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210-182
New Plugback Esets 7/18/2024 Well Name API Number PTD Number ESet Number Date 1J-162 PB2 50-029-23360-71-00 207-080 T39224 5-21-2009 CD3-125 PB1 50-103-20632-70-00 210-189 T39225 4-15-2011 CD3-301A PB1 50-103-20543-71-00 210-017 T39226 4-13-2010 KIGUN 1 PB1 50-629-23239-70-00 205-025 T39227 9-26-2005 1J-105 PB1 50-029-23346-70-00 207-027 T39228 4-23-2009 2K-28A PB1 50-103-20385-70-00 211-133 T39229 2-6-2012 2L-306 PB1 50-103-20630-70-00 210-182 T39230 4-15-2011 3A-17AL1 PB1 50-029-22691-70-00 210-114 T39231 11-24-2010 3G-22AL2 PB1 50-103-20147-70-00 212-047 T39232 7-24-2012 3H-34L1 PB1 50-103-20643-70-00 211-162 T39233 2-28-2012 3N-16AL1 PB1 50-029-21593-73-00 210-107 T39234 11-24-2010 C-12A PB1 50-029-21373-70-00 199-091 T39235 1-17-2002 ODSN-01 PB1 50-703-20648-70-00 211-166 T39236 5-3-2012 ODST-39 PB1 50-703-20572-70-00 208-040 T39237 3-22-2012 OI06-05 PB1 50-029-23437-70-00 210-165 T39238 11-3-2011 OP17-02 PB1 50-029-23431-70-00 210-125 T39239 1-3-2011 2L-306 PB1 50-103-20630-70-00 210-182 T39230 4-15-2011 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13158'feet None feet true vertical 5446'feet None feet Effective Depth measured 11803'feet 10669', 10685', 11307'feet true vertical 5431'feet 5072', 5079', 5303' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 11367' MD 5325' TVD Packers and SSSV (type, measured and true vertical depth) 10669' MD 10685' MD 11307' MD 511' MD 5072' TVD 5079' TVD 5303' TVD 510' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 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 Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 3664' 2371' Burst Collapse Production Liner 11434' 1850' Casing 5360' 3-1/2" 11473' 11307' 13158' 3623' 96'Conductor Surface Intermediate 16" 10-3/4" 55' measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 210-182-0 50-103-20630-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0380051, ADL0380052 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2L-306 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 630 BOPD Gas-Mcf MD 520 psi Size 96' 57 bbl 627 psi427 MCF 300 BOPD 220 psi20 bbl 215 psi N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 266 MCF Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Dusty Freeborn dusty.freeborn@conocophillips.com (907) 659-7224Senior Well Integrity Specialist 11735-11740', 12145-12150', 12560-12564', 12975-12980', 13140-13144' feet 5420-5421', 5444-5443', 5442-5442', 5442-5442', 5446-5446' feet Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: HRD ZXP Liner Top Packer SSSV: Camco DS Nipple By Anne Prysunka at 12:11 pm, Dec 07, 2022 Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Eagle River, Alaska Date: 2022.12.07 08:57:26-09'00' Foxit PDF Editor Version: 12.0.1 Dusty Freeborn P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 7, 2022 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 retrievable tubing patch set across a known tubing leak in producer KRU 2L-306 (PTD 210-182). Please contact me at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@ conocophillips.com Reason: I am the author of this document Location: Eagle River, Alaska Date: 2022.12.07 08:54:29-09'00' Foxit PDF Editor Version: 12.0.1 Dusty Freeborn DTTMSTART JOBTYP SUMMARYOPS 8/14/2022 ACQUIRE DATA DRIFT TUBING W/ 2.84 GAUGE RING TO 6000' RKB. BRUSH FLUSH 2.75 D NIPPLE & SET 2.75 D-CSV @ 10,734' RKB. PULLED OV @ 10,530' RKB (OV WAS FLOW CUT & ONLY RECOVERED UPPER HALF). SET 1/4" OV W/ EXTENDED PACKING IN MANDREL @ 10,530' RKB (PRESSURED UP ON TUBING TO 1000 PSI WHILE STILL ON BOTTOM & IA DIDN'T TRACK) IN PROGRESS. 8/15/2022 ACQUIRE DATA PERFORMED 15 MINUTE TEST TO 1000 PSI ON TUBING (GOOD TEST). DRIFT TUBING W/ BRUSH TO PUSH LOWER HALF OF OV INTO THE CATCHER ON THE D-CSV. PULLED D-CSV @ 10,734' RKB (LOWER HALF OF OV WAS IN CATCHER ON CSV). JOB COMPLETE 8/17/2022 ACQUIRE DATA (AC EVAL) SI RE TIFL (FAILED - DUE TO IA FL INFLOW AND IA PSI INCREASE) 8/26/2022 ACQUIRE DATA SET 2.75" CA-2 PLUG @ 10,734' RKB & ATTEMPT TO 2500 (FAILED); LEAK DETECT W/ HOLEFINDER & DETERMINE LEAK BETWEEN 10,614' & 10,546' RKB; SET CATCHER W/ GUTTED TD ON PLUG @ 10,734' RKB & OPEN CMU @ 10,678' RKB. READY FOR CIRC OUT & CMIT. IN PROGRESS. 8/26/2022 ACQUIRE DATA TAKE OVER WELL FROM SL 17:45 PERFORM CMIT - PASS PERFORM DDT 8/27/2022 ACQUIRE DATA CLOSE CMU @ 10,678' RKB (ATTEMPT TO MITT-FAILED); ESTABLISH LLR @ .4 BPM @ 1400 PS; LEAK DETECT W/ HOLEFINDER & DETERMINE LEAK @ NEAR GLM @ 10,530' RKB; PULLED EXT PKG OV & SET EXT PKG DV @ 10,530' RKB (FAILED TO TEST). JOB SUSPENDED FOR PLAN (CA-2 PLUG & CATCHER STILL IN HOLE). 10/6/2022 ACQUIRE DATA PERFORM LEAK DETECTION LOG FROM JUST ABOVE CA-2 PLUG @ 10,734' TO SURFACE (YJOS HOISTING READ TOOLS), LLR OF 0.5 BBL/MIN MAINTAINED DURING OPERATIONS. LEAK POINT IDENTIFIED AT 10,678' RKB. **JOB IS IN PROGRESS** 10/7/2022 ACQUIRE DATA PERFORM 24-ARM CALIPER LOG FROM 10,729' RKB TO SURFACE. **JOB IS READY FOR PLAN FORWARD** 11/2/2022 ACQUIRE DATA PULLED 2.79''CATCHER/PULLING TOOL ASSEMBLY & CA-2 EQ PRONG @10,729'RKB. PULLED CA-2 PLUG BODY @10,734'RKB. B & F PATCH SETTING INTERVAL FROM 10,650'RKB TO 10,700'RKB, DRIFT DMY PATCH FREELY DWN TO 10,704'RKB READY FOR LOWER. 11/11/2022 ACQUIRE DATA SET LOWER 2.72" P2P (SN: CPP35260) @ 10,685.5' RKB (MID ELEMENT @ 10,688); SET 3 1/2" TTS TEST TOOL IN PKR @ 10,685' RKB & CMIT TBG X IA TO 2500 PSI (PASS). IN PROGRESS. 11/12/2022 ACQUIRE DATA PULLED 3 1/2 TTS TEST TOOL @ 10688' RKB; SET 2.72" P2P (CPP35346) SPACER & 2L-306 Tubing Patch Summary of Operations ANCHOR LATCH (CPAL35128) @ 10,669.55' RKB W/ MID ELEMENT @ 10,672' (OAL 16.84') SET 3 1/2 TTS TEST TOOL @ 10669' RKB & MITT TO 2500 (PASS); CMIT TBG x IA TO 2500 (PASS). IN PROGRESS. ACQUIRE DATA11/13/2022 PULLED EXT PKG DV & SET ETX PKG OV @ 10,529' RKB; MITT TO 2500 PSI (PASS) PULLED 3 1/2" TTS TEST TOOL @ 10,669' RKB. JOB COMPLETE. Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:SLM 11,803.0 2L-306 6/22/2015 lehallf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Installed Patch & Set OV 2L-306 11/13/2022 zembaej Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 14.97 41.0 96.5 96.5 164.00 H-40 WELDED SURFACE 10 3/4 9.95 41.5 3,664.3 2,371.5 45.50 L-80 BTC PRODUCTION 7 5/8 6.87 38.9 11,472.8 5,360.2 29.70 L-80 BTCM LINER 3 1/2 2.99 11,307.5 13,157.6 9.30 L-80 SLHT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 36.5 Set Depth 11,367.5 Set Depth 5,324.8 String Ma 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.5 36.5 0.00 HANGER 10.800 FMC TUBING HANGER 4.500 101.5 101.5 0.33 XO Reducing 4.500 CROSSOVER 4.5 x 3.5, ID 3.958, #12.6, L-80, IBTM 3.500 510.7 509.9 6.78 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.875" PROFILE 2.875 4,022.2 2,499.6 69.44 GAS LIFT 5.390 CAMCO KBMG 2.920 7,558.3 3,798.2 68.94 GAS LIFT 5.390 CAMCO KBMG 2.920 9,436.3 4,494.1 63.20 GAS LIFT 5.390 CAMCO KBMG 2.920 10,529.8 5,011.7 64.31 GAS LIFT 5.390 CAMCO KBMG 2.920 10,678.3 5,075.6 64.67 SLEEVE 5.750 BAKER CMU SLIDING SLEEVE w/ 2.813 DS PROFILE (Closed 8/27/2022) 2.813 10,734.0 5,099.1 65.62 NIPPLE 4.520 CAMCO D NO GO NIPPLE 2.750 11,347.2 5,317.7 69.33 LOCATOR 4.000 LOCATOR COLLAR 3.000 11,347.7 5,317.9 69.33 SEAL ASSY 4.500 GBH-22 80-40 SEAL ASSEMBLY w/ 1/2 MULE SHOE 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 36.5 36.5 0.00 CHEM LINE CHEMICAL INJECTION LINE 4/6/2011 0.000 10,669.5 5,071.9 64.61 PACKER - PATCH - UPR 2.72" UPPER P2P W/ MID ELEMENT @ 10,672' RKB, SPACER PIPE, & ANCHOR LATCH (16.84' OAL) Quadco TTS P2P CPP3 5346 11/12/2022 1.625 10,673.5 5,073.6 64.61 ANCHOR LATCH ON SPACER PIPE SPACER PIPE & ANCHOR LATCH ATTACHED TO UPPER P2P Quadco TTS Anchor Latch CPAL 35128 11/12/2022 1.600 10,678.0 5,075.5 64.66 LEAK - TUBING LEAK IDENTIFIED AT SLEEVE @ 10678' DURING LDL PERFORMED 10/6/22 10/6/2022 2.992 10,685.5 5,078.7 64.79 PACKER - PATCH - LWR 2.72" LOWER P2P W/ MID ELEMENT @ 10,672' RKB (4.01' OAL) Quadco TTS P2P CPP3 5260 11/11/2022 1.625 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 4,022.2 2,499.6 69.44 1 GAS LIFT GLV BK 1 1,643.0 6/24/2018 0.188 7,558.3 3,798.2 68.94 2 GAS LIFT DMY BK-5 1 0.0 4/6/2011 0.000 9,436.3 4,494.1 63.20 3 GAS LIFT DMY BK 1 0.0 1/4/2018 EXT PKG (High Seal) 0.000 10,529.8 5,011.7 64.31 4 GAS LIFT Ext Pkg OV BK 1 0.0 11/13/2022 0.250 10,619.5 5,050.4 64.57 5 CHEM CM- 40R BK-5 1 0.0 4/6/2011 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 11,307.5 5,303.5 68.92 PACKER 6.410 HRD ZXP LINER TOP PACKER w/ HOLD DOWNS 4.940 11,326.5 5,310.4 69.02 NIPPLE 5.500 RS NIPPLE 4.800 11,339.1 5,314.9 69.21 XO THREAD 5.500 5.000 11,359.4 5,322.0 69.51 XO THREAD 3.500 2.992 11,527.8 5,375.7 75.19 Swell Packer 6.380 Swell Packer (3.5" SLHT) OD 6.38" w/ 5" Sealing Element 5.000 11,735.1 5,420.5 79.93 FRAC PORT 5.750 3 1/2 SLHT Ball Actuated Sleeve (2.0" Ball on Seat) MILLED TO 2.72" IN 2011 2.720 11,941.0 5,444.3 87.03 Swell Packer 6.380 Swell Packer (3.5" SLHT) OD 6.38" w/ 5" Sealing Element 5.000 12,145.4 5,443.6 92.48 FRAC PORT 5.750 3 1/2 SLHT Ball Actuated Sleeve (2.0" Ball on Seat) MILLED TO 2.72" IN 2012 2.720 DEVIATED, 2L-306, 12/6/2022 10:29:23 AM Vertical schematic (actual) LINER; 11,307.5-13,157.6 PERFP; 13,140.0-13,144.0 FRAC; 13,140.0 FRAC; 12,975.0 PERFP; 12,975.0-12,980.0 PERFP; 12,560.0-12,564.0 FRAC; 12,560.0 PERFP; 12,145.0-12,150.0 FRAC; 12,145.0 PERFP; 11,735.0-11,740.0 FRAC; 11,735.0 PRODUCTION; 38.9-11,472.8 PACKER - PATCH - LWR; 10,685.5 ANCHOR LATCH ON SPACER PIPE; 10,673.5 LEAK - TUBING; 10,678.0 PACKER - PATCH - UPR; 10,669.5 CHEMICAL; 10,619.4 GAS LIFT; 10,529.8 GAS LIFT; 9,436.3 GAS LIFT; 7,558.3 CHEM LINE; 36.5 GAS LIFT; 4,022.2 SURFACE; 41.5-3,664.3 NIPPLE; 510.7 CONDUCTOR; 41.0-96.5 KUP PROD KB-Grd (ft)RR Date 4/9/2011 Other Elev 2L-306 ... TD Act Btm (ftKB) 13,158.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032063000 Wellbore Status PROD Max Angle & MD Incl (°) 92.95 MD (ftKB) 12,177.13 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm) 25 Date 12/20/2017 Comment SSSV: NIPPLE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 12,351.9 5,440.2 89.82 Swell Packer 6.380 Swell Packer (3.5" SLHT) OD 6.38" w/ 5" Sealing Element 5.000 12,559.8 5,442.2 89.09 FRAC PORT 5.750 3 1/2 SLHT Ball Actuated Sleeve (1.875" Ball on Seat) MILLED TO 2.72" IN 2012 2.720 12,795.8 5,440.9 89.87 Swell Packer 6.380 Swell Packer (3.5" SLHT) OD 6.38" w/ 5" Sealing Element 5.000 12,830.0 5,440.9 89.97 Swell Packer 6.380 Swell Packer (3.5" SLHT) OD 6.38" w/ 5" Sealing Element 5.000 12,974.9 5,442.4 88.95 FRAC PORT 5.750 3 1/2 SLHT Ball Actuated Sleeve (1.75" Ball on Seat) MILLED TO 2.72" IN 2012 2.720 13,085.9 5,444.7 88.72 Swell Packer 6.380 Swell Packer (3.5" SLHT) OD 6.38" w/ 5" Sealing Element 5.000 13,139.6 5,445.9 88.72 FRAC PORT 5.750 3 1/2 SLHT Ball Actuated Sleeve (1.5" Ball on Seat) MILLED TO 2.72" IN 2012 2.720 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 11,735.0 11,740.0 5,420.5 5,421.4 4/3/2011 PERFP FRAC PORT 12,145.0 12,150.0 5,443.6 5,443.4 4/3/2011 PERFP FRAC PORT 12,560.0 12,564.0 5,442.2 5,442.3 4/3/2011 PERFP FRAC PORT 12,975.0 12,980.0 5,442.4 5,442.4 4/3/2011 PERFP FRAC PORT 13,140.0 13,144.0 5,445.9 5,446.0 4/3/2011 PERFP FRAC PORT Stimulation Intervals Top (ftKB)Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 11,735.0 11,740.0 1 FRAC 6/4/2011 0.0 0.00 0.00 12,145.0 12,150.0 2 FRAC 6/4/2011 0.0 0.00 0.00 13,140.0 13,144.0 3 FRAC 6/4/2011 0.0 0.00 0.00 12,975.0 12,980.0 4 FRAC 6/4/2011 0.0 0.00 0.00 12,560.0 12,564.0 5 FRAC 6/4/2011 0.0 0.00 0.00 DEVIATED, 2L-306, 12/6/2022 10:29:27 AM Vertical schematic (actual) LINER; 11,307.5-13,157.6 PERFP; 13,140.0-13,144.0 FRAC; 13,140.0 FRAC; 12,975.0 PERFP; 12,975.0-12,980.0 PERFP; 12,560.0-12,564.0 FRAC; 12,560.0 PERFP; 12,145.0-12,150.0 FRAC; 12,145.0 PERFP; 11,735.0-11,740.0 FRAC; 11,735.0 PRODUCTION; 38.9-11,472.8 PACKER - PATCH - LWR; 10,685.5 ANCHOR LATCH ON SPACER PIPE; 10,673.5 LEAK - TUBING; 10,678.0 PACKER - PATCH - UPR; 10,669.5 CHEMICAL; 10,619.4 GAS LIFT; 10,529.8 GAS LIFT; 9,436.3 GAS LIFT; 7,558.3 CHEM LINE; 36.5 GAS LIFT; 4,022.2 SURFACE; 41.5-3,664.3 NIPPLE; 510.7 CONDUCTOR; 41.0-96.5 KUP PROD 2L-306 ... WELLNAME WELLBORE C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-10-06_15875_KRU_2L-306_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15875 KRU 2L-306 50-103-20630-00 Caliper Survey w/ Log Data 06-Oct-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:210-182 T37169 Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.20 11:24:12 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-10-06_15875_KRU_2L-306_LeakDetectionSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15875 KRU 2L-306 50-103-20630-00 Leak Detect Survey 06-Oct-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:210-182 T37169 Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.20 11:21:27 -08'00' RECEWED ConocoPhillips AUG 2 9 2016 Alaska P.O. BOX 100360 C ANCHORAGE,ALASKA 99510-0360 AOGC August 25, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 SCANNED SEP 3 0 MC: Anchorage,AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement 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 attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter at 907-659-7006 or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Roger Winter ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field Date 8/25/2016 1 D,2A,2L,2N&2W PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 1D-09 50029228750000 1980650 14" NA 14" NA 7 8/24/2016 2A-19A 50103201970100 2010830 11" NA 11" NA 4.25 8/24/2016 2L-306 50103206300000 2101820 12" NA 12" NA 2.55 8/24/2016 2N-341 50103202630000 1981030 14" NA 14" NA 6.8 8/24/2016 2N-347 50103203370000 2000630 13" NA 13" NA 10.2 8/24/2016 2W-10 50029212390000 1842230 10" NA 10" NA 6 8/24/2016 • STATE OF ALASKA T ALA OIL AND GAS CONSERVATION COMOION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r PlugPerforationsPull Tubing I— Operations shutdown E E Fracture Stimulate � p Performed. Suspend I - Perforate Alter Casing E Other� r Change Approved Program Plug for Redrill I- Perforate New Pool Repair Well r Re-enter Susp Well Other:Cond ext F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. • Developmen F Exploratory E 210-182-0 3.Address: Stratigraphi Service 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20630-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380052 ADL0380051 KRU Tarn 2L-306 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 13157 feet Plugs(measured) None true vertical 5446 feet Junk(measured) None Effective Depth measured 13157 feet Packer(measured) 11348 true vertical 5446 feet (true vertical) 5318 Casing Length Size MD TVD Burst Collapse CONDUCTOR 57 16 97 97 0 0 SURFACE 3623 13 3664 2371 0 0 PRODUCTION 11434 10 11473 5360 0 0 LINER 1850 6.59 13158 5446 0 0 Perforation depth: Measured depth: Slotted Liner 11307-131571 016 RECEIVED True Vertical Depth: Slotted Liner 5303-5446 SCAE� OCT 2L U 1'� ,JUN 0 7 2016 Tubing(size,grade,MD,and TVD) 3.5, L-80, 11347 MD, 5318 TVD AOGCC Packers&SSSV(type,MD,and TVD) SEAL ASSY-GBH-22 80-40 SEAL ASSEMBLY W/1/2 MULE SHOE @ 11348 MD and 5318 TVD NIPPLE-CAMCO DS NIPPLE w/2.875"PROFILE @ 511 MD and 510 TVD 12.Stimulation or cement squeeze summary:NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory I— Development F Service I- Stratigraphic E Copies of Logs and Surveys Run E 16.Well Status after work: Oil F Gas E WDSPL 1— Printed Printed and Electronic Fracture Stimulation Data I- GSTOR I- WINJ r WAG r GINJ - SUSP I- SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-654 Contact Roger Winter Email N1927a,conocophillips.com Printed Name Roger Win r` Title WI Field Supervisor Signature Phone:659-7506 Date 6/5/16 Form 10-404 Revised 5/2015 vv-z_ 4 Z !! Submit Original Only 04 RBDMS LL, Jaid 0 7 2016 II • ConocoPhillips Alaska P.O. BOX 100360 RECEIVED ANCHORAGE,ALASKA 99510-0360 JUN 0 7 201b June 5, 2016 AOGC C Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 2L-306, PTD 210-182 conductor extension. Please contact me at 659-7506 if you have any questions. Sincerely, 41()r Roger Winter ConocoPhillips Well Integrity Field Supervisor 4 ` • • 2L-306 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/03/16 Weld 12" extension on conductor w/16" .375 wall pipe. ? '� 7+. a� y �lF r i ,yes ' 4; i ' 'will! , ' , ' ., :':, *,,,,,:i'4::pi , ,..,, -.....,-,-,34-,- ,,,,, -:,,-1..,,,-,,.. ,,,,..,...r., ....,:., _ ..,,, 0 vt ca X '-' >, CU c° "'C5 4., f " ' cD Q a . ` s... >. "_p .Q �x .. z 4 r xa , , • ,-.:',..?„. .-..4T--:-.." .a:„,„„•s- aN. �� .rye 1 > t„,,, ";+ s,.. h, ,res, ..s,�.tia.. 9 � '` is 7 - , , , • • 2_G , WELL LOG TRANSMITTAL PROACTIVE DIAGNOSTIC SERVICES, INC. DATA LOGGED 4..12-1201'5 Vit.K BENDER To: AOGCC Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(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 attention of: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 scoliej r\-• 1) Production Profile 28-Oct-15 2L-306 BL/CD 50-103-20630-00 2) Signed : / 2Z (_i1, /.-le%+� Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx • AtiOF w\��\ s THE STATE Alaska Oil and Gas of/\ L /\ SKA Conservation Commission 333 West Seventh Avenue � GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 WWW.aogcc.alaska.gov MJ Loveland ANNE WI Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2L-306 Sundry Number: 315-654 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this 4.3 day of October, 2015 Encl. L RBDMS Ut..i 26 2015 J E STATE OF ALASKA Al1PKA OIL AND GAS CONSERVATION COM•SION REOC 1 ;(1) 2015 APPLICATION FOR SUNDRY APPROVALS 0-is ic. 1 zZj Is 20 AAC 25.280 AOGCC 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing fl Operations shutdown 1 Suspend r Perforate J Other Stimulate r ' Alter Casing IT Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well E Other:Cond ext ijd 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number ConocoPhillips Alaska, Inc. Exploratory r Development 17 210-182-0 3.Address: Stratigraphic ' Service 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20630-00 . 7. If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 17 KRU Tarn 2L-306 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380052 ADL0380051 ' Kuparuk River Field/Tarn Oil Pool 4 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13157 ' 5446 - 13157' - 5446' • None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 56 16 97' 97' SURFACE 3623 10.75 3664' 2371' PRODUCTION 11434 7.625 11473' 5360' LINER 1850 3.5 13158' 5446' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slotted Liner 11307-13157 e Slotted Liner 5303-5446 3.5 L-80 11347 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SEAL ASSY-GBH-22 80-40 SEAL ASSEMBLY W/1/2 MULE SHOE MD=11348 TVD=5318 NIPPLE-CAMCO DS NIPPLE w/2.875"PROFILE • MD=511 TVD=510 , 12.Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory r Stratigraphic r Development 171 Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/15/2015WINJ 1— WDSPL r Suspended fl OIL r, 16.Verbal Approval: Date: GAS WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r ' Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland Email: N1878@conocophillips.com Printed Name MJ Loveland Title: WI Project Supervisor Signature / �n Phone:659-7043 Date �(f /a /�S ((!! �` Commission Use Only / Sundry Number: Conditions of approval: Notify Commission so that a representative may witness -316— ( 6 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No / Subsequent Form Required: �p�qM g APPROVED BY Approved by: , veil application is vafl(1 TOt!-1-z months from thT� Ei f' 9rr1val. Date: (/O —Z.3r`/S Form 10-403 Re e6 5%2 ORIGINAL ��� �— RBDMSwttacTfwnd �Fori ate �O� • • ✓ . . RECEWED ConocoPhillips OCT 2 0 2015 Alaska GC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 18, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2L-306, PTD 210-182 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska,Inc. Kuparuk Well 2L-306 (PTD 210-182) SUNDRY NOTICE 10-403 APPROVAL REQUEST 10-18-15 This application for Sundry approval for Kuparuk well 2L-306 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about 8". With approval,the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor " KUP PROD • 2L-306 ConocoPhillips , Well Attributes Max Angle&MD TD Aladka.111C. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) ,,,r,,,�„n„11,1„ 501032063000 TARN PARTICIPATING AREA PROD 92.95 12177.13 13,158.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 1 Rig Release Date DEVIATED-2L-306,6724/2015 454'27 PM SSSV:NIPPLE 75 11/2/2014 Last WO: 4/9/2011 Vertical schematic(actual) _ Annotation Depth(ftKB) End Date Annotation f Last Mod By End Date HANGER;365 MB Last Tag:SLM 11,803.0 6/22/2015 Rev Reason:TAG lehallf 6/24/2015 s,7 111 Casing Stnngs Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread , IL^ CONDUCTOR 16 14.969 41.0 96.5 96.5 164.00 FI-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 41.5 3,664.3 2,371.5 45.50 L-80 BTC CONDUCTOR;41.0-96.5 Casing In OD Description p (In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen 0...Grade Top Thread V PRODUCTION 75/8 6.875 38.9 11,472.8 5,360.2 29.70 L-80 BTCM li B Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 312 2.992 11,307.5 13,157.6 9.30 L-80 SLHT NIPPLE;610.7 - Liner Details B - Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 11,307.5 5,303.5 68.92 PACKER HRD ZXP LINER TOP PACKER w/HOLD DOWNS 4.940 11,326.5 5,310.4 69.02 NIPPLE RS NIPPLE 4.800 SURFACE;41.53,664.3-. 11,329.3 5,311.4 69.06 HANGER FLEX LOCK III LINER HANGER 4.800 11,340.9 5,315.5 69.23 SBE 80-40 SEAL BORE EXTENSION 4.000 GAS LIFT;4,022.2 elf 11,527.8 5,375.7 75.19 Swell Packer Swell Packer(3.5"SLHT)OD 6.38"w/5"Sealing 5.000 CHEM LINE;36.5 Element GAS LIFT;7558.3 11,735.1 5,420.5 79.93 FRAC PORT '3 1/2 SLHT Ball Actuated Sleeve(2.0"Ball on Seat) 2.720 MILLED TO 2.72"IN 2011 I i 11,941.0 5,444.3 87.03 Swell Packer Swell Packer(3.5"SLHT)OD 6.38"w/5"Sealing Element 5.000 GAS LIFT;9,436.3 CIS 12,145.4 5,443.6 92.48 FRAC PORT 3 1/2 SLHT Ball Actuated Sleeve(2.0"Ball on Seat) 2.720 • MILLED TO 2.72"IN 2012 GAS LIFT;10,529.8 12,351.9 5,440.2 89.82 Swell Packer Swell Packer(3.5"SLHT)OD 6.38"w/5"Sealing 5.000 Element 12,559.8 5,442.2 89.09 FRAC PORT 3 1/2 SLHT Ball Actuated Sleeve(1.875"Ball on 2.720 CHEMICAL;10,619.4 Seat)MILLED TO 2.72"IN 2012 12,795.8 5,440.9 89.87 Swell Packer Swell Packer(3.5"SLHT)OD 6.38"w/5"Sealing 5.000 Element SLEEVE;10,678.3 t 1- 12,830.0 5,440.9 89.97 Swell Packer Swell Packer(3.5"SLHT)OD 6.38"w/5"Sealing 5.000 Element 12,974.9 5,442.4' 88.95 FRAC PORT 3 1/2 SLHT Ball Actuated Sleeve(1.75"Ball on Seat) 2.720 NIPPLE;10.734.0 MILLED TO 2.72"IN 2012 j 13,085.9 5,444.7 88.72 Swell Packer Swell Packer(3.5"SLHT)OD 6.38"w/5"Sealing 5.000 Element 4 13,139.6 5,445.9 88.72 FRAC PORT 3 1/2 SLHT Ball Actuated Sleeve(1.5"Ball on Seat) 2.720 MILLED TO 2.72"IN 2012 Tubing Strings Tubing Description String Ma...10(In) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(IMO Grade Top Connection LOCATOR;11,347.2 .�. TUBING 31/2 2.992 36.5 11,367.5 5,324.8 9.30 L-80 EUE8RMOD SEAL ASSY;11,347.7 Completion Details Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn Nominal ID(in) 36.5 36.5 0.00 HANGER FMC TUBING HANGER 4.500 101.5 101.5 0.33 XO Reducing CROSSOVER 4.5 x 3.5,ID 3.958,#12.6,L-80,IBTM 3.500 PRODUCTION;38.9-11,472.9 510.7 509.9 6.78 NIPPLE CAMCO DS NIPPLE w/2.875"PROFILE 2.875 10,678.3 5,075.6 64.67 SLEEVE BAKER CMU SLIDING SLEEVE w/2.813 DS PROFILE 2.813 10,734.0 5,099.1 65.62 NIPPLE CAMCO D NO GO NIPPLE 2.750 11,347.2 5,317.7 69.33 LOCATOR LOCATOR COLLAR 3.000 PERFP;11,735.611,740.0 _ 11,347.7 5,317.9 69.33 SEAL ASSY GBH-22 80-40 SEAL ASSEMBLY w/1/2 MULE SHOE 3.000 FRAC;11,735.01 L- � II I Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) I") Des Com Run Date 103230E07)0050: D(in) 36.5 36.5 0.00 CHEM LINE CHEMICAL INJECTION LINE 4/6/2011 0.000 Perforations&Slots Shot Den PERFP;12,145.612,150.0 To TUCB Top(ND) Btm(TVD) (shots/f FRAC;12,145.0 i}� - P( ) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 11,735.0 11,740.0 5,420.5 5,421.4 4/3/2011 PERFP FRAC PORT 12,145.0 • 12,150.0 5,443.6 5,443.4 4/3/2011 PERFP FRAC PORT 12,560.0 12,564.0 5,442.2 5,442.3 4/3/2011 PERFP FRAC PORT 12,975.0 12,980.0 5,442.4 5,442.4 4/3/2011 PERFP FRAC PORT 13,140.0 13,144.0 5,445.9 5,446.0 4/3/2011 PERFP FRAC PORT FRAC;12560.0Stimulations&Treatments PERFP;12,5600412,564.0 J7 1 - Min Top Max Btm Depth Depth Top(TVD) Btm(WD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 11,735.0 11,740.0 5,420.5 5,421.4 FRAC 6/4/2011 FRAC w/657,259#16/20 carbolite proppant. 12,145.0 12,150.0 5,443.6 5,443.4 FRAC 6/4/2011 FRAC w/657,259#16/20 carbolite proppant. • 12,560.0 12,564.0 5,442.2 5,442.3 FRAC 6/4/2011 FRAC w/657,259#16/20 carbolite proppant. 12,975.0 12,980.0 5,442.4 5,442.4 FRAC 6/4/2011 FRAC w/657,259#16/20 carbolite proppant. 13,140.0 13,144.0 5,445.9 5,446.0 FRAC 6/4/2011 FRAC w/657,259#16/20 carbolite proppant. FRAC;12,975.0 Mandrel Inserts PERFP;12.975..612,990.0 rl Ii St aft on Top(TVD) Valve Latch Pon Size TRO Run N Top(ftKB) (ftKB) Make Model OD(In) Sem Type Type (in) (psi) Run Date Com 1' 4,022.2 2,499.6 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/29/2011 2 7,558.3 3,798.2 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 4/6/2011 3 9,436.3 4,494.1 CAMCO KBMG 1 GAS LIFT OV INT 0.313 0.0 7/10/2011 I_ 4 10,529.8 5,011.7 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 6/12/2011 FRAC;13,140.0 5 10,619.5 5,050.4 CAMCO KBMG- 1 CHEM CM- BK-5 0.000 0.0 4/62011 PERFP;13,140.613,144.0 I� LTS 40R LINER;11.307.5-13,157.6 s • KUP PROD 0 2L-306 ConocoPhillips AIdska.it t CouiAiiTT • DEVIATED-2L-306,524/2015 454 28 PM Vertical schematic(actual) HANGER;365 7IMir - 47�1I„ (Notes:General&Safety ( i EndDate Annotation j;,� I 4/19/2011 NOTE:View Schematic w/Alaska Schematic9.0 CONDUCTOR;41.0-96.5 V■ ■ ■ NIPPLE;510.7 a SURFACE;41.53.664.3- 1. 11 GAS LIFT;4,022.2 t CHEM LINE;36.5 15 II GAS LIFT;7,558.3 $ a Ii GAS UFT;9,436.3 - i' I GAS LIFT;10,529.8 •is CHEMICAL;10,619.41 III 1111 SLEEVE;10,678.3 II- a NI NIPPLE;10,734.0 A H II- 1 LOCATOR;11,347.2 IM.SEALASSY;11,347.7 PRODUCTION;38.9-11,472.8 PERFP;11R3A5C0-1117085 L11 _ PERFP;12,145.0-12,150.0 if r FRAC;12,145.01 1J sir FRAC;12,560.0 ' � PERFP;12,560.0-12,564.0 FRAC;12,975.0 PERFP;12,975.0-12.980.0 FRAC;13,140.0 PERFP;13,140.013,144.0 LINER;11,307.5-13.157.6 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. , L Q - L g a Well History File Identifier Organizing (done) Two-sided N1111111 11111 fl Rescan Needed III11111111 1111111 RES AN DIGITAL DATA OVERSIZED (Scannable) C or Items: ❑ Diskettes, No. E Maps: Greyscale Items: ❑ Other, No/Type: they Items Scannable by a Large Scanner i.0 s ❑ Poor Quality Originals: `/ OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: Ito BY: Maria Date: 4..//3")/ /s/ Project Proofing 111111111111011111 Olfi BY: Maria Date: 14P,51/ Li T /s/ Scanning Preparation 7 x 30 = c j Q + 3 = TOTAL PAGES a 13 i) (Count does not include cover sheet) BY: AM Date: �s' J�' /sl Production Scanning 111111111111011111 Stage 1 Page Count from Scanned File:(" ,1 1'' (Count does include cov eet) Pa•e Count Matches Number in Scanni g Pre aration: YES NO BY: g° Date: Lt. Is i / /s/ ri413 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: Is/ Scanning is complete at this point unless rescanning is required. IIIIIIIIIIIIIIIIII ReScanned II IIIIIIIIIIIIIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III 111111 III 1111 III Q 0 0 7- -1m • o yy .E 9 I U J c a CO 0 cc 1 •el E c o f o 0 E o >. 0 o Z i.0 o o o 0 V ru c o 6 i us c c u _ _1J 0 co C7 0 ! • Z H 2 I- 2 1- CO a a a CO CO a CO a J 0 0 0 0 0 0 0 0 0 0 0 0 0 C-! N CO N N N N N N N N N N N 1'i O 0 a) T O) O) 0 0 O) O) O) 0 0 0 Z to U) 10 L0 10 10 U) U) IC �O 14 ) U) 2 _ C as = C C C C C C C C C C C C C too a N N Na N N Na N N a N. N. N0. Eo 1da.+ D� 5 00 0 0 0 O O 0 O O O O O O , Ci Q d (O co (0 co (0 a a a a a a a i` Zi N U M M M M M W coNco coNcoNcoNco coNp_ d Z Z O. 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Q N as as r-- V N- h ci, vt V a ID CV CV CV CV (O CO (O ID 10 ID 0 co f63 CO CO 00 CO 0 A J 0 6 — .M- .- - .M- .- .01 M- .M- Li n Z W it O c t o in o coN- N U CO CO M M M c) W z V 8 Q Z c cc Q c II I J a m 16 ^ 0 N I '1 0) 0 0 0 0 0 0 O O O O rr c zl '', J �I 0 0 0 0 0 0 U U U 5 0 o •tu- W .I'll o 0 -5'11 E0 J f0 N N N N N N N N N W o J M Q N I— X i Q � I C� F- C = ' o ,l CON ; Il W C-12l N II 1 Cl) n a) V/ reQ Q a C Y47. g 1'' o Q C a Z) (A fr _ w - . w w w — • 0 LU Q N ( I p C C N N N N V) N V) co J a' 47, LLM O O a) a) a) Cl) a) a) Cl) t6 Z 0 v CO a R CC a: a' a' a C w w C C C C C C C O) p) 07 —y O N N .2 O O O O O O C J • COI▪ i > > > > a J J > > > > > o 13 ID 'I Z1� c c c c c c c a) 2 2 2 — — — — CV N 0 Z J L. d a)) co .+ H £ Co V NN WO Z. 4 Q O I = 0 iF ..- < o .E+ U. i ' w ;` rnG � uj .2 IX I Z W m E ' 5I1 Q N J ! 0 J 0 0. a' W J 0 0 0 0 J J , 0 1- J 0 H ConocoPhillips Alaska P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 15,2012ai a,ip - I Commissioner Dan Seamount L 3 Alaska Oil&Gas Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Commissioner Dan Seamount: Enclosed are the spreadsheets with a list of wells from the Alpine field(CRU),and the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped in the spring of 2012. The corrosion inhibitor/sealant was pumped in the months of April and May 2012. The attached spreadsheet presents the well name,top of cement depth prior to filling,and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043,if you have any questions. Sincerely, 1 Martin Walters 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 5/15/2012 1C,1D,1E,2L,3H PAD Corrosion _ Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API,# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal -1C-133 50029230130000 2010770 16" 3.9 12" 5/8/2012 6.8 5/14/2012 1D-116 50029229150000 1981720 10" 1.2 10" 5/8/2012 4.3 5/15/2012 1E-123 50029232080000 2040740 5" n/a 18" n/a 5.1 4/9/2012 2L-304 50103206130000 2100110 31" 0.30 20" 3/30/2012 4.3 5/14/2012 2L-306 50103206300000 2101820 8" n/a 8" n/a 3.4 5/14/2012 2L-310 50103206160000 2100280 25" 0.25 12" 3/30/2012 2.6 5/14/2012 2L-312 50103206260000 2101640 13" n/a 13" n/a 2.5 5/14/2012 2L-319 50103205520000 2071120 112" 1.00 20" 3/30/2012 6 5/14/2012 2L-320 50103206270000 2101660 36' 1.00 50" 3/30/2012 3.4 5/14/2012 • 3H-17 50103200810000 1870990 19" n/a 19" n/a 3.4 4/9/2012 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Plug Perforations r Stimulate J Other r Atter Casing r Rill Tubing r Perforate New Fool r Waiver r Time Extension r Change Approved Program r Operat.Shutdown r Perforate r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 210-182-0 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service .: 50-103-20630-00—CIO 7. Property Desigpationn(Lease Number): 8.Well Name and Number: ADL 380052,380051 ,-0 2L-306 9. Field/Pool(s): Kuparuk River Field/Tarn Oil Pool 10.Present Well Condition Summary: Total Depth measured 13157 feet Plugs(measured) None true vertical 5446 feet Junk(measured) None Effective Depth measured 13157 feet Packer(measured) 11308 true vertical 5446 feet (true vertucal) 5304 Casing Length Size MD TVD Burst Collapse CONDUCTOR 56 16 97 97 SURFACE 3623 10.75" 3664 2371 PRODUCTION 11434 7.625" 11473 5360 LINER 1850 3.5" 13158 5446 .CE VED Perforation depth: Measured depth: slotted liner 11307'-13157' True Vertical Depth: 5303'-5446' ,u'i_ i ' )(11' Tubing(size,grade,MD,and TVD) 3.5, L-80, 11367 MD,5325 ND Al "�`a JI{ 8,.. COM Cf3iili111SS10t1 Packers&SSSV(type,MD,and TVD) PACKER-HRD ZXP LINER TOP PACKER @ 11308'MD and 5304'ND NIPPLE-CAMCO DS NIPPLE w/2.875"PROFILE @ 511 MD and 510 TVD 11.Stimulation or cement squeeze summary: Intervals treated(measured): 11735'-13144' Treatment descriptions including volumes used and final pressure: 657259#of 16/20 carbolite proppant 12. 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 13.Attachments 14.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r -Service r Stratigraphic r 15.Well Status after work: ,Oil pW' Gas r WDSPL r Daily Report of Well Operations, XXX GSTOR r WINJ rWAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact John Peirce Cad 265-6471 Printed Name John Peirce Title Wells Engineer Signature 70,4 A r, Phone:265-6471 Date 1112/1 1Z/i.i ge SMS JUL 137 /3-1( Form 10-404 Revised 10/2010 Submit Original Only 2L-306 Well Work Summary DATE SUMMARY 5/27/11 PLA.LED SOV @ 4022' RKB & REPL..,ED WITH DV. MIT TBG 3500 PSI, PASSLLJ. ATTEMPTED MIT IA, QUESTIONABLE. IN PROGRESS. 5/28/11 PULLED DV @ 10529' RKB & REPLACED WITH SPG. IN PROGRESS. 5/29/11 PULLED DV @ 4022' RKB. CIRC OUT 180 BBL SW& 125 BBL DSL DOWN IA. SET DV @ 4022' RKB. MIT TBG & IA 3500 PSI EACH, PASSED. PULLED CATCHER. IN PROGRESS. 5/30/11 PULLED BALL& ROD AND RHC PLUG BODY FROM D NIPPLE @ 10734' RKB. DRIFTED TBG TO 11527' SLM WITH 2.64 CENT. READY FOR PUMP-IN TEST. 5/31/11 Performed injectivity test, preceeded with 1.625"sleeve-opening frac ball. Used two LRS units to pump six stages at 0.5, 1.0, 2.0, 4.0, 7.0, and 10 BPM. Tubing pressure during the 10-bpm seawater stage was 2600-psi. Observed ball seat by a surface pressure spike of 3200-psi with 101-bbl away. Pumped total volume of 245-bbl filtered seawater and 50-bbl diesel freeze-protect. 5/31/11 PULLED HES SPG FROM STA#4 @ 10,529' RKB AND DOWNLOADED INFORMATION. RESET IN SAME. JOB COMPLETE 6/4/11 Performed Bermuda T2 formation frac consisting of 5 main stages utilizing Packers Plus StackFRAC system. Each stage placed approximately 125,000#of 16/20 Carbolite using 25#crosslink gel at 23- 30 bpm, for a job total of 657,259#sand and 7528-bbl pumped (105%design). Stages initiated by dropping frac balls(1.75"-2.125"dia, 0.125" increments)that open specific ports along horizontal liner. The 1.625" ball isolating the bottom zone was pumped in lead of injectivity test on 5/31/2011. The prop fracture treatment was preceded by a breakdown/data-frac using 25#linear gel. 6/7/11 DRIFTED TBG TO 11,600' SLM W/2.64 CENT&2.5" DD BAILER; HAD TO WORK THRU MULTIPLE BRIDGES AND ONLY ABLE TO MAKE HOLE WHILE PUMPING @ MIN RATE. READY FOR COIL 4,�, KUP 2L-306 c ,`1 r C oP1 ilhps ; 'A _Weil Attributes Max Angle 8 MD TD illix:;itt f '4✓)`'�5i'"3 Wellbore APW WI Feld Name Well Status Incl() MD(8Min Act n(ftK8) Issia<cii'hxiNm 501032063000 (TARN PARTICIPATING AREA I EXPEND 1 92.95 I 12,177.13 13,157.0 Comment H2S(ppm) Date Annotation End Date KB.Grd(ft) Rig Release Date wen Cce DEVNT O-t.gt. -131..1 1111 Z43B AM,_ SSSV:NIPPLE 1_ Last WO: _ 4/9/2011.__-_ S_4e1k..er. _ 'Annotatb Depth(ftK8) End Date Annoblion Last Mod.. End Date , -. Last Tag I __ f Rev Reason:FRAC,GLV C/O,PULL BALL 8 ROD ninam 1 6/14/2011 HANGER,37 .:. Casing Strings r r Casing Description String 0... String ID...Top(ftK8) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 1 :.; CONDUCTOR 16 14.969 41.0 96.5 96.5 164.00 H-40 WELDED Casing Description String O... String ID...Top(fIKB) Set Depth(f...Set Depth(TVD)...String Wt...String._String Top Thrid I SURFACE 10 3/4 9.950 41.5 3,664.3 2,371.5 45.50 L-80 BTC Casing Description String 0... String ID...Top(ftK8) Set Depth(t..SN Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR, _-__- - PRODUCTION 75/8 6.875 38.9 11,472.8 5,360.1 29.70 L-80 BTCM 41-97 .-. Set .. Set Dep I V Casing Description String 0... String ID...Top(ftK8) Set Depth(i...Set Depth(ND)...String Wt...String...String Top Thrd LINER 31/2 2.992 11,307.5 13,157.6 9.30 L-80 SLHT Liner Details Top Depth NIPPLE,511 ------- i it (TVD) Top Incl Nom'... I PFra I Top(ftK8) (flKB) (9 Item Description Comment ID(in) 11,307.5 5,303.5 68.74 PACKER HRD ZXP LINER TOP PACKER w/HOLD DOWNS 4.940 i ' 11,326.5 5,310.4 69.02 NIPPLE RS NIPPLE 4.800 Il 11,329.3 5,311.4 69.06 HANGER FLEX LOCK III LINER HANGER 4.800 SU41-3.6RFACE.__ l 4 11,340.9 5,315.4 69.23 SBE 80-40 SEAL BORE EXTENSION 4.000 61 11,527.8 5,376.8 77.92 Swell Packer Swell Packer(3.5"SWT)OD 6.38"w/5"Sealing Element 5.000 GAS iLIFT,_ ----- ,_.022 11,735.1 5,420.3 79.59 SLEEVE 3 1/2 SLHT Ball Actuated Sleeve(2.125"Ball on Seat) 2.000 CHEM LINE,37 ------ -=: 11,941.0 5,445.0 88.94 Swell Packer Swell Packer(3.5"SLHT)OD 6.38"w/5"Sealing Element 5.000 , Cris LIFT r.. 12,145.4 5,443.5 92.48 SLEEVE 31/2 SLHT Ball Actuated Sleeve(2.0"Ball on Seat) 1.875 lssa 12,351.9 5,440.2 89.82 Swell Packer Swell Packer(3.5"SLHT)OD 6.1.8"w/5"Sealing Element 5.000 1 12,559.8 5,446.8 93.28 SLEEVE 3 1/2 SLHT Ball Actuated Sleeve(1.875"Ball on Seat) 1.750 Gas LIFT, i ' 12,795.8 5,441.2 90.40 Swell Packer Swell Packer(3.5"SLIT)OD 638"w/5"Sealing Element 5.000 9.436I 12,830.0 5,441.0 90.09 Swell Packer Swell Packer(3.5"SLHT)OD 6 38"w/5"Sealing Element 5.000 it 12,974.9 5,442.2 88.72 SLEEVE 3 1/2 SLHT Ball Actuated Sleeve(1 75"Bat on Seat) 1.625 GAS LIFT, 13,085.9 5,444.71 88.72 Swell Packer Swell Packer(3.5"SLHT)OD 6,38"w/5"Sealing Element 5.000 10,530 _.. _ 13,139.6, .5.445.91 88.72 SLEEVE 3 1/2 SLHT Ball Actuated Sleeve(1 625 Ball on Seat) 1.500 c. / !Tubing Strings �M ' CHEMICAL, TubingDescription String0... StringID....roe ftK8 I Set Depth(f...I Set Depth(ND) String Wt.. String...IStrin To Thrd 10,619 Pion 11 P( ) P ( 99 P IUBING 31/2 2992 36.5 11,367.5 5,324.6 9.30 L80 EUE8RMOD SLEEVE, Completion Details 10,878 Top Depth, -- - (ND) Top Inc' Nomi... :" Top(MB) (fes) (") !tern Description Comment ID(In) 36.5 36.5 -0.04 HANGER FMC TUBING HANGER 4.500 NIPPLE,10,734 4 101.5 101.5 -0.03 X0 Reducing CROSSOVER 4.5 x 3.5,ID 3.958,1112.6,L-80,IBTM 3.500 510.7 509.9 6.72 MPPLE CAMCO DS NIPPLE w/2.875"PROFILE 2.875 l l- 10,678.3 5,074.7 64.81 SLEEVE BAKER CMU SLIDING SLEEVE WI 2 813 DS PROFILE 2.813 10,734.0 5,098.9 65.68 NIPPLE CAMCO 0 NO GO NIPPLE 2.750 11,347.2 5,317.6 69.33 LOCATOR LOCATOR COLLAR 3.000 11-34// 6.31/.8 69.33 SEAL ASSY GBH-22 80-40 SEAL ASSEMBLY w/1/2 MULE SHOE 3.000 LOCATOR, 11.3i7 dam' Other In Hole(Wireline retrievable plugwalves,pump fishy etc.) SEAL ASSY, _ .t To Depth - __....-.. 11,348 (TVD) Top loci Top(MIA_ MKS) C) Description Comment Run Date ID(in) 37 36.5 -0.04 CI IEM LINE CHEMICAL INJECTION LINE 4/6/2011 0.000 Stimulations&Treatments Bottom -.- _--_-- Min Top Max Btrn Top Depth Depth PRODUCTION, . 4\ Depth Depth (ND) (13/01 39-11,473 (ftK8) (ftKB) (ftK8) (ftK8) Type Date Comment 11,735.1 13,144.3 5,420.3 5,421.2 FRAC 6/4/2011 Fractured well with 657,259 total weight of 16/20 carbolite propant. 11,735.1 13,144.3 5,443.5 5,443.3 FRAC 6/4/2011 Fractured well with 657,259 total weight of 16/20 carbolite propant. FRAC.11T35 1 I 11,735.1 13,144.3 5,446.8 5,446.4 FRAC 6/4/2011 Fractured well with 657,259 total weight of 16/20 carbolate propant. 11,735.1 13,144.3. 5,442.2 5,442.4 FRAC 6/4/2011 Fractured well with 657,259 total weight of 16/20 ! carbolite propant. . 11.735.1 13,144.3 5,445.9 5,446.0 FRAC 6/4/2011 Fractured well with 657,259 total weight of 16/20 I Mollie propant. 1 Notes:General&Safety End Date Annotation - - -.- FRAC,12,145 1 lilt 1 4/19/2011 NOTE:View Schematic WI Alaska Schematic90 FRAC,12,560 i , 1 Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch 511:0 TRO Run Stn Top(8KB) (8KB) (°) Make Model lin) Sery Type Type lie) (psi) Run Date Com... 1 4,022.2 2,499.5 69.32 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/29/2011 2 7,558.3 3,798.2 68.94 CAMCO KBMG 1 GAS LIFT DMY BK-S 0.000 0.0 4/6/2011 3 9,436.3 4,494.1 63.20 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 4/62011 FRAC,12,975 I 4 10,529-8 5,011.8 64.52 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 6/12/2011 5 10,619.5 5,050.3 64.57 CAMCO KBMG-LTS 1 CHEM CM-40R BK-S 0.000 0.0 4/62011 , FRAC,t3,140 I I TO(2L-08), 13,157 LINER, 11,307-13,158 ConocoPhillips p TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT01808 TO: Christine Shartzen ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave, Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 995501 RE: KRU 2L-306, 306PB1 AOGCC permit: 210-182-0 DATE: 5/5/2011 Transmitted: Kuparuk River Unit, North Slope, Alaska 2L-306, 306PB1 Hardcopy and CDROM Final Well report, Mud logging report, CANRIG;well 2L-306 (501032063000); PB1 501032063070); 4/4/2011. Equipment,well data, geological data, pressure/formation strength, drilling data, daily reports,formation logs color prints; Formation log (MD) Formation log (TVD) Gas ratio (MD) Gas ratio (TVD) RECElV3 LWD Combo (TVD) LWD Combo (MD) U1A �li4 Drilling dynamics (MD) g a°it Rs t �fi cos.Ga Drilling dynamics (ND) Ar enG11►g8 CDROM contains; daily reports, DML data, final well report, LAS files, mud log PDF files, remarks and tiff files Sign,scan and return in .pdf format if applicable to Sandra.D.LemkegConocophi//ips.com CC: 2L-306, 306PB1 transmittal folder, production well files, eSearch Receipt: Date: GIS-Technical Data Management I ConocoPhillips I Anchorage,Alaska I Ph:907265.6947 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑✓ Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 51:11.6 LC 12.Permit to Drill Number: ConocoPhillips Alaska,Inc. or Aband.: April'8,2011 210-182/ 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 March 1,2011 50-103-20630-00&50-103-20630-70 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 154'FNL,588'FEL,Sec.22,T1ON,R7E,UM April 3,2011 • 2L-306/2L-306PB1 Top of Productive Horizon: 8.KB(ft above MSL): 40'RKB 15.Field/Pool(s): 2304'FSL,2317'FWL,Sec. 13,T1ON,R7E,UM GL(ft above MSL): 114.8'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 675'FSL,2427'FEL,Sec. 13,T1ON, R7E,UM 13157'MD/5446'TVD Tarn Oil Pool • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-461063 ' y- 5927692 ' Zone-4 • 13157'MD/5446'TVD ' ADL 380052,380051 TPI: x-469256 y- 5930111 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-469786 y- 5928480 Zone-4 nipple @ 511'MD/510'TVD 4600,4599 18.Directional Survey: Yes ❑✓ No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1620'MD/1503'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 164# H-40 41' 96.5' 41' 96.5' 24" Pre Driven 10.75" 45.5# L-80 41' 3664' ./ 41' 2371' 13.5" 1223 sx Class G,114 sx Class G 7.625" 29.7# L-80 41' 11473' 41' 5360' 9.875" 757 sx Class G 3.5" 9.3# L-80 11307' 13157' 5303' 5446' 6.75" slotted liner 24.Open to production or injection? Yes Q No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) 3.5" 11367' 11307'MD/5303'TVD slotted liner 11307'-13157'MD 5303'-5446'ND p ,fit,PIET UN 4 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. ►'4DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED '� �'balanced plug 1 @ 11370'-11824' 301 sx Class G 4`1 4 balanced plug 2 @ 10861'-11370' 301 sx Class G R 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ ' Sidewall Cores Acquired? Yes ❑ No ❑ • If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory anal ical results per 20 AAC 25.071. ECE1V NONE MAY 06 2011 RBDMS MAY 0 6 2011 4th Mika Oil&Gas Cans.Commission Ancnesalge Form 10-407 Revised 12/2009 CONTINUED ON REVERSE .,) Sub '-original only 28. GEOLOGIC MARKERS(List all formations and markers en, .cered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑✓ No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1620' 1503' needed,and submit detailed test information per 20 AAC 25.071. C37 9333' 4450' Top Reservoir 11430' 5346' C35 11626' 5475' N/A 2L-306PB1 total depth 11824' 5564' Formation at total depth: Bermuda 30. LIST OF ATTACHMENTS • Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Nugent @ 263-4228 Printed Name C.Alvord Title: Alaska Drilling Manager Signature 5(�1Zo f.t. g ,�� Phone 265-6120 Date Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 1., KU P 2L-306 conocop ilhips '3'2 Well Attributes .-__ Max Male&MD TD AleskB,MC Wellbore APW WI I Field Name -..- I Well Stat Incl(') MD IRKS) Act Ben(fin) k.onacaNNtkpt 501032063000 TARN PARTICIPATING AREA EXPEND 92.95 12,177.13 13,157.0 ____- Comment 1425(ppm) Date Annotation End Date KB-GM(ft) Rig Rohm*Date •.. wet C"'DEVIR'I'ED 21-305, tt4 p SSSV'NIPPLE Last WO: 4/92011 Sdtemed.Aolaal Annotation (Depth(R(B) Ertl Date An tat n [Last Mod .End Date =' Last Tag: Rev Reason:NEW WELL ninam 4/19/2011 �� r" ler HANGER,37-- a Casing Strings 1. . /. Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 14.969 41.0 96.5 96.5 164.00 H-40 WELDED , '. , Gating Description String 0... String ID...Top(SKS) Set Depth(f...Set Depth(ND)...String Wt_.String...String Top TNM SURFACE 10314 9.950 41.5 3,664.3 2,371.5 45.50 1,-80 BTC f Casing Description Siring 0... String ID...Top(RKB) Set Depth(f...Sat Depth(TVD)...String WL.String...String Top Thad CONDUCT1O.97 R__._ I PRODUCTION 75/8 6.875 38.9 11,472.8 5,360.1 29.70 L-SO BTCM 4 Casing Description String 0... String ID...Top(RKB) Set Depth(L..Set Depth(TVD)...String Wt...String...String Top Thrd LINER 31/2 2.992 11,307.5 13,157.6 9.30 L-80 SLHT I BE Liner Details RE: Top Depth ) NIPPLE,511 3f (TVD) Top not Nomi... pL B) (ftKBi-----(') Item Description Comment -_.- ID(in) 11,307.5 5,303.5 68.74 PACKER HRD ZXP LINER TOP PACKER WI HOLD DOWNS 4.940 11,326.5 5,310.4 69.02 NIPPLE RS NIPPLE 4.800 11,329.3 5,311.4 69.06 HANGER FLEX LOCK III LINER HANGER 4.800 SURFACE, _ I I 1 11,340.9 5,315.4 x.23 SBE 80-40 SEAL BORE EXTENSION 4.000 n 3.664 _____ I - 11,527.8 5,376.8 77.92 Swell Packer Swell Packer(3.5"SLHT)OD 6.38"w/5"Sealing Element 5.000 GAS LIFT• 11,735.1 5,420.3 79.59 SLEEVE '3 1/2 SLHT Ball Actuated Sleeve(2.0"seat ID) 2.000 4,022 CHEM LINE,37- 11,941.0 5,445.0 88.94 Swell Packer Swell Packer(3.5"SLHT)OD 6.38"w/5"Sealing Element 5.000 ' 1214E4 5,443.5 92 48 SLEEVE 3 1/2 SLHT Ball Actuated Sleeve(1.875"seat ID) 1.875 GAS UFT.----- - i,I ---. - --_. _--_---._. 7,558 12,351.9 5,440.2 E9 82 Swell Packer Swell Packer(3 5 SUIT)OD 6 38 WI 5"Sealing Element 5.000 .,t', 12,559.8 5,446.8 93.28 SLEEVE 3 12 SLHT Ball Actuated Sleeve(1.75"seat ID) 1.750 GAS LIFT, 12,795.8 5,441.2 90.40 Swell Packer Swell Packer(3.5"SLHT)OD 638 w/5"Sealing Element 5.000 - - - ---- -- 9,436 `■IILL 12,830.0 5,441.0 90.09 Swell Packer Swell Packer(3.5"SLHT)OD 6.38"w/5"Sealing Element 5.000 II ; 12,974.9 5,442.2 88.72 SLEEVE 3 112 SLHT Ball Actuated Sleeve(1.625"seat ID) 1.625 GAS UFT, -`. 13 085.9 5,444.7 88.72 Swell Packer Swell Packer(3.5'SLHT)OD 6.38"w/5"Sealing Element 5.000 10,530III 13.139.6 5,445.9 88.72 SLEEVE 3 12 SLHT Ball Actuated Sleeve(1.50"seat ID) 1.500 IIF Tubing Strings - -- �_ CHEMICAL,_-. Tubing Description String O.. String ID Top(ftKB) Set Depth(f_.Set Depth(ND) String Wt. String...String Top Thrd 0.619 IUBING t 31/2. I 2.992 I 36.5 111367.5 1 5,324.6 930 L80 I EUE8RMOD Completion Details 10,6]8 SLEEVE, �. Top Depth -- __-- _-- --- (TVD) Top Teel Nomi... M Top(ftKB)_ MKS/ (") p.m Des..100).) Comment ID(in) 36 5 36.5 -0.04 HANGER FMC TUBING HANGER 4.500 NIPPLE,10,734_ - I __ 101.5 101.5 -0.03 XO Reducing CROSSOVER 4.5 x 3.5,ID 3.958,812.6,L-80,IBTM 3.500 $10.7 509.9 6.72 NIPPLE CAMCO DS NIPPLE w/2.875"PROFILE 2.875 ..... 10,678.3 5,074.7 64.81 SLEEVE BAKER CMU SLIDING SLEEVE ted 2.813 DS PROFILE 2.813 I.: 10,734.0 5,068.9 65.68 NIPPLE CAMCO D NO GO NIPPLE w/2.75"PROFILE w/BALL&ROD 2.750 11,347 2 5,317.6 69.33 LOCATOR LOCATOR COLLAR 3.000 la f 11,347 7 5,31 73 69 33 SEAL ASSY GBH-228011 SEAL ASSEMBLY w/1/2 MULE SHOE 3.000 LOCATOR, Other In Hole(Wireline retrievablepiugs,valvespumps fsh,etc.) SEAL ASBV, -(� Top Depth 11,348 Cf (TVD)DI Top Incl Top(NKR) (RKB) ("I Description Comment _ Run Date ID(in) _ - 36 5 36 5 0-04 CHEM LINE CHEMICAL INJECTION LINE -- 4/62011 0.000 I Notes:General&Safety IEnd Date Annotat on 4/19/2011 NOTE:View Schematic wl Alaska Schematic9.0 PRODUCTION --- - - 39-11473 -- --- --- W Pwe..---L III C- i3 <-(,)--. .s( -c I I I I _I Mandrel Details Top Depth Top Port-=- (TVD) Incl 00 Valve Latch Sian TRO Run See Top(RKB) (RKB) C) Make Model (In) Sera TYPW TYM (In) (pe0 RIM Date Can_ 1 4,022.2 2,499.5 69.32 CAMCO KBMG 1 GAS UFT SOV BEK 0.000 0.0 4/6/2011 I 2 7,558.3 3,798.2 68.94 CAMCO KBMG 1 GAS UFT DMY BK-5 0.000 0.0 4162011 3 9,436.3 4,494.1 63.20 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 4/6/2011 I 4 10,529.8 5,011.8 64.52 CAMCO KBMG 1 GAS UFT DMY BK-5 0.000 0.0 4/6/2011 5 10,619.5 5,050.3 64.57 CAMCO KBMG-LTS 1 CHEM CM-40R BK-5 0.000 0.0 4/6/2011 I TD(71308). 13,157 LINER, 11,307-13.158 t to 0 s ;4 ConocoPhill i ios(Alaska) Inc. Kuparuk River Unit Kuparuk 2L Paid 2L-306PB1 ,/ aVF. 501032063070 o 5, Sperry Drilling fl gDefinitive Survey Report 04 April, 2011 • I rgi 5-1P N p 51 • HALLIBURTON Sperry Drilling ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-306(Stella) Project: Kuparuk River Unit TVD Reference: Rig:2L-306 @ 155.15ft(D15(40.35+114.80)) Site: Kuparuk 2L Pad MD Reference: Rig:2L-306 @ 155.15ft(D15(40.35+114.80)) Well: 2L-306(Stella) North Reference: True Wellbore: 2L-306PB1 Survey Calculation Method: Minimum Curvature Design 2L-306PB1 Database: CPAI EDM Production Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2L-306(Stella) Well Position +N/-S 0.00 ft Northing: 5,927,691.60 ft Latitude: 70° 12'48.237 N +E/-W 0.00 ft Easting: 461,063.16 ft Longitude: 150°18'50.476 W 1 Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 114.80ft Wellbore 2L-306PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 3/1/2011 20.92 80.75 57,601 I Design 2L-306PB1 1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 40.35 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 40.35 0.00 0.00 76.58 Survey Program Date 1 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 82.00 945.00 2L-306PB1 Gryo(R100)(2L-306PB1) GYD-GC-SS Gyrodata gyro single shots 3/1/2011 12:0C 959.49 3,613.92 2L-306PB1 MWD(R100)(2L-306PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/1/2011 12:0C 3,677.51 9,359.30 2L-306PB1 MWD(R200)(2L-306PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/8/2011 12:0C 9,441.79 11,779.43 2L-306PB1 MWD(R300)(2L-306PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/14/2011 12:C Survey ..� Map Map Vertical MD Inc Azi TVD TVDSS +N/-S a-UAW Northing ± Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) 0100') (ft) Survey Tool Name 40.35 0.00 0.00 40.35 -114.80 0.00 0.00 5,927,691.60 461,063.16 0.00 0.00 UNDEFINED 82.00 0.39 268.81 82.00 -73.15 0.00 -0.14 5,927,691.60 461,063.02 0.94 -0.14 GYD-GC-SS(1) 171.00 0.10 252.72 171.00 15.85 -0.03 -0.52 5,927,691.57 461,062.64 0.33 -0.51 GYD-GC-SS(1) 261.00 0.27 345.44 261.00 105.85 0.15 -0.65 5,927,691.75 461,062.51 0.32 -0.59 GYD-GC-SS(1) 349.00 3.87 46.68 348.93 193.78 2.39 1.46 5,927,693.98 461,064.63 4.26 1.98 GYD-GC-SS(1) 439.00 5.71 47.48 438.61 283.46 7.50 6.97 5,927,699.06 461,070.17 2.05 8.52 GYD-GC-SS(1) 533.00 7.11 43.86 532.02 376.87 14.85 14.45 5,927,706.38 461,077.68 1.55 17.50 GYD-GC-SS(1) 628.00 8.78 40.16 626.11 470.96 24.63 23.20 5,927,716.11 461,086.48 1.84 28.28 GYD-GC-SS(1) 723.00 12.21 34.76 719.51 564.36 38.43 33.61 5,927,729.86 461,096.96 3.75 41.61 GYD-GC-SS(1) 817.00 15.59 35.24 810.74 655.59 56.92 46.57 5,927,748.27 461,110.01 3.60 58.51 GYD-GC-SS(1) 912.00 22.62 36.99 900.45 745.30 81.97 64.95 5,927,773.23 461,128.52 7.42 82.20 GYD-GC-SS(1) 4/4/2011 11:05:00AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-306(Stella) Project: Kuparuk River Unit TVD Reference: Rig:2L-306 @ 155.15ft(D15(40.35+114.80)) Site: Kuparuk 2L Pad MD Reference: Rig:2L-306 @ 155.15ft(D15(40.35+114.80)) Well: 2L-306(Stella) North Reference: True Wellbore: 2L-306PB1 Survey Calculation Method: Minimum Curvature Design: 2L-306PB1 (Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 945.00 24.92 37.86 930.65 775.50 92 73.03 5,927,783.74 461,136.66 7.05 92.52 GYD-GC-SS(1) 989.94 26.44 40.80 971.15 816.00 107.58 85.38 5,927,798.73 461,149.09 4.41 108.02 MWD+IFR-AK-CAZ-SC(2) 1,023.20 28.13 41.36 1,000.71 845.56 119.07 95.40 5,927,810.17 461,159.17 5.14 120.43 MWD+IFR-AK-CAZ-SC(2) 1,052.01 29.14 42.27 1,026.00 870.85 129.36 104.61 5,927,820.41 461,168.42 3.82 131.78 MWD+IFR-AK-CAZ-SC(2) 1,150.43 29.87 44.69 1,111.66 956.51 164.52 137.97 5,927,855.39 461,201.96 1.42 172.38 MWD+IFR-AK-CAZ-SC(2) 1,243.96 31.85 46.43 1,191.94 1,036.79 198.09 172.23 5,927,888.78 461,236.39 2.32 213.50 MWD+IFR-AK-CAZ-SC(2) 1,339.44 37.43 46.92 1,270.47 1,115.32 235.30 211.71 5,927,925.78 461,276.05 5.85 260.54 MWD+IFR-AK-CAZ-SC(2) 1,383.29 38.72 47.42 1,304.98 1,149.83 253.68 231.54 5,927,944.06 461,295.98 3.02 284.09 MWD+IFR-AK-CAZ-SC(2) 1,434.13 38.08 50.49 1,344.83 1,189.68 274.42 255.35 5,927,964.67 461,319.89 3.96 312.06 MWD+IFR-AK-CAZ-SC(2) 1,528.93 38.37 50.53 1,419.30 1,264.15 311.72 300.61 5,928,001.74 461,365.35 0.31 364.75 MWD+IFR-AK-CAZ-SC(2) 1,623.41 41.41 52.21 1,491.79 1,336.64 349.52 347.96 5,928,039.28 461,412.88 3.41 419.57 MWD+IFR-AK-CAZ-SC(2) 1,718.28 45.25 54.73 1,560.79 1,405.64 388.21 400.28 5,928,077.71 461,465.39 4.44 479.45 MWD+IFR-AK-CAZ-SC(2) 1,811.83 48.27 57.10 1,624.88 1,469.73 426.37 456.73 5,928,115.56 461,522.03 3.72 543.21 MWD+IFR-AK-CAZ-SC(2) 1,907.80 53.89 59.88 1,685.15 1,530.00 465.31 520.38 5,928,154.17 461,585.88 6.27 614.17 MWD+IFR-AK-CAZ-SC(2) 1,950.44 55.17 60.89 1,709.89 1,554.74 482.47 550.57 5,928,171.17 461,616.16 3.57 647.51 MWD+IFR-AK-CAZ-SC(2) 2,000.45 55.91 61.99 1,738.19 1,583.04 502.18 586.79 5,928,190.70 461,652.47 2.34 687.32 MWD+IFR-AK-CAZ-SC(2) 2,097.54 59.57 64.00 1,790.01 1,634.86 539.42 659.94 5,928,227.56 461,725.80 4.16 767.11 MWD+IFR-AK-CAZ-SC(2) 2,188.16 63.32 66.62 1,833.32 1,678.17 572.63 732.25 5,928,260.39 461,798.28 4.85 845.15 MWD+IFR-AK-CAZ-SC(2) 2,284.29 67.37 67.80 1,873.42 1,718.27 606.45 812.78 5,928,293.79 461,878.98 4.36 931.34 MWD+IFR-AK-CAZ-SC(2) 2,378.97 70.80 65.56 1,907.22 1,752.07 641.47 893.97 5,928,328.39 461,960.34 4.24 1,018.44 MWD+IFR-AK-CAZ-SC(2) 2,476.06 71.00 65.15 1,938.99 1,783.84 679.73 977.36 5,928,366.21 462,043.91 0.45 1,108.43 MWD+IFR-AK-CAZ-SC(2) 2,571.42 68.92 64.48 1,971.66 1,816.51 717.85 1,058.42 5,928,403.91 462,125.17 2.28 1,196.13 MWD+IFR-AK-CAZ-SC(2) 2,666.35 68.92 64.82 2,005.80 1,850.65 755.77 1,138.47 5,928,441.42 462,205.40 0.33 1,282.79 MWD+IFR-AK-CAZ-SC(2) 2,761.37 68.77 63.78 2,040.10 1,884.95 794.20 1,218.32 5,928,479.43 462,285.44 1.03 1,369.38 MWD+IFR-AK-CAZ-SC(2) 2,855.26 68.80 64.70 2,074.07 1,918.92 832.24 1,297.15 5,928,517.06 462,364.45 0.91 1,454.88 MWD+IFR-AK-CAZ-SC(2) 2,951.58 69.11 64.42 2,108.66 1,953.51 870.86 1,378.33 5,928,555.25 462,445.82 0.42 1,542.81 MWD+IFR-AK-CAZ-SC(2) 3,046.35 69.55 65.30 2,142.12 1,986.97 908.52 1,458.60 5,928,592.50 462,526.28 0.99 1,629.63 MWD+IFR-AK-CAZ-SC(2) 3,140.61 68.02 65.38 2,176.22 2,021.07 945.19 1,538.45 5,928,628.75 462,606.31 1.63 1,715.81 MWD+IFR-AK-CAZ-SC(2) 3,234.47 68.78 65.12 2,210.78 2,055.63 981.72 1,617.70 5,928,664.87 462,685.74 0.85 1,801.38 MWD+IFR-AK-CAZ-SC(2) 3,329.10 68.07 65.64 2,245.57 2,090.42 1,018.38 1,697.70 5,928,701.11 462,765.92 0.91 1,887.70 MWD+IFR-AK-CAZ-SC(2) 3,423.37 67.84 65.45 2,280.96 2,125.81 1,054.56 1,777.24 5,928,736.87 462,845.64 0.31 1,973.46 MWD+IFR-AK-CAZ-SC(2) 3,519.05 67.79 65.73 2,317.09 2,161.94 1,091.17 1,857.92 5,928,773.07 462,926.50 0.28 2,060.43 MWD+IFR-AK-CAZ-SC(2) 3,613.92 68.07 66.08 2,352.73 2,197.58 1,127.06 1,938.18 5,928,808.54 463,006.93 0.45 2,146.83 MWD+IFR-AK-CAZ-SC(2) 3,677.51 68.07 67.24 2,376.48 2,221.33 1,150.43 1,992.34 5,928,831.63 463,061.21 1.69 2,204.94 MWD+IFR-AK-CAZ-SC(3) 3,772.59 68.98 66.00 2,411.29 2,256.14 1,185.54 2,073.55 5,928,866.32 463,142.59 1.55 2,292.08 MWD+IFR-AK-CAZ-SC(3) 3,866.82 69.37 64.44 2,444.79 2,289.64 1,222.46 2,153.51 5,928,902.82 463,222.73 1.60 2,378.42 MWD+IFR-AK-CAZ-SC(3) 3,962.23 69.31 63.33 2,478.46 2,323.31 1,261.75 2,233.67 5,928,941.69 463,303.08 1.09 2,465.51 MWD+IFR-AK-CAZ-SC(3) 4,056.50 69.52 63.33 2,511.60 2,356.45 1,301.37 2,312.53 5,928,980.89 463,382.14 0.22 2,551.42 MWD+IFR-AK-CAZ-SC(3) 4,152.30 70.07 63.67 2,544.69 2,389.54 1,341.48 2,392.99 5,929,020.59 463,462.80 0.66 2,638.99 MWD+IFR-AK-CAZ-SC(3) 4,245.79 70.28 63.70 2,576.40 2,421.25 1,380.47 2,471.82 5,929,059.17 463,541.82 0.23 2,724.72 MWD+IFR-AK-CAZ-SC(3) 4/4/2011 11:05:00AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-306(Stella) Project: Kuparuk River Unit TVD Reference: Rig:2L-306 @ 155.15ft(D15(40.35+114.80)) Site: Kuparuk 2L Pad MD Reference: Rig:2L-306 @ 155.15ft(D15(40.35+114.80)) Well: 2L-306(Stella) North Reference: True Wellbore: 2L-306PB1 Survey Calculation Method: Minimum Curvature Design: 2L-306PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,341.79 69.18 64.14 2,609.65 2,454.50 1,420.06 2,552.71 5,929,098.34 463,622.90 1.22 2,812.58 MWD+IFR-AK-CAZ-SC(3) 4,435.95 67.88 63.81 2,644.12 2,488.97 1,458.50 2,631.45 5,929,136.37 463,701.83 1.42 2,898.09 MWD+IFR-AK-CAZ-SC(3) 4,530.78 67.99 64.03 2,679.74 2,524.59 1,497.14 2,710.38 5,929,174.60 463,780.96 0.24 2,983.84 MWD+IFR-AK-CAZ-SC(3) 4,623.81 68.25 63.79 2,714.41 2,559.26 1,535.11 2,787.91 5,929,212.16 463,858.68 0.37 3,068.07 MWD+IFR-AK-CAZ-SC(3) 4,715.23 68.22 63.96 2,748.31 2,593.16 1,572.49 2,864.14 5,929,249.15 463,935.09 0.18 3,150.89 MWD+IFR-AK-CAZ-SC(3) 4,814.70 68.50 63.93 2,784.99 2,629.84 1,613.10 2,947.21 5,929,289.32 464,018.35 0.28 3,241.11 MWD+I F R-AK-CAZ-SC(3) 4,911.54 68.56 64.02 2,820.43 2,665.28 1,652.64 3,028.19 5,929,328.44 464,099.53 0.11 3,329.06 MWD+IFR-AK-CAZ-SC(3) 5,004.84 68.52 64.30 2,854.57 2,699.42 1,690.49 3,106.34 5,929,365.88 464,177.87 0.28 3,413.86 MWD+IFR-AK-CAZ-SC(3) 5,097.80 68.51 64.38 2,888.62 2,733.47 1,727.95 3,184.31 5,929,402.93 464,256.02 0.08 3,498.39 MWD+IFR-AK-CAZ-SC(3) 5,195.64 68.72 64.13 2,924.29 2,769.14 1,767.52 3,266.37 5,929,442.08 464,338.28 0.32 3,587.40 MWD+IFR-AK-CAZ-SC(3) 5,287.34 68.78 64.36 2,957.53 2,802.38 1,804.66 3,343.34 5,929,478.82 464,415.43 0.24 3,670.89 MWD+IFR-AK-CAZ-SC(3) 5,382.08 68.88 64.87 2,991.74 2,836.59 1,842.53 3,423.16 5,929,516.27 464,495.44 0.51 3,757.32 MWD+IFR-AK-CAZ-SC(3) 5,479.29 69.09 64.61 3,026.60 2,871.45 1,881.25 3,505.23 5,929,554.57 464,577.69 0.33 3,846.13 MWD+I FR-AK-CAZ-SC(3) 5,574.59 67.61 65.22 3,061.76 2,906.61 1,918.81 3,585.44 5,929,591.70 464,658.10 1.66 3,932.87 MWD+IFR-AK-CAZ-SC(3) 5,664.01 67.47 65.01 3,095.92 2,940.77 1,953.58 3,660.41 5,929,626.09 464,733.23 0.27 4,013.86 MWD+IFR-AK-CAZ-SC(3) 5,761.22 67.37 64.52 3,133.25 2,978.10 1,991.85 3,741.60 5,929,663.93 464,814.61 0.48 4,101.72 MWD+IFR-AK-CAZ-SC(3) 5,858.45 67.30 64.35 3,170.72 3,015.57 2,030.57 3,822.54 5,929,702.23 464,895.74 0.18 4,189.43 MWD+IFR-AK-CAZ-SC(3) 5,953.26 67.30 64.78 3,207.30 3,052.15 2,068.13 3,901.53 5,929,739.38 464,974.91 0.42 4,274.98 MWD+I FR-AK-CAZ-SC(3) 6,048.12 67.16 64.75 3,244.02 3,088.87 2,105.42 3,980.65 5,929,776.26 465,054.22 0.15 4,360.60 MWD+IFR-AK-CAZ-SC(3) 6,142.57 67.07 65.05 3,280.75 3,125.60 2,142.33 4,059.44 5,929,812.76 465,133.20 0.31 4,445.81 MWD+IFR-AK-CAZ-SC(3) 6,235.39 68.65 63.88 3,315.73 3,160.58 2,179.40 4,137.02 5,929,849.42 465,210.95 2.06 4,529.87 MWD+IFR-AK-CAZ-SC(3) 6,331.01 68.94 63.65 3,350.32 3,195.17 2,218.80 4,216.98 5,929,888.41 465,291.11 0.38 4,616.79 MWD+IFR-AK-CAZ-SC(3) 6,425.28 69.04 63.16 3,384.11 3,228.96 2,258.20 4295.67 5,929,927.40 465,369.99 0.50 4,702.48 MWD+IFR-AK-CAZ-SC(3) 6,519.18 68.77 63.71 3,417.91 3,262.76 2,297.38 4,374.03 5,929,966.17 465,448.54 0.62 4,787.79 MWD+IFR-AK-CAZ-SC(3) 6,614.54 68.76 64.93 3,452.45 3,297.30 2,335.90 4,454.13 5,930,004.27 465,528.84 1.19 4,874.64 MWD+IFR-AK-CAZ-SC(3) 6,711.48 68.65 64.85 3,487.66 3,332.51 2,374.23 4,535.92 5,930,042.17 465,610.81 0.14 4,963.09 MWD+IFR-AK-CAZ-SC(3) 6,805.80 68.21 64.94 3,522.33 3,367.18 2,411.44 4,615.35 5,930,078.97 465,690.42 0.47 5,048.99 MWD+IFR-AK-CAZ-SC(3) 6,899.87 68.22 65.05 3,557.24 3,402.09 2,448.37 4,694.51 5,930,115.48 465,769.77 0.11 5,134.56 MWD+IFR-AK-CAZ-SC(3) 6,994.84 67.93 64.61 3,592.70 3,437.55 2,485.83 4,774.25 5,930,152.54 465,849.69 0.53 5,220.82 MWD+IFR-AK-CAZ-SC(3) 7,088.97 68.82 63.51 3,627.40 3,472.25 2,524.11 4,852.93 5,930,190.41 465,928.56 1.44 5,306.24 MWD+IFR-AK-CAZ-SC(3) 7,183.99 68.62 63.12 3,661.88 3,506.73 2,563.88 4,932.04 5,930,229.76 466,007.87 0.44 5,392.41 MWD+IFR-AK-CAZ-SC(3) 7,279.07 68.47 63.04 3,696.66 3,541.51 2,603.94 5,010.94 5,930,269.41 466,086.97 0.18 5,478.46 MWD+IFR-AK-CAZ-SC(3) 7,372.21 68.40 63.03 3,730.89 3,575.74 2,643.22 5,088.15 5,930,308.28 466,164.37 0.08 5,562.67 MWD+IFR-AK-CAZ-SC(3) 7,468.46 68.97 64.50 3,765.88 3,610.73 2,682.85 5,168.57 5,930,347.50 466,244.99 1.54 5,650.10 MWD+IFR-AK-CAZ-SC(3) 7,561.80 68.94 64.78 3,799.40 3,644.25 2,720.16 5,247.29 5,930,384.40 466,323.89 0.28 5,735.33 MWD+IFR-AK-CAZ-SC(3) 7,656.51 69.04 64.52 3,833.36 3,678.21 2,758.02 5,327.19 5,930,421.84 466,403.98 0.28 5,821.83 MWD+IFR-AK-CAZ-SC(3) 7,751.97 69.06 64.85 3,867.49 3,712.34 2,796.14 5,407.78 5,930,459.54 466,484.76 0.32 5,909.07 MWD+IFR-AK-CAZ-SC(3) 7,847.98 68.70 64.83 3,902.08 3,746.93 2,834.21 5,488.85 5,930,497.19 466,566.01 0.38 5,996.76 MWD+IFR-AK-CAZ-SC(3) 7,939.44 68.78 64.56 3,935.25 3,780.10 2,870.65 5,565.90 5,930,533.22 466,643.24 0.29 6,080.17 MWD+IFR-AK-CAZ-SC(3) 8,033.87 68.57 64.72 3,969.59 3,814.44 2,908.32 5,645.39 5,930,570.48 466,722.92 0.27 6,166.23 MWD+IFR-AK-CAZ-SC(3) 4/4/2011 1 1:05:00AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-306(Stella) Project: Kuparuk River Unit TVD Reference: Rig:2L-306 @ 155.15ft(D15(40.35+114.80)) Site: Kuparuk 2L Pad MD Reference: Rig:2L-306 @ 155.15ft(D15(40.35+114.80)) Well: 2L-306(Stella) North Reference: True Wellbore: 2L-306PB1 Survey Calculation Method: Minimum Curvature Design: 2L-306PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,130.19 68.45 64.48 4,004.87 3,849.72 2,946.76 5,726.35 5,930,608.51 466,804.07 0.26 6,253.90 MWD+IFR-AK-CAZ-SC(3) 8,223.22 68.45 64.69 4,039.04 3,883.89 2,983.90 5,804.50 5,930,645.23 466,882.40 0.21 6,338.54 MWD+IFR-AK-CAZ-SC(3) 8,318.19 68.78 64.33 4,073.67 3,918.52 3,021.96 5,884.33 5,930,682.87 466,962.41 0.50 6,425.01 MWD+IFR-AK-CAZ-SC(3) 8,413.78 68.69 64.33 4,108.34 3,953.19 3,060.54 5,964.62 5,930,721.04 467,042.89 0.09 6,512.07 MWD+IFR-AK-CAZ-SC(3) 8,510.76 68.77 64.69 4,143.52 3,988.37 3,099.44 6,046.19 5,930,759.51 467,124.66 0.36 6,600.44 MWD+IFR-AK-CAZ-SC(3) 8,603.61 68.90 64.52 4,177.05 4,021.90 3,136.57 6,124.41 5,930,796.24 467,203.06 0.22 6,685.14 MWD+IFR-AK-CAZ-SC(3) 8,700.54 68.71 64.46 4,212.09 4,056.94 3,175.49 6,205.98 5,930,834.73 467,284.82 0.20 6,773.51 MWD+IFR-AK-CAZ-SC(3) 8,795.55 68.64 64.55 4,246.64 4,091.49 3,213.59 6,285.86 5,930,872.41 467,364.89 0.11 6,860.06 MWD+IFR-AK-CAZ-SC(3) 8,889.87 68.57 64.48 4,281.05 4,125.90 3,251.37 6,365.14 5,930,909.79 467,444.35 0.10 6,945.94 MWD+IFR-AK-CAZ-SC(3) 8,984.40 68.54 64.32 4,315.61 4,160.46 3,289.39 6,444.49 5,930,947.39 467,523.89 0.16 7,031.94 MWD+IFR-AK-CAZ-SC(3) 9,077.45 67.41 67.48 4,350.51 4,195.36 3,324.62 6,523.21 5,930,982.21 467,602.78 3.37 7,116.69 MWD+IFR-AK-CAZ-SC(3) 9,171.68 67.16 71.14 4,386.91 4,231.76 3,355.32 6,604.50 5,931,012.49 467,684.23 3.59 7,202.90 MWD+IFR-AK-CAZ-SC(3) 9,267.33 67.20 75.52 4,424.02 4,268.87 3,380.60 6,688.94 5,931,037.33 467,768.78 4.22 7,290.89 MWD+IFR-AK-CAZ-SC(3) 9,359.30 65.60 77.82 4,460.84 4,305.69 3,400.04 6,770.93 5,931,056.35 467,850.87 2.88 7,375.16 MWD+IFR-AK-CAZ-SC(3) 9,441.79 63.03 80.59 4,496.60 4,341.45 3,413.98 6,843.93 5,931,069.91 467,923.93 4.34 7,449.40 MWD+IFR-AK-CAZ-SC(4) 9,540.08 60.85 85.80 4,542.86 4,387.71 3,424.29 6,930.01 5,931,079.77 468,010.05 5.18 7,535.52 MWD+IFR-AK-CAZ-SC(4) 9,582.73 60.38 87.06 4,563.78 4,408.63 3,426.61 6,967.10 5,931,081.90 468,047.15 2.80 7,572.13 MWD+IFR-AK-CAZ-SC(4) 9,633.23 59.37 89.45 4,589.13 4,433.98 3,427.94 7,010.75 5,931,083.01 468,090.80 4.56 7,614.90 MWD+IFR-AK-CAZ-SC(4) 9,730.21 59.66 93.96 4,638.35 4,483.20 3,425.45 7,094.25 5,931,080.09 468,174.28 4.02 7,695.55 MWD+IFR-AK-CAZ-SC(4) 9,825.31 60.37 98.85 4,685.90 4,530.75 3,416.25 7,176.07 5,931,070.47 468,256.05 4.52 7,773.00 MWD+IFR-AK-CAZ-SC(4) 9,917.43 61.37 103.73 4,730.76 4,575.61 3,400.49 7,254.94 5,931,054.30 468,334.83 4.75 7,846.06 MWD+IFR-AK-CAZ-SC(4) 10,011.46 61.99 107.50 4,775.38 4,620.23 3,378.21 7,334.64 5,931,031.61 468,414.40 3.59 7,918.41 MWD+IFR-AK-CAZ-SC(4) 10,107.07 62.48 111.30 4,819.94 4,664.79 3,350.11 7,414.42 5,931,003.10 468,494.02 3.55 7,989.48 MWD+IFR-AK-CAZ-SC(4) 10,204.22 63.22 116.68 4,864.29 4,709.14 3,314.97 7,493.35 5,930,967.56 468,572.76 4.99 8,058.10 MWD+IFR-AK-CAZ-SC(4) 10,294.23 62.33 120.66 4,905.48 4,750.33 3,276.59 7,563.56 5,930,928.82 468,642.77 4.05 8,117.49 MWD+IFR-AK-CAZ-SC(4) 10,391.88 62.73 123.53 4,950.53 4,795.38 3,230.56 7,636.94 5,930,882.42 468,715.91 2.64 8,178.19 MWD+IFR-AK-CAZ-SC(4) 10,488.13 64.12 127.36 4,993.61 4,838.46 3,180.64 7,707.04 5,930,832.14 468,785.74 3.84 8,234.79 MWD+IFR-AK-CAZ-SC(4) 10,580.03 64.55 131.76 5,033.42 4,878.27 3,127.90 7,770.88 5,930,779.08 468,849.30 4.34 8,284.64 MWD+IFR-AK-CAZ-SC(4) 10,675.06 64.61 136.79 5,074.24 4,919.09 3,068.01 7,832.30 5,930,718.87 468,910.41 4.78 8,330.49 MWD+IFR-AK-CAZ-SC(4) 10,770.93 66.25 140.78 5,114.11 4,958.96 3,002.42 7,889.72 5,930,653.00 468,967.48 4.15 8,371.11 MWD+IFR-AK-CAZ-SC(4) 10,864.03 67.70 144.96 5,150.54 4,995.39 2,934.12 7,941.41 5,930,584.44 469,018.81 4.42 8,405.54 MWD+IFR-AK-CAZ-SC(4) 10,959.28 68.95 149.01 5,185.73 5,030.58 2,859.91 7,989.61 5,930,510.00 469,066.63 4.16 8,435.21 MWD+IFR-AK-CAZ-SC(4) 11,054.79 66.64 151.92 5,221.83 5,066.68 2,783.00 8,033.21 5,930,432.87 469,109.82 3.72 8,459.76 MWD+IFR-AK-CAZ-SC(4) 11,147.85 64.55 155.81 5,260.29 5,105.14 2,706.96 8,070.55 5,930,356.64 469,146.77 4.42 8,478.43 MWD+IFR-AK-CAZ-SC(4) 11,241.67 63.03 159.60 5,301.74 5,146.59 2,629.11 8,102.49 5,930,278.63 469,178.30 3.97 8,491.43 MWD+IFR-AK-CAZ-SC(4) 11,340.68 63.14 159.59 5,346.56 5,191.41 2,546.36 8,133.27 5,930,195.73 469,208.65 0.11 8,502.17 MWD+IFR-AK-CAZ-SC(4) 11,435.73 63.23 159.86 5,389.44 5,234.29 2,466.79 8,162.67 5,930,116.02 469,237.63 0.27 8,512.29 MWD+IFR-AK-CAZ-SC(4) 11,524.78 63.16 159.54 5,429.59 5,274.44 2,392.24 8,190.24 5,930,041.34 469,264.82 0.33 8,521.81 MWD+IFR-AK-CAZ-SC(4) 11,625.32 63.12 159.25 5,475.02 5,319.87 2,308.29 8,221.81 5,929,957.23 469,295.95 0.26 8,533.03 MWD+IFR-AK-CAZ-SC(4) 11,719.90 63.51 159.45 5,517.49 5,362.34 2,229.21 8,251.61 5,929,878.01 469,325.34 0.45 8,543.67 MWD+IFR-AK-CAZ-SC(4) 4/4/2011 11:05:00AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-306(Stella) Project: Kuparuk River Unit TVD Reference: Rig:2L-306 @ 155.15ft(D15(40.35+114.80)) Site: Kuparuk 2L Pad MD Reference: Rig:2L-306 @ 155.15ft(D15(40.35+114.80)) Well: 2L-306(Stella) Itlorth Reference: True Wellbore: 2L-306PB1 Survey Calculation Method: Minimum Curvature Design: 2L-306PB1 Database: CPAI EDM Production Survey Map Map Vertical 1 MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,779.43 63.84 159.20 5,543.89 5,388.74 2,179.29 8,270.45 5,929,828.00 469,343.92 0.67 8,550.41 MWD+IFR-AK-CAZ-SC(4) 11,824.00 63.84 159.20 5,563.54 5,408.39 2,141.89 8,284.65 5,929,790.53 469,357.93 0.00 8,555.54 PROJECTED to TD 4/4/2011 11:05:00AM Page 6 COMPASS 2003.16 Build 69 1 gi V 0 ki 4 4 ti 4 A' H al v 1 ConocoPhilli ps(Alaska) Inc. I 7-it M Pi Kuparuk River Unit a 5 Kuparuk 2L Pad 2L-306 V 5 1, 501032063000 fi p 4 ' a all ▪ I • 1 Sperry Drilling O gg 4 Definitive Survey Report • 0 .• 3 April,ril 2011 DII ▪ 4 4 0 • a, 210 S 4 r0 0 a il Z: f 3 HALLIBURTON 3 Sperry Driifing ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-306(Stella) Project: Kuparuk River Unit TVD Reference: Rig:2L-306 @ 155.15ft(D15(40.35+114.80)) Site: Kuparuk 2L Pad MD Reference: Rig:2L-306 @ 155.15ft(D15(40.35+114.80)) Well: 2L-306(Stella) North Reference: True Wellbore: 2L-306 Survey Calculation Method: Minimum Curvature Design: 2L-306 Database: CPAI EDM Production Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2L-306(Stella) Well Position +N/-S 0.00 ft Northing: 5,927,691.60 ft Latitude: 70° 12'48.237 N +E/-W 0.00 ft Easting: 461,063.16ft Longitude: 150°18'50.476 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 114.80ft Wellbore 2L-306 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 4/1/2011 20.88 80.75 57,601 Design 2L-306 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,959.28 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 40.35 0.00 0.00 161.00 ,� ry t 0"..r�'; 3s)� ,W "Survey Program Date ,,...1,,:,,„,,,,,,,,,n‘,„,;,,,,,;;;, hiT ' From To ,. 1E.1 r (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 82.00 945.00 2L-306PB1 Gryo(R100)(2L-306PB1) GYD-GC-SS Gyrodata gyro single shots 3/1/2011 12:0C 959.49 3,613.92 2L-306PB1 MWD(R100)(2L-306PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/1/2011 12:0C 3,677.51 9,359.30 2L-306PB1 MWD(R200)(2L-306PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/8/2011 12:0C 9,441.79 10,959.28 2L-306PB1 MWD(R300)(2L-306PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/14/2011 12:C 10,979.00 11,443.89 2L-306 MWD(R400)(2L-306) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/23/2011 12:C ' 11,490.00 13,029.60 2L-306 MWD(R600)(2L-306) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/1/2011 12:0C Survey ', Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section I� _ (f (°) °)( (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 40.35 0.00 0.00 40.35 -114.80 0.00 0.00 5,927,691.60 461,063.16 0.00 0.00 UNDEFINED I 82.00 0.39 268.81 82.00 -73.15 0.00 -0.14 5,927,691.60 461,063.02 0.94 -0.04 GYD-GC-SS(1) 171.00 0.10 252.72 171.00 15.85 -0.03 -0.52 5,927,691.57 461,062.64 0.33 -0.14 GYD-GC-SS(1) 261.00 0.27 345.44 261.00 105.85 0.15 -0.65 5,927,691.75 461,062.51 0.32 -0.35 GYD-GC-SS(1) 349.00 3.87 46.68 348.93 193.78 2.39 1.46 5,927,693.98 461,064.63 4.26 -1.78 GYD-GC-SS(1) 439.00 5.71 47.48 438.61 283.46 7.50 6.97 5,927,699.06 461,070.17 2.05 -4.82 GYD-GC-SS(1) 533.00 7.11 43.86 532.02 376.87 14.85 14.45 5,927,706.38 461,077.68 1.55 -9.34 GYD-GC-SS(1) 628.00 8.78 40.16 626.11 470.96 24.63 23.20 5,927,716.11 461,086.48 1.84 -15.74 GYD-GC-SS(1) 723.00 12.21 34.76 719.51 564.36 38.43 33.61 5,927,729.86 461,096.96 3.75 -25.40 GYD-GC-SS(1) 817.00 15.59 35.24 810.74 655.59 56.92 46.57 5,927,748.27 461,110.01 3.60 -38.66 GYD-GC-SS(1) 4/7/2011 10:29:14AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-306(Stella) Project: Kuparuk River Unit TVD Reference: Rig:2L-306 @ 155.1 5ft(D15(40.35+114.80)) Site: Kuparuk 2L Pad MD Reference: Rig:2L-306 @ 155.15ft(D15(40.35+114.80)) Well: 2L-306(Stella) Ulorth Reference: True Wellbore: 2L-306 Survey Calculation Method: Minimum Curvature Design: 2L-306 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 912.00 22.62 36.99 900.45 745.30 81.91 64.95 5,927,773.23 461,128.52 7.42 -56.36 GYD-GC-SS(1) 945.00 24.92 37.86 930.65 775.50 92.53 73.03 5,927,783.74 461,136.66 7.05 -63.71 GYD-GC-SS(1) 989.94 26.44 40.80 971.15 816.00 107.58 85.38 5,927,798.73 461,149.09 4.41 -73.92 MWD+IFR-AK-CAZ-SC(2) 1,023.20 28.13 41.36 1,000.71 845.56 119.07 95.40 5,927,810.17 461,159.17 5.14 -81.53 MWD+IFR-AK-CAZ-SC(2) 1,052.01 29.14 42.27 1,026.00 870.85 129.36 104.61 5,927,820.41 461,168.42 3.82 -88.26 MWD+IFR-AK-CAZ-SC(2) 1,150.43 29.87 44.69 1,111.66 956.51 164.52 137.97 5,927,855.39 461,201.96 1.42 -110.64 MWD+IFR-AK-CAZ-SC(2) 1,243.96 31.85 46.43 1,191.94 1,036.79 198.09 172.23 5,927,888.78 461,236.39 2.32 -131.22 MWD+IFR-AK-CAZ-SC(2) 1,339.44 37.43 46.92 1,270.47 1,115.32 235.30 211.71 5,927,925.78 461,276.05 5.85 -153.56 MWD+IFR-AK-CAZ-SC(2) 1,383.29 38.72 47.42 1,304.98 1,149.83 253.68 231.54 5,927,944.06 461,295.98 3.02 -164.48 MWD+IFR-AK-CAZ-SC(2) 1,434.13 38.08 50.49 1,344.83 1,189.68 274.42 255.35 5,927,964.67 461,319.89 3.96 -176.34 MWD+IFR-AK-CAZ-SC(2) 1,528.93 38.37 50.53 1,419.30 1,264.15 311.72 300.61 5,928,001.74 461,365.35 0.31 -196.87 MWD+IFR-AK-CAZ-SC(2) 1,623.41 41.41 52.21 1,491.79 1,336.64 349.52 347.96 5,928,039.28 461,412.88 3.41 -217.19 MWD+IFR-AK-CAZ-SC(2) 1,718.28 45.25 54.73 1,560.79 1,405.64 388.21 400.28 5,928,077.71 461,465.39 4.44 -236.75 MWD+IFR-AK-CAZ-SC(2) 1,811.83 48.27 57.10 1,624.88 1,469.73 426.37 456.73 5,928,115.56 461,522.03 3.72 -254.44 MWD+IFR-AK-CAZ-SC(2) 1,907.80 53.89 59.88 1,685.15 1,530.00 465.31 520.38 5,928,154.17 461,585.88 627 -270.54 MWD+IFR-AK-CAZ-SC(2) 1,950.44 55.17 60.89 1,709.89 1,554.74 482.47 550.57 5,928,171.17 461,616.16 3.57 -276.93 MWD+IFR-AK-CAZ-SC(2) 2,000.45 55.91 61.99 1,738.19 1,583.04 502.18 586.79 5,928,190.70 461,652.47 2.34 -283.78 MWD+IFR-AK-CAZ-SC(2) 2,097.54 59.57 64.00 1,790.01 1,634.86 539.42 659.94 5,928,227.56 461,725.80 4.16 -295.18 MWD+IFR-AK-CAZ-SC(2) 2,188.16 63.32 66.62 1,833.32 1,678.17 572.63 732.25 5,928,260.39 461,798.28 4.85 -303.04 MWD+IFR-AK-CAZ-SC(2) 2,284.29 67.37 67.80 1,873.42 1,718.27 606.45 812.78 5,928,293.79 461,878.98 4.36 -308.80 MWD+IFR-AK-CAZ-SC(2) 2,378.97 70.80 65.56 1,907.22 1,752.07 641.47 893.97 5,928,328.39 461,960.34 4.24 -315.48 MWD+IFR-AK-CAZ-SC(2) 2,476.06 71.00 65.15 1,938.99 1,783.84 679.73 977.36 5,928,366.21 462,043.91 0.45 -324.50 MWD+IFR-AK-CAZ-SC(2) 2,571.42 68.92 64.48 1,971.66 1,816.51 717.85 1,058.42 5,928,403.91 462,125.17 2.28 -334.15 MWD+IFR-AK-CAZ-SC(2) 2,666.35 68.92 64.82 2,005.80 1,850.65 755.77 1,138.47 5,928,441.42 462,205.40 0.33 -343.95 MWD+IFR-AK-CAZ-SC(2) 2,761.37 68.77 63.78 2,040.10 1,884.95 794.20 1,218.32 5,928,479.43 462,285.44 1.03 -354.28 MWD+IFR-AK-CAZ-SC(2) 2,855.26 68.80 64.70 2,074.07 1,918.92 832.24 1,297.15 5,928,517.06 462,364.45 0.91 -364.59 MWD+IFR-AK-CAZ-SC(2) 2,951.58 69.11 64.42 2,108.66 1,953.51 870.86 1,378.33 5,928,555.25 462,445.82 0.42 -374.67 MWD+IFR-AK-CAZ-SC(2) 3,046.35 69.55 65.30 2,142.12 1,986.97 908.52 1,458.60 5,928,592.50 462,526.28 0.99 -384.15 MWD+IFR-AK-CAZ-SC(2) 3,140.61 68.02 65.38 2,176.22 2,021.07 945.19 1,538.45 5,928,628.75 462,606.31 1.63 -392.82 MWD+IFR-AK-CAZ-SC(2) 3,234.47 68.78 65.12 2,210;78 2,055.63 981.72 1,617.70 5,928,664.87 462,685.74 0.85 -401.56 MWD+IFR-AK-CAZ-SC(2) 3,329.10 68.07 65.64 2,245.57 2,090.42 1,018.38 1,697.70 5,928,701.11 462,765.92 0.91 -410.18 MWD+IFR-AK-CAZ-SC(2) 3,423.37 67.84 65.45 2,280.96 2,125.81 1,054.56 1,777.24 5,928,736.87 462,845.64 0.31 -418.49 MWD+IFR-AK-CAZ-SC(2) 3,519.05 67.79 65.73 2,317.09 2,161.94 1,091.17 1,857.92 5,928,773.07 462,926.50 0.28 -426.84 MWD+IFR-AK-CAZ-SC(2) 3,613.92 68.07 66.08 2,352.73 2,197.58 1,127.06 1,938.18 5,928,808.54 463,006.93 0.45 -434.65 MWD+IFR-AK-CAZ-SC(2) 3,677.51 68.07 67.24 2,376.48 2,221.33 1,150.43 1,992.34 5,928,831.63 463,061.21 1.69 -439.11 MWD+IFR-AK-CAZ-SC(3) 3,772.59 68.98 66.00 2,411.29 2,256.14 1,185.54 2,073.55 5,928,866.32 463,142.59 1.55 -445.87 MWD+IFR-AK-CAZ-SC(3) 3,866.82 69.37 64.44 2,444.79 2,289.64 1,222.46 2,153.51 5,928,902.82 463,222.73 1.60 -454.74 MWD+IFR-AK-CAZ-SC(3) 3,962.23 69.31 63.33 2,478.46 2,323.31 1,261.75 2,233.67 5,928,941.69 463,303.08 1.09 -465.80 MWD+IFR-AK-CAZ-SC(3) 4,056.50 69.52 63.33 2,511.60 2,356.45 1,301.37 2,312.53 5,928,980.89 463,382.14 0.22 -477.58 MWD+IFR-AK-CAZ-SC(3) 4,152.30 70.07 63.67 2,544.69 2,389.54 1,341.48 2,392.99 5,929,020.59 463,462.80 0.66 -489.31 MWD+IFR-AK-CAZ-SC(3) 4,7/2011 10:29:14AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-306(Stella) Project: Kuparuk River Unit TVD Reference: Rig:2L-306 @ 155.15ft(D15(40.35+114.80)) Site: Kuparuk 2L Pad ttD Reference: Rig:2L-306 @ 155.15ft(D15(40.35+114.80)) Well: 2L-306(Stella) North Reference: True Wellbore: 2L-306 Survey Calculation Method: Minimum Curvature Design: 2L-306 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,245.79 70.28 63.70 2,576.40 2,421.25 1,380.47 2,471.82 5,929,059.17 463,541.82 0.23 -500.51 MWD+IFR-AK-CAZ-SC(3) 4,341.79 69.18 64.14 2,609.65 2,454.50 1,420.06 2,552.71 5,929,098.34 463,622.90 1.22 -511.61 MWD+I FR-AK-CAZ-SC(3) 4,435.95 67.88 63.81 2,644.12 2,488.97 1,458.50 2,631.45 5,929,136.37 463,701.83 1.42 -522.33 MWD+I FR-AK-CAZ-SC(3) 4,530.78 67.99 64.03 2,679.74 2,524.59 1,497.14 2,710.38 5,929,174.60 463,780.96 0.24 -533.16 MWD+IFR-AK-CAZ-SC(3) 4,623.81 68.25 63.79 2,714.41 2,559.26 1,535.11 2,787.91 5,929,212.16 463,858.68 0.37 -543.82 MWD+IFR-AK-CAZ-SC(3) 4,715.23 68.22 63.96 2,748.31 2,593.16 1,572.49 2,864.14 5,929249.15 463,935.09 0.18 -554.35 MWD+IFR-AK-CAZ-SC(3) 4,814.70 68.50 63.93 2,784.99 2,629.84 1,613.10 2,947.21 5,929,289.32 464,018.35 0.28 -565.70 MWD+IFR-AK-CAZ-SC(3) 4,911.54 68.56 64.02 2,820.43 2,665.28 1,652.64 3,028.19 5,929,328.44 464,099.53 0.11 -576.72 MWD+IFR-AK-CAZ-SC(3) 5,004.84 68.52 64.30 2,854.57 2,699.42 1,690.49 3,106.34 5,929,365.88 464,177.87 0.28 -587.07 MWD+IFR-AK-CAZ-SC(3) 5,097.80 68.51 64.38 2,888.62 2,733.47 1,727.95 3,184.31 5,929,402.93 464,256.02 0.08 -597.10 MWD+IFR-AK-CAZ-SC(3) 5,195.64 68.72 64.13 2,924.29 2,769.14 1,767.52 3,266.37 5,929,442.08 464,338.28 0.32 -607.80 MWD+IFR-AK-CAZ-SC(3) 5,287.34 68.78 64.36 2,957.53 2,802.38 1,804.66 3,343.34 5,929,478.82 464,415.43 0.24 -617.85 MWD+IFR-AK-CAZ-SC(3) 5,382.08 68.88 64.87 2,991.74 2,836.59 1,842.53 3,423.16 5,929,516.27 464,495.44 0.51 -627.68 MWD+IFR-AK-CAZ-SC(3) 5,479.29 69.09 64.61 3,026.60 2,871.45 1,881.25 3,505.23 5,929,554.57 464,577.69 0.33 -637.57 MWD+IFR-AK-CAZ-SC(3) 5,574.59 67.61 65.22 3,061.76 2,906.61 1,918.81 3,585.44 5,929,591.70 464,658.10 1.66 -646.96 MWD+IFR-AK-CAZ-SC(3) 5,664.01 67.47 65.01 3,095.92 2,940.77 1,953.58 3,660.41 5,929,626.09 464,733.23 0.27 -655.44 MWD+IFR-AK-CAZ-SC(3) 5,761.22 67.37 64.52 3,133.25 2,978.10 1,991.85 3,741.60 5,929,663.93 464,814.61 0.48 -665.18 MWD+IFR-AK-CAZ-SC(3) 5,858.45 67.30 64.35 3,170.72 3,015.57 2,030.57 3,822.54 5,929,702.23 464,895.74 0.18 -675.44 MWD+IFR-AK-CAZ-SC(3) 5,953.26 67.30 64.78 3,207.30 3,052.15 2,068.13 3,901.53 5,929,739.38 464,974.91 0.42 -685.24 MWD+IFR-AK-CAZ-SC(3) 6,048.12 67.16 64.75 3,244.02 3,088.87 2,105.42 3,980.65 5,929,776.26 465,054.22 0.15 -694.74 MWD+IFR-AK-CAZ-SC(3) 6,142.57 67.07 65.05 3,280.75 3,125.60 2,142.33 4,059.44 5,929,812.76 465,133.20 0.31 -703.99 MWD+IFR-AK-CAZ-SC(3) 6,235.39 68.65 63.88 3,315.73 3,160.58 2,179.40 4,137.02 5,929,849.42 465,210.95 2.06 -713.78 MWD+IFR-AK-CAZ-SC(3) 6,331.01 68.94 63.65 3,350.32 3,195.17 2,218.80 4,216.98 5,929,888.41 465,291.11 0.38 -725.01 MWD+IFR-AK-CAZ-SC(3) 6,425.28 69.04 63.16 3,384.11 3,228.96 2,258.20 4,295.67 5,929,927.40 465,369.99 0.50 -736.64 MWD+IFR-AK-CAZ-SC(3) 6,519.18 68.77 63.71 3,417.91 3,262.76 2,297.38 4,374.03 5,929,966.17 465,448.54 0.62 -748.17 MWD+IFR-AK-CAZ-SC(3) 6,614.54 68.76 64.93 3,452.45 3,297.30 2,335.90 4,454.13 5,930,004.27 465,528.84 1.19 -758.51 MWD+IFR-AK-CAZ-SC(3) 6,711.48 68.65 64.85 3,487.66 3,332.51 2,374.23 4,535.92 5,930,042.17 465,610.81 0.14 -768.13 MWD+IFR-AK-CAZ-SC(3) 6,805.80 68.21 64.94 3,522.33 3,367.18 2,411.44 4,615.35 5,930,078.97 465,690.42 0.47 -777.45 MWD+IFR-AK-CAZ-SC(3) 6,899.87 68.22 65.05 3,557.24 3,402.09 2,448.37 4,694.51 5,930,115.48 465,769.77 0.11 -786.59 MWD+IFR-AK-CAZ-SC(3) 6,994.84 67.93 64.61 3,592.70 3,437.55 2,485.83 4,77425 5,930,152.54 465,849.69 0.53 -796.06 MWD+IFR-AK-CAZ-SC(3) 7,088.97 68.82 63.51 3,627.40 3,472.25 2,524.11 4,852.93 5,930,190.41 465,928.56 1.44 -806.64 MWD+IFR-AK-CAZ-SC(3) 7,183.99 68.62 63.12 3,661.88 3,506.73 2,563.88 4,932.04 5,930,229.76 466,007.87 0.44 -818.48 MWD+IFR-AK-CAZ-SC(3) 7,279.07 68.47 63.04 3,696.66 3,541.51 2,603.94 5,010.94 5,930,269.41 466,086.97 0.18 -830.67 MWD+IFR-AK-CAZ-SC(3) 7,372.21 68.40 63.03 3,730.89 3,575.74 2,643.22 5,088.15 5,930,308.28 466,164.37 0.08 -842.67 MWD+IFR-AK-CAZ-SC(3) 7,468.46 68.97 64.50 3,765.88 3,610.73 2,682.85 5,168.57 5,930,347.50 466,244.99 1.54 -853.96 MWD+IFR-AK-CAZ-SC(3) 7,561.80 68.94 64.78 3,799.40 3,644.25 2,720.16 5,247.29 5,930,384.40 466,323.89 0.28 -863.61 MWD+IFR-AK-CAZ-SC(3) 7,656.51 69.04 64.52 3,833.36 3,678.21 2,758.02 5,327.19 5,930,421.84 466,403.98 0.28 -873.39 MWD+IFR-AK-CAZ-SC(3) 7,751.97 69.06 64.85 3,867.49 3,712.34 2,796.14 5,407.78 5,930,459.54 466,484.76 0.32 -883.20 MWD+IFR-AK-CAZ-SC(3) 7,847.98 68.70 64.83 3,902.08 3,746.93 2,834.21 5,488.85 5,930,497.19 466,566.01 0.38 -892.81 MWD+IFR-AK-CAZ-SC(3) 7,939.44 68.78 64.56 3,935.25 3,780.10 2,870.65 5,565.90 5,930,533.22 466,643.24 0.29 -902.17 MWD+IFR-AK-CAZ-SC(3) 4/7/2011 10:29:14AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-306(Stella) Project: Kuparuk River Unit TVD Reference: Rig:2L-306 @ 155.15ft(D15(40.35+114.80)) Site: Kuparuk 2L Pad MD Reference: Rig:2L-306 @ 155.15ft(D15(40.35+114.80)) Well: 2L-306(Stella) North Reference: True Wellbore: 2L-306 Survey Calculation Method: Minimum Curvature Design: 2L-306 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/1001 (ft) Survey Tool Name 8,033.87 68.57 64.72 3,969.59 3,814.44 2,908.32 5,645.39 5,930,570.48 466,722.92 0.27 -911.91 MWD+IFR-AK-CAZ-SC(3) 8,130.19 68.45 64.48 4,004.87 3,849.72 2,946.76 5,726.35 5,930,608.51 466,804.07 0.26 -921.90 MWD+IFR-AK-CAZ-SC(3) 8,223.22 68.45 64.69 4,039.04 3,883.89 2,983.90 5,804.50 5,930,645.23 466,882.40 0.21 -931.57 MWD+IFR-AK-CAZ-SC(3) 8,318.19 68.78 64.33 4,073.67 3,918.52 3,021.96 5,884.33 5,930,682.87 466,962.41 0.50 -941.57 MWD+IFR-AK-CAZ-SC(3) 8,413.78 68.69 64.33 4,108.34 3,953.19 3,060.54 5,964.62 5,930,721.04 467,042.89 0.09 -951.91 MWD+IFR-AK-CAZ-SC(3) 8,510.76 68.77 64.69 4,143.52 3,988.37 3,099.44 6,046.19 5,930,759.51 467,124.66 0.36 -962.13 MWD+IFR-AK-CAZ-SC(3) 8,603.61 68.90 64.52 4,177.05 4,021.90 3,136.57 6,124.41 5,930,796.24 467,203.06 0.22 -971.77 MWD+IFR-AK-CAZ-SC(3) 8,700.54 68.71 64.46 4,212.09 4,056.94 3,175.49 6,205.98 5,930,834.73 467,284.82 0.20 -982.02 MWD+IFR-AK-CAZ-SC(3) 8,795.55 68.64 64.55 4,246.64 4,091.49 3,213.59 6,285.86 5,930,872.41 467,364.89 0.11 -992.03 MWD+IFR-AK-CAZ-SC(3) 8,889.87 68.57 64.48 4,281.05 4,125.90 3,251.37 6,365.14 5,930,909.79 467,444.35 0.10 -1,001.95 MWD+IFR-AK-CAZ-SC(3) 8,984.40 68.54 64.32 4,315.61 4,160.46 3,289.39 6,444.49 5,930,947.39 467,523.89 0.16 -1,012.06 MWD+IFR-AK-CAZ-SC(3) 9,077.45 67.41 67.48 4,350.51 4,195.36 3,324.62 6,523.21 5,930,982.21 467,602.78 3.37 -1,019.74 MWD+IFR-AK-CAZ-SC(3) 9,171.68 67.16 71.14 4,386.91 4,231.76 3,355.32 6,604.50 5,931,012.49 467,684.23 3.59 -1,022.30 MWD+IFR-AK-CAZ-SC(3) 9,267.33 67.20 75.52 4,424.02 4,268.87 3,380.60 6,688.94 5,931,037.33 467,768.78 4.22 -1,018.72 MWD+IFR-AK-CAZ-SC(3) 9,359.30 65.60 77.82 4,460.84 4,305.69 3,400.04 6,770.93 5,931,056.35 467,850.87 2.88 -1,010.40 MWD+IFR-AK-CAZ-SC(3) 9,441.79 63.03 80.59 4,496.60 4,341.45 3,413.98 6,843.93 5,931,069.91 467,923.93 4.34 -999.82 MWD+IFR-AK-CAZ-SC(4) 9,540.08 60.85 85.80 4,542.86 4,387.71 3,424.29 6,930.01 5,931,079.77 468,010.05 5.18 -981.54 MWD+I FR-AK-CAZ-SC(4) 9,582.73 60.38 87.06 4,563.78 4,408.63 3,426.61 6,967.10 5,931,081.90 468,047.15 2.80 -971.66 MWD+IFR-AK-CAZ-SC(4) 9,633.23 59.37 89.45 4,589.13 4,433.98 3,427.94 7,010.75 5,931,083.01 468,090.80 4.56 -958.71 MWD+IFR-AK-CAZ-SC(4) 9,730.21 59.66 93.96 4,638.35 4,483.20 3,425.45 7,094.25 5,931,080.09 468,174.28 4.02 -929.16 MWD+I FR-AK-CAZ-SC(4) 9,825.31 60.37 98.85 4,685.90 4,530.75 3,416.25 7,176.07 5,931,070.47 468,256.05 4.52 -893.83 MWD+I FR-AK-CAZ-SC(4) 9,917.43 61.37 103.73 4,730.76 4,575.61 3,400.49 7,254.94 5,931,054.30 468,334.83 4.75 -853.25 MWD+IFR-AK-CAZ-SC(4) 10,011.46 61.99 107.50 4,775.38 4,620.23 3,378.21 7,334.64 5,931,031.61 468,414.40 3.59 -806.23 MWD+IFR-AK-CAZ-SC(4) 10,107.07 62.48 111.30 4,819.94 4,664.79 3,350.11 7,414.42 5,931,003.10 468,494.02 3.55 -753.69 MWD+IFR-AK-CAZ-SC(4) 10,204.22 63.22 116.68 4,864.29 4,709.14 3,314.97 7,493.35 5,930,967.56 468,572.76 4.99 -694.77 MWD+IFR-AK-CAZ-SC(4) 10,294.23 62.33 120.66 4,905.48 4,750.33 3,276.59 7,563.56 5,930,928.82 468,642.77 4.05 -635.62 MWD+IFR-AK-CAZ-SC(4) 10,391.88 62.73 123.53 4,950.53 4,795.38 3,230.56 7,636.94 5,930,882.42 468,715.91 2.64 -568.21 MWD+IFR-AK-CAZ-SC(4) 10,488.13 64.12 127.36 4,993.61 4,838.46 3,180.64 7,707.04 5,930,832.14 468,785.74 3.84 -498.19 MWD+I FR-AK-CAZ-SC(4) 10,580.03 64.55 131.76 5,033.42 4,878.27 3,127.90 7,770.88 5,930,779.08 468,849.30 4.34 -427.54 MWD+I FR-AK-CAZ-SC(4) 10,675.06 64.61 136.79 5,074.24 4,919.09 3,068.01 7,832.30 5,930,718.87 468,910.41 4.78 -350.91 MWD+I FR-AK-CAZ-SC(4) 10,770.93 66.25 140.78 5,114.11 4,958.96 3,002.42 7,889.72 5,930,653.00 468,967.48 4.15 -27021 MWD+IFR-AK-CAZ-SC(4) 10,864.03 67.70 144.96 5,150.54 4,995.39 2,934.12 7,941.41 5,930,584.44 469,018.81 4.42 -188.80 MWD+IFR-AK-CAZ-SC(4) 10,959.28 68.95 149.01 5,185.73 5,030.58 2,859.91 7,989.61 5,930,510.00 469,066.63 4.16 -102.94 MWD+IFR-AK-CAZ-SC(4) 10,979.00 69.72 148.97 5,192.69 5,037.54 2,844.10 7,999.12 5,930,494.13 469,076.05 3.91 -84.89 MWD+IFR-AK-CAZ-SC(5) 10,981.68 69.82 148.97 5,193.62 5,038.47 2,841.95 8,000.41 5,930,491.97 469,077.33 3.73 -82.43 MWD+IFR-AK-CAZ-SC(5) 11,031.69 70.95 149.54 5,210.41 5,055.26 2,801.46 8,024.50 5,930,451.37 469,101.20 2.50 -36.31 MWD+IFR-AK-CAZ-SC(5) 'i 11,125.43 71.06 152.05 5,240.92 5,085.77 2,724.10 8,067.74 5,930,373.79 469,144.04 2.53 50.91 MWD+IFR-AK-CAZ-SC(5) 11,222.32 69.72 154.84 5,273.44 5,118.29 2,642.47 8,108.54 5,930,291.96 469,184.42 3.04 141.38 MWD+IFR-AK-CAZ-SC(5) 11,315.10 68.85 157.50 5,306.27 5,151.12 2,563.10 8,143.61 5,930,212.42 469219.07 2.84 227.84 MWD+IFR-AK-CAZ-SC(5) 11,411.78 70.28 160.95 5,340.03 5,184.88 2,478.41 8,175.72 5,930,127.57 469,250.75 3.66 318.37 MWD+IFR-AK-CAZ-SC(5) 4/7/2011 10.29:14AM Page 5 COMPASS 2003.16 Build 69 c;onocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 2L-306(Stella) Project: Kuparuk River Unit irVD Reference: Rig:2L-306 @ 155.15ft(D15(40.35+114.80)) Site: Kuparuk 2L Pad D Reference: Rig:2L-306 @ 155.15ft(D15(40.35+114.80)) Well: 2L-306(Stella) North Reference: True Wellbore: 2L-306 Survey Calculation Method: Minimum Curvature Design: 2L-306 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,443.89 70.30 161.37 5,350.86 5,195/1 2,449.80 8,185.48 5,930,098.92 469,260.36 1.23 348.60 MWD+IFR-AK-CAZ-SC(5) 11,490.00 72.99 162.02 5,365.38 5,210.23 2,408.25 8,199.23 5,930,057.30 469,273.89 5.99 392.36 MWD+I FR-AK-CAZ-SC(6) 11,563.20 77.26 163.01 5,384.17 5,229.02 2,340.79 8,220.47 5,929,989.74 469,294.78 5.98 463.06 MWD+IFR-AK-CAZ-SC(6) 11,608.12 76.42 161.66 5,394.39 5,239.24 2,299.11 8,233.74 5,929,948.00 469,307.84 3.47 506.79 MWD+IFR-AK-CAZ-SC(6) 11,653.82 77.50 161.82 5,404.70 5,249.55 2,256.84 8,247.69 5,929,905.65 469,321.57 2.39 551.31 MWD+I FR-AK-CAZ-SC(6) 11,703.61 79.11 161.18 5,414.80 5,259.65 2,210.60 8,263.16 5,929,859.34 469,336.80 3.47 600.06 MWD+IFR-AK-CAZ-SC(6) 11,759.23 80.56 160.53 5,424.61 5,269.46 2,158.88 8,281.12 5,929,807.54 469,354.49 2.85 654.80 MWD+IFR-AK-CAZ-SC(6) 11,798.67 82.15 160.10 5,430.54 5,275.39 2,122.17 8,294.25 5,929,770.76 469,367.43 4.17 693.79 MWD+IFR-AK-CAZ-SC(6) 11,843.74 83.93 160.71 5,436.00 5,280.85 2,080.03 8,309.26 5,929,728.55 469,382.21 4.17 738.53 MWD+I FR-AK-CAZ-SC(6) 11,890.12 84.66 160.73 5,440.61 5,285.46 2,036.46 8,324.49 5,929,684.91 469,397.22 1.57 784.68 MWD+IFR-AK-CAZ-SC(6) 11,988.18 89.24 162.74 5,445.83 5,290.68 1,943.51 8,355.17 5,929,591.80 469,427.42 5.10 882.56 MWD+IFR-AK-CAZ-SC(6) • 12,031.80 89.52 162.22 5,446.30 5,291.15 1,901.91 8,368.30 5,929,550.15 469,440.33 1.35 926.16 MWD+IFR-AK-CAZ-SC(6) 12,082.69 91.54 162.22 5,445.83 5,290.68 1,853.46 8,383.84 5,929,501.62 469,455.62 3.97 977.03 MWD+IFR-AK-CAZ-SC(6) 12,177.12 92.95 161.07 5,442.13 5,286.98 1,763.90 8,413.55 5,929,411.92 469,484.87 1.93 1,071.38 MWD+IFR-AK-CAZ-SC(6) 12,270.60 89.79 160.69 5,439.90 5,284.75 1,675.62 8,444.16 5,929,323.49 469,515.01 3.40 1,164.82 MWD+IFR-AK-CAZ-SC(6) 12,364.59 89.82 160.65 5,440.22 5,285.07 1,586.93 8,475.27 5,929,234.64 469,545.66 0.05 1,258.81 MWD+IFR-AK-CAZ-SC(6) 12,459.82 89.45 160.95 5,440.82 5,285.67 1,496.99 8,506.59 5,929,144.56 469,576.51 0.50 1,354.04 MWD+I FR-AK-CAZ-SC(6) 12,554.58 88.95 160.62 5,442.15 5,287.00 1,407.52 8,537.77 5,929,054.94 469,607.23 0.63 1,448.79 MWD+IFR-AK-CAZ-SC(6) 12,648.66 91.55 162.92 5,441.74 5,286.59 1,318.18 8,56720 5,928,965.45 469,636.20 3.69 1,542.84 MWD+IFR-AK-CAZ-SC(6) 12,742.96 89.71 162.78 5,440.70 5,285.55 1,228.08 8,595.00 5,928,875.22 469,663.53 1.96 1,637.08 MWD+IFR-AK-CAZ-SC(6) 12,839.26 90.00 163.24 5,440.94 5,285.79 1,135.99 8,623.14 5,928,782.99 469,691.19 0.56 1,733.32 MWD+IFR-AK-CAZ-SC(6) 12,933.00 89.13 163.25 5,441.65 5,286.50 1,046.23 8,650.16 5,928,693.11 469,717.75 0.93 1,826.99 MWD+IFR-AK-CAZ-SC(6) 13,029.60 88.72 161.76 5,443.47 5,288.32 954.12 8,679.20 5,928,600.85 469,746.31 1.60 1,923.54 MWD+IFR-AK-CAZ-SC(6) • 13,157.00 88.72 161.76 5,446.31 • 5,291.16 833.15 8,719.06 5,928,479.69 469,785.54 0.00 2,050.89 PROJECTED to TD 417/2011 10:29:14AM Page 6 COMPASS 2003.16 Build 69 Time Log & Summary ConocoPhiIIips Wei(view Web Reporting Report Well Name: 2L-306 Rig Name: DOYON 15 Job Type: DRILLING ORIGINAL Rig Accept: 2/28/2011 1:00:00 AM Rig Release: 4/9/2011 11:00:00 AM Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 02/26/2011 24 hr Summary Secure well 2L-320. Clean out cellar box. Prep rig for skid floor.Skid floor. Move rockwasher. Pull cuttings tanks, and berms. Off of Hi-Line power @ 20:00 HRS. 04:00 12:00 8.00 MIRU MOVE MOB P Held PJSM with crew. Discuss safety&hazard recognition issues. Discuss procedure to prep and move the rig to 2L-306. Prpe rig for skidding floor and move. Crew Change. _Phase 2 road conditions. 12:00 00:00 12.00 MIRU MOVE MOB P Clean out rest of rock washer. Drain &blow down all lines. Disconnect lines. Prep floor for skid.Skid rig floor for move. Rig Off of Hi Line power @ 20:00 HRS. 02/27/2011 Continue move rig from 2L-320 to 2L-306.Spot over well. Install berms,cuttings tanks.Spot&rig up rockwasher. Field Electricians replacing Hi Line trailer unit.Work on rig acceptance checklist. 00:00 12:00 12.00 MIRU MOVE MOB P Continue move rig off of 2L-320. Move pit module. Move sub base. Remove matting boards from 21-320. Install matting boards on 2L-306. Spot Sub Base on 2L-306.Crew Change 12:00 00:00 12.00 MIRU MOVE MOB P Pull old Hi Line power trailer away. Wait for Field electricians to repsot a new trailer unit.Spot Pit Module next to sub base, Rig up,attaching all lines and hoses. Hook up all air, water,steam,and hydraulic lines. Lay pit liner, and spot Rockwasher. Berm all modules. Berm&install cuttings tanks.Allow Hi Line power unit to warm.Change out valves and seats on mud pumps. 02/28/2011 Continue rig up as per checklist. Rig accepted at 0100 HRS.Take on 780 BBLS of spud mud. Rig up Diverter system.Thaw out diverter line from blowing snow. Load pipe shed with 120 joints of 5"DP. Make up diverter buoy line. Pull tools to rig floor. Strap BHA.Clean up cellar and install handrails. pick up 5"DP from shed, racking back 13 stands. Drift same. Page 1 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 12:00 ' 12.00 MIRU MOVE MOB P Continue rig up as per checklist. Rig accepted at 0100 HRS.Take on 390 BBLS of spud mud. Rig up diverter system.Hook up interconnect to rockwasher. Function test conveyors and E-stops.Make up Koomey lines. Install 4"valves on conductor. Install flow riser.Clean suctions and discharges on mud pumps. Crew Change 12:00 22:00 10.00 MIRU MOVE RURD P Load 5"DP in shed.Thaw out diverter buoy line from blown snow. Install diverter line. Lockdown speedhead as per FMC. Pull tools to rig floor.Strap BHA.Clean cellar area,and install handrails on BOP landings. 22:00 00:00 2.00 MIRU MOVE PULD P Pick up 5"DP from shed,drifting with 2.92" Drift. Rack back 13 stands. Crew Change 03/01/2011 Continue pick up 5"DP from shed racking back a total of 40 stands. RIH with one stand to tag ice plug @ 62'. Perform Diverter function test.observed 17 secs for knife valve to open and 35 seconds for annular to close.200 PSI increase in 40 secs,with full 3000 PSI in 145 secs. 5 Nitrogen bottles with avg PSI of 2350. Witness of test waived by AOGCC rep Chuck Scheve. RU Gyro and unit. MU 13 1/2"drilling BHA.Wash ice plug from 62'to bottom of conductor at 136'. Drill form 136'-311'. POOH Make up remaning BHA with MWD assembly. Upload, perform shallow pulse test.TIH to directional drill from 311'-742'MD.TVD=720'. Utilize GYRO surveys each stand. Max gas observed= 13 units. 00:00 01:00 1.00 0 0 MIRU RIGMNT SVRG P Sercvie rig.Top drive,draw works, iron roughneck. Strap HWDP in derrick. 01:00 03:30 2.50 0 0 MIRU MOVE PULD P Continue pick up 5"DP from shed racking back a total of 40 stands. Drift DP to 2.92".Strap HWDP in derrick.Tag ICE plug in conductor @ 62' DPM. 03:30 05:30 2.00 0 0 SURFA(WHDBO BOPE P Charge accumulator and lines to Diverter system. Perform Diverter function test and leak test. Observed opening of knife valve in 17 seconds, and annular closing in 35 secs. First 200 PSI increase in 40 Secs,with full 3000 PSI in 145 secs.5 Nitrogen bottle with avg PSI of 2350. 16 Bottle Nitrogen precharge @ 1000 PSI. Witness of test waived by AOGCC rep Chuck Scheve. 05:30 06:30 1.00 0 0 SURFA( DRILL RURD P Held PJSM, rig up GYRO unit with tool string. Hange sheaves. 06:30 08:30 2.00 0 0 SURFA( DRILL PULD P Held PJSM with Sperry reps. Make up 13 1/2"drilling BHA. Make up HTC MXL-1X bit jetted for a TFA of .875 sq in. on 8"Sperry Lobe Motor with a bend of deg. Continue make up stabilizer, UBHO sub and orient for GYRO tools. Page 2 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 09:00 0.50 0 0 SURFA( DRILL PRTS P Fill DP and flood conductor. Check all lines. Pressure test mud lines to IBOP-3000 PSI. 09:00 09:30 0.50 0 0 SURFA( DRILL WASH P RIH to tag Ice plug at 62'DPM. Wash down in conductor to 136'. RPM's-50, Pumps at 430 GPM's- 500 PSI. UP WT=85K,SO WT= 85K. 09:30 12:00 2.50 0 311 SURFA( DRILL DDRL P Drill 13 1/2"Hole from 136'-311'MD. TVD=311'. Pumps at 500 GPM's- 600 PSI,60 RPM's. Torque on=1K, Torque off= 1K.WOB=5-10K, UP WT=93K.SO WT=93K. ROT WT =93K. ADT=1.06 HRS.AST=.44 HRS.ART=.62 HRS Total Bit HRS =1.06 Total Jar HRS=0 Max gas observed=21 Units. Crew Change 12:00 12:30 0.50 311 311 SURFA( DRILL SRVY P Blow down Top Drive. Run Gyro Survey.WLOH. 12:30 14:00 1.50 311 0 SURFA( DRILL TRIP P POOH with drill string to surface. Clean&inspect bit. 14:00 16:00 2.00 0 0 SURFA( DRILL PULD P Held PJSM with crew&Sperry reps. Make up BHA. Make up MWD assembly. 16:00 16:30 0.50 0 0 SURFA( DRILL PULD P Plug in and Up Load MWD assembly. 16:30 18:00 1.50 0 311 SURFA( DRILL PULD P Make up remaining BHA, including flex drill collars, HWDP&Jars. perform Shallow pulse test with 500 GPM's-1100 PSI.Good test.Total BHA length=536.85' 18:00 18:30 0.50 311 311 SURFA( DRILL TRIP P TIH with drill string to wash to bottom at 311'. 18:30 00:00 5.50 311 742 SURFA( DRILL DDRL P Drill 13 1/2"Hole from 311'-742'MD. _ TVD=720'. Pumps at 500 GPM's- 1430 PSI,60 RPM's. Torque on= 3-4K,Torque off=1-2K.WOB= 10-15K, UP WT= 110K.SO WT= 105K. ROT WT= 105K. ADT= 1.87 HRS.AST= 1.50 HRS.ART=.37 HRS Total Bit HRS=3.00 Total Jar HRS=1.87 Max gas observed= 13 Units.Crew Change 03/02/2011 Continue Directional Drill 13 1/2"Surface hole from 742'-2145'MD.TVD= 1816'.ADT=9.57 HRS.AST= 5.97 HRS.Total Bit HRS= 12.57.Total Jar HRS= 11.44. Max gas observed=1254 units. 00:00 06:00 6.00 742 1,008 SURFA( DRILL DDRL P Drill 13 1/2"Hole from 742'-1008' MD.TVD=987'. Pumps at 505 GPM's-1450 PSI,60 RPM's. Torque on=4-5K,Torque off=3-4K. WOB=20-25K, UP WT= 118K. SO WT= 117K. ROT WT= 118K. ADT =2.02 HRS.AST=1.45 HRS.ART = .57 HRS Total Bit HRS=5.02 Total Jar HRS=3.89 Max gas observed=23 Units. Page 3 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06:00 08:00 2.00 1,008 1,008 SURFA( DRILL REAM T Excessive dogleg. Pump out of hole 2 stands to 900'.Trough from 900- 912'with bit at high side.TIH.Obtain check shot survey,compare with GYRO. 08:00 09:00 1.00 1,008 1,008 SURFA( DRILL CIRC P Observed 262 units of gas at surface before run GYRO during flow check. Circulate at 550 GPM's-1400 PSI. Max gas observed-1122 units. Balance scale at flowline indicate 8.7 ppg mud.Circulate to balance total of 3250 stks. Reciprocate&rotate drill string. 09:00 12:00 3.00 1,008 1,197 SURFA( DRILL DDRL P Drill 13 1/2"Hole from 1008'-1197' MD.ND= 1149'. Pumps at 550 GPM's-1600 PSI,60 RPM's. Torque on=4-6K,Torque off=3-4K. WOB=20-28K, UP WT=120K.SO WT=120K. ROT WT=120K. ADT =1.51 HRS.AST=.63 HRS.ART= .88 HRS Total Bit HRS=6.53 Total Jar HRS=5.40 Max gas observed= 1122 Units. GYRO&E-line unit crew released.Crew Change 12:00 18:00 6.00 1,197 1,670 SURFA( DRILL DDRL P DrjJl 13 1/2"Hole from 1197'-1670' MD.ND= 1526'. Pumps at 550 GPM's-1750 PSI,60 RPM's. Torque on=6-7K,Torque off=4-5K. WOB=20-24K, UP WT= 135K.SO WT= 120K. ROT WT= 125K. ADT =2.76 HRS.AST=1.12 HRS.ART = 1.64 HRS Total Bit HRS=9.29 Total Jar HRS=8.16 Max gas observed= 1254 Units. 18:00 00:00 6.00 1,670 2,145 SURFA( DRILL DDRL P Drill 13 1/2"Hole from 1670'-2145' MD.ND= 1816'. Pumps at 600 GPM's-2200 PSI,60 RPM's.Torque on=7-8K,Torque off=5-6K.WOB =20-24K, UP WT=132K. SO WT= 122K. ROT WT= 125K. ADT=3.28 HRS.AST=1.89 HRS.ART=1.39 HRS Total Bit HRS=12.57 Total Jar HRS=11.44 Max gas observed= 737 Units.Crew Change 03/03/2011 Continue Directional Drill 13 1/2"Surface hole from 2145'-3672'MD.ND=2374'.ADT= 11.75 HRS.AST= 1.65 HRS.Total Bit HRS=24.32.Total Jar HRS=23.19.Max gas observed=615 units,TD section(a.2030 HRS. CBU-no gas observed. BROOH at 20-25 ft/minute at full drilling rates. 00:00 06:00 6.00 2,145 2,524 SURFAt DRILL DDRL P Drill 13 1/2"Hole from 2145'-2524' MD.ND= 1954'. Pumps at 600 GPM's-2080 PSI,65 RPM's.Torque on=7-8K,Torque off=5-7K.WOB =20-24K, UP WT=133K. SO WT= 120K. ROT WT= 125K. ADT=3.25 HRS.AST=1.30 HRS.ART= 1.95 HRS Total Bit HRS= 15.82 Total Jar HRS=14.69 Max gas observed= 302 Units. Page 4 of 39 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 2,524 2,960 SURFA( DRILL DDRL P Drill 13 1/2"Hole from 2524'-2960' MD.ND=2112'. Pumps at 650 GPM's-2250 PSI,65 RPM's.Torque on=9K,Torque off=7K.WOB= 20-24K, UP WT= 138K. SO WT= 122K. ROT WT= 130K. ADT=2.93 HRS.AST=.14 HRS.ART=2.79 HRS Total Bit HRS=18.75 Total Jar HRS=17.62 Max gas observed= 405 Units.Crew Change 12:00 18:00 6.00 2,960 3,495 SURFA( DRILL DDRL P Drill 13 1/2"Hole from 2960'-3495' MD.ND=2307'. Pumps at 650 GPM's-2480 PSI,65 RPM's.Torque on=9K,Torque off=7K.WOB= 20-24K, UP WT=145K.SO WT= 122K. ROT WT= 132K. ADT=3.95 HRS.AST=.21 HRS.ART=3.74 HRS Total Bit HRS=22.70 Total Jar HRS=21.57 Max gas observed= 615 Units. 18:00 20:30 2.50 3,495 3,672 SURFA( DRILL DDRL P Drill 13 1/7"Hole from 349s'-3677 MD.ND=2374'. Pumps at 650 GPM's-2450 PSI,65 RPM's.Torque ftbfq on=10K,Torque off=7K.WOB= 20-22K, UP WT= 148K.SO WT= 125K. ROT WT=132K. ADT= 1.62 HRS.AST=0 HRS.ART=1.62 HRS Total Bit HRS=24.32 Total Jar HRS=23.19 Max gas observed= 215 Units.Surface section TD'd. 20:30 21:30 1.00 3,672 3,672 SURFA( DRILL CIRC P Circulate bottoms up at 600 GPM's- 2100 PSI. Reciprocate 7 rotate drill string.Observed no gas on bottoms up. 21:30 00:00 2.50 2,672 2,700 SURFA( DRILL REAM P BROOH at drilling rates from 3672'- 2,700'.String speed 20-25 ft/minute.Observed excessive clay on the shakers plugging up.Work drill string while clean out troughs and possum belly in shakers. 03/04/2011 Continue BROOH to HWDP @ 537'MD.Observed excessive clay balls&cuttings at shakers,and plugging off at flow line. Clean flow line and shakers. Circulate to obtain 500 GPM's. Monitor well-static.TIH back to TD.Wash down last stand. Observed proper displacement and clean hole conditions. CBU x 3. Pump a nut plug sweep. Cuttings cleaned up. POOH. Breakout&lay down BHA#1. Inspect&grade bit to 1/1/CT/G/E/1/4"/WT/TD. Clean&clear rig floor. RU casing running equipment. Flush riser&bowl area. Held PJSM with crew.Make up shoe track&check floats. Good. RIH with 10 3/4"casing.Observed make up torque @ 10,000 ft/lbs. Observed proper displacement. 00:00 04:30 4.50 2,700 537 SURFA( DRILL REAM P Continue BROOH to HWDP at 537' MD. Observed proper displacement. 04:30 07:00 2.50 537 537 SURFA( DRILL CIRC P Monitor well-static.Circulate @ 300 GPM's while clean shakers,troughs, possuum belly,and flow riser from excessive clay balls and cuttings. Obtain good flow rate to 500 GPM's. Reciprocate&rotate drill string. Blow down top drive&lines. Page 5 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 08:30 1.50 537 3,672 SURFA( DRILL TRIP P Trip in hole from 537'to TD @ 3672' MD.Wash down last stand. Observed proper displacement,good hole conditions. UP WT=150K,SO WT=125K. 08:30 10:30 2.00 3,672 3,672 SURFA( DRILL CIRC P Circulate bottoms up x 3. Pump a nut plug sweep. Reciprocate&rotate drill string. Pumps at 650 GPM's- 2360 PSI. Max gas observed=265 units. 10:30 11:00 0.50 3,672 3,672 SURFA( DRILL OWFF P Monitor well-static. Blow down top drive&lines. 11:00 14:00 3.00 3,672 537 SURFA( DRILL TRIP P POOH on elevators from 3672'-537' MD. Observed good hole conditions, and proper displacement. 14:00 15:00 1.00 537 0 SURFA( DRILL PULD P Monitor well-static. Rack back HWDP in derrick. 15:00 16:00 1.00 0 0 SURFA( DRILL PULD P Held PJSM.breakout&lay down jars, and flex drill collars, and UBHO sub. 16:00 17:00 1.00 0 0 SURFA( DRILL PULD P Plug in and download MWD assembly. Pull pulsar form collar. 17:00 18:30 1.50 0 0 SURFA( DRILL PULD P Continue POOH,breakout&lay down BHA#1. Inspect&grade bit to 1/1/CT/E/1/4"/WT/TD. 18:30 22:30 4.00 0 0 SURFA( CASING RURD P Clean&clear rig floor area. Lay down tools. Remove short bales, install Franks fill up tool, and install long bales. Install pick up line,and elevators. Rig up caing running equipment, including tongs and spiders. Rig up scaffolding for tong operator. Drain riser,and flush clay balls form bowl area of head. Double check all casing and straps. Function test casing tongs. 22:30 23:00 0.50 0 0 SURFA( CASING SFTY P Held PJSM with crew. Discuss safety&hazard recognitions issues. Discuss casing running checklist, and procedure to pick up shoe track assembly and run casing. 23:00 00:00 1.00 0 0 SURFA( CASING RNCS P Make up 10 3/4"shoe track. Check floats.Good.Continue RIH with 10 3/4"casing as per detail. 03/05/2011 Continue RIH with 10 3/4"casing as per detail.Circulate at 891', 1476',&2474'while RIH,staging pumps each rtime to 5 BPM. Run 88 jnts. Make up casing hanger and landing jnt. Land casing.Shoe depth=3664' MD. Break circulation and stage pumps to 7 BPM-520 PSI,while reciprocate casing string in 20-25' increments. UP WT=205K,SO WT=145K.Spot all trucks and cement units. Held PJSM with crew, Cementers,and all truck drivers.Assign Spill Champions,and discuss saftey&hazard recognition issues. Discuss cementing procedure. Pump 10 BBLS of CW100. Pressure test lines to 3000 PSI-good test. Mix and pump 38 bbls CW 100 Chem Wash, Pump 49 BBLs of 10.5 PPG Mud push with Red Dye.Turn over to 10.9 PPG Lead Cement,pump 423 bbls'Lead Cement,Switch To Tail Cement 113 bbl's pumped 12.0 Tail Cement. Dropped top plug and pumped 10 Bbls water.Observed casing hanger stuck one foot off of casing bowl. ND, install emergency slips for centering. Land with 105K tension. ND diverter system. Page 6 of 39 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 09:30 9.50 0 3,664 SURFA(CASING RNCS P Continue RIH with 10 3/4"casing. Make up Torque=10K ft/lbs.Obtain T&D parameters every 10 jnts. Circulate at depth of 891', 1476',and 2474'.Staging pumps to 5 BPM each time.Observed proper displacement.Make up casing hanger and landing jnt. Land casing. UP WT=178K,SO WT=129K. 09:30 12:00 2.50 3,664 3,664 SURFA(CASING CIRC P Breakdown Franks Fill Up tool. Rig up cement head&lines. Break circulation staging pumps to Break circulation and stage pumps to 7 BPM-520 PSI,while reciprocate casing string in 20-25'increments. UP WT=178K,SO WT=129K. Spot all trucks and cement units. Rig down casing running equipment. Clean&clear rig floor.Crew Change 12:00 13:00 1.00 3,664 3,664 SURFA(CASING CIRC P Continue reciprocate casino strina. with pre-cement mud properties of 9.5 PPG,YP-25, PV-41 and Funnel Visc of 90. Batch Mix mud push, and prep for job. UP WT=190K,SO WT = 150K. 13:00 16:00 3.00 3,664 3,664 SURFA( CEMENT CMNT P Turn over to Schlumberger. Pump 10 BBLS of CW100 pressure test lines to 3000 PSI-good test. Mix and pump 38 bbls CW 100 Chem Wash, Pump 49 BBLs of 10.5 PPG Mud push with Red Dye.Turn over to 10.9 PPG Lead Cement, pump Is' CI Lead Cement,Switch To Tail Cement 1131_0.p j..p pumped 12.0 Tail Cement. ropped top plug and pumped 10 Bbls water. Reciprocation stopped just after start pumping Tail,with hanger 1'above casing bowl. 16:00 17:00 1.00 3,664 3,664 SURFA( CEMEN'DISP P Switch to rig pumps and displace with 9.5 PPG Mud. Bumped plug at 347 bbl's pumped for displacement. 3310 stks. Observed 258 bbl's cement to surface. Bumped plug with CIP 15:40 HRS. Full returns throughout job. 17:00 22:00 5.00 0 0 SURFA( DRILL RURD P Rig down cement line&cement head. ND with landing jnt made up. Raise stack. Fluted hanger at 1 foot above landing in bowl. Install emergency slips for a centering guide,with 105K in tension. Set down. 22:00 00:00 2.00 0 0 SURFA( DRILL RURD P Back out&lay down landing joint. Clean&clear rig floor. Send tools out. ND riser and diverter system. Loaded 128 jnts of 5"DP in shed for next run.Crew change Page 7 of 39 7 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/06/2011 24 hr Summary Continue ND Diverter system. NU Casing spool and head. NU BOP's. Install 5"rams. Rig up to test BOP's. Install test plug.Tighten flanges from leaks.trouble shoot leaks.Test Annular to 250/2500 PSI.Observed top rams would not test. Open ram doors. Pull VBR's.Witness of test waived by AOGCC rep-Bob Nobles. 00:00 03:30 3.50 0 0 'SURFA(WHDBO NUND P Held PJSM.Continue ND diverter system. Riser,knife valve, buoy line, and Annular. Remove adapter flange. Remove from rig floor tongs, elevators,and long bales. 03:30 06:15 2.75 0 0 SURFA(WHDBO NUND P NU Casing head and spool as per FMC rep. Install wellhead adapter, Test lower casing head void-1000 PSI-10 minutes. 06:15 12:00 5.75 0 0 SURFA(WHDBO NUND P Held PJSM. NU BOP's. NU Drilling spool adapter. NU riser. Install flowline. Cut bell nipple-install same.Attach Koomey lines. Load 124 jnts of 5"drill pipe in shed. Attach turnbuckles. Begin to change out lower rams from 7 5/8"to 5"solid body. Crew Change 12:00 16:00 4.00 0 0 SURFA(WHDBO NUND P Held PJSM. Continue change out lower rams from 7 5/8"to 5"solid body.Continue NU kill&choke lines. Hook up gas buster line,flare line, overboard line,and bell nipple. 16:00 18:00 2.00 0 0 SURFA(WHDBO BOPE P Rig up test equipment. Install test plug. Fill stack, choke manifold,and lines with water. 18:00 00:00 6.00 0 0 SURFA(WHDBO BOPE P Pressure up for a full body test to 3500 PSI as per permit.Observed leaks on flanges.Tighten flanges on choke line.test annular to 250/2500 PSI.Observed no test on 3 1/2"x 6" VBR's. Repeat attempts and troubleshoot.Open doors,and pull VBR's for inspection.Observed damaged seal rubber. Crew Change 03/07/2011 Continue install 5"solid body rams.Test BOP's to 3500/250 PSI.Test choke manifold,and all floor safety valves.Witness of test waived by AOGCC rep-Bob Nobles. RD Test equipment. Install WB. RILDS. Install bales on Top Drive. Pick up 5"DP from shed and rack back same in derrick.Make up 9 7/8"Drilling BHA with Hycalog DTX619M Bit. Perform shallow pulse test.TIH with 5"DP singles from shed. 00:00 01:00 1.00 0 0 SURFA(WHDBO NUND T Continue install 5"solid body rams. 01:00 06:30 5.50 0 0 SURFA(WHDBO BOPE P Continue test BOP stack.Test Blinds,both sets of rams to 250/ 6°F 3000 PSI.Test Annular to 250/2500 PSI. Continue test choke manifold "S and all valves.Test floor safety valves. Record all tests on chart. Perform Koomey test. First 200 PSI increase in 24 secs,with full 3000 PSI in 144 secs. Observed 5 nitrogen bottles with 2500 avg pressure. 06:30 06:45 0.25 SURFA(WHDBO PULD P Pull test plug. Install wear bushing. ID ofWB=9.94" Page 8 of 39 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 06:45 07:00 0.25 0 0 SURFA( DRILL SFTY P Held PJSM with Crew. Discuss safety&hazard recognition issues. Discuss procedure&checklist to pick up and rack back drill pipe in derrick. 07:00 12:00 5.00 0 0 SURFA( DRILL PULD P Pick up 5"drill pipe form shed, make up stands and rack back in derrick a total of 42 stands. Crew Change 12:00 13:30 1.50 0 0 SURFA( DRILL PULD P Continue pick up 5"drill pipe form shed,make up stands and rack back in derrick a total of 97 stands in derrick. 13:30 14:15 0.75 0 0 SURFA( RIGMNTSVRG P Service rig.Top drive,draw works, and grease blocks.Check Crown-o- matic. 14:15 14:45 0.50 0 0 SURFA( DRILL PULD P Clean&clear rig floor. Send out thread protectors. Pull mouse hole from rotary table. Install same. 14:45 15:00 0.25 0 0 SURFA( DRILL SFTY P Held PJSM with crew&Sperry Sun reps. Discuss safety&hazard recognition issues. Discuss procedure&checklist to make up BHA and install nukes. 15:00 17:00 2.00 0 0 SURFA( DRILL PULD P Make up 9 7/8"Hycaloq DTX619M bit on a 7"Sperrylobe 7/8-6.0 stg motor.Continue make up float sub, and MWD assembly. 17:00 18:00 1.00 0 0 SURFA( DRILL PULD P Plug in and upload MWD assembly. 18:00 18:30 0.50 0 SURFA( DRILL PULD P Make up flex drill collar. 18:30 19:30 1.00 0 0 SURFA( DRILL DHEQ P Perform shallow pulse test with pumps at 500 GPM's-1290 PSI. 19:30 20:30 1.00 0 0 SURFA( DRILL PULD P Blow down Top drive. Pull nukes to floor. Held PJSM. Install nukes as per MWD rep. 20:30 21:30 1.00 0 685 SURFA( DRILL PULD P Pick up remainig flex drill collars, HWDP and jars. Install Mi Well 'commander circulating valve.Total BHA length=685.61' 21:30 00:00 2.50 685 2,677 SURFA( DRILL PULD P TIH picking up singles of 5"drill pipe from shed.Crew Change 03/08/2011 li Continue TIH picking up 5"DP singles form shed to 3341'.Slip&Cut drilling line. Change out Saver Sub on Top Drive.Wash to TOC.CBU. Rig up and test casing to 3000 PSI-30 minutes. Perform FIT to 16 ppg EMW. Directionally drill from 3,672'-4,607'MD. 00:00 00:45 0.75 2,677 3,341 SURFA( DRILL PULD P Continue TIH picking up 5"drill pipe singles from shed to 3341'. 00:45 01:00 0.25 3,341 3,341 SURFA( RIGMNT SFTY P Held PJSM with crew. Discuss safety&hazard recogntion issues. Discuss procedure&checklist to slip&cut drilling line. 01:00 03:00 2.00 3,341 3,341 SURFA( RIGMNT SLPC P Slip&cut drilling line. Inspect brakes &drilling line. 03:00 05:15 2.25 3,341 3,341 SURFA( RIGMNTSVRG P Change out Saver Sub on Top Drive. 05:15 08:30 3.25 3,341 3,567 SURFA( DRILL PRTS P RIH,to FC, circ and cond mud at 3567'MD. PT casing to 3000 psi for 30 min. Page 9 of 39 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 08:30 11:00 2.50 3,567 367 SURFA(CEMEN"DRLG P Drill shoe track. 11:00 11:30 0.50 3,672 3,692 SURFA( DRILL DDRL P Drill 20'of new hole 11:30 12:00 0.50 3,692 3,692 SURFA( DRILL CIRC P Circ and condition mud. 12:00 13:30 1.50 3,692 3,692 SURFA( DRILL FIT P Performed FIT to 16.0 ceo EMW (800 psi with 9.5 ppg mud). Obtained SPR's. 13:30 14:00 0.50 3,692 3,692 INTRM1 RIGMNT SVRG P Rig Maintenance-Add oil to topdrive 14:00 18:30 4.50 3,692 4,135 INTRM1 DRILL DDRL P Directional Drill 9 7/8"Hole from 3692'-4135'MD.TVD=2536'. Pumps at 650 GPM's-2310 PSI.80 RPM's.WOB=6-8 K.Torque on= 9-10 K. UP WT=170K. SO WT= 115K. ROT WT=135K.ADT=2.45 HRS.AST=.33 HRS.ART=2.12 HRS.Total Bit HRS=2.45.Total Jar HRS=2.45. Max gas observed= 243 Units. ECD's-10.49 PPG 18:30 19:30 1.00 4,135 4,135 INTRM1 RIGMNT SVRG P Pump maintenance-do o-ring on back of swab 19:30 00:00 4.50 4,135 4,607 INTRM1 DRILL DDRL P Directional Drill 9 7/8"Hole from 4135'-4607'MD.ND=2706'. Pumps at 800 GPM's-2650 PSI. 120 RPM's.WOB=6-8 K.Torque on =6-12 K,Torque off 9-10 K. UP WT =180K.SO WT=120K. ROT WT= 140K.ADT=2.61 HRS.AST=.14 HRS.ART=2.47 HRS.Total Bit HRS=5.06.Total Jar HRS=5.06. Max gas observed= 120 Units. ECD's-10.66 PPG 03/09/2011 Directionally drill from 4607'-6,182'MD. Circ. BU and short trip(backream)to shoe. Circ.3 BU at shoe rotating&recip. Pull into shoe with BHA,open Well Commander and circ 2 BU. 00:00 12:00 12.00 4,607 5,803 INTRM1 DRILL DDRL P Directional Drill 9 7/8"Hole from 4607'-5803'MD.ND=3149'. Pumps at 790 GPM's-3010 PSI. 120 RPM's. Torque on= 12-13 K, Torque off 11 K.WOB=4-8 K. UP WT=190K.SO WT=148K. ROT WT=128K.ADT=7.06 HRS.AST =.20 HRS.ART=6.86 HRS.Total Bit HRS=12.12.Total Jar HRS= 12.12. Max gas observed=75 Units. ECD's-10.75 PPG Page 10 of 39 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 12:00 15:30 3.50 5,803 6,182 INTRM1 DRILL DDRL P Directional Drill 9 7/8"Hole from 5803'-6182'MD.TVD=3296'.with down hole vibration increasing. Reduced RPM to 90 RPM to correct. Pumps at 790 GPM's-3290 PSI. . Torque on= 10-13 K,Torque off 9- 10K.WOB=8-10K. UPWT= 185K.SOWT= 135K. ROTWT= 155K.ADT=2.63 HRS.AST=.20 HRS.ART=2.63 HRS.Total Bit HRS=14.75.Total Jar HRS=14.75. Max gas observed=48 Units. ECD's -10.74 PPG Took SPR's. 15:30 16:30 1.00 6,182 6,182 INTRM1 DRILL CIRC P Pumped 3 BU's prior to short trip 16:30 21:30 5.00 6,182 3,663 INTRM1 DRILL REAM P BROOH f/6182'-3663'MD w/600 _GPM, 1890 PSI and 90 RPM 21:30 22:00 0.50 3,663 3,663 INTRM1 DRILL CIRC P Circ 3 BU at shoe w/800 GPM.2900 psi and 80 RPM. Significant cuttings at 1st two bottoms up and tapering off at 3rd. Cuttings consisted of clay pads that look like they were stuck _either on the casing wall or drillpipe. 22:00 00:00 2.00 3,663 3,906 INTRM1 DRILL TRIP P Pulled up to 3630'bit depth and dropped ball to open circ sub. TIH on elevators and started circulating with circ sub at at 3600', inside casing. Bit at 4050'MD. Pumped out of hole w/900 GPM, 1200 psi and no rotation to 3906'MD. Pumped 2 BU with very little cutting returns, less than half of previous. 03/10/2011 Complete short trip. Directionally drill from 6,182'to 7,740'MD. 00:00 00:45 0.75 3,906 3,623 INTRM1 DRILL CIRC P Drop Ball and close Well Commander Circ Sub. POOH to 3623'MD. 00:45 01:15 0.50 3,623 3,623 INTRM1 RIGMN7 SVRG P Service Top Drive 01:15 02:45 1.50 3,623 6,182 INTRM1 DRILL TRIP P RIH from 3623'to 6090'MD. Precautiionary wash and ream to 6182'MD. Pumps at 750 GPM's- 3050 PSI. . Torque on=11 K, UP WT= 190K. SO WT=120K 02:45 19:00 16.25 6,182 7,319 INTRM1 DRILL DDRL P Directional Drill 9 7/8"Hole from 6182'to 7319'MD.ND=3711'. Pumps at 790 GPM's-3470 PSI. Torque on= 15-16 K,Torque off 14-16 K.WOB=4-10 K. UP WT= 220K. SO WT=130K. ROT WT= 160K.ADT=8.41 HRS.AST=.69 HRS.ART=7.72 HRS.Total Bit HRS=23.16.Total Jar HRS=23.16. Max gas observed=50 Units. ECD's -10.60 PPG Took SPR's. Page 11 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 19:45 0.75 7,319 7,319 INTRM1 DRILL DHEQ T Trouble shoot MWD signal. Could not log while drilling, but could still get surveys and logs during backreaming. Pump#1 may be causing a background noise. Decided to continue drilling and trouble shoot pump during short trip. 19:45 00:00 4.25 7,319 7,740 INTRM1 DRILL DDRL P Directional Drill 9 7/8"Hole from 7319'to 7740'MD.ND=3863'. Pumps at 790 GPM's-3590 PSI. . Torque on=13-14 K,Torque off 10-11 K.WOB=8-10 K. UP WT= 200K.SO WT=140K. ROT WT= 165K.ADT=4.06 HRS.AST=.17 HRS.ART=3.89 HRS.Total Bit HRS=27.22.Total Jar HRS=27.22. Max gas observed=56 Units. ECD's -10.83 PPG. MWD started working normally again, may have been after bleeding pres.on pulsation dapener. 03/11/2011 Drilled from 7740'to 7887'MD. Had wash out on mud pump fluid end. Repaired and short tripped (backreamed)from 7887'to 6087'MD. RIH and resumed drilling to 8685'MD. 00:00 01:30 1.50 7,740 7,887 INTRMI DRILL DDRL P Directional Drill 9 7/8"Hole from 7740'to 7887'MD.ND=3916'. Pumps at 785 GPM's-3550 PSI. . Torque on= 12-14 K,Torque off 11-12 K.WOB=4-8K. UP WT= 204K. SO WT=140K. ROT WT= 105K.ADT=.74 HRS.AST=.06 HRS.ART=.68 HRS.Total Bit HRS =26.74.Total Jar HRS=26.74. Max gas observed=54 Units. ECD's- 10.91 PPG. 01:30 02:15 0.75 7,887 7,887 INTRM1 DRILL CIRC P Circ and Gond mud prior to short trip. Circulated just under one BU and mud pump#2 had to be taken down. 02:15 06:30 4.25 7,887 7,887 INTRM1 RIGMNT RGRP T Trouble shoot Mud pump#2 and found washout in fluid end(suction side). Change out fluid end. 06:30 07:15 0.75 7,887 7,887 INTRM1 DRILL CIRC P Circ and cond mud prior to short trip with 1 BU at 800 GPM,3700 PSI and 110 RPM. 07:15 10:15 3.00 7,887 6,087 INTRM1 DRILL TRIP P BROOH from 7887-6087'MD at 790 GPM, 3550 PSI and 110 RPM. Torque=10k, UP WT= 185K,SO WT= 131K, ROT WT= 150K 10:15 11:30 1.25 6,087 6,087 INTRMI DRILL CIRC P Circ and cond mud prior to short trip with 1 BU at 800GPM,3450 PSI and 110 RPM. 11:30 13:00 1.50 6,087 7,887 INTRMI DRILL TRIP P RIH on elevators from 6087-7800, wash down to 7887'MD at 750 GPM and 3500 PSI. UP WT=185K,SO WT=131K Page 12 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 00:00 11.00 7,887 8,685 INTRM1 DRILL DDRL P Directional Drill 9 7/8"Hole from 7887'to 8685'MD.TVD=4206'. Pumps at 780 GPM's-3650 PSI. Torque on= 15-19 K,Torque off 12-15 K.WOB=5-10K. UP WT= 210K.SO WT= 150K. ROT WT= 165K.ADT=7.3 HRS.AST=0 HRS.ART=7.3 HRS.Total Bit HRS =33.88.Total Jar HRS=33.88. Max gas observed=73 Units. ECD's- 10.8 PPG. 03/12/2011 Drilled from 8685'to 9134'MD. SCR failed. Had wash out on mud pump fluid end(this time HP end). Started short trip early at 9134'MD. SCR failed again and repaired same. Determined that field power spikes caused failure. Started rig generators. Continue BROOH while repairing pump. 00:00 01:30 1.50 8,685 8,835 INTRM11 DRILL DDRL P Directional Drill 9 7/8"Hole from 8685'to 8835'MD.TVD=4249'. Pumps at 780 GPM-4000 PSI. Torque on= 15 K,Torque off 12 K. WOB=4-6K. UP WT=210K. SO WT=172K. ROT WT= 150K.ADT= .82 HRS.AST=0 HRS.ART=.82 HRS.Total Bit HRS=35.27.Total Jar HRS=35.27. Max gas observed = 15 Units. ECD's-10.91 PPG. 01:30 02:45 1.25 8,835 8,835 INTRM1 RIGMN1 RGRP T Top Drive quit rotating. Trouble shoot _SCR's. Replaced bad capacitor. 02:45 07:15 4.50 8,835 9,134 INTRM1 DRILL DDRL P Directional Drill 9 7/8"Hole from 8835'to 9134'MD.TVD=4372'. Pumps at 780 GPM-3800 PSI. Torque on= 13 K,Torque off 11 K. WOB=6-10K. UP WT=212K. SO / WT=150K. ROT WT= 185K.ADT= 2.32 HRS.AST=0.49 HRS.ART= 1.83 HRS.Total Bit HRS=37.59. Total Jar HRS=37.59. Max gas observed=64 Units. ECD's-10.95 PPG. 07:15 08:45 1.50 9,134 9,134 INTRM1 RIGMNT RGRP T Shut down mud pump#2 to trouble shoot. Found wash out in HP side of fluid end. Circ with MP#1 at 430 GPM and 30 RPM. Decide to short trip while repairing pump 08:45 15:15 6.50 9,134 5,420 INTRM1 DRILL TRIP T Short trip(BROOH)from 9134'to 5420'. Pumps at 450 GPM-1450 PSI. Torque on= 10 K, UP WT= 150K.SO WT= 140K. 15:15 19:15 4.00 5,420 5,420 INTRM1 RIGMNT RGRP T Top Drive quit rotating. Circ and recip while troubleshooting at 175 GPM and 1450 PSI. Repaired SCR again and deterrmined field power spikes occuring with main field generator down. Swapped to rig .generators. 19:15 19:45 0.50 5,420 5,420 INTRM1'RIGMNTRGRP T Service Rig Page 13 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:45 21:00 1.25 5,420 5,420 INTRM1 RIGMN7 RGRP T Trouble shoot pump#2. Determined seat washed out again. Circ and recip at 175 GPM and 120 GPM and 50 PSI 21:00 23:30 2.50 5,420 3,717 INTRM1 RIGMNI RGRP T Repair Pump#2. BROOH on way to shoe. 450 GPM.420 GPM, 100 _RPM 23:30 00:00 0.50 3,717 3,717 INTRM1 RIGMN7 CIRC T Circulate 3 BU @ 450 GPM, 1350 PSI, UP WT= 165K, SO WT= 135K. 03/13/2011 Repaired mud pump#2. RIH and drill from 9,134'MD-9,401'MD. BHA quit drilling,suspect motor failure. POOH for motor. 00:00 01:00 1.00 3,717 3,717 INTRM1 RIGMN7 CIRC T Continue to circulate 3 BU @ 450 GPM, 1350 PSI, UP WT= 165K, SO WT=135K. C/O Fluid end on Mud Pump#2. 01:00 08:15 7.25 3,717 3,717 INTRMI RIGMN7 RGRP T C/O Fluid end on Mud Pump#2. PT to 3000 PSI. 08:15 12:30 4.25 3,717 9,134 INTRMI RIGMNITRIP T RIH from 3623'to 9134'MD. Precautionary wash to bottom 12:30 18:00 5.50 9,134 9,401 INTRM1 DRILL DDRL P Directional Drill 9 7/8"Hole from 9134'to 9401'MD.TVD=4372'. Pumps at 780 GPM-3800 PSI. Torque on= 13 K,Torque off 11 K. WOB=6-10K. UP WT=212K. SO WT=150K. ROT WT=185K.ADT= 2.32 HRS.AST=0.49 HRS.ART= 1.83 HRS.Total Bit HRS=37.59. Total Jar HRS=37.59. Max gas observed=64 Units. ECD's-10.95 PPG. 18:00 19:30 1.50 9,401 9,401 INTRM1 DRILL CIRC T Circ and recip prior to POOH for possible failed motor check. GPM= 450 GPM @ 2600 PSI and 120 RPM. Had 4500 PSI pres spike at ✓ 9400'. Pump rate came back at 100 GPM less rate than previously before the spike. Pumped 2 nut plug pills trying to unball the bit with limited results. Could not get differential across motor when trying to drill indicating it may have failed. Also appears that there may me a plugged jet. Confered with CPAI Engineer and Sperry in Town and decided to POOH to check the motor and change-out the MWD batteries. 19:30 00:00 4.50 9,401 4,858 INTRM1 DRILL TRIP T POOH on elevators from 9401'to 4858"MD. No swabbing or overpulls. 03/14/2011 Changed out failed motor and replaced MWD for batteries. RIH and drilled from 9,401' to 9,630'MD 00:00 03:00 3.00 4,858 685 INTRM1 DRILL TRIP T Continue to POOH from 4858-685' MD with drillpipe Page 14 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 03:00 07:00 4.00 685 0 INTRM1 DRILL PULD T LD BHA #2 including bit,failed motor and MWD tools. Download MWD tools as required. Bit was packed with sections of stator rubber that had plugged most of the jets. Bit is in gauge and re-runnable but will take some time to clean out debris. 07:00 12:15 5.25 0 685 INTRM1 DRILL PULD T PU BHA#3-New RR bit,mud motor,MWD tools. Upload MWD tools, PU remainder of BHA 12:15 14:00 1.75 685 3,520 INTRM1 DRILL TRIP T RIH w/drillpipe from 685'-3520'MD 14:00 15:30 1.50 3,520 3,520 INTRM1 RIGMNT SLPC P Slip and cut drilling line. Perform rig service 15:30 19:30 4.00 3,520 9,401 INTRM1 DRILL TRIP T Cont. RIH from 3520'to 9401'MD 19:30 00:00 4.50 9,401 9,630 INTRM1 DRILL DDRL P Directional Drill 9 7/8"Hole from 9401'to 9630'MD.TVD=4582'. Pumps at 750 GPM-3650 PSI. Torque on= 17 K,Torque off 15 K. WOB=5-10K. UP WT=220K.SO WT=140K. ROT WT=175K.ADT= 1.67 HRS.AST= 1.05 HRS.ART= 1.67 HRS.Total Bit HRS= 1.67. Total Jar HRS=42.45. Max gas observed=841 Units at 9547'. ECD's -10.6 PPG. 03/15/2011 Drilled from 9,630'-11,289'MD. 00:00 12:00 12.00 9,630 10,385 INTRM1 DRILL DDRL P Directional Drill 9 7/8"Hole from 9630'to 10385'MD.TVD=4947'. Pumps at 790 GPM-3750 PSI. Torque on= 17 K,Torque off 15 K. WOB=4-8K. UP WT=225K.SO WT= 150K. ROT WT=182K.ADT= 6.53 HRS.AST=3.68 HRS.ART= ✓ 2.91 HRS.Total Bit HRS=8.26. Total Jar HRS=49.13. Max gas observed=640 Units. ECD's-10.51 PPG. 12:00 00:00 12.00 10,385 11,289 INTRM1 DRILL DDRL P Directional Drill 9 7/8"Hole from 10385'to 11289'MD.TVD=5325'. Pumps at 750 GPM-3750 PSI. Torque on= 17 K,Torque off 15 K. WOB=4-8K. UP WT=240K.SO WT= 150K. ROT WT=182K.ADT= 8.22 HRS.AST=4.99 HRS.ART= 3.23 HRS.Total Bit HRS=16.48. Total Jar HRS=57.35. Max gas observed=640 Units. ECD's-10.51 PPG. 03/16/2011 Drilled from 11,289 to TD of 11,824'MD. Short trip and begin to POOH on elevators. Page 15 of 39 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 08:30 8.50 11,289 11,824 INTRM1 DRILL DDRL P Directional Drill 9 7/8"Hole from 11289'to 11824'MD.TVD=5563'. Pumps at 750 GPM-3750 PSI. Torque on=20 K,Torque off 16 K. WOB=10-15K. UP WT=260K.SO WT=165K. ROT WT=200K.ADT= 7.05 HRS.AST=0.0 HRS.ART= 7.05 HRS.Total Bit HRS=23.53. Total Jar HRS=64.40. Max gas observed=604 Units. ECD's-10.69 PPG. 08:30 10:45 2.25 11,824 11,824 INTRM1 DRILL CIRC P Circ and Gond mud at 11824'MD. GPM=750 @ 3670 PSI and 100 RPM. UP WT=260K. SO WT= 165K. Circ 2 BU. 10:45 13:00 2.25 11,824 9,381 INTRM1 DRILL TRIP P POOH on elevators from 11824- 9381'MD. UP WT=250K. SO WT = 150K 13:00 14:30 1.50 9,381 11,824 INTRM1 DRILL TRIP P Flow check,well static. RIH on elevators from 9381' to 11824'MD. UP WT=250K. SO WT=140K 14:30 17:30 3.00 11,824 11,824 INTRM1 DRILL CIRC P Circ and cond mud at 11824'MD. GPM=750 @ 3750 PSI and 100 RPM. 17:30 22:00 4.50 11,824 11,824 INTRM1 RIGMN1 RGRP T Trouble shoot Top Drive for electrical failure. Could not regain ability to rotate or use make-up/break-out or link tilt. Continue to circulate and recip. 22:00 23:30 1.5011,824 10,773 INTRM1 DRILL TRIP P Held PJSM. Discussed risks and mitigations for POOH without normal top drive functions. Pulled 1 stand and discussed risks with driller/crew. Cont.to POOH on elevators from 11824-10773'MD. No swabbing or overpull. 23:30 00:00 0.50 10,773 10,773 INTRM1 DRILL TRIP P C/o bales from short to long bales to further mitigate risks while standing back stands w/o the use of the link tilt. 03/17/2011 POOH w/DP&LD BHA. C/O 5"rams to VBR's and test. Start in hole with 3-1/2"cement stinger. 00:00 10:45 10.75 10,773 675 INTRM1 DRILL TRIP P Cont POOH with drillpipe from 10773' -675'MD. 10:45 16:00 5.25 675 0 INTRM1 DRILL PULD P LD BHA. Remove sources and secure. break out bit, LD motor and MWD. 16:00 22:00 6.00 0 0 INTRM1 WHDBO BOPE P Pull wear ring and install test plug. C/O top set of 5"pipe rams and install 3-1/2"X 6"VBR's. Test against 3-1/2"and 5"test joint. Test VBR's against 5"test jt.to 250/ 3500 psi and against 3-1/2"test jt.to 250/3000 psi. Test annular against 3-1/2"test joint to 250/2500 PSI. Reinstall wear ring. 22:00 00:00 2.00 0 0 INTRM1 CEMENT TRIP P PU 3-1/2"cement stringer and prepare to RIH. Page 16 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/18/2011 24 hr Summary RIH w/cement stinger and spot cement kick-off plug. Condition contaminated mud before POOH. 00:00 13:30 13.50 0 11,805 INTRM1 CEMEN"TRIP P RIH with cementing string to 11,805' MD. 13:30 15:15 1.75 11,805 11,805 INTRM1 CEMEN'CIRC P Circ BU @ 715 GPM and 3060 PSI. Up Wt. =220K, Dn Wt=150K 15:15 16:30 1.25 11,805 11,805 INTRMI CEMEN"CMNT P Pump balanced plug#1 consisting of 30 BBL MUDPUSH II,51.2 BBL 17 PPG cement and 3.2 BBL MUDPUSH II followed by 187 BBL of 9.7 PPG drilling mud. 16:30 17:45 1.25 11,805 11,370 INTRM1 CEMEN-TRIPP POOH to 11, 370'MD for plug#2 17:45 19:00 1.25 11,370 11,370 INTRM1 CEMEN"CMNT P Pump balanced plug#2 consisting of 30 BBL MUDPUSH II, 51.2 BBL 17 PPG cement and 3.2 BBL MUDPUSH II followed by 179 BBL of 9.7 PPG drilling mud. 19:00 19:45 0.75 11,370 10,861 INTRMI CEMEN"TRIP P POOH to 10,861'MD for circulation. 19:45 00:00 4.25 10,861 10,861 INTRM1 CEMEN"CIRC P Circ and treat contaminated mud until mud returns are clean and free of contaminated cement. 03/19/2011 Circ and treated cement contaminated mud. POOH with cementing string. Started BOPE test. 00:00 11:30 11.50 10,861 9,535 INTRMI CEMEN"CIRC P Circ and treat contaminated mud until mud returns are clean and free of contaminated cement. Estimate 30 BBL cmt to surface. Rack back a stand every 30-45 minutes from 10861'-9535'MD. 11:30 16:30 5.00 9,535 1,099 INTRM1 CEMEN"TRIP P POOH with drillpipe from 9535'to 1099'MD. 16:30 19:00 2.50 1,099 0 INTRM1 CEMEN-PULD P POOH with 3-1/2"PH6 tubing string and lay down same. 19:00 20:15 1.25 0 0 INTRM1 DRILL PULD P Pull wear bushing and wash BOP stack with stack cleaning tool. 20:15 00:00 3.75 0 0 INTRM1 WHDBO BOPE P Install test plug with 5"test joint. Test BOPE per AOGCC regs as follows: Test top&bottom sets of fOle pipe rams,choke manifold and all valves to 250/3500 PSI.Test ('/ Annular to 250/2500 PSI.Test choke manifold and all valves.Test floor safety valves. Record all tests on chart. 03/20/2011 Tested BOPE. PU BHA and RIH to 10,603'MD. 00:00 03:30 3.50 0 0 INTRM1 WHDBO BOPE P Continue testing BOPE. Tested blind rams, upper IBOP, lower IBOP, all to 250/3500 PSI. Perform Koomey test. First 200 PSI increase in 49 secs,with full 3000 PSI in 203 secs. Observed 5 nitrogen bottles back-up with 2350 avg pressure. 03:30 04:00 0.50 0 0 INTRM1 WHDBO BOPE P Install wear bushing Page 17 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 06:00 2.00 0 0 INTRM1 DRILL IPULD P I Clear and org rig floor. CIO long bails for short bails and adjust link tilt bars after Top Drive VFD repair. 06:00 12:00 6.00 0 746 INTRM2 DRILL PULD P PJSM of PU BHA. PU bit, motor and MWD. Upload and pulse test MWD. Load sources and PU rest of BHA. 12:00 12:30 0.50 746 746 INTRM2 RIGMN1SVRG P Service Rig 12:30 14:15 1.75 746 3,503 INTRM2 DRILL TRIP P PJSM. RIH with DP from 746'to 3503'MD. 14:15 14:45 0.50 3,503 3,503 INTRM2 RIGMN7 SLPC P PJSM. Slip&cut drillpipe 14:45 21:30 6.75 3,503 10,319 INTRM2 DRILL TRIP P Cont RIH with DP from 3503'to 10319'. PU Wt=330k,SO Wt= 130k. 21:30 23:00 1.50 10,319 10,603 INTRM2 DRILL TRIP P Started seeing cement stringers. Wash/ream down from 10319 to 10603'. Had a 12.5 ppg ECD spike while backreaming. Had partial losses. Worked stand down to get full returns. SD pumps and and well started breathing at less than 5 GPM declining to zero over 20 minutes. Total of 5 BBL flowed back. 23:00 23:30 0.50 10,603 10,573 INTRM2 DRILL OWFF P Flow check. No flow. 23:30 00:00 0.50 10,573 10,573 INTRM2 DRILL TRIP P Break circulation at 250 GPM and gradually work up to 380 GPM @ 1220 PSI and 70 RPM,TQ=22-25K. 03/21/2011 RIH and wash down to firm cement at 10,861'MD. Drill down and kick-off at 10,867'MD. Drill to TD at 11,488' MD,circ BU and Short Trip. 00:00 03:00 3.00 ' 10,573 10,867 INTRM2 DRILL REAM P Continue to wash cement stringers and condition hole from 10573'to 10861'MD. Drilled firm cement from 10861'to 10867'MD. 03:00 05:30 2.50 10,867 10,936 INTRM2 DRILL DDRL P Orient and begin sliding and kick-off top of cement plug at 10.867'MDKte, Directional Drill 9 7/8"Hole from 10867'to 10936'MD.TVD=5117'. �J Pumps at 750 GPM-3750 PSI. 100 �lUp�uJ RPM.Torque on=25 K,Torque off 26 K.WOB=6-10K. UP WT=310K. SO WT=140K. ROT WT=200K. ADT=.6 HRS.AST=0.31 HRS. ART=.29 HRS.Total Bit HRS=.60. Total Jar HRS=65.0.Max gas observed= 155 Units. ECD's-10.52 PPG. 05:30 08:30 3.00 10,936 10,936 INTRM2 RIGMN1 RGRP P Trouble shoot noise on#1 mud pump. Condition and work hole at reduced rate,420 GPM, 1400 PSI and 90 RPM. Page 18 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 08:30 21:00 12.50 10,936 11,488 INTRM2 DRILL DDRL P Directional Drill 9 7/8"Hole from 10936'to 11488'MD(TD).TVD= 5365. Pumps at 750 GPM-3800 PSI. 100 RPM,Torque on=28 K, Torque off 25 K.WOB=8-10K. UP WT=330K. SO WT=142K. ROT WT=190K.ADT=6.8 HRS.AST= 3.48 HRS.ART=3.32HRS.Total Bit HRS=7.4.Total Jar HRS=70.83. Max gas observed= 113 Units. -`l) ECD's-10.45 PPG. 21:00 21:30 0.50 11,488 11,488 INTRM2 DRILL DDRL P TD at 11,488'MD/Take survey on . bottom, PU one single for 90 recip during BU. 21:30 22:45 1.25 11,488 11,390 INTRM2 DRILL CIRC P Circ BU @ 700 GPM-3500 PSI. Torque off 27 K. UP WT=330K.SO WT=142K. ROT WT=190K 22:45 23:00 0.25 11,390 11,390 INTRM2 DRILL CIRC P Flow check @ 11,390. OK 23:00 00:00 1.00 11,390 10,792 INTRM2 DRILL TRIP P POOH on elevators from 11390- 10792 for short trip. PU=340K,SO = 140K on bottom. 03/22/2011 Continue short trip pulling to 10692'MD.Observe well.TIH to TD @ 11488'MD. Circulate pumping a Hi Visc sweep. Observed 100%increase in cuttings when sweep at surface. POOH on elevators observing good displacement. Pump dry job. POOH. Monitor well at shoe and BHA. POOH breakout&lay down BHA. Observed cement packed off on BHA. Pictures taken.Service rig. Change out upper rams to 7 5/8"and test same to 250/3500 PSI. RU to run 7 5/8"casing. 00:00 00:30 0.50 10,792 11,488 INTRM2 DRILL TRIP P Continue POOH for short trip to 10692'MD. Observed well.TIH to TD @ 11488'MD.Observed proper displacement,and good hole conditions. 00:30 04:30 4.00 11,488 11,488 INTRM2 DRILL CIRC P Circulate pumping a Hi Visc sweep at 730 GPM's-3200 PSI. Observed 100%increase in cuttings when sweep back to surface. Reciprocate &rotate drill string. 04:30 04:45 0.25 11,488 11,488 INTRM2 DRILL OWFF P Monitor well-static. 04:45 12:00 7.25 11,488 3,000 INTRM2 DRILL TRIP P POOH on elevators,observing proper displacement,and good hole conditions. Pump dry job. Blow down Top Drive.Continue POOH on elevators to the shoe at max rate of 100'/minute. Pull to 3000'MD. Crew Change 12:00 13:00 1.00 3,000 650 INTRM2 DRILL TRIP P Continue POOH from 3000'to the BHA. Monitor well-static. UP WT= 150K,SO WT= 150K. 13:00 14:30 1.50 650 550 INTRM2 DRILL PULD P Held BOP Drill. PJSM on pulling nuke source form BHA. Breakout& lay down 5" HWDP. Pull source,and lay down 2-flex drill collars. Page 19 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 18:00 3.50 550 0 INTRM2 DRILL PULD P Plug in and down load MWD assembly. Breakout&lay down remaining BHA. Observed heavy cement build up on BHA.Took pictures&post on S Drive. Breakout &inspect bit.Grade bit to 1/3/CT/G/X/1/PN/TD. 18:00 18:30 0.50 0 0 INTRM2 RIGMN7 SVRG P Service rig. Clean&clear rig floor area. 18:30 19:30 1.00 0 0 INTRM2 WHDBO NUND P Make up test jnt. BOLDS and pull wear bushing. Install test plug. 19:30 20:45 1.25 0 0 INTRM2 WHDBO NUND P Held PJSM with crew. Discuss safety&hazard recognition issues. Discuss procedure to open doors and change upper pipe rams. Install 7 5/8"soild body rams. 20:45 22:00 1.25 0 0 INTRM2 WHDBO BOPE P Rig up test equipment.test 7 5/8" upper pipe rams to 250/3500 PSI. Record on chart. Pull and lay down test plug. 22:00 00:00 2.00 0 0 INTRM2 CASING RURD P Held PJSM. Rig up to run 7 5/8" f casing. lay.down short bales. Install ✓ long bales. Make up Franks Fill up tool. Install 350 ton spiders,and elevators. Make up power tongs. Install 7 5/8"tong heads. Rig up scaffolding. Make up safety valve& head pin.Crew Change. 03/23/2011 Continue RU to run 7 5/8"casing. Held PJSM.MAke up Shoe track aasembly, and check floats.Continue RIH with casing instally Hydroform Centralizers on first 48 Jnts as planned. Run casing filling each jnt, and circulating btms up at shoe&4060',7360.When breaking circulation at 8653', observed packoff conditions, with fluid loss.Good movement ob casing string allowed us to pull back to 8050'MD,staging pumps to obtain flow rates of 6 BPM-520 PSI.Good movement on casing string. Obtain full circulation while reciprocate string. Make up a joint of casing,wash down to 8093'MD. UP WT 250K, SO WT-130K. 00:00 01:30 1.50 0 0 INTRM2 CASING RURD P Continue rig up to run 7 5/8"casing. 01:30 02:00 0.50 0 0 INTRM2 CASING SFTY P Held PJSM with crew and casing rep. Discuss safety&hazard recognition issues. Discuss procedure to make up and run 7 5/8" casing. 02:00 07:15 5.25 0 3,600 INTRM2 CASING RNCS P Make up Shoe track assembly with baker-loc connections. Fill pipe& check floats. -Good. Continue RIH with 7 5/8"casing filling each jnt.Avg Make up tq-10-11K ft/lbs. Install Hydroform Centralizers on each jnt 1- 51.Circulate at depths of 2800', while change out bad hose on power tongs. Continue RIH to 3600'MD. 07:15 08:15 1.00 3,600 3,600 INTRM2 CASING CIRC P Circulate bottoms up at the shoe. Pump at 5 BPM-375 PSI. UP WT= 145K, SO WT=124K. Monitor well- static. Page 20 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 12:00 3.75 3,600 6,588 INTRM2 CASING RNCS P Continue RIH with 7 5/8"to 6588' MD. Filling each jnt.Top off every 10 jnts.Avg Make up tq-10-11K ft/lbs. UP WT=205K,SO WT= 124K. Crew Change 12:00 12:30 0.50 6,588 7,360 INTRM2 CASING RNCS P Continue RIH with 7 5/8"to 7360' MD. Filling each jnt.Top off every 10 jnts.Avg Make up tq-10-11K ft/lbs. UP WT=240K, SO WT=140K. 12:30 14:00 1.50 7,360 7,360 INTRM2 CASING CIRC P Break circulation obtaining 5 BPM- 880 PSI.Observed partial loss of returns,slowing rate to 4 BPM-430 PSI. Flow out=12%Reciprocate casing string.Obtain bottoms up. 14:00 15:30 1.50 7,360 8,653 INTRM2 CASING RNCS P Continue RIH with 7 5/8"to 8653' MD. Filling each jnt.Top off every 10 jnts.Avg Make up tq-10-11K ft/lbs. UP WT=270K,SO WT=110K. 15:30 22:00 6.50 8,653 8,050 INTRM2 CASING RNCS T Attempt to establish circulation @ 8653'MD.Stage to 4 BPM, observing packoff conditions with loss of circulation.Work string with pumps at 1.5 BPM. UP WT-350K, SO WT=90K. POOH to 8440'MD laying down casing.Attempt to gain good circulation observing packoff conditions with loss of circulation. Work casing string finally pulling back to 8050'MD,after laying down 2-4 jnts at a time. ✓/ 22:00 23:30 1.50 8,050 8,050 INTRM2 CASING CIRC T At 8050',work casing string staging pumps to 6 BPM-620 PSI with 13% flow.Obtain full circulation plus 1000 STKS with good reciprocation and flow.Mud wt=9.7 PPG,YP=20, and Viscosity-54. 23:30 00:00 0.50 8,050 8,093 INTRM2 CASING RNCS T Make up another jnt, and wash down to 8093'MD. Pumps at 4 BPM-450 PSI. UP WT=260K,SO WT= 100K.Crew Change 03/24/2011 Continue RIH with 7 5/8 casing washing down to 8224'MD. Change out failed cup on Franks Fill up Tool. Continue work casing to 8215'MD.Attempt to make hole,with no success. Packoff and stacking out issues. Rig up and POOH laying down casing.Observed proepr displacement,with no gas issues.Observed no damage on Casing shoe when out of hole. 00:00 01:00 1.00 8,093 8,224 INTRM2 CASING RNCS T Continue make up and run casing to 8224'washing down each jnt.. Good circulation at 4-5 BPM. Observed failed cup on Frank Fill Up tool. 01:00 01:30 0.50 8,224 8,224 INTRM2 CASING RNCS T Reciprocate casing string with free movement,while change out cup on Franks Fill up tool. Page 21 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 09:00 7.50 8,224 8,180 INTRM2',CASING RNCS T Continue work casing string observing now taking 30-40K at 8224'MD.Work to establish good circulation again at 6 BPM-520 PSI. Continue working casing,tagging up, and packing off. Pull a joint at a time to get back to 8090'MD.We had obtained good circulation with rates at 7 BPM to increase AV's. UP WT =245K,SO WT=130K.We could not get any further in the hole. Decision to POOH. 09:00 10:15 1.25 8,180 8,180 INTRM2 CASING RURD T Rig down long bales,and 3560 ton elevators. Make up short bales and YC elevators. Rig down Franks fill up tool. Prep to POOH lay down casing. 10:15 12:00 1.75 8,180 7,700 INTRM2 CASING PULL T Monitor well-static. Pump dry job. li POOH breakout&lay down 7 5/8" casing to 7700'MD.Obtain T&D parameters every 5 jnts.Observed proper displacement.Crew Change ��E 12:00 00:00 12.00 7,700 120 INTRM2 CASING PULL T Continue POOH, breakout&lay dawn 7 5/8"casing.Obtain T&D parameters every 5 jnts.Observed � proper displacement.Crew Change vv 03/25/2011 Continue POOH&lay down shoe track.Oberved no damage to the shoe. Change out upper rams to VBR's and test same to 250/3500 PSI.Make up cleanout BHA.Slip&Cut Drilling Line.Service rig.Trip in hole circulate bottoms up at shoe.Observed increased amount of cuttings across shakers.Circulate to clean up. Trip in hole filling every 20 stands.Take weight at 8050'DPM.Work drill string to clean up from 8050'-8179' MD.Observed hole packing off,taking fluid at times,then giving it back. Pump rates from 400-700 GPM's. 00:00 01:30 1.50 120 0 INTRM2 CASING PULL T Continue POOH breakout&lay down shoe track assembly. Obtain hot work permit,to heat up baker loc connections. Observed no damage to shoe. 01:30 03:00 1.50 0 0 INTRM2 CASING PULD T Clean&clear rig floor area. Send tools out. 03:00 05:30 2.50 0 0 INTRM2 WHDBO NUND T Open the doors,and change out upper rams to VBR's. Install test plug. Rig up and test rams to 250/ 3500 PSI. Record on chart. Rig down test equipment. Install W.B. RILDS. 05:30 09:00 3.50 0 0 INTRM2 DRILL PULD T Held PJSM with crew. Pull tools to rig floor. Make up 9 7/8"Clean out BHA. Make up first jnt of HWDP. Establish circulation and perform pulse test with pumps at 430 GPM's -750 PSI. Blow down top srive& lines. 09:00 11:00 2.00 0 0 INTRM2 RIGMNT SLPC T Held PJSM.Slip&cut 120'of drilling line. 11:00 12:00 1.00 0 0 INTRM2 DRILL PULD T Continue RIH picking up 5"HWDP. Crew Change 12:00 13:00 1.00 0 0 INTRM2 RIGMNT SVRG T Service rig. Grease up Dra works Top Drive Upper&lower IBOP, and crown section. Page 22 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 13:45 0.75 0 596 INTRM2 DRILL PULD T Contiue RIH picking up remaining 5" HWDP&jars.Total BHA length= 596.60' 13:45 15:30 1.75 596 3,726 INTRM2 DRILL TRIP T Trip in hole form 596'-3726'MD. Shoe @ 3663'MD. UP WT= 160K, SO WT-110K. 15:30 17:00 1.50 3,726 3,726 INTRM2 DRILL CIRC T Circulate @ 800 GPM's-2800 PSI. 100 RPM's-8K TQ. Observed increased cuttings at shakers on bottoms up.Circulate until clean @ 9300 Stks. 17:00 17:30 0.50 3,726 3,726 INTRM2 RIGMNT SVRG T Blow down Top Drive&Lines. Inspect saver sub,and dies. 17:30 20:30 3.00 3,726 8,050 INTRM2 DRILL TRIP T Trip in hole form 3726'-8050'MD. Fill drill string every 20 stands. Observed proper displacement. Tagged up and set down 35K. UP WT=220K, SO WT=130K. 20:30 00:00 3.50 8,050 8,179 INTRM2 DRILL WASH T Wash&ream hole with pumps at 400-700 GPM's.Observed hole packing off with increased torque up to 22K ft/lbs. and taking fluid.Withs pumps off,fluid coming back. No gas issues.Wash with 100 RPMs as per DD.Wash hole to 8179'MD. Pump a 40 BBL Hi-Vis sweep.TQ off bottom 15-17K.crew Change 03/26/2011 Continue wash&ream hole from 8179'. Pull back 2 stands obtaining good circulation again after fighting packoff&fluid loss issues.Obtain good parameters and full pump rates of 650 GPM's.Continue wash& ream in hole working through packoff issues,and fluid loss at times from 7987'-8838'MD.TIH on elevators from 8838'-11053'MD,working through a few tight spots.Wash&ream from 11053'-11488'TD. Stage pumps to obtain 700 GPM's 3700 PSI with noticeable increase in torque. Circulate bottoms up. 00:00 02:00 2.00 8,179 7,987 INTRM2 DRILL WASH T Continue wash&ream hole from 8179'. Pull back 2 stands obtaining good circulation again after fighting packoff&fluid loss issues. 02:00 12:00 10.00 7,987 8,650 INTRM2 DRILL WASH T Continue washing&reaming from 7987'-8650'at rates of 400-700 GPM's,with 100 RPM's. Clean each stand up to obtain better torque values,and free movement without any losses and packing off issues. Observed fluid loss issues,with hole giving it back after packoff cleaned up.Torque issues considerably higher than when we originally drilled this section. Crew Change Page 23 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 16:30 4.50 8,650 8,838 INTRM2 DRILL WASH T Continue washing&reaming from 8650'-8838'MD at rates of 400- 700 GPM's,with 100 RPM's.Clean each stand up to obtain better torque values, and free movement without any losses and packing off issues. Observed fluid loss issues,with hole giving it back after packoff cleaned up.Torque issues considerably higher than when we originally drilled this section. Now at 23-27K 16:30 19:30 3.00 8,838 11,053 INTRM2 DRILL WASH T Trip in hole on elevators form 8838'- 11053'MD.Wash through a few tight spots at 10200'-10263'MD. UP WT =300K,SO WT=130K. 19:30 23:00 3.50 11,053 11,488 INTRM2 DRILL WASH T Continue wash&ream hole from 11053'-11488' MD.Work through tight spots with parameters as above. On bottom UP WT=320K, SO WT=135K.Stage pumps to 705 GPM's-3700 PSI. 23:00 00:00 1.00 11,488 11,488 INTRM2 DRILL CIRC T Circulate&condition mud at 705 GPM's-3700 PSI. Pump Hi visc sweep. Begin increasing mud weight to 9.9 PPG. Reciprocate&rotate drill)string with torques at 25-27K ft/lbs @ 100 RPM's. Obtained SPR's.Observed up to 1150 units of gas. Crew Change 03/27/2011 Continue circulate bottoms up x 3. Increase mud wt to 9.9 PPG. POOH on elevators from 11488'-9100'. Tight Spot. BROOH to 9100'-7890'MD. CBU staging pumps to 700 GPM's.TIH on eleavtors form 7890'- 11488'MD. No issues. CBU x 3,observing increase in cuttings on shakers. Monitor well. POOH on eleavtors. SPot sack black casing running pil from 8900'-7900'MD. Pump a dry job. POOH on eleavtors,working through tight spot @ 6900'.Observed proper displacement and good hole conditions. 00:00 01:45 1.75 11,488 11,488 INTRM2 DRILL CIRC T Continue circulate bottoms x 3. Increase mud weight to 9.9 PPG. Circulation rate=705 GPM's-3700 PSI. Reciprocate&rotate drill string. Monitor well-static. 01:45 05:00 3.25 11,488 9,100 INTRM2 DRILL TRIP T POOH on elevators from 11488'- 9100'. Observed proper displacement.Work through overpull sections to clean up same.Observed 20-50K overpull. String speed rates =5-30 ft/minute. Obtain Torque& drag parameters every 5 stands.At 9100,started pulling tight. 05:00 10:15 5.25 9,100 7,890 INTRM2 DRILL REAM T BROOH from 9100'-7890'MD. 10:15 12:00 1.75 7,890 7,890 INTRM2 DRILL CIRC T Circulate while reciprocate&rotate drill string. Stage pumps up to 700 GPM's-3150 PSI.Observed increase in cuttings at shakers when sweep back. UP WT=225K,SO WT=130K. ROT WT= 165K. 100 RPM's-15-18K TQ.Crew Change Page 24 of 39 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 12:00 14:30 2.50 7,890 11,488 INTRM2 DRILL TRIP T Trip in hole on elevators from 7890'- 11488'TD.Observed proper displacement and good hole conditions. 14:30 16:00 1.50 11,488 11,488 INTRM2 DRILL CIRC T Circulate pumping a Hi Vis nut plug sweep at 700 GPM's. reciprocate& rotate drill string.CBU x 3. 16:00 16:30 0.50 11,488 11,488 INTRM2 DRILL OWFF T Monitor well-static, no breathing issues. Breakout&lay down single DP jnt. 16:30 19:30 3.00 11,488 8,900 INTRM2 DRILL TRIP T POOH on elevators from 11488'- 8900'MD,with string speed of 40- 50 ft/minute.Observed goog hole conditions. 19:30 20:00 0.50 8,900 8,900 INTRM2 DRILL CIRC T Pump to spot 95 BBLS of 12 PPB Sack Black casing running pill. Pump dry job. Mud wt=9.9 PPG. Reciprocate drill string while pumping. 20:00 00:00 4.00 8,900 5,210 INTRM2 DRILL TRIP T POOH on elevators from 8900'- 5210' MD,with string speed of 40- 50 ft/minute.Observed good hole conditions.Work through tight spot at 6900 with 50K overpull, until cleaned up.Crew Change 03/28/2011 Continue POOH on elevators from 5210'to the shoe @ 3663'MD.CBU at the shoe. Breakout&lay down BHA. Bit graded to 1/2/CT/G/X/I/PN/TD.Change upper rams to 7 5/8"solid body.Test same to 250 3500 PSI. RU&run casing to 7270'MD with no issues, and proper displacement. 00:00 01:30 1.50 5,210 3,663 INTRM2 DRILL TRIP T Continue POOH on elevators from 5210' to the shoe at 3663'MD,with string speed of 40-50 ft/minute. Obtain T&D parameters every 5 stands. Observed good hole conditions. • 01:30 03:00 1.50 3,663 3,663 INTRM2 DRILL CIRC T Circulate 1 1/2 bottoms up at the shoe. No noticeable increase in cuttings across sahkers. Pump Dry job, blow down Top Drive&lines. 03:00 04:45 1.75 3,663 590 INTRM2 DRILL TRIP T Continue POOH on eleavtors form • the shoe to BHA. 04:45 07:00 2.25 590 0 INTRM2 DRILL PULD T Breakout&lay down BHA. Rack back HWDP&Jars. Bit graded to 1/2/CT/G/X/I/PN/TD. 07:00 07:30 0.50 0 0 INTRM2 DRILL PULD T Clean&clear rig floor area. Send tools out. 07:30 10:00 2.50 0 0 INTRM2 WHDBO BOPE T BOLDS. Pull wear bushing. Install test plug. Remove 3 1/2"x 6"VBR rams. Install 7 5/8"solid body rams. RU&test rams to 250/3500 PSI/ Record on chart. RD test equipment. 10:00 11:00 1.00 0 0 INTRM2 CASING RURD T Rig up to run casing. Remove short bales. Install long bales. Install casing spiders and elevators. Rig up tongs and scaffolding.Make up Franks fill up tool. Page 25 of 39 I Time Logs Date From To Dur S. Depth E. DepthPhase Code Subcode T Comment 11:00 11:30 0.50 0 0 INTRM2 CASING SFTY T Held PJSM with crew&csing rep. Discuss safety&hazard recognition issues. Discuss checklist& procedure to run 7 5/8"casing. 11:30 12:00 0.50 0 120 INTRM2 CASING RNCS T Make up shoetrack assembly with baker loc connections.AVG make up torque= 12K ft/lbs. Fill pipe& check floats.Crew Change 12:00 16:30 4.50 120 3,465 INTRM2 CASING RNCS T Continue RIH with 7 5/8"casing to 3465'MD. UP WT=148K,SO WT= 120K. 16:30 17:30 1.00 3,465 3,465 INTRM2 CASING CIRC T Circulate bottoms up at the shoe. Stage pumps to 6 BPM-410 PSI. Pump 1800 strokes.Chnage out cup on Franks Fill up tool. 17:30 21:00 3.50 3,465 6,025 INTRM2 CASING RNCS T Continue RIH with 7 5/8"casing to 6025'MD. UP WT=200K,SO WT= 130K. Observed good hole conditions and proper displacement. 21:00 22:00 1.00 6,025 6,025 INTRM2 CASING CIRC T Circulate bottoms up staging pumps to 6 BPM-500 PSI. Reciprocate string. 3 BPM=310 PSI 4 BPM=400 PSI 5 BPM=450 PSI Circulated a total of 2800 Strokes. 22:00 00:00 2.00 6,025 7,270 INTRM2 CASING RNCS T Continue RIH with 7 5/8"casing to 7270'MD. UP WT=230K,SO WT= 130K.Observed good hole conditions and proper displacement. NOTE: Washed down 2 jnts from 6851'- 6936'at 3 1/2 BPM-310 PSI.Crew Change 03/29/2011 Continue run in hole with 7 5/8"casing from 7270'-11472'MD. make up landing joint and hanger and land casing.Circulate 100 BBLS. Break down franks Fill up tool. Make up Cement head.Circulate&condition. Mix&pump 148 BBL Gas Blok cement job. Bump plug with CIP @ 13:35 HRS. RD cement equipment. Make up pack off and RIH.Set packoff&test same to 5000 PSI-10 Minutes. RD all cement equipment. RU and pump 300 BBLS down annulus with rig pump to flush. RU Little Red and frezze protect annulus with 150 BBLS of diesel. SIMOPS: Load out excess casing, loasad pipe shed with 4"DP. 00:00 00:45 0.75 7,270 7,920 INTRM2 CASING RNCS T Continue RIH with 7 5/8"casing to 7920'MD. UP WT=238K, SO WT= 130K. Observed good hole conditions and proper displacement. 00:45 01:45 1.00 7,920 7,920 INTRM2 CASING CIRC T Circulate 1500 Strokes to move mud in open hole. Reciprocate string. Obsrevd after 1400 strokes,pipe a little sticky on the down stroke taking up top 25K downweight. Staged pumps to 5 BPM-550 PSI with good flow.Stopped circulating. 01:45 02:45 1.00 7,920 9,084 INTRM2 CASING RNCS T Continue RIH with 7 5/8"casing to 9084'MD. UP WT=260K, SO WT= 128K. Observed good hole conditions and proper displacement. Note: Through trouble area. Page 26 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:45 03:45 1.00 9,084 9,084 INTRM2 CASING CIRC P Circulate 220 BBLS staging pumps to 5 BPM-550 PSI while reciprocate casing string.Observed good flow. No hole issues.Called for Cementers. 03:45 05:00 1.25 9,084 10,280 INTRM2 CASING RNCS P Continue RIH with 7 5/8"casing to 10280'MD. UP WT=300K, SO WT =150K.Observed good hole conditions and proper displacement. 05:00 05:45 0.75 10,280 10,280 INTRM2 CASING CIRC P Circulate 120 BBLS staging pumps to 6 BPM- PSI while reciprocate casing string.Observed good flow. .No hole issues. 05:45 07:00 1.25 10,280 11,472 INTRM2 CASING RNCS P Continue RIH with 7 5/8"casing to 11472"MD. Make up Casing hanger and landing jnt. Circulate with Franks fill up tool to land hanger. UP WT=330K,SO WT= 150K. Observed good hole conditions and proper displacement. 07:00 07:30 0.50 11,472 11,472 INTRM2 CASING CIRC P Continue circulating staging pumps to 4 BPM-520 PSI. Rig down casing running equipment,and tongs. Reciprocate csing string. 07:30 08:15 0.75 11,472 11,472 INTRM2 CASING RURD P et casing hanger,Rig down Franks Fill up tool. Rig up cement head& lines. Secure cement head. NOTE: Plugs loaded previously as per Schlumberger rep. 08:15 10:45 2.50 11,472 11,472 INTRM2 CASING CIRC P Reciprocate casing string while circulate&condition mud for cement job.Stage pumps to 7 BPM-575 PSI.Short stroke casing working to 25 ft increments. UP WT=325K, SO WT=139K. Rig up cementers and water trucks. 10:45 11:15 0.50 11,472 11,472 INTRM2 CEMENT SFTY P Held PJSM with crews and Schlumberger cementers. Discuss safety&hazard recognition issues. Discuss procedure to pump cement job.Assign Spill Champions. Continue reciprocate casing string, with pre-cement mud properties of 9.9 PPG,YP-17 and Funnel Visc of 47. Batch Mix mud push,and prep for job. UP WT=325K, SO WT= 139K. 11:15 12:45 1.50 11,472 11,472 INTRM2 CEMENTPUCM P Turn over to Schlumberger. Pump 10 BBLS of CW100 pressure test lines to 3500 PSI-good test. Mix and .01 pump 40 bbls CW 100 Chem Wash, Pump 40 BBLs of 11.5 PPG Mud push.Turn over to 15.8 PPG (� GasBlok Cement, p.1.25 147 bbls. Dropped top plug and pumped 10 Bbls water. Reciprocate casing string while pumping cement. Page 27 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:45 13:45 1.00 11,472 11,472 INTRM2 CEMEN"DISP P With Rig, Displace with 9.9 Mud pumping 5123 strokes to bump plug with 650 PSI. Pressure to 1150 PSI- hold 5 minutes. Check floats.CIP @ 13:35 HRS Reciprocate casing string until 450 BBLS pumped on the displacement. 13:45 15:15 1.50 0 0 INTRM2 CEMEN"RURD P Blow down cement lines and head. RD cement head. Pull and lay down landing joint. RD 7 5/8"elevators, and long bales. 15:15 17:00 1.75 0 0 INTRM2 WHDBO NUND P Make up running tool on test joint. Set packoff,and RILDS>test packoff as per FMC rep to 5000 PSI-10 minutes,Good test. Remove double annulus valve from lower annulus. Install on upper annulus. Lay down landing joint&running tool. 17:00 19:00 2.00 0 0 INTRM2 DRILL RURD P Clean 7 clear rig floor of all casing running equipment. Install short bales. Pull thread protectors to rig floor. Pick up MWD short tools and put in shed. 19:00 22:30 3.50 0 0 INTRM2 DRILL FRZP P Rig up in cellar on annulus.With rig pump,pressure test lines to 2000 PSI. Break over pressure at 450 PSI, and flush annulus with 300 BBLS of water as planned FCP=600 PSI. Simops:Change out saver sub and bell guide on Top Drive.Pull 33 joints of casing from shed. 22:30 00:00 1.50 0 0 INTRM2 DRILL FRZP P Blow down lines. RU Little red Services. Held PJSM. Pumo 150 BBLS of diesel down annulus @ 2 BPM for freeze protection. ICP= 450 PSI. FCP 870 PSI. Simops:Service rig,Top Drive and crown section. Held PJSM-Laying down DP from derrick.Crew Change 03/30/2011 Lay down 5"DP from Derrick. Slip&Cut 120' Drilling Line. Load Pipe shed with 4"DP. Pick up 4"DP. rack back 90 Jnts. RU&test BOP's.Witness of test waived by AOGCC rep John Crisp. 00:00 09:30 9.50 0 I 0 INTRM2 DRILL PULD P Lay down 5"Drill pipe from derrick. 09:30 10:30 1.00 0 0 INTRM2 DRILL PULD P Pull mouse hole from rotary table. Change out elevators,and prep rig floor for PU 4"DP. 10:30 12:00 1.50 0 0 INTRM2 RIGMNI SLPC P Held PJSM.Slip&cut 120'of drilling line.Crew Change 12:00 15:30 3.50 0 0 INTRM2 DRILL PULD P Load pipe shed with 4"drill pipe. Starp joints. Lay down all 5"handling equipment. Load 4"equipment. Inspect top drive. 15:30 20:30 5.00 0 0 INTRM2 DRILL PULD P Held PJSM. Pick up and RIH with 90 jnts of 4"drill pipe. Rack back 30 stands. Page 28 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 22:00 1.50 0 0 INTRM2 WHDBO RURD P Rig up test equipment to test BOP's. Install test plug. Fill BOP stack with water. Perform Body test to 3500 PSI. 22:00 00:00 2.00 0 0 INTRM2 WHDBO BOPE P Test BOP's.Test annular to 250/ 2500 PSI.Test choke manifold and all valve to 250/3500 PSI.Test Upper&lower IBOP, NCR's and manual valves.Test Rig floor safety valves,all to 2150/3500 PSI. Record on chart.Calibrate&test all gas alarms.Witness of test waived by AOGCC rep John Crisp. 03/31/2011 Continue test BOP's..Witness of test waived by AOGCC rep John Crisp. Install WB. RILDS. MU BHA#6,6 3/4"drilling assembly.TIH picking up singles of 4"drill pipe from shed. 00:00 05:00 5.00 0 0 INTRM2 WHDBO BOPE P Continue test BOP's.Witness of test waived by AOGCC rep John Crisp. Perform Koomey test. First 200 PSI in 28 secs,with full 3000 PSi at 195 secs. 5 Nitrogen bottles with an avg of 2350 PSI. 16 Bottles-1050 PSI each. 05:00 05:30 0.50 0 0 INTRM2 WHDBO OTHR P Install wear bushing. RILDS. 05:30 06:00 0.50 0 0 INTRM2 WHDBOOTHR P Blow down all lines,choke manifold, and valaves. 06:00 06:30 0.50 0 0 INTRM2 DRILL PULD P Clean&clear rig floor area. Pull tools to rig floor. 06:30 08:00 1.50 0 0 INTRM2 DRILL PULD P Held PJSM. Mqake up BHA 36.6 3/4"drilling assembly with a Reed- Hycalog SX14H+GJNU bit.TFA= .460 sq. in.Make up a 5"Sperrylobe 6/7-6.0 stg Motor.Continue make up MWD assembly. 08:00 09:30 1.50 0 0 INTRM2 RIGMN1 SVRG P Service rig.Top Drive&draw works. (/ Pull Wear Bushing. Inspect same, and Install WB. 09:30 10:45 1.25 0 0 INTRM2 DRILL PULD P Continue make up MWD assembly. 10:45 12:00 1.25 0 0 INTRM2 DRILL PULD P Plug in and Upload MWD assembly. Crew Change 12:00 12:30 0.50 0 0 INTRM2 DRILL PULD P Continue Upload MWD assembly. 12:30 13:30 1.00 0 0 INTRM2 DRILL PULD P Perform Shallow pulse test with pumps at 200 GPM's-950 PSI. Good test. 13:30 14:00 0.50 0 0 INTRM2 DRILL SFTY P Held PJSM with crew&Sperry reps. Discuss safety&hazard recognition issues. Discuss procedure to load nuke sources in BHA. Install safe area signs. 14:00 14:30 0.50 0 0 INTRM2 DRILL PULD P Load Nuke sources as per MWD reps. Page 29 of 39 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 14:30 16:00 1.50 0 589 INTRM2 DRILL PULD P Make up remaining BHA picking up flex drill collars, HWDP,and jars, and commander valve. Install corrosion ring in last collar under circulation sub.Total BHA length= 589.01' 16:00 00:00 8.00 589 6,560 INTRM2 DRILL TRIP P Trip in hole picking up 4"drill pipe singles from pipe shed. Fill every 20 stands.trip to 6560'MD.Crew Change 04/01/2011 Continue Trip in hole with 4"drill pipe singles from shed with BHA#6 to 11203'MD.Wash down to 11377'. Fill every 25 stands. CBU. Perform casing test to 4000 PSI-30 minutes. Drill out shoe track&20'of new hole to 11508'MD. Displace wIl with 9.8 ppg Klayguard.CBU. Perform FIT test to 12.0 PPG EMW. Drill 6 3/4"hole from 11508'-11850'mD.ND=5436'.ADT=4 34 HRS.AST=1.74 HRS.Total Bit&Jar HRS=4.34. ECD = 11.23 PPG. MAX Gas observed 125 Units. 00:00 07:00 7.00 6,560 11,379 INTRM2 DRILL TRIP P Continue tripping in hole with BHA #6,picking up drill pipe singles from shed,from 6560'-11379'. Fill string every 25 stands,and obtain T&D parameters every 10 stands.Wash down from 11300'-11379'. 07:00 08:30 1.50 11,379 11,379 INTRM2 DRILL CIRC P Circulate bottoms up with pumps at 300 GPM's-3450 PSI. UP WT= 225K, SOWT=110K. 08:30 09:30 1.00 11,379 11,379 INTRM2 DRILL RURD P Blow down Top Drive&lines. Rig up equipment for casing test. 09:30 11:00 1.50 11,379 11,379 INTRM2 DRILL PRTS P Perform casing test to 4000 PSI.30 G$� minutes. Record on chart.Good test. i� Bleed pressure&rig down test �•✓ equipment. 11:00 12:00 1.00 11,379 11,393 INTRM2 CEMENT DRLG P Drill Shoe Track from 11379'to 11393'MD. Pumps at 211 GPM- 1750 PSI. RPM's-70.Torque on= 13 K,Torque off 13 K.WOB=5K. UPWT=225K. SOWT= 110K. ROT WT=148K. Crew Change 12:00 13:30 1.50 11,393 11,473 INTRM2 CEMENT DRLG P Continue Drill Shoe Track from 11393'to 11473'MD. Pumps at 250 GPM-1850 PSI. RPM's-70.Torque on=13 K,Torque off 13 K.WOB= 5K. UP WT=225K.SO WT= 110K. ROT WT= 148K. 13:30 14:30 1.00 11,473 11,488 INTRM2 CEMENT DRLG P Continue Drill open hole cement from 11473'to 11488'MD. Pumps at 250 GPM-1850 PSI. RPM's-70. Torque on= 13 K,Torque off 13 K. WOB=5K. UP WT=225K.SO WT = 110K. ROT WT=148K. Displace well with 9.8 PPG Klayguard. Observed torque dropped to 6K after displacement. 14:30 15:00 0.50 11,488 11,508 INTRM2 DRILL DDRL P Continue Drill open hole 11488'- 11508'MD.ND=5370'. MD. Pumps at 250 GPM- 1850 PSI. RPM's-70.Torque on=6 K,Torque off 6 K.WOB=5K. UP WT=225K. SO WT=110K. ROT WT= 148K. Page 30 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment • 15:00 16:00 1.00 11,508 11,508 INTRM2 DRILL FIT P Rig up test equipment,and perform FIT test to 12 PPG. record on chart. 16:00 00:00 8.00 11,508 11,850 PROD1 DRILL DDRL P Directional Drill 6 3/4"Hole from 11508'-11850'MD.TVD=5436'. Pumps at 305 GPM-2850 PSI. Torque on=6 K,Torque off 6 K. WOB=5K. UPWT=190K.SOWT = 127K. ROT WT= 157K.ADT= 4.34 HRS.AST=1.74 HRS.ART= 2.60 HRS.Total Bit HRS=4.34. Total Jar HRS=4.34. Max gas observed=125 Units. ECD's-11.23 PPG. Note:OA pressure=400 PSI. Crew Change 04/02/2011 Continue Directional drill 6 3/4"hole from 11850'-12932'MD.TVD=5440'.ADT=14.88 HRS.AST=5.62 HRS.Total Bit&Jar HRS= 18.54. ECD=11.72 PPG.MAX Gas observed 673 Units.Observed drilling through a Fault @ 12786'MD as per Geo.Observed fluid loss of up to 25 BPH,slowing to 15 BPH. Double backream at times for contolling ECD's. 00:00 06:00 6.00 11,850 12,193 PROD1 DRILL DDRL P Directional Drill 6 3/4"Hole from 11850'-12193'MD.TVD=5441'. Pumps at 305 GPM-2970 PSI. Torque on= 10 K,Torque off 9 K. WOB=5K. UP WT=192K.SO WT = 127K. ROT WT=152K.ADT= 4.12 HRS.AST=1.17 HRS.ART= 2.95 HRS.Total Bit HRS=8.46. Total Jar HRS=8.46. Max gas observed=300 Units. ECD's-11.25 PPG. 06:00 12:00 6.00 12,193 12,433 PROD1 DRILL DDRL P Directional Drill 6 3/4"Hole from 12193'-12433'MD.TVD=5441'. Pumps at 350 GPM-3550 PSI. Torque on= 10 K,Torque off 9 K. WOB=5K. UP WT=190K.SO WT = 127K. ROT WT=152K.ADT= 4.12 HRS.AST=1.45 HRS.ART= 1.99 HRS.Total Bit HRS= 11.90. Total Jar HRS=11.90. Max gas observed=673 Units. ECD's-11.62 PPG. Crew Change 12:00 18:00 6.00 12,433 12,717 PROD1 DRILL DDRL P Directional Drill 6 3/4"Hole from 12433'-12717'MD.ND=5446'. Pumps at 345 GPM-3800 PSI. Torque on=9 K,Torque off 8 K. WOB=5K. UP WT= 190K.SO WT = 130K. ROT WT=155K.ADT= 3.43 HRS.AST= 1.92 HRS.ART= 1.51 HRS.Total Bit HRS= 15.33. Total Jar HRS= 15.33. Max gas observed=515 Units. ECD's-11.75 PPG. Page 31 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 12,717 12,932 PROD1 DRILL DDRL P Directional Drill 6 3/4"Hole from 12717'-12932'MD.ND=5440'. Pumps at 350 GPM-3680 PSI. Torque on=9 K,Torque off 8 K. WOB=5K. UP WT=190K.SO WT = 127K. ROT WT=155K.ADT= 3.21 HRS.AST=1.08 HRS.ART= 2.13 HRS.Total Bit HRS=18.54. Total Jar HRS= 18.54.Max gas observed=402 Units. ECD's-11.72 PPG. Observed drilling through a fault @ 12786'MD as epr GEO. Observed fluid losses of up to 25 BPH,slowing to 15 BPH.Trickle in LCM as per Mud Engineer. Crew Change 04/03/2011 Continue Directional drill 6 3/4"hole from 12932'-13157'MD.ND=5446'.Observed lost circulation at this depth,at any rate pumped. Fluid static in riser,falling slowly. Mix&pump 75 BBLS- 20 PPB LCM pill @ 2 BPM-550 PSI.Adding water to drop wt to 9.8 PPG. POOH, pumping out @ 1.5 BPM to shoe. Monitor well on TT while build and load new mud.No losses while pump across top of hole. RIH to 11455'MD,pump ball to open Well Commander valve.Observed valve shift open.Continue TIH back to 13096'MD. Drop ball to shift Commander valve to full closed position to BHA. Pump initial 75 BBLS of 70 PPB LCM pill.Monitor well- observe well flowing. Monitor well to calculate returns at 18-24 BPH, not slowing down. Finish pumping 25 BBLS of pill out of drill string.Continue monitor well,with returns the same. Free movement in drill string.Observed DP building pressure slowly,through Commander valve to 160 PSI.Shut well in on choke manifold to monitor for gas influx. SIDPP=170,SICP=20 PSI. No increase in pressure after 30 minutes. Total losses for the day=511 BBLS. 00:00 04:30 4.50 12,932 13,157 PROD1 DRILL DDRL P Directional Drill 6 3/4"Hole from 12932'-13157'MD.ND=5446'. Pumps at 345 GPM-3750 PSI. Torque on= 10 K,Torque off 8 K. WOB=5K. UP WT=188K.SO WT =127K. ROT WT=155K.ADT= 3.00 HRS.AST=1.19 HRS.ART= 1.81 HRS.Total Bit HRS=21.54. Total Jar HRS=21.54.Max gas observed=568 Units. ECD's-11.74 PPG.Observed fluid losses with no returns at any rate pumped. Initial fluid loss-50 BBLSFIuid static in riser,falling slowly.Monitor well for losses. No returns at any rate. 04:30 07:00 2.50 13,157 13,157 PROD1 DRILL CIRC T Mix 75 BBL pill with 20 PPB LCM @ 2 BPM-550 PSI. Reciprocate drill string,with good hole conditions-no pump.Ordered more fluid,421 BBLS on location. Prep to POOH to shoe. 07:00 10:30 3.50 13,157 11,391 PROD1 DRILL CIRC T POOH slow,from 13157'-11391', inside shoe. Pumping down Drill string at 1.5 BPM-460 PSI. Spot LCM pill while POOH. Fluid loss on POOH=70 BBLS. 10:30 12:00 1.50 11,391 11,391 PROD1 DRILL OWFF T Monitor well on the trip tank.Staic losses=0 BBLS. Build and load new mud.Total losses for 12 HR tour =249 BBLS.Crew Change Page 32 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:00 13:30 1.50 11,391 11,391 PROD1 DRILL CIRC T Continue circulate across top of hole monitoring well with static losses at 0 BBLS. Continue build and load new mud. SIMOPS: Load,drift&strap 3 1/2"tbg in shed. 13:30 15:30 2.00 11,391 11,455 PROD1 DRILL CIRC T RIH to 11455'MD. Pumps at.5 BPM -280 PSI. Increase pumps to 3 BPM -780 PSI obtaining parameters. Drop ball to close Well Commander valve. Observe valve shift with ball on seat at 635 stks,and stage pumps to shift valve at 2450 PSI. Flow path now only 10%through BHA. 15:30 17:00 1.50 11,455 11,455 PROD1 DRILL CIRC T Continue circulate across top of hole monitoring well with static losses at 0 BBLS.Continue build and load new mud.SIMOPS: Load,drift&strap 3 1/2"tbg in shed. 17:00 18:30 1.50 11,455 13,098 PROD1 DRILL TRIP T TIH on elevators from 11455'-13098' with n issues. UP WT=185K,SO WT= 125K. 18:30 20:30 2.00 13,098 13,098 PROD1 DRILL CIRC T Drop closing ball for Well Commandervalve to shift valve to close off BHA 100%. Pump at 2.5 BPM-470 PSI.Observed increase in pressure to 530 PSI when ball landed. Little or no Flow returns while pumping. Only a trickle into the flow nipple.Chase ball with 20 BBLS clean mud to aid ball in landing ahead of LCM pill. Pump 75 BBLS of 70 PPB LCM pill down DP into annulus @ 2.5 BPM-530 SPI. 20:30 21:30 1.00 13,098 13,098 PROD1 DRILL OWFF T Monitor well as now we have flow in the riser averageing returns of 18-24 BBLS/HR, not slowing down. Suspect breathing issues. 21:30 23:15 1.75 13,098 13,098 PROD1 DRILL OWFF T Pump 25 BBLS of remaining LCM pill out of drill string. Monitor well with flow now @ 3-4 BBLS every 5 minutes. No signs of slowing. Attempt to circulate, pumping open hole volume 1 1/2 times,pumping away 66 BBLS with only 8 BBLS back. Shut down pumps-monitoring well with drill pipe pressure building as well to 180 PSI while monitoring well. Free movement in drill string when moving. Page 33 of 39 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 23:15 00:00 0.75 13,098 13,098 PROD1 DRILL OWFF T Shut in well closing annular. Record on choke, SIDPP @ 190 PSI.SICP -20 PSI.Monitor well for gas influx. No increase in pressure in first 30 minutes of monitoring well.Crew Change Fluid losses for 12 HR tour=262 BBLS Total for day=511 BBLS. 04/04/2011 Continue monitor well on the choke with SIDPP-170 PSI,SICP-20 PSI. No increase in presuure after 45 minutes. Bleed drill pipe pressure to zero,with no annulus pressure.Open up annular. Monitor well with flow steady at 18 BPH with no perssure build.Well breathing. POOH pumping at 2 BPM to keep hole full-5 stands. Monitor well. Lay down BHA. 00:00 01:00 1.00 13,098 13,098 PROD1 DRILL OWFF T Continue monitor well on closed choke.SIDPP-170 PSI.SICP-20 PSI. No increase in pressure after 30 Minutes. Bleed DP pressure.Open annular. Monitor flow with on annulus 18 BPH steady. No pressure build on annulus.Observed pressure on drill ✓ pipe building if closed in. Bleed off same. No indication of gas influx. 01:00 02:00 1.00 13,098 13,098 PROD1 DRILL OWFF T Monitor well: 10 Minutes-4 BBL gain 10 Minutes-3 BBL Gain 10 Minutes-3 BBL Gain 10 Minutes-3 BBL Gain 10 Minutes-3 BBL Gain 10 Minutes-4 BBL Gain-Bled off DP pressure that built. Decision to POOH into shoe,above LCM pill to circulate and monitor well. 02:00 03:00 1.00 13,098 12,622 PROD1 DRILL TRIP T POOH puming at 2 BPM to keep hole full.5 stands with good movement on DP no issues. First 5 stands-5.5 BBLS loss. 03:00 03:15 0.25 12,622 12,622 PROD1 DRILL OWFF T Monitor Well at 12,622-ft. Well continues to breath. 03:15 05:00 1.75 12,622 11,451 PROD1 DRILL TRIP T Continue to POOH with Pumps at 2.0 bpm/460 psi from 12,622-ft up to 11,451-ft. PUW=175K. SOW= 123K. 05:00 06:00 1.00 11,451 11,451 PROD1 DRILL OWFF P Monitor Well at 11,451-ft. Well slightly breathing. 06:00 09:15 3.25 11,451 11,451 PROD1 DRILL OWFF P Pump 3.0 bpm/560 psi.total strokes =315. Observe Well while breathing back Mud. Pumped 32 bbls and the Well breathed back 27.5 bbls.of Mud. 09:15 12:00 2.75 11,451 10,063 PROD1 DRILL TRIP P PJSM. POOH with Pumps at 1.5 bpm/460 psi. From 11,451-ft up to 10,063-ft. PUW=178K. SOW= 123K. Page 34 of 39 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 12:00 19:00 7.00 10,063 4,947 IPROD1 DRILL TRIP P Continue to pump out of hole at 1.5 bpm/310 psi. 0% F/O. From 10,063-ft up to 4,947-ft-ft. PUW= 140K. SOW= 115K. 19:00 20:30 1.50 4,947 2,957 PROD1 DRILL TRIP P POOH from 4,947-ft to 2,957-ft. PUW= 110K. SOW= 105K. 20:30 21:00 0.50 2,957 2,957 PROD1 DRILL CIRC P At 2,957-ft pumped a 10 bbl dry-job (11.0 lb/gal, 55 vis). 21:00 22:00 1.00 2,957 589 PROD1 DRILL TRIP P POOH from 2,957-ft to 589-ft. BHA at surface. PUW=90K. SOW= 95K. 22:00 22:30 0.50 589 589 PROD1 DRILL OWFF P Monitor Well,static. Hold PJSM to lay down BHA. 22:30 23:30 1.00 589 PROD1 DRILL PULD P Lay down BHA. (8 Jts HWDP,Jars, 3 Jts HWDP,Crossover,Circulation Sub, 3 Flex Collars). 23:30 00:00 0.50 PROD1 DRILL PULD P PJSM. Un-load MWD as per Sperry Sun Rep. 04/05/2011 Finish Lay down BHA. Perform final Lower Completion inspection. Pick-up Lower completion and run as designed. 00:00 03:00 3.00 0 0 PROD1 DRILL PULD P Finish Lay down BHA. Clear and clean floor. 03:00 04:00 1.00 0 0 COMPZ CASING RURD P PJSM. Rig up handling equipment to run the 3 1/2"Lower Completion. 04:00 04:30 0.50 0 0 COMPZ CASING SFTY P PJSM. discuss the hazards in picking up and running the 3 1/2" completion. Review running order of jewelry. 04:30 09:30 5.00 0 1,850 COMPZ CASING RUNL P Single in with the 3 1/2"Completion as designed. pp Weight=90K. Down Weight=90K. 09:30 11:00 1.50 1,850 1,850 COMPZ CASING PULD P Pick-up and make-up Baker Flex Lock Liner Hanger and ZXP Liner Top Packer per Baker Service Rep. Mix and let"Pal Mix"set for 30/min. 11:00 11:30 0.50 1,850 1,951 COMPZ CASING RUNL P Run one stand from Derrick. Pump 2 bbls at 210 psi through Liner to ensure Liner is clear. Blow down top Drive. 11:30 12:00 0.50 1,951 2,330 COMPZ CASING RUNL P Trip in with 4"Drill Pipe from the Derrick to 2,330-ft. Up Weight= 92K. Down Weight=90K. (Crew Change). 12:00 21:30 9.50 2,330 13,157 COMPZ CASING RUNL P Continue to trip in with 4"Drill Pipe from the Derrick,filling every 25 stands. Tag bottom 5-ft deep. Put Float Shoe at 13,157-ft. Up Weight =178K. Down Weight= 118K. Page 35 of 39 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 21:30 00:00 2.50 13,157 13,157 COMPZICASING PACK IP Drop ball and pump down at 3.0 bpm/700 psi. Slow rate down to 1.0 bpm/380 psi. Ball on seat. Pressure up to 2,500 psi. Set 35K down on Liner Hanger. Bring pressure up to 3,500 psi. Pick up string weight, plus 5-ft. Not set. Slack off 35K and pressure up to 2,500 psi. Hold 2 minutes. Increase pressure to 4,000 psi.. Pick up string weight. Hanger is set. Pressure up on Annulus to 1,000 psi to confirm. 04/06/2011 Test Liner Hanger. POOH and single down Drill Pipe. Run the Upper 3 1/2"GL Completion section. 00:00 01:30 1.50 11,307 11,307 COMPZ CASING PRTS P Pressure test Liner Hanger at 1,000 psi x 15 minutes. Record on chart. Good. Rig down lines. Blow down Top Drive. 01:30 12:00 10.50 11,307 2,557 COMPZ DRILL PULD P PJSM. POOH. Single down 9 Jts of 4"Drill Pipe. Monitor Well static. Pump"Dry-Job". Continue to single down Drill Pipe to 2,557-ft. 12:00 14:00 2.00 2,557 0 COMPZ DRILL PULD P Continue to single down 4"Drill Pipe in the Pipe Shed. Lay down Baker Running tool. 14:00 15:00 1.00 0 0 COMPZ DRILL PULD P Make-up Running tool. Drain BOP Stack. Pull Wear Bushing. Function BOP Stack Rams and HCR Valve. 15:00 15:30 0.50 0 0 COMPZ DRILL PULD P Lay down Running Tool. Clear Floor. 15:30 17:30 2.00 0 0 COMPZ RPCOM RURD P Rig-up to handle 3 1/2"Tubing. Rig-up Chemical Line Spooler. Bring Chemical Line Clamps to Floor. Hang and double secure Sheave for Chemical Line in Derrick. Rig-up tools for installing Chemical Line Clamps. 17:30 18:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM. Discussed the hazards and the running order for the 3 1/2"GL Completion section. 18:00 20:30 2.50 0 748 COMPZ RPCOM PULD P Pick-up Seal Assembly. Continue to pick-up 3 1/2"Tubing. Pick-up the Camco 2.750" "D"Nipple. Verify that the RHC Plug is installed. Pick-up one Jt of 3 1/2"Tubing. Pick-up the Sliding Sleeve w/2.813" DS profile. (SS in the closed position). Pick-up the Camco GLM w/Chemical Injection Mandrel. Page 36 of 39 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 20:30 23:00 2.50 748 780 COMPZ RPCOM PRTS T Purge Chemical Injection Line. Make-up Line to the Chemical Injection Mandrel. Attempted to get a good test against the Mandrel at 1,000 psi. However, pressure keeps falling off. Disconnect Line. Continue to purge Chemical Line on Spool. 23:00 00:00 1.00 780 780 COMPZ RPCOM PRTS P Pressure test chemical Line on Spool to 5,000 psi.x 10 minutes. Good. Make-up Chemical Line to Injection Mandrel. Tested Line against the Mandrel at 1,000 psi x 15 minutes. Good. 04/07/2011 Continue running the Upper 3 1/2"GL Completion section. Displace Well over to clean Brine. Space-out and land Tubing Hanger. 00:00 12:30 12.50 780 COMPZ RPCOM RCST P Continue to single in with the 3 1/2" GL Completion to Jt#246, installing the Chemical Line and Clamps as designed. Up Weight= 120K. Down Weight=105K. 12:30 13:30 1.00 COMPZ RPCOM RCST T Repair fitting on air tool for clamping the Chemical Line Clamps. 13:30 18:30 5.00 COMPZ RPCOM RCST P Continue to single in with the 3 1/2" GL completion from Jt#246 to Jt# 354. 18:30 20:30 2.00 11,375 11,375 COMPZ RPCOM RCST P Make-up Crossover to the top of Jt #355. Bring Pump on line at 2.0 bpm/560 psi. Entered Seal Bore Extension and observed a pressure increase to 650 psi. Shut down Pumps. continue in with remainder of Jt#355. Plck-up Jt#356 and "No-Go"on Locator at 11,375-ft tbgmd. 20:30 00:00 3.50 11,375 11,350 COMPZ RPCOM CIRC P Pick-up out of the Seal Bore Extension to 11,350-ft. Begin with the Displacement to Brine program. Bring Pump on line at 3.0 bpm/580 psi. Pump 50 bbls 9.8 lb/gal Brine w/Safe-Surf-W. Continue with 50 bbl 9.8 lb/gal Viscosified Brine. Continue with 195 bbls of 9.8 lb/gal Brine. Start the 9.8 lb/gal with Corrosion Inhibitor added Stage. Good returns. Increase pump to rate to 4.0 bpm/640 psi. 04/08/2011 Complete Clean Brine displacement. Space Out. Make-up Tubing Hanger. Land Tubing Hanger. RILDS. Test tubing. Test IA. Shear SOV. ND BOP Stack. NU Tree. Test Tree. Freeze Protect Well. 00:00 01:45 1.75 11,300 11,300 COMPZ RPCOM CIRC P Finish with the 9.8 lb/gal with Corrosion Inhibitor stage. Displace with 65 bbls of 9.8 lb/gal Brine. Total Fluid Loss during the displacement= 26 bbls. Page 37 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:45 04:45 3.00 11,300 11,330 COMPZ RPCOM PULD P PJSM. Lay down Tubing Joints 356 through 352. Pick-up 3 1/2" Space-out Pup Joints. Make-up the 3 1/2"x 4 1/2"Crossover. Pick up 2 Joints of 4 1/2"Tubing. Make-up the Tubing Hanger. Install and test Chemical Line Connection at 5,000 psi x 5 minutes. Good. (Note: 3 1/2"Collar Clamps used=338 ea. 3 1/2"Half Clamps used= 10 ea. 4 1/2"Half Clamps used=2 ea. Stainless Steel Band used=1 ea. 04:45 05:30 0.75 11,330 11,367 COMPZ RPCOM THGR P Land Tubing Hanger. RILDS. Drain Stack. 05:30 06:15 0.75 11,367 11,367 COMPZ DRILL PRTS P Rig up Line to pressure test the annulus. Test the 7 5/8"x 3 1/2" Annulus at 1,000 psi x 10 minutes. Good test. 06:15 10:00 3.75 11,367 11,367 COMPZ DRILL PRTS P PJSM. Drop Ball/Rod. Rig up to test the Tubing. Tested Tubing to 3,500 psi x 30 minutes. Good. Bleed press off to 2,300 psi and block in. Pressure test the 7 5/8"x 3 1/2"Annulus to 3,500 psi x 30 minutes. Good. Bleed pressure from the Tubing side to shear open the DCK-2 Valve. Good. Blow down lines and rig down test equipment. 10:00 10:30 0.50 11,367 11,367 COMPZ DRILL PULD P Back-out Landing Joint and lay down same. Install TWCV. 10:30 12:30 2.00 11,367 11,367 COMPZ DRILL RURD P Rig down tubing running equipment. Rig down Chemical Line Spooling Unit. clear and clean floor. 12:30 15:30 3.00 11,367 11,367 COMPZ WHDBO NUND P Nipple down BOP Stack. 15:30 21:00 5.50 11,367 11,367 COMPZ WHDBO NUND P Run Chemical Line through Well Head port. Nipple up Adaptor flange. Nipple up Tree. 21:00 22:00 1.00 11,367 11,367 COMPZ WHDBO PRTS P Test Tubing Hanger Void at 250/5,000 psi x 10 minutes. Good. 22:00 22:30 0.50 11,367 11,367 COMPZ WHDBO RURD P Rig up to test Production Tree. 22:30 00:00 1.50 11,367 11,367 COMPZ WHDBO PRTS T Tested Production Tree at 250 psi x 5 minutes. Good. Attempted to test Tree at 5,000 psi. However have flange leaks on the Wing Valve and the Swab Valve. 04/09/2011 • Finish Freeze Protect Well. Set BPV. Secure Cellar. Release Rig. Move off of 2L-306 Well Slot. 00:00 02:30 2.50 11,367 11,367 COMPZ WHDBO PRTS T Continue to have flange leaks. Re-tighten every nut on every flange. Finally got a high pressure test at 5,000 psi x 10 minutes. Good. No visible leaks. Page 38 of 39 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 02:30 10:00 7.50 11,367 11,367 COMPZ DRILL RURD P PJSM. Pull TWCV. Rig up Lil'Red and Freeze Protect with 135 bbls of Diesel pumped down the 7 5/8"x 3 1/2"Annulus. Rig down Lil'Red. Hook up lines and allow the diesel to u-tube into the 3 1/2"Tubing. Install Mouse Hole. Lay down the remaining 23 stands of 4"Drill Pipe from the Derrick while the Diesel freeze protect balances out. Rig down lines. Install BPV. 10:00 11:00 1.00 11,367 11,367 COMPZ MOVE RURD P Secure Cellar. Prep to RDMO. Rig released. Page 39 of 39 WELL LOG TRANSMITTAL To: State of Alaska April 12, 2011 Alaska Oil and Gas Conservation Commission Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501-3539 RE: LWD Formation Evaluation Logs: 2L-306+PB1 AK-MW-0007742775 2L-306+PB1 50-103-20630-00: -70 2"x 5" MD TRIPLE COMBO Logs: 1 Color Log for each wellbore 2"x 5"TVD TRIPLE COMBO Logs: 1 Color Log for each wellbore 2"x 5" MD BAT SONIC Logs: 1 Color Log for each wellbore 2" x 5"TVD BAT SONIC Logs: 1 Color Log for each wellbore Digital Log Images&LDWG-formatted LIS Data w/verification listing; 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 31O -- (6a 00/6 a Bryan.Burinda@halliburton.com 714' E3 jr $ Date: Signed: MATTE -. SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 C. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Tarn Oil Pool, 2L-306 ConocoPhillips Alaska, Inc. Permit No: 210-182 Surface Location: 2993' FNL, 2971' FEL, SEC. 13, T1ON, R7E, UM Bottomhole Location: 201' FNL, 2142' FEL, SEC. 24, T1ON, R7E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name KRU 2L-306 plus PH and API number 50-103-20630-70 from records, data and logs acquired for well KRU 2L-306. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, , Daniel T. Seamount, Jr. Chair r DATED this-day of December, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 1 6 2010 PERMIT TO DRILL 20 AAC 25.005 ,..._:;;., W.‘ �. `.J5 ir,Jrts. Commission la.Type of Work: lb.Proposed Well Class: Development-Oil ❑✓ • Service-Winj ❑ Single Zone ❑✓ . 1c.Specify'ifgsrprgp sed for: Drill Re-drill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas Cl Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket ❑Single Well 11.Well Name and Number: Ple+- ConocoPhillips Alaska, Inc. Bond No. 59-52-180 ' 2L-306 " -t- Mo%.. 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 14062' TVD: 5431' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 154'FNL,588'FEL,Sec.22,T1ON, R7E,UM ' ADL 380052,380051 ` Tarn Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2993'FNL,2971'FEL,Sec. 13,T1ON, R7E, UM 4600,4599 2/4/2011 Total Depth: 9.Acres in Property: 14.Distance to 201'FNL,2142'FEL,Sec.24,T1ON,R7E,UM 2560 l Nearest Property: 2993' Ci2Ile•I?_ 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL et 15.Distance to Nearest Well Open Surface:x- 461063 y- 5927692 - Zone- 4 GL Elevation above MSL: 114 feet to Same Pool: 2L-319,1412' ' 16.Deviated wells: Kickoff depth: 400 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 93° deg Downhole:2408 psig Surface: 1835 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 164.8# B-35 Welded 120' Surf Surf 120' 120' Driven 13.5" 10.75" 45.5# L-80 BTC 3065' Surf Surf 3741' 2400' 650 sx ASLite,360 sx Class G 9.875" 7.625" 29.7# L-80 BTCM , 9435' Surf Surf 11424' 5319' 740 sx GasBLOK Class G ‘.75" 3.S 1.3# /--a -5.-/ 2 49s /127S/ SZ S'2! I'i 64.7. 54451' leria.al/ides La/1c.,.r11 firs 7.24._ /2-Z -ie 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program E 20 MC 25.050 requirements Li 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Steve Shultz @ 263-4297 Printed Name C. Alvord Title Alaska Drilling Manager -5644f 41 Signature / > D'i i Phon 265-6120 Date CL-1(040(o Commission Use Only Permit to Drill API Number: Permit Approval See cover letter 2- so- /)• /� `��(" /�� (�? Date: for other requirements Number ,l L 1 I 7 /L 2ie---r-(r J�. L 4:91 i O Conditions of a proval: If box its checked,well may not be used to explore for,test,or produce coalbe ane,gas hydrates,or gas contained in shales: .1( 3560 p se. Ail"1"11- P 1 S f_ Samples req'd: Yes CI .No Mud log req'd: Yes ❑ No L ' Other: 2.560 is r.; /lr►"1""- (CS f( H2, measures: Yes d No ❑ Directional svy req'd: Yes No ❑ APPROVED BY THE COMMISSION 2 �� DATE: / ,COMMISSIONER Form 10-401 (Revised 7/2009) This permit is vali f)' r r4n4nR0144 ,- `,a •f approval(20 AAC 25.005(g)) Submit in Duplicate Prf Post Office Box 100360 iPS Anchorage,Alaska 99510-0360 Chip Alvord Phone(907)265-6120 Email: Chip.Alvord@conocophillips.com December 13 ,2010 RECEIVED Alaska Oil and Gas Conservation Commission DEC 1 6 2010 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Alaska Oil &Gas Cons.Commission RE: Application for Permit to Drill 2L-306 Anchorage Dear Commissioners, ConocoPhillips Alaska,Inc hereby applies for a Permit to Drill for the onshore production well 2L-306. The well will be drilled and completed using Doyon Rig#15. The planned spud date for 2L-306 is Feb 4th, 2011. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information,please contact Steve Shultz 263-4297. Sincerely, A _& Chip Alvord Drilling Manager ®,7, CJ 00 N O O M V in in M co N CO I ICI-.1) M V V V V V V V V V NI- LO LO LO LO LO LO to LO LO LO LO LO 111 r M O coV 0 )) CO M CM0 N r W CMO DI N (O 00 CO in CO 0 CO LO CX) 0 r N N N N CO CO CO M V 1- 111 O co _c M ❑ M N N N N N Q N a) N N a) a) p a N a) N N Q) -t O_ O m co co m .-- ` I 0ul0n !nN LO LO LO LO 3 3 3 3 M M M LO LO LO LO❑ ❑ ❑ ❑O O O O m 07 a) 6)F- Q) co F- Q) O I- co coI- O) O I- O d. Lo C CIC C = c c = c c = C c = c I IE J 15 --Lo J Q 15 -115 15 -116 O F- = cU) = OU) m OU) n = U) m = U) 7 -p o c = I- H =N I- I- = F- I- = I- F- - I- I- - F- a) O 0 J F- F- ,' F- F- � F- F- I- I- � F- F- � H �4,\ -' .(c) cn = = v= = v= = M = _ A_ _ (?= a) M 111 I x C - J J J J J J J J J _J J a) (I) LO U) (n a) U) U) a) CO CO a) CO co a) co co a) co c E.,-_ X M O - Li] e-t imet � e-t _ _)- E O_ _ U U U U U r 2X ka _ a o a _ a @ a @ O co 0 X c, 1._ UMaM UMaM UNaM pMaM UMaM ,_ ~ O 0 E t ID 00 O) 2Oj CT L00 O 20 O L00 N O LoO NO J = M Cr) OLo _ _-Li -- 3 --Li -- 3 _-Li -- 3 _- -- 3 -- _- 3 _-u) I (� U) LL LL(Din N - N (n N - N (n N - N U) CV - N U) N - N U) N - U) -J L @fpr \ `- iO `- \ `- in `- \ `- in `- \ `- inr \ � inr \ N 3 CO 3 < - (0 (0 L O N M V LO CO I� co_ O ,N CO t* LO CO t--- MOO N M V LO a) CD J N N N N N N N NMM MMMM M CO M M V V V V 'V 'c7 O- c /\ U �-' N 111 co ^I O O N N V M N -o Fr`' M 0 N co V N LNO LNO a. r N� . co b O b M cr) co O CO 0 N `- N CD EI co LU V N-0 LOOr r r r _= C N 041 CO ,,,._ 3 r LL L a U 4 a) (CNEJ N N_oo w m _gg M > 0 N N M cD (/ �� a) a)0 a)� o)❑ c a) a.)› m a).o 3 a o) i- O a)b f° -a = o o__ O (� o (� gp 0 0 0 o C .o o in o o ._ m N o ❑ .N v cn 2 w Z 0 0 w 2 w 2 w (n a w csi w L o - in v O QUN LLJ I- WnCODCO WY W Y W = � W Nw � �X r / Ln ❑ � c xw wYwY o o . � - Q uJ > c // 0 N LOM - c O w o)- o o -- o o4tEltEau - u •zu - Eco m / y_ p V a a) CO, a) o * mu EM EM EM @M OOMY CpM _ MM a) O c O � � .- a0i 0 = NF- •rn (j •rn (j •rn 13 0 C.) nrn Loc� rn � rnrn co co O M Cvj U Q.- O O r CD _ _ _-_ _ _ N N N N �N�` _CO p _-___--Q 0 _ U p� Q V -- N N N N N N r r, ,_ r VN - E N N N N o J N = MF- O \ \ rrrrrrAMAM 5r \ Orrrr CD > C O a) F- V V MMMMMM U) MM U MM MMCI) > J I.,... I N ———— O r N CO V LO CO f-- 00 6) O r r N M V LO (O f� COO r r r r r r r r r r N N ` ..::'.. co U C7 ' I co> 05 I0 ORIGINAL o0 F- . ration for Permit to Drill,Well 2L-306 Saved: 13-Dec-10 Permit It — Tarn Well 2L-306 (Stella) rot Application for Permit to Drill Document 'lr4 MpxItnizg WRIT VuIug Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(f) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005(c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 AAC 25.005(c)(5) 4 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 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 5 Requirements of 20 AAC 25.005 (c)(9) 5 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 2L-306 APD Page 1 of 7 (11. R M A L Printed:13-Dec-10 ration for Permit to Drill,Well 2L-306 Saved: 13-Dec-10 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 6 Requirements of 20 AAC 25.005(c)(14) 6 15. Attachments 6 Attachment 1 Directional Plan 6 Attachment 2 Drilling Hazards Summary 6 Attachment 3 Well Schematic 6 Attachment 4 Cement Summary 6 1. Well Name Requirements of 20 AAC 25.005(f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b).For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 2L-306. ✓ 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application fora Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of:the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; This well is planned for a pilot hole for determining the top of the sand and will be plugged back and sidetrack to a new bottom hole location for setting the intermediate casing. Location at Surface 154'FNL, 588'FEL, Sec 22, T1ON,R7E,UM NAD 1927 RKB Elevation 154.8'AMSL Northings: 5,927,692 Eastings: 461,063 Pad Elevation 114.8'AMSL Location at Top of(Bermuda)on Pilot 2,304'FNL,2981' FEL, Sec 13,T10N,R7E,UM Hole Nad 1927 Measured Depth,RKB: 11,410' Northings: 5,930,111 Eastings: 469,238 Total Vertical Depth,RKB: 5,320' Total Vertical Depth, SS: 5,165' Location at Total Depth on 3445'FNL, 2,824'FEL, Sec 13,T1ON,R7E,UM Pilot Hole Nad 1927 Measured Depth,RKB: 11,963' Northings: 5,929,642 Eastings: 469,393 Total Vertical Depth,RKB: 5,563' Total Vertical Depth,SS: 5,408' Location at Top of Productive Interval 2,993'FNL,2971'FEL, Sec 13,T1ON,R7E,UM (Bermuda) Heel Nad 1927 Measured Depth,RKB: 11,424' Northings: 5,930,098 Eastings: 469,246 Total Vertical Depth, RKB: 5,319' Total Vertical Depth, SS: 5,164' Location at Total Depth 201'FNL, 2,142'FEL, Sec 24,T1ON,R7E,UM (Toe) Nad 1927 Measured Depth,RKB: 14,062' Northings: 5,927,603 Eastings: 470,068 Total Vertical Depth,RKB: 5,431' Total Vertical Depth, SS: 5,276' 2L-306 APD Page 2 of 7 0RI G I A ' r L Printed:13-Dec-10 .ation for Permit to Drill,Well 2L-306 Saved: 13-Dec-10 and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except fOr an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPS)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 15. 4. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the jbllowing items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The bottom hole pressures from the 2L-312's offset wells are: Well Type SBHP MW Distance Direction Shut in Time 2L-310 Producer 2,296 psi 8.5ppg ' 1688' SW 550 hrs 2L-311 Injector 1,639 psi 6.1 ppg 1887' S 4368 hrs 2L-319 Producer 1,631 psi 6.0 ppg 1413' E 72 hrs 2L-304 Producer 1090 psi 4.0 ppg 3128' S 96 hrs Given the above range of pressures,2L-306 has a worst case scenario for the BHP range of 2,200—2,400 psi at the reservoir depth of 5,200'TVD. This gives a mud weight range of 8.1 ppg—8.9 ppg..,- Equivalent pg.iEquivalent Mud Weight @ TD=2,400/(5,200*.052)=8.9 ppg=0.463 psi/ft The maximum potential surface pressure(MPSP)while drilling 2L-306 is calculated using the higher end of the predicted reservoir pressure 2,400 psi,a 0.11 psi/ft gas gradient,and a Bermuda sand top TVD of 5,200' (estimated top of reservoir in 2L-306). MPSP =(5,200 ft TVD)*(0.463-0.11 psi/ft) = 1,835 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. ' and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; 2L-306 APD Page 3 of 7 RIG IPrinted:13-Dec-10 ration for Permit to Drill,Well 2L-306 Saved: 13-Dec-10 Please see Attachment 2-Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except Jor an item already on file with the commission and identi/ied in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030(/); Drill out surface casing shoe and perform LOT test or FIT in accordance with the Kuparuk LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre-perforated liner,or screen to be installed; Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (Ib/ft) Grade Conn. (ft) (ft) (ft) Cement Program Driven 16 24 164.8 B-35 Welded 120' Surf 120'/120' Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 BTC 3,065' Surf 3,741'/2,400' 650 sx ASLite Lead 10.7 ppg, ✓ 360 sx Tail Slurry 12.0 ppg Cement Top planned @ 8,800'MD/ 7-5/8 9-7/8 29.7 L-80 BTCM 9,435' Surf 11,424'/5,319' 4,250'TVD. Cemented w/ 740 sx GasBLOK Class"G"15.8 ppg 3 1/2 6 3/4 9.3 L-80 SLHT 2,787 11,27575,280' 14,06275431' 6. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 15. 7. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application fin.a Permit to Drill must be accompanied by each of the fallowing items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 MC 25.033; Drilling will be done using mud systems having the following properties: Surface WBM 110'—3,741 ' Density(ppg) 8.8—9.5 Funnel Viscosity(seconds) 75—250 Yield Point(cP) 60—80 pH 9.0—9.5 API Filtrate(cc) NC—8.0 Chlorides(mg/1) <1000 Intermediate/Production OBM 3,741'—14,062' Density(ppg) 9.1 — 10.0 / Yield Point(cP) 18—28 HTHP Fluid Loss(ml/30min) <5 OWR 75:25—80:20 2L-306 APD Page 4 of 7 ET) i r� t Printed:13-Dec-10 g The proposed drilling program is listed below. Please refer to Attachment 3:Well Schematic. 1. MIRU Doyon 15 on 2L-306 Conductor. 2. NU and function test diverter system and prepare spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. 4. Spud and directionally drill 13-1/2"hole to the 10-3/4"surface casing point(3,741'MD/2,400' TVD)according to the directional plan. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 5. Run and cement 10-3/4"45.5#L-80 BTC casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. Perform top job if required to bring cement to surface. 6. Nipple down diverter and install wellhead and test to 5000 psi. Nipple up BOPE and test to 3,500 psi. Notify state of BOP test. Record results. 7. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results. 8. Drill out cement and 20'minimum to 50'maximum of new hole.Perform LOT. 9. Directionally drill pilot hole to+/-I 1963'MD/5563'TVD, Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. POOH 10. RIH with openended drill pipe and spot a cement plug from 1 1963'MD back to+/-1 1300'MD, POOH 11. RIH with a 9 7/8"bit and directional BHA and sidetrack well at 1 I,300'MD/5287' TVD 12. Directionally drill 9-7/8"hole to 11,424'MD/5,319'TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 13. POOH and LD 5"drill pipe. Run 7-5/8"29.7#L-80 BTCM casing to 11,424'MD/5,319' TVD and cement in place. 14. PU horizontal directional BHA with 4"drill pipe,RIH,drillout shoe,and drill 6'/4"hole to 14,062'MD/5431'TVD. 15. POOH,LD 4"drill pipe 16. Run 3-1/2"completion tubing with packer and set at+/- 14,062'MD/5,431'TVD. 17. LD DP and associated equipment. ND BOP and rig up tree. Test tree and freeze protect annulus. Rig down and move out rig. �cwJGt-" I Z-z-p • o /Z.Zv.,c t ation for Permit to Drill,Well 2L-306 Saved: 13-Dec-10 Electrical Stability(my) >600 Diagram of Doyon 15 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 8. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths ofpredicted abnormally geo-pressured strata as required by 20 AAC 25.033(/); N/A-Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already(milk with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); N/A-Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application Pr a Permit to Drill must be accompanied by each of the following items,except Jim an item already on file with the commission and identified in the application: (I1)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. 11. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application jar a Permit to Drill must be accompanied by each of the following items,except for an item already on/lie with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025(Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska,Inc.is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to Attachment 3:Well Schematic. 1. MIRU Doyon 15 on 2L-306 Conductor. 2. NU and function test diverter system and prepare spud mud. ✓ y s ', • 3. Place warning signs on location indicating the rig has diverter equipment rigged up. (L,Zp(a 4. Spud and directionally drill 13-1/2"hole to the 10-3/4" surface casing pointe , 'TVD - dL � 2,444..d )o according to the directional plan. Run MWD/LWD logging tools in drill string as required for directional, monitoring and formation data gathering. 5. Run and cement 10-3/4"45.5#L-80 BTC casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. Perform top job if required to bring cement to surface. 6. Nipple down diverter and install wellhead and test to 5000 psi. Nipple up BOPE and test to 3,500 psi. Notify state of BOP test. Record results. 2L-306 APD Page 5 of 7 Printed:13-Dec-10 ation for Permit to Drill,Well 2L-306 Saved: 13-Dec-10 7. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results. 8. Drill out cement and 20'minimum to 50'maximum of new hole.Perform LOT. 9. Directionally drill 9-7/8"hole to 11,424'MD/5,319'TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. Icy 10. POOH and LD 5"drill pipe. Run 7-5/8"29.7#L-80 BTCM casing to 11,424' MD/5,319'TVD and cement. 11. PU horizontal directional BHA with 4"drill pipe,RIH,drillout shoe,and drill 6 3A"hole to 14,062'MD/5431'TVD. 12. POOH,LD 4"drill pipe ,rs � t 13. Run 3-1/2"completion tubing wit ',Jur er an sea 2'MD/5,431'TVD. 14. LD DP and associated e ui /2---2-0•46 15. ND BOP and rig up tree. Test tree and freeze protect annulus. Rig down and move out rig. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II - disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska does intend to request authorization for the use of this well for annular disposal operations at a later date provided the well meets the regulatory requirements. 14. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary 2L-306 APD Page 6 of 7 "� G 1 t Printed:13-Dec-10 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-306 (Stella) 2L-306 PB1 Plan: 2L-306 PB1 (wp02) §rq Standard Proposal Report a 08 December, 2010 HALLIBURTON Sperry Drilling Services ORIGINAL II I I I II I I I 1 - II I I I I - o n II I I I I —o ti c.. c E No x _ II I I I I _ n 0 0 E a`) e. v_ m u--..-o'cv II I I I W I •,P CO .�m a m m °J°^'° 51,°2-..... c v� II I I I E. 4 E Eo Eoon mCO '- zoo Z-,NM 11 I I I W I -- o 3„�� WQ lid U000Ui211U Nva n Ne+i v�N II I I I p 1 - m 00 d =oO)0.-nn,-.-0) `'' Np'p, N ODM 11 I I I O tNOnaa�00n N II I W I I ~ I- acV.-cGNM� 9 QnvMc )C�Om cn QN0 MJ. 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Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-306(Stella) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-306(Stella) Survey Calculation Method: Minimum Curvature Wellbore: 2L-306 PB1 Design: 2L-306 PB1 (wp02) Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2L Pad Site Position: Northing: 5,927,695.13 ft Latitude: 70°12'48.272 N From: Map Easting: 461,077.91 ft Longitude: 150°18'50.048 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -0.30° Well Plan:2L-306(Stella) Well Position +N/-S 0.00 ft Northing: 5,927,691.60 ft Latitude: 70°12'48.237 N +EI-W 0.00 ft Easting: 461,063.16 ft Longitude: 150°18'50.476 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 114.80ft Wellbore 2L-306 PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2009 3/1/2011 21.03 80.71 57,659 Design 2L-306 PB1(wp02) Audit Notes: Version: Phase: PLAN Tie On Depth: 40.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 40.00 0.00 0.00 161.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +El-W Rate Rate Rate Tool Face (ft) (0) (0) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (0) 40.00 0.00 0.00 40.00 -114.80 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 145.20 0.00 0.00 0.00 0.00 0.00 0.00 642.20 10.27 20.00 640.37 485.57 28.73 10.46 3.00 3.00 0.00 20.00 1,368.24 37.44 50.88 1,300.00 1,145.20 233.15 208.06 4.00 3.74 4.25 40.00 1,468.24 37.44 50.88 1,379.40 1,224.60 271.51 255.22 0.00 0.00 0.00 0.00 2,289.87 68.55 64.64 1,869.34 1,714.54 601.93 809.79 4.00 3.79 1.67 24.08 9,044.60 68.55 64.64 4,339.70 4,184.90 3,294.27 6,490.91 0.00 0.00 0.00 0.00 11,288.55 72.78 161.37 5,283.72 5,128.92 2,571.83 8,125.86 4.00 0.19 4.31 108.45 11,388.55 72.78 161.37 5,313.33 5,158.53 2,481.32 8,156.38 0.00 0.00 0.00 0.00 11,813.01 60.04 161.37 5,482.85 5,328.05 2,113.48 8,280.41 3.00 -3.00 0.00 180.00 11,963.01 55.54 161.37 5,562.78 5,407.98 1,993.25 8,320.96 3.00 -3.00 0.00 180.00 12/8/2010 10:10:03AM Page 2 COMPASS 2003.16 Build 69 Halliburton -Sperry FIALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-306(Stella) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-306(Stella) Survey Calculation Method: Minimum Curvature Wellbore: 2L-306 PB1 Design: 2L-306 PB1 (wp02) � .u. Planned Survey is,:o. 4 ea l-4517-: 4:'<`„.'. , `° .i-lf "�ti ' , -1:440,` , 3' ,' `z- ,4-B:', 4 -' Measured Vertical Map .tt.. Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-IN Northing 4, Easting DLS Vert Section (ft) (') (°) (ft) ft (ft) (ft) (ft) ti.: (ft) -114.80 40.00 0.00 0.00 40.00 -114.80 0.00 0.00 5,927,691.60 461,063.16 0.00 0.00 SHL:154'FNL,588'FEL-Sec22-T10N-R07E 100.00 0.00 0.00 100.00 -54.80 0.00 0.00 5,927,691.60 461,063.16 0.00 0.00 200.00 0.00 0.00 200.00 45.20 0.00 0.00 5,927,691.60 461,063.16 0.00 0.00 300.00 0.00 0.00 300.00 145.20 0.00 0.00 5,927,691.60 461,063.16 0.00 0.00 400.00 3.00 20.00 399.95 245.15 2.46 0.90 5,927,694.05 461,064.07 3.00 -2.03 500.00 6.00 20.00 499.63 344.83 9.83 3.58 5,927,701.41 461,066.79 3.00 -8.13 600.00 9.00 20.00 598.77 443.97 22.10 8.04 5,927,713.65 461,071.31 3.00 -18.27 642.20 10.27 20.00 640.37 485.57 28.73 10.46 5,927,720.27 461,073.76 3.00 -23.76 700.00 12.13 27.09 697.07 542.27 38.98 14.98 5,927,730.49 461,078.34 4.00 -31.98 800.00 15.63 35.21 794.15 639.35 59.35 27.54 5,927,750.80 461,091.00 4.00 -47.15 900.00 19.32 40.35 889.52 734.72 82.97 46.03 5,927,774.33 461,109.61 4.00 -63.47 972.25 22.06 43.01 957.10 802.30 102.01 63.02 5,927,793.27 461,126.70 4.00 -75.93 Permafrost??? 1,000.00 23.12 43.87 982.72 827.92 109.75 70.35 5,927,800.97 461,134.07 4.00 -80.86 1,100.00 26.97 46.45 1,073.31 918.51 139.53 100.40 5,927,830.60 461,164.27 4.00 -99.24 1,200.00 30.85 48.42 1,160.83 1,006.03 172.19 136.03 5,927,863.07 461,200.06 4.00 -118.52 1,300.00 34.76 49.98 1,244.87 1,090.07 207.55 177.06 5,927,898.22 461,241.27 4.00 -138.60 1,368.24 37.44 50.88 1,300.00 1,145.20 233.15 208.06 5,927,923.65 461,272.39 4.00 -152.72 1,400.00 37.44 50.88 1,325.22 1,170.42 245.34 223.04 5,927,935.76 461,287.44 0.00 -159.36 1,468.24 37.44 50.88 1,379.40 1,224.60 271.51 255.22 5,927,961.76 461,319.75 0.00 -173.62 1,500.00 38.60 51.71 1,404.42 1,249.62 283.74 270.49 5,927,973.91 461,335.08 4.00 -180.22 1,600.00 42.30 54.07 1,480.51 1,325.71 322.83 322.25 5,928,012.73 461,387.03 4.00 -200.33 1,700.00 46.04 56.12 1,552.23 1,397.43 362.65 379.40 5,928,052.25 461,444.38 4.00 -219.37 1,800.00 49.81 57.92 1,619.24 1,464.44 403.01 441.66 5,928,092.28 461,506.85 4.00 -237.26 1,900.00 53.60 59.54 1,681.20 1,526.40 443.71 508.74 5,928,132.63 461,574.13 4.00 -253.90 2,000.00 57.41 61.00 1,737.83 1,583.03 484.55 580.31 5,928,173.10 461,645.90 4.00 -269.22 2,100.00 61.24 62.34 1,788.83 1,634.03 525.34 656.01 5,928,213.50 461,721.80 4.00 -283.14 2,200.00 65.09 63.59 1,833.96 1,679.16 565.88 735.48 5,928,253.62 461,801.47 4.00 -295.60 2,289.87 68.55 64.64 1,869.34 1,714.54 601.93 809.79 5,928,289.28 461,875.97 4.00 -305.49 2,300.00 68.55 64.64 1,873.04 1,718.24 605.97 818.32 5,928,293.28 461,884.51 0.00 -306.53 2,400.00 68.55 64.64 1,909.61 1,754.81 645.82 902.42 5,928,332.70 461,968.81 0.00 -316.84 2,500.00 68.55 64.64 1,946.19 1,791.39 685.68 986.53 5,928,372.12 462,053.11 0.00 -327.14 2,600.00 68.55 64.64 1,982.76 1,827.96 725.54 1,070.63 5,928,411.54 462,137.41 0.00 -337.45 2,700.00 68.55 64.64 2,019.33 1,864.53 765.40 1,154.74 5,928,450.96 462,221.72 0.00 -347.75 2,800.00 68.55 64.64 2,055.90 1,901.10 805.26 1,238.85 5,928,490.38 462,306.02 0.00 -358.06 2,900.00 68.55 64.64 2,092.48 1,937.68 845.12 1,322.95 5,928,529.80 462,390.32 0.00 -368.36 3,000.00 68.55 64.64 2,129.05 1,974.25 884.98 1,407.06 5,928,569.22 462,474.62 0.00 -378.67 3,100.00 68.55 64.64 2,165.62 2,010.82 924.83 1,491.16 5,928,608.64 462,558.92 0.00 -388.97 3,200.00 68.55 64.64 2,202.19 2,047.39 964.69 1,575.27 5,928,648.06 462,643.23 0.00 -399.28 3,300.00 68.55 64.64 2,238.77 2,083.97 1,004.55 1,659.37 5,928,687.48 462,727.53 0.00 -409.58 3,400.00 68.55 64.64 2,275.34 2,120.54 1,044.41 1,743.48 5,928,726.90 462,811.83 0.00 -419.89 3,500.00 68.55 64.64 2,311.91 2,157.11 1,084.27 1,827.58 5,928,766.32 462,896.13 0.00 -430.19 3,600.00 68.55 64.64 2,348.48 2,193.68 1,124.13 1,911.69 5,928,805.74 462,980.43 0.00 -440.50 3,700.00 68.55 64.64 2,385.05 2,230.25 1,163.99 1,995.80 5,928,845.16 463,064.73 0.00 -450.80 12/8/2010 10:10:03AM Page 3 COMPASS 2003.16 Build 69 -' b 4 4 1 1 E: a ' Halliburton -Sperry I-IALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-306(Stella) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-306(Stella) Survey Calculation Method: Minimum Curvature Wellbore: 2L-306 PB1 Design: 2L-306 PB1 (wp02) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (0) (0) (ft) ft (ft) (ft) (ft) (ft) 2,245.20 3,740.87 68.55 64.64 2,400.00 2,245.20 1,180.27 2,030.17 5,928,861.27 463,099.18 0.00 -455.01 Surf Csg @ 3741'MD,2400'TVD:1026'FSL,1444'FWL-Sec14-T10N-R07E-10 3/4" 3,800.00 68.55 64.64 2,421.63 2,266.83 1,203.84 2,079.90 5,928,884.58 463,149.04 0.00 -461.11 3,900.00 68.55 64.64 2,458.20 2,303.40 1,243.70 2,164.01 5,928,924.00 463,233.34 0.00 -471.41 4,000.00 68.55 64.64 2,494.77 2,339.97 1,283.56 2,248.11 5,928,963.42 463,317.64 0.00 -481.72 4,041.09 68.55 64.64 2,509.80 2,355.00 1,299.94 2,282.67 5,928,979.62 463,352.28 0.00 -485.95 C-80 4,100.00 68.55 64.64 2,531.34 2,376.54 1,323.42 2,332.22 5,929,002.84 463,401.94 0.00 -492.02 4,136.79 68.55 64.64 2,544.80 2,390.00 1,338.09 2,363.16 5,929,017.35 463,432.96 0.00 -495.81 Campanian 4,200.00 68.55 64.64 2,567.92 2,413.12 1,363.28 2,416.32 5,929,042.27 463,486.24 0.00 -502.33 4,300.00 68.55 64.64 2,604.49 2,449.69 1,403.14 2,500.43 5,929,081.69 463,570.54 0.00 -512.63 4,400.00 68.55 64.64 2,641.06 2,486.26 1,443.00 2,584.54 5,929,121.11 463,654.85 0.00 -522.94 4,500.00 68.55 64.64 2,677.63 2,522.83 1,482.85 2,668.64 5,929,160.53 463,739.15 0.00 -533.24 4,600.00 68.55 64.64 2,714.21 2,559.41 1,522.71 2,752.75 5,929,199.95 463,823.45 0.00 -543.55 4,700.00 68.55 64.64 2,750.78 2,595.98 1,562.57 2,836.85 5,929,239.37 463,907.75 0.00 -553.85 4,800.00 68.55 64.64 2,787.35 2,632.55 1,602.43 2,920.96 5,929,278.79 463,992.05 0.00 -564.16 4,900.00 68.55 64.64 2,823.92 2,669.12 1,642.29 3,005.06 5,929,318.21 464,076.36 0.00 -574.46 5,000.00 68.55 64.64 2,860.49 2,705.69 1,682.15 3,089.17 5,929,357.63 464,160.66 0.00 -584.77 5,100.00 68.55 64.64 2,897.07 2,742.27 1,722.01 3,173.27 5,929,397.05 464,244.96 0.00 -595.07 5,200.00 68.55 64.64 2,933.64 2,778.84 1,761.86 3,257.38 5,929,436.47 464,329.26 0.00 -605.38 5,300.00 68.55 64.64 2,970.21 2,815.41 1,801.72 3,341.49 5,929,475.89 464,413.56 0.00 -615.68 5,400.00 68.55 64.64 3,006.78 2,851.98 1,841.58 3,425.59 5,929,515.31 464,497.86 0.00 -625.99 5,500.00 68.55 64.64 3,043.36 2,888.56 1,881.44 3,509.70 5,929,554.73 464,582.17 0.00 -636.29 5,600.00 68.55 64.64 3,079.93 2,925.13 1,921.30 3,593.80 5,929,594.15 464,666.47 0.00 -646.60 5,700.00 68.55 64.64 3,116.50 2,961.70 1,961.16 3,677.91 5,929,633.57 464,750.77 0.00 -656.90 5,800.00 68.55 64.64 3,153.07 2,998.27 2,001.02 3,762.01 5,929,672.99 464,835.07 0.00 -667.21 5,900.00 68.55 64.64 3,189.65 3,034.85 2,040.87 3,846.12 5,929,712.41 464,919.37 0.00 -677.51 6,000.00 68.55 64.64 3,226.22 3,071.42 2,080.73 3,930.23 5,929,751.83 465,003.68 0.00 -687.82 6,100.00 68.55 64.64 3,262.79 3,107.99 2,120.59 4,014.33 5,929,791.25 465,087.98 0.00 -698.12 6,200.00 68.55 64.64 3,299.36 3,144.56 2,160.45 4,098.44 5,929,830.67 465,172.28 0.00 -708.43 6,300.00 68.55 64.64 3,335.94 3,181.14 2,200.31 4,182.54 5,929,870.09 465,256.58 0.00 -718.73 6,400.00 68.55 64.64 3,372.51 3,217.71 2,240.17 4,266.65 5,929,909.51 465,340.88 0.00 -729.04 6,500.00 68.55 64.64 3,409.08 3,254.28 2,280.03 4,350.75 5,929,948.93 465,425.18 0.00 -739.34 6,600.00 68.55 64.64 3,445.65 3,290.85 2,319.88 4,434.86 5,929,988.36 465,509.49 0.00 -749.65 6,700.00 68.55 64.64 3,482.22 3,327.42 2,359.74 4,518.96 5,930,027.78 465,593.79 0.00 -759.95 6,800.00 68.55 64.64 3,518.80 3,364.00 2,399.60 4,603.07 5,930,067.20 465,678.09 0.00 -770.26 6,900.00 68.55 64.64 3,555.37 3,400.57 2,439.46 4,687.18 5,930,106.62 465,762.39 0.00 -780.56 7,000.00 68.55 64.64 3,591.94 3,437.14 2,479.32 4,771.28 5,930,146.04 465,846.69 0.00 -790.86 7,100.00 68.55 64.64 3,628.51 3,473.71 2,519.18 4,855.39 5,930,185.46 465,931.00 0.00 -801.17 7,200.00 68.55 64.64 3,665.09 3,510.29 2,559.04 4,939.49 5,930,224.88 466,015.30 0.00 -811.47 7,300.00 68.55 64.64 3,701.66 3,546.86 2,598.89 5,023.60 5,930,264.30 466,099.60 0.00 -821.78 7,400.00 68.55 64.64 3,738.23 3,583.43 2,638.75 5,107.70 5,930,303.72 466,183.90 0.00 -832.08 , 7,500.00 68.55 64.64 3,774.80 3,620.00 2,678.61 5,191.81 5,930,343.14 466,268.20 0.00 -842.39 7,600.00 68.55 64.64 3,811.38 3,656.58 2,718.47 5,275.92 5,930,382.56 466,352.50 0.00 -852.69 12/8/2010 10:10:03AMpig q 4 COMPASS 2003.16 Build 69 (..: ' I U I t4 A L Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-306(Stella) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-306(Stella) Survey Calculation Method: Minimum Curvature Wellbore: 2L-306 PB1 Design: 2L-306 PB1 (wp02) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 3,693.15 7,700.00 68.55 64.64 3,847.95 3,693.15 2,758.33 5,360.02 5,930,421.98 466,436.81 0.00 -863.00 7,732.41 68.55 64.64 3,859.80 3,705.00 2,771.25 5,387.28 5,930,434.75 466,464.13 0.00 866.34 C-50 7,800.00 68.55 64.64 3,884.52 3,729.72 2,798.19 5,444.13 5,930,461.40 466,521.11 0.00 -873.30 7,900.00 68.55 64.64 3,921.09 3,766.29 2,838.05 5,528.23 5,930,500.82 466,605.41 0.00 -883.61 8,000.00 68.55 64.64 3,957.67 3,802.87 2,877.91 5,612.34 5,930,540.24 466,689.71 0.00 -893.91 8,100.00 68.55 64.64 3,994.24 3,839.44 2,917.76 5,696.44 5,930,579.66 466,774.01 0.00 -904.22 8,200.00 68.55 64.64 4,030.81 3,876.01 2,957.62 5,780.55 5,930,619.08 466,858.31 0.00 -914.52 8,300.00 68.55 64.64 4,067.38 3,912.58 2,997.48 5,864.66 5,930,658.50 466,942.62 0.00 -924.83 8,400.00 68.55 64.64 4,103.95 3,949.15 3,037.34 5,948.76 5,930,697.92 467,026.92 0.00 -935.13 8,500.00 68.55 64.64 4,140.53 3,985.73 3,077.20 6,032.87 5,930,737.34 467,111.22 0.00 -945.44 8,600.00 68.55 64.64 4,177.10 4,022.30 3,117.06 6,116.97 5,930,776.76 467,195.52 0.00 -955.74 8,700.00 68.55 64.64 4,213.67 4,058.87 3,156.92 6,201.08 5,930,816.18 467,279.82 0.00 -966.05 8,800.00 68.55 64.64 4,250.24 4,095.44 3,196.77 6,285.18 5,930,855.60 467,364.13 0.00 -976.35 8,853.47 68.55 64.64 4,269.80 4,115.00 3,218.09 6,330.16 5,930,876.68 467,409.20 0.00 -981.86 C-40 8,900.00 68.55 64.64 4,286.82 4,132.02 3,236.63 6,369.29 5,930,895.02 467,448.43 0.00 -986.66 9,000.00 68.55 64.64 4,323.39 4,168.59 3,276.49 6,453.39 5,930,934.45 467,532.73 0.00 -996.96 9,044.60 68.55 64.64 4,339.70 4,184.90 3,294.27 6,490.91 5,930,952.03 467,570.33 0.00 -1,001.56 9,100.00 67.86 66.91 4,360.27 4,205.47 3,315.37 6,537.81 5,930,972.89 467,617.34 4.00 -1,006.24 9,200.00 66.70 71.06 4,398.90 4,244.10 3,348.45 6,623.89 5,931,005.52 467,703.58 4.00 -1,009.49 9,300.00 65.66 75.28 4,439.30 4,284.50 3,374.94 6,711.42 5,931,031.55 467,791.24 4.00 -1,006.04 9,361.17 65.08 77.90 4,464.80 4,310.00 3,387.83 6,765.51 5,931,044.16 467,845.38 4.00 -1,000.62 C-37 9,400.00 64.73 79.57 4,481.27 4,326.47 3,394.70 6,799.99 5,931,050.86 467,879.90 4.00 -995.89 9,500.00 63.93 83.92 4,524.60 4,369.80 3,407.65 6,889.16 5,931,063.34 467,969.12 4.00 -979.11 9,600.00 63.26 88.32 4,569.09 4,414.29 3,413.72 6,978.49 5,931,068.95 468,058.47 4.00 -955.76 9,700.00 62.73 92.77 4,614.52 4,459.72 3,412.87 7,067.54 5,931,067.65 468,147.51 4.00 -925.97 9,800.00 62.34 97.26 4,660.67 4,505.87 3,405.13 7,155.90 5,931,059.44 468,235.82 4.00 -889.88 9,900.00 62.09 101.77 4,707.30 4,552.50 3,390.51 7,243.12 5,931,044.38 468,322.95 4.00 -847.66 10,000.00 61.99 106.30 4,754.20 4,599.40 3,369.10 7,328.78 5,931,022.53 468,408.49 4.00 -799.53 10,100.00 62.04 110.83 4,801.14 4,646.34 3,340.99 7,412.46 5,930,993.99 468,492.02 4.00 -745.71 10,200.00 62.24 115.35 4,847.89 4,693.09 3,306.33 7,493.76 5,930,958.92 468,573.13 4.00 -686.47 10,300.00 62.59 119.84 4,894.21 4,739.41 3,265.28 7,572.28 5,930,917.47 468,651.43 4.00 -622.09 10,400.00 63.08 124.31 4,939.89 4,785.09 3,218.05 7,647.63 5,930,869.85 468,726.53 4.00 -552.90 10,500.00 63.70 128.73 4,984.70 4,829.90 3,164.86 7,719.46 5,930,816.30 468,798.08 4.00 -479.22 10,600.00 64.46 133.09 5,028.42 4,873.62 3,105.97 7,787.40 5,930,757.07 468,865.71 4.00 -401.42 10,700.00 65.35 137.40 5,070.85 4,916.05 3,041.67 7,851.13 5,930,692.45 468,929.10 4.00 -319.88 10,800.00 66.36 141.64 5,111.77 4,956.97 2,972.28 7,910.34 5,930,622.75 468,987.95 4.00 -234.99 10,900.00 67.48 145.81 5,150.98 4,996.18 2,898.12 7,964.74 5,930,548.32 469,041.96 4.00 -147.16 11,000.00 68.71 149.92 5,188.29 5,033.49 2,819.57 8,014.07 5,930,469.53 469,090.87 4.00 -56.83 11,100.00 70.04 153.95 5,223.53 5,068.73 2,737.00 8,058.08 5,930,386.74 469,134.45 4.00 35.57 11,200.00 71.45 157.91 5,256.52 5,101.72 2,650.82 8,096.56 5,930,300.37 469,172.48 4.00 129.58 11,288.55 72.78 161.37 5,283.72 5,128.92 2,571.83 8,125.86 5,930,221.23 469,201.38 4.00 213.81 11,300.00 72.78 161.37 5,287.11 5,132.31 2,561.46 8,129.36 5,930,210.85 469,204.82 0.00 224.75 12/8/2010 10:10:03AM5 COMPASS 2003.16 Build 69 OR % GW4AL Pa Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-306(Stella) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-306(Stella) Survey Calculation Method: Minimum Curvature Wellbore: 2L-306 PB1 Design: 2L-306 PB1(wp02) 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) 5,158.53 11,388.55 72.78 161.37 5,313.33 5,158.53 2,481.32 8,156.38 5,930,130.58 469,231.42 0.00 309.33 2L-Stella PB1 T1 11,400.00 72.43 161.37 5,316.75 5,161.95 2,470.96 8,159.87 5,930,120.21 469,234.86 3.00 320.25 I 11,410.01 72.13 161.37 5,319.80 5,165.00 2,461.93 8,162.92 5,930,111.16 469,237.86 3.00 329.79 Top Bermuda @ 11410'MD,5320'TVD:2304'FSL,2299'FWL-Sec13-T10N-R07E-Top Berm 11,500.00 69.43 161.37 5,349.42 5,194.62 2,381.42 8,190.07 5,930,030.51 469,264.59 3.00 414.75 11,600.00 66.43 161.37 5,386.99 5,232.19 2,293.61 8,219.68 5,929,942.57 469,293.74 3.00 507.41 11,700.00 63.43 161.37 5,429.35 5,274.55 2,207.79 8,248.61 5,929,856.60 469,322.24 3.00 597.98 11,701.01 63.40 161.37 5,429.80 5,275.00 2,206.93 8,248.90 5,929,855.75 469,322.52 3.00 598.88 Base Berm 11,798.79 60.47 161.37 5,475.80 5,321.00 2,125.18 8,276.47 5,929,773.86 469,349.66 3.00 685.16 C-35 11,800.00 60.43 161.37 5,476.40 5,321.60 2,124.18 8,276.81 5,929,772.86 469,349.99 3.00 686.21 11,813.01 60.04 161.37 5,482.85 5,328.05 2,113.48 8,280.41 5,929,762.15 469,353.55 3.00 697.50 11,900.00 57.43 161.37 5,528.00 5,373.20 2,043.03 8,304.17 5,929,691.58 469,376.94 3.00 771.85 11,945.33 56.07 161.37 5,552.85 5,398.05 2,007.10 8,316.28 5,929,655.59 469,388.87 3.00 809.77 2L-Stella PB1 T2 11,963.00 55.54 161.37 5,562.78 5,407.98 1,993.26 8,320.95 5,929,641.72 469,393.46 3.00 824.38 l { iC w• 9 7/8"OH Tu 11,963.01 55.54 161.37 5,562.78 5,407.98 1,993.25 8,320.96 5,929,641.72 469,393.46 3.00 824.38 1't#' Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting -Shape (0) (0) (ft) (ft) (ft) (ft) (ft) 2L-Stella PB1 T2 0.00 0.00 5,482.85 1,963.17 8,331.07 5,929,611.59 469,403.42 -plan misses target center by 83.95ft at 11945.33ft MD(5552.85 TVD,2007.10 N,8316.28 E) -Point 2L-Stella PB1 T1 0.00 0.00 5,313.33 2,481.32 8,156.38 5,930,130.58 469,231.42 -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") ('•) 11,963.00 5,562.78 9 7/8"OH 9-7/8 9-7/8 3,740.87 2,400.00 10 3/4" 10-3/4 13-1/2 12/8/2010 10:10:03AMPa�ef� k COMPASS 2003.16 Build 69 1 I r Halliburton -Sperry I-IALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-306(Stella) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-306(Stella) Survey Calculation Method: Minimum Curvature Wellbore: 2L-306 PB1 Design: 2L-306 PB1 (wp02) Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (°) (*) 11,798.79 5,475.80 C-35 0.00 4,136.79 2,544.80 Campanian 0.00 8,853.47 4,269.80 C-40 0.00 11,410.01 5,319.80 Top Berm 0.00 972.25 957.10 Permafrost??? 0.00 4,041.09 2,509.80 C-80 0.00 9,361.17 4,464.80 C-37 0.00 11,701.01 5,429.80 Base Berm 0.00 7,732.41 3,859.80 C-50 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 40.00 40.00 0.00 0.00 SHL:154'FNL,588'FEL-Sec22-T10N-R07E 3,740.87 2,400.00 1,180.28 2,030.17 Surf Csg @ 3741'MD,2400'TVD:1026'FSL,1444'FWL-Sec14-T10N-R07E 11,410.01 5,319.80 2,461.93 8,162.92 Top Bermuda @ 11410'MD,5320'TVD:2304'FSL,2299'FWL-Sec13-T10N-R07E 11,963.01 5,562.78 1,993.25 8,320.96 TD @ 11963'MD,5563'TVD:1835'FSL,2456'FWL-Sec13-T10N-R07E 12/8/2010 10:10:03AM Page 7 COMPASS 2003.16 Build 69 , M t x ' ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-306 (Stella) r 2L-306 Plan: 2L-306 (wp02) Standard Proposal Report *, 08 December, 2010 HALLIBURTON Sperry Drilling Services Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-306(Stella) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-306(Stella) Survey Calculation Method: Minimum Curvature Wellbore: 2L-306 Design: 2L-306(wp02) 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 j Site Kuparuk 2L Pad Site Position: Northing: 5,927,695.13ft Latitude: 70°12'48.272 N From: Map Easting: 461,077.91 ft Longitude: 150°18'50.048 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -0.30 ° Well Plan:2L-306(Stella) Well Position +N/-S 0.00 ft Northing: 5,927,691.60 ft Latitude: 70°12'48.237 N +EI-W 0.00 ft Easting: 461,063.16 ft Longitude: 150°18'50.476 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 114.80 ft Wellbore 2L-306 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 1 (°) (°) (nT) BGGM2009 3/1/2011 21.03 80.71 57,659 i Design 2L-306(wp02) Audit Notes: Version: Phase: PLAN Tie On Depth: 11,300.00 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (ft) (ft) (ft) (0) 40.00 0.00 0.00 161.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +NI-S +EI-W Rate Rate Rate Tool Face (ft) (0) (0) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 11,300.00 72.78 161.37 5,287.11 5,132.31 2,561.46 8,129.36 0.00 0.00 0.00 0.00 11,423.87 77.72 157.49 5,318.65 5,163.85 2,449.39 8,171.47 5.01 3.99 -3.13 -37.67 11,546.58 76.52 162.37 5,346.02 5,191.22 2,337.08 8,212.51 4.00 -0.98 3.98 104.75 11,635.33 76.52 162.37 5,366.71 5,211.91 2,254.83 8,238.65 0.00 0.00 0.00 0.00 11,883.17 86.39 161.47 5,403.50 5,248.70 2,022.13 8,314.63 4.00 3.98 -0.36 -5.22 12,158.17 86.39 161.47 5,420.82 5,266.02 1,761.90 8,401.85 0.00 0.00 0.00 0.00 12,633.88 87.53 161.47 5,446.04 5,291.24 1,311.49 8,552.79 0.24 0.24 0.00 0.13 13,209.18 93.18 161.47 5,442.48 5,287.68 766.24 8,735.51 0.98 0.98 0.00 -0.01 13,609.51 91.10 161.47 5,427.55 5,272.75 386.94 8,862.63 0.52 -0.52 0.00 -179.94 14,062.04 88.08 161.48 5,430.78 5,275.98 -42.08 9,006.39 0.67 -0.67 0.00 179.89 12/8/2010 10:28:29AM Page 2 COMPASS 2003.16 Build 69 , ibIL iIL. Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-306(Stella) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-306(Stella) Survey Calculation Method: Minimum Curvature Wellbore: 2L-306 Design: 2L-306(wp02) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W NorthingEasting 9 DLS Veil Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) -54.80 1 100.00 0.00 0.00 100.00 -54.80 0.00 0.00 5,927,691.60 461,063.16 0.00 0.00 200.00 0.00 0.00 200.00 45.20 0.00 0.00 5,927,691.60 461,063.16 0.00 0.00 300.00 0.00 0.00 300.00 145.20 0.00 0.00 5,927,691.60 461,063.16 0.00 0.00 400.00 3.00 20.00 399.95 245.15 2.46 0.90 5,927,694.05 461,064.07 3.00 -2.03 500.00 6.00 20.00 499.63 344.83 9.83 3.58 5,927,701.41 461,066.79 3.00 -8.13 600.00 9.00 20.00 598.77 443.97 22.10 8.04 5,927,713.65 461,071.31 3.00 -18.27 700.00 12.13 27.09 697.07 542.27 38.98 14.98 5,927,730.49 461,078.34 3.38 -31.98 800.00 15.63 35.21 794.15 639.35 59.35 27.54 5,927,750.80 461,091.00 4.00 -47.15 900.00 19.32 40.35 889.52 734.72 82.97 46.03 5,927,774.33 461,109.61 4.00 -63.47 1,000.00 23.12 43.87 982.72 827.92 109.75 70.35 5,927,800.97 461,134.07 4.00 -80.86 1,100.00 26.97 46.45 1,073.31 918.51 139.53 100.40 5,927,830.60 461,164.27 4.00 -99.24 1,200.00 30.85 48.42 1,160.83 1,006.03 172.19 136.03 5,927,863.07 461,200.06 4.00 -118.52 1,300.00 34.76 49.98 1,244.87 1,090.07 207.55 177.06 5,927,898.22 461,241.27 4.00 -138.60 1,400.00 37.44 50.88 1,325.22 1,170.42 245.34 223.04 5,927,935.76 461,287.44 2.73 -159.36 1,500.00 38.60 51.71 1,404.42 1,249.62 283.74 270.49 5,927,973.91 461,335.08 1.27 -180.22 1,600.00 42.30 54.07 1,480.51 1,325.71 322.83 322.25 5,928,012.73 461,387.03 4.00 -200.33 1,700.00 46.04 56.12 1,552.23 1,397.43 362.65 379.40 5,928,052.25 461,444.38 4.00 -219.37 1,800.00 49.81 57.92 1,619.24 1,464.44 403.01 441.66 5,928,092.28 461,506.85 4.00 -237.26 1,900.00 53.60 59.54 1,681.20 1,526.40 443.71 508.74 5,928,132.63 461,574.13 4.00 -253.90 2,000.00 57.41 61.00 1,737.83 1,583.03 484.55 580.31 5,928,173.10 461,645.90 4.00 -269.22 2,100.00 61.24 62.34 1,788.83 1,634.03 525.34 656.01 5,928,213.50 461,721.80 4.00 -283.14 2,200.00 65.09 63.59 1,833.96 1,679.16 565.88 735.48 5,928,253.62 461,801.47 4.00 -295.60 2,300.00 68.55 64.64 1,873.04 1,718.24 605.97 818.32 5,928,293.28 461,884.51 3.59 -306.53 2,400.00 68.55 64.64 1,909.61 1,754.81 645.82 902.42 5,928,332.70 461,968.81 0.00 -316.84 2,500.00 68.55 64.64 1,946.19 1,791.39 685.68 986.53 5,928,372.12 462,053.11 0.00 -327.14 2,600.00 68.55 64.64 1,982.76 1,827.96 725.54 1,070.63 5,928,411.54 462,137.41 0.00 -337.45 2,700.00 68.55 64.64 2,019.33 1,864.53 765.40 1,154.74 5,928,450.96 462,221.72 0.00 -347.75 2,800.00 68.55 64.64 2,055.90 1,901.10 805.26 1,238.85 5,928,490.38 462,306.02 0.00 -358.06 2,900.00 68.55 64.64 2,092.48 1,937.68 845.12 1,322.95 5,928,529.80 462,390.32 0.00 -368.36 3,000.00 68.55 64.64 2,129.05 1,974.25 884.98 1,407.06 5,928,569.22 462,474.62 0.00 -378.67 3,100.00 68.55 64.64 2,165.62 2,010.82 924.83 1,491.16 5,928,608.64 462,558.92 0.00 -388.97 3,200.00 68.55 64.64 2,202.19 2,047.39 964.69 1,575.27 5,928,648.06 462,643.23 0.00 -399.28 3,300.00 68.55 64.64 2,238.77 2,083.97 1,004.55 1,659.37 5,928,687.48 462,727.53 0.00 -409.58 3,400.00 68.55 64.64 2,275.34 2,120.54 1,044.41 1,743.48 5,928,726.90 462,811.83 0.00 -419.89 3,500.00 68.55 64.64 2,311.91 2,157.11 1,084.27 1,827.58 5,928,766.32 462,896.13 0.00 -430.19 3,600.00 68.55 64.64 2,348.48 2,193.68 1,124.13 1,911.69 5,928,805.74 462,980.43 0.00 -440.50 3,700.00 68.55 64.64 2,385.05 2,230.25 1,163.99 1,995.80 5,928,845.16 463,064.73 0.00 -450.80 3,740.87 68.55 64.64 2,400.00 2,245.20 1,180.27 2,030.17 5,928,861.27 463,099.18 0.00 -455.01 10 3/4" 3,800.00 68.55 64.64 2,421.63 2,266.83 1,203.84 2,079.90 5,928,884.58 463,149.04 0.00 -461.11 3,900.00 68.55 64.64 2,458.20 2,303.40 1,243.70 2,164.01 5,928,924.00 463,233.34 0.00 -471.41 4,000.00 68.55 64.64 2,494.77 2,339.97 1,283.56 2,248.11 5,928,963.42 463,317.64 0.00 -481.72 4,041.09 68.55 64.64 2,509.80 2,355.00 1,299.94 2,282.67 5,928,979.62 463,352.28 0.00 -485.95 C-80 4,100.00 68.55 64.64 2,531.34 2,376.54 1,323.42 2,332.22 5,929,002.84 463,401.94 0.00 -492.02 12/8/2010 10:28:29AM Page 3 COMPASS 2003.16 Build 69 C. RG1NAL Halliburton -Sperry HALLI B U R TO N Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-306(Stella) Company: ConocoPhillips(Alaska)Inc.-Kup2 ND Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-306(Stella) Survey Calculation Method: Minimum Curvature Wellbore: 2L-306 Design: 2L-306(wp02) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Veil Section (ft) (1 (°) (ft) ft (ft) (ft) (ft) (ft) 2,390.00 4,136.79 68.55 64.64 2,544.80 2,390.00 1,338.09 2,363.16 5,929,017.35 463,432.96 0.00 -495.81 Campanian 4,200.00 68.55 64.64 2,567.92 2,413.12 1,363.28 2,416.32 5,929,042.27 463,486.24 0.00 -502.33 1 4,300.00 68.55 64.64 2,604.49 2,449.69 1,403.14 2,500.43 5,929,081.69 463,570.54 0.00 -512.63 4,400.00 68.55 64.64 2,641.06 2,486.26 1,443.00 2,584.54 5,929,121.11 463,654.85 0.00 -522.94 4,500.00 68.55 64.64 2,677.63 2,522.83 1,482.85 2,668.64 5,929,160.53 463,739.15 0.00 -533.24 4,600.00 68.55 64.64 2,714.21 2,559.41 1,522.71 2,752.75 5,929,199.95 463,823.45 0.00 -543.55 4,700.00 68.55 64.64 2,750.78 2,595.98 1,562.57 2,836.85 5,929,239.37 463,907.75 0.00 -553.85 4,800.00 68.55 64.64 2,787.35 2,632.55 1,602.43 2,920.96 5,929,278.79 463,992.05 0.00 -564.16 4,900.00 68.55 64.64 2,823.92 2,669.12 1,642.29 3,005.06 5,929,318.21 464,076.36 0.00 -574.46 5,000.00 68.55 64.64 2,860.49 2,705.69 1,682.15 3,089.17 5,929,357.63 464,160.66 0.00 -584.77 5,100.00 68.55 64.64 2,897.07 2,742.27 1,722.01 3,173.27 5,929,397.05 464,244.96 0.00 -595.07 5,200.00 68.55 64.64 2,933.64 2,778.84 1,761.86 3,257.38 5,929,436.47 464,329.26 0.00 -605.38 5,300.00 68.55 64.64 2,970.21 2,815.41 1,801.72 3,341.49 5,929,475.89 464,413.56 0.00 -615.68 5,400.00 68.55 64.64 3,006.78 2,851.98 1,841.58 3,425.59 5,929,515.31 464,497.86 0.00 -625.99 5,500.00 68.55 64.64 3,043.36 2,888.56 1,881.44 3,509.70 5,929,554.73 464,582.17 0.00 -636.29 5,600.00 68.55 64.64 3,079.93 2,925.13 1,921.30 3,593.80 5,929,594.15 464,666.47 0.00 -646.60 5,700.00 68.55 64.64 3,116.50 2,961.70 1,961.16 3,677.91 5,929,633.57 464,750.77 0.00 -656.90 5,800.00 68.55 64.64 3,153.07 2,998.27 2,001.02 3,762.01 5,929,672.99 464,835.07 0.00 -667.21 5,900.00 68.55 64.64 3,189.65 3,034.85 2,040.87 3,846.12 5,929,712.41 464,919.37 0.00 -677.51 6,000.00 68.55 64.64 3,226.22 3,071.42 2,080.73 3,930.23 5,929,751.83 465,003.68 0.00 -687.82 6,100.00 68.55 64.64 3,262.79 3,107.99 2,120.59 4,014.33 5,929,791.25 465,087.98 0.00 -698.12 6,200.00 68.55 64.64 3,299.36 3,144.56 2,160.45 4,098.44 5,929,830.67 465,172.28 0.00 -708.43 6,300.00 68.55 64.64 3,335.94 3,181.14 2,200.31 4,182.54 5,929,870.09 465,256.58 0.00 -718.73 6,400.00 68.55 64.64 3,372.51 3,217.71 2,240.17 4,266.65 5,929,909.51 465,340.88 0.00 -729.04 6,500.00 68.55 64.64 3,409.08 3,254.28 2,280.03 4,350.75 5,929,948.93 465,425.18 0.00 -739.34 6,600.00 68.55 64.64 3,445.65 3,290.85 2,319.88 4,434.86 5,929,988.36 465,509.49 0.00 -749.65 6,700.00 68.55 64.64 3,482.22 3,327.42 2,359.74 4,518.96 5,930,027.78 465,593.79 0.00 -759.95 6,800.00 68.55 64.64 3,518.80 3,364.00 2,399.60 4,603.07 5,930,067.20 465,678.09 0.00 -770.26 6,900.00 68.55 64.64 3,555.37 3,400.57 2,439.46 4,687.18 5,930,106.62 465,762.39 0.00 -780.56 7,000.00 68.55 64.64 3,591.94 3,437.14 2,479.32 4,771.28 5,930,146.04 465,846.69 0.00 -790.86 7,100.00 68.55 64.64 3,628.51 3,473.71 2,519.18 4,855.39 5,930,185.46 465,931.00 0.00 -801.17 7,200.00 68.55 64.64 3,665.09 3,510.29 2,559.04 4,939.49 5,930,224.88 466,015.30 0.00 -811.47 7,300.00 68.55 64.64 3,701.66 3,546.86 2,598.89 5,023.60 5,930,264.30 466,099.60 0.00 -821.78 7,400.00 68.55 64.64 3,738.23 3,583.43 2,638.75 5,107.70 5,930,303.72 466,183.90 0.00 -832.08 7,500.00 68.55 64.64 3,774.80 3,620.00 2,678.61 5,191.81 5,930,343.14 466,268.20 0.00 -842.39 7,600.00 68.55 64.64 3,811.38 3,656.58 2,718.47 5,275.92 5,930,382.56 466,352.50 0.00 -852.69 7,700.00 68.55 64.64 3,847.95 3,693.15 2,758.33 5,360.02 5,930,421.98 466,436.81 0.00 -863.00 7,732.41 68.55 64.64 3,859.80 3,705.00 2,771.25 5,387.28 5,930,434.75 466,464.13 0.00 -866.34 C-50 7,800.00 68.55 64.64 3,884.52 3,729.72 2,798.19 5,444.13 5,930,461.40 466,521.11 0.00 -873.30 7,900.00 68.55 64.64 3,921.09 3,766.29 2,838.05 5,528.23 5,930,500.82 466,605.41 0.00 -883.61 8,000.00 68.55 64.64 3,957.67 3,802.87 2,877.91 5,612.34 5,930,540.24 466,689.71 0.00 -893.91 8,100.00 68.55 64.64 3,994.24 3,839.44 2,917.76 5,696.44 5,930,579.66 466,774.01 0.00 -904.22 8,200.00 68.55 64.64 4,030.81 3,876.01 2,957.62 5,780.55 5,930,619.08 466,858.31 0.00 -914.52 12/8/2010 10:28:29AM Page 4py I COMPASS 2003.16 Build 69 Halliburton -Sperry I-IALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-306(Stella) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-306(Stella) Survey Calculation Method: Minimum Curvature Wellbore: 2L-306 Design: 2L-306(wp02) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (ft) C) (°) (ft) ft (ft) (ft) (ft) (ft) 3,912.58 8,300.00 68.55 64.64 4,067.38 3,912.58 2,997.48 5,864.66 5,930,658.50 466,942.62 0.00 -924.83 ' 8,400.00 68.55 64.64 4,103.95 3,949.15 3,037.34 5,948.76 5,930,697.92 467,026.92 0.00 -935.13 8,500.00 68.55 64.64 4,140.53 3,985.73 3,077.20 6,032.87 5,930,737.34 467,111.22 0.00 -945.44 8,600.00 68.55 64.64 4,177.10 4,022.30 3,117.06 6,116.97 5,930,776.76 467,195.52 0.00 -955.74 8,700.00 68.55 64.64 4,213.67 4,058.87 3,156.92 6,201.08 5,930,816.18 467,279.82 0.00 -966.05 8,800.00 68.55 64.64 4,250.24 4,095.44 3,196.77 6,285.18 5,930,855.60 467,364.13 0.00 -976.35 8,853.47 68.55 64.64 4,269.80 4,115.00 3,218.09 6,330.16 5,930,876.68 467,409.20 0.00 -981.86 C-40 8,900.00 68.55 64.64 4,286.82 4,132.02 3,236.63 6,369.29 5,930,895.02 467,448.43 0.00 -986.66 9,000.00 68.55 64.64 4,323.39 4,168.59 3,276.49 6,453.39 5,930,934.45 467,532.73 0.00 -996.96 9,100.00 67.86 66.91 4,360.27 4,205.47 3,315.37 6,537.81 5,930,972.89 467,617.34 2.22 -1,006.24 9,200.00 66.70 71.06 4,398.90 4,244.10 3,348.45 6,623.89 5,931,005.52 467,703.58 4.00 -1,009.49 9,300.00 65.66 75.28 4,439.30 4,284.50 3,374.94 6,711.42 5,931,031.55 467,791.24 4.00 -1,006.04 9,361.17 65.08 77.90 4,464.80 4,310.00 3,387.83 6,765.51 5,931,044.16 467,845.38 4.00 -1,000.62 C-37 9,400.00 64.73 79.57 4,481.27 4,326.47 3,394.70 6,799.99 5,931,050.86 467,879.90 4.00 -995.89 9,500.00 63.93 83.92 4,524.60 4,369.80 3,407.65 6,889.16 5,931,063.34 467,969.12 4.00 -979.11 9,600.00 63.26 88.32 4,569.09 4,414.29 3,413.72 6,978.49 5,931,068.95 468,058.47 4.00 -955.76 9,700.00 62.73 92.77 4,614.52 4,459.72 3,412.87 7,067.54 5,931,067.65 468,147.51 4.00 -925.97 9,800.00 62.34 97.26 4,660.67 4,505.87 3,405.13 7,155.90 5,931,059.44 468,235.82 4.00 -889.88 9,900.00 62.09 101.77 4,707.30 4,552.50 3,390.51 7,243.12 5,931,044.38 468,322.95 4.00 -847.66 10,000.00 61.99 106.30 4,754.20 4,599.40 3,369.10 7,328.78 5,931,022.53 468,408.49 4.00 -799.53 10,100.00 62.04 110.83 4,801.14 4,646.34 3,340.99 7,412.46 5,930,993.99 468,492.02 4.00 -745.71 10,200.00 62.24 115.35 4,847.89 4,693.09 3,306.33 7,493.76 5,930,958.92 468,573.13 4.00 -686.47 10,300.00 62.59 119.84 4,894.21 4,739.41 3,265.28 7,572.28 5,930,917.47 468,651.43 4.00 -622.09 10,400.00 63.08 124.31 4,939.89 4,785.09 3,218.05 7,647.63 5,930,869.85 468,726.53 4.00 -552.90 10,500.00 63.70 128.73 4,984.70 4,829.90 3,164.86 7,719.46 5,930,816.30 468,798.08 4.00 -479.22 10,600.00 64.46 133.09 5,028.42 4,873.62 3,105.97 7,787.40 5,930,757.07 468,865.71 4.00 -401.42 10,700.00 65.35 137.40 5,070.85 4,916.05 3,041.67 7,851.13 5,930,692.45 468,929.10 4.00 -319.88 10,800.00 66.36 141.64 5,111.77 4,956.97 2,972.28 7,910.34 5,930,622.75 468,987.95 4.00 -234.99 10,900.00 67.48 145.81 5,150.98 4,996.18 2,898.12 7,964.74 5,930,548.32 469,041.96 4.00 -147.16 11,000.00 68.71 149.92 5,188.29 5,033.49 2,819.57 8,014.07 5,930,469.53 469,090.87 4.00 -56.83 11,100.00 70.04 153.95 5,223.53 5,068.73 2,737.00 8,058.08 5,930,386.74 469,134.45 4.00 35.57 11,200.00 71.45 157.91 5,256.52 5,101.72 2,650.82 8,096.56 5,930,300.37 469,172.48 4.00 129.58 11,300.00 72.78 161.37 5,287.11 5,132.31 2,561.46 8,129.36 5,930,210.85 469,204.82 3.54 224.75 Tie-on @ 11300'MD,5287'TVD:2404'FSL,2265'FWL-Sec13-T10N-R07E 11,400.00 76.76 158.22 5,313.38 5,158.58 2,470.95 8,162.69 5,930,120.18 469,237.68 5.01 321.18 11,423.87 77.72 157.49 5,318.65 5,163.85 2,449.39 8,171.47 5,930,098.58 469,246.34 5.01 344.42 2L-Stella Heel 11,424.00 77.72 157.49 5,318.68 5,163.88 2,449.27 8,171.52 5,930,098.46 469,246.39 0.00 344.55 7 5/8" 11,429.26 77.67 157.70 5,319.80 5,165.00 2,444.52 8,173.48 5,930,093.70 469,248.33 4.10 349.69 Top Berm 11,500.00 76.96 160.51 5,335.34 5,180.54 2,380.05 8,198.08 5,930,029.11 469,272.60 4.00 418.65 11,546.58 76.52 162.37 5,346.02 5,191.22 2,337.08 8,212.51 5,929,986.07 469,286.81 4.00 463.98 12/8/2010 10:28:29AM Page 5 COMPASS 2003.16 Build 69 OR ( GINAL Halliburton -Sperry 1-IALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-306(Stella) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-306(Stella) Survey Calculation Method: Minimum Curvature Wellbore: 2L-306 Design: 2L-306(wp02) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (1 (°) (ft) ft (ft) (ft) (ft) (ft) 5,203.68 11,600.00 76.52 162.37 5,358.48 5,203.68 2,287.57 8,228.25 5,929,936.48 469,302.28 0.00 515.92 11,635.33 76.52 162.37 5,366.71 5,211.91 2,254.83 8,238.65 5,929,903.69 469,312.52 0.00 550.26 11,700.00 79.09 162.13 5,380.38 5,225.58 2,194.63 8,257.92 5,929,843.40 469,331.47 4.00 613.46 11,800.00 83.08 161.77 5,395.87 5,241.07 2,100.72 8,288.52 5,929,749.34 469,361.59 4.00 712.21 11,883.17 86.39 161.47 5,403.50 5,248.70 2,022.13 8,314.63 5,929,670.63 469,387.29 4.00 795.02 11,900.00 86.39 161.47 5,404.56 5,249.76 2,006.21 8,319.97 5,929,654.68 469,392.55 0.00 811.81 12,000.00 86.39 161.47 5,410.86 5,256.06 1,911.58 8,351.69 5,929,559.90 469,423.77 0.00 911.61 12,100.00 86.39 161.47 5,417.16 5,262.36 1,816.95 8,383.40 5,929,465.12 469,454.99 0.00 1,011.41 12,158.17 86.39 161.47 5,420.82 5,266.02 1,761.90 8,401.85 5,929,409.98 469,473.16 0.00 1,069.46 2L-Stella CP2 12,200.00 86.49 161.47 5,423.42 5,268.62 1,722.32 8,415.12 5,929,370.33 469,486.22 0.24 1,111.21 12,300.00 86.73 161.47 5,429.33 5,274.53 1,627.67 8,446.84 5,929,275.53 469,517.45 0.24 1,211.03 12,400.00 86.97 161.47 5,434.82 5,280.02 1,532.99 8,478.56 5,929,180.70 469,548.68 0.24 1,310.88 12,500.00 87.21 161.47 5,439.90 5,285.10 1,438.30 8,510.30 5,929,085.85 469,579.92 0.24 1,410.74 12,600.00 87.45 161.47 5,444.56 5,289.76 1,343.58 8,542.04 5,928,990.98 469,611.17 0.24 1,510.63 12,633.88 87.53 161.47 5,446.04 5,291.24 1,311.49 8,552.79 5,928,958.84 469,621.76 0.24 1,544.48 2L-Stella CP3 12,700.00 88.18 161.47 5,448.51 5,293.71 1,248.84 8,573.79 5,928,896.09 469,642.43 0.98 1,610.55 12,800.00 89.16 161.47 5,450.83 5,296.03 1,154.05 8,605.55 5,928,801.14 469,673.70 0.98 1,710.52 12,900.00 90.14 161.47 5,451.44 5,296.64 1,059.24 8,637.32 5,928,706.18 469,704.98 0.98 1,810.51 13,000.00 91.12 161.47 5,450.33 5,295.53 964.42 8,669.10 5,928,611.21 469,736.26 0.98 1,910.50 13,100.00 92.11 161.47 5,447.51 5,292.71 869.65 8,700.86 5,928,516.28 469,767.53 0.98 2,010.46 13,200.00 93.09 161.47 5,442.98 5,288.18 774.93 8,732.60 5,928,421.41 469,798.78 0.98 2,110.35 13,209.18 93.18 161.47 5,442.48 5,287.68 766.24 8,735.51 5,928,412.70 469,801.64 0.98 2,119.51 2L-Stella CP4 13,300.00 92.71 161.47 5,437.82 5,283.02 680.24 8,764.33 5,928,326.56 469,830.02 0.52 2,210.21 13,400.00 92.19 161.47 5,433.55 5,278.75 585.51 8,796.08 5,928,231.68 469,861.27 0.52 2,310.12 13,500.00 91.67 161.47 5,430.19 5,275.39 490.74 8,827.84 5,928,136.76 469,892.54 0.52 2,410.06 13,600.00 91.15 161.47 5,427.74 5,272.94 395.95 8,859.60 5,928,041.82 469,923.81 0.52 2,510.02 13,609.51 91.10 161.47 5,427.55 5,272.75 386.94 8,862.63 5,928,032.79 469,926.79 0.52 2,519.53 2L-Stella CP5 13,700.00 90.49 161.47 5,426.29 5,271.49 301.15 8,891.38 5,927,946.86 469,955.10 0.67 2,610.01 13,800.00 89.83 161.47 5,426.01 5,271.21 206.33 8,923.15 5,927,851.89 469,986.38 0.67 2,710.00 13,900.00 89.16 161.47 5,426.89 5,272.09 111.52 8,954.92 5,927,756.93 470,017.66 0.67 2,810.00 14,000.00 88.50 161.48 5,428.93 5,274.13 16.72 8,986.69 5,927,661.97 470,048.93 0.67 2,909.97 i 14,062.04 88.08 161.48 5,430.78 5,275.98 -42.08 9,006.39 5,927,603.08 470,068.32 0.67 2,971.98 TD @ 14062'MD,5431'TVD:201'FNL,2142'FEL-Sec24-T10N-R07E-3 1/2"-2L-Stella Toe 12/8/2010 10:28:29AM Page 6 COMPASS 2003.16 Build 69 ORtOtNAL Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-306(Stella) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Project: Kuparuk River Unit MD Reference: Plan:2L-306 @ 154.80ft(D15(40+114.8)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-306(Stella) Survey Calculation Method: Minimum Curvature Wellbore: 2L-306 Design: 2L-306(wp02) Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting -Shape (`) (`) (ft) (ft) (ft) (ft) (ft) 2L-Stella CP2 0.00 0.00 5,420.82 1,761.90 8,401.85 5,929,409.98 469,473.16 -plan hits target center I -Point 2L-Stella Heel 0.00 0.00 5,318.65 2,449.39 8,171.47 5,930,098.58 469,246.34 -plan hits target center -Point 2L-Stella Toe 0.00 0.00 5,430.78 -42.08 9,006.39 5,927,603.08 470,068.33 -plan hits target center -Point 2L-Stella CP4 0.00 0.00 5,442.48 766.24 8,735.51 5,928,412.70 469,801.64 -plan hits target center -Point 2L-Stella CP5 0.00 0.00 5,427.55 386.94 8,862.63 5,928,032.79 469,926.79 -plan hits target center -Point I 2L-Stella CP1 0.00 0.00 5,395.60 2,141.21 8,274.74 5,929,789.89 469,348.02 -plan misses target center by 5.53ft at 11757.70ft MD(5390.16 TVD,2140.54 N,8275.46 E) -Point 2L-Stella CP3 0.00 0.00 5,446.04 1,311.49 8,552.79 5,928,958.84 469,621.76 -plan hits target center -Point Casing Points ( Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 3,740.87 2,400.00 103/4" 10-3/4 13-1/2 11,424.00 5,318.68 7 5/8" 7-5/8 9-7/8 L14,062.04 5,430.78 3 1/2" 3-1/2 6-3/4 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (1 (°) 9,361.17 4,464.80 C-37 0.00 11,429.26 5,319.80 Top Berm 0.00 8,853.47 4,269.80 C-40 0.00 4,136.79 2,544.80 Campanian 0.00 7,732.41 3,859.80 C-50 0.00 4,041.09 2,509.80 C-80 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 11,300.00 5,287.11 2,561.46 8,129.36 Tie-on @ 11300'MD,5287'TVD:2404'FSL,2265'FWL-Sec13-T1ON-R07E 14,062.04 5,430.78 -42.08 9,006.39 TD @ 14062'MD,5431'TVD:201'FNL,2142'FEL-Sec24-T1ON-R07E 12/8/2010 10:28:29AM Page 7 COMPASS 2003.16 Build 69 m 0 ,L a N 3 c mo J J C. 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J N /( i II „. i 1 i-.1- ',/,... . Q o i o c� lN e _ i In mM N Qv M -0 u) N M - (N �- V N >ao ir a'N J N o �' In 7 7 N 0 10 co C M N '� aam> >aN a 5 al Z O 2 giE • 0 71i ' y 3 d t0 pdass',m CO cL O N aO.- N a u V a. 0 . V m c O J o O • J V = i : ...! / 0 ORIGINAL 2L-306 Drilling Hazards Summary 13-1/2" Hole/ 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate , If observed-control drill,reduce pump rates,reduce drilling fluid temperatures,Additions of Lecithin. Gravel/Sand Sloughing Moderate Increase mud weight/viscosity,High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill(use of Trips trip sheets),Pumping out of hole as needed. Lost Circulation Low Prevent by keeping hole clean. If losses occur-reduce pump rates and mud rheology,use LCM 9-7/8" Hole/ 7-5/8" Casing Interval Event Risk Level Mitigation Strategy Shale stability in HRZ and K-1 Moderate Control with higher MW and proper drilling practices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills,PWD Tools,Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates,Mud rheology,LCM. Use GKA LC decision tree. 6 3/4" Hole/3-1/2" Horizontal Liner Interval Event Risk Level Mitigation Strategy High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills,PWD Tools,Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates,Mud rheology,LCM. Use GKA LC decision tree. 2L-306 Hazards.doc Prepared by Mike Greener Cyt Page 1of1 2L-306 Stella Schlumberger CemCADE Preliminary Job Design 10-3/4" Surface Casino WP-02 V3 Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Volume Calculations and Cement Systems Location: Tarn Volumes are based on 300% excess in the permafrost and 50% excess below the Client: CPAI Revision Date: 12/10/2010 permafrost. The top of the tail slurry is designed to be at 2,750' MD. Prepared by: Steve Shultz Location:Anchorage,AK Lead Slurry Minimum pump time: 280 min. (pump time plus 120 min.) Phone: (907)263-4297 ARCTICSET Lite @ 10.7 ppg-4.51 ft3/sk 0.6381 ft3/ft x (80')x 1.00 (no excess) = 51 ft3 0.3637 ft3/ft x (1620'-80')x 4.00 (300% excess)= 2240 ft3 II < TOC at Surface 0.3637 ft3/ft x (2750'- 1620')x 1.50 (50% excess) = 617 ft3 51 ft3+ 2240 ft3+617 ft3= 2908 ft3 2908 ft3/4.51 ft3/sk = 645 sks Round up to 650 sks Have additional ASL on location for Top Out stage, if necessary. Previous Csg. Tail Slurry Minimum pump time: 190 min. (pump time plus120 min.) < 16",62.6#casing 12.0 ppg DeepCRETE + additives- 1.64 ft3/sk at 80'MD 0.3637 ft3/ft x(3741'-2750')x 1.50 (50% excess) 540 ft3 0.53997 ft3/ft x 80' (Shoe Joint) = 43 ft3 540 ft3+43 ft3 = 583 ft3 589 ft3/ 1.64 ft3/sk = 355 sks Round up to 360 sks BHST = 77°F, Estimated BHCT = 73°F. < Base of Permafrost at (BHST calculated using a gradient of 2.0°F/100 ft. from surface) 1,620 MD(1,503'TVD) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW100 5.0 50.0 10.0 10.0 MUDPUSH II 5.0 50.0 10.0 20.0 < Top of Tail at Drop bottom plug 0.0 0.0 5.0 25.0 2,750'MD ASL 6.0 518.0 86.3 111.3 . DeepCRETE 6.0 103.7 17.5 128.8 Drop top plug 0.0 0.0 5.0 133.8 CW8 5.0 10.0 2.0 135.8 Switch to rig 0.0 0.0 3.0 138.8 MOBM 8.0 337.0 42.1 180.9 Slow&bump plug 3.0 6.0 2.0 182.9 < 10-3/4",45.5#casing in 13-1/2"OH MUD REMOVAL Expected Mud Properties:9.6 ppg, Pv< 25, Ty< 35 TD at 3,741'MD (2,400'TVD) Spacer Properties: 10.5 ppg MudPUSH* II, Pv 20-25, Ty 30-35 Centralizers: As per CPAi program. Recommend minimal 3/2 joints from Shoe thru tail cement column * Mark of Schlumberger J R I G I N A L 2L-306 Schlumberger Ste..a c CemCADE Preliminary Job Design 7-5/8" Longstring (WP-02) V2 Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Location: Alpine Client: CPAI Revision Date: 12/10/2010 Volume Calculations and Cement Systems Prepared by: Steve Shultz Location:Anchorage,AK Volumes are based on 50% excess. The top of the tail slurry is designed to be Phone: (907)263-4297 -8,800' MD. Tail Slurry Minimum pump time: -220 min. (pump time plus 120 min.) 15.8 ppg Class G + 2.0 gps D6000 + 0.2%D46, 0.6%D65, 0.03 gps D177 - 1.17 ft3/sk 0.2148 ft3/ft x (11424'-8800')x 1.50 (50% excess)= 845 ft 3 0.2578 ft3/ft x 80' (Shoe Joint) = 21ft3 845 ft t-21 ft3 = 866 ft 3 Previous Csg. < 10-3/4",45.5.#casing 866 ft P1.17 ft3/sk = 740 sks at 3,741'MD BHST= 136°F, Estimated BHCT= 109°F. (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5.0 40.0 8.0 8.0 MUDPUSH II 5.0 40.0 8.0 16.0 Drop bottom plug 0.0 0.0 5.0 21.0 GasBLOK Slurry 6.0 154.0 25.6 46.6 Drop top plug 0.0 0.0 5.0 51.6 CW8 5.0 10.0 2.0 53.6 Switch to rig 0.0 0.0 3.0 56.6 MOBM 8.0 519.5 65.0 121.6 < Top of Cement at Slow&bump plug 3.0 6.0 2.0 123.6 8,800'MD MUD REMOVAL Expected Mud Properties: ppg, Pv < 25, Ty< 15. < 7-5/8",29.7#casing in 9-7/8"OH Spacer Properties: 11.5 ppg MudPUSH* II, Pv=20-25, Ty= 35 -40 Centralizers: As per COP program TD at 11,424'MD Recommended Centralizer Program: Bow spring @ 3 per 2 joints througout the expected (5,319'TVD) cement column. * Mark of Schlumberger O R I G I R I A L 2L-306 Stella Schlumberger ) CemCADE Preliminary Job Design 7-5/8" Longstring (WP-02) V2 Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Location: Alpine Client: CPAI Revision Date: 12/10/2010 Volume Calculations and Cement Systems Prepared by: Steve Shultz Volumes are based on 50% excess. The topof the tail slurryis designed to be Location:Anchorage,AK g Phone: (907)263-4297 -8,800' MD. Tail Slurry Minimum pump time: -220 min. (pump time plus 120 min.) 15.8 ppg Class G + 2.0 gps D600G + 0.2%D46, 0.6%D65, 0.03 gps D177- 1.17 ft3/sk 0.2148 ft3/ft x (11424'-8800')x 1.50 (50% excess)= 845 ft 3 I 0.2578 ft3/ft x 80' (Shoe Joint) = 21ft3 845 ft 3+ 21 ft3 = 866 ft 3 Previous Csg. 866 ft /31.17 ft3/sk= 740 sks < 10-3/4",45.5.#casing at 3,741'MD BHST= 136°F, Estimated BHCT = 109°F. (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Stage Cumulative Stage Pump Rate Volume Stage Time Time (bpm) (bbl) (min) (min) CW100 5.0 40.0 8.0 8.0 MUDPUSH II 5.0 40.0 8.0 16.0 Drop bottom plug 0.0 0.0 5.0 21.0 I GasBLOK Slurry 6.0 154.0 25.6 46.6 Drop top plug 0.0 0.0 5.0 51.6 CW8 5.0 10.0 2.0 53.6 Switch to rig 0.0 0.0 3.0 56.6 MOBM 8.0 519.5 65.0 121.6 < Top of Cement at Slow&bump plug 3.0 6.0 2.0 123.6 8,800'MD MUD REMOVAL Expected Mud Properties:9.0 ppg, Pv < 25, Ty< 15. < 7-5/8",29.7#casing in 9-7/8"OH Spacer Properties: 11.5 ppg MudPUSH* II, Pv= 20 -25, Ty= 35 -40 Centralizers: As per COP program r TD at 11,424'MD Recommended Centralizer Program: Bow spring @ 3 per 2 joints througout the expected (5,319'TVD) cement column. t * Mark of Schlumberger Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, December 20, 2010 9:47 AM To: 'steve.shultz@contractor.conocophillips.com' Cc: Davies, Stephen F (DOA) Subject: RE: 2L-306 (PTD 210-182) Steve, One more question... I was looking at the outline of the program for the drilling the intermediate section and Pilot hole. There is no mention of drilling to the specified PH target depth of 11963' in the plan at step#9. Can you elaborate and correct the procedure to include this and your plug back intentions??? An email should suffice and I can attach to the PTD application. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L(DOA) Sent: Monday, December 20, 2010 9:31 AM To: 'steve.shultz@contractor.conocophillips.com' Subject: 2L-306 (PTD 210-182) Steve, Can you send me the info for the 3.5" liner w/frac ports? It is not on the 401 cover page in section 18 (casing program). I can hand write it in if you send me the details. Most of it is already on the schematic. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 12/20/2010 2L. -"364 Pr° The proposed proposed drilling program is listed below. Please refer to Attachment 3:Well Schematic. 1. MIRU Doyon 15 on 2L-306 Conductor. 2. NU and function test diverter system and prepare spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. 4. Spud and directionally drill 13-1/2"hole to the 10-3/4"surface casing point(3,741'MD/2,400' TVD)according to the directional plan. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 5. Run and cement 10-3/4"45.5#L-80 BTC casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. Perform top job if required to bring cement to surface. 6. Nipple down diverter and install wellhead and test to 5000 psi. Nipple up BOPE and test to 3,500 psi. Notify state of BOP test. Record results. 7. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results. 8. Drill out cement and 20'minimum to 50'maximum of new hole.Perform LOT. 9. Directionally drill pilot hole to+/-1 1963'MD/5563'TVD, Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. POOH 10. RIH with openended drill pipe and spot a cement plug from 11963'MD back to+/-1 1300'MD, POOH 11. RIH with a 9 7/8"bit and directional BHA and sidetrack well at 1 1,300'MD/5287' TVD 12. Directionally drill 9-7/8"hole to 11,424'MD/5,319' TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 13. POOH and LD 5"drill pipe. Run 7-5/8"29.7#L-80 BTCM casing to 11,424'MD/5,319'TVD and cement in place. 14. PU horizontal directional BHA with 4"drill pipe,RIH,drillout shoe,and drill 6'/4"hole to 14,062'MD/543I'TVD. 15. POOH,LD 4"drill pipe 16. Run 3-1/2"completion tubing with packer and set at+/- 14,062'MD/5,431'TVD. 17. LD DP and associated equipment. ND BOP and rig up tree. Test tree and freeze protect annulus. Rig down and move out rig. The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Doyon 15 on 2L-306 Conductor. 2. NU and function test diverter system and prepare spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. 4. Spud and directionally drill 13-1/2"hole to the 10-3/4"surface casing point(3,741'MD/2,400' TVD)according to the directional plan. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 5. Run and cement 10-3/4"45.5#L-80 BTC casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. Perform top job if required to bring cement to surface. 6. Nipple down diverter and install wellhead and test to 5000 psi. Nipple up BOPE and test to 3,500 psi. Notify state of BOP test. Record results. 7. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results. 8. Drill out cement and 20'minimum to 50'maximum of new hole.Perform LOT. 9. Directionally drill pilot hole to+/-I 1963'MD/5563'TVD, Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. POOH 10. RIH with openended drill pipe and spot a cement plug from I I963'MD back to+/-1 1300'MD, POOH 11. RIH with a 9 7/8" bit and directional BHA and sidetrack well at 1 1,300'MD/5287' TVD 12. Directionally drill 9-7/8"hole to 11,424'MD/5,319' TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 13. POOH and LD 5"drill pipe. Run 7-5/8"29.7#L-80 BTCM casing to 11,424'MD/5,319' TVD and cement in place. 14. PU horizontal directional BHA with 4"drill pipe,RIH,drillout shoe,and drill 6'/4"hole to 14,062'MD/5431'TVD. 15. POOH,LD 4"drill pipe 16. Run 3-1/2"completion tubing with packer and set at+/- 14,062'MD/5,431'TVD. 17. LD DP and associated equipment. ND BOP and rig up tree. Test tree and freeze protect annulus. Rig down and move out rig. OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME l<,? X PTD# (1J r 2— l Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: Kt t,?r �� ( 1�,�c t—_POOL: r v� ° t ( V Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - . API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( G( Z1--' 3 PH) and API number 1 (50-/C j- 7 (te ' -'9) from records, data and logs acquired for well ./1 21el, SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce I inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 0 y N yN. N. ED- ' 7. • d : Cr 07 O N • O , >o -co; O d 3 m a) @ C a m •p t co > L L. co, E m. E. 0. O W u) a). N. o) E' co O C E O • o. , (° j. ma. � � >� (�°. O) •O, �, : — - y. '� °r vi • N o a) 0 3 3 -o, L, E u) c w , y, _ c'31 O 'o op as ._, Q' C) 0 ami' a 0 E co c c m, o. ° c o z o. w.co gW 3 > o L COGS �: a) 7. .LO.� Q1 p, a3 O N 73 �' o o' _ u) N' c .. M c Y 0 0 p O O 3 w ami >, v Cr v c _ _ 0 .;....H u („) 3 O Z oapQ, ° 3 °) u_ a) aO7 - L ' a • ' 5. � 0, C LVaN O Nl°Y C, O, . m .o 9. .2 U• c', .o.-61 c, yaas . t'° O a. 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E. c� -O o, (w. v. y, a= d E c. . ca, ayi as U c, Z C, C, a) U O O a) m. O. ,�°,, y. U , O a. C. >. >. O f° •O. 3' t O N. >' . c V a V. a O c .€ N 'Q o 0 0' E a, m m E. E. c = 3, a c .2 1 H 1- N .-' g i' c a' a' o; -' ,„LOU) co •N a :°, o a). a`o). c, a) a) a)' 7 a 4 4 a) a). CO, a) a 0 7. 2', 2', 2', ca, •°. _* v. '° •c. O. O. L, o a y y c° 'a). a). o. o V' c z; a, _1, S, 5', '5 �' CO — O, O, a a U, �' a', a, U U) U, U, U, U Q, Q, w a CO, m, U, �' cam', �' i d 0, CO, CO, U. W'°' 0. n w O N M v (n m Co O) O N M 'CZ! (n CC r a0 O) O N M V U) (O n OD O T+= E N. ,- N co V co co h co O) cp '- " 0) N N N N N CV CV CV N a') a') CO (•) (M C) M M M C') 0 O p O E. ,- .....4) o C CC w N ICC)) w N O c SEI' O C CO (p (° p a5 � O re 04 0 D O D N D r O ty/) o mEV N C c-:-, N E J„ N C9E C O uj p E a a) °q (.0 c a 0 > a Q < U W a C7 ( a Well History File APPS BIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Apr 08 14:26:18 2011 Reel Header Service name LISTPE Date 11/04/08 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 11/04/08 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Tarn MWD/MAD LOGS WELL NAME: 2L-306 API NUMBER: 501032063000 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling TAPE CREATION DATE: 08-APR-11 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: -MW-0007742775 -MW-0007742775 -MW-0007742775 LOGGING ENGINEER: JOE GRANADOS BENJAMIN SCH BENJAMIN SCH OPERATOR WITNESS: LARRY HILL LARRY HILL LARRY HILL MWD RUN 4 MWD RUN 6 JOB NUMBER: -MW-0007742775 -MW-0007742775 LOGGING ENGINEER: JOE GRANADOS BENJAMIN SCH OPERATOR WITNESS: RAY SPRINGER LARRY HILL SURFACE LOCATION SECTION: 22 TOWNSHIP: 10N RANGE: 7E FNL: 154 FSL: FEL: 588 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 155.15 GROUND LEVEL: 114.80 WELL CASING RECORD OPEN HOLE CASING DRILLERS 010-i'f0 203 BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.500 16.000 110.0 2ND STRING 9.875 10.750 3663.0 3RD STRING 6.750 7. 625 11473.0 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) . ONLY INVERT/ REVERT SECTIONS GREATER THAN 30'TVD ARE PRESENTED. 3. THIS SIDETRACK KICKED OFF OF A CEMENT PLUG AT 10979'MD/5192'TVD IN 2L-306 PB1. 4 . MWD RUNS 1-4, 6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTIL- IZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESIS- TIVITY PHASE-4 (EWR4) , AND DRILLSTRING DYNAMICS SENSOR (DDSr) . MWD RUNS 2-4, 6 ALSO INCLUDED AZIMUTHAL LITHO-DENSITY (ALD) , COMPENSATED THERMAL NEUTRON (CTN) , AND PRESSURE-WHILE-DRILLING (PWD) . MWD RUNS 2,3 ADDITIONALLY INCLUDED BI-MODAL ACOUSTIC TOOL (BAT) . SEE 2L-306 PB1 LOGS FOR BAT DATA. MWD RUN 5 WAS A CLEAN-OUT RUN - NO NEW HOLE WAS MADE. 5. LWD DATA ARE CONSIDERED PRIMARY DEPTH CONTROL PER E-MAIL FROM LISA WRIGHT (CPAI) TO BRYAN BURINDA (SD) DATED 12 JANUARY 2011. 6. MWD RUNS 1-4, 6 REPRESENT WELL 2L-306 WITH API#: 50-103-20630-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13, 157'MD/5446'TVD. MNEMONICS CURVE DESCRIPTION ROPA AVERAGE RATE OF PENETRATION DGRC DGR COMBINED GAMMA RAY RO9P 9 INCH PHASE RESISTIVITY R15P 15 INCH PHASE RESISTIVITY R27P 27 INCH PHASE RESISTIVITY R39P 39 INCH PHASE RESISTIVITY EWXT EWR FORMATION EXPOSURE TIME TNPS CTN POROSITY - SANDSTONE TNFA CTN FAR AVERAGE COUNT RATE TNNA CTN NEAR AVERAGE COUNT RATE ACDC ACAL COMPOSITE HOLE DIAMETER AHSI ALD HOLE-SIZE INDICATOR ACDL ALD LCRB COMPENSATED DENSITY ADCL ALD LCRB DENSITY CORRECTION APEL ALD LCRB Pe FACTOR ALRP ALD RPM (ZERO RPM'S INDICATES SLIDING) BTCS BAT COMPRESSIONAL SLOWNESS BCSS BAT COMBINED SHEAR SLOWNESS BVPS BAT VP/VS RATIO BSFG BAT SHEAR FLAG PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: FIXED HOLE SIZE - 6.75" & 9.875" BITS MUD WEIGHT: 9.45 - 9. 95 PPG MUD SALINITY: 600 - 37,000 PPM CHLORIDES FORMATION WATER SALINITY: 19149 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2. 65 G/CM3 LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0. 6 FT, EXCEPT FOR ROP, AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. BTCS, BCSS, BVPS CURVES ARE SMOOTHED WITH A 2.0 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/08 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 245.0 13102.5 FET 255.0 13109.0 RPS 255.0 13109.0 RPX 255.0 13109.0 RPM 255.0 13109.0 RPD 255.0 13109.0 ROP 311.5 13157.0 DRHO 3655.0 13080.0 CALN 3655.0 13037.5 PEF 3655.0 13080.0 NPHI 3655.0 13065.0 RHOB 3655.0 13080.0 FCNT 3655.0 13065.0 NCNT 3655.0 13065.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 245.0 3672.0 MWD 2 3672.0 9401.0 MWD 3 9401.0 10979.0 MWD 4 10979.5 11488.0 MWD 6 11488.0 13157.0 REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .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 RHOB MWD G/CC 4 1 68 4 2 DRHO MWD G/CC 4 1 68 8 3 CALN MWD IN 4 1 68 12 4 PEF MWD B/E 4 1 68 16 5 GR MWD API 4 1 68 20 6 FET MWD HR 4 1 68 24 7 RPX MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPM MWD OHMM 4 1 68 36 10 RPD MWD OHMM 4 1 68 40 11 ROP MWD FPH 4 1 68 44 12 FCNT MWD CP30 4 1 68 48 13 NCNT MWD CP30 4 1 68 52 14 NPHI MWD PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 245 13157 6701 25825 245 13157 RHOB MWD G/CC 0. 603 2.969 2.30484 18744 3655 13080 DRHO MWD G/CC -2.246 0.491 0.0627502 18744 3655 13080 CALN MWD IN 5. 69 12.88 9.3095 15076 3655 13037.5 PEF MWD B/E 1. 63 15.68 3.03979 18744 3655 13080 GR MWD API 18.24 230.23 110.07 25716 245 13102.5 FET MWD HR 0.16 260.1 1.91459 25586 255 13109 RPX MWD OHMM 0.21 1581.55 6.89542 25586 255 13109 RPS MWD OHMM 0.24 1621.71 8.57301 25586 255 13109 RPM MWD OHMM 0.52 1703.84 10. 6005 25586 255 13109 RPD MWD OHMM 0.81 2000 14.3783 25586 255 13109 ROP MWD FPH 0.32 580.64 149.311 25692 311.5 13157 FCNT MWD CP30 207.31 2442.55 695.467 18686 3655 13065 NCNT MWD CP30 18995.5 170491 108584 18686 3655 13065 NPHI MWD PU 7. 69 57.57 31.3712 18686 3655 13065 First Reading For Entire File 245 Last Reading For Entire File 13157 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/08 Maximum Physical Record65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/08 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 245.0 3605.0 R09P 255.0 3615.0 R39P 255.0 3615.0 R27P 255.0 3615.0 R15P 255.0 3615.0 EWXT 255.0 3615.0 ROPA 311.5 3672.0 LOG HEADER DATA DATE LOGGED: 03-MAR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 3672.0 TOP LOG INTERVAL (FT) : 245.0 BOTTOM LOG INTERVAL (FT) : 3672.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: . 1 MAXIMUM ANGLE: 71.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 149206 EWR4 ELECTROMAG. RESIS. 4 81797 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 13.500 DRILLER'S CASING DEPTH (FT) : 110.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) : 9.60 MUD VISCOSITY (S) : 308.0 MUD PH: 8.8 MUD CHLORIDES (PPM) : 610 FLUID LOSS (C3) : 6.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2.600 61.0 MUD AT MAX CIRCULATING TERMPERATURE: 1. 950 83. 6 MUD FILTRATE AT MT: 3.900 62.0 MUD CAKE AT MT: 2.900 61.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 FET MWD010 HR 4 1 68 8 3 RPX MWDO10 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWDO10 OHMM 4 1 68 24 7 ROP MWD010 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 245 3672 1958.5 6855 245 3672 GR MWD010 API 18.24 139.44 81.6488 6721 245 3605 FET MWD010 HR 0.16 8.07 0.965462 6721 255 3615 RPX MWDO10 OHMM 0.76 92.5 13.3302 6721 255 3615 RPS MWD010 OHMM 0.71 330. 66 18.4648 6721 255 3615 RPM MWD010 OHMM 0.71 692.31 24 .2865 6721 255 3615 RPD MWD010 OHMM 0.97 1726.05 34.4381 6721 255 3615 ROP MWDO10 FPH 1.9 580.64 175.121 6722 311.5 3672 First Reading For Entire File 245 Last Reading For Entire File 3672 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/08 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/08 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 3605.5 9341.5 R39P 3655.0 9351.5 R27P 3655.0 9351.5 R15P 3655.0 9351.5 TNFA 3655.0 9306.5 R09P 3655.0 9351.5 TNNA 3655.0 9306.5 APEL 3655.0 9320.5 TNPS 3655.0 9306.5 AHSI 3655.0 9320.5 ADCL 3655.0 9320.5 ACDL 3655.0 9320.5 EWXT 3655.0 9351.5 ROPA 3672.5 9401.0 LOG HEADER DATA DATE LOGGED: 13-MAR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 9401.0 TOP LOG INTERVAL (FT) : 3672.0 BOTTOM LOG INTERVAL (FT) : 9401.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 65. 6 MAXIMUM ANGLE: 70.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 277300 EWR4 ELECTROMAG. RESIS. 4 127479 CTN COMP THERMAL NEUTRON 11256612 BAT Bi-modal Acoustic 11462979 ALD Azimuthal Litho-Dens 144855 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 9.875 DRILLER'S CASING DEPTH (FT) : 3663.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9. 60 MUD VISCOSITY (S) : 47.0 MUD PH: 9.3 MUD CHLORIDES (PPM) : 600 FLUID LOSS (C3) : 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1.250 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .640 143.0 MUD FILTRATE AT MT: . 950 70.0 MUD CAKE AT MT: 1.150 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 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 RHOB MWD020 G/CC 4 1 68 4 2 DRHO MWD020 G/CC 4 1 68 8 3 CALN MWD020 IN 4 1 68 12 4 PEF MWD020 B/E 4 1 68 16 5 GR MWD020 API 4 1 68 20 6 FET MWD020 HR 4 1 68 24 7 RPX MWD020 OHMM 4 1 68 28 8 RPS MWD020 OHMM 4 1 68 32 9 RPM MWD020 OHMM 4 1 68 36 10 RPD MWD020 OHMM 4 1 68 40 11 ROP MWD020 FPH 4 1 68 44 12 FCNT MWD020 CP30 4 1 68 48 13 NCNT MWD020 CP30 4 1 68 52 14 NPHI MWD020 PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3605.5 9401 6503.25 11592 3605.5 9401 RHOB MWD020 G/CC 1.64 2.79 2.25661 11332 3655 9320.5 DRHO MWD020 G/CC -1.357 0.347 0.0434302 11332 3655 9320.5 CALN MWD020 IN 8.25 12.88 9.74142 10809 3655 9320.5 PEF MWD020 B/E 1.63 15.68 2.62716 11332 3655 9320.5 GR MWD020 API 35.74 230.23 120.402 11473 3605.5 9341.5 FET MWD020 HR 0.23 114.39 1.47555 11394 3655 9351.5 RPX MWD020 OHMM 1.28 25.84 4.02896 11394 3655 9351.5 RPS MWD020 OHMM 0.71 25.98 4.29937 11394 3655 9351.5 RPM MWD020 OHMM 1.81 129.23 4. 69161 11394 3655 9351.5 RPD MWD020 OHMM 1.14 2000 7. 62155 11394 3655 9351.5 ROP MWD020 FPH 1.43 419. 63 158.86 11458 3672.5 9401 FCNT MWD020 CP30 504. 67 2442.55 725.898 11304 3655 9306.5 NCNT MWD020 CP30 109070 170491 126299 11304 3655 9306.5 NPHI MWD020 PU 8.98 57.57 33.4306 11304 3655 9306.5 First Reading For Entire File 3605.5 Last Reading For Entire File 9401 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/08 Maximum Physical Record65535 File Type LO Next File Name STSLIB.004 Physical EOF File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/08 Maximum Physical Record65535 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 TNFA 9307.0 10979.0 TNNA 9307.0 10979.0 TNPS 9307.0 10979.0 APEL 9321.0 10979.0 ADCL 9321.0 10979.0 ACDL 9321.0 10979.0 DGRC 9342.0 10979.0 R09P 9352.0 10979.0 R27P 9352.0 10979.0 R15P 9352.0 10979.0 EWXT 9352.0 10979.0 R39P 9352.0 10979.0 AHSI 9381.0 10979.0 ROPA 9401.5 10979.0 LOG HEADER DATA DATE LOGGED: 16-MAR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 10979.0 TOP LOG INTERVAL (FT) : 9401.0 BOTTOM LOG INTERVAL (FT) : 10979.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 59.4 MAXIMUM ANGLE: 69.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 11321777 EWR4 ELECTROMAG. RESIS. 4 231951 CTN COMP THERMAL NEUTRON 181187 BAT Bi-modal Acoustic 11462979 ALD Azimuthal Litho-Dens 105254 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 9.875 DRILLER'S CASING DEPTH (FT) : 3663.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9. 60 MUD VISCOSITY (S) : 42.0 MUD PH: 9. 6 MUD CHLORIDES (PPM) : 600 FLUID LOSS (C3) : 3.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1.700 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .850 146.3 MUD FILTRATE AT MT: 1.350 70.0 MUD CAKE AT MT: 1.550 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 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 RHOB MWD030 G/CC 4 1 68 4 2 DRHO MWD030 G/CC 4 1 68 8 3 CALN MWD030 IN 4 1 68 12 4 PEF MWD030 B/E 4 1 68 16 5 GR MWD030 API 4 1 68 20 6 FET MWD030 HR 4 1 68 24 7 RPX MWD030 OHMM 4 1 68 28 8 RPS MWD030 OHMM 4 1 68 32 9 RPM MWD030 OHMM 4 1 68 36 10 RPD MWD030 OHMM 4 1 68 40 11 ROP MWD030 FPH 4 1 68 44 12 FCNT MWD030 CP30 4 1 68 48 13 NCNT MWD030 CP30 4 1 68 52 14 NPHI MWD030 PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9307 10979 10143 3345 9307 10979 RHOB MWD030 G/CC 1. 608 2. 692 2.38677 3317 9321 10979 DRHO MWD030 G/CC -0.039 0.336 0.0613367 3317 9321 10979 CALN MWD030 IN 8.78 11.54 10.0285 1515 9381 10979 PEF MWD030 B/E 1. 94 6.22 2.94295 3317 9321 10979 GR MWD030 API 54.46 182.56 123. 602 3275 9342 10979 FET MWD030 HR 0.31 27.98 1.62654 3255 9352 10979 RPX MWD030 OHMM 1.34 39.41 3.87068 3255 9352 10979 RPS MWD030 OHMM 1.4 46. 63 4.15018 3255 9352 10979 RPM MWD030 OHMM 1.44 38.8 4.32854 3255 9352 10979 RPD MWD030 OHMM 1.51 26. 93 4.40334 3255 9352 10979 ROP MWD030 FPH 0.32 412.54 140.071 3156 9401.5 10979 FCNT MWD030 CP30 518.98 2248.77 758.986 3345 9307 10979 NCNT MWD030 CP30 106687 158783 122504 3345 9307 10979 NPHI MWD030 PU 7.69 49.12 30.5541 3345 9307 10979 First Reading For Entire File 9307 Last Reading For Entire File 10979 File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/08 Maximum Physical Record65535 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 11/04/08 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH APEL 10979.5 11406.0 DGRC 10979.5 11427.5 R27P 10979.5 11437.5 TNFA 10979.5 11392.0 EWXT 10979.5 11437.5 R09P 10979.5 11437.5 TNNA 10979.5 11392.0 AHSI 10979.5 11369.5 ROPA 10979.5 11488.0 ADCL 10979.5 11406.0 R15P 10979.5 11437.5 R39P 10979.5 11437.5 TNPS 10979.5 11392.0 ACDL 10979.5 11406.0 LOG HEADER DATA DATE LOGGED: 21-MAR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 11488.0 TOP LOG INTERVAL (FT) : 10979.0 BOTTOM LOG INTERVAL (FT) : 11488.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 68.9 MAXIMUM ANGLE: 71.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 11321777 EWR4 ELECTROMAG. RESIS. 4 231951 CTN COMP THERMAL NEUTRON 181187 ALD Azimuthal Litho-Dens 105254 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 9.875 DRILLER'S CASING DEPTH (FT) : 3663.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.70 MUD VISCOSITY (S) : 68.0 MUD PH: 9.8 MUD CHLORIDES (PPM) : 700 FLUID LOSS (C3) : 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1.250 67.0 MUD AT MAX CIRCULATING TERMPERATURE: . 620 139.7 MUD FILTRATE AT MT: 1.200 67.0 MUD CAKE AT MT: 1.350 67.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .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 RHOB MWD040 G/CC 4 1 68 4 2 DRHO MWD040 G/CC 4 1 68 8 3 CALN MWD040 IN 4 1 68 12 4 PEF MWD040 B/E 4 1 68 16 5 GR MWD040 API 4 1 68 20 6 FET MWD040 HR 4 1 68 24 7 RPX MWD040 OHMM 4 1 68 28 8 RPS MWD040 OHMM 4 1 68 32 9 RPM MWD040 OHMM 4 1 68 36 10 RPD MWD040 OHMM 4 1 68 40 11 ROP MWD040 FPH 4 1 68 44 12 FCNT MWD040 CP30 4 1 68 48 13 NCNT MWD040 CP30 4 1 68 52 14 NPHI MWD040 PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10979.5 11488 11233.8 1018 10979.5 11488 RHOB MWD040 G/CC 1.873 2. 642 2.42485 854 10979.5 11406 DRHO MWD040 G/CC -0.017 0.324 0.0631651 854 10979.5 11406 CALN MWD040 IN 8. 66 10.77 9.69845 483 10979.5 11369.5 PEF MWD040 B/E 1. 98 5.43 3.20186 854 10979.5 11406 GR MWD040 API 70. 91 177.2 139.684 897 10979.5 11427.5 FET MWD040 HR 0.43 136. 6 1.33631 917 10979.5 11437.5 RPX MWD040 OHMM 1.09 7.71 3.854 917 10979.5 11437.5 RPS MWD040 OHMM 1.21 9.21 4.33843 917 10979.5 11437.5 RPM MWD040 OHMM 1.33 14.73 4.90426 917 10979.5 11437.5 RPD MWD040 OHMM 1.37 13.69 5.09017 917 10979.5 11437.5 ROP MWD040 FPH 8. 68 271.59 99.593 1018 10979.5 11488 FCNT MWD040 CP30 492.79 1352 822. 665 826 10979.5 11392 NCNT MWD040 CP30 104817 159279 126470 826 10979.5 11392 NPHI MWD040 PU 15.73 50.62 28.2795 826 10979.5 11392 First Reading For Entire File 10979.5 Last Reading For Entire File 11488 File Trailer Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/08 Maximum Physical Record65535 File Type LO Next File Name STSLIB.006 Physical EOF File Header Service name STSLIB.006 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/08 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 11428.0 13102.5 TNFA 11460.0 13065.0 APEL 11460.0 13080.0 EWXT 11460.0 13109.0 TNNA 11460.0 13065.0 TNPS 11460.0 13065.0 ADCL 11460.0 13080.0 AHSI 11460.0 13037.5 RO9P 11460.0 13109.0 R27P 11460.0 13109.0 ACDL 11460.0 13080.0 R15P 11460.0 13109.0 R39P 11460.0 13109.0 ROPA 11488.5 13157.0 LOG HEADER DATA DATE LOGGED: 03-APR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 13157.0 TOP LOG INTERVAL (FT) : 11488.0 BOTTOM LOG INTERVAL (FT) : 13157.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 73.0 MAXIMUM ANGLE: 93.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 272793 CTN COMP THERMAL NEUTRON 274120 EWR4 Electromag Resis. 4 11274400 ALD Azimuthal Litho-Dens 10508947 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6.750 DRILLER'S CASING DEPTH (FT) : 11473.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9. 90 MUD VISCOSITY (S) : 45.0 MUD PH: 9.3 MUD CHLORIDES (PPM) : 36500 FLUID LOSS (C3) : 7.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .140 67.0 MUD AT MAX CIRCULATING TERMPERATURE: .070 136.6 MUD FILTRATE AT MT: .120 67.0 MUD CAKE AT MT: .120 67.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RHOB MWD060 G/CC 4 1 68 4 2 DRHO MWD060 G/CC 4 1 68 8 3 CALN MWD060 IN 4 1 68 12 4 PEF MWD060 B/E 4 1 68 16 5 GR MWD060 API 4 1 68 20 6 FET MWD060 HR 4 1 68 24 7 RPX MWD060 OHMM 4 1 68 28 8 RPS MWD060 OHMM 4 1 68 32 9 RPM MWD060 OHMM 4 1 68 36 10 RPD MWD060 OHMM 4 1 68 40 11 ROP MWD060 FPH 4 1 68 44 12 FCNT MWD060 CP30 4 1 68 48 13 NCNT MWD060 CP30 4 1 68 52 14 NPHI MWD060 PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11428 13157 12292.5 3459 11428 13157 RHOB MWD060 G/CC 0.603 2. 969 2.35798 3241 11460 13080 DRHO MWD060 0/CC -2.246 0.491 0.131639 3241 11460 13080 CALN MWD060 IN 5.69 9.22 6.68902 2269 11460 13037.5 PEF MWD060 B/E 1.95 13.27 4.53897 3241 11460 13080 GR MWD060 API 63.13 160.67 110.545 3350 11428 13102.5 FET MWD060 HR 0.46 260.1 5.80955 3299 11460 13109 RPX MWD060 OHMM 0.21 1581.55 7.51582 3299 11460 13109 RPS MWD060 OHMM 0.24 1621.71 8.72164 3299 11460 13109 RPM MWD060 OHMM 0.52 1703.84 10.8977 3299 11460 13109 RPD MWD060 OHMM 0.81 1804.31 9.2708 3299 11460 13109 ROP MWD060 FPH 1.22 260.35 88.4523 3338 11488.5 13157 FCNT MWD060 CP30 207.31 1210.52 489.449 3211 11460 13065 NCNT MWD060 CP30 18995.5 40180. 6 27117.4 3211 11460 13065 NPHI MWD060 PU 14.21 42.31 25.7675 3211 11460 13065 First Reading For Entire File 11428 Last Reading For Entire File 13157 File Trailer Service name STSLIB.006 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/08 Maximum Physical Record65535 File Type LO Next File Name STSLIB.007 Physical EOF Tape Trailer Service name LISTPE Date 11/04/08 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 11/04/08 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Apr 06 13:31:29 2011 Reel Header Service name LISTPE Date 11/04/06 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 11/04/06 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Tarn MWD/MAD LOGS WELL NAME: 2L-306 PB1 API NUMBER: 501032063070 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling TAPE CREATION DATE: 06-APR-11 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: -MW-0007742775 -MW-0007742775 -MW-0007742775 LOGGING ENGINEER: JOE GRANADOS BENJAMIN SCH BENJAMIN SCH OPERATOR WITNESS: LARRY HILL LARRY HILL LARRY HILL SURFACE LOCATION SECTION: 22 TOWNSHIP: lON RANGE: 7E FNL: 154 FSL: FEL: 588 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 155.15 GROUND LEVEL: 114.80 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.500 16.000 110.0 2ND STRING 9.875 10.750 3663.0 3RD STRING PRODUCTION STRING ato- /46a 20 3 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3. MWD RUNS 1-3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) , AND DRILLSTRING DYNAMICS SENSOR (DDSr) . MWD RUNS 2, 3 ALSO INCLUDED AZIMUTHAL LITHO-DENSITY (ALD) , COMPENSATED THERMAL NEUTRON (CTN) , BI-MODAL ACOUSTIC TOOL (BAT) , AND PRESSURE-WHILE- DRILLING (PWD) . 4 . LWD DATA ARE CONSIDERED PRIMARY DEPTH CONTROL PER E-MAIL FROM LISA WRIGHT (CPAI) TO BRYAN BURINDA (SD) DATED 12 JANUARY 2011. 5. MWD RUNS 1-3 REPRESENT WELL 2L-306 PB1 WITH API#: 50-103-20630-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11, 824 'MD/5563'TVD. MNEMONICS CURVE DESCRIPTION ROPA AVERAGE RATE OF PENETRATION DGRC DGR COMBINED GAMMA RAY R09P 9 INCH PHASE RESISTIVITY R15P 15 INCH PHASE RESISTIVITY R27P 27 INCH PHASE RESISTIVITY R39P 39 INCH PHASE RESISTIVITY EWXT EWR FORMATION EXPOSURE TIME TNPS CTN POROSITY - SANDSTONE TNFA CTN FAR AVERAGE COUNT RATE TNNA CTN NEAR AVERAGE COUNT RATE ACDC ACAL COMPOSITE HOLE DIAMETER AHSI ALD HOLE-SIZE INDICATOR ACDL ALD LCRB COMPENSATED DENSITY ADCL ALD LCRB DENSITY CORRECTION APEL ALD LCRB Pe FACTOR ALRP ALD RPM (ZERO RPM'S INDICATES SLIDING) BTCS BAT COMPRESSIONAL SLOWNESS BCSS BAT COMBINED SHEAR SLOWNESS BVPS BAT VP/VS RATIO BSFG BAT SHEAR FLAG PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: FIXED HOLE SIZE - 9.875" BIT MUD WEIGHT: 9.45 - 9.75 PPG MUD SALINITY: 600 PPM CHLORIDES FORMATION WATER SALINITY: 19149 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0. 6 FT, EXCEPT FOR ROP, AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. BTCS, BCSS, BVPS CURVES ARE SMOOTHED WITH A 2.0 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. GAP FILL IS SET TO 5 FT FOR ALL CURVES. $ File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 245.0 11761.5 RPX 255.0 11771.5 RPD 255.0 11771.5 RPM 255.0 11771.5 FET 255.0 11771.5 RPS 255.0 11771.5 ROP 311.5 11824.0 PEF 3655.0 11740.0 NCNT 3655.0 11726.0 DRHO 3655.0 11740.0 NPHI 3655.0 11726.0 CALN 3655.0 11740.0 FCNT 3655.0 11726.0 RHOB 3655.0 11740.0 DTC 3671.5 11711.0 SCRA 3691.0 11711.0 DTSH 3691.0 11711.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 245.0 3672.0 MWD 2 3672.0 9401.0 MWD 3 9401.0 11824.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RHOB MWD G/CC 4 1 68 4 2 DRHO MWD G/CC 4 1 68 8 3 CALN MWD IN 4 1 68 12 4 PEF MWD B/E 4 1 68 16 5 DTC MWD USPF 4 1 68 20 6 DTSH MWD USPF 4 1 68 24 7 SCRA MWD NONE 4 1 68 28 8 GR MWD API 4 1 68 32 9 FET MWD HR 4 1 68 36 10 RPX MWD OHMM 4 1 68 40 11 RPS MWD OHMM 4 1 68 44 12 RPM MWD OHMM 4 1 68 48 13 RPD MWD OHMM 4 1 68 52 14 ROP MWD FPH 4 1 68 56 15 FCNT MWD CP30 4 1 68 60 16 NCNT MWD CP30 4 1 68 64 17 NPHI MWD PU 4 1 68 68 18 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 245 11824 6034.5 23159 245 11824 RHOB MWD G/CC 1.608 2.79 2.29763 16171 3655 11740 DRHO MWD G/CC -1.357 0.347 0.0476612 16171 3655 11740 CALN MWD IN 8.25 12.88 9.80112 13650 3655 11740 PEF MWD B/E 1.63 15. 68 2.71909 16171 3655 11740 DTC MWD USPF 57.63 127.24 101.068 16080 3671.5 11711 DTSH MWD USPF 104.82 242. 63 185.2 10474 3691 11711 SCRA MWD NONE 1.12 3.1 1.89764 10474 3691 11711 GR MWD API 18.24 230.23 110.586 23034 245 11761.5 FET MWD HR 0.16 114 .39 1.30464 22955 255 11771.5 RPX MWD OHMM 0.76 92.5 6.76097 22955 255 11771.5 RPS MWD OHMM 0.71 330.66 8.47009 22955 255 11771.5 RPM MWD OHMM 0.71 692.31 10.4206 22955 255 11771.5 RPD MWD OHMM 0.79 2000 14.8711 22955 255 11771.5 ROP MWD FPH 0.32 580.64 156.451 23026 311.5 11824 FCNT MWD CP30 504 . 67 2442.55 745.527 16143 3655 11726 NCNT MWD CP30 106687 170491 125705 16143 3655 11726 NPHI MWD PU 7.69 57.57 32.2763 16143 3655 11726 First Reading For Entire File 245 Last Reading For Entire File 11824 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 245.0 3605.0 EWXT 255.0 3615.0 R27P 255.0 3615.0 R15P 255.0 3615.0 R09P 255.0 3615.0 R39P 255.0 3615.0 ROPA 311.5 3672.0 LOG HEADER DATA DATE LOGGED: 03-MAR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 3672.0 TOP LOG INTERVAL (FT) : 245.0 BOTTOM LOG INTERVAL (FT) : 3672.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 71.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 149206 EWR4 ELECTROMAG. RESIS. 4 81797 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 13.500 DRILLER'S CASING DEPTH (FT) : .0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) : 9.60 MUD VISCOSITY (S) : 308.0 MUD PH: 8.8 MUD CHLORIDES (PPM) : 610 FLUID LOSS (C3) : 6.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2. 600 61.0 MUD AT MAX CIRCULATING TERMPERATURE: 1. 950 83. 6 MUD FILTRATE AT MT: 3. 900 62.0 MUD CAKE AT MT: 2. 900 61.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD010 API 4 1 68 4 2 FET MWD010 HR 4 1 68 8 3 RPX MWDO10 OHMM 4 1 68 12 4 RPS MWDO10 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 ROP MWD010 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 245 3672 1958.5 6855 245 3672 GR MWD010 API 18.24 139.44 81.6488 6721 245 3605 FET MWD010 HR 0.16 8.07 0.965462 6721 255 3615 RPX MWD010 OHMM 0.76 92.5 13.3302 6721 255 3615 RPS MWD010 OHMM 0.71 330. 66 18.4648 6721 255 3615 RPM MWD010 OHMM 0.71 692.31 24.2865 6721 255 3615 RPD MWDO10 OHMM 0. 97 1726.05 34.4381 6721 255 3615 ROP MWDO10 FPH 1.9 580. 64 175.121 6722 311.5 3672 First Reading For Entire File 245 Last Reading For Entire File 3672 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 3605.5 9341.5 TNPS 3655.0 9306.5 AHSI 3655.0 9320.5 APEL 3655.0 9320.5 ACDL 3655.0 9320.5 R39P 3655.0 9351.5 R09P 3655.0 9351.5 TNNA 3655.0 9306.5 R15P 3655.0 9351.5 R27P 3655.0 9351.5 TNFA 3655.0 9306.5 EWXT 3655.0 9351.5 ADCL 3655.0 9320.5 BTCS 3671.5 9291.5 ROPA 3672.5 9401.0 BCSS 3691.0 9215.0 BVPS 3691.0 9215.0 LOG HEADER DATA DATE LOGGED: 13-MAR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 9401.0 TOP LOG INTERVAL (FT) : 3672.0 BOTTOM LOG INTERVAL (FT) : 9401.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 65.6 MAXIMUM ANGLE: 70.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 277300 EWR4 ELECTROMAG. RESIS. 4 127479 CTN COMP THERMAL NEUTRON 11256612 BAT Bi-modal Acoustic 11462979 ALD Azimuthal Litho-Dens 144855 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 9.875 DRILLER'S CASING DEPTH (FT) : 3663.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9. 60 MUD VISCOSITY (S) : 47.0 MUD PH: 9.3 MUD CHLORIDES (PPM) : 600 FLUID LOSS (C3) : 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1.250 70.0 MUD AT MAX CIRCULATING TERMPERATURE: . 640 143.0 MUD FILTRATE AT MT: . 950 70.0 MUD CAKE AT MT: 1. 150 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 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 RHOB MWD020 G/CC 4 1 68 4 2 DRHO MWD020 G/CC 4 1 68 8 3 CALN MWD020 IN 4 1 68 12 4 PEF MWD020 B/E 4 1 68 16 5 DTC MWD020 USPF 4 1 68 20 6 DTSH MWD020 USPF 4 1 68 24 7 SCRA MWD020 NONE 4 1 68 28 8 GR MWD020 API 4 1 68 32 9 FET MWD020 HR 4 1 68 36 10 RPX MWD020 OHMM 4 1 68 40 11 RPS MWD020 OHMM 4 1 68 44 12 RPM MWD020 OHMM 4 1 68 48 13 RPD MWD020 OHMM 4 1 68 52 14 ROP MWD020 FPH 4 1 68 56 15 FCNT MWD020 CP30 4 1 68 60 16 NCNT MWD020 CP30 4 1 68 64 17 NPHI MWD020 PU 4 1 68 68 18 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3605.5 9401 6503.25 11592 3605.5 9401 RHOB MWD020 G/CC 1.64 2.79 2.25661 11332 3655 9320.5 DRHO MWD020 G/CC -1.357 0.347 0.0434302 11332 3655 9320.5 CALN MWD020 IN 8.25 12.88 9.74142 10809 3655 9320.5 PEF MWD020 B/E 1.63 15.68 2. 62716 11332 3655 9320.5 DTC MWD020 USPF 61.05 127.24 104.669 11241 3671.5 9291.5 DTSH MWD020 USPF 109.57 242.63 199.593 5860 3691 9215 SCRA MWD020 NONE 1.12 3.1 1. 96662 5860 3691 9215 GR MWD020 API 35.74 230.23 120.402 11473 3605.5 9341.5 FET MWD020 HR 0.23 114.39 1.47555 11394 3655 9351.5 RPX MWD020 OHMM 1.28 25.84 4.02896 11394 3655 9351.5 RPS MWD020 OHMM 0.71 25.98 4.29937 11394 3655 9351.5 RPM MWD020 OHMM 1.81 129.23 4.69161 11394 3655 9351.5 RPD MWD020 OHMM 1.14 2000 7. 62155 11394 3655 9351.5 ROP MWD020 FPH 1.43 419.63 158.86 11458 3672.5 9401 FCNT MWD020 CP30 504.67 2442.55 725.898 11304 3655 9306.5 NCNT MWD020 CP30 109070 170491 126299 11304 3655 9306.5 NPHI MWD020 PU 8.98 57.57 33.4306 11304 3655 9306.5 First Reading For Entire File 3605.5 Last Reading For Entire File 9401 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Next File Name STSLIB.004 Physical EOF File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 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 BTCS 9292.0 11711.0 TNPS 9307.0 11726.0 TNNA 9307.0 11726.0 TNFA 9307.0 11726.0 ADCL 9321.0 11740.0 APEL 9321.0 11740.0 ACDL 9321.0 11740.0 DGRC 9342.0 11761.5 EWXT 9352.0 11771.5 R27P 9352.0 11771.5 R15P 9352.0 11771.5 RO9P 9352.0 11771.5 R39P 9352.0 11771.5 AHSI 9381.0 11740.0 ROPA 9401.5 11824.0 BCSS 9404.5 11711.0 BVPS 9404.5 11711.0 LOG HEADER DATA DATE LOGGED: 16-MAR-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.20 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 11824.0 TOP LOG INTERVAL (FT) : 9401.0 BOTTOM LOG INTERVAL (FT) : 11824.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 59.4 MAXIMUM ANGLE: 69.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 11321777 EWR4 ELECTROMAG. RESIS. 4 231951 CTN COMP THERMAL NEUTRON 181187 BAT Bi-modal Acoustic 11462979 ALD Azimuthal Litho-Dens 105254 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 9.875 DRILLER'S CASING DEPTH (FT) : 3663.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.60 MUD VISCOSITY (S) : 42.0 MUD PH: 9.6 MUD CHLORIDES (PPM) : 600 FLUID LOSS (C3) : 3.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1.700 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .840 148.5 MUD FILTRATE AT MT: 1.350 70.0 MUD CAKE AT MT: 1.550 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 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 RHOB MWD030 G/CC 4 1 68 4 2 DRHO MWD030 G/CC 4 1 68 8 3 CALN MWD030 IN 4 1 68 12 4 PEF MWD030 B/E 4 1 68 16 5 DTC MWD030 USPF 4 1 68 20 6 DTSH MWD030 USPF 4 1 68 24 7 SCRA MWD030 NONE 4 1 68 28 8 GR MWD030 API 4 1 68 32 9 FET MWD030 HR 4 1 68 36 10 RPX MWD030 OHMM 4 1 68 40 11 RPS MWD030 OHMM 4 1 68 44 12 RPM MWD030 OHMM 4 1 68 48 13 RPD MWD030 OHMM 4 1 68 52 14 ROP MWD030 FPH 4 1 68 56 15 FCNT MWD030 CP30 4 1 68 60 16 NCNT MWD030 CP30 4 1 68 64 17 NPHI MWD030 PU 4 1 68 68 18 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9292 11824 10558 5065 9292 11824 RHOB MWD030 G/CC 1. 608 2.692 2.39368 4839 9321 11740 DRHO MWD030 G/CC -0.039 0.336 0.0575693 4839 9321 11740 CALN MWD030 IN 8.78 11.54 10.0282 2841 9381 11740 PEF MWD030 B/E 1.85 6.22 2.93438 4839 9321 11740 DTC MWD030 USPF 57. 63 110.38 92.7037 4839 9292 11711 DTSH MWD030 USPF 104 .82 222.3 166.921 4614 9404.5 11711 SCRA MWD030 NONE 1.42 2.76 1.81003 4614 9404.5 11711 GR MWD030 API 54.46 182.56 127.498 4840 9342 11761.5 FET MWD030 HR 0.31 27. 98 1.37331 4840 9352 11771.5 RPX MWD030 OHMM 0.99 39.41 4.07022 4840 9352 11771.5 RPS MWD030 OHMM 0.95 46.63 4.40947 4840 9352 11771.5 RPM MWD030 OHMM 0.83 38.8 4. 65246 4840 9352 11771.5 RPD MWD030 OHMM 0.79 26. 93 4.76607 4840 9352 11771.5 ROP MWD030 FPH 0.32 412.54 124.858 4846 9401.5 11824 FCNT MWD030 CP30 518.98 2248.77 791.379 4839 9307 11726 NCNT MWD030 CP30 106687 159342 124316 4839 9307 11726 NPHI MWD030 PU 7.69 49.12 29.5798 4839 9307 11726 First Reading For Entire File 9292 Last Reading For Entire File 11824 File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 11/04/06 Maximum Physical Record65535 File Type LO Next File Name STSLIB.005 Physical EOF Tape Trailer Service name LISTPE Date 11/04/06 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 11/04/06 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File COnocoPh i l l i s p Alaska, Inc. FINAL WELL REPORT MUDLOGGING DATA 2L-306 2L-306PB1 ALL: CANRIG ,),,„it.(..,..CFIwnA,C.V I.II), Approved by: Lisa H. Wright Compiled by: Josh Dubowski Larry Resch Dan Sherwood Distribution: April 25, 2011 Date: April 4, 2011 ConocoPhillips Alaska.Inc. 2L-306 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT& CREW 3 1.1 Equipment Summary 3 1.2 Crew 3 2 WELL DETAILS 4 2.1 Well Summary 4 2.2 Hole Data 4 3 GEOLOGICAL DATA 5 3.1 Formation Tops* 5 3.2 Lithologic Descriptions/Stratigraphy 6 3.3 Connection Gas Summary* 11 3.4 Tripper Gas Summary 11 3.5 Sampling Program/Sample Dispatch 11 4 PRESSURE/FORMATION STRENGTH DATA 12 4.1 Pore Pressure Gradient Evaluation 12 4.2 Quantitative Methods 13 5 DRILLING DATA 14 5.1 Daily Activity 14 5.2 Survey Data 21 5.3 Bit Record 26 5.4 Mud Record: 27 5.4.1 Surface Hole--MiSwaco Spud Mud 27 5.4.2 Intermediate Hole MiSwaco LSND 27 5.4.3 Production Hole MiSwaco LSND-Klashield 29 6 DAILY REPORTS 30 Enclosures: 2"/100' Formation Log (MD and TVD) 2"/100' LWD Combo Log (MD and TVD) 2"/100' Drilling Dynamics Log (MD and TVD) 2"/100'Gas Ratio Log (MD and TVD) Final Well Data on CD 2 CANRIG ye- ConocoPhillips Alaska.Inc. 2L-306 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type/Position Total Comments Downtime QGM agitator and gas trap Ditch gas Flame ionization total gas 0 and chromatography. TOTCO feed Hook Load, Weight on bit TOTCO WITS Feed unreliable throughout well. Derived from Pump Stroke 0 Mud Flow In Rates*and Pump Output Mud Flow Out TOTCO WITS Feed* 0 Mudlogging Unit computer HP Compaq Pentium 4 0 systems (x2: DML& RigWatch) Mudlogging Unit Acromeg In-unit data 0 box collection/distribution center TOTCO feed Pit Volumes, Pit Gain/Loss TOTCO WITS Feed* 0 unreliable throughout well. Pump Pressure TOTCO WITS Feed* 0 Pump Strokes TOTCO WITS Feed* 0 TOTCO Well Monitoring TOTCO computer networked 0 Components in mud logging unit* Derived from TOTCO depth Rate of Penetration tracking components (block 0 height*) RPM TOTCO WITS Feed* 0 Torque TOTCO WITS Feed* 0 1.2 Crew Unit Number: ML057 Unit Type: Custom/Arctic/Steel Mudloggers Years of Days at Sample Catchers Years of Days at Technician Days at Experience 2L-306 Experience 2L-306 2L-306 Josh Dubowski 3 35 Greg Hammond 1 28 Howard Lamp Dan Sherwood 4 28 Zach Beekman 3 11 Allan Williams 1 Larry Resch 9 _ 26 James Foradas 3 10 Jeff McBeth 2 14 Doug Acker 1 12 3 CANRIG Conor Phillips Alaska.Inc. 2L-306 2 WELL DETAILS 2.1 Well Summary Well: 2L-306 API Index#: 50-103-20627-00-00 2L-306PB1 50-103-20627-00-70 Field: Kuparuk River Unit Surface Co-Ordinates: 202' FNL, 792' FEL Tarn Oil Pool Sec. 22, T10N, R7E UM Borough: North Slope Primary Targets: Bermuda Formation State: Alaska Primary Target Depth: 11406' MD/-5170'SSTVD Rig Name/Type: Doyon 15/Arctic/Triple Primary Actual Depth 11339' MD/-5191'SSTVD Spud Date: March 1, 2011 TD Depth: 13156' MD/5446'TVD TD Date: April 4, 2011 Ground Elevation: 115.4'AMSL Days Drilling: 35 KB Elevation: 155.4'AMSL Completion Status: Run Production Liner TD Formation: Seabee Fm. /equivalent Classification: Oil Exploration Days Evaluating: None 2.2 Hole Data Hole Maximum Depth TD Mud Dev. Casing/ Shoe Depth FIT Section MD TVD Formation Weight Liner MD TVD (ppg) (ft) (ft) (ft) (ft) (ppg) (°inc) Conductor Permafrost 0 16" 114 114 13-1/2" 3663 2376 9.5 68 10-3/4" 3663 2376 9-7/8" 11488 5365 Seabee/Eq 9.7 73 7-5/8" 11472' 5365 12.0 6-3/4" 13156 5446 Seabee/Eq 9.8 89 3-1/2" 13147 5446 - 4 CANRIG Conoco hillips Alaska.Inc. 2L-306 3 GEOLOGICAL DATA 3.1 Formation Tops: Prognosed Depth (ft) Actual Depth (ft) Zone or Horizon MD TVD SS MD TVD SS 10-3/4" Casing 3677 2375 -2220 3663 2371 -2216 Shoe 9-7/8" Intermediate Borehole C80 (K10) 3936 2470 -2315 4066 2515 -2360 Camp Sand (Top) 4099 2530 -2375 4236 2570 -2415 C50 7738 3865 -3710 7746 3865 -3710 C40 8829 4265 -4110 8774 4239 -4084 C37 9362 4470 -4315 9333 4450 -4295 Top Reservoir 11406 5325 -5170 11339 5346 -5191 T1.5 base reservoir 11692 5430 -5275 11570 5450 -5295 C35 11626 5475 -5320 TD 11990 5580 -5425 11824 5563 8408 9-7/8" Sidetrack Intermediate Borehole KOP 10979 5192 -5037 T-3 11292 5298 -5143 Top Reservoir 11430 5346 -5191 TD 11488 5365 -5210 6-3/4" Production Borehole 7-5/8" Casing Shoe 11473 5360 -5205 Fault 12129 Fault 12786 TD 14003 13157 5447 -5292 Note: Horizons and Depths provided by wellsite geologist. 5 CANRIG ConocoPhillips Alaska.Inc. 2L-306 3.2 Lithologic Descriptions/Stratigraphy SURFACE TO TOP OF C-80: (114' MD to 4066' MD, 2515'TVDSS to-2360' TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 594 9.3 209.69 1272 0 131.9 Gas Peaks Depth(MD) TG Cl C2 C3 1C4 nC4 iC5 nC5 1493' 1272u 472974 16. 12 0 0 0 0 3120' 677u 130506 445 97 0 0 0 0 High background gas levels and peaks were observed from approximately 1400'MD to 2000'MD with the maximum recorded gas of 1272 units at 1493'MD. At 3120'MD a gas peak of 677 units was recorded associated the corresponding sand. This interval is comprised of interbedded clays, silty claystones, conglomeratic sands, silty sand with patchy cementation, all in varying proportions, along with minor organic material and sporadic conglomerates. The sand conglomerate is generally composed of transparent and translucent grains with occasional medium light gray to light gray grains; upper medium to upper fine with abundant coarse grains; moderate to well sorted; sub-angular to sub-rounded; moderate to low sphericity; loose unconsolidated quartz grains with no apparent cement. A salt and pepper appearance predominates. The sand is composed of milky white, translucent, transparent, opaque quartz; light gray smoky light gray, moderate yellowish brown lithic fragments; upper medium to upper fine grained; light greenish gray; sub- rounded to sub-angular, angular in places; moderately sorted; highly unconsolidated with no apparent cementation. The claystones in this section are dark medium gray to very dark medium gray with blackish hues; poor to moderate induration; brittle to crumbly to occasionally tough; irregular to occasionally blocky to rarely planar; tabular to platy cuttings habit; dull to occasionally earthy luster; smooth to clayey texture; pulverized clay is moderately hydrophilic; moderate to good cohesiveness; poor to moderate adhesiveness; pasty to lumpy consistency. C-80 TO TOP OF CAMP SAND: (4066'to 4236' MD, -2360 TVDSS to-2415'TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 261 34 201 117 15 46.6 Gas Peaks Depth(MD) TG Cl C2 C3 IC4 nC4 iC5 nC5 none Gas is generally low in this formation section with no notable peaks. 6 CANRIG Conoc Phillips Alaska.Inc. 2L-306 The Camp Sand formation is comprised of sandstone, sand, claystone, silty claystone. The sands in this formation are comprised of predominantly white to translucent to transparent quartz; upper very fine to lower fine; very well sorted; sub-rounded to sub-angular; moderate to high sphericity; loose unconsolidated and disaggregated quartz grains with trace amounts of secondary lithics; good apparent permeability and porosity; no hydrocarbon indicators present. The claystones are comprised of medium gray to olive gray coloration; soft and very poorly indurated; pulverulent and malleable to sectile tenacity; massive cuttings habit displayed; clayey to smooth texture; earthy to waxy luster; cohesive and adhesive; clumpy to mushy to tacky; thick apparent bedding. CAMP SAND TO TOP OF C50: (4236"to 7746' MD, -2415'TVDSS to-3710'TVDSS ) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 286 18 177 110 2 36 Gas Peaks Depth(MD) _ TG Cl C2 C3 iC4 nC4 iC5 nC5 8714 93 16833 764 164 0 0 0 0 Gas is generally low in this formation section with no notable drilled gas peaks. The C-50 formation is composed of sandstones, sand, siltstones, claystone. The sands in this formation are composed of predominantly translucent grains with white to smoky hues and occasional transparent quartz; medium to lower coarse grains but ranging from upper very coarse to lower fine;very poorly to poorly sorted;angular to sub-angular with abundant bladed grains and clastics;generally low to very low sphericity with some moderate; trace amounts of grain supported silica cement sandstone fragments; predominantly loose disaggregated and unconsolidated sand grains; approximately 60%quartz and 40%secondary lithics;slight petroleum odor;. a moderate strong yellow orange sample fluorescence on 80-90%of sample;instant moderately strong milky to yellowish green fluorescence with slow brighter yellow to white streamers; bright yellow residual cut fluorescence with moderate strong intensity; none to clear visible cut; very pale brown visible residual ring The sandstone in this unit is comprised of translucent, pale yellowish brown to pale brown to light olive gray clasts;very fine to lower fine some medium grained; round to sub-round some sub-angular; moderate to high sphericity;approximately 75-80%of sample composition is quartz;mostly siliceous cement,occasionally very well cemented with poor visible porosity; abundant siltstone grading to sandstone; no petroleum indicators. Claystones in this section appear medium gray to medium light gray with olive gray hues; soft; non to poorly indurated;cohesive and adhesive;pulverized claystone clumped in mushy cohesive lumps;tacky to somewhat pasty; irregular fracture;massive cuttings habit;waxy to earthy luster;clayey to silty texture;massive bedding structure; silt;very fine to lower fine quartz sand imbedded within claystone matrix; no petroleum indicators. Siltstones are light medium gray to medium gray with occasional olive gray hues; moderately hard to hard occasionally friable;well indurated;tabular to nodular cuttings; silty to abrasive texture;tough to crunchy and fairly dense; occasional thin black and brown laminations in fragments under higher magnification; sample does not appear to be fissile along laminations. 7 CANRIG ConocoPhillips Alaska.Inc. 2L-306 C50 TO TOP OF C40: (7746'to 8774' MD, -3710' TVDSS to-4084'TVDSS) Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 203 22 125 93 2 28.6 Gas Peaks Depth(MD) TG Cl C2 C3 IC4 nC4 iC5 nC5 none Gas is generally low in this formation section with no notable peaks. This interval consists of sandstones, siltstone, calcareous siltstone and silty shale . The sandstones in this section are translucent pale yellowish brown to pale brown to light olive gray lithics; very fine to lower fine, some medium grained; rounded to sub-rounded some sub-angular; moderate to high sphericity;approximately 75-80%of sample composition is quartz;mostly siliceous cement,occasionally very well cemented with poor visible porosity; no petroleum indicators. Siltstones in this formation are light medium gray to light gray with light olive gray to light brownish gray hues; firm to friable to moderately hard with some soft;crunchy to tough with abundant amounts of pulverulent clay which appears to be a fairly cohesive and non to somewhat adhesive slurry; moderate to well induration; irregular to earthy fracture nodular to equant cuttings habit; earthy to dull luster; silty to gritty texture; no hydrocarbon indicators. The calcareous siltstone in this section is grayish white to grayish yellow;pale yellowish hues,pale white with light gray hues; moderately firm to hard; well to very well indurated; dense to stiff tenacity; irregular to occasionally planar and conchoidal fracture; flaky platy cuttings habit; waxy resinous luster; silty, sucrosic texture; thin bedding structure. C40 TO C37: (8774'to 9333' MD, -4295' TVDSS to-5191'TVDSS) Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 171 16 126 95 1 48 Gas Peaks Depth(MD) TG Cl C2 C3 iC4 nC4 iC5 nC5 none - Total gas was generally low in this section of the formation. This interval generally consists of sand, sandstone, siltstone, and shale. The sandstones in this section are translucent and transparent quartz with yellowish gray to very pale orange secondary lithics;very fine to lower fine grained;well sorted; rounded to sub-rounded,sub-angular in places; high to moderate sphericity; soft to easily friable; 70-75 % quartz composition; scattered bright green fluorescence; no other petroleum indicators. 8 CANRIG Conoc Phillips Alaska.Inc. 2L-306 An example of the sand in the C-37 is composed of white to translucent to transparent quartz grains with some light gray to medium; fine to medium sized siltstone fragments intermixed; upper to lower very fine grained; very well sorted; mostly angular to sub-angular with occasional sub-rounded grains; high to very high sphericity; loose unconsolidated quartz sand grains; trace grain supported; 100% clastics; composed of approximately 80%quartz and 20% lithics; moderate to low apparent visible porosity; good apparent visible permeability; no petroleum odor; no visible staining; no sample fluorescence or other hydrocarbon indicators present. Siltstone in the C-37 unit generally appears medium gray to medium light gray; firm friable to easily friable; moderate to poor induration;crumbly to brittle with some pulverulent;irregular fracture;tabular to nodular and equant; earthy to dull luster; silty to gritty to smooth; no hydrocarbon indicators. C37 TO S8 -TOP RESERVOIR: (9333'to 11339' MD, -4295' TVDSS to-5191'TVDSS) NOTE: For 2L-306 PB#1 Pilot Hole Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 329 9 136 743 12 95 Gas Peaks Depth(MD) TG Cl C2 C3 iC4 nC4 IC5 nC5 9583' 743 116852 9219 3455 839 432 0 215 This interval is comprised of sandstone, sand, siltstone and occasional clay and shale. The sand in this section is commonly translucent, very light grey to milky white, smoky to medium grey are common but not abundant; quartz typically makes up 75%of the sands; dark grey to black lithics commonly make up about 20% of the samples; predominantly upper very fine to lower fine grained with upper fine to lower very fine to ultra fine being common;occasionally lower medium grains;sub-angular to sub-rounded to angular, rarely rounded; moderate to well sorted with occasional poorly sorted intervals; poor to occasionally moderate sphericity; clay and silt fill common. In the top part of the section some samples showed 30% yellowish orange to yellowish brown fluorescence with no cut. The lower half of the section showed trace amounts of straw yellow to dull brownish gold to fluorescence and no cut. The sandstone of this formation is commonly medium grey to light medium grey to very light white with occasional yellowish brown or light blue hues; lower very fine to lower fine with some upper fine grain sand; moderately well sorted;angular to sub-angular with some slightly rounded to sub-rounded sections;moderate sphericity;very little loose unconsolidated sand and commonly grain supported; matrix is predominantly clay and non-calcareous;fluorescence uncommon but was bright yellow to dull yellowish brown when observed. The siltstone in this section appear medium gray to medium light gray to medium dark grey with some grayish brown and yellowish brown in places; induration is predominantly firmly friable to moderately hard;very earthy to very dull luster; texture ranges from very silty to slightly gritty; occasionally grades to a shale in some places;very fine carbonaceous detritus is common in samples but not abundant;fluorescence is uncommon but occasionally observed as dull yellowish brown to rarely gold green. 9 CANRIG ConocoPhillips Alaska.Inc. 2L-306 HORIZONTAL SECTION; TOP TO BASE OF RESERVOIR: (11406-13157'MD, -5191'TVDSS to -5292' TVDSS) Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 182 18.7 105.7 113 5 47 Gas Peaks Depth(MD) TG Cl C2 C3 iC4 nC4 IC5 nC5 12136 479 46556.4 6035.2 4426.3 634.2 1753.8 424.5 547.2 12220 653 60007.5 7722.5 6276.8 987.7 2791.4 755.5 970.7 12288 553 53038.2 6337.6 4967.0 787.2 2164.0 593.7 776.0 12318 503 48271.4 48271.4 4621.1 679.0 1877.2 465.8 615.9 12465 501 21316.9 4353.6 6278.9 1295.9 4083.9 1272.5 1702.3 The reservoir zone is predominantly composed of sandstone and sandy siltstone. The sandstone in the reservoir section is composed of very light gray to bluish white to white with abundant transparent grains;upper very fine to lower fine with occasional upper fine grains;mostly friable to firmly friable consolidated sandstone fragments with some loose disaggregated quartz grains;moderate to low sphericity; angular to sub-angular grains; poor to moderate sorting; predominantly matrix supported, grain supported clasts common but not abundant; matrix is commonly made up of a white clay or ash;trace amount of biotite flakes; bright yellow to dull brownish gold fluorescence and no cut. 10 CANRIG Conor Phillips Alaska.Inc 2L-306 3.3 Connection Gas Summary: 1 Unit= 200 ppm =0.05% Methane Equivalent Note: No connection gasses were observed. Depth (ft) Background Units MD/TVD Gas Above C-1 C-2 C-3 C-4 C-5 (Units) Background 3.4 Trip/Wiper Gas Summary 1 Unit= 200 ppm =0.05% Methane Equivalent Depth (ft) Trip to(ft) Max.Gas MD/TVD MD/TVD (Units) Comments Surface 11824/5565 372 Trip in hole with 3-1/2"tubing for cement 11488/5365 7980/3935 1016 Wipe tight hole 11488 to 7980'MD. 3.5 Sampling Program/Sample Dispatch Set _ Type/Purpose Frequency Interval Dispatched To CPAI,ABV 100 Bayview Warehouse A Washed, screened and dried. 50 ft 104'to 10950'MD 619 E. Ship Creek Ave. Set Owner: CPAI 10 ft, 50 ft *10950 to 11824'MD Anchorage,AK 99501 Attn: D. Przywojski/M. McCracken (907)263-4859 CPAI,ABV 100 Bayview Warehouse B Washed, screened and dried. 50 ft 104'to 10950'MD 619 E. Ship Creek Ave. Set Owner: CPAI/AOGCC 10 ft, 50 ft *10950 to 11824'MD Anchorage,AK 99501 Attn: D. Przywojski/M. McCracken (907)263-4859 *Samples from PB#1 begin at 10950' and continue to 11824' (11350'-11660' 10'frequency) Sample frequency was altered locally according to on-site geologist. 11 C:ANRIG N - J t $ 7 0 0 \ k 0U 0 0 0 w $ c I 0 0 0 0 0 0 k k m CO_ ca = 2 2 2 2 fy ± CC C L w LU LU o 0 0 & / > > > w z z z t w-- . . _ > 0 m k § m r CO ¥ ¥ CO o J 0 3 ■ 2 a a a a a 6 a a) ma) D_ g § 2 .E - � @ - ... -0ca) / 2 •§ . CI o c a r co co co w w CO „ 1 2 S 6 a a a a a a R c II II / 0 �� 0 / f 0 \ Cl) b in b w : & O F CO 7 Q CO q k 7 > I f Ni-- 9 9 6.\ \ 5 \ \ k co CO - \ j el - I & N n « r m 0 g Fi !II' ° � = o - 0 b F--- co q % § .E - ^ CO k $ ;Cr \ q m o R 8' ■ o & w n 01- ,- .- ii ii II ii + 6 , 2moo gm0R I- a ,7 + + I- ¢ § o CO -o a o f o + \ « 13o _ ® -a o o no N I CI kk / 0 0 \ I / 2 / I- c $ _1 / q q / q / _ / $ z m / / 0 (3 / ® > y 0 0 / / $ $ 0 2 > g 7_ \ 2 = « 0 0 o c 7 o E o @_ » \ \ ® _ _ _ - § a k § a \ 0 / \ \ % / % .2 m \ s 2 q q coO ƒ � = L ■ o � q = 2 i Lw 2\ it ii l' = a � � Io2 ■ c « ono2L CL § ala o_ 2 a m £ e co o IL) RI k 2 0 0 0 0 0 0 a L — 0 % I- / 7 ConocoPhillips Alaska.Inc. 2L-306 4.2 Quantitative Methods The primary indicators used for PPG evaluation were gas trends relative to mud weight(MW) and effective circulating density(ECD), including increases in background gas(BG),appearance and trends of connection gas (CG), and magnitudes of trip gas (TG) and wiper gas (WG). Regional pore pressure trends from sonic data, provided by ConocoPhillips, and surface manifestations of hole conditions were also considered. As a reference, PPG is calculated initially with a formula provided by Canrig Drilling Technology LTD,and then modified using the indicators described above, DXC and resistivity(RES)data. The formula uses DX, ECD, and BG as measured by total ditch gas: PPG = ECD—(0.6-((.001*TLGSU) + (0.05*DX))) The formula has certain limitations, such that it does not allow for a PPG more than 1 ppg less than the ECD, and TLGSU must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However,the formula proved useful in helping formulate a PPG range,when estimating trends, as with DXC data, with data points in shale intervals. 13 CANRIG ConocoPhillips Alaska.Inc. 2L-306 5 DRILLING DATA 5.1 Daily Activity March 1, 2011 Pick up 5" drill pipe from the shed and stand back in the derrick. Function test diverter line. Pick up bit and BHA. Drill from bottom of conductor at 136'to 725' MD. March 2, 2011 Drill from 724'to 1008'. POOH to 900'and trough to 912'. Trip back to bottom and drill to1038'. Drill ahead watching for hydrates to 2145' MD at report time. March 3, 2011 Drill from 2145'to 3672' MD, 2374'TVD. Circulated bottoms up. Back reamed out of the hole from 3672'to 3241'. March 4, 2011 Back ream out of hole from 2700'to 1900'. No tight spots or over pull noted. TIH from 536'to 3672'.Circulate 3x bottoms up. Pulled out of hole on elevators from 3672' to surface. Laid down BHA. Rigged up to run casing. RIH casing. March 5, 2011 Continue running in casing. While reciprocating the casing stuck 9" high of the hanger. Rigged down cementing equipment. Nipple down stack, set emergency slips. Cleared the rig floor. March 6, 2011 Nipple down the diverter. Installed well head equipment as per FMC. Nipple up BOP.Changed rams and test BOP. March 7,2011 Change out upper rams to 5'. Test BOP. Pick up 5" drill pipe from pipe shed. Pick up 9.875" bit and new BHA as per directional driller. Single in the hole. March 8, 2011 Test casing and drill out plug. Mill shoe and displace to new LSND while drilling out rat hole. Drill 20'of new formation and perform FIT test to 16ppg EMW. Drill ahead per DD to 4607' MD, 2706'ND. March 9, 2011 Drilled from 4,602'to 6,182' MD. Rotate and reciprocate while circulating bottoms up at 6,182'. Back ream out of hole to 3,663'. Circulate bottoms up at shoe, drop ball and open well commander. Pump out from 4,050' to 3,906' MD. March 10, 2011 RIH, wash and ream down from 6,090'to 6,182'. Drilled from 6,812'to 7,740' MD. March 11, 2011 Drilled from 7,740'to 7,887'. Trouble shoot mud pump#2. Back ream out of hole from 7,887 to 6,087'. RIH from 6,087' to 7,800'. Wash down from 7,800'to 7,887'. Continue drilling from 7,887'to 8,685'. March 12, 2011 Drilled from 8,685' to 9,314'. Circulated and conditioned mud while trouble shooting mud pump#2. Back ream out of hole from 9,134'to 5,420'. Circulated mud while trouble shooting TDS-8. Circulate bottoms up, 14 CANRIG ConocoPhillips Aa;ka.inc. 2L-306 Flow check well (static). Lubricate top drive and draw works. Back ream out of hole from 5,420'to 3,717'. Circulate bottoms up at 450 gpm. March 13, 2011 Serviced rig. Change out fluid end on mud pump#2. RIH from 3,623'to 9,134'. Continue drilling to 9,401'. Circulate and condition hole, flow check (static). Blow down top drive. POOH on elevators from 9,401' to 8,363', no swabbing, no over pull. Pump dry job and continue to POOH from 8,363'to 4,858'. March 15, 2011 On the bank. Change upper rams and test BOP's; Make up new BHA and run in hole. Canrig records 606 units trip gas maximum observed. Currently drilling ahead at report time. March 16, 2011 Drill ahead with no problems encountered. Began controlled drilling at 11300'MD/5345'TVD at 60 FPH. Canrig collecting cutting samples at 10 foot intervals starting at 11350 ft. Drilling ahead at report time. March 17, 2011 Continued controlled drilling at<70 FPH from 11350 feet to 11, 824 feet. TD at 11824'MD/5565'TVD at 0925 hours. Circulate and condition mud. Check hole for flow: Static. Short trip from 11824 ft to 9381 ft with no problems. Check hole for flow: Static. Run back to bottom from 9381 ft to 11824 ft with no problems. Circulate and reciprocate pipe while troubleshooting top drive. Canrig records 969 units of short trip gas with pumps off 4.1 hours during trip. Pull out of hole to 10773 ft. Currently changing out bails at report time. March 18, 2011 Continue trip out of hole from 10773 ft to 675 ft. Stand back HWDP and jars from 675 ft to 226 ft. Handle balance of BHA, remove nukes; lay down mud motor and drill bit. Change out top set of pipe rams and install 3-1/2"x 6"variable rams;test same at 250 psi low/3000 psi high. Test annular preventer at 250 psi low/2500 psi high. Blow down kill line and choke; install wear bushing. Rig up to run 3-1/2" PH-6 cement string. Currently running 3-1/2" PH-6 tubing as per detail at report time. March 19, 2011 Continue to run in hole with 3-1/2" PH-6 tubing from 1099 ft to 2237 ft. Transfer weight pipe in derrick from driller's side to off side. Continue RIH from 2237 ft to 4609 ft. Transfer weight pipe in derrick from off side to driller's side. Continue RIH from 4609 ft to 11805 ft. Change out short bails for long before picking up single for cementing. Circulate and condition while reciprocating pipe. Canrig records 372 units maximum trip gas. Turn over operations to cementers. Pump 5 BBL mud push and pressure test mud lines to 3500 psi. Pump 25 bbls mud push at 12.5 ppg; 51.2 bbls of 17 ppg cement; 3.2 bbls 12.5 ppg mud push. Rig displaces 187 bbls of 9.7 ppg mud at 1750 psi, 1850 stks. Break out cement single and POOH from 11824 ft to 11370 ft. Turn over operations to cementers. Pump 30 bbl mud push; 51.2 bbls of 17.0 ppg cement. Rig displaced cement with 179 bbls of 9.7 ppg mud at 1650 psi. POOH from 11370 ft to 10861 ft. Reciprocate pipe wile circulating and conditioning mud after cement job. Vary circulation rates from 3 bpm to 12 bpm. Circulation and conditioning continues at report time. March 20, 2011 Continue to circulate and condition mud while reciprocating after cement job. Circulate each 60 ft reciprocation interval +/- 30 minutes while treating mud. Stage pump rate up to 10 BPM from 10577 ft to 10293 ft. Begin to stage pumps up to 15 BPM at 9535 ft. Begin POOH from 9535 ft to 3902 ft. Monitor well via trip tank. Transfer BHA from driller's side to off side of derrick. Continue to POOH from 3902 ft to 1099 ft. Lay down BHA (3-1/2" PH-6 tubing). Clean stack and make preparations to test BOP's. Testing same at report time. March 21, 2011 Continue to test BOP's. Install wear plug. Change out long bails for short and 5"drill pipe elevators. Tr-adjust link tilt bars. Pick up and orientate motor,stabilizer, balance of MWD assembly. Upload MWD and pulse test at 550 gpm, 1000 psi. Load sources and continue to make up BHA. Run in hole. Tag cement stringer at 15 C:ANRIG ConocoPhillips Alaska.Inc. 2L-306 10319 ft. Attempts to ream down result in excessive torque/stall. Continue washing and reaming from 10319 ft to 10603 ft. Observe partial losses while back reaming with pump pressure increase. Slowed pump rate and worked string to get full returns back at 10515 ft. Flow check well at 10573 ft. Break circulation at 6 BPM, 750 psi, increasing to 9 BPM, 1220 psi; RPM 70, Torque 22-25k. Continue washing and reaming at report time. March 22, 2011 Continue to wash and ream cement stringers from 10603 ft to 10687 ft. Canrig records 155 units maximum gas after trip. Drill top of cement from 10936 ft. Condition, work hole and back ream at 340 GPM, 1400 psi, 90-100 RPM,torque 25-28k from 10925 ft to 10885 ft(tight hole section). Troubleshoot excessive chain slap inside guard on ("A" drive motor)#1 mud pump. Also checked fluid ends, liners and swabs; clean suction screen. Drill ahead from 10936 ft to 11488 ft. TD at 11488'MD/5366'TVD. Take survey on bottom; rack back one stand. Circulate bottoms up. Check flow at 11390 ft. Begin short trip from 11390 ft. Currently POOH during short trip at report time. March 23, 2011 Continue short trip to 10692. RIH from 10692 ft to 11488 ft. Pump sweep and circulate bottoms up. Note 100% increase in cuttings when sweep reaches surface. Canrig records 531 units max gas from short trip. Circulate and condition(4)bottoms up. Observe well. POOH from 11488 ft to 10700 ft. Pump dry job. Blow down top drive. POOH from 10700 ft to 3000 ft.at 100 ft/min+/-. Observe well at the shoe. Continue POOH from 300 ft to top of BHA at 652 ft. Lat down HWDP,jar stand; pull source;download MWD. Continue laying down BHA to bit. Service rig. Change upper 3-1/2"x 6"VBR's to 7-5/8"solid;test same 250psi low/3500 psi high. Rig up to run 7-5/8" casing. Rig up operations continue at report time. March 24, 2011 Preparations to run 7-5/8",29.7#, L-80 casing continue. Pick up and Bakerlock silver bullet shoe joint;#2 joint; float collar joint. Check float collar equipment: OK. Run 51 Hydroforms at one per joint for 51 joints. Circulate at 2800 ft at 5 BPM with 320 PSI. Fill pipe every joint and top off every 10 joints. Monitor well through pit#4.Continue to RIH with casing to 3600 ft. Reciprocate and circulate 1+pipe volume at the shoe: 5 BPM, 375 PSI. Observe well: Static. Continue running 7-5/8"casing from 3600 ft to 7360 ft per detail: Fill pipe each joint;top off every 10 joints. Circulate and condition mud at 7360 ft. Partial loss of returns. Reduce flow rate from 210 GPM to 184 GPM. Continue running 7-5/8"casing from 7360 ft to 8653 ft: fill each joint, top off every 10 joints. Attempt to establish circulation at 8653 ft at 4 BPM. Immediately observed full loss of returns and packing off. Reduce flow rate to 63 GPM while reciprocating pipe. Observed differential sticking, loss of string weight. Lay down joint#202. Continue to establish circulation at 63 GPM. Observed packing off and loss of returns. Lay down joint#s 201,200, 199. Continue to establish circulation at 63 GPM. Establish circulation at 7%flow line returns,450 psi. Observed packing off and loss of returns. Lay down joint#s 199- 195 to 8353 ft. Established circulation at 155 GPM, 470 PSI. Circulate 1100 strokes. Condition mud. Observed partial loss of returns; packing off. Pick up joint 3 195. Wash down to establish circulation at 147 GPM,520 PSI; increase to 210 GPM,700 PSI. Reciprocate pipe. Observe intermittent packing off. Lay down joint#s 195-190 at 8093'MD. Established circulation at 210 GPM, 600 PSI. Reciprocate pipe. Observed packing off, 1350 strokes. Lay down joint#s 190-188 at 8007'MD. Established circulation at 147 GPM,420 PSI, flow out 12%. Increased flow in at.5 BPM increments to 252 GPM, 620 PSI,flow out13%,total strokes 3500. RIH washing down at 168 GPM from 8093 ft: 450 PSI, PU =260k, SO = 90k at report time. March 25, 2011 RIH with 7-5/8" casing. Continue to wash and work tight spots from8093 ft to 8220 ft. Vary pump as conditions dictate from 3-6 BPM,300-900 PSI, HST 245k,SO 125k. Observe well: Static. Break out and lay down Frank's fill up tool. Reciprocate 7-5/8"casing from 8180 ft to 8215 ft. HST 245k,SO 125k. Change out packer cup and re-install Frank's fill up tool. Continue to wash and work 7-5/8" casing. Break circulation at 8215 ft. Stage pump up to 6 BPM while freeing up pipe. Eventual pack off on down stroke. Pull and lay down joint#192. Find free spot and establish circulation at 4-5 BPM with 450-550 PSI. Work casing and free up from 8140 ft to 8180 ft. Continue to attempt to raise annular velocity from hole cleaning to 7 BPG(290 GPM) as directed while working pipe. Pack off and pull joint#191 out of hole and lay down. Work pipe and free up from 8130 ft to 8090(joint#190)and establish circulation at 5 BPM and 500 PSI. Rig down and clean up 350 16 CANRIG ConocoPhillips Alaska.Inc. 2L-306 ton slips, elevators, Frank's tool and long bails. Pick up and rig up short bails, 200 ton HYC type elevators, hand slips and stack tongs in preparation to lay down 7-5/8"intermediate casing string. Observe well. Begin to lay down 7-5/8"casing from 8136 ft to 3600 ft. Monitor hole via the trip tank. Obtain torque and drag every 5 joints. Flow check well at shoe. Obtain PU/SO weights every 5 joints. Continue laying down 7-5/8"casing to 131 feet at report time. March 26, 2011 Continue to lay down 7-5/8"casing, including Baker-Locked shoe track. Observed well. Drain and rinse stack after laying down casing. Change top rams from 7-5/8"to 3-1/2"X 6"variable. Install test plug and test top rams with 5" test joint at 250 PSI low/3500 PSI high. Pull test plug and install wear bushing. Pick up bit, motor, pulser, stabilizer and float sub from beaver slide. Pick up/make up BHA#5 for clean out run. Orient motor to MWD. Pick up remaining BHA to first joint of HWDP. Establish circulation and pulse test MWD at 430 GPM,750 PSI. Slip and cut 120 ft drill line. Service draw works,top drive, upper and lower!BOP,crown. Continue to run in hole to 3726 ft. Circulate bottoms up at 800 GPM,2800 PSI. Canrig records 172 units gas maximum. Continue trip in hole from 3726 ft to 8050 ft. Note: Set down 30k then came back. Wash and ream from 8050 ft to 8179 ft at 700 GPM, 3700 PSI, flow line sensor reading 30%. While washing and reaming observed increased torque and packing off with loss of returns. Pumped 40 BBL high vis nut-plug sweep. Washing and reaming at 8125 ft continues at report time. March 27, 2011 Continue to back wash and back ream from 8179 ft(stand#80). Reduce flow in to 450 GPM to mitigate pack off. Pump out of the hole and rack back drill pipe in derrick. Find free spot on stand #79 and pump at 420 GPM, 1800 PSI, 100 RPM, 18-22k torque. Observed pack off and small loss of returns.. Pump, rotate and work out of the hole: Rack back stand #79 in derrick. Break circulation on stand #78 at 7980 ft with 450 GPM, 1800 PSI, 100 RPM, 16-22k torque. Free up and reciprocate from 7890 ft to 7987 ft. Circulate sweep. Stage pump up to 650 GPM as sweep nears surface. Wash in hole from 7987 ft to 8650 ft. Vary flow in according to hole conditions. Stage down the flow in to 102 SPM,429 GPM, 1400 PSI, 100 RPM, 18k torque, 18%flow out, HST240k/SOW130k. Continue to wash and ream from 8650 ft to 8838 ft. Adjust washing and reaming speed to packing off at 8838 ft. Pump high-vis sweep and circulated out at 750 GPM,3590 PSI,30% flow out, 100 RPM, 18-20k torque, 165k rotating string weight. Trip in hole on elevators from 8838 ft to 10200 ft. Wash and ream from 10200 ft to 10263 ft. Trip in hole on elevators from 10263 ft to 11053 ft. Wash and ream from 11053 ft to 11488 ft. Canrig records 1016 units maximum gas observed during trip Circulating bottoms up at report time. March 28, 2011 Continue to circulate and condition hole for 7-5/8"casing run. Pump sweep out at TD 11488 ft a total of 28123 STKS,706 GPM,3600 PSI, RPM 100,24-27k Torque,HST 285k,SOW 160k. POOH from 11488 ft to 9100 ft. Tight spot at 9100 ft. Monitoring hole via trip tank. Measure torque and drag every 5 stands. Establish circulation and back ream out of hole from 9100 ft to 7890 ft.at 450 GPM, 1550 psi. Circulate and reciprocate from 7890 ft to 7800 ft at 450 GPM, staging up to 700 GPM, 3150 PSI. Rotate/Circ weight 165k, HST 225k, SOW 130k. TIH on elevators from 7890 ft to 11488 ft. Circulate bottoms up at 11488 ft and 35 bbl high-vis nut-plug sweep at 705 GPM, 3850 PSI, 27% flow out, 100 RPM, 26-28k torque. Canrig records 350 units maximum trip gas. Pumped 17,685 strokes total. Lay down single; monitor well: Static. POOH on elevators from 11488 ft to 8900 ft. P/U 240k, S/O130k. At 8900 ft spot 100 BBL pill (12#/BBL Sac-Black)and dry job (11.9 PPG, 60 vis).At 500 GPM,2050 PSI, 50 RPM,20k torque. Continue POOH on elevators from 8900 to 5210 ft. Observed tight spot at 6903 ft (50k over). Worked through until cleaned up. Currently continuing POOH at report time. March 29, 2011 Continue to POOH with drill pipe from 5210 ft to 3726 ft. Obtain torque and drag every 5 stands. Observe well. Reciprocate from 3726 ft to 3670 ft while circulating and conditioning. Stage up from 450 GPM to 700 GPM, 2750 PSI. Canrig records 48 units maximum gas. Pump dry job and continue POOH from 3670 ft to 596 ft. Stand back HWDP in derrick; lay down jars and pick up(1)joint 5"drill pipe to replace jars. Continue POOH with BHA#5 and lay down to pipe shed. Break float sub, pull float, re-make joint sub. Lay down motor and bit. Change out 3-1/2"x 6"variable rams with 7-5/8" solid. Rig up and test same 250 psi low/3500 psi 17 CANRIG ConocoPhillips Alaska.Inc. 2L-306 high. Rig down 5"drill pipe elevators and short bails. Rig up Doyon casing tongs,350 ton elevators and slips, long bails and Frank's fill up tool in preparation to run 7-5/8"casing. Make up shoe track and Baker-Lock first 3 connections. Fill pipe and check floats. Begin running 7-5/8", 29.7#/ft, L-80 BTCM casing per detail from 175 ft to 3465 ft. Begin staging pumps up to 6 BPM,410 PSI. Pumped 1810 strokes, 6 units gas maximum observed. Change out rubber on Frank's tool. Continue running 7-5/8" casing from 3465 ft to 6025 ft. Circulate bottoms up, staging pumps from 5 PBM to 10 BPM. Pumped 2801 strokes, 30 units maximum gas observed. Continue running 7-5/8" casing per detail from 6025 ft to 7270 ft. (joint#170. NOTE: Washed down#161 and 162 (6851 ft to 6936 ft)with 3.5 BPM, 310 psi. Circulated 550 strokes total. Currently RIH with 7-5/8"casing at report time. March 30, 2011 Continue to run 7-5/8", 29.7#intermediate casing from 7270 ft to 7916 ft(joint#185). Reciprocate pipe from 7915 ft to 7876 ft while circulating at 3.5 BPM,450 PSI. Stage pumps up to 5.5 BPM, 575 PSI. Pack off and taking weight on down stroke observed at 1400 strokes(proposed to circulate 1800 strokes total; B/U at this depth 3065 strokes). Continue to run 7-5/8"casing from 7915 ft to 9080 ft. Reciprocate from 9080 ft to 9041 ft and circulate at 3.5 BPM, 450 PSI. Stage pumps up to 5 BPM, 540 PSI. Circulated 2007 strokes total. Continue to run casing from 9080 ft to 10276 ft. Reciprocate casing at 10276 ft and circulate at 3.5 BPM,450 PSI; staged up to 5 BPM, 540 PSI. Continue to run 7-5/8"casing from 10276 ft to 11427 ft(joint#267). Pick up FMC hanger and landing joint. Set on hanger at 11472 ft. Establish circulation at 3.5 BPM, 500 PSI. Reciprocate from 11472 ft to 11457 ft. Canrig records 74 units maximum trip gas observed. Set on hanger. Break out Frank's tool and lay down same. Rig up cement head, line and valves. Reciprocate 20 ft and circulate in preparation for cement job. Stage pump up to 7 BPM, 550 psi. Total strokes pumped 8330. Continue with cement job as per Dowell. Drop bottom plug; pump gas block 147 BBLS 15.9 PPG at 6 BPM. Drop top plug; kick out with 10 BBLS water. Turn over to rig and displace cement. Pumped 9.9 PPG mud at 7 BPM, 800 PSI,4900 strokes. Slow down to 4 BPM, 620 PSI. Bumped plug at 5123 strokes; pressure up to 1200 PSI and hold for 5 minutes. Bleed off check floats: OK, no returns to surface. Blow down and rig down cement line. Rig down cement head and pull 7-5/8" landing joint. Pick up 5" test joint; make up pack off running tool and set/torque lock downs to 450 ft/lbs. Test pack off to 5000 PSI for 10 minutes. Removed double annulus valve from lower annulus and install on upper annulus. Lay down running tool and test joint. Installed short bails with 5"elevators. Rig up in cellar to flush OA with 300 BBBLS water. Pressure test lines to 2000 PSI: OK. Flush OA with water. Final circulating pressure 600 PSI, shut in pressure 550 PSI. Rig down and blow down lines; rig up little red to freeze protect. Continue preparations to lay down 5"drill pipe at report time. March 31, 2011 Lay down 105 stands of 5" drill pipe and 5 stands HWDP from derrick. Simultaneous operations include changing 7-5/8"top rams to 3-1/2"x 6"variable; bottom 5"solid to 4"solid. Start loading 4"drill pipe into pipe shed on off driller's side. Pull mouse hole from rotary table and put back into mouse hole position. Pick up 1 joint of 4"drill pipe in preparation to cut and slip 120 ft drill line. C/S same. Remove 4"drill pipe from rotary and lay down to pipe shed. Load pipe shed with 268 joints of 4" drill pipe; Strap and remove thread protectors. Clear floorof4-1/2"IF and 5"handling tools. Pick up 3-1/2",XT-39 and 5"handling tools. Inspect and power wash topdrive. Pick up 4"drill pipe(XT-39)and rack back 90 joints in derrick; drift to 2.25". Make up pup joint to test joint with head pin; set plug; rig up test manifold and hoses. Use rig pump to fill stack with water; perform body test to 3500 psi. Test BOP's 250 psi low,3500 psi high(bag 250 psi low,2500 psi high). Continue testing BOP's at report time. April 1, 2011 Continue and complete testing BOP's. Install wear bushing. Blow down choke, kill line to stack, choke manifold. Pick up/clean up rig floor. Pick up BHA#6: Bit, motor, float sub, stabilizer, Phase 4 collar, DM, PWD and Pulser. Pull old wear bushing and install new one. Grease draw works, top drive and iron roughneck. Continue to pick up BHA#6 per directional driller and MWD hand. Upload MWD. Shallow pulse test at 200 gpm, 950 psi. Blow down top drive. Load nukes per MWD. Pick up remaining BHA items: 2 Flex collars, circ sub crossover sub, 3 joints HWDP,jars, 8 joints HWDP. Continue trip in hole with 4" drill pipe singles from 598 ft to 6560 ft at report time. 18 CANJRIG ConocoPhillips Alaska,Inc. 2L-306 ApriI2, 2011 Continue to single in from pipe shed with 4" drill pipe: From 6560 ft to 11203 ft. Trip in hole from derrick 11203 ft to 11377 ft. Wash down from 11377 ft with 205 gpm,2090 psi. Circulate bottoms up at 11377 ft, 300 gpm,3450 psi. Circulated 3800 strokes. Blow down top drive and rig up for casing test. Test 7-5/8"casing to 4000 psi. Bleed off and rig down test equipment. At 11379 ft drill floats and cement to 11488 ft with 211 gpm, 1750 psi. Pumped sweep while drilling on the shoe. Continue to circulate and displace mud at 11488 ft,340 gpm, 3250 psi. Drill from 11488 ft to 11508 ft. Lay down single; blow down top drive; perform leak off test to 12.0 ppg EMW. Drill ahead from 11508 ft to 11870 ft with no problems encountered at report time. April 3, 2011 Drill ahead from 11850 ft to 12786 ft with no problems encountered. Cross fault at 12786 ft and lost 47 bbls mud initially and 15 bph for the next 3 hours. Pump Safe Carb 250, Safe Carb 40 and G Seal to heal the losses while drilling ahead. Drill to 12954 ft at report time. April 4, 2011 Drill ahead from 12954 ft to 13156 ft. Observed losses at 13156 ft. Initial loss 50 bbls while pumping at 345 gpm, 3750 psi: Little or no returns at flow line. Observed slight static losses while monitoring well. Mix and pump LCM pill per MlSwaco.at 2 bpm, 550 psi, no returns at flow line. POOH with pumps from 13156 ft to 11391 ft at 63 gpm, 460 psi. Spot LCM pill while POOH. Actual displacement (-70 bbls) from trip out; calculated displacement(-12.4 bbls). Monitor hole on trip tank at 11391 ft. Build and take on volume into pits per MiSwaco engineer. Total losses from 0001-1200 hrs were 249 bbls. Circulate over top of hole from trip tank(no losses). Wait on mud while building 100 bbl LCM pill. RIH and circulate from 11391 ft to 11455 ft at 21 gpm, 280 psi, 0% returns at flow line. Increase to 126 gpm, 780 psi, 0% returns at flow line. Shut down and drop ball to open circulation sub. Wait 20 minutes to let ball fall. Pump ball down with 105 gpm, 60 psi, 0%returns at flow line. Ball on seat at 635 strokes. Pressure up to 1500 psi,wait 15 seconds;pressure up to 2000 psi, wait 15 seconds; pressure up to 2450 psi. Tool shifted open. Tool open with 105 gpm, 410 psi (note: Flow path is 90% out of circulation sub, 10% out bit. Continue to build 100 bbl LCM pill and take on mud into the pits. POOH on elevators from 11455 ft to 13098 ft. Drop ball and pump down to close BHA off 100%with 105 gpm,470 psi, 0% return flow. Observed flow going down flow line from rig floor. Chase ball with 20 bbls mud and 100 bbl LCM pill (9.8 ppg). Spot 75 bbl LCM pill out of circulation sub. Monitor well: Breathing at 2 bbls every 5 minutes. Pump 250 strokes to clear LCM pill out of pipe. Shut down. Observe well breathing 3-4 bpm every 5 minutes. Pump 733 strokes at 126 gpm, 580 psi. Observed flow at floor but not at TOTCO screen. Lost 68 bbls and observed 8 bbl gain. Shut down and monitor well. Well breathing at 4-5 bpm every 5 minutes; pressure on drill string increased to 180 psi in 5 minutes. Bleed pressure off drill string: Observed pressure going through bleeder and breathing on back side down flow line. Open choke HCR and shut annular to record pressures: 190 psi on drill string and 30 psi on casing. Note losses from 1200 2359 hours at 262 bbls. Well is currently closed in at 2359 hrs report time. April 5, 2011 Continue to perform exhale test: SIDPP= 170 psi, SICP = 0 psi. Bleed drill pipe pressure to pits and shut back in. Monitor SIDPP = 0, SICP = o. Open well per company man: Monitor well on trip tank. Well breathing back 3 bbls/10 minutes. Observe well breathing for 1 hour. Well gives back 23 bbls in 1 hour. POOH with pumps from 13067 ft to 12622 ft: at 1 bpm, 380 psi. Monitor well at 12622 ft. Well still breathing. Continue POOH with pumps from 12622 ft to 11451 ft at 2 bpm, 460 psi. Monitor well at 11451. Well still slightly breathing. Pump 317 strokes at 3 bpm,560 psi. Observe well breath back mud. Pumped 32 bbls and well breathed back 27.5 bbls. Wait on orders from town. POOH with pumps from 11451 ft to 10063 ft at 1.5 bpm,460 psi. Continue to POOH with pumps at 60 fpm, 1.5 bpm, 310 psi from 10063 ft to 4947 ft. POOH on elevators from 4947 ft to 2957 ft. At 2957 ft pump dry job(11.8 ppg, 55 vis)at 150 gpm,220 psi. Continue to POOH on elevators from 2957 ft to 589 ft. Monitor well at 589 ft: Static. Currently laying down BHA at report time. April 6, 2011 Complete laying down BHA. Rig up to run 3-1/2"liner. Run 3-1/2"liner per detail to 1850 ft. Make up hanger assembly; mix and let PAL mix set for 30 minutes. RIH with 1 stand 4"drill pipe from 1850 ft to 1951 ft. Pump through string to ensure liner is clear at 2 bpm, 210 psi. Blow down top drive. RIH with 4" drill pipe from 19 CANRIG ConocoPhillips Alaska.Inc 2L-306 derrick from 1951 ft to 13157 ft filling pipe every 10 stands with no problems encountered. At 113157 ft drop ball and pump down at 3 bpm, 380 psi, no returns. Ball on seat at 1157 strokes. Pressure up to 2500 psi,set 35k on hanger; bring pressure up to 3500 psi; bleed off. Pick up to 178k (+5): Hanger not set. Slack off to 75k; pressure up to 2500 psi and hold for 2 minutes. Pressure up to 4500 psi; blow ball out. Pull up to see if hanger is set. Pressure up to 1000 psi on annulus: Hanger set at report time. Total mud loss 1200 to 2359 hours= 121 bbls. April 7, 2011 Continue to set liner per Baker hand at 11307 ft. Lay down 3 joints 4"drill pipe. Test annulus to 1000 psi for 15 minutes. Rig down and blow down lines. Monitor well at 11184 ft: Monitor until static. Pump slug at 11184 ft. POOH on trip tank and lay down 4"drill pipe from 11184 ft to 57 ft. Lay down hanger landing tool. Drain stack, pull wear ring,function BOPE. Lay down running tool and XT-39 thread protectors from rig floor. Rig up to run 3-1/2" tubing with chemical line. RIH with 3-1/2", 9.3#, L-80, EUD 8RD tubing from seal assembly mule shoe to chemical injection mandrel (748 ft). Currently trouble shooting chemical injection mandrel and spool at report time. April 8,2011 Continue to RIH with 3-1/2",9.3#, L-80, EU 8RD MOD completion tubing per detail. Make up crossover to top over joint#355. Tag top of seals at 11356 ft. at 11350 ft displace to brine: 50 bbl 9.8 brine with 2 drums Safe-Surf w; 50 bbl 9.8 brine viscosified with 3#/bbl Flowzan; 195 bbls 9.8 brine; 231 bbls 9.8 brine with 2% CRW at 3 bpm, 580 psi at 2466 strokes; increase to 4 bpm, 640 psi. Continue ops at report time. April 9, 2011 Rig down and prepare for rig move 20 C:ANRIG 1.-- ConocoPhillips Alaska.Inc. 2L-306 5.2 Survey Data Measured Inclination Azimuth True Latitude Departure Vertical Dogleg Depth Vertical N(+)/S(-) E(+)/W(-) Section Rate Depth (feet) (degrees)) (degrees) (feet) (feet) (feet) (feet) (°/100ft) 40.35 0 0 40.35 0 0 0 0 82.00 0.39 268.81 82.00 0 -0.14 -0.04 0.94 171.00 0.1. 252.72 171.00 -0.03 -0.52 -0.14 0.33 261.00 0.27 345.44 261.00 0.15 -0.65 -0.35 0.32 334.00 3.87 46.68 348.93 2.39 1.46 -1.78 4.26 439.00 5.71 47.48 438.61 7.50 6.97 -4.82 2.05 533.00 7.11 43.86 532.02 14.85 14.45 -9.34 1.55 628.00 8.78 40.16 626.11 24.63 23.20 -15.74 1.84 723.00 12.21 34.76 719.51 38.43 33.61 -25.40 3.75 817.00 15.89 35.26 810.68 57.11 46.71 -38.80 3.92 912.00 22.62 36.99 900.31 82.35 65.23 -56.63 7.11 945.00 24.92 37.86 930.51 92.91 73.32 -63.98 7.05 989.94 26.44 40.80 971.01 107.96 85.66 -74.19 4.41 1023.20 28.13 41.36 1000.57 119.46 95.69 -81.80 5.14 1052.01 29.14 42.27 1025.86 129.74 104.89 -88.53 3.82 1150.43 29.87 44.69 1111.52 164.90 138.25 -110.91 1.42 1243.96 31.85 46.43 1191.80 198.47 172.51 -131.49 2.32 1339.44 37.43 46.92 1270.33 235.68 211.99 -153.83 5.85 1383.29 38.72 47.42 1304.84 254.07 231.82 -164.75 3.02 1434.13 38.08 50.49 1344.69 274.80 255.63 -176.61 3.96 1528.93 38.37 50.53 1419.16 312.10 300.89 -197.14 0.31 1623.41 41.41 52.21 1491.65 349.90 348.24 -217.46 3.41 1718.28 45.25 54.73 1560.65 388.60 400.56 -237.02 4.44 1811.83 48.27 57.10 1624.74 426.75 457.01 -254.71 3.72 1907.80 53.89 59.88 1685.01 465.69 520.66 -270.81 6.27 1950.44 55.17 60.89 1709.75 482.85 550.85 -277.20 3.57 2000.45 55.91 61.99 1738.05 502.56 587.07 -284.05 2.34 2097.54 59.57 64.00 1789.87 539.81 660.22 -295.45 4.16 2188.16 63.32 66.62 1833.19 573.01 732.53 -303.31 4.85 2284.29 67.37 67.80 1873.28 606.83 813.06 -309.07 4.36 2378.97 70.80. 65.56 1907.08 641.86 894.25 -315.75 4.24 2476.06 71.00 65.15 1938.85 680.11 977.64 -324.77 0.45 2571.42 68.92 64.48 1971.52 718.23 1058.71 -334.42 2.28 2666.35 68.92 64.82 2005.67 756.15 1138.75 -344.22 0.33 2761.37 68.77 63.78 2039.96 794.58 1218.60 -354.55 1.03 21 CANRIG ConocoPhillips Alaska.Inc. 2L-306 Measured Inclination Azimuth True Latitude Departure Vertical Dogleg Depth Vertical N(+)/S(-) E(+)/W(-) Section Rate Depth (feet) (degrees)) (degrees) (feet) (feet) (feet) (feet) (°/100ft) 2855.26 68.80 64.70 2073.94 832.62 1297.43 -364.86 0.91 2951.58 69.11 64.42 2108.52 871.24 1378.61 -374.94 0.42 3046.35 69.55 65.30 2141.98 908.91 1458.88 -384.42 0.99 3140.61 68.02 65.38 2176.09 945.57 1538.73 -393.09 1.63 3234.47 68.78 65.12 2210.64 982.10 1617.99 -401.83 0.85 3329.10 68.07 65.64 2245.44 1018.77 1697.98 -410.45 0.91 3423.37 67.84 65.45 2280.82 1054.94 1777.52 -418.76 0.31 3519.05 67.79 65.73 2316.95 1091.55 1858.20 -427.11 0.28 3613.92 68.07 66.08 2352.59 1127.44 1938.46 -434.92 0.45 3677.51 68.07 67.24 2376.34 1150.81 1992.62 -439.38 1.69 3772.59 68.98 66.00 2411.15 1185.93 2073.83 -446.14 1.55 3866.82 69.37 64.44 2444.65 1222.84 2153.79 -455.01 1.60 3962.23 69.31 63.33 2478.32 1262.14 2233.95 -466.07 1.09 4056.50 69.52 63.33 2511.46 1301.75 2312.81 -477.85 0.22 4152.30 70.07 63.67 2544.55 1341.86 2393.27 -489.58 0.66 4245.79 70.28 63.70 2576.26 1380.85 2472.10 -500.78 0.23 4341.79 69.18 64.14 2609.52 1420.44 2552.99 -511.88 1.22 4435.95 67.88 63.81 2643.98 1458.89 2631.73 -522.60 1.42 4530.78 67.99 64.03 2679.60 1497.52 2710.66 -533.43 0.24 4623.81 68.25 63.79 2714.27 1535.49 2788.19 -544.09 0.37 4715.23 68.22 63.96 2748.17 1572.87 2864.42 -554.62 0.18 4814.70 68.50 63.93 2784.85 1613.49 2947.49 -565.97 0.28 4911.54 68.56 64.02 2820.30 1653.03 3028.47 -576.99 0.11 5004.84 68.52 64.30 2854.43 1690.87 3106.62 -587.34 0.28 5097.80 68.51 64.38 2888.48 1728.33 3184.59 -597.37 0.08 5195.64 68.72 64.13 2924.15 1767.90 3266.65 -608.07 0.32 5287.34 68.78 64.36 2957.39 1805.04 3343.62 -618.12 0.24 5382.08 68.88 64.87 2991.60 1842.91 3423.44 -627.95 0.51 5479.29 69.09 64.61 3026.46 1881.64 3505.51 -637.84 0.33 5574.59 67.61 65.22 3061.62 1919.19 3585.72 -647.23 1.66 5664.01 67.47 65.01 3095.79 1953.96 3660.69 -655.70 0.27 5761.22 67.37 64.52 3133.11 1992.23 3741.88 -665.45 0.48 5858.45 67.30 64.35 3170.58 2030.95 3822.82 -675.71 0.18 5953.26 67.30 64.78 3207.17 2068.51 3901.81 -685.51 0.42 6048.12 67.16 64.75 3243.88 2105.80 3980.93 -695.01 0.15 22 ConocoPhillips Alaska.Inc. 2L-306 Measured Inclination Azimuth True Latitude Departure Vertical Dogleg Depth Vertical N(+)/S(-) E(+)/W(-) Section Rate Depth (feet) (degrees)) (degrees) (feet) (feet) (feet) (feet) (°/100ft) 6142.57 67.07 65.05 3280.61 2142.72 4059.72 -704.26 0.31 6235.39 68.65 63.88 3315.59 2179.78 4137.30 -714.05 2.06 6331.01 68.94 63.65 3350.18 2219.19 4217.26 -725.28 0.38 6425.28 69.04 63.16 3383.98 2258.58 4295.95 -736.91 0.50 6519.18 68.77 63.71 3417.77 2297.76 4374.31 -748.44 0.62 6614.54 68.76 64.93 3452.31 2336.28 4454.41 -758.78 1.19 6711.48 68.65 64.85 3487.52 2374.61 4536.20 -768.39 0.14 6805.80 68.21 64.94 3522.19 2411.82 4615.63 -777.72 0.47 6899.87 68.22 65.05 3557.11 2448.75 4694.79 -786.86 0.11 6994.84 67.93 64.61 3592.57 2486.22 4774.53 -796.33 0.53 7088.97 68.82 63.51 3627.26 2524.50 4853.21 -806.90 1.44 7183.99 68.62 63.12 3661.74 2564.26 4932.32 -818.74 0.44 7279.07 68.47 63.04 3696.52 2604.32 5011.22 -830.94 0.18 7372.21 68.40 63.03 3730.75 2643.60 5088.43 -842.94 0.08 7468.46 68.97 64.50 3765.74 2683.23 5168.85 -854.23 1.54 7561.80 68.94 64.78 3799.26 2720.55 5247.57 -863.88 0.28 7656.51 69.04 64.52 3833.22 2758.40 5327.47 -873.66 0.28 7751.97 69.06 64.85 3867.35 2796.52 5408.06 -883.47 0.32 7847.98 68.70 64.83 3901.94 2834.60 5489.13 -893.08 0.38 7939.44 68.78 64.56 3935.11 2871.03 5566.18 -902.44 0.29 8033.87 68.57 64.72 3969.45 2908.70 5645.67 -912.18 0.27 8130.19 68.45 64.48 4004.73 2947.15 5726.63 -922.17 0.26 8223.22 68.45 64.69 4038.90 2984.28 5804.78 -931.84 0.21 8318.19 68.78 64.33 4073.53 3022.34 5884.61 -941.83 0.50 8413.78 68.69 64.33 4108.20 3060.93 5964.90 -952.18 0.09 8510.76 68.77 64.69 4143.38 3099.82 6046.47 -962.40 0.36 8603.61 68.90 64.52 4176.91 3136.95 6124.69 -972.04 0.22 8700.54 68.71 64.46 4211.95 3175.87 6206.26 -982.29 0.20 8795.55 68.64 64.55 4246.50 3213.97 6286.14 -992.30 0.11 8889.87 68.57 64.48 4280.91 3251.76 6365.42 -1002.22 0.10 8984.40 68.54 64.32 4315.47 3289.77 6444.77 -1012.33 0.16 9077.45 67.41 67.48 4350.37 3325.00 6523.49 -1020.00 3.37 9171.68 67.16 71.14 4386.77 3355.70 6604.78 -1022.57 3.59 9267.33 67.20 75.52 4423.88 3380.99 6689.22 -1018.99 4.22 9359.30 65.60 77.82 4460.71 3400.42 6771.21 -1010.67 2.88 23 CANRIG ConocoPhillips Alaska.Inc 2L-306 Measured Inclination Azimuth True Latitude Departure Vertical Dogleg Depth Vertical N(+)/S(-) E(+)/W(-) Section Rate Depth (feet) (degrees)) (degrees) (feet) (feet) (feet) (feet) (°/100ft) 9441.79 63.03 80.59 4496.46 3414.36 6844.21 -1000.08 4.34 9540.08 60.85 85.80 4542.72 3424.68 6930.29 -981.81 5.18 9582.73 60.38 87.06 4563.65 3426.99 6967.38 -971.92 2.80 9633.23 59.37 89.45 4588.99 3428.33 7011.03 -958.97 4.56 9730.21 59.66 93.96 4638.21 3425.83 7094.53 -929.43 4.02 9825.31 60.37 98.85 4685.76 3416.64 7176.35 -894.10 4.52 9917.43 61.37 103.73 4730.63 3400.87 7255.22 -853.52 4.75 10011.46 61.99 107.50 4775.25 3378.59 7334.92 -806.50 3.59 10107.07 62.48 111.30 4819.80 3350.49 7414.70 -753.96 3.55 10204.22 63.22 116.68 4864.15 3315.35 7493.63 -695.04 4.99 10294.23 62.33 120.66 4905.35 3276.97 7563.84 -635.89 4.05 10391.88 62.73 123.53 4950.40 3230.94 7637.22 -568.48 2.64 10488.13 64.12 127.36 4993.47 3181.02 7707.32 -498.45 3.84 10580.03 64.55 131.76 5033.29 3128.28 7771.16 -427.80 4.34 10675.06 64.61 136.79 5074.10 3068.39 7832.58 -351.18 4.78 10770.93 66.25 140.78 5113.98 3002.81 7890.00 -270.48 4.15 10864.03 67.70 144.96 5150.40 2934.51 7941.69 -189.07 4.42 10959.28 68.95 149.01 5185.59 2860.30 7989.89 -103.21 4.16 10979.00 69.72 148.97 5192.55 2844.48 7999.40 -85.16 3.91 10981.68 69.82 148.97 5193.48 2842.33 8000.69 -82.70 3.73 11031.69 70.95 149.54 5210.27 2801.84 8024.78 -36.58 2.50 11125.43 71.06 152.05 5240.78 2724.48 8068.02 50.65 2.53 11222.32 69.72 154.84 5273.31 2642.86 8108.82 141.11 3.04 11315.10 68.85 157.50 5306.13 2563.48 8143.89 227.57 2.84 11411.78 70.28 160.95 5339.89 2478.79 8176.00 318.10 3.66 11443.89 70.30 161.37 5350.72 2450.18 8185.76 348.33 1.23 11490.00 72.99 162.02 5365.24 2408.64 8199.51 392.09 5.99 11563.20 77.26 163.01 5384.03 2341.17 8220.75 462.79 5.98 11608.12 76.42 161.66 5394.26 2299.50 8234.02 506.52 3.47 11653.82 77.50 161.82 5404.57 2257.22 8247.97 551.04 2.39 11703.61 79.11 161.18 5414.66 2210.98 8263.44 599.79 3.47 11759.23 80.56 160.53 5424.48 2159.27 8281.40 654.54 2.85 11798.67 82.15 160.10 5430.40 2122.56 8294.53 693.52 4.17 11843.74 83.93 160.71 5435.86 2080.41 8309.54 738.26 4.17 11890.12 84.66 160.73 5440.48 2036.85 8324.77 784.41 1.57 24 CANRIG COnocc hiiiips Alaska.Inc. 2L-306 Measured Inclination Azimuth True Latitude Departure Vertical Dogleg Depth Vertical N(+)/S(-) E(+)/W(-) Section Rate Depth (feet) (degrees)) (degrees) (feet) (feet) (feet) (feet) (°/100ft) 11988.18 89.24 162.74 5445.69 1943.89 8355.45 882.29 5.10 12031.80 89.52 162.22 5446.16 1902.3 8368.58 925.89 1.35 12082.69 91.54 162.22 5445.69 1853.84 8384.12 976.77 3.97 12177.12 92.95 161.07 5441.99 1764.29 8413.83 1071.11 1.93 12270.60 89.79 160.69 5439.76 1676.00 8444.44 1164.55 3.40 12364.59 89.82 160.65 5440.08 1587.31 8475.55 1258.54 0.05 12459.82 89.45 160.95 5440.69 1497.38 8506.87 1353.77 0.50 12554.58 88.95 160.62 5442.01 1407.91 8538.05 1448.52 0.63 12648.66 91.55 162.92 5441.60 1318.56 8567.48 1542.57 3.69 12742.96 89.71 162.78 _ 5440.56 1228.47 8595.28 1636.82 1.96 12839.26 90.00 163.24 5440.81 1136.37 8623.42 1733.06 0.56 12933.00 89.13 163.25 5441.52 1046.61 8650.44 1826.72 0.93 13029.60 88.72 161.76 5443.33 954.50 8679.48 1923.27 1.60 13157.00 88.72 161.76 5446.18 833.53 8719.34 2050.62 0.00 pb 10959.28 68.95 149.01 5185.59 2860.30 7989.89 8435.57 4.16 pb 11054.79 66.64 151.92 5221.69 2783.39 8033.49 8460.12 3.72 pb 11147.85 64.55 155.81 5260.15 2707.34 8070.83 8478.79 4.42 pb 11241.67 63.03 159.60 5301.60 2629.49 8102.77 8491.79 3.97 pb 11340.68 63.14 159.59 5346.42 2546.74 8133.55 8502.53 0.11 pb 11435.73 63.23 159.86 5389.30 2467.17 8162.95 8512.66 0.27 pb 11524.78 63.16 159.54 5429.46 2392.63 8190.52 8522.18 0.33 pb 11625.32 63.12 159.25 5474.88 2308.67 8222.09 8533.39 0.26 pb 11719.90 63.51 159.45 5517.36 2229.59 8251.89 8544.03 0.45 pb 11779.43 63.84 159.20 5543.76 2179.67 8270.73 8550.77 0.67 pb 11824.00 63.84 159.20 5563.41 2142.28 8284.93 8555.91 0.00 NOTE: Surveys indicated by (Pb) are from plugged back hole section. 25 CANRIG CD N X a N X 0. 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Tarn 2L-306 Daily Report Report for: Scott Heim Springer/Larry Date: 03/1/2011 Time: 00:00 Current Depth (MD): 725 Current Drilling Ahead Current Depth (TVD): 713 Operations: 24 hr Footage (MD): 725 Drilling Parameters ROP: Current: _ 214 Max: 335 Torque: Current: N/A Max: N/A WOB: Current 19.5 Max: 22 RPM: Current: 0 Max: 61 PP: Current: 1338 Max: 1439 Lag: Strokes: 398 Time: 2.6min Surf-Surf: Strokes: 474 Time: 3.1 min ECD: Current: - Max: - Mud Properties @ 540 MW: 8.9 FV: 318 PV: 50 YP: 60 FL: 8.4 Gels: 31/62/81 Sol: 4% pH: 8.4 Cr: 600 Ca' 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: Ou Max: 48u Depth (MD/TVD): Trip Gas/BU gas Average: 5u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) 23u 719' MD 9893.457 - - - - - - Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 80% Sand, 20% Conglomeritic Sand Last 24 hrs: Sand, Conglomeritic Sand, Conglomerate Operational Summary: Pick up 5"Drill pipe from the shed and stand back in the derrick. Function test diverter line. Pick up bit and BHA. Drill from bottom of conductor at 136'to 725' MD. Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3,430.00 CANRIG ,DRAIN,rI„1.o1. 1 Lrn_ ConocoPhillips Alaska,Inc. Tarn 2L-306 Daily Report Report for: Scott Heim Larry Hill Date: 03/2/2011 Time: 00:00 Current Depth (MD): 2145 Current Drilling Ahead Current Depth (TVD): 1816 Operations: 24 hr Footage (MD): 1420 Drilling Parameters ROP: Current: 127 _ Max: 343 Torque: Current: N/A Max: N/A WOB: Current 18.3 Max: 41.8 RPM: Current: 64 Max: 65 PP: Current: 2004 Max: 2037 _ _Lag: Strokes: 3208 Time: 22.6min Surf-Surf: Strokes: 9939 Time: 70min ECD: Current: - Max: Mud Pro e rties @ 1927' MW: 9.5 FV: 303 PV: 60 YP: 65 FL: 6.8 Gels: 20/52/66 Sol: 7% pH: 8.4 Cr: 600 Ca++ 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 110u Max: 1254u Depth (MD/TVD): Trip Gas/BU gas Average: 200u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 _Gases (MD/TVD) - - - Gas Peaks _ Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 80% Claystone, 20% Sand Last 24 hrs: Claystone, Sand, Conglomeritic Sand, Conglomerate Operational Summary: Drill from 724'to 1008'. POOH to 900'and trough to 912'.Trip back to bottom and drill 1038'. Drill ahead watching for hydrates to 2145' MD. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 Daily Report Report for: Scott Heim Larry Hill Date: 03/3/2011 Time: 00:00 Current Depth (MD): 3672 Current Back reaming out Current Depth (TVD): 2374 Operations: 24 hr Footage (MD): 1527 Drilling Parameters ROP: Current: 0 Max: 304 Torque: Current: N/A Max: N/A WOB: Current 0 Max: 32.5 RPM: Current: 0 Max: 65 PP: Current: 1238 Max: 2477 Lag: Strokes: 5496 Time: 35.7min Surf-Surf: Strokes: 11626 Time: 75.5min ECD: Current: - Max: - Mud Properties @ 3672' MW: 9.5 FV: 274 PV: 54 YP: 62 FL: _ 6.6 Gels: 12/51/74 Sol: 7.5% pH: 8.7 Cr: 600 Ca++ 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: Ou Max: 568u Depth (MD/TVD): Trip Gas/BU gas Average: 110u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 100%Claystone Last 24 hrs: Claystone, Sand, Conglomeritic Sand, Conglomerate Operational Summary: Drill from 2145'to 3672' MD, 2374'TVD. Circulated bottoms up. Back reamed out of the hole from 3672'to 3241'. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,370.00 CANRIG Dxuirec 1r11,,, ',,I.rr, ConocoPhillips Alaska,Inc. Tarn 2L-306 Daily Report Report for: Scott Heim Larry Hill Date: 03/4/2011 Time: 00:00 Current Depth (MD): 3672 Current RIH Casing Current Depth (TVD): 2374 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: _ 0 Max: 0 Torque: Current: N/A Max: _ N/A WOB: Current 0 Max: 0 RPM: Current: 0 Max: _ 0 PP: Current: 0 Max: 1284 Lag: Strokes: 5496 Time: 35.7min Surf-Surf: Strokes: 11626 Time: 75.5min ECD: Current: , - Max: - Mud Properties @ 3672' MW: 9.5 FV: 308 PV: 52 YP: 53 FL: 5.8 _ Gels: 12/44/62 Sol: 7.5% pH: 8.8 Cr: 600 Ca" 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: Ou Max: 263u Depth (MD/TVD): Trip Gas/BU gas Average: 120u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth C1 C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 105 nC5 Lithologies: Current: 100%Claystone Last 24 hrs: Claystone, Sand, Conglomeritic Sand, Conglomerate BROOH from 2700'to 1900'. No tight spots or overpulls noted. TIH from 536'to 3672'. Operational Summary: Circulate 3x bottoms up. Pulled out of hole on elevators form 3672'to surface. Laid down BHA. Rigged up to run casing. RIH casing. Calibrations: Chromatograph, THA. Failures: None Daily Cost:$3,370.00 CANRIG ConocoPhillips • Alaska,Inc. Tarn 2L-306 Daily Report Report for: Scott Heim Larry Hill Date: 03/5/2011 Time: 00:00 Current Depth (MD): 3672 Current Nipple down stack Current Depth (TVD): 2374 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0._ Torque: Current: N/A Max: N/A WOB: Current 0 Max: _ 0 RPM: Current: 0 Max: _0____ PP: Current: 0 Max: 0 Lag: Strokes: 5496 Time: 35.7min Surf-Surf: Strokes: 11626 Time: 75.5min ECD: Current: - Max: - Mud Properties @ 3672' MW: 9.4 FV: 58 PV: 41 _ YP: 20 FL: 6.4 Gels: 6/10/13 Sol: 6.8% pH: 8.3 Cr: 600 Ca" 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: _ Ou Max: Ou Depth (MD/TVD): Trip Gas/BU gas Average: Ou Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 100% Claystone Last 24 hrs: Claystone, Sand, Conglomeritic Sand, Conglomerate Continue running in casing.While reciprocating the casing stuck 9"high of the hanger. Operational Summary: Rigged down cementing equip. Nipple down stack, set emergency slips. Cleared the rig floor. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 Daily Report Report for: Scott Heim Larry Hill Date: 03/6/2011 Time: 00:00 Current Depth (MD): 3672 Current Testing BOP Current Depth (TVD): 2374 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: N/A Max: N/A WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 5496 Time: 35.7min Surf-Surf: Strokes: 11626 Time: 75.5min ECD: Current: - Max: - Mud Properties @ 3672' MW: _ 9.5 FV: 51 PV: 10 YP: 22 FL: 6 Gels: 8/10/12 Sol: 4.5% pH: 8.7 Cr: 400 Ca++ 140 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: Ou Max: Ou Depth (MD/TVD): Trip Gas/BU gas Average: Ou Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) - - Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 100%Claystone Last 24 hrs: Claystone, Sand, Conglomeritic Sand, Conglomerate Operational Summary: N/D diverter. Installed well head equip as per FMC. N/U BOPE. Changed rams and test BOPS.. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 Daily Report Report for: Scott Heim Larry Hill Date: 03/7/2011 Time: 00:00 Current Depth (MD): 3672 Current RIH Current Depth (TVD): 2374 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: N/A Max: N/A WOB: Current _ 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: _ 0 Max: 0 Lag: Strokes: 5496 Time: , 35.7min Surf-Surf: Strokes: 11626 Time: 75.5min ECD: Current: - Max: - Mud Properties @ 3672' MW: 9.5 FV: 51 PV: 11 _ YP: _ 20 FL: 6 Gels: 8/9/12 Sol: 4.5% pH: 8.8 Cr: 400 Ca" 120 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: Ou Max: Ou Depth (MD/TVD): Trip Gas/BU gas Average: Ou Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 100%Claystone Last 24 hrs: Claystone, Sand, Conglomeritic Sand, Conglomerate Operational Summary: Change out upper rams to 5'. Test BOPE. Pick up 5"drill pipe from pipe shed. Pick up 9.875"bit and new BHA as per DD. Single in the hole. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 Daily Report Report for: Pat Archey Larry Hill Date: 03/8/2011 Time: 00:00 Current Depth (MD): 4607 Current Drilling Ahead Current Depth (TVD): 2706 Operations: 24 hr Footage (MD): 935 Drilling Parameters ROP: Current: 202 Max: 255 Torque: Current: 13011 Max: 13479 WOB: Current n/a Max: RPM: Current: 120 Max: 122 PP: Current: 2577 Max: 2962 Lag: Strokes: 3187 Time: 16.7min Surf-Surf: Strokes: 9400 Time: 49.2min ECD: Current: - Max: - Mud Properties @ 4286' MW: 9.5 FV: 48 PV: 11 YP: 25 FL: 6.5 Gels: 11/16/19 Sol: 5% pH: 9.5 Cr: 400 Ca" 60 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 80u Max: 207u Depth (MDJTVD): Trip Gas/BU gas Average: 50u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 80% Claystone, 20%Siltstone Last 24 hrs: Claystone, Sand, Conglomeritic Sand, Conglomerate, Siltstone Test casing and drill out plug. Mill shoe and displace to new LSND while drilling out rat Operational Summary: hole. Drill 20'of new hole and perform FIT test to 16ppg EMW. Drill ahead per DD to 4607' MD, 2706'TVD. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,370.00 CANRIG Dxu ninr T111,01111 Ln_ ConocoPhillips Alaska,Inc. Tarn 2L-306 Daily Report Report for: Pat Archey Larry Hill Date: 03/9/2011 Time: 00:00 Current Depth (MD): 6182 Current Pumping out of hole Current Depth (TVD): 3296 Operations: 24 hr Footage (MD): 1575 _Drilling Parameters _ ROP: Current: 0 Max: 235 Torque: Current: 0 Max: 13932 WOB: Current n/a Max: RPM: Current: 0 Max: 137 PP: Current: 0 Max: 3220 Lag: Strokes: 2975 Time: 15.6min Surf-Surf: Strokes: 13011 Time: 68.1 min ECD: Current: - Max: - Mud Properties @ 6182' MW: 9.5 FV: 45 _ PV: 15 YP: 24 FL: 4.4 Gels: 8/14/18 Sol: 6% pH: 9.7 Cr: 600 Ca" 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: Ou Max: 89u Depth (MD/TVD): Trip Gas/BU gas Average: 30u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 60%Siltstone, 40%Sandstone Last 24 hrs: Claystone, Sand, Siltstone Drilled F/4,602'T/6,182' MD. Rotate and Reciprocate while circulating bottoms up @ Operational Summary: 6,182'. Backream out of hole to 3,663'. Circulate bottoms up @ shoe, drop ball and open well commander. Pump out from 4,050'to 3,906' MD. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 Daily Report Report for: Pat Archey Larry Hill Date: 03/10/2011 Time: 00:00 Current Depth (MD): 7740 Current Drilling Ahead Current Depth (TVD): 3863 Operations: 24 hr Footage (MD): 1558 Drilling Parameters ROP: Current: 178 Max: 235 Torque: Current: 14874 Max: 19084 WOB: Current n/a Max: n/a RPM: Current: 120 Max: 125 PP: Current: 3590 Max: 3645 Lag: Strokes: 5350 Time: 28min Surf-Surf: Strokes: 14903 Time: 78min ECD: Current: - Max: - Mud Properties @ 7510' MW: 9.5 FV: 45 PV: 14 YP: 23 FL: 4.7 Gels: 8/11/15 Sol: 7% pH: 9.3 Cr: 600 Ca++ 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 86u Max: 86 Depth (MD/TVD): Trip Gas/BU gas Average: 37u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 100% Siltstone Last 24 hrs: Claystone, Sandstone, Sand, Siltstone Operational Summary: RIH,wash and ream down from 6,090'to 6,182'. Drilled from 6,812'to 7,740' MD. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 Daily Report Report for: Pat Archey Larry Hill Date: 03/11/2011 Time: 00:00 Current Depth (MD): 8685 Current Drilling Ahead Current Depth (TVD): 4206 Operations: 24 hr Footage (MD): 945 Drilling Parameters ROP: Current: 120 Max: 143 Torque: Current: 16742 Max: 17864 WOB: Current 6.7 Max: 8.7 RPM: Current: 122 Max: 123 PP: Current: 3791 Max: 3988 Lag: Strokes: 6003 Time: 31.4min Surf-Surf: Strokes: 13725 Time: 71.9min ECD: Current: - Max: - Mud Properties @ 8486' MW: 9.6 FV: 44 PV: 16 YP: 24 FL: 3.3 Gels: 8/11/14 Sol: 8% pH: 9.3 CF: 600 Ca' 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 54u Max: 172 Depth (MD/TVD): Trip Gas/BU gas Average: 30u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 70% Siltstone, 30%Silty Shale Last 24 hrs: Claystone, Sandstone, Sand, Siltstone, Shale Drilled from 7,740'to 7,887'.Trouble shoot mud pump#2. BROOH from 7,887 to Operational Summary: 6,087'. RIH from 6,087'to 7,800'. Wash down from 7,800'to 7,887'. Continue drilling from 7,887'to 8,685'. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 Daily Report Report for: Pat Archey Larry Hill Date: 03/12/2011 Time: 00:00 Current Depth (MD): 9134 Current BROOH Current Depth (TVD): 4372 Operations: 24 hr Footage (MD): 439 Drilling Parameters ROP: Current: 0 Max: 121 Torque: Current: 0 Max: 16564 WOB: _ Current 0 Max: 6.8 RPM: Current: 0 Max: 123 PP: Current: 0 Max: 3878 Lag: Strokes: 2775 Time: 14.5min Surf-Surf: Strokes: 10755 Time: 56.3min ECD: Current: - Max: - Mud Properties @ 9135' MW: 9.7 FV: 47 PV: 12 YP: 18 FL: 3.5 Gels: 5/9/12 Sol: 9% pH: 9.3 Cr: 600 Ca++ 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: Ou Max: 89 Depth (MD/TVD): Trip Gas/BU gas Average: 34u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth C1 C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 60% Siltstone, 30%Silty Shale, 10%Calcilutite Last 24 hrs: Claystone, Sandstone, Sand, Siltstone, Shale, Calcilutite Drilled from 8,685'to 9,314'. Circulated and conditioned mud while trouble shooting Operational Summary: mud pump#2. BROOH from 9,134'to 5,420'. Circulated mud while trouble shooting TDS-8. Circulate bottoms up, Flow check well (static). Lubricate Top Drive and draw works. BROOH from 5,420'to 3,717'. Circulate bottoms up @ 450 gpm Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 Daily Report Report for: Pat Archey Larry Hill Date: 03/13/2011 Time: 00:00 Current Depth (MD): 9401 Current POOH Current Depth (TVD): 4478 Operations: 24 hr Footage (MD): 267 Drilling Parameters ROP: Current: 0 Max: 128 Torque: Current: 0 Max: 18139 WOB: Current _ 0 Max: 48 RPM: Current: 0 Max: 122 PP: Current: _ 0 Max: 3917 Lag: _ Strokes: 2945 Time: 15.4min Surf-Surf: Strokes: 10045 Time: 52.6min ECD: Current: - Max: - Mud Properties @ 9407' MW: 9.6 FV: 45 PV: 11 YP: _ 17 FL: 3.2 Gels: 6/9/13 Sol: 9% pH: 9.0 Cr: 700 Ca" 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: Ou Max: 13.4 I Depth (MD/TVD): Trip Gas/BU gas Average: 45u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Gas Peaks _ Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 80% Sand, 20% Siltstone Last 24 hrs: Sandstone, Sand, Siltstone, Shale Serviced rig. Change out fluid end on mud pump#2. RIH from 3,623'to 9,134'. Operational Summary: Continue drilling to 9,401'. Circulate and condition hole, flow check(static). Blow down top drive, POOH on elevators from 9,401'to 8,363', no swabbing, no over pull. Pump dry job and continue to POOH from 8,363'to 4,858'. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3,370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 Daily Report Report for: Pat Archey Larry Hill Date: 03/16/2011 Time: 00:01 Current Depth (MD): 11333 Current Drilling Ahead Current Depth (TVD): 5360 Operations: 24 hr Footage (MD): 1680 Drilling Parameters ROP: Current: 55 Max: 366 Torque: Current: ' 2100 Max: 21100 WOB: Current 45 Max: 74 RPM: Current: 100 Max: 104 PP: Current: 3560 Max: 3906 Lag: Strokes: 7939 Time: 46 Surf-Surf: Strokes: 8870 Time: 57 ECD: Current: - Max: - Mud Properties @ 9487/4550 _ MW: 9.7 FV: 42 PV: 14 _ YP: 23 FL: 3.3 Gels: 9/13/16 Sol: 9 pH: 9.6 Cr: 600 Ca" 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: _ 86u Max: 301 Depth (MD/TVD): 10959 Average: 86 Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth C1 C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) NONE - - - - - - Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 40%shale, 30%siltstone, 30%sandstone Last 24 hrs: Sand, sandstone, sand Drill ahead with no problems encountered. Began controlled drilling at Operational Summary: 11300'MD/5345'TVD at 60 FPH. Canrig collecting cutting samples at 10 foot intervals starting at 11350 ft. Drilling ahead at report time. Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 Daily Report Report for: Pat Archey Larry Hill Date: 03/17/2011 Time: 00:01 Current Depth (MD): 11824 Current POOH Current Depth (TVD): 5565 Operations: 24 hr Footage (MD): 491 Drilling Parameters ROP: Current: N/A Max: 85 Torque: Current: N/A Max: 23112 WOB: Current N/A Max: 26 RPM: Current: N/A Max: 102 PP: Current: N/A Max: 3900 Lag:_ Strokes: 8283 Time: 48 _ Surf-Surf: Strokes: 10300 Time: 60 ECD: Current: - Max: - Mud Properties @ 11824/5565 MW: 9.7 FV: 43 PV: 12 YP: 19 FL: 3.2 Gels: 7/10/15 Sol: 10 __ pH: 9.2 Cr: 600 Ca" 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: _ N/A Max: 638 Depth (MD/TVD): 11547/5432 Average: 212u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) 969u 11824/5564 - - - - - - - Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) NONE - - - - - - Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: 30% shale, 40%siltstone, 30%sandstone Last 24 hrs: SILTSTONE, SANDSTONE, SHALE Continued controlled drilling at<70 FPH from 11350 feet to 11, 824 feet. TD at 11824'MD/5565'TVD at 0925 hours. Circulate and condition mud. Check hole for flow: Static. Short trip from 11824 ft to 9381 ft with no problems. Check hole for flow: Operational Summary: Static. Run back to bottom from 9381 ft to 11824 ft with no problems. Circulate and reciprocate pipe while troubleshooting top drive. Canrig records 969 units of short trip gas with pumps off 4.1 hours during trip. Pull out of hole to 10773 ft. Currently changing out bails at report time. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 Daily Report Report for: Pat Archey Larry Hill Date: 03/18/2011 Time: 00:01 Current Depth (MD): 11824 Current Prep to run cement Current Depth (TVD): 5565 Operations: string 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: n/a Max: n/a Torque: Current: n/a Max: n/a WOB: Current n/a Max: n/a RPM: Current: n/a Max: n/a PP: Current: _ n/a Max: n/a Lag: Strokes: n/a Time: n/a Surf-Surf: Strokes: n/a Time: n/a ECD: Current: - Max: - Mud Properties @ 11824/5565 MW: 9.6 FV: 44 PV: 12 YP: 19 FL: _ 3.4 Gels: , 6/9/12 Sol: 10 pH: 9.3 Cr: 600 Ca" 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: n/a Max: -- Depth (MD/TVD): Average: n/a Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) NONE - - - - - - Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: Last 24 hrs: No new footage drilled last 24 hours Continue trip out of hole from 10773 ft to 675 ft. Stand back HWDP and jars from 675 ft to 226 ft. Handle balance of BHA, remove nukes; lay down mud motor and drill bit. Operational Summary: Change out top set of pipe rams and install 3-1/2"x 6"variable rams;test same at 250 psi low/3000 psi high. Test annular preventer at 250 psi low/2500 psi high. Blow down kill line and choke; install wear bushing. Rig up to run 3-1/2" PH-6 cement string. Currently running 3-1/2"ph-6 tubing as per detail at report time. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report Report for: P. Archey R. Springer Date: 03/19/2011 Time: 00:01 Current Depth (MD): 11824 Current Cement Ops Current Depth (TVD): 5565 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: n/a Max: n/a Torque: Current: n/a Max: n/a WOB: Current n/a Max: n/a RPM: Current: n/a Max: n/a PP: Current: n/a Max: n/a Lag: Strokes: n/a Time: n/ n/a Strokes: n/ Time: n/a ECD: Current: - Max: - Mud Properties n/a at report time MW: FV: PV: YP: FL: Gels: Sol: pH: Cr: Ca' Gas Data Ditch Gas: Current: 8u Max: 51u Depth (MD/TVD): n/a Average: 14u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) 372u 11824/5565 - - - - - - - Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Lithologies: Current: Last 24 hrs: No new footage drilled this period. Continue to run in hole with 3-1/2" PH-6 tubing from 1099 ft to 2237 ft. Transfer weight pipe in derrick from driller's side to off side. Continue RIH from 2237 ft to 4609 ft. Transfer weight pipe in derrick from off side to driller's side. Continue RIH from 4609 ft to 11805 ft. Change out short bails for long before picking up single for cementing. Circulate and condition while reciprocating pipe. Canrig records 372 units maximum trip gas. Turn over operations to cementers. Pump 5 BBL mud push and pressure test Operational Summary: mud lines to 3500 psi. Pump 25 bbls mud push at 12.5 ppg;51.2 bbls of 17 ppg cement; 3.2 bbls 12.5 ppg mud push. Rig displaces 187 bbls of 9.7 ppg mud at 1750 psi, 1850 stks. Break out cement single and POOH from 11824 ft to 11370 ft. Turn over operations to cementers. Pump 30 bbl mud push; 51.2 bbls of 17.0 ppg cement. Rig displaced cement with 179 bbls of 9.7 ppg mud at 1650 psi. POOH from 11370 ft to 10861 ft. Reciprocate pipe wile circulating and conditioning mud after cement job. Vary circulation rates from 3 bpm to 12 bpm. Circulation and conditioning continues at report time. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 ST1 Daily Report Report for: P. Archey, R. Springer Date: 03/20/2011 Time: 00:01 Current Depth (MD): 11824 Current On The Bank: Test Current Depth (TVD): 6656 Operations: BOP's 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: _ Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag:_ _ Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: - Max: - Mud Properties @ 11824/5565 _ MW: 9.6 FV: 54 PV: 20 YP: 24 FL: 8.2 --Gels: 9/26/39 Sol: 10 pH: 9.7 Cr: 900 Ca" 920 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: n/a Max: n/a Depth (MD/TVD): Average: n/a Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) NONE - - - - - - Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: Last 24 hrs: No new footage drilled this period. Continue to circulate and condition mud while reciprocating after cement job. Circulate each 60 ft reciprocation interval+/-30 minutes while treating mud. Stage pump rate up to 10 BPM from 10577 ft to 10293 ft. Begin to stage pumps up to 15 BPM at 9535 ft. Operational Summary: Begin POOH from 9535 ft to 3902 ft. Monitor well via trip tank. Transfer BHA from driller's side to off side of derrick. Continue to POOH from 3902 ft to 1099 ft. Lay down BHA (3-1/2" PH-6 tubing). Clean stack and make preparations to test BOP's. Testing same at report time. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 ST1 Daily Report Report for: P. Archey, R. Springer Date: 03/21/2011 Time: 00:01 Current Depth (MD): 11824 Current Wash and Ream Current Depth (TVD): 6656 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: _ Torque: Current: Max: WOB: Current Max: RPM: Current: _ Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: - Max: - Mud Properties @ 11824/5565 MW: 9.7 FV: 68 PV: 14 YP: 26 FL: 6.8 Gels: 10/23/38 Sol: 8 pH: 9.8 Cr: 700 Ca++ 400 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: 35 Max: 155 u Depth (MD/TVD): While RIH Average: 50 u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) NONE - - - - - - Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: Last 24 hrs: No new footage drilled this period. Continue to test BOP's. Install wear plug. Change out long bails for short and 5"drill pipe elevators. Tr-adjust link tilt bars. Pick up and orientate motor, stabilizer, balance of MWD assembly. Upload MWD and pulse test at 550 GPM, 1000 psi. Load sources and continue to make up BHA. Run in hole. Tag cement stringer at 10319 ft. Operational Summary: Attempts to ream down result in excessive torque/stall. Continue washing and reaming from 10319 ft to 10603 ft. Observe partial losses while backreaming with pump pressure increase. Slowed pump rate and worked string to get full returns back at 10515 ft. Flow check well at 10573 ft. Break circulation at 6 BPM, 750 psi, increasing to 9 BPM, 1220 psi; RPM 70,Torque 22-25k. Continue washing and reaming at report time. Calibrations: Chromatograph, THA. Failures: None CANRIG Daily Cost: $3370.00 CANIRIG r ConocoPhillips Alaska,Inc. Tarn 2L-306 ST1 Daily Report Report for: P. Archey, R. Springer Date: 03/22/2011 Time: 00:01 Current Depth (MD): 11488 Current Wiper trip at Current Depth (TVD): 5366 Operations: intermediate casing point 24 hr Footage (MD): 623 Drilling Parameters ROP: Current: Max: 299 Torque: Current: Max: 29364 WOB: Current Max: 61 RPM: Current: Max: 103 _P_P: Current: Max: 4388 Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: - Max: - Mud Properties @ 11488/5365 MW: 9.6 FV: 42 PV: 15 YP: 19 FL: 5 Gels: 7/12/26 Sol: 8 pH: 9.5 Cr: 700 Ca" 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: n/a Max: 301u Depth (MD/TVD): 10959/5186 Average: 72u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) NONE - - - - - - Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: Last 24 hrs: Sandstone 60%, sand 20%, siltstone 20% Continue to wash and ream cement stringers from 10603 ft to 10687 ft. Canrig records 155 units maximum gas after trip. Drill top of cement from 10936 ft. Condition,work hole and backream at 340 GPM, 1400 psi, 90-100 RPM, torque 25-28k from 10925 ft to Operational Summary: 10885 ft (tight hole section). Troubleshoot excessive chain slap inside guard on ("A" drive motor)#1 mud pump. Also checked fluid ends, liners and swabs;clean suction screen. Drill ahead from 10936 ft to 11488 ft. TD at 11488'MD/5366'TVD. Take survey on bottom; rack back one stand. Circulate bottoms up. Check flow at 11390 ft. Begin short trip from 11390 ft. Currently POOH during short trip at report time. Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 ST1 Daily Report Report for: P. Archey, R. Springer Date: 03/23/2011 Time: 00:01 Current Depth (MD): 11488 Current Prep to run 7-5/8" Current Depth (TVD): 5366 Operations: casing 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: - Max: - Mud Properties @ 11488/5365 MW: 9.7 FV: 47 PV: 14 YP: 24 FL: 5 Gels: 7/12/19 Sol: 9 pH: 9.6 Cr: 600 Ca" 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: n/a Max: n/a Depth (MD/TVD): Average: n/a Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) -from short trip 531 - - - Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) NONE - - - - - - Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: Last 24 hrs: No new footage drilled this period. Continue short trip to 10692. RIH from 10692 ft to 11488 ft. Pump sweep and circulate bottoms up. Note 100% increase in cuttings when sweep reaches surface. Canrig records 531 units max gas from short trip. Circulate and condition (4) bottoms up. Observe well. POOH from 11488 ft to 10700 ft. pump dry job. Blow down top drive. Operational Summary: POOH from 10700 ft to 3000 ft.at 100 ft/min+/-. Observe well at the shoe. Continue POOH from 300 ft to top of BHA at 652 ft. Lat down HWDP,jar stand; pull source; download MWD. Continue laying down BHA to bit. Service rig. Change upper 3-1/2"x 6"VBR's to 7-5/8"solid;test same 250psi low/3500 psi high. Rig up to run 7-5/8" casing. Rig up operations continue at report time. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 ST1 Daily Report Report for: S. Heim, R. Springer Date: 03/24/2011 Time: 00:01 Current Depth (MD): 11488 Current Reciprocate 7-5/8" Current Depth (TVD): 5366 Operations: casing at 8050'MD 24 hr Footage (MD): 0 Drilling Parameters Mud Properties t@a 11488/5365 1815 hrs MW: 9.7 FV: 51 PV: 17 YP: 20 FL: 4 Gels: 9/16/21 Sol: 8.8 pH: 9.9 Cr: 600 Ca" 48 Gas Data < 50 units Ditch Gas: Current: while Max: n/a Depth (MD/TVD): circulating Average: n/a Gas Events None Gas Peaks None Preparations to run 7-5/8",29.7#, L-80 casing continue. Pick up and Bakerlock silver bullet shoe joint;#2 joint;float collar joint. Check float collar equipment: OK. Run 51 Hydroforms at one per joint for 51 joints. Circulate at 2800 ft at 5 BPM with 32o PSI. Fill pipe every joint and top off every 10 joints. Monitor well through pit#4. Continue to RIH with casing to 3600 ft. Reciprocate and circulate 1+pipe volume at the shoe: 5 BPM, 375 PSI. Observe well: Static. Continue running 7-5/8"casing from 3600 ft to 7360 ft per detail: Fill pipe each joint;top off every 10 joints. Circulate and condition mud at 7360 ft. Partial loss of returns. Reduce flow rate from 210 GPM to 184 GPM. Continue running 7-5/8"casing from 7360 ft to 8653 ft: fill each joint,top off every 10 joints. Attempt to establish circulation at 8653 ft at 4 BPM. Immediately observed full loss of returns and packing off. Reduce flow rate to 63 GPM while reciprocating pipe. Observed differential sticking, loss of string weight. Lay down joint#202. Continue to Operational Summary: establish circulation at 63 GPM. Observed packing off and loss of returns. Lay down joint#s 201, 200, 199. Continue to establish circulation at 63 GPM. Establish circulation at 7%flow line returns, 450 psi. Observed packing off and loss of returns. Lay down joint#s 199-195 to 8353 ft. Established circulation at 155 GPM,470 PSI. Circulate 1100 strokes. Condition mud. Observed partial loss of returns;packing off. Pick up joint 3 195. Wash down to establish circulation at 147 GPM, 520 PSI; increase to 210 GPM, 700 PSI. Reciprocate pipe. Observe intermittent packing off. Lay down joint#s 195-190 at 8093'MD. Established circulation at 210 GPM, 600 PSI. Reciprocate pipe. Observed packing off, 1350 strokes. Ly down joint#s 190-188 at 8007'MD. Established circulation at 147 GPM,420 PSI,flow out 12%. Increased flow in at .5 BPM increments to 252 GPM,620 PSI,flow out13%,total strokes 3500. RIH washing down at 168 GPM from 8093 ft : 450 PSI, PU =260k, SO=90k at report time. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 ST1 Daily Report Report for: S. Heim, R. Springer Date: 03/25/2011 Time: 00:01 Current Depth (MD): 11488 Current Laying down 7-5/8" Current Depth (TVD): 5366 Operations: casing 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: - Max: - Mud Properties @ 11488/5365 2000 hrs MW: 9.7 FV: 47 PV: 13 YP: 19 FL: 4.2 Gels: 6/10/14 Sol: 8 pH: 9.7 Cr: 600 Ca' 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: n/a Max: n/a Depth (MD/TVD): Average: < 50 units while circulating. Gas Events None Gas Peaks None RIH with 7-5/8"casing. Continue to wash and work tight spots from8093 ft to 8220 ft. Vary pump as conditions dictate from 3-6 BPM,300-900 PSI, HST 245k,SO 125k. Observe well: Static. Break out and lay down Frank's fill up tool. Reciprocate 7-5/8" casing from 8180 fto to 8215 ft. HST 245k,SO 125k. Change out packer cup and re- install Frank's fill up tool. Continue to wash and work 7-5/8"casing. Break circulation at 8215 ft. Stage pump up to 6 BPM while freeing up pipe. Eventual pack off on down stroke. Pull and lay down joint#192. Find free spot and establish circulation at 4-5 BPM with 450-550 PSI. Work casing and free up from 8140 ft to 8180 ft. Continue to Operational Summary: attempt to raise annular velocity from hole cleaning to 7 BPG (290 GPM)as directed while working pipe. Pack off and pull joint#191 out of hole and lay down. Work pipe and free up from 8130 ft to 8090(joint#190)and establish circulation at 5 BPM and 500 PSI. Rig down and clean up 350 ton slips, elevators, Frank's tool and long bails. Pick up and rig up short bails, 200 ton HYC type elevators, hand slips and stack tongs in preparation to lay down 7-5/8" intermediate casing string. Observe well. Begin to lay down 7-5/8"casing from 8136 ft to 3600 ft. Monitor hole via the trip tank. Obtain torque and drag every 5 joints. Flow check well at shoe. Obtain PU/SO weights every 5 joints. Continue laying down 7-5/8"casing to 131 feet at report time. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 ST1 Daily Report Report for: S. Heim, R. Springer Date: 03/26/2011 Time: 00:01 Current Depth (MD): 11488 Current Wash and Ream Current Depth (TVD): 5366 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: - Max: - Mud Properties @ 11488/5365 2030 hrs MW: 9.7 FV: 50 PV: 11 YP: 19 FL: 4.2 Gels: l 6/10/13 Sol: 8 pH: 9.0 Cr: 600 Ca" 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: n/a Max: n/a Depth (MD/TVD): Average: < 50 units while circulating. Gas Events None Gas Peaks None Continue to lay down 7-5/8"casing, including Baker-Locked shoe track. Observed well. Drain and rinse stack after laying down casing. Change top rams from 7-5/8"to 3-1/2"X 6"variable. Install test plug and test top rams with 5"test joint at 250 PSI low/3500 PSI high. Pull test plug and install wear bushing. Pick up bit, motor, pulser, stabilizer and float sub from beaver slide. Pick up/make up BHA#5 for clean out run. Orient motor to MWD. Pick up remaining BHA to first joint of HWDP. Establish Operational Summary: circulation and pulse test MWD at 430 GPM, 750 PSI. Slip and cut 120 ft drill line. Service draw works,top drive, upper and lower IBOP, crown. Continue to run in hole to 3726 ft. Circulate bottoms up at 800 GPM, 2800 PSI. Canrig records 172 units gas maximum. Continue trip in hole from 3726 ft to 8050 ft. Note: Set down 30k then came back. Wash and ream from 8050 ft to 8179 ft at 700 GPM,3700 PSI,flow line sensor reading 30%. While washing and reaming observed increased torque and packing off with loss of returns. Pumped 40 BBL high vis nut-plug sweep. Washing and reaming at 8125 ft continues at report time. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3370.00 CANRIG D.uasr Tun.nu:.. ru. ConocoPhillips Alaska,Inc. Tarn 2L-306 ST1 Daily Report Report for: S. Heim R. Springer Date: 03/27/2011 Time: 00:01 Current Depth (MD): 11488 Current Circulate and condition Current Depth (ND): 5365 Operations: at 11488 ft TD 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: - Max: - Mud Properties @ 11488'/5365' 2030hrs MW: 9.7 FV: 51 PV: 13 YP: 25 FL: 3.3 Gels: 7/10/13 Sol: 9 pH: 9.2 Cr: 600 Ca" 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: n/a Max: n/a Depth (MD/TVD): Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Max 1016u - - - - - - - Gas Peaks n/a Lithologies: Current: Last 24 hrs: No new footage drilled this period. Continue to back wash and back ream from 8179 ft(stand#80). Reduce flow in to 450 GPM to mitigate pack off. Pump out of the hole and rack back drill pipe in derrick. Find free spot on stand#79 and pump at 420 GPM, 1800 PSI, 100 RPM, 18-22k torque. Observed pack off and small loss of returns.. Pump, rotate and work out of the hole: Rack back stand#79 in derrick. Break circulation on stand#78 at 7980 ft with 450 GPM, 1800 PSI, 100 RPM, 16-22k torque. Free up and reciprocate from 7890 ft to 7987 ft. Circulate sweep. Stage pump up to 650 GPM as sweep nears surface. Wash Operational Summary: in hole from 7987 ft to 8650 ft. Vary flow in according to hole conditions. Stage down the flow in to 102 SPM,429 GPM, 1400 PSI, 100 RPM, 18k torque, 18%flow out, HST240k/SOW130k. Continue to wash and ream from 8650 ft to 8838 ft. Adjust washing and reaming speed to packing off at 8838 ft. Pump high-vis sweep and circulated out at 750 GPM, 3590 PSI,30%flow out, 100 RPM, 18-20k torque, 165k rotating string weight. Trip in hole on elevators from 8838 ft to 10200 ft. Wash and ream from 10200 ft to 10263 ft. Trip in hole on elevators from 10263 ft to 11053 ft. Wash and ream from 11053 ft to 11488 ft. Canrig records 1016 units maximum gas observed during trip Circulating bottoms up at report time. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 ST1 Daily Report Report for: S. Heim R. Springer Date: 03/28/2011 Time: 00:01 Current Depth (MD): 11488 Current POOH for 7-5/8' casing Current Depth (TVD): 5365 Operations: run. 24 hr Footage (MD): 0 Drilling Parameters ROP: _ Current: Max: Torque: Current: Max: WOB: Current _ Max: RPM: Current: _ Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: - Max: - Mud Properties @ 11488'/5365' 2030hrs MW: 9.9 FV: 52 PV: 16 YP: 22 FL: 3 Gels: } 8/10/13 Sol: 10.5 pH: 9.4 Cr: 600 Ca++ 40 MW Change: Depth: (none) From: (none) To: Reason: Mud Loss event: Depth: (none) Volume: (none) Gas Data Ditch Gas: Current: n/a Max: n/a _ 1 Depth (MD/TVD): Gas Events _ _ _ Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Max 350 u - - - - - - - Gas Peaks n/a Lithologies: Current: Last 24 hrs: No new footage drilled this period. Continue to circulate and condition hole for 7-5/8"casing run. Pump sweep out at TD 11488 ft a total of 28123 STKS, 706 GPM, 3600 PSI, RPM 100, 24-27k Torque, HST 285k, SOW 160k. POOH from 11488 ft to 9100 ft. Tight spot at 9100 ft. Monitoring hole via trip tank. Measure torque and drag every 5 stands. Establish circulation and back ream out of hole from 9100 ft to 7890 ft. at 450 GPM, 1550 psi. Circulate and reciprocate from 7890 ft to 7800 ft at 450 GPM, staging up to 700 GPM,3150 PSI. Rotate/Circ weight 165k, HST 225k, SOW 130k. TIH on elevators from 7890 ft to Operational Summary: 11488 ft. Circulate bottoms up at 11488 ft and 35 bbl high-vis nut-plug sweep at 705 GPM, 3850 PSI, 27%flow out, 100 RPM, 26-28k torque. Canrig records 350 units maximum trip gas. Pumped 17,685 strokes total. Lay down single; monitor well: Static. POOH on elevators from 11488 ft to 8900 ft. P/U 240k, S/O130k. At 8900 ft spot 100 BBL pill (12#/BBL Sac-Black)and dry job(11.9 PPG, 60 vis). At 500 GPM, 2050 PSI, 50 RPM, 20k torque. Continue POOH on elevators from 8900 to 5210 ft. Observed tight spot at 6903 ft(50k over). Worked through until cleaned up. Currently continuing POOH at report time. Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 ST1 Daily Report Report for: S. Heim R. Springer Date: 03/29/2011 Time: 00:01 Current Depth (MD): 11488 Current RIH with7-5/8"casing Current Depth (TVD): 5365 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: _ PP: Current: Max: _ Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: - Max: - Mud Properties @ 11488'/5365' 2030hrs MW: 9.9 FV: 55 PV: 15 YP: 22 FL: 3 Gels: 6/8/12 Sol: 10.5 pH: 9.3 Cr: 600 Ca" 40 Gas Data Ditch Gas: Current: n/a Max: n/a Depth (MD/TVD): Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Max 48 u - - - - - - - Gas Peaks n/a Lithologies: Current: Last 24 hrs: No new footage drilled this period. Continue to POOH with drill pipe from 5210 ft to 3726 ft. Obtain torque and drag every 5 stands. Observe well. Reciprocate from 3726 ft to 3670 ft while circulating and conditioning. Stage up from 450 GPM to 700 GPM, 2750 PSI. Canrig records 48 units maximum gas. Pump dry job and continue POOH from 3670 ft to 596 ft. Stand back HWDP in derrick; lay down jars and pick up (1)joint 5"drill pipe to replace jars. Continue POOH with BHA#5 and lay down to pipe shed. Break float sub, pull float, re- make joint sub. Lay down motor and bit. Change out 3-1/2"x 6"variable rams with 7- 5/8"solid. Rig up and test same 250 psi low/3500 psi high. Rig down 5"drill pipe elevators and short bails. Rig up Doyon casing tongs, 350 ton elevators and slips, long Operational Summary: bails and Frank's fill up tool in preparation to run 7-5/8"casing. Make up shoe track and Baker-Lock first 3 connections. Fill pipe and check floats. Begin running 7-5/8", 29.7#/ft, L-80 BTCM casing per detail from 175 ft to 3465 ft. Begin staging pumps up to 6 BPM, 410 PSI. Pumped 1810 strokes, 6 units gas maximum observed. Change out rubber on Frank's tool. Continue running 7-5/8"casing from 3465 ft to 6025 ft. Circulate bottoms up, staging pumps from 5 PBM to 10 BPM. Pumped 2801 strokes, 30 units maximum gas observed. Continue running 7-5/8"casing per detail from 6025 ft to 7270 ft. (joint#170. NOTE: Washed down#161 and 162 (6851 ft to 6936 ft)with 3.5 BPM, 310 psi. Circulated 550 strokes total. Currently RIH with 7-5/8"casing at report time. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 ST1 Daily Report Report for: S. Heim R. Springer Date: 03/29/2011 Time: 00:01 Current Depth (MD): 11488 Current Wait on cement; Current Depth (TVD): 5365 Operations: Prepare to lay down 5" drill pipe. 24 hr Footage (MD): 0 Drilling Parameters Mud Properties @ 11488'/5365' 2130hrs Note: Currently dum ing and cleaning pits at report time. MW: 10.0 FV: 50 PV: 14 YP: 16 FL: 3.4 Gels: 4/6/10 Sol: 11 pH: 9.3 Cr: 600 Ca" 40 Gas Data n/a Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) Max 74 u - - - - - - - Gas Peaks n/a LITHOLOGY: Last 24 hrs: No new footage drilled this period. • Continue to run 7-5/8", 29.7#intermediate casing from 7270 ft to 7916 ft(joint#185). Reciprocate pipe from 7915 ft to 7876 ft while circulating at 3.5 BPM,450 PSI. Stage pumps up to 5.5 BPM, 575 PSI. Pack off and taking weight on down stroke observed at 1400 strokes (proposed to circulate 1800 strokes total; B/U at this depth 3065 strokes). Continue to run 7-5/8"casing from 7915 ft to 9080 ft. Reciprocate from 9080 ft to 9041 ft and circulate at 3.5 BPM,450 PSI. Stage pumps up to 5 BPM, 540 PSI. Circulated 2007 strokes total. Continue to run casing from 9080 ft to 10276 ft. Reciprocate casing at 10276 ft and circulate at 3.5 BPM, 450 PSI; staged up to 5 BPM, 540 PSI. Continue to run 7-5/8"casing from 10276 ft to 11427 ft (joint#267). Pick up FMC hanger and landing joint. Set on hanger at 11472 ft. Establish circulation at 3.5 BPM, 500 PSI. Reciprocate from 11472 ft to 11457 ft. Canrig records 74 units maximum trip gas observed. Set on hanger. Break out Frank's tool and lay down same. Rig up cement head, line and valves. Reciprocate 20 ft and circulate in Operational Summary: preparation for cement job. Stage pump up to 7 BPM, 550 psi. Total strokes pumped 8330. Continue with cement job as per Dowell. Drop bottom plug;pump gas block 147 BBLS 15.9 PPG at 6 BPM. Drop top plug;kick out with 10 BBLS water. Turn over to rig and displace cement. Pumped 9.9 PPG mud at 7 BPM, 800 PSI, 4900 strokes. Slow down to 4 BPM, 620 PSI. Bumped plug at 5123 strokes; pressure up to 1200 PSI and hold for 5 minutes. Bleed off check floats: OK, no returns to surface. Blow down and rig down cement line. Rig down cement head and pull 7-5/8"landing joint. Pick up 5"test joint; make up pack off running tool and set/torque lock downs to 450 ft/lbs. Test pack off to 5000 PSI for 10 minutes. Removed double annulus valve from lower annulus and install on upper annulus. Lay down running tool and test joint. Installed short bails with 5"elevators. Rig up in cellar to flush OA with 300 BBBLS water. Pressure test lines to 2000 PSI: OK. Flush OA with water. Final circulating pressure 600 PSI, shut in pressure 550 PSI. Rig down and blow down lines; rig up little red to freeze protect. Continue preparations to lay down 5"drill pipe at report time. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Tarn 2L-306 ST1 Daily Report Report for: S. Heim L. Hill L. Hill Date: 03/31/2011 Time: 00:01 Current Depth (MD): 11448 Current Test BOP's Current Depth (TVD): 5365 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: _ Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: - Max: - Mud Properties Note: Cleaning pits and building MI Clay Sheild mud at re ort time. MW: FV: PV: YP: FL: Gels: Sol: pH: Cr: Ca' Gas Data Ditch Gas: Current: n/a Max: n/a Depth (MD/TVD): Average: n/a Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) n/a - - - - - - - - Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) N/A - - - - - - Gas Peaks Depth (MD/TVD) TG Cl C2 C3 iC4 nC4 iC5 nC5 Lithologies: Current: Last 24 hrs: No new footage drilled this period. Lay down 105 stands of 5"drill pipe and 5 stands HW DP from derrick. Simultaneous operations include changing 7-5/8"top rams to 3-1/2"x 6"variable; bottom 5"solid to 4" solid. Start loading 4"drill pipe into pipe shed on off driller's side. Pull mouse hole from rotary table and put back into mouse hole position. Pick up 1 joint of 4"drill pipe in preparation to cut and slip 120 ft drill line. C/S same. Remove 4"drill pipe from Operational Summary: rotary and lay down to pipe shed. Load pipe shed with 268 joints of 4"drill pipe; Strap and remove thread protectors. Clear floor of 4-1/2" IF and 5"handling tools. Pick up 3- 1/2", XT-39 and 5" handling tools. Inspect and power wash topdrive. Pick up 4"drill pipe (XT-39) and rack back 90 joints in derrick;drift to 2.25". Make up pup joint to test joint with head pin; set plug; rig up test manifold and hoses. Use rig pump to fill stack with water;perform body test to 3500 psi. Test BOP's 250 psi low, 3500 psi high (bag 250 psi low, 2500 psi high). Continue testing BOP's at report time. Calibrations: Chromatograph,THA. Failures: None Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report 2L-306 ST1 Report for: L. Hill S. Heim Date: 04/01/2011 Time: 00:01 Current Depth (MD): 11488 Current RIH with 4"drill pipe Current Depth (TVD): 5365 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: n/a Max: n/a Torque: Current: n/a Max: n/a WOB: Current n/a Max: _ n/a RPM: Current: n/a _ Max: n/a PP: Current: n/a Max: n/a Lag: Strokes: n/a Time: n/ n/a Strokes: n/ Time: n/a ECD: Current: - Max: - Mud Properties 2030 hrs MW: 10.0 FV: 54 PV: 14 YP: 17 FL: 3.4 Gels: 4/6/10 Sol: 11 pH: 9.0 CF: 600 Ca' 40 Gas Data Ditch Gas: Current: n/a Max: Depth (MD/TVD): Average: Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) None - Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) Lithologies: Current: Last 24 hrs: No new footage drilled this period. Continue and complete testing BOP's. Install wear bushing. Blow down choke, kill line to stack, choke manifold. Pick up/clean up rig floor. Pick up BHA#6: Bit, motor,float sub, stabilizer, Phase 4 collar, DM, PWD and Pulser. Pull old wear bushing and install Operational Summary: new one. Grease draw works,top drive and iron roughneck. Continue to pick up BHA #6 per directional driller and MWD hand. Upload MWD. Shallow pulse test at 200 gpm, 950 psi. Blow down top drive. Load nukes per MWD. Pick up remaining BHA items: 2 Flex collars, circ sub crossover sub,3 joints HWDP,jars, 8 joints HWDP. Continue trip in hole with 4"drill pipe singles from 598 ft to 6560 ft at report time. Calibrations: Chromatograph, THA. Failures: None Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report 2L-306 ST1 Report for: L. Hill S. Heim Date: 04/02/2011 Time: 00:01 Current Depth (MD): 11870 Current Drilling Ahead Current Depth (TVD): 5476 Operations: 24 hr Footage (MD): 382 Drilling Parameters ROP: Current: 98 Max: 165 Torque: Current: 8473 Max: 13961 WOB: Current 7 Max: 44 RPM: Current: 66 Max: 74 PP: Current: 2807 Max: 3578 Lag: Strokes: 3560 Time: 49.4 Surf to Bit Strokes: 1248 Time: 17.3 ECD: Current: - Max: - Mud Properties 11697/5413 MW: 9.8 FV: 46 PV: 11 YP: 19 FL: 3.6 Gels: 5/7/9 Sol: 6.5 pH: 9.8 Cr: 31.5k Ca++ 92 Gas Data Ditch Gas: Current: <25u Max: 167u Depth (MD/TVD): 11768/5424 Average: 64u Gas Events Trip Gas Depth Cl C2 C3 1C4 nC4 iC5 nC5 (MD/TVD) None - - - - - - - Connection Depth Cl C2 C3 iC4 nC4 105 nC5 Gases (MD/TVD) none Lithologies: Current: Sandstone, siltstone, trace clay Last 24 hrs: Sandstone and siltstone Continue to single in from pipe shed with 4"drill pipe: From 6560 ft to 11203 ft. Trip in hole from derrick 11203 ft to 11377 ft. Wash down from 11377 ft with 205 gpm, 2090 psi. Circulate bottoms up at 11377 ft, 300 gpm, 3450 psi. Circulated 3800 strokes. Blow down top drive and rig up for casing test. Test 7-5/8"casing to 4000 psi. Bleed Operational Summary: off and rig down test equipment. At 11379 ft drill floats and cement to 11488 ft with 211 gpm, 1750 psi. Pumped sweep while drilling on the shoe. Continue to circulate and displace mud at 11488 ft, 340 gpm, 3250 psi. Drill from 11488 ft to 11508 ft. Lay down single;blow down top drive; perform leak off test to 12.0 ppg EMW. Drill ahead from 11508 ft to 11870 ft with no problems encountered at report time. Calibrations: Chromatograph, THA. Failures: WITS feed to Canrig from TOTCO. Data lost from 11488 to 11636 ft Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report 2L-306 ST1 Report for: L. Hill S. Heim Date: 04/03/2011 Time: 00:01 Current Depth (MD): 12954 Current Drilling Ahead Current Depth (TVD): Operations: 24 hr Footage (MD): 1084 Drilling Parameters ROP: Current: 35 Max: 205.7 Torque: Current: 9348 Max: 11432 WOB: Current 7 Max: 46 RPM: Current: 101 Max: 103 PP: Current: 2807 Max: 3578 Lag: Strokes: 3560 Time: 49.4 Surf to Bit Strokes: 1248 Time: 17.3 ECD: Current: - Max: - Mud Properties 12214/5440 MW: 9.9 FV: 46 PV: 13 YP: 23 FL: 3 Gels: 6/8/12 Sol: 8.5 pH: 9.3 Cr: 36.5K Ca++ 80 Gas Data Ditch Gas: Current: 81u Max: 653u Depth (MD/TVD): 1 222 0/5 441 Average: 252u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) None - - - - - - - Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) none Lithologies: Current: 90% Sandstone, 20%siltstone, trace clay Last 24 hrs: Sandstone and siltstone Drill ahead from 11850 ft to 12786 ft with no problems encountered. Cross fault at Operational Summary: 12786 ft and lost 47 bbls mud initially and 15 bph for the next 3 hours. Pump Safe Carb 250, Safe Carb 40 and G Seal to heal the losses while drilling ahead. Drill to 12954 ft at report time. Calibrations: Chromatograph,THA. Failures: none Daily Cost: $3370.00 CANRIG I.11 rec T111,011)1 f.rn. ConocoPhiIPips Alaska,Inc. Daily Report 2L-306 ST1 Report for: L. Hill S. Heim Date: 04/04/2011 Time: 00:01 Current Depth (MD): 13156 Current Monitoring Well Current Depth (TVD): 5446 Operations: 24 hr Footage (MD): 202 Drilling Parameters ROP: Current: - Max: 212 Torque: Current: - Max: 10815 WOB: Current - Max: 44 RPM: Current: - Max: 103 161 psi PP: Current: shut in Max: 3796 pressure Lag: Strokes: 3926 Time: - Surf to Bit Strokes: 1386 Time: - ECD: Current: - Max: Mud Properties 13156/5446 MW: 9.8 FV: 52 PV: 12 YP: 21 FL: 3.4 Gels: 6/7/10 Sol: 7 pH: 9.0 Cr: 33k Ca" 40 Gas Data Ditch Gas: Current: - Max: 568u Depth (MD/TVD): 13048/5444 Average: 184u Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) None - - - - - - - Connection Depth Cl C2 C3 iC4 nC4 iC5 nC5 Gases (MD/TVD) none Lithologies: Current: n/a Last 24 hrs: 100% Sandstone Drill ahead from 12954 ft to 13156 ft. Observed losses at 13156 ft. Initial loss 50 bbls while pumping at 345 gpm, 3750 psi: Little or no returns at flow line. Observed slight static losses while monitoring well. Mix and pump LCM pill per MlSwaco.at 2 bpm, 550 psi, no returns at flow line. POOH with pumps from 13156 ft to 11391 ft at 63 gpm, 460 psi. Spot LCM pill while POOH. Actual displacement(-70 bbls)from trip out; calculated displacement(-12.4 bbls). Monitor hole on trip tank at 11391 ft. Build and Operational Summary: take on volume into pits per MlSwaco engineer. Total losses from 0001-1200 hrs was 249 bbls. Circulate over top of hole from trip tank(no losses). Wait on mud while building 100 bbl LCM pill. RIH and circulate from 11391 ft to 11455 ft at 21 gpm, 280 psi,0% returns at flow line. Increase to 126 gpm, 780 psi, 0% returns at flow line. Shut down and drop ball to open circulation sub. Wait 20 minutes to let ball fall. Pump ball down with 105 gpm, 60 psi,0% returns at flow line. Ball on seat at 635 strokes. Pressure up to 1500 psi,wait 15 seconds; pressure up to 2000 psi, wait 15 seconds; pressure up to 2450 psi. Tool shifted open. Tool open with 105 gpm,410 psi (note: CANRIG Flow path is 90%out of circulation sub, 10%out bit. Continue to build 100 bbl LCM pill and take on mud into the pits. POOH on elevators from 11455 ft to 13098 ft. Drop ball and pump down to close BHA off 100%with 105 gpm,470 psi, 0%return flow. Observed flow going down flow line from rig floor. Chase ball with 20 bbls mud and 100 bbl LCM pill (9.8 ppg). Spot 75 bbl LCM pill out of circulation sub. Monitor well: Breathing at 2 bbls every 5 minutes. Pump 250 strokes to clear LCM pill out of pipe. Shut down. Observe well breathing 3-4 bpm every 5 minutes. Pump 733 strokes at 126 gpm, 580 psi. Observed flow at floor but not at TOTCO screen. Lost 68 bbls and observed 8 bbl gain. Shut down and monitor well. Well breathing at 4-5 bpm every 5 minutes; pressure on drill string increased to 180 psi in 5 minutes. Bleed pressure off drill string: Observed pressure going through bleeder and breathing on back side down flow line. Open choke HCR and shut annular to record pressures: 190 psi on drill string and 30 psi on casing. Note losses from 1200 2359 hours at 262 bbls. Well is currently closed in at 2359 hrs report time. Calibrations: Chromatograph, THA. Failures: none Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report 2L-306 ST1 Report for: L. Hill S. Heim Date: 04/05/2011 Time: 00:01 Current Depth (MD): 13156 Current POOH: L/D BHA Current Depth (TVD): 5446 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: _ - Max: - Torque: Current: - Max: - WOB: Current - Max: - RPM: Current: - Max: - PP: Current: - Max: - Lag: Strokes: 3926 Time: - Surf to Bit Strokes: 1386 Time: - ECD: Current: - Max: - Mud Properties 13156/5446 MW: 9.8 FV: 51 _ PV: 10 YP: 19 FL: 3.4 Gels: , 5/7/10 Sol: 7 pH: 9.5 Cr: 34k Ca" 40 Gas Data Ditch Gas: Current: - Max: - Depth (MD/TVD): - Average: - Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) None - - - - - - - Lithologies: Current: n/a Last 24 hrs: No new footage drilled this period. Continue to perform exhale test: SIDPP = 170 psi, SICP =0 psi. Bleed drill pipe pressure to pits and shut back in. Monitor SIDPP =0, SICP =o. Open well per company man: Monitor well on trip tank. Well breathing back 3 bbls/10 minutes. Observe well breathing for 1 hour. Well gives back 23 bbls in 1 hour. POOH with pumps from 13067 ft to 12622 ft:at 1 bpm,380 psi. Monitor well at 12622 ft. Well still breathing. Continue POOH with pumps from 12622 ft to 11451 ft at 2 bpm,460 psi. Operational Summary: Monitor well at 11451. Well still slightly breathing. Pump 317 strokes at 3 bpm, 560 psi. Observe well breath back mud. Pumped 32 bbls and well breathed back 27.5 bbls. Wait on orders from town. POOH with pumps from 11451 ft to 10063 ft at 1.5 bpm,460 psi. Continue to POOH with pumps at 60 fpm, 1.5 bpm, 310 psi from 10063 ft to 4947 ft. POOH on elevators from 4947 ft to 2957 ft. At 2957 ft pump dry job (11.8 ppg, 55 vis) at 150 gpm,220 psi. Continue to POOH on elevators from 2957 ft to 589 ft. Monitor well at 589 ft: Static. Currently laying down BHA at report time. Calibrations: Chromatograph, THA. Failures: none Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report 2L-306 ST1 Report for: L. Hill S. Heim Date: 04/06/2011 Time: 00:01 Current Depth (MD): 13156 Current Set Hanger Current Depth (TVD): 5446 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: - Max: - Torque: Current: - Max: - WOB: Current - Max: - RPM: Current: - Max: - PP: Current: - Max: - Lag: Strokes: - Time: - Surf to Bit Strokes: - Time: - ECD: Current: Max: - Mud Properties 1 31 56/5446 2000 hrs MW: 9.8 FV: 51 _ _ PV: 10 YP: 21 FL: 3.4 Gels: 6/7/9 Sol: 7 pH: 9.4 Cr: 34.5k Ca' 40 Gas Data Ditch Gas: Current: - Max: - Depth (MD/TVD): - Average: - Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 j_M D/TV D) None - - - - - - - Lithologies: Current: n/a Last 24 hrs: No new footage drilled this period. Complete laying down BHA. Rig up to run 3-1/2" liner. Run 3-1/2" liner per detail to 1850 ft. Make up hanger assembly; mix and let PAL mix set for 30 minutes. RIH with 1 stand 4"drill pipe from 1850 ft to 1951 ft. Pump through string to ensure liner is clear at 2 bpm, 210 psi. Blow down top drive. RIH with 4"drill pipe from derrick from 1951 ft to 13157 ft filling pipe every 10 stands with no problems encountered. At 113157 ft Operational Summary: drop ball and pump down at 3 bpm, 380 psi, no returns. Ball on seat at 1157 strokes. Pressure up to 2500 psi, set 35k on hanger; bring pressure up to 3500 psi; bleed off. Pick up to 178k(+5): Hanger not set. Slack off to 75k; pressure up to 2500 psi and hold for 2 minutes. Pressure up to 4500 psi; blow ball out. Pull up to see if hanger is set. Pressure up to 1000 psi on annulus: Hanger set at report time. Total mud loss 1200 to 2359 hours= 121 bbls. Calibrations: Chromatograph, THA. Failures: TOTCO pit sensors fluctuating, making it difficult to track gains/losses. Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report 2L-306 ST1 Report for: L. Hill S. Heim Date: 04/07/2011 Time: 00:01 Current Depth (MD): 13156 Current Testing chemical Current Depth (TVD): 5446 Operations: injection mandrel and spool. 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: - Max: - Torque: Current: - Max: - WOB: Current - Max: - RPM: Current: - Max: - PP: Current: - _ Max: - _ Lag: Strokes: - Time: - Surf to Bit Strokes: - Time: - ECD: Current: - Max: - Mud Properties 1 31 56/5446 2000 hrs MW: 9.8 FV: 51 PV: 10 YP: 21 FL: 3.4 Gels: 6/7/9 Sol: 7 pH: 9.4 Cr: 34k Ca' 40 Gas Data Ditch Gas: Current: - Max: - Depth (MD/TVD): - Average: - Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) None - - - - - - - Lithologies: Current: n/a Last 24 hrs: No new footage drilled this period. Continue to set liner per Baker hand at 11307 ft. Lay down 3 joints 4"drill pipe. Test annulus to 1000 psi for 15 minutes. Rig down and blow down lines. Monitor well at 11184 ft: Monitor until static. Pump slug at 11184 ft. POOH on trip tank and lay down Operational Summary: 4"drill pipe from 11184 ft to 57 ft. Lay down hanger landing tool. Drain stack, pull wear ring,function BOPE. Lay down running tool and XT-39 thread protectors from rig floor. Rig up to run 3-1/2"tubing with chemical line. RIH with 3-1/2", 9.3#, L-80, EUD 8RD tubing from seal assembly mule shoe to chemical injection mandrel (748 ft). Currently trouble shooting chemical injection mandrel and spool at report time. Calibrations: Chromatograph,THA. Failures: TOTCO pit sensors fluctuating, making it difficult to track gains/losses. Daily Cost: $3370.00 CANRIG ConocoPhillips Alaska,Inc. Daily Report 2L-306 ST1 NOTE: This is the final Canrig Daily Report for 2L-306 ST1. Report for: L. Hill S. Heim Date: 04/08/2011 Time: 00:01 Current Depth (MD): 13156 Current Pickle well. Current Depth (TVD): 5446 Operations: 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: - Max: - Torque: Current: - Max: - WOB: Current - Max: - RPM: Current: - Max: - PP: Current: - Max: - Lag: Strokes: - Time: - Surf to Bit Strokes: - Time: - ECD: Current: - Max: - Mud Properties Brine 2000 hrs MW: 9.8 FV: 28 PV: YP: FL: Gels: Sol: pH: Cr: 158k Ca" Gas Data Ditch Gas: Current: - Max: - Depth (MD/TVD): - Average: - Gas Events Trip Gas Depth Cl C2 C3 iC4 nC4 iC5 nC5 (MD/TVD) None - - - - - - Lithologies: Current: n/a Last 24 hrs: No new footage drilled this period. Continue to RIH with 3-1/2", 9.3#, L-80, EU 8RD MOD completion tubing per detail. Make up crossover to top over joint#355. Tag top of seals at 11356 ft. at 11350 ft Operational Summary: displace to brine: 50 bbl 9.8 brine with 2 drums Safe-Surf w; 50 bbl 9.8 brined viscosified with 3#/bbl Flowzan; 195 bbls 9.8 brine; 231 bbls 9.8 brine with 2%CRW at 3 bpm, 580 psi at 2466 strokes; increase to 4 bpm,640 psi. Continue ops at report time. Calibrations: Chromatograph, THA. Failures: Daily Cost: $3370.00 CANRIG
