of 5 COMPASS CanacoP'hillips ConocoPhillips Alaska, Inc. Kuparuk River Unit ~ Kuparuk 3C Pad ' Plan: 3C-15A (wp08) 1/4 Mile Pool Scan ~°-'° Sperry Drilling Services May 2, 2008 HALLIBURT©!`- 8perr`Y Ortlliny ~ewtcareas Closest in POOL Closest A roach: Reference Well: 3C-15A w 08 Plan Offset Well: 3C-03 3-D ctr-ctr Distance. Meas. De th Ind. An le TRUE Azi. Subsea TVD Coords. -ASP N + /S - E + /W - View VS 346° Comments Meas. De th Incl. An le TRUE Azi. Subsea ND Coords. -ASP N + /S - E + /W - View VS 346° Comments 157.02 7~s:'i 397.67 5.00 10.00 522.90 997101.92 24428.42 764.66 POOL Min Distance (1157.02 ft) in POOL (8700 - 9397.67 MD) to 3C-03 (5900 - 6682.89 TVDss) 089.00 2.18 00.83 682.89 997822.23 25319.66 244.20 POOL Min Distance (1157.02 ft) in POOL (8700 - 9397.67 MD) to 3C-15A (wp08) Plan (5900 - 6682.89 TVDss) Closest A roach: Reference Well: 3C-15A w 08 Plan Offset Well: 3C-02 3-D ctr-ctr Distance. : Meas. De th Ind. An le TRUE Azi. Subsea TVD Coords. -ASP N + /S - E + /W(- View VS 346° Comments Meas. De th Incl. An le TRUE Azi. Subsea TVD Coords. -ASP N + /S - E + /W - View VS 346° Comments 092.47 700.00 4.33 09.92 967.02 996833.19 24751.31 424.90 POOL Min Distance (2092.47 ft) in POOL (8700 - 9397.67 MD) to 3C-02 (5900 - 6585.71 TVDss) 159.00 0.07 48.61 225.09 995038.36 25795.54 240.72 POOL Min Distance (2092.47 ft) in POOL (8700 - 9397.67 MD) to 3C-15A (wp08) Plan (5900 - 6585.71 TVDss) edo.......s~ P'"'"'r -~ POOL Summary Template1 5/2/2008 7:18 PM ConocoPhillips 5a 0 _.._. .___. ~' r~-~- HALLIl31,.JRTON Sperry Drlllirig S®rvic®s k River Unit c 3C Pad Ground Level: 47.70 RKB: 3C-1 SA ~ 87.708 (Dt 6 (40+47.7(( NmthinglASP Y: 5994990.36 Fasting/ASP X: 1668364.65 ,.{•. ;•• . . . .:. .., ,,.. ,.,: .z` 3C-15'. c .. .. . . .----- --- - -- -,~------------------------------------------f._-.....-------------~----------..._...---.--- .------------ -- - -- --- - ---- _ -- -- - - - -. 7" TOW ~. - 5/8" - 9 5/8" /` 3 1 /2" ' ~ ~ 3C-03 ~trr _ 6000 .. ~ : ;` :'~s ----- ---._- - ------ ------ -- - - ,~:: - -- ---.. .--------..- ----.---------- -- -- -- ------..--- 000 . .,,, .. ,.... 3 .; 3 -02-- , 7rr -... •-~ .. ... ..................•-•------ 2 i :'~' " -----------------~--•----•----....-..i---- -_ _ __ ------- -------•----•-- - ----•---•--•-- - - - - ._. _ .....-- ----.. \ ODD y: r'. ~, 3C-15A (wp08) '; ., ,: , . , , , 0 0 0 0 0 0 0 o° o° o° o° o ° ~r~ ~- m cti ° i ~ t i i -000 - 2000 - 3000 -4000 0 0 0 cv • 3C-15A Drilling Hazards 6-1/8 x 7"" Hole • Event Risk Level Miti ation Strate High ECD and swabbing with Low Condition mud prior to trips. Monitor ECD's with PWD tool. Pump hi her MW's re uired and rotate out on trips as a last resort. Barite Sag Low Use Good drilling practices as documented in well plan and keep track of mud properties in line with mud ro am. Differential Sticking High Do not leave pipe static for extended period of time. Proper drilling practices and keep connection time to minimum. Hole instability while drilling High Use enough MW to stabilize HRZ / Kalubik without sustaining losses HRZ / Kalubik Shale section Lost Circulation Moderate Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree as needed. 4-3/4" Hole Event Risk Level Miti ation Strate High ECD and swabbing with High Condition mud prior to trips. Monitor ECD's with PWD tool while close tolerance and higher drilling across pay interval. Pump and rotate out on trips as a last MW's re uired resort. Abnormal Reservoir Pressure High Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increase mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Have spike fluid available. Differential Sticking Moderate Wiper trips as needed. Do not leave pipe static for extended period of time. Lost Circulation Moderate Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology. Use LC decision tree. ~IGINAL 9-5/8" x 7" annulus arctic packed October1985 w/ 30 bbls cmt & 61 bbls Arctic Pack. 0 - 3000'. 3C-15A Schematic _ 3C-15A SIDE~RACK ~onocoPhillips PROPOSED 3'/z" Camco SCSSSV TRMAXX-5E with 2.812 Profile Nipple Bore sssv set at +/- 2000' MD/ 2000' TVD 3'/2' 9.3# L-80 IBT Mod tubing 5.5" X 7" Liner Top @ +/- 2800' MD / 2792' TVD 9-5/8" 36# J-55 BTC casing Set @ 3841' MD / 3714' TVD (Original FIT 12.5 ppg EMWj Sidetrack KOP w/ window in 7" @ +/- 3000' MD / 2981' TVD ' GLM # MD-RKB TVD-RKB Number and depth To Be Determined Baker "K-1" CIBP below set point for whipstock @ +/- 3017' MD 2-7/8" tbg cut and pulled from +/- 6800' MD / 5902' TVD Retainer set at 7155' MD. Top of cmt P&A ' ` plug @ 7000' MD. PKR 7196' MD Perfs 7346' - 7362' MD (Sqz) PKR 7439' MD Perfs: 7542' - 7547' 7567' - 7582' LWD Loaaina: 3-'/2" D nipple with 6-1/8" hole: GR/RES 2.75" No Go profile 4-3/4" hole: GRlRES two joints above the seal assemby 5 '/:" liner Assembly w/ 200' liner Ian: 5-1/2" 15.5# Hydril 563 Liner @ 8700' MD / 6055' TVD BHP Est.: 13.4 ppg EMW in A Sand TD: 9223' MD / 6611' TVD ~ 3 '/:" liner Assembly top w/ 200' liner lap: 3-1/2" 9.3# Hydril 511 Liner @ 9398' MD / 6611' TVD Original Wellbore ~ 7.0" csg 26.0# J-55 @ 7$26' MD ; ~ j\ ~ DAN 5/13/08 MAY-19-2008 14 14 ~G i WELLS • FACSXM~LE TRAZV'SMYTTAL SHEET 907 265 1336 P.01 DATE: ~~02 ~ ~ Q ~' p ° T~"~~° TO: ~ p r~ /wt ,~ v n1 ~ ~ tilq FA.~#- ~ ~ ~ - .~ S `~~ k~ Ail ~, ~~ ~~ ~'RONI: `~ a~} ~ t l~ U G~ N r ~~l~or~~Q ~~$~iv~* f~ N Votes : _._ G~~~.~i'%~~ C~'t~~~ Vol v,~.~s 3C-~~~~ ~TO.4F PACES FO~,T~OWY~1'G COVE~t: ~,_ Fax: (90'~ 26S -1336 MAY-19-2008 14 14 ~G i JELLS pn AmWPtl In°IR tlBtB. FOr Rig: Doyon 141 Location: West S2k Client: ConacoPhillips Alaska Revision Date: 5/20/2008 Prepared by: Maureen Tome Location: Anchorage, AK Phone: (907) 265-6336 ~ Mobile: (907) 952-0445 i email: mtorriet~sib.com ~ Top of lead at 2,640' MD ~ Liner Top at 2,800' MD Previous Csg. 7", 26.0# casing at 3,000' Mp t Tap of Tail at 8,03p' MP ~ 51/Z", 15,5# casing in 7" OH TD at 8,530' MD (6,064' ND) Mark of Schlumberger 907 265 1336 P.02 ~I~I'~!P Volume Calculations and Cement S stems Volumes are based on 35% excess. Displacement is calculated with a 3.5"-15.5# drill string. Lead Sluff Minimum thickening time: 160 min. (pump time plus 120 min.) LiteCRETE 11 ppg , 3.3 ft3/sx Annular Vplume: 0.1480ft3/ft x (100') x 1.00 (no excess) ; 14,8 ft 0.0498 ft3/tt x (300') x 1 _p0 (np excess) = 14.9 ft~ 0.1023 ftg/Pt x (503fl') x 1.35 (35% excess) = 684.7 ft Totals: 14.8 'ft3 + 14.9 ft3 + 694.7 ft3 = 724.4 ft3 724.4 fta/ 3.3ft9/sk = 219.5 sks Round up to 220 sks Tail Slurrv Minimum thickening time: 160 min. (pump time plus 120 min.) GasBLOK w/ Class G + 2 gps D600G + 0.1 °/p 8155 + 0.2 gps D047 + 0,35% D065 Q 15.8 ppg -1.17 ft3/sk Annular Volume: 0.1023 ft3/ft x (500') x 1.35 (35°/p excess) = 69.1 ft3 Shoe Volume: 0.1336 ft3/ft x 80' x 1.00 (no excess) = 10.7 ft3 Totals: GG 3 * ~t3 W ~p~i ~ ^f' ~'p• '~ 7'~ ~ ~ 79.8 ft3 79.$ ft3/ 1.17ft3/sk = 6$.2 sks Round up to 70 sks BHST =130, Estimated BHCT = 89`P. (BHST calculated using a gradient of 2.2`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Stage Cumulative Rate Volume lime Time Sta e b m bl min min Comments Chemical Wash 6 30 6.Q 6.0 Star# Pumping Nash MudPUSH II 6 30 5.0 11,Q Start Pumping Spacer Lead Slurry 6 129 21,6 32.5 Tail Slurry 6 15 2.5 35,0 Mix and Pump Tail Slurry Drpp Wiper Dart 3,0 38.0 Displacement 6 135 22.6 60.5 Start Displacement Slow Rate 2 20 10.U 70,5 MUD REMOVAL Recommended Mud Properties: 10 ppg, Pv ~ 15, TY c 22. As thin and light as possible to aid in mud rempva) during cementing. Spacer Properties: 11.5 ppg MudpUSH* II, Py ~ 19-22, T„ ~ 22-29 Centralizers: Recommend 2 per joint over zones of interest TOTAL P. 02 ' ~ Schlumberger CemCADE Preliminary Job Design 5 1/2" Liner Preliminary Job Design based on limited input data. For esfimale purposes only. Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska Revision Date: 4/30/2008 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com < Top of Lead at 2,600' MD < Liner Top at 2,800' MD Previous Csg. 7", 26.0# casing at 3,000' MD < Top of Tail at 8,030' MD < 5 1/2", 15.5# casing. in 7" OH TD at 8,530' MD (6,064' TVD) Mark of Schlumberger Volume Calculations and Cement Systems Volumes are based on 35% excess. Displacement is calculated with a 3.5"- 15.5# drill string. Lead Slurry Minimum thickening time: 160 min LiteCRETE 11 ppg - 3.3 ft3/sx Annular Volume: 0.1480ft3/ft x (100') x 1.00 (no excess) _ 0.0498 ft3/ft x (300') x 1.00 (no excess) _ 0.1023 ft3/ft x (5030') x 1.35 (35% excess) _ Totals: 14.8 ft3 + 14.9 ft3 + 694.7 ft3 = 724.4 ft3/ 3.3ft3/sk = Round up to 220 sks (pump time plus 120 min.) 14.8 ft3 14.9 ft3 694.7 ft3 724.4 ft3 219.5 sks Tail Slurry Minimum thickening time: 160 min. (pump time plus 120 min.) GasBLOK w/ Class G + 2 gps D600G + 0.1 % B155 + 0.2 gps D047 + 0.35% D065 @ 15.8 ppg - 1.17 ft3/sk Annular Volume: 0.1023 ft3/ft x (500') x 1.35 (35% excess) = 69.1 ft3 Shoe Volume: 0.1336 ft3/ft x 80' x 1.00 (no excess) = 10.7 ft3 Totals: 694.7 ft3 + 724.4 ft3 = ? SCF C''QV1S~.01^ 79.8 ft3 69.1 ft3/ 10.7 ft3lsk = ~() ~ 68.2 sks Round up to 70 sks t~.- BHST = 130, Estimated BHCT = 89~. (BHST calculated using a gradient of 2.2/100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Stage Cumulative Rate Valume Time Time Stage (bpm) (bbl) (min) (min) Comments Chemical Wash 5 30 6.0 6.0 Start Pumping Wash MudPUSH II 6 30 5.0 11.0 Start Pumping Spacer Lead Slurry 6 129 21.5 32.5 Tail Slurry 6 15 2.5 35.0 Mix and Pump Tail Slurry Drop Wiper Dart 3.0 38.0 Displacement 6 135 22.5 60.5 Start Displacement Slaw Rate 2 20 10.0 70.5 MUD REMOVAL Recommended Mud Properties: 10 ppg, Pv < 15, TY < 22. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.5 ppg MudPUSH* I I, Pv = 19-22, TY = 22-29 Centralizers: Recommend 2 per joint over zones of interest ORIGINAL ' - Schlumberger CemCADE Preliminary Job Design 3 1/2" Liner Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska Revision Date: 4/30/2008 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com Top of Tail at < 8,130' MD < Liner Top at 8,330' MD Previous Csg. 5 1/2", 15.5# casing at 8,530' MD < 3 1/2", 9.3# casing in 4 3/4" OH TD at 9,222' MD (6,611' TVD) Mark of Schlumberger Volume Calculations and Cement Systems Volumes are based on 35% excess. Displacement is calculated with a 2.9"- 10.4# drill string. Cementjob is designed to seal off liner top by bringing cement 200' above liner top, with 15.8 ppg G cement. Tail Slurry Minimum thickening time: 140 min. (pump time plus 120 min.) GasBLOK w/ Class G + 2 gps D600G + 0.1 % B155 + 0.2 gps D047 + 0.35% D065 15.8 ppg - 1.17 ft3/sk Liner Cap: 0.0886 ft3/ft x 200' x 1.00 (no excess) = 17.7 ft3 Liner Lap: 0.0668 ft3/ft x 200x 1.00 (no excess) = 13.4 ft3 Annular Volume: 0.0562 ft3/ft x (692') x 1.35 (35% excess) = 52.5 ft3 Shoe Volume: 0.0488 ft3/ft x 80' x 1.00 (no excess) = 3.9 ft3 Totals: 17.7 ft3+13.4ft3+52.5ft3+3.9ft3= 87.5 ft3 87.5 ft3/ 1.17 ft3/sk = 74.8 sks Round up to 80 sks BHST = 142, Estimated BHCT = 128. (BHST calculated using a gradient of 2.2/100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Stage Cumulative Rate Volume Time Time Stage (bpm) (bbl) (min) (min} Comments CUU101J 4 10 2.5 2.5 MudPUSH II 4 20 5.0 7.5 Start Pumping Spacer Tail Slurry 4 17 4.3 11.8 Mix and Pump Tail Slurry Drop Wiper Dart 3.0 14.8 Displacement 4 34 8.5 23.3 Start Displacement Displacement 3 10 3.3 26.6 Slow to Bump MUD REMOVAL Recommended Mud Properties: 14.3 ppg, Pv < 15, TY < 22. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 15.0 ppg MudPUSH" I I, Pv = 19-22, TY = 22-29 Centralizers: Recommend 2 per joint from Previous Casing to TD. ORIGIPdAL TRANSMITTAL LE/T,TER CHECKLIST WELL NAME ~~~c. -3 C ~ ~S~ PTD# Z ~ - Ov /Development~ Service Exploratory Stratigraphic Test Non-Conventional Well ___ .. - ,~' ~~,~ FIELD: ~u/~4.'r-c-~'~~' POOL: _ ~~ ~i~~ .o~ Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) ~~ FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well -~ (If last two digits in _ permit No. , APt No. 50- - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and togs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervais from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed mejhane is not allowed for (name of weU) until after ~Comnanv Narae) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ~,Comaanv Narae) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1/1 i20Q8 WELL PERMIT CHECKLIST Fietd & Pool KUPARUK RIVER, KUPARUK RIVOIL - 490100 Well Name: KUPARUK RIV UNIT 3C-15A Program DEV Well bore seg ^ PTD#:2080810 Company rnNnrOPHILLIPS ALASKA INC Initial Classltype DEV 11.O}L GeoArea 890 Unit 11160 On10ff Shore _~ Annular Disposal ^ Administration 1 Pe[mitf~saita>;hed ----- -------- - - --- - NA ---- - - --- -- --- - ----- --- --- -- - ----- -- 2 Leasenumber appropriate_ _ _ _ _ _ - - - _ _ _ - - - - - - - _ - _ _ - - - _ - - - - - - - -Yes - - - - - - - Sr~rface tocatioa in ADL 25634; top prod interval 8 TD in_ADL_25629_ _ _ - - - _ _ _ - _ - - - - - - - - - - - - - - 3 Uniqu@well-Rameand number---- ---- --- - - -- - -- -Yes---- ---- -- - -- ---- ---- --- -- - --- 4 Well located in_adefinedpool____--_--__---_-----------_ __-----__Yes___._ -_KUPARUKRIVER,KUPARUK RIV OIL-494100,_governedbyC0432C-------------------------- 5 Well located proper distancefrom dri)Gng unit_boundary- - - - - - - - - - - -- - - - - - - _ Yes - - - _ - - CO 4820 has n9 spacing restrictions with respectto dulling unit boundaries. - - _ - - _ - - - _ - - - _ _ _ - - 6 We1112cate~ProDerdistanCefrom4iherwglls___---------------- ----_---_Yes---_ -_G9432Chasnointerwell spacing restrictions.-__-_-_____._------__------_--_---_--_-- 7 Sufficient acreage ayaiiable in_drilling unit- - - - - - - - - - - - - -Yes . - - - N4 ssues• - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 8 Ifdegiated,iswellborePlatinclgded---- - ------- -- ----- --Yes- -- -- --- - --- - -- - -- ------ -- - -- -- - ----- 9 O~eratoroalyaffectedparw--- ------ - -- - -- --- ----- -Yes-- -- --- ---- -- - -- -- - -- ------ --- -- - - -- - --- 10 Operator has-apprDPriatebondinfQrce - - --~ --- ---- --Yes --- --- --- -- --- - -------------- -- --- - ---...---- - ----- - 11 PermitcanbeissUedwitt~oulCOnserYati9n4rder----------------- ---------. Yes----- --------------------.--------------------------------------- ---- Appr Date 12 Permitcanbeissuedvmhoutadmioistrati~app[oval.------------- ----------Yes----- ---------------.-----.------------------------- - -- ----.. ----- 13 CanpBrmitbeappr4vedbeforQ15itaywait-------------------- ----_-----Yes----- ----------.------------------------------------ -- -- -- -- -- SFD 511912008 14 Well locatedwithigareaand_strataauih4rizgdby_Inje~tioe0[de[#(putl0#in.comments)-(For_ NA______ _________------_------.---_.-_---_.-------------------------------- 15 Allwells_withinll4_mileatea.ofreyiQwidentifiQd(FOr&ervieewellgnly)----- ---------- NA------ ---------.-------------------------------- -- --- - --- -- - 16 Pre-producedinjeGtor:durationotpre~roductienlessthan8months-(ForserviceweRonly)--_NA_---- ---------_---------------------------------- ---- -- -- -- --- 17 NonCOnven:9aseQnf4rmsiaAS31.05.0804.1.A),(L2.A~D) -- - - -- ----- . NA--- - --- --- -- -- - --- ---- ----- -- - - ---- -- - -- -- Engineering 18 Conductorstrnl9-Plovided------------------------------ -----------NA------ -C4nductor_set-in3~-15(185-240).----------.---------------.------------------ 19 Surface_casirlgprotectsaN_knownUSDWS-_------_----------- -----_--- NA_____ __Rllaquifersexempted,40CFR_147.102(pu8)----------------------------------------- 20 CMTVOIadequate#ocirculateoncenducto[8surf-csg-------------- ---------- NA-_--._ _-Surface casing set in BC-15._.__---.---___--_-__----._------_------ - --- 21 CMT_votadequaietgtie-inlongstnngtosprfcsg__________________ ______---Yes_--_ --TQCorlnewdrilling liner planned above window.______._-___--._-----._---------_--.-- 22 CMT willooYef-ahknown-productivehQrizQns --- - ---- -- --- -------Yes-- - ---- --- -- -- --- -------- ----- ----- --- -- - ---- 23 Casing des~nsait4equateforC,T,B&petmafrosi-.. ---- --~- -- ---Yes.. -- - --- - -- -... - -- ---- ----- ----- -- - -- --~----- 24 Adequate tankage_ orreserve pik - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - - _ - - - -Rig equipped with steel pits, No reserve pk planned._ All waste_to approved disposalwell(s). - - - - . _ - - _ - - 25 If.a_re-drill,Des_atOr408 for abandonment been approved_---------- ---------Yes--- - .-808-147------------------------------------------------------ ---- 26 Adequatewellbore separation-proposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes . - _ - - _ Pcoxitity analysis performed. Traveling cylinderpatD calculated. _ - - _ - - _ _ - - - - - - - - - - . - - _ - - - - _ _ 27 Ifd-iverterrequirfld,d2eslimeetre9ufatipns--------------------- ----------~----- --B~PStaGkwillalreadY-be inpleee,------------------.------.--------------------- Appr Date 28 Drhlirtgfiuid-program schematic $ Qquiplistadequate- - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ _ - - - - Maximum eXpeCted fo[mati4n prQSSUre 18 4 EMW._ MW_plannecf up_t413.7 ppg. _ _ - - _ - - - - - - . - - - - - - - - TEM 512012008 29 BOPI=S..dotheym~regulation- ----- -- -- -- - - ---- Yes-- ---- -- - --- --- ---- ---- --- -- ------- -- ---- O A,,, ~ ~ 30 BOPE_press rating app[opriate; iestto_(put psig in_comments)- - - - - - - - - - - - - - - - - - - - Yes _ - - - - - - MA$P calculated at 3740psi, 5000-psi_BOP testplanned. - _ - - - - - _ - - - - - - - - _ - - - - - _ _ - - - - - - . - . , l,~fiivW' , 31 Choke-manifoldcompliBSwIAPI_RP-53 (May84). - -- - - -- --- Yes-- --- - --- ----- --------- - ---- --- -- -- --- - --- ~T ~ 32 Work N~ilf 9ocur without operation shutdown- - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 33 is presence of N2S gas probable - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes _ - _ - _ _ _ H2$ is reported at 1C pad. Mud should preclude H2S on [ig. _ Rig has-sensors and alarms. _ - - - - - - _ - _ - - 34 Mechanical-condition of wellswlthinA9Ryerified(FOrserwcewell only)---- ---------NA---- --------------------------------------------------------------------- Geology 35 Permh can be issued wlo hydrogensulfide measures - - - - - - - - - - - - - - - - - - - - - - - No_ - - _ _ _ _ _ Nearby wells 8G-41 amd 8G-08 measured 125 io 150 ppm_ H2S in Nov. 2045 _ _ _ _ - - _ _ _ _ _ - - _ - - _ - - - _ 36 Data_prasented on potential overpressu[ezones- - - - - - - - - - - - - - -- - - - - - - - - - - -Yes - - _ - - _Nearby-wei18C-02 measured-13,4_ppg EMyV in reservoir. Will be drilled with 13,7_ ppgmud.. - - - - - - - - - - . - - Appr Date 37 Seismic analysis of;hallow gas-aones______--__------------ ----------NA___- -_--_----_------ SFD 511912008 38 Seabed_condition suniey_(ifoff-shore) - - - - - - - - - - - - - 39 Contactnamelphoneforweekly_P_rolressrepods_[exploratoryonly]------- --------- NA------ ----.--------------------------------------------------------------- Geologic Engineering Pu ' Date: C ' r: Date Co ' n n i Date Commissicner: s n e s=~~ g s~~o~ o • Welt History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • • 3c-15a.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Aug 14 15:42:09 2008 Reel Header Service name .............LISTPE Date . ...................08/08/14 Ori 9in ...................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 . ...................08/08/14 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 Kuparuk River unit MWD/MAD LOGS WELL NAME: 3C-15A API NUMBER: 500292142601 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 14-AUG-08 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: w-0005772142 w-0005772142 w-0005772142 LOGGING ENGINEER: P. ORTH P. ORTH P. ORTH OPERATOR WITNESS: M. THORNTON M. THORNTON M. THORNTON MWD RUN 4 MWD RUN 5 MWD RUN 6 ]OB NUMBER: w-0005772142 W-0005772142 w-0005772142 LOGGING ENGINEER: P. ORTH B. HENNINGSE B. HENNINGSE OPERATOR WITNESS: M. THORNTON F. HERBERT M. THORNTON SURFACE LOCATION SECTION: 14 TOWNSHIP: 12N RANGE: 9E FNL: 1193 FSL: FEL: 1241 FWL: Page 1 3c-15a.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: $4.66 GROUND LEVEL: 47.70 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 6.125 7.000 2749.0 2ND STRING 4.750 5.500 8725.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE 3C-15 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 2749'MD/2744'TVD. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 1, PRIOR TO PICKING UP LWD TOOLS. ONLY SROP DATA ARE PRESENTED FOR RUN 1. 4. MWD RUNS 2-6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY- PHASE 4 (EWR4). MWD RUNS 2-4 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD) AND DRILLSTRING DYNAMICS SENSOR (DDS). 5. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM PAT PERFETTA (CPAI) TO BRYAN BURINDA (SDS), DATED 14 AUGUST 2008. 6. MWD RUNS 1-6 REPRESENT WELL 3C-15A WITH API# 50-029-21426-01. THIS WELL REACHED A TOTAL DEPTH OF 9327'MD/6620' 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 - DEEP RESISTIVITY. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. 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 Page 2 ARE SMOOTHED WITH A FOR ALL CURVES. 3c-15a.tapx 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/14 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped DEPTH INCREMENT: .5000 FILE SUMMARY curves; all bit runs merged. PBU TOOL CODE START DEPTH STOP DEPTH GR 2736.5 9267.5 RPx 2743.5 9279.5 RPS 2743.5 9279.5 RPM 2743.5 9279.5 FET 2743.5 9279.5 RPD 2743.5 9279.5 RoP 2749.0 9327.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP 1 2749.0 2 2794.0 3 3286.0 4 5262.0 5 8748.0 6 9007.0 REMARKS: MERGED MAIN PASS. MERGE BASE 2794.0 3286.0 5262.0 8748.0 9007.0 9327.0 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 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ......... .. ... ..... Datum specification Block sub-type...0 Page 3 3c-15a.tapx Name Servi ce order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name Servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 2736.5 9327 6031.75 13182 2736.5 9327 RPD MWD OHMM 0.23 2000 7.28796 13073 2743.5 9279.5 RPM MWD OHMM 0.06 1780.18 6.4279 13073 2743.5 9279.5 RPS MWD OHMM 0.33 2000 9.52977 13073 2743.5 9279.5 RPX MWD OHMM 0.31 1718.1 5.54021 13073 2743.5 9279.5 FET MWD HR 0.39 164.48 3.47586 13073 2743.5 9279.5 GR MWD API 23.22 516.17 108.988 13063 2736.5 9267.5 ROP MWD FPH 0.02 299.47 89.225 13157 2749 9327 First Reading For Entire File..........2736.5 Last Reading For Entire File...........9327 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/14 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.......08/08/14 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY header data for each bit run in separate files. 1 .5000 VENDOR TOOL CODE ROP START DEPTH STOP DEPTH 2749.0 2794.0 Page 4 3c-15a.tapx LOG HEADER DATA DATE LOGGED: 06-JUL-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 2794.0 TOP LOG INTERVAL (FT): 2749.0 BOTTOM LOG INTERVAL (FT): 2794.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 13.3 MAXIMUM ANGLE: 15.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232605 EWR4 Electromag Resis. 4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 2749.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 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 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ......... .. ......... Datum specification Block sub-type...0 Lignosulfanate 9.80 49.0 .4 550 7.5 .900 60.0 .910 59.0 1.700 60.0 1.600 60.0 Name Service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWDO10 FPH 4 1 68 4 2 Page 5 3c-15a.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2749 2794 2771.5 91 2749 2794 ROP MWDO10 FPH 0.02 45.02 15.5311 91 2749 2794 First Reading For Entire File..........2749 Last Reading For Entire File...........2794 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/14 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF File Header service name... .......STSLI6.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/14 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.002 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 GR 2736.5 3228.5 RPD 2743.5 3235.5 RPM 2743.5 3235.5 FET 2743.5 3235.5 RPS 2743.5 3235.5 RPx 2743.5 3235.5 RoP 2794.5 3286.0 LOG HEADER DATA DATE LOGGED: 07-JUL-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 3286.0 TOP LOG INTERVAL (FT): 2794.0 BOTTOM LOG INTERVAL (FT): 3286.0 Page 6 3c-15a.tapx BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 15.0 MAXIMUM ANGLE: 28.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232605 EWR4 Electromag Resis. 4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 2749.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G): 9.80 MUD VISCOSITY (S): 53.0 MUD PH: 9.8 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3): 7.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.400 78.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.150 96.8 MUD FILTRATE AT MT: 1.500 78.0 MUD CAKE AT MT: 1.200 78.0 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 .lIN 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 MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 Page 7 3c-15a.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2736.5 3286 3011.25 1100 2736.5 3286 RPD MWD020 OHMM 0.79 2000 21.5787 985 2743.5 3235.5 RPM MWD020 OHMM 0.06 1748.55 15.237 985 2743.5 3235.5 RPS MWD020 OHMM 0.7 961.16 11.9463 985 2743.5 3235.5 RPX MWD020 OHMM 0.43 1718.1 14.0602 985 2743.5 3235.5 FET MWD020 HR 0.39 22.6 2.83111 985 2743.5 3235.5 GR MWD020 API 23.22 98.15 61.326 985 2736.5 3228.5 ROP MWD020 FPH 0.97 241.34 132.692 984 2794.5 3286 First Reading For Entire File..........2736.5 Last Reading For Entire File...........3286 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/14 Maximum Physical Record..65535 File Ty ~e ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLI6.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/14 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. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3229.0 5204.5 RPM 3236.0 5211.5 RPD 3236.0 5211.5 RPS 3236.0 5211.5 FET 3236.0 5211.5 RPx 3236.0 5211.5 RoP 3286.5 5262.0 LOG HEADER DATA DATE LOGGED: 09-JUL-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory Page 8 3c-15a.tapx TD DRILLER (FT): 5262.0 TOP LOG INTERVAL (FT): 3286.0 BOTTOM LOG INTERVAL (FT): 5262.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 30.2 MAXIMUM ANGLE: 64.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 EWR4 Electromag Resis. 4 156404 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 2749.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G): 9.80 MUD VISCOSITY (S): 60.0 MUD PH: 10.1 MUD CHLORIDES (PPM): 600 FLUID LOSS (C3): 5.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.500 78.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.090 109.4 MUD FILTRATE AT MT: 1.600 78.0 MUD CAKE AT MT: 1.500 78.0 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 .lIN 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 MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 RoP MWD030 FPH 4 1 68 28 8 Page 9 3c-15a.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3229 5262 4245.5 4067 3229 5262 RPD MWD030 OHMM 0.3 47.48 5.37085 3952 3236 5211.5 RPM MWD030 OHMM 0.33 38.2 4.72061 3952 3236 5211.5 RPS MWD030 OHMM 0.33 68.77 5.06875 3952 3236 5211.5 RPX MWD030 OHMM 0.31 189.58 5.56152 3952 3236 5211.5 FET MWD030 HR 0.42 15.93 1.58946 3952 3236 5211.5 GR MWD030 API 37.21 138.44 93.9507 3952 3229 5204.5 ROP MWD030 FPH 0.09 238.76 105.527 3952 3286.5 5262 First Reading For Entire File..........3229 Last Reading For Entire File...........5262 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/14 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.......08/08/14 Maximum Physical Record..65535 File Type.. ............LO PreVi0U5 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 GR 5205.0 8690.5 FET 5212.0 8697.5 RPx 5212.0 8697.5 RPS 5212.0 8697.5 RPD 5212.0 8697.5 RPM 5212.0 8697.5 ROP 5262.5 8748.0 LOG HEADER DATA DATE LOGGED: 14-JUL-08 SOFTWARE Page 10 ~ i 3c-15a.tapx SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8748.0 TOP LOG INTERVAL (FT): 5262.0 BOTTOM LOG INTERVAL (FT): 8748.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 31.4 MAXIMUM ANGLE: 69.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 EWR4 Electromag Resis. 4 156404 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 2749.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S): 46.0 MUD PH: 9,9 MUD CHLORIDES (PPM): 600 FLUID LOSS (C3): 5.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.900 74.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.160 125.6 MUD FILTRATE AT MT: 1.500 74.0 MUD CAKE AT MT: 1.100 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 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order DEPT RPD MWD040 RPM MWD040 RPS MWD040 RPX MWD040 Units Size Nsam FT 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 Rep Code offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 Page 11 3c-15a.tapx FET MWD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5205 8748 6976.5 7087 5205 8748 RPD MWD040 OHMM 1.25 1567.99 5.26338 6972 5212 8697.5 RPM MWD040 OHMM 1.15 66.82 4.11209 6972 5212 8697.5 RPS MWD040 OHMM 1.2 25.24 3.88417 6972 5212 8697.5 RPX MWD040 OHMM 1.22 26.73 3.87109 6972 5212 8697.5 FET MWD040 HR 0.39 16.38 1.81736 6972 5212 8697.5 GR MWD040 API 55.14 516.17 128.162 6972 5205 8690.5 ROP MWD040 FPH 0.16 299.47 83.6034 6972 5262.5 8748 First Reading For Entire File..........5205 Last Reading For Entire File...........8748 File Trailer Service name... .......STSLI6.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/14 Maximum Physical Record..65535 File TyPe ................L0 Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLI6.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/14 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.005 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 GR 8691.0 8947.5 RPS 8698.0 8959.0 RPM 8698.0 8959.0 FET 8698.0 8959.0 RPx 8698.0 8959.0 RPD 8698.0 8959.0 ROP 8748.5 9007.0 Page 12 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 3c-15a.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 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 Po~nt .............. undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999 Depth units. .. .. ..... Datum Specification Block sub-type...0 • 22-7uL-08 Insite 4.3 Memory 9007.0 8748.0 9007.0 32.4 36.7 TOOL NUMBER 93091 10811224 4.750 8725.0 Polymer 13.30 44.0 10.0 400 8.2 4.000 75.8 2.210 142.7 1.400 75.8 2.700 75.8 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 Page 13 C~ 3c-15a.tapx RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MwD050 OHMM 4 1 68 16 5 FET MwD050 HR 4 1 68 20 6 GR MwD050 API 4 1 68 24 7 ROP MwD050 FPH 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 8691 9007 8849 633 8691 9007 RPD MwD050 OHMM 0.23 1384.2 22.992 523 8698 8959 RPM MwD050 OHMM 0.17 1780.18 33.6204 523 8698 8959 RPS MWD050 OHMM 0.4 2000 117.268 523 8698 8959 RPX MWD050 OHMM 1.74 743.16 9.00606 523 8698 8959 FET MWD050 HR 1.67 164.48 35.425 523 8698 8959 GR MWD050 API 38.76 146.28 86.1276 514 8691 8947.5 ROP MWD050 FPH 0.12 167.16 31.8803 518 8748.5 9007 First Reading For Entire File..........8691 Last Reading For Entire File...........9007 File Trailer service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/14 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.......08/08/14 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.006 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 GR 8948.0 9267.5 FET 8959.5 9279.5 RPX 8959.5 9279.5 RPD 8959.5 9279.5 RPM 8959.5 9279.5 RPS 8959.5 9279.5 Page 14 • 3c-15a.tapx RoP 9007.5 9327.0 LOG HEADER DATA DATE LOGGED: 24-JUL-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9327.0 TOP LOG INTERVAL (FT): 9007.0 BOTTOM LOG INTERVAL (FT): 9327.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 34.9 MAXIMUM ANGLE: 36.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 93091 EWR4 ELECTROMAG. RESIS. 4 10811224 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.750 DRILLER'S CASING DEPTH (FT): 8725.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 13.70 MUD VISCOSITY (S): 51.0 MUD PH: 10.2 MUD CHLORIDES (PPM): 350 FLUID LOSS (C3): 6.4 RESISTIVITY (OHMM) AT TEMPERAT URE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 3.000 76.0 MUD AT MAX CIRCULATING TERM PERATURE: 1.600 148.9 MUD FILTRATE AT MT: 1.800 76.0 MUD CAKE AT MT: 6.000 76.0 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 Log~iny Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing ........ ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Page 15 • 3c-15a.tapx Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MwD060 HR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8948 9327 9137.5 759 8948 9327 RPD MWD060 OHMM 2.07 58.27 6.35546 641 8959.5 9279.5 RPM MWD060 OHMM 1.79 83.03 6.41897 641 8959.5 9279.5 RPS MWD060 OHMM 1.8 105.56 6.82058 641 8959.5 9279.5 RPX MWD060 OHMM 1.83 155.97 7.64329 641 8959.5 9279.5 FET MWD060 HR 0.5 29.79 8.06839 641 8959.5 9279.5 GR MWD060 API 26.9 116.53 84.69 640 8948 9267.5 ROP MWD060 FPH 0.61 255.47 39.863 640 9007.5 9327 First Reading For Entire File..........8948 Last Reading For Entire File...........9327 File Trailer Service name... .......STSLIB.007 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/08/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/08/14 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/08/14 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library scientific Technical services scientific Technical services Page 16 ~~ Physical EOF Physical EOF End Of LIS File 3c-15a.tapx Page 17 • • FINAL WELL REPORT MUDLOGGING DATA 3C-15A • Approved by: Provided by: E-1 EPOCH ~~1 ~ ~~~ ~~ ~ Compiled by: Ryan Massey Steven Pike James Foradas Date: 07/31 /2008 Distribution:8/8/08 ~~ L__~ ConocoPhillips Alaska, Inc. 3C-15A TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ............... 1.1 Equipment Summary ...................................... 1.2 Crew ............................................................... 2 WELL DETAILS .................................................... 2.1 Well Summary ................................................ 2.2 Hole Data ....................................................... 3 GEOLOGICAL DATA ............................................ 3.1 Lithostratigraphy ............................................. 3.2 Mudlog Summary ........................................... 3.3 Connection Gases .......................................... 3.4 Trip (Wiper) Gases ......................................... 3.5 Sampling Program /Sample Dispatch ........... 4 PRESSURE /FORMATION STRENGTH DATA .. 4.1 Pore Pressure Gradient Evaluation ................ 4.2 Quantitative Methods ..................................... 5 DRILLING DATA ................................................... 5.1 Survey Data .................................................... 5.2 Bit Record ...................................................... 5.3 Mud Record .................................................... 6 MORNING REPORTS ........................................... Enclosures: • 2"/100' Formation Log (MD &TVD) 2"/100' Drilling Dynamics Log (MD &TVD) 2"/100' LWD / Lithology Log (MD &TVD) 2"/100' Gas Ratio Log (MD &TVD) t. J EPOCH 1 ConocoPhillips Alaska, Inc. 3C-15A • 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summaro • • Parameter Equipment Type /Position Total Downtime Comments QGM Agitator (Mounted in possum Ditch as g belly) Flame ionization total gas & 0 chromato rah . Effective Circulating Density From Sperry-Sun 2080' to TD 0 ECD Hook Load / Wei ht on bit Totco Sensors 0 Mud Flow In Totco Sensors 0 Mud Flow Out Totco Sensors 0 Mudlogging unit computer HP Compaq Pentium 4 (X2, DML & 0 s stem Ri watch Mudlo In unit DAC box gg g In-unit data collection/distribution 0 center Pit Volumes, Pit Gain/Loss Totco Sensors 0 Pum Pressure Totco Sensors 0 Pum stroke counters Totco Sensors 0 Totco Well Monitoring Totco RigWatch Sensors 0 Com onents Rate of enetration Totco Sensors 0 RPM Totco Sensors 0 Tor ue Totco Sensors 0 1.2 Crew Mudloggers Years Da~s Sample Catchers Years Days Technician Days Ryan Massey 1 19 Jeff McBeth 0 26 Allen Williams 1 M. Chowdhury 2 13 Justin Vanderberg 0 26 Steven Pike 5 18 James Foradas 1 13 Unit Type Unit Number ~ ML030 ~' Years experience as Mudlogger .Z Days at wellsite between spud and total depth of well EPOCH 2 ConocoPhillips Alaska,lnc. 3C-15A • 2 WELL DETAILS 2.1 Well Summary Well: 3C-15A API Index #: 50-029-21426-01 Field: Kuparuk Field Surface Co-Ordinates: 1193' FNL, 1241' FEL Sec 14, T12N, R9E Borough: North Slope Primary Target Depth: 8877' State: Alaska TD Depth: 9327' Rig Name /Type: Doyon 15, Arctic Triple Suspension Date: Primary Target: Kuparuk Sands License: Spud Date: 7/6/2008 Ground Elevation: 48.00' Completion Date: 7/24/2008 RT Elevation: 84.66' Completion Status: Secondary Target: Depth: NONE Classification: TD Date: 7/24/2008 TD Formation: Kuparuk Days Testing: NONE Days Drilling: 25 2.2 Hole Data Maximum De th Mud C i / Shoe De th LOT Hole Section MD ft TVDSS ft TD Formation Weight (ppg) Dev. o. (mc) Coring as ng Liner MtD TVftSS (pj g 6.125" 8748' -2841' NA 9.6 32.5 NA 5.5" 2749' 2744' 16.0 4.75" 9329' -6460 Miluveach 12.0 36.8 NA 3.5" Additional Comments Daily Activity 7/4//2008 Arrive at the rig and begin rigging up Epoch unit. 7/5/2008 continue rigging up unit and prep for logging services. 7/6/2008 Changed out tubing spool, NU and test BOP. Pick up whip stock and milling BHA and run in hole. Displace well to LSND. Set whip stock and begin milling window. Pump sweeps as needed. 7/7/2008 Mill window and drilled 32' of new hole, pumped sweep. Perform LOT = 14ppg EMW. Pull out of hole and lay down Milling BHA. Picked up drilling BHA and run in hole. Service rig and drill ahead. 7/8/2008 Drill to 3280' MD, pumped sweeps for bit balling. Pull out of hole to change out mud motor. Run in hold and drill ahead to 3700' MD. 7/9/2008 Drill from 3613' to 4691' MD. 7/10/2008 Drill ahead from 4691' MD to 5264' MD. Pump sweep and dry job. Pull out of hole and lay down BHA. Pick up BHA and trip in hole. ~^ E~~~~ 3 ColnocoPhillips Alaska, Inc. 3C-15A • 7/11/2008 Run hole with BHA # 5. Service Rig. Drill ahead to 5922' MD, took losses while back reaming stand at 5922'. Monitor hole pumps off- static. Pumps on at 250 gpm losses 14bph. 7/12/2008 Condition hole with sweeps, Drill ahead adding LCM to mud system. Circulate and condition mud to a 9.5 ppg. Pump out of the hole to the window. Service rig, run in hole, reduce mud weight to 9.4 ppg. Drill ahead. 7/13/2008 Drill ahead from 6405' MD to 7475' MD. Pumping sweeps as needed. 7/14/2008 Drill ahead form 7475' MD to 8272' MD pumping sweeps as needed. 7/15/2008 Drill from 8263' to 8747' for interval TD. Pump sweeps as needed, short trip to 8330'. 7/16/2008 Pumps sweeps, short trip to 2765'. Run in hole, circulate and condition mud. Pull out of the hole and lay down BHA. Rig up and run in hole with 5-'/z' liner. 7/17/2008 Run in hole with liner, circulate at 6302'. Stuck 20' off bottom and circulate (1-2 BPM) and try to work liner. Release liner and pull out of hole. Pick up squeeze tools and run in hole. 7/18/2008 Service rig, perform cement squeeze. Pumped 48 bbls of 15.8 ppg cement with 21 bbls 9.3 ppg mud behind. Strip through annular and set packer. Circulate 2.5 BTU's the long way at 295 gpm, reserve out 2 DS volumes. Lay down 4" DP, test BOPS and run in hole for scraper run. 7/19/2008 Scraper run. POOH and lay down scrapper assembly. Rigup to run USIT log on wire line. Wireline logging. 7/20/2008 Wireline logging (USIT log) completed; TIH to landing collar with retainer; squeeze cement at shoe, reverse cement out of drill pipe. 7/21/2008 TIH to top of retainer with drilling assembly; cut and slip drilling line; drill retainer, shoe to 8748'MD, displace well with 12.0 ppg LSND mud in preparation to drill 20' of new hole. 7/22/2008 Drilled 20' of new hole to 8768' MD at 0316hrs; Circulated B/U and conducted LOT; Drilled ahead to 8795' MD circulating frequently and weighing up mud to 13.3 by 1804hrs. Drilling ahead at low ROP through Kuparuk C sands. 7/23/08 Drilled through Kuparuk C sands in Kuparuk B. Circulated and weighted up mud to 13.7bb1 in preparation to drill through Kuparuk A sands. Drilling stopped at 9008' MD due to washout. POOH at 1000hrs on 07/22/2008 to determine location of washout. Washout found, problems corrected, new BHA and string assembly 1616.27' (versus previous 1617.22') total length. Begin TIH with new BHA at 2315 hrs 07/22/2008. 7/24/08 Drilled through Kuparuk A sands. Currently drilling rathole in Miluveach to a projected TD of 9327' MD. Show report attached as separate document. 7/25/08 Finished drilling rathole in Miluveach formation. Reached TD of 9327' MD/6620' TVD at 1730hrs. Circulated B/U. Short trip to shoe on elevators at 8725'. Serviced Top Drive at shoe. TIH at bottom, watched, swabbed and surged. Trip gas during swabbing reached 536 units (Gas Chromatography itemized above). Circulated and changed to MW 13.5 to get YP to 29. TOOH to the 2.875" pipe to drop a 1.3" steel drift on slick line. 7/26/08 BROOH to 8725'. POOH on elevators. Lay down HWT DP, drill collars and BHA. R/U/ and TIH with 3.5" liner on 2.875 drill pipe. Circulate B/U at MD 2485' (117u), 4982' (178u), and 7542' (108u). GC Gas events at B/U at 4982' and 7542' recorded above. Continuing liner run. Rig down Epoch logging unit. 7/27/08 Finished liner run. Circulated B/U at bottom (411 u max gas). Circulated and conditioned mud for ~ EPQCH 4 ConocoPhillips Alaska, Inc. 3C-15A cementing. Pumped cement. Liner hung up at 6100. POOH on elevators racking back in derrick then lay down all 3.5" liner. P/U cleaned out assembly, TIH on cleaner run. 7/28/08 TIH on cleaner run, swabbing and circulating. Trip/wiper/connection gasses common throughout TIH below 8750' MD. Max gas per peak typically in 100-3306u range with two trip gas peaks at 647u and approx 1202u sampled with GC (see above). Continue wiping and circulating to remove cement encountered at depths below 7100'. 7/29/08 Cleaner Run completed. Circulated and conditioned hole on bottom; max gas while circulating during remainder of liner trip was 127u (see above). POOH, R/D cleaner BHA, swapped out BHA for liner trip. TIH with liner. Plan is to circulate B/U and monitor well every 17 stands. B/U Gas 36u at 2738' MD (see above). Seventeen more stands in place. Circulating at 4900' MD. 7/30/08 Liner run continued, circulating B/U every seventeen stands. Max gas at 5010'MD was 112u and 69u at 7282'MD. Continued to wash and ream, circulating B/U as needed (max Gas 39u) until 89 stands, two singles and cement head were in. Tagged bottom at approx. 1730hrs and circulated. Max gas 28u. Dropped 3/" ball and pressured up in prep for cementing. Started cementing. • • EPOCH ConocoPhillips Alaska, Inc. 3C-15A 3 GEOLOGICAL DATA 3.1 Lithostratigraphy • LWD tops refer to provisional picks by the CPAI well site geologist. FORMATION PROGNOSED LWD PICK MD ft SSTVD ft MD ft) SSTVD (ft TOW 2,697' -2,609' 2,749' -2,659' BOW -- -- 2,762' -2,672' Top West Sak D 3,255' -3,135' 3,247' -3,123' Base West Sak 3,823' -3,585' 3,794' -3,561' C-70 -- -- 7,210' -5,263' HRZ -- -- 8,073' -5,587' Base HRZ/Top Kalubik 8,300' -5,743' 8,489' -5,845' 5 1/2" int casing pt 8,523' -5,889' 8,748' -6,062' Top Kuparuk D 8,641' -5,974' 8732' -6049' Top Kuparuk C 8,818' -6,119' 8811' -6115' Top Kuparuk B 8,896' -6,181' 8877' -6170' Top Kuparuk A3 9,073' -6,323' 9030' -6295' Top Kuparuk A2 9,119' -6,360' 9078' -6333' Base Kprk / Miluveach 9,206' -6,431' 9156' -6397' TD 9,406' -6,594' 9329' -6538' ~ EPOCH ConocoPhillips Alaska, Inc. 3C-15A 3.2 Mudlog Summary West Sak D Group (-3123' to -3561' SSTYD) Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 222 14 118 600 3 173 This interval from around 3,247 feet measured depth (MD) to about 3,794 feet MD and consists of alternating sequences of tuffaceous claystone, tuffaceous siltstone with some clay and shale with very thin and sparse sand lenses. The tuffaceous claystone in this section is comprised of very light gray to gray with occasional medium gray hues; very poor to poorly indurated; dull earthy luster; very slight ashy texture to clayey to silty texture; irregular cuttings habit; silt and sand grains accumulate on the outside of masses; silt to fine upper size volcanics with minor lithics; pasty to mushy texture; no sample fluorescence, cut, stain, or oil odor present. The average tuffaceous siltstone in the West Sak D is composed of light gray to medium gray; dull earthy luster; silty to gritty to slightly sandy texture; ashy clay matrix dominates; earthy irregular fracture; moderately cohesive and adhesive; interbedded with clays and sands; common reddish brown to black oil present; appears to be interbedded within silty sand fraction; fine lower sand grains stained yellowish brown; dull orange fluorescence; light milky white cut; slight oil odor present. The average claystone in this unit are comprised of gray with brownish hues becoming light gray to medium gray with depth; very tough to malleable; very cohesive and adhesive; clayey to silty to slightly gritty; irregular cuttings habit; dull earthy luster; common siltstone to very fine upper sand interbedded throughout; sand grains accumulate to the outside of clay; silt becoming more common with depth; sand grains are dominantly sub angular quartz with common volcanic lithics; no sample fluorescence, cut, stain, or oil odor present. Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 3351 600 69196 359 651 753 689N 302 300 C-70 Group (-5263' to -5587' SSTVD) Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 205 12 109 61 14 37 This section which starts at around 7210 feet MD to approximately 8073 feet MD is comprised of alternating beds of tuffaceous claystone, tuffaceous siltstone, tuffaceous shale with claystone, carbonaceous shale and shale and sands. The average sands in this sequence are comprised of gray to pale orange light gray; clasts size ranges from very coarse upper to fine upper; angular to sub angular; moderately developed sphericity; fair to very poor shorting; dominant fraction is coarse grain to medium upper; matrix sand composed of fine grained polished texture; sub mature nature; non to very slight silica cement; abundant tuffaceous clay, silt and ash structured matrix materials; poor fillings and loosely attached; of >70% quartz with lithic materials; loosely attached with>10 silica and lithics materials; poor porosity and permeability; no visible fluorescence or oil cut in samples. ~ EPOCH ConocoPhillips Alaska,lnc. 3C-15A Mostly the tuffaceous siltstones and claystones in this section are composed of medium gray to light gray with pale orange hues of both color; poor to moderate induration; crumbly to crunchy; mushy to pasty; slightly stiff in parts; slight to some moderate cohesive; non to slightly adhesive; earthy to amorphous fracture; massive to sub nodular habit; dull to earthy luster; silt to gritty to clayey ashy texture; gradation massive beds of tuffaceous silt, tuffaceous clay and conglomerate sand with laminae; no fluorescence or oil cut in sample. Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 7438' 61 15709 653 186 43 49 NA NA HRZ Group (-5587' to -5845' SSTVD) Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 146 8 77 136 4 61 This section which was encountered at approximately 8073 feet MD to approximately 8498 feet MD and is comprised of shale, carbonaceous shale, tuffaceous shale, tuffaceous siltstone and with a lesser percentage of sands. The carbonaceous shales in this section is comprised mainly of blackish red to very dark red to reddish black hues; slightly tacky to stiff; brittle to somewhat elastic in places; overall splintery fracture with some very planar; platy to somewhat tabular cuttings habit; very resinous to almost vitreous in places; very smooth texture with some almost crystalline; very thin throughout with some very fissile in places; no • visible sample fluorescence was observed; no solvent cut. However, the shales in HRZ group are composed primarily of light gray to dark gray with some very pale green and yellowish gray hues; mostly pasty to mushy; very brittle to mostly crumbly; mostly irregular fracture with some blocky to slightly planar in places; predominantly amorphous cuttings habit with a small amount slightly tabular; waxy to somewhat greasy luster; very silty texture with some fairly gritty; thin to thick bedded; interbedded with very fine grained sand lenses and carbonaceous shale with abundant dark colored lithic fragments throughout; bright deep gold colored sample fluorescence approximately 30% of sample; instant milky white solvent cut; poor apparent sample porosity; abundant pyrite crystals throughout. While the sands in the HRZ are mostly medium gray to dark gray with some white to light gray and clear; predominantly quartz grain sand matrix; lower to upper fine grain size with some lower medium; fair to well sorted throughout; well rounded to subrounded; moderate sphericity; some sand grains slightly frosted in places; faint yellow gold sample fluorescence, approximately 20%; instantaneous bright milky white solvent cut; fair to poor apparent porosity. Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 8484' 136 27563 2864 2095 500 502 250 239 8473' 108 21433 2068 1297 333 343 136 92 • ~~~~~ 8 ConocoPhillips Alaska,lnc. 3C-15A Kuparuk D Group (- 6049' to 6115' SSTVD) Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 103.1 2.4 35.2 21 1 7.4 This interval from around 8,732 feet MD to about 8,811 feet MD consists of mainly alternating sequences of shale and sand, with siltstone in lesser amounts. The shale in this sequence occurs primarily in the interval from around 8,732 feet MD to about 8,770 feet MD. It is comprised of mostly medium to light gray; crumbly to very brittle throughout; irregular to blocky to somewhat planar fracture; slightly tabular to amorphous cuttings habit, with rare butter curl PDC; greasy to slightly waxy luster; slightly fissile in places; thin laminae interbedded with thin lenses of sand and thin beds of siltstone; no visible sample fluorescence; no solvent cut. The representative siltstone characteristic of this formation elsewhere is poorly represented in this well. Where present it consists of light gray to dominantly medium gray with common brownish hues; firm; crumbly; irregular fracture; platy to irregular cuttings habit; trace very fine lower sand size clasts interbedded throughout; silty to gritty to slightly sandy texture in spots; dull earthy luster; thin beds of carbonaceous material interbedded throughout as parallel laminae and occasionally as contorted laminae. Sand lenses in the shales described above make up approximately 10% of the unit in the interval from around 8,732 feet MD to about 8,770 feet MD. These sands are composed primarily of very fine to fine translucent-quartz grains, with dark lithic fragments and pyrite also present. The sands exhibit bright gold to dull orange fluorescence, and weak milky white solvent cut. The basal portion of the Kuparuk D is represented by sands in the interval from around 8,770 feet MD to about 8,811 feet MD. The basal sands are composed of clear, translucent, light gray and yellowish orange hues of predominantly very fine to upper fine textures of quartz. Individual grains are subrounded to subangular, with moderate to low sphericity. Rare pyrite and glauconite grains in similar textural and sphericity ranges are also part of the sand matrix. The sands are interbedded with thin lenses of the shales described above for this member. The yellowish orange oil stained sands in this unit exhibit weak yellow brown fluorescence and weak pale milky white solvent cut. If should be noted that these descriptions are based on poor quality samples. This was caused by abundant quantities of mud additives (e.g. Calcarb) and LCM mixed in with relatively few cuttings. Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 8750' 21 4102 325 184 123 57 NA NA Kuparuk C Group (-6115' to -6169' SSTVD) Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 159.7 5.5 28.4 70 2 15.5 The Kuparuk C is poorly developed in this well and occurs in the interval from around 8811 feet MD to about 8876 feet MD. The member consists almost entirely of sand interbedded in places with gray shales. The sands are typically greenish gray and not oil stained, and rarely brown with reddish hues where oil stained; fine to medium grained translucent to smoky quartz forms the bulk of the sand, but siderite and ~ EPOCH ~ 9 ConocoPhillips Alaska, Inc. 3C-15A glauconite are also present as accessories. No oil odor was detected; however a yellow fluorescence and streaming white cut was observed in the oil stained samples which made up a minor portion of the sample. As above, these descriptions are based on poor quality samples caused by abundant quantities of mud additives (e.g. Calcarb) and LCM mixed in with relatively few cuttings. Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 8818' 21 1590 75 37 NA NA NA NA 8877' 70 1304 95 61 12 26 NA NA Kuparuk B Group (-6170' to -6294' SSTVD) Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 137.1 5.6 42.9 238 2 81.2 This section begins around 8877 feet MD to approximately 9029 feet MD is comprised of siltstone and sands. The siltstone intervals are light gray to gray with some grayish brown hues very pasty to slimy; crunchy to somewhat crumbly; irregular fracture; amorphous cuttings habit; very earthy to slightly dull luster; silty texture with some slightly gritty in places; thinly interbedded with thin beds of shale and thin beds of tuffaceous siltstone tuffaceous claystone; no sample fluorescence; no solvent cut; no oil indicators were observed. The sand intervals are white to light gray with some clear, translucent, and dark yellowish brown hues; composed predominantly of fairly to poorly sorted upper very fine to upper fine quartz matrix, though lower medium grain size grains are also present. Individual grains are very well rounded to subangular to angular with moderate sphericity. Some grains appeared to be slightly frosted in places, and most were polished throughout. Golden yellow fluorescence was observed in 30% of the sample, as well as milky white solvent cut; no other petroleum indicators were present. Samples were generally of good quality with little mixing of mud additives and LCM materials. Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 8963' 238 4595 370 243 154 68 NA NA Kuparuk A3 Group (-6295' to -6332' SSTVD) Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 149.0 22.6 85 738 28 312 This section begins around 9030 feet MD to approximately 9077 feet MD is comprised of sand siltstone and shale. The sand in this section is comprised of white to clear with some translucent and light gray; mostly quartz grain sand matrix; upper very fine to upper fine with some lower medium grained sand; fair to poorly sorted; well rounded to subrounded with some very angular to subangular; moderate to high sphericity; abundant petroleum hydrocarbon etching was observed on sand grains; faint golden yellow sample fluorescence; instant milky white solvent cut; fair to good apparent sample porosity. ~PQCH 10 ConocoPhillips Alaska, Inc. 3C-15A The siltstones are composed of medium gray to dark gray with some light gray hues; tacky to lumpy; crumbly to crunchy to almost brittle; irregular fracture; amorphous cuttings habit; dull to somewhat earthy; very silty grading to very gritty in places; very thin interbedded with thin lenses of sand and thin beds of shale and carbonaceous shale; bright yellow gold sample fluorescence; milky white solvent cut; no oil odor present. Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 9047' 738 137256 11418 7385 2355 2300 2008 990 9060' 512 88590 6060 4087 1600 1025 1064 900 Kuparuk A2 Group (-6333' to -6378' SSTVD Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 124 8 70 950 82 412 This section begins around 9078 feet MD to approximately 9133 feet MD is comprised of sand siltstone and lesser amounts of shale. The sands in this formation are composed of white to light gray with some clear to translucent and moderate to dark yellowish brown hues; predominantly quartz sand matrix; upper very fine to upper fine with some lower medium grain as well; fair to poorly sorted throughout; very well rounded to subrounded with some subangular to very angular; moderate sphericity; some grains appeared to be slightly frosted in places; most were polished throughout; faint golden yellow sample fluorescence approximately 30°/a; instant milky white solvent cut. The siltstone are made up of siltstone =dark gray to medium gray; mostly stiff to slightly firm; brittle to somewhat crumbly; irregular fracture; amorphous cuttings habit; dull to slightly earthy; very silty texture with some slightly gritty; very thin interbedded with thick lenses of sand very thin lenses of shale; very faint golden yellow sample fluorescence; instant milky white solvent cut. Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 9090' 950 171672 9764 6695 2074 2000 1013 600 EPOCH 11 ConocoPhillips Alaska, Inc. 3C-15A 3.3 Connection Gases • • Connection Gases 1 unit = 0.05% Methane Equivalent De th Gas over BGG feet units 2810 175 2906 34 3000 5 3189 92 3377 71 3755 5 3943 98 4037 72 4130 76 4224 37 4318 42 4413 62 4886 4 4980 5 5072 40 5072 40 5167 11 5358 7 5433 7 5547 8 5642 8 5736 4 6019 15 6114 13 6208 16 6397 11 6491 15 6586 29 6775 5 6569 12 6963 16 7058 7 7152 4 7247 17 7341 5 7435 54 7530 11 7627 20 7719 12 7813 8 7907 23 8191 7 8285 53 8377 25 8474 63 8568 82 EPOCI~ 12 ConocoPhillips Alaska, Inc. 3C-15A 3.4 Trip (Wiper) Gases 1 unit = 0.05% Methane Equivalent • • De th Tri to Gas Downtime feet feet units hours 5264' 0' 464 12 6303' SHOE 331 5.5 8309' 7719' 225 1.0 8748' 8303' 213 1.0 8719' SHOE 610 12 8748' 0' 14 144 9008' 0' 30 24 9329' 8800' 537 3.5 9329' 0 47 8 9329' 0 1202 24 9329 0 112 24 3.5 Sampling Program /Sample Dispatch Set T e /Pur ose Fre uenc Interval Dis atched to CPAI A Washed Samples Set owner: CPAI 50' and 10' 2780 - 9329' Bayview Geologic Facility 619 East Ship Creek Ave Ste 14 Anchorage, AK 99501 Attn: D. P o ski 265-6340 7 Sample frequency was locally altered according to drill rate constraints and zones of interest. Set T e /Pur ose Fre uenc Interval Dis atched to CPAI B Washed Samples Set owner: CPAI 50' and 10' 2780' - 9329 Bayview Geologic Facility 619 East Ship Creek Ave Ste 14 Anchorage, AK 99501 Attn: D. Prz o~ski 265-6340 EPOCH 13 • 4 PRESSURE /FORMATION STRENGTH DATA Cond~hillips Alaska, Inc. 3C-15A The pore pressure gradient (PPG) is estimated to have varied from 9.6 in the West Sak D formation to 13.5 in the Kuparuk A2 Group. The mud weight was raised from 9.9 ppg to 13.7 before drilling the Kuparuk sands. 4.1 Pore Pressure Gradient Evaluation F ti Primary Secondary Interval To s Pore Pressure EMW orma on Interval Lithology Lithology MD SSTVD Min Max Trend Trend Indicators (%) ("~o) ft ~ Top West Sak D TffCI Sh Sltst, Sn 3,247' -3,123' 9.6 9.6 FG,CG, TG Increase C-70 TffSlst, TffCI st, Sltst Sn 7,210' -5,263' g.2 9.3 Slight Increase FG,CG,TG HRZ Sh, Clyst, TffSltst Sn g,073' -5,587' 9.2 9.2 NO Increase FG,CG, TG Base HRZ/Top Sh, Slst, Clyst Sn 8,489' -5 845' 9.2 9.2 No FG TG CG Kalubik , Increase , , Top Kuparuk D Sn, Slst, Sh 8732' -6049' 9.4 9.4 Increase FG,CG, TG Top Kuparuk C Sn, Slst Sh 8811' -6115' 13.1 13.1 Increase FG,CG, TG Top Kuparuk B Sn, Slst Sh 8877' -6170' 13.1 13.1 Increase FG,CG, TG To Ku aruk A3 Sn, Sltst Sh 9030' -6295' 13.1 13.5 Increase FG,CG, TG Top Kuparuk A2 Sn, Sltst Sh 9,078' -6,333' 13.3 13.5 Incrlease FG,CG, TG Base Kprk / Sh, Sltst Sn 9156' -6397' 13.0 13.1 Slight FG CG TG Miluveach Increase , , NOTE: TffClyst =Tuffaceous Claystone, TffSltst= Tuffaceous Siltstone, Clyst =Claystone/Clay, Sd =Sand, Sltst =Siltstone, Sh =Shale, Sn = Sand, Coal=Co ~1 EPUCH 14 Cono~hillips Alaska, Inc. 3C-15A 4.2 Quantitative Methods C] 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. ~ EPOCH 15 ConocoPhillips Alaska, Inc. 3C-15A 5 DRILLING DATA 5.1 Survey Data • r Measured Depth ft Incl. () ~°-iom• () True Vertical De th ft Latitude (ft) N+,S- Departure (ft) E+,W- Vertical Section ft Dogleg Rate °/100ft 0.00 0.00 0.00 0.00 O.OON 0.00E 0.00 TIE-IN 36.96 0.00 0.00 36.96 O.OON 0.00E 0.00 0.00 99.66 0.07 337.58 99.66 0.04N 0.01 W 0.04 0.11 199.66 0.18 76.84 199.66 0.13N 0.12E 0.10 0.20 299.66 0.32 85.57 299.66 0.18N 0.55E 0.05 0.14 399.66 0.37 110.87 399.66 0.09N 1.13E -0.18 0.16 499.66 0.27 121.70 499.66 0.15S 1.63E -0.54 0.12 599.66 0.23 94.40 599.65 0.29S 2.03E -0.77 0.12 699.66 0.32 139.18 699.65 0.51 S 2.41 E -1.08 0.23 799.66 0.35 163.16 799.65 1.02S 2.68E -1.64 0.14 899.66 0.37 172.97 899.65 1.63S 2.81 E -2.26 0.06 999.66 0.43 199.86 999.65 2.30S 2.72E -2.89 0.19 1099.66 0.48 216.94 1099.64 2.99S 2.34E -3.47 0.14 1199.66 0.45 229.74 1199.64 3.58S 1.79E -3.91 0.11 1299.66 0.23 234.91 1299.64 3.95S 1.33E -4.15 0.22 1399.66 0.32 180.10 1399.64 4.34S 1.16E -4.50 0.27 1499.66 0.88 174.60 1499.63 5.39S 1.24E -5.53 0.56 1599.66 1.18 171.30 1599.62 7.17S 1.46E -7.31 0.31 1699.66 1.23 158.54 1699.59 9.19S 2.01 E -9.40 0.27 1799.66 1.23 158.04 1799.57 11.18S 2.81 E -11.53 0.01 1899.66 1.25 150.57 1899.55 13.13S 3.74E -13.64 0.16 1999.66 1.68 132.31 1999.52 15.06S 5.36E -15.91 0.63 2099.66 1.97 134.40 2099.46 17.25S 7.68E -18.60 0.30 2199.66 1.68 135.43 2199.41 19.50S 9.93E -21.32 0.29 2299.66 1.88 122.74 2299.37 21.43S 12.34E -23.78 0.44 2399.66 2.47 125.39 2399.29 23.57S 14.48E -26.61 0.60 2499.66 5.42 167.72 2499.06 29.43S 18.24E -32.97 3.96 2599.66 9.40 169.12 2598.21 42.07S 20.79E -45.85 3.98 2699.66 13.45 169.74 2696.21 61.54S 24.40E -65.62 4.05 2749.00 14.99 173.98 2744.03 73.53S 26.09E -77.66 3.77 2802.83 17.17 180.80 2795.76 88.41 S 26.71 E -92.24 5.35 2847.64 17.26 186.07 2838.56 101.63S 25.92E -104.88 3.49 2866.19 17.83 188.21 2856.25 107.18S 25.22E -110.10 4.64 2902.23 18.79 192.16 2890.47 118.31 S 23.21 E -120.41 4.35 2932.61 18.99 195.29 2919.21 127.86S 20.87E -129.12 3.40 2960.92 19.20 198.14 2945.97 136.73S 18.21 E -137.08 3.38 2991.61 19.39 201.14 2974.93 146.28S 14.80E -145.51 3.29 3027.43 20.08 204.49 3008.65 157.42S 10.11 E -155.19 3.70 3057.12 21.86 203.50 3036.37 167.13S 5.79E -163.57 6.11 3083.75 23.44 205.59 3060.95 176.45S 1.53E -171.58 6.66 EPOCH 16 ConocoPhillips Alaska, Inc. 3C-15A • • 3113.94 24.11 211.00 3088.58 187.16S 4.24W -180.57 7.55 3149.40 24.52 215.01 3120.90 199.39S 12.20W -190.52 4.80 3193.62 26.11 214.98 3160.87 214.88S 23.04W -202.92 3.60 3244.77 28.62 214.50 3206.29 234.20S 36.43W -218.43 4.93 3293.20 30.17 214.58 3248.48 253.78S 49.91 W -234.17 3.20 3338.29 30.38 214.29 3287.42 272.53S 62.77W -249.25 0.57 3383.15 32.11 217.45 3325.78 291.37S 76.41 W -264.23 5.31 3432.36 33.56 222.07 3367.13 311.85S 93.48W -279.98 .5.88 3476.60 35.75 222.22 3403.52 330.51 S 110.36W -293.99 4.95 3527.71 37.54 222.62 3444.53 353.02S 130.94W -310.86 3.53 3575.12 38.91 223.62 3481.77 374.43S 150.99W -326.78 3.17 3619.91 40.73 227.18 3516.18 394.55S 171.42W -341.36 6.51 3667.47 41.91 227.73 3551.90 415.78S 194.55W -356.37 2.60 3714.81 42.19 229.65 3575.05 436.71 S 218.37W -370.91 2.78 3764.12 41.87 233.13 3623.68 157.31 S 244.15W -384.66 4.77 3809.05 41.76 234.79 3657.17 474.93S 268.38W -395.90 2.48 3855.59 41.73 239.13 3691.90 491.82S 294.34W -406.00 6.21 3903.43 41.93 241.26 3727.55 507.67S 322.02W -414.69 3.00 3948.38 42.22 245.27 3760.92 521.21 S 348.91 W -421.32 6.01 3997.16 42.49 247.98 3796.97 534.25S 379.07W -426.67 3.78 4042.39 42.02 250.62 3830.45 545.OOS 407.52W -430.23 4.06 4091.77 40.60 254.33 3867.55 554.83S 438.59W -432.24 5.73 4137.53 41.17 257.04 3902.15 562.23S 467.60W -432.40 4.07 4186.16 42.78 260.52 3938.30 568.54S 499.50W -430.81 5.82 4227.32 43.77 264.51 3968.28 572.20S 527.46W -427.60 7.07 4280.31 44.89 266.14 4006.18 575.21 S 564.36W -421.60 3.01 4317.33 45.46 269.64 2032.28 576.18S 590.59W -416.19 6.88 4375.11 45.58 275.00 4072.78 574.51 S 631.76W -404.61 6.62 4420.70 46.12 279.55 4104.55 570.36S 664.19W -392.74 7.26 4469.44 45.61 283.55 4138.49 563.37S 698.45W -377.66 5.98 4511.46 46.89 284.39 4167.55 556.04S 727.90W -363.43 3.37 4563.85 49.08 284.80 4202.61 546.23S 765.57W -344.79 4.22 4609.57 50.87 286.99 4232.02 536.63S 799.23W -327.34 5.36 4657.98 53.04 287.82 4261.82 525.22S 835.61 W -307.47 4.68 4704.70 53.64 290.54 4289.75 512.91 S 871.OOW -286.96 4.84 4752.98 54.38 293.01 4318.12 498.42S 907.27W -264.12 4.41 4801.22 55.88 293.40 4345.70 482.82S 943.64W -240.19 3.18 4845.51 57.97 294.71 4369.87 467.69S 977.53W -217.31 5.33 4895.42 58.58 296.94 4396.12 449.19S 1015.73W -190.13 3.99 4939.74 58.91 298.86 4419.12 431.47S 1049.22W -164.82 3.78 4985.25 59.14 300.68 4442.54 412.09S 1083.08W -137.83 3.47 5034.98 58.96 304.69 4468.12 389.07S 1118.97W -106.81 6.92 5085.48 59.64 308.57 4493.91 363.16S 1153:80W -73.25 6.74 5129.65 61.82 310.32 4515.51 338.68S 1183.55W -42.30 6.03 5175.36 62.94 311.44 4536.70 312.18S 1214.17W -9.17 3.27 5224.01 64.16 311.01 4558.37 283.47S 1246.93W 26.61 2.63 5270.54 65.49 313.26 4578.16 255.22S 1278.15W 61.57 5.23 5318.27 65.19 313.39 4598.08 225.46S 1309.71 W 98.08 0.68 ~ EPOCH 17 ConocoPhillips Alaska, Inc. 3C-15A • 5365.89 64.92 313.74 4618.16 195.70S 1340.99W 134.52 0.87 5412.57 64.69 313.899 4638.03 166.46S 1371.47W 170.27 0.57 5459.77 64.73 313.02 4658.20 137.11 S 1402.45W 206.25 1.67 5507.05 66.69 312.37 4677.65 107.89S 1434.12W 242.26 4.33 5556.86 66.79 310.67 4697.32 77.55S 1468.38W 279.98 3.14 5601.62 67.51 309.36 4714.70 51.03S 1499.97W 313.36 3.14 4648.68 67.38 310.83 4732.75 23.04S 1533.22W 348.56 2.90 5696.14 67.49 309.35 4750.96 5.18N 1566.75W 384.05 2.89 5745.50 68.87 305.96 4769.31 33.16N 1603.02W 419.98 6.96 5790.59 68.64 307.41 4785.65 58.27N 1636.72W 452.49 3.04 5836.81 68.31 307.46 4802.61 84.40N 1670.86W 486.11 0.72 5880.62 68.22 307.55 4818.84 109.18N 1703.15W 517.96 0.28 5935.58 67.71 308.09 4839.46 140.42N 1743.39W 558.01 1.30 5980.38 67.50 308.41 4856.52 166.06N 1775.92W 590.76 0.81 6027.35 67.20 308.07 4874.61 192.89N 1809.97W 625.03 0.92 6074.04 66.97 307.75 4892.79 219.32N 1843.90W 658.88 0.80 6120.34 66.65 307.07 4911.02 245.17N 1877.70W 692.14 1.52 6167.95 66.33 306.87 4930.02 271.43N 1912.58W 726.06 0.77 6214.57 65.96 306.28 4948.87 296.83N 1946.82W 758.99 1.40 6262.28 65.70 306.82 4968.40 322.76N 1981.79W 792.60 1.17 6309.66 65.58 305.82 4987.95 348.32N 2016.56W 825.82 1.94 6355.79 65.30 306.20 5007.12 372.99N 2050.50W 857.96 0.96 6402.55 66.58 307.35 5026.19 398.55N 2084.70W 891.04 3.54 6451.71 66.78 307.40 5045.65 425.95N 2120.58W 926.31 0.42 6498.29 66.81 307.64 5064.00 452.03N 2154.53W 959.82 0.48 6545.99 66.51 307.83 5082.90 478.83N 2189.17W 994.21 0.73 6591.78 66.52 308.17 5101.15 504.69N 2222.26W 1027.30 0.68 6637.89 66.87 310.07 5119.39 531.41 N 2255.11 W 1061.18 3.86 6686.68 66.68 309.95 5138.63 560.23N 2289.45W 1097.45 0.45 6734.18 66.38 309.89 5157.55 588.19N 2322.87W 1132.67 0.64 6781.47 65.92 309.31 5176.67 615.76N 2356.20W 1667.48 1.48 6828.88 66.47 310.00 5195.80 643.44N 2389.59W 1202.42 1.77 6922.89 67.26 310.86 5232.74 699.51 N 2455.39W 1272.74 1.19 7017.52 66.67 311.53 5269.77 756.86N 2520.92W 1344.24 0.90 7111.79 66.04 311.13 5307.58 813.89N 2585.77W 1415.26 0.77 7207.11 65.87 311.59 5346.42 871.41 N 2651.10W 1486.88 0.48 7300.31 67.34 312.32 5383.42 928.60N 2714.71 W 1557.76 1.73 7395.97 66.38 311.71 5421.01 987.48N 2780.06W 1630.70 1.16 7488.58 68.18 311.10 5456.78 1043.97N 2844.13W 1701.01 2.04 7584.27 68.18 311.10 5491.42 1100.60N 2913.03W 1772.63 3.49 7678.77 68.99 307.70 5525.01 1154.66N 2982.89W 1841.98 0.42 7772.67 68.78 307.68 5558.83 1208.21 N 3052.21 W 1910.71 0.22 7866.95 68.59 308.18 5593.10 1262.19N 3121.50W 1979.84 0.51 7961.62 68.24 308.22 5627.93 1316.61 N 3190.69W 2049.39 0.38 8010.03 67.55 308.42 5646.15 1344.42N 3225.88W 2084.89 1.48 8056.20 65.19 307.95 5664.65 1370.57N 3259.12W 2118.30 5.20 8086.23 63.62 307.41 5677.62 1387.12N 3280.56W 2139.55 5.47 8188.24 61.91 307.53 5692.27 1404.43N 3303.15W 2161.81 5.35 8150.23 61.00 307.29 5707.56 1421.51 N 3325.47W 2183.78 2.92 E~~ ~~ 18 ConocoPhillips Alaska, Inc. 3C-15A • 8183.20 58.22 307.02 5724.24 1438.68N 3348.13W 2205.93 8.46 8213.31 56.40 306.72 5740.50 1453.89N 3368.40W 2225.58 6.10 8245.08 54.33 307.15 5758.55 1469.59N 3389.30W 2245.88 6.61 8275.42 51.90 307.15 5776.76 1484.25N 3408.64W 2264.77 8.01 8307.49 49.70 306.94 5797.03 1499.22N 3428.47W 2284.10 6.88 8339.16 47.32 305.97 5818.01 1513.32N 3447.55W 2302.39 7.86 8371.62 44.89 306.36 5840.51 1527.14N 3466.43W 2320.35 7.54 8401.44 42.63 307.08 5862.05 1539.44N 3482.96W 2336.31 7.76 8434.34 39.83 308.09 5886.79 1552.66N 3500.15W 2353.30 8.75 8480.48 36.15 308.65 5923.15 1570.29N 3522.41 W 2375.78 8.01 8528.50 34.87 308.85 5962.24 1587.74N 3544.17W 2397.98 2.68 8575.36 33.58 309.30 6000.98 1604.36N 3564.63W 2419.05 2.81 8623.31 31.82 309.84 6041.33 1620.85N 3584.60W 2439.89 3.72 8669.38 31.44 309.77 6080.56 1636.32N 3603.16W 2459.39 0.83 8709.11 32.53 310.08 6114.25 1649.83N 3619.30W 2476.40 2.77 8782.74 32.42 310.25 6176.37 1675.33N 3649.51 W 2508.45 0.19 8804.67 32.81 310.06 6194.84 1682.95N 3658.54W 2518.03 1.84 8833.79 33.49 309.41 6219.22 1693.13N 3670.79W 2530.87 2.63 8877.81 33.49 309.18 6255.94 1708.51 N 3689.59W 2550.34 0.29 8924.57 35.28 310.37 6294.52 1725.41 N 3709.88W 2571.65 4.09 8970.47 36.70 309.79 6331.66 1742.77N 3730.51 W 2593.49 3.18 9006.82 36.43 309.59 6360.86 1756.60N 3747.18W 2610.94 0.81 9038.00 36.41 309.48 6385.95 1768.39N 3761.45W 2625.83 0.22 9065.54 36.20 309.78 6408.14 1778.79N 3774.01 W 2638.96 1.00 9101.04 35.29 309.68 6436.95 1792.04N 3789.96W 2655.68 2.57 9132.63 35.11 310.10 6462.77 1803.72N 3803.93W 2670.39 0.96 9160.36 34.88 310.13 6485.48 1813.97N 3816.10W 2683.27 0.83 9194.52 35.28 310.02 6513.44 1826.61 N 3831.12W 2699.17 1.19 9226.25 36.03 309.76 6539.22 1838.47N 3845.31 W 2714.11 2.41 9253.88 36.82 310.88 6561.45 1849.08N 3857,82W 2727.44 3.74 9290.19 36.85 309.84 6590.51 1863.18N 3874.40W 2745.13 1.72 9327.00 36.85 309.84 6619.97 1877.32N 3891.35W 2762.95 0.00 EPQCH 19 • 5.2 Bit Record Cono~hillips Alaska, Inc. 3C-15A Bit Size Make Type / S# Jets / Depth In Total Bit Aug' O WOB RPM PP Wear BHA TFA MD / Footage Hrs h ft (Klbs) (psi) r l 1 6.125" Smith M513/JX5823 5x10 2794' 499' 15.51 65 2-11 60 1666 1-3-BT-A-X-I- CT-BHA #2,3 2 6.125" Smith M513/JX5823 5x10 3286' 1976' 46.69 65 2-11 61 1941 1-2-CT-G-X-I- NO-DTF ~ 2rr1 6.125" Smith M513/JX5823 5x10 3286' 1976' 46.69 65 2-11 61 1941 1-3-BT-A-X-I- CT-BHA ~ 3 6.125" S ty FM2543/501082 3x13 5262' 3486' 105.8 60 4-10 66 2281 0-1-WT-S-X-I- NO TD #5 DBS - 5 4.75 Hughes HC404Z/7010257 4X12 8748' 259' 13 20 5-10 65 2550 #7 6 4 75" S ty FM3443/10969090 4x12 9008' 321' 36 9 7-12 70 3450 #8 . DBS 5.3 Mud Record Contractor: MI SWACO Mii~l Tvna• I SNf~ Date Depth MW ECD VIS s/ t PV YP Gels FL cc FC Sols % OIW Ratio Sd % pH CI mill Ca mlll 7/5/08 2751' 9.8 9.5 49 11 19 6/7/8 7.5 1/- 6.5 /94 Tr 9.8 550 20 7/6/08 3070' 9.8 9.5 53 14 22 6/7/8 7.5 1 /- 7 /93 Tr 9.8 500 12 7/7/08 3613' 9.8 9.6 60 17 23 5/8/9 5.5 1/- 7.5 2/91 Tr 10.1 600 12 7/8/08 4691' 9.8 9.5 54 16 20 5/12/19 6 1/- 7.75 2/91 Tr 9.9 500 8 7/9/08 5262' 9.8 9.6 58 20 25 8/18/22 4.9 1/- 7.5 2/91 Tr 10.0 550 22 7/10/08 5922' 9.8 9.5 56 19 22 8/19/25 4.5 1/- 7.5 1/92 Tr 10.0 500 20 7/11 /08 6405' 9.5 9.2 49 21 27 9/20/25 5.5 1 /- 7 1 /92 Tr 9.6 300 8 7/12/08 7475' 9.4 9.1 51 13 19 6/12/19 5.2 1/- 6 1/93 Tr 9.8 300 12 7/13/08 8263' 9.4 9.1 52 13 16 6/10/15 5.1 1/- 6 1/93 Tr 9.8 100 20 7/14/08 8748' 9.4 9.1 46 14 19 7/10/14 5 1/- 6 1/94 0.1 9.9 600 60 7/15/08 8748' 9.5 9.2 41 10 14 4/8/11 5 1/- 6 1/94 0.1 10.0 400 40 7/16/08 8748' 9.6 9.3 45 10 12 4/5/8 5 1 /- 6.5 1 /93 0.1 10.0 400 40 7/17/08 8748' 9.5 9.2 46 12 13 .4/9/15 5.8 1/- 6 1/93 0.1 10.7 400 20 7/18/08 8748' 9.6 9.3 47 12 15 5/15/25 6 1/- 7 1/92 0.1 10.8 300 20 ~ EPOCH 20 Cono~illips '~ Alaska, Ina 3C-15A 7/19/08 8748' 9.6 9.3 46 13 13 5/13/23 6 1/- 7 1/92 0.1 10.9 100 20 7/20/08 8748' 9.9 9.6 46 14 15 5/22/34 6.8 1 /- 8.5 1 /91 0.1 11.6 400 20 7/21/08 8856' 13.3 12.9 44 24 22 5/8/11 8.2 1/- 20 TR/80 0.3 10.0 400 40 7/22/08 9006' 13.7 13.4 47 18 26 5/7/9 0.0 1/- 22 TR/78 0.5 9.9 500 30 7/23/08 9211' 13.7 13.5 51 27 25 6/8/10 6.4 0/- 22 TR/78 0.5 10.2 350 40 7/24/08 9329' 13.5 13.2 59 37 29 10/14/18 -/- 2/- 22 TR/78 0.3 10.5 350 40 7/25/08 9329' 13.5 13.2 47 22 24 6/8/11 6.4 1/- 22 TR/78 0.25 10.0 350 40 7/26/08 9329' 13.5 13.2 59 27 29 10/14/19 6.8 2/- 22 TR/78 0.25 10.2 350 40 7/27/08 9329' 13.5 13.2 56 25 36 18/34/46 9 2/- 22 TR/78 0.25 11.4 350 80 7/28/08 9329' 13.5 13.2 49 22 28 9/14/18 11.5 2/- 22 1/78 0.25 10.8 500 20 7/29/08 9329' 13.6 13.4 51 22 29 9/14/18 11 2/- 22 1/78 0.2 10.7 400 20 Abbreviations MW =Mud Weight WL = Water or Filtrate Loss Ca =Hardness Calcium YP =Yield Point Gels =Gel Strength Sd =Sand content ECD =Effective Circulating Density CI =Chlorides VIS =Funnel Viscosity FC =Filter Cake PV =Plastic Viscosity Sols =Solids O/W =Oil to Water ratio ~ EPOCH 2, • ConocoPhillips Alaska Inc. 3C-15A Daily Report Report for: M. Thornton S. Lapiene Date: 7/07/08 Time: 3:00 Current Depth (MD): 3188' Current Drilling Ahead. Current Depth (TVD): 3127' Operations: 24 hr Footage (MD): 0' ~~„+e. ROP: Current: 154.965 Max: 248.0 Tor ue: Current: 1498.049 Max: 4350 WOB: Current 2.488 Max: 15 RPM: Current: 58.000 Max: 100 PP: Current: 1887.849 Max: 2160 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: •.M MW. v9.8v _ - _ __ ••FV: 53 PV: 14 YP: 22 FL: 7.5 GELLS 6/7/8 Sol: 7 pH: 9.8 CI-~ 500 Ca++ 12 MW Change: Mud Loss event: Gas Data Depth: From: Depth: Volume: Ditch Gas: Current: Max: Av BG : 10u 199u Gas Events 2876' To: Reason: Depth MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection C1 C2 C3 C41 C4N C51 C5N Gases 175 2810' 34 2906' 5 3000' 92 3189' No. vM De th MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N in hole. Service rig and drill ahead. Calibrations: Span and calibrate THA Failures: Lithologies: Current: Sands, Claystones. Last 24 hrs: Sands, Claystones. Mill window and drilled 32' of new hole, pumped sweep. Perform LOT = 14ppg Operational Summary: EMW. Pull out of hole and lay down Milling BHA. Picked up drilling BHA and run ~~~~~ • ConocoPhillips Alaska Inc. 3C-15A Daily Report Report for: M. Thornton S. Lapiene Date: 7/08/08 Time: 2:00 Current Depth (MD): 3700' Current Drilling Ahead. Current Depth (TVD): 3537' Operations: 24 hr Footage (MD): 512' ~~,.+e• ROP: Current: 102.276 Max: 248.7 Tor ue: Current: 2539.789 Max: 6045 WOB: Current 9.825 Max: 43 RPM: Current: 59.000 Max: 63 PP: Current: 1946.416 Max: 2360 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: nn,~,~ D~...,~hie~ /:Yl7Z•~n hrclQAnn' ._.~~ .-r MW: -. _.-- -- - 9.8 ---- ~-'-- - FV: -- 60 PV: 17 YP: 23 FL: 5.5 GELLS 5/8/9 Sol: 7.5 pH: 10.1 CI-~ 600 Ca++ 12 MW Change: Mud Loss event: Gas Data Depth: From: Depth: Volume: Ditch Gas: Current: Max: Av BG : 75u 606u Gas Events r~ LJ 3351 ' To: Reason: De th (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection C1 C2 C3 C41 C4N C51 C5N Gases 71 3377' 5 3755' r_.,~ c~.,,.,io~ No. ~...~.-- Depth MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Sands, Tuffaceous Claystone, Tuffaceous Siltstone Last 24 hrs: Sands, Tuffaceous Claystone, Tuffaceous Siltstone; Siltstone, Claystone. Operational Summary: Drill to 3280' MD, pumped sweeps for bit balling. Pull out of hole to change out mud motor. Run in hold and drill ahead to 3700' MD. Calibrations: Span and calibrate THA Failures: ~~~~~ ConocoPhillips Alaska Inc. 3C-15A Daily Report Report for: F. Herbert S. Lapiene Date: 7/09/08 Time: 3:00 Current Depth (MD): 4750' Current Drilling Ahead. Current Depth (TVD): 4324' Operations: 24 hr Footage (MD): 1050' ~~„+e• ROP: Current: 21.771 Max: 296.6 Torque: Current: 1427.068 Max: 6088 WOB: Current 12.268 Max: 28 RPM: Current: 0.000 Max: 63 PP: Current: 1984.787 Max: 2404 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: nn~~.J or......rt~.~~ /l 7Z• 2n hrc/S2~I(1(1' MW: 9.8 FV: 54 PV: 16 YP: 20 FL: 6 GELLS 5/12/19 Sol: 7.75 pH: 9.9 CI- 500 Ca++ 8 MW Change: Depth: From: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Avq BG : 10u 501 u 3905' To: Reason: D/TVD): Gas Events • Depth MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection C1 C2 C3 C41 C4N C51 C5N Gases 98 3943' 72 4037' 76 4130' 37 4224' 42 4318' 62 4413' ~-.,.. ~.,.,.,..~o~ No. v~ De th (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Sands, Tuffaceous Claystone, Tuffaceous Siltstone Last 24 hrs: Sands, Tuffaceous Claystone, Tuffaceous Siltstone Operational Summary: Drill from 3613' to 4691' MD. Calibrations: Span and calibrate THA Failures: EPOCH • ConocoPhillips Alaska Inc. 3C-15A Daily Report Report for: F. Herbert S. Lapiene Date: 7/10/08 Time: 3:00 Current Depth (MD): 5264' Current Tripping in hole. Current Depth (TVD): 4575' Operations: 24 hr Footage (MD): 514' AI n+o ROP: Current: 0 Max: 174.5 Tor ue: Current: 0 Max: 6757 WOB: Current 0 Max: 30 RPM: Current: 0 Max: 63 PP: Current: 0 Max: 2771 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: Moir! Drnnor4iec rnl 77•(1(1 hre/~7Rd' - _ MW: 9.8 FV: 58 PV: 20 YP: 25 FL: 4.9 GELLS 8/18/22 Sol: 7.5 H: 10.0 CI-~ 550 Ca++ 22 MW Change: Depth: From: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Av BG : Ou 36u Gas Events Depth (M 5074' To: Reason: De th (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection C1 C2 C3 C41 C4N C51 C5N Gases 4 4886' 5 4980' 40 5072' 11 5167' No. De th MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Conglomerate Sands, Tuffaceous Claystone, Tuffaceous Siltstone Last 24 hrs: Sands, Tuffaceous Claystone, Tuffaceous Siltstone, Conglomerate Sands Operational Summary: Drill ahead from 4691' MD to 5264' MD. Pump sweep and dry job. Pull out of hole and lay down BHA. Pick up BHA and trip in hole. Calibrations: Span and calibrate THA Failures: X11 EPtJCH ConocoPhillips Alaska Inc. 3C-15A Daily Report Report for: F. Herbert S. Lapiene Date: 7/11/08 Time: 2:40 Current Depth (MD): 6008' Current Drilling Ahead Current Depth (TVD): 4891' Operations: 24 hr Footage (MD): 774' ni.,to• ROP: Current: 63.523 Max: 269.1 Tor ue: Current: 4509.$24 Max: 5762 WOB: Current 3.095 Max: 25 RPM: Current: 58.000 Max: $9 PP: Current: 2154.299 Max: 2771 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: ~A~irl Prnnerliee rnl 77•nn hrc/FA~7' MW: 9.8 FV: 56 PV: 19 YP: 22 FL: 4.5 GELLS 8/19/25 Sol: 7.5 pH: 10 CI- 500 Ca++~ 20 MW Change: Mud Loss event: Gas Data Ditch Gas: Current: Av BG : 6u Gas Events ~~ Depth: From: Depth: Volume: Max: 39u 5287' To: Reason: Depth MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas 5264' 464u Connection C1 C2 C3 C41 C4N C51 C5N Gases 7 5358' 7 5453' 8 5547' 8 5642' 4 5736' Gas Sam les No. De th MD/TVD TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Sands, Tuffaceous Claystone, Tuffaceous Siltstone Last 24 hrs: Sands, Tuffaceous Claystone, Tuffaceous Siltstone, Conglomerate Sands Run hole with BHA # 5. Service Rig. Drill ahead to 5922' MD, took losses while Operational Summary: back reaming stand at 5922'. Monitor hole pumps off- static. Pumps on at 250 gpm losses 14bph. Calibrations: Span and calibrate THA Failures: EPOCH • Report for: F. Herbert Cono~coPhillips Alaska Inc. 3C-15A Daily Report S. Lapiene Date: 7/12!08 Time: 2:45 Current Depth (MD): 6585' Current Drilling Ahead Current Depth (TVD): 5133' Operations: 24 hr Footage (MD): 577' Note: ROP: Current: 84.656 Max: 126.1 Torque: Current: 4718.833 Max: 6483 WOB: Current 24.684 Max: 34 RPM: Current: 66.000 Max: 69 PP: Current: 2395.264 Max: 2693 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: Miirl Prnr~ar+iac ~nl 77•(1(1 hrc/Rdn~,' MW: 9.5 FV: 49 PV: 21 YP: 27 FL: 5.5 GELLS 9/20/25 Sol: 7 H: 9.6 CI- 300 Ca++ 8 Depth: From: Depth: Vo-ume: MW Change: Mud Loss event: Gas Data Ditch Gas: Current: Av BG : 6u Gas Events Max: 23u To: Reason: Depth (MD/TVD): 6443' Depth MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas 6303' 337u Connection C1 C2 C3 C41 C4N C51 C5N Gases 15 6019' 13 6114' 16 6208' 11 6397' 15 6491' Gas Samples No. De th MD/TVD TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Sands, Tuffaceous Claystone, Tuffaceous Siltstone, Sandstone Last 24 hrs: Sands, Tuffaceous Claystone, Tuffaceous Siltstone, Sandstone, Carbonaceous Shale, Tuff. Condition hole with sweeps, Drill ahead adding LCM to mud system. Circulate and Operational Summary: condition mud to a 9.5 ppg. Pump out of the hole to the window. Service rig, run in hole, reduce mud weight to 9.4 ppg. Drill ahead. Calibrations: Span and calibrate THA Failures: • EP(JCH Report for: F. Herbert ROP: Current: 56.012 Max: 218.7 Tor ue: Current: 1047.197 Max: 6678 WOB: Current 47.917 Max: 47 RPM: Current: 0.000 Max: 80 PP: Current: 2187.442 Max: 2703 Lag: Strokes: 2111 Time: 32.5min Surf-to Surf: Strokes: 9780 Time: 150.5min ECD: Current: Max: ConocoPhillips Alaska Inc. 3C-15A Daily Report S. Lapiene Date: 7!13/08 Time: 2:45 Current Depth (MD): 7756' Current Drilling Ahead Current Depth (TVD): 5488' Operations: 24 hr Footage (MD): 971' Note: ~Aiirl Prnnartiac n 77•(1(1 hrc/7d7.ri' MW: 9.4 FV: 51 PV: 13 YP: 19 FL: 5.2 GELLS 6/12/19 Sol: 6 H: 9.8 CI~ 300 Ca++ 12 Depth: From: Depth: Volume: MW Change: Mud Loss event: Gas Data Ditch Gas: Current: Av BG : 10u Gas Events Max: ~ ~ Depth 60u 7438' To: Reason: Depth MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection C1 C2 C3 C41 C4N C51 C5N Gases 5 6775' 12 6869' 16 6963' 7 7058' 4 7152' 17 7247' 5 7341' 54 7435' 11 7530' vas aampies No. De th MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Sands, Tuffaceous Claystone, Tuffaceous Siltstone, Sandstone Last 24 hrs: Sands, Tuffaceous Claystone, Tuffaceous Siltstone, Sandstone, Carbonaceous Shale, Tuff. Operational Summary: Drill ahead from 6405' MD to 7475' MD. Pumping sweeps as needed. • Calibrations: Span and calibrate THA Failures: ~~~~~ ConocoPhillips Alaska Inc. 3C-15A Daily Report Report for: F. Herbert S. Lapiene Date: 7/14/08 Time: 3:00 Current Depth (MD): 8307' Current Drilling Ahead Current Depth (TVD): 5802' Operations: 24 hr Footage (MD): 551' Nnta• ROP: Current: 26.831 Max: 132.2 Tor ue: Current: 0.000 Max: 7127 WOB: Current 27.881 Max: 36 RPM: Current: 0.000 Max: 64 PP: Current: 1969.132 Max: 2624 Lag: Strokes: 2366 Time: 37.6min Surf-to Surf: Strokes: 11221 Time: 178.1 min ECD: Current: Max: ~Ai iri Prnncrtiac n 71 ~3nhrc/R7R3' MW: 9.4 FV: 52 PV: 13 YP: 16 FL: 5.1 GELLS 6/10/115 Sol: 6 pH: 9.8 CI- 100 Ca++~ 20 MW Change: Mud Loss event: Gas Data Ditch Gas: Current: Av BG : 27u • Gas Events • Depth: From: Depth: _ Volume: Max: 64u To: Reason: Depth (MD/TVD 8117' De th MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection C1 C2 C3 C41 C4N C51 C5N Gases 8 7813' 22 7907' 7 8191' 53 8285' Gas Sam les No. Depth MD/TVD TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Sands, Tuffaceous Claystone, Siltstone, Shale Last 24 hrs: Sands, Tuffaceous Claystone, Tuffaceous Siltstone, Sandstone, Carbonaceous Shale, Shale, Tuffaceous Shale. Operational Summary: Drill ahead form 7475' MD to 8272' MD pumping sweeps as needed. Calibrations: Span and calibrate THA Failures: ~ EPOCH ConocoPhillips Alaska Inc. 3C-15A Daily Report Report for: F. Herbert S. Lapiene Date: 7/15/08 Time: 3:00 Current Depth (MD): 8748' Current Tri m to shoe. Current Depth (TVD): 6118' Operations: pp g 24 hr Footage (MD): 441' Nnta• ROP: Current: 0 Max: 147.0 Torque: Current: 0 Max: 7700 WOB: Current 0 Max: 61 RPM: Current: 0 Max: 71 PP: Current: 0 Max: 2746 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: ~Ai irl Prnnartiac n 1 n•dRhrc/R7dR' MW: 9.4 FV: 46 PV: 14 YP: 19 FL: 5 GELLS 7/10/14 Sol: 6 H: 9.9 CI- 600 60 20 MW Change: Depth: Mud Loss event: Depth: Gas Data Ditch Gas: Current: Max: Av BG : Ou 178u Gas Events From: To: Reason: Volume: Depth (MD/TVD): 8579' Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas 8330' 213u Connection C1 C2 C3 C41 C4N C51 C5N Gases 25 8377' 63 8474' 82 8568' Gas Samples No. Depth MD/TVD TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Sands, Siltstone, Shale Last 24 hrs: Sands, Tuffaceous Claystone, Tuffaceous Siltstone, Sandstone, Carbonaceous Shale, Shale, Tuffaceous Shale. Operational Summary: Drill from 8263' to 8747' for interval TD. Pump sweeps as needed, short trip to 8330' Calibrations: Span and calibrate THA Failures: EPOCH ConocoPhillips Alaska Inc. 3C-15A Daily Report Report for: F. Herbert S. Lapiene Date: 7/16/08 Time: 3:00 Current Depth (MD): 8748' Current Run in hole with 5- %2" Current Depth (TVD): 6118' Operations: liner 24 hr Footage (MD): 0' ni.,+o• ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: ~A~~.J Drr~nehicc n 7.17hrc/S27i1 R' MW: 9.5 FV: 41 PV: 10 YP: 14 FL: 5 GELLS 4/8/11 Sol: 6 H: 10.0 CI- 400 Ca+ 40 To: Reason: MW Change: Mud Loss event: Gas Data Depth: From: Depth: Volume: Ditch Gas: Current: Max: Av BG : Ou Ou . Gas Events • De th MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas 610u 8719' Connection Gases C1 C2 C3 C41 C4N C51 C5N No. ~ Depth MD/TVD TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Sands, Siltstone, Shale Last 24 hrs: Sands, Siltstone, Shale Operational Summary: Pumps sweeps, short trip to 2765'. Run in hole, circulate and condition mud. Pull out of the hole and lay down BHA. Rig up and run in hole with 5- h liner. Calibrations: Span and calibrate THA Failures: ~ EPOCH ConocoPhillips Alaska Inc. 3C-15A Daily Report • Report for: F. Herbert S. Lapiene Date: 7/17/08 Time: 4:55 Current Depth (MD): 8748' Current Prep for squeeze job Current Depth (TVD): 6118' Operations: 24 hr Footage (MD): 0' AI n4c ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: ~Ai~rl Drnneriioc rnl 77•/1(lhre/S27dR' MW: 9.6 FV: 45 PV: 10 YP: 12 FL: 5 GELLS 4/5/8 Sol: 6.5 pH: 10.0 CI- 400 Ca+ 40 Depth: From: Depth: Volume: MW Change: Mud Loss event: Gas Data Ditch Gas: Current: Av BG : Ou • Gas Events • Max: Ou To: Reason: D/TVD): Depth MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas 795u 6302' Connection Gases C1 C2 C3 C41 C4N C51 C5N Gas Sam les No. De th MD/TVD TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Sands, Siltstone, Shale Last 24 hrs: Sands, Siltstone, Shale Run in hole with liner, circulate at 6302'. Stuck 20' off bottom and circulate (1-2 Operational Summary: BPM) and try to work liner. Release liner and pull out of hole. Pick up squeeze tools and run in hole. Calibrations: Span and calibrate THA Failures: E~V ~~ • Report for: F. Herbert ConocoPhillips Alaska Inc. 3C-15A Daily Report Date: 7/18/08 Time: 3:48 Current Depth (MD): 8748' Current RIH for scraper run Current Depth (TVD): 6118' Operations: 24 hr Footage (MD): 0' N n4a Miirl Drnncr+ice rnl'7~•Mhrc/R7dR' ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: MW: 9.5 FV: 46 PV: 12 YP: 13 FL: 5.8 GELLS 4/9/15 Sol: 6 H: 10.7 CI- 400 Ca+ 20 MW Change: Depth: _ Mud Loss event: Depth: Gas Data Ditch Gas: Current: Max: Av BG : Ou Ou • Gas Events • From: Volume: To: Reason: De th (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases C1 C2 C3 C41 C4N C51 C5N vas yam ies No. Depth MD/TVD TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Sands, Siltstone, Shale Last 24 hrs: Sands, Siltstone, Shale Service rig, perform cement squeeze. Pumped 48 bbls of 15.8 ppg cement with 21 Operational Summary: bbls 9.3 ppg mud behind. Strip through annular and set packer. Circulate 2.5 BTU's the long way at 295 gpm, reserve out 2 DS volumes. Lay down 4" DP, test BOPS and run in hole for scraper run. Calibrations: Span and calibrate THA Failures: EPC~C~-I Report for: F. Herbert ConocoPhillips Alaska Inc. 3C-15A Daily Report Date: 7/19/08 Time: 3:58 Current Depth (MD): 8748' Current Wireline Logging Current Depth (TVD): 6118' Operations: 24 hr Footage (MD): 0' n~~rA• ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: ~Aiirl Prnncrticc n 73•Mhrc/R7dR' MW: 9.6 FV: 47 PV: 12 YP: 15 FL: 6.0 GELLS 5/15/25 Sol: 7 H: 10.8 CI- 300 Ca+ 20 From: Volume: MW Change: Depth: Mud Loss event: Depth: Gas Data Ditch Gas: Current: Max: Av BG : Ou Ou Gas Events De To: Reason: De th MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases C1 C2 C3 C41 C4N C51 C5N Gas Sam les No. De th MD/TVD TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Sands, Siltstone, Shale Last 24 hrs: Sands, Siltstone, Shale Operational Summary: Scraper run. POOH and lay down scrapper assembly. Rigup to run USIT log on wire line. Wireline logging. Calibrations: Failures: EP~~H ConocoPhillips Alaska Inc. 3C-15A Daily Report • Report for: F. Herbert J. Keener Date: 7/20/08 Time: 3:58 Current Depth (MD): 8748' Current Cementing Current Depth (TVD): 6118' Operations: 24 hr Footage (MD): 0' N nta ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: Mi iri Prnnarticc n 73•Mhrc/R7dR' MW: 9.6 FV: 46 PV: 13 YP: 13 FL: 6.0 GELLS 5/13/23 Sol: 7 H: 10.9 CI- 400 Ca+ 20 MW Change: Depth: _ Mud Loss event: Depth: Gas Data Ditch Gas: Current: Max: Av BG : Ou Ou • Gas Events n U From: To: Reason: Volume: De Depth (MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases C1 C2 C3 C41 C4N C51 C5N Gas Sam les No. Depth MD/TVD TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Sands, Siltstone, Shale Last 24 hrs: Sands, Siltstone, Shale Operational Summary: Wireline logging (USIT log) completed; TIH to landing collar with retainer; squeeze cement at shoe, reverse cement out of drill pipe. Calibrations: Gas Chromatograph calibrated. Failures: ~ EPOCH ConocoPhillips Alaska Inc. 3C-15A Daily Report • Report for: F. Herbert J. Keener Date: 7/21/08 Time: 3:10 Current Depth (MD): 8748' Current Displacing well Current Depth (TVD): 6147' Operations: 24 hr Footage (MD): 0' AI nto ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: ~/li ~rl Prnncr4icc n 73•dF,hrc/R7dR' MW: 9.9 FV: 46 PV: 14 YP: 15 FL: 6.8 GELLS 5/22/34 Sol: 8.5 H: 11.6 CI- 400 Ca+ 20 MW Change: Depth: 8748' Mud Loss event: Depth: Gas Data Ditch Gas: Current: Max: Av BG : Ou Ou Gas Events • From: 9.9 To: 12.0 Reason: Displacement Volume: De De th MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases C1 C2 C3 C41 C4N C51 C5N Gas Sam les No. De th MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Sands, Siltstone, Shale Last 24 hrs: Sands, Siltstone, Shale TIH to top of retainer with drilling assembly; cut and slip drilling line; drill retainer, Operational Summary: shoe to 8748'MD, displace well with 12.0 ppg LSND mud in preparation to drill 20' of new hole; . Calibrations: Failures: Brief power failure during day tour, instruments unaffected, no data lost; Totco feeding incorrect bit depth during drilling of shoe, problem corrected. ~~~~~ ConocoPhillips Alaska Inc. 3C-15A Daily Report Report for: F. Herbert J. Keener Date: 7/22/08 Time: 3:00 Current Depth (MD): 8879' Current Drilling ahead Current Depth (TVD): 6256' Operations: 24 hr Footage (MD): 131' AI n+o ROP: Current: 0 Max: 147 Tor ue: Current: 1409 Max: 889 WOB: Current 8.3 Max: 61 RPM: Current: 3 Max: 64 PP: Current: 3541 Max: 3989 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: ~Aiir! Drnnortiec rnl 7Z•d ~.hre/A7dS2' MW: 13.3 FV: 44 PV: 24 YP: 22 FL: 8.2 GELLS 518/11 Sol: 20 H: 10.0 CI-~ 400 Ca+ 40 MW Change: Depth: 8795' Mud Loss event: Depth: Gas Data Ditch Gas: Current: Max: Av BG : 28u 70u • Gas Events From: 12.0 To: 13.3 Reason: Kuparuk C Volume: 8869'/6249' De th MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases C1 C2 C3 C41 C4N C51 C5N Gas Sam les No. Depth (MD/TVD TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Sands, Shale Last 24 hrs: Sands, Mudstone, Siltstone, Shale Drilled 20' of new hole to 8768' MD at 0316hrs; Circulated B/U and conducted Operational Summary: LOT; Drilled ahead to 8795' MD circulating frequently and weighing up mud to 13.3 by 1804hrs. Drilling ahead at low ROP through Kuparuk C sands. Calibrations: Failures: • EP(J~H • Report for: F. Herbert J. Keener ConocoPhillips Alaska Inc. 3C-15A Daily Report Date: 7/23/08 Time: 3:53 Current Depth (MD): 9008' Current TIH Current Depth (TVD): 6256' Operations: 24 hr Footage (MD): 129' Note: ROP: Current: 0 Max: 159.7 Torque: Current: 0 Max: 7649 WOB: Current 0 Max: 33 RPM: Current: 0 Max: 62 PP: Current: 0 Max: 3937 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: Marl Prnnartiac n ~3•d5hrc/R7dR' MW: 13.7 FV: 47 PV: 18 YP: 26 FL: 8.0 GELLS 5!7/9 Sol: 22 H: 9.9 CI- 500 Ca+ 30 Depth: 8975' From: 13.3 Depth: Volume: MW Change: Mud Loss event: Gas Data Ditch Gas: Current: Av BG : Ou . Gas Events • Max: ~ ~ Depth (MD/ 238u 8963'/6326' To: 13.7 Reason: Kuparuk A Depth (MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases C1 C2 C3 C41 C4N C51 C5N Gas Sam les No. De th (MD/TVD TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Sands, Shale Last 24 hrs: Sands, Mudstone, Siltstone, Shale Drilled through Kuparuk C sands in Kuparuk B. Circulated and weighted up mud to 13.7bb1 in preparation to drill through Kuparuk A sands. Drilling stopped at Operational Summary: 9008' MD due to washout. POOH at 1000hrs on 07/22/2008 to determine location of washout. Washout found, problems corrected, new BHA and string assembly 1616.27' (versus previous 1617.22') total length. Begin TIH with new BHA at 2315 hrs 07/22/2008. Calibrations: Recalculated Lag time based on new BHA. Failures: Washout in HWDP requiring POOH for repair. EPOCH • Report for: F. Herbert J. Keener Date: 7/24/08 Time: 3:53 Nnta• Current Depth (MD): 9229' Current Drilling Current Depth (TVD): 6452' Operations: 24 hr Footage (MD): 230' ROP: Current: 6 Max: 156.3 Torque: Current: 3738 Max: 6160 WOB: Current 18 Max: 58 RPM: Current: 54 Max: 60 PP: Current: 3478 Max: 3901 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: ~Aiirl Prnnarfiioe n 7n•Mhrc/g1R7' MW: 13.7 FV: 51 PV: 27 YP: 25 FL: 6.4 GELLS 6/8/10 Sol: 22 pH: 10.2 CI- 350 Ca+ 40 MW Change: Depth: _ Mud Loss event: Depth: Gas Data Ditch Gas: Current: Max: Av BG : 17u 950u Gas Events • From: Volume: To: Reason: 9090'/6428' Depth MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection Gases C1 C2 C3 C41 C4N C51 C5N Gas Sam les No. Depth MD/TVD TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Sands, Shale Last 24 hrs: Sands, Mudstone, Siltstone, Shale Operational Summary: Drilled through Kuparuk A sands. Currently drilling rathole in Miluveach to a projected TD of 9327' MD. Show report attached as separate document. Calibrations: Failures: ConocoPhillips Alaska Inc. 3C-15A Daily Report E~~~~ ConocoPhillips Alaska Inc. 3C-15A Daily Report Report for: F. Herbert J. Keener Date: 7125/08 Time: 3:04 Current Depth (MD): 9327' Current TOOH Current Depth (TVD): 6620' Operations: 24 hr Footage (MD): 100' AI n+o ROP: Current: 0 Max: 95.9 Tor ue: Current: 0 Max: 5293 WOB: Current 0 Max: 42 RPM: Current: 0 Max: 69 PP: Current: 0 Max: 3873 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: ~Aiir! Drnncr+ioc /irl 1Q•(1(lhrc/Q~77' MW: 13.5 FV: 59 PV: 37 YP: 29 FL: 5.5 GELLS 10/14/18 Sol: 22 pH: 10.5 CI- 350 Ca+ 40 MW Change: Depth: 9327 Mud Loss event: Depth: Gas Data Ditch Gas: Current: Max: Av BG : 1.7u 22u Gas Events From: 13.7 To: 13.5 Reason: YP Increase Volume: 9311'/6607' De th (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas 8300'/6382' 5141 582 376 73 154 42 42 Connection Gases C1 C2 C3 C41 C4N C51 C5N Gas Sam les No. Depth MD/TVD TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: N/A Last 24 hrs: Shale, Sand, Finished drilling rathole in Miluveach formation. Reached TD of 9327' MD/6620' TVD at 1730hrs. Circulated B/U. Short trip to shoe on elevators at 8725'. Operational Summary: Serviced Top Drive at shoe. TIH at bottom, watched, swabbed and surged. Trip gas during swabbing reached 536 units (Gas Chromatography itemized above). Circulated and changed to MW 13.5 to get YP to 29. TOOH to the 2.875" pipe to drop a 1.3" steel drift on slick line. Calibrations: Failures: • ~I EP(»H ConocoPhillips Alaska Inc. 3C-15A Daily Report Report for: F. Herbert J. Keener Date: 7/26/08 Time: 4:08 Current Depth (MD): 9327' Current TIH with 3.5" liner Current Depth (TVD): 6620' Operations: 24 hr Footage (MD): 0' ni~tA~ ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 1647 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: ~Ai ir! DrnncrFicc n 1 Q•nnhrc/Q4~7' MW: 13.5 FV: 47 PV: 22 YP: 24 FL: 6.1 GELLS 6/8/11 Sol: 22 H: 10.0 CI- 350 Ca+ 40 MW Change: Depth: Mud Loss event: Depth: Gas Data Ditch Gas: Current: Max: Av BG : 2.7u 178u Gas Events From: To: Reason: Volume: 4982'/4441' De th (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas 4982'/4441' 690 100 104 42 76 21 23 Tri Gas 7542'/5476' 1965 169 110 20 42 14 16 vas ~ampies No. De th (MD/TVD TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: N/A Last 24 hrs: N/A BROOH to 8725'. POOH on elevators. Lay down HWT DP, drill collars and BHA. Operational Summary: R/U/and TIH with 3.5" liner on 2.875 drill pipe. Circulate B/U at MD 2485' (117u), 4982 (178u), and 7542' (108u). GC Gas events at B/U at 4982' and 7542' recorded above. Continuing liner run. Calibrations: Failures: • EPOCH ConocoPhillips Alaska Inc. 3C-15A Daily Report • Report for: F. Herbert J. Keener Date: 7/27/08 Time: 3:01 Current Depth (MD): 9327' Current TIH Clean out run Current Depth (TVD): 6620' Operations: 24 hr Footage (MD): 0' Nntc• ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 1647 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: Miirl Prnnartiac (n~ 19•nnhrc/Q~~7' MW: 13.5 FV: 59 PV: 27 YP: 29 FL: 6.8 GELLS 10/14/19 Sol: 22 pH: 10.2 CI- 350 Ca+ 40 MW Change: Depth: Mud Loss event: Depth: Gas Data Ditch Gas: Current: Max: Av BG : 2.5u 411 u Gas Events From: To: Reason: Volume: Depth (MD/ 9280'/6582' De th MD/TVD C1 C2 C3 C41 C4N C51 C5N Trip Gas Tri Gas vas 5ampies No. De th MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: N/A Last 24 hrs: N/A Finished liner run. Circulated B/U at bottom (411 u max gas). Circulated and Operational Summary: conditioned mud for cementing. Pumped cement. Liner hung up at 6100. POOH on elevators racking back in derrick then lay down all 3.5" liner. P/U cleaned out assembly, TIH on cleaner run. Calibrations: Failures: Liner hung up necessitating POOH and TIH for cleanout run before another cementing attempt ~i E~~~~ ConocoPhillips Alaska Inc. 3C-15A Daily Report • Report for: F. Herbert J. Keener Date: 7/28/08 Time: 3:06 Current Depth (MD): 9327' Current Wiper Trip Current Depth (TVD): 6620' Operations: 24 hr Footage (MD): 0' Nnta• ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 2561 Max: 4121 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: Mi irl Prnnartias n 19•Mhr_c/A~~7' MW: 13.5 FV: 56 PV: 25 YP: 36 FL: 9.0 GELLS 18!34/46 Sol: 22 pH: 11.4 CI- 350 Ca+ 80 MW Change: Depth: _ Mud Loss event: Depth: Gas Data Ditch Gas: Current: Max: Av BG . Gas Events • From: To: Reason: Volume: De th MD/TVD C1 C2 C3 C41 C4N C51 C5N Tri Gas 647u 8710'/6115' 4885 971 767 157 356 114 129 Trip Gas 1202u) 8695'/6102' 4620 1770 2416 635 1437 468 522 vas Sam ies No. De th MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: N/A Last 24 hrs: N/A TIH on cleaner run, swabbing and circulating. Trip/wiper/connection gasses common throughout TIH below 8750' MD. Max gas per peak typically in 100- Operational Summary: 3306u range with two trip gas peaks at 647u and approx 1202u sampled with GC (see above). Continue wiping and circulating to remove cement encountered at depths below 7100'. Calibrations: Failures: Trackball malfunction during THA calibration. Problem Resolved quickly. EPOCH • Report for: F. Herbert Date: 7/29108 Time: 3:40 Current Depth (MD): 9327' Current Monitoring Well Current Depth (TVD): 6620' Operations: 24 hr Footage (MD): 0' nl n+c 11Aivi Prnncr4iee rnl 1Q•nnhre/QQ')7' ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: MW: 13.5 FV: 49 PV: 22 YP: 28 FL: 11.5 GELLS 9/14/18 Sol: 22 pH: 10.8 CI- 500 Ca+ 20 ConocoPhillips Alaska Inc. 3C-15A Daily Report MW Change: Depth: Mud Loss event: Depth: Gas Data Ditch Gas: Current: Max: Av BG : 2.2 127u • Gas Events • From: To: Reason: Volume: Depth (MD/TVD 9240'/6550' De th MD/TVD C1 C2 C3 C41 C4N C51 C5N B/U Gas 36u 2738'/2733' 222 14 10 NA NA NA NA Gas Samples No. De th (MD/TVD TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: N/A Last 24 hrs: N/A Cleaner Run completed. Circulated and conditioned hole on bottom; max gas while circulating during remainder of liner trip was 127u (see above). POOH, R/D Operational Summary: cleaner BHA, swapped out BHA for liner trip. TIH with liner. Plan is to circulate B/U and monitor well every 17 stands. B/U Gas 36u at 2738' MD (see above). Seventeen more stands in place. Circulating at 4900' MD. Calibrations: Failures: Totco not taking notes from M/L calling out Max gas peaks E~~~~ ConocoPhillips Alaska Inc. 3C-15A Daily Report • Report for: F. Herbert J. Keener Date: 7/30/08 Time: 3:05 Current Depth (MD): 9327' Current Cementing Current Depth (TVD): 6620' Operations: 24 hr Footage (MD): 0' Nnfa• ROP: Current: 0 Max: 0 Tor ue: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 1688 Max: 0 Lag: Strokes: Time: Surf-to Surf: Strokes: Time: ECD: Current: Max: AAurJ Prnner+iec n 1Q•Mhre/Q~77' • MW: 13.6 FV: 51 PV: 22 YP: 29 FL: 11 GELLS 9/14/18 Sol: 22 H: 10.7 CI- 400 Ca+ 20 MW Change: Depth: 9327'MD From: 13.5 To: 13.6 Reason: Cementing Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: De th MD/TVD Avg BG : 1.5 112u 5010'/4456' Gas Events De th MD/TVD) C1 C2 C3 C41 C4N C51 C5N vas aam ies No. De th MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: N/A Last 24 hrs: N/A Liner run continued, circulating B/U every seventeen stands. Max gas at 5010'MD was 112u and 69u at 7282'MD. Continued to wash and ream, circulating B/U as Operational Summary: needed (max Gas 39u) until 89 stands, two singles and cement head were in. Tagged bottom at approx. 1730hrs and circulated. Max gas 28u. Dropped 3/" ball and pressured up in prep for cementing. Started cementing. Calibrations: Failures: Power failure at approx 0156 hrs for several minutes. No effect on instruments after power restored. EPOCH
