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206-157
ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 10, 2020 Commissioner Jesse Chmielowski Alaska Oil & Gas Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jesse Chmielowski: RECEIVED Mpl,'Y 13 2020 AOCCC Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement/sand if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement/sand was installed April 215f thru April 24`h, 2020. The corrosion inhibitor/sealant was pumped on April 22°d thru April 25`h, 2020. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerel !, � Roger Winter ConocoPhillips Well Integrity Field Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Alpine Field Date 5/10/2020 CD2, 3, 4 & MT6 Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement/Sand top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal CD2 -02 *501032051300 2051090 30" 14 gals 9" 4/24/2020 1.5 4/25/2020 CD2 -73 *501032059000 2081960 11" 1 gal 6" 4/24/2020 0.5 4/2512020 CD2 -468 *501032058700 2081800 11" 1 gal 7" 4/24/2020 0.8 4/25/2020 CD3 -111A *501032052601 2170040 14" 4 gals V. 4/21/2020 1.3 4/22/2020 CD3 -198 *501032063700 2110240 10" 10" 3 4/22!2020 CD4 -215 *501032053900 2061570 40" 28 gals 9" 4/23/2020 1.4 4/23/2020 CD4 -291 *501032067200 2131100 2r 80 gals 6" 4/23/2020 0.5 4/23/2020 CD4 -321 *501032053600 2061420 18.5' 4 gals 6" 4/23/2020 0.5 4/23/2020 MT6-02 *501032079200 2181600 30" 14 gals 8" 4/23/2020 1 4/24/2020 MT6-03 *501032077000 2180160 49" 32 gals 10" 4/23/2020 1.7 4/24/2020 MT6-04 *501032077500 2181080 24" 17 gals 8" 4/23/2020 1 4/24/2020 MT6-05 *501032077100 2180450 30" 10 gals 7" 4/23/2020 1.3 4/24/2020 MT6-06 *501032077300 2180930 25' 7 gals 8" 4/23/2020 1 4/24/2020 MT6-08 *501032077200 2180480 12" 2.5 gals 7" 4/23/2020 1 4/24/2020 MT6-09 *501032077900 2181340 34" 15 gals 9" 4/23/2020 1.5 4/24/2020 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: WHIPSTOCK Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 14,761 feet None feet true vertical 6,205 feet None feet Effective Depth measured 14,675 feet 8,205 feet true vertical 6,212 feet 5,856 feet Perforation depth:N/A feet N/A feet Tubing (size, grade, measured and true vertical depth)3.5 ''L-80 9,380' MD 6,197' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER PREMIER PACKER 8,205' MD 5,856' TVD SAFETY VLV - CAMCO TRMAXX-5E 2,142' MD 1,925' TVDMD12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: James Ohlingerr Contact Name:Ryan McLalughlin Authorized Title:Staff CTD Engineer Contact Email:Ryan.McLaughlin@cop.com Contact Phone:907 265-6218 3. Address:P. O. Box 100360, Anchorage, Alaska 99510 50-103-20539-00 8. Well Name and Number:CRU CD4-215ADL 380077, ADL 384209, ADL 388902 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name:ConocoPhillips Alaska, Inc.4. Well Class Before Work: 5. Permit to Drill Number: 206-157 Packer measured true vertical Casing Length Size MD TVD N/A Colville River Field / Nanuq Oil Pool Plugs measured Junk measured Burst Collapse CONDUCTOR 77 feet 16 '' 114' MD 114' TVD INTERMEDIATE 9,480 feet 7 9,515' MD 6214' TVD SURFACE 2,817 feet 9 5/8 2,854' MD 2392' TVD LINER 5,314 feet 3 1/2 14,675' MD 6212' TVD N/A Representative Daily Average Production or Injection Data Measured depth: True Vertical depth: N/A -- -- 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure N/A -- -- Authorized Name: Authorized Signature with date: Senior Engineer: Senior Res. Engineer: Printed and Electronic Fracture Stimulation Data WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-101 GINJ SUSP SPLUG Gas Service Form 10-404 Revised 3/2020 Submit Within 30 days of Operations 4/20/20 4/21/2020 By Samantha Carlisle at 11:09 am, Apr 21, 2020 RBDMS HEW 4/21/2020 VTL 4/28/20 DSR-4/21/2020 SFD 4/28/2020 -00 CD4-215 Final CTD Schematic3-1/2" 9.3# VIT from 9380' RKB to surface3-1/2" 9.3# L-80 liner from 14675' RKB to surfaceCamco TRMAXX-5E SSSV @ 2142' RKB (min ID 2.812")3-1/2" VIT x 3-1/2" IBT XO @ 3997' RKBCamco KBMG GLMs @ 4355' & 8115' RKBBaker Premier Packer @ 8205' RKB (2.875" ID)HES XN Nipple @ 8283' RKB (milled out to 2.80")Locator/WLEG No-Go @ 9351' RKB (2.992" ID)HR Liner Setting Sleeve @ 9361' RKBBaker RS Sealing Nipple @ 9374' RKBBaker Flex Lock DG Liner Hanger @ 9378' RKB9-5/8" 40# L-80 shoe @ 2854' MD7" 26# L-80 shoe @ 9515' MD16" 65# H-40shoe @ 114' 3-1/2" Liner shoe @ 14675' MDKOP @ 9602' MDCD4-215L1 TD @ 10,854' MDSlotted Liner 9570-10,853' MD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: 10,800.0 7/11/2008 CD4-215 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Mill XN 1/24/2020 CD4-215 boehmbh Casing Strings Casing Description CONDUCTOR 46" Insulated OD (in) 16 ID (in) 15.25 Top (ftKB) 37.0 Set Depth (ftKB) 114.0 Set Depth (TVD) … 114.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 36.8 Set Depth (ftKB) 2,854.2 Set Depth (TVD) … 2,392.1 Wt/Len (l… 40.00 Grade L-80 Top Thread Buttress Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 34.6 Set Depth (ftKB) 9,514.5 Set Depth (TVD) … 6,214.1 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description LINER OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 9,361.0 Set Depth (ftKB) 14,675.0 Set Depth (TVD) … 6,212.3 Wt/Len (l… 9.30 Grade L-80 Top Thread SLHT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,361.0 6,194.6 81.41 SLEEVE "HR" LINER SETTING SLEEVE 4.420 9,374.0 6,196.5 81.60 NIPPLE BAKER "RS" SEALING NIPPLE 4.250 9,377.8 6,197.1 81.66 HANGER BAKER FLEX LOCK "DG" LINER HANGER 4.400 Tubing Strings Tubing Description TUBING VITxNORMAL String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.4 Set Depth (ft… 9,379.6 Set Depth (TVD) (… 6,197.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.4 31.4 0.14 HANGER FMC TUBING HANGER 4.500 44.8 44.8 0.20 XO-Reducing 4.5"x3.5" 3.500 2,142.2 1,925.2 48.83 SAFETY VLV CAMCO TRMAXX-5E #HYS-405 2.812 3,996.9 3,164.1 45.37 XO VITxIBT CROSOVER FROM VACUUM INSULATED 3.5" TBG INSIDE 4.5" TUBING TO NORMAL 3.5" TUBING 2.992 8,204.5 5,856.5 63.33 PACKER BAKER PREMIER PACKER 2.875 8,282.5 5,890.6 64.57 NIPPLE HES 'XN' NIPPLE @ 64 DEG. 2.75" Milled to 2.80" 2.800 9,350.6 6,193.0 81.28 WLEG LOCATOR/WLEG FLUTED NO GO 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 9,600.0 6,221.8 84.91 WHIPSTOCK - THRU TBG 3-1/2" Monobre XL Whipstock 1/18/2020 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,501.0 9,712.0 6,212.8 6,233.9 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots 9,555.0 9,575.0 6,217.9 6,219.7 4/22/2007 6.0 APERF 2.5" Hyperjet Charges, 60 deg orient 10,550.0 10,733.0 6,231.1 6,219.1 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots 10,857.0 11,039.0 6,217.5 6,227.0 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots 11,566.0 11,627.0 6,246.6 6,244.2 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots 12,184.0 12,730.0 6,219.1 6,214.5 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots 12,852.0 13,395.0 6,218.7 6,225.0 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots 13,549.0 13,638.0 6,234.2 6,240.3 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots 13,793.0 14,280.0 6,248.4 6,246.9 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots 14,342.0 14,403.0 6,243.1 6,238.8 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots 14,497.0 14,673.0 6,230.9 6,212.5 11/23/2006 16.0 SLOTS Alternating solid/slotted pipe w/0.125" x2 .25" slots Frac Summary Start Date 4/25/2007 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 4/25/2007 Top Depth (ftKB) 10,550.0 Btm (ftKB) 14,673.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 4,354.5 3,420.5 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.188 1,600.0 11/12/2019 2 8,115.1 5,814.6 CAMCO KBMG 1 GAS LIFT OV BK-5 0.250 0.0 11/12/2019 Notes: General & Safety End Date Annotation 12/5/2009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Horizontal, CD4-215, 4/17/2020 3:08:00 PM Vertical schematic (actual) LINER; 9,361.0-14,675.0 SLOTS; 14,497.0-14,673.0 SLOTS; 14,342.0-14,403.0 SLOTS; 13,793.0-14,280.0 SLOTS; 13,549.0-13,638.0 SLOTS; 12,852.0-13,395.0 FRAC; 10,550.0 SLOTS; 12,184.0-12,730.0 SLOTS; 11,566.0-11,627.0 SLOTS; 10,857.0-11,039.0 SLOTS; 10,550.0-10,733.0 SLOTS; 9,501.0-9,712.0 WHIPSTOCK - THRU TBG; 9,600.0 APERF; 9,555.0-9,575.0 INTERMEDIATE; 34.6-9,514.5 WLEG; 9,350.5 NIPPLE; 8,282.5 PACKER; 8,204.5 GAS LIFT; 8,115.1 GAS LIFT; 4,354.5 SURFACE; 36.8-2,854.2 SAFETY VLV; 2,142.2 CONDUCTOR 46" Insulated; 37.0-114.0 HANGER; 31.4 L1; -1,283.4-0.0 WNS PROD KB-Grd (ft) 43.78 Rig Release Date 12/25/2006 CD4-215 ... TD Act Btm (ftKB) 14,761.0 Well Attributes Field Name NANUQ Wellbore API/UWI 501032053900 Wellbore Status PROD Max Angle & MD Incl (°) MD (ftKB) WELLNAME WELLBORECD4-215 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP Page 1/7 CD4-215 Report Printed: 4/15/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/16/2020 12:00 3/16/2020 16:30 4.50 MIRU MOVE RURD P Complete RD on CD4-214. 3/16/2020 16:30 3/16/2020 16:42 0.20 MIRU MOVE MOB P PJSM with Peak crew, 3/16/2020 16:42 3/16/2020 17:30 0.80 MIRU MOVE MOB P Jack service mod, pull mats and crab walk down the pad. 3/16/2020 17:30 3/16/2020 18:00 0.50 MIRU MOVE MOB P Crew change, tire check on sub 3/16/2020 18:00 3/16/2020 18:42 0.70 MIRU MOVE MOB P Jack sub, and pull off well 3/16/2020 18:42 3/16/2020 19:00 0.30 MIRU MOVE MOB P Reposition mats in between modules 3/16/2020 19:00 3/16/2020 20:18 1.30 MIRU MOVE MOB P Spot Sub over well - CD2-415 3/16/2020 20:18 3/16/2020 22:18 2.00 MIRU MOVE MOB P Spot inner service mats, crab walk service mod back to Sub, spot service mod, spot outer mats. off jack. 3/16/2020 22:18 3/16/2020 22:48 0.50 MIRU MOVE MOB P Complete spot up, drop landings and prep entrances / egress. 3/16/2020 22:48 3/17/2020 00:00 1.20 MIRU WHDBOP RURD P Work RU checklist. Extend PUTZ, connect steam to sub, 3/17/2020 00:00 3/17/2020 03:00 3.00 MIRU WHDBOP NUND P Work RU checklist, Extend PUTZ, connect steam to sub, stab stack, rig up PUTZ/interconnect, connect comms, grease valves, Swap out 4' (big tools) riser for 3' and harvest RKB's ***Rig accept @ 01:00, 0.0 0.0 3/17/2020 03:00 3/17/2020 06:00 3.00 MIRU WHDBOP RURD P Continue to grease valves, Start to inventory pits ( Pills 1&2 plus 3 with seawater, Pit 7 125 bbls Power Pro), Grease R7, reconfigure test joint, flood stack 0.0 0.0 3/17/2020 06:00 3/17/2020 09:00 3.00 MIRU WHDBOP BOPE P Prepare equipment for BOP test. 0.0 0.0 3/17/2020 09:00 3/17/2020 14:30 5.50 MIRU WHDBOP BOPE P Test 1. Swab 2 - fail Test 2. Blind/Shear, BOP TV2, Charlie 4, 5, 8, &12 Test 3. BOP TV 1, Charlie 3, 7, & 11 Test 4. Manual choke D & Super choke C Test 5. Romeo 3, Bleeder 3, Tango 2, Charlie 2, & 10 Test 6. Charlie 1, 9, Bravo 5, and Tango 1 – install TIW test joint Test 7. Lower 2” pipe slip rams, TIW #1, Romeo 1, Bleeder 1 Test 8. Annular BOP Test 9. Upper 2” pipe slip rams, Bravo 6, & 8 Test 10. Bravo 7 – swap out 2” test joint for 2-3/8” Test 11. 2-3/8” pipe slip rams, TIW#2 – check N2 levels, swap to 2” test joint Test 12. Draw down accumulator Test 13. Stab injector and line up to reverse circulate coil, test inner reel valve and stripper. Tested all gas detectors, pits, cellar, Verified flow alarms - PVT Service Swab 2 and retest: Pass 0.0 0.0 Rig: NABORS CDR3-AC Page 2/7 CD4-215 Report Printed: 4/15/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/17/2020 14:30 3/17/2020 16:54 2.40 MIRU WHDBOP RURD P RU LRS. Fill CT. Spear in with 10 bbls of MeOH followed by seawater at .41 bpm. 0.0 0.0 3/17/2020 16:54 3/17/2020 18:12 1.30 MIRU WHDBOP PRTS P PT inner reel iron, PDLs, and tiger tank line 0.0 0.0 3/17/2020 18:12 3/17/2020 20:30 2.30 PROD1 RPEQPT CTOP P MU CTC and pull test. MU UQC and pressure test. 0.0 0.0 3/17/2020 20:30 3/17/2020 21:06 0.60 PROD1 RPEQPT CTOP P Install nozzle, blow down choke, inspect pack offs 0.0 0.0 3/17/2020 21:06 3/17/2020 23:42 2.60 PROD1 RPEQPT PULD P PU and PD BHA #1, clean out assembly 0.0 53.0 3/17/2020 23:42 3/18/2020 02:18 2.60 PROD1 RPEQPT DISP P Bump up, set counters. Line up down the backside bullhead 40 bbls seawater ~3 bpm, 0.0 53.0 3/18/2020 00:00 3/18/2020 00:24 0.40 PROD1 RPEQPT DISP P Continue to bullheadd down the backside bullhead ~3 bpm, 53.0 53.0 3/18/2020 00:24 3/18/2020 02:12 1.80 PROD1 RPEQPT TRIP P RIH pumping seawater down the coil. Park @ 1498' inspect goose neck alignment - good. Continuin in hole. Shut down pumps, Differential pressure no falling. Try RIH, bullhead more fluid down backside. No change, Note diff was 115 psi @ surface prior to pumping. 53.0 5,038.0 3/18/2020 02:12 3/18/2020 03:12 1.00 PROD1 RPEQPT TRIP T POOH for new upper Coiltrak 5,038.0 53.0 3/18/2020 03:12 3/18/2020 04:12 1.00 PROD1 RPEQPT PULD T PUD BHA #1 53.0 0.0 3/18/2020 04:12 3/18/2020 05:12 1.00 PROD1 RPEQPT PULD T PD BHA #2 0.0 53.0 3/18/2020 05:12 3/18/2020 05:42 0.50 PROD1 RPEQPT TRIP T RIH 53.0 5,038.0 3/18/2020 05:42 3/18/2020 07:42 2.00 PROD1 RPEQPT TRIP P RIH Park, Close EDC, PU Wt 38 k lbs 5,038.0 8,081.0 3/18/2020 07:42 3/18/2020 08:18 0.60 PROD1 RPEQPT DLOG P Attempt to tie into Albian 97. Very nondescript peaks and valleys. Thinking -9' correction but a certain amount of imagination is needed. 8,081.0 8,718.0 3/18/2020 08:18 3/18/2020 08:30 0.20 PROD1 RPEQPT TRIP P RIH 8,718.0 9,430.0 3/18/2020 08:30 3/18/2020 09:03 0.55 PROD1 RPEQPT DLOG P 9,430.0 9,573.0 3/18/2020 09:03 3/18/2020 09:06 0.05 PROD1 RPEQPT DLOG P RIH spinning the bit, hole clean to 9650' 9,573.0 9,335.0 3/18/2020 09:06 3/18/2020 09:12 0.10 PROD1 RPEQPT DLOG P PUH to CCL loging depth 9,335.0 9,700.0 3/18/2020 09:12 3/18/2020 09:36 0.40 PROD1 RPEQPT DLOG P Logg CCL from 9335 - 9650 9,335.0 9,700.0 3/18/2020 09:36 3/18/2020 11:30 1.90 PROD1 RPEQPT TRIP P Park and open EDC, POOH 9,700.0 74.0 3/18/2020 11:30 3/18/2020 12:00 0.50 PROD1 RPEQPT CTOP P Park and inspect saddle clamps and verify torque on reel hubs. 74.0 74.0 3/18/2020 12:00 3/18/2020 13:00 1.00 PROD1 RPEQPT PULD P Tag up, space out, PUD BHA #2 74.0 0.0 3/18/2020 13:00 3/18/2020 13:54 0.90 PROD1 RPEQPT PULD P PD BHA #3, 3-1/2" MonoBore XL Whipstock - 2.625" OD 0.0 72.0 3/18/2020 13:54 3/18/2020 16:12 2.30 PROD1 RPEQPT WPST P RIH 72.0 9,449.0 3/18/2020 16:12 3/18/2020 16:36 0.40 PROD1 RPEQPT DLOG P Tie into the Albain / Nanuk interface for a -10' 9,449.0 9,555.4 Rig: NABORS CDR3-AC Page 3/7 CD4-215 Report Printed: 4/15/2020 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 3/18/2020 16:36 3/18/2020 17:00 0.40 PROD1 RPEQPT WPST P PU Wt 41 k lbs, continue in hole to set depth PU to neutral weight, close EDC pump 0.4 bpm shear at 3700 psi. S/D 3.84 k lbs WOB, PU Wt 44 k lbs 9,555.4 9,610.8 3/18/2020 17:00 3/18/2020 17:24 0.40 PROD1 RPEQPT WPST P PU Wt 41 k lbs, continue in hole to set depth PU to neutral weight, close EDC pump 0.4 bpm shear at 3700 psi. S/D 3.84 k lbs WOB, PU Wt 44 k lbs 9,555.4 9,610.8 3/18/2020 17:24 3/18/2020 19:12 1.80 PROD1 RPEQPT TRIP P POOH, with open EDC 9,610.8 73.0 3/18/2020 19:12 3/18/2020 20:42 1.50 PROD1 RPEQPT PULD P At surface, PUD setting tools. 73.3 0.0 3/18/2020 20:42 3/18/2020 21:54 1.20 PROD1 WHPST PULD P PD Window milling assembly 0.0 63.2 3/18/2020 21:54 3/18/2020 23:30 1.60 PROD1 WHPST TRIP P RIH 63.2 9,440.0 3/18/2020 23:30 3/18/2020 23:54 0.40 PROD1 WHPST DLOG P Log formation for depth control (Nanuq), minus 9.0', PUW 40 k 9,440.0 9,553.0 3/18/2020 23:54 3/19/2020 00:00 0.10 PROD1 WHPST TRIP P Continue IH, dry tag TOWS @ 9,602.2', 9,553.0 9,601.5 3/19/2020 00:00 3/19/2020 00:18 0.30 PROD1 WHPST TRIP P PUH bring pump online obtain pump parameters 9,601.5 9,601.5 3/19/2020 00:18 3/19/2020 02:18 2.00 PROD1 WHPST MILL P Start milling, 1.87 bpm at 3,600 psi, Diff=446, WHP=581, BHP=3,542, IA=683, OA=393 9,601.5 9,603.9 3/19/2020 02:18 3/19/2020 02:46 0.48 PROD1 WHPST MILL P OB Milling, 1.86 bpm at 3983 psi, Diff=613, WHP=680, BHP=3,629, IA=682, OA=389, @ 9,603.3' spike in motor work, continue milling ahead, notice diff pressure drop @ 9,604', 9,603.9 9,604.4 3/19/2020 02:46 3/19/2020 04:46 2.00 PROD1 WHPST MILL P OB Milling 1.86 bpm at 3,992 psi, Diff=721 psi, WHP=699, BHP=3,650, IA=682, OA=388 9,604.4 9,606.1 3/19/2020 04:46 3/19/2020 05:58 1.20 PROD1 WHPST MILL P OB Milling 1.86 bpm at 4084 psi, Diff=514 psi, WHP=819, BHP=3,751, ROP- 2.0 FT/hr 9,606.1 9,607.5 3/19/2020 05:58 3/19/2020 06:52 0.90 PROD1 WHPST MILL P Increse ROP to 2.5 Ft/hr 9,607.5 9,609.5 3/19/2020 06:52 3/19/2020 08:46 1.90 PROD1 WHPST MILL P Drill ahead @ 10 ft/hr, drilling rat hole 9,609.5 9,622.0 3/19/2020 08:46 3/19/2020 10:04 1.30 PROD1 WHPST REAM P PU Wt 42 k lbs, Pull three reaming up passes as milled - straight motor- Time out 5x5 sweep, dry drift, window clean - tag bottom. 9,622.0 9,580.0 3/19/2020 10:04 3/19/2020 11:40 1.60 PROD1 WHPST TRIP P PU Wt 42 k lbs. POOH 9,580.0 50.0 3/19/2020 11:40 3/19/2020 12:34 0.90 PROD1 WHPST PULD P PUD BH #4, Mill gauged out 2.80" go, 2.79" no, mill shows good indication of successful window. 50.0 0.0 3/19/2020 12:34 3/19/2020 13:34 1.00 PROD1 DRILL PULD P PD BHA #5 2.5° KO motor over a RR BH Dynamus 0.0 72.0 3/19/2020 13:34 3/19/2020 15:22 1.80 PROD1 DRILL TRIP P RIH 72.0 9,440.0 3/19/2020 15:22 3/19/2020 15:46 0.40 PROD1 DRILL DLOG P Tie in to Albian/ Nanook interface for - 10' correction. 9,440.0 9,545.0 3/19/2020 15:46 3/19/2020 15:58 0.20 PROD1 DRILL DLOG P Continue to RIH 9,545.0 9,622.0 3/19/2020 15:58 3/19/2020 16:22 0.40 PROD1 DRILL DRLG P CT 3,767 psi @ 1.84 bpm in / 0 out, diff press 486 psi, BHP 3,663 psi, CT Wt 18k lbs, WOB 3 k lbs. 9,622.0 9,634.0 Rig: NABORS CDR3-AC 3/18/2020 17:00 3/18/2020 17:24 0.40 PROD1 WPSTRPEQPT P PU Wt 41 k lbs, continue in hole to set depth PU to neutral weight, close EDC pump 0.4 bpm shear at 3700 psi. S/D 3.84 k lbs W OB, PU Wt 44 k lbs 9,555.4 9,610.8 THE STATE ALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Nanuq Oil Pool, CRU CD4 -215 Permit to Drill Number: 206-157 Sundry Number: 320-101 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 07�� Daniel T. Seamount, Jr. Commissioner d r DATED this 2,— of March, 2020. 1SDMSL1" / APP 0 7 7070 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVE® MAR 4 2020 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Weil ❑ A ©� pSRhutdown ❑ Suspend F-1Perforate El Other Stimulate El Pull Tubing ElChange Approve Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: _Whipstock_Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development ❑' ` Stratigraphic ❑ Service ❑ 206-157 3. Address: 6. API Number: PO Box 100360, Anchorage AK 99510 50-103-20539-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A CRU CD4 -215 Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 380077, 384209, 388902 Colville River Field / Nanuq Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14,761' 6205' 14,675' 6212' 3636 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 77' 16" 114' 114' Surface 2817' 9-5/8" 2854' 2392' Intermediate 9478' 7" 9514' 6216' Liner 5314' 3-1/2" 14,675' 6212' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade:Tubing MD (ft): N/A N/A 3-1/2" L-80 9380' Packers and SSSV Type: Baker Premier Packer Packers and SSSV MD (ft) and TVD (ft): 8205' MD / 5856' TVD Camco TRMAXX-5E #HYS-405 2142' MD / 1925' TVD 12. Attachments: Proposal Summary Q Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/16/2019 OIL ❑Q - WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ - Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. James Ohlinger Authorized Name: Contact Name: Ryan McLaughlin Authorized Title: Staff CTD Engine Contact Email: R an.MCLaU hlin co .Cam /�0 Contact Phone: 907-265-6218 Authorized Signature L► Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: F1so Plug Integrity BOP Test `�' Mechanical Integrity Test ❑ Location Clearance ❑ Other: 5 O fCrSf 1`� 3Jr©op$-.I . t,,<r fa 7917"vl�r pr< v<v, <S 7' 2 5-v0 Post Initial Injection MIT Req'd? Yes ❑ NoL�J{/ "hP� / �OLO Spacing Exception Required? Yes ❑ No a Subsequent Form Required: /L — 4 ��®'y15 ` APPROVED BY Approved b6e/� COMMISSIONER THE COMMISSION Date: ,y, ��. ei ✓I �i7� ��6��6 Submit Form and or 10-403 Revised 4/2017 Approved application isoR is2 n#. rdate of approval. Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 2, 2020 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Sundry Application (10-403) to set a mechanical whipstock in CRU CD4 -215 (PTD #206-157) in order to drill two CTD laterals using the coiled tubing drilling rig, Nabors CDR3-AC. Attached to this application are the following documents: — 10-403 Sundry Application for CRU CD4 -215 — Operations Summary in support of the 10-403 Sundry Application — Proposed CTD Schematic — Current Well Bore Schematic If you have any questions or require additional information, please contact me at 907-265-6218. Sincerely, Ryan McLaughlin ConocoPhillips Alaska Coiled Tubing Drilling Engineer CRU CD4 -215 (PTD #206-157) CTD Summary for Sundry Summary of Operations: CD4 -215 is a Nanuq producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the Nanuq lobes 3 and 4 to the northwest of CD4 -215. Nabors CDR3-AC will set a mechanical whipstock inside the 3-1/2" slotted liner at the planned kick off point of 9600' MD. The CD4 -215 lateral will exit through the 3-1/2" liner at 9600' MD and be drilled to a TO of 14,000' MD, targeting the Nanuq lobe 3 to the Northwest. It will be completed with 2-3/8" slotted liner from TD up to 10,150' MD with an aluminum billet for kicking off the CD4 -215L1-01 lateral. The CD4 -215L1-01 lateral will drill to a TO of 14,000' MD targeting the Nanuq lobe 4 to the Northwest. It will be completed with 2-3/8" slotted and solid liner from TD up into the 3-1/2" liner at 9580' MD. CTD Drill and Complete C104-215 Laterals: March 2020 Pre -CTD Work 1. Prep site for Nabors CDR3-AC rig. Ria Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. CD4 -2151-1 Lateral (Nanuq lobe 3 - Northwest) a. Set top of whipstock at 9600' MD. 3 b. Mill 2.80" window at 9600' MD. c. Drill 3" bi-center lateral to TO of 14,000' MD. d. Run 2-3/8" slotted liner with aluminum billet from TD up to 10,150' MD. 3. CD4 -2151-1 -0 1 Lateral (Nanuq lobe 4 - Northwest) a. Kickoff of the aluminum billet at 10,150' MD. b. Drill 3" bi-center lateral to TO of 14,100' MD. c. Run 2-3/8" slotted liner and solid liner from TO up to 9580' MD. 4. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Ria Work 1. Return well to production. Page 1 of 1 3/2/2020 16" 65# H-40 shoe @ 114' 9-5/8" 40# L-80 shoe @ 2854' MD CD4 -215 Proposed CTD Schematic 7" 26# L-80 shoe @ 9515' MD 3-1/2" 9.3# VIT from 9380' IRKS to surface 3-1/2" 9.3# L-80 liner from 14675' RKB to surface Camco TRMAXX-5E SSSV @ 2142' RKB (min ID 2.812") 3-1/2" VITx 3-1/2" IBT XO @ 3997' RKB Camco KBMG GLMs @ 4355'& 8115' RKB Baker Premier Packer @ 8205' RKB (2.875" ID) HES XN Nipple @ 8283' RKB (min ID 2.75") Locator/WLEG No -Go @ 9351' RKB (2.992" ID) HR Liner Setting Sleeve @ 9361' RKB Baker RS Sealing Nipple @ 9374' RKB Baker Flex Lock DG Liner Hanger @ 9378' RKB FOP @ 9600' MD 3-1/2" Liner shoe @ 14675' MD I _________________________________ .n - C134-2151-1-01 WP01 TD @ 14,000' MD C134-2151-1 Wp05 D @ 14,000' MD Lop of Billet -10,150' MD WNS PROD CD4 -215 WellAttributes Max Ai le&MD TD Wellbore /aPIIUWI So1032053900 FIeIE Neme We11Eore 3[etuc Incl °) MO (XKBI ACI Bim tXKR) NANUO PROD 14,]61.0 Comment N3¢ Ippml Date A -cation SSSV: TRDP Last WO: Ertl gain K6Grd Do Rlg Release Date 43.]8 12/25/2006 Annatat-OapiM1 (XKB) et. Core Arctation La¢[Mod By I End Dale Last Tdg: 10,80D.0 7/112008 Rev Reason: WELL REVIEW Cabo tl 9/5/2013 'Gasin 5tdn as Casing Description CONDUCTOR 46" Insulated ettlng0.. 16 String ID... 15,250 Top IXKe) Set Depth if... 37.0 114.0 Set Depth (Ten) String Wt.. 114.0 65.00 string- string Top Thrd H40 WELDED Casing Description SURFACE String 0... 95/8 Shing to... 6.835 To,(XKB) Set Depth" 36.8 2,854.2 Set Depth(WDL.. String Wt... 2,392.2 40.00 Siring... String Top TAtd L-80 Entire. Cages Description INTERMEDIATE String 0... 7 String to... 6.276 Top(nKS) Set Depth it 34.6 9,514.5 San Depth HVD)... Siring WI... 6,215.9 26.00 String ... Siang Tap That L-80 BTCM Casing Description LINER String O... 3112 String to... 2992 Top(XKBI set Depth p... 9,351.0 14,675.0 Set Depth(Wn) Bbmg Wt_ 6.2120 9.30 string... String Top TM1m L-80 SLHT Ungar Detallig rap oepm two) Top ma N-1 Top gftKS)D K8) V) Item Description crmmem m (in) 9,361.0 6,194.6 81,10 SLEEVE "HR" LINER SETTING SLEEVE 4.420 9,374.0 6.193.6 80.34 NIPPLE BAKER "RS"SEALING NIPPLE 4.250 9,377.8 6,194.4 80.45 HANGER BAKER FLEX LOCK "DG"LINER HANGER 4.400 Tublna Strtn s Tubing 0eecrlptlon TUBING VITxNORMAL string 0... 3112 String ID... 2.992 Top IXKBI Set 31.4 Depth (f_ 9,3]9.6 Set Dep[A IiVD)._ 6.194.8 Slring Wt.. 9.311 String... L-80 string Top TM1rtl EUE8rdM00 Comidlellign Details . Top Depth (rv0) rop incl Noml... To nnn (XK91 (°I Item oeccripnon Comment ID (n) 31.4 31.4 0.27 HANGER EMC TUBING HANGER 4.500 44.8 44.8 0.29 X6Reducing 4.5"x3.5" 3.500 2142.2 1,925.3 48.83 SAFEWVLV CAMEO TRMAXX-RE#HVS-005. 2.812 3.996.9 3,164.1 45.37 XO VITABT CROSOVER FROM VACUUM INSULATED 3.5" TBG INSIDE 4.5" 2.992 TUBING TO NORMAL 3.5- TUBING 8,204.5 5,856.4 63.33 PACKER BAKER PREMIER PACKER 2.875 8,282.5 5,8904 64.47 NIPPLE HES'XN' NIPPLE@ 64 DEG. 2.750 9,350.6 6,193.0 81.25 WLEG LOCATORANLEG FLUTED NO GO 2.992 Perforations & Slots Ta XKB Top Her) atm (XKB) (nnn) Sim ITVDI (XKB) Zpne Data an. Dens (an ry v Comment 9,5D1.0 9,712.D (r2154 6,230.3 11/2312006 16.0 SLOTS Alternating solid/slotted pipe W/D.125"x2.25"sIKIS 9,555.0 9,575.0 6,218.2 6,219.7 4/222007 6.0 APERF 2.5° Hypedet Charges, 60 deg orient 10,550.0 1D,733.0 6,231.1 6,219.1 11123/2006 16.0 SLOTS Alternating Soliftlotted pipe W/0.125"x2.25"slol.A 10,857.0 11,039.0 6,217.6 6.226.4 11/2312006 iSD SLOTS Alternating solid/slotted pipe w/0.125- x2.25" 51915 11,566.0 11,627.0 6,246.6 5244.7 11/2312006 16.0 SLOTS Alternating solidolotled pipe w/D.126" x2.25" slots 12,184.0 12,730.0 6,221.3 6,211.7 11123/2006 15.0 SLOTS Alternating sDlidlslotted pipe w/0.125" x2.25" slots 12,852.0 13.395.0 6,218.6 6,225.1 112312006 16.0 SLOTS Alternating solid/slotted pipe S/0.125- x2.25" slots 13,549.0 13,638.0 6,234.1 5240.3 1112312006 16.0 SLOTS Alternating solidebtmd pipe w/0.12F x2.25"slots 13,793.0 14,280.0 6,248.4 6,2457 11/232006 16.0 SLOTS Alternating solid/slotted pipe w1D.125" x2.25" slots 14,342.0 14,403.0 6,243.1 6,238,7 112312006 16.0 SLOTS Alternating solidlslotted pipe w/0.125"x2.25"slots 14,497.0 14.673.0 6,231.0 5212.1 1112312006 16.0 SLOTS Alternating solid/slotted pipe wT.125"x2.25'slms Stimulations &Treatments.... Mm Top oeDepthDe"Oh(ry (flKB) season TopDe0hjDepN (XKB) C)Dl (flKBI venom (rvDl (flKBI Type Date Comment 10,550.0 14,6]3.0 6,231.1 6,212.1 I FRAC 41252007 FRAC NANUO FORMATION 310,000#20140 CARBOLITE WORKING UP FROM 1 Pipe TO 12 ppb ON FORMATION. Notes: General & Safe Ena Dine Annotation 1215/2009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Man drel.Detafla 5... N... Top Depth (ND) To (flKBI 1XKD) an Incl P) Make Motlel OD (lnl go, Valve Type port Latch Sit' Type (int TRO Rr (Ps) Ren Con Cam.,. 1 4,354.5 3,420.5 43.11 CAMEO KBMG 1 GAS LIFT DMV BKS D.DOD 0.0 ]2912008 2 8,115.1 5,814.5 60]2 CitMCO KBMG 1 GAS LIFT OV BK -5 0.250 0.0 ]1291'2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed- Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well E Re-enter Susp Well ❑ Other: SC REPAIR ❑✓ 2. Operator Name: ConocOPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development ❑✓ Exploratory ❑ 206-157 3. Address: P. O. Box 100360, Anchorage, Alaska Stratigraphic ❑ Service ❑ 6. API Number: 99510 50-103-20539 00 7. Property Designation (Lease Number): Name and Number: ADL0380077/ADLO384209/ADLO388902 =Well CRU CD4 -215 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Colville River Field / Nanu Oil Pool 11. Present Well Condition Summary: Total Depth measured 14,761 feet Plugs measured None feet true vertical 6,205 feet Junk measured None feet Effective Depth measured 0 feet Packer measured 8205, 8283 feet true vertical 0 feet true vertical 5856, 5891 feet Casing Length Size MD ND Burst Collapse 46" INSULATED 77 feet 16 114' MD 114' TVD SURFACE 2,817 feet 95/8" 2,854'MD 2,392'TVD �������� INTERMEDIATE 9,480 feet 7 " 9,515' MD 6,216' TVD LINER 5,314 feet 31/2" 14,675'MD 6,216`TVD NOV 12 2019 Tubing (size, grade, measured and true vertical depth) 3.5 " L-80 9,375' /n� ,—% N E �tD f#".S ,'1@7' TVD Packers and SSSV (type, measured and true vertical depth) PACKER -BAKER PREMIER PACKER 8,205' MD 5,856' TVD NIPPLE - HES'XN' NIPPLE @ 64 DEG. 8,283' MD 5,891' TVD SAFETY VLV - CAMCO TRMAXX-5E # 2,142' MD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water Bbl Casing Pressure I Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments (repelred per20 MC25.070,25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory ❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-413 Authorized Name: Roger Mouser Contact Name: Roger Mouser / Roger Winter Authorized Title: Well Integrity Field Supervisor ContactEmail: N1927@conocophillips.com Authorized Signature: Date: l f / 1 5 Contact Phone: 907-659-7506 ABDMS LEJ NOV 13 2019 Form 10-404 Revised 4/2017 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 11, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, RECEIVE® NOV 12 2019 AVGCC Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the Surface casing repair patch, on CRU CD4 -215 PTD# 206-157. Please contact Roger Winter or me at 659-7506 if you have any questions. Sincerel , Roger Mouser Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Date Event Summary 09/04/1 CD4 -215 DESCRIPTION OF WORK COMPLETED SUMMARY 9 Operations reported the smell of diesel in the CD4 -215 wellhouse and saw something in the conductor. They also noted that the OA pressure had dropped from —430 psi to 180 psi for no apparent reason. Well is to be shut-in and DHD will investigate 09/07/19 10/23/1 10/242019 (AC EVAL) SCLD FOUND LEAK @ 59" (COMPLETE), OA DDT (PASSED), IC POT (PASSED), IC PPPOT (PASSED). g Remove insulation - cut and remove 16" conductor - remove sealant and bad cement around SC - buff SC and had inspected By Kakivik. Initial T/I/O = SI 0/0/5 Bled OA to 0 psi in 2 seconds Pressured OA to 150 psi heard audible leak measured @ 88' from bottom of OA valve Drilled and tapped 1/2" NPT in SC and lowerd FL to 41" (13" below bottum of band "B") FL is 137" below btm of OA valve Pressured OA to 20 psi and got N2 at plug , bled off OA redressed plug and threads added locktite to plug and rigged down 15 bbls water vac'd out 10/28/19 AOGCC inspector Jeff Jones waived inspection of damage to SC. 11/01/19 11/02/1 11/03/1 (SC REPAIR) IN PROGRESS- WELDED FIRST PIECES OF "A" AND "B" COLLARS. AWAITING MT/UT RESULTS FOR CONTINUATION OF COLLAR WELDS AND SLEEVE/PATCH INSTALL. 9 (SC REPAIR) IN PROGRESS- COMPLETED WELDING OF "A" AND "B" COLLARS. MT/UT INSPECTIONS PASSED. INSTALLED 8'6" of 12".500 WALL SLEEVE/PATCH. WELDED LONGITUDINAL ROOT AND HOT PASS WELDS. (FILL AND CAP WELDS REMAIN TO BE COMPLETED). OAL OF PATCH = 8' 10". 9 (SC REPAIR) IN PROGRESS- COMPLETED WELDING OF SLEEVE/PATCH. MT/UT INSPECTIONS PASSED. OAL OF PATCH = 8'10". MITOA/SCLD TO FOLLOW IN THE MORNING. AOGCC IS UNABLE TO VIEW REPAIR, BUT REQUESTED PHOTOS OF REPAIR AND COPY OF SUNDRY. 11/04/19 (SC REPAIR) IN PROGRESS.MITOA/SCLD WITH N2 PASSED @1300 PSI. SC Repair - Emailed copyrighted photos of damge and repair as well as a copy of approved sundry #319-413, as requested by AOGCC inpsector Matt Herrera. 11/05/19 Copyright 2019: All rights rovided to the AOGCC wit se. Copying for any other rohibited without the exp Alaska, Inc." 4 d. This photograph is ission to copy for its own or by other party is isent of ConocoPhillips V J n I ki of yright 2019. All hts reserved. This graph is provid to the AOGCC with ermission to copy fo s own use. opying for any other purpose or by other party is prohibited without the expTins consent] CO 11 s Ataska, Inc" THE STATE OfALASKA GOVERNOR MIKE DUNLEAVY Roger Mouser Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Nanuq Oil Pool, CRU CD4 -215 Permit to Drill Number: 206-157 Sundry Number: 319-413 Dear Mr. Mouser: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 vewve. a ogc c.oloska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ssie L. Chmielowski Commissioner DATED this I I day of September, 2019. 'IBDMS --'/ SEP 12 2019 C";. EEC rnm €g V.g� 3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION j�� ��'� APPLICATION FOR SUNDRY APPROVALS 2n AAr 2s 2an 1. Type of Request: Abandon Ll Plug Perforations ❑ Fracture Stimulate LJ Repair Well ' _'Q la8b U31Aown LJ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑Q Other: Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocOPhilli s Alaska Inc. Exploratory ❑ Development Stratigraphic ❑ Service ❑ 206-157 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 501032053900 7. If perforating: N/A 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 7 !v Will planned perforations require a spacing exception? Yes ❑ No Q CRU CD4 -215 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0380077/ADLO384209/ADLO388902 I I Colville River Field / Nanuq Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14,761' 6,205' 10800' 6217 Casing Length Size MD TVD Burst Collapse Structural Conductor77' 16" 114' 114' Surface 2,817' 9.625" 2,854' 2392' Intermediate 9,480' 7" 9,515' 6216' Production Liner 5,314' 3.5" 14675' 6216' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9501' to 14497' MD 6215' to 6212' 3.500" L-80 9,375' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - BAKER PREMIER PACKER MD= 8205 TVD= 5856 SAFETY VLV - CAMCO TRMAXX-5E #HYS-405 MD= 2142 TVD= 1925 12. Attachments: Proposal Summary ❑' Wellbore schematic O 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 10/8/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑� WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Roger Mouser Roger Mouser / Roger Winter Contact Name: g g Authorized Title: Well Integrity Field Supervisor Contact Email: N1927@conocophillips.com Contact Phone: 907-659-7506 Authorized Signature: Date: 9/8/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ 9 y ❑ Location Clearance Other: .t �ha/OG�oGvmc�-i'71' c'i�h-,q/ z f / t�a/�•�" Post Initial Injection MIT Regd? Yes ❑ No Spacing Exception Required? -IBDMS�' c"'n Yes ❑ No Subsequent Form Required: �� "Lt012 2019 f APPROVED BY 1 Approved by: /' COMMISSIONER THE COMMISSION Date: q ,, �,` y,,,,79 ORIGINAL ��Q�b-r5 '` Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. / /attachments in Duplicate ��Yj'/•�`l�/ � y,/cam �' 7y ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 8, 2019 Commissioner Jesse Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7 1 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski: Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well CD4 -215 (PTD# 206-157-0) for a proposed surface casing repair. _ Please contact Roger Mouser or Roger Winter at 659-7506 if you have any questions. Sincerely, �/ �J� ` 4 Roger Mouser Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Attachments: CD4 -215 Well Schematic Proposed work CD4 -215 Photo ConocoPhillips Alaska, Inc. Alpine Well CD4 -215 (PTD 206-157-0) SUNDRY NOTICE 10-403 APPROVAL REQUEST September 08 2019 This application for Sundry approval for Alpine well CD4 -215 is for the inspection and repair of surface casing with a suspected surface casing leak. Subsequent diagnostics indicate that the leak is relatively shallow. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with mechanical plug in tubing 2. Remove the floor grate, well house, flow lines, and other equipment as necessary from around the wellhead. 3. Install nitrogen purge equipment for the conductor and OA (if needed) so that hot work may be conducted in a safe manner. 4. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. 5. Remove gravel around well head and excavate to --20' Remove additional conductor as necessary. 6. Notify AOGCC Inspector for opportunity to inspect. 48 hour notice. 7. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 8. QA/QC will verify the repair for a final integrity check. 9. Perform a low-pressure test (Open OA shoe) to confirm no fluid to surface. 10. Install anti -corrosion coating as specified by CPAI Corrosion Engineer. 11. Replace the conductor and fill the void with cement and top off with sealant. 12. Backfill as needed with gravel around the wellhead. 13. Remove plug(s) and return the well to injection. 14. File 10-404 with the AOGCC post repair. �. WNS PROD L. ConocoPhitlips Well AtlAbutes Alai a IIIC 0Wellbore gplNWl Fleltl __ 501032053900 NqN comment SURFACE _ 3] 28k GAS LIFT,_ 1.05 GAS LIFT,_ 5.115 �ACNEfl. a.ZIN — NIPPLE. .283--- WLEG, 9,551 Stm Max BIT I Top Bep15 Bepfa Bepth )NB) (NB) ('RB) PDS) )RNB) 3].0 TUBING CD4 -215 .25"slo% slots SIOIE IBOUTE WORKING UP FROM 1 ppa TO 12 ppa FORMATION. ConocoPhillips a~~ P.O. SOX 100360 ANCHORAGE, ALASKA 99510-0360 March 19, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~ ~~~ -~ E ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped March 18~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sinc Perry ~C~n ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Alpine Field Date 3/19/2009 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # .cement um ed cement date inhibitor sealant date ft bbls ft al CD4-301 B 207-180 SF NA 7" NA 2.55 3/18/2009 CD4-302 207-056 28" NA 28" NA 22.95 3/18/2009 CD4-304 207-132 8" NA 8" NA 1.70 3/18/2009 CD4-05 207-155 SF NA 7" NA 1.70 3/18/2009 CD4-306 207-094 SF NA 5" NA 1.70 3/18/2009 CD4-07 2.07-11R SF NA 8" NA 0.42 3/18/2009 CD4-208 205-162 SF NA 7" NA 1.27 3/18/2009 CD4-209 206-065 SF NA 6" NA 0.85 3/18/2009 CD4-210 206-077 SF NA 7" NA 1.27 3/18/2009 CD4-211 206-153 9" NA 9" NA 3.82 3/18/ZUUy CD4-214' 206-145 7" NA 7" NA 2.12 3/18/2009 CD4-215 ~ 206-157 5" NA 5" NA 2.55 3/18/2009 CD4-16 206-131 SF NA 5" NA 2.55 3/18/2009 Cp4-17 206-118 SF NA 11" NA 1.27 3/18/2009 CD4-318A 206-113 7" NA 7" NA 1.70 3/18/2009 CD4-319 205-148 SF NA 7" NA 1.27 3/18/2009 CD4-320 206-055 6" NA 6" NA 0.85 3/18/2009 CD4-321' 206-142 SF NA 8" NA 1.70 3/18/2009 CD4-322 207-101 SF NA 5" NA 1.27 3/18/2009 a~~~~v~~ DATA SUBMITTAL COMPLIANCE REPORT 10/15/2008 Permit to Drill 2061570 Well Name/No. COLVILLE RIV NAN-N CD4-215 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20539-00-00 MD 14761 TVD 6205 Completion Date 12/25/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Log s Run: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Ty Med/Frmt Number Name D D Asc Directional Survey D C Lis 14571 InductionlResistivity ~ ~/ Rpt 14571 LIS Verification ~D C 15671 Induction/Resistivity Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? Y-~l-~l- Analysis l~`r'I~ Received? (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval Scale Media No Start Stop py / Cy Received Comments 0 14761 Open 3/27/2007 1 2830 14761 Open 4/4/2007 LIS Veri, GR, FET, ROP 2830 14761 Open 4/4/2007 LIS Veri, GR, FET, ROP 0 0 Open 11/12/2007 EWR MD/TVD in PDF and EMF graphics Sample Interval Set Start Stop Sent Received Number Comme nts Daily History Received? (1, Formation Tops t!/ N Comments: Compliance Reviewed By: Date: ~ ~ WELL LOG TRANSMITTAL 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: CD4-215 November 1, 2007 AK-MW-4788290 CD4-215: Digital Log Images: 50-103-20539-00 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. Anchorage, Alaska 99518 Date: s Signed: V ~~- ~5~ ~r5~~-1 r~ ~ ~r~~cc~'~ ~ sv;~~,,,~!- Detailed Casin Tall g y o~ C-~j~ - ~ b ~~~~~ ~D4-215 ~~~ ~. (~ Surface, Set Depth: 2,854.2 ftKB Primary Job Type Job Category AFE / RFE / Maint.# Actual Start Date Spud / KO Date End Date DRILLING ORIGINAL DRILLING 10149948 12/5/2006 12/6/2006 12/25/2006 - - -- _ __ iCasing Run Tally " __ Item Description OD (in1 Wt (Ibsfft) yde Ref NoNo R Len (ft) Centraliz_ dirt Jwlry i~op {ftKBa Cum Len {ftj _ Yes No 0.0 2,854.15 Yes No 0.0 2,854.19 Yes No 0.0 2,854.19 Doyon 19 RKB to 9 5/8 40.00 L-80 Yes 36.85 No 0.0 2,854.19 Landing Ring FMC Gen V Hanger 9 5/8 40.00 L-80 Yes 2.15 No 36.8 2,817.34 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 74 Yes 39.02 No 39.0 2,815.19 Csg 9-5/8" 40# L-80 BTC 9 5!8 40.00 L-80 73 Yes 36.09 No 78.0 2,776.17 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 1-80 72 Yes 35.52 No 114.1 2,740.08 Csg 9-518" 40# L-80 BTC 9 5/8 40.00 L-80 71 Yes 38.92 No 149.6 2,704.56 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 70 Yes 36.37 No 188.5 2,665.64 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 69 Yes 38.39 No 224.9 2,629.27 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 68 Yes 38.69 No 263.3 2,590.88 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 67 Yes 37.98 No 302.0 2,552.19 Csg 9-518" 40# L-80 BTC 9 5/8 40.00 L-80 66 Yes 34.74 No 340.0 2,514.21 Csg 9-5/8" 40# L-80 BTC 9 518 40.00 L-80 65 Yes 35.87 No 374.7 2,479.47 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 64 Yes 39.61 No 410.6 2,443.60 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 63 Yes 36.43 No 450.2 2,403.99 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 62 Yes 38.67 No 486.6 2,367.56 Csg 9-518" 40# L-80 BTC 9 5/8 40.00 L-80 61 Yes 39.90 No 525.3 2,328.89 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 60 Yes 36.76 No 565.2 2,288.99 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 59 Yes 36.93 No 602.0 2,252.23 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 58 Yes 35.97 No 638.9 2,215.30 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 57 Yes 34.33 No 674.9 2,179.33 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 56 Yes 38.46 No 709.2 2,145.00 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 55 Yes 39.09 No 747.6 2,106.54 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 54 Yes 37.12 No 786.7 2,067.45 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 53 Yes 35.92 No 823.9 2,030.33 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 52 Yes 39.30 No 859.8 1,994.41 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 51 Yes 39.79 No 899.1 1,955.11 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 50 Yes 38.61 No 938.9 1,915.32 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 49 Yes 38.91 No 977.5 1,876.71 Csg Page 1/23 Report Printed: 7/30!2007 r~ ~ ~ Detailed Casing Tally CD4-215 Surface, Set Depth: 2,854.2 ftKB Primary Job Type Drilling Support Job Category Well Intervention AFE / RFE / Maint.# 10149949 Actual Start Date 12/24/2006 Spud / KO Date End Date 12/25/2006 ~- - - -_ _ - - - .Casing Run Tally _ - - --- ~~ Ex# 3wlry Top (fflB~ Gum Len (ft} Item Description ~~. ,c ~ VJt pbsfft) ~3rade Ref No. Run? Len (ft) Centraliz.-. _ 9-5/8" 40# L-80 BTG 9 5/8 40.00 L-80 48 Yes 38.83 No 1,016.4 1,837.80 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 47 Yes 38.88 No 1,055.2 1,798.97 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 46 Yes 39.20 No 1,094.1 1,760.09 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 45 Yes 38.81 No 1,133.3 1,720.89 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 44 Yes 37.91 No 1,172.1 1,682.08 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 43 Yes 38.80 No 1,210.0 1,644.17 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 42 Yes 38.43 No 1,248.8 1,605.37 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 41 Yes 38.68 No 1,287.3 1,566.94 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 40 Yes 39.13 No 1,325.9 1,528.26 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 39 Yes 38.10 No 1,365.1 1,489.13 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 38 Yes 38.31 No 1,403.2 1,451.03 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 37 Yes 39.34 No 1,441.5 1,412.72 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 36 Yes 35.99 No 1,480.8 1,373.38 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 35 Yes 37.67 No 1,516.8 1,337.39 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 34 Yes 38.08 No 1,554.5 1,299.72 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 33 Yes 37.85 No 1,592.6 1,261.64 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 32 Yes 37.98 No 1,630.4 1,223.79 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 31 Yes 39.25 No 1,668.4 1,185.81 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 30 Yes 34.64 No 1, 707.6 1,146.56 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 29 Yes 39.55 No 1,742.3 1,111.92 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 28 Yes 36.62 No 1,781.8 1,072.37 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 27 Yes 38.38 No 1,818.4 1,035.75 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 26 Yes 39.80 No 1,856.8 997.37 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 25 Yes 37.29 No 1,896.6 957.57 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 24 Yes 37.34 No 1,933.9 920.28 Csg 9-5/8" 40# L-80 BTC 9 5!8 40.00 L-80 23 Yes 35.07 No 1,971.3 882.94 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 22 Yes 34.85 No 2,006.3 847.87 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 21 Yes 39.03 No 2,041.2 813.02 Csg 9-5/8" 40# L-80 BTC 9 5!8 40.00 L-80 20 Yes 38.95 No 2,080.2 773.99 Csg Page 2/23 Report Printed: 7/30/2007 IT ~--~ ~ ~ - - Detailed Casing Tally - CD4-215 ." Surface, Set Depth: 2,854.2 ftKB Primary Job Type Job Category AFE / RFE / Maint.# Actual Start Date Spud / KO Date End Date Drilling Support-Capital We lllntervention 10149949 1/16/2007 1 /16/2007 'Casing Run Tally 3tem~escr+piron O~ (rc ~. Wt ( Ibsfft) ~ a.;:-~ Ref Ho Run? L~-. ~f i) Ce ~ ~.z E t i; i.; Top (ftF E ~~ ! ~ Cum ~e~ (ft} 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 _ 19 Yes 38.65 No 2,1 t 5.2 735.04 Csg 9-5l8" 40# L-80 BTC 9 5/8 40.00 L-80 18 Yes 38.52 No 2,157.8 696.39 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 17 Yes 38.40 No 2,196.3 657.87 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 16 Yes 38.38 No 2,234.7 619.47 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 15 Yes 37.08 No 2,273.1 581.09 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 14 Yes 38.15 No 2,310.2 544.01 Csg 9-5/8" 40# L-80 BTC 9 5!8 40.00 L-80 13 Yes 39.68 No 2,348.3 505.86 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 12 Yes 36.57 No 2,388.0 466.18 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 11 Yes 39.29 No 2,424.6 429.61 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 10 Yes 36.99 No 2,463.9 390.32 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 9 Yes 38.70 No 2,500.9 353.33 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 8 Yes 38.59 No 2,539.6 314.63 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 7 Yes 38.64 No 2,578.2 276.04 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 6 Yes 39.61 No 2,616.8 237.40 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 5 Yes 37.25 No 2,656.4 197.79 Csg 9-5/8" 40# L-80 BTC 9 518 40.00 L-80 4 Yes 37.79 No 2,693.7 160.54 Csg 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 3 Yes 39.68 No 2,731.4 122.75 Csg Halliburton Float 9 5/8 Yes 1.50 No 2,771.1 83.07 Collar 9-5/8" 40# L-80 BTC 9 5/8 40.00 L-80 2 Yes 39.66 No 2,772.6 81.57 Csg 9-5/8" 40# L-80 BTC 9 5!8 40.00 L-80 1 Yes 39.66 No 2,812.3 41.91 Csg Ray Oil Tools "Silver 9 5/8 Yes 2.25 No 2,851.9 2.25 Bullet" Float Shoe Page 3/23 Report Printed: 7/30/2007 r ~ Cement Detail Report C D4-215 c~f~ ~ -- t . «.. _ Surface Casing Cement Primary Job Type Job Category AFE / RFE / Maint.# Actual Start Date Spud / KO Date End Date DRILLING ORIGINAL DRILLING 10149948 12/5/2006 12/6/2006 12/25/2006 Cement Details -- - - _ __ Description Cementing Start Date Cementing End Date Weilbore Name Surface Casing Cement 12/9/2006 06:30 12/9/2006 08:30 CD4-215 Comment Cement 9 5/8" csg as follows :Pumped 40 bbls Biozan wafer w/nut plug as marker -Pumped 5 bbls water w/ Doweli -Tested lines to 2500 psi -Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 314 bbls lead slurry (ASL) @ 10.7 ppg (` Observed nut plug marker @ shakers w/ 371 bbls lead pumped -pumped down surge can) Pumped 48 bbls tail slurry (Class G w/ additives) @ 15.8 ppg -Dropped top plug w/ 20 bbls water f/ Dowell - Switched over to rig pumps & displaced cmt w/ 190.4 bbls 9.8 ppg water base mud -Displaced @ 7.0 bbls/min for first 180 bbls -slowed to 4 bbls/min for last 10.4 bbls -Bumped plug w/ 1200 psi (prep bump pressure 720 psi) Check float (held OK) CIP @ 08:30 hrs. -Full circulation throughout job w/ 110 bbls 10.7 ppg tint returns to surface -reciprocated pipe while circulating & through cement job until last 90 bbls of displacement. - - _ ''Cement Stages -- rStage # 1 -- __ ___ _ ___ Description Objective Top (ftKB) Bottom (ftKB) Fu11 Return? Cmnt Rtrn (... Top Plug? Btm Plug? Surface Casing Cement 36.9 2,854.0 Yes 170.0 Yes Yes O (start) (bbl/min) O (end) (bbl/min) O (avg) (bbllmin) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 6 720.0 1,200.0 Yes 20.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out O (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Descrption Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 36.9 2,354.0 397 G 314.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.45 20.77 10.70 Additives Additive Type Concentration Conc Unit label _- - ' Fluid - - -.-- Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,354.0 2,854.0 231 G 48.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label Page 1/23 Report Printed: 7/27/2007 r Security Level: Development Daily Drilling Report CD4-215 Report Number: 5 Rig: DOYON 19 Report Date: 12/9/2006 Ncir, a-:li) # Tota l AFE+SuF:~ 10149948 7,341,000.00 Wellbore Well Type Field Name Original Spud Date DFS (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) CD4-215 Development NANUQ 12/6/2006 3.46 2,864.0 2,864.0 0.00 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 5,260.27 43,271.54 327,777.31 1,074,644.58 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 2,854.2ftKB 3 1/2 14,675.00 Ops and Depth @ Morning Report 24hr Forecast Slip & Cut Drilling fine @ 2625' RIH -Drill out shoe -LOT -Drill 8 3/4" Hole Last 24hr Summary Run and Cement 9 5/8" casing - ND Riser -Install Wellhead and NU and test BOPE. General Remarks Weather Head Count 6-N@8mph 50.0 - -- -- Titie Larry HIII, Rig Supervisor /Rig Supervisor Nina Woods, Rig Supervisor Rig Supervisor r Time Log ', Start End D.r - l ~~~ - Depth Start I _ _ _ __ I?oo:h 6 ~ i Time Time (hr~ Pi ,~ . Op Code OpS~L r ?~ F-N-~ '. f rhl Code ~ Trbl Class (HKB) `~F--~~ "~F ~ iacon 00:00 01:15 1.25 SURFAC CASING RNCS P 997.0 1,528.0 Run 48 jts S 5/8" 40# L 80 BTC casing from 997' to 1,528'. (74 totaljts) 01:15 01:45 0.50 SURFAC CASING CIRC P 1,528.0 1,528.0 Circulated Casing volume+ 10 Bbls. @ 4 BPM ICP 290 psi FCP 200 psi. 01:45 04:00 2.25 SURFAC CASING RNCS P 1,528.0 2,854.0 Ran 9 5/8" 40# L 80 BTC casing from 1,528' to 2,854'. Landed casing on hanger. 04:00 04:45 0.75 SURFAC CEMENT RURD P 2,854.0 2,854.0 Laid down Franks tool and installed cement head. 04:45 06:30 1.75 SURFAC CEMENT CIRC P 2,854.0 2,854.0 Circulated casing to condition mud Worked rate up to 7 BPM FCP 340 psi. PJSM. 06:30 08:30 2.00 SURFAC CEMENT DISP P 2,854.0 0.0 Cement 9 5/8" csg as follows :Pumped 40 bbls Biozan water w/ nut plug as marker -Pumped 5 bbls water w/ Dowell -Tested lines to 2500 psi -Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 314 bbls lead slurry (ASL) @ 10.7 ppg Observed nut plug marker @ shakers w/ 371 bbls lead pumped -pumped down surge can) Pumped 48 bbls tail slurry (Class G w/ additives) @ 15.8 ppg - Dropped top plug w/ 20 bbls water f/ Dowell -Switched over to rig pumps & displaced tint w/ 190.4 bbls 9.8 ppg water base mud -Displaced @ 7.0 bbls/min for first 180 bbls -slowed to 4 bbls/min for last 10.4 bbls -Bumped plug w/ 1200 psi (prep bump pressure 720 psi Check float (held OK) CIP @ 08:30 hrs. - Full circulation throughout job w/ 110 bbls 10.7 ppg tint returns to surface - reciprocated pipe while circulating & through cement job until last 90 bbts of displacement. 08:30 09:15 0.75 SURFAC CASING DHEO P 0.0 0.0 Rigged up and tested casing to 2,500 psi for 30 Min. Latest BOP Test Data --- __~ - - C~a'e Comment _ -- -- _ - - - ---- - 12/9/2006 Tested BOPE to 250 and 5000 si. Tested H dril to 250 and 3500 si, Page 1/2 Report Printed: 7/27/2007 Security Level: Development Daily Drilling Report CD4-215 Report Number: 5 Rig: DOYON 19 Report Date: 12/9/2006 Time Log I part Ln:J ^ur Tme Depth Start G~gtt~ Entl ', l`~ri~- lio~c !h~s) Phase OpGode OpS_L rx;~,. _ P-~-T TrblCode Trbl 'i , ~~s. ~' (ftKB) ittKB) ,,_~n 09:15 10:30 1.25 SURFAC CASING RURD P 0.0 0.0 Rigged down casing and cementing tools. Laid down landing jt. 10:30 12:30 2.00 SURFAC CASING NUND P 0.0 0.0 Nippled down riser. Install WH & test to to 1000 psi for 10 min. 12:30 15:00 2.50 SURFAC CASING NUND P 0.0 0.0 NU BOPE turn buckles flow line. 15:00 15:30 0.50 SURFAC WELCTL BOPE P 0.0 0.0 Install test plug - RU to begin testing BOPE - Annular to 250 & 3500 psi f/5 mins. 15:30 23:00 7.50 SURFAC WELCTL BOPE P 0.0 0.0 Test upper, lower, blinds, manual valves, and HCR's on stack, choke, mainfold. Upper & lower IBOP's, dart floor valves. All tested to 250 and 5000 psi for 5 mins. 23:00 00:00 1.00 SURFAC CASING RURD P 0.0 PU Bails, Elevators -Blow down lines - Set mouse hole. Prep to PU BHA. Mud Check Data - Type Deg h ;nhE ~ uens (Ib/g ~ ~ ~~~~ v ii _ Pv ~ , i p~ i Y Gel {1o~ Q6f/t60ft') pbf/10Qrt') ~wu ~~„31t=~ 2 2~ ~ _ ~~~~.i ~i HTHP I=iIt Dens t, T. r, '.E h Ccn~ Ge~(3 ~ (Ibfl100R=~ ~ Mtsi Ib/bbl (mU3Dmin) , H I i ---- p S ud 2 36-7 0 ~, 9 45 ~0 ° 0 .g 1 1 000 0 ~ 4 000, 27.5 9.0 ! 4 _ _ ~_~ i _ ~ - ~ ~----- _-- Wellbores Wellbore Name 'Wellbore AP I/UWI CD4-215 50103053500 ~c --- -- -- ti ~s Size (in) ~ - - Act Top (flYF~ nct.B - - tm (ftKB)i i ~ I s,z CrdDate COND1 SURFAC 36 12 1 /4 0.0 114.0 114.0 12/5/2006 12/5/2006 2, 864.0 12/6/2006 12/8/2006 INTRM 1 8 1 /2 2,864.0 9,524.0 12!10/2006 12/13/2006 PROD1 6.13 9,524.0 14,761.0 12/15/2006 12/20/2006 - LCement - _-- _ -_ - - , Surface Cas in Cement -Started 12/9/2006 Type Wellbore Cemented String Cement Evaluation Results casing CD4-215 Surface, 2,854.2ftK6 110 Bbls to surface. Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Surface Casing Cement 36.9 2,854.0 4 720.0 ~ - -__- - Fu:d - --- - v - ass Amour .;sacs) ':~ (oal) ~. Densdv ~' ~ _ ~ T t~~aal; Yeid {ft' ~ ~ F.~ -' Est T~ -tKeJ L... G.:.: ,i:Pt6; __- _. -- - -- ---- Lead Cement ---- G _.._..__ _ _ 397 314.0 10.70 4.45 36.9 2,354.0 Tail Cement G 231 48.0 15.80 1.17 2,354.0 2,854.0 Page 2/2 Report Printed: 7/27/2007 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. 'Well Name: CD4-215 Rig: Doyon 19 Date: 12/9/2006 Drilling Supervisor: L. Hill / N. Woods Pump used: #2 Mud Pump _ ~ P i d ' ~ Volume Input strokes ~ Volume/Stroke 0.1000 Bbls/strk ~ openholeTest LOT/Frr ~ Type of Test: ump ng own annulus and DP. Casing Test PrE Hole Size: 8-3/4" I ~ Casin Shoe Depth Hole Depth Pumpin Shut-in Pur RKB-CHF: ;3F.9 Ft 2,854 Ft-MD 2,392 Ft-TVD 2,864 Ft-MD 2.398 Ft-TVD Strks psi Min psi Strks Casing Size and Description: ' 9-5/8" 40#/Ft L-80 BTC ~ O 0 0 2500 1 Casin Test Pressure Inte rit Test 2 100 1 2500 2 Mud Weight: 9.8 ppg Mud Weight: 9.6 ppg 4 350 2 2500 3 Mud 10 min Gel: 30.0 Lb/100 Ft2 Mud 10 min Gel: 40.0 Lb/100 Ft2 6 500 3 2500 4 Test Pressure: 2,500 psi Rotating Weight: 135 Lbs 8 775 4 2500 5 Rotating Weight: 75,000 Lbs Blocks/Top Drive Weight: 75,000 Lbs 10 1000 5 2500 6 Blocks/Top Drive Weight: 75,000 Lbs Desired PIT EMW: 18.0 ppg 12 1175 6 2500 7 Estimates for Test: 2 bbls Estimates for Test: 1045 psi 1 bbls 14 1325 7 2500 8 ~ ~ ~ 16 1500 8 2500 9 900 3 EMW =Leak-off Pressure + Mud Weight = 1000 _ PIT 15 Second 18 1700 9 2500 10 1000 0.052 x TVD 0.052 x 2392 + 9.6 ~ Shut-in Pressure, psi 20 1900 10 2500 11 1040 4 EMW at 2854 Ft-MD (2392 Ft-ND) = 17.6 1045 22 2100 15 2500 12 1050 sooo -- ' --' ^ --' ~.~ ~--'--' '--'-' 24 2300 20 2500 13 1060 5 - -- -- ------ - - 26 2500 25 2500 - 30 2500 6 2soo - _ 7 2000 ---- 8 w Q: ~ lsoo - - 9 - - w o: a loon - - soo a 1.51 1000 9 0 1 2 3 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes Volume Volume Volume Volume ~~CASING TEST BLEAK-OFF TEST O PIT Point PUm ed Bled Back PUm ed Bled Back s s s s Casing tested after bumping plugs on cement job. Pump Rate: 8.0 Strk/min ~ ure Inte rit Test i Shut-in psi Min psi 90 0 1050 7" Csg Detail ConocoPhillips Alaska, Inc. Well: CD4-215 Date: 12/14/2006 Subsidiary of PHILLIPS PETROLEUM Company DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 34.57 FMC Gen V Hanger 2.61 34.57 Jts 3 to 221 219 Jts 7" 26# L-80 BTCM Csg 9388.11 37.18 Halliburton Float Collar 1.05 9425.29 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 86.02 9426.34 Ray Oil Tools "Sliver Bullet" Float Shoe 2.10 9512.36 7" Shoe @ 9514.46 8 3/4" hole TD @ 9524.00 8 3/4" hole TD @ 9524 ' MD / 6215' TVD 7" Shoe @ 9514.46' MD / 6214 ' TVD Total Centralizers: 57 Straight blade centralizers one per jt. on jts. # 1-14 Straight blade cent. one per jt. on jts. # 94 - 103 Straight blade cent. One per jt # 156-158 Straight blade cent. One every other jt. 160 to 218 235 jts in shed - 221 total jts. to run Last 14 jts. Out Used Jet Lube Run-N-Seal pipe do e Remarks: Up wt - 275 k Dnwt-150k Blocks - 70k Make up torque - -8000 ft/Ibs SupervisorD. Burley/D. Mickey • PHILLIPS ALASKA INC CASING TALLY PAGE: 2 of 4 WELL NUMBER: CD4-215 RIG: Doyon 19 CASING DESCRIPTION: 7" 26# L-80 BTCM DATE: 12/14/06 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 42.93 26 43.29 51 43.50 76 43.26 101 43.40 126 41.62 151 43.50 176 43.17 2 43.09 27 43.36 52 43.23 77 42.02 102 43.53 127 43.07 152 41.70 177 43.33 3 43.48 28 43.30 53 43.50 78 43.21 103 43.19 128 42.85 153 41.62 178 43.39 4 38.71 29 43.45 54 43.44 79 42.93 104 42.11 129 42.63 154 43.24 179 43.51 5 43.45 30 43.35 55 43.23 80 40.96 105 43.67 130 42.96 155 43.33 180 42.44 6 42.35 31 43.36 56 41.53 81 42.58 106 42.80 131 42.71 156 43.32 181 43.65 7 42.71 32 43.20 57 43.44 82 43.44 107 43.55 132 41.39 157 42.79 182 43.48 8 43.41 33 43.37 58 42.84 83 43.24 108 41.78 133 42.54 158 40.56 183 43.30 9 42.45 34 43.08 59 42.44 84 43.82 109 42.21 134 42.75 159 42.96 184 43.24 10 43.16 35 43.42 60 36.11 85 43.35 110 41.48 135 41.59 160 43.39 185 43.46 11 41.19 36 41.29 61 41.66 86 43.34 111 43.19 136 43.52 161 40.93 186 43.42 12 43.61 37 43.47 62 42.64 87 42.97 112 43.06 137 43.29 162 43.15 187 39.59 13 43.27 38 43.22 63 43.57 88 43.51 113 43.23 138 43.51 163 43.40 188 43.35 14 41.81 39 43.46 64 42.46 89 43.41 114 43.26 139 43.53 164 40.18 189 43.99 15 43.24 40 42.39 65 43.29 90 43.67 115 43.16 140 43.59 165 43.41 190 43.48 16 43.51 41 41.11 66 41.82 91 40.84 116 41.45 141 43.10 166 42.25 191 43.32 17 43.54 42 43.35 67 43.42 92 43.02 117 42.97 142 43.36 167 43.50 192 43.39 18 43.39 43 43.06 68 43.52 93 43.40 118 42.63 143 39.19 168 44.01 193 43.52 19 43.44 44 42.78 69 42.83 94 43.88 119 43.36 144 43.35 169 44.06 194 43.08 20 43.22 45 43.40 70 43.45 95 43.59 120 43.39 145 42.96 170 43.37 195 43.52 21 43.68 46 41.67 71 42.62 96 42.15 121 43.19 146 42.58 171 42.34 196 43.24 22 43.51 47 41.86 72 43.27 97 43.52 122 43.56 147 43.55 172 41.63 197 43.30 23 43.35 48 43.50 73 41.13 98 41.67 123 43.30 148 42.74 173 43.41 198 43.53 24 43.58 49 43.27 74 43.23 99 43.46 124 43.44 149 43.59 174 43.18 199 42.30 25 43.50 50 43.17 75 41.64 100 43.79 125 43.17 150 43.38 175 43.44 200 43.62 Tot 1073.58 Tot 1074.18 Tot 1063.81 Tot 1075.03 Tot 1074.08 Tot 1069.35 Tot 1068.67 Tot 1079.62 TOTAL LENGTH THIS PAGE = 8578.32 DIRECTIONS: TOTAL JOINTS THIS PAGE = 200 RKB - 34.40 Hanger - 2.64 FC - 1.04 FS - 2.08 PHILLIPS ALASKA INC CASING TALLY PAGE: 3 of 4 WELL NUMBER: CD4-215 RIG: Doyon 19 CASING DESCRIPTION: 7" 26# L-80 BTCM DATE: 12/14/06 Column 9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 43.10 226 432 251 276 301 326 351 376 202 41.98 227 493 252 277 302 327 352 377 203 43.09 228 42-20 253 278 303 328 353 378 204 43.46 229 43.87 254 279 304 329 354 379 205 43.51 230 42.34 255 280 305 330 355 380 206 41.67 231 43-29 256 281 306 331 356 381 207 43.65 232 43.43 257 282 307 332 357 382 208 41.49 233 42:27 258 283 308 333 358 383 209 43.21 234 42-63 259 284 309 334 359 384 210 43.47 235 4x-52 260 285 310 335 360 385 211 43.50 236 261 286 311 336 361 386 212 43.28 237 262 287 312 337 362 387 213 43.13 238 263 288 313 338 363 388 214 37.89 239 264 289 314 339 364 389 215 43.39 240 265 290 315 340 365 390 216 40.75 241 266 291 316 341 366 391 217 42.19 242 267 292 317 342 367 392 218 43.24 243 268 293 318 343 368 393 219 42.55 244 269 294 319 344 369 394 220 43.89 245 270 295 320 345 370 395 221 43.37 246 271 296 321 346 371 396 222 4356 247 272 297 322 347 372 397 223 43.47 248 273 298 323 348 373 398 224 42.93 249 274 299 324 349 374 399 225 43-38 250 275 300 325 350 375 400 Tot 1069.07 Tot 426.23 Tot Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 1495.30 TOTAL JOINTS THIS PAGE = 35.00 AVERAGE JT = 42.72 r ~ Cement Detail Report CD4-215 Intermediate Casing Cement Primary Job Type Job Category AFE / RFE / Maint.# Actual Start Date Spud / KO Date End Date DRILLING ORIGINAL DRILLING 10149948 12/5/2006 12/6/2006 12/25/2006 'Cement Details - - Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 12/14/2006 00:00 12!14/2006 00:00 CD4-215 Comment Cemented 7" csg as follows: Pumped 5 bbls CW-100 -Tested lines to 3700 psi -Pumped 15 bbls CW-100 @ 3.8 bbls/min @ 333 psi -Mixed & pumped 30 bbls 10.5 ppg MudPush @ 5 bbls/min @ 422 psi -Dropped btm plug -Mixed & pumped 122 bbs 11.0 ppg Lead slurry (LiteCrete) @ 5.8 bbls/min @ 400 psi - Mixed & pumped 67 bbls 15.8 ppg tail slurry (Class G w/ additives) @ 6 bbls/min @ 300 psi -Dropped top plug w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced cmt w/ 340.5 bbls 9.9 ppg LSND mud @ 6.5 bbls/min for first 150 bbls - 6 bbls /min for next 100 bbls - 5.2 bbls/min for next 70 bbls - 3.5 bbls /min for last 20.5 bbls -final pressure prior to bumping plug 840 psi -Bumped plug w/1300 psi -Checked floats OK - CIP @ 23:22 hrs. -Full circ thoughoutjob -- -- --- - - -- - - 'Cement Stages - - -- -- - -- --- - Sta e # <Sta .:Number?> Description Objective Top (ftK6) Bottom (ftK6) Full Return? Cmnt Rtm (... Top Plug? Btm Plug? Intermediate Casing 4,802.0 9,514.0 .Yes 0.0 Yes Yes Cement Q (start) (bbl/min) O (end) (bbl/min) O (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 4 6 840.0 1,300.0 Yes 25.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment - - ~,Cement Fluids ?£Additives -- - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) CW-100 2,946.0 3,692.0 20.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.30 Additives Additive Type Concentration Conc Unit label 'Fluid Fluid Type 'Fluid Description Estirated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class 'Volume Pumped (bbl) Mud Push 3,692.0 4,802.0 30.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid _ - ---- Fluid Type Flwd Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbi) Lead Cement 4,802.0 7,869.0 195 LiteCrete 122.0 Yield (ft'lsack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) Cmpr tr 1 (psi) 3.35 11.22 11.00 Additives Additive Type Concentration Conc Unit label -- ---- - - Fluid -- - -- Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 7,869.0 8,514.0 321 G 67.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.10 15.80 Additives Additive Type Concentration Conc Unit label Stage t# <Stage Number?> Description Objective Top (ftKB) Bottom (ftK6) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? No No No Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Page 1/23 Report Printed: 7/27/2007 Security Level: Development Daily Drilling Report CD4-215 Report Number: 10 tig: DOYON 19 Report Date: 12/14/2006 Nc~. r.n-FrID# - io:aA~E+Sup 10149948 --- - - 7,341,000.00 Wellbore Well Type Field Name Original Spud Date DFS (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) CD4-215 Development NANUQ 12/6/2006 8.46 9,524.0 9,524.0 0.00 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 3, 576.21 168, 325.66 523, 085.21 2,494,473.70 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 9,514.5ftK6 3 1/2 14,675.00 Ops and Depth ~ Morning Report 24hr Forecast MU BHA # 3 RIH -clean out shoe track -FIT -Drill 6 1/8" hole Last 24hr Summary LD BHA - RU -Run & Cmt 7" csg -Test csg General Remarks Weather Head Count 3/-17 WC / NE@ 14mph 50.0 Supervisor - 7iic Dave Burley, Rig Supervisor Rig Supervisor Don Mickey, Rig Supervisor Rig Supervisor Time Log Start ~. Fn~i Dur ~ Time j Gq h 3la~t .r. plh Fnd ', ~ Tim., Toy ~ i I P~~~;, c'F, ;,,d-, t rSuL Co~:je P-N-T ~ t Cr,d~~ ~ Trk~l .i-=s ~ '~F-h? ~I1KF! ',. Operation 00:00 01:00 ~ 1.00 INTRM2 DRILL TRIP P 3,108.0 711.0 PUDH from 3108' to 711' -laid down Ghost reamers -flow checks at shoe & 711', static. 01:00 03:45 2.75 INTRM2 DRILL PULD P 711.0 0.0 Stand back hwdp & flex collars - LD jars - Down load LWD - LD MWD, pony collar - GeoPilot and bit -blow down Geospan skid -clear tools from rig floor 03:45 04:00 0.25 INTRM2 WELCTL SFTY P 0.0 0.0 PJSM on changing pipe rams 04:00 06:15 2.25 INTRM2 WELCTL OTHR P 0.0 0.0 Change Top pipe rams to 7" -pull wear bushing and install test plug -test 7" pipe rams 250/5000 psi -pull test plug and install thin wall wear bushing 06:15 07:30 1.25 INTRM2 CASING RURD P 0.0 0.0 RU to run 7" casing 07:30 07:45 0.25 INTRM2 CASING SFTY P 0.0 0.0 Held pre-job safety and opts meeting with crew 07:45 12:15 4.50 INTRM2 CASING RNCS P 0.0 4,075.0 Run 7" 26# L-80 BTCM csg as follows: FS (Ray Oil tools silver bullet) 2 jts. csg - FC (Hallibutton) 2 jts, csg (first 4 jts. made up w/BakerLoc -filled pipe & checked floats) 91 jts to 4075' (95 jts total) 12:15 13:00 0.75 INTRM2 CASING CIRC P 4,075.0 4,075.0 Break circ -stage pump to 6.0 bbls/min. - Circulate and condition mud -FCP 500 psi -PUW 155 SOW 130 13:00 16:00 3.00 INTRM2 CASING RNCS P 4,075.0 7,717.0 Run 7" 26# L-80 BTCM from 4075' to 7717 (180 jts total) 16:00 17:00 1.00 INTRM2 CASING CIRC P 7,717.0 7,717.0 Break circ -stage pump to 6.0 bbls/min. - Circulate and condition mud -FCP 670 psi -PUW 225 SOW 150 17:00 18:45 1.75 INTRM2 CASING RNCS P 7,717.0 9,514.0 Continue running 7" 26# L-80 BTCM f/ 7717' to 9477' (221 jts total PU FMC fluted hanger & landing jt. -Land 7" csg in wellhead on FMC fluted hanger w/ shoe @ 9514.46' & FC @ 9425.29' 18:45 19:00 0.25 INTRM2 CASING OTHR P 9,514.0 9,514.0 LD fill up tool -Blow down TD - RU cmt head & lines 19:00 21:00 2.00 INTRM2 CEMENT CIRC P 9,514.0 9,514.0 Break circ @ 2.0 bbls /min & stage pump up to 6 bbls/min @ 520 psi - Circ & condition mud for cmt job Latest BOP Test Data ~, ~.r - - r .i meat 12/9/2006 Tested BOPE to 250 and 5000 si. Tested H dril to 250 and 3500 si. Page 1!2 Report Printed: 7/27/2007 ~~ Security Level: Development Daily Drilling Report CD4-215 Report Number: 10 .. . Rig: DOYON 19 Report Date: 12/14/2006 --- Time Log -_ - - Start end Dur Time Depth Start Depth Cad Time -ri:-r._ (hrs) Phase OpG©C_ r~~~~L Ca:i~> P-N-T ~ -r~,Ua Trbl Class_ (ftK6) (n P: E;~ ~eraho. 21:00 21:15 0.25 INTRM2 CEMENT SFTY P 9,514.0 9,514.0 Held pre job safety meeting on cementing csg with crew 21:15 23:30 2.25 INTRM2 CEMENT DISP P 9,514.0 9,514.0 Cemented 7" csg as follows: Pumped 5 bbls CW-100 -Tested lines to 3700 psi - Pumped 15 bbls CW-100 @ 3.8 bbls/min @ 333 psi -Mixed & pumped 30 bbls 10.5 ppg MudPush @ 5 bbls/min @ 422 psi -Dropped btm plug -Mixed & pumped 122 bbs 11.0 ppg Lead slurry LiteCrete) @ 5.8 bbls/min @ 400 psi - Mixed & pumped 67 bbls 15.8 ppg tail slurry (Class G w/ additives) @ 6 bbls/min @ 300 psi -Dropped top plug w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced cmt w/ 340.5 bbls 9.9 ppg LSND mud @ 6.5 bbls/min for first 150 bbls - 6 bbls /min for next 100 bbls - 5.2 bbls/min for next 70 bbls - 3.5 bbls /min for last 20.5 bbls -final pressure prior to bumping plug 840 psi - Bumped plug w/1300 psi -Checked floats OK - CIP @ 23:22 hrs. -Full circ thoughoutjob 23:30 00:00 0.50 INTRM2 CEMENT OTHR P 9,514.0 9,514.0 RU & test 7" csg to 3500 psi for 30 mins. __ -- --- - - Mud Check Data _ _ __ _ __ ~'~ ~ ~ t,;~l- 'Gel (10s) Gel (10m) Gel.{30mj HTHP Fllt ! ,i D'n I-~ i~~ ', olids, Corr. T.ps L~•;th (flhl- I;~.~~, i ~r, yqt) PV Ca_,_~j I t 1uC!iP~ ~ (Ibf/1 DDft') (Ibf1100R') {bflt00ft') MBT (blbt :; ;mU30mIn) ~, off ~ 'i {%) _ _ J -- - - -- -- - LSND 9,524.0 10.10 48 9.0 23.000 9.0 11.0 13.000 19.0 9.2 9.1 84.0 11.0 LSND 9,524.0 9.80 42 8.0 23.000 10.0 12.0 13.000 17.5 9.0 9.3 90.0 9.5 In"ection Fluid - - __ --- --- -- ----_ - -- __ . ~: F na Source Fri n L~r-: - i:,. ~,-.... -. - Cir.t ~.ii i~r~. Nate - - - - -- -- -- -- i - - - c, Water Based Mud 560.0 CD 1 1 F! CD4-215 ---1 Wellbores Wellbore Name Wellbore API/UWI CD4-Z15 501032053900 JI Se_Go~ Size {ini Acf Top (ftK6) Ac3 Btm (ftK6)- i r~=~~~- -~ End fia~, ~~ CON D 1 36 0.0 114.0 12/5/2006 12/5/2006 SURFAC 12 1 /4 114.0 2,864.0 12/6/2006 12/8/2006 I NTRM 1 8 1 /2 2,864.0 9,524.0 12/10/2006 12/13/2006 PROD1 6.13 9,524.0 14,761.0 12/15/2006 12/20/2006 Casin Strin s _ _ _ _ i Casing Description F ~r I i - ) ( ) p ( ) - l~l)~in 1Nt Ibslft Grade Set De th #1KB Goimnent Intermediate 12/14 0~6 71 ?6.00 L-80 9,514.51. -- -- - -- - __ ICement Intermediate Casin Cement -Started 12/14/2006 Type Wellbore Cemented String Cement Evaluation Results casing CD4-215 Intermediate, 9,514.5ftK6 Stg No. Description Top (ftK6) Bottom (ftK6) Q (end) (bbl/... P (final) (psi) Intermediate Casing Cement 4,802.0 9,514.0 4 840.0 -- ;_1; - - - - - - ~ ~,d Class Amount (sar .,1 ~. hbi Densi , I , Y ~'~d ffl %? -, Est Top (ftY.[3) ---~, E=t Btm {ftK6) CW-100 20.0 8.30 2,946.0 3,692.0 Mud Push 30.0 10.50 3,692.0 4,802.0 Lead Cement LiteCrete 195 122.0 11.00 3.35 4,802.0 7,869.0 Tail Cement G 321 67.0 15.80 1.16 7,869.0 9,514.0 Stg No. Description Top (ftK6) Bottom (ftK6) Q (end) (bbl/... P (final) (psi) Page 2/2 Report Printed: 7/27/2007 ~~ Security Level: Development Daily Drilling Report CD4-215 Report Number: 11 Rig: DOYON 19 Report Date: 12/15/2006 __. -- - ---- - - - ---- --- -- Total AFE+Sup - - _- N etwork/ID ? _. 10149948 _ _ 7,341,000.00 Wellbore Well Type Field Name Original Spud Date DFS (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) CD4-215 Development NANUQ 12/6/2006 9.46 9,524.0 9,546.0 22.00 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 8,375.00 176,700.66 254,637.00 2,749,110.70 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 9,514.5ftKB 3 1/2 14,675.00 Ops and Depth ~ Morning Report 24hr Forecast Monitor well Drill6 1/8" hole Last 24hr Summary RD cmt equip.- Set & test pack-off - MU BHA #3 -RIH to top cmt -Clean out shoe track -Drill 20' new hole -perform FIT 12.5 - CO to 9.2 FlowPro General Remarks Weather Head Count Function tested BOPE 0/-22 we / NE@ 21 mph 52.0 ,~~~- nave Burley, Kig Supervisor Rlg Supervisor Don Mickey, Rig Supervisor Rig Supervisor _ _ _ _ - - - - Time Loq , -- - r - ~ _- - -- - Start End Dur ', ~.n~,~ 1 i C I~ i F+=a Time Time (hi,~ I~r ;~ I ri ~,,,;:.. I U;~8uL t, - i'N T GI-; Code -Trbl Class r.b i ~ tiE,l i,~-,a~~cn 00:00 00:15 0.25 INTRM2 CASING DHECt P 9,514.0 9,514.0 Complete 3500 psi casing test -blow down lines 00:15 01:15 1.00 INTRM2 CASING NUND P 0.0 0.0 LD cement head, Landing jt. & casing running tools -pull thin wall wear bushing 01:15 02:00 0.75 INTRM2 CASING DHEQ P 0.0 0.0 Install and test packoff to 5000 psi for 10 minutes 02:00 03:45 1.75 INTRM2 WELCTL OTHR P 0.0 0.0 Change top pipe rams to 3 1/2" X 6" VBR's -set test plug & test rams to 250/5000 psi -pull test plug -install wear bushing 03:45 07:00 3.25 INTRM2 DRILL PULD P 0.0 375.0 MU BHA #3 -Bit /Geo Pilot / nmpc / stab / MWD ! PWD / FS / -initialize tools - PU 3 NMFC's / xo -RIH with hwdp to 375' 07:00 07:30 0.50 INTRM2 RIGMNT SVRG P 375.0 375.0 Service top drive and drawworks 07:30 08:00 0.50 INTRM2 DRILL TRIP P 375.0 1,403.0 RIH w/ 4" drill pipe from 375' to 1,403' 08:00 08:30 0.50 INTRM2 DRILL OTHR P 1,403.0 1,403.0 Pressure test Geo Span skid to 3500 psi -shallow test tools 08:30 12:15 3.75 INTRM2 DRILL TRIP P 1,403.0 9,238.0 RIH from 1,403' to 9,238' -fill pipe every 20 stands 12:15 12:45 0.50 INTRM2 DRILL OTHR P 9,238.0 9,310.0 Wash down from 9,238' to 9310' -break in Geopilot seals 12:45 14:00 1.25 INTRM2 CEMENT COCF P 9,310.0 9,417.0 Clean out cement from 9,310' to 9417' (drill pipe measurements) 14:00 21:45 7.75 INTRM2 CEMENT DRLG P 9,417.0 9,546.0 Drill up wiper plugs - FC - tint to FS drill out shoe -clean out rat hole & Drill 20' new hole to 9546' 21:45 22:45 1.00 INTRM2 DRILL CIRC P 9,546.0 9,546.0 Circ hole clean for FIT - 197 GPM @ 1250 psi w/ 40 rpm 22:45 23:30 0.75 INTRM2 DRILL FIT P 9,546.0 9,546.0 RU & perform FIT to 12.5 ppg EMW - RD 23:30 00:00 0.50 PROD1 DRILL CIRC P 9,546.0 9,546.0 Chnage well over f/ 9.6 ppg LSND to 9.2 ppg FlowPro ~MUd Check Data _ _ _ , f' i,as G21 (COs) I t.r-i; I ;GT HTHP Filt I'Crc I i i~ I J ~~~-r I, -- - _. _ _~ - I r~t>/T~i__Jj ~mL130min H - --~ _- . Type DeF..~ ~`.tKBj Dens Q6lgalj V... ,...:, ; PJ .._i_ ,_~ ~:,`t) Qbfl'ItlOft" ~ I ~ ~ "ff` ~ I r ~~~~ 1 ) p ~ ~ LSND 9,524.0 9.60 33 6.0 16.000 5.0 7.0 8.000 16.0 9.6 10.3 8.5 LSND 9,524.0 9.85 39 7.0 18.000 6.0 8.0 8.000 17.5 9.6 9.0 10.OI Latest BOP Test Data -- - _ - - - -- _ Comment 12/9/2006 (Tested BOPE to 250 and 5000 psi. Tested Hydril to 250 and 3500 psi. Page 112 Report Printed: 7/27/2007 r Security Level: Development Daily Drilling Repo rt CD4-215 Report Number: 11 Rig: DOYON 19 Report Date: 12/15/2006 _ In'ection Fluid - _ - _ Flu,d --- S~ _ ~ ~r ----- From lease (bbl) _. _. r~ati~n U - N.:~ - Diesel Water 64.0 300.0 Freeze protect CD4-215 Annular flush CD4-215 Water Based Mud 1400.0 CD1-19 f/ CD4-215 Water Based Mud 7.0 Annular LOTCD4-215 - -- ' Drill Strips: BHA No. 3 - Production / Bit Run No. 3 - - 6 118in, Halliburton Security DBS - , FSF2553Z , <SN?> - - Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (ins) Nozzles (l32") IADC Bit Dull String Wt (10001b~ WOB (max) (700... WOB (min) (1000... 9,524.0 14,761.0 2-1-ER-N-X-I-NO-TD 9 0 0 Drill String Components _ _ _ ,its P.=m Descraptlr ~- OD{in) ID ~ ~~, r ' Top Conn Sz (in) Top Thread Cum Len (ft) 1 Geo Pilot 4 3/4 1.500 3 1/2 NC 38 16.19 1 Drill Collar -Flex Non Mag 4 3/4 1.500 3 1/2 NC 38 27.71 1 Stabilizer (Non Mag) 4.76 1.500 3 1/2 NC 38 31.30 1 MWD DM HOC 4 3/4 1.500 3 1/2 NC 38 39.82 1 MWD GR/RES 4.73 1.500 3 1/2 NC 38 64.36 1 MWD PWD 4.7 1.500 3 1/2 NC 38 75.22 1 MWD TM HOC 4.62 1.500 3 1/2 NC 38 86.12 1 Float Sub 4.66 2.313 3 1/2 NC 38 88.30 1 Stabilizer (Non Mag) 4 3/4 2.250 3 1/2 NC 38 93.84 1 NMDC 4.68 2.250 3 1/2 NC 38 124.83 1 NMDC 4.56 2.250 3 1/2 NC 38 155.74 1 NMDC 4.52 2.250 3 1/2 NC 38 186.88 1 XO Sub 4.8 2.563 4 XT 39 189.38 3 HWDP 4 2.563 4 XT 39 280.94 1 Drilling Jars - DNT 4 3/4 2.000 4 XT 39 313.11 2 HWDP 4 2.563 4 XT 39 374.45 - I Drilling'Parameters - Flow Rate Slicl na Cum Dn7I (9Pm) RPM '.>'.ar `•BH; F .`•RB) Time ~ ^ C.:rr D ,i ;'.~~ I n~c (hrs) (9Pm) WOB (Ibt•) PPm) SPP {psi) _- ____ Fi i ;i- Wt Dnl r'.J ~ i UOiof) (1 ~ ~I:,t - ~ - I - - ~ r ~ I 1~_ It ~ - Bt~r l q ~~, L I Ty 5,524.0 9-545.0 22 00 0.25 200 10.0 40 1,240.0 230 165 130 12000.0 12.000.© ellbores Wellbore Name _ 1Nellbore API/UWI ___ CD4-2i5 501032053900 Section ~ Size {in) Act Top (ftKB) Act Bim (8K B) Start Date End Date GON D 1 36 0.0 114.0 12/5/2006 12!5/2006 SURFAC 12 1 /4 114.0 2,864.0 12/6/2006 12/8/2006 INTRMI 8 1!2 2,864.0 9,524.0 12/10/2006 12/13/2006 PROD1 6.13 9,524.0 14,761.0 12/15/2006 12/20/2006 Page 2/2 Report Printed: 7/27/2007 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-215 Rig: Doyon 19 Date: 12/15/2006 Volume Inpu Drilling Supervisor: D. Burley / D. Mickey Pump used: Cement Unit ~ Barrels Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. ~ Cas Hole Size: 8-3/4" ~ Casin Shoe Depth Hole Depth Pumpin RKB-CHF: 34 Ft 2,854 Ft-MD 2,392 Ft-TVD 4,802 Ft-MD 3.748 Ft-TVD Bbls psi Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC ~ Description references outer casing string. Inner casing OD: 7.0 In. ize is that drilled below outer casing. timated TOC for Hole Depth. Enter inner casing OD at right Desired PIT EMW: 16.0 ppg Estimates for Test: 771 psi 0.4 bbls ~ ~ EMW =Leak-off Pressure + Mud Weight = 958 + 9 8 PIT 15 Second 0.052 x TVD 0.052 x 2392 Shut-in Pressure, psi EMW at 2854 Ft-MD (2392 Ft-TVD) = 17.5 544 1500 Bbls/Strk • Shut-in 1 Pump Rate: 0.8 Bbl/min Shut-in in si 0 570 .25 544 0.5 504 1 4~ 1.5 2 492 2.5 490 3 489 3.5 488 5 485 5.5 484 6 484 7.51 481 looo w w a soo 9 0 1 2 3 4 5 6 7 8 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes Volume Volume Volume Vol ~~CASING TEST --i-LEAK-OFF TEST O PIT Point PUm ed Bled Back Pum ed Bled s s s ~: 9 5/8" casing shoe PIT = 17.8 ppg STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS l~E~EIVED JUN 0 1 2007 nv,.,.~- r,•~ 1. Operations Performed: Abandon ^ Repair Weli ^ Plug Perforations ^ Stimulate 0 Other ' chorage 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 ^ 206-157 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20539-00 ` 7. KB Elevation (ft): 9. Well Name and Number: RKB 57' CD4-215 - 8. Property Designation: 10. Field/Pool(s): ADL 380077, 384209,388902 Colville River Field, Nanuq Nanuq Oil Pool ~ 11. Present Well Condition Summary: Total Depth measured 14761' feet true vertical 6205' i feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing ~ Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' SURFACE 2797' 9-5/8" 2854' PRODUCTION 9458' 7" 9515' SLOTTED LINER 5314' 3-1/2" 14675' Perforation depth: Measured depth: slotted liner from 9501'-14673', add perfs 9555'-9575' true vertical depth: slotted liner from 6213', add perfs 6218'-6220' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 9380' MD. Packers &SSSV (type & measured depth) Baker Premier Packer Packer = 8204' Schlumberger TRM4XX-SE SSSV = 2142' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 9501'-14675' Treatment descriptions including volumes used and final pressure : See attachment 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-bbl Casin Pressure Tubin Pressure Prior to well operation 403 ~ 638 248 Subsequent to operation 756 ~ 927 1185 537 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: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: ®`1 contact Jack Walker Printed Name Jac k W alker Title Production Engineer Signature G~'C ' ~) , q a ~ ,, (/v _ ~ Date ~ ~~/`(~', Phone ~~ J ~ ~ /' ` / v , P r an ne Haa 263-4470 ....._...e._...e..., .~~ G- 5~. o~ Form 10-404 Revised 04/2006 ~ ~ JUN ! ~ ~~~ (~ Submit Original Only ~StQ CD4-215 Stimulation results: 4-25-07 Pump frac stages in stair steps; 2, 3, 5, & 6 with 12 PPA, 49 bbls. diesel for freeze protect. 25 BPM, 310,000 lbs. 20/40 Carbolite in perfs. ALPINE CD4-21.5 CD4-215 API: 501032053900 Well T e: PROD An le TS: de SSSV T e: TRDP Ori Com letion: 12/25/2006 An le TD: 95 de 14761 Annular Fluid: Last W/O: Rev Reason: FRAC, PULL FRAC SLV GLV C/O Reference Lo 31' RKB Ref Lo Date: Last U ate: 5/20/2007 Last Ta TD: 14761 ftK6 Last Tag Date: Max Hole Qngl~~ 9S tleq 1@ 4629 , Perf (9501-9712) FRAC (10550-14673) Perf (11566-11627) Perf (12184-12730) Perf (12852-13395) Perf (13549-13638) Perf (13793-14280) Perf (14342-14403) Perf (14497-14673) 1 I i I 1 1 1 I I 1 I ~ ~ I 1 1 1 1 I 1 I 1 1 I 1 I 1 I 1 I 1 ' 1 I Casing 5tring -ALL STRINGS Descri lion Size To Bottom TVD YVt Grade Thread CONDUCTOR 16.000 0 114 114 68.00 H-40 WELD SURFACE 9.625 0 2854 2392 40.00 L-80 BTC PRODUCTION 7.000 0 9515 6214 26.00 L-80 BTCM CI nTTFn I INFR v snn Q'~R1 1dC.7S 8711 Q ~n 1 _Rn CI HT Tubing String -TUBING Size To Bottom TVD Wt Grade Thread 4.500 0 3997 3164 9.30 L-80 IBTM 3.500 3997 9380 6197 9.30 L-80 IBTM/ 3.5" VIT inside 4.5" TR(' - (Perforations Summary __ Interval TVD Zone Status Ft SP F Date T e Comment 9501 - 9555 6213 - 6218 54 16 11/23/2006 Slots Alternating solid/slotted pipe w/0.125" x2 .25" slots 9555 - 9575 6218 - 6220 20 22 4/22/2007 APERF 2.5" Hyperjet Charges, 60 deg orient 9575 - 9712 6220 - 6235 i37 16 11 /23/2006 Slots Altemating solidlslotted pipe w/0.125" x2 .25" slots 10550 - 10733 6231 - 6219 183 16 11/23/2006 Slots Alternating solid/slotted pipe w/0.125" ~C2 .25" slots 10857 - 11039 6218 - 6227 182 16 11/23/2006 Slots Alternating solid/slotted pipe w/0.125" x2 .25" slots 11566 - 11627 6247 - 6244 61 16 11/23/2006 Slots Alternating solid/slotted pipe w/0.125" XL .25" slots 12184 - 12730 6219 - 6215 546 16 11/23/2006 Slots Alternating solidlslotted pipe w/0.125" x2 .25" slots 12852 - 13395 6219 - 6225 543 16 11 /23!2006 Slots Altemating solid/slotted pipe w/0.125" x2 .25" slots 13549 - 13638 6234 - 6240 89 16 11/23!2006 Slots Altemating solid/slotted pipe w10.125" x2 .25" slots 13793 - 14280 6248 - 6247 487 16 11/23/2006 Slots Alternating solid/slotted pipe w/0.125" x2 .25" slots 14342 - 14403 6243 - 6239 61 16 11/23/2006 Slots Alternating solid/slotted pipe w/0.125" X2 .25" slots 14497 - 14673 6231 - 6213 176 16 11/23/2006 Slots Alternating solid/slotted pipe wl0 125" ~ 25" slots 5timlllations tSr. Treatments Interval Date T e Comment ~.~9E"- 14673 4/25/2007 FRAC FRAC NANUO FORMATION 310,000# 20/40 CARBOLITE `IUD/ ,rw _ WORKING UP FROM 1 ppa TO 12 ppa ON FORMATION. Gas Lift MandrelsNa lves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmn 1 4355 3421 CAMCO KBMG GLV 1.0 BK-5 0.188 1907 4/27/2007 2 8115 5814 CAMCO KBMG OV 1 0 BK_-5 _ 0250 0 4/2.6/2007 _Other (plugs, equip., etc.) - COMPi.E TION Death I TVD Tvoe I Description I ID 8204 1 5856 I PACKER SLICKLINE NOIT ABLE TO PULL DEBRIS OR RHC ASSEMBLY IS IN TBG; - 2.875 8283 5891 NIP HES'XN' NIPPLE ~ 2.750 93 6197 WLEG I BAKER WIRELINE GUIDE 2 RSn ,Other De th (plug TVD s, equip., T e _ etc.) -SLOTTED LINER QETAIL Descri tion ID 9361 6195 SLEEVE BAKER'HR' LINER SETTING SLEEVE 4.420 9374 6196 NIP BAKER'RS' SEAL NIPPLE 4.250 9378 6197 HANGER BAKER'DG' FLEX LOCK HANGER 4.400 93RR 6198 XO CROSSOVER 5.5"x4.5" 4.500 w • ~~Q~f~ Ofd ~~~~~~G:~~~{l~ /,.,..a~.w~,~. Jack Walker Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Nanuq Nanuq Oil Pool, CD4-215 Sundry Number: 307-135 Dear Mr. Walker: 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. DATED this day of April, 2007 Encl. Sincerely, ' ~ ~/18> r -'~"~'~~ ~ ~' q..I S-off STATE OF ALASKA ~~ry~~g RECEIVEd ALASKA OIL AND GAS CONSERVATION COMMISSION APR 1 7 2Q07 APPLICATION FOR SUNDRY APPROVALp~aska Oil & Gas Cons. Commission 20 AAC 25.280 Anrhnr~nn 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repairwell ^ Plug Perforations ^ Stimulate Q Time Extension ^ 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 ^ f Exploratory ^ 206-157 ~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20539-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Y0S ^ NO Q CD4-215 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380077, 384209, 388902 ~ RKB 57' Colville River Field, Nanuq Nanuq Oil Pool ~ 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Ptugs (measured}: Junk (measured): 14761' ~ 6205' Casing Length Size MD ND Burst Collapse CONDUCTOR 114' 16" 114' SURFACE 2787' 9-5/8" 2854' PRODUCTION 9458' 7" 9515' SLOTTED LINER 5314' 3-1/2" 14675' Perforation Depth MD (ft): ~, / Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): ~ riv- ~/,e, 1'/0~`~ /.%Y.>' 3-1/2" L-80 9380' Pa keys and SSSV Type: Packers and SSSV MD (ft) Baker Premier Packer Packer = 8204' SSSV= SSSV SG/ilwr~ivw w T''d-MQ.X k -sue ~ SSSV= 2142' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ ' Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: April 7s, 2007 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 ~~~ (~- Phone 265-6268 Date ~~/7/O~ Commission Use Only Conditions of a roval: Notif Commission so that a re resentati ve ma witness Sundry N~er_ /~ 77 y pp p y Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~~ APPROVED BY 9 Approved by: COMMISSIONER THE COMMISSION Date: y r Form 10-403 Revised 06/2006 APR ~ U 20D7 Submit in Duplicate •/8a j ~.`C• Overview: ~ CD4-215: A hydraulic fracture treatment will be performed in the horizontal section to establish communication vertically through the Nanuq sand. This will increase the production rate and reserves. A coil cleanout will only be performed should it be necessary post-frac. Procedure: ,, 1. Perforate slotted liner with 6 shots per foot at 10,900 - 10,920'MD to help pass proppant. 2. MIRU seven clean insulated frac tanks with a berm surrounding the tanks that holds the tank volume plus 10%. Load tanks with seawater from the injection system (approximately 2500 bbls are required for the treatment) 3. Rig up Dowell equipment and stab Tree Saver. (Test tree saver seals to expected pressure using warm diesel to assure seal integrity in tubing hanger). 4. Pressure test surface lines to 9500 psi ~~h~~~~v~~~ ~ ~®~~ ~~ ~ ~~~ `~ I~~ 5. Pump the 100 bbl Breakdown with Dowell's YF125ST fluid system. Bring pumps up to maximum rate ASAP. 6. Pump the following schedule at 25BPM with a maximum pressure of 9000 psi, add breaker as per lab results. Maintain 3000 psi on the IA during the treatment. • 300 bbls YF125ST Pad • 240 bbls YF125ST w/ 2 ppa 16/20 low density ceramic proppant • 480 bbls YF125ST w/ 4 ppa 16/20 low density ceramic proppant • 1000 bbls YF125ST w/ 7 ppa 16/20 low density ceramic proppant • Flush with linear YF125ST and freeze protect Total Sand: -300,000 lbs. 7. Monitor the surface pressure fall-off at the end of the job for 30 min (or until closure is verified) if the well does not screen out. 8. Rig down equipment move off location. d v- ,fI-~/a1 /'~ ~~ ~~'ELL LOG TRa~rSYiITTAL To: State of Alaska April 2, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska 9901-3539 RE: M~VD Formation Evaluation Logs: CD4-215, AK-'VIW-4788290 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 LD~VG formatted CD Rom with verification listing. API#: 50-103-20539-00. jam': I .~ z - ,._~ 3 ~~ -~ ~ a 'ate s ate- i1 /~ i~. ~ 1 tjti ~L? i V v' 'dJ r r 26-Jan-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD4-215 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 36.75' MD Window /Kickoff Survey ' MD (if applicable) Projected Survey: 14,761.00' 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 ~ Si ned ~~ ~ Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ConocoPhillips January 26, 2007 • G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 Commissioner ~I~~Q State of Alaska Alaska Oil & Gas Conservation Commission J.~N 2 9 2007 333 West 7th Avenue Suite 100 Alaska Oil & Gas Cans. Commission Anchorage, Alaska 99501 Anchorage Subject: Well Completion Report for CD4-215 (APD 206-157) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the Well Completion Report for the recent drilling operations on the Alpine well CD4-215. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, ~. ~. C G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned ^ Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other_ 1b. Well Class: Development O Exploratory ^ Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: December 25, 2006 12. Permit to Drill Number: 206-157 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: December 6, 2006 13. API Number: 50-103-20539-00 ' 4a. Location of Well (Governmental Section): Surface: 2952' FNL, 341' FEL, Sec. 24, T11 N, R4E, UM 7. Date TD Reached: December 20, 2006 ' 14. Well Name and Number: CD4-215 At Top Productive Horizon: 1735' FNL, 1084' FWL, Sec. 25, T11 N, R4E, UM 8. KB Elevation (ft): 56.5' MSL 15. Field/Pool(s): Colville River Field Total Depth: 1237' FNL, 1892' FEL, Sec. 36, T11 N, R4E, UM 9. Plug Back Depth (MD + TVD): 14761' MD / 6205' TVD Nanuq Nanuq Oil Pool - 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377902 y- 5957461 Zone- 4 10. Total Depth (MD + TVD): ' 14761' MD / 6205' TVD " 16. Property Designation: ADL 380077, 384209, 388902 TPI: x- 373982 y- 5953463 Zone- 4 Total Depth: x- 376209 - 5948644 - Zone- 4 11. Depth where SSSV set: SSSV @ 2142' 17. Land Use Permit: ALK 380077 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1395' MD 21. Logs Run: GR/Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 37' 114' 37' 114' 24" Pre-installed 9.625" 40# L-80 37' 2854' 37' 2392' 12.25" 397 sx AS Lite, 231 sx Class G Tail 7" 26# L-80 37' 9514' 37' 6214' 8.75" 195 sx LiteCRETE, 321 sx Class G 3.5" 9.3# L-80 9361' 14675' 6194' 6213' 6.125" slotted liner (refer to attachment) 23. Pertorations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 3.5" 9380' 8204' slotted liner from 9501'-9712; 10550'-10733', 10857'- 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11039', 11566'-11627', 12184'-12730', 12852'-13395', DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 13549'-13638', 13793'-14280', 14342'-14403', 14497'- n/a 14673' M D 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) waiting on facility hook-up Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ,.s:~~.4.ry~q:.:qq.,,pp _ q~ y~~(/~w+(#~ ) ''UViYIQ3~l:':~1 SJ±4 p{@y~ NONE t ~ <~Di +/s Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ,~ t • 3(• r' 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD4-215 Nanuq sand 9440' 6258' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheets 31. I hereby certify that the foregoing is true and corcect to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name ^ vord Title: Alpine Drilling Team Leader / ~ Signature ~/c~F.-~~ Phone ~ ~ ~- _ ,~, f Zv Date ~ fz ~ 1 ~ ~ INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 elevation in feet abour mean low low water. 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: True vertical thickness. 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ConocoPhiflip~ i Liner Detail Well: CD4-215 3 7/2° Slotted and Blank Liner Date: 11/23/2006 DEPTH UN LENGTH- TOPS Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT R Top of Liner Hanger @ Baker "HR" Liner Setting Sleeve 5.79 OD x 4.42 ID ID 12.98 80 3 9361.16 9361.16 9374.14 - Baker "RS" Packoff Seal Nipple 5.60 OD x 4.25 Baker "DG" 5" x 7" Flex Lock Hanger 5.92 OD x 4.40 ID . 9.92 9377.94 XO - 5" L-80 BTC x 4 1/2" L-80 SLHT 5.57 OD x 4.00 ID Pup - 4-1/2", 12.6#, L-80, SLHT BLANK PIPE Pup - 4-1/2", 12.6#, L-80, SLHT BLANK PIPE XO - 4 1/2" SLHT x 3 1/2" SLHT W/ 3.78' - 3 112" pup 1.86 3.79 9.74 5.55 22 92 9387.86 .9389.72 9393.51 9403.25 9408.80 Jts 170 to 172 Jts 163 to 169 3 Jts 7 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE. 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER . 211.34 20 9501.02 36 9712 Jts 136 to 162 27 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 837. 33 183 . 10549.56 Jts 130 to 135 Jts 126 to 129 6 Jts 4 Jts 3-112", 9.3#, L-80, SLHT SLOTTED LINER 3-1/2", 9.3#, L-80, SLHT BLANK PIPE . 124.03. 52. 182 10732.89 10856.92 Jts 120 to 125 6 Jts 3-112", 9.3#, L-80, SLHT SLOTTED LINER . 33 526 1'1039.44 Jts 103 to 119 Jts 101 to 102 Jts 83 to 100 Jts 65 to 82 17 Jts 2 Jts 18 Jts 18 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 3-112", 9.3#, L-80, SLHT SLOTTED LINER . 61.76 556.86 545.56 22 11565.77 11627.53 12184.39 95 12729 Jts 61 to 64 Jts 43 to 60 4 Jts 18 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 122. 542.57 21 4 . 12852.17 74 13394 Jts 38 to 42 5 Jts 3-1/2", 9.3#, L-80, SLHT BLANK PIPE . 15 43 89 . 13548.95 Jts 35 to 37 Jts 30 to 34 Jts 14 to 29 Jts 12 to 13 3 Jts 5 Jts 16 Jts 2 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 3-1/2", 9.3#, L-80, SLHT BLANK PIPE . 154.26 487.43 62.12 7 . 13638.38 13792.64 14280.07 19 14342 Jts 10 to 11 Jts 7 to 9 FALSE 2 Jts 3 Jts 6 Jts 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 3-1/2", 9.3#, L-80, SLHT BLANK PIPE 3-1/2", 9.3#, L-80, SLHT SLOTTED LINER 60.8 93.89 176.24 81 1 . 14403.06 14496.95 19 14673 Baker V set float shoe 5.05" OD h @ " li . . 14675.00 oe ner s 3 1/2 l = 118" h 14379.76 e o TD of 6 Run-N-Seal pipe dope Remarks: Up Wt - k Cnncn,icnrr Dn Wt - k ~~ Time Logs Date From To Dur S De th__E. Depth Phase Code _ Subcode T COM_ _ 12/08/2006 05:45 06:45 1.00 2,864 2,864 SURFA DRILL CIRC P Circulated hole clean with 650 GPM. 2100 si 70 RPM. 06:45 11:30 4.75 2,864 981 SURFA DRILL WPRT P POOH Backreaming from 2,864' to 981' wirh 550 GPM and 50 RPM. 11:30 13:30 2.00 981 2,864 SURFA DRILL WPRT P RIH from 891' to 2864'. Circulate hole clean - 60 r m - 650 m 1980 si. 13:30 16:00 2.50 2,864 0 SURFA DRILL TRIP P Blow dwn TD -Observe well, static - POOH on TT. Encountered Tight spots at 1010' - 2110' - 2320'. 16:00 18:00 2.00 0 0 SURFA DRILL PULD P Stand back NM Flex Collars & Jars - Down load MWD data - LD BHA - Cleartools. 18:00 20:00 2.00 0 0 SURFA CASIN( RURD P RU to run Casing: LD Drilling Elevators & bails - MU Fill up tool -Install casing elev., bails, & slips - RU casing ton s & work latform. 20:00 20:15 0.25 0 0 SURFA CASIN( SFTY P Pre Job safety meeting prior to running 9 5/8" casin . 20:15 00:00 3.75 0 997 SURFA CASIN( RNCS P Run 9 5/8" 40# L-80 BTC csg as follows: Float shoe (Ray Oil Tools silver bullet) 2 jts csg - Halliburton Float collar - 26 jts. csg. First 4 connections made up w/ BakerLoc - filled pipe & checked floats. Bowspring Centralizers on jts #1-13 & every other jt after. Stop rings on jts #1 & #2. `Note"` Circ. w/4 bbl min @ 250 psi from 921' - 997'. 12/09/2006 00:00 01:15 1.25 997 1,528 SURFA CASIN( RNCS P Run 48 jts 9 5/8" 40# L 80 BTC casing from 997' to 1,528'. 74 total 'ts 01:15 01:45 0.50 1,528 1,528 SURFA CASIN< CIRC P Circulated Casing volume + 10 Bbls. 4 BPM ICP 290 si FCP 200 si. 01:45 04:00 2.25 1,528 2,854 SURFA CASIN< RNCS P Ran 9 5/8" 40# L 80 BTC casing from 1,528' to 2,854'. Landed casing on han er. 04:00 04:45 0.75 2,854 2,854 SURFA CEME~ RURD P Laid down Franks tool and installed cement head. 04:45 06:30 1.75 2,854 2,854 SURFA CEMEI~ CIRC P Circulated casing to condition mud Worked rate up to 7 BPM FCP 340 si. PJSM. ~° ~® P~c~ rsf 9 2 J l Time Logs Date From To Dur S. De th E. De th Phase ` Code Subcode T COM __ 12/09/2006 _ 06:30 __ 08:30 _ 2.00 2,854 0 SURFA CEME~ DISP P _ _ _ Cement 9 5/8" csg as follows Pumped 40 bbls Biozan water w/nut plug as marker -Pumped 5 bbls water w/ Dowell -Tested lines to 2500 psi - Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 314 bbls lead slurry (ASL) @ 10.7 ppg (' Observed nut plug marker @ shakers w/ 371 bbls lead pumped - pumped down surge can) Pumped 48 bbls tail slurry (Class G w/ additives) @ 15.8 ppg -Dropped top plug w/ 20 bbts water f/ Dowell -Switched over to rig pumps & displaced cmt w/ 190.4 bbls 9.8 ppg water base mud - Displaced @ 7.0 bbls/min for first 180 bbls -slowed to 4 bbls/min for last 10.4 bbls -Bumped plug w/ 1200 psi (prep bump pressure 720 psi) Check float (held OK) CIP @ 08:30 hrs. -Full circulation throughoutjob w/ 110 bbls 10.7 ppg cmt returns to surface - reciprocated pipe while circulating & through cement job until last 90 bbls of dis lacement. 08:30 09:15 0.75 0 0 SURFA CASIN( DHEO P Rigged up and tested casing to 2,500 si for 30 Min. 09:15 10:30 1.25 0 0 SURFA CASIN( RURD P Rigged down casing and cementing tools. Laid down landin 't. 10:30 12:30 2.00 0 0 SURFA CASIN( NUND P Nippled down riser. Install WH & test to to 1000 si for 10 min. 12:30 15:00 2.50 0 0 SURFA CASIN( NUND P NU BOPE turn buckles flow line. 15:00 15:30 0.50 0 0 SURFA WELCT BOPE P Install test plug - RU to begin testing BOPE - Annular to 250 & 3500 psi f/5 mins. 15:30 23:00 7.50 0 0 SURFA WELCT BOPE P Test upper, lower, blinds, manual valves, and HCR's on stack, choke, mainfold. Upper & lower IBOP's, dart floor valves. All tested to 250 and 5000 si for 5 mins. 23:00 00:00 1.00 0 SURFA CASIN( RURD P PU Bails, Elevators -Blow down lines -Set mouse hole. Pre to PU BHA. 12/10/2006 00:00 02:45 2.75 0 1,960 SURFA DRILL PULD P PU BHA. PT surface lines & e ui ment to 3500 si. 02:45 05:00 2.25 1,960 2,625 SURFA DRILL TRIP P RIH to 1960' - PU Jars, Fill pipe, test tools. RIH f/ 1960' - 2625' with 4" DP. PJSM. 05:00 06:30 1.50 2,625 2,625 SURFA RIGMN SVRG P Slipped and cut drilling line. Serviced to drive. 06:30 07:30 1.00 2,625 2,754 SURFA CEME~ COCF P Washed down f/2625' to TOC @ 2,754'. 07:30 13:00 5.50 2,754 2,864 SURFA CEME~ DRLG P Drilled out Shoetrack from 2,754' to 2,854' Cleaned out rat hole to 2,864'. Had rubber along side BHA. Plugs and FC took 3.5 hrs. ~ - ~ k~~~ ~ e~f 2 i Time Logs Date From To Dur S. De th E De th Phase Code Subcode T COM 12/10/2006 13:00 13:15 0.25 2,864 2,884 SURFA DRILL DDRL P Drilled From 2,864' to 2,884'. 13:15 13:45 0.50 2,884 2,884 SURFA CEMEt~ CIRC P CBU. 13:45 14:30 0.75 2,884 2,884 SURFA CEME~ LOT P Rigged up and did LOT to 17.8 PPG EMW. 14:30 00:00 9.50 2,884 3,980 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 2,884' to 3980' MD 3152' TVD ADT - 5.74 ECD 11.1 ppg WOB 8/12 RPM 120 GPM 550 @ 1750 psi String Wt: PU 152 - SO 118 -Rot 150 Tor ue on/off btm - 9000/8000 12/11/2006 00:00 12:00 12.00 3,980 5,050 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 3980' t/ 5050' MD 3920' TVD ADT - 8.76 ECD 11 ppg WOB 10/12 RPM 120 GPM 575 @ 2130 psi String Wt: PU 165 - SO 125 -Rot 145 Tor ue on/off btm - 9500/8000 12:00 00:00 12.00 5,050 6,362 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/5050' t/6362' MD 4771' TVD ADT - 9.19 ECD 10.7 ppg WOB 10/15 RPM 120 GPM 600 @ 2600 psi String Wt: PU 195 - SO 127 -Rot 152 Tor ue on/off btm -12000/10000 12/12/2006 00:00 11:00 11.00 6,362 7,391 INTRM2 DRILL DDRL P Drill 8 3/4" hole w/GP f/6,362' t/7,391' MD 5,409' TVD ADT - 7.25 ECD 10.9 ppg WOB 10/15 RPM 120/155 GPM 650 @ 3040 psi String Wt: PU 220 - SO 133 -Rot 167 Tor ue on/off btm - 13,500/12,000 11:00 12:00 1.00 7,391 7,391 INTRM2 RIGMN SVRG P Service Top Drive and Drawworks - troubleshootgrabber -slipping when attem tin to break out stand 12:00 12:45 0.75 7,391 7,391 INTRM2 RIGMN RGRP NP Replace grabber blocks and dies 12:45 00:00 11.25 7,391 8,690 INTRM2 DRILL DDRL P Drilled 8 3/4" hole w/ GP f/ 7391' to 8690' MD 6050' TVD ADT - 8.08 hrs ECD - 18.30 ppg WOB 10/15 k RPM 150 GPM 650 @ 3700 psi String wt. PU 218 SO 140 Rot. 170 Torque on/off btm. - 14,000/12,000 ft/Ibs 12/13/2006 00:00 11:30 11.50 8,690 9,524 INTRM2 DRILL DDRL P Drilled 8 3/4" hole w/ GP f/ 8690' to 9524' MD 6215' TVD ADT - 8.72 hrs ECD - 10.6 - 10.7 ppg WOB 10/15 k RPM 150 GPM 650 @ 3700 psi String wt. PU 205 SO 140 Rot. 170 Torque on/off btm. - 13,000/12,000 fUlbs Fagg o~ 12 I ~~ ~ Time Loc~~ Date From To Dur S De th E_ De th Phase Code Subcode T COM -- 12/13/2006 11:30 13:30 2.00 9,524 9,201 -- INTRM2 - DRILL - CIRC P - - Pumped 40 bbls high vis sweep - circulate and condition mud - 650 gpm / 3700 psi / 150 rpm -stood back 1 std/30 minutes to 9201' -flow check well, static 13:30 15:15 1.75 9,201 8,153 INTRM2 DRILL TRIP P Wipe hole from 9201' to 8153' - 550 gpm / 2700 psi / 100 rpm -hole in ood condition -flow check well, static 15:15 16:00 0.75 8,153 9,524 INTRM2 DRILL TRIP P RIH from 8153' to 9487' -precautionary wash and ream to 9524' 16:00 17:45 1.75 9,524 9,492 INTRM2 DRILL CIRC P Circulate and condition mud - 650 gpm / 3850 psi / 130 rpm -set back one stand to 9492 17:45 19:45 2.00 9,488 8,158 INTRM2 DRILL TRIP P Spot WSP/CL pills to bit -POOH f/ 9492' to 8158' -spotting pits @ 2.5 bbls/min 350 si 19:45 00:00 4.25 8,158 3,108 INTRM2 DRILL TRIP P Flow check -well static -POOH on TT f/ 8158' to 3108' -Hole taking proper fill & no ti ht s ots - 12/14/2006 00:00 01:00 1.00 3,108 711 INTRM2 DRILL TRIP P POOH from 3108' to 711' -laid down Ghost reamers -flow checks at shoe & 711', static. 01:00 03:45 2.75 711 0 INTRM2 DRILL PULD P Stand back hwdp & flex collars - LD jars -Down load LWD - LD MWD, pony collar - GeoPilot and bit -blow down Geospan skid -clear tools from ri floor 03:45 04:00 0.25 0 0 INTRM2 WELCT SFTY P PJSM on changing pipe rams 04:00 06:15 2.25 0 0 INTRM2 WELCT OTHR P Change Top pipe rams to 7" -pull wear bushing and install test plug - test 7" pipe rams 250/5000 psi -pull test plug and install thin wall wear bushin 06:15 07:30 1.25 0 0 INTRM2 CASIN( RURD P RU to run 7" casing 07:30 07:45 0.25 0 0 INTRM2 CASINC SFTY P Held pre-job safety and opts meeting with crew 07:45 12:15 4.50 0 4,075 INTRM2 CASINC RNCS P Run 7" 26# L-80 BTCM csg as follows: FS (Ray Oil tools silver bullet) 2 jts. csg - FC (Hallibutton) 2 jts. csg (first 4 jts. made up w/BakerLoc -filled pipe & checked floats) 91 jts to 4075' (95 ~ts total 12:15 13:00 0.75 4,075 4,075 INTRM2 CASIN( CIRC P Break circ -stage pump to 6.0 bbls/min. -Circulate and condition mud -FCP 500 psi -PUW 155 SOW 130 13:00 16:00 3.00 4,075 7,717 INTRM2 CASIN( RNCS P Run 7" 26# L-80 BTCM from 4075' to 7717 180 ~ts total 16:00 17:00 1.00 7,717 7,717 INTRM2 CASIN( CIRC P Break circ -stage pump to 6.0 bbls/min. -Circulate and condition mud -FCP 670 psi -PUW 225 SOW 150 ~____ ~ ~ ____~ --~-F'~~~ a~f 1 ~ Time Logs Date From To Dur S. Depth_ E De th Phase Code Subcode T_ COM 12/14/2006 17:00 18:45 1.75 7,717 9,514 INTRM2 CASIN( RNCS P Continue running 7" 26# L-80 BTCM f! 7717' to 9477' (221 jts total PU FMC fluted hanger & landing jt. -Land 7" csg in wellhead on FMC fluted hanger w/shoe 9514.46' & FC 9425.29' 18:45 19:00 0.25 9,514 9,514 INTRM2 CASIN( OTHR P LD fill up tool -Blow down TD - RU cmt head & lines 19:00 21:00 2.00 9,514 9,514 INTRM2 CEME~ CIRC P Break circ @ 2.0 bbls /min & stage pump up to 6 bbls/min @ 520 psi - Circ & condition mud for cmt 'ob 21:00 21:15 0.25 9,514 9,514 INTRM2 CEMEf` SFTY P Held pre job safety meeting on cementin cs with crew 21:15 23:30 2.25 9,514 9,514 INTRM2 CEME~ DISP P Cemented 7" csg as follows: Pumped 5 bbls CW-100 -Tested lines to 3700 psi -Pumped 15 bbls CW-100 @ 3.8 bbls/min @ 333 psi -Mixed & pumped 30 bbls 10.5 ppg MudPush @ 5 bblslmin @ 422 psi -Dropped btm plug -Mixed & pumped 122 bbs 11.0 ppg Lead slurry (LiteCrete) @ 5.8 bbls/min @ 400 psi -Mixed & pumped 67 bbls 15.8 ppg tail slurry (Class G w/ additives) @ 6 bbls/min @ 300 psi - Dropped top plug w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced cmt w/ 340.5 bbls 9.9 ppg LSND mud @ 6.5 bbls/min for first 150 bbls - 6 bbls /min for next 100 bbls - 5.2 bbls/min for next 70 bbls - 3.5 bbls /min for last 20.5 bbls -final pressure prior to bumping plug 840 psi - Bumped plug w/1300 psi -Checked floats OK - CIP @ 23:22 hrs. -Full circ thou hout'ob 23:30 00:00 0.50 9,514 9,514 INTRM2 CEME~ OTHR P RU & test 7" csg to 3500 psi for 30 mins. 12/15/2006 00:00 00:15 0.25 9,514 9,514 INTRM2 CASIN( DHEQ P Complete 3500 psi casing test -blow down lines 00:15 01:15 1.00 0 0 INTRM2 CASIN< NUND P LD cement head, Landing jt. & casing running tools -pull thin wall wear bushin 01:15 02:00 0.75 0 0 INTRM2 CASIN( DHEQ P Install and test packoff to 5000 psi for 10 minutes 02:00 03:45 1.75 0 0 INTRM2 WELCT OTHR P Change top pipe rams to 3 1/2" X 6" VBR's -set test plug & test rams to 250/5000 psi -pull test plug -install wear bushin 03:45 07:00 3.25 0 375 INTRM2 DRILL PULD P MU BHA #3 -Bit /Geo Pilot / nmpc / stab / MWD / PWD / FS / -initialize tools - PU 3 NMFC's / xo - RIH with hwd to 375' 07:00 07:30 0.50 375 375 INTRM2 RIGMN SVRG P Service top drive and drawworks 07:30 08:00 0.50 375 1,403 INTRM2 DRILL TRIP P RIH w/ 4" drill pipe from 375' to 1,403' 08:00 08:30 0.50 1,403 1,403 INTRM2 DRILL OTHR P Pressure test Geo Span skid to 3500 si -shallow test tools __ ~ -~e l~~sn~~ of 12 Time Lis _ _ _ _ ___ _ __ --- - - Date From To Dur S. Depth_ E_._D~e th Phase Code Subcode T COM __ i 12/15/2006 08:30 12:15 3.75 1,403 9,238 INTRM2 DRILL TRIP P RIH from 1,403' to 9,238' -fill pipe eve 20 stands 12:15 12:45 0.50 9,238 9,310 INTRM2 DRILL OTHR P Wash down from 9,238' to 9310' - break in Geo ilot seals 12:45 14:00 1.25 9,310 9,417 INTRM2 CEME~ COCF P Clean out cement from 9,310' to 9417' drill i e measurements 14:00 21:45 7.75 9,417 9,546 INTRM2 GEMEP DRLG P Drill up wiper plugs - FC - cmt to FS drill out shoe -clean out rat hole & Drill 20' new hole to 9546' 21:45 22:45 1.00 9,546 9,546 INTRM2 DRILL CIRC P Circ hole clean for FIT - 197 GPM @ 1250 si w/ 40 r m 22:45 23:30 0.75 9,546 9,546 INTRM2 DRILL FIT P RU & perform FIT to 12.5 ppg EMW - RD 23:30 00:00 0.50 9,546 9,546 PROD1 DRILL CIRC P Chnage well over f/ 9.6 ppg LSND to 9.2 FlowPro 12/16/2006 00:00 01:15 1.25 9,546 9,546 PROD1 DRILL CIRC P Displace well to 9.2 ppg FloPro mud - 223 gpm / 1668 psi / 60 rpm -flow check well, static 01:15 03:45 2.50 9,546 9,723 PROD1 DRILL DDRL P Drilled 6-1/8" hole w/GeoPilot f/ 9,546' to 9,723' MD/6235' TVD ADT = 1.92 hrs ECD = 10.5 ppg WOB = 10/12k RPM = 110 GPM = 220 @ 1600 psi String Wt -- PU Wt = 185 SO Wt = 140 ROT Wt = 160 Tor ue On/Off Btm - 9,500/8,000 ft/Ibs 03:45 06:00 2.25 9,723 9,723 PROD1 WELCT CIRC T Driller observed 2% increase in flow returns, PVT showed 6 bbls pit gain - picked up and flow checked well, well flowing -shut in well and monitored pressures -SIDPP = 40 psi -SICP=O psi, monitored pressures for 15 minutes, no change -Circulated BU thru full open choke, observed badly airated mud back, no gas cut mud back -shut in well, SIDPP = 40 psi, SICP = 0 psi monitored pressure for 15 minutes, no change. Open up well, slight flow of airated mud observed. **Lou Grimaldi (AOGCC) was informed of event b tele hone. 06:00 12:00 6.00 9,723 10,040 PROD1 DRILL DDRL P Drilled 6-1/8" hole w/ GeoPilot f/ 9,723' to 10,040' MD/6,256' TVD ADT = 4.61 hrs ECD = 10.6 ppg WOB = 10/12k RPM = 110 GPM = 220 @ 1730 psi String Wt -- PU Wt = 190 SO Wt = 135 ROT Wt = 160 Tor ue On/Off Btm - 9,500/8,000 fUlbs 12:00 00:00 12.00 10,040 10,575 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 10,040' to 10,575' MD 6230' TVD ADT - 8.67 hrs. ECD 10.85 ppg WOB 10/12 k RPM 110 GPM 220 @ 1870 psi String wt. PU 190 SO 130 Rot 155 Tor ue on/off btm. - 10,500/9,500 ft/Ibs ______~ ~~ P~~ 7 oaf 12 ~ C~ Time Logs Date _____From To bur S be th E. De th Phase Code Subcode T__ COM _ __ 12/17/2006 00:00 01:00 1.00 10,575 10,683 PROD1 DRILL DDRL _ P Drill 6 1/8" hole w/ GP f/ 10,575' to 10,683' MD 6221' ND ADT - 1.00 hrs. ECD 10.73 ppg WOB 10/12 k RPM 110 GPM 220 @ 1790 psi String wt. PU 190 SO 130 Rot 160 Tor ue on/off btm. - 11,000/9,500 fUlbs 01:00 02:15 1.25 10,683 10,683 PROD1 DRILL CIRC T GeoPilot accepting target commands but actual toolface was locked up - CBU - 220 gpm / 1750 psi / 110 rpm - troubleshoot GeoPilo 02:15 06:15 4.00 10,683 9,514 PROD1 DRILL TRIP T POOH from 10,683 to 9,514' 220 gpm / 1650 psi / 80 rpm -worked through tight spot 2 10.147' -slight packing off. Trouble shoot tools at shoe -the actual toolface began tracking with the tar et toolface. 06:15 07:30 1.25 9,514 10,683 PROD1 DRILL TRIP T RIH from 9514' -washed through tight spot @ 10,525' - 3 bpm / 800 psi / 20 rpm -RIH to 10,663' -precautionary wash and ream to 10,683' 07:30 12:00 4.50 10,683 10,915 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 10,683' to 10,915' MD 6220' ND ADT - 1.00 hrs. ECD 10.74 ppg WOB 10/12 k RPM 110 GPM 220 @ 1860 psi String wt. PU 190 SO 130 Rot 160 Tor ue on/off btm. - 10,500/9,500 ft/Ibs 12:00 00:00 12.00 10,915 11,485 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 10,915' to 11,485' MD 6249' ND ADT - 9.4 hrs. ECD- 10.84 WOB 10/14 k RPM 130 GPM 220 @ 1910 psi String wt. PU 195 SO 125 Rot 160 Tor ue on/off btm. - 11,500/9,500 ft/Ibs 12/18/2006 00:00 12:00 12.00 11,485 11,920 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP f/ 11,485' to 11,920' MD 6231' ND ADT - 10.2 hrs. ECD- 10.78 ppg WOB 10/14 k RPM 130 GPM 220 @ 1870 psi String wt. PU 200 SO 120 Rot 160 Torque on/off btm. - 12,000/10,500 ft/Ibs 12:00 00:00 12.00 11,920 12,400 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP F/ 11,920' to 12,400' MD 6214' ND ADT - 9.1 hrs. ECD - 10.73 ppg WOB 10/14 k RPM 130 GPM 220 @ 1830 psi String wt. PU 205 SO 115 Rot 160 Torque on/off btm. - 10,500/10,000 fUlbs Note Lost high line power @ 1900 hrs. - Back on hi h line ower 2245 hrs .. __ _ l~~g~ caf 12 ~ Time Logs - _ _ _ _ -- ~ Date From To Dur S. De th E. De th Phase Code Subcode T COM 12/19/2006 00:00 12:00 12.00 12,400 13,234 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP F/ 12,400' to 13,234' MD 6220' ND ADT - 9.56 hrs. ECD - 10.72 ppg WOB 8/14 k RPM 130 GPM 220 @ 1840 psi String wt. PU 215 SO 105 Rot 160 Torque on/off btm. - 13,000/11,000 fUlbs 12:00 00:00 12.00 13,234 13,940 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP F/ 13,234' to 13,940' MD 6252' ND ADT - 8.95 hrs. ECD - 10.9 ppg WOB 7/12 k RPM 130 GPM 220 @ 2060 psi String wt. PU 220 SO 105 Rot 160 Torque on/off btm. - 13,500/12,000 ft/Ibs 12/20/2006 00:00 12:00 12.00 13,940 14,575 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP F/ 13,940' to 14,575' MD 6222' ND ADT - 9.69 hrs. ECD - 10.9 ppg WOB 7/14 k RPM 130 GPM 220 @ 1970 psi String wt. PU 220 SO 110 Rot 160 Torque on/off btm. - 13,000/12,000 ft/Ibs 12:00 15:15 3.25 14,575 14,761 PROD1 DRILL DDRL P Drill 6 1/8" hole w/ GP F/ 14,575' to 14,761' MD 6205' ND ADT - 3.12 hrs. ECD - 10.9 ppg WOB 10/12 k RPM 130 GPM 220 @ 2040 psi String wt. PU 220 SO 100 Rot 160 Torque on/off btm. - 13,500/11,500 ft/Ibs 15:15 17:45 2.50 14,761 14,379 PROD1 DRILL CIRC P Circulate hole clean - 3 X BU - 220 gpm / 1980 psi / 120 rpm -set back one stand/30 minutes to 14,379'. 17:45 00:00 6.25 14,379 11,787 PROD1 DRILL TRIP P POOH with pump from 14,379' to 11,787'. 170 GPM 90 RPM. Average over ull 15 K. 12/21/2006 00:00 02:30 2.50 11,787 10,663 PROD1 DRILL TRIP P POOH with pump from 11,778' to 10663' - 4.5 bpm / 1450 psi / 80 rpm - average overpull 10/15 K. Worked through several tight spots from 11,634' to 11,220' some packing off - lost 50 bbls of mud 02:30 05:15 2.75 10,663 9,514 PROD1 DRILL TRIP P Continue to POOH with pump - 10,663' to 9514' - 4 bpm / 1250 psi / 80 r m 05:15 05:45 0.50 9,514 9,514 PROD1 WELCT OWFF P Flow check well at shoe, observed slight amout of flow (breathing) -well static in 20 minutes 05:45 07:30 1.75 9,514 8,570 PROD1 DRILL TRIP P POOH with pump from 9514' to 8570' -3.Ob m/750 si 07:30 08:00 0.50 8,570 8,570 PROD1 DRILL CIRC P Circulate to clean up casing- 5.2 bpm / 1550 si / 80 r m ~~® ~ P~~ ~ cif 12 I • i Time Logs --- - - - -- Date From To Dur S De th E. Depth Phase___ Code __ Subcode T COM __ 12/21/2006 08:00 09:15 1.25 8,570 8,570 PROD1 DRILL CIRC P Displace well to 9.6 ppg KCL brine - 5.2 bpm / 1450 psi / 80 rpm -flow check well, static -blow down top drive and eo-s an skid. 09:15 15:30 6.25 8,570 371 PROD1 DRILL TRIP P POOH on trip tank from 8570' to 371' - flow check well 1896', static 15:30 18:30 3.00 371 0 PROD1 DRILL PULD P Stand back flex collars and hwdp - Laid down BHA. 18:30 19:15 0.75 0 0 COMPZ CASIN( RURD P Rigged up to run 3.5" liner. PJSM. 19:15 00:00 4.75 0 3,109 COMPZ CASIN( RUNL P Ran 100 jts 3.5" slot/blank liner to 3,109'. 12/22/2006 00:00 01:45 1.75 3,109 5,250 COMPZ CASIN( PUTB P Ran 72 jts 3.5" slot/blank liner from 3,109' to 5250'. 01:45 03:15 1.50 5,250 5,250 COMPZ CASIN( RUNL P Picked up and made up liner hanger. 03:15 08:15 5.00 5,250 14,675 COMPZ CASINO RUNL P RIH with liner on Drillpipe from 5,250' to 14,675'. 08:15 09:00 0.75 14,675 9,266 COMPZ CASIN( RUNL P Dropped ball with liner on depth and set liner hanger with 2000 psi. Slacked down weight to confirm set. Pressured up to 4,000 psi and released from hanger. POOH 1 stand to 9,266'. TOL 9,361'. 09:00 10:00 1.00 9,266 9,266 COMPZ CASIN( CIRC P CBU while slip and cut drilling line. 10:00 15:00 5.00 9,266 0 COMPZ CASINO RUNL P POOH and laid down liner running tool. 15:00 16:45 1.75 0 0 COMPZ RPCOh RURD P Pulled wear bushing and rigged up to run com letion. 16:45 00:00 7.25 0 6,045 COMPZ RPCOh RCST P Ran 170 jts 3 1/2" 9.3# L-80 EUEM tubin to 6,045'. 12/23/2006 00:00 06:30 6.50 6,045 7,257 COMPZ RPCOA RCST P Ran VIT 3.5 x 4.5 tubing from 6,045' to 7,257' installn Cannon clam s. 06:30 07:30 1.00 7,257 7,257 COMPZ RPCOh PULD P Rigged up control line and installed SSSV. 07:30 15:30 8.00 7,257 9,380 COMPZ RPCO6 RCST P Ran VIT 3.5 x 4.5 tubing with control line from 7,257' to 9,380' installing Cannon clam s. 15:30 17:00 1.50 9,380 0 COMPZ RPCOR HOSO P Spaced out and made up tubing hanger. Landed tubing. Found top of liner 26' dee b tall . 17:00 18:00 1.00 0 0 COMPZ RPCOA DHEO P Laid down landing jt A. Installed TWO. Picked up landing jt B and tested han er seals. to 5,000 si. 18:00 19:00 1.00 0 0 COMPZ RPCOh NUND P Nippled down BOP. 19:00 20:00 1.00 0 0 COMPZ RPCOh NUND P Nippled up and tested tree. 20:00 21:30 1.50 0 0 COMPZ RPCO0. FRZP P Rigged up lines and squeeze manifold. PJSM. i P~~~. 93 ~f 12 1 I Time Loc~~ -- --- _ _ Date __ From To Dur S Depth E. De th Phase Code Subcode T COM __ __ _ 12/23/2006 21:30 00:00 2.50 0 0 COMPZ RPCOh FRZP __ T _ Tested lines to 2,000 psi. Pumped 30 Bbls of 9.6 PPG inhibited brine @ 3 BPM with Dowell. After 30 Bbls. pumped pressure spiked to 2,000 psi. Pressure bled down slowly. Checked all surface lines and manifold. Attempted to pump at .5 BPM lines pressured up. Pumped down backside no problem. Concluded there is somethin in the tubin . 12/24/2006 00:00 02:15 2.25 0 0 COMPZ RPCOh CIRC T Reverse circulated 90 Bbls of 9.5 PPG brine @ 1.5 BPM with normal presure 160 psi. Pumped down the tubing 2.2 Bbls and pressured up returns stopped indicating plugged tubing. Reverse circulated 90 Bbls of 9.5 PPG brine @ 3 BPM with normal presure 560 psi. Pumped down the tubing 8 Bbls and pressured up returns sto ed indicatin lu ed tubin . 02:15 03:15 1.00 0 0 COMPZ RPCOA RURD T Rigged down manifold. 03:15 05:15 2.00 0 0 COMPZ DRILL PULD P Rigged up and laid down HWDP, Jars, and Flex collars from derrick. 05:15 08:00 2.75 0 0 COMPZ RPCOfi SLKL T Rigged up Slickline and tested lubractor. 08:00 09:30 1.50 0 0 COMPZ RPCOh SLKL T Ran Bailer on Slickline to 8282' to clean out junk from RHC. POOH no recove 09:30 11:15 1.75 0 0 COMPZ RPCOA SLKL T RIH with GR pulling tool on Slickline to pull RHC @ 8,282'. Unable to engage. POOH. 11:15 13:00 1.75 0 0 COMPZ RPCOh SLKL T Ran Drive Down Bailer on Slickline to 8282' to clean out junk from RHC. POOH no recove 13:00 14:45 1.75 0 0 COMPZ RPCOR SLKL T Ran LIB on Slickline to 8282' to checkt 'unk in RHC. POOH. 14:45 16:45 2.00 0 0 COMPZ RPCOA SLKL T Ran 2" Pump Bailer on Slickline to 8282' to clean out junk from RHC. POOH no recove 16:45 18:15 1.50 0 0 COMPZ RPCOR SLKL T Ran Wireline Grab on slickline to clean out junk from RHC Would not ass cou lin s. POOH. 18:15 22:15 4.00 0 0 COMPZ RPCOh SLKL T RIH with GR pulling tool on slickline to pull RHC @ 8,282'. Unable to engage. POOH. 22:15 00:00 1.75 0 0 COMPZ RPCOh CIRC T Rigged down Slickline. Pumped 5 Bbls reverse circulating to prevent freezing. Rigged up to pump down tubin . f}~3~t* 11 oaf ~2 C: ~~ Time Logs Date From To Dur S. De th_E_ Depth Phase Code Subcode T __ COM _____ __ 12/25/2006 00:00 01:30 1.50 0 0 COMPZ RPCOR PACK T .Tested Dowell lines to 4800 psi. Circulated 85 Bbls @ 1 to 3.5 BPM. Trere was not enough pressure differiental to ensure packer set. The pressure was higher than normal but the slickline work had moved the junk around enough so it no longer sealed in the ball seat. 01:30 03:30 2.00 0 0 COMPZ RPCOA RURD T PJSM and rigged down slick line. Ri ed u lines to um . 03:30 07:15 3.75 0 0 COMPZ DRILL PULD P Rigged up and laid down DP from derrick while mud lant mixed brine. 07:15 11:15 4.00 0 0 COMPZ RPCOR FRZP P Tested Dowell lines and circulated through tubing. Pressure was too high at rate needed to keep diesel from migrating while pumping. Rigged up to reverse. Freeze protected well with 67 Bbls 10.1 Brine followed by 44 Bbls diesel and 180 Bbls 10.1 brine um ed 3.5 BPM. Blow down lines. 11:15 13:00 1.75 0 0 COMPZ RPCOII RURD P Rigged up FMC lubractor and set BPV. Dressed out tree and secured well 13:00 16:30 3.50 0 0 COMPZ DRILL PULD P Cleared floor and laid down DP from the derrick for rig move. Released Rig to move. I • • Halliburton Company Survey Report Comp:my: ConocoPhillips Alaska Inc . Date: 1/24/2007 Time: 16:13:39 Page: 1 Field: Colville River Unit Co -ordiuate(NF,) Reference: .Well: CD4-215, True North Site: Alpine CD4 Ve rtical (TVD) Re ference: CD4-215:56.6 Well: CD4-215 Section (VS) Reference: Well (O.OON,O.OOE,189.85Azi) Wellpath: CD4-215 Su rvey Calculation Method: Minimum Curvature llb: Oracle Field: Colville River Unit __ North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Coordinate System: Well Centre Geomagnetic Model: bggm2006 Well: CD4-215 Slot Name; Well Position: +N/-S -69.59 ft Northing: 5957460.92 ft Latitude: 70 17 32.281 N +E/-W -271.27 ft Easti ng : 377902.36 ft ~ Longitude: 150 59 18.669 W Position Uncertainty: 0.00 ---- ------ ft -- - - - --~I Wellpath: CD4-215 _ Drilled From: Well Ref. Point 501032053900 Tie-on Depth: 36.75 ft i Current Datum: CD4-215: Height 56.55 ft Above System Datum: Mean Sea Level ! Magnetic Data: 12/7/2006 Declination: 22.96 deg Field Strength: 57554 nT Mag Dip Angle: 80.67 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36_75 0.00 0.00 189.85 Survey Program for Definitive Wellpath Date: 10/12/2006 Validated: No V ersion: 4 i Actual From To Survey Toolcode Tool Name ' ft ft 79.00 898.00 CD4-215 gyro (79.00-898.00) C B-GYRO-SS Camera based gyro single shot 934.61 14723.12 CD4-215 (934.61-14723.12) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC i Survey e MD Incl Azim TVD Sys TVD N1S E/W DiapN M1IapE Toul ft dPg deg ft ft ft ft ft ft 36.75 0.00 0.00 36.75 -19.80 0.00 0.00 5957460.92 377902.36 TIE LINE ii 79.00 0.35 272.00 79.00 22.45 0.00 -0.13 5957460.93 377902.23 CB-GYRO-SS 169.00 0.50 266.00 169.00 112.45 -0.01 -0.80 5957460.92 377901.56 CB-GYRO-SS 257.00 0.80 265.00 256.99 200.44 -0.09 -1.79 5957460.86 377900.57 CB-GYRO-SS 349.00 1.25 260.00 348.98 292.43 -0.32 -3.42 5957460.65 377898.94 CB-GYRO-SS 441.00 2.75 252.00 440.92 384.37 -1.18 -6.51 5957459.85 377895.84 CB-GYRO-SS 531.00 5.10 252.00 530.70 474.15 -3.08 -12.36 5957458.04 377889.95 CB-GYRO-SS 621.00 6.50 254.00 620.24 563.69 -5.72 -21.07 5957455.54 377881.21 CB-GYRO-SS '~ 713.00 7.50 255.00 711.55 655.00 -8.71 -31.87 5957452.73 377870.35 CB-GYRO-SS 803.00 9.50 260.00 800.56 744.01 -11.52 -44.86 5957450.13 377857.32 CB-GYRO-SS i 898.00 13.90 260.00 893.56 837.01 -14.87 -63.83 5957447.09 377838.30 CB-GYRO-SS 934.61 15.89 249.93 928.95 872.40 -17.35 -72.87 5957444.75 377829.22 MWD+IFR-AK-CAZ-SC 1029.82 16.90 247.41 1020.28 963.73 -27.14 -97.89 5957435.37 377804.05 MWD+IFR-AK-CAZ-SC 1125.03 19.27 241.53 1110.79 1054.24 -39.95 -124.48 5957423.00 377777.25 MWD+IFR-AK-CAZ-SC 1220.17 24.49 238.73 1199.05 1142.50 -57.68 -155.16 5957405.77 377746.30 MWD+IFR-AK-CAZ-SC 1315.53 26.63 237.20 1285.07 1228.52 -79.52 -190.02 5957384.50 377711.09 MWD+IFR-AK-CAZ-SC 1410.76 29.03 243.48 1369.30 1312.75 -101.41 -228.65 5957363.25 377672.11 MWD+IFR-AK-CAZ-SC 1505.66 31.62 245.83 1451.21 1394.66 -121.88 -271.96 5957343.48 377628.48 MWD+IFR-AK-CAZ-SC 1600.89 34.69 244.74 1530.93 1474.38 -143.67 -319.26 5957322.47 377580.84 MWD+IFR-AK-CAZ-SC 1695.73 38.23 244.61 1607.20 1550.65 -167.78 -370.19 5957299.19 377529.53 MWD+IFR-AK-CAZ-SC 1790.84 41.63 246.28 1680.12 1623.57 -193.11 -425.72 5957274.76 377473.60 MWD+IFR-AK-CAZ-SC 1886.01 43.59 245.10 1750.16 1693.61 -219.64 -484.42 5957249.19 377414.47 MWD+IFR-AK-CAZ-SC ! . 1981.32 46.03 242.10 1817.78 1761.23 -249.54 -544.55 5957220.28 377353.87 MWD+IFR-AK-CAZ-SC 2076.10 49.00 240.49 1881.79 1825.24 -283.12 -605.84 5957187.70 377292.05 MWD+IFR-AK-CAZ-SC 2171.45 48.76 240.42 1944.50 1887.95 -318.54 -668.33 5957153.30 377229.00 MWD+IFR-AK-CAZ-SC 2266.74 47.91 242.29 2007.84 1951.29 -352.67 -730.79 5957120.19 377166.00 MWD+IFR-AK-CAZ-SC 2361.92 49.12 243.55 2070.89 2014.34 -385.12 -794.28 5957088.78 377102.00 MWD+IFR-AK-CAZ-SC 2456.90 48.75 243.63 2133.29 2076.74 -416.97 -858.41 5957057.98 377037.36 MWD+IFR-AK-CAZ-SC 2552.02 48.83 242.38 2195.96 2139.41 -449.45 -922.17 5957026.54 376973.09 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Compam: ConocoPhillips Alaska lnc. D:~te: .1!24/2007 Time: 16:13:39 Pale: 2 Field: Colville River Unit Co-ordinate(NE) Reference: Well: CD4-215, True North Site: Alpine CD4 Vertical (I'VD) Reference: CD4-215:56.6 Nell: CD4-215 Section (VS) Reference: WeR (Q.OON,O.OOE;189.85Azi) ~Vellpath: CD4-215 Survey Calculation Method: Minimum Curvature Db: Oracle Sun cv ~1D Tncl Azim T1'D Sys TVD N/S E/~V D1apN ?~1apE "fool ft deg deg ft ft ft ft ft ft __ ___ __ 2646.62 50.24 240.61 2257.35 2200.80 -483.81 -985.41 5956993.22 376909.31 MWD+IFR-AK-CAZ-SC 2742.12 49.80 241.06 2318.71 2262.16 -519.47 -1049.31 5956958.60 376844.84 MWD+IFR-AK-CAZ-SC 2816.51 48.84 240.70 2367.20 2310.65 -546.92 -1098.59 5956931.96 376795.12 MWD+IFR-AK-CAZ-SC 2885.99 47.89 240.74 2413.36 2356.81 -572.32 -1143.89 5956907.30 376749.42 MWD+IFR-AK-CAZ-SC 2981.20 49.08 239.20 2476.47 2419.92 -608.00 -1205.60 5956872.63 376687.15 MWD+IFR-AK-CAZ-SC 3076.66 49.39 239.67 2538.80 2482.25 -644.77 -1267.85 5956836.88 376624.31 MWD+IFR-AK-CAZ-SC 3172.20 48.79 240.21 2601.37 2544.82 -680.94 -1330.34 5956801.74 376561.24 MWD+IFR-AK-CAZ-SC 3268.43 47.83 240.98 2665.37 2608.82 -716.22 -1392.94 5956767.48 376498.08 MWD+IFR-AK-CAZ-SC 3362.67 47.37 240.90 2728.92 2672.37 -750.02 -1453.77 5956734.67 376436.72 MWD+IFR-AK-CAZ-SC 3458.07 46.93 241.15 2793.80 2737.25 -783.90 -1514.96 5956701.79 376374.99 MWD+IFR-AK-CAZ-SC 3553.19 47.03 241.51 2858.69 2802.14 -817.27 -1575.98 5956669.42 376313.45 MWD+IFR-AK-CAZ-SC 3648.29 47.34 245.04 2923.34 2866.79 -848.63 -1638.27 5956639.08 376250.66 MWD+IFR-AK-CAZ-SC 3743.62 46.76 244.06 2988.29 2931.74 -878.61 -1701.28 5956610.13 376187.18 MWD+IFR-AK-CAZ-SC 3838.84 46.15 244.12 3053.89 2997.34 -908.77 -1763.36 5956580.99 376124.62 MWD+IFR-AK-CAZ-SC 3934.17 45.71 245.26 3120.20 3063.65 -938.05 -1825.27 5956552.72 376062.25 MWD+IFR-AK-CAZ-SC 4029.40 45.20 245.97 3187.00 3130.45 -966.07 -1887.09 5956525.70 375999.99 MWD+IFR-AK-CAZ-SC ', 4124.91 44.58 246.40 3254.66 3198.11 -993.29 -1948.75 5956499.49 375937.90 MWD+IFR-AK-CAZ-SC 4220.04 43.82 247.73 3322.86 3266.31 -1019.14 -2009.82 5956474.64 375876.42 MWD+IFR-AK-CAZ-SC 4315.13 43.32 248.26 3391.76 3335.21 -1043.70 -2070.59 5956451.08 375815.27 MWD+IFR-AK-CAZ-SC 4410.44 42.80 248.08 3461.40 3404.85 -1067.89 -2131.00 5956427.86 375754.48 MWD+IFR-AK-CAZ-SC 4505.20 42.52 248.08 3531.08 3474.53 -1091.87 -2190.57 5956404.87 375694.53 MWD+IFR-AK-CAZ-SC 4600.42 42.55 248.63 3601.25 3544.70 -1115.61 -2250.40 5956382.10 375634.32 MWD+IFR-AK-CAZ-SC 4696.17 43.00 249.72 3671.53 3614.98 -1138.72 -2311.18 5956359.98 375573.19 MWD+IFR-AK-CAZ-SC 4791.48 43.96 250.30 3740.69 3684.14 -1161.14 -2372.81 5956338.57 375511.20 MWD+IFR-AK-CAZ-SC 4886.52 44.56 250.30 3808.75 3752.20 -1183.50 -2435.26 5956317.23 375448.41 MWD+IFR-AK-CAZ-SC 4981.75 44.68 250.19 3876.54 3819.99 -1206.11 -2498.21 5956295.64 375385.10 MWD+IFR-AK-CAZ-SC 5077.27 44.56 249.15 3944.53 3887.98 -1229.42 -2561.12 5956273.36 375321.82 MWD+IFR-AK-CAZ-SC ~~ 5172.61 45.33 249.21 4012.01 3955.46 -1253.36 -2624.07 5956250.45 375258.49 MWD+IFR-AK-CAZ-SC 5268.00 46.21 248.70 4078.54 4021.99 -1277.90 -2687.86 5956226.95 375194.32 MWD+IFR-AK-CAZ-SC 5363.01 47.89 247.60 4143.28 4086.73 -1303.79 -2752.40 5956202.11 375129.37 MWD+IFR-AK-CAZ-SC 5458.32 49.28 247.32 4206.33 4149.78 -1331.19 -2818.42 5956175.79 375062.93 MWD+IFR-AK-CAZ-SC 5552.17 49.78 243.86 4267.25 4210.70 -1360.70 -2883.41 5956147.35 374997.47 MWD+IFR-AK-CAZ-SC 5648.92 50.19 242.59 4329.46 4272.91 -1394.08 -2949.56 5956115.05 374930.79 MWD+IFR-AK-CAZ-SC 5743.71 51.63 240.43 4389.23 4332.68 -1429.18 -3014.21 5956081.00 374865.59 MWD+IFR-AK-CAZ-SC 5839.52 52.19 237.94 4448.34 4391.79 -1467.81 -3078.96 5956043.43 374800.23 MWD+IFR-AK-CAZ-SC 5934.85 52.23 236.17 4506.76 4450.21 -1508.77 -3142.17 5956003.50 374736.36 MWD+IFR-AK-CAZ-SC i 6030.51 51.77 234.47 4565.66 4509.11 -1551.66 -3204.16 5955961.63 374673.69 MWD+IFR-AK-CAZ-SC 6125.74 51.61 232.91 4624.69 4568.14 -1595.90 -3264.37 5955918.37 374612.77 MWD+IFR-AK-CAZ-SC 6221.25 51.89 232.53 4683.82 4627.27 -1641.34 -3324.05 5955873.92 374552.37 MWD+IFR-AK-CAZ-SC 6316.67 50.97 230.14 4743.32 4686.77 -1687.93 -3382.30 5955828.28 374493.37 MWD+IFR-AK-CAZ-SC 6412.06 50.69 228.66 4803.57 4747.02 -1736.06 -3438.45 5955781.08 374436.45 MWD+IFR-AK-CAZ-SC 6507.26 50.86 229.86 4863.78 4807.23 -1784.18 -3494.33 5955733.87 374379.81 MWD+IFR-AK-CAZ-SC 6602.91 51.74 230.09 4923.58 4867.03 -1832.19 -3551.49 5955686.80 374321.88 MWD+IFR-AK-CAZ-SC 6698.39 51.36 230.79 4982.95 4926.40 -1879.81 -3609.14 5955640.13 374263.47 MWD+IFR-AK-CAZ-SC i 6793.90 51.63 231.25 5042.42 4985.87 -1926.83 -3667.24 5955594.06 374204.62 MWD+IFR-AK-CAZ-SG 6886.47 51.87 231.05 5099.72 5043.17 -1972.43 -3723.85 5955549.39 374147.27 MWD+IFR-AK-CAZ-SC 6983.22 52.18 228.98 5159.26 5102.71 -2021.44 -3782.28 5955501.35 374088.06 MWD+IFR-AK-CAZ-SC 7079.20 51.98 224.04 5218.27 5161.72 -2073.51 -3837.19 5955450.17 374032.32 MWD+IFR-AK-CAZ-SC 7174.39 52.22 218.47 5276.77 5220.22 -2129.95 -3886.68 5955394.55 373981.93 MWD+IFR-AK-CAZ-SC I 7269.53 52.28 213.06 5335.04 5278.49 -2190.95 -3930.62 5955334.28 373937.01 MWD+IFR-AK-CAZ-SC 7364.95 51.98 207.55 5393.65 5337.10 -2255.93 -3968.60 5955269.93 373897.97 MWD+IFR-AK-CAZ-SC 7460.16 52.48 201.89 5451.99 5395.44 -2324.25 -4000.04 5955202.13 373865.43 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report • Company: ConocoPhillips Alaska lnc. Unto: 1/24/2007 Time: 16:13:39 Page: 3 Field: Colville River Unit Co-ordiuate(NF,) Reference: Well: CD4-215, True North Site: Alpine CD4 Vertical (TVD) Reference: CD4-215:56.6 R'ell: CD4-215 Section (VS) Reference: Well (O.OON,O.OOE,189.85Azi) ~Vellpath: CD4-215 Survey Calculation ~lcthod: Minimum Curvature Db: Oracle Sun cv 4D Incl Azim TVD Sys TVU N/S E/1i' D1apN D1apE Tool ft deg deg ft ft ft ft ft ft 7555.24 53.75 198.76 5509.07 5452.52 -2395.56 -4026.44 5955131.27 373837.88 MWD+IFR-AK-CAZ-SC 7650.47 55.57 195.55 5564.16 5507.61 -2469.77 -4049.32 5955057.44 373813.80 MWD+IFR-AK-CAZ-SC 7745.36 56.23 193.87 5617.36 5560.81 -2545.77 -4069.27 5954981.79 373792.62 MWD+IFR-AK-CAZ-SC 7840.92 56.40 192.18 5670.36 5613.81 -2623.23 -4087.19 5954904.63 373773.45 MWD+IFR-AK-CAZ-SC 7936.18 57.24 190.86 5722.50 5665.95 -2701.35 -4103.10 5954826.79 373756.27 MWD+IFR-AK-CAZ-SC 8029.55 59.12 187.84 5771.73 5715.18 -2779.62 -4115.97 5954748.74 373742.13 MWD+IFR-AK-CAZ-SC 8126.53 61.05 186.17 5820.10 5763.55 -2863.05 -4126.21 5954665.50 373730.54 MWD+IFR-AK-CAZ-SC 8221.58 63.83 183.34 5864.08 5807.53 -2947.00 -4133.16 5954581.68 373722.22 MWD+IFR-AK-CAZ-SC 8316.83 64.99 180.57 5905.23 5848.68 -3032.85 -4136.08 5954495.90 373717.91 MWD+IFR-AK-CAZ-SC 8411.61 66.43 176.67 5944.23 5887.68 -3119.19 -4133.99 5954409.54 373718.60 MWD+IFR-AK-CAZ-SC 8507.09 67.56 173.41 5981.55 5925.00 -3206.72 -4126.38 5954321.90 373724.79 MWD+IFR-AK-CAZ-SC 8602.60 68.10 170.06 6017.60 5961.05 -3294.24 -4113.66 5954234.20 373736.08 MWD+IFR-AK-CAZ-SC 8697.71 70.40 170.11 6051.29 5994.74 -3381.84 -4098.35 5954146.36 373749.97 MWD+IFR-AK-CAZ-SC 8792.86 73.08 168.15 6081.11 6024.56 -3470.57 -4081.30 5954057.38 373765.57 MWD+IFR-AK-CAZ-SC 8888.15 75.25 165.29 6107.11 6050.56 -3559.77 -4060.23 5953967.86 373785.19 MWD+IFR-AK-CAZ-SC 8983.62 77.92 160.91 6129.27 6072.72 -3648.59 -4033.23 5953878.62 373810.74 MWD+IFR-AK-CAZ-SC 9079.27 79.80 158.06 6147.75 6091.20 -3736.47 -4000.34 5953790.23 373842.20 MWD+IFR-AK-CAZ-SC 9174.74 80.49 157.31 6164.09 6107.54 -3823.48 -3964.62 5953702.65 373876.49 MWD+IFR-AK-CAZ-SC II 9270.62 80.22 155.59 6180.16 6123.61 -3910.13 -3926.86 5953615.40 373912.84 MWD+IFR-AK-CAZ-SC ~ 9366.09 81.48 154.28 6195.34 6138.79 -3995.51 -3886.93 5953529.40 373951.38 MWD+IFR-AK-CAZ-SC ~I 9461.24 82.92 153.73 6208.25 6151.70 -4080.23 -3845.61 5953444.02 373991.31 MWD+IFR-AK-CAZ-SC 9497.09 83.98 154.45 6212.34 6155.79 -4112.27 -3830.05 5953411.74 374006.35 MWD+IFR-AK-CAZ-SC 9578.27 85.29 152.68 6219.93 6163.38 -4184.64 -3794.07 5953338.80 374041.15 MWD+IFR-AK-CAZ-SC 9673.89 83.61 152.94 6229.18 6172.63 -4269.29 -3750.58 5953253.46 .374083.25 MWD+IFR-AK-CAZ-SC 9769.04 80.12 153.94 6242.64 6186.09 -4353.53 -3708.47 5953168.56 374123.99 MWD+IFR-AK-CAZ-SC 9864.62 84.48 154.53 6255.45 6198.90 -4438.81 -3667.31 5953082.63 374163.75 MWD+IFR-AK-CAZ-SC 9959.75 90.66 155.50 6259.48 6202.93 -4524.92 -3627.18 5952995.88 374202.47 MWD+IFR-AK-CAZ-SC 10054.77 91.96 155.57 6257.31 6200.76 -4611.38 -3587.84 5952908.80 374240.39 MWD+IFR-AK-CAZ-SC ~ 10150.29 93.75 154.84 6252.55 6196.00 -4697.98 -3547.84 5952821.57 374278.99 MWD+IFR-AK-CAZ-SC 10245.44 92.58 157.09 6247.29 6190.74 -4784.74 -3509.15 5952734.20 374316.26 MWD+IFR-AK-CAZ-SC 10340.83 92.94 157.82 6242.70 6186.15 -4872.74 -3472.62 5952645.62 374351.35 MWD+IFR-AK-CAZ-SC 10436.12 93.32 156.94 6237.50 6180.95 -4960.57 -3436.02 5952557.22 374386.51 MWD+IFR-AK-CAZ-SC 10531.27 93.13 155.66 6232.14 6175.59 -5047.55 -3397.84 5952469.63 374423.28 MWD+IFR-AK-CAZ-SC 10626.90 94.06 152.45 6226.15 6169.60 -5133.37 -3356.09 5952383.16 374463.62 MWD+IFR-AK-CAZ-SC 10721.62 93.69 151.93 6219.75 6163.20 -5216.95 -3312.00 5952298.88 374506.35 MWD+IFR-AK-CAZ-SC 10816.81 89.67 151.11 6216.96 6160.41 -5300.57 -3266.64 5952214.54 374550.34 MWD+IFR-AK-CAZ-SC 10912.30 87.39 152.80 6219.41 6162.86 -5384.81 -3221.76 5952129.59 374593.84 MWD+IFR-AK-CAZ-SC i 1007.20 86.09 154.44 6224.80 6168.25 -5469.69 -3179.66 5952044.05 374634.55 MWD+IFR-AK-CAZ-SC 11102.49 86.03 157.72 6231.35 6174.80 -5556.57 -3141.12 5951956.56 374671.67 MWD+IFR-AK-CAZ-SC i 11197.49 86.77 157.35 6237.32 6180.77 -5644.19 -3104.89 5951868.37 374706.47 MWD+IFR-AK-CAZ-SC 11289.06 86.52 155.03 6242.68 6186.13 -5727.82 -3067.99 5951784.16 374742.00 MWD+IFR-AK-CAZ-SC 11388.36 87.51 153.69 6247.85 6191.30 -5817.21 -3025.08 5951694.09 374783.45 MWD+IFR-AK-CAZ-SC 11483.45 91.22 154.62 6248.90 6192.35 -5902.77 -2983.64 5951607.87 374823.50 MWD+IFR-AK-CAZ-SC Ili + - M IFR-AK-CAZ-SC 11578.94 92.08 153.83 6246.15 6189.60 5988.72 -2942.13 5951521.27 374863.60 WD 11673.64 93.01 151.36 6241.95 6185.40 -6072.71 -2898.59 5951436.59 374905.76 MWD+IFR-AK-CAZ-SC 11769.09 92.20 151.23 6237.61 6181.06 -6156.34 -2852.80 5951352.24 374950.19 MWD+IFR-AK-CAZ-SC 11864.39 92.70 151.29 6233.53 6176.98 -6239.82 -2807.02 5951268.03 374994.61 MWD+IFR-AK-CAZ-SC 11959.54 93.13 154.09 6228.69 6172.14 -6324.25 -2763.42 5951182.91 375036.82 MWD+IFR-AK-CAZ-SC 12054.74 92.45 154.61 6224.06 6167.51 -6409.96 -2722.26 5951096.54 375076.58 MWD+IFR-AK-CAZ-SC I 12149.67 91.96 154.79 6220.41 6163.86 -6495.73 -2681.72 5951010.14 375115.72 MWD+IFR-AK-CAZ-SC 12244.88 92.88 155.57 6216.39 6159.84 -6582.06 -2641.79 5950923.18 375154.24 MWD+IFR-AK-CAZ-SC 12340.45 90.10 154.80 6213.90 6157.35 -6668.77 -2601.70 5950835.84 375192.91 MWD+IFR-AK-CAZ-SC 12435.60 90.17 151.72 6213.68 6157.13 -6753.73 -2558.89 5950750.20 375234.33 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Company: ConocoPhill!ps Alaska Inc. Date: 1/24/2007 'Time: 16:13:39 P;~ge 4 Field: Colville River Unit Co-ordiuate(NE) Reference: Well: CD4-215, True North Site: Alpine CD4 Vertical (TVD) Reference CD4-215:56.6 Well: CD4-215 Section (VS) Reference: Well (O.OON,O.OOE,189.85Azi) Wellpath: CD4-215 Survey Calculation iVtethod: Minimum Curvature Db: Oracle S u i1 et _-- - - A1ll incl Azim TVD Svs 1ti'D N/S E/W MapN V1apE 'Cool ft de;~ deg ft ft ft ft ft ft __ i~ 12530.71 89.80 152.73 6213.70 6157.15 -6837.88 -2514.57 5950665.34 375277.28 MWD+IFR-AK-CAZ-SC 12625.88 89.73 156.89 6214.09 6157.54 -6923.98 -2474.07 5950578.61 375316.37 MWD+IFR-AK-CAZ-SC 12721.13 89.80 156.82 6214.48 6157.93 -7011.57 -2436.64 5950490.43 375352.38 MWD+IFR-AK-CAZ-SC 12816.42 87.14 153.73 6217.03 6160.48 -7098.07 -2396.80 5950403.30 375390.79 MWD+IFR-AK-CAZ-SC 12911.90 87.88 151.70 6221.18 6164.63 -7182.84 -2353.08 5950317.84 375433.13 MWD+IFR-AK-CAZ-SC 13007.09 91.77 152.55 6221.47 6164.92 -7266.97 -2308.58 5950233.00 375476.25 MWD+IFR-AK-CAZ-SC 13102.54 90.47 154.70 6219.60 6163.05 -7352.46 -2266.19 5950146.84 375517.25 MWD+IFR-AK-CAZ-SC '~ 13197.41 88.68 155.49 6220.31 6163.76 -7438.50 -2226.24 5950060.17 375555.79 MWD+IFR-AK-CAZ-SC 13293.24 89.06 155.41 6222.20 6165.65 -7525.65 -2186.43 5949972.39 375594.17 MWD+IFR-AK-CAZ-SC 13388.55 87.82 152.55 6224.79 6168.24 -7611.26 -2144.64 5949886.13 375634.57 MWD+IFR-AK-CAZ-SC 13482.97 86.21 151.28 6229.71 6173.16 -7694.45 -2100.26 5949802.24 375677.59 MWD+IFR-AK-CAZ-SC 13576.76 85.90 153.62 6236.16 6179.61 -7777.40 -2056.98 5949718.60 375719.51 MWD+IFR-AK-CAZ-SC 13672.77 86.52 156.21 6242.51 6185.96 -7864.15 -2016.37 5949631.20 375758.70 MWD+IFR-AK-CAZ-SC 13768.67 87.64 156.64 6247.39 6190.84 -7951.93 -1978.07 5949542.82 375795.57 MWD+IFR-AK-CAZ-SC 13863.63 87.76 153.96 6251.21 6194.66 -8038.13 -1938.42 5949456.00 375833.81 MWD+IFR-AK-CAZ-SC 13959.78 89.12 152.32 6253.82 6197.27 -8123.87 -1895.00 5949369.57 375875.83 MWD+IFR-AK-CAZ-SC 14054.34 90.78 151.88 6253.91 6197.36 -8207.43 -1850.75 5949285.31 375918.71 MWD+IFR-AK-CAZ-SC 14149.72 91.15 154.24 6252.30 6195.75 -8292.45 -1807.55 5949199.61 375960.53 MWD+IFR-AK-CAZ-SC 14245.52 93.01 154.62 6248.82 6192.27 -8378.80 -1766.23 5949112.60 376000.43 MWD+IFR-AK-CAZ-SC 14341.09 93.81 154.70 6243.14 6186.59 -8465.02 -1725.40 5949025.74 376039.85 MWD+IFR-AK-CAZ-SC 14435.79 94.55 153.47 6236.24 6179.69 -8549.97 -1684.12 5948940.14 376079.74 MWD+IFR-AK-CAZ-SC 14531.74 95.92 154.79 6227.48 6170.93 -8635.94 -1642.43 5948853.51 376120.03 MWD+IFR-AK-CAZ-SC 14629.46 96.35 156.32 6217.04 6160.49 -8724.39 -1602.23 5948764.43 376158.79 MWD+IFR-AK-CAZ-SC 14723.12 94.74 156.55 6207.99 6151.44 -8809.83 -1564.96 5948678.40 376194.66 MWD+IFR-AK-CAZ-SC 14761.00 94.74 156.55 6204.86 6148.31 -8844.47 -1549.94 5948643.53 ~ 376209.12 PROJECTED to TD Re: BOPE test-CD4-215 (206-157) r Subject: Re: BOPE test-CD4-215 (206-157) From: Thomas Maunder <toin_maunder a,,admin.state.ak.us> Date: Tue, 19 Dec 2006 1 1:12:41 -0900 To: "G~iliunas, I~lizaheth ('~~ 'Flicabcth.~'.Gaiiunasl~i?c~noc~,hliillips.corn=> Liz, I have looked at your original message. It would appear that the BOP was closed for a total of about 2 hours. The reported maximum SI pressure was 40 psi. The pressures experienced while circulating would have been higher, however the SI and circulating did not likely compromise the ability of the BOP to be used to SI the well were a actual well control situation to occur. It is acceptable to remain on the present BOP schedule. A copy of this message should be available on the rig. Call or message with any questions. Tom Maunder, PE AOGCC Galiunas, Elizabeth C wrote, On 12/19/2006 8:47 AM: Tom, As discussed earlier, since the exhale test performed on Saturday was confirmed as breathing and not well control, a BOPE test is not necessary if we were to come out of the hole before reaching the next test date. Thanks, Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907)-265-6247 Cell: (907)-441-4871 1 of 1 12/19/2006 11:12 AM Further Notification of Precautionary Well Control Exercise Subject: Further Notification of Precautionary Well Control Exercise From: "Galunas, ElizabEthC" <_Elizabeth.C.Galiunas a~conocophillips.com> Date: Sat, 16 Dec 200G U9: ~U:U9 -0900 To: ~Chom,is i~~launder ~ tommaundcrctadn~in.state.ak.us%. "Johnson, Vern•• -b~crn.Jolmson~<<:conocophillips.com-.>, "f~l~~ord, Chip" =~:C11ip..Alvord(ci~~.conocophillips.com~=~, Do~,~on 1 ~) Compan~~~ ~°lan <~dovon 1 ~~l~c~onoe.ophillips.com> While drilling the horizontal section of CD4-215 at 9723' MD a 2% increase in flow was observed and a 6 bbl pit gain (12/16/06, 03:45 hrs). The well was SI and monitored with SICP of 0 psi & SIDPP of 40 psi (04:00 hrs). As a precautionary measure, the rig circulated bottoms up through the choke, no gas was observed, but the mud was aired up. Then the well was SI and monitored with zero pressure on the casing and 40 psi on the DP. The State representative in the field was notified by the company man this morning via phone. After performing the exhale test, the rig concluded the well was breathing and not experiencing a "well control" event. At 05:50 hrs drilling was resumed and the well was static on connections. Regards, Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907)-265-6247 Cell: (907)-441-4871 1 of 1 12/19/2006 11:12 AM STATE OF ALASKA 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim re~g ~3adr~:in.state.ak.us• aogc^ pr~Ed~oe h:~~ad:nn.state.alv.us holy eckensten~~adrr:i:~.stUte.ak.us Contractor: Doyon Rig No.: 19 DATE: 12/9/2006 Rig Rep.: Welsh / Grazulis Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Hill /Woods Field/Unit & Well No.: Colville Rv CD4-215 PTD # 206-157 Operation: Drlg: x Workover: Explor.: Test: Initial: x Weekly: Bi-Weekly Test Pressure: Rams: 250/5000 Annular: 250!3500 Valves: 250/5000 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test R Location Gen.: P Well Sign P Upper Kelly 1 P Housekeeping: P Drl. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size Test Result Annular Preventer 1 13-5/8 P Pipe Rams 1 3-1/2x 6 P Lower Pipe Rams 1 3-1/2x 6 P Blind Rams 1 blinds P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kill Line Valves 1 3-1/8 FP Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results CHOKE MANIFOLD: Quantity Test Resu No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Resu System Pressure 3000 P Pressure After Closure 1550 P 200 psi Attained 32 P Full Pressure Attained 2 min 58 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ 1900 psi Number of Failures: 1 Test Time: 7.5 Hours Components tested 30 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: jim r~:~~ :~3azir~:i:~.state.alc.u~• Remarks: Manual kill failed -Serviced Manual kill, retested-good. Re-torqued hub clamp had slight drip on bottom of stack to wellhead - no leak after re- torqued. Tested VRB's to 5", 4", 3-1/2", & 4-1/2". 24 HOUR NOTICE GIVEN YES X NO Date 12/07/06 Time 5:10 Test start 3:30pm Finish Waived By Chuck Scheve Witness John Welsh /Larry Hill BOP Test (for rigs) BFL 11/09/04 Doyon19 12-09-06 CD4-215.x1s _. _. u, .. . _ .~. ~ ~. ~, _s t1•itt~a7~ O~ Al`D COI~SERVATIOlOT COMbIISSIO~T Chip Alvord WNS Drilling Team Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 I FRANK H. MURKOWSKI, GOVERNOR 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907j 27&7542 Re: Colville River Field, Nanuq-Nanuq Oil Pool, CD4-215 ConocoPhillips Alaska, Inc. Permit No: 206-157 Surface Location: 2952' FNL, 341' FEL, SEC. 24, T11N, R4E Bottomhole Location: 1248' FNL, 1879' FEL, SEC 36, T11N, R4E Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. 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). DATED this % day of November, 2006 cc: Department of Fish 8z; Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~~( ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: Drill ^/ Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone ^ Single Zone Q 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: CD4-215 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 14760' TVD: 6205' 12. Field/Pool(s): Colville River Field 4a. Location of Well (Governmental Section): Surface: 2952' FNL, 341' FEL,. Sec 24 T11 N R4E 7. Property Designation: ADL 380077, 384209, 388902 Nanuq Nanuq Oil Pool • Top of Productive Horizon: 1680' FNL, 4236' FEL, Sec. 25 T11 N R4E 8. Land Use Permit: ALK 380077 13. Approximate Spud Date: 12111!2006 Total Depth: 1248' FNL, 1879' FEL, Sec. 36 T11 N R4E 9. Acres in Property: 2560 14. Distance to Nearest Property: 5280' Nanuq PA 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377902. y- 5957461 Zone- 4 10. KB Elevation (Height above GL): 37' RKB feet 15. Distance to Nearest Well within Pool: Nanuk 2 , 967' 16. Deviated wells: Kickoff depth: 300. ft. Maximum Hole Angle: 94° deg 17. Maximum Anticipated Pressures in psig (see zo arc 25.035) Downhole: 2806 psig Surface: 2185 psig • 18. Casing Program if S ti Setting Depth Quantity of Cement Size ica pec ons Top Bottom c. f. or sacks 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-$0 BTC 2806 37 37 2843 2400 544 sx AS Lite3, 230 sx 15.8 G 8.75" 7" 26# L-80 BTCM 9375 37 37 9412 6204 187 sx 11.0 Litecrete, 2$6 sx 15.8G 6.125" 3.5" 9.3# L-80 SLHT 5540 9210 6181 14750 6205 Slotted Liner 3.5" 9.3 L-80 EUE-M 9178 32 32 9210 6181 tubing & vac. Insul tubing {4000' MD) 19 PRESENT WELL CONDITION SUMMARY (To be wmpleted for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch^ Drilling Program^/ Time v. Depth Plot ^ Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^ 20 AAC 25.050 requirements^ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact L. Galiuna5 Printed Name C. Alvord Title WNS Drilling Team Lead Signature ' ,/_ ~ Phone Date (I ~(G ~ t' o G l~ Z(,4 -G t'( e Commission Use Only Permit to Drill Number: ~~~ ~ ~S ~ API Numb//er~~: ^~ ~~ p ` 50- ~V ~ '~G•~.•r-~ ~ / ~ ~) Permit Approval Date: See cover letter for other requirements Conditions of approval : tf box is checked, weA may not be used to explore for, test, or produce Coalbed m hane, gas ales, or gas contained in shales: ~$~~ i~~S`f ,,,~~,~.~ ~~ ~`~ ~~~~ Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No [~ Other: ` ^ `` `` ~~a/~ `` ~~ _ll~[['~~11 lLLl`` ln1' H`/2llS measCures: Ye\)s ^ No []~ ~ e i al svy req'd: Yes [.~' No ^ ~~~,~~ ~ w~~ V~ ~ Y ^~a~ i~ ~~ Y~~~J ~O6 APPROV YTHECOMMISSION DATE: ~''~ ,COMMISSIONER Form 10-401 Revised 12/2005 ~~~~,5~ ¢mit in Duplicate ConocoPhilli s Alaska Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 CanoCOPhiIip5 Telephone 907-276-1215 November 16, 2006 Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 - Anchorage, Alaska 99501 ~ `~ Re: Application for Permit to Drill CD4-215 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore producer well from the Nanuq (CD4) drilling pad. The intended spud date for this well is 12/11/2006. It is intended that Doyon Rig 19 be used to drill the well. After setting 7" intermediate casing, the undulating horizontal section will be drilled and the well completed as a slotted liner producer. At the end of the rig work program, the well will be closed in awaiting completion of well work and facilities connection. Afterwards the well will be flowed back for 2-3 days and at field start up, put on production. It is expected that the K2 (Qannik) sand could be considered a significant hydrocarbon bearing zone. If considered significant, a single stage cement job is planned with lealc."and tail cement isolating up to 500' above the K2 interval. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. There have been 10 surface holes drilled at CD4 and there has not been a significant show of shallow gas or gas hydrates. /,,~a~s~.x:~\,~~~~,`.o.,~~ ,~ "~ ~~~ `~/~' Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to~Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program 4. A drilling fluids program summary. 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. 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, 265-6247, or Chip Alvord at 265-6120. Sincerely, Liz Gali nas • Drilling Engineer Attachments cc: CD4-215 Well File /Sharon Allsup Drake Chip Alvord Vern Johnson Liz Galiunas Jack Walker Lanston Chin ATO 1530 ATO 1700 ATO 1702 ATO 1704 ATO 1740 Kuukpik Corporation r • CD4-215 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) ~ 7_~ /d" Nnlo / Q_~/R" [_acinn Intarval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) Burin interval. Well Collision Low G ro sin le shots, travelin c tinder dia rams Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight Surface Formations ~ >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densi cement slurries Q_~/dD7 1-Inln / 7" (_acinn Intarval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations ~ Check for flow during connections and if needed, >2000' TVD increase mud wei ht. Lost circulation Low 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, mud properties, proper hole filling, pumping oufi of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure ~ mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low ~ H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers G ~ /Q» LJ..1.~ / LJ~r:~~nf~l Drnrl~~~finn 1-Inlo .. 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 • Nanug : CD4-215 Procedure 1) Move on Doyon 19, dewater cellar as needed. 2) Rig up riser. 3) Drill 12-'/4" hole to the surface casing point per the directional plan. (Directional/MWD). 4) Run and cement 9-5/8" surface casing. 5) Install and test BOPE to 5000 psi. 6) Pressure test casing to 2500 psi. 7) Drill out 20' of new hole. Perform leak off test. 8) Pick up and run in hole with 8-3/4" drilling BHA. 9) Drill 8-3/4" hole to intermediate casing point in the reservoir sand. (LWD Program: GR/RES/PWD) 10) Run and cement 7" casing as per program. Carry out a leak off Pest down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11) BOPE test to 5000 psi. 12) Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 13) Displace well to water based, Flo-Pro mud. r 14) Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). 15) Circulate the hole clean and pull out of hole. 16) Run lower completion with slotted liner and liner hanger, set hanger and pull out of hole. 17) Run 3-'h, 9.3#, L-80 tubing with Vacuum insulated tubing, TRMAXX SCSSSV, gas lift mandrels, packer and stinger assembly. Sting in, space out and land hanger. 18) Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19) Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20) Circulate tubing to diesel and install freeze protection in the annulus. 21) Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 22) Set BPV and secure well. Move rig off. 0 ~~uii~/,L • Well Proximity Risks: • Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD4-17 is the closest well. Well separation is 35' @ 935' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. ~ Lost circulation: Faulting within the Nanuq 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 CD4-215 will be injected into a permitted annulus on CD4 pad or the class 2 disposal well on CD1 pad. The CD4-215 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only potentially significant hydrocarbon zone is the K2 (Qannik). If it is determined to be significant, a single stage cement job will be used to isolate it. Upon completion of CD4-215 form 10-403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. / The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) " (0.052) * (Surf. Shoe TVD) + 1,500 psi _ (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 -1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 40 L-80 3 BTC 9,090 psi 1,717 psi 5,750 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi ~ni~ini n w • • DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing point -12 '/4" Intermediate hole to 7" casing point - 8'/<" Production Hole Section - 6 1/8" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.0-9.3 pp9 PV 10 - 25 10 -15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 - 15 10 minute gels <18 12 - 20 API Filtrate NC -10 cc / 30 min 4 -12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5-9.0 9.0-10.0 9.0-9.5 KCL 6 Surface Hole: i A standard high viscosity fresh water /gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel /polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. 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. OR161NAL • • CD4 - 215 Nanuq Nauuq Producer Completion 16" Insulated Conductor to -114' ~ 2) 4-''/z' x 3-''/2' Vacuum insulated tubing (VIT) 2.813" 'X' TRMAXX SCSSSV 9-5/8" 40 ppf L-80 BTCM SurFace Casing 2843' MD / 2400' TVD 4) 4?/2' x 3-'/i' Vacuum insulated tubing (VIT) to +/- 4000' MD Upper Completion: Top MD TVD 1) Tubing Hanger 32' 32' 2) 4-1 /2" x 3-''/i' VIT 3-''/i' buttress-Mod connection 3) 3-1/2" Camp TRMAXX SCSSSV w/ X profile 2247' 2000' O ' 4) 4-1/2" x 3-'/i' VIT 3-'/i' buttress-Mod connection + TVD $79' MD / 3766 5) Crossover from VIT (3-/z" IBTM) to EUE-M tubing 4000' 3176' 6) 3-''/z' 9.3#/ft, EUE-M 7) Camco KBMG 1" GLM w/ dummy valve 4333' 3400' 8) 3'/z'9.3#/ft,EUE-M 9) Camco KBMG 1" GLM w/ dummy valve 8089' 5824' fop K2/Qannik sand 10) 3??/2' 9.3#/ft, EUE-M (2) */-5379' MD / 4102' TVD 11) Baker Premier Packer 8169' 5862' 12) 3-'/~' 9.3#/ft, EUE-M (2) 13) HES "XN" (2.75" min ID) @ 64° 8249' 5898' 14) 3?/z" 9.3#/ft, EUE-M 15) BOT Stinger with Fluted WLEG/pup/shear sub 9207' 6181' bottom, 3' spaceout @ 9220' Lower Completion: Top MD TVD 16) Baker 5" x 7" Flexlock Liner Hanger 9210' 6181' 17) 3-''/z" 9.3#/ft L-80 SLHT Tubing 18) 3-''/i' 9.3#/ft L-80 SLHT slotted liner w/ blank across shale and slots across sand ~`j, 19) Baker Shoe 14650' 6212' 3-'/i' 9.3#/ft L-80 SLHT Slotted liner Pattern: Top Reservoir at +/- Nanuq 9359' MD / 6199' 7" 26 ppf L-80 BTC Mod Production Casing @ +/-85° 9412' MD, 6204' TVD TD 6-1/8" hole 14760' MD / 6201' TVD ORIGIN,n,L • CD4-215 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: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 2843 / 2400 14.5 1086 1570 7" 9412/ 6204 16.0 2805 2185 N/A 14760 / 6205 16.0 2806 ~ N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 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 Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1] D =[(10.9x0.052)-0.1]x114=53 psi OR ASP =FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1 ] D _ [(14.5 x 0.052) - 0.1] x 2400 = 1570 psi OR ASP =FPP - (0.1 x D) = 2805 - (0.1 x 6204') = 2185 psi 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 2806- (0.1 x 6205') = 2186 psi - OR!GIN;L • Cementing Program: • 9-5/8" Surface Casing run to 2843' MD / 2400' TVD. Cement from 2843' MD to 2343' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2343' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (assume 1600' TVD). Lead slurry: (2343'-1686') X 0.3132 ft3/ft X 1.5 (50% excess) = 308.7 ft3 below permafrost 1686' X 0.3132 ft3/ft X 4 (300% excess) = 2112.2 ft3 above permafrost Total volume = 308.7 + 2112.2 = 2420.9 ft3 => 544 Sx @ 4.45 ft3/sk System: 544 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% 5001 accelerator, 50% D124 extender and 9% BWOW1 D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 9412' MD / 6204' TVD: Cemented in two stages Cement from 9412' MD to 7869' MD with Class G + adds @ 15.8 PPG and from 7869' MD to 4879' MD (+/- 500' above the K2) with LiteCRETE @ 11.0 ppg. Assume 40% excess annular volume. First Stage• Lead: (7869' -4879') X 0.1503 ft3/ft X 1.4 (40% excess) = 627.3 ft3 annular volume Total volume = 627.3 ft3 => 187 Sx @ 3.35 ft3/sk System: 187 Sx LiteCrete with 0.4% D046 antifoamer, 1.0 % D065 dispersant, 0.010% B155 retarder, 0.25% D167 fluid loss @ 11.0 PPG yielding 3.35 ft3/sk Tail: (9412' -7869') X 0.1503 ft3/ft X 1.4 (40% excess) = 324.7 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 313.7 + 17.2 = 341.9 ft3 => 295 Sx @ 1.16 ft3/sk System: 295 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk ' By Weight Of mix Water, all other additi s~e~B~C'~r ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Dater 11/3/2006 Time: 1545:3T Page: 1 Field: Colville River Unit Co-ordinate(NE) Re~ereuce: WeII: Plarr: CD4-215, True North Site: Alpine CD4 Verticat(TVD) Reference: Plan: CD4-21556.1 Well: Plain. CD4-2fi5 Section (VS) Reference: Well (O.OON,O.OOE,189.85Azi) Wellpath: Plan: CD4-215 Survey Calculation Method: Minimum Curvature Db: Qraae Plan Section Information MD Incl Azim TVD +N/~ +E!-W DLS Build. Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 700.00 8.00 260.00 698.70 -4.84 -27.46 -2.00 2.00 0.00 260.00 2042.82 47.84 242.00 1862.62 -265.50 -581.94 3.00 2.97 -1.34 -20.74 6520.82 47.84 242.00 4868.53 -1823.54 -3512.71 0.00 0.00 0.00 0.00 9360.72 85.04 154.00 6199.10 -4007.04 -3895.12 3.00 1.31 -3.10 -92.34 CD4-215wp04 T1 9383.05 84.37 153.99 6201.16 -4027.02 -3885.37 3.00 -3.00 -0.06 -178.82 9821.97 84.37 153.99 6244.20 -4419.58 -3693.79 0.00 0.00 0.00 0.00 9962.68 90.00 154.10 6251.10 -4545.89 -3632.31 4.00 4.00 0.08 1.18 CD4-215wp04 T2 10024.29 92.46 154.10 6249.77 -4601.30 -3605.41 4.00 4.00 0.00 0.01 10799.79 92.46 154.10 6216.43 -5298.28 -3267.02 0.00 0.00 0.00 0.00 10861.41 90.00 154.09 6215.10 -5353.69 -3240.11 4.00 -4.00 -0.03 -179.63 CD4-215wp04 T3 10965.39 85.84 154.09 6218.87 -5447.13 -3194.71 4.00 -4.00 0.00 179.98 11357.75 85.84 154.09 6247.33 -5799.12 -3023.71 0.00 0.00 0.00 0.00 11461.73 90.00 154.07 6251.10 -5892.56 -2978.30 4.00 4.00 -0.02 -0.23 CD4-215wp04 T4 11526.94 92.61 154.07 6249.62 -5951.19 -2949.80 4.00 4.00 0.00 0.00 12296.67 92.61 154.07 6214.58 -6642.72 -2613.59 0.00 0.00 0.00 0.00 12361.88 90.00 154.07 6213.10 -6701.35 -2585.08 4.00 -4.00 -0.01 -179.89 CD4-215wp04 T5 12409.19 88.11 154.07 6213.88 -6743.89 -2564.39 4.00 -4.00 0.00 -179.99 13512.47 88.11 154.07 6250.32 -7735.52 -2082.16 0.00 0.00 0.00 0.00 13559.79 90.00 154.09 6251.10 -7778.07 -2061.48 4.00 4.00 0.04 0.62 CD4-215wp04 T6 14759.11 94.30 154.09 6206.10 -8855.80 -1537.86 0.36 0.36 0.00 0.00 CD4-215wp04 T7 Plan: CD4-215wp04 Date Composed: 11/3/2006 Version: 8 PrincipaL• Yes Tied-to: From Well Ref. Point Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: Alpine CD4 Site Position: Northing: 5957526.10 ft Latitude: 70 17 32.966 N From: Map Easting: 378174.70 ft Longitude: 150 59 10.763 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.93 deg Well: Plan: CD4-215 Slot Name: WeII Position: +N/-S -69.59 ft Northing: 5957460.92 ft ~ Latitude: 70 17 32.281 N +E/-W -271.27 ft Easting : 377902.36 ft ~ Longitude: 150 59 18.669 W Position Uncertainty: 0.00 ft Wellpath: Plan: CD4-215 Drilled From: WeII Ref. Point Tie-on Depth: 36.30 ft Current Datum: Plan: CD4-215 Height 56.10 ft Above System Datum: Mean Sea Level Magnetic Data: 7/18/2006 Declination: 23.12 deg Field Strength: 57544 nT Mag Dip Angle: 80.65 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.30 0.00 0.00 189.85 Survey Program for Definitive Wellpath Date: 10/12/2006 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft ORIGINAL WELL DETAILS Jame +N/-S +E/-W Northing Easting Latitude Longitude Slot 'lan: CD4-215 -69.59 -271.27 5957460.92 377902.36 70°1T32.281N 150°59'18.669W N/A WELLPATH DETAILS Plan: CD4-215 Rig: Doyon 19 Ref. Datum: Plan: CD4-215 56.1Oft V.Section Origin Origin Starting Angle +N/-S +E/-W From TVD 189.85° 0.00 0.00 36.30 T M Azimuths to True North Magnetic North: 23.12° Magnetic Field Strength:57544nT Dip Angle: 80.65° Date: 7/18/2006 Model: bggm2006 SURVEY PROGRAM Depth Fm Depth To Survey/Plan Tool 36.30 1000.00 Planned: CD4-215wp04 V8 CB-GYRO-SS 1000.00 14759.11 Planned: CD4-215wp04 V8 MWD+IFR-AK-CAZ-SC a 0 3 .~ 2 F Kick off; 2 DL' Build; 3 DLS,' 3~ Sail; 47.8° 9....,518" ~~ 300' MD 0' MD ° ' ~ Kick off• 2 DLS, 300' MI Sail; 47.8 for 44 78 ~ 9 5/8" cs t 2400' TVD --- ~~ Build• 3 DLS 700' MD ~~ B uild; 3 DLS 4868' TVD o ~ -- s -2165 0 a .6000 7" cs t• 9360' MD 6199' TVD r -4331 T2 o y .... T3 T4 -6496 TS T6 CD4-215w 04 -8662 -6496 -4331 -2165 0 2165 West(-)/East(+) [ft] r 4478' t 2400' TVD _ 0 __ Build• 31; bo LS, 4868' TVD CD4-215w 04 7" cs it; 9360' MD 6199' TVD ~ T2 T3 T4 TS T6 ~~ ~ ° °, ~ ~ ~ oo' ~ ~ ~ c a ° ~ oo° `p 4000 6000 8000 10000 Vertical5ec6on at 189.85° [2000fVin] MALLIBUATON ~OI'lOCt~'f1IIII 7-S sp..ry a.~a~~ s.rwcs I Alaska REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: Plan: CD4-2I5, True North Vertical (TVD) Reference: Plan: CD4-215 56.10 Section (VS) Reference: Slot - (O.OON,O.OOE) Measured Depth Reference: Plan: CD4-215 56.10 Calculation Method: Minimum Curvature ConocoPhillips Alaska, Inc. CPAI Report Company:. ConocoPhillips Alaska Inc. Date: 11/3/2006 Time: 15:45:37 Page: z Field: Cotvilie River Unit Co-ardinate(NE) Reference: WeII: Plan: CD4-215, True North Site; Alpine CD4 Vertica l (T~'D) Reference: Pl an: CD4-215 56.1 Well: Plan: C D4-2 15 ' Sec tion (VS) Reference: Well (O.OON,O.OOE,189 .85Azi) Wellpath: " `Plan: C D4-2 1fr Survey Galcnlation Method: Minimum Curvature Db: Oracle Survey MD incl Azim TVD Sys TVD N/S E/W 1CZapN MapE -DLS VS Comore t ff deg deg ft ft ft ft ft ft deg/100ft R 36 .30 0. 00 0 .00 36. 30 -19. 80 0 .00 0 .00 5957460. 92 377902 .36 0.00 0 .00 100 .00 0. 00 0 .00 100. 00 43. 90 0 .00 0 .00 5957460. 92 377902. 36 0.00 0 .00 200 .00 0. 00 0 .00 200. 00 143. 90 0 .00 0 .00 5957460. 92 377902. 36 0.00 0 .00 300 .00 0. 00 0 .00 300. 00 243. 90 0 .00 0 .00 5957460. 92 377902. 36 0.00 0 .00 Kick off; 2 DLS, 0 400 .00 2. 00 260 .00 399 .98 343. 88 -0 .30 -1 .72 5957460. 64 377900 .64 2.00 0 .59 500 .00 4. 00 260 .00 499. 84 443. 74 -1 .21 -6 .87 5957459. 82 377895. 47 2.00 2 .37 600 .00 6. 00 260 .00 599. 45 543. 35 -2 .73 -15 .46 5957458. 45 377886. 86 2.00 5 .33 700 .00 8. 00 260 .00 698. 70 642. 60 -4 .84 -27 .46 5957456. 53 377874. 83 2.00 9 .47 Build; 3 DLS, 70 ' 800 .00 10. 86 254 .35 797. 34 741. 24 -8 .59 -43 .38 5957453. 04 377858. 85 3.00 15 .89 900 .00 13. 77 251 .06 895. 03 838. 93 -15 .00 -63 .72 5957446. 96 377838. 41 3.00 25 .68 1000 .00 16. 72 248 .90 991. 50 935. 40 -24 .04 -88. 40 5957438. 32 377813. 58 3.00 38 .82 1100 .00 19. 68 247 .37 1086. 49 1030. 39 -35 .71 -117 .38 5957427. 13 377784. 43 3.00 55 .26 1200 .00 22. 66 246 .23 1179. 73 1123. 63 -49 .95 -150 .55 5957413. 43 377751. 03 3.00 74 .97 1300 .00 25. 63 245 .35 1270. 97 1214. 87 -66 .74 -187 .85 5957397. 25 377713. 47 3.00 97 .90 1395 .49 28. 48 244 .66 1356. 00 1299. 90 -85 .10 -227 .20 5957379. 53 377673. 82 3.00 122 .72 Base Permafrost 1400 .00 28. 62 244. 63 1359. 96 1303. 86 -86 .03 -229. 15 5957378. 63 377671. 86 3.00 123 .97 1500 .00 31. 60 244. 04 1446. 46 1390. 36 -107 .76 -274. 36 5957357. 64 377626. 31 3.00 153 .11 1600 .00 34. 59 243. 55 1530. 23 1474. 13 -131 .87 -323. 34 5957334. 33 377576. 95 3.00 185 .25 1700 .00 37. 58 243. 12 1611. 04 1554. 94 -158 .31 -375. 96 5957308. 75 377523. 91 3.00 220 .31 1800 .00 40. 57 242. 75 1688. 66 1632. 56 -186 .99 -432. 08 5957280. 98 377467. 34 3.00 258 .17 1900 .00 43. 56 242. 42 1762. 89 1706. 79 -217 .85 -491. 54 5957251. 10 377407. 39 3.00 298 .74 2000 .00 46. 55 242. 12 1833. 52 1777. 42 -250 .78 -554. 18 5957219. 19 377344. 22 3.00 341 .91 2042 .82 47. 84 242. 00 1862. 62 1806. 52 -265 .50 -581. 94 5957204. 93 377316. 24 3.00 361 .16 Sail; 47.8° for 44 2100 .00 47. 84 242. 00 1901. 00 1844. 90 -285 .40 -619. 36 5957185. 64 377278. 50 0.00 387 .16 2200 .00 47. 84 242 .00 1968. 13 1912. 03 -320 .19 -684. 81 5957151. 92 377212. 50 0.00 432 .64 2300 .00 47. 84 242 .00 2035. 25 1979. 15 -354 .98 -750 .26 5957118. 20 377146. 50 0.00 478 .12 2400. 00 47. 84 242. 00 2102. 38 2046. 28 -389 .78 -815. 71 5957084. 48 377080. 50 0.00 523 .60 2500. 00 47. 84 242. 00 2169. 51 2113. 41 -424 .57 -881. 15 5957050. 75 377014. 50 0.00 569 .08 2551. 39 47. 84 242. 00 2204. 00 2147. 90 -442 .45 -914. 79 5957033. 42 376980. 59 0.00 592 .45 C-40 2600. 00 47. 84 242. 00 2236. 63 2180. 53 -459 .36 -946. 60 5957017. 03 376948. 50 0.00 614 .56 2700. 00 47. 84 242. 00 2303. 76 2247. 66 -494 .15 -1012. 05 5956983. 31 376882. 50 0.00 660 .04 2800. 00 47. 84 242. 00 2370. 89 2314. 79 -528 .95 -1077. 50 5956949. 58 376816. 50 0.00 705 .51 2843 .37 47. 84 242. 00 2400. 00 2343. 90 -544 .04 -1105. 89 5956934. 96 376787. 88 0.00 725 .24 9 5/8" 2855 .29 47. 84 242. 00 2408. 00 2351. 90 -548 .19 -1113. 69 5956930. 94 376780. 01 0.00 730 .66 C-30 2900 .00 47. 84 242. 00 2438. 01 2381. 91 -563 .74 -1142. 95 5956915. 86 376750. 50 0.00 750 .99 3000 .00 47. 84 242. 00 2505. 14 2449. 04 -598 .53 -1208. 40 5956882, 14 376684. 50 0.00 796 .47 3100 .00 47. 84 242. 00 2572. 27 2516. 17 -633 .33 -1273. 84 5956848. 42 376618. 50 0.00 841 .95 3200. 00 47. 84 242. 00 2639. 39 2583. 29 -668. 12 -1339. 29 5956814. 69 376552. 50 0.00 887. 43 3300. 00 47. 84 242. 00 2706. 52 2650. 42 -702. 91 -1404. 74 5956780. 97 376486. 51 0.00 932 .91 3400. 00 47. 84 242. 00 2773. 64 2717. 54 -737. 71 -1470. 19 5956747. 25 376420. 51 0.00 978 .39 3406. 49 47. 84 242. 00 2778. 00 2721. 90 -739. 97 -1474. 44 5956745. 06 376416. 22 0.00 981 .34 C-20 3500. 00 47. 84 242. 00 2840. 77 2784. 67 -772 .50 -1535. 64 5956713. 52 376354. 51 0.00 1023 .87 3600 .00 47. 84 242. 00 2907. 90 2851. 80 -807 .29 -1601. 09 5956679. 80 376288. 51 0.00 1069 .34 3700 .00 47. 84 242. 00 2975. 02 2918. 92 -842 .09 -1666. 53 5956646. 08 376222. 51 0.00 1114 .82 3800 .00 47. 84 242. 00 3042. 15 2986. 05 -876 .88 -1731. 98 5956612, 36 376156. 51 0.00 1160 .30 3900 .00 47. 84 242 .00 3109. 28 3053. 18 -911 .67 -1797. 43 5956578. 63 376090. 51 0.00 1205 .78 4000 .00 47. 84 242 .00 3176. 40 3120. 30 -946 .47 -1862 .88 5956544. 91 376024. 51 0.00 1251 .26 4100 .00 47. 84 242 .00 3243. 53 3187. 43 -981 .26 -1928 .33 5956511. 19 375958. 51 0.00 1296 .74 4200. 00 47. 84 242. 00 3310. 66 3254. 56 -1016 .05 -1993. 78 5956477. 46 375892. 51 0.00 1342 .22 4300. 00 47. 84 242. 00 3377. 78 3321. 68 -1050 .85 -2059. 22 5956443. 74 375826. 51 0.00 1387 .70 4400 .00 47. 84 242. 00 3444. 91 3388. 81 -1085 .64 -2124. 67 5956410. 02 375760. 51 0.00 1433 .17 4500 .00 47. 84 242. 00 3512. 03 3455. 93 -1120 .43 -2190. 12 5956376. 30 375694. 51 0.00 1478 .65 4600 .00 47. 84 242. 00 3579. 16 3523. 06 -1155 .23 -2255. 57 5956342. 57 375628. 51 0.00 1524 .13 )` ~' ! ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 11/3/2006 Time: 15:45:37 ' Page: 3 Fieid: Colville River Unit Co-ordinate(NE) Re ferenc e: Well: PIamCD4-215, True North Site: Alpine CD4 Vertical (TVD) Reference: Plan: CD4-215 56.1 Well: Plan;'CD4-215. Sectioa (VS) Reference: Well-(O.OON,O.OOE,189.85Azi) Wellpath: Plan: C D4-21.5 Survey Gaiculation Method: Minimum Curvature Ab: Orade Survey MD 3ncl Azm TVD Sys TVD N/$ E/W MapN MapE 1)LS VS Comm t ft deg deg ft ft ft ft ft ft ` deg/100ft ft 4700 .00 47. 84 242 .00 3646 .29 3590. 19 -1190 .02 -2321 .02 5956308. 85 375562 .52 0.00 1569 .61 4800 .00 47. 84 242 .00 3713 .41 3657. 31 -1224 .81 -2386 .47 5956275. 13 375496 .52 0.00 1615 .09 4900 .00 47. 84 242 .00 3780 .54 3724. 44 -1259 .61 -2451 .91 5956241. 40 375430 .52 0.00 1660 .57 4997 .52 47. 84 242 .00 3846 .00 3789. 90 -1293 .54 -2515 .74 5956208. 52 375366 .16 0.00 1704 .92 K-3 5000 .00 47. 84 242 .00 3847 .67 3791. 57 -1294 .40 -2517 .36 5956207. 68 375364 .52 0.00 1706 .05 5100 .00 47. 84 242 .00 3914 .79 3858. 69 -1329 .19 -2582 .81 5956173. 96 375298 .52 0.00 1751 .53 5200 .00 47. 84 242 .00 3981. 92 3925. 82 -1363 .99 -2648 .26 5956140. 24 375232. 52 0.00 1797 .00 5300 .00 47. 84 242 .00 4049. 05 3992. 95 -1398 .78 -2713 .71 5956106. 51 375166. 52 0.00 1842 .48 5378 .89 47. 84 242 .00 4102 .00 4045. 90 -1426 .23 -2765 .34 5956079. 91 375114. 45 0.00 1878 .36 K-2 5400 .00 47. 84 242 .00 4116 .17 4060. 07 -1433 .57 -2779 .15 5956072. 79 375100 .52 0.00 1887 .96 5500 .00 47. 84 242 .00 4183 .30 4127. 20 -1468 .37 -2844 .60 5956039. 07 375034 .52 0.00 1933 .44 5535 .31 47. 84 242 .00 4207 .00 4150. 90 -1480 .65 -2867 .71 5956027. 16 375011 .22 0.00 1949 .50 K-2 Base 5600 .00 47. 84 242 .00 4250 .42 4194. 32 -1503 .16 -2910 .05 5956005. 34 374968 .52 0.00 1978 .92 5700 .00 47. 84 242 .00 4317 .55 4261. 45 -1537 .95 -2975 .50 5955971. 62 374902 .52 0.00 2024 .40 5800 .00 47. 84 242 .00 4384 .68 4328. 58 -1572 .75 -3040 .95 5955937. 90 374836 .52 0.00 2069 .88 5900 .00 47. 84 242 .00 4451. 80 4395. 70 -1607 .54 -3106 .40 5955904. 18 374770 .52 0.00 2115 .36 6000 .00 47. 84 242 .00 4518. 93 4462. 83 -1642 .33 -3171 .84 5955870. 45 374704. 52 0.00 2160 .83 6100 .00 47. 84 242 .00 4586. 06 4529. 96 -1677 .13 -3237 .29 5955836. 73 374638 .53 0.00 2206 .31 6200 .00 47. 84 242 .00 4653 .18 4597. 08 -1711 .92 -3302 .74 5955803. 01 374572 .53 0.00 2251 .79 6300 .00 47. 84 242 .00 4720 .31 4664. 21 -1746 .71 -3368 .19 5955769. 28 374506 .53 0.00 2297 .27 6400 .00 47. 84 242 .00 4787 .44 4731. 34 -1781 .51 -3433 .64 5955735. 56 374440 .53 0.00 2342 .75 6500 .00 47. 84 242 .00 4854 .56 4798. 46 -1816 .30 -3499 .09 5955701. 84 374374 .53 0.00 2388 .23 6520 .82 47. 84 242 .00 4868 .53 4812. 43 -1823 .54 -3512 .71 5955694. 82 374360 .79 0.00 2397 .69 Build; 3 DLS, 48 6600 .00 47. 78 238 ,80 4921 .72 4865. 62 -1852 .51 -3563 .71 5955666. 68 374309 .33 3.00 2434 .96 6700 .00 47. 84 234 ,75 4988 .89 4932. 79 -1893 .10 -3625 .67 5955627. 11 374246 .73 3.00 2485 .55 6800 .00 48. 05 230 .72 5055. 89 4999. 79 -1938 .04 -3684 .73 5955583. 14 374186. 94 3.00 2539 .94 6900 .00 48. 39 226 .72 5122. 54 5066. 44 -1987 .22 -3740 .75 5955534. 88 374130. 14 3.00 2597 .98 7000 .00 48. 87 222 .78 5188. 64 5132. 54 -2040 .51 -3793 .55 5955482. 46 374076. 48 3.00 2659 .52 7100 .00 49. 48 218 .89 5254 .03 5197. 93 -2097 .75 -3843 .00 5955426. 03 374026. 11 3.00 2724 .37 7200 .00 50. 22 215 .09 5318 .52 5262. 42 -2158 .79 -3888 .97 5955365. 75 373979 .17 3.00 2792 .38 7300 .00 51. 08 211 .37 5381 .93 5325. 83 -2223 .46 -3931 .32 5955301. 78 373935 .77 3.00 2863 .34 7400 .00 52. 06 207 .75 5444 .10 5388. 00 -2291 .59 -3969 .95 5955234. 30 373896 .05 3.00 2937 .07 7500 .00 53. 14 204 .23 5504 .85 5448. 75 -2362 .98 -4004 .73 5955163. 48 373860 .11 3.00 3013 .37 7600 .00 54. 33 200 .81 5564 .01 5507. 91 -2437 .45 -4035 .59 5955089. 53 373828 .05 3.00 3092 .02 7700 .00 55. 61 197 .50 5621 .43 5565. 33 -2514 .79 -4062 .43 5955012. 65 373799 .96 3.00 3172 .81 7800 .00 56. 97 194 .28 5676. 94 5620. 84 -2594 .78 -4085 .19 5954933. 05 373775. 91 3.00 3255 .51 7900 .00 58. 42 191 .17 5730 .39 5674. 29 -2677 .21 -4103 .79 5954850. 94 373755. 97 3.00 3339 .91 8000 .00 59. 93 188 .16 5781 .64 5725. 54 -2761 .85 -4118 .19 5954766. 55 373740 .20 3.00 3425 .76 8100 .00 61. 52 185 .24 5830 .54 5774. 44 -2848 .47 -4128 .35 5954680. 11 373728 .64 3.00 3512 .84 8109 .37 61. 67 184 .97 5835 .00 5778. 90 -2856 .67 -4129 .08 5954671. 92 373727 .77 3.00 3521 .05 Albian 97 8200 .00 63. 16 182 .41 5876 .97 5820. 87 -2936 .83 -4134 .23 5954591. 87 373721 .32 3.00 3600 .91 8300 .00 64. 86 179 .66 5920 .79 5864. 69 -3026 .69 -4135 .84 5954502. 05 373718 .26 3.00 3689 .72 8400 .00 66. 61 176 .98 5961 .89 5905. 79 -3117 .80 -4133 .15 5954410. 92 373719 .46 3.00 3779 .03 8500 .00 68. 41 174 .38 6000 .15 5944. 05 -3209 .92 -4126 .18 5954318. 71 373724 .94 3.00 3868 .59 8600 .00 70. 24 171 .84 6035. 46 5979. 36 -3302 .78 -4114 .95 5954225. 68 373734 .66 3.00 3958 .17 8700 .00 72. 11 169 .36 6067. 74 6011. 64 -3396 .15 -4099 .48 5954132. 08 373748 .61 3.00 4047 .51 8800 .00 74. 00 166 .93 6096. 88 6040. 78 -3489 .75 -4079 .82 5954038. 18 373766 .74 3.00 4136 .37 8900 .00 75. 93 164 .55 6122 .82 6066. 72 -3583 .34 -4056 .03 5953944. 22 373789 .01 3.00 4224 .50 9000 .00 77. 88 162 .21 6145 .48 6089. 38 -3676 .66 -4028 .17 5953850. 48 373815 .35 3.00 4311 .68 9100 .00 79. 85 159 .90 6164 .80 6108. 70 -3769 .44 -3996 .31 5953757. 19 373845 .69 3.00 4397 .64 9200 .00 81. 83 157 .62 6180 .73 6124. 63 -3861 .45 -3960 .54 5953664. 62 373879 .96 3.00 4482 .17 9300 .00 83. 83 155 .36 6193 .21 6137. 11 -3952 .42 -3920 .96 5953573. 03 373918 .05 3.00 4565 .03 ORIGINAL ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhiifips Alaska lnc. Date: 11/3/2006 Time: 15 :4&37 Page: 4 Field: Colville RiverUn it Co-ordinate{NE) Reference: Well: Plan: CD4-215, True Nortlt Site: Alpine CD4 Vertical (TVD) Reference: P lan: CD4-21556.1 Well:. Plan: CD4-215. Section (VS) Reference: - Well ( O.OON,O.OOE,189.85Azi) Wellpath: Plan: GD4-215 Survey Calcalation Method: - Minimum Curvat ure Db: Orade ~ Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DL5 VS Comm t ft deg deg ft ft ft ft ft ft degl100ft ft 9359 .56 85. 02 154 .03 6199. 00 6142. 90 -4006 .01 -3895 .62 5953519. 04 373942 .51 3.00 4613.49 Top Nanuq (Atbi 936II ~72 85. 04 154 .00 199.10 6143. 00 -4007 .04 -3895 .12 5953518. 00 373943. 00 3.00 4614.43 CD4-215wp04 T 9383 .05 84. 37 153 .99 6201 .16 6145. 06 -4027 .02 -3885 .37 5953497. 86 373952 .42 3.00 4632.45 9400 .00 84. 37 153 .99 6202 .82 6146. 72 -4042 .19 -3877 .97 5953482. 58 373959 .57 0.00 4646.12 9500 .00 84. 37 153 .99 6212 .63 6156. 53 -4131 .62 -3834 .32 5953392. 46 374001 .76 0.00 4726.77 9600 .00 84. 37 153 .99 6222 .43 6166. 33 -4221 .06 -3790 .68 5953302. 33 374043 .94 0.00 4807.42 9700 .00 84. 37 153 .99 6232. 24 6176. 14 -4310 .49 -3747 .03 5953212. 21 374086. 13 0.00 4888.06 9800 .00 84. 37 153 .99 6242. 04 6185. 94 -4399 .93 -3703 .38 5953122. 08 374128. 31 0.00 4968.71 9821 .97 84. 37 153 .99 6244. 20 6188. 10 -4419 .58 -3693 .79 5953102. 28 374137. 58 0.00 4986.43 9900 .00 87. 49 154 .05 6249. 73 6193. 63 -4489 .54 -3659 .70 5953031. 78 374170. 53 4.00 5049.53 9962 .68 90. 00 154 .10 6251 .10 6195. 00 -4545 .89 -3632 .31 5952975. 00 374197. 00 4.00 5100.36 CD4-215wp04 T 10000 .00 91. 49 154 .10 6250 .61 6194. 51 -4579 .46 -3616 .01 5952941. 17 374212. 75 4.00 5130.65 10024 .29 92. 46 154 .10 6249 .77 6193. 67 -4601 .30 -3605 .41 5952919. 16 374223 .00 4.00 5150.35 10100 .00 92. 46 154 .10 6246 .52 6190. 42 -4669 .34 -3572 .37 5952850. 60 374254 .92 0.00 5211.74 10200 .00 92. 46 154 .10 6242 .22 6186. 12 -4759 .22 -3528 .74 5952760. 03 374297 .09 0.00 5292.82 10300 .00 92. 46 154 .10 6237. 92 6181. 82 -4849 .09 -3485 .10 5952669. 47 374339 .25 0.00 5373.90 10400 .00 92. 46 154 .10 6233 .62 6177. 52 -4938 .97 -3441 .47 5952578. 90 374381. 42 0.00 5454.99 10500 .00 92. 46 154 .10 6229 .32 6173. 22 -5028 .84 -3397 .83 5952488. 34 374423. 58 0.00 5536.07 10600 .00 92. 46 154 .10 6225 .02 6168. 92 -5118 .72 -3354 .20 5952397. 78 374465. 75 0.00 5617.15 10700 .00 92. 46 154 .10 6220 .72 6164. 62 -5208 .59 -3310 .56 5952307. 21 374507. 92 0.00 5698.24 10800 .00 92. 46 154 .10 6216 .42 6160. 32 -5298 .47 -3266 .93 5952216. 65 374550. 08 0.00 5779.32 10861 .41 90. 00 154 .09 6215 .10 6159. 00 -5353 .69 -3240 .11 5952161. 00 374576 .00 4.01 5829.14 CD4-215wp04 T 10900 .00 88. 46 154 .09 6215 .62 6159. 52 -5388 .40 -3223 .25 5952126. 03 374592 .29 4.00 5860.45 10965 .39 85. 84 154 .09 6218 .87 6162. 77 -5447 .13 -3194 .71 5952066. 84 374619 .87 4.00 5913.44 11000 .00 85. 84 154 .09 6221 .38 6165. 28 -5478 .18 -3179 .63 5952035. 55 374634 .45 0.00 5941.45 11100 .00 85. 84 154 .09 6228 .63 6172. 53 -5567 .89 -3136 .04 5951945. 15 374676. 56 0.00 6022.38 11200 .00 85. 84 154 .09 6235 .89 6179. 79 -5657 .61 -3092 .46 5951854. 76 374718. 68 0.00 6103.31 11300 .00 85. 84 154 .09 6243 .14 6187. 04 -5747 .32 -3048 .88 5951764. 36 374760 .80 0.00 6184.24 11357 .75 85. 84 154 .09 6247 .33 6191. 23 -5799 .12 -3023 .71 5951712. 15 374785 .12 0.00 6230.98 11400 .00 87. 53 154 ,08 6249 .77 6193. 67 -5837 .06 -3005 .28 5951673. 92 374802 .93 4.00 6265.20 11461 .73 90. 00 154 .07 6251 .10 6195 .00 -5892 .56 -2978 .30 5951618. 00 374829 .00 4.00 6315.26 CD4-215wp04 T 11500 .00 91. 53 154 .07 6250 .59 6194 .49 -5926 .98 -2961 .57 5951583. 32 374845 .17 4.00 6346.31 11526 .94 92. 61 154 .07 6249 .62 6193 .52 -5951 .19 -2949 .80 5951558. 92 374856 .55 4.00 6368.15 11600 .00 92. 61 154 .07 6246 .29 6190 .19 -6016 .83 -2917 .88 5951492. 78 374887 .39 0.00 6427.36 11700 .00 92. 61 154 .07 6241 .74 6185 .64 -6106 .67 -2874 .20 5951402. 25 374929 .60 0.00 6508.40 11800 .00 92. 61 154 .07 6237 .19 6181. 09 -6196 .51 -2830 .53 5951311. 71 374971. 81 0.00 6589.44 11900 .00 92. 61 154 .07 6232 .64 6176. 54 -6286 .35 -2786 .85 5951221. 18 375014 .02 0.00 6670.49 12000 .00 92. 61 154 .07 6228 .09 6171. 99 -6376 .19 -2743 .17 5951130. 65 375056 .23 0.00 6751.53 12100 .00 92. 61 154 .07 6223 .53 6167. 43 -6466 .03 -2699 .49 5951040. 12 375098 .44 0.00 6832.57 12200 .00 92. 61 154 .07 6218 .98 6162. 88 -6555 .87 -2655 .81 5950949. 59 375140 .65 0.00 6913.61 12296 .67 92. 61 154 .07 6214 .58 6158 .48 -6642 .72 -2613 .59 5950862. 08 375181 .45 0.00 6991.95 12300 .00 92. 48 154 .07 6214 .44 6158 .34 -6645 .71 -2612 .13 5950859. 06 375182 .86 4.00 6994.66 12361 .88 90. 00 154 .07 6213 .10 6157 .00 -6701 .35 -2585 .08 5950803. 00 375209 .00 4.00 7044.84 CD4-215wp04 T 12400 .00 88. 48 154 .07 6213 .61 6157 .51 -6735 .62 -2568 .41 5950768. 46 375225 .11 4.00 7075.76 12409 .19 88. 11 154 .07 6213 .88 6157 .78 -6743 .89 -2564 .39 5950760. 13 375228 .99 4.00 7083.22 12500 .00 88. 11 154 .07 6216 .88 6160. 78 -6825 .51 -2524 .70 5950677. 88 375267 .35 0.00 7156.84 12600 .00 88. 11 154 .07 6220 .18 6164 .08 -6915 .39 -2480 .99 5950587. 31 375309 .59 0.00 7237.92 12700 .00 88. 11 154 .07 6223 .49 6167 .39 -7005 .27 -2437 .28 5950496. 74 375351 .83 0.00 7318.99 12800 .00 88. 11 154 .07 6226 .79 6170 .69 -7095 .15 -2393 .57 5950406. 17 375394 .07 0.00 7400.07 12900 .00 88. 11 154 .07 6230 .09 6173 .99 -7185 .03 -2349 .87 5950315. 60 375436 .31 0.00 7481.15 13000 .00 88. 11 154 .07 6233 .39 6177 .29 -7274 .91 -2306 .16 5950225. 03 375478 .55 0.00 7562.22 13100 .00 88. 11 154 .07 6236 .70 6180 .60 -7364 .79 -2262 .45 5950134. 45 375520 .79 0.00 7643.30 13200 .00 88. 11 154 .07 6240 .00 6183 .90 -7454 .67 -2218 .74 5950043. 88 375563 .03 0.00 7724.38 96 ORIGIN:4L ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 11/3/2006 Timer 15:45:37 Page:. 5 Field: Colville River Unit Co-ord inate(NE) Reference; Well: Plan: CD4-215, True. North Site: Alpine CD4 ` Vertical (TVD) Reference: Plan: CD4-215 56.1 Well: Plan: CD4-215 Section (VS) Reference: Well (O.OON,O.OOE,189.85Azi) Wellpath: Plan: CD4-215 Survey Calcalation Method: Minimum Curvature Db: Oracle '' Survey MD lncl Azhn 'TVD Sys TVD N/S E/W MapN MapE DLS VS Comm t ft deg deg ft ft ft ft ft ft deg/100ft ft 13300.00 88.11 154.07 6243.30 6187.20 -7544.55 -2175.03 5949953.31 375605.27 0.00 7805.45 13400.00 88.11 154.07 6246.60 6190.50 -7634.44 -2131.32 5949862.74 375647.51 0.00 7886.53 13500.00 88.11 154.07 6249.91 6193.81 -7724.32 -2087.61 5949772.17 375689.75 0.00 7967.61 13512.47 88.11 154.07 6250.32 6194.22 -7735.52 -2082.16 5949760.88 375695.01 0.00 7977.72 13559.79 90.00 154.09 6251.10 6195.00 -7778.07 -2061.48 5949718.00 375715.00 4.00 8016.10 CD4-215wp04 T 13600.00 90.14 154.09 6251.05 6194.95 -7814.24 -2043.91 5949681.55 375731.98 0.36 8048.73 13700.00 90.50 154.09 6250.48 6194.38 -7904.19 -2000.21 5949590.92 375774.21 0.36 8129.87 13800.00 90.86 154.09 6249.29 6193.19 -7994.13 -1956.51 5949500.29 375816.44 0.36 8211.01 13900.00 91.22 154.09 6247.48 6191.38 -8084.06 -1912.82 5949409.67 375858.66 0.36 8292.13 14000.00 91.58 154.09 6245.03 6188.93 -8173.98 -1869.13 5949319.06 375900.88 0.36 8373.25 14100.00 91.94 154.09 6241.97 6185.87 -8263.88 -1825.45 5949228.46 375943.09 0.36 8454.36 14200.00 92.30 154.09 6238.27 6182.17 -8353.77 -1781.78 5949137.89 375985.29 0.36 8535.44 14300.00 92.65 154.09 6233.95 6177.85 -8443.63 -1738.12 5949047.34 376027.48 0.36 8616.51 14400.00 93.01 154.09 6229.01 6172.91 -8533.46 -1694.47 5948956.81 376069.66. 0.36 8697.55 14500.00 93.37 154.09 6223.44 6167.34 -8623.27 -1650.84 5948866.32 376111.83 0.36 8778.57 14600.00 93.73 154.09 6217.24 6161.14 -8713.04 -1607.22 5948775.85 376153.98 0.36 8859.55 14700.00 94.09 154.09 6210.42 6154.32 -8802.78 -1563.63 5948685.43 376196.11 0.36 8940.51 ~ 14759.11 94.30 154.09 6206.10 , 6150.00 -8855.80 -1537.86 5948632.00 376221.00 0.36 8988.34 CD4-215wp04 T Targets Map Map <- Latitude --> <- Longitude --> Name Description TVD +N/-S +E/-VV Northing Easting Deg Min Sec Deg Min .Sec Dip. Dir: ft ft ft ft ft CD4-215wp04 T1 6199.10 -4007.04 -3895.12 5953518.00 373943.00 70 16 52.862 N 151 1 12.120 W -Rectangle (100x100) CD4-215wp04 T7 6206.10 -8855.80 -1537.86 5948632.00 376221.00 70 16 5.183 N 151 0 3.433 W -Rectangle (100x100) CD4-215wp04 T5 6213.10 -6701.35 -2585.08 5950803.00 375209.00 70 16 26.369 N 151 0 33.936 W -Rectangle (100x100) CD4-215wp04 T3 6215.10 -5353.69 -3240.11 5952161.00 374576.00 70 16 39.621 N 151 0 53.025 W -Rectangle (100x100) CD4-215wp04 T2 6251.10 -4545.89 -3632.31 5952975.00 374197.00 70 16 47.564 N 151 1 4.458 W -Rectangle (100x100) CD4-215wp04 T4 6251.10 -5892.56 -2978.30 5951618.00 374829.00 70 16 34.322 N 151 0 45.395 W -Rectangle (100x100) CD4-215wp04 T6 6251.10 -7778.07 -2061.48 5949718.00 375715.00 70 16 15.781 N 151 0 18.683 W -Rectangle (100x100) Annotation MD TVD __ ft ft 300.00 300.00 Kick off; 2 DLS, 300' MD 700.00 698.70 Build; 3 DLS, 700' MD 2042.82 1862.62 Sail; 47.8° for 4478' 2843.37 2400.00 9 5/8" csg pt, 2400' TVD 6520.82 4868.54 Build; 3 DLS, 4868' TVD 9360.72 6199.10 7" csg pt; 9360' MD 6199' TVD 9962.68 6251.10 T2 10861.41 6215.10 T3 11461.73 6251.10 T4 12361.88 6213.10 T5 ORI6INA' ConocoPhillips Alaska, Inc. CPAI Report ~O Z'" Company: ConocoPhillips Alaska Inc. Date: 11/3!2006 Time: 15:45:37 Page: 6 ~ Field: COIvilleRiver Unit Co-ordmate(NE) Reference: Well: Plan: CD4-215, True North Site:. Alpine CD4 Vertical (TVD) Reference: Plans CD4-2i5 56.1 •Well: Plan: CD4-215 Section (VS) Reference: Well (O.OON,O.OOE,189.85Azi) Wellpath: Plan: CD4-215 Survey Calcalation iVIethodr Minimum Curvature Db: Oracle Annotation I1ID TVD ft ft' 13559.79 6251.10 T6 14759.10 6206.10 TD Casing Points MD TVD Diameter Hole Size Name ft ft in in 2843.37 2400.00 9.625 12.250 9 5/8" 9360.72 6499:t$`- 7.000 8.750 7" 14759.11 6206.10 3.500 6.125 31/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft it deg deg 1395.49 1356.00 Base Permafrost 0.00 0.00 2551.39 2204.00 C-40 0.00 0.00 2855.29 2408.00 C-30 0.00 0.00 3406.49 2778.00 C-20 0.00 0.00 4997.52 3846.00 K-3 0.00 0.00 5378.89 4102.00 K-2 0.00 0.00 5535.31 4207.00 K-2 Base 0.00 0.00 8109.37 5835.00 Albian 97 0.00 0.00 9359.56 6199.00 Top Nanuq (Albian 96) 0.00 0.00 ORIGIN^I ConocoPhillips Alaska, Inc. Anticollision Report Company: ConocoPhilfips Alaska lnc. Date: 11/3/2006 Time: 13:33:43 Page: 1 Field: Colville River Unit Reference Site: Alpine CD4 Co-ordiaate(NE) Reference: Well: Pla n: CD4-215, True North Reference Well: Plan; CD4-215 Vertical (TVD) Reference: Plan: CD4-215 56.1 Reference Wellpath: Plan: CD4-215 Db: Orade GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: CD4-215wp04 & NOT PLANNED P Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 36.30 to 14759.11 ft Scan Method: Trav Cylinder No rth Maximum Radius: 1672.28 ft Erro r Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft in in 2843.37 2400.00 9.625 12.250 9 5/8" 9360.72 6199.10 7.000 8.750 7" 14759.11 6206.10 3.500 6.125 31/2" Plan: CD4-21 5wp04 Date Composed: 11 /3/2006 Version : 6 Principal: Yes Tied-to: From Well Ref. Point Summary <--------- Offset Wellpath - a Reference Offset Ctr-Ctr No-Gfl Allowable Site Well Wellpath MD Mb Distance Area Deviation Warning ft ft ft ft' g Alpine CD4 CD4-17 CD4-17 V13 935.24 925.00 35.05 15.79 19.26 Pass: Major Risk Alpine CD4 CD4-208 CD4-208 V7 348.59 350.00 139.46 6.62 132.83 Pass: Major Risk Alpine CD4 CD4-208 CD4-208P61 V6 348.59 350.00 139.46 6.52 132.94 Pass: Major Risk Alpine CD4 CD4-209 CD4-209 V4 371.75 375.00 116.79 7.13 109.66 Pass: Major Risk Alpine CD4 CD4-210 CD4-210 V3 342.42 325.00 100.12 6.36 93.76 Pass: Major Risk Alpine CD4 CD4-318 CD4-318 V6 939.79 925.00 62.15 16.15 46.00 Pass: Major Risk Alpine CD4 CD4-318 CD4-318A V5 938.72 925.00 62.14 16.13 46.00 Pass: Major Risk Alpine CD4 CD4-318 CD4-318P61 V3 939.79 925.00 62.15 16.15 46.00 Pass: Major Risk Alpine CD4 CD4-319 CD4-319 V5 454.76 450.00 83.85 8.42 75.43 Pass: Major Risk Alpine CD4 CD4-320 CD4-320 V7 837.21 825.00 92.70 14.74 77.97 Pass: Major Risk Alpine CD4 CD4-320 CD4-320P61 V4 837.21 825.00 92.70 14.74 77.97 Pass: Major Risk Alpine CD4 Nanuq 3 Nanuq 3 V1 1034.86 950.00 231.65 16.15 215.51 Pass: Major Risk Alpine CD4 Nanuq 5 Nanuq 5 V1 253.39 250.00 61.69 4.57 57.12 Pass: Major Risk Alpine CD4 Nanuq 5 Plan: CD4-212 VO Plan: 253.39 250.00 61.69 4.59 57.10 Pass: Major Risk Alpine CD4 Plan: CD4-16 Plan: CD4-16 V1 Plan: 576.92 575.00 18.40 10.92 7.47 Pass: Major Risk Alpine CD4 Plan: CD4-203 Plan: CD4-203 V1 Plan: 347.06 350.00 240.48 7.15 233.33 Pass: Major Risk Alpine CD4 Plan: CD4-204 Plan: CD4-204 V1 Plan: 324.15 325.00 220.30 6.70 213.60 Pass: Major Risk Alpine CD4 Plan: CD4-205 Plan: CD4-205 V1 Plan: 347.68 350.00 200.47 7.16 193.31 Pass: Major Risk Alpine CD4 Plan: CD4-206 Plan: CD4-206 V4 Plan: 125.97 125.00 180.91 2.59 178.32 Pass: Major Risk Alpine CD4 Plan: CD4-207 Plan: CD4-207 V3 Plan: 347.45 350.00 160.44 7.16 153.28 Pass: Major Risk Alpine CD4 Plan: CD4-211 Plan: CD4-211wp05 VO P 348.44 350.00 80.56 7.28 73.28 Pass: Major Risk Alpine CD4 Plan: CD4-213 Plan: CD4-213 V1 Plan: 448.82 450.00 40.33 7.90 32.43 Pass: Major Risk Alpine CD4 Plan: CD4-222 Plan: CD4-222 V2 Plan: 8836.92 9225.00 157.03 122.99 34.04 Pass: Major Risk Alpine CD4 Plan: CD4-223 Plan: CD4-223 VO Plan: 942.03 925.00 105.48 17.98 87.50 Pass: Major Risk Alpine CD4 Rig: CD4-214 Plan: CD4-214 V2 Plan: 349.65 350.00 20.56 7.29 13.26 Pass: Major Risk Alpine CD4 Rig: CD4-214 Rig: CD4-214 V6 523.54 525.00 18.57 9.20 9.36 Pass: Major Risk Alpine CD4 Rig: CD4-321 Rig: CD4-321 V9 905.55 875.00 122.14 15.47 106.67 Pass: Major Risk Alpine Nanuq EIS Pa~lan: Nanuq 4 Prelim: Nanuq 4 Lat A 56.10 0.00 89.84 No Offset Stations Alpine Nanuq EIS Pa~lan: Nanuq 4 Prelim: Nanuq 4 Lat B 56.10 0.00 89.84 No Offset Stations Alpine Satellites Nanuk 2 Nanuk 2 V1 8406.42 6825.00 562.22 119.75 442.47 Pass: Major Risk )GRAM ORIGINAL +W-S C[X-215 -69.59 +}'-W -27127 WELL DETMS Northvrg Emtirig 5957460.92 377WI2.16 lutinak I.vvgitude 70°17'32.?BIN IAl"57'18 /~fiYW Slot N/A -175 -150 0 17 Ian: CD4-211wp05) 8 0 -207 (Plan: CD4-207) (CD4-210) 4-214 (Rig: CD4-214) 9-214 (Plan: CD4-214) ;11laraG#1-212) 7 rRSSa cm neM a'a smeymi.o i~l n.m.a: co.rls>yoa vs acvao-ss loon.m i:~av:ll n.~e~cJr-xlsdrw va MwatFR-nwcnzsc 0 ig: CD4-214 (Rig: CD4-21 g: CD4-214 (Plan: CD4-21 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [251Uin] -150 175 ANTI-COLLISION SETTINGS COMPANY DETAILS Interpolation MethodMD Interval: 25.00 ConwPlWllps Alaska Bk. t Depth Range From: 36.38 To: 14759.1 I ~gnwermg Maximwn Range: 1(,72.'8 Reference: Plan: CD4-215x~yJ4 0alc Wntiun MethN'. Minimum Curvature Fmrr Svslan: ISC WSA Scan Mphd-. Trnv Cylivder North I~:rror SuAece: Elliprical-Casivg Warning McOad: Rules Base] From Colour To MD 36 250 250 500 500 750 750 1000 1000 1250 1250 8400 8400 8650 8650 8900 8900 __- 9150 9150 11900 38 ' 12150 12400 25000 33 CTX I7 (('D4I7), Major Risk CD4-208 (CD4-206), Major Risk CU4208 (CD4-216PB 1), Major Risk CD0.209 (CU4-209), Major Risk ('U9-210 (CD4-270),M jot Risk CD4-318 (CD4-318), Major Risk C'.D4-718 fCIX318A), Major Risk CD4-318 (CD4378PB7), Major Risk (:IX319101X379), Major Risk ('1X3'-0 (CU4-3?0), Major Risk C'DC3'_0 (CD4-3?OP81k Major Risk Nancy 3 (Nanuq 3), Major Rlsk Nanuq 5 (Nmuq 5), Major Risk Nanuq 5 (Plan: CD4-212), Major Risk Plan:CDilfi (Plan: (.D4-I fi), Mjor Risk Plan CD1203 (Plan- CD4-20J), Major Risk I.CGPMy Plan: CD4->04 (Plan: CM-204), Ma err Risk Plan: CD4-205 (Plan: CIN-205), Mnlor Risk Plan: C'U4-20G (PUn: CD4-206J, A1gNr Risk Plan CU4-207 (Nlao: CD4-207), Major Ruk Plan: CD4-211 (Plan: CD4-211wpf15), Marx Rixk Plnn:CD4273 (Plan: 0D4--?13), Mnlor Risk Plan: (:1X222 (Plan: CD4-2'_2) Malur Risk Plan: (:U422i (Plan: CD4-?211, Major Risk Rig:CD4-214 (PIan:CDL214), Major Risk Rig: (:D4-214 (Rig: CD4-2141. Major Risk Pla i Navuq 4 (RPrelimNanuq ~41e A Major Risk Plan: Nanuq 4 (Bator: Nmuy 4 Lnt B), Major Risk Nenuk 2 Q'(avxk 2), Major Risk INen:CD4-215 CD4-215xp04 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [75ft/in] Sec MD 4c Aa TVD ~N/-S aFJ-W Dleg TFaa VSec Talga 1 36.30 000 D.00 36.30 000 0.00 0.00 0.00 0.00 z 301.11 1.aa 1.11 3ao.a1 0.00 0.00 1.11 1.11 0.00 3 700.00 8.00 260.00 698.70 -0.84 -27.46 2.00 260.00 9.47 4 ?042.82 47.84 24200 186262 -265.5[1 -581.94 3.00 -20.74 361.16 5 6520.82 47.84 2420(1 4868.53 -182354 -3512.71 0.00 0.00 2397.h9 6 97f,(1.72 85.U4 154.00 6199.10 -4007.04 -3895.12 300 -Y2.34 4614.47 CD4-215wp04 TI 7 9383.05 64.37 153.99 6201.16 -4027.02 -3865.37 7.00 -176.82 463245 8 9821,97 8417 153.99 624420 -447958 -3693.79 0.00 0.00 4986.43 9 99fi2.fi8 91.011 154.10 6251.10 -454589 -3fi32.J1 4.00 1.18 5100.36 CD0.215wpf14 T2 IO 700?429 92.4fi 154.10 6249.77 -0601.30 -3605.41 4.00 0.01 515035 11 10799.79 92.4fi 154.10 6216.43 -5296.28 -3267.02 0.00 0.00 5779.15 12 10861.41 9000 159.09 6215.10 -5353.69 -3240.11 400 -179.67 5829.14 CD4215wp04 T7 13 10965.39 85.84 151.09 6218.87 -5447.13 -3194.71 4.00 179.98 591344 14 11357.75 85 84 15409 6247.33 -5799.12 -3023.71 0.00 0.00 62311.98 IS 11461.73 90.00 154.07 631.10 -5892.56 -2978.30 4.00 -0.27 671526 CD4-215x~4T4 I6 I15?fi.94 92.61 154.07 6249.62 -5951.19 -2949.80 4.00 0.00 6368.15 17 12296.67 92.61 154.07 6214.58 -6642.72 -2613.59 0.00 0.00 6991.95 IS 12361.88 90.00 154.07 6213.10 -670735 -2585.08 4.00 -179.89 70M.81 CD4-215wp04 T5 19 12109.19 86.11 151.07 6213.88 -6743.89 -2564.39 1.011 -179.99 7083.22 20 13512.17 88.11 154.07 6250.32 -7735.52 -2082.16 0.00 0.00 7977.72 JI 13559.79 911.00 15409 6251.10 -T/78.07 -2061.48 4.00 0.62 8016.70 CD0.215wp119 T6 22 11759.11 94.30 151.09 6206.10 -8855.80 -1537.86 0.36 0.00 8988.34 CD4215wp04 T7 Rm Na IIS Rig Doyoe l9 R6 O~mm Plm' CD~213 S4.IOfl v.sm„, m;gm o,igm Avple •M-a •C-W From Ml Iro6° 0.00 000 J4.J0 From Colour To MD 36 250 250 500 `^^ 750 1000 1250 8400 8650 8900 9150 11900 12150 12400 25000 Closest in POOL '^"'~ t''~~.J i.i I Closest Approach: Reference Well: CD4-21 5wp04 Plan Offset Well: Nanu k 2 Coords. - Coords. - 3-D ctr- ASP ASP ctr Min. .._. Meas. Incl. TRUE Subsea N(+yS(-) View VS Meas, Incl. TRUE Subsea N(+)/S(•) mew VS Dist. ~.c, Depth Angle Azi. TVD E(+)/IN(- (189.85°) Comments Depth Angle Azi. TVD E(+)/W(- (189.85° Comments POOL Min POOL Min Distance (967.39 ft Distance (967.39 ft in POOL (9360 - in POOL (9360 - 14759 MD) to 14759 MD) to CD4 Nanuk 2 (6140 - 215wp04 Plan (61 967.3 936 85.0 15 6142.42 595351 373944. 4614.81 6325 TVDSS) 706 1.9 272. 6154.30 595442 374272. 3683.95 -6325 TVDss) Closest Approach: Reference Weli: CD4-21 5wp04 Plan Offset Well: Rig: CD4-214 Coords. Coords. - 3-D ctr- ASP ASP ctr Min. to Meas. Incl. TRUE Subsea N(+)/S(-) Vew VS Meas. Incl. TRUE Subsea N(+US(-) View VS Dist. Depth Angle Azi. TVD E(+)/w(- (189.85°) Comments Depth Angle Azi. TVD E(+pNf(- (189.85° Comments POOL Min POOL Min Distance (1388.29 Distance (1388.29 ft) in POOL (9360 - ft) in POOL (9360 - 14759 MD) to Rig: 14759 MD) to CD4 CD4-214 (8361 - 215wp04 Plan (8 1388.2 936 85.0 15 6142.42 595351 373944. 4614.8 8677 MD) 8361 85.2 145. 6130.47 595416 375173. 3751.37 -8677 MD) Closest Approach: Reference Weii: CD4-21 5wp04 Plan Offset Well: Nanuq 3 Coords. Coords. - 3-D ctr- ASP ASP ctr Min. Meas. Incl. TRUE Subsea N(+NS(-) Yew VS Meas. Incl. TRUE Subsea N(+)/S(-) View VS Dlst. Depth Angle Azi. TVD E(+)/yy(_ (189.85°) Comments Depth Angle Azi. TVD E(+)/w(- (189.85° Comments POOL Min POOL Min Distance (3823.99 Distance (3823.99 ft) in POOL (9360 - ft) in POOL (9360 - 14759 MD) to 14759 MD) to CD4 Nanuq 3 (6140 - 215wp04 Pian (61 3823.9 936 85.0 15 6142.42 595351 373944. 4614.8 6325 TVDSS) 754 23.6 272. 6154.6 595733 373657. 922.56 -6325 TVDss) Closest Approach: Reference Well: CD4-21 5wp04 Plan .Offset Well: CD4- 210 Coords. - Coords. - 3-D ctr- ASP ASP cV Min. Meas. Incl. TRUE Subsea N(+uS(-) mew VS Meas. Incl. TRUE Subsea N(+)/S(-) Vew VS Dist. ~ Depth Angle Azi. TVD E(+)/w(_ (189.85°) Comments Depth Angle Azi. TVD E(+)ryy(_ (189.85°) Comments POOL Min POOL Min Distance (3930.23 Distance (3930.23 ft) in POOL (9360 - ft) in POOL (9360 - 14759 MD) to CD4 14759 MD) to CD4 210 (7468 -11710 215wp04 Plan (7 3930.2 936 85.0 15 6142.42 595351 373944. 4614.8 MD) 746 85.0 335. 6196.92 595703 375701. 833.054 -11710 MD) CD4-215wp04 POOLSummary.xls 11/3/2006 3:36 PM ConocoPhilli S PLAN DETAILS p Alaska CD4-215w 04 P Quarter Mile NALLIBURTON (1320 feet) ~~, ,..,.,o,........k.. Version 7 radius plot 11/3/2006 I I (`I~ T (~p~.). V ~~ - CD4-210 CD4-210 00 r' ~ ~~,,, ~o° O J moo = \~ ~~ - - Ri :CD4-214 Ri :CD4-214 ~~__ ~- - ,~ o --- - - Nanu 3 Nanu 3 ~`'~ O ~O ~~~ CD4-215w - Nanuk 2 anuk 2 ~O 00 - . - ~~o 00~ • 00 00 O ~O ~O O~ O • ~ ~ ~, esponsible: Noel , Maxwell 1,.1 p x 13 . W r t 'Jal~~n ~ Com~xlete Casing Prog ram xM Hole Size (in.) Casing Size (in.) Setting Depth (MD) (ft) TVD (SS) (ft) TVD (RKB) (ft) Proposed TOC (ft) Centr ali- zation Comments 42 16 114 114 surface no Insulated conductor 12.25 9.625 2,845 2,400 surface es 8.75 7 9,360 6,198 es TOC-500' and above Nanuq or (K-2 if resent 6.125 3.5 14,760 6,205 Slotted liner Fluids From MD (RKB) (ft) To MD (RKB) (ft) Mud Type Density (PPG) Viscosity (sec/quart) Fluid Loss (CC/30 min) Other Comments 114 2,845 S ud 8.8-9.6 Hi h vis, fresh water/ el 2,845 9,360 LSND 9.6-10.0 Fresh water el/pol mer 9.360 14,760 Flopre 9 Fresh water of mer Flo- ro Final Directional Profile Responsible: Noel Status: Complete From MD (RKB) (ft) To MD (RKB) (ft) Azimuth Max DLS Desired Hole ,Angle Max Hole Angle Comments 114 2,045 3/100 KO at 300' and build to sail an le 48 de 2,045 6,520 Hold an le & azimuth 6,520 9,360 3/100 Directional work to land at heel tar et 9,360 14,760 Horiz hole, hold azi & undulate throe h sands Drillin Issues Issue Detailed Description Mitigation Cuttin s dis oal No ermitted annulus on CD4 Haul to CD1-19A Drillin undulatin horizontal 6 asses throe h sand acka eat 2 de /100 Rota steerable, inc at bit, control drill Sta in in zone, avoid water/ as contacts Achievin turns at to /bottom of undulation Rota steerable, inc at bit, control drill Horizontal hole cleanin Cuttin s removal from undulatin rofile Mana a ECD & flow rates, wi er trips Lost circulation In intermediate drillin & 7" cement'ob Add LCM, wellbore stren then for 7" run. Lost circulation In horizontal Mana a ECD, add LCM. ORI6'11+'~L Coordinate System: X / Y (ASP) Coord. Slot # 15: NAD 83 X - 1517935.87, Y - 5957208.07 Nad 27: X - 377902.43, Y - 5957460.79 Latitude: (Decimal Degrees) Longitude: (Decimal Degrees) Geolo is Tar et s Formation TVD (SS) (ft) MD (ft) X Y Desired Hole Angle Target Boundaries Comments Nanu - 7" casin pint 6,143 1,513,978 5,953,264 rectan ular 100' dee pint#1 6,194 1,514,233 5,952,720 rectan ular100' to pint#2 6,159 1,514,610 5,951,909 rectan ular100' dee pint#2 6,194 1,514,865 5,951,363 rectan ular100' too point #3 6.157 1.515.248 5.950.543 rectangular 100' Geolo Ic Tar et Discussion ~'~ ~_. The planned wellbore will be landed lust below fop Nar~.c afier co"~ r°-i~6on with gamma ray and resisitivity logs. Landing inclination ~n~ili be ro~.g^ y 85 degrees. The ±arget points are designed `or 3 complete undulations ove?~ aoo-eximately 5400 feet of horizontal section. A down to the south fa ~', wi,h '10 ', 5 ~ee^ of Throw ma be crossed ro~gn y ~~~ ~ _o .:^e r.,rizontal >e-.~~~. (97~'v °8C0 ~ 'd' ;cone ercy c~he iineame~' asst. ~ ,~_.. n, tr , s poss b~E `aclt extends ncaheasi Towards CD4 208 wrere c w aJo~- ~~es : , a'ea o` ~~s :ieeamen~ Geolo is Pro nosis Formation Two-Wa Time Uncertaint Gross Net Pa Tem Porosit Perm Comments (SS) (ft) MD (ft) y y Thickness y p y (ft) (ft) (miliseconds) (ft) (ft) (ft) (deg C) (%) (mD) CD4-215 is a horizontal producer in the Nanuq reservoir of the Nanuq Satellite field. The well is to be landed approximately tiSU' west or the rvanult-[ wen and ~ buu west of offset injector CD4-211. CD4-215 will undulate 3 times through lobes 4 and 3. The crest of each undulation will reach near the top of lobe 4, there by increasing the risk of popping out of lobe 4 into mudstones above top Nanuq. Top Nanuq depth along the planned wellbore is expected to be deeper than the estimated GOC at 6133 sstvd. The lowest-most depth of each undulation is 6,195 sstvd which is approximately the top of the transition zone above the OWC at 6207 ssNd. The Nanuq fan is interpreted to contain 4 sheet-lobe sand bodies separated by 3 continuous lobe bounding mudstones. The lobe bounding mudstones are 4-8 feet thick. Based on the Nanuk-2 core, the net sand to gross interval over the total interval is roughly 70 %. Net sand to gross interval is expected to decrease gradually from heel to toe in the horizontal section. A down to the south fault, with 10-15 feet of throw may be crossed roughly 350' into the horizontal section (9700-9800 md). A coherency cube lineament associated with this possible fault extends northeast towards CD4-208, where circulation losses did occur in Pore Pressure Executive Summa Responsible: Walker Status: Complete 1vlormal Pressure Gradient Offset Pore Pressure -Fracture Gradient Profile* Fracture pore Pressure Well Name or Seismic Line TVD (SS) (ft) Gradient (EMw) Measurement Method eMw Nanuq #3, Nanuk #2 RFT's & 0.65 psi/ft frac grad rule of Nanuq #3 &Nanuk #2 K-2 4,050 12.50 8.90 thumb Nanuk 2 Nanua Sand 6.150 10.60 8.60 Nanuk #2 RFT &Nanuq sand datafrac 0'f~?G°~tl AL 11/3/2006 10:50 AM • ~11/312~O:SAHI ~~'~ ~, • • • ~I CIpAi Coordinate Converter - From: - _ _ _ _ _ _ _ _ _ - - -- - T o: _ _ _ _ _ _ _ --- _ Datum: NAD83 Region: alaska i Datum: NAD27 Region: alaska • ---- ~` Lat~udelLongitude Decimal Degrees ' r` LakikudelLongitude Decimal Degrees ~ i <' UTM Zone ~~ I South <' UTM Zone: True ~ South f: Skate Plane Zone: 4 ~ Units: us-ft +: State Plane Zone: 4 ~ Units: us-ft t' Legal Description (NAD27 only) ~~ _ __ __~~ ~~, _-- - _ -- - ___ _ _ ~: 37?902.3562?8194 - Starting Coordinates: - _ ~ X: 1517335.87 ' Y: 5957208.07 ~~ 5957460.92252688 r'[l.~ r,.l ~ nlJ rf~9 l=l~ LIIC~itIi l~I I'~Jdij`i~i fi5 I'~Idij~' G CPAs Coordinate Converter r From. -------___ _ _------------ --------- -To:----------_ _._ _--- ---- --------__ ' Datum: NA.D27 . Region: alaska Datum: NAD27 Region: alaska + i _ -__ _- I i LatitudelLongitude Decirnal Degrees . ', t` LakitudelLongitude Decimal Degrees ~ , ~'- UTM Zone: ~~ j" South ', t' UTM Zane: True r South State Plane Zone: 4 Units: us-ft . ' {"' State Plane Zane: 4 . Urnks: us-ft . l' ' i ; - _ !~ Legal Description (NAD27 only) -Starting Coordinates - -- - - - ----- _ Legal Description _ '' X: 377902.36 Township: 011 N . Range: 004 E ', Y: 5957460.92 Meridian: U 9ectian:24 ___ - _ -___ _ _ --_ _ FNL 2552.1716 FEL + 341.37456 ' __ _ __ CD4-215 Surface Location • • ~L CPt~I Coordinate Converter -` _ .. rom: _ _ _ - _ - - - _ _ , o: - Datum: NAD27 Region: alaska Datum: NAD27 Region: alaska t' LatitudelLongitude Decimal Degrees . ! ~` LatikudelLongitude Decimal Degrees . ~ I ' f UTM Zone: ~~~~ (`" South r"' UTM Zone: True ~ South ~' ,,, C` State Plane Zone: q ~ Unks: us-ft <` State Plane Zone: 4 ~ Units: us-fk t" - ~~ <•' Legal Description (NAD27 only) StartingCoordinakes: -- - - - -- _-_. __ - _-_---___- -Legal Description - -- __-----___ .---_--__---, X: 373943.00 Township: 011 N Range: 004 E j Y: 5953513.00 Meridian: U ~ Sectian:25 ' _---- FNL 1680.2207 FEL 4236.6797 CD4-215wpOd 7" Casing Point sr=; fx.~s. ~; ~ Cf"'JU Caordinrete Converter ~, .^ rom - ---- - o: -- ', ', Datum: NAD27 Region: alaska ', Datum: NP,D27 Region: alaska ~ ~' ~' LatikudelLongitude Decimal Degrees ~" LatitudelLongitudeDecimal Degrees ~~ C' UTM Zone: ~~ ~ South ', t" UTM Zone: True lY South ~+' State Plane Zone: 4 ~ Units: us-tt ~' State Plane Zone: 4 ~ Units: us-ft . C ~ r Legal Description (NAD27 only] -Starting Coordinates: - _ --- ------- ---- ___ _ , Legal Description ----- - -___- -- -____-- . -----.---._ - X: 376221 Township: 011 N . Range: 004 E - Y: 5948632 I Meridian: ~~ ~ Section: 36 FNL 1248.1407 FEL 1879.6550 CD4-21~wp Toe nnrr~nlll~ • SHARON K. ALLSUP-DRAKE CONOCOPHILLIPS ATO 1530 700 G ST. ANCHORAGE AK 99501 1162 DATE v ~ 56441 ~'~ PAY TO THE C~~ ~[~.~ ,; ORDER OF / `i ~ / 1 L~fSflC- (~C~~ ~~ $ ~f~7 r~~ ~1 =~~ U4GL `/S Lt"` ~~ ~~L~ ~JQtCvAVRS (/LJ ~.~,,.«,,., JPMorganChase ~ j Valid Up To 5000 Dollars JPMorgan Chase Bank, N.A. Columbus, OH ~~, MEMO C~_-~+" ` ~-1 / --- ~~-Y -- ` --- _?-~~_-_ ~:0~,41~55L~~:528747L90792711'1162 • ~ ~~~5~~~~A~ L~~~~~ ~~~~~~,,~~~' w-ELL ~AdIE G'~GC ~ yt z/~ '~®evelopment Ser~~ise E~ploratory~ Stratigraphic Zest _ dron-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CI-IECK i .aDD-ONS ! TEXT FOR APPROVAL LETTER ~~ WHr1T (OPTIONS) APPLIES vtL'LTI LATERAL ~ The permit is for a new weHbore segment of existing I well ~~ (If fast two digits in 'Permit No. . API No_ ~0- ~~ API number are ~ - - between 60-69) ,Production should continue to be reported as a function of the original API number stated above. PLOT HOLE In accordance with 20 A.~C 25.00~(f), all records, data and Logs acquired for the pilot hole must be clearly differentiated in both ~.vell name ( PH) and API number I (~0- - -_~ from records, data and fogs 'acquired for well i SPACING 'The permit is approved subject to full compliance with 20 AAC j EXCEPTION I ?~.0». Approval to perforate and produce ,' iJect is contingent i upon issuance of a conservation order approving a spacing exception. assumes the [iabi[ity of any protest to the spacing exception that may occur. ~~ DRY DITCH 'All dry ditch sample sets submitted to the Commission must be in SAMPLE j no greater than 30' sample intervals from below the permafrost or i from where samples are first caught and 10' sample intervals through target zones. '' 'Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowedi Well ;for (name of well) until after (Company Name} has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ~Companv Name) must contact the !' Commission to obtain advance approval of such water well testing _ ! proffram. R~v: 1; 25:06 C-'~jody`transmitta( checklist • • C,! ^ y , m 0 a ; i N C] Q N ~ ~ ~ ~, ~ ~ C O ~ ~~ ,,,,, N~ ' 'G ~ ~ ~ p y '~ O, N l ~ ~ ~ d. ~ ~~ ~ ' ~ . ~ ~ ~ ~ T . ~ ~ ~ O' ` E' ~ 01 ~ ~ ~ ~ ~ ~ ~~ ~~ C• ~ ~~ N• y = ~ ~ N ; Z o; •3; ~ a; ~ a ~ ~, ' E. ~ O tl ~ °' E C O l' ~ ~ G U O, o a .° O. a N' ~~ M a °' O. y ~, ~ Q M m rn ~ ~ ~ T ~ a~ y. ~ a~ ~ ~ ~ ~ ~ o $ ~, , y: $ o y ~ ~ ~ ~, ca: ~ o ~ , a `, ~ y. o y m 3. a: Q, ~ ~ ~ 3. O ~ . N ~ ~ ~ ~ ~ N' ~ O: U' N ~ ~ .. ~~ c c 3~ ~ ~ ~ ~ ~ ~ ~ Q, L S ~ ~~ N _ ~ p. 0.. ~ ~ ~ a a, ~ N. ~ c , m m. v°; ~ O c>a ~ O ~ y. ~ ~ ~ . n n ~ U ~ O; c ~ .v ~ v4i m ~ ~ ~ 4 ~~ a- i, ~ 4 ~ 3 c~ n ar m, o c o S fl ~, y' ~ ~ . o N Y' ~ Z : ~ : ~ U ~ ~ , (6 .O w, Z Z O. , L ~ 'C, y C. C. 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' ar ii U f0' ~ - a -a a v. c, a u a m ca' .Q, .a. a a. r. o i U c 1 y, •y. a~ m. > a a o .m ~ y s. ~ 3~ a~ y. o ~n •c ~. , I ! ~ .Q, c. o, ~ c ~ y, ~~ ~, ~~ ~~ ;~ , ~~ O, L: c, c~ o E N~ ~ , . 3 ' ~ m, ~ o ~ m U ~ v -, - ' a' o: m, c; ~ ~ c, d~ . o~ o o m~ c r. ~ Z ~: ~ g: ~ ~ ~ ~ ~ o o ~ ° ° i: ~ o c ~ v' u , ~' ' c, o. ' ' v, ~' ' ' o, o, ' ' ~' m ' ~' ~ ~' v, m a a E uS, ~_: . , a> c i 3 ~, ~ . , ~ a, ~, O U ai ~, _° - - 'o: •~ ~, ~, a ° a~, a o 3 ~ c > > 3 ~? ~ ~ ~ a~ ~ w. w 0 y ~° ~ , a °- ~ o ~ m m c ~i Y ~ ~, a aoi •~ °~ °~ °~ ~, 0 4 ~ ~ ~;~' ~;~n ~;o 4 a~, ~ ~ ;n O o ;U ~ : ~ o ¢;a;z'i ~' o _ U ~ ~ g; U U U ~ a U ~ ~ 'v' _ ~-~o ~: ~ t, U m ~ a i ~; ~;~;( ~ a;~~ , . , ;i i ; . V~ m o U , , , , , , , . . ~ ,~, ~ ~ , :Q' ; -~Q~ . m~ : ~ n w a O r N M V to CO I~ W O O r N M V' ~ CO 1`~ t0 _ O O ' ~ M M M M O r __. _. N M [t LO CO I~ O O __-_ r r r r _______________ r r r r _.____ r r N N N N N N N N N N M M M M M M U ._ ..__ ___ _ ~ U m ° co ° ` i ' co ° .. c C G o r+ N y ~ o ~ o y N a~ U C ~ N ~ ~ N ~' ~ N O ~ d to ~:. ~ ~ ~ C ~ O' -1 O N y ' d d r >. O1 U' E ~ C p _ W o p U Q a W a ~ a ~ ~ Well History File APPENDIX Information of detailed nature that is not particularly germane io the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify minding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Mar 30 11:55:36 2007 Reel Header Service name .............LISTPE Date .....................07/03/30 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................07/03/30 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Colville River Nanuq MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 W-0004788290 D. RICHARDSO L. HILL SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD • Scientific Technical Services Scientific Technical Services CD4-215 501032053900 ConocoPhillips Alaska Inc Sperry Drilling Services 30-MAR-07 MWD RUN 3 W-0004788290 ERIC QUAM DAVE BURLEY 24 11N 4E 2952 341 56.55 19.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 2854.0 2ND. STRING 6.125 7.000 9514.0 3RD STRING PRODUCTION STRING # /~l ~~ I REMARKS: 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. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2,3 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 1-3 REPRESENT WELL CD4-215 WITH API#: 50-103-20539-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14761'MD/6205'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). File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number. .........1.0.0 Date of Generation.......07/03/30 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2830.0 14703.5 RPD 2840.0 14710.5 FET 2840.0 14710.5 RPS 2840.0 14710.5 RPM 2840.0 14710.5 RPX 2840.0 14710.5 ROP 2864.5 14761.0 • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2830.0 9524.0 MWD 3 9524.0 14761.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 .Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 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 HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 2830 14761 8795.5 23863 RPD MWD OHMM 0.77 2000 18.1888 23742 RPM MWD OHMM 0.3 2000 15.1446 23742 RPS MWD OHMM 0.24 2000 12.1743 23742 RPX MWD OHMM 0.13 1599.79 10.2963 23742 FET MWD HOUR 0.14 129.75 1.21905 23742 GR MWD API 45.36 181.07 101.177 23748 ROP MWD FT/H 3.47 406.92 124.042 23794 First Reading 2830 2840 2840 2840 2840 2840 2830 2864.5 Last Reading 14761 14710.5 14710.5 14710.5 14710.5 14710.5 14703.5 14761 First Reading For Entire File..........2830 Last Reading For Entire File...........14761 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/30 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.......07/03/30 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2830.0 9489.5 FET 2840.0 9482.0 RPX 2840.0 9482.0 RPS 2840.0 9482.0 RPM 2840.0 9482.0 RPD 2840.0 9482.0 ROP 2864.5 9524.0 LOG HEADER DATA DATE LOGGED: 13-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9524.0 TOP LOG INTERVAL (FT) 2864.0 BOTTOM LOG INTERVAL (FT) 9524.0. BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 42.5 MAXIMUM ANGLE: 84.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA .RAY 97054 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 8.750 2854.0 Polymer 9.70 37.0 9.8 300 1.0 2.500 70.0 1.260 145.0 1.620 70.0 3.000 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2830 9524 6177 13389 2830 9524 RPD MWD020 OHMM 0.77 2000 8.8849 13285 2840 9482 RPM MWD020 OHMM 0.7 1743.45 6.76911 13285 2840 9482 RPS MWD020 OHMM 0.86 1703.34 6.34617 13285 2840 9482 RPX MWD020 OHMM 0.83 1040.58 6.20806 13285 2840 9482 FET MWD020 HOUR 0.14 129.75 0.930866 13285 2840 9482 GR MWD020 API 50.67 181.07 106.111 13320 2830 9489.5 ROP MWD020 FT/H 4.92 406.92 154.446 13320 2864.5 9524 First Reading For Entire File..........2830 Last Reading For Entire File...........9524 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/30 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 9482.5 14710.5 RPD 9482.5 14710.5 RPM 9482.5 14710.5 FET 9482.5 14710.5 RPS 9482.5 14710.5 GR 9490.0 14703.5 ROP 9524.5 14761.0 LOG HEADER DATA DATE LOGGED: 20-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 14761.0 TOP LOG INTERVAL (FT) 9524.0 BOTTOM LOG INTERVAL (FT) 14761.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 80.1 MAXIMUM ANGLE: 96.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 9514.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.40 MUD VISCOSITY (S) 40.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 33000 FLUID LOSS (C3) 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .180 72.0 MUD AT MAX CIRCULATING TERMPERATURE: .090 143.6 MUD FILTRATE AT MT: .160 72.0 MUD CAKE AT MT: .120 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 MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9482.5 14761 12121.8 10558 9482.5 14761 RPD MWD030 OHMM 6.99 2000 30.0088 10457 9482.5 14710.5 RPM MWD030 OHMM 0.3 2000 25.7852 10457 9482.5 14710.5 RPS MWD030 OHMM 0.24 2000 19.5785 10457 9482.5 14710.5 RPX MWD030 OHMM 0.13 15 99.79 15.4901 10457 9482.5 14710.5 FET MWD030 HOUR 0.36 62.3 1.58516 104.57 9482.5 14710.5 GR MWD030 API 45.36 1 48.51 94.8754 10428 9490 14703.5 ROP MWD030 FT/H 3.47 188 85.377 10474 9524.5 14761 First Reading For Entire File..........9482.5 Last Reading For Entire File...........14761 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/03/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/03/30 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 .....................07/03/30 • • Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
