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y Samantha Carlisle at 3:40 pm, Apr 13, 2021 Mark Shulman Digitally signed by Mark Shulman Date: 2021.04.13 15:08:05 -08'00' SFD 4/19/2021 SFD 4/19/2021DSR-4/14/21 RBDMS HEW 4/15/2021 VTL 5/5/21 Alipine Oil Pool CD3-107L1 Summary of Operations Perforations DTTMSTART JOBTYP Summary OPS 3/19/2021 ZONAL Perforate with 2.0" PJ Omega 6spf 60 deg phasing from 15,300'-15,320' RKB. 3/19/2021 ZONAL Perforate with 2.0" PJ Omega 6spf 60 deg phasing from 14,680’-14,700' RKB. 3/20/2021 ZONAL Perforate with 2" PJ Omega 6spf 60 deg phasing from 14,030'-14,050' RKB. JOB COMPLETE Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: 13,242.0 3/30/2007 CD3-107 claytg Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Install Modified WRDP/ Slip Stop 3/22/2021 CD3-107 boehmbh Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 37.0 Set Depth (ftKB) 114.0 Set Depth (TVD) … 114.0 Wt/Len (l… 62.50 Grade Top Thread Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 36.8 Set Depth (ftKB) 3,092.9 Set Depth (TVD) … 2,478.8 Wt/Len (l… 40.00 Grade L-80 Top Thread MBTC Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 34.2 Set Depth (ftKB) 11,874.0 Set Depth (TVD) … 7,075.3 Wt/Len (l… 26.00 Grade L-80 Top Thread MBTC Casing Description OPEN HOLE OD (in) 6.181 ID (in) Top (ftKB) 11,874.0 Set Depth (ftKB) 18,315.0 Set Depth (TVD) … Wt/Len (l…Grade Top Thread Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.0 Set Depth (ft… 11,153.0 Set Depth (TVD) (… 6,855.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.0 31.0 0.00 HANGER FMC TUBING HANGER 4.000 121.3 121.3 0.62 XO 4.5x3.5" CROSSOVER 4 1/2" IBT x 3 1/2" EUE 8RD 3.000 2,209.3 1,999.4 46.32 SAFETY VLV- LO CAMCO TRMAXX-5E SAFETY VALVE w/ 2.813" PROFILE (LOCKED OUT- 4/13/20) 2.813 10,820.8 6,699.7 58.54 NIPPLE HES X NIPPLE 2.813 10,861.8 6,720.9 59.07 PACKER BAKER PREMIER PACKER 2.870 11,008.9 6,793.2 62.46 SLEEVE-C BAKER SLIDING SLEEVE CMD w/ 2.813 PROFILE: CLOSED 1/4/2020 2.813 11,032.1 6,803.7 63.57 PACKER BAKER PREMIER PACKER 2.870 11,079.5 6,824.3 64.49 NIPPLE HES X LANDING NIPPLE 2.813 11,122.2 6,842.5 65.17 FLUTED SUB FLUTED NO GO SUB w/ SHEAR PIN 2.992 11,152.0 6,854.9 65.75 WLEG WIRELINE ENTRY GUIDE 3.010 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 2,208.0 1,998.5 46.26 SLIP STOP 3.5" SLIP STOP, 2.31" G-FN 3/22/2021 1.500 2,209.0 1,999.2 46.31 WRDP WRDP-2 (S/N HSS-125) 3/22/2021 1.500 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 10,944.0 10,970.0 6,762.3 6,774.8 KUPC, CD3-107 5/2/2007 6.0 CMT SQZ 2" HSD PJ Omega Guns Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 4,772.5 3,410.8 57.38 Camco KBMG- 2 1 GAS LIFT DMY BK-5 0.000 0.0 2/23/2009 2 8,826.7 5,614.5 57.20 Camco KBMG- 2 1 GAS LIFT DMY BK-5 0.000 0.0 2/23/2009 3 10,772.3 6,674.2 57.92 Camco KBMG- 2 1 GAS LIFT OV BK 0.250 0.0 2/12/2018 4 10,919.1 6,750.0 60.10 Camco KBMG- 2 1 PROD DMY BK 1/2/2020 Notes: General & Safety End Date Annotation 4/30/2012 NOTE: ORIGINAL HOLE COLLAPSED @ APPROX 13,000' 8/15/2008 NOTE: Well sidetracked to L1, original wellbore not plugged, only L1 producing 4/26/2006 NOTE: Well PERF'd in KUPARUK zone for temporary flowback. Horizontal, CD3-107, 4/13/2021 2:16:51 PM Vertical schematic (actual) OPEN HOLE; 11,874.0-18,315.0 WINDOW L1; 12,892.0-12,900.0 LINER L1 4.5"x3.5" @12917.34'; 11,125.2-19,475.0 FRAC; 12,840.0 FRAC; 11,874.0 INTERMEDIATE; 34.2-11,874.0 WLEG; 11,152.0 TUBING SUB; 11,123.2 FLUTED SUB; 11,122.2 NIPPLE; 11,079.5 PACKER; 11,032.1 SLEEVE-C; 11,008.9 SQZ PERFS; 10,944.0 ftKB CMT SQZ; 10,944.0-10,970.0 GAS LIFT; 10,919.1 PACKER; 10,861.8 NIPPLE; 10,820.8 GAS LIFT; 10,772.3 GAS LIFT; 8,826.7 GAS LIFT; 4,772.5 SURFACE; 36.8-3,092.9 SAFETY VLV- LO; 2,209.3 WRDP; 2,209.0 SLIP STOP; 2,208.0 CONDUCTOR; 37.0-114.0 HANGER; 31.0 WNS PROD KB-Grd (ft) 37.03 Rig Release Date 4/27/2006 CD3-107 ... TD Act Btm (ftKB) 18,315.0 Well Attributes Field Name FIORD KUPARUK Wellbore API/UWI 501032052901 Wellbore Status PROD Max Angle & MD Incl (°) 93.62 MD (ftKB) 17,675.70 WELLNAME WELLBORECD3-107 Annotation Last WO: End Date 4/16/2008 H2S (ppm) DateComment SSSV: TRDP Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:CD3-107L1 osborl Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: FCO / Add Perfs 3/20/2021 CD3-107L1 claytg Casing Strings Casing Description WINDOW L1 OD (in) 8 ID (in) 7.00 Top (ftKB) 12,892.0 Set Depth (ftKB) 12,900.0 Set Depth (TVD) … 7,054.3 Wt/Len (l…Grade Top Thread Casing Description LINER L1 4.5"x3.5" @12917.34' OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 11,125.2 Set Depth (ftKB) 19,475.0 Set Depth (TVD) … 6,926.8 Wt/Len (l… 9.30 Grade L-80 Top Thread 8RD EUE Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 11,125.2 6,843.9 65.24 PACKER BAKER 'HRD 5' ZXP LINER TOP PACKER w/HD SETTING SLEEVE 4.950 11,145.0 6,852.1 65.70 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.870 11,148.7 6,853.6 65.73 HANGER BAKER 'DG' FLEX LOCK LINER HANGER 3.970 11,158.3 6,857.6 65.80 XO BUSHING XO BUSHING 5.5x4.5" 3.970 11,207.2 6,877.5 66.24 XO CROSSOVER 4.5x3.5" 3.958 11,249.7 6,894.4 66.56 SLEEVE-O BAKER CMD SLIDING SLEEVE w/ X PROFILE 2.812 12,337.1 7,068.6 93.07 FRAC PORT BAKER DRILLABLE BALL DROP Sliding Sleeve (Open 2/27/2009) 2.000 12,730.6 7,057.0 90.92 SWELL TAM SWELL PACKER TAP FREE PACK 3.875 12,787.7 7,056.1 91.00 PACKER PACKERS BAKER OPEN HOLE 3.500 12,839.9 7,055.2 90.91 SWELL TAM SWELL PACKER TAP FREE PACK 3.500 12,917.3 7,054.2 90.68 XO Enlarging CROSSOVER 3.5 x 4.5, 12.6#, L-80, IBTM 4.500 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 13,232.0 19,295.0 7,058.8 6,948.4 NECHELIK, CD3-107L1 4/29/2008 4.0 PERFP 24 preperfed pups spaced every 6 jts (~260') each w/ six 1/2" holes, 120-deg phasing 14,030.0 14,050.0 7,043.3 7,043.0 NECHELIK, CD3-107L1 3/20/2021 APERF 2.00" Guns - 6 spf - 60 Deg - 2006 PJ Omega HMX - 7.3gm - 3.5" casing - 0.22" Ent Hole - 21.80" Penetration 14,680.0 14,700.0 7,030.0 7,029.3 NECHELIK, CD3-107L1 3/20/2021 APERF 2.00" Guns - 6 spf - 60 Deg - 2006 PJ Omega HMX - 7.3gm - 3.5" casing - 0.22" Ent Hole - 21.80" Penetration 15,280.0 15,300.0 7,018.6 7,018.1 NECHELIK, CD3-107L1 3/20/2021 APERF 2.00" Guns - 6 spf - 60 Deg - 2006 PJ Omega HMX - 7.3gm - 3.5" casing - 0.22" Ent Hole - 21.80" Penetration Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 2/27/2009 12,840.0 19,482.0 0.0 0.00 0.00 1 FRAC 3/4/2009 11,874.0 12,731.0 0.0 0.00 0.00 Notes: General & Safety End Date Annotation 4/30/2012 NOTE: ORIGINAL HOLE COLLAPSED @ APPROX 13,000' 8/15/2008 NOTE: Well sidetracked to L1, original wellbore not plugged, only L1 producing 7/11/2008 NOTE: View Schematic w/ Alaska Schematic9.0 Horizontal, CD3-107L1, 4/12/2021 5:47:10 PM Vertical schematic (actual) LINER L1 4.5"x3.5" @12917.34'; 11,125.2-19,475.0 PERFP; 13,232.0-19,295.0 FRAC; 12,840.0 APERF; 15,280.0-15,300.0 APERF; 14,680.0-14,700.0 APERF; 14,030.0-14,050.0 OPEN HOLE; 11,874.0-18,315.0 WINDOW L1; 12,892.0-12,900.0 FRAC; 11,874.0 INTERMEDIATE; 34.2-11,874.0 WLEG; 11,152.0 TUBING SUB; 11,123.2 FLUTED SUB; 11,122.2 NIPPLE; 11,079.5 PACKER; 11,032.1 SLEEVE-C; 11,008.9 CMT SQZ; 10,944.0-10,970.0 SQZ PERFS; 10,944.0 ftKB GAS LIFT; 10,919.1 PACKER; 10,861.8 NIPPLE; 10,820.8 GAS LIFT; 10,772.3 GAS LIFT; 8,826.7 GAS LIFT; 4,772.5 SURFACE; 36.8-3,092.9 SAFETY VLV- LO; 2,209.3 WRDP; 2,209.0 SLIP STOP; 2,208.0 CONDUCTOR; 37.0-114.0 HANGER; 31.0 WNS PROD KB-Grd (ft) 37.03 Rig Release Date 4/27/2006 CD3-107L1 ... TD Act Btm (ftKB) 19,482.0 Well Attributes Field Name FIORD KUPARUK Wellbore API/UWI 501032052960 Wellbore Status PROD Max Angle & MD Incl (°) 97.28 MD (ftKB) 19,252.33 WELLNAME WELLBORECD3-107 Annotation Last WO: End Date 4/16/2008 H2S (ppm) DateComment SSSV: TRDP 14,030.0 14,050.0 7,043.3 7,043.0 NECHELIK, CD3-107L1 3/20/2021 APERF 2.00" Guns - 6 spf - 60 Deg - 2006 PJ Omega HMX - 7.3gm - 3.5" casing - 0.22" Ent Hole - 21.80" Penetration 14,680.0 14,700.0 7,030.0 7,029.3 NECHELIK, CD3-107L1 3/20/2021 APERF 2.00" Guns - 6 spf - 60 Deg - 2006 PJ Omega HMX - 7.3gm - 3.5" casing - 0.22" Ent Hole - 21.80" Penetration 15,280.0 15,300.0 7,018.6 7,018.1 NECHELIK, CD3-107L1 3/20/2021 APERF 2.00" Guns - 6 spf - 60 Deg - 2006 PJ Omega HMX - 7.3gm - 3.5" casing - 0.22" Ent Hole - 21.80" Penetration Si l i I l 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. ~Q ~ - Q .S~ Well History File Identifier Organizing (done) ^ Two-sided III 111111 II III II III ^ Rescan Needed RESCAN DIG TAL DATA OVERSIZED (Scannable) ^ Color Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other: BY' Maria Date: oLI 9 ~~D /s/ 1 ~ I Project Proofing II I II ~I II I I III I I III BY: Maria Date: ~ O /s/ ~ = ~ + ~ =TOTAL PAGES Scannin Pre aration g x 30 /~ (Count does not include cover sheet) BY: Maria Date: ~,,, I ~ I ~ 0 _ lsl Production Scanning Stage 7 BY: Stage 7 BY: Page Count from Scanned File: ~ (count does include cove neet) Page Count Matches Number in Scanning Preparation: YES NO Maria Date: q ~ ~ /s/ If NO in stage 1, page(s) discrepancies we/re found: YES NO Maria Date: /sl.. ~~~~~~~~~~~ ~~~~ Scanning is complete at this point unless rescanning is required. ReScanned III IIIIIIIIIII II III BY: Maria Date: /s/ Comments about this file: Quality Checked III II'lll III II'I I I 10!6!2005 Well History File Cover Page doc DATA SUBMITTAL COMPLIANCE REPORT 2/2/2010 Permit to Drill 2080510 Well Name/No. COLVILLE RIV FIORD CD3-107L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20529-50-00 MD 19482 TVD 6926 Completion Date 5!30/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surve Yes ' DATA INFORMATION Types Electric or Other Logs Run: GR/RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type MediFrmt Number Name Scale Media No Start Stop CH Received Comments Rpt LIS Verification 12915 19482 Open 5/21/2008 LIS Veri, GR, RPD, FET, ~~ "; ~ ' ED C ~ Lis 16290vlnduction/Resistivity 12915 19482 Open 5/21/2008 RPS, RPM, RPX, ROP LIS Veri, GR, RPD, FET, ~ ~ RPS, RPM, RPX, ROP ED D Directional Survey Asc 34 19482 Open 6/24/2008 pt Directional Survey 34 19482 Open 6/24/2008 ~ D C 16607 nduction/Resistivity 12973 19482 Open 7/16/2008 EMF, CGM, and PDF graphics for EWR logs. ~ og Induction/Resistivity 25 Col 12973 19482 Open 7/16/2008 MD ROP, DGR, EWR 26- Apr-2008 Log Induction/Resistivity 25 Col 6925 7053 Open 7/16/2008 TVD DGR, EWR 26-Apr- 2008 og Production 2 Col 10462 11236 Case 11/7/2008 PPL, MPL, Pres, GR, CCL, FCAP, Temp, Spin 26-Oct- 1 C ~~ ~~ Las 17030 LPressure 10638 11236 Case 11/7/2008 2008 PPL, Spin, GR, Temp, CCL Well Cores/Samples Information: Interval Name Start Stop Sample Set Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/2/2010 Permit to Drill 2080510 Well Name/No. COLVILLE RIV FIORD CD3-107L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20529-60-00 MD 19482 TVD 6926 Completion Date 5/30/2008 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL fNFORMATION Well Cored? Y ~ Daily History Received? / N Chips Received? -~-/-Pt-- Formation Tops Q/ N Analysis Received? --- - - - - Comments: Compliance Reviewed 8y: __ - _ Date: 7 __ l ~~ V ~ ~ ~ MAR ~ 2009 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oii & Gay Cons. Commission REPORT OF SUNDRY WELL OPERATIONS aR~nor~rta 1. operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate 0 Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^'~ Exploratory ^ 208-051 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20529-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 37' GD3-107L1 8. Property Designation: 10. Field/Pool(s): ADL 372104, 372105, 364471, 374472 Colville River Field / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 19482' feet true vertical 6926' feet Plugs (measured; Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse CONDUCTOR 114' 16" 114' 114' SURFACE 3057' 9-5/8" 3093' 2479' PRODUCTION 11841' 7" 11874' 7076' LINER 8350' 4-1/2" 19475' 6927' Production hole depth: Measured depth: 10944' - 10970' true vertical depth: 6746' - 6761' Tubing (size, grade, and measured depth} 3-1 /2" L-80 tubing @ 1 1153' Packers &SSSV (type & measured depth) Baker Premier Packer @ 10862' Camco SSSV @ 2209' 12. Stimulation or cement squeeze summary : Intervals treated (measured) 11874'-12731' heel frac and 12840'-19475' toe frac Treatment descriptions including volumes used and final pressure : See attached report Of well Operations 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 927 ~ 754 3 1235 231 Subsequent to operation 1622 950 75 None 500 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: CQ Ga;~^ WAG^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-030 contact Jack Walker Printed Name Ja ck Walker Title Production Engineer ~ ~ Signature ~ ~G ~ Phone 265-6268 Date ~ ~ ~1 ~r-2, '009 G ' ~=~-~~ i Pre ared b Jeanne L. Haas 263-4470 Form 10-404 Revised 04/2006 ~ ~ ~ # -• _ v~~ ~ ~~~~ _~ i. L~09 t~Submft Origin I Only • CD3-107L1 Stimulation Report of Well Operations Sundry Approval 309-030 04-Mar-2009 Heel Frac Summary Arrive on location, Spot equipment, Stab TS rig up location for Frac. 325,920# 16/30 Sand, 230 bbls Diesel and 2803 bbls Sea Water on location. LRS TEST POPOFFS. TESTED 3750@ 3700, PT TO 4000# ALL THE WAY TO WELL. PJSM 26 on Location consisting of 18 = SLB, 3 = CPAI, 2 =LRS, and 3 = ASRC. Discussed job execution, slips trips and falls, pressure hazards, congested location, Discussed spills and 0 0 0 targets. Prime and roll pumps. Stall pumps against 3" hydraulic valve. Thaw ice plug in missile. Pressure test lines to 7500#. LRS pressured IA up to 3500#. Begin pumping breakdown stage, attempt to set tree saver. Shut down pumping, TS tree saver problems. Begin pumping @ 8.2 bpm @ 3000 psi, set tree saver. Pumped breakdown @ 30 BPM @ 5800 psi, no apparent breakdown due to possible friction from sliding sleeve. Pumped a total of 200 BBLS FG = .70, ISIP 1818 psi. Begin pumping second try FRAC @ 25 BPM. FRAC PUMPED AS FOLLOWS: STAGE # AVERAGE PPA COMMENTS PRESSURE PSI TYPE RATE (BPM) STAGE (BBL) 1 0 PAD : 5100 YF127ST 25 163.0 2 0 PAD 5100 YF127ST 25 237.0 3 2 Flat 4700 YF127ST 25 240.0 4 4 Flat 4700 YF127ST 25 480.0 5 4 Flat 4747 YF127ST 25 400.0 6 7 Flat 6300,: YF127ST 24 784 7 Pumped frac with a total of 306,467# 7 PPA, 16/30 Badger sand to formation. Flushed 107 bbls to completion w/ 63 bbls SW and 44 bbls of diesel for freeze protect. Went to flush 16 bbls early due to increasing treatment pressure of 6200 psi. Lost Deck side motor 179 bbls into the 480 bbl 4 ppa stage down for 8 min came on with Roadside and continued the frac. SD ISIP= 3175 psi FG = .89. 10 Min = 2130 psi, used 2233 bbls of SW and 130 bbls of diesel CD3-107L1 Stimulation Report of Well Operations Sundry Approval 309-030 27-Feb-2009 Toe Frac Summary COMPLETED THE HYDRAULIC FRACTURE STIMULATION OF THE NECHELICK SAND. PUMPED A TOTAL OF 580,167# OF 16/30 BADGER SAND, PLACING 580,110# INTO FORMATION. FRAC CONSISTED OF 5 SEPARATE STAGES EACH WITH 2, 4, AND 7 PPA SAND CONCENTRATIONS. EACH OF THE 5 PAD STAGES CONTAINED L65 SCALE INHIBITOR. AFTER 100 BBLS OF FLUSH, A 2.25" BALL WAS DROPPED TO SHIFT OPEN THE BAKER SLIDING SLEEVE. WELL FREEZE PROTECTED WITH 35 BBLS OF DIESEL. 09:00 AM MIRU SCHLUMBERGER FRAC EQUIP. 09:30 AM LRS ON LOCATION HEATING SLB TRANSPORT. CONTINUE TO RIG UP SLB EQUIPMENT. 12:15 PM LRS MOVED OVER TO RIG UP AND TEST POPOFFS TO 3500#. ALL GOOD. 02:04 PM CONDUCT PJSM. TOTAL OF 25 ON LOCATION (17 SLB, 3 CPAI, 2 LRS, 3 ASRC.) 02:46 PM START PUMPS TO WARM EQUIPMENT. 02:49 PM PRIME UP ALL EQUIPMENT. 03:07 PM ROLL PUMPS. 03:22 PM STALL PUMP 4 @ 1000#. CHECK FLANGE @ 1500#. 03:28 PM OPEN WELL AND PUMP DIESEL DOWNHOLE TO CHECK FLANGE. UNABLE TO CATCH FLUID PUMPING DIESEL AT 11 BPM. SHUT DOWN AND PT FIRST BEFORE SETTING TREESAVER. 03:49 PM PUMP 16.0 BPM @ 2500 PSI TO SEND TREESAVER DOWN. TREESAVER DOWN AND FINALLY SET. 04:22 PM STALL PUMP @ 3100# AND PRESSURE TEST TO 8200# AGAINST 3" VALVE. ALL GOOD. 04:28 PM PUMP BREAKDOWN: --> 150 BBLS LINEAR GEL. PERFORMED SD AND THE END OF THE PUMP STAGE. ISIP = 550#. FG = 0.52. WBF = 475 # @ 25 BPM. 04:49 PM FRAC STAGE 1 SHUT DOWN TO DUE TO LEAK IN L65 LINE. MAKE REPAIRS. RESTART PUMPING PAD. --> PAD OF 200 BBLS 27# XL @ 25 BPM. FWHTP = 4984 #. L65 ADDED @ 53 GPM FOR A TOTAL OF 420 GALLONS. --> 150 BBLS OF 2 PPA. FWHTP = 5251 psi @ 25 BPM. --> 300 BBLS OF 4 PPA. FWHTP = 5498 psi @ 25 BPM --> 300 BBLS OF 7 PPA. FWHTP = 6075 psi @ 25 BPM --> 25 BBLS WITH 24 BIOBALLS FOR DIVERSION 05:50 PM FRAC STAGE 2 --> PAD OF 160 BBLS 27# XL @ 25 BPM. FWHTP = 5848 #. L65 ADDED @ 53 GPM FOR A TOTAL OF 336 GALLONS. --> 150 BBLS OF 2 PPA. FWHTP = 5465 psi @ 25 BPM. --> 300 BBLS OF 4 PPA. FWHTP = 5479 psi @ 25 BPM --> 300 BBLS OF 7 PPA. FWHTP = 6061 psi @ 25 BPM --> 25 BBLS WITH 20 BIOBALLS FOR DIVERSION 06:29 PM FRAC STAGE 3 --> PAD OF 160 BBLS 27# XL @ 25 BPM. FWHTP = 5852 #. L65 ADDED @ 53 GPM FOR A TOTAL OF 336 GALLONS. --> 150 BBLS OF 2 PPA. FWHTP = 5666 psi @ 25 BPM. --> 300 BBLS OF 4 PPA. FWHTP = 5629 psi @ 25 BPM --> 300 BBLS OF 7 PPA. FWHTP = 6292 psi @ 25 BPM --> 25 BBLS WITH 16 BIOBALLS FOR DIVERSION 07:05 PM FRAC STAGE 4 --> PAD OF 160 BBLS 27# XL @ 25 BPM. FWHTP = 6062 #. L65 ADDED @ 53 GPM FOR A TOTAL OF 336 GALLONS. --> 150 BBLS OF 2 PPA. FWHTP = 5582 psi @ 25 BPM. --> 300 BBLS OF 4 PPA. FWHTP = 5859 psi @ 25 BPM --> 300 BBLS OF 7 PPA. FWHTP = 6452 psi @ 25 BPM --> 25 BBLS WITH 16 BIOBALLS FOR DIVERSION. 07:41 PM FRAC STAGE 5 --> PAD OF 150 BBLS 27# XL @ 25 BPM. FWHTP = 6053 #. L65 ADDED @ 53 GPM FOR A TOTAL OF 315 GALLONS. DROPPED RATE TO 23.5 BPM TO PREVENT FROM PRESSURING OUT. --> 150 BBLS OF 2 PPA. FWHTP = 5767 psi @ 25 BPM. --> 300 BBLS OF 4 PPA. FWHTP = 5846 psi @ 25 BPM --> CD3-107L1 Stimulation Report of Well Operation Sundry Approval 309-030 300 BBLS OF 7 PPA. FWHTP = 6500 psi @ 25 BPM. GO TO FLUSH @ 223 BBLS OF THE 300 BBLS STAGE. 08:14 PM FLUSH --> 100 BBLS OF XL GEL. FWHTP = 6250 PSI @ 25 BPM. DROP 2.25" BALL. --> 80 BBLS LINEAR GEL. FWHTP = 5515 PSI --> 35 BBLS DIESEL. FWHTP = 4457 PSI. 08:25 PM SHUTDOWN AND MONITOR WHTP. ISIP = 1700 psi. PUMPED A TOTAL OF 580,167 # OF 16/20 BADGER SAND PLACING 580,110 # INTO THE FORMATION WITH 5 STAGES OF 7# PPA @ THE PERFS. MONITOR WHTP FOR 15 MINS. FINAL PRESSURE IS 1620 PSI. SHUT IN WELL AND BLEED BACK IA TO 500 PSI. SAW APPROX. 1250# PRESSURE DROP WHEN 2.25" BALL SHIFTED THE BALL DROP SLIDING SLEEVE OPEN. 08:45 PM BEGIN TO RIG DOWN FRAC EQUIPMENT. 08:53 PM TREESAVER UP AND MASTER VALVE CLOSED. CONTINUE TO RIG DOWN FRAC EQUIP. 11:30 PM NOTIFY DSO OF WELL CONDITION. S`l~~°11~L~ o ~ ~fl ,~,«G~G;~ ALASSA OII. A11TD GAS COI~TSERQA~'IO1~T COl-Il-IISSIOI~T Jack Walker Production Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-107L1 Sundry Number: 309-030 Dear Mr. Walker: SARAH PALlN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~ Daniel T. Seamount, Jr. ~ Chair DATED this .,~ day of February, 2009 Encl. c~ ~~ _~~ ,~ l~,~iD .J ~~ ~ • ''~~ STATE OF ALASKA REC'EI V E a ALASKA OIL AND GAS CONSERVATION COMMISSION ~ /~ APPLICATION FOR SUNDRY APPROVA~~ JAN 2 7 2009 20 AAC 25.280 ~ •, ~ n__ r,..,~ t^nmmiCCiAn 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver_Ch ge Other ^ AA f( ll Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ • Time Exten si o n ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q . Exploratory ^ 208-051 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20529-60• 7. If pertorating, closest approach in pool(s) opened by this operation to nearest property line where 8. Well Name and Number: ownership or landownership changes: Spacing Exception Required? YeS NO ^~ CD3-107L1 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 372104, 372105, 364471, 374472 RKE = 37" `/4.4 SAS Colville River Field / Fiord Oil Pool 12. PRESENT WELL CON I MARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 19482' 6926' ' Casing Length Size MD ND Burst Collapse CONDUCTOR 114' 16" 114' SURFACE 3057' 9-5/8" 3093' PRODUCTION 11841' 7" 11874' LINER 8350' 4-1 /2" 19475' Pertoration Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10944' - 10970' 6746' - 6761' 3-1 /2" L-80 11153' Packers and SSSV Type: Packers and SSSV MD (ft) Baker Premier Packer Packer = 10862' Camco TRMAXX 5E SSSV = 2209' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^d Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: February 15, 2009 Oil ^~ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Walker Printed Name Jack Walker Title: Production Engineer Signature qtr ~~ ~,L~'~ Phone 2ti5-6268 Date ~ ~ ~b Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness r~~~ ""' ~ ~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~v ~./ t~~ ;, APPROVED BY '~ Approved by: COMMISSIONER THE COMMISSION Date: ~L inn i~~eeviaeu vwcvvv/ ' ~~, ~~ ~l~o~''d• " z7. CD3-107L1 Stimulation CD3-107L1: A hydraulic fracture treatment will be performed in the horizontal section to establish communication vertically and longitudinally through the Nechelik zone. A coil cleanout will only be performed should it be necessary post-frac. Procedure: 1. MIRU at least ten clean insulated frac tanks. Load tanks with seawater (approximately 4500 bbls are required for the treatment). 2. Rig up Schlumberger pumping services equipment and stab the Tree Saver. (Test tree saver seals to expected pressure using warm diesel to assure seal integrity in tubing hanger) 3. Pressure test surface lines to 9000 psi. 4. Pump treatment for toe section of horizontal lateral: a. 250 bbl breakdown with W120 fluid b. Pump Schlumberger's schedule at 25 BPM with a maximum pressure of 7000 psi, add breaker as per lab results. Maintain 3500 psi on the IA during the treatment. c. 5 Stages of 2,4,7 PPA ramped containing: • 935 to 950 bbls dirty YF125ST (4680 bbl total) • 122 M Ib - 16/20 sand (609 Mlb total) • 16-24 bio-balls via the ball drop after each 7 ppa stage (76 balls total) • Flush with 50 bbls YF125ST; 50 bbls WF120, and 25 bbls diesel 5. Open frac sleeve in production hole liner at 12337'MD and isolate toe section. 6. Pump treatment for heel section of horizontal lateral: a. 200 bbl breakdown with WF125 b. 820 bbl dirty volume at 25 BPM with 349 Mlb 16/30 sand CD3-107 Schematic Maunder, Thomas E (DOA) Page 1 of 1 From: Walker, Jack A [Jack.A.Walker@conocophillips.comJ Sent: Monday, February 02, 2009 2:12 PM To: Maunder, Thomas E (DOA) Subject: CD3-107 Schematic Attachments: CD3-107L1.pdf; CD3-107.pdf Tom, A quirk in our system yields two schematics for the same well; I'm sending both because the tubing is shown in one schematic, and the liner is shown in the other (one is for the mother bore and the other is for the sidetrack). Please call with any questions. Jack 265-6268 «CD3-107L1.pdf» «CD3-107.pdf» 2/2/2009 Conoc Phillips . • • wa cwmD: Hon:onw - ct3a-v _ _ _ sd,enlenp HANGER, 10 REDUCE XO. 100 CONDUCTOR, a-114 SAFETY VLV. _ x.18e SURFACE, ___ _ 37-3.093 GAS LIFT, 4,752 GAB LIFT B,BOfi -_-. - _ GAS UFT, _ _ 1o,nz NIP%.E. 10 921 PACKER. 10,862 GAS LIFT, 10919 -'- - IPERF. 10,944-10,9]0 Squeeze KUP - ~~ Pede, 10725 SLEEVE-0, 11,009 ---- PACKER, 11 032 NIPPLE. 11980 - FLUTED SUB, -- 11.122 -- SUB. 11.123 WLEG, 11.152 NTERMEDIATE, 34-11,874 SLOTS. 13.232-19.295 LINER - INACTIVE, - - - - 5.330-18,315 I LINER SLOTTED, 11.125.196]5 TD (CD3-10]L1), 1s.4e2 ~ ~ a~ ~ y~Ng CD3-107L1 _ __ _ wen ¢ttributes Wellbore API/UWI Fieltl Name - Well Status Prod/In1 Wall Type InCI (°) MD (1tKB) TD (max) (R... 501032052960 FIORD KUPARUK PROD 97.28 19.252.33 19 482.0 Comment H2S (ppm) Date Annotation End Dab KB-Drd (ft) Rlg Release Date - SSSV. TRDP 0 7/1/2008 Last WO 37 03 412712006 ril2008 d_4924 PM 'Annotation Depth (f[KB) End Date Annotation End Date Last Tag- 13 242.0 3/30!2007 Rev Reason: SHIF7 SLEEVE, GL V CK> 9/2 612 0 0 8 St i ~ C i ng r ngs as Casing Descdphon S(ring D String ID -Top (ftKB) Set Depth (i... Bet Depth (TVD) Stnng Wt.. String Gr .. String Top Thrd ' "" LINER SLOTTED 3 ill 2.992 11,125.2 19.475.0 6,926.8 9.30 L-80 8RD EUE Liner Details __ Top DaD[h '~ (TVD) Top Top IttKel (Itl(B) Inc! (°) Item Descnptlon Comment _ ID (in) 11,125.2 6,843.9 65.54 HANGER _ Hanger assembly w/ZXP packer 3.961 -_' _ _ 11,207.2 6,877.6 66.77 REDUCE XO _ _ _. _ CROSSOVER - __~ 3.951 __ ~. 1 t Odg ] R liQd d ~ fifi Sfi CI FFVE-O _--_ Baker CMD SIIdInD Sleeve W/ X pfOfle 91.14~PACKER Packers Baker Open hole - - - - - -- 89.88 PACKER Packers TAM free cap 3.5 ----- -- -. 2.9 90.68 ENLARGE XO XO pup 4 ill" x 3 1/2" w/ shear sub -x <. <~:. _. _.- Shot Top (TVD) Btm (TVD) DS^s (TtlCB) (ftKB) Zone Data Ish.,. Type Comment _ _ 7,058.8 6,948.4 227NCH, 5/2/2008 4.0-SLOTS CD3-107 - _-~ yyNg ` CD3-107 r CQEIQCQPI'tllll }5 - ~ ll A ib t _ _ ~ ,~.?"`ti : a-; u es _ We ttr ~ Wellbore API/UWI Field Name ~ Well Status Prod/lnJ Well Type Incl (') MD (kKB) TD (max) (R... 501032052960 FIORD KUPARUK PROD a - - - 97.28 19,252.33 19 482.E - _ - - _ _ _.. Comment R2S (ppm) Date Annotation End Dab _ _ Ke-Grd (R) Rlg Release Date "' .. _,SSSV~ TRDP 0 7l1 /2008 Last WO~. _- 37.03 4/2712006 _ WeN ~ CD~1~0)~9 - /a2F 2o~'._aslcS JM Pth (kK8) End Dab Annotation Annotation End Date ---- q 13,242.0 3/3012007 Rev Reason. SHIFT SLEEVE, GLV GO Last is _ 9/26/2008 _ HANGER, t0 "; ,Casing Strings Lasing Description String 0... Str ng ID Top (itKB) Set Depth ((. Set Depth (ND) String WL. String Gr... String Top-TIIrtl . ___ _._ ~~ -- ._ _- _. CONDUCTOR 16 15 062 0 0 114.0 114 0 Casing Description SMng O.. String ID Top (kKB) Set Depth ((... Set Depth (ND) .. 62.50 String Wt... String Gr... String Top Thrd INTERMEDIATE 7 6.276 34.2 11,874.0 7,075.5 . 26.00 L-80 _ - K~ ~ ~, Casing Deacdptlon String 0... SMrg 10 ... ToP Irnce) -- ~Sst Depth (f... Set Depth (TVD) ... SMng Wt.. SMng Gr... String Top Thrd °'"~'~ ~ ""°~~'~` SURFACE 9 5/8 8.835 36.8 3,092.9 2,478.8 40.00 L-80 REDUCE %O ~ Caaing DescdPtlon String O._ String ID ... 7oP (kKB) Set Depth ((... Set Depth (TVD) .,, SMng Wt... SMng Gr... String Top Thrd . 100 LINER -INACTIVE 7 6.276 5.329.6 18,315.0 26.00 L-80 Buttress Thread _., CONDUCTOR. ° _. _. .._ _.._.. .__. -,-_ _ _.,_. bi St T _ .~_ _ __ o..,,a rings _ ng u Tubing Descnp.lon String 0... String ID . -Top (itl(B) -- -Set DaPM (f... Sat Dep[h (lYD) . SMng Wt... String Gr._ 'String Top Thrd SAFETV VLV, ' TUBING 31/2 2.992 102 11,153.0 6855.3 _ T _. . ._.--r 9.30 L80 _____._-°~-y. ,.a-gym-, 2,,ae _ _ - _. ICompletionDetails _ __ s:_-._._~ -_.-. ' Top DeP[h. _...- __. (ND) Top ToP1~B) (hKd) Incl (°) Itarr, Descdpton Comment _.. ID (In) - - - 10.2 10.2 -0.36 HANGER FMC TUBING HANGER 4.000 SURFACE. - - -- - 54 REDUCE XO Cross Over 4 1!2" BT x 3 1/2" EUE BRD 4 100 4 0 100 - - - - 3.000 3]-3.1]93 . . . 2,188.4 1,984.7 45.31 SAFETY VLV ~CAMCO TRMAXX-5E w%2.813" PROFILE - 2.813 ___ ___, GAS UFT a.]sz --_._-_ - -. 10,820.8- 6,699.5. 58.44~NIPPLE Nipple HES"X^ ` 2.813' GAS LIFT. a.BOfi e Top (TVD) Btm (TVD) ~ s a a Top (kKB) Btm (itl(B) (kKB) (kKB) Zone Dale (h... Type Comment ~ GAS LIFT, c - -- , 970.0 6 762.3 6 774.8 KUPC, CD3-107 5/2/2007 6 0 IPERF 2 HSD PJ Omega Guns 1 944 0 10 10 t0.nz a a a d , . _.. _____ _... - ___ __.._. _.. -._ .._ -. < ~ ~ Cement Squeezes - _° Dpth To rv Pth Btm ~ NIPPLE. 10.521 - -d ,} N D ( ) ( ) a a 'Top (ttKB) Btm (ftKB) (kK8) (kK8) Description Start Date Comment _ . ,f 10,725 0 10.960.0 6 648.7 6 770.0 CSG SOUEEZE 4l17I2008 SQUEEZE KUPARUK PERFS ~ ._ PACKER. _ ,o.e5z - -- ~=~4 i Not®s: General 8 Safety - ~ "' r _ End Date Annotation < a ~ 7111/2008 NOTE VIEW SCHEMATIC wl9 0 ~ , - original wellbore not plugged, only Li producing 8/15%2008 NOTE: Well sideVacked to L1 GAS uFT, 1os1s - - d '.. d a , _ _ _. __ -_ - __ __.~ IPERF, < e 10.944-10 970 ~~ ~ Squeeze KUP ~__ - I Parts, 10 725 ~ 1, SLEEVE-0, - 11.009 ' PACKER, _ _ _ 11,032 NIPPLE. 11.080 - FLUTED SUB, - - _ - ; 11.122 SUe, 11,123 - - WLEG, 11,152 ---- - NTERMEDIATE, . __ -_' -__. .... _. _. '-..~-..-~- _ _ 34-11874 . __. tMaedrel Details "`' - ioaoepm rod. __ ~ .--- -- __POrt -_"_ (7V0) Incl OD Valve Latch Slza TRO Run sN. Ten IfrKe1 (kK8) (°) Make Model Ilnl Sarv TYPe TYPe (In) (Psi) -Run Date Comment LINER INACTIVE, ~ 5.330-18375 'I TD (CD3-10]), ~1 18.315 LINER SLOTTED, i - 11,125-19 475 I L _ ;> ~/'f/~/ N~IVI~~~ ~` ~~ 'A~ _ __ ProActive Diagnostic Services, Inc. To: State of Alaska - AOGCC Christine Mahnken 333 West 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing 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 following ProActive Diagnostic Services, Inc. Attn: Robert Q. Richey 130 West International Airport Road ap`~_p5 Suite C Anchorage, AK 99518 (~-p3~ Fax. (907j 245-8952 1 J Production Profile 26-0ct-08 CD3-107L1 1 Color Log / EDE 50-103-20529-60 2j Si ned : ~ Date g Print Name: ~l (..~ ~~~.p, ~~lk~-.,~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907y245-8951 Fax: (907}245-88952 E-MAIL: ~~s~r~ci~~~~~I~Ca2~serrjo~v~c~~s.r~In WEBSITE: ~M1~nnn+.~~€~~~~,_~c~ C:\DocumenLs and Settingsl0wnet\Desktop\Ttansmit_Conoco.docx r • V6~LL L®G TRANSIVIITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-107 L1 July 1, 2008 AK-MW-5700040 CD3-107 L1 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 50-103-20529-60 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 50-103-20529-60 Digital Log Images: 50-103-20529-60 1 Color Logs 1 Color Logs 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchgr~,ge, Alaska .995..18 Date: Signed: ConocoPhillips June 23, 2008 P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 Commissioner JUN 2 3 ZDD~ State of Alaska ~, _ ~. ; Alaska Oil & Gas Conservation Commission Alaska C?i1 & Gay ~~c~~ ~.~~~~ ~~~~~~~~ 333 West 7th Avenue Suite 100 Asl~~~~,~~a Anchorage, Alaska 99501 Subject: Well Completion Reports for CD3-107 and CD3-107L1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the Alpine well CD3-107 and CD3-107L1. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, ~ . ~,/'~ G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells G. C. Alvord Alpine Drilling Team Leader Drilling & Wells GCA/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION fP~O~F~~&AND LOG 1a. Well Status: Oil ^/ Gas Plugged Abandoned Suspended A~~t~~~ ~6~ ~ ~~~ ~ 20AAC25.105 20AAC25.110 ~~~,~§~~, GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: i r,7V~iClTlT~isi'~~ Vie' ~v~elopment / Exploratory ^ Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: May 3, 2008 12. Permit to Drill Number: 208-051 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: April 19, 2008 13. API Number: 50-103-20529-60 4a. Location of Well (Governmental Section): Surface: 3926' FNL, 797' FEL, Sec. 5, T12N, R5E, UM' 7. Date TD Reached: ~ April 26, 2008 gyp.(, 14. Well Name and Number: 7•~'~ CD3-107L1 Top of Productive Horizon: 857' FNL, 1318' FWL, Sec. 3, T12N, R5E, UM 8. KB (ft above MSL): ~Z-GC14B" ~ Ground (ft MSL): ,1.3"AMSL f,3'.2 15. Field/Pool(s): Colville River Field Total Depth: 1058' FSL, 681' FWL, Sec. 28, T13N, R5E, UM 9. Plug Back Depth (MD + TVD): 19475' MD ! 6927' TVD Fiord Oil Pool ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 388247 ' y- 6003847 • Zone- 4 10. Total Depth (MD + TVD): 19482' MD / 6926' TVD 16. Property Designation: ALK 372104, 372108, 364471, 364472 TPI: x- 395678 y- 6006809 Zone- 4 Total Depth: x- 392488 • - 6014049 Zone- 4 11. SSSV Depth (MD + TVD): 2209' MD / 1999' TVD 17. Land Use Permit: LAS2112 18. Directional Survey: Yes Q No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1268' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): k0~• ~2~ ~,: ~ /yJ~ GR/RES p ~ /D ~ 7•B•ot`~ 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE CEMENTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 37' 114' 37' 114' 24" 1o cu yds Portland Type III 9-5/8" 40# L-80 37' 3093' 37' 2479' 12.25" 385 sx Class G, 230 sx Class G 7" 26# L-80 37' 11874' 37' 7075' 8.75" 277 sx Class G 4.5" 12.6# L-80 11125' 19475' 6844' 6927' 6.125" perforated liner 23. Open to production or injection? Yes / No If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 11153' 10862', 11032' perforated liner from 13232'-19295' MD 7059'-6948' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED balance plug from 10015'-10960' 152 sx Class G (to cover Kuparuk perforations) 26. PRODUCTION TEST Date First Production May 12, 2008 Method of Operation (Flowing, gas lift, etc.) gas lift oil Date of Test 5/12/2008 Hours Tested 8 hours Production for Test Period -> OIL-BBL 785 GAS-MCF 561 WATER-BBL 77 CHOKE SIZE 100% GAS-OIL RATIO 870 Flow Tubing press. 229 psi Casing Pressure 1716 Calculated 24-Hour Rate -> OIL-BBL 2162 GAS-MCF 1882 WATER-BBL 229 OIL GRAVITY -API (core) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No / Sidewall Cores Acquired? Yes No / If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. COMPLr=TION NONE _-~• V~Riflrrt? Form 10-407 Revised 2/2007 URIG~JAL CONTINUED ON REVERSE SIDE ~~ e~~~ ~ ~ L~~V 28. GEOLOGIC MARKERS (List all formations and markers encountered): 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 1287' 1268' needed, and submit detailed test information per 20 AAC 25.071. C-30 3117' 2491' C-20 3812' 2887' K-3 5687' 3905' K-2 6029' 4091' Nanuq 9553' 6010' K-1 10778' 6677' Kuparuk C 10944' 6762' Nuiqsut 11157' 6857' Nechelik 11758' 7059' N/A Formation at total depth: Kuparuk C 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Liz G8liunas @ 265-6247 Printed Name + hi Alvord Title: Drillino Team Leader , / . Signature / r'-~-- Phone Date ~ a~'~' ( ~ INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 212007 CD3-107 Pre and Post Rig Events DATE SUMMARY 4/9/08 Gauge tubing with 2.80" GR, found restriction in X nipple. Break through with 2.80" GR. Ran and set Cat SV in XN nipple. Pressure test tubing to 2500 psi. LDFN job in progress. 4/10/08 PULLED GLV's FROM 4804', 8769' & 10,714' RKB. SET DV's @ 4804 & 8769' RKB. LOADED TUBING AND IA W/ 9.3 PPG Nacl & 2500' DIESEL CAP. 2500 PSI COMBO MIT: PASSED. PULLED STANDING VALVE FROM 10,902' RKB. WELL IS READY FOR E-LINE TO CHEM CUT. 4/11/08 CHEMICAL CUT PREMIER PACKER IN CUTTING WINDOW AT 10861.9'. SEVERING HEAD IN EXCELLENT CONDITION AT RETURN TO SURFACE. 6" OF 1 ARM OF THE BOTTOM CENTRALIZER IS BROKEN AND LEFT IN HOLE. 4/11/08 RECOVER 6" SECTION OF E-LINE CENTRALIZER FROM TOP OF SWAB VALVE. RAN PDS CALIPER FROM 10,798' RKB TO SURFACE. SET FRAC SLEEVE IN SSSV @ 2236' RKB. JOB COMPLETE. 5/7/08 PULL BALL & ROD AND RHC PLUG FROM 11,080' RKB. PULL SOV/BK LATCH FROM 10,772' RKB. C/O W/ PECKS CREW, CONTINUED ON NEW NEW WSR. 5/8/08 SET 1/4" OV @ 10,772' RKB. BAILED DRILLING MUD FROM 11,187' SLM TO TOP OF DEBRIS CATCHER @ 11,220' SLM. PULLED DEBRIS CATCHER FROM 11,250' RKB. CONT. ON 5/09/08 WSR. 5/9/08 PULLED 2.81" XX PLUG FROM 11,250' RKB. JOB COMPLETE. C ConocoF'hillips Time Log & Summary ~~~ ~~~~W ~,~e R~~°,~n9 Report Well Name: CD3-107 Rig Name: DOYON 19 Job Type: DRILLING RE-ENTRY Rig Accept: 4/13/2008 11:00:00 AM Rig Release: 5/4/2008 3:30:00 PM Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 4/13/2008 R4 hr summary Moved rig and rigged up. Killed well and circulated. 04:30 11:00 6.50 0 0 MIRU MOVE MOB P Doyon 19 Rigged down and moved from CD3-303 to CD3-107L1. Positioned Do on 19 ri and RU. 11:00 12:00 1.00 0 0 MIRU DRILL RURD P Connected service lines and and ower. 12:00 14:00 2.00 0 0 MIRU DRILL RURD P Rigged up lines and valves to choke and Ti er tank. 14:00 15:00 1.00 0 0 COMPZ RPCOM OTHR P Rigged up and pulled BPV. 350 psi on tubin . 50 si on annulus. 15:00 17:00 2.00 0 0 COMPZ RPCOM RURD P Continue rigging up lines to circulate well. 17:00 18:30 . 1.50 0 0 COMPZ RPCOM OTHR P PJSM Bled off gas until liquid to surface. 200 psi on tubing. 50 psi on the annulus. 18:30 22:30 4.00 0 0 COMPZ RPCOM CIRC P PJSM Circulated 9.6 ppg brine to the Tiger tank until cleaned up. Rates vaired from 2 BPM to 4 BPM Estimated 70% returns. 22:30 23:00 0.50 0 0 COMPZ RPCOM OWFF P Observed well while mixing brine. 0 si. 23:00 00:00 1.00 0 0 COMPZ RPCOM CIRC P Continue pumping @ 3.5 BPM 460 psi. Returns to pits loss 16 BPH. 9.6 ppg in and out. Pumped poleymer LCM pill 35 Bbls and displaced 25 Bbls to annulus. 4/,14/2008 Installed BPV and nippled down tree. NU and tested BOP 250/2500/3500 psi. Test waived by Chuck Shevie AOGCC. Rigged up and worked pipe to free packer. RU E Line and RIH with cutter. Would not pass SSSV. POOH E Line. 00:00 01:00 1.00 0 0 COMPZ RPCOM CIRC P Monitor well, static -Blow down lines -Install BPV in hanger - RU to keep annulus full 01:00 02:00 1.00 0 0 COMPZ RPCOM NUND P ND tree -disconnect SSSV control line and fiber optic cable terminations -Install blanking plug into tubing han er 02:00 04:30 2.50 0 0 COMPZ WELCTL NUND P NU BOP stack -Install riser and flowline 04:30 05:30 1.00 0 0 COMPZ WELCTL BOPE T Attempted to test blind rams - located leak on choke line -replaced seal rin in Oteco union Page 1 c:f 3 ! • Time Logs Da e From To Dur S De th E. De th Ph e Code Subcode T Comment 05:30 12:00 6.50 0 0 COMPZ WELCTL BOPE P Tested Blind Rams 250/3500 psi - engaged blanking plug with 31/2" test joint -Tested Pipe rams ,choke, kill, manifold and surface safety valves to 250/3500 psi -tested annular preventor 250/2500 psi -blow down choke and kill lines -Chuck Sheve waived witnessin tests 12:00 12:15 0.25 0 0 COMPZ RPCOM SFTY P Held prejob Safety and Opts meeting with crew 12:15 13:45 1.50 0 32 COMPZ RPCOM PULD P Pulled BPV - MU xo's onto landing joint A back to 4" XT - MU landing joint into tubing hanger - MU top drive into LJ 13:45 20:45 7.00 32 32 COMPZ RPCOM PACK P Work pipe to release Packer -Recorded PUW of Completion =149K -staged straight pull up from 190K to 230K -work Completion strip from 100K to 230K 20:45 22:45 2.00 32 32 COMPZ RPCOM RURD P PJSM. Rigged up Slumberger E Line unit. 22:45 00:00 1.25 32 0 COMPZ FISH ELNE T RIH with E Line Chemical cutter 2 3/8" to 2236'. Unable to pass SSSV. Talked with Slickline Rep and found the Lockout sleeve was 2.3" ID. POOH with cutter. 4/15/2008 Fin POOH W/E-line & LD chem. cutter, MU retrieving tool, RIH & rerieved sleeve f/SSSV, POOH LD same, ND BOP stack, PU & pumped open SSSV, capped line, NU stack & tested break 250/3,500 psi, MU landing jt, Pull tbg at 170K and set slips. RU E-line &RIH cutting mandrel on pkr 10863.3', PU & pkr was free, circ hole, no gas at btms up, cont. to circ hole & spotted hi vis pill on btm, monitored well-static, RU spools then ulled tb h r to ri floor & LD same, LD 2 'ts 4 1/2" tb then RU to be in LD 3 1/2" tb . 00:00 02:45 2.75 0 0 COMPZ FISH ELNE T POOH with E-Line and laid down cutter. Made up pulling tool and RIH to SSSV. Retrieved Lockout sleeve and POOH. Ri down. 02:45 04:00 1.25 0 0 COMPZ RPCOM OTHR T Drained stack and landed tubing hap er. 04:00 07:15 3.25 0 0 COMPZ RPCOM NUND T Nippled down BOP and Pumped control line to 6000 psi. and opened SSSV, Capped line and Nippled up BOP. 07:15 08:15 1.00 0 0 COMPZ WELCTL BOPE T Made up 3 1/2" testjt and tested BOP flange and lower rams to 250/3500 psi. Laid down test jt and blankin lu . 08:15 09:00 0.75 0 0 COMPZ RPCOM OTHR T Pulled BPV and rigged up landing jt A. Pull tubin at 170K and set sli s. 09:00 12:00 3.00 0 0 COMPZ FISH ELNE P Rigged up Schlumberger and RIH with 2 3/8" Chem Cutter. P~g~ ~ of 1fi Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:00 16:45 4.75 0 10,914 COMPZ FISH ELNE P Correlated 2 3/8" chemical cutter with Baker packer at 10,863.3' and cut same, began circ btms up and staging pump rate up to 3.5 bpm at 340 psi while POOH with E-line, observed gas breaking out at surface, RD cutter and SLB. Had slight problem pulling thru gauge carrier and X nipple with cutter after cuttin acker. 16:45 21:30 4.75 10,914 10,882 COMPZ RPCOM CIRC P PU 145k st wt on tbg and pkr was free, circ btms upstaging pump rate up to 4 bpm at 410 psi w/no gas at btms up, pumped 80 bbl hi vis tube pill and circ out of the hole, followed with 35 bbl hi vis pill and spotted on btm, spotted pill at 4.5 bpm at 480 psi. Monitored well-static, PU on tbg string and pulled tbg hanger to rig floor and LD same. 21:30 22:30 1.00 10,882 10,882 COMPZ RPCOM RURD P RU Camco and Baker Quest Spools and scheaves for control line and TEC wire. 22:30 00:00 1.50 10,882 10,800 COMPZ RPCOM PULD P POOH LD 2 jts of 4 1/2" tbg and XO to 3 1/2" tbg, changed out elevators to 3 1/2" and RU double stack power tongs. Note: Lost 125 bbls 9.6 ppg brine last 24 hrs. 4/16/2008 Fin. POOH LD 3 1/2" completion with Baker Premier Packer and Baker Quest gauge and wire. Installed wear bushin , RU & RIH to 310' with 3 1/2" cmt stin er. 00:00 12:00 12.00 10,800 5,333 COMPZ RPCOM PULD P POOH laying down 3.5" Completion strin from 10,800' to 5,333'. 12:00 22:00 10.00 5,333 0 COMPZ RPCOM PULD P Fin. POOH LD 3 1/2" completion, LD Baker Premier packer and Baker Quest gauge and wire, recovered 2 jts 4 1/2" 12.6#, L-80 IBTM and 343 jts 3 1/2" 9.3#, L-80 EUE-M tbg, SSSV and control line, GLM's and cannon clamps per detail sheet. NOTE: Lost 2 pins from Cannon clam s downhole. 22:00 22:45 0.75 0 0 COMPZ RPCOM RURD P RD Baker scheave from derrick and cleared ri floor. 22:45 23:15 0.50 0 0 COMPZ RPCOM PULD P Installed wear bushing 23:15 23:30 0.25 0 0 COMPZ RPCOM RURD P RU to run 3 1/2" cement stinger 23:30 00:00 0.50 0 310 COMPZ RPCOM PULD P RIH with 3 1/2" tubing for cement stinger to 310'. NOTE: Lost 130 bbls 9.6 Brine to form. last 24 hrs 4/17/2008 Fin PU 4" DP &RIH W/3 1/2" stinger to 11,833', CBU & spotted 35 bbl hi vis pill, POOH to 10,960', pumped 31 bbl balanced cmt plug, POOH to 10,015', CBU, performed 22 bbl Bradenhead squeeze leaving 9 bbls inside cs , ave 2 b mat 1,400 si. CBU & um ed d 'ob, POOH to 935' 31/2" cmt stin er 00:00 00:30 0.50 310 935 COMPZ RPCOM PULD P Picked up and RIH 3 1!2" cement strip from 310' to 935'. 30 'ts total 00:30 10:15 9.75 935 11,833 COMPZ RPCOM PULD P Picked up and RIH 4" Drill Pipe from 935' to 11,833'. 342 'ts total gaga 3 nf't6 i ~~ Time Logs _ D e From To Dur 5 De th E. De th Ph se Code Subcode T Comment 10:15 11:45 1.50 11,833 11,833 COMPZ RPCOM CIRC P Made up Top drive and CBU 5 BPM 710 psi. Did not see any Oil to surface. 11:45 12:15 0.50 11,833 11,833 COMPZ RPCOM CIRC P Pumped and spotted 35 bbl 9.6 ppg hi vis pill on btm, circ at 5 bpm at 710 si, monitored well-static. 12:15 13:00 0.75 11,833 10,960 COMPZ RPCOM TRIP P POOH from 11,833' spotting pill to 10,960' 13:00 14:30 1.50 10,960 10,960 COMPZ RPCOM CIRC P RU cmt lines and circ btms up at 6 bpm at 980 psi, no sign of hi vis pill at btms u ,monitored well-static 14:30 15:30 1.00 10,960 10,960 COMPZ CEMEN" DISP P Dowell pumped 5 bbls water, pressure tested lines to 3,000 psi and pumped 15 bbls add. water then pumped 31 bbls (152 sxs) of 15.8 ppg, 1.16 yield class "G" cmt w/additives and followed with 7 bbls water, rig pumped 91.5 bbls of 9.6 ppg brine to balance plug, pumped at 6 b mat 980 si, CIP at 15:19 hrs 15:30 16:30 1.00 10,960 10,015 COMPZ CEMEN" TRIP P POOH 10 stds to 10,015' 16:30 17:30 1.00 10,015 10,015 COMPZ CEMEN" CIRC P RU and circ btms up at 10,015', staged pump rate up to 9 bpm at 1,760 psi, no cmt at btms up only a sli ht increase in PH. 17:30 18:30 1.00 10,015 10,015 COMPZ CEMEN" SQEZ P Closed rams and performed bradenhead squeeze, pumped 22 bbls total at an ave 2 bpm at 1,400 psi, final pressure after 10 min's was 500 psi, left 9 bbls inside csg for an est. TOC at 10,725'. Pumped at ave of 2 bpm and broke over initialy at 1,480 psi. squeeze cmt in 4 stages. Pumped 6 bbls, broke over at 1,480 psi, pumped at 2 bpm ave 1,400 psi, shut down 10 min and bled down to 400 psi. Pumped 6 bbls, broke over at 1,420 psi, pumped at 2 bpm ave 1,390 psi, shut down 10 min and bled down to 425 psi. Pumped 5 bbls, broke over at 1,450 psi, pumped at 2 bpm ave 1,330 psi, shut down 10 min and bled down to 475 psi. Pumped 5 bbls, broke over at 1,440 psi, pumped at 2 bpm ave 1,410 psi, shut down 10 min and bled down to 500 si. 18:30 19:30 1.00 10,015 10,015 COMPZ RPCOM CIRC P Circ btms up at 8 bpm, 1,380 psi then um ed d 'ob, RD cmt line. 19:30 00:00 4.50 10,015 935 COMPZ RPCOM TRIP P Monitored well-static, POOH 114 stds to 3 1/2" cmt stin er at 935' P~y~ ~ of 16 ~~ Time Logs Date From To Dur S. De th E. De th Pha e Code Subcode T Comment /18/2008 24 hr Summary POOH & LD 3 1/2" cmt stinger, MU & RIH setting bridge plug @ 186', tested same to 3,500 psi, ND BOP stack & tbg spool, changed out spool & tested seals, NU BOP's & tested break on tbg spool to 250/3,500 psi. Retrieved bridge plug, MU 6 1/8" BHA #1, slip & cut drlg line, Cont to RIH W/BHA #1 PU 4" DP, RIH @ 4,189' 00:00 02:00 2.00 935 0 COMPZ RPCOM PULD P Laid down 30 jt 31/2" cement strin . 02:00 02:15 0.25 0 0 COMPZ RPCOM PULD P Pulled wear bushing. 02:15 04:30 2.25 0 0 COMPZ RPCOM DHEQ P RIH and set Bridge Plug @186'. POOH with running tool. RU and tested lu to 3,500 si for 10 min's. 04:30 05:30 1.00 0 0 COMPZ RPCOM NUND X Held PJSM and Nippled down flowline riser and BOP stack. 05:30 07:15 1.75 0 0 COMPZ RPCOM NUND X ND annulus valve, actuator valve and tbg spool and removed same. Sim-op removed cannon clamps from rig floor and PU Geo-span, stab's and bit to ri floor. 07:15 10:30 3.25 0 0 COMPZ RPCOM NUND X NU new FMC tbg spool, and re-installed annulus valve and actuator valve, tested seals and ackoff and ck'd ok. 10:30 13:00 2.50 0 0 COMPZ RPCOM NUND X NU BOP stack, riser and flowline. 13:00 14:00 1.00 0 0 COMPZ RPCOM DHEQ X RU and tested break on tbg spool against blind rams and bridge plug, tested to 250/3,500 si. 14:00 14:15 0.25 0 0 COMPZ RPCOM PULD P Installed wear bushing 14:15 15:30 1.25 0 0 COMPZ RPCOM PULD P RIH to 186' and retrieved Baker bridge plug, POOH and LD same. Hole full and did not take any add. fluid to fill hole. 15:30 19:00 3.50 0 407 PROD1 DRILL PULD P PU and MU Geopilot BHA #1 RIH to 407', MU bit, Geopilot and MWD, tested Geospan and uploaded MWD, RIH with NMFDC's, HWDP and jars, shallow tested Geo ilot and MWD. 19:00 20:30 1.50 407 407 PROD1 RIGMNT SVRG P Slip and cut 120' of drilling line and serviced to drive. 20:30 00:00 3.50 407 4,189 PROD1 DRILL PULD P Cont. to RIH w/BHA #1 PU 4" DP out of the pipe shed, RIH from 407' to 4,189' 4/19!2008 Fin PU 4" DP &RIH W/ BHA #1, washed down & cleaned out cmt stringers to csg shoe, (11,847') began cleaning out in open hole to 11,907' and began packing off, PU to below csg shoe & displaced hole over to 9.6 ppg Flo pro mud, cunt . to wash and ream old hole to 12,973', troughed well for sidetracking well then time drilled to sidetrack well from 12,973' to 12,976' 00:00 03:15 3.25 4,189 8,775 PROD1 DRILL PULD P Cont. to RIH w/BHA #1 PU 4" DP out of the pipe shed, RIH from 4,189' to 8,775' 03:15 04:00 0.75 8,775 10,013 PROD1 DRILL TRIP P RIH with stands from 8,775' to 10.013'. 04:00 11:30 7.50 10,013 11,907 PROD1 CEMEN" COCF P Wash and ream out cement stringers from 10,013' to 10,900'. Cleaned out with 3 - 5 K WOB to 11,907'. 4.7 BPM 75-RPM 1570 psi. Hole ackin off 11,907'. Pa~~3~ ~ of 1S Time Logs _ Date From To Dur S. De th E. De th Ph e Code Subcode T Comment 11:30 13:30 2.00 11,907 11,877 PROD1 DRILL CIRC P PU to below csg shoe and displaced hole over from 9.6 ppg brine to 9.6 ppg Flo Pro mud, displaced hole at 100 rpm's, 210 gpm at 1,590 psi, monitored well-static. Est clean hole ECD of 10.5 13:30 22:30 9.00 11,877 12,973 PROD1 DRILL REAM P Cont. to wash and ream old hole from 11,907' to 12,973' saw slight ~~ - ir~ ~ ~~C1 packing off and taking some wt thru out, washed and reamed at 120 rpm's, 3-7K wob, 210 gpm, 1,770 si. 22:30 23:00 0.50 12,973 12,973 PROD1 STK CIRC P Troughed well for sidetracking from 12,933' to12,973', trenched at 120 m's, 210 m, 1,720 si. 23:00 00:00 1.00 12,973 12,976 PROD1 STK KOST P Time drilled to sidetrack well from ~ KOP of 12,973' to 12,976' MD/7,053' .. MD, ADT .5 hrs. 4/20/2008 Time drilled to side track well from 12,976' to 13,001', cont. to directionally drill 6 1/8" hole with Geopilot from 13,001' to 14,395' 00:00 06:00 6.00 12,976 13,001 PROD1 STK KOST P Time drilled to sidetrack well from 12,976' to 13,001' MD/7,054' ND. ADT 6 hrs. 06:00 12:00 6.00 13,001 13,360 PROD1 DRILL DDRL P Drill 6 1/8" hole from 13,001' to 13,360' MD/ 7,059' (359') ND ADT 4.72 hrs, 10-12 K wob, 120 rpm's, 50 spm, 210 gpm, 1,900 psi, off btm torque, 9,000 ft-Ibs, on btm 11,000 ft-Ibs off, Rot wt 173 K, up wt 200 K, do wt 147 K, 9.6 ppg MW, ave ECD 10.71 12:00 00:00 12.00 13,360 14,395 PROD1 DRILL DDRL P Drill 6 1/8" hole from 13,360' to 14,395' MD/ 7,035' ND (1,035') ADT 9.15 hrs, 11-13 K wob, 120 rpm's, 50 spm, 210 gpm, 2,040 psi, off btm torque, 10,000 ft-Ibs, on btm 12,000 ft-Ibs, Rot wt 171 K, up wt 201 K, do wt 140 K, 9.6 ppg Flo Pro MW, ave ECD 11.15 ppg. Adding new 9.6 ppg Flo Pro to actives stem eve 700'. /21 /2008 Directionally drilled 6 1/8" hole with Geopilot from 14,395' to 15,980'. 00:00 12:00 12.00 14,395 15,368 PROD1 DRILL DDRL P Drilled 6 1/8" hole from 14,395' to 15,368' MD/ 7,017' ND (973') ADT 9.07 hrs, 10-13 K wob, 120 rpm's, 50 spm, 210 gpm, 2,170 psi, off btm torque, 11,000 ft-Ibs, on btm 13,500 ft-Ibs, Rot wt 172 K, up wt 205 K, do wt 135 K, 9.6 ppg Flo Pro MW, ave ECD 11.3 ppg. Adding new 9.6 ppg Flo Pro to actives stem eve 700'. ~ags~ ~ zit 1& 1 Time Logs Date From To Dur S De th E. De th Ph e Code Subcode T Comment 12:00 00:00 12.00 15,368 15,980 PROD1 DRILL DDRL P Drilled 6 1/8" hole from 15,368' to 15,980' MD/ 7,006' TVD (612') ADT 9.53 hrs, 8-12 K wob, 120 rpm's, 46 spm, 193 gpm, 1,970 psi, off btm torque, 11,000 ft-Ibs, on btm 12,000 ft-Ibs, Rot wt 171 K, up wt 205 K, do wt 130 K, 9.65 ppg Flo Pro MW, ave ECD 11.2 ppg. ROP slowed at 15,906' and began seeing 28 to 52 bph losses, (ROP improved by 15,960') pumped 30 bbl, 25 ppb LCM pill and began adding 1 sxs every 5 min. of Dyna red fiber to system and losses have slowed to 15 bph at report time. 140 bbls of mud lost to hole last 24 hrs. 4/22/2008 Drilled 6 1/8" hole from 15,980' to 16,292' when Geopilot failed, monitored well- breathing slightly but decreasing, backreamed out of hole from 16,292' to csg shoe, monitored well, very slight breathing, pumped out of hole 20 stds to 9,917', displaced hole over to 9.6 ppg brine, monitored well till static, POOH on elevators to 4,189' 00:00 05:30 5.50 15,980 16,292 PROD1 DRILL DDRL P Drilled 6 1/8" hole from 15,980' to 16,292' MD/ 7,005' TVD (312') ADT 4.23 hrs, 10-12 K wob, 120 rpm's, 47 spm, 200 gpm, 1,980 psi, off btm torque, 11,500 ft-Ibs, on btm 13,500 ft-Ibs, Rot wt 175 K, up wt 210 K, do wt 130 K, 9.6 ppg Flo Pro MW, ave ECD 11.15 ppg. Cont. adding 1 sxs of Dyna red fiber to system every 5 min and losses ave 13 boh. 157 bbls of mud lost to ho Geo ilot be an to see housin roll. 05:30 06:00 0.50 16,292 16,292 PROD1 DRILL OWFF T Monitored well 20 min while trouble shooting Geopilot, vYell breathing but flow decreasin ,determined Geopilot had failed. 06:00 07:00 1.00 16,292 16,292 PROD1 DRILL CIRC T Circ btms up at 200 gpm, 1,950 psi and 80 m's. 07:00 14:30 7.50 16,292 11,830 PROD1 DRILL REAM T Backreamed out of hole from 16,292' to 11,830' (csg shoe @ 11,874') BROOH at 50 rpm's, 190 gpm, ICP 1,730 si, FCP 1,500 si. 14:30 15:00 0.50 11,830 11,830 PROD1 DRILL OWFF T Blew down and monitored well, breathing and decreased to very sli ht flow. 15:00 17:30 2.50 11,830 9,917 PROD1 DRILL TRIP T Pumped out of hole 20 stds to 9,917', pumped out at 2.5 bpm. Calc fill to 9,917' 44 bbls, actual fill 111 bbls. 17:30 19:00 1.50 9,917 9,917 PROD1 DRILL CIRC T Displaced hole over from 9.6 ppg Flo Pro to 9.6 ppg brine, circ at 500 psi and 50 m's. 19:00 20:00 1.00 9,917 9,917 PROD1 DRILL OWFF T Monitored well till static. 20:00 00:00 4.00 9,917 4,189 PROD1 DRILL TRIP T POOH on elevators from 9,917' to 4,189', talc fill with brine 37 bbls, actual fill 42.5 bbls. Page 7 of 16 ~~ Time Logs _ D to From To Dur 5 Depth E. Depth Phase Code Subcode T Comment 4/23/2008 z4 hr summary Finished POOH, changed out BHA, RIH to 10,873. Displaced to 9.6 Flo Pro. RIH to 16,229'. Washed down to 16,292' Directionall drilled from 16,292' to 16,525' 00:00 01:15 1.25 4,189 376 PROD1 DRILL TRIP T POOH on TT from 4,189' to 376' Flow Check -well static 01:15 03:30 2.25 376 0 PROD1 DRILL PULD T SB HWDP, jars, & NMFC's. Download MWD - LD Stab, float sub, bit & GP. No oil in GP, bit had one broken cutter. Monitored hole on TT -losses of 1.5 BPH 03:30 06:30 3.00 0 376 PROD1 DRILL PULD T M/U B_ IiA # 2 replace bit, & upload MWD. Conduct shallow hole test ood 06:30 10:15 3.75 376 9,917 PROD1 DRILL TRIP T RIH from 376' to 9,917' 10:15 10:30 0.25 9,917 9,917 PROD1 RIGMNT SFTY T PJSM -cut and slip drill line o eration 10:30 12:00 1.50 9,917 9,917 PROD1 RIGMNT SVRG T Cut and slip 60' drill line & service TD 12:00 12:30 0.50 9,917 10,873 PROD1 DRILL TRIP T RIH from 9,917' to 10,873' 12:30 12:45 0.25 10,873 10,873 PROD1 DRILL SFTY T PJSM - Dis lace brine with Flo Pro 12:45 14:00 1.25 10,873 10,873 PROD1 DRILL CIRC T Displace brine with 9.6 PPG Flo Pro 210 GPM, 50 RPM, & 200 PSI 14:00 17:00 3.00 10,873 16,229 PROD1 DRILL TRIP T RIH from 10,873' to 16,229' 17:00 17:30 0.50 16,229 16,292 PROD1 DRILL REAM T Wash down from 16,229' to 16, 292' 200 GPM, 50 RPM, 2000 PSI 17:30 00:00 6.50 16,292 16,525 PROD1 DRILL DDRL P Drilled 6 1/8" hole from 16,292' to 16,525' MD/ 7,004' TVD (233') ADT 5.01 hrs, 9-12 K wob, 120 rpm's, 47 spm, 200 gpm, 1,990 psi, off btm torque, 11,500 ft-Ibs, on btm 13,000 ft-Ibs, Rot wt 172 K, up wt 210 K, do wt 128 K, 9.65 ppg Flo Pro MW, ave ECD 11.3 ppg. Ave 15-20 hnh , losses, lost 95 bbls las 1 4/24/2008 Directionally drilled from 16,525' to 17,742' 00:00 12:00 12.00 16,525 17,238 PROD1 DRILL DDRL P Drilled 6 1/8" hole from 16,525' to 17,238' MD/ 6990' TVD (713') ADT 10.02 hrs, 10/15 K wob, 120 rpm's, 47 spm, 200 gpm, 1980 psi, off btm torque, 12,000 ft-Ibs, on btm 14,000 ft-Ibs, Rot wt 176 K, up wt 215 K, do wt 126 K, 9.60 ppg Flo Pro MW, ave ECD 11.12 ppg. Ave 23 bnh losses. lost 275 bbls last 12 hrs. 12:00 00:00 12.00 17,238 17,742 PROD1 DRILL DRLG P Drilled 6 1/8" hole from 17,238' to 17,742' MD/ 6981' TVD (504'} ADT 10.46 hrs, 13/15 K wob, 120 rpm's, 47 spm, 200 gpm, 2060 psi, off btm torque, 12,500 ft-Ibs, on btm 14,000 ft-Ibs, Rot wt 174 K, up wt 215 K, do wt 118 K, 9.55 ppg Flo Pro MW, ave ECD 11.36 ppg. Ave 26 bph losses, lost 310 bbls last 12 hrs. 4/25/2008 Directionally drilled from 17,742' to 18,955' Page 8 caf 1& Time Logs D e From To Dur S. De th E. De th Ph Code Subcode T Comment 00:00 12:00 12.00 17,742 18,238 PROD1 DRILL DDRL P Drilled 6 1!8" hole from 17,742' to 18,238' MD/ 6996' TVD (496') ADT 9.83 hrs, 10/15 K wob, 120 rpm's, 47 spm, 200 gpm, 2050 psi, off btm torque, 12,500 ft-Ibs, on btm 15,500 ft-Ibs, Rot wt 175 K, up wt 223 K, do wt 113 K, 9.5 ppg Flo Pro MW, ave ECD 11.31 ppg. Average 25 bph losses lost 300 bbls in last 12 hrs. 12:00 00:00 12.00 18,238 18,955 PROD1 DRILL DDRL P Drilled 6 1/8" hole from 18,238' to 18,955' MD/ 6981' TVD (717) ADT 9.75 hrs, 12/14 K wob, 120 rpm's, 47 spm, 200 gpm, 2170 psi, off btm torque, 13,500 ft-Ibs, on btm 15,500 ft-Ibs, Rot wt 174 K, up wt 225 K, do wt 105 K, 9.6 ppg Flo Pro MW, ave ECD 11.5 ppg. Average 35 bph losses, lost 420 bbls in last 12 hrs. /26/2008 , Directionally drilled 6 1/8" hole from 18,955' to 19,482' TD. CBU, Back reamed out of hole from 19,482' to 11,829' cs shoe 11,874' 00:00 09:00 9.00 18,955 19,482 PROD1 DRILL DDRL P Drilled 6 1/8" hole from 18,955' to 19,482' MD 6925' TVD (527) ADT 7.69 hrs, 12 K wob, 120 rpm's, 47 spm, 200 gpm, 2220 psi, off btm torque, 14,000 ft-Ibs, on btm 15,500 ft-Ibs, Rot wt 170 K, up wt 220 K, do wt 105 K, 9.6 ppg Flo Pro MW, ave ECD 11.45 ppg. Well continuing to ~ breath on connections. 09:00 12:00 3.00 19,482 19,003 PROD1 DRILL REAM P Circulate btms up and back ream out slow from 19,482' to 19,003'. circ at 200 m, 2,000 si and 120 r m's 12:00 23:00 11.00 19,003 11,829 PROD1 DRILL REAM P Cont to back ream out of hole from 19,003' to 11,829'. BROOH at 126 m, 800 si and 120 m's. 23:00 00:00 1.00 11,829 11,829 PROD1 DRILL OWFF P Blew down TD and monitored well. Initial flow rate of 0.5 bpm and after 30 min rate slowed to .25 b m. 4/27/2008 Circ 2X BU @ 11,829', pumped out 20 stds to 9,917', monitored well, hole breathing at 20 bph, Shut in & performed exhale test, SICP 70 psi, bled off & press up to SICP of 70 psi, bled off. Pumped out to 8,101', well cont. to breath at 5 bph, RIH to 11,829', circ & raised MW to 10.0 ppg & well still breathing, raised MW to 10.3 ppg. Shut in &SICP press to 44 psi & bled do to 5 psi, opened well-static, POOH on trip tank to 10,586' didn't take ro er fill, um in out at 10,395' 00:00 02:15 2.25 11,829 11,829 PROD1 DRILL CIRC P Circ 2 X btms up @ 11,829' -Monitor well -well breathin 02:15 05:00 2.75 11,829 9,917 PROD1 DRILL TRIP P Continue POOH w/ pump f/ 11,829' to 9917' - 1.5 bbls/min w/380 si 05:00 07:30 2.50 9,917 9,917 PROD1 DRILL OWFF T Monitor well -well breathing @ 20 bbls / h -Inspect & grease TD while monitorn well ..Pane 9 of 1S • w Time Lo~c s Date From To Dur S De th E. De th Ph Code Subcode T Comment 07:30 10:00 2.50 9,917 9,917 PROD1 DRILL OWFF T RU & perfornm exhale test -SIDPP 15 psi SICP 70 psi -Bleed through choke for 5 mins - 1!2 bbls returns - Shut in -SIDPP 15 psi SICP 70 psi -Bleed off & RD -Blow down choke & kill lines -monitor well well breathin 8 bbls/hr 10:00 12:45 2.75 9,917 8,101 PROD1 DRILL TRIP P y POOH w/pump @ 1.5 bbls/min @ 300 si - f/ 9917' to 8101' 12:45 13:15 0.50 8,101 8,101 PROD1 DRILL OWFF T Monitor well -breathing @ 5 bbls/ hr. 13:15 15:00 1.75 8,101 11,829 PROD1 DRILL TRIP T RIH f/ 8101' to 11,829' 15:00 17:00 2.00 11,829 11,829 PROD1 DRILL CIRC T Circ & bump mud wt. f/ 9.6 ppg to 10.0 ppg, circ at 190 gp, 1,550 psi and 50 rpm's, with 10.0 ppg around had as breakin out at surface. 17:00 17:30 0.50 11,829 11,829 PROD1 DRILL OWFF T Monitored well and well still breathin . 17:30 20:00 2.50 11,829 11,829 PROD1 DRILL CIRC T Circ & bump mud wt. f/ 10.0 ppg to 10.3 ppg, circ at 190 gp, 1,550 psi and 50 m's. 20:00 21:30 1.50 11,829 11,829 PROD1 DRILL OWFF T Shut in well to monitor, SICP up to 44 psi in 14 min, bled down to 5 psi in 1 hr, o ened well-static 21:30 23:30 2.00 11,829 10,586 PROD1 DRILL TRIP T POOH on trip tank from 11,829' to 10,856' and hole was not taking ro er fill. 23:30 00:00 0.50 10,586 10,395 PROD1 DRILL TRIP T Pumped out of hole from 10,586' to 10,395', pumped out at 1.5 bpm 300 si. 4/28/2008 Cont to pump out to 8,674', monitored well, breathing slightly, shut in 30 min & had 0 psi, opened up & well was static, attempted to POOH & well swabbing, pumped out to 4,665', monitored well, still slight flow. Circulate well to equalize mud weight. Well static after 15 minutes after circulation. POOH & LD BHA #2. Test BOP's 250/3500 si Chuck Scheve with AOGCC waived witnessin of test . RU to run liner. 00:00 02:45 2.75 10,395 8,674 PROD1 DRILL TRIP P Continue POOH f/ 10,395' to 8674' w/ pump @ 1.5 bbls/min @ 280 psi - Blowdown TD -Flow check -slight flow 02:45 04:00 1.25 8,674 8,674 PROD1 DRILL OTHR T Shut in well -monitor pressure - Csg pressure 0 psi -Open well -flow the - stati i 04:00 09:45 5.75 8,674 4,665 PROD1 DRILL TRIP Continue POOH f/ 8674' to 4665' w/ pump @ 1.5 bbls/min @ 210 psi - Blow down TD -Flow check -slight flow. 09:45 11:15 1.50 4,665 4,665 PROD1 DRILL CIRC P Circ btms up plus to equalize mud wt. @ 10.3 ppg in & out - 2.5 bbls / min @ 450 psi w/ 60 rpm's -Flow check -static in 15 mins. 11:15 15:45 4.50 4,665 376 PROD1 DRILL TRIP P POOH on TT f/ 4665' to 376' -top of HWDP -retrieve drift -flow ck -static - Stand back HWDP & 'ars. 15:45 17:30 1.75 376 0 PROD1 DRILL PULD P Stand back non-magnetic flex collars. Plug into Geo-Pilot service loo La down BHA. 17:30 18:00 0.50 0 0 PROD1 DRILL PULD P Retrieve wear bushing. F'az~~ 'i 0 cf 16 i i Time Logs Date From To Dur S De th E. De th Phase Code Subcode T Comment 18:00 22:45 4.75 0 0 PROD1 WELCTI BOPE P Tested pipe rams 250/3500 psi to 3.5", 4"and 4.5' .Tested blind rams , choke, kill, manifold and surface safety valves to 250/3500 psi -tested annular preventor 250!2500 psi -blow down choke and kill lines -Chuck Sheve waived witnessin tests. 22:45 23:15 0.50 0 0 PROD1 DRILL PULD P Install wear bushing. Blow down choke and kill lines. 23:15 00:00 0.75 0 0 PROD1 CASING RURD P Rig up power ton sand liner runnin e ui ment. /29/2008 MU& run 4 1/2"/ 3 1/2" combo liner w/ componets - RIH w/ liner on 4" DP to 19,482' _ PU to 19,472' & set liner hanger & open hole packer -Set ZXP packer & test to 1000 psi for 30 mins -Pull up to 11,029' & Circ btms u 00:00 00:15 0.25 0 0 PROD1 CASING SFTY P Held Pre-job Safety and Opts meetin with crew 00:15 05:00 4.75 0 6,532 COMPZ CASING PUTS P MU guide shoe on 41/2" 12.6#, L-80, IBTM Liner -RIH picking up , liner with a perf nipple every six joints to 6,532' 149'ts & 24 erf u s 05:00 05:15 0.25 6,532 6,532 COMPZ CASING RURD P Change running tools to 3 1/2" 05:15 09:30 4.25 6,532 8,353 COMPZ CASING PUTB P Continue to RIH with 3 1/2" Completion components as follows: All tbg 9.3# L-80 EUE 8 rd mod.- XO pup 3 1/2 EUE to 4 1/2"IBTM w/ ball catcher/shear out sub - 2 jts tbg - Tam free Cap w/ pup jts - 1 jt tbg - Baker o en hole acker w/pup jts. - 1 jt tbg -TAM Free Cap w/pup jts - 12 jts tbg -Baker Drillable ball drop sliding sleeve w/ pup jts. - 34 jts tbg - Baker CMD sliding sleeve w/ X profile w/ pup jts.- 1 jt tbg - XO 3 1/2" EUE to 4 1/2"IBTM - 1 jt 4 1/2" 12.6# IBTM tbg - MU Baker flex lock han er assembly w/ ZXP_ liner too _ total liner lenthg 8349.83') - Fill tie back with Pall mix and let set for 30 minutes 09:30 20:00 10.50 8,353 19,482 COMPZ CASING RUNL P RIH with liner on 4"drill pipe to 11,216' (1 std.) Pump thru liner hanger to ensure flow path clear - Continue RIH w/ liner f/ 11,216' to 19482' (tag btm) Note' Had to work liner down f/ - 18 854' to btm -Hole an le 19,252' - 97.28 & 96.7 19,482' laar~e 11 of 4fi Time Logs Date From To Dur S. De th E. De th Phase Code Su code T Comment 20:00 22:00 2.00 19,482 19,472 COMPZ CASING CIRC P Set liner setting depth 19, 472' _ (10' off btm) Drop setting ball & pump down @ 3 bbls/min to ball seat - pressure up to 3300 psi to set open hole packer & liner hanger -bleed off pressure & slack off 60 k ensure hanger set - PU to check liner hanger set -Pressure up to shear ball -sheared @ 3600 psi - PU to release setting dogs for ZXP -set down w/ 40 k to set ZXP acker observed shear - PU & Set back down w/ 40 k (2 more times to ensure packer set) -Pressure up on 5" DP annulus to test ZXP packer to 1000 psi pressure bled down to 470 si in 30 mis -sus ect perfs in Kup C to be leakin 22:00 00:00 2.00 19,472 11,029 COMPZ DRILL TRIP P Pull out & std back 2 stds DP to clear running tool f/ liner top (11029') - Circ btms up @ 4 bbls/min @ 710 si 4/30/2008 Finish circ btms up -monitor well -static in 20 mins -change over to 10.1ppg brine monitor well static in 1hr 15 mins -POOH on TT to 2917' - C&S drill line -Finish POOH (hole took proper fill) LD liner setting tool - RU slick line & set XX plug in CMD SS@ 12,246' - Test to 1000 psi bled down to 200 psi in 15 mins -RIH & set junk catcher top of XX plug - RD SL -Prep to run packer to confirm breakdown of orginal perts in Kup C or ZXP acker / XX lu 00:00 03:45 3.75 11,029 11,029 COMPZ RPCOM CIRC P Observed well breathing after CBU - monitorwell, static in 25 minutes - Displace 10.3 ppg FloPro mud with with 10.1 ppg Brine 4 bpm /640 psi - Observed well breathing -monitor well, static in 1 hr & 15 mins 03:45 08:15 4.50 11,029 2,917 COMPZ DRILL TRIP P POOH from 11,029' to 2,917' -hole takin ro er fill 08:15 09:45 1.50 2,917 2,917 COMPZ RIGMNT SVRG P PJSM -Slip and cut drilling line - Service top drive and drawworks Monitor well, observed static losses at-5b h 09:45 12:00 2.25 2,917 0 COMPZ DRILL TRIP P POOH from 2917' -service break and LD Baker runnin tools 12:00 18:30 6.50 0 0 COMPZ RPCOM SLKL P PJSM - RU Halliburton slickline -RIH with 2.831 XX plug w/ fill extension - appeared to be chasing debris from 5407' to 5553' - POOH w/ plug - RU and RIH with 2.5" bailer and wire brush to 11,250' -POOH and LD Bailer - RU and RIH with 2.831" XX plug -set DILg,jp X ~ofile in ton CrL~ slidin ' -POOH - RD slick line. Not lu wa Page 12 of 'l E ~ ~ ~ Time Logs Date From To Dur 5. De th E. De th Phase Code Subcode T Comment 18:30 19:00 0.50 0 0 COMPZ RPCOM OTHR P RU & attem t to test XX lu to 1000 psi -bled off to 200 psi in 15 mins -~ similar to the attempt to test ZXP packer -Will run packer to confirm perfs leaking or XX plug & ZXP ac er - RD 19:00 21:15 2.25 0 0 COMPZ RPCOM SLKL RU slick line - ARIH & set junkcatcher on top of XX plug - POOH & RD slick line 21:15 00:00 2.75 0 0 COMPZ RPCOM OTHR T Service & clean rig while waiting on packer Monitor well on TT - No losses & No sin 5/01 /2008 RIH w/ packer & set @ 11,015' -Fill pipe -Pressure up DP to 1000 psi -test ZXP packer & XX plug on liner for 25 mins Good test -Pressure annulus to 1000 psi -bled off to 300 psi in 6 mins.- assume old perfs breaking down -displace DP f/ 10.1 ppg to 8.7 ppg brine & perform negivite test on ZXP packer & XX plug - Observed flow f/ DP @ 4.5 gals/hr slowing to 2.25 gals/hr in 45 mins -Finish displacing well to 8.7 ppg brine - Observed some gas break out - circ additional 80 bbls -Flow ck DP static -slight flow f/annulus 135 gph to 18 gph in 60 mins. -POOH on TT to 10,030' proper fill -flow ck -slight flow 20 gph to 16 gph in 20 mins - Perform exhale test FCP 100 psi FDPP 45 psi -Bled off - Circ btms up observed approz. 9 bbls 9.1 ppg mud & gas break @ btms up -Set packer monitor DP & annulus -Annulus static -flow f/DP 2 12,5 gph slowing to 8 h in 2 hrs. -release acker & re to dis lace well f/ 8.7 to 10.1 brine 00:00 07:00 7.00 0 11,015 COMPZ RPCOM OTHR T PJSM - MU Baker 7" EA Retrieve-a-matic packer - RIH w/ 4" drill i e to 11,015' 07:00 08:15 1.25 11,015 11,015 COMPZ RPCOM DHEQ T Fill pipe and establish circulation - set packer -anchor with 30K SOW @ 11,015' -blow down top drive - RU & test ZXP Liner to acker and XX plug to 1000 psi for 25 minutes wit no bleed off. 08:15 08:45 0.50 11,015 11,015 COMPZ RPCOM DHEQ Bleed off drill pipe - RU and test 7" x 4"annulus above sacker to 1000 e off - assume leak off old erferations 08:45 10:45 2.00 11,015 11,015 COMPZ RPCOM DHEO T MU top drive - PU to string wt. to open bypass on packer -Displace drill pipe with 120 bbls of 8.65 ppg KCL brine 3 bpm / 650 psi FCP - slack off to close bypass -bled off 460 psi from drill pipe -shut in and monitor pressure for 5 minutes -zero - break off top drive and visually monitor returns up drill pipe for 45 minutes -slight amount of returns - intial volume at 4.5 gal/hr -final at 2.25 al/hr 10:45 13:30 2.75 11,015 11,015 COMPZ RPCOM CIRC T Pick up to string wt. to open Packer bypass -displace annulus to 8.65 brine @ 3 bpm FCP 230 psi - 350 bbls pumped -monitor well, observed as breakin ou - continued to circulate an additional 80 bbls -age 13 oaf 'S 6 Time Logs _ _ _ _ Date From To Dur S. De th E. Depth Phase Code Subcode T Comment 13:30 14:45 1.25 11,015 10,983 COMPZ RPCOM OWFF T LD 1 joint of drill pipe -Blow down top drive -Monitor well -drill pipe static - returns from annulus dropped from 35 h to 18 h in 60 minutes - 14:45 16:15 1.50 10,983 10,030 COMPZ RPCOM TRIP P POOH on TT from 10,983' to 10,030' - hole took ro er fill 16:15 17:00 0.75 10,030 10,030 COMPZ RPCOM OWFF T Flow check well -continued to observe slight flow from annulus - returns decreased from 20 gph to 16 h last 30 minutes 17:00 19:00 2.00 10,030 10,030 COMPZ RPCOM OWFF T RU & perform exhale test - FCP - __ 100 psi FDPP - 45 psi -Bled off annulus in 8 mins to 0 psi w/ 17 gals brine recovered - DP went to 0 si 19:00 19:30 0.50 10,030 11,015 COMPZ RPCOM TRIP T RIH f/ 10,030' to 11,015' 19:30 21:15 1.75 11,015 11,015 COMPZ RPCOM CIRC T Circ btms up @ 3 bbls/min @ 230 psi -Observed approx. 9 bbls 9.1 ppg mud & slight gas break out @ talc. btms up strokes -returned to 8.7 brine 21:15 00:00 2.75 11,015 11,015 COMPZ RPCOM OWFF T Set packer to isolate Kup C & liner to ~-Monitor DP for liner & annulus for Kup C -Annulus static -Observed flow f/ DP @ 12.5 gals/hr -rate slowed to 8 gals/hr in 2 hrs. - Released packer -Prep to displace well to 10.1 brine 5/02/2008 Displace well f/ 8.7 to 10.1 ppg brine -Flow ck (static) RIH & tag liner top @ 11,125' (DP measurement) POOH w/ Baker packer - LD packer -Flow ck (static) - RU to run 3 1/2" completion -PJSM -Run 3 1/2" tom letion to 9559' 00:00 03:00 3.00 11,015 11,015 COMPZ RPCOM CIRC T Displace well f/ 8.7 ppg to 10.1 ppg brine @ 3 BMP @ 250 psi -Flow ck static 03:00 03:30 0.50 11,015 11,125 COMPZ RPCOM TRIP T RIH & tag top of liner @ 11,125' 03:30 11:30 8.00 11,125 0 COMPZ RPCOM TRIP T POOH on TT f/ 11,125' -J_D Baker - Flow ck static 11:30 12:00 0.50 0 0 COMPZ RPCOM OTHR P Pull wear bushing -Install tbg runnin wear bushin 12:00 12:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM w/ crew on running completion 12:15 21:45 9.50 0 8,931 COMPZ RPCOM RCST P RU r 1/2" completion -All tbg & pups 3 1/2" 9.3# L-80 EUE 8RD - Run as follows: Baker Shear indicating WLEG assembly - 1 jt tbg - HES X nipple w/ RHC plug - 1 jt tbg - Baker Premier packer w/ pup jts - Baker CMD sliding sleeve w/ pup jts - 2 jts tbg -Camco GLM w/dummy & pup jts - 1 jt tbg -Baker Premier packer w/ pup jts - HES X nipple - Camco GLM w/shear valve & pup jts - 62 jts tbg -Camco GLM w/dummy & pup jts. -130 jt tbg -Camco GLM w/dummy & pup jts. - 82 jts tbg- to 8931' Page 14 taf 1 & • l ~ ~ Time Logs Date From To Dur S. D th E. D th Phase Coe Subco e T Comment 21:45 22:45 1.00 8,931 8,931 COMPZ RPCOM OTHR P PU SSSV -Set up control line spool - Connect control line to SSSV & test line to 6500 si for 10 mins 22:45 00:00 1.25 8,931 9,559 COMPZ RPCOM RCST P Continue running 3 1/2" completion f/ 8931' to 9559' - 15 js -banding control line to tb 5/03/2008 Finish running 31/2" completion f/ 9959' to 11,025' - MU XO & run 4" DP in space out tbg -Tag liner top @ 11,125' -observed brass shear on locator -Std back DP - MU space out pup & PU 4 1/2" tbg -Retrieve tbg running wear bushing - MU tbg hanger & Terminate control line through hanger -test connection -Land tbg w/ tail @ 11,153' -Test hanger seals to 5000 psi - ND BOPE -terminate control line through well head - NU & test tree -Spot 20 bbls 10.1 ppg inhibited brine to above top packer -Drop packer setting rod/ball -Pressure upon tbg & set packers -Test tbg to 3500 psi for 30 mins.OK -Bleed down tbg to 2200 psi & pressure up 3 1/2' x 7" annulus & test to 3500 psi for 30 mins OK -bleed off annulus & tbg -Pressure up annulus to 2911 psi & shear out DCK valve in GLM @ 10,772' -Displace 10.1 ppg brine w/ 8.7 ppg inhibited brine 232 bbls (annular vol - 2000') -followed by 146 bbls diesel (tbg vol + 2000' in annulus) for freeze protect -Shut well - blow down lines - RD & set BPV - Be in to LD 4" D f/derrick for ri move 00:00 02:15 2.25 9,559 11,014 COMPZ RPCOM RCST P Continue running 3 1/2" completion f/ 9559' to 11014' - 52 js -banding control line to tb 02:15 03:30 1.25 11,014 11,058 COMPZ RPCOM HOSO P XO to 4" drill pipe and RIH - observed locator pins shear with 10 K SOW - tagge top o mer -stand back 2 stands of drill pipe - MU 3 1/2" pup (4.12') - 3 1/2" EUE (P) x 4 1/2" IBTM (B) XO -and one jt of 4 1 /2" 12.6#, L-80 tb 03:30 04:45 1.25 11,058 11,058 COMPZ RPCOM OTHR P MU wear bushing retrieving tool and LJb -retrieve wear bushing - LD wear bushin LJb and tool 04:45 06:15 1.50 11,058 11,153 COMPZ RPCOM RCST P MU 2nd joint of 4 1/2" tubing & FMC tubing hanger -strip control line through hanger -test control line / hanger fittings to 6500 psi for 10 minutes -Land hanger in wellhead with WLEG @ 11,153' - X nipple w/ RHC plug @ 11079' - Btm Baker , acker 110 - CMD SS @ 11008' -GLM W/dummy @ 10919' - To Baker acker '-X nipple @ 10820' -GLM w/Shear valve @ 10772' -GLM w/dummy @ 8826' -GLM w/dummy @ 4772' - Camco TRAMAXX-5E SSSV 2209' 06:15 08:00 1.75 11,153 0 COMPZ RPCOM DHEO P RILDS - LD LJa -install TWC -rig up and test M/M hanger seals to 5000 si - 08:00 09:15 1.25 0 0 COMPZ RPCOM NUND P ND Flowline, Riser and BOP stack 09:15 11:00 1.75 0 0 COMPZ RPCOM NUND P Terminate SSSV control line through wellhead -install adaptor flange and Tree 11:00 11:30 0.50 0 0 COMPZ RPCOM DHEO P Test adaptor flange to 5000 psi for 10 minutes -Pressure up TRMAXX-5E SSSV to 6200 si 11:30 12:00 0.50 0 0 COMPZ RPCOM DHEQ P RU and test tree to 5000 psi for 10 minutes .'~cJe 55 of 1fi l J l Time Logs _ Date From To Dur S De th E. De th Ph Code Subcode T Comment 12:00 13:00 1.00 0 0 COMPZ RPCOM PULD P Pull TWC -Rig up hardlines and circulatin manifold 13:00 14:00 1.00 0 0 COMPZ RPCOM CIRC N Test lines to 2500 psi -Attempt to break circulation with 1000 psi, unable -double check all surface e ui ment - OK. 14:00 15:30 1.50 0 0 COMPZ RPCOM CIRC P Establish circulation with 10.1 ppg brine @ 1200 psi -initial rate 1.1 bpm / 940 psi -rate /pressure improved to 2.0 bpm / 970 psi - Pumped 20 bbls of corrosion inhibited 10.1 ppg brine and displaced with 92 bbls of 10.1 ppg brine ave rate 1.8 bpm / 1050 psi Packer be ins to set at 1500 si 15:30 16:00 0.50 0 0 COMPZ RPCOM PACK P RU Do on lubricator and drop ball / rod - RD lubricator- RU hard lines 16:00 17:15 1.25 0 0 COMPZ RPCOM PACK P Test lines to 4000 psi -Set packer with 3700 psi -Test tubing for 30 minutes FP = 3670 psi -Bleed down.. tubing to 2200 psi -Pressure up 7" x _ 3 1/2" annulus to 3560 psi -bled to 3520 psi in 30 minutes -bleed off annulus & tubing -pressure up ~ annulus - DCK-2 valve sheared @ 2911 si 17:15 17:30 0.25 0 0 COMPZ RPCOM CIRC P Establish circ through shear valve @ 10772' -Pump 50 bbls 8.7 ppg brine 36PM 15500 si 17:30 19:15 1.75 0 0 COMPZ RPCOM CIRC P Switch over to Dowell -Pumped 232 bbls 8.7 ppg inhibited brine followed by 146 bbls diesel (tbg vol + 2000' annular cap) @ 3.7 BPM @ 1995 to 2200 si -Shut down & shut in well 19:15 21:00 1.75 0 0 COMPZ RPCOM OTHR P Blow down hard lines & RD hard line - RU FMC lubricator & set BPV - RD lubricator -Install gauges on tree & wellhead -Remove outside annular valve -secure well 21:00 00:00 3.00 0 0 COMPZ RPCOM PULD P Set mouse hole - RU & LD 4" DP f/ derrick for ri move 5/04/2008 LD 4" DP from derrick for rig move -Release rig @ 15:30 hrs 00:00 15:30 15.50 0 0 COMPZ RPCOM PULD P LD 4" DP f/derrick for rig move Release ri 15:30 hrs P~~ 16 ~at'i6 ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad CD3-107L1 50-103-20529-60 _..,,. 7 ., ~ r ..~~ Definitive Survey Report 22 May, 2008 ~ ; ~ Mµ. = .s:.. Sperry '.Drilling Services • • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well CD3-107 Project: Westem North Slope TVD Reference: CD3-107L1 @ 49.61ft (Doyon 19 (13.2+36.41)) Site: CD3 Fiord Pad MD Reference: CD3-107L1 @ 49.61ft(Doyon 19 (13.2+36.41)) WeIC CD3-107 North Reference: True Wellbore: CD3-107L1 Survey Calculation Method: Minimum Curvature Design: CD3-107L1 Database: CPAI EDM Production -r Project Westem North Slope, North Slope Alaska 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 _ _ CD3107 __ __ __ Well Position +N/-S 0.00 ft Northing: 6,003,847.17 ft Latitude: 70° 25' 10.055 N +EI-W 0.00 ft Easting: 388,247.02 ft Longitude: 150° 54' 37.443 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.20ft Wellbore ~D' 1071 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2007 4/11/2008 17.1'1 75.66 57,242 ~ BGGM2007 4/17/2008 17.10 79.66 57,243 Design CD3-107L1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,973.00 Vertical Section: Depth From (TVD) +N!-S +E!-W Direction (ft) (ftl Itt) (°) 3b.41 0 00 0 .00 324.00 Survey Program Date From To (ft) (tt) Survey (Wellbore) Tool Name Description Survey Date 80.06 438.16 CD3-307 gyro (CD3-307) CB-GYRaSS Camera based gyro single shot 4/22/2000 12: 475.18 3,057.46 CD3-307 (CD3-307) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/22/2006 12: 3,098.21 12,973.00 CD3-107 (CD3-107) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/24/2007 12: 13,035.38. 19,441 .47 CD3-107L1 TD (CD3-107L1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4/21/2008 12: i Survey Map Map Vertical MD Inc Azl TVD T VDSS +N/-S +E/-W Northing Easting DLS Section (ft) (') (°) (ft) (tt) (ft) (tt) (ft) (ft) (°1100') (ft) Survey Tool Name 30.41 U.uu u.uu 3b.41 -13.lii il.liu u.uu b,uv3,tld7.17 ~00,247.U2 u.uJ U.uJ UNDEFINED 80.06 0.60 105.00 80.06 30.45 -0.O6 0.22 6,003,847.11 388,247.24 1.37 -0.18 CB-GYRO-SS (1) 166.06 0.65 118.00 166.05 116.44 -0.40 1.09 6,003,846.75 388,248.10 0.17 -0.97 CB-GYROSS (1) 258.06 0.80 139.00 258.05 208.44 -1.13 1.97 6,003,846.01 388,248.97 0.33 -2.07 CB-GYRO-SS (1) 348.06 1.30 120.00 348.03 298.42 -2.12 3.26 6,003,845.00 388,250.25 0.67 -3.63 CB-GYRO-SS (1) 438.06 1.75 109.00 438.00 388.39 -3.08 5.45 6,003,844.01 388,252.42 0.59 -5.69 CB-GYRO-SS (1) I 475.18 1.82 103.04 475.10 425.49 -3.39 6.56 6,003,843.68 388,253.52 0.53 -6.60 MWD+IFR-AK-CAZ-SC (2) 564.82 3.24 99.39 564.65 515.04 -4.13 10.44 6,003,842.88 368,257.40 1.59 -9.48 MWD+IFR-AK-CAZ-SC (2) 656.90 5.80 104.30 656.44 606.83 -5.70 17.52 6,003,841.20 388,264.45 2.81 -14.91 MWD+IFR-AK-CAZ-SC (2) 746.78 7.18 105.72 745.74 696.13 -8.35 27.33 6,003,838.41 388,274.22 1.55 -22.82 MWD+IFR-AK-CAZ-SC (2) 5/222008 9:11:34AM Page 2 COMPASS 2003.16 Build 42F ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well CD3-107 Project: Western North Slope ND Reference: CD3-10711 @ 49.61ft (Doyon 19 (13.2+36.41)) Site: CD3 Fiord Pad MD Reference: CD3-107L1 @ 49.61ft (Doyon 19 (13.2+36.41)) Well: CD3-107 North Reference: True Wellbore: CD3-107L1 Survey Calculation Method: Minimum Curvature Design: CD3-107L1 Database: CPAI EDM Production Survey MD Inc Axi TVD TVDSS +N/-S +E/-W (ft) (°) (°) lft) (ft) Itt) (ft) ts35.55 b.i/6 ti13.Bb x34.71 it35.~I1 -1 1.57 3y.b1 931.93 10.61 93.69 928.59 878.98 -13.93 55.64 1,027.76 12.77 90.94 1,022.45 972.84 -14.67 75.04 1,123.07 17.26 87.60 1,114.46 1,064.85 -14.26 99.71 1,216.63 20.95 83.21 1,202.86 1,153.25 -t 1.70 130.20 1,311.68 23.33 82.25 1,290.89 1,241.28 -7.15 165.73 1,406.89 29.03 77.18 1,376.31 1,326.70 0.53 206.97 1,502.56 34.77 74.48 1,457.50 1,407.89 12.99 255.94 1,597.50 36.98 74.21 1,534.43 1,484.82 28.00 309.50 1,693.26 38.65 74.12 1,610.07 1,560.46 44.03 365.99 1,788.35 38.86 75.22 1,684.23 1,634.62 59.76 423.39 1,863.78 39.38 74.20 1,758.27 1,708.66 75.64 481.47 1,979.29 40.01 72.87 1,831.76 1,782.15 92.93 539.97 2,074.84 43.25 68.37 1,903.18 1,853.57 114.06 599.78 2,170.10 44.40 68.74 1,971.91 1,922.30 138.17 661.17 2,265.17 49.04 68.61 2,037.07 1,987.46 163.34 725.63 2,360.04 51.97 68.13 2,097.40 2,047.79 190.33 793.67 2,455.19 54.76 67.21 2,154.17 2,104.56 219.34 864.29 2,549.64 56.39 66.83 2,207.57 2,157.96 249.76 936.01 2,644.68 59.07 68.24 2,258.31 2,208.70 280.45 1,010.27 2,739.97 60.50 69.58 2,306.26 2,256.65 310.07 1,087.09 2,834.29 61.70 71.75 2,351.85 2,302.24 337.40 1,165.01 2,928.15 59.93 69.99 2,397.62 2,348.01 364.24 1,242.42 3,023.51 60.59 66.65 2,444.93 2,395.32 394.63 1,319.34 3,057.31 60.61 66.32 2,461.52 2,411.91 406.58 1,346.34 3,098.21 60.81 65.72 2,481.53 2,431.92 421.08 1,378.94 3,148.13 57.19 62.88 2,507.24 2,457.63 439.61 1,417.49 3,243.37 55.09 60.50 2,560.31 2,510.70 477.09 7,487.12 3,338.54 54.42 58.04 2,615.24 2,565.63 516.80 1,553.92 3,433.80 53.38 58.19 2,671.36 2,621.75 557.45 1,619.28 3,528.71 53.97 59.66 2,727.59 2,677.98 596.92 1,684.77 3,623.96 55.79 63.41 2,782.39 2,732.78 634.01 1,753.25 3,719.30 56.00 65.58 2,835.86 2,786.25 668.00 1,824.49 3,814.30 56.61 67.58 2,888.56 2,838.95 699.41 1,897.02 3,909.22 56.89 69.19 2,940.61 2,891.00 728.65 1,970.61 4,005.49 56.21 68.55 2,993.67 2,944.06 757.60 2,045.73 4,100.62 57.40 68.92 3,045.76 2,996.15 786.47 2,119.92 4,195.59 56.78 66.43 3,097.36 3,047.75 815.46 2,194.19 4,291.61 57.45 68.03 3,149.49 3,099.88 845.37 2,269.07 4,386.71 56.81 67.43 3,201.10 3,151.49 875.64 2,342.99 Map Map Northing Easting DLS (ft) (ft) (°/100') 5,003,835.01 352i,[5o.44 2.11 6,003,832.41 388,302.44 2.44 6,003,831.37 388,321.83 2.33 6,003,831.42 388,346.49 4.80 6,003,833.53 388,377.02 4.23 6,003,837.54 388,412.60 2.53 6,003,844.60 388,453.96 6.43 6,003,856.32 388,503.10 6.18 6,003,670.53 388,556.88 2.33 6,003,885.71 388,613.59 1.74 6,003,900.58 388,671.22 0.76 6,003,915.59 388,729.52 0.87 6,003,932.00 388,788.27 1.11 6,003,952.23 388,848.38 4.61 6,003,975.42 388,910.13 1.24 6,003,999.61 388,974.95 4.88 6,004,025.58 389,043.38 3.11 6,004,053.53 389,114.42 3.03 6,004,082.87 389,186.58 1.76 6,004,112.44 389,261.28 3.09 6,004,140.91 389,338.54 1.93 6,004,167.06 389,416.84 2.38 6,004,192.74 389,494.64 2.50 6,004,222.17 389,572.01 3.12 6,004,233.51 389,599.18 0.85 6,004,247.52 389,631.98 1.37 6,004,265.47 389,670.81 8.74 6,004,301.90 389,740.98 3.03 6,004,340.60 389,808.37 2.23 6,004,380.27 389,874.32 1.10 6,004,418.75 389,940.38 1.39 6, 004, 454.81 390 , 009.41 3.74 6,004,487.72 390,081.15 1.90 6,004,518.04 390,154.13 1.87 6,004,546.17 390,228.34 1.45 6,004,574.00 390,303.69 0.90 6,004,601.75 390,378.29 1.29 6,004,629.62 390,452.98 0.78 6,004,658.40 390,528.29 0.78 6,004,687.56 390,602.65 0.86 Vertical Section (it) Survey Tool Name -32.04 MWD+IFR-AK-CAZ-Sl, ~2~ -43.98 MWD+IFR-AK-CAZ-SC (2) -55.98 MWD+IFR-AK-CAZ-SC (2) -70.14 MWD+IFR-AK-CAZSC (2) -85.99 MWD+IFR-AK-CAZ-SC (2) -103.20 MWD+IFR-AK-CAZ-SC (2) -121.23 MWD+IFR-AK-CAZ-SC (2) -139.93 MWD+IFR-AK-CAZ-SC (2) -159.27 MWD+IFR-AK-CAZ-SC (2) -179.50 MWD+IFR-AK-CAZ-SC (2) -200.52 MWD+IFR-AK-CAZ-SC (2) -221.81 MWD+IFR-AK-CAZ-SC (2) -242.20 MWD+IFR-AK-CAZ-SC (2) -260.27 MWD+IFR-AK-CAZ-SC (2) -276.84 MWD+IFR-AK-CAZ-SC (2) -294.37 MWD+IFR-AK-CAZ-SC (2) -312.53 MWD+IFR-AK-CAZ-SC (2) -330.56 MWD+IFR-AK-CAZ-SC (2) -348.11 MWD+IFR-AK-CAZ-SC (2) -366.93 MWD+IFR-AK-CAZ-SC (2) -388.12 MWD+IFR-AK-CAZ-SC (2) -411.81 MWD+IFR-AK-CAZ-SC (2) -435.60 MWD+IFR-AK-CAZ-SC (2) -456.07 MWD+IFR-AK-CAZ-SC (2) -462.43 MWD+IFR-AK-CAZ-SC (2) -469.86 MWD+IFR-AK-CAZ-SC (3) -477.53 MWD+IFR-AK-CAZ-SC (3) -468.13 MWD+IFR-AK-CAZ-SC (3) -495.27 MWD+IFR-AK-CAZ-SC (3) -500.80 MWD+IFR-AK-CAZSC (3) -507.37 MWD+IFR-AK-CAZ-SC (3) -517.61 MWD+IFR-AK-CAZ-SC (3) 531.99 MWD+IFR-AK-CAZ-SC (3) -549.20 MWD+IFR-AK-CAZ-SC (3) -568.93 MWD+IFR-AK-CAZ-SC (3) -589.54 MWD+IFR-AK-CAZ-SC (3) -609.79 MWD+IFR-AK-CAZ-SC (3) E29.99 MWD+IFR-AK-CAZ-SC (3) -649.81 MWD+IFR-AK-CAZ-SC (3) -668.77 MWD+IFR-AK-CAZ-SC (3) 5/222008 9: J 1:34AM Page 3 COMPASS 2003.16 Build 42F • Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fiord Pad Well: CD3-107 Wellbore: CD3-107L1 Design: CD3-107L1 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reterence~ Well CD3-107 TVD Reference: CD3-107L1 @ 49.61ft (Doyon 19 (13.2+36.41)) MD Reference: CD3-107L1 @ 49.61ft (Doyon 19 (13.2+36.41)) North Reference: True Survey Calculation Method: Minimum Curvature Database: CPAI EDM Production Map MD Inc Azl TVD TVDSS +N/-S +Ef-W Northing (n) 1°) (°) Ift) lh) Ift) (ft) (ft) 4,48.27 8.35 67.81 3,253.(u1 J,2G9.43 5Cti.18 2,417.io 6,004,716.98 4,577.27 56.67 67.46 3,304.76 3,255.15 936.50 2,490.85 6,004,746.19 4,672.42 57.10 67.23 3,356.75 3,307.14 967.19 2,564.40 6,004,775.78 4,766.98 57.39 66.67 3,407.91 3,358.30 998.33 2,637.57 6,004,805.82 4,862.66 57.16 66.77 3,459.63 3,410.02 1,030.14 2,711.51 6,004,836.52 4,958.02 57.68 66.90 3,510.98 3,461.37 1,061.75 2,765.39 6,004,867.02 5,052.82 57.04 66.36 3,562.11 3,512.50 1,093.42 2,858.67 6,004,897.58 5,148.13 57.16 66.71 3,613.88 3,564.27 1,125.28 2,932.07 6,004,928.34 5,243.31 57.86 67.18 3,665.01 3,615.40 1,156.72 3,005.94 6,004,958.66 5,338.36 57.26 66.52 3,716.00 3,666.39 1,188.25 3,079.70 6,004,989.09 5,433.59 57.52 66.98 3,767.32 3,717.71 1,219.92 3,153.40 6,005,019.64 5,529.05 57.40 66.25 3,818.66 3,769.05 1,251.86 3,227.27 6,005,050.47 5,623.93 56.50 67.44 3,870.41 3,820.80 1,283.13 3,300.38 6,005,080.65 5,719.34 57.15 67.23 3,922.62 3,873.01 1,313.91 3,374.07 6,005,110.31 5,814.42 56.81 66.47 3,974.43 3,924.82 1,345.25 3,447.38 6,005,140.55 5,909.84 57.02 66.69 4,026.52 3,976.91 1,377.03 3,520.74 6,005,171.22 6,004.99 57.25 67.59 4,078.15 4,028.54 1,408.07 3,594.38 6,005,201.16 6,100.38 57.24 67.26 4,129.76 4,080.15 1,438.87 3,666.46 6,005,230.84 6,195.61 56.86 66.32 4,181.56 4,131.95 1,470.36 3,741.90 6,005,261.23 6,291.01 57.02 66.79 4,233.60 4,183.99 1,502.17 3,815.25 6,005,291.93 6,385.93 56.70 65.82 4,285.50 4,235.89 1,534.11 3,888.03 6,005,322.77 6,480.68 56.44 66.86 4,337.70 4,288.09 1,565.84 3,960.46 6,005,353.42 6,575.68 57.19 66.57 4,389.69 4,340.08 1,597.27 4,033.49 6,005,383.75 6,670.60 57.11 66.86 4,441.18 4,391.57 1,628.80 4,106.74 6,005,414.17 6,765.79 57.54 67.03 4,492.57 4,442.96 1,660.17 4,180.46 6,005,444.44 6,860.92 57.02 66.59 4,543.99 4,494.38 1,691.69 4,254.03 6,005,474.84 6,956.48 56.90 67.27 4,596.10 4,546.49 1,723.08 4,327.73 6,005,505.12 7,051.15 57.42 66.13 4,647.44 4,597.83 1,753.26 4,401.32 6,005,534.20 7,147.27 56.90 67.24 4,699.56 4,649.95 1,783.92 4,476.03 6,005,563.73 7,242.08 57.33 66.43 4,751.04 4,701.43 1,815.24 4,549.23 6,005,593.95 7,337.43 57.04 67.46 4,802.71 4,753.10 1,846.62 4,622.96 6,005,624.23 7,432.78 57.55 67.29 4,854.23 4,804.62 1,877.49 4,697.02 6,005,653.98 7,528.24 57.09 66.31 4,905.78 4,856.17 1,909.14 4,770.87 6,005,684.52 7,623.34 56.82 66.45 4,957.63 4,908.02 1,941.08 4,843.91 6,005,715.36 7,718.66 56.55 66.91 5,009.99 4,960.38 1,972.61 4,917.05 6,005,745.79 7,813.91 57.05 67.12 5,062.14 5,012.53 2,003.74 4,990.43 6,005,775.81 7,909.36 57.03 66.93 5,114.07 5,064.46 2,035.00 5,064.16 6,005,805.96 8,004.47 56.96 67.30 5,165.88 5,116.27 2,066.01 5,137.65 6,005,835.87 8,100.83 57.17 67.42 5,218.27 5,168.66 2,097.15 5,212.29 6,005,865.88 8,193.81 56.79 66.44 5,268.94 5,219.33 2,127.69 5,284.01 6,005,895.34 Map Vertical Fasting DLS Section (ft) (°1100'1 (ft) Survey Tool Name 3yU,bii.LO 0.66 -ui3ZE~ti MvtiD+iFh-i.hti.r+~-j~. (Sj 390,751.39 0.78 -706.44 MWD+IFR-AK-CAZ-SC (3) 390,825.38 0.50 -724.84 MWD+IFR-AK-CAZ-SC (3) 390,899.01 0.58 -742.66 MWD+IFR-AK-CAZ-SC (3) 390,973.41 0.26 -760.38 MWD+IFR-AK-CAZSC (3) 391,047.74 0.56 -778.23 MWD+IFR-AK-CAZSC (3) 391,121.48 0.83 -795.69 MWD+IFR-AK-CAZ-SC (3) 391,195.35 0.33 -813.06 MWD+IFR-AK-CAZ-SC (3) 391,269.68 0.85 -831.04 MWD+IFR-AK-CAZ-SC (3) 391,343.89 0.86 -848.88 MWD+IFR-AK-CAZ-SC (3) 391,418.06 0.49 -866.59 MWD+IFR-AK-CAZ-SC (3) 391,492.38 0.66 -884.16 MWD+IFR-AK-CAZSC (3) 391,565.95 1.42 -901.84 MWD+IFR-AK-CAZ-SC (3) 391,640.09 0.71 -920.26 MWD+IFR-AK-CAZ-SC (3) 391,713.85 0.76 -937.99 MWD+IFR-AK-CAZ-SC (3) 391,787.67 0.29 -955.40 MWD+IFR-AK-CAZ-SC (3) 391,861.76 0.83 -973.57 MWD+IFR-AK-CAZ-SC (3) 391,936.29 0.29 -992.20 MWD+IFR-AK-CAZSC (3) 392,010.19 0.92 -1,009.89 MWD+IFR-AK-CAZSC (3) 392,084.00 0.45 -1,027.27 MWD+IFR-AK-CAZ-SC (3) 392,157.24 0.92 -1,044.21 MWD+IFR-AK-CAZ-SC (3) 392,230.13 0.96 -1,061.11 MWD+IFR-AK-CAZ-SC (3) 392,303.62 0.83 -1,078.60 MWD+IFR-AK-CAZ-SC (3) 392,377.32 0.27 -1,096.16 MWD+IFR-AK-CAZ-SC (3) 392,451.50 0.48 -1,114.10 MWD+IFR-AK-CAZSC (3) 392,525.53 0.67 -1,131.85 MWD+IFR-AK-CAZ-SC (3) 392,599.68 0.61 -1,149.78 MWD+IFR-AK-CAZ-SC (3) 392,673.71 0.94 -1,168.61 MWD+IFR-AK-CAZ-SC (3) 392,748.86 0.95 -1,187.72 MWD+IFR-AK-CAZ-SC (3) 392,822.52 0.85 -1,205.47 MWD+IFR-AK-CAZ-SC (3) 392,896.70 0.96 -1,223.36 MWD+IFR-AK-CAZ-SC (3) 392,971.21 0.56 -1,241.92 MWD+IFR-AK-CAZ-SC (3) 393,045.52 0.99 -1,259.72 MWD+IFR-AK-CAZ-SC (3) 393,119.02 0.31 -1,276.81 MWD+IFR-AK-CAZ-SC (3) 393,192.63 0.49 -1,294.29 MWD+IFR-AK-CAZ-SC (3) 393,266.45 0.56 -1,312.24 MWD+IFR-AK-CAZ-SC (3) 393,340.64 0.17 -1,330.29 MWD+IFR-AK-CAZ-SC (3) 393,414.57 0.33 -1,348.39 MWD+IFR-AK-CAZ-SC (3) 393,489.66 0.24 -1,367.08 MWD+IFR-AK-CAZ-SC (3) 393,561.83 0.97 -1,384.53 MWD+IFR-AK-CAZSC (3) ra/22/2008 9:11:34AM Page 4 COMPASS 2003.16 Build 42F • r ConocoPh illips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordi nate Reference: Well CD3-107 Project: Western North Slope TVD Reference: CD3-107L1 @ 49.61ft (Doyon 19 (13.2+36.41)) Site: CD3 Fiord Pad MD Reference: CD3-107L1 @ 49.61ft (Doyon 19 (13.2+36.41)) Well: CD3-107 North Referen ce: True Wellbore: CD3-107L1 Survey Calcu lation Method: Minimum Curvature Design: CD3-107L1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (~) (ft) (~) lft) lft) ln) lft) (°1100') (ft) Survey Toot Name ti,285.50 07.15 00.57 5,321.25 5,271.08 2,155.50 5,356.02 6,uu5,926.1u 353,0JO.31 0.62 -1,402.25 MWG+IFR-Hh-GNZ-S~ (:i/ 8,384.79 56.73 66.14 5,373.02 5,323.41 2,191.21 5,431.00 6,005,956.64 393,709.74 0.88 -1,419.54 MWD+IFR-AK-CAZ-SC (3) 8,478.41 56.44 65.82 5,424.58 5,374.97 2,223.01 5,502.38 6,005,987.38 393,781.58 0.42 -1,435.76 MWD+IFR-AK-CAZ-SC (3) 8,573.42 56.92 66.54 5,476.77 5,427.16 2,255.08 5,575.01 6,006,018.35 393,854.68 0.81 -1,452.51 MWD+IFR-AK-CAZ-SC (3) 8,670.58 56.77 66.72 5,529.91 5,480.30 2,287.34 5,649.68 6,006,049.49 393,929.81 0.22 -1,470.30 MWD+IFR-AK-CAZ-SC (3) 8,765.68 57.36 67.28 5,581.61 5,532.00 2,318.53 5,723.15 6,006,079.57 394,003.74 0.79 -1,488.25 MWD+IFR-AK-CAZ-SC (3) 8,861.13 57.11 67.98 5,633.27 5,583.66 2,349.07 5,797.37 6,006,109.00 394,078.40 0.67 -1,507.17 MWD+IFR-AK-CAZ-SC (3) 8,956.17 57.25 67.76 5,684.78 5,635.17 2,379.16 5,871.35 6,006,137.97 394,152.82 0.24 -1,526.37 MWD+IFR-AK-CAZ-SC (3) 9,051.01 56.33 67.04 5,736.73 5,687.12 2,409.65 5,944.61 6,006,167.36 394,226.52 1.16 -1,544.70 MWD+IFR-AK-CAZ-SC (3) 9,146.29 56.33 66.88 5,789.55 5,739.94 2,440.69 6,017.58 6,006,197.30 394,299.94 0.14 -1,562.49 MWD+IFR-AK-CAZ-SC (3) 9,241.28 57.03 66.69 5,841.73 5,792.12 2,471.96 6,090.53 6,006,227.49 394,373.34 0.76 -1,580.05 MWD+IFR-AK-CAZ-SC (3) 9,336.21 57.41 66.86 5,893.13 5,843.52 2,503.45 6,163.87 6,006,257.85 394,447.15 0.43 -1,597.70 MWD+IFR-AK-CAZ-SC (3) 9,431.54 57.19 67.86 5,944.63 5,895.02 2,534.33 6,237.91 6,006,287.62 394,521.63 0.91 -1,616.24 MWD+IFR-AK-CAZ-SC (3) 9,525.89 57.60 66.07 5,995.47 5,945.86 2,565.43 6,311.05 6,006,317.62 394,595.22 1.66 -1,634.07 MWD+IFR-AK-CAZ-SC (3) 9,621.11 56.20 67.18 6,047.47 5,997.86 2,597.08 6,384.26 6,006,348.17 394,668.89 1.77 -1,651.49 MWD+IFR-AK-CAZ-SC (3) 9,716.17 56.37 67.13 6,100.24 6,050.63 2,627.78 6,457.13 6,006,377.77 394,742.21 0.18 -1,669.49 MWD+IFR-AK-CAZ-SC (3) ~ 9,811.02 55.69 67.97 6,153.23 6,103.62 2,657.82 6,529.83 6,006,406.72 394,815.34 1.03 -1,687.92 MWD+IFR-AK-CAZ-SC (3) 9,904.40 56.60 67.43 6,205.26 6,155.65 2,687.25 6,601.58 6,006,435.07 394,887.51 1.09 -1,706.28 MWD+IFR-AK-CAZ-SC (3) 10,001.32 57.01 68.18 6,258.32 6,208.71 2,717.69 6,676.67 6,006,464.57 394,963.05 0.77 -1,725.63 MWD+IFR-AK-CAZ-SC (3) 10,096.75 57.72 67.44 6,309.78 6,260.17 2,748.24 6,751.08 6,006,493.81 395,037.90 0.99 -1,744.81 MWD+IFR-AK-CAZ-SC (3) 10,192.01 57.44 67.10 6,360.85 6,311.24 2,779.31 6,825.25 6,006,523.76 395,112.52 0.42 -1,763.27 MWD+IFR-AK-CAZ-SC (3) 10,287.11 57.75 66.58 6,411.82 6,362.21 2,810.89 6,899.07 6,006,554.23 395,186.80 0.57 -1,781.12 MWD+IFR-AK-CAZSC (3) 10,381.84 57.11 66.49 6,462.81 6,413.20 2,842.66 6,972.30 6,006,584.91 395,260.49 0.68 -1,798.44 MWD+IFR-AK-CAZ-SC (3) 10,476.82 57.32 66.80 6,514.24 6,464.63 2,874.33 7,045.61 6,006,615.46 395,334.25 0.35 -1,815.92 MWD+IFR-AK-CAZ-SC (3) 10,571.74 57.03 66.37 6,565.70 6,516.09 2,906.03 7,118.80 6,006,646.06 395,407.91 0.49 -1,833.30 MWD+IFR-AK-CAZ-SC (3) 10,616.48 56.63 64.83 6,590.18 6,540.57 2,921.50 7,152.91 6,006,661.01 395,442.24 3.02 -1,840.83 MWD+IFR-AK-CAZ-SC (3) 10,666.93 57.26 60.53 6,617.70 6,568.09 2,940.90 7,190.46 6,006,679.85 395,480.07 7.25 -1,847.21 MWD+IFR-AK-CAZ-SC (3) 10,761.97 57.79 56.83 6,668.75 6,619.14 2,982.57 7,256.93 6,006,720.49 395,549.15 3.33 -1,853.74 MWD+IFR-AK-CAZ-SC (3) 10,857.64 59.00 54.71 6,718.89 6,669.28 3,028.41 7,326.28 6,006,765.31 395,617.18 2.27 -1,856.25 MWD+IFR-AK-CAZ-SC (3) 10,907.90 59.77 53.06 6,744.48 6,694.87 3,053.90 7,361.22 6,006,790.28 395,652.49 3.21 -1,856.16 MWD+IFR-AK-CAZ-SC (3) 10,952.85 61.07 51.86 6,766.67 6,717.06 3,077.72 7,392.21 6,006,813.63 395,683.84 3.71 -1,855.10 MWD+IFR-AK-CAZ-SC (3) 11,001.67 62.11 50.45 6,789.90 6,740.29 3,104.66 7,425.65 6,006,840.06 395,717.66 3.32 -1,852.97 MWD+IFR-AK-CAZ-SC (3) ~ 11,048.08 64.32 47.42 6,810.82 6,761.21 3,131.88 7,456.88 6,006,866.80 395,749.30 7.53 -1,849.30 MWD+IFR-AK-CAZ-SC (3) 11,098.81 64.59 45.41 6,832.70 6,783.09 3,163.43 7,490.03 6,006,897.85 395,782.92 3.61 -1,843.26 MWD+IFR-AK-CAZ-SC (3) 11,142.94 65.68 41.82 6,851.26 6,801.65 3,192.42 7,517.64 6,006,926.42 395,810.95 7.78 -1,836.04 MWD+IFR-AK-CAZ-SC (3) 11,194.41 66.09 40.08 6,872.29 6,822.68 3,227.90 7,548.42 6,006,961.43 395,842.27 3.19 -1,825.43 MWD+IFR-AK-CAZ-SC (3) 11,238.47 66.62 37.56 6,889.96 6,840.35 3,259.34 7,573.72 6,006,992.49 395,868.03 5.38 -1,814.86 MWD+IFR-AK-CAZ-SC (3) 11,289.42 66.37 35.83 6,910.28 6,860.67 3,296.80 7,601.64 6,007,029.53 395,696.50 3.15 -1,800.96 MWD+IFR-AK-CAZ-SC (3) 11,333.67 66.55 32.90 6,927.96 6,878.35 3,330.28 7,624.54 6,007,062.66 395,919.89 6.08 -1,787.33 MWD+IFR-AK-CAZ-SC (3) 11,384.12 66.58 30.89 6,948.02 6,898.41 3,369.58 7,648.99 6,007,101.58 395,944.93 3.66 -1,769.92 MWD+IFR-AK-CAZ-SC (3) 5/22/2008 9:11:34AM Page 5 COMPASS 2003.16 Build 42F • ConocoPh illips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ord inate Reference : Well CD3-107 Protect: VJestem North Slope ND Reference: CD3-107L1 @ 49.61ft (Doyon 19 (13.2+36.41)) Site: CD3 Fiord Pad MD Reference: CD3-107L1 @ 49.61ft (Doyon 19 (13.2+36.41)) Well: CD3-107 North Refere nce: True Wellbore: CD3-107L1 Survey Calcu lation Method: Minimum Curvature Design: CD3-107L1 .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 11,4'28.67 68.12 2o.5a 6,a65.1a 6,515.58 3,405.55 7,Ci6tl.87 6,007,1`57.25 395,9115.35 8.75 -1,752.50 MWD+IFR-AK-GAZ-3C (J) 11,480.63 69.27 24.48 6,984.14 6,934.53 3,449.33 7,689.97 6,007,180.70 395,987.10 5.00 -1,729.49 MWD+IFR-AK-CAZ-SC (3) 11,523.48 71.55 22.02 6,998.44 6,948.83 3,486.24 7,705.82 6,007,217.37 396,003.50 7.62 -1,708.94 MWD+IFR-AK-CAZ-SC (3) 11,574.75 72.12 20.04 7,014.43 6,964.82 3,531.71 7,723.30 6,007,262.57 396,021.65 3.83 -1,682.43 MWD+IFR-AK-CAZ-SC (3) 11,618.73 73.97 16.55 7,027.25 6,977.64 3,571.64 7,736.50 6,007,302.30 396,035.45 8.68 -1,657.88 MWD+IFR-AK-CAZ-SC (3) 11,669.85 75.40 14.70 7,040.76 6,991.15 3,619.12 7,749.77 6,007,349.57 396,049.43 4.47 -1,627.27 MWD+IFR-AK-CAZ-SC (3) 11,714.03 78.36 12.55 7,050.79 7,001.18 3,660.93 7,759.90 6,007,391.22 396,060.18 8.21 -1,599.40 MWD+IFR-AK-CAZ-SC (3) 11,765.12 80.11 10.56 7,060.33 7,010.72 3,710.10 7,769.95 6,007,440.23 396,070.97 5.14 -1,565.53 MWD+IFR-AK-CAZ-SC (3) 11,803.36 81.69 8.09 7,066.38 7,016.77 3,747.36 7,776.07 6,007,477.38 396,077.64 7.60 -1,538.98 MWD+IFR-AK-CAZ-SC (3) 11,845.05 62.44 6.61 7,072.13 7,022.52 3,788.31 7,781.35 6,007,518.25 396,083.53 3.95 -1,508.96 MWD+IFR-AK-CAZ-SC (3) 11,956.21 89.05 5.45 7,080.38 7,030.77 3,898.49 7,792.98 6,007,628.23 396,096.81 6.04 -1,426.66 MWD+IFR-AK-CAZ-SC (3) 12,051.37 91.71 1.73 7,079.74 7,030.13 3,993.43 7,798.94 6,007,723.07 396,104.19 4.81 -1,353.35 MWD+IFR-AK-CAZ-SC (3) 12,146.73 92.39 356.97 7,076.33 7,026.72 4,088.70 7,797.86 6,007,818.33 396,104.54 5.04 -1,275.64 MWD+IFR-AK-CAZ-SC (3) 12,242.30 91.95 353.68 7,072.71 7,023.10 4,183.87 7,790.08 6,007,913.60 396,098.18 3.47 -1,194.07 MWD+IFR-AK-CAZ-SC (3) 12,337.50 93.07 350.07 7,068.54 7,018.93 4,278.00 7,776.64 6,008,007.92 396,086.15 3.97 -1,110.02 MWD+IFR-AK-CAZ-SC (3) 12,428.79 91.34 346.50 7,065.03 7,015.42 4,367.31 7,758.12 6,008,097.48 396,068.98 4.34 -1,026.88 MWD+IFR-AK-CAZ-SC (3) 12,528.08 91.58 345.39 7,062.50 7,012.89 4,463.59 7,734.01 6,008,194.11 396,046.32 1.14 -934.82 MWD+IFR-AK-CAZ-SC (3) 12,623.07 91.95 341.82 7,059.57 7,009.96 4,554.66 7,707.22 6,008,285.56 396,020.89 3.78 -845.39 MWD+IFR-AK-CAZ-SC (3) 12,717.76 90.90 336.96 7,057.22 7,007.61 4,643.24 7,673.91 6,008,374.62 395,988.91 5.25 -754.15 MWD+IFR-AK-CAZ-SC (3) 12,813.07 91.03 333.21 7,055.61 7,006.00 4,729.65 7,633.77 6,008,461.61 395,950.07 3.94 -660.65 MWD+IFR-AK-CAZ-SC (3) 12,909.33 90.60 330.00 7,054.24 7,004.63 4,814.31 7,588.00 6,008,546.94 395,905.59 3.36 -565.26 MWD+IFR-AK-CAZ-SC (3) • 12,973.00 91.26 328.23 7,053.21. 7,003.60 4,868.94 7,555.33 6,008,602.05 395,873.73 2.96 501.86 MWD+IFR-AK-CAZ-SC (3) 13,035.38 88.40 327.62 7,053.39 7,003.78 4,921.79 7,522.21 6,008,655.39 395,841.41 4.69 -439.63 MWD+IFR-AK-CAZ-SC (4) 13,130.96 88.28 325.61 7,056.16 7,006.55 5,001.57 7,469.64 6,008,735.93 395,790.05 2.11 -344.19 MWD+IFR-AK-CAZ-SC (4) 13,226.54 86.71 322.95 7,058.67 7,009.06 5,079.13 7,413.86 6,008,814.32 395,735.44 2.82 -248.66 MWD+IFR-AK-CAZ-SC (4) 13,322.27 90.68 319.85 7,059.18 7,009.57 5,153.93 7,354.15 6,008,890.00 395,676.86 3.84 -153.04 MWD+IFR-AK-CAZ-SC (4) 13,417.78 91.61 316.91 7,057.27 7,007.66 5,225.31 7,290.73 6,008,962.31 395,614.53 3.23 -58.02 MWD+IFR-AK-CAZ-SC (4) 13,513.43 90.99 314.95 7,055.10 7,005.49 5,294.01 7,224.23 6,009,031.99 395,549.06 2.15 36.65 MWD+IFR-AK-CAZ-SC (4) 13,609.09 91.06 318.29 7,053.39 7,003.78 5,363.52 7,158.54 6,009,102.47 395,484.43 3.49 131.49 MWD+IFR-AK-CAZ-SC (4) 13,704.63 91.12 322.04 7,051.57 7,001.96 5,436.86 7,097.36 6,009,176.71 395,424.36 3.92 226.78 MWD+IFR-AK-CAZ-SC (4) 13,801.13 91.61 323.17 7,049.27 6,999.66 5,513.50 7,038.78 6,009,254.21 395,366.93 1.28 323.22 MWD+IFR-AK-CAZ-SC (4} 13,896.30 91.73 324.71 7,046.50 6,996.89 5,590.40 6,982.78 6,009,331.93 395,312.10 1.62 418.35 MWD+IFR-AK-CAZ-SC (4) 13,991.71 91.30 324.29 7,043.98 6,994.37 5,668.05 6,927.40 6,009,410.40 395,257.89 0.63 513.72 MWD+IFR-AK-CAZ-SC (4) 14,087.42 90.19 324.07 7,042.73 6,993.12 5,745.65 6,871.39 6,009,488.82 395,203.05 1.18 609.42 MWD+IFR-AK-CAZ-SC (4) ~ 14,182.99 90.31 322.03 7,042.32 6,992.71 5,822.02 6,813.94 6,009,566.03 395,146.76 2.14 704.97 MWD+IFR-AK-CAZ-SC (4) 14,278.69 91.61 321.34 7,040.71 6,991.10 5,897.09 6,754.62 6,009,641.98 395,088.58 1.54 800.58 MWD+IFR-AK-CAZ-SC (4) 14,374.23 91.11 322.30 7,038.45 6,988.84 5,972.17 6,695.58 6,009,717.93 395,030.67 1.13 896.02 MWD+IFR-AK-CAZ-SC (4) 14,469.72 91.48 324.46 7,036.29 6,986.68 6,048.79 6,638.64 6,009,795.38 394,974.89 2.29 991.48 MWD+IFR-AK-CAZ-SC (4) 14,565.36 91.30 327.46 7,033.97 6,984.36 6,128.01 6,585.13 6,009,875.39 394,922.57 3.14 1,087.02 MWD+IFR-AK-CAZ-SC (4) 14,660.87 92.54 326.72 7,030.77 6,981.16 6,208.14 6,533.26 6,009,956.29 394,871.92 1.51 1,182.34 MWD+IFR-AK-CAZ-SC (4) 5122/2008 9:11:34AM Page 6 COMPASS 2003.16 Build 42F ConocoPh illips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordi nate Reference: Well CD3-107 Project: Western North Slope TVD Reference: CD3-107L1 @ 49.61ft (Doyon 19 (13.2+36.41)) Srce: CD3 Fiord Pad MD Reference: CD3-107L1 @ 49.61ft (Doyon 19 (13.2+36.41)) Well: CD3-107 North Referen ce: True Wellbore: CD3-107L1 Survey Calcu lation Method: Minimum Curvature Design: CD3-107L1 Database: CPAI EDM Production Survey - - -- - - --~ I Map Map Vertical MD Inc Azl TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100'} {ft} Survey Tool Name I 14,756.32 90.93 324.83 702~.ba v, 9.4.27 a '8;.02 ii,d7y.ti1 6,O10,0o5.65 3~i,d19.45 2.60 1,277,69 MWL+,FR-AK-CAZ-SC (4) '~ 14,852.07 91.30 324.36 7 026.01 6,976.40 6365.05 6,424.14 6,010,114.80 394,765.17 0.62 1,373.42 MWD+IFR-AK-CAZ-SC (4) 14,948.21 91.18 322.81 7,023.93 6,974.32 6,442.40 6,367.09 6,010,192.98 394,709.28 1.62 i 1,469.53 MWD+IFR-AK-CAZ-SC (4) 15,043.27 90.87 321.27 7,022.23 6,972.62 6,517.33 6,308.63 6,010,268.78 394,651.95 1.65 1,564.51 MWD+IFR-AK-CAZ-SC (4) 15,138.88 90.74 321.94 7,020.89 6,971.28 6,592.26 6,249.25 6,010,344.58 394,593.71 0.71 1,660.03 MWD+IFR-AK-CAZ-SC (4) 15,234.33 90.93 324.70 7,019.50 6,969.89 6,668.79 6,192.25 6,010,421.95 394,537.86 2.90 1,755.45 MWD+IFR-AK-CAZ-SC (4) 15,330.29 91.73 326.76 7,017.27 6,967.66 6,748.07 6,138.23 6,010,502.02 394,485.04 2.30 7,851.34 MWD+IFR-AK-CAZ-SC (4) 15,425.89 91.30 325.51 7,014.74 6,965.13 6,827.42 6,084.98 6,010,582.15 394,432.99 1.38 1,946.84 MWD+IFR-AK-CAZ-SC (4) 15,521.37 92.10 320.07 7,011.91 6,962.30 6,903.40 6,027.29 6,010,658.98 394,376.45 5.76 2,042.22 MWD+IFR-AK-CAZ-SC (4) 15,570.93 90.75 317.41 7,010.68 6,961.07 6,940.64 5,994.62 6,010,696.70 394,344.34 6.02 2,091.55 MWD+IFR-AK-CAZ-SC (4) I 15,617.71 90.87 317.84 7,010.07 6,960.40 6,975.19 5,963.09 6,010,731.72 394,313.34 0.95 2,138.03 MWD+IFR-AK-CAZ-SC (4) 15,663.03 90.50 319.33 7,009.47 6,959.86 7,009.18 5,933.11 6,010,766.15 394,283.88 3.39 2,183.15 MWD+IFR-AK-CAZ-SC (4) 15,713.24 90.93 320.08 7,008.85 6,959.24 7,047.47 5,900.64 6,010,804.92 394,251.99 1.72 2,233.21 MWD+IFR-AK-CAZ-SC (4) i 15,808.86 91.67 319.60 7,006.68 6,957.07 7,120.53 5,838.99 6,010,878.88 394,191.44 0.92 2,328.55 MWD+IFR-AK-CAZ-SC (4) I 75,904.51 89.76 320.87 7,005.48 6,955.87 7,194.04 5,777.82 6,010,953.30 394,131.38 2.40 2,423.98 MWD+IFR-AK-CAZ-SC (4) 15,999.88 89.45 323.10 7,006.14 6,956.53 7,269.17 5,719.09 6,011,029.29 394,073.79 2.36 2,519.29 MWD+IFR-AK-CAZ-SC (4) 16,095.49 89.14 323.32 7,007.32 6,957.71 7,345.73 5,661.84 6,011,106.70 394,017.69 0.40 2,614.88 MWD+IFR-AK-CAZ-SC (4) ~ 16,191.10 90.50 324.54 7,007.62 6,958.01 7,423.01 5,605.55 6,011,184.80 393,962.57 1.91 2,710.49 MWD+IFR-AK-CAZ-SC (4) 16,253.48 92.29 325.02 7,006.10 6,956.49 7,473.96 5,569.58 6,011,236.27 393,927.38 2.97 2,772.84 MWD+IFR-AK-CAZ-SC (4) i 16,287.06 93.27 324.81 7,004.47 6,954.86 7,501.40 5,550.30 6,011,264.00 393,908.51 2.98 2,806.37 MWD+IFR-AK-CAZ-SC (4) 16,382.74 89.86 324.58 7,001.66 6,952.25 7,579.44 5,495.04 6,011,342.86 393,854.42 3.57 2,902.00 MWD+IFR-AK-CAZ-SC (4) 16,478.50 I 88.63 323.42 7,003.12 6,953.51 7,656.91 5,438.76 6,011,421.15 393,799.31 1.77 2,997.75 MWD+IFR-AK-CAZ-SC (4) 16,573.97 89.06 324.98 7,005.04 6,955.43 7,734.32 5,382.92 6,011,499.38 393,744.65 1.69 3,093.19 MWD+IFR-AK-CAZ-SC (4) I 16,669.50 91.53 323.06 7,004.55 6,954.94 7,811.61 5,326.81 6,011,577.50 393,689.70 3.27 3,188.71 MWD+IFR-AK-CAZ-SC (4) 16,764.94 91.65 322.17 7,001.90 6,952.29 7,887.42 5,268.88 6,011,654.16 393,632.92 0.94 3,284.08 MWD+IFR-AK-CAZ-SC (4) 16,860.71 90.78 322.39 6,999.87 6,950.26 7,963.16 5,210.30 6,011,730.75 393,575.49 0.94 3,379.79 MWD+IFR-AK-CAZ-SC (4) 16,956.77 91.03 321.44 6,998.36 6,948.75 8,038.75 5,151.06 6,011,807.22 393,517.39 1.02 3,475.77 MWD+IFR-AK-CAZ-SC (4) 17,052.19 91.59 321.19 6,996.17 6,946.56 8,113.22 5,091.43 6,011,882.57 393,458.89 0.64 3,571.06 MWD+IFR-AK-CAZ-SC (4) I 17,147.68 91.96 322.57 6,993.22 6,943.61 8,188.30 5,032.52 6,011,958.52 393,401.11 1.50 3,666.44 MWD+IFR-AK-CAZ-SC (4} 17,243.55 90.54 322.68 6,991.13 6,941.52 8,264.47 4,974.34 6,012,035.54 393,344.08 1.49 3,762.25 MWD+IFR-AK-CAZ-SC (4) 17,339.10 91.09 322.58 6,989.77 6,940.16 8,340.40 4,916.35 6,012,112.32 393,287.24 0.59 3,857.77 MWD+IFR-AK-CAZ-SC (4) 17,435.62 91.22 323.40 6,987.82 6,938.21 8,417.46 4,858.26 6,012,190.24 393,230.32 0.86 3,954.25 MWD+IFR-AK-CAZ-SC (4) 17,531.23 90.11 321.53 6,986.71 6,937.10 8,493.26 4,800.02 6,012,266.90 393,173.22 2.27 4,049.82 MWD+IFR-AK-CAZ-SC (4) 17,626.87 91.28 322.07 6,985.55 6,935.94 8,568.42 4,740.88 6,012,342.92 393,115.22 1.35 4,145.38 MWD+IFR-AK-CAZ-SC (4) 17,722.20 91.40 324.22 6,983.32 6,933.71 8,644.67 4,683.72 6,012,420.02 393,059.21 2.26 4,240.66 MWD+IFR-AK-CAZ-SC (4) 17,817.94 88.44 323.82 6,983.45 6,933.84 8,722.14 4,627.48 6,012,498.31 393,004.14 3.12 4,336.39 MWD+IFR-AK-CAZ-SC (4) 17,912.77 89.06 324.14 6,985.52 6,935.91 8,798.82 4,571.72 6,012,575.87 392,949.55 0.74 4,431.20 MWD+IFR-AK-CAZ-SC (4) 18,008.49 92.64 328.61 6,984.10 6,934.49 8,878.48 4,516.75 6,012,656.25 392,697.77 5.98 4,526.79 MWD+IFR-AK-CAZ-SC (4) 18,058.69 89.68 328.81 6,983.09 6,933.48 8,921.36 4,492.68 6,012,699.81 392,872.35 5.91 4,576.80 MWD+IFR-AK-CAZ-SC (4) 18,105.49 87.70 328.83 6,984.16 6,934.55 8,961.39 4,468.46 6,012,739.90 392,848.74 4.23 4,623.42 MWD+IFR-AK-CAZ-SC (4) ra/22/2008 9:11:34AM Page 7 COMPASS 2003.16 Buitd 42F Company: ConocoPhillips(Alaska) Inc. Project: Western North Slope Site: CD3 Fiord Pad Well: CD3-107 Wellbore: CD3-107L1 Design: CD3-107L1 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well CD3-107 CD3-107L1 @ 49.61ft (Doyon 19 (13.2+36.41)) CD3-107L1 @ 49.61ft (Doyon 19 (13.2+36.41)) True Minimum Curvature CPAI EDM Production Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft} (ft) (°1100') (ft) Survey Tool Name 18,201.42 87.7ti 329.45 6,987.96 6,938.35 9,043.67 4,419.29 6,012,82[.90 392,800.81 0.65 4,718.88 <v7VVD+IFRa~h-CaZ-SC t4) 18,296.57 90.41 333.49 6,989.48 6,939.87 9,127.23 4,373.87 6,012,907.12 392,756.64 5.08 4,813.19 MWD+IFR-AK-CAZ-SC (4) 18,347.12 91.22 334.91 6,988.76 6,939.15 9,172.74 4,351.87 6,012,952.95 392,735.33 3.23 4,862.94 MWD+IFR-AK-CAZ-SC (4) 18,392.11 91.65 335.47 6,987.63 6,938.02 9,213.56 4,333.00 6,012,994.05 392,717.07 1.57 4,907.06 MWD+IFR-AK-CAZ-SC (4) 18,487.71 90.85 336.98 6,985.54 6,935.93 9,301.03 4,294.47 6,013,082.07 392,679.86 1.79 5,000.46 MWD+IFR-AK-CAZ-SC (4) 18,583.32 90.35 339.34 6,984.54 6,934.93 9,389.76 4,258.90 6,013,171.32 392,645.63 2.52 5,093.16 MWD+IFR-AK-CAZ-SC (4) 18,678.95 92.14 341.42 6,982.47 6,932.86 9,479.81 4,226.80 6,013,261.63 392,614.89 2.87 5,184.88 MWD+IFR-AK-CAZ-SC (4) 18,774.39 91.34 343.15 6,979.57 6,929.96 9,570.68 4,197.78 6,013,353.12 392,587.23 2.00 5,275.45 MWD+IFR-AK-CAZ-SC (4) 18,870.02 91.28 345.64 6,977.38 6,927.77 9,662.75 4,172.06 6,013,445.56 392,562.89 2.60 5,365.05 MWD+IFR-AK-CAZ-SC (4) 18,965.78 91.59 347.09 6,974.98 6,925.37 9,755.78 4,149.49 6,013,538.91 392,541.72 1.55 5,453.58 MWD+IFR-AK-CAZ-SC (4) 19,061.48 92.70 348.96 6,971.40 6,921.79 9,849.33 4,129.65 6,013,632.73 392,523.29 2.27 5,540.92 MWD+IFR-AK-CAZ-SC (4) 19,156.75 95.60 351.16 6,964.51 6,914.90 9,942.91 4,113.25 6,013,726.53 392,508.29 3.62 5,626.27 MWD+IFR-AK-CAZ-SC (4) 19,252.32 97.28 355.75 6,953.78 6,904.17 10,037.22 4,102.42 6,013,821.00 392,498.88 5.09 5,708.94 MWD+IFR-AK-CAZ-SC (4) 19,304.68 9722 356.57 6,947.17 6,697.56 10,069.05 4,098.94 6,013,872.86 392,496.17 1.56 5,752.91 MWD+IFR-AK-CAZ-SC (4) 19,346.76 97.04 356.83 6,941.95 6,892.34 10,130.73 4,096.54 6,013,914.58 392,494.39 0.75 5,788.05 MWD+IFR-AK-CAZ-SC (4) 19,441.47 96.67 356.27 6,930.65 6,881.04 10,224.59 4,090.88 6,014,008.50 392,490.14 0.71 5,867.31 MWD+IFR-AK-CAZ-SC (4) 19,482.00 96.67 356.27 6,925.94 6,876.33 10,264.77 4,088.26 6,014,048.70 ~ 392,488.12. 0.00 5,901.35 PROJECTED to TD 5/222008 9: ? 1:34AM Page 8 COMPASS 2003.16 Build 42F I~ LJ 08-Jun-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD3-107 L1 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 12,909.33' MD Window /Kickoff Survey: 12,973.00' MD (if applicable) Projected Survey: 19,482.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~Y ~~~~ Signed v Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~ i WELL LOG TRANSMITTAL To: State of Alaska May 19, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Data: CD3-107L1 AK-MW-5700040 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention o£ Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20529-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Atli Alaska 9~9~.1,8 ~.~ . , -, Date: Signed: ~ ~o~_c~l ~/~~9 d ~ ~ .~ ~ ~ ~ ~ ~~. LJ L SARA ~ H PAL/N, GOVERNOR ~~ ~ ~ 333 W. 7th AVENUE, SUITE 100 C01~5ER~A~`IO1K CbAII-II55IO1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Chip Alvord FAx (so7> 27sa5az WNS Drilling Team Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Fiord Oil Pool, CD3-107L1 ConocoPhillips Alaska, Inc. Permit No: 208-051 Surface Location: 3926' FNL, 797' FEL, SEC. 5, T12N, R5E, UM Bottomhole Location: 4394' FNL, 4586' FEL, SEC. 28, T13N, R5E Dear Mr. Alvord: Enclosed is the approved application for permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well CRU CD3-107, Permit No 206-189, API 50-103-20529-01. Production should continue to be reported as a function of the original API number stated above. 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerel Daniel T. Seamount, Jr. Chair DATED this ~ day of April, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ ~ ECEiVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ Aril ~ 3 ZOOH ~ PERMIT TO DRILL +~~~a Oil & Gas Cons. Comrr~ssi0ft 20 AAC 25.005 1 a. Type of Work: 1 b. Current Well Class: Exploratory ^ Development Oil ^ ~ 1 c. Specify if well is proposed for: Drill ^ Re-drill Q Stratigraphic Test ^ Service ^ Development Gas ^ Coalbed Methane ^ Gas Hydrates ^ Re-entry Multiple Zone^ Single Zone /^ Shale Gas ^ 2. Operator Name: ~ ~,, 5. Bond: / Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 CD3-107L1 • 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 19306' TVD: 6954' , Colville River Field 4a. Location of Well (Governmental Section): 7. Property Designation: /-iIDL ~(~ y/~~ L Surface: 3926' FNL, 797' FEL, Sec 5, T12N, R5E, UM i ADL 372104, 372105, 364471 Fiord Oil Pool Top of Productive Horizon: 8. Land Use Permit: ~„ 13. Approximate Spud Date: 845FNL, 3961 FEL, SEC3, T12N, R5E LAS2112 4/12/2008 Total Depth: 9. Acres in Property: 14. Distance to 4394FNL, 4586FEL, SEC28, T13N, R5E 5759 Nearest Property:14893' to CRU Boundary 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x- 388247.00 • y- 6003847 • Zone- 4 (Height above GL): 37' RKB feet Well within Pool: Fiord 5: 817' at 18,773' ,' 16. Deviated wells: Kickoff depth: 12900 • ft. 17. Maximum Anticipated Pressures in psig (see 20 aAC zs.o35) Maximum Hole Angle: 90° deg Downhole: 3123 psig , Surface: 2493 psig • 18. Casing Program if ti S Setting Depth Quantity of Cement pec ica ons T B tt f k Size om o op . or sac s c. Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 77 37 37 114 114' pre-installed 12.25" 9-5/8" 40# L-80 BTC-M 3056 37 37 3093 2479 385 sx AS Lite3, 230 sx 15.8 G 8.75" 7" 26# L-80 BTCM 11837 37 37 11874 7075 277 sx 15.8G 6.125" 3.5" 9.3# L-80 EUE-M 11748 32 32 11780 6755 Tbg 6.125" 3.5" 9.3# L-80 EUE-M 7516 11780 6755 19296 6954 Liner with perforated pup joints 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): 18315 Total Depth TVD (ft): 6975 Plugs (measured) 13242 Effective Depth MD (ft): 13242 Effective Depth TVD (ft): 7044 Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural 77.00 16" Pre-Installed 114 114 Surface 3,056.00 9-5/8" 385sx ASLite3, 230sx 15.8 G 3093 2479 Intermediate 11,837.00 7" 277 sx Class G 15.8 ppg 11874 7075 Production 11,748.00 3.5" Tubing 11780 6755 Perforation Depth MD (ft): Perforation Depth TVD (ft): 10944-10970 6746'-6761' 20. Attachments: Filing Fee ^ BOP Sketch^ Drilling ProgramQ Time v. Depth Plo^ Shallow Hazard Analysis ^/ Properly Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Prograrr^/ 20 AAC 25.050 requirements /^ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact L. Galiunas Printed Name C. Alvord Title WNS Drilling Team Lead Signature Phone ~,,~t~tr~ Date (3 (2~~ Commission Use Only Permit to Drill _ API Number: Permit Approval See cover letter Number: !~~ Lim r 50-v`?j ~~i~L~ ~~~ Date: 9. ~ g for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed meth~rae, gas hydrates, or gas contained in shales: _ f ~ Samples req'd: Yes ^ No []~ Mud log req'd: Yes ^ No [~ Other. ~~j ~V ~~ ~~~ ~S~ H2S measures: Yes ^ No ~ Directional svy req'd: Yes [i]~ No ^ Form 10-401 Revised 12/2005 DATE: APPROVED BY THE COMMISSION COMMISSION ,.~ ~ ? ~$Ubmlt in Duplicate ~ ~ ConocoPhillips Alaska, Inc. ~,, Post Office Box 100360 Anchorage, Alaska 99510-0360 ~QnacOPtilfip5 Telephone 907-276-1215 April 3, 2008 RECEIVELI Alaska Oil and Gas Conservation Commission APR 0 3 2008 333 West 7th Avenue, Suite 100 Alaska Oi{ 8~ Gas Cons. Commission Anchorage, Alaska 99501 Anchorage Re: Application for Permit to Re-enter and Re-Drill: CD3-107L1 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a permit to return to CD3-107 and re-drill the lateral that collapsed in 2007. The plan is to perform a open hole sidetrack at 12,900'MD and re-drill the lateral (As CD3-107L1). It is intended that Doyon 19 would return to CD3-107 and perform the work described in this permit application. ConocoPhillips Alaska drilled CD3-107 (PTD#: 206-189 & 206-046) in 2007. After drilling the first thousand feet of the lateral, the Nechelik sand was exited into the shale above (between 13242' MD-13500'MD). After 13500'MD the lateral continued in the Nechelik sand to a TD of 18315' MD. Once the well was handed over to production, the shale section collapsed and the Nechelik horizontal would not produce. The well has been producing out of a short section of perforations in the Kuparuk. When Doyon 19 returns to the well in April, the proposed plan. is to pull the packer/tubing, cement off the perforations, and redrill the lateral by open hole sidetracking at approx. 12,900' MD in the original horizontal hole. The redrill directional plan parallels the original borehole with approx 50 feet of separation, and the planned TD is 1000' deeper. The Kuparuk C sand will be re-perforated. Two packers will be run on either side of the Kuparuk perforations and a sliding sleeve run to continue to produce out of the Kuparuk perforations. Apre-perfd liner will be run to facilitate future frac options. Upon completion, the collapsed lateral will remain as CD3-107 (API: 50-103-20529-01) and the new re-drilled lateral will be CD3-107L1 (API: 50-103-20529-60). The parent wellbore will remain CD3-107. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 application for a Permit to Drill per 20 ACC 25.005 (a). 2. Current well schematic 3. A proposed drilling program 4. A drilling fluids program summary. 5. Planned schematic post re-drill operations 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. Email correspondence with AOGCC on naming CD3-107L1 8. Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Liz Galiunas at 265- 6247, or Chip Alvord at 265-6120. Sincerely, Liz Galiunas Drilling Engineer Attachments cc: CD3-107L1 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1570 Nina Anderson ATO 1706 Liz Galiunas ATO 1704 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation C~ Maunder, Thomas E (DOA) • Page 1 of 1 From: Galiunas, Elizabeth C [Elizabeth.C.Galiunas@conocophillips.com] Sent: Monday, Apri107, 2008 10:18 AM To: Maunder, Thomas E (DOA) Cc: Anderson, Nina M Subject: CD3-107L1 Morning Tom, Thanks again for logging in on your weekend. We really appreciate it. I hope it did not disturb your weekend too much. I wanted to give you a heads up on the CD3-107L1 work. Thursday a sundry and permit to re-enter were brought over to the AOGCC. With the timing on CD3-303 and the ice road, we have time for Doyon 19 to perform the planned CD3-107L1 work. As of today, it looks like Doyon 19 could move to CD3-107as early as this Saturday. This permit and sundry will need a quick turn around. If there is any more information you need for the CD3-107L1 permit and sundry let Nina or myself know. Regards, l.iz Galiunas Drilling Engineer Alpine Drilling Team ConocoPhillips Alaska ATO--1704 Office: (907)--2G5-0247 Cell: (907}x441--4871 4/7/2008 Davies, Stephen F (DOA) From: Galiunas, Elizabeth C [Elizabeth.C.Galiunas@conocophillips.com] Sent:. Tuesday, April 01, 20081:13 PM To: Maunder, Thomas E (DOA) Cc: Davies, Stephen F (DOA) Subject: RE: CD3-107 and CD3-107L1 No, problem. I will submit both. Thanks for the guidance. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Se~rt: Tuesday, April 01, 2008 12:57 PM To: Galiunas, Elizabeth C Cc: Steve Davies Subject: RE: CD3-107 and CD3-107L1 Page 1 of 5 Liz, I don't want to cause any extra paperwork, but it is probably appropriate to submit a sundry to get on the well and pull the tubing, etc and then the 401 for the lateral. Call or message with any questions. Tom Maunder, PE AOGCC From: Davies, Stephen F (DOA) Sent: Tuesday, April 01, 2008 12:48 PM To: Maunder, Thomas E (DOA) Subject: FW: Naming Question on CD3-107 Could you reply to Liz? From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophillips.com] Sent: Tuesday, April 01, 2008 12:47 PM To: Davies, Stephen F (DOA) Subject: RE: Naming Question on CD3-107 Steve, Would CD3-107L1 need a 10-403 to pull tubing plus a 10-401 to re-drill or only the 10-401? Thanks, 4/7/2008 Page 2 of 5 From: Davies, Stephen F {DOA) [mailto:steve.davies@alaska.gov] Se~rt: Thursday, March 20, 2008 2:11 PM To: Galiunas, Elizabeth C; Maunder, Thomas E (DOA) Cc: Saltmarsh, Arthur C (DOA}; Anderson, Nina M Subject: RE: Naming Question on CD3-107 Liz, Since the some of the Nechelik from the existing CD3-107 well bore will be open to production, I think the clearest way to segregate records from the new wellbore segment is to name it CD3-107L1. Please let me know if I can help further. Thanks, Steve Davies AOGCC From: Galiunas, Elizabeth C [maitto:Elizabeth.C.Galiunas@conocophillips.com] Sent: Tuesday, March 18, 2008 10:55 AM To: Davies, Stephen F (DOA); Maunder, Thomas E (DOA) Cc: Saltmarsh, Arthur C (DOA); Anderson, Nina M Subject: RE: Naming Question on CD3-107 Steve, Sorry it has taken so long to get back to you. 1 want to clarify our proposed operations for CD3-107 redrill and make sure we are naming the wellbore correctly. We have evidence that a shale section in the Nechelik open hole horizontal collapsed (see attached x-section and well operation summary below). Attempting to clean out the collapsed lateral and run a liner has risks and time is short with CD3 being a winter only access pad. When Doyon 19 returns to the well in April, the proposed plan is to pull the packer/tubing and redrill the lateral by open hole sidetracking at approx. 12,900' MD in the original horizontal hole. The redrill directional plan parallels the original borehole with approx 50 feet of separation, and the planned TD is 1000' deeper, A pre-perfd liner will be run to facilitate future frac options. Since the open hole sidetrack will be in zone off an existing horizontal would the name be CD3-107L1 or CD3-107A? Here is the sequence of events for CD3-107 showing how the Nechelik lateral is isolated with fill. We can provide anything else you would need to prove the lateral for CD3-107 has collapsed. We also intend to complete the well for a frac that would impact the new lateral, to not risk opening the CD3-107 lateral. SEQUENCE OF EVENTS 4/'7/2008 Page 3 of 5 2~28C2007 7:00 Db n 19 com led converting CD3-307 Kuparak pa+~luees to CD3-107 Nechelik peoducer. 3!7/20070:30 Started CD3-107 Nechelikflowback. 318!2007 6:30 GD3-107 rate st~rEe~d precipitous fall off' 31912007 7:15 Shut in. Final rate 300 BOPD lifli at ve high GLR. 3/1012007 Pam d 50 bbl down tubin ,tub' eared to 2300 " at a nd of 3t18I200715:D0 SL: Drifted 2" to 11623'RtfH {below tubing ta>7 at 1091aRI:H.~ Taols slapped 74 degree incline in.7"casing. POOH wl emptybailer. 3/30/2007 Lail: Tagged up 13,242' CT1~ID with 2" dawn je t nazxle. CTn~le to pass abstraction with said attom hole equipmnertt. Na averpall witnessed. Suggest Di~taced well aver to diesel while POOH. Depth of obstr~ iron corresponds to depth drilling exited sand into upper shale. 4t3E2007 I~.estarted productian testing with CD3 test ~p~xator. ~,pproximatelgor~ tubing volnrne produced ~ surface an gas lift. 4!5!2007 9:27 Gancluded production testing via CD3 separator and shut ~. No liquid flow to surface while circ n]a ' lift down IA and tub' . Canclw~le wellbore colla at -13200' 1VItl. Let me know if you need any additional information. Thanks, From: Davies, Stephen F (DOA) [mailtasteve.davies@alaska.gov] Sent: Friday, March 07, 2008 5:35 PM To: Galiunas, Elizabeth C; Maunder, Thomas E (DOA) Cc: Saltmarsh, Arthur C (DOA) Subject: RE: Naming Question on CD3-107 Liz, There is no clean answer to this one. Since the Kuparuk and Nechelik sandstones are in pressure communication within the Fiord Field, AOGCC assigns them to a single oil paol, the Fiord Oil Pool. The 300 series numbers denote Fiord wells within the Kuparuk sandstone, and 100 series numbers denote Fiord wells within the Nechelik sandstone. This well was originally a Kuparuk well (CD3-307, PTD 206-046, API 50-103-20529-00-00) that was subsequently deepened to the Nechelik. Deepening the well required a new permit to drill (number 206-189}, and since the well was 4/7/2008 Page 4 of 5 being redrilled to the Nechelik, the well was renamed CD3-107 and given a new APl number of 50-103-20529-01-00. We couldn't call the deepening CD3-307A, because it was being drilled to the Nechelik. In retrospect, maybe we should have named the deepened wellbore CD3-107A, but at the time I thought that name would cause too much confusion. It seemed like CD3-107 was the best name for the deepened wellbore. •Now, I'm assuming that ConocoPhillips will plug and abandon the pay zones within CD3-107, before redrilling to a new target in the Nechelik. So long as nothing is left open in the existing CD3-107 wellbore, the best approach is to name the new wellbore CD3-107A and give it an API number of API 50-103-20529-02-00. AOGCC will assign this new wellbore a new permit to drill number. In the future, people will be confused by what appears to be a mistake in naming or numbering, but I think it would be more confusing to give the new wellbore the name CD3-1076. Then people would just wonder why there wasn't a "CD3- 107Afl wellbore. Copies of this email will be placed in the CD3-307, CD3-107 and CD3-107A well history files to help clear up any confusion. Thanks, Steve Davies AOGCC From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophillips.com] Sent: Friday, March 07, 2008 12:07 PM To: Davies, Stephen F (DOA) Subject: Naming Question on CD3-107 Hi, Steve, We are getting ready to submit. a sundry and a new permit to drill for CD3-107. Here is a brief description for the sundry and the new permit to drill . 1 need some guidance on naming. ConocoPhillips Alaska drilled CD3-107 (PTDs#: 206-189 & 206-046 API 50-103- 20529-00/01). After drilling the first thousand feet of the lateral, the Nechelik sand was exited into the shale above (between 13200' MD-13500'MD). After 13500'MD the lateral continued in the Nechelik sand to a TD of 18315' MD. Once the well was handed over to production, the shale section collapsed and the Nechelik horizontal would not produce. It is believed that the basal Nuiquist collapsed, filling the lateral, preventing any production from the Nechelik. The well was perforated in the Kuparuk sand above the Nechelik, and has been producing out of a short section of perforations for around a year. The asset would like to return to this well, decomplete it, sidetrack off the existing lateral at 12,900' MD, and redrill the Nechelik lateral to a TD of 19306' MD. Since returning to the well is a re-entry, planned sidetrack/re-drill the well should take an a letter (I.e.CD3-107A?), but since this well was also CD3-307 (API 50-103-20529- 00) 1 am not sure what the API or name would be for the re-drilled section since -01 is taken already. Would we name it B and -02? C~ I attached a schematic to help visualize the currentwell and proposed work. I do not 4/7/2008 have Jim Regg's information to send this to him also since Tom is out of the office. Regards, 4/7!2008 ~J CD3-107L1 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 6-1 /8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 8.8 ppg. Pressure , Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers ORIGINAL u Fiord Nechelik :CD3-107L1 Procedure to decomplete CD3-107 Pre-Riq Work 1. Slickline will change out the GLMs to dummy valves .Leave bottom mandrel open for circulation. 2. Bull head kill weight brine and diesel freeze protect down tubing. 3. Rig up E-line and chemical cut the Premier Packer. 4. RU SL and perform memory caliper log to determine chemical cut location. 5. BPV set in well. Riq Procedure 1) Move on Doyon 19, dewater cellar as needed. 2) Rig up riser. 3) Pull BPV and displace well to 9.2 ppg brine, taking returns to an open top tank. 4) Install two way check, nipple down the tree. 5) Nipple up and test BOPE to 3500 psi. 6) Pull two way check. 7) Attempt to pull tubing hanger to floor. Only pull 40,000 Ibs over on the packer, if not moving then rig up E- Line to re-cut the packer. If possible, pull out of hole laying down 3-1/2" tubing with permanent pressure gauge and the completion. If packer still does not release, cut above the packer and RIH with overshot to cut the slips on the packer and fish out. ORIGINAL Plan for Cementing off Perforations Cement Volumes for Squeeze: Perfs: 30 sacks Casing: (11874-10944)*0.2148=200 ft^3 = 173 sacks Open Hole: (13242-11874)*0.2046*1.25= 349.9 ft^3 = 302 sacks Total: 504 sacks Top of Nechel 18,315' `-'~.V ~~~ cation! ~`~ ~~~ ~~'1 8) PU and run in hole with mill tooth bit and clean out assembly. Swap well over to 9.2 ppg brine. Close Hydril squeeze off the Kuparuk perforations and 1000' of open hole-with 504 sacks of class G cement. 9) PU above the estimated cement top and circulate to clean up drill string. ~` 10) Drill out using mill tooth and cleanout assembly drill out cement in open hole. Get kicked off at 12,900' MD -~~~i ~ and displace well to 9.2 ppg Flo-Pro drilling fluid. 1 ~~.~ 11) POOH and LD cleanout BHA. 12) PU and RIH with 6 1/8" drilling assembly and continue to drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). / 13) Circulate hole clean and pull out of the hole. 14) Run lower completion, consisting of shoe, 4.5" perforated pup joints, 4.5" x 3.5" crossover, swell packers, open hole Packer with pump out plug, drillable ball drop sliding sleeve, 3.5" blank liner, X CMD sliding sleeve, Liner hanger. Space out and land liner hanger. 15) Run 3-'/2", 9.3#, L-80 tubing, SSSV, gas lift mandrels, permanent pressure gauge, packers, CMD sliding sleeve and X nipples. Space out and land hanger. 16) Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 17) Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. ORIGINAL 7" 26 ppf L-80 BTC Mod Proposed low side sidetrack point at Production Casing @ 11874' MD / 7077' 12;900' MD ND @ 84° 18) Circulate tubing to diesel and install freeze protection in the annulus. I~ L~ 19) Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. Set BPV and secure well. Move rig off. Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD3-301 is the closest existing well. Ellipse to ellipse separation is 1174' @ 19306' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Nechelik reservoir section is considered to be the most likely cause of lost . circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD3-107L1 will be injected into a permitted annulus on CD3 pad or the class 2 disposal well on CD1 pad. DRILLING FLUID PROGRAM Production Hole Section - 6 1/8" Density 9.0-9.3 ppg PV 10 -15 YP 25 - 30 Funnel Viscosity Initial Gels 10 - 15 10 minute gels 12 - 20 API Filtrate HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 9.0 - 9.5 KCL 6 Production Hole Section The horizontal production interval will be drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with ± 30PP6 calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. ORIGINAL Current Schematic CD3-107 ~ 16" Conductor to 114' Updated 4/4/07 Completion after Rig moved off 9-5/8" 40 ppf L-80 BTC-Mod Surface Casing @ 3093' MD / 2479' TVD 3-1/2" 9.3 ppf L-80 EUE M cemented to surface tubing run with Jet Lube Run'n'Seal pipe dope Completion MD Inc Tubing Hanger 32' 4-''/i' 12.6 #/ft IBT-Mod Tubing (2) Crossover 3-''/2" 9.3#/ft EUE -Mod Tubing Camco TRMAXX-5E SSSV (2.812") 2236' 47 3-%2" 9.3#/ft EUE -Mod Tubing Camco KBMG GLM (2.867" ID) 4804' 57 3-'/=' 9.3#/ft EUE -Mod Tubing Camco KBMG GLM (2.867" ID) 8769' S7 3-''/z" 9.3#/ft EUE -Mod Tubing Camco KBMG GLM (2.867" ID) 10714' 57 3-'/z" 9.3#/ft EUE -Mod Tubing (1) HES 2.813" X Profile 10763' 58 3-''/=" Tubing Joints EUE-Mod (1) 3-'/=" Baker Gauge Mandrel 10805' S8 3-'/z" Tubing Joints EUE-Mod (1) Baker Premier Packer 10856' 59° 3-''/2' 9.3#/ft EUE -Mod Tubing (1) HES XN (2.75" NoGo) 10902' S9 3-'/~' 10' pup joint WLEG 10914' 60 Calc TOC +500' above top of Kuparuk C Interval Kuparuk Perforations: ~% 10944-10970'MD Top of Nechelik 11763' MD/ 7075' TVD " ' ~ 7" 26 ppf L-80 BTC Mod Production Casing @ 11874' MD / 7077' TVD @ 84° OR161NAL Collasped area above Nechelik 13,200-13,500' MD Proposed low side sidetrack point at 12,900' MD Well TD at 18,315' MD Planned Completion Schematic for CD3-107L1 Uooer Completion MQ T~ Tubing Hanger 32' 32' 4Yi' 12.6 #/ft IBT-Mod Tubing (2) Crossover 3-'/z" 9.3#/ft EUE -Mod Tubing TRMAXX SE SSSV 2 812" 2200' 1992 16" Conductor to 114' 1) Camco - (. ) 3-%" 9.3#/ft EUE -Mod Tubing ' 3-1/2" 9.3 ppf L-80 EUE M 2) Camco KBMG GLM wl dummy (2.867" ID) 4754' 3400 tubing run with Jet Lube '~-~'" 9.3#fft EUE -Mod Tubing " ' Run'n'Seal ID) 3) Camco KBMG GLM wl dummy (2.867 8801 5600 3-%° 9.3#Ift EUE -Mod Tubing pipe dope 4) Camco KBMG GLM w/ SOV (2.867" ID) 10731' 6651 3-%° 9.3#Ift EUE -Mod Tubing (1) 5) HES 2.813" X Profile 3-%" 9.3#/ft EUE -Mod Tubing (1) 9-5/8" 40 ppf L-80 BTC-Mod 6) 3-%:" Baker Gauge Mandrel 10777' 6640 Surface Casing 3-' ~" Tubing Joints EUE-Mod (2) ' ° ' ' pup Tubing Joints EUE-Mod 10 3-Y= MD / 2479 ND @ 3093 7) Baker Premier Packer ~ 58° 10811' 6693' Cemented to sulfate 3-%" Tubin Joints EUE-Mod 10' pup g 8) Camco KBMG GLM w/dummy (2.867" ID) 9) 3-%° Tubing Joints IBT-Mod 5 joints (with crossovers 8 cross over couplings) 50' of Blast rings 12' above perfs to 12' below perfs (10932'-10982') 3-%z" Tubing Joints EUE-Mod 10' pup 10) Baker "X" CMD Sliding Sleeve 2.813" 11021' 6773' 3-'/z:" Tubing Joints EUE-Mod 10' pup 3-%° Tubing Joints EUE-Mod 10' pup 11) Baker Premier Packer @ 62° 11041' 6806' 3-%:" Tubing Joints EUE-Mod 10' pup 3-%" 9.3#/ft EUE -Mod 1 joints 12) HES 2.813" X Profile @ 64° w/ RHC plug 11081' 6824' 3-%' 9.3#/ft EUE -Mod 1 joint 13) BOT Stinger with Fluted WLEGI stinger 11121' 6842 Stung into tieback extension with tbg tail 3' above top of line * Upper completion based off of blast rings around perforations & CMD below perforations. r ~wor Comole "on MD TVD 14) Baker 5" x 7" Flexlock Liner Hanger 11140' 6849 w/ tie back sleeve (top of liner at 11,124') 15) 5" BTC x 3'/::" EUE Crossover 3-%", 1 joint 9.3#/ft, Blank EUE 8rd Mod 11150 16) Baker "X" CMD Sliding Sleeve 2.813" 11200' 6874 66° w/ 10' DUDS 3-%', 9.3#/ft, Blank EUE 8rd Mod 17) 3-'/:", Baker Drillable Ball Drop Sliding Sleeve TBA w/ 3.5" EUE 8rd -2.1" Ball Seat (2.25" ball) 3-%" 9.3#/ft L-80 Blank EUE 8rd Mod 18) TAM 3.5" x 5.75" 10' FreeCap TBA 3-%" 9.3#!ft L-80 Blank EUE 8rd Mod 19) Baker 3-%" x 6-1 /8" Open Hole Packer TBA with pump out plug (-1.25" ball seat & 1.5" ball) 3%:" 9.3#!ft L-80 Blank EUE 8rd Mod (1) 20) TAM 3.5" x 5.75" 10' FreeCap 3-%" 9.3#/ft L-80 Blank EUE 8rd Mod (1) 21) 3-'/:" x 4-%" Crossover (EUE-M (B) x IBTM (P)) Ball seat 22) 300 ft 4-%", 12.6#/ft, Blank IBT Mod liner 23) 4-%" perforated pups, 1 every 6 jts 24) Baker Shoe 19296' 6954' Calc TOC +500' above top Kuparuk C Interval Kuparuk Interval 26' Perforations: 10944-10970'MD * Lower completion based off of CMD at 66 degrees loo l loo l l 7" 26 ppf L-80 BTC Mod Production Casing @ 11874'. MD / 7075' TVD @ 84° Well TD at 19,306' MD / ' 6954' TVD - oRisinia~ i ~- CD3-118 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 (c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling in MD/TVD ft lbs. / al si si 7" 11874 / 7075 16.0 3201 2451 N/A 19306 / 6954 16.0 3147 N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1 ]D Where: ASP =Anticipated Surface pressure in psi FG =Fracture gradient at the casing seat in Ib/gal 0.052 =Conversion from Ib./gal to psi/ft 0.1 =Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP - (0.1 x D) Where; FPP =Formation Pore Pressure at the next casing point ASP CALCULATIONS 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3147 - (0.1 x 6954) = 2451 psi ORIGINAL ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad CD3-307 Plan: CD3-107L1 Plan: CD3-107L1wp01 Standard Proposal Report 03 April, 2008 :.. 1F .___ ~~.~ Sperry. Drifting Seruicee I G4M1q[p~1~~5 Error SysOan: I9CWSA Sean Mdhod: Trav. Cylinder Nartlr Emor Surface: Ellfptleal COnic blaming Metlrod: RWes Basetl Geodetlc DaWm: Nortlr Arnedesn DaWm 1993 Magrretle Mold: BGGM2097 Western North Slope CD3 Fiord Pad CD3-307 Plan: CD3-107L1 CD3-107L1wp01 CD3-107L1 wp01 I Ground Level: 13.39 RKB: CD3-107: ~49.40ft CD3-107: Northing/A5P Y: 6003594.40 EastinglASP X: 1528278.93 11 Ir_c` 0 0 4500 0 0 w 0 6000 c~ U_ N N 7500 CD3-107Awp01 T4 -1500 0 1500 3000 4500 Vertical Section at 324.00° (1500 ft/inl 6000 ORIGINAL 0 2000 4000 6000 8000 10000 12000 West(-)/East(+) (2000 ft/in) • ConocoPhillips ~~ ~ `~ Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well CD3-307 Company: ConocoPhillips(Alaska) Inc. -WNS ND Reference:. CD3-107: @ 49.40ft (CD3-107:) Project: Western North Slope MD Reference: CD3-107: @ 49.40ft (CD3-107:) Site: CD3 Fiord Pad North Reference: True Welk CD3-307 Survey Calculation Method : Minimum Curvature Wellbore: Plan: CD3-107L1 Design: CD3-107L1wp01 -- Project . ,. Western North Slope North Slope Alaska, United States 1 Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor ___ __ Site CD3 Fiord Pad _-- - -- -_ Site Position: Northing: 6,003,634.02ft Latitude: 70° 25' 9.315 N From: Map Easting: 1,528,520.01 ft Longitude: 150° 54' 41.768 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -0.86 ° Well CD3-307 Well Position +N/-S 0.00 ft Northing: 6,003,594.40 ft Latitude: 70° 25' 8.890 N ~ +E/-W 0.00 ft Easting: 1,528,278.93 ft Longitude: 150° 54' 48.820 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.30ft Wellbore Plare CD3-107L1 Magnetics Model Name Sam ple Date Declination Dip Angle Field Stre ngth ~ BGGM2007 4~3/200~ 22.23 80 ~ 5 57,589 Design CD3-107L1wp01 Audit Notes: Version: 1 Phase: PLAN Tie On Depth: 12,900.00 ', Vertical Section: Depth From (TVD) +N/-S `' +E/-W Direction (ft) (ft) (ft) (°) 'L_ 36.10 0.00 0.00 324_00 Plan Sections Measured Vertical ND Dogleg Build Turn Depth I nclination Azimuth Depth ''. System +N/-S +E(-W Rate Rate Rate Tool Face (ft) (~) (°) ($) ft (ft) (ft) ( `I100ft) (°I100ft) (°/100ft) (°) 12,900.00 90.64 330.30 7,054.13 7,004.73 4,806.40 7,592.54 0.00 0.00 0.00 0.00 12,975.00 88.04 328.80 7,054.99 7,005.59 4,871.04 7,554.55 4.00 -3.46 -2.00 -150.00 13,075.00 88.05 324.80 7,058.40 7,009.00 4,954.66 7,499.84 4.00 0.00 -4.00 -90.00 13,133.54 90.00 323.51 7,059.40 7,010.00 5,002.10 7,465.57 4.00 3.34 -2.21 -33.49 ~ 13,383.54 90.00 313.51 7,059.40 7,010.00 5,189.13 7,300.15 4.00 0.00 -4.00 -90.00 13,433.54 90.00 315.01 7,059.40 7,010.00 5,224.02 7,264.35 3.00 0.00 3.00 90.00 ~ 13,743.81 91.20 324.24 7,056.14 7,006.74 5,460.12 7,063.59 3.00 0.39 2.98 82.55 ~ 14,951.45 91.20 324.24 7,030.83 6,981.43 6,439.88 6,358.03 0.00 0.00 0.00 0.00 15,025.13 91.02 322.78 7,029.40 6,980.00 6,499.11 6,314.22 2.00 -0.24 -1.99 -96.90 17,825.00 91.02 322.77 6,979.40 6,930.00 g,72g.11 4,620.60 0.00 0.00 0.00 -92.56 19,306.59 90.86 355.49 6,954.40 6,905.00 10,093.53 4,099.95 2.21 -0.01 2.21 90.01 4/3/2008 9:25:49AM Page 2 COMPASS 2003. i6 Build 42F ~~J'~4~ti~L • ~,~ -' Database: EDM v16 Prod `Company: ConocoPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: CD3 Fiord Pad Well: CD3-307 Wellbore: Plan: CD3-107L1 Design: CD3-107L1wp01 Planned Survey Measured Vertical Depth Inclination Azimuth Depth (ft) (°) (`) (ft1. 12,900.00 90.64 330.30 7,054.13 KOP; 4 DLS 12,975.00 88.04 13,000.00 88.04 13,074.92 88.05 Top Nechelik 13,075.00 88.05 13,100.00 88.88 13,133.54 90.00 13,200.00 90.00 13,300.00 90.00 13,383.54 90.00 13,400.00 90.00 13,433.54 90.00 13,500.00 90.26 13,600.00 90.65 13,700.00 91.03 13,743.81 91.20 13,800.00 91.20 13,900.00 91.20 14,000.00 91.20 14,100.00 91.20 14,200.00 91.20 14,300.00 91.20 14,400.00 91.20 14,500.00 91.20 14,600.00 91.20 14,700.00 91.20 14,800.00 91.20 14,900.00 91.20 14,951.45 91.20 15,000.00 91.08 15,025.13 91.02 15,100.00 91.02 15,200.00 91.02 15,300.00 91.02 15,400.00 91.02 15,500.00 91.02 15,600.00 91.02 15,700.00 91.02 15,800.00 91.02 15,900.00 91.02 16,000.00 91.02 16,100.00 91.02 16,200.00 91.02 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well CD3-307 CD3-107: @ 49.40ft (CD3-107:) CD3-107: @ 49.40ft (CD3-107:) True Minimum Curvature . Map Map TVDss +N/-S +E!-W Northing Easting DLS" Vert Section ft (ft} (ft) (ft) (ft) 7,004.73 7,004.73 4,806.40 7,592.54 6,008,285.80 1,535,942.16 3.43 -574.33 328.80 7,054.99 7,005.59 4,871.04 7,554.55 6,008,351.00 1,535,905.14 4.00 -499.69 327.80 7,055.84 7,006.44 4,892.30 7,541.42 6,008,372.45 1,535,892.34 4.00 -474.78 324.80 7,058.40 7,009.00 4,954.59 7,499.88 6,008,435.35 1,535,851.74 4.00 -399.97 324.80 7,058.40 7,009.00 4,954.66 7,499.84 6,008,435.42 1,535,851.70 4.00 -399.89 324.25 7,059.07 7,009.67 4,975.01 7,485.33 6,008,455.98 1,535,837.50 4.00 -374.90 323.51 7,059.40 7,010.00 5,002.10 7,465.57 6,008,483.37 1,535,818.15 4.00 -341.37 320.85 7,059.40 7,010.00 5,054.60 7,424.82 6,008,536.46 1,535,778.19 4.00 -274.94 316.85 7,059.40 7,010.00 5,129.88 7,359.03 6,008,612.72 1,535,713.55 4.00 -175.37 313.51 7,059.40 7,010.00 5,189.13 7,300.15 6,008,672.84 1,535,655.58 4.00 -92.83 314.00 7,059.40 7,010.00 5,200.51 7,288.26 6,008,684.40 1,535,643.86 3.00 -76.63 315.01 7,059.40 7,010.00 5,224.02 7,264.35 6,008,708.27 1,535,620.30 3.00 -43.55 316.99 7,059.25 7,009.85 5,271.83 7,218.18 6,008,756.76 1,535,574.86 3.00 22.26 319.96 7,058.46 7,009.06 5,346.68 7,151.89 6,008,832.59 1,535,509.71 3.00 121.78 322.94 7,057.00 7,007.60 5,424.87 7,089.59 6,008,911.70 1,535,448.59 3.00 221.66 324.24 7,056.14 7,006.74 5,460.12 7,063.59 6,008,947.34 1,535,423.13 3.00 265.46 324.24 7,054.96 7,005.56 5,505.71 7,030.76 6,008,993.41 1,535,390.99 0.00 321.64 324.24 7,052.87 7,003.47 5,586.84 6,972.33 6,009,075.40 1,535,333.80 0.00 421.61 324.24 7,050.77 7,001.37 5,667.97 6,913.91 6,009,157.39 1,535,276.60 0.00 521.59 324.24 7,048.68 6,999.28 5,749.10 6,855.48 6,009,239.38 1,535,219.41 0.00 621.57 324.24 7,046.58 6,997.18 5,830.23 6,797.06 6,009,321.38 1,535,162.21 0.00 721.55 324.24 7,044.48 6,995.08 5,911.36 6,738.63 6,009,403.37 1,535,105.02 0.00 821.52 324.24 7,042.39 6,992.99 5,992.49 6,680.21 6,009,485.36 1,535,047.82 0.00 921.50 324.24 7,040.29 6,990.89 6,073.62 6,621.78 6,009,567.35 1,534,990.63 0.00 1,021.48 324.24 7,038.20 6,988.80 6,154.75 6,563.36 6,009,649.34 1,534,933.43 0.00 1,121.45 324.24 7,036.10 6,986.70 6,235.88 6,504.93 6,009,731.34 1,534,876.24 0.00 1,221.43 324.24 7,034.00 6,984.60 6,317.01 6,446.51 6,009,813.33 1,534,819.05 0.00 1,321.41 324.24 7,031.91 6,982.51 6,398.14 6,388.09 6,009,895.32 1,534,761.85 0.00 1,421.39 324.24 7,030.83 6,981.43 6,439.88 6,358.03 6,009,937.50 1,534,732.43 0.00 1,472.82 323.28 7,029.86 6,980.46 6,479.04 6,329.33 6,009,977.08 1,534,704.32 2.00 1,521.36 322.78 7,029.40 6,980.00 6,499.11 6,314.22 6,009,997.38 1,534,689.51 2.00 1,546.49 322.78 7,028.06 6,978.66 6,558.72 6,268.94 6,010,057.65 1,534,645.14 0.00 1,621.33 .322.78 7,026.28 6,976.88 6,638.33 6,208.45 6,010,138.16 1,534,585.86 0.00 1,721.29 322.78 7,024.49 6,975.09 6,717.95 6,147.97 6,010,218.67 1,534,526.59 0.00 1,821.25 322.78 7,022.70 6,973.30 6,797.57 6,087.49 6,010,299.18 1,534,467.31 0.00 1,921.21 322.78 7,020.92 6,971.52 6,877.18 6,027.00 6,010,379.68 1,534,408.04 0.00 2;021.17 322.78 7,019.13 6,969.73 6,956.79 5,966.52 6,010,460.19 1,534,348.76 0.00 2,121.13 322.77 7,017.35 6,967.95 7,036.41 5,906.04 6,010,540.70 1,534,289.48 0.00 2,221.09 322.77 7,015.56 6,966.16 7,116.02 5,845.55 6,010,621.20 1,534,230.21 0.00 2,321.05 322.77 7,013.77 6,964.37 7,195.64 5,785.06 6,010,701.71 1,534,170.93 0.00 2,421.02 322.77 7,011.99 6,962.59 7,275.25 5,724.58 6,010,782.22 1,534,111.65 0.00 2,520.98 322.77 7,010.20 6,960.80 7,354.86 5,664.09 6,010,862.72 1,534,052.37 0.00 2,620.94 322.77 7,008.42 6,959.02 7,434.47 5,603.60 6,010,943.23 1,533,993.09 0.00 2,720.90 4/3/2008 9:25:49AM Page 3 COMPASS 2003.16 Build 42F Q~lG1l~AL Cono coPhillips Standard Pro posal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well CD3-307 Company: ConocoPhillips(Alaska) Inc. -WNS ND Reference: CD3- 107: @ 49.40ft (CD3-107:) Project: Western North Slope MD Reference: CD3- 107: @ 49.40ft (CD3-107:) Site: CD3 Fiord Pad North Reference: True Well: CD3-307 Survey Calculation Method: Minimum Curvature Weilbore: Plan: CD3-107L1 Design: CD3-107L1wp01 Planned Surv ey Measured Vertical Map Map Depth Inclination Azimuth Depth NDss +N/-S +E!-W Northing Easting DLS Vert Section (ft) (`) (°) (ft) ft (ft) (ft) (ft) (rt) 6,957.23 16,300.00 91.02 322.77 7,006.63 6,957.23 7,514.08 5,543.12 6,011,023.73 1,533,933.81 0.00 2,820.86 16,400.00 91.02 322.77 7,004.84 6,955.44 7,593.70 5,482.63 6,011,104.23 1,533,874.53 0.00 2,920.82 16,500.00 91.02 322.77 7,003.06 6,953.66 7,673.31 5,422.14 6,011,184.74 1,533,815.25 0.00 3,020.78 16,600.00 91.02 322.77 7,001.27 6,951.87 7,752.92 5,361.65 6,011,265.24 1,533,755.97 0.00 3,120.74 16,700.00 91.02 322.77 6,999.49 6,950.09 7,832.53 5,301.16 6,011,345.74 1,533,696.68 0.00 3,220.70 16,800.00 91.02 322.77 6,997.70 6,948.30 7,912.14 5,240.67 6,011,426.24 1,533,637.40 0.00 3,320.67 16,900.00 91.02 322.77 6,995.92 6,946.52 7,991.74 5,180.17 6,011,506.75 1,533,578.12 0.00 3,420.63 17,000.00 91.02 322.77 6,994.13 6,944.73 8,071.35 5,119.68 6,011,587.25 1,533,518.83 0.00 3,520.59 17,100.00 91.02 322.77 6,992.34 6,942.94 8,150.96 5,059.19 6,011,667.75 1,533,459.55 0.00 3,620.55 17,200.00 91.02 322.77 6,990.56 6,941.16 8,230.57 4,998.70 6,011,748.25 1,533,400.26 0.00 3,720.51 17,300.00 91.02 322.77 6,988.77 6,939.37 8,310.17 4,938.20 6,011,828.75 1,533,340.98 0.00 3,820.47 17,400.00 91.02 322.77 6,986.99 6,937.59 8,389.78 4,877.71 6,011,909.25 1,533,281.69 0.00 3,920.43 17,500.00 91.02 322.77 6,985.20 6,935.80 8,469.39 4,817.21 6,011,989.75 1,533,222.40 0.00 4,020.39 17,600.00 91.02 322.77 6,983.42 6,934.02 8,548.99 4,756.72 6,012,070.25 1,533,163.11 0.00 4,120.35 17,700.00 91.02 322.77 6,981.63 6,932.23 8,628.60 4,696.22 6,012,150.74 1,533,103.83 0.00 4,220.31 17,800.00 91.02 322.77 6,979.85 6,930.45 8,708.20 4,635.72 6,012,231.24 1,533,044.54 0.00 4,320.27 17,825.00 91.02 322.77 6,979.40 6,930.00 8,728.11 4,620.60 6,012,251.37 1,533,029.71 0.00 4,345.27 CD3-10 7Awp01 T3 17,900.00 91.02 324.42 6,978.06 6,928.66 8,788.46 4,576.09 6,012,312.37 1,532,986.13 2.21 4,420.25 18,000.00 91.02 326.63 6,976.28 6,926.88 8,870.88 4,519.51 6,012,395.63 1,532,930.79 2.21 4,520.19 18,100.00 91.02 328.84 6,974.50 6,925.10 8,955.42 4,466.13 6,012,480.95 1,532,878.70 2.21 4,619.96 18,200.00 91.01 331.05 6,972.73 6,923.33 9,041.95 4,416.06 6,012,568.22 1,532,829.93 2.21 4,719.40 18,300.00 91.00 333.26. 6,970.97 6,921.57 9,130.35 4,369.36 6,012,657.31 1,532,784.57 2.21 4,818.37 18,400.00 91.00 335.47. 6,969.22 6,919.82 9,220.49 4,326.10 6,012,748.08 1,532,742.67 2.21 4,916.71 18,500.00 90.99 337.67 6,967.49 6,918.09 9,312.22 4,286.35 6,012,840.39 1,532,704.30 2.21 5,014.30 18,600.00 90.98 339.88 6,965.78 6,916.38 9,405.42 4,250.16 6,012,934.11 1,532,669.52 2.21 5,110.97 18,700.00 90.96 342.09 6,964.09 6,914.69 9,499.95 4,217.59 6,013,029.11 1,532,638.38 2.21 5,206.58 18,800.00 90.95 344.30 6,962.42 6,913.02 9,595.66 4,188.68 6,013,125.24 1,532,610.92 2.21 5,301.01 18,900.00 90.93 346.51 6,960.77 6,911.37 9,692.41 4,163.49 6,013,222.35 1,532,587.18 2.21 5,394.09 19,000.00 90.92 348.72 6,959.16 6,909.76 9,790.07 4,142.04 6,013,320.31 1,532,567.20 2.21 5,485.70 19,100.00 90.90 350.93 6,957.57 6,908.17 9,888.47 4,124.37 6,013,418.96 1,532,551.02 2.21 5,575.70 19,175.32 90.88 353.13 6,956.40 6,907.00 9,963.05 4,113.93 6,013,493.68 1,532,541.70 2.93 5,642.17 Base N uiqsut 19,200.00 90.88 353.13 6,956.02 6,906.62 9,987.49 4,110.51 6,013,518.16 1,532,538.65 0.00 5,663.95 19,300.00 90.86 355.34 6,954.50 6,905.10 10,086.97 4,100.48 6,013,617.77 1,532,530.11 2.21 5,750.33 19,306.59 90.86 355.49 6,954.40 6,905.00 .10,093.53 4,099.95 6,013,624.34 1,532,529.68 2.21 5,755.95 CD3-107Awp01 T4 4/3/2008 9:25:49AM Page 4 COMPASS 2003.16 Build 42F ~RIGI~AL ConocoPhillips ;'. Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well CD3-307 Company: ConocoPhillips(Alaska) Inc. -WNS ND Reference: CD3-107: @ 49.40ft (CD3-107:) Project: Western North Slope MD Reference: CD3-107: @ 49.40ft (CD3-107:) Site: CD3 Fiord Pad North Reference: True Welh CD3-307 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-107L1 Design: CD3-107L1wp01 Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (`) (°) (ft) (ft) (ft) (ft) (ft) CD3-107Awp01 T4 0.00 0.00 6,954.40 10,093.53 4,099.95 6,013,624.34 1,532,529.68 - plan hits target - Point CD3-107Awp01 T1 0.00 0.00 7,059.40 5,213.18 7,261.01 6,008,697.48 1,535,616.80 - plan misses by 10.03ft at 13428.32ft MD (7059.40 TVD , 5220.34 N, 7268.04 E) - Point CD3-107Awp01 T3 0.00 0.00 6,979.40 8,728.11 4,620.60 6,012,251.37 1,533,029.71 - plan hits target - Point CD3-107Awp01 T2 0.00 0.00 7,029.40 6,508.33 6,324.34 6,010,006.44 1,534,699.77 - plan misses by 13.63ft at 15026.35ft MD (7029.38 TVD , 6500.08 N, 6313.48 E) - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (~~) (~~) 3,092.91 2,478.84 9 5/8" x 12 1/4" 9-5/8 12-1/4 11,874.25 7,075.35 7"x 8 3/4" 7 8-3/4 19,306.59 6,954.40 4 1/2" x 6 1/8" 4-1/2 6-1/8 Formations Measured Vertical Depth Depth (ft) (ft) 10,696.19 6,633.40 11,155.75 6, 856.40 ~~ 9,551.92 6,009.40 ~ 11,405.84 6,956.40 10,944.27 6,762.40 i 11,755.07 7,058.40 10,521.65 6,538.40 9,092.07 5,759.40 10,856.89 6,718.40 ~ 10,776.55 6,676.40 10,967.05 6,773.40 Plan Annotations Measured Vertical Depth Depth lft) lft) 12,9GO.OQ 7,U54.13 Vertical Depth SS ft Name Base HRZ Top Nuiqsut Albian 96 Base Nuiqsut Top Kuparuk C Top Nechelik Top HRZ Albian 97 Top Kuparuk D K-1 LCU Local Coordinates +N/-S +E/-W (ft) (ft) Comment 4,806.40 7,592.54 KOP; 4 DLS Dip Dip Direction L-Rhology (~) {~) 4/3/2008 9:25:49AM Page 5 COMPASS 2003.16 Build 42F ~~ ~~~~~ ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad CD3-307 Plan: CD3-107L1 CD3-107L1wp01 Clearance Summary Anticollision Re ort p 03 April, 2008 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad -CD3-307 -Plan: CD3-107L1 -CD3-107L1wp01 Well Coordinates: 6,003,594.40 N, 1,528,278.93E (70° 25' 08.89" N, 150° 54' 48.82" W) Datum Height: CD3-107: @ 49.40ft (CD3-107:) Scan Range: 12,900.00 to 19,306.59 ft. Measured Depth. Scan Radius is 2,127.05 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 ~.. ~,a.. .. ». ~ La ~ ~ ~..~ Sperry ©rllling ~3ervlces 9:42, Apri103 2008 y~__,~./ ConocoPhillips Project: Western North Slope Site: CD3 Fiord Pad Well: CD3-307 Parent Well: CD3-107 Wellbore: Plan: CD3-107L1 REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well CU3-3U7, 'true North Vertical (TVD) Reference: CU's-1U'I: (f£ 40A08 (CD3-10?:) Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: CD3.107: !~ d9.40U (CD3-10?:) CD3-107L1 wp01 12900.00 To 19306.59 ANTI~COLLISION SETTINGS Interpolatlon Method: MD, In(erval: 15.00 Maximum Range: 111].06 Scan Method: Trav. Cylinder North Error BUrtace: EIIIpllcal COnlc warnm¢ Memod~. Roves eases GLOBAL FILTER APPLIED: All welipaths wlthln 100'i 10011000 of reference SIR\'t:l' 1'It0(: R,1.~1 zlw7m-1lTIIO~w.00 cnud.,md: c~, a~~~w~~n. I I Drp(h I'i~ m Drpih T. <~!1'Inn lxl ]9.Px JJt.Nt f'1)JJU? Q rv (('D.IJU]] f'I{~:1 HI) S,~ na.v? 3u u5 a~~tl]fcuaana anvil»u~x-,xti-c.~zsc ~nvs.ng IzMalw t1>3_to]lan-ma am~o-u~~-nn-clzsc 1zv00.tro l9)M~_59 X111-m-1.tn (dl lnan.cna-unl.u +rn~rrR..(N~c.1i e<~ Geodetic System: US State Plane 1983 Datum: North American Datum Ellipsoid: GRS 1980 Zone: Alaska Zone 4 Critical Issues: From Colour To MD -90 / 0!380 0 ..:..: `..,.,,""""` 250 2500 8000 9000 250 500 3600 3600 16044 50p 750 350U 4000 12oaa 750 105U 4caom 45an 140Gtl 3000 1250 4500 5U00 10QOU 1250 1500 5000 `"°""'°" '"^'^' OQOfl 18000 lsoo ° ~•~-P° 1r5o eao5 7000 zoaaa 9750 ~"" 2000 7000 °' '" 8000 2090 2500 8000 9000 1 QI}99 12000 14000 15UOtl 10000 2UOOU 2!1000 _1 -180 / 180 TraveAirrg Cylinder Azimuth (TFO+AZI) ['] us Centre to Centre Separation [50 ft/in] SECTION DETAILS Sec MD Inc Azi TVD +N/$ +E/-W DLeg TFxce VSec Target 1 12900.00 90.64 330.30 7054.13 4806.40 7592.54 0.00 0.00 -574.33 2 12975,00 88.04 328.80 7054.99 4871.04 7554.55 4.00 -150.00 -099.69 3 13075.00 88.05 324,80 7058.40 4954.66 7499.84 4.00 -90,00 -399.89 4 13133.54 90.00 323,51 7059.40 5002.10 7465,57 4.00 -33.49 -341.37 5 13383,54 90.00 313.51 7059.40 5189.13 7300.15 4.00 -90.00 -92.83 6 13433.54 90.00 315.01 7059.40 .5224.02 7264.35 3.00 90.00 -03.5.5 7 13743.81 91.20 324,24 7U56.14 5460.12 7063.59 3.00 82,55 2fi5.46 8 14951.45 91.20 324.24 7030.83 fi439,88 6358.03 0.00 0.00 1472.82 9 15025.13 9].02 322.78 7029.40 fi499.11 6314.22 2.00 -96.90 1.546.49 10 17825.00 91.02 322.77 6979.40 8728.11 4610.60 0.00 -92.56 4345.27 CD3-107AWpU1 T3 ConocoPhillips(Alaska) Inc. -WNS Anticollision Report for CD3-307 -CD3-107L1wp01 Western North Slope Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad -CD3-307 -Plan: CD3-107L1 -CD3-107L1wp01 Scan Range: 12,900.00 to 19,306.59 ft. Measured Depth. Scan Radius is 2,127.05 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Site Name Comparison Well Name - Welibore Name -Design CD3 fiord Pad CD3-108 -CD3-108 -CD3-108 CD3-108 -CD3-108 -CD3-108 CD3-301 -CD3-301 -CD3-301 CD3-301 -CD3-301 P81 -CD3-301 P61 CD3-307 -CD3-107 -CD3-107 CD3-307 -CD3-107 -CD3-107 """" Plan: CD3-106 -Plan: CD3-106 -Plan: CD3-106 (wp01 Plan: CD3-106 -Plan: CD3-106 -Plan: CD3-106 (wp01 ^q .y~"''- ~°` Survey tool groaram Measured Minimum Measured Ellipse Measured Clearance Summary Based on Depth Distance Depth Separation Depth Factor Minimum (ft) (ft) (ft) (ft) ft 17,175.68 1,793.20 17,175.68 1,631.55 12,025.00 11.093 Centre Distance 17,350.67 1,795.46 17,350.67 1,629.90 12,200.00 10.845 Clearance Factor 19,306.59 1,426.82 19,306.59 1,174.67 13,800.00 5.659 Clearance Factor 19,306.59 1,450.26 19,306.59 1,198.52 13,775.00 5.761 Clearance Factor Separation Warning From To Survey/Plan (ft) (ft) 79.85 437.85 474.97 3,057.25 3,098.00 12,900.00 12,900.00 19,306.59 CD3-107L1wp01 Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Survey Tool CB-GYRO-SS MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor =Distance Between Profiles / (Distance Between Profiles -Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 03 April, 2008 - 9:36 Page 2 of 4 COMPASS Opsmlon Cenace9hlAlpr(Abska) bc. ~WNS Held: W.d.m Nodh Sbp. Walk CD3~l0YAwp01 R19: MN/A s~rbe. m~nuon %: 1318318.93 It y: 600339N.R0 tl Comments: VI ~~ s n 0 0 U t N 1 N N T n cite een.dlen: ~o.ee Ion Ne: Nx/A Mo0nsNc DecRnellen: 8231 AfF NO: MN/A dp: O0.R3 ° API No: MN/A Doq(efl par 100 fl SYd.m (iVDj Aelsr.nca: Maon Sac level Orlglnal VS Plane: 324.00 ° Par.nl w.R cD3ao% View VS Plane: 324.00 ° R%R x.i9n1: ~+.AO n UnU Syd.m: API Oared r PPS Sec0en (VS) l.lsrenc.: Sbl 8 Plan View 8 8 ~ ~ S 0 gg R 8 8 8 ~ ° ~ 'c z P®OL: CD3-1g7Awpg1 Ptan: 129gq'to 19386.59' MD CD3-1 g7:69gq'to7O5q' TVDss CD3-3q7: 6900' to 6994.29' TVDss CD3-108: 69gq' to 6958.79' TVDss i 1 eolsooo _,._,,.~. . [ .--"'"m"- ` ^-",_...".-'""'"-" ~ e ' _.. --'--- ~ _____.,~.. __,. 6017000 { f ~ f _.. `~ _. .._..... O ! .._...._....,... ..~ s ._. _...,,__..~tt_~~_ _....._..,.... ...,W..._ 6016000 .........:...__...,.,, ...,..._, ._, ? x ~ ,.........__,._.,,m„„.~p_._..n._... ~ ............,........., ...~..........°___.__ ......___....._.._...,.. 6015000 ...... ...,... .....„._....+ i a ,_.,......~..,..„.fie .,...... s--....._._......._.._-» _.,..~., ....._., w. 6014000 t .,..,...... ..... _ ~ _ ,.. _ i ..m..._°.6 _.__ ............._.., _ , 6013000 _ 1 6012000 . _--. -'.~.""...,_- -°-".""5 w`~."""" _ - ~ I "- .. _. .___ ._W ~..., ,_..._...,....,. ~ ~ _._ .. _..e...~I i ._...__.. ..... . ...___..x ._... ...._,.. ........ ~ ._._..~._ _........ 6011000 i i ~ ioloooo !009000 !008000 !007000 1006000 1005000 5004000 1003000 :mm~nn ~ ~ ~ o ° ° ~ ~ Vertical Section along "View VS Plane" Combo Preview Page 1 of 1 (CD3-107Awp01 Toolbox.xls) 7000 0 g 2/13/2008 1:36 PM • Closest in POOL Closest Approach: Reference Well: CD3-107Awp01 Plan Offset Weil: CD3-108 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS Distance. Depth Angle TRUE Azi. ND E(+)/W(-) (324°) Comments Depth Angle TRUE Azi. ND E(+)!W(-) (324°) Comments POOL Min Distance (1794.43 ft) in POOL POOL Min Distance (12900 - 19306.59 (1794.43 ft) in POOL MD) to CD3- (12900 - 19306.59 107Awp01 Plan MD) to CD3-108 (690 (6900 - 6958.79 1794.43 17175 91.02 322.77 6942.07 6011728 1533417 3693.88 - 6958.79 TVDss) 12027.12 92.84 322.87 6942.46 6010668 1531970 3652.43 NDss) est Approac h: Reference Well: CD3-107Awp01 Plan Offset Well: GD3-107 Coords. - Coords. - ASP ASP r-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS ' t ce. Depth Angle TRUE Azi. ND E(+)/W(-) (324°) Comments Depth Angle TRUE Azi. ND E(+)IW(-) (324°) Comments POOL Min Distance (1.58 ft) in POOL POOL Min Distance (12900 - 19306.59 (1.58 ft) in POOL MD) to CD3- (12900 - 19306.59 107Awp01 Plan MD) to CD3-107 (690 (6900 - 7030.77 1.58 12900 90.64 330.3 7005.047 6008286 1535945 -575.9721 - 7030.77 NDss) 12898.12 90.65 330.37 7004.76 6008285 1535944 -576.19 NDss) Closest Approac h: Reference Well: CD3-107Awp01 Plan Offset Well: CD3-307 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS Distance. Depth Angle TRUE Azi. ND E(+)/W(-) (324°) Comments Depth Angle TRUE Azi. ND E(+)/W(-) (324°) Comments POOL Min Distance (391.53 ft) in POOL POOL Min Distance (12900 - 19306.59 (391.53 ft) in POOL MD) to CD3- (12900 - 19306.59 107Awp01 Plan MD) to CD3-307 (690 (6900 - 6994.29 391.53 12900 90.64 330.3 7005.047 6008286 1535945 -575.9721 - 6994.29 NDss) 13030 89.26 341.93 6994.287 6008246 1536334 -832.5147 TVDss) CD3-107Awp01 PoolSummary.xls 2/13/2008 1:49 PM • CD3-107Awo01 Surface Location: ___,. __. _. I r- E`t CPAI Coordinate Converter l~,' __ _ ___ °Frain ___.__ - _.~ .__ __.. 1i _ __ I Datum: t~1~D83 - : R -'~1O'r~ alaska ~ .rakufr5; Fd.~D~7 ~ Fegiort: alaska ~' i' ,.. ~ .~ -. , iatrt~.~,je, ~ -riq;ti~de ~Geara,~! G _g;ces ~ LatAude; L-~nituds De.~irna(DegfPes ±~ t~ ~iTAd ~~u~e' ~~ ~ South ~ ~`~ UTM ~~~p' ~True~ ~ Suuth is Stage?lane ~~~r,r ~."~- Uerits~ us-k ~ ~ ~ ,.StareFlarie ~ana.l"~ .~..:.! Unit~_ usdt ~ .-~_.~ a: Legal D,A~,-7ipricn'+ I~IbL~~7 er~y~ bra. i_ 7 ~~o~ ~rdrcia?c~ ~~ -, Le}~aI DeSGrip~ie~n -_ °2$378.93 ~ rF C~12 N ~ R ~n t ~- ~ 1 Town>h' : ~ 9===~35 E ~- , ~~' 6t703594.~0..~_~ ~ ~ Meridian_~ ~ ~, ,-~r,~,~.r~---'" ~FNL ~ 3826.32t>¢ FEL ~ X96 r h; Transform Q~.rit Nell ~., CD3-107Awp01 Intermediate Casing Point: _ __ f=~ CPAI Cootdinate Convener -~~~C~`,,,,~,,~'; m _ s _ - ~: ~~ .-`From---- - - - -T~,:----- -- - -- -- ' ^a`'r"' NAD83 Regan: alaska ~ ' Datum: P~AD27 ~ Rayicrr alaska ~~ ~"` Lahrude l .r~7uud£ Gecirnal Degrees ~~ ,, ~` Lat~t~elt.~ngitude De~:ima[ Degrees j - i ,__ 'JTf;q ~~,r~; -'~ ~"' South ~"` LrTM ~~P. Tfug ~ _~~ul{ ~~ j _~ ~: ~.~ie Plane ~crre; 4 ~ `~ ilrnts. ~us-h ~~ 5°~Fe Plane La`~e: q ~ Urr+s: lus-it ~' ~^ Lehi Da>cr~ptic+n [~i~D2i r-,ly ;~,3,~~gGar?r~r~ate: _~_-___- LegalT~?sc.~~~ ~~ ,~536tt9.36 7 „~~~,i, II12 N ~ Range: X005 ~E ~.; 6d0729~.0~ t•~terid~.3n_ ~ ~ ~ Section:~.._~ ____. _ , ~ r- -- ,___ ~' ~ _ Ft~IL ~ 173.737 ~FE~ -, I "Fiit_~L` °-- : i 3 .. .,.. ` _ ..Trap forr ~ ~ (quit f Ft~J~, ~ j I _ _ - ----------~ ORIGINAL • CD3-107Awp01 Kick off Point - ~ __ CF1A1 C+iot dinnte Converter - i' ~ ~ Frorr. _ _ __ ~_ ~ _ ~ ~' (' [~,yt UCC: pt (;._;^ ~ i -.7i~=~'Y. 81~3£~d ~. 1~8;Uftl ~( 1.! ~~ ~ ~''iEQi4Ti: ~f:;~a r r' Lut:tude.'L;~:.~itude QecimalDegrees ~ r' Ld~~rude''Longitude Decim~l?egrees ~~~ '; J "~ IJTM __~~~ ~ S ~~r, a~ !!'ip4 gone True ~ S~iut;~: i ~ ~ ;rate Plane Z~y ~e (e ~ Uniis, us-fit ~ t ` St -r~ P'~onr~ ~_,ne j~ ~ Units_ u~-ft ~~ --~ ; y ~ I ~tartirrgGoord~-+cte, _ Le~alDescription~ - _- 1x35942.16 e~ 1'at~~nshi~+_ 913 hd ,~ Range_ ~ E ., i faJ082ff5.80 ~~ ~'~~~dicr+. ~{ 6~n ~ i^^~'~_ ~FNL ~ 440A.A0~ FEL ~ 711t88&2 i .. _... Tr.~nsturm~ Ouit He(~ CD3-107Awp01 TD: . _. ' ~~ CPAI Coordinate Converter _ ~~ -From: - - - - ~ ~: - - - --- - --- I C+~7t~7rr• N~,~193 ~ P ~"'n` ~.31as~ka~~--~ datum I3.~C~22 ~ ~r~ ;alaska i _ I i_ainade.,'l ;r laude Decnnal Degrees ~ C_atitude/[_ongitude ~~-~n~ D~~ees ~'.1 iJTt:.~ gone ~ ~."' SnutFi '` UTp~ ~~rn,_ 'TruF ~ ~--'utE; .. __ ~•' S~a~e Plane ~onF: ~ Ur~NS ~us.R ~ ~'~ State ~'I~ne gone: ~~ ~~nit~: }u tf -, ~, _._ Legal E~,r.~_npsn-~~t [1~ACt2i ur~Iy~ ~ ,, ~~fd7f:r.7 i. G?d ~.jrt-i 9I8 t5325~9.62 ~ - 1l ~i~ Lull?escnpticat ___ TQYVfLStt~: ~~1'S N ri FiBngE'_ ~OQJ ~~ Meru: U ~ SeGtion:2g ~~ 1~L ~ 439 2Q5t~ FE! ~ - 45.6737 j Ttan~furrr~ ~ Quit ~ Helr i ORIGWAL Office Project 7 April 2008 INPUT State Plane, NAD83 5004 - Ala~ca 4, U.S. Feet OUTPUT • / State Plane, NAD27 5004 -Alaska 4, U.S. Feet Accuracies of conversions from NAD 83 to NAD 27 are tyµcaNy 72 to 78 cm. 1 /1 Northing/Y: 60035 94.3 8 Easting/X: 152 827 8.93 NOrthing/Y: 6003 8 4 7.16 9 Easting/X: 38 82 4 7.019 Convergence: -0 51 38.65516 Scale FBCtOr: 0. 9 9 9 914 2 8 6 Convergence: -0 51 27.94168 Scale Factor: 0. 9 9 9 91418 7 Grid Shift (U.S. ft.}: X/Easting = -1140031.9, YlNorthing =252.8 Datum Shift (m.): Delta Lat. =36.126, Delta Lon = -118.256 • Remark: Corpscon v6.0.1, U.S. Army Corps of Engineers ,~-vU C~ Galiunas, Elizabeth C • From: Davies, Stephen F (DOA) [steve.davies@alaska.gov] Sent: Thursday, March 20, 2008 2:11 PM To: Galiunas, Elizabeth C; Maunder, Thomas E (DOA) Cc: Saltmarsh, Arthur C (DOA); Anderson, Nina M Subject: RE: Naming Question on CD3-107 Liz, Since the some of the Nechelik from the existing CD3-107 well bore will be open to production, I think the clearest way to segregate records from the new wellbore segment is to name it CD3-107L1. Please let me know if I can help further. Thanks, Steve Davies AOGCC From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophillips.com] Sent: Tuesday, March 18, 2008 10:55 AM To: Davies, Stephen F (DOA); Maunder, Thomas E (DOA) Cc: Saltmarsh, Arthur C (DOA); Anderson, Nina M Subject: RE: Naming Question on CD3-107 Steve, Sorry it has taken so long to get back to you. I want to clarify our proposed operations for CD3-107 redrill and make sure we are naming the wellbore correctly. We have evidence that a shale section in the Nechelik open hole horizontal collapsed (see attached x-section and well operation summary below). Attempting to clean out the collapsed lateral and run a liner has risks and time is short with CD3 being a winter only access pad. When Doyon 19 returns to the well in April, the proposed plan is to pull the packer/tubing and redrill the lateral by open hole sidetracking at approx. 12,900' MD in the original horizontal hole. The redrill directional plan parallels the original borehole with approx 50 feet of separation, and the planned TD is 1000' deeper. A pre-perfd liner will be run to facilitate future frac options. Since the open hole sidetrack will be in zone off an existing horizontal would the name be CD3-107L1 or CD3-107A? Here is the sequence of events for CD3-107 showing how the Nechelik lateral is isolated with fill. We can provide anything else you would need to prove the lateral for CD3-107 has collapsed. We also intend to complete the well for a frac that would impact the new lateral, to not risk opening the CD3-107 lateral. SEQUENCE OF EVENTS (:IGINAL 4/3/2008 • a 2!2812007 7:00 Do yon 19 completed comrerting CD3-307 Kuparuk producer do CD3-107 hlechelik producer. 3 1712 007 0:30 S farted CD3-107 Ne chelik flowback. 3!$12007 6:30 CD3-107 rate started precipitous fall off. 3!912007 7:15 Shut in. Final mte -300 $OPD lifting at veryhigh GLR. 3! 1012007 Pum d 50 bbl down tubin , tubi ssured u to 2500 i at a nd of 3!1812007 15:00 SL: Drifted 2" to 11623'RKB (below tubing tail at 10914RKB.} Too Ls stopped 74 degree incline in 7"casing. POOH w! emptybailer. 3!3012007 Coil: Tagged up 13,242' CTMD with 2" down jet naxzle. Unable to pass abstraction with said ottom !vole a quipment. No overpull witnessed. S uggest Displac ed well ave r to diesel while POOH. Depth of obstruc tion corresponds to depth drilling exited sand into upper shale. 4/3/2007 Restar6ed production testing with C D3 test separator. Approximatelyone tubing volume produced to surface on gas lift. 4/512007 9:27 Concluded produ,ctian testing via C D3 se pastor and shut in. No liquid flow to surface while circulstin as lift down IA and u tub' .Conclude welIbore calla ed at -13200' MD. Let me know if you need any additional information. Thanks, Liz Galiunas Drilling Engineer Alpine Drilling Team Conoco~illips Alaakn ATO.-1704 Office: (907~265r6247 Cell: (907)•44.1.-4871 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Friday, March 07, 2008 5:35 PM To: Galiunas, Elizabeth C; Maunder, Thomas E (DOA) Cc: Saltmarsh, Arthur C (DOA) Subject: RE: Naming Question on CD3-107 Liz, There is no clean answer to this one. Since the Kuparuk and Nechelik sandstones are in pressure communication within the Fiord Field, AOGCC assigns them to a single oil pool, the Fiord Oil Pool. The 300 series numbers denote Fiord wells within the Kuparuk sandstone, and 100 series numbers denote Fiord wells within the Nechelik sandstone. This well was originally a Kuparuk well (CD3-307, PTD 206-046, API 50-103-20529-00-00) that was subsequently deepened to the Nechelik. Deepening the well required a new permit to drill (number 206-189), and since the well was. being redrilled to the Nechelik, the well was renamed CD3-107 and given a new API number of 50-103-20529-01-00. We couldn't call the deepening CD3-307A, because it was being drilled to the Nechelik. In retrospect, maybe we should have ~~~ 4 2008 named the deepened wellbore CD3-1• , but at the time I thought that name would cause too much confusion. It seemed like CD3-107 was the best name for the deepened wellbore. Now, I'm assuming that ConocoPhillips will plug and abandon the pay zones within CD3-107, before redrilling to a new target in the Nechelik. So long as nothing is left open in the existing CD3-107 wellbore, the best approach is to name the new wellbore CD3-107A and give it an API number of API 50-103-20529-02-00. AOGCC will assign this new wellbore a new permit to drill number. In the future, people will be confused by what appears to be a mistake in naming or numbering, but I think it would be more confusing to give the new wellbore the name CD3-1076. Then people would just wonder why there wasn't a "CD3- 107A" wellbore. Copies of this email will be placed in the CD3-307, CD3-107 and CD3-107A well history files to help clear up any confusion. Thanks, Steve Davies AOGCC From: Galiunas, Elizabeth C [mailto:Elizabeth.C.Galiunas@conocophillips.com] Sent: Friday, March 07, 2008 12:07 PM To: Davies, Stephen F (DOA) Subject: Naming Question on CD3-107 Hi, Steve, We are getting ready to submit a sundry and a new permit to drill for CD3-107. Here is a brief description for the sundry and the new permit to drill . I need some guidance on naming. ConocoPhillips Alaska drilled CD3-107 (PTDs#: 206-189 & 206-046 API 50-103- 20529-00/01). After drilling the first thousand feet of the lateral, the Nechelik sand was exited into the shale above (between 13200' MD-13500'MD). After 13500'MD the lateral continued in the Nechelik sand to a TD of 18315' MD. Once the well was handed over to production, the shale section collapsed and the Nechelik horizontal would not produce. It is believed that the basal Nuiquist collapsed, filling the lateral, preventing any production from the Nechelik. The well was perforated in the Kuparuk sand above the Nechelik, and has been producing out of a short section of perforations for around a year. The asset would like to return to this well, decomplete it, sidetrack off the existing lateral at 12,900' MD, and redrill the Nechelik lateral to a TD of 19306' MD. Since returning to the well is a re-entry, planned sidetrack/re-drill the well should take on a letter (I.e.CD3-107A?), but since this well was also CD3-307 (API 50-103-20529- 00) I am not sure what the API or name would be for the re-drilled section since -01 is taken already. Would we name it B and -02? attached a schematic to help visualize the currentwell and proposed work. I do not have Jim Regg's information to send this to him also since Tom is out of the office. ORIGINAL 4 2008 Regards, Liz Galianas ding Engineer Alpine Drilling Team ConocoPhillips Alaska ATO~I704 Office: (907).-265-6247 Cell: (907~441.A~II71 OR~6INAL i 4 2008 TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ G1.~ ~ _ ~~ ~ L PTD# ~~ ~~~- S I t° _ °~ Developments Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~\'~`~~\~-~~~~ POOL: ~~~ ~ ~ ~ ~dU 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 ~/G l~ ~'Z~ ~ - /~ '7 (If last two digits in permit No. ~'~.~ ~~ L:% ,API No. 50- /~% - ZC ~Z ~ - Z} . API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any ~otest 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 throu h tar et 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 (Comaanv 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 wel! testing ro am. Rev: I/1 t/2008 WELL PERMIT CHECKLIST Field & Pool COLVILLE RIVER, FIORD OIL -120120 Well Name: COLVILLE RIV FIORD CD3-107L1 Program DEV Well bore sag ~ PTD#:2080510 Company ~~NOCOPHILLIPS ALASKA INC Initial ClassRype DEV! PEND GeoArea 890 Unit 50360 On/off Share ~ Annular Disposal ^ Administration 1 Perm+tfeeatlached - - ----- -- - - - - ---- --- NA - - ---- - -- -- ----- ------- - --- - -- -- --- - - 2 Lease number appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No- - _ _ _ _ _ Cgrtected omission qn 10.407:_sr~d iocinAOL 3721 Q5; top prod int inADi_ 372104;-prgd-int-passes thru _ _ - . _ _ 3 Uniquewell_nameandnumber__________---__----------- ---------Yes---_ _ADt,364471;TDin_ADL_364472,-----------------------------------.----- _.--- 4 Welllgcatedin-adefinedAggl______________________.____ __-______Yes______ _COI.VILLE_RIVER,-FIORQOIL-•12Q120,-governed byCO-562._------__-__-___-___-_-._____ 5 Wflll located proper distance f[om drilling unitboundary_ _ _ _ _ - - _ - _ - _ _ _ _ _ _ _ _ Yes _ - _ _ _ _ Cgnservation Order Nq. 562 contains no spacing restrictions wkh respecttq drilling unit boupdaries. _ _ _ _ . _ 6 Wflll Igcated proper distance from ether wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ - _ _ Yes _ _ _ . _ _ Cgnservation Order Nq. _552 bas,nq intenvell-spacingresirictigns. _ _ - _ _ - . _ _ _ _ _ - _ _ _ _ _ - _ _ _ - _ _ _ 7 Sufficientacreage available in dritling unit_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ Cgn_servation Order Nq._552 bas-no intenveltspacingresirictigns, WeUbore will be mgrs than 5Qt)' from _ _ _ - _ _ _ 8 If deviated, is.welWore plat-included _ _ _ _ _ _ - _ _ _ _ _ - _ _ _ _ _ - - _ ..Yes _ - . _ - _ _ external property line where-ownership ct lando~rnershipehanges._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ - _ _ _ 9 Operator onlya[factadparly------------------------------ ----------Yes------ -NlslllieseMirelyWifhinColvil(e_RiverUnit.-.----------------------------------------- 10 Operatotbas-aPpropflatebondinfgrca- -- ---- -- - .- - ---- ---Yes---- -- - -- --~ ----- ---------- ------ -- -- ----- -- ----- -- 11 Pear}itoanbetssuedwithqutgonsen!atigngrder------------------ ---- -----Yes------ ----.--------------------------------------------------- - - --- Appr Date 12 Permitcanbeissuedwithouiadminisirathte_approval--------------- ----------Yes.----- --------------------------------------------------- ------- ----- 13 Canpermilbeapprovedbefgrel5•dal!wait_..---- -- - - - -- --- Yes--- -- --- -- -- - -------- ---------- -- -- - -- - - --- SFD 4812008 14 Well Igcated wtthin area a~ strata authgrzed by_ Injection prdet # (pqt-10# in-comments) (Fgr- Yes _ _ - _ _ _ . AIO-30, issued ,luly 25, 2Q06_ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 A-Ilwells+~ithinl(4_roilear~ofreyiewidentified(Focservicewellonly)---- ---------- NA------- ------------------------------------------------------------------ 16 Pre-producadinJectgr:duration_ofpre~roductiontessthan3montbs-(FgrservicewellgNy)__-NA------ ----------------_------------------------------------- -- ----- -- 17 Kongonven,gas.confgrms to AS31,05,03Q(1.1.A)~(1.2.A•D) - - - - - - - - - - - - - NA- - - - - - - - - - ~ - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - Engineering 18 Conductorst[fng_ptgvided_______-_--_----------------- -----------NA__._._ _CgndpqiqrsetinCD3.3Q7(2Q6•Q46).----------------.-.-----.-------._----.----- 19 Surface casingprgtectsallkngwnUSDWS_------------------- -----------N~------ -Ngaquifsrs,AIQ16A,_conelusions.--------------.--------.----------------------- 20 CMT_voladequatetgcirculate_onc~ductgr8,surf-csg_--___------- -----------KA---- - -Surface casing sat in CD3.307,-----------------..--------.-------------------- 21 CMT_voladequaietgtie•hrlgngstringto_surfcsg------------------ --------- NA_.----- -Long string set inCl)3r307._---------.--------------------------------------- 22 CMT-vrillcovera)Iknown_producthreborizvns____________________ _______---No------- -Pre-pertoratedpipe tobausedtglinelaterah--------------..------------------------ 23 Casing desigDS adequate fqr. C, T 9_&permafrost_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ . _ _ _ - - . Qriginat well-met design spaciflcations.. NAfor perfect finer, - - _ - - - - - - - - - - _ _ _ _ _ - _ _ _ - . _ _ _ _ _ . _ _ _ 24 -Adequate tankage-or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes - _ _ _ _ _ _ Rig equipped with stefll pis, No reserve pit planned._ All waste_tq apprgved annuli.- - - - - - _ - - _ _ _ _ _ _ - _ . _ 25 Ifa_rs•dtilGhas_a10_•40$forabandgnmentheenapprgved----------- ---------Yes------ -308.124,--------------.----------------------------------------------- 26 Adequate wetlkore separationpl'opgsed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Ye& _ _ _ _ _ _ _ Traveling cylinder path ealculated._ Nearest segment is gollaps8d portion of C43.1Q7 and paths dikerge, _ _ . - _ _ 27 If dive[terlequired,doesttmeetreguJatigns_____________________ __________KA------- -BOPStackwillalready_belnRlaoe,_.___._-_________-__-___...------------------- Appr Date 28 Dtitlingfiuid-program sohematic-& equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ . _ _ _ _ _ Maximum expected fgrmatign pressure 8,7. EMWt MW pl2nned up to 9,3_ppg.- - - - . _ _ _ - - _ _ , _ _ _ _ _ _ _ _ TEM 4Rl2008 29 BOPEs,doiheymeetregulation ---- ---- - - -- - -------- Yes-- -- --- - ----- -- - ---- - ------ ------ - - ----- ---- X 30 BOPE_pres9 rating appropriaie;l8sito-(put psig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ - _ _ _ _ _ _ _ . SOP testplanned< _ _ _ _ _ _ _ .. _ _ _ _ _ _ . _ MASP calculated at 2493psi, 3500_psi . _ _ _ _ _ . ~yvf~ 31 Choke_manifgldcgmpliaswlAPLRP-53 (May 84}----- ------------- ----------Yes------ _ = _ _ -----.-- 32 Work willgcourwithoutoperatianshutdown -- -- - ---- -- ---Yes --- - - -- ---- ----- ------ ------- ----- - --- - --- - - 33 Is presence ofH2Sgasprgbable_------------------------- ---------- No---___ _H2$isnoi_reRottadinCRU, Rig_hassensgrsendalarms.---._____-____--____-__-___--- 34 -Mechanicatconditiongfwel~withinAORyerified(F9rservicawellgnlya---- -----NA------- ----- -----------------.-------------------------------------------------- Geology 35 Pe[mitean be issued w1o hydrogen_sutfiderneasures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ Ngne expected,_butH2$ andgas detectors will be used during drilling, Mitigation in Hazards Summary,- - _ - - - - 36 Data_plesented on potential overpressure zones- - - - - - - - - - - - - - - - - - - - - - - - - - -Yes _ - _ _ _ _ Expected gradient is 8,7_pAg EMV~I; will be drilled witb 2.D - 2.3Ap9 mud,- _ - - _ _ _ _ _ - - - - - - - - _ _ - - - _ - Appr Date 37 Seismicanah~sisgfshallo+Ngaszgtres---- -- - -- --- -- - ----- NA-- --- ---------------------- -- - -- -- -- ----- ------ ------- - SFD 41712008 38 Seabed-conditions~niey_(ifgti~•shore)- -- - - -- -- - -- -- NA' ---- ----- ---- - --- - ----- ------ -- --- ----- ---- - 39 Cgniacinamelphonefotweekly-Rrggressrepcrtslexploratgrygn~]---_-- ---------- NA------- ----------------------------------------------------------------- Geologic Commissioner. g Date: Engineerin Date I~ om ' o C o Date ~j ~, ~-~-~~ ~ ' - / ~ 4^~ o~ C1 Welt History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronofogicaliy organize this category of information. i ~ cd3-10711.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri May 16 15:04:42 2008 Reel Header Service name .............LISTPE Date . ...................08/05/16 Ori 9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................08/05/16 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Physical EOF comment Record TAPE HEADER Colville River MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 W-0005700040 E.QUAM L. HILL SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD '~~~-~ scientific Technical services Library. scientific Technical services CD3-107 L1 501032052960 ConocoPhillips Alaska Inc. Sperry Drilling Services 16-MAY-08 MWD RUN 2 W-0005700040 E. QUAM D. LUTRICK 5 12N 5E 3926 797 49.61 13.20 Page 1 ~~~~ ~ r~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: cd3-10711.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 11874.0 ~~ 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL IS AN OPENHOLE SIDETRACK, EXITING CD3-107 AT 12973'MD/6926'TVD. 4. MWD RUNS 1,2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), GEOPILOT ROTARY STEERABLE BHA (GP), AND PRESSURE WHILE DRILLING (PWD). 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1-2 REPRESENT WELL CD3-107 L1 WITH API#: 50-103-20529-60. THIS WELL HAS A TOTAL DEPTH (TD) OF 19482'MD/6926'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 Service sub Level Name... Page 2 version Number. ........1.0.0 Date of Generation.......08/05/16 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD FET RPS RPM RPX ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 12915.0 12922.0 12922.0 12922.0 12922.0 12922.0 12973.5 STOP DEPTH 19424.5 19431.5 19431.5 19431.5 19431.5 19431.5 19482.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD BIT RUN NO MERGE TOP MERGE BASE 1 12915.0 16292.0 2 16292.0 19482.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 cd3-10711.tapx Page 3 cd3-10711.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12915 19482 16198.5 13135 12915 19482 RPD MWD OHMM 3.31 1763.71 11.9056 13020 12922 19431.5 RPM MWD OHMM 2.5 1764.34 11.2279 13020 12922 19431.5 RPS MWD OHMM 1.96 1762.86 10.3924 13020 12922 19431.5 RPX MWD OHMM 1.5 20.64 9.00667 13020 12922 19431.5 FET MWD HR 0.38 38.46 1.21431 13020 12922 19431.5 GR MWD API 36.66 131.46 56.7514 13020 12915 19424.5 ROP MWD FPH 0.62 142.72 87.6159 13018 12973.5 19482 First Reading For Entire File..........12915 Last Reading For Entire File...........19482 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/16 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 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 GR 12915.0 16234.0 FET 12922.0 16241.0 RPx 12922.0 16241.0 RPS 12922.0 16241.0 RPM 12922.0 16241.0 RPD 12922.0 16241.0 ROP 12973.5 16292.0 LOG HEADER DATA DATE LOGGED: 22-APR-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory Page 4 C~ TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: cd3-10711.tapx 16292.0 12973.0 16292.0 88.3 92.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232602 EWR4 Electromag Resis. 4 228502 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 11874.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S): 42.0 MUD PH: 9,0 MUD CHLORIDES (PPM): 7 FLUID LOSS (C3): 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .140 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .060 176.0 MUD FILTRATE AT MT: .000 70.0 MUD CAKE AT MT: .180 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 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWDO10 OHMM 4 1 68 4 2 RPM MWDO10 OHMM 4 1 68 8 3 RPS MWDO10 OHMM 4 1 68 12 4 RPX MWDO10 OHMM 4 1 68 16 5 FET MWDO10 HR 4 1 68 20 6 GR MWDO10 API 4 1 68 24 7 ROP MWDO10 FPH 4 1 68 28 8 Page 5 cd3-10711.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12915 16292 14603.5 6755 12915 16292 RPD MWDO10 OHMM 3.31 18.47 10.6461 6639 12922 16241 RPM MWDO10 OHMM 2.5 18.54 10.1912 6639 12922 16241 RPS MWDO10 OHMM 1.96 19.28 9.53441 6639 12922 16241 RPX MWDO10 OHMM 1.5 14.86 8.49977 6639 12922 16241 FET MwD010 HR 0.38 8.42 0.841322 6639 12922 16241 GR MwD010 API 40.16 131.46 57.0907 6639 12915 16234 ROP MWDO10 FPH 0.62 142.72 101.816 6638 12973.5 16292 First Reading For Entire File..........12915 Last Reading For Entire File...........16292 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/16 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF File Header service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/16 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY header data for each bit run in separate files. 2 .5000 VENDOR TOOL CODE START DEPTH GR 16234.5 RPx 16241.5 RPD 16241.5 RPM 16241.5 FET 16241.5 RPS 16241.5 ROP 16292.5 LOG HEADER DATA DATE LOGGED: SOFTWARE STOP DEPTH 19424.5 19431.5 19431.5 19431.5 19431.5 19431.5 19482.0 26-APR-08 Page 6 • cd3-10711.tapx SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 19482.0 TOP LOG INTERVAL (FT): 16292.0 BOTTOM LOG INTERVAL (FT): 19482.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.8 MAXIMUM ANGLE: 95.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUM BER DGR DUAL GAMMA RAY 232602 EWR4 Electromag Resis. 4 228502 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 11874.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S): 44.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 52000 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .120 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .050 180.0 MUD FILTRATE AT MT: .700 70.0 MUD CAKE AT MT: .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 .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 offs et chann el DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 Page 7 cd3-10711.tapx FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MwD020 FPH 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 16234.5 19482 17858.3 6496 16234.5 19482 RPD MWD020 OHMM 4.56 1763.71 13.2159 6381 16241.5 19431.5 RPM MWD020 OHMM 3.63 1764.34 12.3065 6381 16241.5 19431.5 RPS MWD020 OHMM 2.66 1762.86 11.285 6381 16241.5 19431.5 RPX MWD020 OHMM 1.72 20.64 9.53407 6381 16241.5 19431.5 FET MWD020 HR 0.46 38.46 1.60239 6381 16241.5 19431.5 GR MWD020 API 36.66 126.86 56.3984 6381 16234.5 19424.5 ROP MWD020 FPH 0.62 136.18 72.841 6380 16292.5 19482 First Reading For Entire File..........16234.5 Last Reading For Entire File...........19482 File Trailer service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/16 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/05/16 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 . ...................08/05/16 Ori 9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF scientific Technical services Page 8 End Of LIS File • cd3-10711.tapx Page 9