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207-004
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Corrective Action 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 17338'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary 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: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17280'8072' 4-1/2"x 3-1/2" 6860' Packer: Baker Premier Packer SSSV: Camco TRMAXX-5E SSSV Perforation Depth MD (ft): L-80 9330' 2583' 9364' Perf Pups: 9542-17145' 2023 Perfs: 11500-11520', 14000-14040' 4-1/2" Perf Pups: 6926-6856' 2023 Perfs:6882-6883', 6904- 6905' Perforation Depth TVD (ft): 114' 2619' 16" 9-5/8" 74' 7" 9230' MD MD 114' 2474' 6910' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Fiord Nechelik Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL372105, ADL384215, ADL264471 207-004 P.O. Box 100360, Anchorage, AK 99510 50-103-20541-00-00 Colville River Field Fiord Nechelik Oil Pool AOGCC USE ONLY Victoria Loepp 3/26/2024 Tubing Grade: Tubing MD (ft): 8561' MD and 6677' TVD 2064' MD and 2023' TVD Kate Dodson Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: kate.dodson@conocophillips.com (907) 265-6181 Senior Well Intervention Engineer CRU CD3-113 6858' 8602' 6695' 8602' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 3/27/2024 By Grace Christianson at 8:18 am, Mar 27, 2024 Digitally signed by Kate Dodson DN: OU=Wells, O=ConocoPhillips, CN=Kate Dodson, E=kate.dodson@ conocophillips.com Reason: I am the author of this document Location: Date: 2024.03.27 06:40:16-08'00' Foxit PDF Editor Version: 13.0.0 Kate Dodson 324-182 X 10-404 Alpine Oil Pool 364471 VTL 4/11/2024 A.Dewhurst 28MAR24 Alpine Oil Pool -A.Dewhurst 28MAR24 DSR-4/12/24JLC 4/12/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.04.12 14:29:23 -08'00' RBDMS JSB 041624 Review of well work that caused IA to increase above 45% burst rating: Initial Tubing Pressure = 2200 psi Initial IA Pressure = 1450 psi Slickline ran in hole with a Cat Standing Vave (CSV) to set in the XN Nipple at 8606’ RKB. As they passed the packer at 8561’ RKB, Little Red Services (LRS) started pumping crude. The CSV was set in the XN Nipple and pressured up the tubing to 500 psi over Shut-in tubing pressure (2700 psi). CSV was confirmed to be holding. When pulling the OV at 8450’ RKB, The IA pressure increased from 1450 psi to 3400 psi. To manage the pressure increase, the well was fluid packed the well. Lastly, a new OV was set in station #3. Final Tubing Pressure = 2900 psi Final IA Pressure = 1900 psi Plan Forward: Coil: 1. Remove ice plug in tubing as necessary, cleanout down to plug, ensure tubing & IA are clear. Slickline: 2. Pressure test tubing to 2500psi. a. if passes proceed with GLD. b. If fails, troubleshoot leak path. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTMD 16,065.0 CD3-113 1/28/2021 claytg Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled WRDP, Set CSV, c/o OV CD3-113 3/25/2024 rmoore22 Notes: General & Safety Annotation End Date Last Mod By NOTE: Original wellbore drilled in 2007 suspended, re-entered March, 2008; NO Sidetrack 'A' 3/23/2008 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 40.0 114.0 114.0 62.50 H-40 Welded SURFACE 9 5/8 8.83 36.3 2,619.3 2,474.3 40.00 L-80 BTCM INTERMEDIATE 7 6.28 33.7 9,364.0 6,910.2 26.00 L-80 BTCM LINER 4 1/2 3.96 9,208.0 17,280.0 6,859.6 12.60 L-80 IBTM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.2 Set Depth … 9,230.4 Set Depth … 6,892.0 String Max No… 3 1/2 Tubing Description TUBING 4.5"x3.5" @132.6' Wt (lb/ft) 9.30 Grade L-80 Top Connection EUEM ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.2 31.2 0.00 HANGER 11.000 FMC 4 1/2" Tbg hanger w/ 2.28' pup FMC 3.980 132.6 132.6 0.39 XO-Reducing 4.500 XO - 3 1/2" EUE (P) X 4 1/2" IBTM (B) 5.1875" OD x 3" ID 3.000 2,064.1 2,023.0 28.37 SAFETY VLV 5.170 Camco 3.5" TRMAXX-5E SSSV (LOCKED OUT 4/27/2010) 2.812 3,891.9 3,387.9 43.48 GAS LIFT 5.390 Camco 3 1/2" KBMG GLM 5.390" OD x 2.920" ID CAMCO KBMG 2.920 6,963.4 5,617.8 44.10 GAS LIFT 5.390 Camco 3 1/2" KBMG GLM 5.390" OD x 2.920" ID CAMCO KBMG 2.920 8,450.8 6,623.1 59.29 GAS LIFT 5.390 Camco 3 1/2" KBMG GLM 5.390" OD x 2.920" ID CAMCO KBMG 2.920 8,499.2 6,647.4 60.67 X NIPPLE 4.250 HES "X" Nipple 2.813" ID HES 2.813 8,541.8 6,667.7 62.16 GAUGE 5.690 Baker Gauge Carrier 2.992 8,561.3 6,676.7 62.86 PACKER 5.980 3.5" X 7" Baker Premier PACKER BAKER 2.875 8,606.3 6,696.7 64.47 XN NIPPLE 4.250 HES "XN" NIPPLE 2.813" Polish Bore w/ 2.75" No Go HES 2.750 9,229.4 6,891.8 79.69 WLEG 4.120 FMC 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,602.5 6,695.1 64.34 PLUG 2.81" XN CAT STANDING VALVE . OAL=46" 3/24/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,891.9 3,387.9 43.48 1 GAS LIFT DMY BK 1 2/12/2019 6,963.4 5,617.8 44.10 2 GAS LIFT GLV BK 1 1,970.0 2/11/2019 0.188 8,450.8 6,623.1 59.29 3 GAS LIFT OV BK 1 3/24/2024 Camco BKO-3 0.250 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,208.0 6,887.8 78.90 SLEEVE 5.000 Baker 5" x 7" HR Liner Setting Sleeve 4.420 9,220.9 6,890.3 79.37 NIPPLE 5.000 RS Nipple 4.250 9,234.4 6,892.7 79.87 XO Bushing 5.000 XO Bushing 3.940 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,542.0 9,547.0 6,926.1 6,926.5 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 9,807.0 9,812.0 6,933.8 6,933.7 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 10,073.0 10,078.0 6,925.5 6,925.3 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 10,338.0 10,343.0 6,917.5 6,917.3 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 10,604.0 10,609.0 6,909.1 6,908.9 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 10,871.0 10,875.0 6,916.1 6,916.2 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 11,136.0 11,141.0 6,910.9 6,910.8 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 11,400.0 11,404.0 6,906.2 6,906.1 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 11,500.0 11,520.0 6,905.2 6,905.0 227NCH, CD3- 113 2/15/2023 6.0 APERF 20' of holes, 6 SPF, 60 deg - PJ Omega HMX Guns 11,500.0 11,520.0 6,905.2 6,905.0 227NCH, CD3- 113 2/14/2023 6.0 PERFP 6 SPF WITH 60 DEG. PHASE 11,663.0 11,668.0 6,902.5 6,902.6 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup CD3-113, 3/26/2024 3:26:44 PM Vertical schematic (actual) LINER; 9,208.0-17,280.0 PERFP; 17,140.0-17,145.0 PERFP; 16,921.0-16,925.0 PERFP; 16,655.0-16,660.0 PERFP; 16,395.0-16,400.0 PERFP; 16,131.0-16,136.0 PERFP; 15,870.0-15,875.0 APERF; 15,630.0-15,650.0 PERFP; 15,607.0-15,612.0 PERFP; 15,342.0-15,347.0 PERFP; 15,078.0-15,082.0 PERFP; 14,818.0-14,823.0 PERFP; 14,552.0-14,557.0 APERF; 14,500.0-14,520.0 PERFP; 14,290.0-14,295.0 PERFP; 14,034.0-14,039.0 APERF; 14,020.0-14,040.0 RPERF; 14,020.0-14,040.0 APERF; 14,000.0-14,020.0 PERFP; 14,000.0-14,020.0 PERFP; 13,768.0-13,773.0 PERFP; 13,503.0-13,507.0 PERFP; 13,245.0-13,250.0 PERFP; 12,986.0-12,991.0 PERFP; 12,723.0-12,728.0 PERFP; 12,458.0-12,463.0 PERFP; 12,193.0-12,198.0 APERF; 12,000.0-12,020.0 PERFP; 11,928.0-11,933.0 PERFP; 11,663.0-11,668.0 PERFP; 11,500.0-11,520.0 APERF; 11,500.0-11,520.0 PERFP; 11,400.0-11,404.0 PERFP; 11,136.0-11,141.0 PERFP; 10,871.0-10,875.0 PERFP; 10,604.0-10,609.0 PERFP; 10,338.0-10,343.0 PERFP; 10,073.0-10,078.0 PERFP; 9,807.0-9,812.0 PERFP; 9,542.0-9,547.0 INTERMEDIATE; 33.7-9,364.0 PLUG; 8,602.5 PACKER; 8,561.3 GAS LIFT; 8,450.8 GAS LIFT; 6,963.4 GAS LIFT; 3,891.9 SURFACE; 36.3-2,619.3 SAFETY VLV; 2,064.1 CONDUCTOR; 40.0-114.0 WNS PROD KB-Grd (ft) 42.61 RR Date 2/4/2007 Other Elev… CD3-113 ... TD Act Btm (ftKB) 17,338.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032054100 Wellbore Status PROD Max Angle & MD Incl (°) 93.60 MD (ftKB) 17,018.27 WELLNAME WELLBORECD3-113 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: LOCKED OUT Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,928.0 11,933.0 6,906.8 6,906.8 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 12,000.0 12,020.0 6,906.6 6,906.5 227NCH, CD3- 113 1/29/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX guns 12,193.0 12,198.0 6,905.1 6,905.2 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 12,458.0 12,463.0 6,905.0 6,905.0 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 12,723.0 12,728.0 6,904.5 6,904.6 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 12,986.0 12,991.0 6,911.9 6,911.9 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 13,245.0 13,250.0 6,905.7 6,905.5 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 13,503.0 13,507.0 6,895.4 6,895.1 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 13,768.0 13,773.0 6,884.1 6,884.1 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 14,000.0 14,020.0 6,883.1 6,883.0 227NCH, CD3- 113 2/14/2023 6.0 PERFP 6 SPF WITH 60 DEG. PHASE 14,000.0 14,020.0 6,883.1 6,883.0 227NCH, CD3- 113 2/14/2023 6.0 APERF 20' of holes, 6 SPF, 60 deg - PJ Omega HMX guns 14,020.0 14,040.0 6,883.0 6,882.8 227NCH, CD3- 113 2/15/2023 6.0 RPERF 6 SPF WITH 60 DEG. PHASE 14,020.0 14,040.0 6,883.0 6,882.8 227NCH, CD3- 113 2/14/2023 6.0 APERF 20' of holes, 6 SPF, 60 deg - PJ Omega HMX guns 14,034.0 14,039.0 6,882.9 6,882.8 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 14,290.0 14,295.0 6,877.7 6,877.7 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 14,500.0 14,520.0 6,877.4 6,877.4 227NCH, CD3- 113 1/29/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX guns 14,552.0 14,557.0 6,877.5 6,877.5 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 14,818.0 14,823.0 6,877.6 6,877.6 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,078.0 15,082.0 6,875.8 6,875.8 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,342.0 15,347.0 6,875.0 6,875.1 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,607.0 15,612.0 6,879.1 6,879.2 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,630.0 15,650.0 6,879.5 6,879.8 KUPD, CD3-113 1/29/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX guns 15,870.0 15,875.0 6,881.4 6,881.4 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 16,131.0 16,136.0 6,882.6 6,882.6 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 16,395.0 16,400.0 6,884.7 6,884.7 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 16,655.0 16,660.0 6,883.5 6,883.4 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 16,921.0 16,925.0 6,878.1 6,877.9 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 17,140.0 17,145.0 6,866.2 6,865.9 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup CD3-113, 3/26/2024 3:26:45 PM Vertical schematic (actual) LINER; 9,208.0-17,280.0 PERFP; 17,140.0-17,145.0 PERFP; 16,921.0-16,925.0 PERFP; 16,655.0-16,660.0 PERFP; 16,395.0-16,400.0 PERFP; 16,131.0-16,136.0 PERFP; 15,870.0-15,875.0 APERF; 15,630.0-15,650.0 PERFP; 15,607.0-15,612.0 PERFP; 15,342.0-15,347.0 PERFP; 15,078.0-15,082.0 PERFP; 14,818.0-14,823.0 PERFP; 14,552.0-14,557.0 APERF; 14,500.0-14,520.0 PERFP; 14,290.0-14,295.0 PERFP; 14,034.0-14,039.0 APERF; 14,020.0-14,040.0 RPERF; 14,020.0-14,040.0 APERF; 14,000.0-14,020.0 PERFP; 14,000.0-14,020.0 PERFP; 13,768.0-13,773.0 PERFP; 13,503.0-13,507.0 PERFP; 13,245.0-13,250.0 PERFP; 12,986.0-12,991.0 PERFP; 12,723.0-12,728.0 PERFP; 12,458.0-12,463.0 PERFP; 12,193.0-12,198.0 APERF; 12,000.0-12,020.0 PERFP; 11,928.0-11,933.0 PERFP; 11,663.0-11,668.0 PERFP; 11,500.0-11,520.0 APERF; 11,500.0-11,520.0 PERFP; 11,400.0-11,404.0 PERFP; 11,136.0-11,141.0 PERFP; 10,871.0-10,875.0 PERFP; 10,604.0-10,609.0 PERFP; 10,338.0-10,343.0 PERFP; 10,073.0-10,078.0 PERFP; 9,807.0-9,812.0 PERFP; 9,542.0-9,547.0 INTERMEDIATE; 33.7-9,364.0 PLUG; 8,602.5 PACKER; 8,561.3 GAS LIFT; 8,450.8 GAS LIFT; 6,963.4 GAS LIFT; 3,891.9 SURFACE; 36.3-2,619.3 SAFETY VLV; 2,064.1 CONDUCTOR; 40.0-114.0 WNS PROD CD3-113 ... WELLNAME WELLBORECD3-113 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Corrective action Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 17338'feet 8602'feet true vertical 6858' feet None feet Effective Depth measured 8602'feet 8561'feet true vertical 6695' feet 6677' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" x 3-1/2" L-80 9230' MD 6892' TVD Packers and SSSV (type, measured and true vertical depth) 8561' MD 2064' MD 6677' TVD 2023' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 324-182 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker Premier Packer SSSV: Cam;co TRMAXX-5E SSSV Kate Dodson kate.dodson@conocophillips.com (907) 265-6181Well Integrity Specialist Perf Pups: 9542-17145', 2023 Perfs: 11500-11520', 14000-14040' Perf Pups: 6926-6856', 2023 Perfs: 6882-6883', 6904-6905' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 866 Gas-Mcf MD ~ Size 114' 1914 14408159 Well was Shut-In ~~ 1016 measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 207-004 50-103-20541-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL372105, ADL384215, ADL364471 Colville River Unit / Alpine Oil Pool CRU CD3-113 Plugs Junk measured Length Production Liner 9330' 8072' Casing 6910' 4-1/2" 9364' 17280' 6860' 2583' 114'Conductor Surface Intermediate 16" 9-5/8" 74' 2619' 2474' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:52 pm, May 01, 2024 Digitally signed by Kate DodsonDN: OU=Wells, O=ConocoPhillips, CN=Kate Dodson, E=kate.dodson@conocophillips.comReason: I am the author of this document Location: Date: 2024.05.01 11:43:44-08'00' Foxit PDF Editor Version: 13.0.0 Kate Dodson RBDMS JSB 051324 DSR-5/1/24 DTTMSTART JOBTYP SUMMARYOPS 3/30/2024 OPTIMIZE WELL DRIFT TBG W/ 2.75" DJN PUMPING HOT DIESEL DOWN CT & TAG CSV @ 8588' CTMD. POOH - IN PROGRESS. 3/31/2024 OPTIMIZE WELL RAN IN HOLE TO PULL CSV & STARTED FALLING IN HOLE SLOW @ 1000', ATTEMPT TO ESTABLISH CIRCULATION (UNABLE TO CIRCULATE), PUH DETAINED @ 529'. DECIDE TO DUMP WELLHEAD TO TIGER TANK, GET PIPE TO MOVE, ESTABLISH CIRCULATION, AND CIRCULATE OUR WAY TO SURFACE. PULLED CSV @ 8602' RKB. SET RBP @ ME 8596'. MIT TO 2665 PSI (HELD FOR 15 MIN ENDING PSI 2650 PSI / GOOD TEST). WELL IS READY FOR SLICKLINE. 4/7/2024 OPTIMIZE WELL DRIFT W/ 2.79" GAUGE RING TO RBP @ 8593' RKB. SET CATCHER @ SAME. PULL AND SET GLV ( TRO 1741# 3/16 PORTS) @ 6963' RKB. PULLED ST#1 DMY @ 3892' RKB. UNABLE TO LOC OR SD W/ GLV. LDFN. JOB IN PROGRESS. 4/8/2024 OPTIMIZE WELL SET GLV IN ST#1 @ 3891' RKB. ( TRO-1688 3/16" PORTS) TBG @ 1100 DDIA FROM 1450# TO 1100# WATCHED FOR 15 MINS NO PRESSURE CHANGE. PULLED CATCHER @ 8585' RKB. LDFN. JOB IN PROGRESS 4/14/2024 OPTIMIZE WELL PULLED RBP @ 8575' RKB. ATTEMPT 2 TIMES TO SET 3.5" SSSV WRDP-1 IN SVLN @ 2064' RKB. UNABLE TO EST C/L INTEGRITY. CONFER W/ COMP REP. SET 3.5" ISO SLEEVE @ SAME. OAL = 50". JOB COMPLETE. CD3-113 Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTMD 16,065.0 CD3-113 1/28/2021 claytg Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull RBP, Set Iso CD3-113 4/14/2024 boehmbh Notes: General & Safety Annotation End Date Last Mod By NOTE: Original wellbore drilled in 2007 suspended, re-entered March, 2008; NO Sidetrack 'A' 3/23/2008 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 40.0 114.0 114.0 62.50 H-40 Welded SURFACE 9 5/8 8.83 36.3 2,619.3 2,474.3 40.00 L-80 BTCM INTERMEDIATE 7 6.28 33.7 9,364.0 6,910.2 26.00 L-80 BTCM LINER 4 1/2 3.96 9,208.0 17,280.0 6,859.6 12.60 L-80 IBTM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.2 Set Depth … 9,230.4 Set Depth … 6,892.0 String Max No… 3 1/2 Tubing Description TUBING 4.5"x3.5" @132.6' Wt (lb/ft) 9.30 Grade L-80 Top Connection EUEM ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.2 31.2 0.00 HANGER 11.000 FMC 4 1/2" Tbg hanger w/ 2.28' pup FMC 3.980 132.6 132.6 0.39 XO-Reducing 4.500 XO - 3 1/2" EUE (P) X 4 1/2" IBTM (B) 5.1875" OD x 3" ID 3.000 2,064.1 2,023.0 28.37 SAFETY VLV 5.170 Camco 3.5" TRMAXX-5E SSSV (LOCKED OUT 4/27/2010) CAMCO TRMAX X-5E 2.812 3,891.9 3,387.9 43.48 GAS LIFT 5.390 Camco 3 1/2" KBMG GLM 5.390" OD x 2.920" ID CAMCO KBMG 2.920 6,963.4 5,617.8 44.10 GAS LIFT 5.390 Camco 3 1/2" KBMG GLM 5.390" OD x 2.920" ID CAMCO KBMG 2.920 8,450.8 6,623.1 59.29 GAS LIFT 5.390 Camco 3 1/2" KBMG GLM 5.390" OD x 2.920" ID CAMCO KBMG 2.920 8,499.2 6,647.4 60.67 X NIPPLE 4.250 HES "X" Nipple 2.813" ID HES X 2.813 8,541.8 6,667.7 62.16 GAUGE 5.690 Baker Gauge Carrier 2.992 8,561.3 6,676.7 62.86 PACKER 5.980 3.5" X 7" Baker Premier PACKER BAKER 2.875 8,606.3 6,696.7 64.47 XN NIPPLE 4.250 HES "XN" NIPPLE 2.813" Polish Bore w/ 2.75" No Go HES XN 2.750 9,229.4 6,891.8 79.69 WLEG 4.120 FMC 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,064.1 2,023.0 28.37 ISO-SLEEVE ISO SLEEVE ON X-LOCK, 2.84" FRUDENBERG 4/14/2024 1.730 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,891.9 3,387.9 43.48 1 GAS LIFT GLV BK 1 1,688.0 4/8/2024 0.188 6,963.4 5,617.8 44.10 2 GAS LIFT GLV BK 1 1,741.0 4/7/2024 0.188 8,450.8 6,623.1 59.29 3 GAS LIFT OV BK 1 3/24/2024 Camco BKO-3 0.250 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,208.0 6,887.8 78.90 SLEEVE 5.000 Baker 5" x 7" HR Liner Setting Sleeve 4.420 9,220.9 6,890.3 79.37 NIPPLE 5.000 RS Nipple 4.250 9,234.4 6,892.7 79.87 XO Bushing 5.000 XO Bushing 3.940 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,542.0 9,547.0 6,926.1 6,926.5 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 9,807.0 9,812.0 6,933.8 6,933.7 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 10,073.0 10,078.0 6,925.5 6,925.3 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 10,338.0 10,343.0 6,917.5 6,917.3 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 10,604.0 10,609.0 6,909.1 6,908.9 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 10,871.0 10,875.0 6,916.1 6,916.2 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 11,136.0 11,141.0 6,910.9 6,910.8 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 11,400.0 11,404.0 6,906.2 6,906.1 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 11,500.0 11,520.0 6,905.2 6,905.0 227NCH, CD3- 113 2/15/2023 6.0 APERF 20' of holes, 6 SPF, 60 deg - PJ Omega HMX Guns 11,500.0 11,520.0 6,905.2 6,905.0 227NCH, CD3- 113 2/14/2023 6.0 PERFP 6 SPF WITH 60 DEG. PHASE 11,663.0 11,668.0 6,902.5 6,902.6 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup CD3-113, 4/29/2024 2:45:56 PM Vertical schematic (actual) LINER; 9,208.0-17,280.0 PERFP; 17,140.0-17,145.0 PERFP; 16,921.0-16,925.0 PERFP; 16,655.0-16,660.0 PERFP; 16,395.0-16,400.0 PERFP; 16,131.0-16,136.0 PERFP; 15,870.0-15,875.0 APERF; 15,630.0-15,650.0 PERFP; 15,607.0-15,612.0 PERFP; 15,342.0-15,347.0 PERFP; 15,078.0-15,082.0 PERFP; 14,818.0-14,823.0 PERFP; 14,552.0-14,557.0 APERF; 14,500.0-14,520.0 PERFP; 14,290.0-14,295.0 PERFP; 14,034.0-14,039.0 APERF; 14,020.0-14,040.0 RPERF; 14,020.0-14,040.0 APERF; 14,000.0-14,020.0 PERFP; 14,000.0-14,020.0 PERFP; 13,768.0-13,773.0 PERFP; 13,503.0-13,507.0 PERFP; 13,245.0-13,250.0 PERFP; 12,986.0-12,991.0 PERFP; 12,723.0-12,728.0 PERFP; 12,458.0-12,463.0 PERFP; 12,193.0-12,198.0 APERF; 12,000.0-12,020.0 PERFP; 11,928.0-11,933.0 PERFP; 11,663.0-11,668.0 APERF; 11,500.0-11,520.0 PERFP; 11,500.0-11,520.0 PERFP; 11,400.0-11,404.0 PERFP; 11,136.0-11,141.0 PERFP; 10,871.0-10,875.0 PERFP; 10,604.0-10,609.0 PERFP; 10,338.0-10,343.0 PERFP; 10,073.0-10,078.0 PERFP; 9,807.0-9,812.0 PERFP; 9,542.0-9,547.0 INTERMEDIATE; 33.7-9,364.0 PACKER; 8,561.3 GAS LIFT; 8,450.8 GAS LIFT; 6,963.4 GAS LIFT; 3,891.9 SURFACE; 36.3-2,619.3 SAFETY VLV; 2,064.1 CONDUCTOR; 40.0-114.0 WNS PROD KB-Grd (ft) 42.61 RR Date 2/4/2007 Other Elev… CD3-113 ... TD Act Btm (ftKB) 17,338.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032054100 Wellbore Status PROD Max Angle & MD Incl (°) 93.60 MD (ftKB) 17,018.27 WELLNAME WELLBORECD3-113 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: LOCKED OUT Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,928.0 11,933.0 6,906.8 6,906.8 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 12,000.0 12,020.0 6,906.6 6,906.5 227NCH, CD3- 113 1/29/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX guns 12,193.0 12,198.0 6,905.1 6,905.2 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 12,458.0 12,463.0 6,905.0 6,905.0 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 12,723.0 12,728.0 6,904.5 6,904.6 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 12,986.0 12,991.0 6,911.9 6,911.9 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 13,245.0 13,250.0 6,905.7 6,905.5 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 13,503.0 13,507.0 6,895.4 6,895.1 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 13,768.0 13,773.0 6,884.1 6,884.1 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 14,000.0 14,020.0 6,883.1 6,883.0 227NCH, CD3- 113 2/14/2023 6.0 PERFP 6 SPF WITH 60 DEG. PHASE 14,000.0 14,020.0 6,883.1 6,883.0 227NCH, CD3- 113 2/14/2023 6.0 APERF 20' of holes, 6 SPF, 60 deg - PJ Omega HMX guns 14,020.0 14,040.0 6,883.0 6,882.8 227NCH, CD3- 113 2/15/2023 6.0 RPERF 6 SPF WITH 60 DEG. PHASE 14,020.0 14,040.0 6,883.0 6,882.8 227NCH, CD3- 113 2/14/2023 6.0 APERF 20' of holes, 6 SPF, 60 deg - PJ Omega HMX guns 14,034.0 14,039.0 6,882.9 6,882.8 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 14,290.0 14,295.0 6,877.7 6,877.7 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 14,500.0 14,520.0 6,877.4 6,877.4 227NCH, CD3- 113 1/29/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX guns 14,552.0 14,557.0 6,877.5 6,877.5 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 14,818.0 14,823.0 6,877.6 6,877.6 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,078.0 15,082.0 6,875.8 6,875.8 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,342.0 15,347.0 6,875.0 6,875.1 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,607.0 15,612.0 6,879.1 6,879.2 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,630.0 15,650.0 6,879.5 6,879.8 KUPD, CD3-113 1/29/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX guns 15,870.0 15,875.0 6,881.4 6,881.4 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 16,131.0 16,136.0 6,882.6 6,882.6 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 16,395.0 16,400.0 6,884.7 6,884.7 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 16,655.0 16,660.0 6,883.5 6,883.4 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 16,921.0 16,925.0 6,878.1 6,877.9 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 17,140.0 17,145.0 6,866.2 6,865.9 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup CD3-113, 4/29/2024 2:45:57 PM Vertical schematic (actual) LINER; 9,208.0-17,280.0 PERFP; 17,140.0-17,145.0 PERFP; 16,921.0-16,925.0 PERFP; 16,655.0-16,660.0 PERFP; 16,395.0-16,400.0 PERFP; 16,131.0-16,136.0 PERFP; 15,870.0-15,875.0 APERF; 15,630.0-15,650.0 PERFP; 15,607.0-15,612.0 PERFP; 15,342.0-15,347.0 PERFP; 15,078.0-15,082.0 PERFP; 14,818.0-14,823.0 PERFP; 14,552.0-14,557.0 APERF; 14,500.0-14,520.0 PERFP; 14,290.0-14,295.0 PERFP; 14,034.0-14,039.0 APERF; 14,020.0-14,040.0 RPERF; 14,020.0-14,040.0 APERF; 14,000.0-14,020.0 PERFP; 14,000.0-14,020.0 PERFP; 13,768.0-13,773.0 PERFP; 13,503.0-13,507.0 PERFP; 13,245.0-13,250.0 PERFP; 12,986.0-12,991.0 PERFP; 12,723.0-12,728.0 PERFP; 12,458.0-12,463.0 PERFP; 12,193.0-12,198.0 APERF; 12,000.0-12,020.0 PERFP; 11,928.0-11,933.0 PERFP; 11,663.0-11,668.0 APERF; 11,500.0-11,520.0 PERFP; 11,500.0-11,520.0 PERFP; 11,400.0-11,404.0 PERFP; 11,136.0-11,141.0 PERFP; 10,871.0-10,875.0 PERFP; 10,604.0-10,609.0 PERFP; 10,338.0-10,343.0 PERFP; 10,073.0-10,078.0 PERFP; 9,807.0-9,812.0 PERFP; 9,542.0-9,547.0 INTERMEDIATE; 33.7-9,364.0 PACKER; 8,561.3 GAS LIFT; 8,450.8 GAS LIFT; 6,963.4 GAS LIFT; 3,891.9 SURFACE; 36.3-2,619.3 SAFETY VLV; 2,064.1 CONDUCTOR; 40.0-114.0 WNS PROD CD3-113 ... WELLNAME WELLBORECD3-113 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 17,338 feet None feet true vertical 6,858 feet None feet Effective Depth measured 17,280 feet 8,561 feet true vertical 6,860 feet 6,677 feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4.5" x 3.5" L-80 9,230'MD 6,892'TVD Packers and SSSV (type, measured and true vertical depth) 8,561'MD 2,064' MD 6,677'TVD 2,023' TVD locked out WRDP installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 9244 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer:Baker premier Production Packer/ SSSV-Camco TRMAXX-5E Mark Shulman mark.shulman@cop.com (907) 263-3782Sr. Production Engineer Perf Pups from 9,542'-17,145': 2023 Perfs: 11,500'-11,520' MD and 14,000'-14,040' MD 6,926'-6,866': 2023 Perfs: 6,904'-6,905' and 6,882'-6,883' TVD measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 1084 Gas-Mcf MD 1998 Size 114 2705 144810144 188 4144723 375 measured TVD 7" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 207-004 50-103-20541-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 372105, ADL 384215, ADL 264471 Colville River Field/Fiord Nechelik CRU CD3-113 Plugs Junk measured Length Liner 9330' 8072' Casing 6910 6860 9364 17280 2583' 114Conductor Surface Intermediate 16" 9-5/8" 74' 2619 2474 Burst Collapse e Fra O g g s g y e 6. A y PG 25.070, 2 Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Samantha Carlisle at 12:38 pm, Feb 24, 2023 DTTMSTART JOBTYP SUMMARYOPS 2/14/2023 MAINTAIN WELL DRY DRIFTED TO 14476' AND HIT LOCK UP. RIH WITH PERF RUN #1. PERFORATE INTERVAL 14020' - 14040' CTMD. RIH WITH PERF RUN #2. PERFORATE INTERVAL 14000' - 14020' CTMD.CONFIRMED GUNS FIRED 2/15/2023 MAINTAIN WELL RIH W GUN RUN #3 AND PERFORATE FROM 11500' TO 11520' CTMD, READY FOR SLICKLINE. CD3-113 Perforations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTMD 16,065.0 CD3-113 1/28/2021 claytg Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set WRDP Post Squeeze CD3-113 2/21/2023 oberr Notes: General & Safety Annotation End Date Last Mod By NOTE: Original wellbore drilled in 2007 suspended, re-entered March, 2008; NO Sidetrack 'A' 3/23/2008 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 40.0 114.0 114.0 62.50 H-40 Welded SURFACE 9 5/8 8.83 36.3 2,619.3 2,474.3 40.00 L-80 BTCM INTERMEDIATE 7 6.28 33.7 9,364.0 6,910.2 26.00 L-80 BTCM LINER 4 1/2 3.96 9,208.0 17,280.0 6,859.6 12.60 L-80 IBTM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 31.2 Set Depth 9,230.4 Set Depth 6,892.0 String Ma 3 1/2 Tubing Description TUBING 4.5"x3.5" @132.6' Wt (lb/ft) 9.30 Grade L-80 Top Connection EUEM ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.2 31.2 0.00 HANGER 11.000 FMC 4 1/2" Tbg hanger w/ 2.28' pup FMC 3.980 132.6 132.6 0.39 XO-Reducing 4.500 XO - 3 1/2" EUE (P) X 4 1/2" IBTM (B) 5.1875" OD x 3" ID 3.000 2,064.1 2,023.0 28.37 SAFETY VLV 5.170 Camco 3.5" TRMAXX-5E SSSV (LOCKED OUT 4/27/2010) 2.812 3,891.9 3,387.9 43.48 GAS LIFT 5.390 Camco 3 1/2" KBMG GLM 5.390" OD x 2.920" ID CAMCO KBMG 2.920 6,963.4 5,617.8 44.10 GAS LIFT 5.390 Camco 3 1/2" KBMG GLM 5.390" OD x 2.920" ID CAMCO KBMG 2.920 8,450.8 6,623.1 59.29 GAS LIFT 5.390 Camco 3 1/2" KBMG GLM 5.390" OD x 2.920" ID CAMCO KBMG 2.920 8,499.2 6,647.4 60.67 X NIPPLE 4.250 HES "X" Nipple 2.813" ID HES 2.813 8,541.8 6,667.7 62.16 GAUGE 5.690 Baker Gauge Carrier 2.992 8,561.3 6,676.7 62.86 PACKER 5.980 3.5" X 7" Baker Premier PACKER BAKER 2.875 8,606.3 6,696.7 64.47 XN NIPPLE 4.250 HES "XN" NIPPLE 2.813" Polish Bore w/ 2.75" No Go HES 2.750 9,229.4 6,891.8 79.69 WLEG 4.120 FMC 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,064.1 2,023.0 28.37 WR-SSSV 3.5" WRDP-1 ON 2.81" X- LOCK (OAL=89.5", STD PKG) CAMCO WRDP-1 C15S- 0519 2/21/2023 1.562 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,891.9 3,387.9 43.48 1 GAS LIFT DMY BK 1 2/12/2019 6,963.4 5,617.8 44.10 2 GAS LIFT GLV BK 1 1,970.0 2/11/2019 0.188 8,450.8 6,623.1 59.29 3 GAS LIFT OV BK 1 0.0 2/29/2008 0.250 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,208.0 6,887.8 78.90 SLEEVE 5.000 Baker 5" x 7" HR Liner Setting Sleeve 4.420 9,220.9 6,890.3 79.37 NIPPLE 5.000 RS Nipple 4.250 9,234.4 6,892.7 79.87 XO Bushing 5.000 XO Bushing 3.940 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,542.0 9,547.0 6,926.1 6,926.5 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 9,807.0 9,812.0 6,933.8 6,933.7 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 10,073.0 10,078.0 6,925.5 6,925.3 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 10,338.0 10,343.0 6,917.5 6,917.3 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 10,604.0 10,609.0 6,909.1 6,908.9 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 10,871.0 10,875.0 6,916.1 6,916.2 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 11,136.0 11,141.0 6,910.9 6,910.8 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 11,400.0 11,404.0 6,906.2 6,906.1 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 11,500.0 11,520.0 6,905.2 6,905.0 227NCH, CD3- 113 2/15/2023 6.0 APERF 20' of holes, 6 SPF, 60 deg - PJ Omega HMX Guns 11,663.0 11,668.0 6,902.5 6,902.6 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 11,928.0 11,933.0 6,906.8 6,906.8 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup CD3-113, 2/22/2023 5:42:21 AM Vertical schematic (actual) LINER; 9,208.0-17,280.0 GLIDE SHOE; 17,275.5- 17,280.0 PERFP; 17,140.0-17,145.0 PERFP; 16,921.0-16,925.0 PERFP; 16,655.0-16,660.0 PERFP; 16,395.0-16,400.0 PERFP; 16,131.0-16,136.0 PERFP; 15,870.0-15,875.0 APERF; 15,630.0-15,650.0 PERFP; 15,607.0-15,612.0 PERFP; 15,342.0-15,347.0 PERFP; 15,078.0-15,082.0 PERFP; 14,818.0-14,823.0 PERFP; 14,552.0-14,557.0 APERF; 14,500.0-14,520.0 PERFP; 14,290.0-14,295.0 PERFP; 14,034.0-14,039.0 APERF; 14,020.0-14,040.0 APERF; 14,000.0-14,020.0 PERFP; 13,768.0-13,773.0 PERFP; 13,503.0-13,507.0 PERFP; 13,245.0-13,250.0 PERFP; 12,986.0-12,991.0 PERFP; 12,723.0-12,728.0 PERFP; 12,458.0-12,463.0 PERFP; 12,193.0-12,198.0 APERF; 12,000.0-12,020.0 PERFP; 11,928.0-11,933.0 PERFP; 11,663.0-11,668.0 APERF; 11,500.0-11,520.0 PERFP; 11,400.0-11,404.0 PERFP; 11,136.0-11,141.0 PERFP; 10,871.0-10,875.0 PERFP; 10,604.0-10,609.0 PERFP; 10,338.0-10,343.0 PERFP; 10,073.0-10,078.0 PERFP; 9,807.0-9,812.0 PERFP; 9,542.0-9,547.0 INTERMEDIATE; 33.7-9,364.0 Float Shoe; 9,362.0-9,364.0 Float Collar; 9,277.2-9,278.2 XO Bushing; 9,234.4-9,236.2 WLEG; 9,229.4 HANGER; 9,224.5-9,234.4 NIPPLE; 9,220.9-9,224.5 SLEEVE; 9,208.0-9,220.9 XN NIPPLE; 8,606.3 PACKER; 8,561.3 GAUGE; 8,541.8 X NIPPLE; 8,499.2 GAS LIFT; 8,450.8 GAS LIFT; 6,963.4 Stage Collar; 5,285.1-5,288.0 GAS LIFT; 3,891.9 SURFACE; 36.3-2,619.3 Float Shoe; 2,617.0-2,619.3 Float Collar; 2,540.4-2,541.5 WR-SSSV; 2,064.1 SAFETY VLV; 2,064.1 CONDUCTOR; 40.0-114.0 Casing Hanger; 33.7-35.9 HANGER; 31.2 WNS PROD KB-Grd (ft) 42.61 RR Date 2/4/2007 Other Elev CD3-113 ... TD Act Btm (ftKB) 17,338.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032054100 Wellbore Status PROD Max Angle & MD Incl (°) 93.60 MD (ftKB) 17,018.27 WELLNAME WELLBORECD3-113 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: LOCKED OUT Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 12,000.0 12,020.0 6,906.6 6,906.5 227NCH, CD3- 113 1/29/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX guns 12,193.0 12,198.0 6,905.1 6,905.2 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 12,458.0 12,463.0 6,905.0 6,905.0 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 12,723.0 12,728.0 6,904.5 6,904.6 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 12,986.0 12,991.0 6,911.9 6,911.9 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 13,245.0 13,250.0 6,905.7 6,905.5 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 13,503.0 13,507.0 6,895.4 6,895.1 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 13,768.0 13,773.0 6,884.1 6,884.1 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 14,000.0 14,020.0 6,883.1 6,883.0 227NCH, CD3- 113 2/14/2023 6.0 APERF 20' of holes, 6 SPF, 60 deg - PJ Omega HMX guns 14,020.0 14,040.0 6,883.0 6,882.8 227NCH, CD3- 113 2/14/2023 6.0 APERF 20' of holes, 6 SPF, 60 deg - PJ Omega HMX guns 14,034.0 14,039.0 6,882.9 6,882.8 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 14,290.0 14,295.0 6,877.7 6,877.7 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 14,500.0 14,520.0 6,877.4 6,877.4 227NCH, CD3- 113 1/29/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX guns 14,552.0 14,557.0 6,877.5 6,877.5 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 14,818.0 14,823.0 6,877.6 6,877.6 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,078.0 15,082.0 6,875.8 6,875.8 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,342.0 15,347.0 6,875.0 6,875.1 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,607.0 15,612.0 6,879.1 6,879.2 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,630.0 15,650.0 6,879.5 6,879.8 KUPD, CD3-113 1/29/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX guns 15,870.0 15,875.0 6,881.4 6,881.4 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 16,131.0 16,136.0 6,882.6 6,882.6 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 16,395.0 16,400.0 6,884.7 6,884.7 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 16,655.0 16,660.0 6,883.5 6,883.4 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 16,921.0 16,925.0 6,878.1 6,877.9 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 17,140.0 17,145.0 6,866.2 6,865.9 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup CD3-113, 2/22/2023 5:42:22 AM Vertical schematic (actual) LINER; 9,208.0-17,280.0 GLIDE SHOE; 17,275.5- 17,280.0 PERFP; 17,140.0-17,145.0 PERFP; 16,921.0-16,925.0 PERFP; 16,655.0-16,660.0 PERFP; 16,395.0-16,400.0 PERFP; 16,131.0-16,136.0 PERFP; 15,870.0-15,875.0 APERF; 15,630.0-15,650.0 PERFP; 15,607.0-15,612.0 PERFP; 15,342.0-15,347.0 PERFP; 15,078.0-15,082.0 PERFP; 14,818.0-14,823.0 PERFP; 14,552.0-14,557.0 APERF; 14,500.0-14,520.0 PERFP; 14,290.0-14,295.0 PERFP; 14,034.0-14,039.0 APERF; 14,020.0-14,040.0 APERF; 14,000.0-14,020.0 PERFP; 13,768.0-13,773.0 PERFP; 13,503.0-13,507.0 PERFP; 13,245.0-13,250.0 PERFP; 12,986.0-12,991.0 PERFP; 12,723.0-12,728.0 PERFP; 12,458.0-12,463.0 PERFP; 12,193.0-12,198.0 APERF; 12,000.0-12,020.0 PERFP; 11,928.0-11,933.0 PERFP; 11,663.0-11,668.0 APERF; 11,500.0-11,520.0 PERFP; 11,400.0-11,404.0 PERFP; 11,136.0-11,141.0 PERFP; 10,871.0-10,875.0 PERFP; 10,604.0-10,609.0 PERFP; 10,338.0-10,343.0 PERFP; 10,073.0-10,078.0 PERFP; 9,807.0-9,812.0 PERFP; 9,542.0-9,547.0 INTERMEDIATE; 33.7-9,364.0 Float Shoe; 9,362.0-9,364.0 Float Collar; 9,277.2-9,278.2 XO Bushing; 9,234.4-9,236.2 WLEG; 9,229.4 HANGER; 9,224.5-9,234.4 NIPPLE; 9,220.9-9,224.5 SLEEVE; 9,208.0-9,220.9 XN NIPPLE; 8,606.3 PACKER; 8,561.3 GAUGE; 8,541.8 X NIPPLE; 8,499.2 GAS LIFT; 8,450.8 GAS LIFT; 6,963.4 Stage Collar; 5,285.1-5,288.0 GAS LIFT; 3,891.9 SURFACE; 36.3-2,619.3 Float Shoe; 2,617.0-2,619.3 Float Collar; 2,540.4-2,541.5 WR-SSSV; 2,064.1 SAFETY VLV; 2,064.1 CONDUCTOR; 40.0-114.0 Casing Hanger; 33.7-35.9 HANGER; 31.2 WNS PROD CD3-113 ... WELLNAME WELLBORECD3-113 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 17,338 feet None feet true vertical 6,858 feet None feet Effective Depth measured 17,280 feet 8,561 feet true vertical 6,860 feet 6,677 feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4.5" x 3.5" L-80 9,230'MD 6,892'TVD Packers and SSSV (type, measured and true vertical depth) 8,561'MD 2,064' MD 6,677'TVD 2,023' TVD locked out WRDP installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 9244 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer:Baker premier Production Packer/ SSSV-Camco TRMAXX-5E Mark Shulman mark.shulman@cop.com (907) 263-3782Sr. Production Engineer Perf Pups from 9,542'-17,145': 2023 Perfs: 11,500'-11,520' MD and 14,000'-14,040' MD 6,926'-6,866': 2023 Perfs: 6,904'-6,905' and 6,882'-6,883' TVD measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 1084 Gas-Mcf MD 1998 Size 114 2705 144810144 188 4144723 375 measured TVD 7" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 207-004 50-103-20541-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 372105, ADL 384215, ADL 264471 Colville River Field/Fiord Nechelik CRU CD3-113 Plugs Junk measured Length Liner 9330' 8072' Casing 6910 6860 9364 17280 2583' 114Conductor Surface Intermediate 16" 9-5/8" 74' 2619 2474 Burst Collapse e Fra O g g s g y e 6. A y PG 25.070, 2 Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Samantha Carlisle at 12:38 pm, Feb 24, 2023 DTTMSTART JOBTYP SUMMARYOPS 2/14/2023 MAINTAIN WELL DRY DRIFTED TO 14476' AND HIT LOCK UP. RIH WITH PERF RUN #1. PERFORATE INTERVAL 14020' - 14040' CTMD. RIH WITH PERF RUN #2. PERFORATE INTERVAL 14000' - 14020' CTMD.CONFIRMED GUNS FIRED 2/15/2023 MAINTAIN WELL RIH W GUN RUN #3 AND PERFORATE FROM 11500' TO 11520' CTMD, READY FOR SLICKLINE. CD3-113 Perforations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTMD 16,065.0 CD3-113 1/28/2021 claytg Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set WRDP Post Squeeze CD3-113 2/21/2023 oberr Notes: General & Safety Annotation End Date Last Mod By NOTE: Original wellbore drilled in 2007 suspended, re-entered March, 2008; NO Sidetrack 'A' 3/23/2008 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 40.0 114.0 114.0 62.50 H-40 Welded SURFACE 9 5/8 8.83 36.3 2,619.3 2,474.3 40.00 L-80 BTCM INTERMEDIATE 7 6.28 33.7 9,364.0 6,910.2 26.00 L-80 BTCM LINER 4 1/2 3.96 9,208.0 17,280.0 6,859.6 12.60 L-80 IBTM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 31.2 Set Depth 9,230.4 Set Depth 6,892.0 String Ma 3 1/2 Tubing Description TUBING 4.5"x3.5" @132.6' Wt (lb/ft) 9.30 Grade L-80 Top Connection EUEM ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.2 31.2 0.00 HANGER 11.000 FMC 4 1/2" Tbg hanger w/ 2.28' pup FMC 3.980 132.6 132.6 0.39 XO-Reducing 4.500 XO - 3 1/2" EUE (P) X 4 1/2" IBTM (B) 5.1875" OD x 3" ID 3.000 2,064.1 2,023.0 28.37 SAFETY VLV 5.170 Camco 3.5" TRMAXX-5E SSSV (LOCKED OUT 4/27/2010) 2.812 3,891.9 3,387.9 43.48 GAS LIFT 5.390 Camco 3 1/2" KBMG GLM 5.390" OD x 2.920" ID CAMCO KBMG 2.920 6,963.4 5,617.8 44.10 GAS LIFT 5.390 Camco 3 1/2" KBMG GLM 5.390" OD x 2.920" ID CAMCO KBMG 2.920 8,450.8 6,623.1 59.29 GAS LIFT 5.390 Camco 3 1/2" KBMG GLM 5.390" OD x 2.920" ID CAMCO KBMG 2.920 8,499.2 6,647.4 60.67 X NIPPLE 4.250 HES "X" Nipple 2.813" ID HES 2.813 8,541.8 6,667.7 62.16 GAUGE 5.690 Baker Gauge Carrier 2.992 8,561.3 6,676.7 62.86 PACKER 5.980 3.5" X 7" Baker Premier PACKER BAKER 2.875 8,606.3 6,696.7 64.47 XN NIPPLE 4.250 HES "XN" NIPPLE 2.813" Polish Bore w/ 2.75" No Go HES 2.750 9,229.4 6,891.8 79.69 WLEG 4.120 FMC 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,064.1 2,023.0 28.37 WR-SSSV 3.5" WRDP-1 ON 2.81" X- LOCK (OAL=89.5", STD PKG) CAMCO WRDP-1 C15S- 0519 2/21/2023 1.562 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,891.9 3,387.9 43.48 1 GAS LIFT DMY BK 1 2/12/2019 6,963.4 5,617.8 44.10 2 GAS LIFT GLV BK 1 1,970.0 2/11/2019 0.188 8,450.8 6,623.1 59.29 3 GAS LIFT OV BK 1 0.0 2/29/2008 0.250 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,208.0 6,887.8 78.90 SLEEVE 5.000 Baker 5" x 7" HR Liner Setting Sleeve 4.420 9,220.9 6,890.3 79.37 NIPPLE 5.000 RS Nipple 4.250 9,234.4 6,892.7 79.87 XO Bushing 5.000 XO Bushing 3.940 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,542.0 9,547.0 6,926.1 6,926.5 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 9,807.0 9,812.0 6,933.8 6,933.7 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 10,073.0 10,078.0 6,925.5 6,925.3 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 10,338.0 10,343.0 6,917.5 6,917.3 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 10,604.0 10,609.0 6,909.1 6,908.9 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 10,871.0 10,875.0 6,916.1 6,916.2 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 11,136.0 11,141.0 6,910.9 6,910.8 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 11,400.0 11,404.0 6,906.2 6,906.1 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 11,500.0 11,520.0 6,905.2 6,905.0 227NCH, CD3- 113 2/15/2023 6.0 APERF 20' of holes, 6 SPF, 60 deg - PJ Omega HMX Guns 11,663.0 11,668.0 6,902.5 6,902.6 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 11,928.0 11,933.0 6,906.8 6,906.8 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup CD3-113, 2/22/2023 5:42:21 AM Vertical schematic (actual) LINER; 9,208.0-17,280.0 GLIDE SHOE; 17,275.5- 17,280.0 PERFP; 17,140.0-17,145.0 PERFP; 16,921.0-16,925.0 PERFP; 16,655.0-16,660.0 PERFP; 16,395.0-16,400.0 PERFP; 16,131.0-16,136.0 PERFP; 15,870.0-15,875.0 APERF; 15,630.0-15,650.0 PERFP; 15,607.0-15,612.0 PERFP; 15,342.0-15,347.0 PERFP; 15,078.0-15,082.0 PERFP; 14,818.0-14,823.0 PERFP; 14,552.0-14,557.0 APERF; 14,500.0-14,520.0 PERFP; 14,290.0-14,295.0 PERFP; 14,034.0-14,039.0 APERF; 14,020.0-14,040.0 APERF; 14,000.0-14,020.0 PERFP; 13,768.0-13,773.0 PERFP; 13,503.0-13,507.0 PERFP; 13,245.0-13,250.0 PERFP; 12,986.0-12,991.0 PERFP; 12,723.0-12,728.0 PERFP; 12,458.0-12,463.0 PERFP; 12,193.0-12,198.0 APERF; 12,000.0-12,020.0 PERFP; 11,928.0-11,933.0 PERFP; 11,663.0-11,668.0 APERF; 11,500.0-11,520.0 PERFP; 11,400.0-11,404.0 PERFP; 11,136.0-11,141.0 PERFP; 10,871.0-10,875.0 PERFP; 10,604.0-10,609.0 PERFP; 10,338.0-10,343.0 PERFP; 10,073.0-10,078.0 PERFP; 9,807.0-9,812.0 PERFP; 9,542.0-9,547.0 INTERMEDIATE; 33.7-9,364.0 Float Shoe; 9,362.0-9,364.0 Float Collar; 9,277.2-9,278.2 XO Bushing; 9,234.4-9,236.2 WLEG; 9,229.4 HANGER; 9,224.5-9,234.4 NIPPLE; 9,220.9-9,224.5 SLEEVE; 9,208.0-9,220.9 XN NIPPLE; 8,606.3 PACKER; 8,561.3 GAUGE; 8,541.8 X NIPPLE; 8,499.2 GAS LIFT; 8,450.8 GAS LIFT; 6,963.4 Stage Collar; 5,285.1-5,288.0 GAS LIFT; 3,891.9 SURFACE; 36.3-2,619.3 Float Shoe; 2,617.0-2,619.3 Float Collar; 2,540.4-2,541.5 WR-SSSV; 2,064.1 SAFETY VLV; 2,064.1 CONDUCTOR; 40.0-114.0 Casing Hanger; 33.7-35.9 HANGER; 31.2 WNS PROD KB-Grd (ft) 42.61 RR Date 2/4/2007 Other Elev CD3-113 ... TD Act Btm (ftKB) 17,338.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032054100 Wellbore Status PROD Max Angle & MD Incl (°) 93.60 MD (ftKB) 17,018.27 WELLNAME WELLBORECD3-113 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: LOCKED OUT Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 12,000.0 12,020.0 6,906.6 6,906.5 227NCH, CD3- 113 1/29/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX guns 12,193.0 12,198.0 6,905.1 6,905.2 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 12,458.0 12,463.0 6,905.0 6,905.0 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 12,723.0 12,728.0 6,904.5 6,904.6 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 12,986.0 12,991.0 6,911.9 6,911.9 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 13,245.0 13,250.0 6,905.7 6,905.5 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 13,503.0 13,507.0 6,895.4 6,895.1 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 13,768.0 13,773.0 6,884.1 6,884.1 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 14,000.0 14,020.0 6,883.1 6,883.0 227NCH, CD3- 113 2/14/2023 6.0 APERF 20' of holes, 6 SPF, 60 deg - PJ Omega HMX guns 14,020.0 14,040.0 6,883.0 6,882.8 227NCH, CD3- 113 2/14/2023 6.0 APERF 20' of holes, 6 SPF, 60 deg - PJ Omega HMX guns 14,034.0 14,039.0 6,882.9 6,882.8 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 14,290.0 14,295.0 6,877.7 6,877.7 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 14,500.0 14,520.0 6,877.4 6,877.4 227NCH, CD3- 113 1/29/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX guns 14,552.0 14,557.0 6,877.5 6,877.5 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 14,818.0 14,823.0 6,877.6 6,877.6 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,078.0 15,082.0 6,875.8 6,875.8 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,342.0 15,347.0 6,875.0 6,875.1 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,607.0 15,612.0 6,879.1 6,879.2 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,630.0 15,650.0 6,879.5 6,879.8 KUPD, CD3-113 1/29/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX guns 15,870.0 15,875.0 6,881.4 6,881.4 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 16,131.0 16,136.0 6,882.6 6,882.6 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 16,395.0 16,400.0 6,884.7 6,884.7 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 16,655.0 16,660.0 6,883.5 6,883.4 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 16,921.0 16,925.0 6,878.1 6,877.9 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 17,140.0 17,145.0 6,866.2 6,865.9 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup CD3-113, 2/22/2023 5:42:22 AM Vertical schematic (actual) LINER; 9,208.0-17,280.0 GLIDE SHOE; 17,275.5- 17,280.0 PERFP; 17,140.0-17,145.0 PERFP; 16,921.0-16,925.0 PERFP; 16,655.0-16,660.0 PERFP; 16,395.0-16,400.0 PERFP; 16,131.0-16,136.0 PERFP; 15,870.0-15,875.0 APERF; 15,630.0-15,650.0 PERFP; 15,607.0-15,612.0 PERFP; 15,342.0-15,347.0 PERFP; 15,078.0-15,082.0 PERFP; 14,818.0-14,823.0 PERFP; 14,552.0-14,557.0 APERF; 14,500.0-14,520.0 PERFP; 14,290.0-14,295.0 PERFP; 14,034.0-14,039.0 APERF; 14,020.0-14,040.0 APERF; 14,000.0-14,020.0 PERFP; 13,768.0-13,773.0 PERFP; 13,503.0-13,507.0 PERFP; 13,245.0-13,250.0 PERFP; 12,986.0-12,991.0 PERFP; 12,723.0-12,728.0 PERFP; 12,458.0-12,463.0 PERFP; 12,193.0-12,198.0 APERF; 12,000.0-12,020.0 PERFP; 11,928.0-11,933.0 PERFP; 11,663.0-11,668.0 APERF; 11,500.0-11,520.0 PERFP; 11,400.0-11,404.0 PERFP; 11,136.0-11,141.0 PERFP; 10,871.0-10,875.0 PERFP; 10,604.0-10,609.0 PERFP; 10,338.0-10,343.0 PERFP; 10,073.0-10,078.0 PERFP; 9,807.0-9,812.0 PERFP; 9,542.0-9,547.0 INTERMEDIATE; 33.7-9,364.0 Float Shoe; 9,362.0-9,364.0 Float Collar; 9,277.2-9,278.2 XO Bushing; 9,234.4-9,236.2 WLEG; 9,229.4 HANGER; 9,224.5-9,234.4 NIPPLE; 9,220.9-9,224.5 SLEEVE; 9,208.0-9,220.9 XN NIPPLE; 8,606.3 PACKER; 8,561.3 GAUGE; 8,541.8 X NIPPLE; 8,499.2 GAS LIFT; 8,450.8 GAS LIFT; 6,963.4 Stage Collar; 5,285.1-5,288.0 GAS LIFT; 3,891.9 SURFACE; 36.3-2,619.3 Float Shoe; 2,617.0-2,619.3 Float Collar; 2,540.4-2,541.5 WR-SSSV; 2,064.1 SAFETY VLV; 2,064.1 CONDUCTOR; 40.0-114.0 Casing Hanger; 33.7-35.9 HANGER; 31.2 WNS PROD CD3-113 ... 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(! !3 &' 6< ! 6< : & & < B +/1*-0)5#5*.0 0 ! ! & & /5518 07*7 )/1 ).)1 7 +> 01 021*14021*4C020.5- ); /#23.; *; 7#30; *78 02.58 $ , : :! !"# $% &' 2 % ! 211 *$( ( (< !3 71 () 3 ! < * + ",, , -", )2 ? #6 @ < ( . .1*08 01118#01018472118#720184 /52 )70 A %5#5 &,D ,D$,!%? !& 9$! 66$$! /0*/1 *2 (34'/5 60 *0/ 1*4( 7,#,,! -,", 7,-!",, !3 5 7" = " < *. % ( $ E % 5555) %,5*0124%,5.7024%,0)77* 7 50/ #= < *0.1 9# 6FF#2&+ < " % - "$!@"? 0511 " #= &' 7 0)/ /5)7 18' 1#717 530101 " 51( By Samantha Carlisle at 12:36 pm, Feb 24, 2021 Mark Shulman Digitally signed by Mark Shulman Date: 2021.02.24 11:36:03 -09'00' -00 SFD 2/24/2021 364471 Alpine Oil Pool SFD 2/24/2021 RBDMS HEW 2/24/2021 VTL 3/3/21 SFD 2/24/2021 SFD 2/24/2021 DSR-2/24/21 ! " #$ % "&# ! % ' ' % % ' ! $ ! ' ' ! ! ( ! ) * '# + ' ! ) * & +& ! )# * + , # #$ '& % #-. /// /// , # ( &#'! ' ( "# ! # #+#0112-34567-2894:; 7-54-2894:;2:.<2=7:>9?9894: Hybrid Scale Inhibitor Squeeze Job pumped from 0730 - 1630 hrs on 1/31/21. LRS = Little Red Services ACF = Alpine Central Facility x Initial pressure TBG/IA/OA – 1988/1932/517 x LRS and ACF pumped 290 bbls WAW5206/Diesel at 0.5 – 3 bpm, TBG/IA/OA – 2400/1776/516 x LRS pumped 290 bbls Seawater/SCW3001 scale inhibitor main treatment at 1 – 2.5 bpm, TBG/IA/OA – 0/1722/524 Interval treated: 9,364’ – 17,338’ MD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:CD3-113 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pull WRDP, Add Perfs 1/29/2021 CD3-113 rogerba Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 40.0 Set Depth (ftKB) 114.0 Set Depth (TVD) … 114.0 Wt/Len (l… 62.50 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 36.3 Set Depth (ftKB) 2,619.3 Set Depth (TVD) … 2,474.3 Wt/Len (l… 40.00 Grade L-80 Top Thread BTCM Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 33.7 Set Depth (ftKB) 9,364.0 Set Depth (TVD) … 6,910.2 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 9,208.0 Set Depth (ftKB) 17,280.0 Set Depth (TVD) … 6,859.6 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,208.0 6,887.8 78.90 SLEEVE Baker 5" x 7" HR Liner Setting Sleeve 4.420 9,220.9 6,890.3 79.37 NIPPLE RS Nipple 4.250 9,224.5 6,890.9 79.51 HANGER Baker 5 " X 7" DG Flex-lock Liner Hanger 4.420 9,234.4 6,892.7 79.87 XO Bushing XO Bushing 3.940 Tubing Strings Tubing Description TUBING 4.5"x3.5" @132.6' String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.2 Set Depth (ft… 9,230.4 Set Depth (TVD) (… 6,892.0 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUEM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.2 31.2 0.00 HANGER FMC 4 1/2" Tbg hanger w/ 2.28' pup 3.980 132.6 132.6 0.39 XO-Reducing XO - 3 1/2" EUE (P) X 4 1/2" IBTM (B) 5.1875" OD x 3" ID 3.000 2,064.1 2,023.0 28.37 SAFETY VLV Camco 3.5" TRMAXX-5E SSSV (LOCKED OUT 4/27/2010) 2.812 8,499.2 6,647.4 60.67 X NIPPLE HES "X" Nipple 2.813" ID 2.813 8,541.8 6,667.7 62.16 GAUGE Baker Gauge Carrier 2.992 8,561.3 6,676.7 62.86 PACKER 3.5" X 7" Baker Premier PACKER 2.875 8,606.3 6,696.7 64.47 XN NIPPLE HES "XN" NIPPLE 2.813" Polish Bore w/ 2.75" No Go 2.750 9,229.4 6,891.8 79.69 WLEG 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,542.0 9,547.0 6,926.1 6,926.5 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 9,807.0 9,812.0 6,933.8 6,933.7 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 10,073.0 10,078.0 6,925.5 6,925.3 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 10,338.0 10,343.0 6,917.5 6,917.3 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 10,604.0 10,609.0 6,909.1 6,908.9 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 10,871.0 10,875.0 6,916.1 6,916.2 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 11,136.0 11,141.0 6,910.9 6,910.8 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 11,400.0 11,404.0 6,906.2 6,906.1 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 11,663.0 11,668.0 6,902.5 6,902.6 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 11,928.0 11,933.0 6,906.8 6,906.8 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 12,000.0 12,020.0 6,906.6 6,906.5 227NCH, CD3- 113 1/29/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX - 7.3 gm. 0.22" Ent hole - 21.8" Penetration 12,193.0 12,198.0 6,905.1 6,905.2 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 12,458.0 12,463.0 6,905.0 6,905.0 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 12,723.0 12,728.0 6,904.5 6,904.6 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 12,986.0 12,991.0 6,911.9 6,911.9 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 13,245.0 13,250.0 6,905.7 6,905.5 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 13,503.0 13,507.0 6,895.4 6,895.1 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 13,768.0 13,773.0 6,884.1 6,884.1 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 14,034.0 14,039.0 6,882.9 6,882.8 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 14,290.0 14,295.0 6,877.7 6,877.7 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 14,500.0 14,520.0 6,877.4 6,877.4 227NCH, CD3- 113 1/29/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX - 7.3 gm. 0.22" Ent hole - 21.8" Penetration 14,552.0 14,557.0 6,877.5 6,877.5 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup CD3-113, 1/29/2021 10:56:08 PM Vertical schematic (actual) LINER; 9,208.0-17,280.0 PERFP; 17,140.0-17,145.0 PERFP; 16,921.0-16,925.0 PERFP; 16,655.0-16,660.0 PERFP; 16,395.0-16,400.0 PERFP; 16,131.0-16,136.0 PERFP; 15,870.0-15,875.0 APERF; 15,630.0-15,650.0 PERFP; 15,607.0-15,612.0 PERFP; 15,342.0-15,347.0 PERFP; 15,078.0-15,082.0 PERFP; 14,818.0-14,823.0 PERFP; 14,552.0-14,557.0 APERF; 14,500.0-14,520.0 PERFP; 14,290.0-14,295.0 PERFP; 14,034.0-14,039.0 PERFP; 13,768.0-13,773.0 PERFP; 13,503.0-13,507.0 PERFP; 13,245.0-13,250.0 PERFP; 12,986.0-12,991.0 PERFP; 12,723.0-12,728.0 PERFP; 12,458.0-12,463.0 PERFP; 12,193.0-12,198.0 APERF; 12,000.0-12,020.0 PERFP; 11,928.0-11,933.0 PERFP; 11,663.0-11,668.0 PERFP; 11,400.0-11,404.0 PERFP; 11,136.0-11,141.0 PERFP; 10,871.0-10,875.0 PERFP; 10,604.0-10,609.0 PERFP; 10,338.0-10,343.0 PERFP; 10,073.0-10,078.0 PERFP; 9,807.0-9,812.0 PERFP; 9,542.0-9,547.0 INTERMEDIATE; 33.7-9,364.0 WLEG; 9,229.4 XN NIPPLE; 8,606.3 PACKER; 8,561.3 GAUGE; 8,541.8 X NIPPLE; 8,499.2 GAS LIFT; 8,450.8 GAS LIFT; 6,963.4 GAS LIFT; 3,891.9 SURFACE; 36.3-2,619.3 SAFETY VLV; 2,064.1 CONDUCTOR; 40.0-114.0 HANGER; 31.2 WNS PROD KB-Grd (ft) 42.61 Rig Release Date 2/4/2007 CD3-113 ... TD Act Btm (ftKB) 17,338.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032054100 Wellbore Status PROD Max Angle & MD Incl (°) 93.60 MD (ftKB) 17,018.27 WELLNAME WELLBORECD3-113 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: LOCKED OUT Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 14,818.0 14,823.0 6,877.6 6,877.6 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,078.0 15,082.0 6,875.8 6,875.8 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,342.0 15,347.0 6,875.0 6,875.1 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,607.0 15,612.0 6,879.1 6,879.2 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,630.0 15,650.0 6,879.5 6,879.8 227NCH, CD3- 113 1/29/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX - 7.3 gm. 0.22" Ent hole - 21.8" Penetration 15,870.0 15,875.0 6,881.4 6,881.4 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 16,131.0 16,136.0 6,882.6 6,882.6 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 16,395.0 16,400.0 6,884.7 6,884.7 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 16,655.0 16,660.0 6,883.5 6,883.4 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 16,921.0 16,925.0 6,878.1 6,877.9 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 17,140.0 17,145.0 6,866.2 6,865.9 227NCH, CD3- 113 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 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 3,891.9 3,387.9 CAMCO KBMG 1 GAS LIFT DMY BK 2/12/2019 2 6,963.4 5,617.8 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,970.0 2/11/2019 3 8,450.8 6,623.1 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 2/29/2008 Notes: General & Safety End Date Annotation 1/29/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 3/23/2008 NOTE: Original wellbore drilled in 2007 suspended, re-entered March, 2008; NO Sidetrack 'A' CD3-113, 1/29/2021 10:56:09 PM Vertical schematic (actual) LINER; 9,208.0-17,280.0 PERFP; 17,140.0-17,145.0 PERFP; 16,921.0-16,925.0 PERFP; 16,655.0-16,660.0 PERFP; 16,395.0-16,400.0 PERFP; 16,131.0-16,136.0 PERFP; 15,870.0-15,875.0 APERF; 15,630.0-15,650.0 PERFP; 15,607.0-15,612.0 PERFP; 15,342.0-15,347.0 PERFP; 15,078.0-15,082.0 PERFP; 14,818.0-14,823.0 PERFP; 14,552.0-14,557.0 APERF; 14,500.0-14,520.0 PERFP; 14,290.0-14,295.0 PERFP; 14,034.0-14,039.0 PERFP; 13,768.0-13,773.0 PERFP; 13,503.0-13,507.0 PERFP; 13,245.0-13,250.0 PERFP; 12,986.0-12,991.0 PERFP; 12,723.0-12,728.0 PERFP; 12,458.0-12,463.0 PERFP; 12,193.0-12,198.0 APERF; 12,000.0-12,020.0 PERFP; 11,928.0-11,933.0 PERFP; 11,663.0-11,668.0 PERFP; 11,400.0-11,404.0 PERFP; 11,136.0-11,141.0 PERFP; 10,871.0-10,875.0 PERFP; 10,604.0-10,609.0 PERFP; 10,338.0-10,343.0 PERFP; 10,073.0-10,078.0 PERFP; 9,807.0-9,812.0 PERFP; 9,542.0-9,547.0 INTERMEDIATE; 33.7-9,364.0 WLEG; 9,229.4 XN NIPPLE; 8,606.3 PACKER; 8,561.3 GAUGE; 8,541.8 X NIPPLE; 8,499.2 GAS LIFT; 8,450.8 GAS LIFT; 6,963.4 GAS LIFT; 3,891.9 SURFACE; 36.3-2,619.3 SAFETY VLV; 2,064.1 CONDUCTOR; 40.0-114.0 HANGER; 31.2 WNS PROD CD3-113 ... WELLNAME WELLBORECD3-113 15,630.0 15,650.0 6,879.5 6,879.8 227NCH, CD3- 113 1/29/2021 6.0 APERF 20' of holes, 6 SPF, 60 deg - 2006 PJ Omega HMX - 7.3 gm. 0.22" Ent hole - 21.8" Penetration 15 630 0 15 650 0 6 879 5 6 879 8 227NCH CD3 1/29/2021 6 0 APERF 20' f h l 6 SPF 60 d STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS "LAOC1 V CLJ MAR 17 2020 AOGCC 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Scale Inhibitor Treatment ❑� 2. Operator ConocoPhilllps Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑Q Exploratory ❑ Stratigraphic ❑ Service ❑ 207-004 3. Address: PO Box 100360, Anchorage, AK 99510 6. API Number: 50-103-20541-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 384215, 372105, 264471 CRU CD3 -113 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/POol s): None Colville River Field / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 17338 feet Plugs measured None feet true vertical 6858 feet Junk measured None feet Effective Depth measured 17280 feet Packer measured 8561 feet true vertical 6860 feet true vertical 6677 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 16" 114' 114' Surface 2583' 9.625" 2619' 2474' Intermediate 9330' 7" 9364' 6910' Production Liner 8072' 4.5" 17280' 6860' Perforation depth Measured depth Perf Pups from 9542' - 17145' True Vertical depth 6926'- 6866' Tubing (size, grade, measured and true vertical depth) 4.5" x 3.5", L-80, 9230' MD, 6892' ND Packers and SSSV (type, measured and true vertical depth) Packer- Baker Premier Packer, 8561' MD, 6677' TVD SSSV - Cameo TRMAXX-5E, 2064' MD, 2023' TVD, locked out and WRDP installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9364'- 17338' Treatment descriptions including volumes used and final pressure: See attached summary 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 232 2131 2762 14 19 296 Subsequent to operation: 299 2834 2808 1420 296 14. Attachments (required per20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations ❑Q - Exploratory ❑ Development p ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Ka lie Plunkett contact Name: Kaylie Plunkett Authorized Title: Senior Production Engineer Contact Email: Kaylie.B.Plunketticoo com Authorized SignaturecJ"�Date:3-/3-202-6 Contact Phone: 265-6450 Farm 10-404 Revised 4/2017 RBDMS 114V MAR 2 7 2020 Submit Original Only CD3 -113 Scale Inhibition Treatment 2/11/20 —2/12/20 Hybrid Scale Inhibitor Squeeze Job pumped from 0000 hrs on 2/11/20 to 0200 hrs on 2/12/20. LRS = Little Red Services • Initial pressure TBG/IA/OA-1600/1880/500 • LRS pumped 290 bbls WAW5206/Diesel preflush at 1.0 — 3.0 bpm, TBG/IA/OA —1300/1600/500 • LRS pumped 290 bbls Seawater and SCW3001 scale inhibitor main treatment at 1.5 — 3.0 bpm, TBG/IA/OA — 1500/1600/485 • LRS pumped 3106 bbls Dead Crude/M209 overflush at 1.2-2.6 bpm, TBG/IA/OA- 1200/1660/520 • Final pressure TBG/IA/OA-1200/1660/520 Interval treated: 9,364'— 17,338' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS KLULIVEL) NOV 13 2019 1. Operations Abandon Plug Perforations Ll Fracture Stimulate Pull Tubing Operations shutdown Ll Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Scale Inhibitor Treatment 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑� Exploratory ❑ Stratigraphic ❑ Service ❑ 207-004 3. Address: PO Box 100360, Anchorage, AK 99510 6. API Number: 50-103-20541-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 384215, 372105, 264471 CRU CD3 -113 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): None Colville River Field / Fiord Oil Pool 11. Present. Well Condition Summary: Total Depth measured 17338 feet Plugs measured None feet true vertical 6858 feet Junk measured None feet Effective Depth measured 17260 feet Packer measured 8561 feet true vertical 6860 feet true vertical 6677 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 16" 114' 114' Surface 2583' 9.625" 2619' 2474' Intermediate 9330' 7" 9364' 6910' Production Liner 8072' 4.5" 17280' 6860' Perforation depth Measured depth Perf Pups from 9542' - 17145' True Vertical depth 6926'- 6866' Tubing (size, grade, measured and true vertical depth) 4.5" x 3.5", L-80, 9230' MD, 6892' TVD Packers and SSSV (type, measured and true vertical depth) Packer - Baker Premier Packer, 8561' MD, 6677' TVD SSSV - Carrico TRMAXX-5E, 2064' MD, 2023' TVD, locked out and WRDP installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9364'- 17338' Treatment descriptions including volumes used and final pressure: See attached summary 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 190 958 1 2777 1555 1 275 Subsequent to operation: 88 1132 1 3026 1581 1 291 14. Attachments (required Per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations ❑Q Exploratory ❑ Development ❑] Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Fv] 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: N/A Authorized Name: Ka lie Plunkett Contact Name: Kaylie Plunkett Authorized Title: Senior Engineer Contact Email: Kaylie.B.Plunkettfi�coo corn rProduction Authorized Signature: Date: N-11-11 Contact Phone: 265-6450 V77- /2 /b l 9 Form 10-404 Revised 4/2017 A /' I/� // I � �j V D'•"nj�Q '�11�v NOV 14 [ 9 019 Submit Original Only CD3 -113 Scale Inhibition Treatment 10/14/19 Hybrid Scale Inhibitor Squeeze Job pumped from 1000 - 1700 hrs on 10/14/19. LRS = Little Red Services ACF = Alpine Central Facility - Initial pressure TBG/IA/OA-607/1484/544 - LRS pumped 90 bbls diesel/WAW5206 preflush at 0.4 bpm, TBG/IA/OA - 682/1402 - /506 - LRS pumped 90 bbls seawater and SCW3001 scale inhibitor treatment at 1.5 bpm, TBG/IA/OA - 321/1312/487 - ACF pumped 350 bbls diesel overflush at 1.4 bpm, TBG/IA/OA - 1304/1297/481 - Final pressure TBG/IA/OA-1010/1310/482 Interval treated: 9,364'— 17,338' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS MAR a AlOGUCC 1. Operations Abandon Plug Perforations Fracture Stimulate LJ 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: Scale Inhibitor Treatment ❑� 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Exploratory ❑ Stratigraphic ❑ Service ❑ 207-004 3. Address: PO Box 100360, Anchorage, AK 99510 6. API Number: 50-103-20541-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 384215, 372105, 264471 CRU CD3 -113 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): None Colville River Field / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 17338 feet Plugs measured None feet true vertical 6858 feet Junk measured None feet Effective Depth measured 17280 feet Packer measured 8561 feet true vertical 6860 feet true vertical 6677 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 16" 114' 114' Surface 2583' 9.625" 2619' 2474' Intermediate 9330' 7" 9364' 6910' Production Liner 8072' 4.5" 17280' 6860' Perforation depth Measured depth Pelf Pups from 9542' - 17145' True Vertical depth 6926'-6866' Tubing (size, grade, measured and true vertical depth) 4.5" x 3.5", L-80, 9230' MD, 6892' TVD Packers and SSSV (type, measured and true vertical depth) Packer - Baker Premier Packer, 8561' MD, 6677' TVD SSSV - Carrico TRMAXX-5E, 2064' MD, 2023' ND, locked out and WRDP installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9364'- 17338' Treatment descriptions including volumes used and final pressure: See attached summary 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 304 172 1 2419 1723 445 Subsequent to operation: 1 299 162 1 2360 1723 540 14. Attachments (required Per 20 AAC 25.070, 25.071, &25.283) 15. Well Class after work: Daily Report of Well Operations ❑� Exploratory ❑ Development 2 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: N/A Authorized Name: Ka lie Plunkett Contact Name: Kaylie Plunkett Authorized Title: Senior Production Engineer Contact Email: Kavlie.B.Plunkett0coo.00m Authorized Signature: Date: 3 - 6 - Contact Phone: 265-6450 LI Form 10-404 Revised 412017 M 3115�iy �Ag/j� CiBDM� �MAK 0 8 2019 Submit Original Only CD3 -113 Scale Inhibition Treatment 2/8/19 —2/10/19 Hybrid Scale Inhibitor Squeeze Job pumped from 09:15 hrs on 2/8/19 to 08:30 hrs on 2/10/19. LRS = Little Red Services • Initial pressure TBG/IA/OA-980/1780/526 • LRS pumped 290 bbls WAW5206/Diesel preflush at 2.5-3.0 bpm, TBG/IA/OA —1990/1604/500 • LRS pumped 290 bbls Seawater and SCW3001 scale inhibitor main treatment at 1.5 — 2.5 bpm, TBG/IA/OA — 1490/1525/490 • LRS pumped 2641 bbls Dead Crude/M209 overflush at 1.0-2.8 bpm, TBG/IA/OA- 2000/1500/480 • Final pressure TBG/IA/OA-1700/1500/450 Interval treated: 9,364'— 17,338' MD • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMAIN ' 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 ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Scale Inhibitor Treatment 0 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development El Exploratory ❑ 207-004 3.Address: Stratigraphic❑ Service ❑ 6.API Number: P.O. Box 100360, Anchorage, AK 99510 50-103-20541-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 384215, 372105, 264471 CRU CD3-113 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 17338 feet Plugs measured None feet true vertical 6858 feet Junk measured None feet Effective Depth measured 17280 feet Packer measured 8561 feet true vertical 6860 feet true vertical 6677 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 16" 114' 114' Surface 2583' 9.625" 2619' 2474' Intermediate 9330' 7" 9364' 6910' RECEIVED Production Liner 8072' 4.5" 17280' 6860' Perforation depth Measured Depth: Perf Pups from 9542'- 17145' MAR 0 9 2018 True Vertical Depth: 6926'-6866' SCANNEDAOGCC Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 9230' MD, 6892'TVD Packers and SSSV(type,measured and true vertical depth) Packer-Baker Premier Packer,8561'MD,6677'TVD SSSV-Camco TRMAXX-5E,2064'MD,2023'TVD, locked out and WRDP installed 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9542'- 16364'CTMD Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 795 708 2875 1713 281 Subsequent to operation: 729 737 3240 1849 313 14.Attachments(required per 20 AAc 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ DevelopmentL Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Kaylie Plunkett /Ak)V , QntS- Email Kaylie.B.Plunkettcop.com Printed Name Kaylie Plunkett Title Production Engineer Signature ,,,: 9 Phone2711 1 g 265-6450 Date vT` 3/16// ' ,!G /AO, RBDMS LL K,A, 2018 Form 10-404 Revised 5/2015 Submit Original Only • • CD3-113 Scale Inhibition Treatment 2/12/18—2/14/18 Non-Aqueous Scale Inhibitor Squeeze Treatment pumped from 16:15 hrs on 2/12/18 to 01:00 hrs on 2/14/18. LRS= Little Red Services CT=Schlumberger Coiled Tubing - Initial pressure TBG/IA/OA—255/1988/513 - RIH with CT to 14880' CTMD - Pumped 290 bbls Diesel/M209/WAW5206 pre-flush through CT at 1.3 bpm while pulling CT from 14880'—9542' CTMD. TBG/IA/OA—1635/1741/435 - RBIH with CT to 16364' CTMD - Pumped 290 bbls 70/30 EG/Seawater and SCW3001 scale inhibitor through CT at 1.3 bpm while pulling CT from 16364'—9542' CTMD. TBG/IA/OA—1600/1605/421 - POOH with CT. LRS pumped 2644 bbls dead crude/M209 over-flush at 1.4—3.3 bpm. TBG/IA/OA—2970/1842/517 Interval treated: 9542'—16364' CTMD RECEIVED 111 STATE OF ALASKA OCT 2 5 Z017 ALASKA OIL AND GAS CONSERVATION COMMIWON REPORT OF SUNDRY WELL OPERATIONS AOGCC 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:Scale Inhibitor Treatment 0 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ❑ 207-004 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage,AK 99510 50-103-20541-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 384215, 372105, 264471 CRU CD3-113 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 17338 feet Plugs measured None feet true vertical 6858 feet Junk measured None feet Effective Depth measured 17280 feet Packer measured 8561 feet true vertical 6860 feet true vertical 6677 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 16" 114' 114' Surface 2583' 9.625" 2619' 2474' Intermediate 9330' 7" 9364' 6910' Production Liner 8072' 4.5" 17280' 6860' Perforation depth Measured Depth: Peri Pups from 9542'- 17145' SCANNED DEC 2 '7 2017 True Vertical Depth: 6926'-6866' Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 9230' MD, 6892'TVD Packers and SSSV(type,measured and true vertical depth) Packer-Baker Premier Packer, 8561' MD,6677'TVD SSSV-Camco TRMAXX-5E, 2064'MD, 2023'TVD, locked out and WRDP installed 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9364'- 17338' Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 709 1155 2841 1686 307 Subsequent to operation: 688 947 2984 1693 300 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 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.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Kaylie Plunkett Email Kavlie.B.Plunkettaacop.com Printed Name Kaylie Plunkett Title Production Engineer Signature -741:, P/AJt=c19 Phone 265-6450 Date 16-Z 5- l-7 177/-7, !z/7-/r 7 e 7 RBDJS O .' ULA 7 2017 Form 10 404 Revised 5/2015 X/7// Submit Original Only • CD3-113 Scale Inhibition Treatment 9/24/17 Hybrid Scale Inhibitor Squeeze Job pumped from 12:00 hrs to 20:25 hrs on 9/24/17. LRS= Little Red Services ACF=Alpine Central Facility • Initial pressure TBG/IA/OA—267/1674/553 • LRS pumped 90 bbls WAW5206/Diesel preflush at 1.25 bpm,TBG/IA/OA—1000/1520/500 • LRS pumped 90 bbls 70/30 EG/Seawater and SCW3001 scale inhibitor main treatment at 1.25 bpm,TBG/IA/OA—400/1448/479 • ACF pumped 350 bbls Diesel overflush at .92- 1.04 bpm,TBG/IA/OA-1535/1433/483 Interval treated: 9,364'—17,338' MD STATE OF ALASKA AIIIKA OIL AND GAS CONSERVATION COMM ION 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 ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Scale Inhibitor Treatment 0 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development I] Exploratory ❑ 207-004 3.Address: Stratigraphic❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage, AK 99510 50-103-20541-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 384215, 372105, 264471 CRU CD3-113 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 17338 feet Plugs measured None feet true vertical 6858 feet Junk measured None feet Effective Depth measured 17280 feet Packer measured 8561 feet true vertical 6860 feet true vertical 6677 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 16" 114' 114' Surface 2583' 9.625" 2619' 2474' SCANNED APR 1 8 201 . Intermediate 9330' 7" 9364' 6910' Production Liner 8072' 4.5" 17280' 6860' Perforation depth Measured Depth: Peri Pups from 9542'- 17145' RECEIVED True Vertical Depth: 6926'-6866' MAR 2 4 2017 Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 9230' MD, 6892'TVD p V OG C Packers and SSSV(type,measured and true vertical depth) Packer-Baker Premier Packer,8561'MD,6677'TVD �1 SSSV-Camco TRMAXX-5E,2064'MD,2023'ND, locked out and WRDP installed 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9364'- 17338' Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 964 3016 2679 1526 362 Subsequent to operation: 894 3015 2726 1651 352 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Ill Exploratory❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil I] Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ LI WAG ❑ GINJ❑ SUSPLI SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact John Cookson Email John.Cookson@cop.com Printed Name .JdI)F'CO•.\ on ; Title Principal Petroleum Engineer Signature itkj Phone 265-6547 Date -V'Z`V/7 v L- 3/z 6/ /y1X Form 10-404 Revised 5/2015 RBD IS t . ,41A R Z 4 2017 Submit Original Only 1 • S CD3-113 Scale Inhibition Treatment 2/20/17—2/22/17 Hybrid Scale Inhibitor Squeeze Job pumped from 21:45 hrs on 2/20/17 to 12:00 hrs on 2/22/17. LRS= Little Red Services • Initial pressure TBG/IA/OA-175/1526/486 • LRS pumped 290 bbls WAW5206/M209/Diesel preflush at 2.25-2.45 bpm,TBG/IA/OA— 1960/1491/460 • LRS pumped 290 bbls Seawater and SCW720 scale inhibitor main treatment at 2.1—2.5 bpm, TBG/IA/OA—1440/1440/442 • LRS pumped 2644 bbls Dead OiI/M209 overflush at 1.0—2.5 bpm,TBG/IA/OA—1913/1362/266 Interval treated: 9,364'—17,338' STATE OF ALASKA RECEIVED AIL OIL AND GAS CONSERVATION COMAION OCTC t � REPORT OF SUNDRY WELL OPERATIONS OGCC 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:Scale Inhibitor Treatment ❑✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑✓ Exploratory ❑ 207-004 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage, AK 99510 50-103-20541-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 384215, 372105, 264471 CRU CD3-113 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 17338 feet Plugs measured None feet true vertical 6858 feet Junk measured None feet Effective Depth measured 17280 feet Packer measured 8561 feet true vertical 6860 feet true vertical 6677 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 16" 114' 114' Surface 2583' 9.625" 2619' 2474' Intermediate 9330' 7" 9364' 6910' Production Liner 8072' 4.5" 17280' 6860' Perforation depth Measured Depth: Perf Pups from 9542'- 17145' SCANNED FEB 17 True Vertical Depth: 6926'-6866' Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 9230' MD, 6892'TVD Packers and SSSV(type,measured and true vertical depth) Packer-Baker Premier Packer, 8561' MD, 6677'TVD SSSV-Camco TRMAXX-5E,2064'MD, 2023'TVD, locked out and WRDP installed 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9364'- 17338' Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1021 1991 2512 1575 327 Subsequent to operation: 1039 2136 2550 1765 323 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q 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.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact John Cookson Email John.Cookson@cop.com Printed Name (32.,...14-1400 on Title Principal Petroleum Engineer Signature Phone 265-6547 Date ?-27—(‘ b jVTV 6a l/,t-0t /�Form 10-404 Revised 5/2015 if 1O( z'%G RBDMS O�,T 0 2016 Submit Original Only • • CD3-113 Scale Inhibition Treatment 9/4/16 Non-Aqueous Scale Inhibitor Squeeze Job pumped from10:32 hrs to 23:08 hrs on 9/4/16. LRS= Little Red Services ACF=Alpine Central Facility • Initial pressure TBG/IA/OA—295/1563/578 • LRS pumped 18 bbls WAW5206 preflush at .25 bpm while ACF pumped 72 bbls Diesel at 1 bpm, TBG/IA/OA—1132/1464/532 • LRS pumped 90 bbls 70/30 EG/Water and SCW3001WC scale inhibitor main treatment at 1.5 bpm,TBG/IA/OA—710/1374/504 • ACF pumped 500 bbls Diesel overflush at .7- 1 bpm,TBG/IA/OA—1739/1351/502 Interval treated: 9,364'—17,338' I. WNS PROD •w CD3-113 ConocoPhillips ; Well Attributes Max Angle&MD TD AlaSlca,Inc. ' Wellbore API/UWI Field Name Wellbore Status ncl C) MD(ftKB) 'Act Btm(ftKB) ccxv.rottollipc 501032054100 FIORD NECHELIK PROD 93.60 17,018.27 17,338.0 Comment H2S(ppm) Date Annotation End Date 613-Grd(ft) -Rig Release Date CD3-113,112720154:09'03 PM SSSV:LOCKED OUT Last WO: 42.61 2/4/2007 Vertmal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date --- -- -HANGER,31.2- tt,h31 Last Tag: Rev Reason:RESET WRDP lehallf 1/27/2015 Casing Strings CONDUCTOR;40.0-114.0 I I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 40.0 114.0 114.0 62.50 H-40 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread • SURFACE 95/8 8.835 36.3 2,619.3 2,474.3 40.00 L-80 BTCM SAFETY VLV;2,064.1 CasingDescription OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread WRDP;2,064.1 ,ii.' INTERMEDIATE 7 6.276 33.7 9,364.0 6,910.2 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread I LINER 41/2 3.958 9,208.0 17,280.0 6,859.6 12.60 L-80 IBTM SURFACE;36.3-2.6193 Liner Details Nominal ID GAS LIFT;3,8913 Top(ftKB) Top IND)(ftKB) Top Incl(°) Item Des Com (in) 9208.0 6,887.8 78.90 SLEEVE Baker 5"x 7"HR Liner Setting Sleeve 4.420 9,220.9 6,890.3 79.37 NIPPLE RS Nipple 4.250 GAS LIFT;6,963.4 9,224.5 6,890.9 79.51 HANGER Baker 5"X 7"DG Flex-lock Liner Hanger 4.420 9,234.4 6,892.7 79.87 XO Bushing XO Bushing 3.940 GAS LIFT;8,450.8 r Tubing Strings ■■ Tubing Description String Ma...ID I (in Top(ftKB) Set Depth(ft.Set Depth(TVD)(...Wt(INR) Grade Top Connection NIPPLE;8,499.2 lam: TUBING 4.5"x3.5" 3121 )2.9921 31.21 9,230.41 6,892.01 9.301 L-80 IEUEM @132.6' GAUGE:8541.8Completion Details PACKER;8.561.3 � .. Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) I 31.2 31.2 0.00 HANGER FMC 4 1/2"Tbg hanger w/228'pup 3.980 NIPPLE;8,6116.3 132.6 132.6 0.39 XO-Reducing XO-3 1/2"EUE(P)X 4 1/7'IBTM(B) 5.1875"OD x 3" 3.000 ID 2,064.1 2,023.0 28.37 SAFETY VLV Camco 3.5"TRMAXX-5E SSSV(LOCKED OUT 2.812 WLEG;9,229.4. 4/27/2010) 8,499.2 6,647.4 60.67 NIPPLE HES"X"Nipple 2.813"ID 2.813 8,541.8 6,667.7 62.16 GAUGE Baker Gauge Carrier 2.992 8,561.3 6,676.7 62.86 PACKER 3.5"X 7"Baker Premier PACKER 2.875 INTERMEDIATE;33.79 PERFP;9,542.0-9,547.0--::titi l• No Go PERFP;9.807.0-9.812.0-_- 9,229.4 6,891.8 79.69 WLEG 3.000 PERFP;10,073.0.10,078A-_ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PERFP;10,338.0-10,343.0-_ Top(ND) Tap Incl in- �- Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) _ 2,064.1 2,023.0 28.37 WRDP •3.5"WRDP-2 w/2.81"XX-Lock(HTS-614)2.84" 1/25/2014 1.562 PERFP;10,604.0.10.609.0- - - PACKING(sal=89.5") PERFP;10,871.0-10,075.0-- in = Perforations&Slots I=7 - Shot PERFP;11,136.0-11,141.0-:-iii Dens Top(TVD) Bhn(ND) (shots/f PERFP;11,400.0-11,404.0 � Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) TYPO Com i- jsji�- 9,542.0 9,547.0 6,926.1 6,926.5 227NCH,CD3 223/2008 1.0 PERFP Six 1/2"holes per Peri PERFP;1103.0-11,668.0-:- - -113 Pup _ 9,807.0 9,812.0 6,933.8 6,933.7 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/7'holes per Perf PERFP;11,928.041,933.0_:'t-l1 -113 Pup • PERFP;12,193.0.12,198.0-- ;mii 10,073.0 10,078.0 6,925.5 6,925.3 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -111. -113 Pup PERFP;12,458.012,463.0-;,#a,;- 10,338.0 10,343.0 6,917.5 6,917.3 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/7'holes per Perf -113 Pup PERFP;12.723.0-12,728.0 - • 10,604.0 10,609.0 6,909.1 6,908.9 227NCH,CD3 223/2008 1.0 PERFP Six 12"holes per Perf PERFP;12,986.0-12,991.0-- - -113 Pup - tit: 10,871.0 10,875.0 6,916.1 6,916.2 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;13,245.0.13,250.0- ti I- -113 Pup --- 11,136.0 11,141.0 6,910.9 6,910.8 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -�. T. -- 113 PDP PERFP;13.503.0-13,607.0-= 11,400.0 11,404.0 6,906.2 6,906.1 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf --- -113 Pup PERFP;13768.0.13,773.0- '+0-E 11 663.0 11,668.0 6,902.5 6,902.6 227NCH,CD3 2232008 1.0 PERFP Six 12"holes per Perf -113 Pup PERFP;14,034.0.14,039.0 'X23:' - • 11,928.0 11,933.0 6,906.8 6,906.8 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf _■- -113 Pup PERFP;14,290.0.14295.0 Cif - 12 193.0 12,198.0 6,905.1 6,905.2 227NCH,CD3 2232008 1.0 PERFP Six 1/2"holes per Perf - if -113 Pup PERFP;14,562.0-14557.0-_l itiE 12,458.0 12,463.0 6,905.0 6,905.0 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf _ -113 Pup PERFP;14,818.014,823.0 '::GR. - j-- 12,723.0 12,728.0 6,904.5 6,904.6 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf - itti.. ' -113 Pup PERFP;15,078.015,082.0- 12,986.0 12,991.0 6,911.9 6,911.9 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf --- -113 Pup PERFP;15,342.015,347.07 l XV _ 13,245.0 13,250.0 6,905.7 6,905.5 227NCH,CD3 223/2008 1.0 PERFP Six 12"holes per Perf PERFP;15,607.0.15,612.0--- -113 Pup PERFP:15.6700.15.875.0- t, -• 13,503.0 13,507.0 6,895.4 6,895.1 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -113 Pup PERFP;16.131.0.16,136.0 --- 13,768.0 13,773.0 6,884.1 6,884.1 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf - -113 Pup -t - 14,034.0 14,039.0 6,882.9 6,882.8 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;16,395.016,400.0 -i-ig ;- -113 Pup -:- 14,290.0 14,295.0 6,877.7 6,877.7 227NCH,CD3 223/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;16,055.0.16.660.0 y4 -113 Pup In 14,552.0 14,557.0 6,877.5 6,877.5 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;16.921.0.16,925.0-=i;n:i- -113 Pup ' 14,818.0 14,823.0 6,877.6 6,877.6 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -113 Pup PERFP;17,1404-17,1450 - a,..,- LINER;9,208.0.17.280.0- z WNS PROD • CD3-113 ConocoPhillips a Alaska,Inc. Co.-..ita6ps CO3.113,1272015 4:09:05 PM Vertical sohematIc(actual) .HANGER;31.2— 4;. ot,ip^ip T Perforations&Slots malow CONDUCTOR;40.0-114.0 I Shot -- Den no Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SAFETY VLV;2,064.1 15,078.0 15,082.0 6,875.8 6,875.8 227NCH,CD3 223/2008 1.0 PERFP Six 1/2"holes per Pert WRDP,2,0641 -'f -113 Pup 15,342.0 15,347.0 6,875.0 6,875.1 227NCH,CD3 223/2008 1.0'PERFP Six 1/2"holes per Perf 1 -113 Pup SURFACE;38.3-2,819.3 . 15,607.0 15,612.0 6,879.1 6,879.2 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -113 Pup GAS LIFT;3,891.9 15,870.0 15,875.0 6,881.4 6,881.4 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -113 Pup 16,131.0 16,136.0 6,882.6 6,882.6 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/7'holes per Perf GAS LIFT;6,963.4 -113 Pup 16,395.0 16,400.0 6,884.7 6,884.7 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Pert -113 Pup GAS LIFT;8,450.8 S 16,655.0 16,660.0 6,883.5 6,883.4 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Pert NIPPLE;8,499.2 '113 Pup IC16,921.0 16,925.0 6,878.1 6,877.9 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Peri GAUGE;8.541-8 -113 Pup PACKER;6,561.3 17,140.0 17,145.0 6,866.2 6,865.9 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf M -113 Pup NIPPLE;8,606.3 I Mandrel Inserts St on Top(TVD) Valve Latch Port Size TRO Run WLEG;9,229.4 '' I N Top(ftKB) (8Ke) Make Model 00(in) Sery Type Type (in) (psi) Run Date Cons .1' 3,891.9 3,387.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.250 1,870.0 3/1/2008 2 6,963.4 5,617.8 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 2/20/2011 3 8,450.8 6,623.1 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 2/29/2008 Notes:General&Safety INTERMEDIATE;33.7-9,361.0 End Date Annotation PERFP;9,542.09,547.0 ifil::- 323/2008 NOTE:Original wellbore drilled in 2007 suspended,re-entered March,2008;NO Sidetrack'A' PERFP;9,807.09,812.0- !-- 129/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 PERFP;10,073.010,078.0 :- ..N6::_ —-_ PERFP;10,338.0-10,343.0— i)$l mat PERFP;10,604.0-10,609.0— 4} — PERFP;10,871.0-10,875.0— i 0 r — .Di — PERFP;11,136.0-11,141.0—�— :W: — PERFP;11,400.0-11,404.0 i;p:i PERFP;11,663.011,668,0--I PERFP;11,928.0-11,933.0 --_. — fl:--a _ PERFP;12,193.0-12,198.0— � PERFP;12,458.0-12,463.0— :tt: PERFP;12,723.0-12,728.0= - _ PERFP;12,986.0-12,991.0 —'-— —- PERFP;13,245.0-13,250.0— :M: PERFP;13,503.0-13,507.0-- l - --_ PERFP;13,768.013,773.0— ::808 PERFP;14,034.0-14,039.0— ;:_:}:: ■ PERFP;14.290.0.14.255.0— {y ---- PERFP;14,552.014,557.0— ::ra_::_ —_ PERFP;14,818.0-14,823.0 ::1_:. PERFP;15,078.015,082.0 _ :ft:: — III:_ -_ PERFP;15,342.015,347.0— :;6_t_:: PERFP;15,607.015,612.0— _ PERFP;15,870.0-15,875.0 ::(y PERFP;16,131.016,136.0--;- _ ■ PERFP;16,395.016,400.0— ii77 - :ft: PERFP;16,655.0-16,660.0 -— PERFP;16,921.0-16,925.0— r- i PERFP;17,140.0-17,145.0— • LINER;9,208.017,280.0— STATE OF ALASKA • APSKA 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 ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:Scale Inhibitor Treatment Li 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ❑ 207-004 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360, Anchorage,AK 99510 50-103-20541-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 384215, 372105, 264471 CRU CD3-113 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 17338 feet Plugs measured None feet true vertical 6858 feet Junk measured None feet Effective Depth measured 17280 feet Packer measured 8561 feet true vertical 6860 feet true vertical 6677 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 16" 114' 114' Surface 2583' 9.625" 2619' 2474' Intermediate 9330' 7" 9364' 6910' :RECEIVED Production Liner 8072' 4.5" 17280' 6860' MAR 10 2016 Perforation depth Measured Depth: Perf Pups from 9542'- 17145' SCANNEV M ,.-, ! .(; AOGCC True Vertical Depth: 6926'-6866' Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 9230' MD, 6892'TVD Packers and SSSV(type,measured and true vertical depth) Packer-Baker Premier Packer, 8561' MD,6677'TVD SSSV-Camco TRMAXX-5E,2064'MD, 2023'TVD, locked out and WRDP installed 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9364'- 17338' Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1274 3071 2044 1420 345 Subsequent to operation: 1165 3316 2411 1564 350 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development E Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil E Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 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 N/A Contact Kerry Freedman Email Kerry.C.Freedmanncop.com Printed Name Kerry Freedman Title Principal Production Engineer Signature Z, -1/1.4.4424.----‘____ Phone 265-6579 Date 3f 7 ii 6 v1-1- iii 1-1lii 1 if- RBDMS u MAR 1 1 2016 Form 10-404 Revised 5/2015 ,//y4 Submit Original Only • • CD3-113 Scale Inhibition Treatment 2/11/16—2/12/16 Non-Aqueous Scale Inhibitor Squeeze Job pumped from12:00 hrs on 2/11/16 to 08:05 hrs on 2/12/16. LRS= Little Red Services • Initial pressure TBG/IA/OA—933/1411/506 • LRS pumped 290 bbls WAW5206/Diesel/M209 preflush at 1-4 bpm,TBG/IA/OA— 1708/1280/468 • LRS pumped 290 bbls 70/30 EG/Water and SCW3001WC scale inhibitor main treatment at 1- 3.7 bpm,TBG/IA/OA—929/1251/472 • LRS pumped 1686 bbls Dead Crude overflush at 1—3 bpm,TBG/IA/OA—1978/1220/452 Interval treated: 9,364'—17,338' • • • WNS PROD CD3-113 CQi1QCQ illipSWell Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) conn,,, alip, 501032054100 FIORD NECHELIK PROD 93.60 17,018.27 17,338.0 •-• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date CO3-113,1/2720154;0903 PM SSSV:LOCKED OUT Last WO 42.61 2/4/2007 Vertical schematic(actual) Annotation Depth(ftK8) End Date Annotation Last Mod By End Date HANGER;312- -:..a .rc Last Tag: Rev Reason:RESET WRDP lehallf 1/27/2015 Casing Strings CONDUCTOR,40.0.114.0 II Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 40.0 114.0 114.0 62.50 H-40 Welded III Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 36.3 2,619.3 2,474.3 40.00 L-80 BTCM SAFETY VLV;2,064.1 Casing Description OD(In) ID(in) Top(ftKB) Set Depth((KB) Set Depth(ND)... Wt/Len(I...Grade Top Thread WRDP:2064.1 -.l' INTERMEDIATE 7 6.276 33.7 9,364.0 6,910.2 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread I LINER 4 1/2 3.958 9,208.0 17,280.0 6,859.6 12.60 L-80 IBTM SURFACE;36,3-2,619.3 l Liner Details Nominal ID GAS LIFT;6891,9 Top(ftKB) Top(ND)(ftKB) Top Incl(') Item Des Com (in) 9,208.0 6,887.8 78.90 SLEEVE Baker 5"x 7"HR Liner Setting Sleeve 4.420 9,220.9, 6,890.3 79.37 NIPPLE RS Nipple 4.250 GAS LIFT;6.963.4 9.224.5 6,890.9 79.51 HANGER Baker 5"X 7"DG Flex-lock Liner Hanger 4.420 • 9,234.4 6,892.7 79.87 XO Bushing XO Bushing 3.940 GAS LIFT;8,450.8 ._ Tubing Strings NIPPLE;8.499.2 I,tTubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 4.5"x3.5" 312 2.992 31.2 9,230.4 6,892.0 9.30 L-80 EUEM II @132.6' GAUGE;8,541.8 Completion Details PACKER;8,561.3 01:1'_'111'I Nominal ID 1 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) NIPPLE;8606331.2 31.2 0.00 HANGER FMC 4 1/2"Tbg hanger w/2.28'pup 3.980 1 132.6 132.6' 0.39 XO-Reducing XO-3 12"EUE(P)X 4 1/2"IBTM(B) 5.1875"OD x 3" 3.000 -" ID 2,064.1 2,023.0 28.37 SAFETY VLV Camco 3.5"TRMAXX-5E SSSV(LOCKED OUT 2.812 WLEG;9229.4 .,-._-1 4272010) 8,499.2 6,647.4 60.67 NIPPLE 'HES"X"Nipple 2.813"ID 2.813 8,541.8 6,667.7 62.16 GAUGE Baker Gauge Carrier 2.992 8,561.3 6,676.7 62.86 PACKER 3.5"X 7"Baker Premier PACKER 2.875 INTERMEDIATE;33.7-9,364.0 _ 8,606.3 6,696.7 64.47 NIPPLE 3.5"HES"XN"NIPPLE 4.25"OD x 2.813 ID w/2.75" 2.750 PERFP;9,542.09.547.0 _- 1-I-- No Go PERFP;9,807.09,8120- 9,229.4 6,891.8 79.69 WLEG 3.000 PERFP.10,073.0-10,078.0-_ _ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PERFP;10,338.0.10.343.0 Top(ND) Top Incl _ _ Top(ftKB) (ftKB) (") Des Com Run Date ID(in) _ 2,064.1 2,023.0 28.37 WRDP 3.5"WRDP-2 w12.81"XX-Lock(HTS-614)2.84" 1/25/2014 1.562 PERFP;10,604.0.10,609.0-::_li_ �- PACKING(oal=89S") PERFP;10.671.0-10,875.0-1 i 0I 1_ Perforations&Slots Shot PERFP;11,136.0-11,141.0=ii Dens Top(TVD) Btm(ND) (shots/f PERFP;11,400.0-11.404.0 i i H;i- Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com -coo.- 9,542.0 9,547.0 6,926.1 6,926.5 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Pert PERFP;11,663.0-11,668.0--•44-•_ -113 Pup PERFP;11,928.0.11,933.0=..- 9,807.0 9,812.0 6,933.8 6,933.7 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2'holes per Perf _-_ -113 Pup PERFP;12193.0-12,198.0- I III 10,073.0 10,078.0 6,925.5 6,925.3 227NCH,CD3 2/23/2008 1,0 PERFP Six 1/7'holes per Perf 113 Pup PERFP;12.450.Q72.463.0=- 10,338.0 10,343.0 6,917.5 6,917.3 227NCH,CD3 223/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;12,723.0.12,728.0--- i°I: - -113 Pup : PERFP;12.986.0.12,991.0= _ 10,604.0 10,609.0 6,909.1 6,908.9 227NCH,CD3 2/23/2008 1.0 PERFP Six 12"holes per Perf 11-1`1 -113 Pup }--j 10,871,0 10,875.0 6,916.1 6,916.2 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;13,245.0-13,2500-T i rt -113 Pup -I.- 11,136.0 11,141.0 6,910.9 6,910.8 227NCH,CD3 223/2008 1.0 PERFP Six 1/2"holes per Perf _i IV:- -113 Pup PERFP;13,503.0-13,507.0= 'f_f 11,400.0 11,404.0 6,906.2 6,906.1 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Pert ---- -113 Pup PERFP;13,768.0-12773.0 = ttt.- - 11,663.0 11,668.0 6,902.5 6,902.6 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;14,034.0-14.039.0- -113 Pup- 11,928.0 11,933.0 6,906.8 6,906.8 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -- - -113 Pup PERFP;14,290.0.14,295.0 - }!! - 12,193.0 12,198.0 6,905.1 6,905.2 227NCH,CD3 2232008 1.0 PERFP Six 1/2"holes per Perf --- -113 Pup PERFP;14652.0-14557.0_'1E11' 12,458.0 12,463.0 6,905.0 6,905.0 227NCH,CD3 2/23/2008 ' 1.0 PERFP Six 1/2'holes per Perf PERFP;14.818.0.14823.0- -113 Pup . 12,723.0 12,728.0 6,904.5 6,904.6 227NCH,CD3 223/2008 1.0 PERFP Six 1/2'holes per Pert i{i(i 1.1-_ -113 Pup PERFP;15,078.0.15,082.0-- 12,986.0 12,991.0 6,911.9 6,911.9 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2'holes per Pert PERFP;15,342.0-15,347.0- - -113 Pup - - 13,245.0 13,250.0 6,905.7 6,905.5 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;15,607.0-15.612.0-_•18111:_ -113 Pup - 13,503.0 13,507.0 6,895.4 6,895.1 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;15,870.0-16875.0-- lit 113 Pup PERFP;16131.0-05136.0 - ,- 13,768.0 13,773.0 6,884.1 6,884.1 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/7'holes per Perf -113 Pup PERFP;16.395.0-t6.a000- • 14,034,0 14,039.0 6,882.9 6,882.8 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf _: t:- -113 Pup -.- 14,290.0 14,295.0 6,877.7 6,877.7 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;16,655.0-16,6600- vii -113 Pup 14,552.0 14,557.0 6,877.5 6,877.5 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;16921.0-16,925.0=i in:- -113 Pup it 14,818.0 14,823.0 6,877.6 6,877.6 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;17,140.0.17,145.0- gti -113 Pup__ LINER;9,208.0.17,280.0 0 w 9 WNS PROD CD3-113 ConocoPhillips Alaska,Inc. COrksmitattipe CD3-113.1/272015 4.0905 PM Vertical schematic(actual) HANGER;31 2—gr,n)apT,1 Perforations&Slots .,,yy"a1u' ShotCONDUCTOR;40.0-1140 I l Dens Top(TVD) Btm(TVD) (shotslf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SAFETY VLV;2.064.1 15,078.0 15,082.0 6,875.8 6,875.8 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf WRDP;2.064.1 — , -113 Pup 15,342.0 15,347.0 6,875.0 6,875.1 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf 1 -113 Pup SURFACE;36.3-2,619.3 l 15,607.0 15,612.0 6,879.1 6,879.2 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -113 Pup GAS LIFT;88.91.9 15,870.0 15,875.0 6,881.4 6,881.4 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf 113 Pup 16,131.0 16,136.0 6,882.6 6,882.6 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf GAS LIFT;6.963.4 -113 Pup 16,395.0 16,400.0 6,884.7 6,884.7 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -113 Pup GAS LIFT;8.450.8—$. ___ 16,655.0 16,660.0 6,883.5 6,883.4 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2'holes per Perf NIPPLE;8,499.2 -113 Pup 16,921.0 16,925.0 6,878.1 6,877.9 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2'holes per Perf GAUGE;6541.8 - _ -113 Pup PACKER;8,561.3 ,tt 17,140.0 17,145.0 6,866.2 6,865.9 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -113 Pup NIPPLE;8,606.3 Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run WLEG;9229.4 I;' '•I N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 3,891.9 3,387.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.250 1,870.0 3/1/2008 2' 6,963.4 5,617.8 CAMCO KBMG 1 GAS LIFT DMY BK 0.000' 0.0 2/20/2011 3 8450.8 6,623.1 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 229/2008 Notes:General&Safety INTERMEDIATE;33.79,364.0 End Date Annotation PERFP;9s42.0-9s47.0 :-tap: 3/23/2008 NOTE:Original wellbore drilled in 2007 suspended,re-entered March,2008;NO Sidetrack'A' PERFP;9,807.09,812.0_ 1/29/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 PERFP;10,073.0-10.078.0--I 151:I_ _=� _ PERFP;10,338.0-10,343.0 . l; PERFP;10.604.0-10,609.0- -t-� PERFP;10,871.0-10,875.0—_ �_ los.PERFP;11,136.0-11.141.0— it-it I PERFP;11,400.0-11,404.0 i i . — i 0 Uii PERFP;11,663.0.11,668.0—:r PERFP;11,928.0-11.933.0— ' imi PERFP;12,193.0-12.198.0— l a; PERFP;12,458.0-12,463.0—l• — PERFP;12,723.0.12,728.0--- PERFP;12,986.0-12,991.0—:EEC I --y _ PERFP;13,245.0-13,250.0— I:11 PERFP;13503.0.13507.0—i i PERFP;13.768.0-13,773.0— ::}_i: PERFP;14.034.0-14.039.0— ::tt: ■_ PERFP;14,290.0-14,295.0 s{a{ PERFP;14,552.0-14,557.0— ,t=t:': PERFP;14,618.0.14,823.0—::l-t: PERFP;15.078.0-15,082.0—_ :lir, _ PERFP;15.342.0-15847.0— ;lll-llt11;.. PERFP;15,607.0-15,612.0—.' _ PERFP;15.870.0-15.875.0—I: , PERFP;16.131.0.16.136.0— — PERFP;16,395.0-16,4000— Ili PERFP;16,605.0-16.660.0— _ PERFP;16,921.0-16.925.0— , i,Iil i PERFP;17,140.0.17,145.0— LINER;9,208.0-17280.0 STATE OF ALASKA 0 • AKA 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 ❑ Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well ❑ Other: Scale Inhibitor Treatment Q 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ❑ 207-004 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage,AK 99510 50-103-20541-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 384215, 372105, 264471 CRU CD3-113 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 17338 feet Plugs measured None feet true vertical 6858 feet Junk measured None feet Effective Depth measured 17280 feet Packer measured 8561 feet true vertical 6860 feet true vertical 6677 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 16" 114' 114' Surface 2583' 9.625" 2619' 2474' Intermediate 9330' 7" 9364' 6910' Production Liner 8072' 4.5" 17280' 6860' RECEIVED Perforation depth Measured Depth: Perf Pups from 9542'- 17145' True Vertical Depth: 6926'-6866' �� , - NOV 24 2015 Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5", L-80, 9230' MD and 6892'TVD 4OGCC Packers and SSSV(type,measured and true vertical depth) Packer-Baker Premier Packer, 8561'MD and 6677'TVD SSSV-Camco TRMAXX-5E,2064'MD and 2023'TVD, locked out and WRDP installed 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9364'- 17338' Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: _ 1318 2106 2060 1554 316 Subsequent to operation: 1377 2609 2048 1499 332 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: None Contact Kerry Freedman Email Ken ry.C.Freedman(a�cop.com Printed Name Kerry Freedman I1 Title Principal Production Engineer 1 Signature f` '7iu�-x�c�-- ---- Phone 265-6579 Date 023 3 (1,1— i _ /2//5— RBDMS/fQV 2 5 2015 Form 10-404 Revised 5/2015 / / /d.-_- Submit Original Only • • CD3-113 Scale Inhibition Treatment 10/29/2015 Non-Aqueous Scale Inhibitor Squeeze Job pumped 10/29/15 from 10:12—21:27 hrs. LRS= Little Red Services ACF=Alpine Central Facility - Initial pressure TBG/IA/OA—289/1540/524 - LRS pumped 90 bbls WAW5206/Diesel pre-flush at 2 bpm,TBG/IA/OA—916/1393/472 - LRS pumped 90 bbls 70/30 EG/Water and SCW3001WC scale inhibitor main treatment at 2 bpm, TBG/IA/OA—422/1295/444 - ACF pumped 500 bbls Diesel over-flush at .8—1 bpm,TBG/IA/OA—1652/1331/477 Interval treated: 9,364'—17,338' STATE OF ALASKA ' AL KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed Abandon r Repair w ell r Rug Perforations r Perforate rOther Scale Inhibitor Alter Casing r Pull Tubing r Stimulate-Frac Waiver Treatment r r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. Development r Exploratory r 207-004 - 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20541-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 384215,372105,264471 CRU CD3-113 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 17338 feet Plugs(measured) None true vertical 6858 feet Junk(measured) None Effective Depth measured 17280 feet Packer(measured) 8561 true vertical 6860 feet (true vertical) 6677 Casing Length Size MD TVD Burst Collapse Conductor 74' 16" 114 114 Surface 2583' 9.625" 2619 2474 Intermediate 9330' 7" 9364 6910 Liner 8072' 4.5" 17280 6860 RECEIVED SCAMMED MAY' 122015 APR 282015 Perforation depth: Measured depth: perf pups from 9542'-17145' True Vertical Depth: 6926-6866' AOGCC Tubing(size,grade,MD,and TVD) 4.5 x 3.5, L-80, 9230 MD and 6892 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PACKER @ 8561 MD and 6677 TVD SSSV-CAMCO TRMAXX-5E SSSV @ 2064 MD and 2023 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9364'-17338' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1284 1439 2065 1563 329 Subsequent to operation 1171 1108 2231 1573 316 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil F Gas r VVDSPL r Daily Report of Well Operations XXX GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt. none Contact Kerry Freedman Email Kerrv.C.Freedmancop.com Printed Name Kerry Freedman Title Principal Production Engineer Signature 1 Phone:265-6579 Date (Z B (ic rrt 5/ 1 I i . RBDMS)k APR 2 9 2015 /ems/i,// - Form 10-404 Revised 10/2012 Submit Original Only CD3-113 Scale Inhibition Treatment 3/28/15—3/29/15 Non-Aqueous Scale Inhibitor Squeeze Job pumped 3/28/15 03:00 to 3/29/15 07:30. LRS= Little Red Services - Initial pressure TBG/IA/OA—1348/1484/497 - LRS pumped 203 bbls Diesel/M209/WAW5206 pre-flush at 2 -3 bpm,TBG/IA/OA— 1415/1406/474 - LRS pumped 203 bbls 70/30 EG/Water and SCW3001WC scale inhibitor main treatment at 1.5— 2.75 bpm,TBG/IA/OA—970/1378/478 - LRS pumped 2580 bbls Dead Crude/M209 over-flush at .9-3.5 bpm,TBG/IA/OA— 2156/1288/444 Interval treated: 9,364'—17,338' s WNS PROD CD3-113 ConocoPhillips ' l ? Well Attributes Max Angle&MD TD Alaska,Inc. '436,440.. Wellbore API/UWI Field Name L Wellbore Status (°) MD(ftKB) Act Btm(ftKB) Co,,,,,drp,"` 501032054100 FIORD NECHELIK PROD incl 93.60 17,018.27 17,338.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD3-113,1272015 4:0903 PM SSSV:LOCKED OUT Last WO: 42.61 2/4/2007 Vertical schematic(actual) - Annotation Depth(ftKB) End Date Annotation Last Mad By End Date "HANGER;31.2Tr4.&LA Last Tag: Rev Reason:RESET WRDP lehallf 1/27/2015 Casing Strings y+wapCON,wUMCT74 -W:IL, narN" Il Casing Description OD(in) 10(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 40.0 114.0 114.0 62.50 H-40 Welded ,7 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 36.3 2,619.3 2,474.3 40.00 L-80 BTCM SAFETY VLV;2,064.1 Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)..."Wt/Len(I...Grade Top Thread WRDP;2.064.1 -,1('' INTERMEDIATE 7 6.276 33.7 9,364.0 6,910.2 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread I LINER 41/2 3.958 9,208.0 17,280.0 6,859.6 12.60 L-80 IBTM SURFACE;36.3.2,619.3 Liner Details Nominal ID GAS LIFT;3,891.9 Top(ftKB) Top(TVD)(ftKB) Top Incl(°I Item Des Com (in) 9,208.0 6,887.8 78.90 SLEEVE Baker 5"x 7"HR Liner Setting Sleeve 4.420 9,220.9 6,8903 79.37 NIPPLE RS Nipple 4250 GAS LIFT;6,963.4 9,224.5 6,890.9 79.51 HANGER Baker 5"X 7"DC Flex-lock Liner Hanger 4.420 9,234.4 6,892.7 79.87 XO Bushing XO Bushing 3.940 • GAS LIFT;8,450.8 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection NIPPLE;8,499.2 TUBING 4.5"x3.5" 31/2 2.992 31.2 9,230.4 6,892.0 9.30 L-80 EUEM @132.6' GAUGE;8,541.8 - Completion Details PACKER;8,561.3 . Nominal ID 1111 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) NIPPLE;8,606.3 - _ 31.2 31.2 0.00 HANGER FMC 4 1/2"Tbg hanger w/2.28'pup 3.980 132.6 132.6 0.39 XO-Reducing XO-3 1/2"EUE(P)X 4 1/2"IBTM(B) 5.1875"OD x 3" 3.000 ID 2,064.1 2,023.0 28.37 SAFETY VLV Camco 3.5"TRMAXX-5E SSSV(LOCKED OUT 2.812 W �'= 4/27/2010) LEG;9,229A 8,499.2 6,647.4 60.67 NIPPLE HES"X"Nipple 2.813"ID 2.813 8,541.8 6,667.7 62.16 GAUGE Baker Gauge Carrier 2.992 I 8,561.3 6,676.7 62.86 PACKER 3.5"X 7"Baker Premier PACKER 2.875 INTERMEDIATE;33.7.9,364.0 4.• 8,606.3 6,696.7 64.47 NIPPLE 3.5"HES"XN"NIPPLE 4.25"OD x 2.813 ID w/2.75" 2.750 PERFP;9,542.0-9,547.0 .-_SEL NO Go PERFP;9,807.0.9,812.0-: 9,229.4 6,891.8 79.69 WLEG 3.000 PERFP;10,073.0.10.078.0 -- Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PERFP;10.338.0-10,343.0 Top(ND) Top Incl --i i•- ..._ Top(ftKB) (ftKB) (') Des Com Run Date ID(in) PERFP;t0,60d.410,6090� ` 2,064.1 2,023.0 28.37 WRDP 3.5"WRDP-2 w/2.81"XX-Lock(HTS-614)2.84" 1/25/2014 1.562 - iiia:- PACKING(oat=89.5") PERFP;10.871.o-10.875.0-: - Perforations&Slots ot PERFP;11.136.0.11,141.0- G: Dens mum De Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com PERFP;11,400.0.11,4040 p r '- 9,542.0 9,547.0 6,926.1 6,926.5 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;11.663.0.11,668.0--C- 1,coa � o.l1,668.0 - -113 Pup I PERFP;11,928.811,933.o-1' 9,807.0 9,812.0 6,933.8 6,933.7 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf - -113 Pup PERFP;12,193.0-12,198.0-- 10,073.0 10,078.0 6,925.5 6,925.3 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -• '- -113 Pup PERFP;12,456.0.12,463.0 10,338.0 10,343.0 6,917.5 6,917.3 227NCH,CD3 2/23/2008 1.0 PERFP 'Six 1/2"holes per Perf -'MI _ -113 Pup PERFP;12,7230-12,728.0- "- 10,604.0 10,609.0 6,909.1 6,908.9 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;12,986.0-12,991.0- -113 Pup • 10,871.0 10,875.0 6,916.1 6,916.2 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf • PERFP;13,245.0-13,250.0- -113 Pup 11,136.0 11,141.0 6,910.9 6,910.8 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2'holes per Perf PERFP;13,503.813,507.0-----: -113 Pup 11,400.0 11,404.0 6,906.2 6,906.1 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -113 Pup PERFP;13,7600-13,773.0-_. 11,663.0 11,668.0 6,902.5 6,902.6 227NCH,CD3 223/2008 1.0 PERFP Six 1/2'holes per Perf PERFP;14,034.0.14,039.0- -113 Pup - •- 11,928.0 11,933.0 6,906.8 6,906.8 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -113 Pup I PERFP;14,290.0.14,2950 - 12 193.0 12,198.0 6,905.1 6,905.2 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"hales per Perf - _ -113 Pup PERFP;14,552.0.14,557.0 12,458.0 12,463.0 6,905.0 6,905.0 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;14,818.0.14,8230--.--- -113 Pup _ _ 12,723.0 12,728.0 6,904.5 6,904.6 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;15,078.0-15,082.0-�_ 0 -113 Pup 12,986.0 12,991.0 6,911.9 6,911.9 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -113 Pup PERFP;15,342.0.15,347.0 -' - 13,245.0 13,250.0 6,905.7 6,905.5 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -.-.. PERFP;15,607.0-15.612.0 -113 Pup PERFP;15,670.0.15,875.0 13,503.0 13,507.0 6,895.4 6,895.1 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf _ = .. -113 .. Pup .. PERFP;16,131.0-16.136O_ 13,768.0 13,773.0 6,884.1 6,884.1 227NCH,CD3 2/23/2008 1.0 PERFP -Six 1/2"holes per Perf ` -113 Pup PERFP;16,3950-16,4000-__ 14,034.0 14,039.0 6,882.9 6,882.8 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf _ -113 Pup 14,290.0 14,295.0 6,877.7 6,877.7 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;16,655.0.16,660.0-• _ -113 Pup 14,552.0 14,557.0 6,877.5 6,877.5 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;16,921.0-18,925. '" 0 -113 Pup 0 • 14,818.0 14,823.0 6,877.6 6,877.6 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;17.140.0-17,145.0-- -113 Pup � LINER;9.208,0.17,280.0 WNS PROD CD3-113 ConocoPhillips O' t , Alaska,Inc, ConoeoITul6ps ••• CD3-113,1/2720154:09:05 PM Vertical schematic(actual) "'-"-'HANGER;31.2 ---siry10.tlfy'aiT�.{.a�,a�.Perforations&Slots NDUCTOR; .0.114.0mi. v r CO40Shot Den . Top(TVD) Btm(ND) (shots/f Top(ftKB) Btm(NKB) (ftKB) (ftKB) Zone Date t) Type Com SAFETY VLV;2,064.1-� 15,078.0 15,0820 6,875.8 6,875.8 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Per) WRDP;2,064.1 }i -113 Pup • 15,342.0 15,347.0 6,875.0 6,875.1 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2'holes per Perf -113 Pup SURFACE;36.3-2,619.3—& I . 15,607.0 15,612.0 6,879.1 6,879.2 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -113 Pup GAS LIFT;3,891.9 15,870.0 15,875.0 6,881.4 6,881.4 227NCH,CD3 223/2008 1.0 PERFP Six 1/2"holes per Perf -113 Pup • 16,131.0 16,136.0 6,882.6 6,882.6 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf GAS LIFT;6,963.4 -113 Pup 16,395.0 16,400.0 6,884.7 6,884.7 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Ped -113 Pup GAS LIFT;8,450.8 16,655.0 16,660.0 6,883.5 6,883.4 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf NIPPLE;8,4992 -113 Pup 16,921.0 16,925.0 6,878.1 6,877.9 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf GAUGE;8,541 8 -113 Pup PACKER;8,561.3 -- 17,140.0 17,145.0 6,866.2 6,865.9 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf • -113 Pup NIPPLE;8,606.3 I Mandrellnserts at on Top(ND) Valve Lateh Port Size TRO Run WLEG;92294 _- N Top(19KB) (11KB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com ,{ 3,891.9 3,387.9 CAMCO KBMG 1 GAS LIFT GLV BK 0.250 1,870.0 3/1/2008 2 6,963.4 5,617.8 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 2202011 I 3 8,450.8 6,623.1 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 2/29/2008 Notes:General&Safety INTERMEDIATE;33.7-9,364.0 End Date Annotation PERFP;9,542.0-9,547.0 .x=1_,_ 3/23/2008 NOTE:Original wellbore drilled in 2007 suspended,re-entered March,2008;NO Sidetrack'A' PERFP;9,807.0-9,812.0—� e._ 1/29/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 PERFP;10,073.0-10,078.0_ PERFP;10,338.0-10,343.0—-i:61: — PERFP;10,604.0-10,609.0—.-:1111 PERFP;10,871.0-10875.0—�i.p r PERFP;11,136.0-11,141.0 I% PERFP;11,4000-11,404.0 i i 0 t PERFP;11,663.0-11,668.0—. 1a PERFP;11,928.0-11,933.0_:.it PERFP;12,193.0-12,198.0— ;.ii PERFP;12,458.0-12,463.0;; PERFP;12,723.0-12,7280--.9IE — , PERFP;12,986.0-12,991.0—lie -j j PERFP;13,245.0-13,250.0 i:Y PERFP;13,503.0-13,507.0—_t i 0: = PERFP;13,768.0-13,773.0— :.:-t.- - PERFP;14,034.0-14,039.0-- i:I . ■ PERFP;14,290.0-14,295.0—_ .y-..- _ 1- PERFP;14,552.0-14,557.0— ,411 :—= PERFP;14,818.0-14,823.0— :31 PERFP;15,078.0-15,082.0—_ _-— PERFP;15,342.0.15,347.0— ;.;r- _ PERFP;15,607.0-15,612.0— .111 PERFP;15,870.0-15,875.0 i:t PERFP;16,131.0-16.136.0 ■ PERFP;16,395.0-16,400.0 :iE, PERFP;16,655.0-le.eex0—_ : _ Mil PERFP;16,921.0-16,925.0—:i 1 0 _ PERFP;17,1400-17,1450 ;'sE MIN LINER;9,208.0-17,280.0 STATE OF ALASKA AL, A OIL AND GAS CONSERVATION COM, SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed. Abandon r Repair w ell r Rug Perforations r Perforate rOther r Scale Inhibitor Alter Casing r Pull Tubing r Stimulate-Frac Waiver r Treatment r r Time Extension Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: ' 4.Well Class Before Work: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc _ Development r' Exploratory r 207-004 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic - Service r 50-103-20541-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 384215,372105,264471 CRU CD3-113 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Colville River Field/Fiord Oil Pool 11.Present Well Condition Summary: Total Depth measured 17338 feet Plugs(measured) None true vertical 6858 feet Junk(measured) None Effective Depth measured 17280 feet Packer(measured) 8561 true vertical 6860 feet (true vertical) 6677 Casing Length Size MD TVD Burst Collapse Conductor 74' 16" 114 114 Surface 2583' 9 625" 2619 2474 Intermediate 9330' 7" 9364 6910 Liner 8072' 4.5" 17280 6860 RECEIVED SCANNED ��,r : :i x:�; . �;'l i Perforation depth Measured depth: MAR 0 3 2015 perf pups from 9542'-17145' True Vertical Depth: 6926'-6866' AOGCC Tubing(size,grade,MD,and TVD) 4.5 x 3.5, L-80, 9230 MD and 6892 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PACKER @ 8561 MD and 6677 TVD SSSV-CAMCO TRMAXX-5E SSSV @ 2064 MD and 2023 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9364'-17338' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1150 1463 2080 -- 323 Subsequent to operation 1105 1277 2183 -- 313 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development rz7 Service r Stratigraphic r 16.Well Status after work: Oil J1 Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt. none Contact Jack Walker @ 265-6268 Email Jack A.Walker(cilcop.com Printed Name Jack Walker Title WNS Production Engineering Supervisor Signature Phone:265-6268 Date 6‘r --r/(.,4----14)ade, o 3 )7L4.-1- 2 v/S \ r� 3/���, RBDMS,1� MAR - 5 2015 ilk' ItXC Form 10-404 Revised 10/2012 Submit Original Only CD3-113 Scale Inhibition Treatment 2/8/15 Non-Aqueous Scale Inhibitor Squeeze Job pumped 2/8/15 from 05:30 to 16:00. LRS= Little Red Services - Initial pressure TBG/IA/OA—1120/1620/478 - LRS pumped 290 bbls Diesel/M209/WAW5206 pre-flush at 1-5 bpm,TBG/IA/OA— 1604/1567/473 - LRS pumped 290 bbls 70/30 EG/Water and SCW3001WC scale inhibitor main treatment at 1-4 bpm,TBG/IA/OA—1292/1604/479 - LRS pumped 737 bbls Dead Crude/M209 over-flush at.8-3.1 bpm,TBG/IA/OA—1720/2001/452 Interval treated:9,364'—17,338' • E WNS PROD CD3-113 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska.Inc. : Wellbore APIIUWI Field Name Wellbore Status 'Incl(1 MD(ftKB) Act Btm(ftKB) G..,Snanps 501032054100 FIORD NECHELIK PROD 93.60 17,018.27 17,338.0 .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(k) Rig Release Date CD3-113,1/27/2015 4.09.03 PM SSSV:LOCKED OUT Last WO: 42.61 2/4/2007 • Vesical schematic(actual) 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;31.2- .utu , Last Tag: Rev Reason:RESET WRDP lehallf 1/27/2015 Casing Strings CONDUCTOR 40.0-114.0 I 1 Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 40.0 114.0 114.0 62.50 H-40 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WVLen(I...Grade Top Thread SURFACE 9 5/8 8.835 36.3 2,619.3 2,474.3 40.00 L-80 BTCM SAFETY VLV;2064.1 Casing Description -OD(In) -113(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len g...Grade Top Thread WRDP,2,064.1 - INTERMEDIATE 7 6.276 33.7 9,364.0 6,910.2 26.00 L-80 BTCM Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread I LINER 41/2 3958 9208.0 17,280.0 6,8596 12.60 L-80 IBTM SURFACE;36.32,619.3-4, Liner Details Nominal ID GAS LIFT;3.891.9AL Top(ftKB) Top(TVD)(ftKB) Top Incl F) Item Des Com • (in) 9,208.0 6,887.8 78.90 SLEEVE Baker 5"x 7"HR Liner Setting Sleeve 4.420 9,220.9 6,890.3 79.37 NIPPLE RS Nipple 4.250 GAS LIFT:6,963.4 9224.5 6,890.9 79.51 HANGER Baker 5"X T'DG Flee-lock Liner Hanger 4.420 . 9,234.4 6,892.7 79.87 XO Bushing XO Bushing 3.940 GAS LIFT;8,450.8 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection NIPPLE;8,499.2 TUBING 4.5"x3.5" 31/2 2.992 31.2 92304 6,892.0 9.30 L-80 EUEM @132.6' GAUGE;8,5418ill Completion Details PACKER;8,561.3 ` �' Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com (in) NIPPLE;8,6063 31.2 31.2 0.00 HANGER FMC 4 1/2"Tbg hanger w/2.28'pup 3.980 132.6 132.6 0.39 XO-Reducing XO-3 1/2"EUE(P)X 4 1/2"IBTM(B) 5.1875"OD x 3" 3.000 ID 2,064.1, 2,023.0 28.37'SAFETY VLV Camco 3.5"TRMAXX-5E SSSV(LOCKED OUT 2.812 WLEG;9229.4 '`_� 4272010) 8,499.2 6,647.4 60.67 NIPPLE HES"X"Nipple 2.813"ID 2.813 8,541.8 6,667.7 62.16 GAUGE Baker Gauge Carrier 2.992 ( 8,561.3 6,676.7 62.86 PACKER 3.5"X 7"Baker Premier PACKER 2.875 INTERMEDIATE;33.7-9,364.0 8,606.3 6,696.7 64.47 NIPPLE 3.5"HES"XN"NIPPLE 4.25"OD x2.813 ID w/2.75" 2.750 PERFP;9,542.0-9,547.0_ E=E::_ No Go PERFP;9,807.0-9,812.09_E::= 9,229.4 6,891.8 79.69 WLEG 3.000 PERFP;10,073.0.10,078.0EE-E= - Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PERFP;10,338.0.10,343.0 Top(ND) Top Incl ilit: - Top(kKB) (ftKB) (°) Des Com Run Date ID(in) 2,064.1 2,023.0 28.37 WRDP 3.5"WRDP-2w2.81"XX-Lock(HTS-614)2.84" 125/2014 1.562 PERFP;10,604.0.10,609.03-E'- = PACKING(cal=89.5") PERFP;10,871.0-10,875.0-. Perforations&Slots x.22 PERFP;11,138.0-11,141.0 _::tit:= _ I Dons Top(ND) Btm(ND) (shotsk PERFP;11.400.411.404.0=ilori Top(ftKB) Ben(ftKB) (ftKB) ORB) Zone Date t) Type Com -'i.. 0..'- 9,542.0 9,547.0 6,926.1 6,926.5 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;11.663.0.11,668.0:._E=EE: -113 Pup PERFP;11,928.0.11,933.0= :1E-(; '- 9,807.0 9,812.0 6,933.8 6,933.7 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -113 Pup PERFP;12,193.0.12,198.0- #e- #: 10,073.0 10,078.0 6,925.5 6,925.3 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf - - - -113 Pup PERFP;12,458.0.12,463.0-I:ti - 10,338.0 10,343.0 6,917.5 6,917.3 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf - - -113 Pup PERFP;12723.0-12720.0lite:_ 10,604.0 10,609.0 6,909.1 6,908.9 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;12,986.0.12,991.0 _E3.:- -113 Pup �$ 10,871.0 10,875.0 6,916.1 6,916.2 227NCH,CD3 223/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;13,245.0.13,250.0 I"If -113 Pup - - 11,136.0 11,141.0 6,910.9 6,910.8 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Pert -113 Pup PERFP;13,503.0.13,507.0- in -- 11,400.0 11,404.0 6,906.2 6,906.1 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf - - -113 Pup PERFP;13,768.0.132730 .6.8.•_ 11,663.0 11,668.0 6,902.5 6,902.6 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;14.034.614,0390 I:Bili - -113 Pup - _ 11,928.0 11,933.0 6,906.8 6,906.8 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf - - -113 Pup PERFP;14,290.0.14,295.0- 1- - - 12,193.0 12,198.0 6,905.1 6,905.2 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -113 Pup • PERFP;14,552.0.14,557.0--- d3::- 12,458.0 12,463.0 6,905.0 6,905.0 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;14,818.0.14,823.0-'EE=EE: -113 Pep 12,723.0 12,728.0 6,904.5 6,904.6 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Pert , , - -113 Pup PERFP;15,078.0-15,082.0--: 12,986.0 12,991.0 6,911.9 6,911.9'227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Pert - - -113 Pup PERFP;15,342.0-15,347.0 :Eli: - -� 13,245.0 13,250.0 6,905.7 6,905.5 227NCH,CD3 223/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;15.607,O-15.R12.0--------' ::9 U _ -113 Pup 1.tya' - 13,503.0 13,507.0 6,895.4 6,895.1 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Pert PERFP;15,870.615,875.0-1 -- -113 Pup PERFP;16,131.0.16,136.0 :AEU: 13,768.0 13,773.0 6,884.1 6,884.1 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf - - -113 Pup PERFP;1Q395.0.1Qa00.0- 14,034.0 14,039.0 6,882.9 6,882.8 227NCH,CD3 223/2008 1.0 PERFP Six 1/2"holes per Perf _- ; } _ -113 Pup - _ 14,290.0 14,295.0 6,877.7 6,877.7 227NCH,CD3 2/23/2008 ' 1.0 PERFP Six 1/2"holes per Perf PERFP;16,605.0-16,660.0 -113 Pup (y 14,552.0 14,557.0 6,877.5 6,877.5 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;16,921.0-16,925.0--- :17T i- -113 Pup [3 14,818.0 14,823.0 6,877.6 6,877.6 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf PERFP;17,140.0-17.145.0-- - -113 Pup LINER;9,208.0.17,280.0- WNS PROD CD3-113 Conoco-Phillips a Alaska,WIC. CO3-113,112712015 4:09:05 PM Vertical schematic(actual) HANGER,31.2 II'u /0!, :. ,rTPerforations&Slots CONDUCTOR;40.0.114.0 ( I Shot Dens Top(ND) Btm(ND) (shots/f ` Top(ftKB) elm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SAFETY VLV;2064.1 15,078.0 15,082.0 6,875.8 6,875.8 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2'holes per Perf WRDP;2,064.1 -113 Pup 15,342.0 15,347.0 6,875.0 6,875.1 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -113 Pup SURFACE;36.3-2,619.3 15,607.0 15,612.0 6,879.1 6,879.2 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -113 Pup GAS LIFT;3,891.9 15,870.0 15,875.0 6,881.4 6,881.4 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf 1 -113 Pup 16,131.0 16,136.0 6,882.6 6,882.6 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf GAS LIFT;6,963.4 -113 Pup M 16,395.0 16,400.0 6,884.7 6,884.7 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf -113 Pup GAS LIFT;8,450.8 16,655.0 16,660.0 6,883.5 6,883.4 227NCH,CD3 223/2008 1.0 PERFP Six 1/2"holes per Perf NIPPLE;8,499.2 = -113 Pup 16,921.0 16,925.0 6,878.1 6,877.9 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2"holes per Perf GAUGE;8,541.8 -113 Pup PACKER;8,561.3 17,140.0 17,145.0 6,866.2 6,865.9 227NCH,CD3 2/23/2008 1.0 PERFP Six 1/2'holes per Perf -113 Pup NIPPLE;e.606.3 Mandrel Inserts St an • on Top(ND) Valve Latch Port Size TRO Run WLEG;9,229.4 N, Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 3,891.9 3,387.9 CAMCO KBMG 1 GAS LIFT GLV BK 0250 1,870.0 3/1/2008 -- 2 6,963.4 5,617.8 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 2/20/2011 3 8,450.8 6,623.1 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 2/29/2008 Notes:General&Safety INTERMEDIATE;33.7-9.364.0 End Date Annotation PERFP;9,542.0-9,547.0-_:-tdr'_. 3/23/2008 NOTE:Original wellbore drilled in 2007 suspended,re-entered March,2008;NO Sidetrack'A' PERFP;9,807.0-9,812.0-_-_ 1/29/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 PERFP;10,073.0.10,078.0_ _- -_ PERFP;10,338.0-10,343.0 . PERFP;10,604.0-10,609.0—�- . PERFP;10,871.0.10875.0 I. PERFP;11,136.0-11,141.0— PERFP;11.400.0-11.404.0—= i0r PERFP;11,663.0-1t,668.0-- 9tEE _ PERFP;11,928.0.11,933.0—-:- PERFP;12,193.0-12,198.0—- :#:f: PERFP;12.458.0-12.463.0—:• _ PERFP;12,723.0.12,728.0—:- PERFP;12,986.0-12,991.0— - PERFP;13,245.013,250.0— :#:f: _ [-[ey7� PERFP;13,503.013,507.0—=_ 4l3� 1- PERFP:13,768.0-13,773.0— 33: PERFP;14,034.0-14,039.0— _■ PERFP;14,290.0.14,295.0— 6 PERFP;14.552.0-14,5579 PERFP.14,818.0.14,823.0 . PERFP;15978.015.082.0—_ _ - s[ PERFP;15,342.0.15,347.0— ERE .—_- PERFP; PERFP;15,607.015,612.0--. - PERFP;15,870.0.15,875.0— PERFP;16,131.0-16,136.0—- - ■_ PERFP;16,395.0.16,400.0— L{{ PERFP;16,655.016,660.0— q-q PERFP;16921.0-16,925.0 ._ PERFP;17,140.0.17,1450 - LINER;9,208.0.17,280.0 "�' Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~ - ~ (~ ~- Well History File Identifier wo-sided III II~IIIIIIII VIII Rescan Needed III IIIIIIIIII IIIIII Organ-z-ng (done) ~ T ^ RESCAN DIGITAL DATA Color Items: ,.~~iskettes, No. r~Greyscale Items: ~^ Other, NolType: ^ Poor Quality Originals: ^ Other: NOTES: BY: ~ Maria ~ Date: ~ Project Proofing OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ BY: ~ ria Date: ~ g~ `b /s/ I 1 ~ Scanning Preparation ~ x 30 = ~~ + ~ =TOTAL PAGES ~ s~ I~~ (Count does not include cover sheet) ' /~ n BY: Maria Date: / /s/ U ~/' Production Scanning Stage 1 BY: Stage 7 BY: Page Count from Scanned File: ~~~ (Count does include cov sheet) nt Matches Number in Scannin Pre aration: YES NO Page Cou 9 p Maria Date: ~ ~{ ~O /s/ If NO in stage 1, page(s) discrepancies were found: YES NO Maria Date: /s/,~ ~~.~.~~~.~. ~..~~ Scanning is complete at this point unless rescanning is required. Rescanned III IIIIIIIIIII VIII BY: Maria Date: /s/ Comments about this file: Quality Checked III VIII III IIII III 10/6/2005 Well History File Cover Page doc STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM•ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon E Repair w ell Rug Perforations r Perforate E Other Scale Inhibition Alter Casing I — Pull Tubing E Stimulate - Frac Waiver E Time Extension Chan Approved Program EOperat. Shutdow n E Stimulate - Other F Re -enter Suspended Well r 2. Operator Name: ,/ 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development j;� Exploratory " 207 -004 3. Address: 6. API Number: / P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic (" Service E 50- 103- 20541 -00 7. Property Designation (Leesp lumber): 8. Well Name and Number: r ADL 384215, 372105, CD3 - 113 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): / none Colville River Field / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 17338 feet Plugs (measured) none true vertical 6858 feet Junk (measured) none Effective Depth measured 17275 feet Packer (measured) 8561 true vertical 6860 feet (true vertical) 6676 Casing Length Size MD TVD Burst Collapse 1 CONDUCTOR 74' 16" 114' 114' SURFACE 2583' 9.625" 2619' 2474' INTERMEDIATE 9330' 7" 9364' 6910' RECEIVED LINER 8072' 4.5" 17280' 6859' MAY 0 6 2013 Perforation depth: Measured depth: perfs from 9542'- 17145' SCANNED J UL 0 3 2 AO CC True Vertical Depth: 6923' - 6866' Tubing (size, grade, MD, and TVD) 4.5" x 3.5 ", L - 80, 9230 MD, 6892 TVD Packers & SSSV (type, MD, and TVD) PACKER = BAKER PREMIER PACKER @ 8561 MD and 6676 TVD SSSV = CAMCO TRMAXX -5E SSSV @ 2064 MD and 2023 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9364'- 17338' Treatment descriptions including volumes used and final pressure: referred to attached summary 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 2101 3292 1342 — 363 Subsequent to operation 2715 1265 466 -- 302 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory I` Development W. Service I- Stratigraphic E _ 16. Well Status after work: Oil 1,7 Gas fl WDSPL Daily Report of Well Operations _XXX GSTOR E WINJ r WAG !' GINJ E SUSP E SPLUG I 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Tim Nelson a, 265 - 6859 Email Tim.J.Nelson a(2conocoohillips.com Printed Name im Nelson Title Staff Production Engineer Signature Phone: 265 -6859 Date ,10-1 2.0 13 - / 1 / 0 RBDM - 6 MAY �� �/ 201g Form 10 -404 Revised 10/2012 Submit Origi Only • • Scale Inhibition Treatment: CD3 -113 4/27/2013 Initial pressure TBG /IA /OA- 200/1308/484; LRS pumped 85 bbl arctic low endpoint diesel containing 840 gal WAW5206 at 2.1 bpm, 900/1192/487; 131 bbl of 60:40 EG containing 990 gal SCW3001WC was then pumped at 2.3 bpm, 900/1114/486; and 2034 bbl of crude overflush at 2.5 bpm. Final pressures 2800/1128/489. Interval treated for this well was 9364' — 17338' I ' g WNS CD3 -113 Conoc �� Well Attributes Max Angle & MD TD Wel!bore API /UWI Field Name Web Status Inc! ( °) MD (ftKB) Act Btm (ftKB) y 501032054100 FIORD NECHELIK PROD 93.60 17,018.27 17,338.0 "° b Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date -- SSSV: LOCKED OUT Last WO: 42.61 2/4/2007 Well Conflo - CD3 -113 2125M20139.24. 17 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date HANGER, 31 --ir ' 1 Last Tag: Rev Reason: RESET WRDP osborl 2/25 /2013 ` Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd coNDUCTOR, �. ' CONDUCTOR 16 15.062 40.0 114.0 114.0 62.50 H-40 Welded 40 -114 < Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd SURFACE 95/8 8.835 36.3 2,619.3 2,473.7 40.00 L -80 BTCM SAFETY VLV, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd WRDP 2.084 { I INTERMEDIATE 7 6.276 33.7 9,364.0 6,909.6 26.00 L -80 BTCM --. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd LINER 41/2 3.958 9,208.0 17280.0 6,859.5 12.60 L -80 IBTM L Details SURFACE. L Top Depth 36 -2.619 (TVD) Top Intl Nomi... 055 LIFT. . Top (ftKB) (ftKB) 1 Item Description Comment ID (in) r _ ,892 9,208.0 6,886.6 78.86 SLEEVE Baker 5" x 7" HR Liner Setting Sleeve 4.420 9,220.9 6,889.5 79.34 NIPPLE RS Nipple 4.250 9,224.5 6,890.3 79.48 HANGER Baker 5" X 7' DG Flex -lock Liner Hanger 4.420 GAS LIFT, 6,963 t - 9,234.4 6,892.3 79.85 X0 Bushing X0 Bushing 3.940 Tubing Strings GAS LIFT, Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ( .. 8,451 TUBING 4.5 "x3.5" 31/2 2.992 31.2 9,230.4 6,891.5 9.30 L -80 EUEM NIPPLE,8,499 @132.6' I J Completion Details GAUGE, 8,542 - - - - - - i i I Top Depth PACKER. 8,561 _ - (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) ( °) Hem Description Comment ID (in) NIPPLE, e,6a6 ,._ 31.2 31.2 -0.03 HANGER FMC 4 1/2' Tbg hanger w/ 2.28' pup 3.980 132.6 132.6 0.28 XO- Reducing X0 - 3 1/2" EUE (P) X 4 1/2' IBTM (B) 5.1875" OD x 3" ID 3.000 I_ .I 2,064.1 2,023.0 28.45 SAFETY VLV Camco 3.5" TRMAXX -5E SSSV (LOCKED OUT 4/27/2010) 2.812 3 8,499.2 6,647.3 60.63 NIPPLE HES "X" Nipple 2.813" ID 2.813 1 WLEG, 9,229 ��=' � 8,541.8 6,667.4 62.16 GAUGE Baker Gauge Carrier 2,992 8,561.3 6,676.3 62.86 PACKER 3.5" X 7' Baker Premier PACKER 2.875 _ . 8,606.3 6,696.6 65.89 NIPPLE 3.5" HES "XN" NIPPLE 425" OD x 2.813 ID w/ 2.75" No Go 2.750 NTERMEDIATE, 349,384 \ 9,229.4 6,891.3 79.66 WLEG 3.000 PERFP, _ f __ 9,542 - 9,547 _ Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) PERFP, 9,807 -9,812 Top Depth _I ® €- P P PERFP, (TVD) Top Inc' 70,073- 10,078 'Nil ``^ ®-74 Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) PERFP, `., 2,064.1 2,023.0 28.45 WRDP 3.5" WRDP -1 w/2.81" )04-Lock (HTS -685) set in locked out 2/16/2013 1.562 10,338 - 10,343 TRDP PERFP, 10,60410,609 ® Perforations & Slots PERFP. Shot 10,871 - 10,875 Top( Btm (TVD) Dens I _ Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh -. Type Comment 11,138 ---11R 41 i� ` 9,542.0 9,547.0 6,923.0 6,923.9 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup , CD3 -113 PERFP, lI � , „ 11,400 - 11,404 1..,_ F 9,807.0 9,812.0 6,934.9 6,934.7 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup PERFP, CD3 -113 17,883 - 17,888 PERFP . [� El 10,073.0 10,078.0 6,925.5 6,925.3 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup 17.928 - 11,933 CD3 -113 12,193-12,1 e 1 i i I 1 10,338.0 10,343.0 6,917.5 6,917.3 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup CD3 -113 12,458- P i E z.463 RFP, L : : I 10,604.0 10,609.0 6,909.4 6,9092 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup PERFP, _ - -- CD3 -113 72,723 - 72,728 � � i• 12,986- 1 2,991 P, II .• - al 10,871.0 10,875.0 6,916.7 6,916.7 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup . CD3 -113 PERFP. .thir -- g 11,136.0 11,141.0 6,910.9 6,910.8 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup 13,245- 13,250 CD3-113 PERFP, 1-11 11,400.0 11,404.0 6,906.2 6,906.1 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup il 13,503- 13,507 CD3 -113 PERFP, 11111 , 11,663.0 11,668.0 6,902.2 6,902.3 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup 13,788-13,773 CD3 -113 iminin PERFP, ® 11,928.0 11,933.0 6,906.7 6,906.7 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup -11 14,034-14,039 CD3 -113 mmli PE IM RFP, , 12,193.0 12,198.0 6,905.2 6,905.2 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup 14,290- 14,295 L. CD3 -113 PEFP, ! 12,458.0 12,463.0 6,905.1 6,905.0 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 14,552-14R,557 ' 1■ CD3-113 PERFP, 14,61814,823 I w 5. ® 12,7290 12,728.0 6,904.6 6,904.6 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup _ CD3 -113 15,078-75,0 2 1 I! 12,986.0 12,991,0 6,911.7 6,911,8 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup IMI CD3 -113 15,342 PE- 75,347 RFP, Sr.' . 13,245.0 13,250.0 6,907.7 6,907.1 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup - PERFP. CD3 -113 _II 75,807 - 15,812. 13,503.0 13,507.0 6,896.8 6,896.5 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 15,870.15,875 i -' • I CD3 -113 PERF P, „ . 13,768.0 13,773.0 6,884.1 6,884.1 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup 15131 - 151-� Imo CD3 -113 PERFP, 14,034.0 14,039.0 6,882.8 6,882.8 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup 16.395 -16.400 : j CD3 -113 PERFP, 16.655-16.660 ■ N. Mandrel Details Top Depth Top Port PERFP, 't g (TVD) Inc! OD Valve Latch Size TRO Run 16,921 - 16,925 . N... Top (ftKB) (ftKB) (°) Make Model (in) Sery Type Type (in) (psi) Run Date Com... PERFP, 1 3,891.9 3,388.0 43.69 CAMCO KBMG 1 GAS LIFT GLV BK 0.250 1,870.0 3/1/2008 140-17 145 ii , 9,208 - 17,280 2 6,963.4 5,617.9 44.50 CAMCO KBMG 1 GAS LIFT DMY BK 0.000' 0.0 2/20/2011 TO (CD3 -113), 3 8,450.8 6,622.2 58.89 CAMCO KBMG 1 GAS LIFT OV BK 0250 0.0 2/29/2008 77,338 r T WNS CD3 -113 ts ConocoPhillips eaaSea. CanocoPhdllps KB -Grd (ft) Rig Release Date -- - _ 4261 2/4/2007 Well Con6q' - CO3 -113 2/25/2013 9:24.17 AM Schematic - Actual .--- HANGER. 31.._. {:..� a .... ai .. Perforations & Slots Shot CONDUCTOR, Top (TVD) Btm (TVD) Dens 40-114 Top (ftKB) Btm (ftKB) OMB) (ftKB) Zone Date ( Type Comment 14,290.0 14,295.0 6,877.9 6,877.8 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup SAFETY VLV. CD3 -113 MEM WRDP, 2,0 64 ` 14,552.0 14,557.0 6,877.7 6,877.7 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup CD3.113 14,818.0 14,823.0 6,877.6 6,877.6 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup SURFACE, _ CO3 -113 36 2,619 15,078.0 15,082.0 6,875.9 6,875.8 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup GAS LIFT, { • _ CD3 -113 3,892 '- --- 15,342.0 15,347.0 6,874.9 6,875.0 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup CD3 -113 ( 15,607.0 15,612.0 6,879.0 6,879.1 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup GAS LIFT 8,983 CD3 -113 IMO 15,870.0 15,875.0 6,881.4 6,881.4 227NCH, 2/23/2008 1.0 PERFP Six 1/2' hales per Perf Pup CD3.113 GAS LIFT, 8,451 16,131.0 16,136.0 6,882.6 6,882.7 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup NIPPLE, 8,499 CD3.113 16,395.0 16,400.0 6,885.6 6,885.4 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup GAUGE, 8,542 CD3 -113 PACKER 8.561 - - -- =- 16,655.0 16,660.0 6,882.4 6,882.4 227NCH, 2/23/2008 1.0 PERFP Six 112" holes per Perf Pup uniorm CD3 -113 NIPPLE, 6,606 16,921.0 16,925.0 6,878.1 6,879.7 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup CD3 -113 17,140.0 17,145.0 6,866.2 6,866.0 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup WLEG,9,229 CD3 - 113 Notes Genera! & Safety End Date Annotation 3/23/2008 NOTE: Original wellbore drilled in 2007 suspended, re- entered March, 2008; NO Sidetrack 'A' NTERMEDIATE, 34-9,364 L_ _- 1/29/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 PERFP. 9,542-9,547 PERFP, S.. 0 9,807 - 9,812 PERFP, al 10,073- 70,078 PERFP, 70,338- 10,343 PERFP, 10,804-10,609 PERFP, 7 • ''. 10,871 - 10,875 PERFP, _ 11 11,136- 17,141 PERFP, 11,400.11,404 95 PERFP, -' 11,66341,668 ! R El PERFP, 11,928 - 11,933 PERFP, 12,193 - 12,198 - PEFP, 12,458 -72, , MEI PERFP,_ 12,723 - 12,726 - -11 PERFP, 12,986 - 12,991 1 PERFP, IN g 73,245- 13,250 13,503 - 73 PERFP, ,5 PERFP, - II 13,768 - 73,773 PERFP, 14,034-14,039 PERFP, 14,290 - 14,295 - PERFP, - 111M • 14,552 - 14,557 - PERFP, 14,818 - 14,8231 PERFP, 15,078 - 15,082 ' EMI PERFP, 15,342 - 15,347 MEN PERFP, 15007 - 15,612 PERFP, -- 75,870-15.875 PERFP, -ri al 90 16,737- 16,736 PERFP, 16,395 - 16,400 Effl 16,655-1 ,660 'a PERFP, 16,921 - 16,925 PERFP, 17,1 1111 40-17,145 LINER,' 9, (CO3 -1 230 13 17.338 TD (CD 3 7,338 s ofP I / /7; THE STATE Alaska Oil and Gas ofALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue ALAS Anchorage, Main: 99501-3572 907 279.1433 Fax: 907.276.7542 Robert Blakney Completion Engineer Conocorhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3 -113 Sundry Number: 313 -079 SCANNED MAR 1 1 2013 Dear Mr. Blakney: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4 4 ') . 7 11 ` — ' Cathy . Foerster ��yy�� Chair DATED this 4` A. day of March, 2013. Encl. STATE OF ALASKA D i AI (A OIL AND GAS CONSERVATION COMMON PM 3 1 Z APPLICATION FOR SUNDRY APPROVALS r E R 14 2013 20 AAC 25.280 //��'��'' 1. Type of Request: Abandon E Plug for Redrill M Perforate New Pool r Repair w ell r Changilb�ulam (a_ Suspend E Plug Perforations ("" Perforate ]i:. Pull Tubing E lime Extension [ Operational Shutdow n fl Re -enter Susp. Well E Stimulate N1. Alter casing E Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development I . Exploratory f 207 - 004 • 3. Address: Stratigraphic I"'" S erv i ce 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20541 - 00 • 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes I No i CD3 - 113 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 384215, 372105, 364471 Colville River Field / Fiord Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 17338 6858 17275' 6860' none none• Casing Length Size MD TVD Burst Collapse CONDUCTOR 74' 16" 114' 114' SURFACE 2583 9.625" 2619' 2474' INTERMEDIATE 9330' 7" 9364' 6910' LINER 8072' 4.5" 17280' 6859' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): perfs from 9542' 17145' • 6923' - 6866' 3.5 L - 9230 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER PREMIER PACKER " MD =8561 TVD =6676 SSSV - CAMCO TRMAXX -5E • MD =2064 TVD =2023 12. Attachments: Description Summary of Proposal I✓ • 13. Well Class after proposed work: Detailed Operations Program E BOP Sketch r Exploratory E Stratigraphic I Development F,,i • Service E 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2013 011 9 • Gas [ WDSPL E Suspended E 16. Verbal Approval: Date: VVINJ r GINJ E WAG r Abandoned i Commission Representative: GSTOR E SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Robert Blakney @ 265 -6417 Email: Robert. G.Blaknevta7.conocophillips.com Printed Name Robert BI Title: Completion Engineer 2-7/ 3 i _ ._ Signature Phone: 265 -6417 Date 0 Commission Use Only Sundry Number: 31 3- 0 07 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity is BOP Test r Mechanical Integrity Test I Location Clearance I �A fl x • Other: RBDMS MAR 0 5 20 fi, Spacing Exception Required? Yes ❑ No 21 Subsequent Form Required: i APPROVED BY I � Approved by: P p ication is varct �rII - ar the from th l 30 val. Date: 3" 4 / 3 Form 10 -403 (Revi ed 10/2012) 3/ill ORIGINAL Submit Form and Attachments in Duplicate �\� \yo�� • a WNS • CD3 -113 ConocoPhillips g Well Attributes Max Angle 8 MD TD Alaska Inc. Wel!bore API/UWI Field Name Well Status Incl ( °) MD (RKB) Act Btm IRKS) ,,,.. 501032054100 FIORD NECHELIK PROD 93.60 17,018.27 17,338.0 °' Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date "- - SSSV: LOCKED OUT Last WO: 42.61 2/4/2007 Welt Cantle - CD3 -113, 2/4/2013 8:44.49 AM Schematic - Actual Annotation Depth (kKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: PULL WRDP osborl 2/2/2013 Casing Strings Casing Description String O.. String ID ... Top (kKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CTO, CONDUCTOR 16 15.062 40.0 114.0 114.0 62.50 H - 40 Welded CONDU 40-1 tRo _ ' Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.835 36.3 2,619.3 2,473.7 40.00 L -80 BTCM SAFETY VLV, Casing Description String 0... String ID ... Top (kKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd WRDP- I - 2.064 INTERMEDIATE 7 6.276 33.7 9,364.0 6,909.6 26.00 L -80 BTCM PULLED, 2.064 �, Casing Description String O... String ID ... Top (kKB) Set Depth If... Set Depth (TVD)... String Wt... String ... String Top Thrd LINER 41/2 3.958 9,208.0 17,280.0 6,859.5 12.60 L -80 IBTM Liner Details SURFACE, a\ Top Depth 36 -2,619 (TVD) Top Incl Nomi... GAS LIFT, Top (RKB) (kKB) (1 Item Description Comment ID (in) 3,892 r 9,208.0 6,886.6 78.86 SLEEVE Baker 5" x 7" HR Liner Setting Sleeve 4.420 9,220.9 6,889.5 79.34 NIPPLE RS Nipple 4.250 ' 9,224.5 6,890.3 79.48 HANGER Baker 5" X r DG Flex - lock Liner Hanger 4.420 GAS LIFT, 6,983 1 9,234.4 6,892.3 79.85 XO Bushing XO Bushing 3.940 , 111111 Tubing Strings GAS LIFT, - •.- Tubing Description String 0... String ID ... Top MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd eASt TUBING 4.5 "x3.5" 3 1/2 2.992 31.2 9,230.4 6,891.5 9.30 L - 80 EUEM SEM NIPPLE. 8,499 @132.6 MOIR Completion Details GAUGE, 8,542 i I Top Depth PACKER, 8,581 ,:„°:,,R.„,,, 1 (TVD) Top Inc! Nomi... -,'' Top (RKB) (RKB) C) Item Description Comment ID (in) NIPPLE, 8,606 _ 31.2 31.2 -0.03 HANGER FMC 4 1/2' Tbg hanger w/ 2.28' pup 3.980 132.6 132.6 0.28 XO- Reducing XO - 3 1/2" EUE (P) X 4 1/2' IBTM (B) 5.1875" OD x 3" ID 3.000 IT _I 2,064.1 2,023.0 28.45 SAFETY VLV Cameo 3.5" TRMAXX -5E SSSV (LOCKED OUT 4/27/2010) 2.812 8,499.2 6,647.3 60.63 NIPPLE HES "X" Nipple 2.813" ID 2.813 WLEG. 9.229 !la 8,541.8 6,667.4 62.16 GAUGE Baker Gauge Carrier 2.992 8,561.3 6,676.3 62.86 PACKER 3.5" X 7' Baker Premier PACKER 2.875 8,606.3 6,696.6 65.89 NIPPLE 3.5" HES " XN" NIPPLE 4.25" OD x 2.813 ID w/ 2.75" No Go 2.750 NTERMEDIATE, 364 "- .� 9,229.4 6,891.3 79.66 WLEG 3.000 34- 9, PEFP, 9,5429R,547 i in PERFP. 1• Perforations & Slots 9.0079,812 el "i= ® Shot 10,073- 70p78 "' ■ Top (TVD) Rho (TVD) Dens Top (kKB) Stm (RKB) (MB) (MB) Zone Date ( Type Comment PERFP, ® tin 10,338 9,542.0 9,547.0 6,923.0 6,923.9 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup CD3 -113 10,604- 1 el - ■ 9,807.0 9,812.0 6,934.9 6,934.7 227NCH, 2/23/2008 1.0 PERFP ' Six 1/2' holes per Perf Pup -IM - CD3 -113 PERFP, a!a 10,071-10,075 I I... ■ 10,073.0 10,078.0 6,925.5 6,925.3 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup ERFP, - -T' :- CD3 113 11,138- PERFP, [ j - " � - 10,338.0 10,343.0 6,917.5 6,917. 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup Lill 11 ,400 - 11, � CD3 -113 PERFP. {„ 10,604.0 10,609.0 6,909.4 6,909.2 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 11,663 -01,868 CD3 -113 PERFP, -all 11,928 - 11,933 10,871.0 10,875.0 6,916.7 6,916.7 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup PERFP, • a 12,193 - 12,198 5 ■ I CD3 -113 11,136.0 11,141.0 6,910.9 6,910.8 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 12,459 - 1 PE2,463 RFP, E U - g ki (,•D3 -113 PERFP. _ 11,400.0 11,404.0 6,906.2 6,906.1 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup 12,723- 12,72e i - .. E CD3 -113 PERFP, M 12.986 - 12.991 11,663.0 11,668.0 6,902.2 6,902.3 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup CD3 -113 PEFP, 13,z4s- t3, 5 , 11,928.0 11,933.0 6,906.7 6,906.7 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup CD3 -113 PERFP, 13,503 - 13.507 ■ 12,193.0 12,198.0 6,905.2 6,905.2 227NCH, 2/23/2008 1.0 PERFP Six 1 /2 "holes per Perf Pup _ CD3 -113 13.768-13.773 ® 12,458.0 12,463.0 6,905.1 6,905.0 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup CD3 -113 PERFP, I -111 14,034- mom 12,723.0 12,728.0 6,904.6 6,904.6 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup CD3-113 PERFP. RFP, II 14,290-14,295 `. 12,986.0 12,991.0 6,911.7 6,911.8 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup - CD3 -113 PERFP, 4t . 13, 24 5.0 13250.0 6,907.7 6,907.1 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup p MIMI PERFP, CD3 -113 14,818 - 14,823 II _ 13,503.0 13,507.0 6,896.8 6,896.5 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup PERFP, :. 15,078 - 15,082 III CD3.113 - 13,768.0 13,773.0 6,884.1 6,884.1 227 2/23/2008 1.0 PERFP Six 1/2" holes per Pert Pup 15,342- 1 PE5,347 RFP,- f;• . PERFP, 2 14,034.0 14,039.0 6,882.8 6,882.8 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup 15,607 - 15,61 = ■ CD3 -113 15,870PE- 15,875 RFP, - t , 14,290.0 14,295.0 6,877.9 6,877.8 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup CD3 -113 PERF 16,131- 1 Q736� 14,552.0 14,557.0 6,877.7 6,877.7 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup CD3 -113 MI PERFP, 16,395 -06,400 14,818.0 14,823.0 6,877.6 6,877.6 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup _ CD3 -113 PERFP, II 18,855 - 18,860 Mandrel Details MI Top Depth Top Port PERFP, 5,,, (TVD) Inc! OD Valve Latch Sloe TRO Run 16,921 - 16,925 ` • ■ N... Top (RKB) (RKB) C) Make Model (In) Seri/ Type Type (IN (Psi) Run Date Corn- PERFP, 17,140- PERFP, _ ® 1 3,891.9 3,388.0 43.69 CAMCO KBMG 1 GAS LIFT GLV BK 0.250 1,870.0 3/1/2008 LINER. ■ ' 2 6,963.4 5,617.9 44.50 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 2/20/2011 9,208 - 17,280 TD (CD3 -113), 17,338 i 3 8,450.8 6,622.2 58.89 CAMCO KBMG 1 GAS LIFT OV BK 0.250 0.0 2/29/2008 '�� WNS CD3 -113 Conoc 41 Alasice. Inc. ,y< CAroadtalbps KB -Grd (ft) Rig Release Date "' 42.61 2/4/2007 Well COMM : - CD3 -3, 2/4/2013 8. 44 49 AM '. Schematic - Actual HANGER 31 `':' Perforations & Slots Shot CONDUCTOR, _II Top (NO) Btm (TAD) Dens 40-114 Top (ftKB) Btm (ftKB) (RKB) (ftKB) Zone Date Oh- Type Comment 15,078.0 15,082.0 6,875.9 6,875.8 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup SAFETY VLV, CD3-113 2,064 '^"tDP - 1 -- ( 15,342.0 15,347.0 6,874.9 6,875.0 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup PULLED, 2.064 I CD3 -113 15,607.0 15,612.0 6,879.0 6,879.1 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup SURFACE, Aft CD3 -113 38 -2,819 15,870.0 15,875.0 6,881.4 6,881.4 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup GAS LIFT, CD3-113 3,892 16,131.0 16,136.0 6,882.6 6,882.7 227NCH, 2/23/2008 1.0 PERFP Six 1/2' holes per Perf Pup CD3 -113 GAS LIFT, 16,395.0 16,400.0 6,885.6 6,885.4 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup 6.963 ff. CD3 -113 16,655.0 16,660.0 6,882.4 6,882.4 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup GAS LIFT, CD3 -113 e,451 16,921.0 16,925.0 6,878.1 6,879.7 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup NIPPLE, 8,499 CD3 -113 IIIII 17,140.0 17,145.0 6,866.2 6,866.0 227NCH, 2/23/2008 1.0 PERFP Six 1/2" holes per Perf Pup GAUGE, 8,542 - CD3 - 113 PACKER, 6.561 Notes: General & Safety End Date Annotation NIPPLE, 6'606 - 3/23/2008 NOTE: Original wellbore drilled in 2007 suspended, re- emtered March, 2008 1/29/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 I_ C 3 i= WLEG, 9.229 ��. NTERM E4 9,364 34 lATE, 9,54PLR, a _ • sot PERFP, ® c 9,807-9,812 - 70,0737078 _ - II PERFP, 70,338 - 70,343 PERFP, is 10,604-10,609 MINIM PERFP, !• , 70,871 - 10,875 17,136 - P ,7, , V 17,400 - ,1, 4 1 II 11,663-11,868 PERFP, g = 6 ERFP. PERFP. 4 ,1,928 - 71,933 ill 72,79372,798 :` =. 12,458- 72,463 HE PEFP, 72,723 - 12,R728 3 a PERFP, M 9 12,986 - 12,997 i -. PERFP, M 13,245 - 73,250 - 11 PEFP, 13,503 - 13, U PERFP, E 13,768-13,773 MEM PERFP, 74,03474,038 PERFP, 74,290-14,295 i PERFP. -1111 la 14,552 - 14,657 _. PEFP, 14,818- 14, _ PEFP, 75,078 - 75, PERFP, .3 5 75,342- 75,347 PERFP, , ! 6. - 411 1 75,607 - 15,812U - PERFP, -` 15,870 - 15,875 PERFP, IM 1 CAI lift Oa 8,137- 16,736 PERFP, 76,395- 76,400 PERFP, - _ 78,655 - 18,880 .,t IR ' PERFP, 18,821 - 16,926 �� _ PERFP. 17,140 - 17,146 "" LINER, - l j'` 9,208 - 17,280 TO (CO3 -113), r - 1 17,338 • • CD3 —113 Sundry Application CD3 -113 was completed in 2008 as horizontal producer in the Nechelik formation. The well was completed with a 4.5" liner in the horizontal. Due to concerns about scale on the liner, we will be perforating the 4.5" liner at the heel of the well prior to the frac. The stimulation will be a single stage treatment with approximately 340,000 lbs. of 16/20 carbolite. We expect the increased production to be 200 bpd in 2013 if a successful stimulation is achieved. Proposed Procedure: Schlumberger Pumping Services: (Nechelik Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Perforate 4.5" liner. 3. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 4. Ensure the 10 -403 Sundry has been reviewed and approved by the AOGCC. 5. MIRU 7 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10 %. Load tanks with 100° F seawater (approx. 2800 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 6. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 7. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 8. PT Surface lines to 8,000 psi using a Pressure test fluid. 9. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 10. Pump the 240 bbl breakdown stage (25# linear gel, WF125) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 40 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 11. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 12. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 6000 psi. • 360 bbls YF125ST Pad • 240 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 480 bbls YF125ST w/ 4 ppa 16/20 Carbolite • 400 bbls YF125ST w/ 4 ppa 16/20 Carbolite • 860 bbls YF125ST w/ 7 ppa 16/20 Carbolite • Flush with 106 bbls of linear fluid (WF125) and freeze protect • Total Sand: Approx. 340,000 lbs 16/20 Carbolite 13. Monitor the surface pressure fall -off at the end of the job for 30 minutes, if the well does not screen out. RB • • 14. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 15. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). 16. Flowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (initial flowback fluids to be taken to CD1 -01 disposal well until they are clean enough for production.) Production Casing Cement Report: CD3 -113: 7" casing cement pump report on 2/2/2007 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, and displaced with 9.6 ppg mud. Tested casing and cement to 3550 psi, both held. CD3 -123: 7" casing cement pump report on 4/12/2010 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, and displaced with 10.2 ppg mud. Bumped the plugs at 1460 psi, pressured up to 1930 psi, and the pressure held. Summary Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect wells within a 1 /4 mile radius or any other nearby well. RB • • Stimulation Surface Rig -Up r )tt <, , T i1 T 3f1F'. r. ... f l.Yv 2 • Minimum pressure rating on all surface treating lines 10,000 psi *..":€11 • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3500 psi w 5 - • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 1r,∎ psi. 0 11 1 a V loco' dund U 1.30 If Tan6: 1 F i-ir T- Pop -Off Tank a N y Z IT di Li fIa-kur — L ; ) IV I Frac Pump :1cPu.' 4' r. XYa'' vi -- [:' .: r.. F P F fac Pu' 1 p { FracPunp RB • 40 Stimulation Tree Saver OPEN POSITION CLOSED POSITION (PRIOR TO MANDREL INSERTION) (MANDREL INSERTED( FRAC IRON CONNECTION r .,„,. D-0. n ,,,,,-.., .. ,., .,.., ,�. R EMOTE OPERATED , , .,„ „ MASTER VALVE moulimem ,. ■ amlow Q r t i MANUAL. OPERATED E MASTER VALVE t ...lo..hw ...11111111111ww s 10•1111r10r Stinger Stinger I I MANDREL 4 III IN 11 ........, s. TT :0 ..�^ ALVE { » \. OPEN E - • 7 y,,, f tti; %Mu • k O \`* FLOW TEE AND .tj UM ft- - VENT VALVE WELLHEAD a i Ohm VALVES 'U /f/ /� /! OPEN a n r ]� Ilia VALVES WE r f` CLOSED 1. *.e% IN =". 4 kWil n °, QUAD PACKOFF %., ti* ASSEMBLY IN i E; wrr ti PUCE IN TUBING N. Til61NG 4 • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 L /2 tubing and 1.75" down 3 %2 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm RB GU3 -111 • FIO FIORD 5PB1 . • • 4. • 1. i;D3- 301APB1 CD3 1 • CD3 -115 • • • 4 CD3 -118 '� C�3 302 • • • a • CD3 117 • • • NIGLIQ 1A �i....._ r • • i Legend • • • • • • • • • • • • • r ''. wen , • • • • • • • • •,...,: ur • ,,,,,.._,...N..... Service ...; • • . ,tMS.tt:;.t�,i.:i1i,• Producer :s"' +isn + + + t 1 • Observation • • y, :.""". .... ,..,. "?�'� . Injection: SW • .. ,,!; * .,. • Injection: SAPW II • Injection: PW r ° ' • • • • ., ?8 �,. " " • Injection: MWAG ACTIVE INJ, MG • • • • +, d • ` i' ACTIVE sal , INJ, IWAG ACTIVE, INJ, GAS • •s "'•• '•••' ACTIVE, INJ, DG • •; ACTIVE, I NJ , < PartNull> • :•s ; ;; ••• "' j o ® CD3 -113 CD3 127P81 s p ConocoP hillips Operated Units • CD3 125PB1 Nanuq Nanu Participating Area p NPR -A boundary 4 COI"tOCOP 1IlIIpS • CD 3 -1 Fracture Locatins • N Frac CONFIDENTIAL • A 0 :el. 25 0.5 • CD3 -123 1 miles i FrPm CS 1 -10 -2013 • CD3-1 13 Nechelik Frac Model • ., Frac Design --km? Job Description Step Pump Fluid Name Step Fluid Gel Prop. Prop. • Name Rate Volume Conc. Type and Mesh Conc. (bbl/min) (gal) {Ibfmgal} (PPA) Pad 40.0 YF125ST 21840 25.0 0.00 2.0 PPA 40.0 YF125ST 9269 25.0 CarboLite 16/20 2.00 4.0 PPA 40.0 YF125ST 17157 25.0 CarboLite 16/20 4.00 4.0 PPA 40.0 YF125ST 14297 25.0 CarboLite 16/20 4.00 7.0 PPA 40.0 YF125ST 27650 25.0 CarboLite 16/20 7.00 Flush 40.0 WF125 6722 25.0 0.00 Fluid Totals • 90212 gal _ of YF125ST 6722 gal _ of s WF125 Proppant Totals 337900 lb of s CarboLite 16/20 M odel Initial Fracture Top TVD.__ 6960.0 ft Initial Fracture Bottom T11D _--- _ - - - 7010.0 ft • Propped Fracture Half- Length._____-p-__ .315.4 It EOJ Hyd Height at well 140.8 ft Average Propped width �_��_�--- _ - - - -� 0.401 in • Disclaimer Notice: — This model was generated using vendor supplied modeling software and is based on engineering estimates of reservoir • properties. ConocoPhillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. ~: y w ~:. ~~ ~+ i ~ `!~ ~Y`c • '~ i .. ~~ ~.. n~ ~ t~. r l ~,~~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~ ~: /4~~ ~~ ~1 DATA SUBMITTAL COMPLIANCE REPORT 3/1/2010 Permit to Drill 2070040 Well Name/No. COLVILLE RIV FIORD CD3-113 Operator CONOCOPHILLIPS ALASKA INC MD 17338 TVD 6858 Completion Date 2/25/2008 Compietion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION Mud Log No Samples No API No. 50-103-20541-00-00 UIC N Directional Survey DATA INFORMATION Types Electric or Other Logs Run: GR/RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log! Electr Data Digital Dataset Log Log Run Interval OH ! Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~D D Asc Directional Survey 0 9374 Open 3/27/2007 ED C Lis 15113~nduction/Resistivity 2593 9374 Open 5/8/2007 LIS Veri, FET, GR, ROP i Rpt 15113 LIS Verification 2593 9374 Open 5/8/2007 LIS Veri, FET, GR, ROP i !I pt Directional Survey 0 17338 Open 5/7/2008 pt LIS Verification 2593 17338 Open 5/19/2008 LIS Veri, GR, FET, RPS, RPM, RPD, RPX ~~ ~ ED C Lis 16264~nduction/Resistivity 2593 17338 Open 5/19/2008 LIS Veri, GR, FET, RPS, I RPM, RPD, RPX !! ~;JCog Induction/Resistivity 25 Col 114 6858 Open 5/19/2008 TVD ROP, DGR, GM, __ EWR, ALD Log Induction/Resistivity 25 Col 114 17338 Open 5/19/2008 MD ROP, DGR, GM, EWR, ALD ED C 16265 /See Notes 0 0 5/19/2008. MD and TVD of EWR, ROP, GM and DGR logs in I CGM, PDS and EMF graphics ~ Well Cores/Samples Information: Sample interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 3/1 /2010 Permit to Drill 2070040 Well Name/No. COLVILLE RIV FIORD CD3-113 Operator CONOCOPHILLIPS ALASKA INC MD 17338 TVD 6858 Completion Date 2/25/2008 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMATION Well Cored? Y ll~ Daily History Received? Y Chips Received? ~#- Formation Tops ~ N Analysis Y-~-1d~ Received? API No. 50-103-20541-00-00 Comments: Compliance Reviewed By: _______ ~~"'-_L"_ Date: __. ~_~~~" ~ ''~-~ ~~ C~ s ~+ • Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] ~ ~~i~ Sent: Friday, February 05, 2010 5:31 PM ~~~ Page 1 of 2 ~'~(,. Cl~ 3- I l 3 P %~ zo7- c~~ G To: Regg, James B (DOA) Cc: ALP DS Lead and Simops Coord; DOA AOGCC Prudhoe Bay; NSK Problem Well Supv; NSK Prod Engr Specialist; NSK Well Integrity Proj Subject: RE: Request clarification regarding a SSSV Attachments: 01 _SafetyValveSysGuide. pdf Jim, The SSSV was repaired and tested on 1/25/10 and can be witnessed as scheduling allows. ...~ CPAI only allows 24 hr man watches on LPS systems as outlined in the Safety Valve Systems Guidelines ..~ published by the AOGCC on 08/12/98. Last week there was some confusion with our personnel caused by the wording in our internal documents. Our internal documents that were originally created for the Kuparuk field (where SSSV's are not required) did not specifically exclude SSSV's from the man watch allowance. It is understood that the SSSV's only have the 15 day grace period, however the poor wording of our document led personnel to believe it was ok. We will modified the CPAI guidelines to ensure that all pertinent personnel understand the Regulations. Please let me know if you have any questions. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, January 25, 2010 12:29 PM To: NSK Problem Well Supv; DOA AOGCC Prudhoe Bay Cc: NSK Well Integrity Proj; CPA Wells Supt; ALP Ops Maint Supt; Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Subject: RE: Request clarification regarding a SSSV CO 569 expands on 20 AAC 25.265 by requiring all Fiord Oil Pool production wells to have afail-safe SSV and SCSSV. Those valves must be "maintained in good working order at all times". The Commission's SVS Failure Policy addresses the required response to a failed SVS component and establishes some limited ability to continue operating a well with either a SSV or SCSSV failure. The SCSSV on CD3-113 failed a test on 1/7/2010; that starts the time clock for allowing well to produce up to 2 weeks (within that time the failed valve must be repaired and ready for retest or the well must be shut in). The string of troubleshooting efforts on 1/8, 1/14, 1/22, 1/23, and 1/24 do not restart the 2 week clock. Curious about CPAI's interpretation of Commission rules that led to the decision to produce this well with a failed 2/8/2010 Page 2 of 2 SCSSV beyond the 2 week allowance by instituting a 24 hour manwatch. What constitutes your"24 hour manwatch"? When were you planning to fix the failed SCSSV? Inspector is correct that the well needs to be shut in until the valve is repaired and ready for Commission witnessed test. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, January 25, 2010 11:08 AM To: Maunder, Thomas E (DOA); Regg, James 6 (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPA Wells Supt; ALP Ops Maint Supt Subject: Request clarification regarding a SSSV Jim, ConocoPhillips requests some clarification regarding the SSSV regulations at Alpine. Alpine gas lifted. producer CD3-113 (PTD 207-004) had the following events: 01-07-10: The SSSV was exercised and failed the drawdown test. 01-08-10: The well was SI and further attempts were made to exercise the SSSV with surface controls. The well was then BOL. 01-14-10: The well was SI and slickline attempted to brush and flush and exercise the SSSV manually. Following the slickline work the well was BOL. 01-22-10: The well was SI and slickline continued to troubleshoot the SSSV. Following the slickline work, the well was BOL with a 24 hour manwatch. 01-23-10: Well was SI and continued attempts were made to troubleshoot SSSV with slickline. 01-24-10: Well was BOL with 24 hour manwatch. On 01-24-10, AOGCC witnessed SVS testing was performed on CD3 pad. The Field inspector advised that the well be SI or notification and approval be given to leave the well online. Currently the well is producing with a 24 hour manwatch. It is our understanding that the regulation does not require notification and the well may be produced with a 24 hour manwatch on the pad. Please advise. 2/8/2010 • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri16, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • .:~, ,~~a - APF~ 0 ~ 2000 ° til as ~'nso C~~ ~sso~ ~~ .>_ t~'~ ~.~' " ~~ ~ -- ~,~ ~~ Enclosed please fmd a spreadsheet with a list of wells from the Coville River Unit (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with 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 Apri15~', 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. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Alpine Field Ila+p 4/6/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al CD3-301 206-020 9" NA 9" NA 0.85 4/5/2009 CD3-302 206-010 5" NA 5" NA 0.43 4/5/2009 CD3-303 208-013 9" NA 9" NA 1.70 4/5/2009 CD3-305 208-193 8" NA 8" NA 0.85 4/5/2009 CD3-316A 208-011 26" NA 26" NA 8.93 4/5/2009 CD3-107 206-189 34" NA 34" NA 11.05 4/5/2009 CD3-108 205-033 10" NA 10" NA 1.26 4/5/2009 CD3-109 205-059 9" NA 9" NA 2.13 4/5/2009 CD3-110 205-041 4" NA 4" NA 0.43 4/5/2009 CD3-111 206-030 5" NA 5" NA 0.85 4/5/2009 CD3-112 206-032 3" NA 3" NA 0.43 4/5/2009 CD3-113 207-004 14" NA 14" NA 1.28 4/5/2009 CD3-114 207-033 5" NA 5" NA 0.85 4/5/2009 CD3-115 209-006 8" NA 8" NA 1.28 4/5/2009 CD3-117 209-026 6" NA 6" NA 0.43 4/5/2009 CD3-118 208-025 8" NA 8" NA 0.85 4/5/2009 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Sunday, July 20, 2008 12:29 PM To: Allsup-Drake, Sharon K Cc: 'Chip Alvord ;Liz Galiunas Subject: 207-004_CD3-113_407. pdf Attachments: 207-004_CD3-113 407.pdf Sharon, et al, I am in catching up and reviewing the 407 for this well. I have attached a copy of page 1. It appears that the PBTD entered is not correct. The depth entered is the 7" casing shoe and the completion interval for the well is the 4-1/2" perforated liner run to a TD of 17280. I have used the top of the guide shoe as the PBTD. Please let me know if you agree with this determination. I have made hand corrections on the 407, so there is no need to send in a new one. I have found one other report where the 7" casing shoe is shown as the PBTD. I will send a separate message on that one. I am not sure if there are other 407s with the 7" shoe .listed as PBTD. I will check reports as I can, however it may be appropriate to confirm that there aren't other reports out there with similar errors. Call or message with any questions. Tom Maunder, PE AOGCC 7!20/2008 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-113 i May 2, 2008 AK-MW-5556217 CD3-113: 2" x 5" MD ADR Logs: 1 Color Logs 50-103-20541-00 2" x ~" TVD ADR Logs: 1 Color Logs 50-103-20541-00 Digital Log Images: 1 CD Rom 50-103-20541-00 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 _a ,_ Date: '/1 ~, Signed: ~ ~~~ -0G~ ~ 1~~~~ WELL LOG TRANSMITTAL To: State of Alaska Apri130, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Data: CD3-113 RESUBMIT REDO AK-MW-555621 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20541-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 _ __ ; Date: '' ~ ;r;. Signed: ~ ' ~o~-ooh ~/~:~~'I .. 12-Apr-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Sa~rvey Data for Well CD3-113 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) Tie-on Survey: 9,341.76' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 17,338.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBUIRTON.COM OR SIGNING AND RETURNING A COPY OF ~'HE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry~Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 /~ Date ~ Signed lJ Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachmen4~s) 2~-c~7-- ° ~ H STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 207-044 ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 7. Well Name: CD3-113 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ SUSPEND ~ 50-103-20541-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^ or Final ~ 307-067 3/20/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous totals (bbls): 2007 / 1st 0 0 349"` 349 0 2007 / 2nd 0 0 5' S 0 2007 / 3rd 0 0 0 0 0 2007 / 4th 0 0 0 0 0 Zoos / 1st 31520 100 0 31620 33 1/15/2008 3/19/2008 CD3-316, CD3-118 Total Ending Report is due on the 20th volume 31520 100 354" 31974 33 of the month following the final month of the quarter. Ex: (bbis>: July 20 for the second quarter, Apri120 for the first quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fOUrth uarter. 12. Remarks and Approved Substances Description(s): freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~-~~ ~ Date: ~~~ ~ ~~ a Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INJ I KUG I IVIVJ VIV KCVCKJC JIUC .,,.,,,,,,, ~~~ ..,.r~~.,~•., ConocoPhillips April 1, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 Subject: !Nell Completion Report for CD3-113 Dear Commissioner: G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 Per the request from AOGCC, ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the Alpine well CD3-113. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad __ ~ ; r ~ . STATE OF ALASKA ~ APR 0 1 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION RT9~'~DISL~« 1a. Well Status: Oil ^/ Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. W Development Q Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: February 25, 2008 i 12. Permit to Drill Number: 207-004 / 308-034 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: January 24, 2007 13. API Number. 50-103-20541-00 • 4a. Location of Well (Governmental Section): Surface: 3955' FNL, 914' FEL, Sec. 5, T12N, R5E, UM• 7. Date TD Reached: February 21, 2008 14. Well Name and Number: CD3-113 Top of Productive Horizon: 2564' FNL, 772' FEL, Sec. 6, T12N, R5E, U M ~1 8. KB (ft above MSL): ~ 37' RKB ~ Ground (ft MSL): d-49.5' AMSL~ 15. Field/Pool(s): Colville River Field e , Total Depth: f~~,," i-' 1337 FNL, 2790' FEL, Sec. 36, T13N, R4E, UM p't~j 9. Plug Back Depth (MD + ND): ~~ ~~a'1 6 MD / ~' TVD Fiord Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 388129. y- 6003820 • Zone- 4 10. Total Depth (MD + ND): ~ ~ 17338' MD / 6858' ND 16. Property Designation: ALK 3sa215, 372105, 384471 TPI: x- 383010 y- 6005290 Zone- 4 Total Depth: x- 378448 ~ - 6011870 Zone- 4 11. SSSV Depth (MD + ND): 2604' MD / 2463' ND 17. Land Use Permit: LAS 2112 18. Directional Survey: Yes ^/ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (lVD): 1249' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/RES 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE G CO D AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTIN RE R PULLED 16" 62.5# H-40 36' 114' 36' 114' 24" pre-installed 9-5/8" 40# L-80 36' 2619' 36' 2482' 12.25" 45o sx Class G, 236 sx Class G 7" 26# L-80 36' 9364' 36' 6910' 8.75" 195 sx Class G, 180 sx Class G 4.5" 12.6# L-80 9208' 17280' 6887' 6859' 6.125" slotted liner 23. Open to production or injection? Yes / No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 9230' 8561' see attached schematic for full details of perforation summary 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none 26. PRODUCTION TEST Date First Production March 6, 2008 Method of Operation (Flowing, gas lift, etc.) gas lift oil Date of Test 3/11!2008 Hours Tested 12 hours Production for Test Period --> OIL-BBL 1881 GAS-MCF 1456 WATER-BBL 1 CHOKE SIZE 100 Bean GAS-OIL RATIO 774 Flow Tubing press. 656 psi Casing Pressure 1700 Calculated 24-Hour Rate -> OIL-BBL 3762 GAS-MCF 2912 WATER-BBL 1 OIL GRAVITY -API (corn) not available 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No / Sidewall Cores Acquired? Yes No / If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. COQ:"F'U'~T101R DAT NONE Z ~ 2 VERtFI@ R Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE _ e [~ ! ('` ~ ` /~ ~~ ~/ z• as t ~ t U ~ t ~t 1~- ~ ~ ~~ .)Ui_ ~ ~ 2DD6 ~.%6~j.~ ~ 28. GEOLOGIC MARKERS (List all formations and m ers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1249' 1249' needed, and submit detailed test information per 20 AAC 25.071. C-30 2629' 2481' C-20 3176' 2866' K-3 4554' 3872' K-2 4784' 4041' Nanuq 7337' 5888' K-1 8640' 6710' Kuparuk C 8878' 6799' Nuiqsut 9021' 6843' Nechelik 9316' 6905' N/A Formation at total depth: Nechelik 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, perforation detail summary 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dina Anderson @ 265-6403 Printed Name Chi Alvord Title: Drillin4 Team Leader Date~~ iw~ Signature~Phone ~ .- ~ ~ - a ~ LfJ INSTRUCTIONS Sharon Allsu/rDrake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ConoccaPhilips Time Log Summary Wel/v7ex+ Web ReAOrt/7tg Well Name: CD3-113 Job Type: DRILLING ORIGINAL Time Logs Date From To Dur S. De th E Da th _ Phase Code Subcode T COM _ 01/24/2007 08:00 09:00 - 1.00 0 114 -___- MIRU MOVE MOB P Moved to CD3-113, spot rig. Scheduled maintenance on TD -Hook up service lines. Installed mouse hole - Flowline - NU Riser. Rid accepted 080 hr 1/2 09:00 13:00 4.00 114 114 MIRU MOVE RURD P PU 5" DP from shed - 66 jts. total - 24 HWDP. 13:00 14:00 1.00 114 114 MIRU MOVE RURD P Cut Drilling line. 14:00 16:00 2.00 114 114 MIRU MOVE RURD P PU BHA - MU Bit -Orient -Upload MWD 16:00 17:30 1.50 114 114 MIRU MOVE RURD P Pre Spud Meeting -Fill Riser -Check for Leaks -Test Mud Lines to 3500 si. 17:30 00:00 6.50 114 525 SURFA DRILL DDRL P Drilled 12 1/4" hole from 114' to 525' MD 525' TVD ADT 2.24 hrs ART 2.07 hrs AST 0.17 hrs. WOB 10/15 K, RPM 0/40, GPM 449 PP 960 psi. PU Wt 110 - SO Wt 105 -ROT Wt 100 K Torq ON 4500 Off 3500 Ft Lbs. 5 G ro surve s. 01/25/2007 00:00 12:00 12.00 525 1,489 SURFA DRILL DDRL P Drilled 12 1/4" hole from 525' to 1,489' MD 1,485' TVD ADT 7.1 hrs ART 4.19 hrs AST 2.91 hrs. WOB 10/25 K, RPM 0/60, GPM 550 PP 1025 psi. PU Wt 130 - SO Wt 128 -ROT Wt 130 K Torq ON 6000 Off 4000 Ft Lbs. 4 G ro surve s. 12:00 00:00 12.00 1,489 2,398 SURFA DRILL DDRL P Drilled 12 1/4" hole from 1,489' to 2,517' MD 2,398' TVD ADT 8.14 hrs ART 5.58 hrs AST 2.56 hrs. WOB 15/25 K, RPM 0/60, GPM 600 PP 2020 psi. PU Wt 135 - SO Wt 135 -ROT Wt 140 K Tor ON 6500 Off 6000 Ft Lbs. F~age 1 of ~ • Time Logs _ ___ Date From To Dur S. De th E De th Phase Code Subcode T COM 01/26/2007 00:00 01:45 1.75 2,398 2,630 SURFA DRILL DDRL P D ~ 1 1 f/ 2,517' 1;/ 2.630, ADT 1.75 hrs ART .50 hrs AST 1.25 hrs. WOB 15/25 K, RPM 0/60, GPM 650 PP 2120 psi. PU Wt 140 - SO Wt 135 -ROT Wt 135 K Tor ON 6500 Off 6000 Ft Lbs. 01:45 02:30 0.75 2,630 2,630 SURFA DRILL CIRC P Circulate hole clean. 650 GPM - 60 RPM - PP 2120 psi. Flow Check static. 02:30 06:00 3.50 2,630 820 SURFA DRILL WPRT P POOH to 820' Backreaming with 60 RPM and 550 GPM Slowed to 400 GPM above Permafrost. Blow down TD -Flow check static. 06:00 07:15 1.25 820 2,630 SURFA DRILL WPRT P RIH to 2,630'. 07:15 08:15 1.00 2,630 2,620 SURFA DRILL CIRC P Circulate hole clean. 650 GPM - 60 RPM - PP 2120 si. Blow dwn TD. 08:15 11:45 3.50 2,620 220 SURFA DRILL TRIP P Flow checked well- static. POOH from 2,630' to 220' on TT. Stand back HWDP. 11:45 14:30 2.75 220 0 SURFA DRILL RURD P SB Jars - NMFC's. Download MWD Data -Break Bit - LD BHA -Clear floor. 14:30 16:00 1.50 0 0 SURFA CASIN RURD P RU for 9-5/8" casing run: PU csg elevator, bails, slips, casing tongs, work latform. MU fill u tool. RU 16:00 16:15 0.25 SURFA CASIN( SFTY P PJSM. 16:15 18:00 1.75 0 1,354 SURFA CASINC RNCS P RIH with 9-5/8" 40# L-80 BTC casing__ as follows: Float Shoe "Ray oil tools Silver Bullet" - 2 jts csg - Halliburton Float Collar - 33 jts csg. First 4 jts made up with Baker Loc.- Bowspring centralizers on jts #1-13 & every other 't after. Sto rin son 'ts #1 & 2. 18:00 18:30 0.50 1,354 1,354 SURFA CASINC CIRC P Circ PV @ 50 spm - ICP 220, FCP 180 si. 18:30 21:00 2.50 1,354 2,619 SURFA CASINC RNCS P Run 32 jts 9-5/8" -FMC Gen V Hgr. (67 total jts) Landed csg on hgr, shoe 2619' MD. 21:00 22:00 1.00 2,619 2,619 SURFA CASINC RURD P LD Franks FU tool -Blow dwn TD - MU Cement Head. 22:00 00:00 2.00 2,619 2,619 SURFA CASIN CIRC P Condition mud and establish circulation at 1.5 bpm working up to 7 bpm @ 280 psi. PJSM for csg cement 'ob. Page 2 cif 9 Time Logs Dur 5. De th E. De th Pha e Code Subcode T COM Date From To 01/27/2007 00:00 _ 02:00 2.00 2,619 0 SURFA CEME~ DISP P Cement 9 5/8" csg as follows :Rig Pumped 40 bbls Biozan water w/nut plug as marker -Pumped 5 bbls water w/ Dowell -Tested lines to 2500 psi - Pumped -Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 356 bbls lead slur ASL @ 10.7 ppg (` Observed nut plug marker @ shakers w/ 342 bbls lead pumped -pumped down surge can) Pumped 48 bbls tail slurry (Class G w/additives 15.8 - Dropped top plug w/ 20 bbls water f/ Dowell -Switched over to rig pumps & displaced cmt w/ 173 bbls 9.7 ppg water base mud -Displaced @ 7.0 bbls/min for first 170 bbls -slowed to 4 bbls/min for last 2.9 bbls -Bumped plug w/ 1100 si re bum ressur 59 ~ .Check float (held OK) CIP @ 01:54 hrs. -Full circulation throughout job w/ 145 bbls 10.7 cmt returns to surface - reci rotated i e while circulatin &throu hcement'ob. 02:00 02:45 0.75 0 0 SURFA CASINC DHEQ P RU and test 9 5/8" casin to 2,500 si for 30 Min. 02:45 05:30 2.75 0 0 SURFA CASINC RURD P Rigged down Cement head and casing running tools. Released riser connection. 05:30 07:00 1.50 0 0 SURFA CASINC NUND P Nippled down riser. 07:00 09:00 2.00 0 0 SURFA WELCT NUND P Nippled up BOP. 09:00 09:30 0.50 0 0 SURFA DRILL RURD P Changed out Top Drive sub. 09:30 14:30 5.00 0 0 SURFA WELCT BOPE P Set test plug. Test BOPE Annular 250 / 3500 si. Lwr & Blind rams, upper rams with 4" & 5". Tested HCR & Man choke, kill choke, Valves 1-16, Auto and manual IBOP, dart & TIW to 250 / 5000 si. Pulled test lu . 14:30 15:30 1.00 0 0 SURFA WELCT P Install wear ring -Blow down choke & kill -Install Bails and elevators. 15:30 18:30 3.00 0 262 SURFA DRILL RURD P PU BHA #2 -Test GeoSpan to 3500 psi -Shallow test MWD tools @ 262' - PU Jars. 18:30 20:00 1.50 262 2,437 SURFA DRILL TRIP P RIH to 2437' with HWDP - WF Ghost Reamers - 5" DP - XO to 4" DP. 20:00 20:30 0.50 2,437 2,536 SURFA DRILL DDRL P Wash down to 2536' and tag Float Collar/Plugs @ 550 GPM - 90 RPM - 1700 si. 20:30 23:00 2.50 2,536 2,630 SURFA DRILL DDRL P Drilled shoetrack from 2536' to 2620'. Cleaned out rathole to 2630'. FC took 40min, FS took 25 min. Rubber along side BHA. Page 3 of 9 Time Logs Da e From To Dur S De th E. De th Ph se Code Subcode T COM 01/27/2007 23:00 23:15 0.25 2,630 2,650 SURFA DRILL DDRL P Drill 20' new hole f/ 2540' U 2560' MD 2496' ND ADT - 0.15 hrs WOB 3/10 90 RPM 584 GPM @ 1900 psi Up Wt -135, Dwn Wt -125, Rot Wt 130 psi. On /Off Tr - 7500 / 7000 ft*Ibs 23:15 00:00 0.75 2,650 2,650 SURFA DRILL CIRC P Circulate and condition mud for FIT @ 584 GPM - 90 RPM - 1860 si. 01/28/2007 00:00 01:00 1.00 2,598 2,650 SURFA DRILL FIT P Pull up into csg -Blow Dwn TD - RU & perform formation integrity test to 18 EMW - 9.5 mud 24 ' ND. RIH to 2650'. 01:00 12:00 11.00 2,650 3,872 INTRM1 DRILL DDRL P Displace to 9.6 ppg LSND mud system. Drilled 8-3/4" hole w/GeoPilot fl2650' t/3872' MD 3372' ND ADT = 5.55 hrs ECD = 11.29 WOB = 15/25 K RPM = 130 GPM = 600 @ 2020 psi PU Wt = 148 SO Wt = 127 ROT Wt = 135 K Tor On/Off btm = 8000/6000 ft/Ibs 12:00 00:00 12.00 3,872 5,488 INTRM1 DRILL DDRL P Drilled 8-3/4" hole w/GeoPilot f/3872' t/5488' MD 4548' ND ADT = 8.05 hrs ECD = 10.9 WOB = 16/19 K RPM = 130 GPM = 650 @ 2770 psi PU Wt = 175 SO Wt = 137 ROT Wt=154K Tor On/Off btm = 10,000/8000 ft/Ibs 01/29/2007 00:00 12:00 12.00 5,488 7,007 INTRM1 DRILL DDRL P Drilled 8-3/4" hole w/GeoPilot f/5,488' t/7,007' MD 5,650' ND -ADT = 7.01 hrs -ECD = 11 WOB = 15/25 K RPM = 130 GPM = 650 @ 3270 psi PU Wt = 205 SO Wt = 146 ROT Wt=166K Tor On/Off btm = 12,000/9,000 ft/Ibs 12:00 00:00 12.00 7,007 8,070 INTRM1 DRILL DDRL P Drilled 8-3/4" hole w/GeoPilot f/7077' U8070' MD 6402' ND -ADT = 8.04 hrs -ECD = 10.43 WOB = 20/23 K RPM = 90 GPM = 500 @ 2200 psi PU Wt = 207 SO Wt = 165 ROT Wt = 183 K Tor On/Off btm = 12,500/8000 ft/Ibs Fie 4 oaf ~ Time Logs ~ _ __ Date From To Dur S_De th E. De th Ph Code Subcode T COM 01/30/2007 00:00 12:00 12.00 8,070 8,883 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GP f/ 8070' to 8883' MD - 6800' TVD ADT - 8.22 hrs ECD - 10.36 ppg WOB 20/25 k RPM 130 GPM 650 @ 3500 psi String wt. PU 204 SO 165 Rot 185 Tor ue on/off btm. -11,500/8,500 ft/Ibs 12:00 17:30 5.50 8,883 9,374 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/GP f/ 8883' to 9374' MD 6911' TVD ADT - 3.98 hrs ECD - 10.6 ppg WOB 20/25 k RPM 130 GPM 650 @ 3780 psi String wt. PU 200 SO 160 Rot 185 Torque on/off btm - 13,000 / 9,500 ft/Ibs 17:30 20:00 2.50 9,374 9,107 INTRM1 DRILL WPRT P Circulate 3x BU @ 450 GPM, 130 RPM, 2000 psi. Standing back 1 std every 30 minutes to 9107' MD. #2 Mud Pump down due to wash out on dischar a side. Flow check static. 20:00 22:00 2.00 9,107 8,249 INTRM1 DRILL WPRT P Short trip with pump from 9107' to 8249' MD @ 450 GPM, 90 RPM, 1950 si. Blow Dwn TD. Flow check static. 22:00 22:30 0.50 8,249 9,298 INTRM1 DRILL WPRT P RIH from 8249' - 9298' MD. 22:30 00:00 1.50 9,298 9,374 INTRM1 DRILL TRIP P Precautionary wash down to 9374' MD. Circulate and condition mud for trip out. Pump 2x BU @ 450 GPM, 120 RPM, 2100 psi. Make up wellbore stren thenin and Lube ill in the its. 01/31/2007 00:00 00:45 0.75 9,374 9,374 INTRM1 DRILL CIRC P Circ hole clean -flow ck (static) -Spot WSP & Lub ills to bit 00:45 03:00 2.25 9,374 7,964 INTRM1 DRILL TRIP P POOH spotting WS & CL pills to top of HRZ 8278' -POOH w/ pump to 7964' -Flow ck static -Blow down TD 03:00 12:00 9.00 7,964 1,395 INTRM1 DRILL TRIP P POOH on TT to 5583' -Hole in good condition & taking proper fill -Flow ck (static) Pump dry job -Blow down TD - Continue to POOH on TT to 9 5/8" shoe -Flow ck (static) Cont. POOH to 1395' 12:00 13:30 1.50 1,395 716 INTRMI DRILL TRIP P Continue POOH on TT to 716' MD - Flow check static - SB HWDP. 13:30 16:00 2.50 716 0 INTRM1 DRILL PULD P Stand back NMFC -Read MWD data - Break off Bit & Service GP - LD BHA. 16:00 16:30 0.50 0 0 INTRM1 DRILL RURD P Clean and clear rig floor for casing run. Pull wear rin . 16:30 19:00 2.50 0 0 INTRM1 DRILL P CO to rams to 7" and test to 250 & 5000 si. Install thin wear rin . 19:00 20:45 1.75 0 0 INTRM1 CASIN RURD P RU for 7" casing run: PU csg elevator, bails, slips, casing tongs, and work latform. MU fill u tool. 20:45 21:00 0.25 0 0 INTRM1 CASIN( SFTY P PJSM to discuss running casing. P~acJ~ s of 9 Time Logs _ -Date From To Dur S. De th E. De th Phase Code Subcode T COM 01/31/2007 21:00 00:00 3.00 0 1,783 INTRM1 CASIN RNCS P Run 7" 26# L-80 BTCM csa as follows: Ray Oil Tools Float shoe - 2 jts csg - Halliburton Float collar - 2 jts csg.(first 4 connections made up w/ Baker Loc -Filled pipe & checked float) - 38 jts to 1783' (42 jts total) Ran centralizers on 'ts. # 1-14 02/01/2007 00:00 00:45 0.75 1,783 2,757 INTRM1 CASIN RNCS P Continue running 7" csg f/ 1783' to 2757' (65 jts. total) PU wt. 135 SO 125 00:45 01:15 0.50 2,757 2,757 INTRM1 CASINC CIRC P Break circ & stage pump to 5 bbls/min -Circ i e vol. - 5 bbls/min 290 si 01:15 02:45 1.50 2,757 4,076 INTRMI CASINC RNCS P Continue running 7" csg f/ 2757' to 4076' . to 02:45 03:00 0.25 4,076 4,079 INTRM1 CASIN RNCS P Install TAM 96. Baker I 03:00 04:45 1.75 4,079 5,539 INTRM1 CASINC RNCS P Continue running 7" csg f/ 4079' to 5539' (130 jts. total) PU wt - 200 SO wt 150 04:45 05:30 0.75 5,539 5,539 INTRM1 CASIN CIRC P Break circ & stage pump to 4 bbls/min -Circ btms u 320 si 05:30 08:30 3.00 5,539 8,113 INTRM1 CASINC RNCS P Continue running 7" csg f/ 5539' to 8113' (190 jts. total) PU wt. 200 SO wt. 150 08:30 09:30 1.00 8,113 8,113 INTRM1 CASINC CIRC P Break circ & stage pump to 4 bbls/min -circ btms u 390 si 09:30 11:15 1.75 8,113 9,364 INTRM1 CASINC RNCS P Finish runni " csa f/ 8113' to 9328' 21 ' s. tal - PU FMC fluted hanger & landing jt. -Land 7" csg w! FS 93 4' F - 5285' 11:15 12:00 0.75 9,364 9,364 INTRM1 CASIN OTHR P LD fill - up tool -Blow down TD - RU cmt head & lines 12:00 14:00 2.00 9,364 9,364 INTRM1 CEME~ CIRC P Est. Circ@ 1.5 bbls/min & stage pump up to 5.5 bbls/min -Circ & condition for cmtjob - ICP 610 psi - FCP 460 psi -Held pre -job safety meetin 14:00 16:00 2.00 9,364 9,364 INTRM1 CEME~ DISP P Cement 7" casing as follows: Pumped 5 bbls CW-100 -Pressure test lines to 3700 psi -Pumped remaining 15 bbls CW-100 -Mix & pumped 40 bbls - 10.5 ppg MudPush -Dropped btm plug - Mixed & pumped 40 bbls 15.8 ppg__ tail slurry (Class G w/ additives) - Dropped top plug w/ 20 bbls fresh water f/ Dowell -Switched to rig pumps & displaced cmt w/ 133 bbls 9.6 ppg inhibited brine followed by 199.6 bbls 9.6 ppg brine -Displaced @ 6 bbls/min - 250 to 580 psi for first 310 bbls -slowed pumps to 3.5 bbls/min - 360 to 580 psi for last 22.6 bbls of displacement -Bumped plug w/ 1 ~ -Checked floats OK - CIP @ 15:45 hrs.- Full returns & pipe movement hr Pa~}~ 8 of 9 • Time Logs Date From To Dur S Depth E. Depth Phase Code Subcode T COM 02/01/2007 16:00 17:30 1.50 0 0 INTRM1 CEME RURD P RU and test Casin to 3500 si for 15 minutes. RD Cement equipment and and landin 't. 17:30 18:30 1.00 0 0 INTRM1 CASIN( DHEO P Pull thin wall wear ring -Install and test PO to 5000 si for 10 minutes. 18:30 20:30 2.00 0 0 INTRM1 WELCT OTHR P Change upper rams to 3-1 /2" x 6" VBR's and test to 250 / 5000 psi. Pull test lu and set wear bushin . 20:30 00:00 3.50 0 0 INTRM1 CEME PULD P MU TAM combo tool. Unable to RIH w/combo tool. The upper seal cups appear to be hanging up just inside 7" casing. MU 1 std HWDP for added wrt. 02/02/2007 00:00 05:15 5.25 0 5,166 INTRM1 CEME TRIP P MU Tam Combo tool & RIH w/tool on 4" DP to 5166' MD. 05:15 07:00 1.75 5,166 5,288 INTRM1 CEME RURD P PU a single jt and RU swivel, XO, TIW Valve for cementing. RIH t/ 5288' to locate the combo tool inside the port collar. 07:00 07:30 0.50 5,288 5,288 INTRM1 CEME RURD P RU Cement hose and valves. 07:30 08:00 0.50 5,288 5,288 INTRM1 CEME CIRC P Circulate PV to ensure ball seat clean - 50 BBLS of 9.6 ppg brine, 20 spm @ 110 si. 08:00 08:45 0.75 5,288 5,288 INTRMI CEME CIRC P Displace drill string with 9.8 ppg mud while pumping down ball to choke seat - 25 spm @ 210 psi. Pressure test tool to 1000 si. 08:45 10:00 1.25 5,288 5,288 INTRMI CEME CIRC P Slack off 10,000 psi to open port collar -open annulus valve & attempt to establish circulation 15 s m through PC. Flow observed at flowline. Close H dril -achieved flow throu h annulus. Stage pumps to 50 spm @ 770 si um in BU's. 10:00 10:30 0.50 5,288 5,288 INTRM1 CEME CIRC P Bleed off pressure -open Hydril - 2nd Attempt to circulate thru annulus pumping 50 spm. Flow observed again at flowline. 10:30 12:00 1.50 5,288 5,288 INTRM1 CEME OTHR P Suspect ball not on seat -Begin steps for 2nd ball drop: Close hydril and displace drill string with 9.8 ppg mud - 50spm - 730 psi. PU 12,000 psi to shift port collar closed. Blow ballseat with 2600 psi. Drop 2nd ball & chase to seat with mud. Unable to PT. 12:00 12:45 0.75 5,288 5,288 INTRM1 CEME CIRC P PUH 12' above port collar to 5276' MD. Test on blank pipe. RIH to located on port collar -slack off to 12,000 psi to open. Circulate and condition for cement 'ob - 5 b m - 880 si. PJSM. Page 7 €~f ~~ • Time Loas Date V From To Dur 5 D th E. De th Phase Code Subcode T COM 02/02/2007 12:45 14:15 1.50 5,288 5,288 INTRM1 CEME DISP P Cemented 2nd sta a cmt'ob to isolate Qannik formation as follows: Pumped 5 bbls CW-100. Tested lines to 3500 psi. Pump 5 bbls CW-100. Mixed and pumped 20 bbls Mud Push @ 10.5 ppg - 3.96 bpm, 700 psi followed by 37 bbls tail slurry - 15.8 ppg Class GCement - @ 4 bpm, 450 psi. Displaced w/10 bbls fresh water from Dowell. Inserted wiper plug & displaced cement with 48.4 bbls of 9.6 ppg brine. Plug bumped -Pressured up to 3600 psi attempting to shear plug catcher -Unsuccessful -Cement in Place at 1405 hrs. 14:15 15:15 1.00 5,288 5,160 INTRM1 CEME RURD P Shift port collar closed. SB to 5160'. Break out and lay down side entry assembl and RD Cement E ui ment. 15:15 20:15 5.00 5,160 124 INTRM1 CEME TRIP P Flow check well -static. Pooh on TT f/ 5160' - 124'. LD HWDP. LD Tam combo tools. Dart lodged inside the to of dart catcher. 20:15 21:15 1.00 0 0 INTRM1 CEME OTHR P RU and test 7" Cs to 35 0 ' minu 21:15 22:15 1.00 0 0 INTRM1 CEME PULD P Break down TAM tools. 22:15 23:45 1.50 0 2,581 INTRM1 DRILL TRIP P RIH t/ 2581' with 4" DP. 02/03/2007 00:00 00:30 0.50 2,581 5,241 INTRM1 DRILL TRIP P Continue RIH w/ 4" DP f/ 2851' to 5241' - Strin wt. PU 145 SO 120 00:30 00:45 0.25 5,241 5,241 INTRM1 DRILL SFTY X Pre-job on Inhibited brine dis lacement. 00:45 01:30 0.75 5,241 5,241 INTRM1 DRILL CIRC X Displace hole w/ 9.6 ppg inhibited brine f/ 5241' to 1600'. 6 bbls/min @ 350 si. 01:30 06:00 4.50 5,241 0 INTRM1 DRILL TRIP X POOH & LD 4" DP - 165 jts 06:00 06:15 0.25 0 0 INTRM1 DRILL O]~HR X Pull wear bushing 06:15 07:15 1.00 0 INTRM1 RPCOh OTHR X RU to run 3 1/2" kill string 07:15 07:30 0.25 INTRM1 RPCO SFTY X Pre job meeting on running kill string 07:30 10:45 3.25 0 1,608 INTRM1 RPCOti RCST X Run 3 1/2" kill string as follows: WLEG - 48 jts 3 1/2" 9.3 # EUE tbg - XO 3 1 /2" x 4 1 /2" - 2 jts. 4 1 /2" 12.6# L-80 IBTM tbg -FMC tbg hanger w/ tail 1608' 10:45 12:00 1.25 1,608 1,608 INTRM1 RPCOh OTHR X Run -in lock downs - LD landing jt A - Set TWC - MU landing jt. B -Test han er seals to 5000 si OK 12:00 12:30 0.50 0 0 INTRM1 RPCOh OTHR X Lay down Geospan and Ghost Reamers 12:30 14:00 1.50 0 0 INTRM1 RPCO OTHR X Lay down mouse hole & ND BOPE. 14:00 15:30 1.50 0 0 INTRMI RPCOti OTHR X NU Tree and test to 5000 psi. Test Han er to 5000 si. Pull TWC. Time Logs _ ~_ Date From To Dur S. De th E. Depth Phi e Code Subco e T COM 02/03/2007 15:30 17:00 1.50 0 0 INTRM1 RPCOh OTHR X PJSM. Displace with 60 bbls diesel. Blow dwn R/D lines. 17:00 18:00 1.00 0 0 INTRM1 RPCOh OTHR X et BPV -secure well. Ri released at 1600 .hrs. Page ~ of 9 • i ~onocaPhillps Time Log Summary We/iview Web ReAOrtfig Well Name: CD3-113 Job Type: DRILLING RE-ENTRY Time Logs __ From To Dur S. De th E. De th Phase Code Subcode T COM Date _ 02/12/2008 12:00 14:00 2.00 0 MIRU MOVE RURD X Rigged down and moved Ball Mill and Pi eshed. 14:00 22:30 8.50 MIRU MOVE DMOB T Attempted to skid back floor. Would not skid. Trouble shoot and worked free 2230 hrs. 22:30 00:00 1.50 MIRU MOVE RURD X Rigged down to move rig floor back. 02/13/2008 00:00 05:00 5.00 0 0 MIRU MOVE PSIT X Move out Pits and Motor Complex - skid floor to move position -Move off CD3-316 -Move rig on to CD3-113 - skid floor over well center -Move in Pits and Motors Comlex -move in i eshed 05:00 06:00 1.00 0 0 MIRU MOVE RURD X Connect Electric and service lines - air, steam, water and mud - Acce tp ed ~. ri 0600 hours. 06:00 07:45 1.75 0 0 COMPZ RPCO DHEQ X Ru work platform on tree -Thaw out swab valve -Pull BPV - Set TWC 07:45 08:00 0.25 0 0 COMPZ RPCOh SFTY X PJSM -Removing Tree - NU BOPE 08:00 12:00 4.00 0 0 COMPZ WELCT NUND X Remove tree - NU BOPE -riser and flow line -install mousehole NU choke line. "" Notified North Slope Inspector and received approval via email from Town inspector Tom Maunder to test BOPE following decompletion of the tbg string. Contingent on a good 30 min casin test rior to start of 'ob. 12:00 13:00 1.00 0 0 COMPZ WELCT BOPE X RU and test Blind Rams / TWC to 250/3500 -blow down lines -Pull TWC 13:00 13:15 0.25 0 31 COMPZ RPCOh OTHR X PU & MU LJb to tubing hanger 13:15 13:30 0.25 31 31 COMPZ RPCOh SFTY X Pre-job Safety and Opts meeting for dis lacin diesel to Ti er tank 13:30 14:30 1.00 31 31 COMPZ RPCOh CIRC X Test return line to 500 psi -Displace freeze protection diesel from 1606' - FCP 430 psi @ 4 bpm -blow down lines 14:30 15:30 1.00 31 31 COMPZ RPCOh DHEQ X RU and test casin to 3500 si for 30 minutes - RD /blow down lines 15:30 16:45 1.25 1,606 1,482 COMPZ RPCO PULD X BOLDS- pull hanger and kill string - LD tubing hanger - LD 2 jts of 4 1/2" tubing and XO -change running tools to 3 1/2" 16:45 19:45 3.00 1,482 0 COMPZ RPCOh PULD X POOH - LD 48 jts of 3 1/2" tubing 19:45 00:00 4.25 0 0 COMPZ WELC BOPE X Set test plug and tested BOPE to 250/3500 si. Time Logs e th E. De th Date From To Dur S D PhaSe Code Subcode T COM 02/14/2008 00:00 01:45 1.75 _ 0 0 COMPZ WELC BOPE X Tested pipe rams with 3 1/2", 4"and 4 1/2" test joints 250 / 3500 psi- Performed koome tests 01:45 02:15 0.50 0 0 COMPZ WELC OTHR X Pull test plug and set wear ring 02:15 02:45 0.50 0 0 INTRM1 DRILL OTHR P Change elevators -move small bha com onents to ri floor 02:45 07:15 4.50 0 393 INTRM1 DRILL PULD P MU BHA #1 -Bit, 5200 Geo-Pilot, GP flex, DM HOC, ILS, ADR, ILS, Gamma, PWD, TM HOC, FS, IBS, - Initialize tools -continue to MU BHA - 3 Flex collars, xo, 3 jts. hwdp, jars, 2 jts. hwdp -Pressure test mud lines and Geo-Span to 3500 psi -Shallow test tools 220 m / 230 si 07:15 08:45 1.50 393 393 INTRM1 DRILL TRIP P RIH -picked up 24 jts. of 4"drill pipe - POH stand back 8 stands 08:45 14:00 5.25 393 5,157 INTRMI DRILL TRIP P RIH picking up 4"drill pipe from 393' to 5157' - fill i e eve 20 stands 14:00 15:45 1.75 5,157 5,729 INTRM1 DRILL REAM P Wash and ream from 5 157' to 5 634' (Tam Collar @ 5,285') - RIH to 5,729' - No indication of cement below ort collar observ d 15:45 96:15 0.50 5,729 5,729 INTRM1 CASIN DHEQ P Pressure test 7" casin to 3500 si for 10 minutes - ood -blow down lines 16:15 19:15 3.00 5,729 9,158 INTRM1 DRILL TRIP P Continue to RIH picking up 4"drill pipe from 5,729' to 9,158' -fill pipe every 20 stands 19:15 00:00 4.75 9,158 9,250 INTRM1 CEME DRLG P Wash and ream from 9,063' -drill out hard cement from 9,115' to 9,250' 02/15/2008 00:00 00:30 0.50 9,250 9,275 INTRM1 CEME DRLG P Drill out cement from 9,250' to 9,275' - 210 gpm / 1230 psi / 60 rpm WOB 3/10 K 00:30 07:30 7.00 9,275 9,278 INTRM1 CEME DRLG P Drill out wiper plugs and float collar from 9,275' to 9,278' - 210 gpm / 1230 si / 60 r m WOB 3/15 K 07:30 08:00 0.50 9,278 9,349 INTRM1 CEME DRLG P Drill out cement from 9,278' to 9,349' 08:00 08:45 0.75 9,349 9,349 INTRM1 CEME CIRC T Circulate BU - 210 gpm / 1210 psi / 70 rpm 12 K ft/Ibs torque -Troubleshoot communication problems with GeoPilot 08:45 10:15 1.50 9,349 9,374 INTRM1 CEME DRLG P Drill out cement, FS and clean out rathole from 9,349' to 9,374' 10:15 10:30 0.25 9,374 9,394 INTRM1 DRILL DDRL P Drill 20' of new hole from 9 374' to 9,394' ADT=0.23 hrs. 10:30 11:30 1.00 9,394 9,394 INTRM1 CEME CIRC P CBU for FIT test - 210 gpm / 1170 psi / 60 rpm -Flow check well, static - Mud wt. in & out 9.0 11:30 12:30 1.00 9,394 9,394 INTRM1 CEME LOT P Blow down top drive - RU and perform FIT to 12.5 EMW - RD & blow down lines Page 2 saf 8 ~, Time Logs __ ~ From To Dur S De th E De th . D te Ph se Code Subcode T COM _ 02/15/2008 12:30 00:00. 11.50 9,394 10,239 PROD1 DRILL DDRL P Drill 6 1/8 "horizontal section w/ GeoPilot f/ 9,394' to 10,239' MD 6922' ND ADT 7.2 hrs. ECD 10.4 ppg WOB 10/13 RPM 135 GPM 210 @ 1590 psi String wt. PU 187 SO 150 Rot 172 Torque on/off btm. -10,000/8,000 ft/Ibs ** Changed mud to 9 PPG FlowPro while drilling. ** ADR tool failed - no deep res signal - Continued drlg w/Shallow res & Gamma. 02/16/2008 00:00 12:00 12.00 10,239 11,196 PROD1 DRILL DDRL P Drill 6 1/8 "horizontal section w/ GeoPilot f/ 10,239' to 11,196' MD 6909' ND ADT 8.31 hrs. ECD 10.4 ppg WOB 10/20 RPM 110 GPM 210 @ 1790 psi String wt. PU 195 SO 143 Rot 170 Torque onloff btm. - 12,000/10,000 ft/Ibs 12:00 00:00 12.00 11,196 12,200 PROD1 DRILL DDRL P Drill 6 1/8 "horizontal section w/ GeoPilot f/ 11,196'to 12,200' MD 6905' ND ADT 8.49 hrs. ECD 10.61 ppg WOB 10/15 RPM 110 GPM 210 @ 1900 psi String wt. PU 200 SO 135 Rot 170 Torque on/off btm. - 12,000/11,000 ft/lbs 02/17/2008 00:00 06:30 6.50 12,200 12,706 PROD1 DRILL DDRL P Drill 6 1/8 "horizontal section w/ GeoPilot f/ 12,200' to 12,706' MD 6904' ND ADT 4.83 hrs. ECD 10.73 ppg WOB 10/15 RPM 110 GPM 210 @ 1980 psi String wt. PU 204 SO 136 Rot 168 Torque on/off btm. -14,000/11,500 ft/Ibs Losses to hole -10 b 06:30 07:45 1.25 12,706 12,706 PROD1 DRILL CIRC T Unable to control GeoPilot toolface - CBU-210 m/1950 si/110r m 07:45 08:00 0.25 12,706 12,706 PROD1 DRILL OWFF T Monitor well -observed slight breathing -returns reduced to a drip in 15 minutes 08:00 14:00 6.00 12,706 9,349 PROD1 DRILL TRIP T POOH from 12,706' to 9349' - 190 gpm / 1580 psi / 80 rpm _ no problems - flow check well, static in 12 minutes 14:00 17:45 3.75 9,349 6,409 PROD1 DRILL TRIP T POOH w/ pump from 9,349' to 6,409' - 105 gpm / 680 psi -Flow check well, static in 8 minutes -Attempted to POOH without um -well swabbin 17:45 18:45 1.00 6,409 6,409 PROD1 DRILL CIRC T Circulated and displaced well to 9.2 PPG brine @ 5 BPM 1100 psi. Flow checked well static. F~age 3 cif ~ • Time Logs Date From To Dur S De th E. De th Phase Code Subcode T COM 02/17/2008 18:45 22:45 4.00 6,409 393 PROD1 DRILL TRIP T POOH on trip tank from 6,409' to 393'. 22:45 00:00 1.25 393 60 PROD1 DRILL PULD T Stood back HWDP and flex collars. Laid down smart stab. 02/18/2008 00:00 01:00 1.00 60 0 PROD1 DRILL PULD T Continued laying down BHA and bit. 01:00 02:45 1.75 0 187 PROD1 DRILL PULD T Picked up new BHA and uploaded tool. 02:45 03:15 0.50 187 290 PROD1 DRILL PULD T Made up XO changed elevators to 290'. 03:15 03:30 0.25 290 290 PROD1 DRILL CIRC T Shallow tested tool OK. 03:30 09:00 5.50 290 9,344 PROD1 DRILL TRIP T RIH from 290' to 9,344' filling pipe eve 20 stands. 09:00 11:00 2.00 9,344 9,344 PROD1 RIGMN SVRG P Slipped and cut drilling line while circulating out brine. Serviced Top Drive. 11:00 14:15 3.25 9,344 12,578 PROD1 DRILL TRIP T RIH from 9,344' to 12,578'. Took surveys @ 9,777', 10,252', 11,817', & 11,912'. 14:15 14:45 0.50 12,578 12,706 PROD1 DRILL REAM T Washed and reamed from 12,578' to 12,706'. 14:45 17:00 2.25 12,706 12,876 PROD1 DRILL DDRL P Drill 6 1/8 "horizontal section w/ GeoPilot f/ 12,706' to 12,876' MD 6908' TVD ADT 1.38 hrs. ECD 10.59 ppg WOB 10/15 RPM 80 GPM 210 @ 1940 psi String wt. PU 204 SO 136 Rot 168 Torque on/off btm. - 14,000/11,500 ft/Ibs Losses h > 17:00 18:15 1.25 12,876 12,876 PROD1 DRILL OTHR NP Relogged hole from 12,876' to 12,620' checking logging tools. Not working. RIH to 12,876'. 18:15 00:00 5.75 12,876 1,330 PROD1 DRILL DDRL P Drill 6 1/8 "horizontal section w/ GeoPilot f/ 12,876' to 13,330' MD 6908' TVD ADT 3.82 hrs. ECD 10.50 ppg WOB 10/15 RPM 80 GPM 210 @ 1940 psi String wt. PU 210 SO 120 Rot 167 Torque on/off btm. - 14,000/12,000 ft/Ibs Losses to hole >8 b h 02/19/2008 00:00 12:00 12.00 13,330 14,350 PROD1 DRILL DDRL P Drill 6 1/8 "horizontal section w/ GeoPilot f/ 13,330' to 14,350' MD 6877' TVD ADT 8.44 hrs. ECD 10.91 ppg WOB 10/15 RPM 80 GPM 210 @ 2150 psi String wt. PU 217 SO 95 Rot 165 Torque on/off btm. - 15,500/12,000 ft/Ibs Losses to hole >8 b h lost 108 bbls mud last 12 hrs. l~~e 4 ~f ~ Time Logs _ __ _ Date From To Dur 5 De th E. De th Phase Code Subcode T COM 02/19/2008 12:00 00:00 12.00 14,350 15,275 PROD1 DRILL DDRL P Drilled 6 1/8" horizontal section w/ Geopilot f/14,350' to 15,275' MD/ 6,876' ND (925') ADT 8.65 hrs, 10-15K WOB, 110 RPM's, 210 gpm at 2,280 psi, 9.0 ppg MW, ECD 11.2 ppg, off btm torque 13K ft-Ibs, on btm 15K ft-Ibs, string wt PU 207K, SO 107K, Rot wt 163K. Cont to ave +/- 8 b h mud losses. 02/20/2008 00:00 12:00 12.00 15,275 16,090 PROD1 DRILL DDRL P Drilled 6 1/8" horizontal section w/ Geopilot f/15,275' to 16,090' MD/ 6,881' ND (815') ADT 8.99 hrs, 10-14K WOB, 110 RPM's, 210 gpm at 2,310 psi, 9.0 ppg MW, ECD 10.93 ppg, off btm torque 11,500 ft-Ibs, on btm 13,500 ft-Ibs, string wt PU 210K, SO 105K, Rot wt 161 K. Cont to ave +/- 10 bph mud losses. Lost 100 bbls mud last 12 hrs. 12:00 00:00 12.00 16,090 16,909 PROD1 DRILL DDRL P Drilled 6 1/8" horizontal section w/ Geopilot f/16,090' to 16,909' MD/ 6,878' ND (819') ADT 8.97 hrs, 10-12K WOB, 110 RPM's, 210 gpm at 2,350 psi, 9.0 ppg MW, ECD 11.15 ppg, off btm torque 13,000 ft-Ibs, on btm 14,500 ft-Ibs, string wt PU 207K, SO 105K, Rot wt 163K. Cont to ave +/- 10 b h mud losses. 02/21/2008 00:00 08:00 8.00 16,909 17,338 PROD1 DRILL DDRL P Drilled 1/8" horizontal section w/ Geo ilot f/16 909' to 17 338' MD/ 6 858' ND T.D. (429') ADT 6.72 hrs, 10-14 K WOB, 110 RPM's, 210 gpm at 2,700 psi, 8.9 ppg MW, ECD 11.53 ppg, off btm torque 13,500 ft-Ibs, on btm 15,000 ft-Ibs, string wt PU 215 K, SO 100 K, Rot wt 163 K. Cont to ave +/- 10 b h mud losses. 08:00 09:45 1.75 17,338 17,338 PROD1 DRILL CIRC P CBU 210 GPM 2700 psi 110 RPM. 09:45 21:30 11.75 17,338 11,056 PROD1 DRILL REAM P Backreamed out of the hole from 17,338'to 11,056', BROOH at 100 rpm's, 200 gpm, ICP 2,400 psi, FCP 1,650 si, no roblems 21:30 22:45 1.25 11,056 11,056 PROD1 RIGMN RGRP T Trouble shoot problem with top drive, worked on pipe grabbers and TD air anel 22:45 00:00 1.25 11,056 10,104 PROD1 DRILL REAM P Cont. to BROOH from 11,056' to 10,104', BROOH at 100 rpm's, 7.5K ft-Ibs torque and 200 gpm at 1,430 psi with no problems, hole taking add. mud over talc fill. 02/22/2008 00:00 01:30 1.50 10,104 9,334 PROD1 DRILL TRIP P Cont. to BROOH from 10,104' to 9,334', (Shoe @ 9,364') BROOH at 100 rpm's and 4 bpm at 1,430 psi with no problems, dropped rabbit @ 9,820'. Monitored well at the shoe, well-static. Aac~e 5 of & • Time Logs Date From To Dur S D th E. De th Phase Code Subcode T COM 02/22/2008 01:30 02:15 0.75 9,334 9,334 PROD1 DRILL CIRC P CBU at the shoe, circ at 210 gpm 1,920 si and 100 r m's. 02:15 03:45 1.50 9,334 8,390 PROD1 DRILL TRIP P POOH 10 stds with pump from 9,334' to 8,390'. 2.5 BPM at 800 psi. Calc fill while POOH to 8,390' 60 bbls, actual fill 130 bbls -70 bbls 03:45 05:00 1.25 8,390 8,390 PROD1 DRILL CIRC P Displaced well to 9.2 PPG brine. 5 BPM 1310 si. Flow checked well OK. 05:00 11:15 6.25 8,390 387 PROD1 DRILL TRIP P POOH on trip tank from 8,390' to 387'. Stood back HWDP & 'ars 11:15 13:15 2.00 387 0 PROD1 DRILL PULD P Laid down BHA #2 and downloaded LWD. Laid down Geos an. 13:15 13:30 0.25 0 0 COMPZ CASINC SFTY P Held PJSM on RU and running of 4 1/2" liner 13:30 14:30 1.00 0 0 COMPZ CASIN( RURD P RU to run 4 1/2" liner 14:30 20:45 6.25 0 8,040 COMPZ CASIN PUTS P PU and RIH with 183 its of 4 112" 12.6 f L-80 IBTM liner with 30 - 4 1/2" x ave of 4.8' Ion erf subs w/6 holes each, RIH to 8,040', ave MU 3,200 ft-Ibs. 20:45 22:00 1.25 8,040 8,081 COMPZ CASIN( PUTS P MU Baker 5" x 7" DG Flex Lock Liner hanger assembly and filled with Pal Mix, RIH to 8,081' liner wt up 150K, do wt 135K. 22:00 22:45 0.75 8,081 9,316 COMPZ CASINC RUNL P RIH with 4 1/2" liner with 4" DP from 8,081' to 9,316'. 22:45 23:15 0.50 9,316 9,316 COMPZ CASIN CIRC P Circ a DP cap. at csg shoe, circ at 4 bpm at 120 psi, PU wt 165K, SO wt 140K, blew down to drive. 23:15 00:00 0.75 9,316 10,939 COMPZ CASINC RUNL P Cont. RIH with 4 1!2" liner on DP to 10,939', PU wt 165K, SO wt 140K. 02/23/2008 00:00 04:00 4.00 10,939 17,280 COMPZ CASINC RUNL P Cont. RIH with 4 1/2" liner on DP from 10,939' to 17,280', PU wt 225 K, SO wt 125 K. Dro ed ball 17,180'. 04:00 04:30 0.50 17,280 9,208 COMPZ CASINC RUNL P Pumped down ball and set liner. 04:30 12:30 8.00 9,208 0 COMPZ DRILL TRIP P POOH and laid down liner running tool. 12:30 13:00 0.50 0 0 COMPZ DRILL PULD P Pulled drilling wear bushing and installed com letion wear bushin 13:00 14:45 1.75 0 0 COMPZ RPCOh RURD P RU to run 3 1/2" complet_ io~.PU cannon clamps to rig floor and stacked same. 14:45 15:00 0.25 0 0 COMPZ RPCO SFTY P Held PJSM with Baker reps and rig crew on runnin of 3 1/2" com letion. 15:00 16:00 1.00 0 665 COMPZ RPCO RCST P RIH with Baker shear pin sub on WLEG and 3 1/2" comp. per well plan to 665'. 16:00 17:00 1.00 665 685 COMPZ RPCO RURD P MU Baker production Quest pressure gauge and carrier then RU spooling unit and line 17:00 00:00 7.00 685 3,756 COMPZ RPCOh RCST P Cont to RIH with 3 1/2" completion per well Ian to 3,756' 120 of 287'ts PU 02/24!2008 00:00 06:30 6.50 3,756 7,166 COMPZ RPCOh RCST P Cont to RIH with 3 1/2" completion per well Ian to 7,166' 225 of 287 'ts PU --- Page ~ of 8 • ' Time Logs Date From To Dur S De th E. De th Phase Code Subcode T COM 02/24/2008 06:30 07:30 1.00 7,166 7,166 COMPZ RPCOh PULD P Rigged up Camco Safety Valve and s ooler. Tested control line. 07:30 11:00 3.50 7,166 9,086 COMPZ RPCOti RCST P Cont to RIH with 3 1/2" completion per well Ian to 9,086' 287 of 287 'ts PU . 11:00 13:00 2.00 9,086 9,230 COMPZ RPCO HOSO P Changed elevators and spaced out with 4" DP. Found liner top 1' deep @ 9209'. Stood back 4" DP and MU 3 1/2" x 4 1!2" XO, 3-pup jts and 2 full 'ts of 4 1 /2", 12.6#, L-80 I BTM tb . 13:00 13:30 0.50 9,230 9,230 COMPZ RPCOh PULD P MU completion wear bushing retrieving tool, RIH and retrieved same. 13:30 15:00 1.50 9,230 9,230 COMPZ RPCOh HOSO P MU FMC hanger, terminated SSSV control line and Baker Quest press. gauge lines, RIH and landed hanger, st wt up 135K, do wt 117K, blk wt 70K, RILDS, Landed with end of tbg at 9,230' w/no go at 9,206'. 3' above TOL. 15:00 16:15 1.25 9,230 9,230 COMPZ RPCOh OTHR P Changed out landing jts, installed TWC, tested hanger seals to 5,000 psi for 10 min. 16:15 17:00 0.75 9,230 9,230 COMPZ RPCO RURD P RD tbg handling equipment and cleared ri floor. 17:00 18:30 1.50 9,230 9,230 COMPZ WELC NUND P ND BOP stack, Sim-Ops changed out top drive saver sub from 4" XT 39 to 5" DP- 4 1/2" IF. 18:30 21:15 2.75 9,230 9,230 COMPZ WELCT OTHR P Connected SSSV control line and pressure gauge lines to wellhead and tested pressure gauge and opened SSSV, NU tree and tested tree and void to 5,000 psi for 10 min, ck'd ok. Final Quest gauge readings 3,174.53 psi, 150 deg's, 21.35 volts, current 15 MA. 21:15 21:45 0.50 9,230 9,230 COMPZ WELCT OTHR P RU lubricator and pulled TWC 21:45 22:30 0.75 9,230 9,230 COMPZ RPCO RURD P RU circ manifold and prep. to displace hole. 22:30 22:45 0.25 9,230 9,230 COMPZ RPCOh SFTY P Held PJSM with Dowell, rig crew and vac truck drivers on displacing well with inhibited brine and diesel. 22:45 00:00 1.25 9,230 9,230 COMPZ RPCOh CIRC P Circ hole with 192 bbls of 9.2 ppg inhibited brine, circ at 3 bpm, ave 600 si. 02/25/2008 00:00 00:45 0.75 9,230 0 COMPZ RPCO FRZP P Finish circ hole with 118 bbls of diesel for freeze protection, circ at 3 bpm, ave 1,100 psi. Shut down with 800 psi on tubin when finished. 00:45 01:30 0.75 0 0 COMPZ RPCOh PACK P Ri ed u and dro ped 1 5116" ured up to 4,900 psis Ball/Rod. Pres s and set acker 01:30 03:30 2.00 0 0 COMPZ RPCOh DHEQ P Tested tubin to 4,500 psi for 30 min. Bled tubing to 2,000 psi and tested annulus and acker to 3 500 si. for 30 min. bled tubin ressure and sheared DCK valve. Page 7 ~sf 8 • Time Logs _ Date From To Dur S De th E. De th Phase Code Subcode T COM 02/25/2008 03:30 05:00 1.50 0 0 COMPZ RPCOh RURD P Rigged down manifold and lines. Installed BPV thru lubricator and secured well. (SITP 800 psi, IA -0- si . 05:00 16:00 11.00 0 0 COMPZ RPCO PULD P Laid down excess 4" & 5" DP from derrick in mousehole. Sim-Ops, fin. cleanin mud its 16:00 17:00 1.00 0 0 COMPZ RPCO OTHR P RD mousehole and cleared rig floor. RELEASED RIG @ 17:00 hrs to move to CD3-118. Page $ of 3 ~ ~ • ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad CD3-113 50-103-20541-00 .. ., s Definitive Survey Report 14 March, 2008 :~;~F ~w Sperry Drilling Services • ConocoPhillips Definitive Sulvey Report Company: ConocoPhillips(Alaska) Ina Local Co-ordinate Reference: Well CD3-113 • Project: Westem North Slope TVD Reference: CD3-113 2008 ~ 49.90ft (Doyon 19 2008) Site: CD3 Fiord Pad MD Reference: CD3-113 2008 @ 49.90ft (Doyon 19 2008) Well: CD3-113 North Reference: True Wellbore: CD3-113 Survey Calculation Method: Minimum Curvature Design: CD3-113 Database:. CPAI EDM Production Project Westem North Slope Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor __ Well __ _ _ CD3-113 __ - - - Well Position +N/S 0.00 ft Northing: 6,003,820.41 ft Latitude: 70° 25' 9.775 N +EI-W 0.00 ft Easting: 388,129.47 ft Longitude: 150° 54' 40.878 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.10ft ' Wellbore -- CD3-113 Maynetlcs Model Name Sample Date Declin ation Dip Angle Field Strength (~ ) (') InTI I e~'C'M2007 2'12/2008 17.18 79 55 S.L35 Design CD3-113 Audit Notes: Version: 6 Phase: ACTUAL Tie On Depth: 36.80 Vertical Section: Depth From (TVD) +NI-S +E/-W Direction In) (h) (ft) (') 36.80 0 00 0 00 302'i0 Survey Program Date From To Survey (ft) (ft) Survey (Wellbore) Tool Name Description Start Date 81.11 803.21 CD3-113 Gyro (CD3-113) CB-GYRO-SS Camera based gyro single shot 03/14/'2008 892.58 9,341 .76 C03-113 MWD+SAG+IIFR+MS 2007 (CD MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 03/14!2008 9,411.22 17,303.78 CD3-113 MWD+SAG+IIFR+CA+MS 200 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 03/14/2008 - Survey - i Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (`) (ft) (ft) (ft) (ft) (ft) (tt) (°1100') (ft) Survey Tool Name sti.tlU u.UU Q.uU 3o.d0 -"18.10 0.00 O.OU b,Uils,ktZi1.41 388,1[y.47 0.00 uuu UNDEFINED 81.11 0.25 218.00 81.11 31.21 -0.08 -0.O6 6,003,820.33 388,129.41 0.56 0.01 CB-GYRO-SS (1) 171.11 0.50 159.00 171.11 121.21 -0.60 -0.04 6,003,819.81 388,129.42 0.48 -0.29 CB-GYRO-SS (1) 260.11 1.00 166.00 260.10 210.20 -1.71 0.29 6,003,818.69 388,129.73 0.57 -1.16 CB-GYRO-SS (1) 349.11 1.00 152.00 349.09 299.19 -3.15 0.84 6,003,817.24 388,130.26 0.27 -2.40 CB-GYRO-SS (1) 440.11 1.50 159.00 440.06 390.16 -0.97 1.64 6,003,815.42 388,131.03 0.57 -4.05 CB-GYRO-SS (1) ~ 530.11 1.75 146.00 530.03 480.13 -7.21 2.83 6,003,813.16 388,132.19 0.49 -6.26 CB-GYRO-SS (1) 621.11 1.25 140.00 621.00 571.10 -9.12 4.25 6,003,811.23 388,133.58 0.58 -8.48 CB-GYRO-SS (1) 713.11 0.50 117.00 712.99 663.09 -10.07 5.25 6,003,810.26 388,134.57 0.88 -9.84 CB-GYRO-SS (1) 803.11 0.25 177.00 802.98 753.08 -10.44 5.61 6,003,809.89 388,134.92 0.48 -10.34 CB-GYRO-SS (1) 892.58 1.61 269.02 892.44 842.54 -t 0.66 4.36 6,003,809.69 388,133.67 1.83 -9.41 MWD+IFR-AK-CAZ-SC (2) 935.31 2.22 271.70 935.15 885.25 -10.64 2.93 6,003,809.72 388,132.24 1.44 -8.19 MWD+IFR-AK-CAZ-SC (2) 3/14/2008 1:19:03PM Page 2 COMPASS 2003.16 Build 42F ~~ ConocoPhillips Definitive Survey Report : :Company: ConocoPhillips(Alaska) Inc. Local Co-ordi nate Relerence; Well CD3-113 • Protect: Western North Slope TVD Referenc e: CD3-113 2008 @ 49.90ft (Doyon 19 2008) Site: CD3 Fiord Pad MD Reference : CD3-113 2008 @ 49.90ft(Doyon 192008) Well: CD3-113 North Referen ce: True Wellbore: CD3-113 Survey Calcul ation Method: Minimum Curvature Design: CD3-113 _ - Database: CPAI EDM Production -- Survey - -: Map Map Vertical MD Inc Azl TVD TVDSS +N!-S +E!-W Northing Easting DLS Section (ft) (°) (`) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,U3u.7a 2.44 z71.aa 1,0311.5u 98abu -10.54 -0.94 6,003su9.es 388,128.31 u.za -4.87 MvvL*IFR-AK-CFti-sue i2) 1,124.74 2.45 273.76 1,124.41 1,074.51 -10.36 -4.95 6,003,810.13 388,124.37 0.11 -1.39 MWD+IFR-AK-CAZ-SC (2) 1,219.88 3.53 281.07 1,219.42 1,169.52 -9.66 -9.85 6,003,810.90 388,119.47 1.20 3.12 MWD+IFR-AK-CAZ-SC (2) 1,315.22 7.05 283.52 1,314.34 1,264.44 -7.73 -18.42 6,003,812.96 388,110.93 3.70 11.39 MWD+IFR-AK-CAZ-SC (2) 1,410.56 10.27 288.17 1,408.58 1,358.68 -3.71 -32.19 6,003,817.18 388,097.23 3.45 25.16 MWD+IFR-AK-CAZ-SC (2) 1,505.90 13.30 290.19 1,501.90 1,452.00 2.73 -50.56 6,003,823.89 388,078.96 3.21 44.11 MWD+IFR-AK-CAZ-SC (2) 1,600.90 15.79 288.21 1,593.85 1,543.95 10.54 -73.10 6,003,832.04 388,056.54 2.67 67.32 MWD+IFR-AK-CAZ-SC (2) 1,696.39 18.26 285.15 1,685.15 1,635.25 18.51 -99.89 6,003,840.41 388,029.88 2.75 94.19 MWD+IFR-AK-CAZ-SC (2) 1,791.52 20.74 282.66 1,774.82 1,724.92 26.10 -130.71 6,003,848.46 387,999.17 2.75 124.26 MWD+IFR-AK-CAZ-SC (2) 1,886.03 23.04 280.10 1,862.51 1,812.61 33.01 -165.25 6,003,855.89 387,964.74 2.63 157.11 MWD+IFR-AK-CAZ-SC (2) I 1,981.33 25.74 277.39 1,949.30 1,899.40 38.94 -204.14 6,003,862.40 387,925.95 3.07 193.10 MWD+IFR-AK-CAZ-SC (2) 2,076.80 28.77 276.31 2,034.16 1,984.26 44.14 -247.55 6,003,868.25 387,882.63 3.22 232.49 MWD+IFR-AK-CAZ-SC (2) 2,171.61 31.17 276.29 2,116.29 2,066.39 49.33 -294.62 6,003,874.15 387,835.65 2.53 274.98 MWD+IFR-AK-CAZ-SC (2) 2,266.89 33.25 276.54 2,196.90 2,147.00 55.01 -345.09 6,003,880.58 387,785.28 2.19 320.59 MWD+IFR-AK-CAZ-SC (2) 2,362.01 35.40 277.44 2,275.45 2,225.55 61.55 -398.32 6,003,887.91 387,732.15 2.32 369.00 MWD+IFR-AK-CAZ-SC (2) 2,457.49 37.81 276.80 2,352.10 2,302.20 68.60 -454.81 6,003,895.81 387,675.78 2.56 420.43 MWD+IFR-AK-CAZ-SC (2) . 2,552.39 41.99 276.52 2,424.88 2,374.98 75.65 -515.26 6,003,903.76 387,615.44 4.41 475.20 MWD+IFR-AK-CAZ-SC (2) IC ~ 2,582.34 42.40 276.86 2,447.07 2,397.17 77.99 -53524 6,003,906.41 387,595.50 1.57 493.31 MWD+IFR-AK-CAZ-SC (2) I 2,670.94 42.73 278.04 2,512.33 2,462.43 85.76 -594.66 6,003,915.07 387,536.21 0.97 547.61 MWD+IFR-AK-CAZ-SC (2) 2,693.58 43.25 277.43 2,528.69 2,478.99 87.84 -609.96 6,003,917.37 387,520.95 2.94 561.62 MWD+IFR-AK-CAZ-SC (2) 2,788.89 46.45 278.02 2,596.45 2,546.55 96.88 -676.56 6,003,927.41 387,454.50 3.39 622.65 MWD+IFR-AK-CAZ-SC (2) 2,884.13 47.08 279.75 2,661.69 2,611.79 107.61 -745.11 6,003,939.16 387,386.12 1.48 686.22 MWD+IFR-AK-CAZ-SC (2) 2,979.41 46.04 280.51 2,727.21 2,677.31 119.77 -813.21 6,003,952.34 387,318.22 1.24 750.19 MWD+IFR-AK-CAZ-SC (2) 3,074.77 45.27 280.25 2,793.86 2,743.96 132.06 -880.29 6,003,965.63 387,251.34 0.83 813.37 MWD+IFR-AK-CAZ-SC (2) 3,170.12 43.77 280.00 2,861.84 2,811.94 143.81 -946.10 6,003,978.37 387,185.71 1.58 875.19 MWD+IFR-AK-CAZ-SC (2) 3,265.28 43.33 280.10 2,930.81 2,880.91 155.25 -1,010.66 6,003,990.78 387,121.34 0.47 935.78 MWD+IFR-AK-CAZ-SC (2) 3,360.98 43.25 280.23 3,000.47 2,950.57 166.83 -1,075.25 6,004,003.32 387,056.94 0.13 996.48 MWD+IFR-AK-CAZ-SC (2) 3,456.28 42.93 280.29 3,070.07 3,020.17 178.43 -1,139.31 6,004,015.88 386,993.06 0.34 1,056.74 MWD+IFR-AK-CAZ-SC (2) 3,551.62 43.44 280.07 3,139.58 3,089.68 189.96 -1,203.53 6,004,028.37 386,929.03 0.56 1,117.09 MWD+IFR-AK-CAZ-SC (2) 3,647.16 42.79 280.77 3,209.33 3,159.43 201.77 -1,267.75 6,004,041.14 386,864.99 0.84 1,177.60 MWD+IFR-AK-CAZ-SC (2) 3,742.14 43.07 28D.55 3,278.87 3,228.97 213.73 -1,331.32 6,004,054.05 386,801.61 0.33 1,237.65 MWD+IFR-AK-CAZ-SC (2) 3,837.17 43.31 280.59 3,348.16 3,298.26 225.67 -1,395.26 6,004,066.94 386,737.87 0.25 1,297.98 MWD+IFR-AK-CAZ-SC (2) 3,932.98 43.60 280.10 3,417.71 3,367.81 237.50 -1,460.09 6,004,079.74 386,673.23 0.46 1,359.01 MWD+IFR-AK-CAZ-SC (2) 4,028.30 43.40 278.47 3,486.85 3,436.95 248.09 -1,524.84 6,004,091.30 386,608.65 1.20 1,419.31 MWD+IFR-AK-CAZ-SC (2) 4,123.77 43.16 279.01 3,556.35 3,506.45 258.03 -1,589.53 6,004,102.21 386,544.12 0.46 1,479.21 MWD+IFR-AK-CAZ-SC (2) 4,219.26 42.50 279.55 3,626.38 3,576.48 268.50 -1,653.59 6,004,113.63 386,480.23 0.79 1,538.87 MWD+IFR-AK-CAZ-SC (2) 4,314.46 42.81 280.02 3,696.40 3,646.50 279.46 -1,717.16 6,004,125.55 386,416.84 0.47 1,598.37 MWD+IFR-AK-CAZ-SC (2) 4,409.90 42.93 279.81 3,766.35 3,716.45 290.64 -1,781.12 6,004,137.68 386,353.06 0.20 1,658.32 MWD+IFR-AK-CAZ-SC (2) 4,505.18 42.63 279.53 3,83628 3,786.38 301.51 -1,844.91 6,004,149.51 386,289.44 0.37 1,717.96 MWD+IFR-AK-CAZ-SC (2) 4,600.80 42.81 278.37 3,906.53 3,856.63 311.60 -1,908.99 6,004,160.56 386,225.52 0.84 1,777.42 MWD+IFR-AK-CAZ-SC (2) - 3/14/2008 1:19:03PM Page 3 COMPASS 2003.16 Build 42F • 'Company: Project: Slte: Well: Wellbore: Design: Survey ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad CD3-113 CD3-113 CD3-113 ConocoPhillips Definitive Survey Report local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well CD3-113 CD3-113 2008 @ 49.90ft (Doyon 19 2008) CD3-113 2008 @ 49.90ft (Doyon 19 2008) True Minimum Curvature CPAI EDM Production - 1 i I Map Map Vertical MD Inc Azl TVD TVDSS +N/-S +FJ-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,695.95 a3A5 278.71 3,576.20 3,926.30 32123 -1,573.Od 6,004,179.14 3ao,161.59 0.35 1,836.64 MWD+VFR-AK-CAZ-SG t2/ 4,791.31 43.03 279.41 4,045.89 3,995.99 331.47 -2,037.35 6,004,182.35 386,097.49 0.50 1,696.36 MWD+IFR-AK-CAZ-SC (2) 4,886.64 43.60 279.75 4,115.26 4,065.36 342.36 -2,101.84 6,004,194.20 386,033.18 0.65 1,956.59 MWD+IFR-AK-CAZ-SC (2) 4,962.16 43.85 278.24 4,184.29 4,134.39 352.68 -2,167.04 6,004,205.49 385,968.14 1.12 2,077.13 MWD+IFR-AK-CAZ-SC (2) 5,076.85 43.77 279.04 4,252.62 4,202.72 362.53 -2,231.85 6,004,216.31 385,903.49 0.59 2,077.08 MWD+IFR-AK-CAZ-SC (2) 5,172.28 43.65 279.29 4,321.60 4,271.70 373.03 -2,296.95 6,004,227.78 385,838.56 0.22 2,137.62 MWD+IFR-AK-CAZ-SC (2) 5,267.69 43.51 278.92 4,390.72 4,340.82 383.44 -2,361.89 6,004,239.16 385,773.79 0.30 2,197.99 MWD+IFR-AK-CAZ-SC (2) 5,363.18 43.68 279.02 4,459.87 4,409.97 393.70 -2,426.93 6,004,250.40 385,708.92 0.19 2,258.36 MWD+IFR-AK-CAZ-SC (2) 5,458.46 43.24 279.63 4,529.03 4,479.13 404.32 -2,491.61 6,004,261.99 385,644.42 0.64 2,318.61 MWD+IFR-AK-CAZ-SC (2) 5,553.93 44.13 278.96 4,598.07 4,548.17 414.97 -2,556.68 6,004,273.61 385,579.51 1.05 2,379.21 MWD+IFR-AK-CAZ-SC (2) ~ 5,648.76 44.32 277.56 4,666.03 4,616.13 424.47 -2,622.13 6,004,284.09 385,514.22 1.05 2,439.51 MWD+IFR-AK-CAZ-SC (2) 5,744.21 43.78 278.32 4,734.63 4,684.73 433.63 -2,687.86 6,004,294.24 385,446.64 0.79 2,499.87 MWD+IFR-AK-CAZ-SC (2) 5,839.31 43.41 278.12 4,803.51 4,753.61 443.01 -2,752.76 6,004,304.58 365,383.89 0.42 2,559.65 MWD+IFR-AK-CAZ-SC (2) 5,934.78 44.12 278.62 4,872.45 4,822.55 452.62 -2,818.10 6,004,315.17 385,318.71 0.83 2,619.91 MWD+IFR-AK-CAZ-SC (2) i 6,030.34 43.43 279.03 4,941.45 4,891.55 462.77 -2,883.42 6,004,326.29 385,253.55 0.78 2,680.46 MWD+IFR-AK-CAZ-SC (2) 6,125.93 43.43 278.91 5,010.87 4,960.97 473.01 -2,948.34 6,004,337.51 385,188.81 0.09 2,740.71 MWD+IFR-AK-CAZ-SC (2) 6,221.76 43.86 278.79 5,080.22 5,030.32 483.19 -3,013.69 6,004,348.66 385,123.62 0.46 2,801.29 MWD+IFR-AK-CAZ-SC (2) 6,316.89 44.05 279.31 5,148.70 5,098.80 493.57 -3,078.89 6,004,360.02 385,058.58 0.43 2,861.87 MWD+IFR-AK-CAZ-SC (2) 6,411.98 44.06 278.48 5,217.04 5,167.14 503.80 -3,144.22 6,004,371.22 384,993.42 0.61 2;922.45 MWD+IFR-AK-CAZ-SC (2) 6,506.98 42.89 277.51 5,285.98 5,236.08 512.89 -3,208.94 6,004,381.29 384,928.85 1.42 2,981.93 MWD+IFR-AK-CAZ-SC (2) 6,602.20 42.62 277.77 5,355.89 5,305.99 521.49 -3,273.01 6,004,390.84 384,864.92 0.34 3,040.58 MWD+IFR-AK-CAZ-SC (2) 6,697.64 43.50 278.16 5,425.63 5,375.73 530.52 -3,337.54 6,004,400.84 384,800.54 0.96 3,099.86 MWD+IFR-AK-CAZ-SC (2) ~ I 6,792.96 43.87 279.15 5,494.56 5,444.66 540.43 -3,402.63 6,004,411.72 384,735.61 0.82 3,160.07 MWD+IFR-AK-CAZ-SC (2) 6,888.26 43.42 277.98 5,563.53 5,513.63 550.23 -3,467.68 6,004,422.49 384,670.72 0.97 3,220.20 MWD+IFR-AK-CAZ-SC (2) 6,983.56 44.28 277.77 5,632.25 5,582.35 559.27 -3,533.07 6,004,432.51 384,605.48 0.92 3,280.20 MWD+IFR-AK-CAZ-SC (2) 7,078.46 43.25 278.17 5,700.78 5,650.88 568.37 -3,598.07 6,004,442.58 384,540.63 1.12 3,339.92 MWD+IFR-AK-CAZ-SC (2) 7,173.77 43.84 278.44 5,769.86 5,719.96 577.86 -3,663.05 6,004,453.04 384,475.81 0.65 3,399.81 MWD+IFR-AK-CAZ-SC (2) 7,268.14 43.79 280.15 5,837.96 5,788.06 588.41 -3,727.52 6,004,464.56 384,411.51 1.26 3,459.85 MWD+IFR-AK-CAZ-SC (2) i 7,363.40 43.84 279.63 5,906.70 5,856.80 599.73 -3,792.49 6,004,476.86 384,346.72 0.38 3,520.74 MWD+IFR-AK-CAZ-SC (2) 7,458.53 44.41. 278.31 5,974.99 5,925.09 610.06 J,857.91 6,004,488.16 384,261.47 1.14 3,581.45 MWD+IFR-AK-CAZ-SC (2) 7,553.51 43.24 279.91 6,043.51 5,993.61 620.46 -3,922.85 6,004,499.53 384,216.70 1.70 3,641.81 MWD+IFR-AK-CAZ-SC (2) 7,648.37 43.25 282.15 6,112.62 6,062.72 632.89 -3,986.63 6,004,512.92 384,153.12 1.62 3,702.28 MWD+IFR-AK-CAZ-SC (2) 7,743.36 44.72 285.02 6,180.97 6,131.07 648.41 -0,050.73 6,004,529.39 384,089.26 2.61 3,764.68 MWD+IFR-AK-CAZ-SC (2) 7,839.13 45.98 285.11 6,248.27 6,198.37 666.11 -4,116.52 6,004,548.08 384,023.75 1.32 3,829.68 MWD+IFR-AK-CAZ-SC (2) 7,934.24 47.68 285.61 6,313.34 6,263.44 684.49 -4,183.40 6,004,567.45 383,957.15 1.83 3,895.96 MWD+IFR-AK-CAZ-SC (2) I 8,029.58 49.86 286.96 6,376.17 6,326.27 704.61 -4,252.22 6,004,588.60 383,888.65 2.52 3,964.81 MWD+IFR-AK-CAZ-SC (2) ~ 8,124.65 51.63 290.54 6,436.34 6,386.44 728.29 -4,321.89 6,004,613.32 383,819.35 3.46 4,036.30 MWD+IFR-AK-CAZ-SC (2) 8,219.91 53.33 292.18 6,494.36 6,444.46 755.82 -0,392.25 6,004,641.90 383,749.42 2.25 4,110.42 MWD+IFR-AK-CAZ-SC (2) 8,315.03 55.33 293.55 6,549.82 6,499.92 785.85 -4,463.44 6,004,672.99 383,678.69 2.41 4,186.60 MWD+IFR-AK-CAZ-SC (2) _ 8,410.14 56.12 295.72 6,602.01 6,552.11 819.01 -4,535.69 6,004,707.23 383,606.95 3.50 4,265.36 MWD+IFR-AK-CAZ-SC (2) 3/14/2008 1:19:03PM Page 4 COMPASS 2003.16 Build 42F ConocoPhillips Definitive Survey Report • Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well CD3-113 . Project: Western North Slope TVD Reference: CD3-113 2008 @ 49.90ft (Doyon 19 2008) Site: CD3 Fiord Pad MD Reference: CD3-113 2008 @ 49.90ft (Doyon 19 2008) Well: CD3-113 North Reference: True Wellbore: CD3-113 Survey Calculation Method: Minimum Curvature Design: CD3-113 Database: CPAI EDM Production Survey ~I Map Map Vertical MD Inc Azl TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name ~~ 8,505.30 60.85 298.61 ti,650.33 6,600.43 856.a6 -a,6u6.6u 6,004,745.76 363,534.62 3.88 a,3d6.96 MWD+IFR-AK-CAZ-SC (2) 8,600.71 64.28 301.54 6,694.29 6,644.39 898.91 -4,681.84 6,004,789.30 383,462.03 4.51 4,431.54 MWD+IFR-AK-CAZ-SC (2) 8,696.26 67.44 306.50 6,733.38 6,683.48 947.71 -4,754.04 6,004,839.17 383,390.57 5.78 4,518.66 MWD+IFR-AK-CAZ-SC (2) 8,791.49 69.08 311.25 6,768.67 6,718.77 1,003.22 -4,822.87 6,004,895.70 383,322.59 4.94 4,606.53 MWD+IFR-AK-CAZ-SC (2) 8,887.05 70.02 315.23 6,802.07 6,752.17 1,064.55 -4,888.07 6,004,957.99 383,258.32 4.02 4,694.48 MWD+IFR-AK-CAZ-SC (2) 8,982.48 72.51 317.68 6,832.72 6,782.82 1,130.05 -4,950.31 6,005,024.42 383,197.07 3.57 4,782.16 MWD+IFR-AK-CAZ-SC (2) 9,077.96 75.78 321.73 6,858.81 6,808.91 1,200.10 -5,009.67 6,005,095.34 383,138.78 5.33 4,869.86 MWD+IFR-AK-CAZ-SC (2) 9,173.26 77.62 325.16 6,880.74 6,830.84 1,274.59 -5,064.89 6,005,170.64 383,084.69 4.00 4,956.46 MWD+IFR-AK-CAZ-SC (2) 9,268.89 81.14 327.59 6,898.37 6,648.47 1,352.84 -5,116.91 6,005,249.66 383,033.84 4.45 5,042.38 MWD+IFR-AK-CAZ-SC (2) 9,341.76 83.87 328.36 6,907.87 6,857.97 1,414.09 -5,155.22 6,005,311.47 382,996.46 3.89 5,107.60 MWD+IFR-AK-CAZ-SC (2) 9,411.22 84.13 327.29 6,915.13 6,865.23 1,472.56 -5,192.00 6,005,370.48 382,960.56 1.58 5,170.04 MWD+IFR-AK-CAZ-SC (3) 9,506.04 85.80 326.48 6,923.45 6,873.55 1,551.67 -5,243.61 6,005,450.34 382,910.15 1.96 5,256.07 MWD+IFR-AK-CAZ-SC (3) 9,600.96 85.29 327.17 6,930.83 6,880.93 1,630.87 -5,295.39 6,005,530.31 382,859.57 0.90 5,342.30 MWD+IFR-AK-CAZ-SC (3) 9,696.20 89.96 323.47 6,934.77 6,684.87 1,709.09 -5,349.51 6,005,609.32 382,806.63 6.25 5,429.97 MWD+IFR-AK-CAZ-SC (3) 9,744.18 90.76 321.26 6,934.47 6,884.57 1,747.08 -5,378.81 6,005,647.74 382,777.91 4.90 5,475.09 MWD+IFR-AK-CAZ-SC (3) 9,791.43 90.49 319.38 6,933.96 6,884.06 1,783.44 -5,408.97 6,005,684.55 382,748.29 4.02 5,520.07 MWD+IFR-AK-CAZ-SC (3) 9,886.20 92.10 317.54 6,931.81 6,881.91 1,854.35 -5,471.80 6,005,756.39 382,686.54 2.58 5,611.16 MWD+IFR-AK-CAZ-SC (3) 9,981.02 91.91 317.57 6,928.50 6,878.60 1,924.28 -5,535.75 6,005,827.26 382,623.65 0.20 5,702.67 MWD+IFR-AK-CAZ-SC (3) 10,079.69 91.85 317.99 6,925.26 6,875.36 1,997.31 -5,602.02 6,005,901.27 382,558.49 0.43 5,797.80 MWD+IFR-AK-CAZ-SC (3) 10,171.29 91.66 323.12 6,922.45 6,872.55 2,067.99 -5,660.17 6,005,972.81 382,501.41 5.60 5,884.82 MWD+IFR-AK-CAZ-SC (3) 10,217.68 91.25 324.20 6,921.27 6,871.37 2,105.35 -5,687.65 6,006,010.57 382,474.49 2.49 5,928.07 MWD+IFR-AK-CAZ-SC (3) 10,265.96 91.91 323.23 6,919.94 6,870.04 2,144.25 -5,716.21 6,006,049.89 382,446.52 2.43 5,973.06 MWD+IFR-AK-CAZ-SC (3) 10,361.02 92.09 326.24 6,916.63 6,866.73 2,221.81 -5,771.06 6,006,128.26 382,392.85 3.17 6,060.99 MWD+IFR-AK-CAZ-SC (3) 10,456.17 91.29 327.89 6,913.82 6,863.92 2,301.63 -5,822.76 6,006,208.84 382,342.35 1.93 6,147.49 MWD+IFR-AK-CAZ-SC (3) 10,551.20 92.40 327.29 6,910.76 6,860.86 2,381.81 -5,873.67 6,006,289.77 382,292.66 1.33 6,233.51 MWD+IFR-AK-CAZ-SC (3) 10,646.14 90.42 325.88 6,908.42 6,858.52 2,461.03 -5,925.93 6,006,369.75 382,241.59 2.56 6,320.15 MWD+IFR-AK-CAZ-SC (3) 10,741.29 86.77 324.19 6,910.76. 6,860.86 2,538.97 -5,980.43 6,006,448.49 382,188.27 4.23 6,407.99 MWD+IFR-AK-CAZ-SC (3) 10,836.40 87.90 326.30 6,915.18 6,865.28 2,617.02 -6,034.59 6,006,527.34 382,135.29 2.51 6,495.61 MWD+IFR-AK-CAZ-SC (3) 10,931.73 90.93 329.61 6,916.15 6,866.25 2,697.80 -6,085.15 6,006,608.86 382,085.95 4.71 6,581.66 MWD+IFR-AK-CAZ-SC (3) 11,026.86 91.54 331.37 6,914.10 6,864.20 2,780.57 -6,132.00 6,006,692.31 382,040.35 1.96 6,665.64 MWD+IFR-AK-CAZSC (3) 11,121.97 91,78 328.44 6,911.35 6,861.45 2,862.81 -6,179.66 6,006,775.25 381,993.93 3.09 6,750.03 MWD+IFR-AK-CAZ-SC (3) 11,217.54 90.92 324.67 6,909.09 6,859.19 2,942.61 -6,232.17 6,006,855.83 381,942.63 3.84 6,837.19 MWD+IFR-AK-CAZ-SC (3) 11,312.22 90.98 323.09 6,907.52 6,857.62 3,019.16 -6,287.84 6,006,933.21 381,888.12 1.88 6,925.28 MWD+IFR-AK-CAZ-SC (3) 11,407.74 90.73 321.60 6,906.10 6,856.20 3,094.79 x,346.19 6,007,009.68 381,830.91 1.58 7,015.12 MWD+IFR-AK-CAZ-SC (3) 11,503.01 90.43 320.24 6,905.13 6,855.23 3,168.74 -6,406.24 6,007,084.52 381,771.98 1.46 7,105.50 MWD+IFR-AK-CAZ-SC (3) 11,598.22 91.85 318.04 6,903.24 6,853.34 3,240.73 x,468.51 6,007,157.42 381,710.80 2.75 7,196.70 MWD+IFR-AK-CAZ-SC (3) 11,693.54 88.26 314.14 6,903.15 6,853.25 3,309.37 -6,534.59 6,007,227.05 381,645.76 5.56 7,289.32 MWD+IFR-AK-CAZ-SC (3) 11,747.48 88.43 319.27 6,904.71 6,854.81 3,348.60 -6,571.56 6,007,266.82 381,609.39 9.51 7,341.57 MWD+IFR-AK-CAZ-SC (3) 11,789.24 88.89 317.99 6,905.68 6,855.78 3,379.93 -6,599.15 6,007,298.56 381,582.28 3.26 7,381.68 MWD+IFR-AK-CAZSC (3) 11 884 36 89 81 319 00 6 906 76 6 856 86 3 451 16 -6 662 18 6 007 370.72 381 520.33 1.44 7,473.11 MWD+IFR-AK-CAZ-SC (3) 3/142008 1:19:03PM Page 5 COMPASS 2003.16 Build 42F • ConocoPhillips Definitive Survey Report =Company: ConocoPhillips(Alaska) Inc. • Project: Western North Slope Slte: CD3 Fiord Pad Well: CD3-113 Wellbore: CD3-113 Design: CD3-113 Survey • MD Inc Azl TVD TVDSS (ft) (°) (°) lftl (ftl 11,575.54 X7.24 323.26 6,50u'.72 6,856.8 12,074.70 90.80 326.85 6,905.86 6,855. 12,169.53 90.05 326.60 6,905.15 6,855.2 12,264.58 89.75 325.35 6,905.32 6,855.4 12,359.67 90.06 327.13 6,905.48 6,855.5 12,454.69 90.43 329.51 6,905.07 6,855.1 12,549.77 90.24 326.86 6,904.51 6,854.6 12,645.08 90.12 326.46 6,904.22 6,854.3 12,734.23 89.32 327.58 6,904.65 6,854.7 12,827.56 87.96 324.61 6,906.87 6,856.9 12,920.00 87.90 323.61 6,910.21 6,860.3 13,020.77 89.95 324.74 6,912.10 6,862.2 13,115.47 91.80 324.86 6,910.65 6,860.7 13,210.98 92.35 324.53 6,907.19 6,857.2 13,305.65 93.22 324.49 6,902.59 6,852.6 13,399.87 90.79 320.84 6,899.29 6,849.3 13,496.25 93.41 323.65 6,895.76 6,845.8 13,591.54 93.15 324.95 6,890.31 6,840.4 13,684.81 92.03 326.66 6,886.10 6,836.2 13,781.63 90.49 324.63 6,883.97 6,834.0 13,877.03 90.12 324.60 6,883.46 6,833. 13,971.94 90.13 325.69 6,883.25 6,833.3 14,067.23 90.75 327.08 6,882.52 6,832.6 14,162.66 91.55 324.22 6,880.60 6,630.7 14,255.90 91.24 323.14 6,878.33 6,828. 14,353.53 89.93 323.19 6,877.34 6,827. 14,448.30 90.07 323.77 6,877.34 6,827. 14,542.81 89.75 324.82 6,877.49 6,827. 14,638.27 90.00 324.62 6,877.69 6,827. 14,733.36 90.00 325.65 6,877.69 6,827. 14,828.89 90.19 326.63 6,877.54 6,827. 14,924.01 90.13 328.52 6,877.27 6,827. 15,019.69 90.81 324.82 6,876.48 6,826. 15,115.12 90.37 324.76 6,875.50 6,825. 15,209.58 90.56 321.95 6,874.74 6,824. 15,304.49 89.50 319.39 6,874.69 6,824. 15,399.69 89.26 319.37 6,875.72 6,825. 15,494.91 89.39 320.81 6,876.84 6,826. 15,587.29 88.45 321.91 6,878.58 6,828. 15 685.41 89.76 322.84 6,880.11 6,830. Local Co-ordinate Reference: JVell CD3-113 TV D Refere nce: CD3-113 2008 @ 49.90ft (Doyon 19 2008) MD Reference: CD3-113 2008 @ 49.90ft (Doyon 19 2008) North Reference: True Survey Calc ulation Method: Minimum Curvature Databasa: CPAI EDM Production Map Map Vertical +N!-S +E/-W Northing Easting DLS Section (ft) (ft) (ft) (ft) (°l100') (ft) Survey Tool Name 2 3,525.25 ~'i,721.86 5,u07,445.5b 381,461.73 4.50 7,563.26 tvluvD+IFR-AK-CAZSC (s/ 6 3,603.24 -6,776.39 6,007,524.47 381,408.42 3.82 7,651.14 MWD+IFR-AK-CAZ-SC (3) 5 3,682.51 -6,828.42 6,007,604.52 361,357.59 0.83 7,737.62 MWD+IFR-AK-CAZ-SC (3) 2 3,761.29 -6,881.60 6,007,684.07 381,305.59 1.35 7,824.80 MWD+IFR-AK-CAZ-SC (3) 8 3,840.34 -6,934.44 6,007,763.90 381,253.95 1.90 7,911.85 MWD+IFR-AK-CAZ-SC (3) 7 3,921.20 -6,984.34 6,007,845.49 381,205.27 2.53 7,997.37 MWD+IFR-AK-CAZSC (3) 1 4,001.98 -7,034.46 6,007,927.01 381,156.37 2.79 8,083.05 MWD+IFR-AK-CAZ-SC (3) 2 4,081.61 -7,086.84 6,008,007.40 381,105.19 0.44 8,170.01 MWD+IFR-AK-CAZ-SC (3) 5 4,156.39 -7,135.37 6,008,082.90 381,057.80 1.54 8,251.12 MWD+IFR-AK-CAZ-SC (3) 7 4,233.82 -7,187.41 6,008,161.09 381,006.93 3.50 8,336.62 MWD+IFR-AK-CAZ-SC (3) 1 4,308.66 -7,241.56 6,008,236.73 380,953.91 1.08 8,422.50 MWD+IFR-AK-CAZ-SC (3) 0 4,390.34 -7,300.53 6,008,319.28 380,896.18 2.32 8,516.13 MWD+IFR-AK-CAZ-SC (3) 5 4,467.71 -7,355.11 6,008,397.45 380,842.77 1.96 8,603.73 MWD+IFR-AK-CAZ-SC (3) 9 4,545.61 -7,410.27 6,008,476.16 380,788.78 0.67 8,692.11 MWD+IFR-AK-CAZ-SC (3) 9 4,622.60 -7,465.17 6,008,553.95 380,735.05 0.92 8,779.77 MWD+IFR-AK-CAZ-SC (3) 9 4,697.45 -7,522.26 6,008,629.64 380,679.09 4.65 8,868.14 MWD+IFR-AK-CAZ-SC (3) 6 4,773.58 -7,581.22 6,008,706.65 380,621.28 3.98 8,958.78 MWD+IFR-AK-CAZ-SC (3) 1 4,650.84 -7,636.74 6,008,784.72 380,566.93 1.39 9,047.11 MWD+IFR-AK-CAZ-SC (3) 0 4,927.90 -7,689.10 6,008,862.55 380,515.74 2.19 9,132.68 MWD+IFR-AK-CAZ-SC (3) 7 5,007.80 -7,743.72 6,008,943.26 380,462.33 2.63 9,221.68 MWD+IFR-AK-CAZ-SC (3) 6 5,085.58 -7,798.96 6,009,021.85 380,408.26 0.39 9,310.06 MWD+IFR-AK-CAZ-SC (3) 5 5,163.46 -7,853.20 6,009,100.53 380,355.20 1.15 9,397.65 MWD+IFR-AK-CAZ-SC (3) 2 5,242.81 -7,905.95 6,009,180.65 380,303.65 1.60 9,484.78 MWD+IFR-AK-CAZSC (3) 0 5,321.58 -7,959.78 6,009,260.21 380,251.01 3.11 9,572.50 MWD+IFR-AK-CAZ-SC (3) 3 5,396.68 -8,014.99 6,009,336.12 380,196.94 1.20 9,659.42 MWD+IFR-AK-CAZ-SC (3) 4 5,474.61 -8,073.52 6,009,415.12 380,139.59 1.34 9,750.76 MWD+IFR-AK-CAZ-SC (3) 4 5,550.97 -8,129.91 6,009,492.11 380,084.35 0.63 9,839.25 MWD+IFR-AK-CAZ-SC (3) 9 5,627.72 -8,185.07 6,009,569.66 380,030.35 1.16 9,927.00 MWD+IFR-AK-CAZ-SC (3) 9 5,705.64 -8,240.20 6,009,648.40 379,976.40 0.34 10,015.37 MWD+IFR-AK-CAZ-SC (3) 9 5,783.66 -8,294.56 6,009,727.22 379,923.22 1.08 10,103.14 MWD+IFR-AK-CAZ-SC (3) 4 5,862.99 -8,347.79 6,009,807.33 379,871.19 1.04 10,190.65 MWD+IFR-AK-CAZ-SC (3) 7 5,943.28 -8,398.79 6,009,888.36 379,821.41 1.99 10,276.80 MWD+IFR-AK-CAZ-SC (3) 8 6,023.20 -8,451.35 6,009,969.06 379,770.05 3.93 10,364.08 MWD+IFR-AK-CAZ-SC (3) 0 6,101.17 -8,506.37 6,010,047.84 379,716.21 0.47 10,452.37 MWD+IFR-AK-CAZ-SC (3) 4 6,176.95 -8,562.74 6,010,124.45 379,660.99 2.98 10,540.64 MWD+IFR-AK-CAZ-SC (3) 9 6,250.36 -8,622.89 6,010,198.74 379,601.95 2.92 10,630.81 MWD+IFR-AK-CAZ-SC (3) 2 6,322.61 -8,684.86 6,010,271.91 379,541.07 0.25 10,721.90 MWD+IFR-AK-CAZ-SC (3) 4 6,395.64 -8,745.95 6,010,345.84 379,481.09 1.52 10,812.66 MWD+IFR-AK-CAZ-SC (3) 8 6,467.79 -8,803.62 6,010,418.84 379,424.51 1.57 10,900.06 MWD+IFR-AK-CAZ-SC (3) 1 6,545.49 -8,863.51 6,010,497.42 379,365.80 1.64 9 5 4 4 4 5 7 7 6 3 5 6 8 7 8 9 6 10,992.33 MWD+IFR-AK-CAZ-SC (3) 2 I 3/14/2008 t:19:03PM Page 6 COMPASS 2003.16 Build 42F Company: • Project: Site: Well: Wellbore: Design: Survey C] ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad CD3-113 CD3-113 CD3-113 MD Inc Azl TVD TVDSS (ft) P) (°) Ift) (ft) 15,780.58 89.26 325.15 6,880.93 0,831.03 15,875.57 90.19 327.04 6,881.38 6,831.48 15,970.75 90.13 323.95 6,881.12 6,831.22 16,066.35 89.13 323.53 6,881.73 6,831.83 16,161.65 89.51 323.52 6,882.86 6,832.96 16,256.87 89.32 322.41 6,883.84 6,833.94 16,351.97 89.70 323.17 6,884.65 6,834.75 16,447.11 90.63 324.91 6,884.38 6,834.48 16,542.42 89.32 324.34 6,884.42 6,834.52 16,637.98 91.31 325.37 6,883.89 6,833.99 16,733.08 90.68 327.02 6,882.24 6,832.34 16,828.54 91.36 327.53 6,880.54 6,830.64 16,922.84 91.73 327.18 6,878.00 6,828.10 17,018.29 93.60 326.74 6,873.56 6,823.66 17,113.23 93.40 327.41 6,867.76 6,817.86 17,208.28 92.96 327.02 6,862.49 6,812.59 17,303.78 91.29 326.83 6,858.95 6,809.05 17,338.00 91.29 326.83 6,858.18 ~ 6,808.28 ConocoPhillips Definitive Survey Report Local Co-or dinate Reference : Well CD3-113 TVD Refere nce: CD3-113 2008 [~ 49.90ft (Doyon 19 2008) MD Referen ce: CD3-113 2008 @ 49.90ft (Doyon 19 2008) North Refer ence: True Survey Calculation Method: Minimum Curvature Database: CPAI EDM Production Map Map Vertical +N/-S +E/-W Northing Easting DLS Section (ft) (ft) (ft) (ft) ( `1100') (ft) Survey Tool Name 6,622.47 -8,919.45 6,010,575.22 379,311.02 2.40 11,080.87 MWD+IFR-AK-CAZ-SC (3) 6,701.30 -8,972.44 6,010,654.83 379,259.23 2.22 11,167.91 MWD+IFR-AK-CAZ-SC (3) 6,779.73 -9,026.35 6,010,734.05 379,206.51 3.25 11,255.52 MWD+IFR-AK-CAZ-SC (3) 6,856.81 -9,082.89 6,010,811.97 379,151.13 1.13 11,344.62 MWD+IFR-AK-CAZ-SC (3) 6,933.44 -9,139.54 6,010,889.43 379,095.64 0.40 11,433.57 MWD+IFR-AK-CAZ-SC (3) 7,009.44 -9,196.88 6,010,966.28 379,039.44 1.18 11,522.78 MWD+IFR-AK-CAZ-SC (3) 7,085.18 -9,254.39 6,011,042.86 378,983.08 0.89 11,611.97 MWD+IFR-AK-CAZ-SC (3) 7,162.18 -9,310.26 6,011,120.69 378,928.38 2.07 11,700.47 MWD+IFR-AK-CAZ-SC (3) 7,239.90 -9,365.43 6,011,199.21 378,874.38 1.50 11,788.76 MWD+IFR-AK-CAZ-SC (3) 7,318.03 -9,420.44 6,011,278.15 378,620.56 2.34 11,877.13 MWD+IFR-AK-CAZ-SC (3) 7,397.04 -9,473.34 6,011,357.94 378,768.85 1.86 11,964.20 MWD+IFR-AK-CAZ-SC (3) 7,477.33 -9,524.93 6,011,438.99 378,718.47 0.89 12,050.86 MWD+IFR-AK-CAZ-SC (3) 7,556.71 -9,575.78 6,011,519.11 378,668.82 0.54 12,136.39 MWD+IFR-AK-CAZ-SC (3) 7,636.63 -9,627.77 6,011,599.80 378,618.04 2.01 12,223.18 MWD+IFR-AK-CAZ-SC (3) 7,716.17 -9,679.27 6,011,680.10 378,567.74 0.74 12,309.36 MWD+IFR-AK-CAZ-SC (3) 7,795.96 -9,730.66 6,011,760.64 378,517.56 0.62 12,395.57 MWD+IFR-AK-CAZ-SC (3) 7,875.92 -9,782.74 6,011,841.37 378,466.68 1.76 12,482.46 MWD+IFR-AK-CAZ-SC (3) 7,904.56 -9,801.46 6,011,870.26 - 378,448.40 - 0.00 12,513.64 PROJECTED to TD 3/14/2008 f:19:03PM Page 7 COMPASS 2003.16 Build 42F TUBING (32-9230, OD:3.500, ID:2.992) ~" Tubing String-TUBING - I S¢e i _ Top i Bottom i TVD Wt Grade Thread _ 500 3Z ~,_?30 6L~11 - 9 30 L-:~;0 - - - CUE. rd1,10D Perforations Summary _ __ - - Interval i TVD i Zone i Status i Ft i SPF t Daie i Tvpe i Comment I 1/2" 11928-11933 12193 - 12198 .~-~ ,- 17dSR _ 17dn7 IJGYJ- IJLJV 13503 - 13507 V~VV- VDVJ 6895 - 6895 :J 4 1 1 L/LJ,cVVV 2/23/2008 ViVt Slot Vrn VL Vv,va c, , c,,, u Six 1/2" holes er Perf Pu 13768 - 13773 6884 - 6884 5 1 2/23/2008 Slot Six 1 /2" holes er Pert Pu 14034 - 14039 6883 - 6883 5 1 2/23/2008 Slot Six 1/2" holes er Pert Pu 14290 - 14295 6878 - 6878 5 1 2/23/2008 Slot Six 1/2" holes er Perf Pu 14552 - 14557 6878 - 6878 5 1 2/23/2008 Slot Six 1/2" holes er Perf Pu 14818 - 14823 6878 - 6878 5 1 2/23/2008 Slot Six 1/2" holes er Pert Pu 15078 - 15082 6876 - 6876 4 1 2/23/2008 Slot Six 1/2" holes er Pert Pu 15342 - 15347 6875 - 6875 5 1 2/23/2008 Slot Six 1/2" holes er Pert Pu 15607 - 15612 6879 - 6879 5 1 2/23/2008 Slot Six 1/2" holes er Perf Pu 15870 - 15875 6881 - 6881 5 1 2/23/2008 Slot Six 1 /2" holes er Perf Pu 1 16131 - 16136 6883 - 6883 5 1 2/23/2008 Slot Six 1/2" holes er Perf Pu 16395 - 16400 6885 - 6885 5 1 2/23/2008 Slot Six 1 /2" holes er Perf Pu - 16655 - 16660 6884 - 6884 5 1 2/23/2008 Slot Six 1 /2" holes er Perf Pu 16921 - 16925 6878 - 6878 4 1 2/23/2008 Slot Six 1!2" holes er Perf Pu ' ~ cr. 17140 - 17145 6866 - 6866 Gas Lift MandrelSNalves - ,~, 1 2/23/200R Slot Six 1!2" holes per Perf Pup - -- _ _ - - - - St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3892 3388 CAMCO KBMG-2 GLV 1.0 BK 0.250 1870 3/1/2008 2 6963 5617 CAMCO KBMG-2 GLV 1.0 BK 0.250 1904 2!29/2008 3 8451 6623 CAMCO KBMG-2 OV 1.0 BK 0.250 0 2/29/2008 Other lu s, equi ., etc. - COMPLETION Depth TVD -Type Description ID 31 31 HANGER FMC TUBING HANGER 2.992 2064 2023 SSSV CAMCO TRMAXX SE SSSV'"BAL-O NIPPLE TOP PORT IS PLUGGED -CONTROL 2.812 NIP Perf (9542-9547) Perf (9807-9812) Perf 10073-10078) Perf 10338-10343) Pert 10604-10609) Pert :13245-13250) Perf ;13503-13507) Pert ;13768-13773) Perf :14034-14039) Perf :14290-14295) ~>~~t~~t~Phi~lip~ ~las~ca, ~~. ALPINE IDE CD3-113 CD3-113 API: 501032054100 Vdell T e: PROD An le TS: d SSSV T e: TRDP Ori Com letion: 2/25/2008 An le TD: 91 de 17338 Annular Fluid: Last W/O: Rev Reason: NEW WELL, Pull Ball, rod, GLV C/O Reference L 36' RKB Ref Lo Date: Last U date: 3/23/2008 Last Ta TD: 17338 ftKB Last Tag Date: .Casing Stringy -ALL STRINGS Descri lion Size Max Hole Angle: __ _ To 94 deg (a) 17018 Bottom _ TVD _ Wt __' Grade Thread CONDUCTOR 16.000 0 114 114 62.50 H-40 WELDED PRODUCTION 7.000 33 9364 6910 26.00 L-80 MBTC SURFACE 9.625 36 2619 2474 40.00 L-80 MBTC LINER-Blank w/Pert Pus 4.500 9208 17280 6Lt50 12 Br1 L-RO IBTM i • Well: CD3-113 / 4-7/2" Liner Date: 2123/2008 ~onocoPhillips Alaska, Inc. DEPTH Jt Number Num ofJts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 LENGTH TOPS Top of liner @ 9208.04 Baker 5" x 7" HR Liner Settinng Sleeve 12.89 9208.04 RS Nipple 3.60 9220.93 Baker 5 " X 7" DG Flex-lock Liner Hanger 9.90 9224.53 XO Bushing 5" TKC x 4%2" IBT 1.81 9234.43 Pupjt 4%2" , 12.6#, IBT 3.83 9236.24 Jts 177 to 183 . 7 Jts 4%" 12.6# L-80 IBTM Tbg 301.95 9240.07 Perf Pup - 4'/2" 12.6# L-80 IBTM Tbg 4.79 9542.02 Jts 171 to 176 6 Jts 4%2" 12.6# L-80 IBTM Tbg 260.40 9546.81 Perf Pup - 4'/2" 12.6# L-80 IBTM Tbg 4.80 9807.21 Jts 165 to 170 6 Jts 4%" 12.6# L-80 IBTM Tbg _ 261.17 9812.01 Perf Pup - 4'/2" 12.6# L-80 IBTM Tbg 4.80 10073.18 Jts 159 to 164 6 Jts 4%" 12.6# L-80 IBTM Tbg 260.45 10077.98 Perf Pup - 4'/2" 12.6# L-80 IBTM Tbg 4.79 10338.43 53 to 158 6 Jts 4%2" 12.6# L-80 IBTM Tbg 260.93 10343.22 Pert Pup - 4'/z" 12.6# L-80 IBTM Tbg 4.80 10604.15 Jts 947 to 152 6 Jts 4%2" 12.6# L-80 IBTM Tbg 261.76 10608.95 PerF Pup - 4'/2" 12.6# L-80 IBTM Tbg ~ 4.78 10870.71 Jts 141 to 146 6 Jts 4%" 12.6# L-80 IBTM Tbg 260.70 10875.49 Perf Pup - 4'/i" 12.6# L-8o IBTM Tbg 4.79 11136.19 Jts 135 to 140 6 Jts 4%" 12.6# L-80 IBTM Tbg 258.58 11140.98 Perf Pup - 4'/z" 12.6# L-80 IBTM Tbg 4.80 11399.56 Jts 129 to 134 6 Jts 4%" 12.6# L-80 IBTM Tbg 258.73 11404.36 Perf Pup - 4'/Z" 12.6# L-80 IBTM Tbg 4.80 11663.09 Jts 123 to 128 6 Jts 4'/z" 12.6# L-80 IBTM Tbg 260.29 11667.89 Perf Pup - 4'/z" 12.6# L-80 IBTM Tbg ~ 4.81 11928.18 Jts 117 to 122 6 Jts 4%2" 12.6# L-80 IBTM Tbg 260.17 11932.99 Perf Pup - 4'/z" 12.6# L-80 IBTM Tbg 4.81 12193.16 Jts 111 to 116 6 Jts 4%" 12.6# L-80 IBTM Tbg 259.99 12197.97 Perf Pup - 4'/Z" 12.6# L-80 IBTM Tbg 4.80 12457.96 Jts 105 to 110 6 Jts 4%" 12.6# L-80 IBTM Tbg 260.45 12462.76 Pert Pup - 4'/z" 12.6# L-80 IBTM Tbg 4.77 12723.21 Jts 99 to 104 6 Jts 4%2' 12.6# L-80 IBTM Tbg 257.91 12727.98 Perf Pup - 4'/z" 12.6# L-80 IBTM Tbg ~ 4.77 12985.89 Remarks: Drifted to 3.833", Ave MU 3,200 ft-Ibs Up WT 225K Dn WT 125K Block Wt 70K Supervisors: Hill /Wilson umber Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 2 LENGTH TOPS Jts 93 to 98 6 Jts 4%2" 12.6# L-80 IBTM Tbg 254.11 12990.66 Perf Pup - 4'/2" 12.6# L-80 IBTM Tbg ~ 4.79 13244.77 Jts 87 to 92 6 Jts 4%2" 12.6# L-80 IBTM Tbg 253.01 13249.56 Pert Pup - 4'/z" 12.6# L-80 IBTM Tbg 4:82 13502.57 Jts 81 to 86 6 Jts 4%2" 12.6# L-80 IBTM Tbg 260.92 13507.39 Pert Pup - 4'/2" 12.6# L-80 IBTM Tbg 4.79 13768.31 Jts 75 to 80 6 Jts 4%2" 12.6# L-80 IBTM Tbg 260.64 13773.10 Perf Pup - 4'/z" 12.6# L-80 IBTM Tbg 4.82 14033.74 Jts 69 to 74 6 Jts 4%2" 12.6# L-80 IBTM Tbg 251.88 14038.56 Perf Pup - 4'/:" 12.6# L-80 IBTM Tbg ~ 4.77 14290.44 Jts 63 to 68 6 Jts 4%2' 12.6# L-80 IBTM Tbg 257.18 14295.21 Perf Pup - 4'/z" 12.6# L-80 IBTM Tbg 4.80 14552.39 Jts 57.to 62 6 Jts 4%' 12.6# L-80 IBTM Tbg 260.58 14557.19 Perf Pup - 4'/2" 12.6# L-80 IBTM Tbg 4.78 14817.77 Jts 51 to 56 - 6 Jts 4%2' 12.6# L-80 IBTM Tbg 254.97 14822.55 Perf Pup - 4'/2" 12.6# L-80 IBTM Tbg 4.79 15077.52 Jts 45 to 50 6 Jts 4%2' 12.6# L-80 IBTM Tbg 260.15 15082.31 Perf Pup - 4'/2" 12.6# L-80 IBTM Tbg 4.77 15342.46 Jts 39 to 44 6 Jts 4%z" 12.6# L-80 IBTM Tbg 259.71 15347.23 Perf Pup - 4'/z" 12.6# L-80 IBTM Tbg 4.78 15606.94 33 to 38 6 Jts 4'/2" 12.6# L-80 IBTM Tbg 258.01 15611.72 Perf Pup -,4'/i" 12.6# L-80 IBTM Tbg 4.84 15869.73 ,,,~ 27 to 32 6 Jts 4'/2" 12.6# L-80 IBTM Tbg 256.37 15874.57 Perf Pup - 4'/Z" 12.6# L-80 IBTM Tbg 4.77 16130.94 Jts21 to 26 6 Jts 4%2" 12.6# L-80 IBTM Tbg 259.73 16135.71 Perf Pup - 4'/z" 12.6# L-80 IBTM Tbg ~ 4.79 16395.44 Jts 15 to 20 6 Jts 4%2' 12.6# L-80 IBTM Tbg 255.26 16400.23 Perf Pup - 4'/Z" 12.6# L-80 IBTM Tbg 4.80 16655.49 Jts 9 to 14 6 Jts 4%' 12.6# L-80 IBTM Tbg 260.36 16660.29 Perf Pup - 4'/Z" 12.6# L-80 IBTM Tbg 4.81 16920.65 Jts 4 to 8 5 Jts 4%2" 12.6# L-80 IBTM Tbg 214.97 16925.46 Perf Pup - 4'/2" 12.6# L-80 IBTM Tbg 4.79 17140.43 Jts 1 to 3 3 Jts 4%" 12.6# L-80 IBTM Tbg 130.32 17145.22 Closed end Guide - 4'/Z" 12.6# L-80 IBTM Tbg 4.46 17275:54 END OF LINER 17280.00 ~~ . ,; ~ F _ .; k, ,.. M ,~ n, ~ t x °a . ~ ~ : ~ 4 ~ \ ~ .. , a_ . yr t_.t a_ ,;w1 ., .mi l..,r ~~ l ~,~F __~~ ~...~ ~. i .J i_~ _ A ~.J l»$ ALASSA Ol°iL ~1~TD G~5 CO1~T5ER~ATI011T COM1~II55IO1~T Chip Alvord Alpine Drilling Team Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Fiord Oil Pool, CD3-113 Sundry Number: 308-034 Dear Mr. Alvord: Enclosed is the approved Application for Sundry above referenced well. Please note the conditions enclosed form. SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Approval relating to the of approval set out in the When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount Jr. Chair DATED this ~? day of February, 2008 Encl. ~O~"'U~f ~'~~~~ STATE OF ALASKA ! ~,~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS~~IJAN ~ 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ ~~ ~ ~ Othe ~~ GS'9€!Yfl 8 Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ 7ne Extension ~ ~ ?~~~ ~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended We ~~ ~ru 2. Operator Name: 4. Current Well Class: 5. Permit to Dr I Number. ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 207-004 3. Address: Stratigraphic ^ Service ^ 6. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 50-103-20541-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No Q CD3-113 9. Property Designation: ~ 10. KB Elevation (ft): 11. Field/Pool(s): ADL 3, 384215, 372105 .!~ ~ ~. ~~ `-/`~7 f a '~'' 49.5' MSL, 37 RKB Colville River Field / Fiord Oil Pool 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9374 6910 Casing Length Size MD TVD Burst Collapse Structural Conductor 77 16" 114 114 Surface 2582 9 5/8" 2619 2482 5750 3090 Intermediate 9327 7" 9364 6910 7240 5410 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NA NA 3.5" L-80 2000' Packers and SSSV Type: Packers and SSSV MD (ft): None None 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ^ Exploratory ^ Development^ Service ^ 15. Estimated Date for 2/11/2008 16. Well Status after proposed work: Commencing Operations: Oil 0 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 L. Galiunas 907-265-6247 Printed Name C. Atvord 907-265-6120 Title Alpine Drilling Team Lead Si nature p ~~ Phone ~~ ~ ~~ Date 9 4.,. ~ i (~v ~2.o a ~'i COMMISSION USE ONLY hh z ss Sund Number: JV 8 - O J~ ti itn th t l N if C i i t f ry ve may w e a represen a : y omm ss on so a Conditions o approva ot rity Test ^ Location Clearance ^ Integ Plug Integrity ^ BOP Test ~ Mechanical ~ (` Other: t'C ~~6'C1.~~©t~~ ~TT~U°°~ C~~C~'~CJ~~Cs~CC_~~~ ~~~ ~t ~~ `~~~"'t . '~~~~ ~E~ a 31009 Subsequent Form Required: '' `~\~C~~~3~^ , Q~ e>JE. ~,~ ~~ ~ i..a ~ C-e4~ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ' Form 10-403 Revis 06/2006 ~~~=--~ ~~ Submit in Duplicate ~~ CD3-113 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 6-1 /8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 8.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers ORIGINAL Nechelik : CD3-107 0 Pre-Riq Work 1) BPV set in well. Riq Procedure 1. Move in and rig up with Doyon 19, dewater cellar as needed 2. Pull BPV. 3. Install and test 2 way check. 4. ND tree. 5. NU and test BOPE to 3500 psi. 6. Displace diesel freeze protection to brine. 7. Pull tubing hanger and 2000' of freeze protect string. 8. Pick up and run in hole with 6 1/8" drilling assembly. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 9. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). 10. Circulate the hole clean and pull out of hole. 11. Run 3 'h, 9.3#, L-80 EUE Mod tubing with TRMAXX SSSV, gas lift mandrels, sliding sleeve, packer XN nipple, and wireline entry guide. Land hanger. 12. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 13. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 14. Circulate tubing to diesel and install freeze protection in the annulus. 15. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. 16. Set BPV and secure well. Move rig off. ORIGIN!1L • Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD3-114 is the nearest to the CD3-113 plan with 16.8' well to well separation at 550' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Nechelik reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: This well is currently permitted for Annular Disposal (Approval number 307-067) therefore all incidental fluids developed from drilling operations will be taken to the class two disposal well, CD1-19A. DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing point -12 %4" Intermediate hole to 7" casing point - 8 3/4" Production Hole Section - 6 1/8" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.0-9.3 ppg 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 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. OR!GIN~L TOC @ +)- 4296' MD ! 3698' TVD TAM Stage cementing tool +/- 5317' M D / 4433' TVD Fiord (CD3) Colville River Field CD3-113 Production Well Completion Plan 16" Conductor to 114' 9-5/8" 40 ppf L-80 BTC-Mod Surface Casing 2619' MD / 2482' TVD cemented to surface Qannik interval top +/- 4796' MD / 4058' TVD 3-1/2" 9.3 ppf L-80 EUE M tubing run with Jet Lube Run'n'Seal pipe dope TOC @ +l- 8419' MD 6587' TVD Top Kuparuk C 8919' MD / 6798' TVD Top Nechelik 9446' MD / 6916' TVD Updated 01/25/08 Sperry Drilling Services Directional Plan WP03 Packer Fluid mix: Inhibited 9.4 pia KCI Brine with 1500' TVD diesel cao Completion MD ND Tubing Hanger 32' 32' 4-''/2" 12.6#/ft IBT-Mod Tubing (2 jts) Crossover 3-'/z' 9.3 #/ft EUE-Mod Tubing Camco TRMAXX-5E SSSV (2.812" ID) 2035' 2000' 3-'/=" 9.3 #/ft EUE-Mod Tubing Camco KBMG GLM (2.867" ID) 3882' 3400' 3-''/2' 9.3 #/ft EUE-Mod Tubing Camco KBMG GLM (2.867" ID) 6937' 5600' 3-%z' 9.3 #/ft EUE-Mod Tubing Camco KBMG GLM (2.867" ID) 8460' 6608' 3-'/~' tubing joints (1) HES 2.813" X Profile 8500' 6627' 3-'/:" Tubing Joints EUE-Mod (1) 3-%2" Baker Gauge Mandrel 8550' 6650' 3-'/2" Tubing Joints EUE-Mod (1) Baker Premier Packer (63.5°) 8600' 6674' 3-''/2' tubing 1 joint HES XN 2.813" (2.75" NoGo)-64.6° inc 8650 6696' 3-1/2" 10' pup joint WEG 8662 6701' Baker Premier Packer at +/- 8600' MD +/- 250 TVD above Nechelik 7" 26 ppf L-80 BTC Mod Production Casing @ 9364' MD / 6910' TVD ORIGINAL CD3-113 TD at 17~ MD / 6899' TVD 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 (Ibs. /gal) Pore pressure (psi) ASP Drilling (psi) 16 N/A N/A N/A N/A 9 5/8 N/A N/A N/A N/A 7" 9364 / 6910 16.0 3126 2435 N/A 17484 / 6899 16.0 3122 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=[(FGx0.052)-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 intermediate casing (7") ASP =FPP - (0.1 x D) = 3126 - (0.1 x 6910') = 2435 psi 2. Drilling to TD ASP =FPP - (0.1 x D) = 3122 - (0.1 x 6899') = 2432 psi ORIGINAL J7 ._._ 7 ~' i :'F ,~ t, :,r. ~h. ~r "'Y her `r~• ^. .t t ~` s,. *z "F ~: ~:; f 'rt ~; r, M -T ?~~; ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad CD3-113 CD3-113 Plan: CD3-113wp04 Standard Proposal Report 25 January, 2008 HALLIBURfiO1V i3perry Drilling Services OR161NAL Er m: ISCWSA Swn M rav. Cylinder North ..- Error ce: E~~Iptiw~Conic Western North Slo ConocoPhillips WarningMethotl: Rules Based CD3 Fiord Pad Geodetic Datum: North American Datum 1983 C D 3 113 w p 0 4 MagnMlc Motlel: BGGM2007 ~ CD3-113 Ground revel: D.00 CD3-113 RKB: CD3-113: @ 49.79ft (CD3-113:1 NorthinglAS°V; 6003567.62 CD3-113wp04 Easting!ASP X: 1528167.38 0~ ~~Q 1~ x,03 x 6-1/8" CD3-113wp03 T3 7500 .-. c 0 0 N 5000 - .- o Z .-. 2500 '- ~ 7" x 8-3/4" ~~ ~9-5/8" x 12-1/4" 0 _~- - I -12500 -10000 -7500 -5000 -2500 0 2500 West(-)/East(+) (2500 ft/in) 0 - c 10 0 2d ~ 30 ~ 9-5/8" x 12-1/4" 2500-{ _ - -~ a ~ o ~~ ~a U ~ 5000 - > a~ ~, L j h~ ~ 7" x 8-3/4" 0 3-1/2" x 6-1 /8" 0 ~' ~O ~° ~ ~ p CD3-113wp03 T3 7500 - ', -- _ - - - 0 2500 5000 7500 10000 1 ~ 0 0 o ORIGINAL Operator: ConocoPhillips(Alaska) Inc. -WNS Grid Correction: -0.86 Job No: #N/A Fteld: Western North Slope Magnetic Declination: 22.87 AFE No: #N/A Well: CD3-113wp04 Plan Dip: 80.74 API No: #N/A Rig: #N/A Dogleg per. 100 fl North Reference: TRUE Surface Location Original VS Plane: 309.53 Pareni Well: CD3-113 X: 388729.47' fl Vlew VS Plane: 309.53 RKB Height: 49.79 fl Y: 8003820.47 ft Meas. Incl. TRUE Subsea RKB Local ASP or Grid Dogleg Original 'ie~ Tooi Build Turn Course Drilled Depfh (K) Angle (deg) Asl. (deg) TVb Ift) TVD (ff} N(+)/S(-) (fi) E(+)/W(-) (ff) N(+)/S(-) Lat. (Y) E{+)/W(-) Dep. (X) Severity (°/100 fl) VS (310°) (R) 13 fij Toce (deg) (°/100 ft) (°/100 #) Length (ft) Distance (R) 0 Comments 100.00 0.27 198.22 50.21 IQO 00 -0.15 •0.10 6003820.27 388129.37 QOCi =0'A2 200.00 0.66 162.44 150.21 200.00 -0.92 0.00 6003819.49 388129.48 0.47 •0.59 'k •58 0.39 •35.78 100.00 100.00 CB-GYRO-SS (1) 300.00 0.99 759.71 250.26 299.94 -2.28 0.47 6003818.12 388129.91 0.33 •1.82 -8 0.33 •2,73 100.00 200.00 400.00 1.28 756.60 3,50.1$ 349.97 -4.12 1.22 6003818.28 388130.62 0.30 -3.56 -14 0.29 -3.17 100.00 300.00 500.00 1.66 149.89 45(:.14 499.93 -6.40 2.39 4.)03$13.98 388131.78 0.42 -5.97 ri -28 0.38 -6.71 100.00 400.00 600.00 1.36 141.77 550:11 599.90 -8.58 3.85 6003871.78 388133.19 0.37 -8.43 # -148 -0.30 -8.12 100.00 500.00 700.00 0.60 723.65 650.09 699.88 -9.80 5.02 6003810.54 388134.34 0.81 -10.17 +? •167 -0.76 -18.12 100.00 600.00 800.00 0.25 173.70 750.09 799.88 -10.31 5.48 5v^0387C.02 388134.79 0.48 -10.79 158 -0.35 50,05 100.00 700.00 900.00 1.72 269.63 850.08 899.87 -10.54 4.00 6003809.$2 388133.31 1J8 -9.79 ~ 704 1.47 95.93 100.00 800.00 MWD+IFR-AK-CAZ-SC (2) 1000.00 2.37 271.52 950.01 999.80 -10.49 0.43 8003809.92 388129.74 0.85 -7.01 r, 7 0.65 1.89 100.00 900.00 ;,.,,1100.00 2.45 273.15 1049.92 7494.71 -10.32 -3.77 6003810.15 388125.55 0.11 -3.88 ~d 42 0.08 1.63 100.00 1000.00 200.00 3.30 279.95 1149.$0 1194.54 -9.70 -8.74 6(Xi3810.$4 388120.59 0.91 0.56 w 25 0.85 6.80 100.00 1100.00 1300.00 6.49 283.31 12a9.a2 1299.27 -7.91 •17.07 6003812.J7 388112.28 3.20 8.14 ?± 7 3.19 3.36 100.00 1200.00 400.00 9.91 287.81 1348.38 1398.17 -3.97 -30.77 G0038i6.90 388098.6A 3.48 27.20 13 3.42 4.50 100.00 7300.00 500.00 13.12 290.09 1448.36 t498.t5 2.56 •49.63 60(.)3823.72 388079.89 3.24 39.91 9 3.21 2.28 100.00 1400.00 1600.00 15.77 288.22 1.543.19 7592.98 10.71 -73.20 6003832.[1 388058.44 2.69 63.27 -11 2.65 -1.87 100.00 1500.00 700.00 18.38 285.04 i 638.78 1888.57 19.05 •101.32 60038x0 98 388028.45 2.75 90.27 -21 2.59 -3.18 100.00 1600.00 800.00 20.95 282.47 1732.95 7782.74 26.98 •134.00 6003849.40 387995.89 2.74 120.52 -20 2.59 -2.63 100.00 1700.00 900.00 23.44 279.66 7825.53 1875.32 34.18 -171.07 60038.57.14 387958.93 2.70 153.68 -24 2.49 -2.75 100.00 1800.00 000.00 26.34 277.16 1916.24 7986.03 40.26 •212.70 6003863.x,6 387917.40 3.08 189.68 -21 2.90 -2.50 100.00 1900.00 700.00 29.38 278.30 2004.65 2054.44 45.72 •259.09 8003870.02 387871.09 3.05 228.93 r, -8 3.02 -0.88 100.00 2000.00 2200.00 31.79 276.37 '1.090.73 2140.52 51,33 •309.84 6(H)3F.t76.39 387820.63 2.43 271.49 ? 1 2.43 0.07 100.00 2100.00 2300.00 34.00 276.87 2174J0 2224.49 57.60 •383,59 8003883.4.5 387766.79 2.23 317.09 ~ 7 2.21 0.50 100.00 2200.00 2400.00 36.38 277.18 1256.43 2308.22 84.65 -420.76 6003891.37 387709.72 2.37 385.88 r? 4 2.36 0.31 100.00 2300.00 2500.00 39.69 276.87 2335.19 2384.98 72.07 -481.91 6003899.70 387648.70 3.34 417,58 N. -8 3.33 -0.51 100.00 2400.00 2800.00 42.47 277.10 2410.56 2460.35 79.95 -547.14 600390$.57 387583.59 2.79 472.89 ±` 6 2.'8 0.43 100.00 2500.00 2619.29 42,54 277.38 2424.7$ 2A7457 81.59 -560.07 6003910.40 387570.69 0.98 483.90 ~~ 88 0.36 7.35 19.29 2519.29 9-5/8"x 12-1 /4" 2700.00 43.47 277.47 2483.80 2533.59 88.69 -614.85 GG03918.;i2 387516.22 1.16 530.53 ~ 5 1.15 0.14 80.71 2600.00 2800.00 46.52 278.23 7.554.51 2804.30 98.38 -684.68 6003929.04 387446.34 3.10 590.70 ?' 10 3.05 0.76 100.00 2700.00 2900.00 46.91 279.88 ?6:?3.08 2672.87 109.82 •756.57 6003941_58 387374.84 1.26 653.43 # 73 0.39 1.65 100.00 2800.00 3000.00 45.87 280.45 2692.05 2741.84 122.60 -827.83 6003955.42 387303.57 1.12 718.53 759 -1.04 0.57 100.00 2900.00 3100.00 44.87 280.18 27G1.,'i0 2812.09 135.34 •897.85 6003959.2'2 387233.75 1.02 778.64 -1 b4 -1.00 -0.27 100.00 3000.00 3200.00 43.83 280.03 2833A3 2883.72 147.58 -968.54 6003982.49 387165.25 1.24 839.42 -775 -1.24 -0.15 100.00 3100.00 3300.00 43.30 280.15 2908.51 2956,30 159.64 -1034.27 6003995.56 387047.71 0.34 899.33 tbb -0.33 0.12 100.00 3200.00 3400.00 43.12 280.25 2979.40 3029.79 171.78 -1101.86 8004008.69 387030.51 0.19 959.02 759 -0.18 0.10 100.00 3300.00 3500.00 43.16 280.19 30:12.37 3102.78 183.89 -1188.95 60040121.83 386963.41 0.06 1018.64 •46 0.04 -0.08 100.00 3400.00 3800.00 43.11 280.42 3125.3a 3175.13 198.12 -1236.22 6:8)403,5.07 386898.33 0.17 1078.31 108 -0.OS 0.23 100.00 3500.00 3700.00 42.95 280.65 .3198.44 3248.23 208.60 -1303.31 600x04855 388829.44 0.22 1138.00 13a -0.ib 0.23 100.00 3600.00 3800.00 43.22 280.57 3271.47 3321.26 221.18 •1370.45 !x')04062.14 386782.50 0.28 1197.79 tt -12 0.27 •0.08 100.00 3700.00 3900.00 43.50 280.27 3344.18 3393.97 233.59 -1437.97 600x07556 388695.16 0.35 1257.77 7? -36 0.28 •0.30 100.00 3800.00 4000.00 43.46 278.95 3x16.74 3466.53 245.08 •1505.81 8004088.07 388627.50 0.91 1317.41 # -43 -0.04 -7.32 100.00 3900.00 4100.00 43.22 278.88 3489.47 3539.24 255.72 •7573.62 6004099.72 388559.87 0.24 1376.48 ~ -tb4 -0.24 •0.07 100.00 4000.00 4200.00 42.63 279.44 3562.70 3812.44 266.56 •1640.85 6004111.57 386492.80 0.70 1435.23 ?? 147 -0.59 0.58 100.00 4100.00 4300.00 42.76 279.95 3636.19 3685.98 277.98 •1707.89 6004123.99 388428.14 0.37 1494.05 # 70 0.13 0.57 100.00 4200.00 4400.00 42.92 279.83 3709.52 3759.31 289.65 -1774.68 6004136.67 388359.34 0.18 1553.15 ?± -27 0.18 -0.12 100.00 4300.00 4500.00 42.85 279.54 3782.91 3832.70 301.08 -1841.63 G(Nix1x9.10 388292.56 0.33 1812.07 $` -744 -0.27 -0.29 100.00 4400.00 Meas. Incl. TRUE Su6sen RK& Local ASP or Grid Dogleg Original 'ic. Taol Build Tarn Course Drilled Depth (h) Angle (de91 A[I. (deg) TVD (('ll 1V0 (N) N(+)/S(-) (ft) E(+)/W(-) (ft) hi;+)/S{-) Lat. (Y) E(+)/W(-) Dep. (X) Severity (°/100 fi) VS (310°) (R) (.',1 (fry Face (deg} (°/100 ft) (°/100 fY) Length (ft) Distance (ff) '~ Comments 4600.00 42.81 278.38 3856.37 3405.1& 311.65 -1908.66 6004160.68 386225.70 0.80 1670.49 # -74 0.16 -1.16 100.00 4500.00 4700.00 43.05 278.74 3929.59 3979.38 321.79 -1976.07 6004171.82 386158.51 0.34 1728.89 # 46 0.24 0.36 100.00 4600.00 4800.00 43.08 279.44 4002.64 4052.43 332.57 •2043.43 6004183.62 386091.26 0.48 1787.76 +.` 87 0.03 0.70 100.00 4700.00 4900.00 43.63 279.54 4075.36 A725.25 343.89 •2111.15 6004195.96 38&023.72 0.55 1847.19 ~ 7 0.55 0.10 100.00 4800.00 5000.00 43.83 278.39 4147.62 A197.41 354.66 -2179.43 6004207.; 5 385955.61 0.82 1906.71 :~ -76 0.20 -1.15 100.00 4900.00 5100.00 43.74 279.10 A219.81 4269.60 365.18 -2247.82 6004219.30 385887.39 0.50 1966.15 101 -0.09 0.71 100.00 5000.00 5200.00 43.61 279.18 4292.14 4341.43 376.15 -2316.00 6004231.29 385819.3$ 0.14 2025.72 !' 157 -0.13 0.08 100.00 5100.00 5300.00 43.57 278.95 4364.57 4414.3& 387.02 •2384.08 6004243.17 385751.46 0.16 2085.15 •104 -0.04 •0.23 100.00 5200.00 5400.00 43.51 279.26 4437.C6 4486.85 397.92 -2452.10 6004255.09 385683.62 0.22 2144.55 - lOd -0.06 0.31 100.00 5300.00 5500.00 43.63 279.34 4509.51 4559.30 409.06 -2520.12 6.04267.25 385615.77 0.13 2204.10 25 0.12 0.08 100.00 5400.00 5600.00 44.22 278.28 4581.54 A631.33 419.68 •2588.67 6004278.90 385547.39 0.94 2263.74 ~ -52 0.59 -1.06 100.00 5500.00 5700.00 44.03 277.97 4553.32 4703.12 429.52 -2657.59 6004289.77 385478.62 0.29 2323.16 -131 -0.19 -0.31 100.00 5600.00 5800.00 43.56 278.20 4725.50 4775.29 439.25 -2726.11 6004300.,53 385420.25 0.50 2382.20 161 -0.47 0.23 100.00 5700.00 5900.00 43.86 278.44 471.78 4847.57 449.25 •2794.49 6004311.5.5 385342A4 0.34 2441.30 rt 24 0.30 0.24 100.00 5800.00 &000.00 43.65 278.90 4870A2 4919.81 459.67 -2862.85 by^04323.01 385273.8A 0.38 2500.67 124 -0.21 0.46 100.00 5900.00 6100.00 43.43 278.94 4942.50 4992.29 470.36 -2930.91 6004334.71 385205.95 0.22 2559.96 173 -0.22 0.04 100.00 6000.00 6200.00 43.76 278.82 5014.93 5064.72 481.00 -2999.04 6004346.37 385137.99 0.34 2619.28 T; -14 0.33 -0.12 100.00 6100.00 00.00 44.02 279.22 5L18G.99 5136.78 491.87 -3067.51 6004358.27 3850&4.69 0.38 2&79.01 ?: 47 0.26 0.40 100.00 6200.00 0.00 44.06 278.58 5156.88 5208.67 502.62 •3136.18 6004370.05 385001.18 0.45 2738.82 1' -8S 0.04 -0.64 100.00 6300.00 00.00 42.97 277.58 5231.40 5281.14 512.31 •3204.35 6C44380.;'6 384933.17 1.29 2797.56 r. -148 -1.09 -1.00 100.00 6400.00 00.00 42.63 277.7& 5304.77 5354.5& 521.37 -3271.69 6004390.84 384865.47 0.36 2855.27 r 140 -0.34 0.18 100.00 6500.00 00.00 43.51 278.19 5377.82 5427.61 530.85 •3339.32 6004401.33 384798.50 0.93 2913.46 .r'• 19 0.88 0.43 100.00 6600.00 ' 00.00 43.84 279.06 5450.15 5499.94 541.21 -3407.59 6(X14412.71 384730.34 0.69 2972.71 # d2 0.33 0.87 100.00 6700.00 900.00 43.53 277.95 5522.47 5572.26 551.43 •3475.90 6004423 45 384662.24 0.83 3031.90 -112 -0.31 -1.11 100.00 6800.00 0.00 44.10 277.84 5.544.62 5&44.41 560.93 -3544.47 6004434.49 384593.81 0.58 3090.85 •8 0.57 -0.11 100.00 6900.00 7100.00 43.38 278.23 5666.87 5716.&6 570.60 -3612.93 6004445.17 384525.51 0.77 3149.80 160 -0.72 0.39 100.00 7000.00 200.00 43.82 278.92 5739.29 5789.08 580.88 -3681.12 000445h.48 384457.48 0.65 3208.94 47 0.44 O.b9 100.00 7100.00 00.00 43.81 279.98 :iP,ll.45 5861.24 592.25 -3749.41 6004468.87 384389.37 0.73 3268.85 41 -0.O1 1.06 100.00 7200.00 0.00 44.06 279.12 5883.46 5933.25 603.76 -3817.84 6004481.41 384321.12 O.bS 3328.94 •68 0.25 -0.86 100.00 7300.00 7500.00 43.90 279.00 5955.42 4005.22 614.69 •3886.41 6004493.37 384252.72 0.18 3388.79 # -252 -0.16 -0.12 100.00 7400.00 7600.00 43.24 281.01 6027.88 &077.67 626.66 -3954.28 6,:04506.35 384185.04 1.53 3448.76 116 -0.66 2.01 100.00 7500.00 7700.00 44.04 283.73 6100.25 5150.04 641.45 -4021.67 6004522.16 384117.88 2.04 3510.15 d6 0.80 2.72 100.00 7600.00 7800.00 45.47 285.07 6171.26 6227.05 658.97 -4089.8& 5004540J0 384049.9& 1.71 3573.90 # 34 1.43 1.34 100.00 7700.00 7900.00 47.07 285.43 6240.39 &290.18 677.98 -4159.58 6004560.75 383980.54 1.62 3639.76 ~ 4 1.60 0.36 100.00 7800.00 8000.00 49.18 284.55 6307.14 &356.93 698.50 -4231.15 6004582.34 383904..28 2.27 3708.03 s.' 22 2.11 1.12 100.00 7900.00 8100.00 51.16 289.63 6371.19 6420.98 722.37 •4304.12 6004607.30 383836.68 3.08 3779.50 sp 52 1.98 3.08 100.00 8000.00 8200.00 52.97 291.85 643267 6482.46 750.31 -4377.86 tyJU463G.35 383763.37 252 3854.16 ?' 45 1.81 2.22 100.00 8100.00 8300.00 55.02 293.34 6491.46 654L25 781.40 -4452.53 6004668.56 383689.17 2.38 3931.55 ?? 3T 2.05 1.49 100.00 8200.00 8400.00 57.82 295.50 6546.7! 6546.56 815.86 -4528.36 6004704.15 383613.86 3.33 4011.97 ?' 33 2.80 2.16 100.00 8300.00 8500.00 60.70 298.46 6597.88 6647.67 854.87 -4604.92 GD04744.31 383537.89 3.84 4095.85 42 2.88 2.96 100.00 8400.00 8600.00 64.26 301.52 6644.09 6693.88 899.22 -4681.69 GC04789.80 383461.80 4.48 4183.28 38 3.56 3.06 100.00 8500.00 8700.00 67.50 306.69 6684.97 6734.76 950.41 -4757.19 6004842.12 383387.08 5.72 4274.10 57 3.24 5.17 100.00 8600.00 8800.00 69.16 311.61 6721.92 6771.71 1009.08 -4829.21 6004901.86 383315.45 4.86 436&.99 # 71 1.66 4.92 100.00 8700.00 8900.00 70.36 315.57 6756.52 6806.32 1073.76 -4897.14 6004967.56 383248.94 3.90 4460.55 73 1.20 3.96 100.00 8800.00 9000.00 73.11 318.44 6787.87 6837.66 1143.21 -4961.87 N,)O;i037.97 383185.31 3.87 4554.68 45 2.75 2.87 100.00 8900.00 9100.00 76.20 322.53 6814.34 6864.13 1217.60 •5023.19 6005113.27 3$3125.12 5.01 4649.32 t~ 52 3.09 4.09 100.00 9000.00 9200.00 78.61 325.85 6836.15 6885.94 1296.73 •5080.27 6005193.2:1 3830&9.24 4.04 4743.71 # 54 2.41 3.32 100.00 9100.00 9300.00 82.31 327.92 6852.72 5902.51 1379.32 •5134.12 6005276.64 383016.63 4.23 4837.82 # 29 3.70 2.07 100.00 9200.00 9341.65 83.87 328.36 ti857.73 &907.52 1414.44 -5155.95 6005312.08 382945.33 3.89 4877.00 17 ld 3.75 1.06 41.65 9241.65 9364.33 83.87 328.36 6850.15 6909.94 1433.63 -5167.78 6005331.45 382983.79 0.04 4898.34 r 40 0.00 0.00 22.68 9264.33 T' x 8-3/4" - MWD+IFR-AK-CAZ-SC (3) 9374.00 83.87 328.36 6861.19 6410.98 1441.82 -5172.82 6005339.71 382978.87 0.08 4907.44 it 40 0.00 0.00 9.67 9274.00 KOP;3.5 DLS 9400.00 84.78 328.36 6863.76 6413.55 1463.85 -5186.39 6065361.94 382965.63 3.50 4931.93 i) 1 3.50 0.00 26.00 9300.00 9500.00 88.28 328.36 6869.81 6474.60 1548.81 •5238.75 600,5447.68 382914.56 3.50 5026.39 .~ 0 3.50 0.00 100.00 9400.00 9515.25 88.81 328.36 6870.20 6919.99 1561.79 •5246.74 6005460J8 382906.76 3.48 5040.82 ?` 1 3.48 0.00 15.25 9415.25 J Meas. Incl. .TRUE Subsea ftK0 Local ASP ar Grid Dogleg Original " i~~ Toal Build Turn Course Drilled ^' Depth {M) Angle (deg) Azl. (deg) TVD Ih) TVD Crr} N(+)/S(-) (fll E(+)/W(•) (tt) N(+)/,i(-) Lat. (Y) E{+)/W(-) Dep. (X) Severity (°/100 R) VS (310°) (H) ffti Face (deg? (°/100 ft) {°(100 ft) Length (ftl Dbtonce (ft) Comments 9549.14 90.00 328.36 6870.55 6420.34 1590.64 -5264.52 50;05489.89 382889.42 3.51 5072.89 # 0 3.51 0.00 33.89 9449.14 9600.00 90.08 326.58 6..+170.51 6929.36 1633.52 •5297.87 by^05533.18 382862,71 3.50 5121.28 ~ -87 0.16 •3.50 50.86 9500.00 9646.05 90.15 324.97 6870.42 642031 1671.60 -5317.77 bv^05571.6d 382837.39 3.50 5765.49 # -88 0.15 -3.50 46.05 9546.05 9700.00 90.15 324.97 6870.28 6420.07 1715.77 -5348.74 6005E16.27 3$2807.09 0.02 5217.49 .~ 4fl O.OD 0.00 53.95 9600.00 9800.00 90.15 324.97 U'370.D'2 6974.$1 1797.66 -5406.74 6905699.01 382750.92 0.01 5313.88 ~?' 9fl 0.00 0.00 100.00 9700.00 9900.00 90.15 324.97 6869.?G 6914.55 1879.54 •5463.54 6(115?81.75 382694.76 0.01 5410.27 ?f 90 0.00 0.00 100.00 9800.00 9914.12 90.15 324.97 6864.72 6919.51 1891.11 -5471.64 6005?93.43 382686.83 0.06 5423.88 81 90 0.00 0.00 14.12 9874.12 10000.00 90.15 324.97 6859.49 6414.28 1961.43 -5520.94 6005864.49 382638.59 0.01 5506.66 T' 90 0.00 0.00 85.88 9900.00 10100.00 90.15 324.97 6FS69.23 6419A2 2043.31 -5578.34 600.5947.22 382582.43 0.01 5603.06 90 0.00 0.00 100.00 10000.00 10200.00 90.15 324.97 6868.97 6918.76 2125.20 •5635.74 6006029 96 382526.26 0.01 5699.45 40 0.00 0.00 100.00 10100.00 10300.00 90.15 324.97 6865.71 6918.50 2207.08 -5693.14 6006112.70 382470.10 0.01 5795.84 90 0.00 0.00 100.00 10200.00 10400.00 90.15 324.97 6868.45 6418.24 2288.97 ~ -5750.54 6006195.44 382413.93 0.01 5892.23 40 0.00 0.00 100.00 10300.00 10500.00 90.15 324.97 6868.18 6917.47 2370.85 -5807.94 6906278.17 382357.77 0.01 5988.62 ~! 90 0.00 0.00 100.00 10400.00 10600.00 90.15 324.97 GY,G7 9? 6417.71 2452.74 -5865.34 6(H)636D.91 382301.60 0.01 6985.01 i. 90 0.00 0.00 100.00 10500.00 10700.00 90.15 324.97 6867.66 6917.45 2534.62 -5922.74 600f,443.65 382245.44 0.01 6187.40 9D 0.00 0.00 100.00 10600.00 10800.00 90.15 324.97 6867.A0 6417.14 2616.51 •5980.14 6006526.38 382189.27 0.01 6277.79 r` 4D 0.00 0.00 100.00 10700.00 10900.00 90.15 324.97 6867.14 6416.43 2698.39 -6037.54 6906609.12 382133.11 0.01 6374.18 19 90 0.00 0.00 100.00 70800.00 11000.00 90.15 324.97 6866.88 6916.67 2780.28 •6094.94 6006691.86 382076.94 0.01 6470.57 # 90 0.00 0.00 100.00 10900.00 11100.00 11200.00 90.15 90.15 324.97 324.97 6866.61 6865.35 6416.40 6976.14 2862.16 2944.05 -6152.34 -6209.74 6006774.60 6006857.33 382020.78 387964,61 0.01 0.01 6566.96 6663.35 r'• 3" 9fl 9D 0.00 0.00 0.00 0.00 100.00 100.00 11000.00 11100.00 11300.00 90.15 324.97 6866.09 6915.$8 3025.93 -6267.14 6006949.07 381908.45 0.01 6759.74 ~ 90 0.00 0.00 100.00 17200.00 11400.00 90.15 324.97 6865.83 6915.62 3107.82 -6324.54 6('R702'1..81 381852.29 0.01 6856.73 ~ 90 0.00 0.00 100.00 11300.00 11500.00 90.15 324.97 6865.57 6915.36 3189.70 -6381.94 6007105.54 381796.12 0.01 6952.52 ?' 46 0.00 0.00 100.00 11400.00 71600.00 90.15 324.97 6865.31 6915.10 3271.59 -6439.34 .6007188.28 381734.96 0.01 7048.91 ~ 96 0.00 0.00 100.00 17500.00 11700.00 90.15 324.97 6865.04 6914.$3 3353.47 -6496.74 6007271.0:? 381683.79 0.01 7145.31 4 90 0.00 0.00 100.00 11600.00 11800.00 90.15 324.97 6864.78 6414.57 3435.36 •6554.14 600735376 381627.63 0.01 7241.70 'k 40 0.00 0.00 100.00 11700.00 17900.00 12000.00 12700.00 90.15 90.15 90.15 324.97 324.97 324.97 6864.52 6864.26 6864.00 6914.31 6914.95 6973.79 3517.24 3599.13 3681.01 -6611.54 -6668.94 -6726.34 6007436.49 6007519.23 6007601.y7 381571.46 381575.30 381459.73 0.01 0.01 0.01 7338.09 7434.48 7530.87 k 90 90 90 0.00 0.00 0.00 0.00 0.00 0.00 100.00 100.00 100.00 11800.00 11900.00 12000.00 72200.00 90.15 324.97 6863.7;; 6913.52 3762.90 •6783.75 6:)0768470 387402.97 0.01 7627.26 r, 90 0.00 0.00 100.00 12100.00 12300.00 90.15 324.97 6863A7 6913.24 3844.78 -6841.15 6,)07767.44 387346.80 0.01 7723.65 9D 0.00 0.00 100.00 12200.00 12400.00 90.15 324.97 6863.21 6973.90 3926.67 -6898.55 6007850.18 381240.64 0.01 7820.04 r; 40 0.00 0.00 100.00 12300.00 12500.00 90.15 324.97 6862.95 6912.74 4008.55 -6955.95 6007932.92 381234.47 0.01 7916.43 99 0.00 0.00 100.00 12400.00 12600.00 90.15 324.97 686269 6972.48 4090.44 -7013.35 6008015.65 381178.31 0.01 8012.82 t' 9fl 0.00 9.00 100.00 12500.00 12700.00 90.15 324.97 6862.43 6472.22 4172.32 -7070.75 6008098.39 381122..14 0.01 8109.21 # 40 0.00 0.00 100.00 12600.00 12800.00 90.15 324.97 6862.16 6971.45 4254.20 •7128.15 6008181.13 381065.98 0.01 8205.60 %' SD 0.00 0.00 100.00 12700.00 72900.00 90.15 324.97 6861.90 6471.69 4336.09 -7185.55 6908263.87 381009.87 0.01 8301.99 ~%' 96 0.00 0.00 100.00 72800.00 13000.00 90.15 324.97 6861.64 6971.43 4417.97 -7242.95 6908346.60 380953.65 0.01 8398.38 90 0.00 0.00 100.00 12900.00 13100.00 90.15 324.97 6861.38 6411.17 4499.86 -7300.35 6(X?8429 34 389897.48 0.01 8494.77 90 0.00 0.00 100.00 13000.00 13200.00 90.15 324.97 6861.12 6410.41 4581.74 -7357.75 6008512.08 380841.32 0.01 8591.17 90 0.00 0.00 100.00 73100.00 13300.00 90.15 324.97 6f5G0.85 6919.64 4663.63 -7415.15 6008594.81 380785.15 0.01 8687.56 40 0.00 0.00 100.00 13200.00 13400.00 90.15 324.97 6860.59 6910.38 4745.51 -7472.55 6008677.55 380728.99 0.01 8783.95 40 0.00 0.00 100.00 73300.00 13500.00 90.15 324.97 6866.33 6910.72 4827.40 •7529.95 6008769.29 380672.82 0.01 8880.34 90 0.00 0.00 100.00 13400.00 13600.00 90.15 324.97 6860.07 6909.56 4909.28 -7587.35 6008843.03 386676.66 0.01 8976.73 9D 0.00 0.00 140.00 73500.00 73706.00 90.15 324.97 6859.91 6904.49 4991.17 -7644.75 690892:1.76 3$0560.49 0.01 9073.12 96 0.00 0.00 100.00 13600.00 13800.00 90.15 324.97 6859.55 6469.34 5073.05 •7702.15 6:)09008.50 389504.33 0.01 9169.51 4D 0.00 0.00 100.00 13700.00 13900.00 90.15 324.97 6859.28 6464.07 5154.94 -7759.55 6009091:)4 380448.16 0.01 9265.90 9D 0.00 0.00 100.00 13800.00 14000.00 90.15 324.97 6859.02 6448.87 5236.82 •7816.95 6009173.97 380392.00 0.01 9362.29 rt 9fl 0.00 0.00 100.00 13900.00 14100.00 90.15 324.97 685875 6408.55 5318.71 •7874.35 6009256.71 380335.83 0.01 9458.68 ~ 4fl 0.00 0.00 100.00 14000.00 14200.00 90.15 324.97 6858.50 6998.29 5400.59 -7931.75 6009339.45 386279.67 0.01 9555.07 N 99 0.00 0.00 100.00 14100.00 14300.00 90.15 324.97 5858.24 6998.03 5482.48 -7989.15 6009422.19 380223,50 0.01 9651.46 # 40 0.00 0.00 100.00 74200.00 14400.00 90.15 324.97 6857.97 5497.76 5564.36 -8046.55 6009504.92 380167.34 0.01 9747.85 .ri 9D 0.00 0.00 100.00 74300.00 14500.00 90.15 324.97 68:11.71 6997.50 5646.25 -8103.95 6009587.66 380111.18 0.01 9844.24 ~ 90 0.00 0.00 100.00 14400.00 14600.00 90.15 324.97 6857.45 6997.24 5728.13 -8161.35 6(109670.40 380055.01 0.01 9940.63 9fl 0.00 0.00 100.00 14500.00 Meas. Incl. TRUE Subsen RK6 Local ASP or Grid Dogleg Original Toai Build Turn Course Drilled ^' Depth (fT) Angle (deg) Azi. (deg) iVD {ft) TVD (ftl N{+)/S{-) Itt) E(+)/W(-) (fF) N{+)/S{-) Lat. (Y) E(+)/W(-) Dep. (X) Severity (°/100 ft) VS (310°) (tl) {31 (`a1 Pace (deg) )°/100 ft) (°/100 fO Length If1) Distance (h) Comments 14700.00 90.15 324.97 6857.19 6406.98 5810.02 -8218.75 6009753.13 379998.85 0.01 10037.02 90 0.00 0.00 100.00 14600.00 14800.00 14900.00 90.15 90.15 324.97 324.97 G85G °3 685567 6406.72 6406.46 5891.90 5973.79 -8276.15 •8333.55 by^09835.87 6009918.61 379942.68 379886.52 0.01 0.01 10133.42 10229.81 ;! r< 40 40 0.00 0.00 0.00 0.00 100.00 100.00 14700.00 74800.00 15000.00 90.15 324.97 6855.40 6406.14 6055.67 •8390.95 GOICf)01.3:i 374830.35 0.01 10326.20 ~~ 40 0.00 0.00 100.00 14900.00 15100.00 15200.00 15300.00 90.15 90.15 90.15 324.97 324.97 324.97 68:16.14 6855.88 6855.52 6405.93 4405.47 4905.41 6137.56 6219.44 6301.33 -8448.35 -8505.75 •8563.16 &010084.08 6016166.8?. 6010249.5E 374774.19 379718.02 379661.86 0.01 0.01 0.01 10422.59 10518.98 10615.37 ?` ?` ?` 90 90 40 0.00 0.00 0.00 0.00 0.00 0.00 100.00 100.00 100.00 15000.00 15100.00 15200.00 15400.00 15500.00 90.15 90.15 324.97 324.97 6855.36 6£755.09 4405.15 4904.88 6383.21 6465.10 -8620.56 -8677.96 0010332.29 6010415.03 374605.69 379549.53 0.01 0.01 10711.76 10808.15 ~ 40 90 0.00 0.00 0.00 0.00 100.00 100.00 15300.00 15400.00 15600.00 90.15 324.97 6854.83 6404.62 6546.98 -8735.36 6010497.77 379493.36 0.01 10904.54 90 0.00 0.00 100.00 15500.00 15700.00 15800.00 15900.00 90.15 90.15 90.15 324.97 324.97 324.97 6854.57 6854.37 6854.0,5 6404.36 6404.30 6903.84 6628.87 6710.75 6792.64 -8792.76 •8850.16 -8907.56 6010586.51 6010663.24 6010745.98 379437.20 379381.03 379324.87 0.01 0.01 0.01 11000.93 11097.32 11193.71 90 90 90 0.00 0.00 0.00 0.00 0.00 0.00 100.00 100.00 100.00 15600.00 15700.00 15800.00 16000.00 90.15 324.97 0853.79 6903.58 6874.52 -8964.96 fKlli78.'1.8.72 379268.70 0.01 11290.10 rr` 40 0.00 0.00 100.00 15900.00 16100.00 90.15 324.97 5853.52 690331 6956.41 •9022.36 6;110911 A5 379212.54 0.01 11386.49 # 90 0.00 0.00 100.00 16000.00 16200.00 90.15 324.97 6853.26 6903.05 7038.29 -9079.76 6010994.19 379156.37 0.01 11482.88 r# 40 0.00 0.00 100.00 16100.00 16300.00 90.15 324.97 6853.00 6402.74 7120.18 •9137.16 6011076.93 379100.21 0.01 11579.28 ~ 9fl 0.00 0.00 100.00 16200.00 16400.00 90.15 324.97 685274 6902.53 7202.06 •9194.56 6011159.67 379044A4 0.01 11675.67 # 40 0.00 0.00 100.00 16300.00 16500.00 90.15 324.97 6852.48 6402.27 7283.95 -9251.96 6011242.40 378987.88 0.01 11772.06 # 90 0.00 0.00 100.00 16400.00 16600.00 90.15 324.97 68:12.22 6402.07 7365.83 -9309.36 E011325.14 378931.71 0.01 11868.45 #4 40 0.00 0.00 100.00 16500.00 16700.00 90.15 324.97 6851.95 6401.74 7447.72 -9366.76 6011407.88 378875.55 0.01 11964.84 ?' 90 0.00 0.00 100.00 16600.00 16800.00 90.15 324.97 6851.54 6901.48 7529.60 -9424.16 6011440.62 378819.38 0.01 12061.23 90 0.00 0.00 100.00 16700.00 16900.00 90.15 324.97 68,`;1.43 4401.22 7611.48 •9481.56 6011,`,73.35 378763.22 0.01 12157.62 ?' 40 0.00 0.00 100.00 16800.00 17000.00 90.15 324.97 6851.17 4400.46 7693.37 -9538.96 GCilE5G.09 378707.05 0.01 12254.01 90 0.00 0.00 100.00 16900.00 17100.00 90.15 324.97 6850.91 6400.70 7775.25 -9596.36 6011738.83 378650.89 0.01 12350.40 90 0.00 0.00 100.00 17000.00 17200.00 90.15 324.97 b$5Q.64 6900.43 7857.14 -9653.76 6011821.56 378594.72 0.01 12446.79 40 0.00 0.00 100.00 17100.00 17300.00 90.15 324.97 6856.38 6400.17 7939.02 •9711.16 6011904.30 378538.56 0.01 12543.18 40 0.00 0.00 100.00 17200.00 17400.00 90.15 324.97 68:10.12 6849.41 8020.91 -9768.56 601198704 378482.40 0.01 12639.57 90 0.00 0.00 100.00 17300.00 17500.00 17515.05 90.15 90.15 324.97 324.97 6849.86 E849.fl2 6849.65 6899.61 8102.79 8115.12 -9825.96 -9834.60 b012UE9.78 6012052.23 378426.23 37841T.78 0.01 0.05 12735.96 12750.47 > ~; 40 40 0.00 0.00 0.00 0.00 100.00 15.05 17400.00 17415.05 3-1/T x 6-1 /8"- CD3-113wp03 T3 ~u..®. J • r -~- -. 1 ~,N. ;... ~_. K. ~F. _~ . :~ ~. .~.~. r-s' ~ ~~' ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad CD3-113 CD3-113 CD3-113wp04 :5iipe~r~y Ciri~linr„~ iervices Clearance Summary Anticollision Report 25 January, 2008 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad -CD3-113 -CD3-113 -CD3-113wp04 Well Coordinates: 6,003,567.62 N, 1,528,161.38E (70° 25' 08.61" N, 150° 54' 52.26" W) Datum Height: CD3-113: @ 49.79ft (CD3-113:) Scan Range: 9,341.65 to 17,515.05 ft. Measured Depth. Scan Radius is 1,947.84 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference c..~., r...,e• ~~ nn ! - r = ~l•~ ~~~ Sperry Drilling Services C ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for CD3-113 -CD3-113wp04 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad -CD3-113 -CD3-113 -CD3-113wp04 Scan Range: 9,341.65 to 17,515.05 ft. Measured Depth. Scan Radius is 1,947.84 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft CD1 AlpinePad CD3 Fiord Pad • CD3-113 -CD3-113 -CD3-113 9,374.00 0.00 9,374.00 -4.81 9,374.00 0.000 Clearance Factor FAIL -Major Risk Survey tool program From To Survey/Plan Survey Tool (ft) (ft) 81.00 803.00 CB-GYRO-SS 892.47 9,341.65 MWD+IFR-AK-CAZ-SC I~ 9,341.65 17,515.05 CD3-113wp04 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. • Distance Between centres is the straight line distance between wellbore centres. Clearance Factor =Distance Between Profiles / (Distance Between Profiles -Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 25 January, 2008 - 12:11 Page 2 of 4 COMPASS HALLIBURTON Anticollision Report for CD3-113 -CD3-113wp04 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to CD3-113: @ 49.79ft (CD3-113:). Northing and Easting are relative to CD3-113. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is -150.00°, Grid Convergence at Surface is: -0.86 °. Ladder D I r.• ~~.~i N r-- ~0- O c+'7 O .~ L Q 60- Q) a--+ C Q1 O ~~_ Q} 0 0 i i i i i i i i i i i i i i i i i i ~ i i i i i i i i i i i i i i i ~ i i ~ ~ i i i ~ i i i i i i i i i i i i i i i ~ i i i ~ i i i ~ i i i ~ i i i ~ i i i i i i i i i i i i i i i ~ i i i ~ i i i ~ i i i ~ i i i ~ i i i ~ i i ~ i i i i ~ i i i i i i i i i i i i i i i ~ i i t ~ i i i ~ i i i i i i i ~ i i i ~ i i i ~ i i i 1 I ~ ~ ~ 2000 4000 6000 $000 10000 Measured Depth X2000 ftlin) ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3-110, CD3-110,CD3-110wp06 V1 CD3-111, CD3-111 ,CD3-111 V7 CD3-111, CD3-111 ,CD3-111wp02 ~!2 GD3-111, CD3-111 L1, CD3-111L1 V1 CD3-112, CD3-112, CD3-112 V3 CD3-112, CD3-112, CD3-112wpD3 V3 CD3-113, CD3-113, CD3-113 VB CD3-114, CD3-114, CD3-114 V14 CD3-3D1,CD3.301,CD3.3D1 V4 CD3-3D1, CD3-301 ,CD3-3Dtw p04 U8 CD3.301, CD3-301P81,CD3-3D1PB1 V1 CD3.302, CD3-302, CD3-302 V3 CD3-302, CD3-302PB1,GD3-302PB1 V11 CD3-302, CD3-3D2PB1, CD3-302wp08 V2 C03-3D2, CD3-302PB2, CD3-302PB2 VB CD3-302, CD3-302PB3, CD3-3D2PB3 V2 CD3-3D7, CD3-107, CD3-107 V7 GD3-3D7, CD3-3D7.CD3-3D7 V4 CD3-307, CD3-3D7, Plan: CD3.1D7 (wp01) V4 CD3-307, Plan: CD3.107A, CD3-107Awp01 V1 Plan: CD3-106, Plan: CD3-108, Plan: CD3-106 (w Plan: CD3-115, Plan: CD3-115, CD3-115wp03 V4 Plan: CD3-117, Plan: CD3-117, CD3.117wp02 VB Plan: CD3-11$, Plan: CD3-11$, CD3-11$wp02 U$ Plan: CD3-303, Plan: CD3-303, GD3-3D3wpD6 V4 Plan: CD3-304, Plan: CD3.304, CD3-304wp07 V2 w \J ni__ rr.n nnw n,__ rnn ~nw nn~ nn~ nnwn n~... _ 25 January, 2008 - 12:11 Page 3 of 4 COMPASS HALLIBURTON ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for CD3-113 -CD3-113wp04 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor IG.00 8.' S .50 C 0 u-, cv '^-~ 5.~5 O w~y~ U JN' to c 5.00 o .~ g "~~ ~ 3.. 5 Y I~ 2aU I._5 G.GG -~- $' '~- '~ T ~F "~ ~F ~- -~- $' ~' 0 1400 000 3000 X000 5000 5000 ~G00 8000 9000 10000 11000 I^_000 M assured Depth (2000 ftlln) $ ~~ GD3-110, GD3-110, CD3-11D 1112 CD3-110, CD3-110, CD3-11Dwp06 Vt CD3-111, CD3.111 , CD3.111 V7 CD3-1 1 1 ,CD3-1 1 1, CD3.1 1 1 wp02 V3 CD3.1 1 1 ,CD3-1 1 1 L1 ,CD3-1 1 1 L1 Vt GD3-112, CD3.112, CD3.113 V3 • CD3-112, CD3-112, CD3-112wp03 113 CD3-113, CD3-113, CD3-113 1x16 CD3-114, CD3.114, CD3.114 1114 CD3-3D 1 ,GD3-3D1 ,CD3-301 V4 CD3-3D 1 ,CD3-301 ,CD3-301 wp04 1r8 GD3-3D1, CD3.3D1 PB1, CD3.3D1PB1 111 CD3-3D2, CD3-3D2, C03-302 V3 GD3-3D2, CD3-302PB1, CD3-302PB1 V11 CD3-3D2, CD3.3D2PB1, CD3-302wp0$ V2 CD3-3D2, CD3.303PB2, CD3-3D2PB21r16 GD3-3D2, CD3-302PB3, CD3-3D2PB31l2 CD3-3D7, CD3.107, CD3-iD7 V7 CD3-3D7, CD3-307, CD3-307 114 CD3-307, CD3-307 ,Plan :CD3-107 (wpD 1) V4 CD3-3D7, Plan: CD3-107A, CD3-1D7AwpD1 V1 • Plan: CD3-1D6, Plan: CD3-106, Plan: CD3-1D6 (wpD 1)` Plan: CD3-115, Plan: CD3-115, CD3-115wpD3 V4 Plan: CD3-117, Plan: CD3-117, CD3-117wpD2 VB Plan: CD3-11 $, Plan: CD3.118, CD3-118wp02 V$ Plan: CD3-303, Plan: CD3.303, CD3.303wp06 V4 Plan: CD3-3D4, Plan: CD3-3D4, CD3-304wp07 1f2 ai~„~rn~_~na aim., rn~-~ndapi rn~z_znaaa~~~,.,n7 25 January, 2008 - 12:11 Page 4 of 4 COMPASS ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 28, 2008 • ~~11~~! S ~~ p Alaska ~iM ~aa ~a~~, ~u: ~ ~ , ~-, Alaska Oil and Gas Conservation Commission AnCh®rage 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for change to Re-enter suspended well CD3-113 (permit no. 207-004) Dear Sir or Madam: ConocoPhillips Alaska, Inc. herby applies for a Sundry for Re-enter CD3-113. Last winter CD3-113 began on 1/24/07 with Doyon 19 (permit no. 207-004). This well was drilled to the Nechelik reservoir where 7" casing was set and cemented. The well was temporarily shutdown due to reservoir pressure in the formation and the well suspended at the intermediate casing point on 2/3/2007. The plan is to return to CD3-113 on 2/28/08, decomplete the kill string, and drill the horizontal interval. In the initial plan, the well had a lateral in the middle of the horizontal to gather more data for the geologist. Due to the advancement in technology, LWD tools will be used instead to gather this data. After the productive interval is drilled, the well CD3-113, will be completed as an horizontal open hole producer in the Nechelik reservoir. Please find attached the information required by 20 AAC 25.010 and 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-403 APPLICATION FOR Sundry approval 20 ACC 25.010 (a) 2. A proposed drilling program, including pre-rig work 3. Proposed completion diagram. 4. Proposed directional plan 5. A drilling fluids program summary. 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 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. If you have any questions or require further information, please contact Liz Galiunas, 265-6247, or Chip Alvord at 265-6120. Sincerely, Liz Galiunas ~ ®~ I V ~ 1 V /"1 Drilling Engineer • • Attachments cc: CD3-113 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1570 Nina Woods ATO 1706 Jack Walker ATO 1740 • • Page 1 of 2 Maunder, Thomas E (D4A) From: Maunder, Thomas E (DOA) Sent: Tuesday, February 12, 2008 4:45 PM To: 'Woods, Nina'; Doyon 19 Company Man Cc: Alvord, Chip; Chambers, Mark A; Galiunas, Elizabeth C Subject: RE: CD3-113 {207-004) Thanks Nina, Your plans look appropriate. Tom Maunder, PE AOGCC From: Woods, Nina [mailto;Nina.Woods@conocophillips.com] Sent: Tuesday, February 12, 2008 4:44 PM To: Maunder, Thomas E (DOA); Doyon 19 Company Man Cc: Alvord, Chip; Chambers, Mark A; Galiunas, Elizabeth C Subject: RE: CD3-113 (207-004) Tom - The casing test is planned for 30 minutes and wilt be recorded. If the casing does not test than we will proceed with a standard test of the BOPE to 3500 psi. Thanks, Nina (Woods) Anderson Drilling Engineer Alpine Drilling Team Office: (907)-265-6403 Cell: (907) 575-3256 From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] Sent: Tuesday, February 12, 2008 4:38 PM To: Woods, Nina; Doyon 19 Company Man Cc: Alvord, Chip; Chambers, Mark A; Galiunas, Elizabetfi C Subject: RE: CD3-113 (207-~4) Nina, et al, t confirm the conversation with Dave. Yes, it is acceptable to proceed as you plan. Is the casing test planned for 30 minutes as usual? If the casing should not test for some reason, how do you propose to proceed? Look forward to your reply. Tom Maunder, PE AOGCC From: Woods, Nina [mailto:Nina.Woods@conocophillips.com] Sent: Tuesday, February 12, 2008 4:32 PM To: Maunder, Thomas E (DOA); Doyon 19 Company Man Cc: Alvord, Chip; Chambers, Mark A; Galiunas, Elizabeth C Subject: 2/12/2008 Page 2 of 2 Tom - Below is an email in regards to the conversation you had with Doyon 19 Company Rep Dave Burley this rr>orning. We will be moving onto CD3-113 later this evening to decomplete the well and continue drilling operations. (Sundry 308-034). GD3-113 was temporarily shutdown with Intermediate 7" casing. The 7" casing was pressure tested to 3550 psi for 30 minutes following a successful cerrrertt job on 02102!2007. Floats were checked following the plug being bumped. The wellbore currency contains kill weight fluff. P review the planned procedure below and let us know if this is acceptable. Thanks. 1. Before moving on CD3-113, confirm that a BPV is installed. 2. Move on Doyon 19 3. Rig up over CD3-113, dewater cellar as required. 4. Pull BPV and install two way check. 5. ND Tree. NU B4PE. Body test BQP and flange break. 6. Pull two way check. 7. Circulate out inhibited brine and diesel with 9.0 ppg brine through circulation string, taking diesel returns to a tank. Pressure test rasing to 3500 psi. 8. Pull tubing hanger to floor and stated back freeze protect string. 9. Set test plug and test BOPS to 35~ psi.. Nina (Woods) Anderson Drilling Engineer Alpine Drilling Team Office: (907} 265-6403 Cell: (907) 575-3256 2/12/2008 Page 1 of 1 ~ ~ Maunder, Thomas E (D4A) From: Galiunas, Elizabeth C [Elizabeth.C.Galiunas@conocophiNips.com] Sent: Monday, February 11, 200$ 2:02 PM To: Maunder, Thomas E (DOA) Cc: Alvord, Chip; Noel, Brian; Wilson, Chris; Woods, Nina Subject: CD3-303 and CD3-113 Next wells issue Tam, With the multiple faults and fractures encountered on CD3-316A, the risk of drilling CD3-303 and encountering faults/fractures that communicate with CD3-316A is high. The asset would like to reassess the CD3-303 targets and possibly re-permit the well as a high angle slant well. The option to fill part of the time to get CD3-303 planned would be to move the rig back on CD3-113 to pull the kill string and drill the horizontal. A sundry to re-enter this weN was submitted on Jan 28 and it was discovered that a sundry was not submitted to do a temporary shutdown in 2007. The 2008 sundry to re-enter the well has not been returned and we would tike to know what is necessary to return and drill the horizontal on CD3-113. We would like to see if returning to CD3- 113 is even possible with this short of notice. If necessary, we will put the rig on standby. The rig is finishing up operations on CD3-316A and would be ready to move tomorrow. Please provide any guidance as to our next step. Call if you have any questions. Thanks, L.iz Galiunas Drilling Pngineer Alpine Drilling Team ConocoPhillips Alaska ATO--1704 Office: (907)x265--6247 Cell: (907)441--4871 ~ThE~~SJ~ o~ ~ s~ n~ ~~ ~CCcJ ~ ` i ~ ~C~ ~~ ~~ C ~ ~ ~C-~f~ ~ AQQ~av~, ~ ~ ~~:~ s~~~~Li ~~ 1`cc_c~aa~~~ ~ ~~ , 9~~ 2111 /2008 • Page 1 of 1 Regg, James B (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, February 01, 2008 2:37 PM To: Regg, James B (DOA) Subject: CPAI "Issue" Jim, Here are the details of the sundry issue I just mentioned. c~~-i~3 ~#~-9~(207-004) was spudded 1/24/07. The possibility of low reservoir pressure in the Nechelik was anticipated and it was stated in the PTD that if such was the case, operations would be SD to all the reservoir to repressure. Operations were halted on the well 2/3/07 after setting 7" casing at 9364' md. In the attachments to 401, I made the note that a 403 would be required if that was the course of events. I did not include any specific instruction on the 401 form or in the letter to submit a 403. We have just received a 403 to resume operations on the well. I have checked my message file as well as the well file folder and do not find that I received any messages from CPAI on the OSD. I will bring you the file. Tom 2~ ~4A-C- 2-S _ G7 2. 2/4/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF AririuLAR ^viSPvSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 207-Q04 ConocoPhillips Alaska, Inc. Development 0 Exploratory ^ 7. Well Name: CD3-113 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ SUSPEND ~ 50-103-20541-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^~ or Final ^ 307-067 3/20/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous totals (bbls): 2007 / 1st 0 0 349* 349 0 2007 / 2nd 0 0 5* 5 0 2007 / 3rd 0 0 0 0 0 2007 / 4th 0 0 0 0 0 Total Ending * Report is due on the 20th volume 0 0 354 354 0 of the month following the final month of the quarter. Ex: (bbis): Apri120 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): freeze rotect volumes is true and correct to the best of my knowledge. I hereby certify that the foregoing , ` l ~l ~oZ ~ - Date: Signature: \ Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ~ ~ WELL LOG TRANSMITTAL To: State of Alaska May 4, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-113 AK-MW-4878587 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20541-00 ~ m ~-~. ~' ~'~ ~ ~~~~ '~ • • i = SARAH PALIN, GOVERNOR ~~TT~~++~1 ~-y~1~~~ ® ~r~+~~T 1`1711I~~~gi®id ~®~~-7s7~®id Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-113 Sundry Number: 307-067 Dear Mr. Alvord: 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. 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 far 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 March, 200' Encl. Sincerely, ~~ D ,~~.. <~;~ C;~ e C? ~ cf '° ~°~/ STATE OF ALASKA ~~ ~~~ RECEIVED FEB 1 6 2007 ALASKA OIL AND GAS CONSERVATION COMMI~~~l~il & Gas Cons. Commission ANNULAR DISPOSAL APPLICATION Anchorage 20 AAC 25.080 1. Operator 3. Permit to Drill Name: Number: 207-004 ConocoPhillips Alaska 4. API Number: 50-103-20541-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD3-113 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: CD3-110, CD3-111, CD3-112 Torok and Seabee formation, shale, siltstone and sandstone b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1607' MD / 1 600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 2317 PSI 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. / / / Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- diesel, formation fluids associated with the completior~fluids contaminated drilling mud 16. Estimated start date: , , act of drilling a v'~iell, drill rig wash fluid, domestic waste water, any added~water 28-Feb-07 needed to facilitate pumping of drilling mud or drilling cuttings, new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations and ~~¢~ SJ ~ ~ova:~ 17. Attachments: t c~, v.~~~~~ ~~ tt t~e~ke~Hlc~.> ©ro,~Q\~ce,,~zo ~ c~ v,xss~es c.~ssc~~r,~ ~ p ~ o~c c~ri\~:.,`` C+~w~\\o fem. ~ va.~e c c~ecosrds w7L~T Graph L~~/ etl Well Schematic (Include MD and TVD) Cement Boni Log (if requ~Y ) Surf. Casing Cementing Data ~ Other ~ Q~ Z 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: Title: ~ `.//~Y ~~ ~.~' Printed Phone Name: ChipAlvord Number: 265-6120 Date: L((4. O Commission Use Only Conditions of approval: ~~\~C~,v~t~ W I ~ ~, ~~ LOT review and approval: ~ ~ -O uired: { O °~"~ d- ~ uent form re Subse proval number: ~®~'~ D lQ A q q p APPROVED BY THE COMMISSION D 3 ~D~ Approved by: ate: .~0 MMISSIONER Form 10-403RD Rev. 6/2004 1 ~ ~ 1-~ ~ ~ n ~STRUCTIONS ON REVE ~~ ~A~ ~5ubmitT~9r'uPecat~ V {{{ ~~i 11 llJJ /1 ~ `~ 2~~~ ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 ConocoPhillips ~~~G~ y ~1.J February 13, 2007 Alaska Oil and Gas Conservation Commission 333 West 7t'' Avenue, Suite 100 Anchorage, Alaska 99501-3539 ~E~ ~ 6 Z0~7 ,A~sska Oa ~ Gas Cnns. Commi~~~a~ Anct~~raq~ Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD3-113 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD3-113 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD3-113 approximately February 28, 2007. CD3-113 currently has 7" casing landed in the Nechelik formation. The horizontal production hole has not been drilled, however this should not have an effect on annular disposal operations. Please find attached form 10-403RD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD3 pad and the lateral distance from the surface casing shoe. 11. Additional information regarding wells within % mile radius at AOGCC: No new wells 12. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations. The initial annular LOT (16.3 ppg) occurred at a lower equivalent mud weight than the casing shoe test (18.0 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. If you have any questions or require further information, please contact Vern Johnson at 265-6081; Chip Alvord can also be reached by calling 265-6120. Sin y, z/~y/~- c.:_- ~-- Vern Johnson Drilling Engineer cc: CD3-113 Well File Chip Alvord ATO-1700 Anadarko Sharon Allsup-Drake ATO-1530 i Annulus Disposal Transmittal Form -Well CD3-113 A(1(1f'('' Rartnl~4innc ~n e e~ ~s nQn (hl 1 v Desi ation of the well or wells to receive drillin wastes: CD3-113 2 The depth to the base of freshwater aquifers and permafrost, i There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost = 1600' TVD RKB 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/1. (Ref. AOGCC Conservation Order No. 443, 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drillin waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipement after producing drilling/completion fluid (see included note from CD1&2 authorization}. 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2317 psi.. See attached calculation calculations showin how this value was determined. a e. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT /FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand antici ated ressure of dis osal o erations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casin shoe. 11 Identification of the hydrocarbon zones, if any above the N/A de th to which the inner casin is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD3-107, CD3-302, CD3-113, CD3-301, CD3-115, CD3-114 will be enerated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why coin liance would be im rudent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. s ~ Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Version 1.0-Jan'OS Well CD 3- 113 Assumptions Date 2/12 /2 007 Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.457 psi/ft Header Pressure (for wells on gas lift) 0 psi Maximum Fluid Density to avoid Burst of Surface Casing U Pburst85% -PHydrostatic +PApplied - PFormation 4,888 = ( 2,475 * 0.052 *MWmax ) + 1500 - ( 0.4337 * 2,475 ) N Qom.' MWmax = 34.7 PPg 2,475 TVD - Surface CaSing String Size 9.625 in ~ ~ Weight 40 ppf a d Grade L 80 pA "° "o Y 5,750 psi burst100 /o C '~ Pburst85% 4 $$$ psi U Depth of Shoe 2,475 ft FIT/LOT @ Shoe 18 ppg or 2,317 psi FIT/LOT for Annulus 16.3 ppg o°o Max Surf. Pressure 1,500 psi r TOC Est. @ 4,286' MD 3,675' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% -PHydrostatic +PApplied - PGasGradient - PHeader 4,599 = ( 3,675 * 0.052 ~` M W max ) + 1,500 - (0.4570 * 3,675) - 0 MWmax = 25 PPg 3.5 "Tubing PLANN D 2nd Casing String Size 7 in 6,905 TVD Weight 26 ppf Grade L 80 Ycollapse100% 5,410 psi Pcoltapse85% 4,599 psi Top of Cement 3,675 ft Gas Gradient 0.457 psi/ft Max Surf. Pressure 1,500 psi Header Press 0 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable =Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable - ( 2,475 * .052 * 18 ) Pmax allowable - 2,317 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". ConocoPhilli $ Casing Detail 9 5/8"Surface Casing Well: CD3-113 Date: 1 /26/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.30 FMC Gen V Hanger 2.22 36.30 Jts 3 to 67 65 Jts 9-5/8" 40# L-80 BTC Csg 2501.86 38.52 HOWCO Float Collar 1.16 2540.38 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 75.49 2541.54 Ray Oil Tools "Silver Bullet" Float Shoe 2.26 2617.03 2619.29 TD 12 1/4" Surface Hole 2629.29 TOTAL BOWSPRING CENTRALIZERS -40 1 per jt on Jt # 1 - # 13 (stop ring on Jt # 1 & 3 ) and over collars on jts# 15, 17, 19, 21, 23, 25, 27, 29, 31, 33, 35, 37, 39, 41, 43, 45, 47, 49, 51, 53, 55, 57, 59, 61, 63 65, 66. 73 joints in the pipe shed. Run 67 joints - 6 joints stay out Casing shoe 2619.29' MD/ 2482' ND Hole TD 2630' MD 2484' TVD Use Best-o-Life 2000 pipe dope MU torgue ~ 8600 ft/Ibs Remarks: Up Wt - 170 k Dn Wt - 130k Block Wt - 75k Supervisor: Hill/Woods r ~. ~ Cement Detail Report CD3-113 M Surface Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10161473 1/24/2007 1/24/2007 Cement Details _ _ Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 1/27/2007 00:00 1/27/2007 02:45 CD3-113 Comment Cement 9 5/8" csg as follows :Rig Pumped 40 bbls Biozan water w/ nut plug as marker -Pumped 5 bbls water w/ Dowell -Tested lines to 2500 psi -Pumped - Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 356 bbls lead slurry (ASL) @ 10.7 ppg (` Observed nut plug marker @ shakers w/ 342 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/ 173 bbls 9.7 ppg water base mud -Displaced @ 7.0 bbls/min for first 170 bbls -slowed to 4 bbls/min for last 2.9 bbls -Bumped plug w/ 1100 psi (pre bump pressure 590 psi) Check float (held OK) CIP @ 01:54 hrs. -Full circulation throughout job w/ 145 bbls 10.7 ppg cmt returns to surface -reciprocated pipe while circulating & throughout cement job. Cement Sta es Stage # 1 ___ Description Objective Top (ftKB) Bottom (ftKB) Full Retum? Cmnt Rtrn (... Top Piug? Btm Plug? Surface Casing Cement 36.3 2,619.0 Yes 145.0 Yes Yes Q (start) (bbl/min) Q (end) (bbl/min) O (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 8 5 6 590.0 1,100.0 Yes 20.00 No Depth tagged (ftK6) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives ___ _ --- - _ ____ Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 36.3 2,136.0 450 G 356.0 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 Ffuid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Glass Volume Pumped (bbl) Tail Cement 2,136.0 2,619.0 236 G 48.0 Yield (ft'Isack) 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 1/1 Report Printed: 2/14/2007 l~ ~~ Security Level: Development Daily Drilling Report CD3-113 ° Report Number: 4 _• ~ .., Rig: DOYON 19 Report Date: 1/27/2007 Wellbore Wetl Type Field Name Spud Date DFS (days) Depth Start (ftK6) Depth End (ftK6) Depth Progress (ft) CD3-113 Development FIORD NECHELIK 1/24/2007 3.27 2,630.0 2,650.0 20.00 AFE / RFE / Maint.# Daily Mud Cost Cummulative Mud Cost Daily Cost Total Cummulative Cost Total AFE Amount 10161473 4,855.85 44,377.17 256,120.69 1,227,293.44 8,135,000.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Surface, 2,619.3ftKB Ops and Depth @ Morning Report 24hr Forecast Drilling 8-3/4" @ 3200' Drill 8-3/4" hole Last 24hr Summary Cement 9-5/8" Csg - ND Riser - NU BOP -Test BOPE - PU BHA #2 -Wash down to shoe -Drill out shoe track & 20' new hole t/2650' MD. General Remarks Weather Head Count -4/NE@14 mph 47.0 .S. ••:ISJf ~ TIfIE? Don Mickey __- Rig Supervisor Nina Woods Rig Supervisor Time Loa Start Time End lime Lor nrs; Fh:s~= Op Code OpSub-Co__ Tir,,e ~I P-~J-T ~ 7rhl ,..,_ lm ~_;iass. i D nth 5~~7 ~ nKP.~ D aCi End ':r::B) - -- ~~,,.n-~~: -~-.~,rn~ 00:00 02:00 2.00 SURFAC CEMENT DISP _ P 2,619.0 0.0 Cement 9 5/8" csg as follows :Rig Pumped 40 bbls Biozan water w/ nut plug as marker -Pumped 5 bbls water w/ Dowell -Tested lines to 2500 psi -Pumped - Dropped btm plug - Pumped 50 bbls MudPush @ 10.5 ppg -Mixed & pumped 356 bbls lead slurry (ASL) @ 10.7 ppg (" Observed nut plug marker @ shakers w/ 342 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/ 173 bbls 9.7 ppg water base mud -Displaced @ 7.0 bbls/min for first 170 bbls -slowed to 4 bbls/min for last 2.9 bbls -Bumped plug w/ 1100 psi (pre bump pressure 590 psi) Check float (held OK) CIP @ 01:54 hrs. -Full circulation throughout job w/ 145 bbls 10.7 ppg cmt returns to surface -reciprocated pipe while circulating & through cement job. 02:00 02:45 0.75 SURFAC CASING DHEO P 0.0 0.0 RU and test 9 518" casing to 2,500 psi for 30 Min. 02:45 05:30 2.75 SURFAC CASING RURD P 0.0 0.0 Rigged down Cement head and casing running tools. Released riser connection. 05:30 07:00 1.50 SURFAC CASING NUND P 0.0 0.0 Nippled down riser. 07:00 09:00 2.00 SURFAC WELCTL NUND P 0.0 0.0 Nippled up BOP. 09:00 09:30 0.50 SURFAC DRILL RURD P 0.0 0.0 Changed out Top Drive sub. 09:30 14:30 5.00 SURFAC WELCTL BOPE P 0.0 0.0 Set test plug. Test BOPE Annular 250 / 3500 psi. Lwr & Blind rams, upper rams with 4" & 5". Tested HCR & Man choke, kill choke, Valves 1-16, Auto and manual IBOP, dart & TIW to 250 / 5000 psi. Pulled test plug. 14:30 15:30 1.00 SURFAC WELCTL P 0.0 0.0 Install wear ring -Blow down choke & kill -Install Bails and elevators. 15:30 18:30 3.00 SURFAC DRILL RURD P 0.0 262.0 PU BHA #2 -Test GeoSpan to 3500 psi -Shallow test MWD tools @ 262' - PU Jars. 18:30 20:00 1.50 SURFAC DRILL TRIP P 262.0 2,437.0 RIH to 2437' with HWDP - WF Ghost Reamers - 5" DP - XO to 4" DP. 20:00 20:30 0.50 SURFAC DRILL DDRL P 2,437.0 2,536.0 Wash down to 2536' and tag Float Collar/Plugs @ 550 GPM - 90 RPM - 1700 psi. 20:30 23:00 2.50 SURFAC DRILL DDRL P 2,536.0 2,630.0 Drilled shoetrack from 2536' to 2620'. Cleaned out rathole to 2630'. FC took 40min, FS took 25 min. Rubber along side BHA. Latest BOP Test Data - - ___ ~ ate ~ m..F ~. 1/27!2007 Tested BOPE to 250 & 5000 si Tested H dril to 250 & 3500 si Page 1/3 Report Printed: 2/14/2007 ~~ 'I ~ ~~ Security Level: Development Daily Drilling Report CD3-113 .: Report Number: 4 Rig: DOYON 19 Report Date: 1/27/2007 Time Log _ --- _ - Start End D i~ Tir, e Dep I Start D ~n„ Frey Tirr I T!o ~rs1 Pr 3~c ~ ~)[ .x _~ OpSUb vv ~'-N ~ Zs be Gu~e ~ 7a~i ~, ~i s (Y. :.,~ ~ ,;;E, ~ rn Ups a ~i, 23:00 23:15 0.25 SURFAC DRILL DDRL P 2,630.0 2,650.0 Drill 20' new hole f/ 2540' V 2560' MD 2496' TVD ADT - 0.15 hrs WOB 3/10 90 RPM 584 GPM @ 1900 psi Up Wt - 135, Dwn Wt - 125, Rot Wt 130 psi. On /Off Trq - 7500 / 7000 ft"Ibs 23:15 00:00 0.75 SURFAC DRILL CIRC P 2,650.0 2,650.0 Circulate and condition mud for FIT @ 584 GPM - 90 RPM - 1860 psi. Mud Check Data YF' Celr_ G~ ~ us; ,~ , 1Ji~i ~r :~Oa~l HTNP Filt Uee~it, T_~n~i, $gli~ls Cnrr TYpc Cecth 1ftK8) Den< ~L gall i V i '_. I•; '., ~'V Calc (ep) Il~t.'~~-t=; Qbfr100ft'~~ t J'ifl=1 Itq~:;;- , MHl I~ •~~I1 (mlJ30min) pli ~. ; Y ~. ~_ -- - SPUD ~ 2,630.0 9.45 6.8 ~ 10.8 22.000 55.000 85.000 ~ 55~ 18A 11.000 In'ectian Fluid ~ - Fluid '~ 5~..:,e Frcm Lease (bbl) D.,.L a .~ Diesel 40.0 CD3-112 FP Other 678.0 CD3-112 Cmt & mud f/ CD3-113 Water 290.0 CD3-112 Ffush Water Based Mud 1848.0 CD3-112 f/ CD3-113 Drill Strin s: BHA No. 2 - Geo Pilot / Bit Run No. 2 - 8 3/4in, Halliburton Security DBS , FSF2453 , 10761829 _ Depth Yn (ftKB) Depth Out (ftKB) TFA (incl Noz) (ins) Nozzles (/32") IADC Bit Dull String Wt (10001bf) WOB (max) (100... WOB jmin) (1000... 2,630.0 9,374.0 3-3-CT-N-X-I-LT-TD 70 0 0 Drill Stnn Com onents P _ _ _ Jts h.~=m Description OG ~in1 ID nn', Too Conn Sz (in) Te~p thread ~ ~:um Len (ft) ~ 1 7600 Geo Pilot 24.78 6 3/4 1.500 4 1/2 NC 50 1 Non-Mag GP DM Flex 6 3/4 1.920 4 1/2 NC 50 33.98 1 Stabilizer (Non Mag) ILS 6 3/4 1.920 4 1/2 NC 50 36.17 1 MWD (Logging) 6.71 1.920 4 1/2 NC 50 57.14 1 Stabilizer (Non Mag) 6 3/4 1.920 4 1/2 NC 50 59.34 1 MWD (Logging) H-Cim 6.78 1.920 4 1/2 NC 50 66.10 1 MWD (Dir & Logging) T-M 6.77 1.920 4 1/2 NC 50 76.15 1 Float Sub NM 6.6 2.813 4 1/2 NC 50 78.64 3 NMDC 6.64 2.813 4 1/2 NC 50 171.53 3 HWDP 5 3.000 4 1/2 NC 50 261.62 1 Drilling Jars -Mechanical 6 1/4 2.250 4 1/2 NC 50 294.32 14 HWDP 5 3.000 4 1/2 NC 50 713.13 1 Drill Pipe 5 4.276 4 1/2 NC 50 744.85 1 Ghost Reamers 6.54 2.875 4 1/2 NC 50 751.80 33 Drill Pipe 5 4.276 4 1!2 NC 50 1,798.29 1 Ghost Reamer 6.54 2.875 4 1/2 NC 50 1,804.35 2 Drill Pipe 5 4.276 4 1/2 NC 50 1,867.93 1 Cross Over 6.62 2.563 3 1/2 XT-39 1,870.89 Drillin Parameters _ r li _ urn ~ Fr s ~ ~ 4`, F` un Dnll 0 fl ~w ~, ~ H ~ ~~~~P II.1 ~ti~ Nip HI ~'~.~tt rice n~) Orr etm T. [,~~,u 7q I ~NN n r Ic~ Time [~ - - - ~ ~ ~ 630.0 ~ 6 ~0 0 0.15 ~ _ 135' 135, 6.000 0 6.500.0 ~a4 10 0 - 90-- 140~ 20.00 -- - Wellbofes Wellbore Name Wellbore API/UWI CD 3-113 501032054100 - - Act Top {ftKB) Act Btm (IfKB) - to D='t` - _ _ Er~J Ga-e - --- - ~ - PROD1 6 1/8 PROD2 6 1 /8 COND 1 16 36.0 114.0 1 /24/2007 1 /24/2007 SURFAC 12 1!4 114.0 2,620.0 1 /24/2007 1 /26/2007 INTRM1 8 3/4 2,630.0 9,374.0 1/27/2007 1/30/2007 Cement Surface Casin Cement -Started 1/27/2007 Type Wellbore String Cement Evaluation Results casing CD3-113 Surface, 2,619.3ftKB 145 BBLS to Surface Page 2/3 Report Printed: 2114/2007 Security Level: Development Daily Drilling Report CD3-113 . ,~ . Report Number: 4 Rig: DOYON 19 Report Date: 1/27/2007 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Surface Casing Cement 36.3 2,619.0 5 590.0 ____ I w~a" Class - Amount (sa ~s1 I d Lt~--'. `. Densiy ; u..lgal) l field (ft lsacki Fs. fap~{fl KH', Est BYm (ftKB) -~ Lead Cement G 450 356.0 10.70 4.45 36.3 2,136.0 Tail Cement G 236 48.0 15.80 1.17 2,136.0 2,619.0 Page 3/3 Report Printed: 2/14/2007 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-113 Rig: Doyon 19 Date: Drilling Supervisor: L. Hill / N. Woods Pump used: #z Mud Pump ~ ' ' Volume Input Volume/Stroke Pump Rate: Strokes ~ 0.1000 13b1s/Strk', ~ 8.0 strk/min ~ Type of Test: openhoieTest LOT/Frr ~ ~ annulus and ~P. Pumping down ~ Casin Test Pressure In te rit Test Hole Size: 8-3/4" ~ ~ Casin Shoe Depth Hole Depth Pum pin Shut-in Pumpin Shut-in RKB-CHF: 36.6 Ft 2,620 Ft-MD 2,475 Ft-TVD 2,650 Ft-MD 2,497 Ft-TVD Strks psi Min psi Strks psi Min psi Casinq Size and Description: 19-5/8" 4o#/Ft L-8o grc ~ 0 0 0 2500 1 0 0 1100 Casinq Test Pressure Int e rit Test 2 125 1 2500 2 40 0.25 980 Mud Weight: 9.7 ppg Mud Weight: 9.5 ppg 4 300 2 2500 3 60 0.5 860 Mud 10 min Gel: 10.0 Lb/100 Ft2 Mud 10 min Gel: 55.0 Lb/100 Ft2 6 550 3 2500 4 110 1 780 Test Pressure: 2,500 psi Rotating Weight: 135,000 Lbs 8 800 4 2500 5 200 1.5 1~1 Rotating Weight: 75,000 Lbs Blocks/Top Drive Weight: 75,000 Lbs 10 1000 5 2500 6 320 2 72 Blocks/Top Drive Weight: 75,000 Lbs Desired PIT EMW: 18.0 ppg 12 1150 6 2500 7 420 2.5 700 Estimates for Test: 1.9 bbls Estimates for Test: 1094 psi 0.7 bbls 14 1350 7 2500 8 500 3 700 ~I ~ 16 1525 8 2500 9 580 3.5 690 EMW =Leak-off Press ure + Mud W eight = 1 100 PIT 15 Second 18 1750 9 2500 10 `` 650 4 690 0.052 x T VD 0.052 + x 2475 9.5 Shut-in Pressure, ps i 20 1950 10 2500 11 `-` 710 4.5 690 EMW at 2620 F t-MD (247 5 Ft-ND) = 18.0 p pg 980 22 2200 15 2500 12 -'~' 760 5 680 - 0 - - held Lost 0 psi during test 24 2400 20 2500 13 .,_ 810 5 5 680 300 - , . 100% of test pressure. 25 2500 25 2500 14 ' ` 860 6 680 - ` - 30 2500 15 `~ ' 910 6.5 670 _ - - 60 -' 7 660 z5oo _ 16 > 9 _ °` 660 -- 17 ~ --1000 7.5 - - 18 1040 8 660 - - - zooo - _ 19 ' ~ 1080 8.5 660 ~ -- - -- _ 20 '- 1100 9 660 ~ - - - - - 5 9 66 . N i5oo - ---- 10 6 w - - ~ - - - - a - - - - ~ - -- - iooo _ - _ - _ 1 500 - - - o 2 5 0 5 10 15 20 25 3 0 0.0 0 ~~ .5 1. 0 1 Barrels .5 2 OFF BLEAK .0 TEST . Shut-In time, Minutes O PIT Point Volume PUm ed Volume Bled Back Vol PU ume m ed Vol Bled ume Back CASI NG TEST - s s s s Comments: Casing tested after bumping plugs on cement job. ,~ ~Cor~©c Philli s p Casing Detail 7" Casing Well: CD3-113 Date: 1 /30/2007 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS. Doyon 19 RKB to Lower lock down 34.05 FMC Gen V Hanger 2.21 34.05 Jts 97 to 219 123 Jts 7 " 26# L-80 BTCM Csg 5249.16 36.26 TAM Port Collar 2.93 5285.42 Jts 3 to 96 94 Jts 7" 26# L-80 BTCM Csg 3989.14 5288.35 Halliburton Float Collar 1.05 9277.49 Jts 1 to 2 2 Jts 7 " 26# L-80 BTCM Csg 83.76 9278.54 ROT Float Shoe 2.03 9362.30 7" Shoe @ 9364.33 8 3/4" Hole TD 9374.33 8 3/4" Hole TD @ 9,374' MD / 6,911 ' ND 7" Shoe @ 9,364.33 ' MD / 6,910' ND Total Centralizers: 60 Centralizer one per jt on jts # 1-14 Centralizer on jts # 90 - 103 (Above/Below TAM Port Collar) Centralizers jts # 157-159 (Above/Below 9-5/8" shoe) Centralizer one per jt on every other joint from # 161 - 217 Top Nechelik - 9318' MD - 6905' ND ' K2/Qannik Top 4786' MD/4057 ND, Base 4807' MD/4162 ND 227 joints in shed - 219 total jts. to run Last 8 jts. out Use Run 8~ Seal i e do e Average MU torque 6500 ft/Ibs Remarks: ' U p Wt -275 k DnWt-150k Block Wt - 75k Supervisor.• D. Mickey / N. Woods i ~~ ConocaPhilli s p CASING TALLY PAGE: 1 of 2 WELL NUMBER: CD3-113 RIG: Doyon 19 TUBING DESCRIPTION: 7", 26# L-80 BTCM DATE: 01104/07 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 40.75 26 43.75 51 41.83 76 43.03 43.49 126 40.31 151 43.45 176 42.46 43.01 27 43.34 52 43.29 77 42.82 41.88 127 43.42 152 41.75 43.37 40.55 28 42.07 53 43.08 78 43.42 41.66 128 43.39 153 41.86 178 42.60 35.57 29 42.36 54 43.12 79 43.52 104 42.94 129 43.54 154 43.27 43.49 43.19 30 42.24 55 43.24 80 38.49 105 42.87 130 41.47 155 43.45 180 42.74 43.40 31 39.04 56 42.50 81 43.14 106 43.14 131 43.43 156 43.50 43.24 43.48 32 43.38 57 43.50 82 41.23 107 43.61 132 42.38 39.71 182 42.37 43.47 33 42.07 58 43.52 83 43.55 108 43.33 133 42.29 43.44 43.44 41.99 34 43.50 59 43.49 84 41.08 109 43.28 134 43.14 42.84 184 43.08 43.47 35 43.20 60 38.23 85 43.43 110 43.10 135 43.44 160 43.28 41.51 43.41 36 43.52 61 39.27 86 43.44 111 43.50 136 43.31 43.34 186 43.41 39.55 37 43.54 62 42.12 87 43.12 112 43.45 137 43.45 162 43.50 42.56 43.27 38 43.37 63 43.46 88 43.79 113 43.05 138 43.85 43.58 188 43.63 43.42 39 42.72 64 43.54 89 43.88 114 39.22 139 41.82 164 43.36 43.50 15 42.94 40 42.07 65 43.64 43.41 115 43.37 140 43.52 43.48 190 43.77 16 43.32 41 43.52 66 40.75 43.46 116 43.22 141 43.51 166 40.72 43.59 17 38.49 42 41.80 67 39.06 43.52 117 42.84 142 42.35 42.89 192 41.92 18 41.24 43 43.43 68 43.53 42.99 118 42.80 143 41.82 168 43.52 42.37 19 41.80 44 43.62 69 43.43 43.51 119 43.62 144 43.49 43.49 194 41.15 20 43.42 45 43.50 70 41.29 43.40 120 43.51 145 43.35 170 43.44 43.42 21 43.11 46 42.92 71 38.06 43.39 121 43.52 146 41.11 42.93 196 42.95 22 43.08 47 37.74 72 42.72 42.72 122 43.46 147 38.72 172 43.17 43.23 23 43.47 48 42.77 73 41.29 43.44 123 43.51 148 43.22 43.41 198 43.43 24 42.02 49 41.91 74 43.48 43.15 124 43.41 149 43.37 174 43.00 39.78 25 43.41 50 40.23 75 43.40 43.44 125 43.45 150 43.67 43.54 200 43.57 Tot 1054.83 Tot 1061.61 Tot 1054.84 To t 1074.37 Tot 1075.23 Tot 1067.37 Tot 1073.92 Tot 1070.58 TOTAL LENGTH THIS PAGE = 8532.75 DIRECTIONS: TOTAL JOINTS THIS PAGE = 200 FLOAT SHOE 2.1 FLOAT COLLAR 1 HANGER 2.6 RKB 34 i r ~ Cement Detail Report CD3-113 Production Casing Cement Primary Job Type Job Category AFE I RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10161473 1/24/2007 1/24/2007 - - - 'Cement Deta+ls Description Cementing Start Date Cementing End Date Welibore Name Production Casing Cement 2/1/2007 14:00 2/1/2007 15:45 CD3-113 Comment Cement 7" casing as follows: Pumped 5 bbls CW-100 -Pressure test lines to 3700 psi -Pumped remaining 15 bbls CW-100 -Mix & pumped 40 bbls - 10.5 ppg MudPush -Dropped btm plug -Mixed & pumped 40 bbls 15.8 ppg tail slurry (Class G w/ additives) -Dropped top plug w/ 20 bbls fresh water f/ Dowell - Switched to rig pumps & displaced cmt w/ 133 bbls 9.6 ppg inhibited brine followed by 199.6 bbls 9.6 ppg brine -Displaced @ 6 bbls/min - 250 to 580 psi for first 310 bbls -slowed pumps to 3.5 bbls/min - 360 to 580 psi for last 22.6 bbls of displacement -Bumped plug w/ 1000 psi -Checked floats OK - CIP @ 15:45 hrs.- Full returns & pipe movement throughout job. _ __ - - - - --- _ -- -_ - - ( ~ ISta e # 1 -- --- ' ~ , ( - Top Pluy? Btm Pluy? Descri tion Ob ective To ftKB Bottom ftKB) Full Retum. Cmnt Rtrn ... P 1 p Production Casing 8,380.0 9,364.0 Yes Yes Yes Cement 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) 6 4 6 580.0 1,000.0 Yes 20.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment - - -- ',.Cement Fluids & Additives -- - - -- --- Fluid _ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 8,380.0 9,364.0 195 G 40.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.09 15.80 Additives Additive Type Concentration Conc Unit label Sta a#2 Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Piug? Btm Plug? Production Casing Zone Isolation 4,286.0 5,285.0 Yes Yes No Cement O (start) (bbl/min) O (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 4 4 1,165.0 3,670.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pumped job through TAM port collar @ 5285' -- -_ - Cement Fluids & Additives _- - Fluid _ Fluid Type Fiuid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbq Production Cement 4,286.0 5,285.0 180 G 37.0 Yield (ft'/sack) Mix H2O Ratio (gallsa... 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 1/1 Report Printed: 2/14/2007 - Security Level: Development Daily Drilling Report CD3-113 Report Number: 9 Rig: DOYON 19 Report Date: 2/1/2007 Wellbore Well Type Field Name Spud Date DFS (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) CD3-113 Development FIORD NECHELIK 1/24/2007 8.27 9,374.0 9,374.0 0.00 AFE / RFE / Maint.# Daily Mud Cost Cummulative Mud Cost Daily Cost Total Cummulative Cost Total AFE Amount 10161473 29,503.89 249,032.46 496,823.94 2,729,407.34 8,135,000.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 9,364.OffK6 Ops and Depth @ Morning Report 24hr Forecast RIH with 4" DP & TAM combo tool Pump 2nd stage cmt job -Reverse circ - UD DP -LOT -Test csg - Pump inh. brine - RU to run KS Last 24hr Summary Run 7" csg to 9364' -Circ & cmt csg -Set & test pack-off - CO upper rams to VBR - MU TAM combo tool. General Remarks Weather Head Count 48.0 :3,ipervisor Don Mickey Rig Supervisor Title __-. - Nina Woods Rig Supervisor Time Loa A~~:~' E.-~u Tn~~~ Tine - 00:00 00:45 ' Der ', '. Tin-~~ _ _.. ~hrsi I Pha,~:~ ' F. (':,~ic ~ OpSu,n..Cc ~P-PJ-T. l ml CnJ,_ T r t:-as= __ - -_ - 0.75 INTRMI CASING RNCS P Det h S~~ii ~ (irt,Nj ,783.0 Dept`. End ~flF:B;~, Comm,OF~raTion - - - 2,757.0 Continue running 7" csg f/ 1783' to 2757 (65jts. total) PU wt. 135 SO 125 00:45 01:15 0.50 INTRMI CASING CIRC P 2,757.0 2,757.0 Break circ & stage pump to 5 bbls/min -Circ pipe vo-. - 5 bbls/min @ 290 psi 01:15 02:45 1.50 INTRM1 CASING RNCS P 2,757.0 4,076.0 Continue running 7" csg f/ 2757' to 4076' (96 jts. total) 02:45 03:00 0.25 INTRM1 CASING RNCS P 4,076.0 4,079.0 Install TAM port collar @ top ofjt. # 96. Baker loc. 03:00 04:45 1.75 INTRM1 CASING RNCS P 4,079.0 5,539.0 Continue running 7" csg f/ 4079' to 5539' (130 jts. total) PU wt - 200 SO wt 150 04:45 05:30 0.75 INTRMI CASING CIRC P 5,539.0 5,539.0 Break circ & stage pump to 4 bbls/min -Circ btms up @ 320 psi 05:30 08:30 3.00 INTRM1 CASING RNCS P 5,539.0 8,113.0 Continue running 7" csg f/ 5539' to 8113' (190 jts. total) PU wt. 200 SO wt. 150 08:30 09:30 1.00 INTRM1 CASING CIRC P 8,113.0 8,113.0 Break circ & stage pump to 4 bbls/min -circ btms up @ 390 psi 09:30 11:15 1.75 INTRMI CASING RNCS P 8,113.0 9,364.0 Finish running 7" csg f/ 8113' to 9328' (219 jts. total) - PU FMC fluted hanger & landing jt. -Land 7" csg w/ FS @ 9364' FC @ 9277' -TAM PC @ 5285' 11:15 12:00 0.75 INTRMI CASING OTHR P 9,364.0 9,364.0 LD fill - up tool -Blow down TD - RU cmt head & lines 12:00 14:00 2.00 INTRMI CEMENT CIRC P 9,364.0 9,364.0 Est. Circ @ 1.5 bbls/min & stage pump up to 5.5 bbls/min -Circ & condition for cmtjob - ICP 610 psi - FCP 460 psi -Held pre job safety meeting 14:00 16:00 2.00 INTRM1 CEMENT DISP P 9,364.0 9,364.0 Cement 7" casing as follows: Pumped 5 bbls CW-100 - Pressure test lines to 3700 psi.- Pumped remaining 15 bbls CW-100 -Mix & pumped 40 bbls - 10.5 ppg MudPush -Dropped btm plug -Mixed & pumped 40 bbls 15.8 ppg tail slurry (Class G w/ additives) -Dropped top plug w/ 20 bbls fresh water f/ Dowell -Switched to rig pumps & displaced cmt w/ 133 bbls 9.6 ppg inhibited brine followed by 199.6 bbls 9.6 ppg brine -Displaced @ 6 bbts/min - 250 to 580 psi for first 310 bbls -slowed pumps to 3.5 bbls/min - 360 to 580 psi for last 22.6 bbls of displacement -Bumped plug w/ 1000 psi -Checked floats OK - CIP @ 15:45 hrs.- Full returns & pipe movement throughout job. 16:00 17:30 1.50 INTRM1 CEMENT RURD P 0.0 0.0 RU and test Casing to 3500 psi for 15 minutes. RD Cement equipment and and landing jt. 17:30 18:30 1.00 INTRM1 CASING DHEO P 0.0 0.0 Pull thin wall wear ring -Install and test PO to 5000 psi for 10 minutes. 18:30 20:30 2.00 INTRM1 WELCTL OTHR P 0.0 0.0 Change upper rams to 3-1/2" x 6" VBR's and test to 250 / 5000 psi. Pull test plug and set wear bushing. Latest BOP Test Data _ _ _ _ Date Camment _. - - - - -- 1/27/2007 Tested BOPE to 250 & 5000 si Tested H dril to 250 & 3500 si Page 1/2 Report Printed: 2/14/2007 Security Level: Development D aily Drilling Report CD3-113 Report Number: 9 Rig: DOYON 19 _ Report Date: 2/1/2007 __ _ _ ___ .Time Log - -- - - - _ St: t F~a U r ~ it ~= T.rr~ r P~ _~~~~ ~I [ Cod J_Suc Co F'-N-i Trbl Gode 0:30 00:00 3.50 INTRM1 CEMENT PULD P D ~ ~ Sr,d Jepth E' ~ Trol Gtass. iF,~) (ftKG' ion u,uvperetrun 0.0 0.0 MU TAM combo tool. Unabte to RIH w/combo tool The upper seal cups appear to be hanging up just inside 7" casing. MU 1 std HWDP for added wrt. Mud Check Data _ - -- - - Yt' ~~I l;-ca Gct~U.~ (ftF.E', ~ Der iiL da;~ ~ ~%~u F U .il: ~.: ~,I t 1 JCrft LSND 9,374.0 9.60 38 13.0 24.000 __ _ Gel 1 t I i~ -c~ Gel (30m) ', IiTHF' I dt l)en r Temp lids Cor hr ~) ~~ lof . ~ ~-,~ {IbN700ft~) MF1 Ir hl i L 5rr~n, pH _ _ F~ __ ~' 11,000 14.000 16.000 ~0 ~~-- In ection Flwd - - _ Fluid Source _ _ F ~orn Lease (bhl) 1 Destination N ,t~ Diesel , - - __ - 1Q.O;CD3-112 _ _ ~FP __ __ ~ Wellbores --- _--_-- - - Wellbore Name --- - __ Wellbore API/UWI 3 501032054100 - - - -- -- s rr Section Act Top (ft - KB) Act Btm (ftKB) Start Date En.i Dale PR(~D1 6 1 /8 PROD2 6 1 /8 CON D 1 16 36.0 114.0 1 /24/2007 1 /24/2007 SURFAC 12 1 /4 114.0 2,620.0 1 /24/2007 1 /26/2007 INTRMI 8 3/4 2,630.0 9,374.0 1/27/2007 1/30/2007 - _- _ ___ - -- - - - 'Cement ~----- Production Casin Cement -Started 2/1/2007 Type Wellbore String Cement Evaluation Results CD3-113 Intermediate, 9,364.OftK6 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Production Casing Cement 8,380.0 9,364.0 4 580.0 i_ Fluid ~ ~~ Crass-. Amo~mt rs,~ r :i _. Tail Cement G 195 v rC; ~ Density (Iblgal) Yi.ad eft' ~ Eck; Est Top {ftKB) ~ Es~F Bim (ftKB) 40.0 15.80 1.16 8,380.0 9,364.0 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 2 Production Casing Cement 4,286.0 5,285.0 4 1,165.0 Fluid Cla--, ~' ?,n~ourtt{sacks) V (bbl) Derr its In a~.; field (ft'Isack) Est Top (ft1~8) EstBtrda(ftK6) Production Cement G 180 37A 15.80 1.17 4,286.0 5,285.0 Page 2/2 Report Printed: 2/14/2007 ire Security Level: Development Daily Drilling Report CD3-113 Report Number: 10 Rig: DOYON 19 Report Date: 2/2/2007 Wellbore Well Type Field Name Spud Date DFS (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) CD3-113 Development FIORD NECHELIK 1/24/2007 9.27 9,374.0 9,374.0 0.00 AFE / RFE / Maint.# Daily Mud Cost Cummulative Mud Cost Daily Cost Total Cummulative Cost Total AFE Amount 10161473 32,158.09 281,190.55 201,218.54 2,930,625.88 8,135,000.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 9,364.OftK6 Ops and Depth ~ Morning Report 24hr Forecast Pull Wear Ring - RU to run Kill String RU &RIH w/3-1/2" Kill String -Land tbg -Test Hngr - ND BOPE - NU Tree -Pull TWC - FP -Secure i~ Release Rig Last 24hr Summary RIH w/TAM combo tool -Pump 2nd stage cmt job to isolate Qannik -POOH on TT - RD Swivel, XO, Cement Equip -Test 7" csg -Annular LOT to 16.6 ppg - RIH w/4" DP. General Remarks Weather Head Count 12/NE@20 mph 51.0 ---- - - -__ _~_ _ _ 3upernsor 1 if3e _ __ _ _ Don Mickey '~ Rig Supervisor Nina Woods Rig Supervisor Time Log St. E-.c Dur ' T cue ~~ - -----~ U Ft : R~.art Depth Erid ', Tin icrr {hrs) Phase Op Code UpSUI i,a fit'-N-T' 1rblGOtle I I ~.~I:~«. 'fth8j (ftKB) CorrimfOperadroc. 00:00 05:15 5.25 INTRM1 CEMENT TRIP P 0.0 5,166.0 MU Tam Combo tool & RIH w/tool on 4" DP to 5166' MD. 05:15 07:00 1.75 INTRM1 CEMENT RURD P 5,166.0 5,288.0 PU a single jt and RU swivel, XO, TIW Valve for cementing. RIH t/ 5288' to locate the combo tool inside the port collar. 07:00 07:30 0.50 INTRMI CEMENT RURD P 5,288.0 5,288.0 RU Cement hose and valves. 07:30 08:00 0.50 INTRMI CEMENT CIRC P 5,288.0 5,288.0 Circulate PV to ensure ball seat clean - 50 BBLS of 9.6 ppg brine, 20 spm @ 110 psi. 08:00 08:45 0.75 INTRM1 CEMENT CIRC P 5,288.0 5,288.0 Displace drill string with 9.8 ppg mud while pumping down ball to choke seat - 25 spm @ 210 psi. Pressure test tool to 1000 psi. 08:45 10:00 1.25 INTRM1 CEMENT CIRC P 5,288.0 5,288.0 Slack off 10,000 psi to open port collar -open annulus valve & attempt to establish circulation @ 15 spm through PC. Flow observed at flowline. Close Hydril - achieved flow through annulus. Stage pumps to 50 spm @ 770 psi pumping BU's. 10:00 10:30 0.50 INTRMI CEMENT CIRC P 5,288.0 5,288.0 Bleed off pressure -open Hydril - 2nd Attempt to circulate thru annulus pumping 50 spm. Flow observed again at flowline. 10:30 12:00 1.50 INTRM1 CEMENT OTHR P 5,288.0 5,288.0 Suspect ball not on seat -Begin steps for 2nd ball drop: Close hydril and displace drill string with 9.8 ppg mud - 50spm - 730 psi. PU 12,000 psi to shift port collar closed. Blow ballseat with 2600 psi. Drop 2nd ball & chase to seat with mud. Unable to PT. 12:00 12:45 0.75 INTRM1 CEMENT CIRC P 5,288.0 5,288.0 PUH 12' above port collar to 5276' MD. Test on blank pipe. RIH to located on port collar -slack off to 12,000 psi to open. Circulate and condition for cement job - 5 bpm - 880 psi. PJSM. 12:45 14:15 1.50 INTRM1 CEMENT DISP P 5,288.0 5,288.0 Cemented 2nd stage cmt job to isolate Qannik formation as follows: Pumped 5 bbls CW-100. Tested lines to 3500 psi. Pump 5 bbls CW-100. Mixed and pumped 20 bbls Mud Push @ 10.5 ppg - 3.96 bpm, 700 psi followed by 37 bbls tail slurry - 15.8 ppg Class GCement - @ 4 bpm, 450 psi. Displaced w/10 bbls fresh water from Dowell. Inserted wiper plug & displaced cement with 48.4 bbls of 9.6 ppg brine. Plug bumped -Pressured up to 3600 psi attempting to shear plug catcher - Unsuccessful -Cement in Place at 1405 hrs. Latest BOP Test Data ~ Date ~ r _Trn~n~ _ __ 1/27/2007 Tested BOPE to 250 & 5000 si Tested H dril to 250 & 3500 si Page 1/2 Report Printed: 2/14/2007 Security Level: Development Daily Drilling Report Time Log CD3-113 Report Number: 10 tig: DOYON 19 Report Date: 2/2/2007 ~ ,n - End ~ Dur T~r~c Time ?hrs) - Phase I ,.u i ~ i ~ ~.r~ - , C7pSu. Co ~'-N i ~~ - - - ~ Del h Stan ' l r!.I O~na 7 C _^~s ~ kP,? Depth End (ftK6) i;~ yin -~~perafion 14:15 15:15 1.00 INTRM1 CEMENT RURD P 5,288.0 5,160.0 Shift port collar closed. SB to 5160'. Break out and lay down side entry assembly and RD Cement Equipment. 15:15 20:15 5.00 INTRM1 CEMENT TRIP P 5,160.0 124.0 Flow check well -static. Pooh on TT f/ 5160' - 124'. LD HWDP. LD Tam combo tools. Dart lodged inside the top of dart catcher. 20:15 21:15 1.00 INTRM1 CEMENT OTHR P 0.0 0.0 RU and test 7" Csg to 3550 psi for 30 minutes. 21:15 22:15 1.00 INTRM1 CEMENT PULD P 0.0 0.0 Break down TAM tools. 22:15 23:45 1.50 INTRM1 DRILL TRIP P 0.0 2,581.0 RIH t/ 2581' with 4" DP. Mud Check Data ~ __ YP Calc Ge ~'~ I 'gym! i0 n HTHP Filt Denrit Temp li ;oir-' ~ 1, pe Depth (ftK6) Dens ( Ib/gal) Vis {s/qt) PV Calc (cp) ,i i ~i I f.1 Wrt ~ ~ i~r ~ ~qg I r r„ ~, (mtJ30min) p}~ _ __ F (16f1106R~) Qbf, 1 ~ -' KCL 6RINE 9,376.0 9.60 ~ 'I~ection Fluid •=1uid S ,~ r r Fr ,i Lee ~ ~. Destination Note Diesel 50.0 CD3-112 FP Diesel 43.0 Annular Leakoff CD3-113 Water 300.0 Annular Leakoff CD3-113 Water 150.0 CD3-112 Flush Water Based Mud 1410.0 CD3-112 f/CD3-113 Water Based Mud 6.5 Annular Leakoff CD3-113 Wellbores Wellbore Name _ Welibore API/UWI 1 CD3-11~ 501032054100 Section ' Size Qc! Act Top (ftK8) Ac[ Btm (ftKB) Start Date [nd Date PROD1 6 1/8 PROD2 6 1 /8 COND1 16 36.0 114.0 1 /24/2007 1 /24/2007 SURFAC 12 1 /4 114.0 2,620.0 1 /24/2007 1 /26/2007 INTRMI 8 3/4 2,630.0 9,374.0 1/27/2007 1/30/2007 Page 2/2 Report Printed: 2/14/2007 WELLPATH DETAILS oPh i I I i C onoc p-s Rig: CD3-113PB1 Alaska Rig: Doyon 19 Ref Datum: Plan: CD3-113 49.40ft Quarter Mile V.Sec[ion Origin Origin Starting Angle +N/-S +E/-W FromTVD (1320 feet) MALLIBURTQN aw~oat~a...trs~ 302.50° 0.00 D.00 36.30 radius plot CD3-109 CD3-302 CD3-302PB1 CD3-112 CD3-112 CD3-110 CD3-110 - ~ _ _ _ _ _ _ 2723 -- -- CD3-111 CD3-111 CD3-302 CD3 -302PB2 CD3-111 CD3-111L1 2042 :, - -- -- 1361 0 ~ ~~ ~ ~ CD3-307 Ri :CD3-107 a p ~ - - Ri :CD3-113 PB1 ~ \ / -- - --- - - - - 681 - 0 ------- -------- -681 - - - -3404 -2723 -2042 -1361 -681 0 681 1361 2042 2723 West(-)/East(+) [ft] PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-113 Rig: Doyon 19 Date: 2/2/2007 Volume Input Pump Rate: Drilling Supervisor: D. Mickey / N. Woods Pump used: Cement Unit ~ Barrels I ~ Bbls/strk ~ 0.8 Bbl/min ~ Type of Test: ~ Annulus Leak off Test for Disposal Adequacy ~ ~ Pumping down ~i annulus. ~ Casin Test Pressure Inltegrity Test Hole Size: 8-3/4" ~ Casing Shoe Depth Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 34.4 Ft 2,620 Ft-MD 2,475 Ft-TVD 4,286 Ft-MD 3,675 Ft-TVD Bbls psi Min psi Bbls psi Min psi Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC ~ 0 0 0 0 755 Changes for Annula r Adequa cy Test Pressure Int e rit Test 1 0.5 370 0.25 594 uter casing shoe test results in comments Mud Weight: 9.8 ppg 2 1 497 0.5 580 Description references outer casing string. Inner casing OD: 7.0 In. 3 1.5 611 1 569 ize is that drilled below outer casing. 4 2 726 1.5 5"" timated TOC for Hole Depth. 5 2.5 837 2 56 Enter inner casing OD at right Desired PIT EMW: 16.0 ppg 6 3 875 2.5 559 Estimates for Test: 798 psi 0.4 bbls 7 3.5 802 3 557 ~ ~ I ~ 8 4 789 3.5 555 EMW =Leak-off Pressure + Mud Weight = 837 PIT 15 Second 9 4.5 783 4 553 + 9 8 0.052 x TVD 0.052 x 2475 / Shut-in Pressure, psi 10 5 763 4.5 551 EMW at 2620 Ft-MD (2475 Ft-ND) = 16.3 594 15 5.5 758 5 550 ~ooo - -- - 20 6 758 5.5 550 25 6.5 755 6 548 - - - ~~ - --- - 30 6.5 547 ~~ • ~ ` ~~ 7 546 _ 7.5 545 - - _-- 8 545 w ~ 8.5 543 9 543 -- -- _ _ __ 9.5 54 N soo w - - - 10 5 ~ -- - a -- ---_ 0 0 1 2 3 4 5 6 7 0 5 1 0 1 5 2 0 2 5 3 0 ~~C ASING TE Ba ST rrels -LEA K-OFF TES T S hut-I O P n tim IT Poi e, M nt inute s Volume PUm ed Volume Bled Back Volume PUm ed Volume Bled Back s s s s Comments: 9 5/8" casing shoe PIT = 18.0 ppg a • SURFACE CASING SHOE SEPARATION FROM CD3-113 `I'a~t ark ~hattnar , ~'atr haves re~e~ted tt~ disposes cif "rt~;d-L~rvdu~t" a~a<azi tip fluids fx-~am the xc~utir. mixirrc~} t=f mt,t:~ and GPT"'=~ziV aT. .~},}'sir;cz as *holl ~,s tl<e cle~.r up fluid-. r~~zthtinct f roziz ~-.lraninq at,t thy. ta~xcs at the rnud plant in l~r~}>aratian tc,r t:,i.nc~ .oil base ::,uc?. 'TY s w Cc~.-:snissic~i }xMc} p:r~~~.aas}.}~ n~Yaravcrl di>pnsing of tY-~ ®xxev,~ prac,_ict'~ clan ;tfa Lltziezs via az:z-zular c3i~po:~a1 at CAD 1 patY. DrzE. to the <:evicc~i~a. sez~t_ir:c_. at ~ZY>n~~ ~'l.a~s } a:tel C'1a:~:~ 2 di:~po:~~t1 opLia~I are la.:s~ocl. 1?h~l:l.~, prcdc•~~~.ar, =~~('C7, hid e t~:k~~~'4x~d L:}xe l.m.t~~tta.ars c,f spo.>a 1 c~F~tivras tv ti1~ L:«~:~rii~son`s ~~rrs~.~`raz 3z-:il az-,rtilaa- c1isZ,e,~al was apa~rc~vecJ a~ ~}~o :-~z.zcr,~ca' anc} ertvirerzrrcntal alternat_~,f~. Ir_ these requests t2xe waste Llua.iJs tiro ixa di iferc~t:t t}-~rr r.revic~usly ac?pz~c,ved arci ,-sre -ho s-o:cult o= the on~7oine~ ~develUr~nten;: at ti•~.i..ias zit ;~lpan~-~_ . TYie Corz~ttissoners h<~ve t~uthorz~~d me ,_o sr_nd yc~<.x th_s m=~s-sac~e. ~~ copy of ~h~ czr:~il, I~hillips is ~;>~t~ktv~izer7 Cry rist~czyc of cLc~arx. up flui3s 2is cle~;cribeci it2. your c?^~ i 1 . F1ea~;e c~1Z wit_.}i ~xzxy r_lues~5ar.5. 'f ,m ~'Iruni3c:.r' , PG tr. Petx~.,leuxzt Ent~ir.eer ? ~~dr >Is . bSatzrl~eT , > ris nater:~ i:t t},e att.ac~xecl erna9.l, 'i'c~trz t~iazisC,n Y,,-=at.*icau`~l f reque.~ted r ~=u vixoz-a aatiz~:t to dz.sF>osc of noTrr-proctxct cl~aa up fuG:is surtax ~`ts eem~r~t; rin atez, a:x~i c;uci arxr ~,r`ire X>it z'i.xses fx'r}[iz rzi:~nq ~:7~ratiors aria annular > itaCLiaii it Zi~rmitC~~: ~E.re:li.s zit the :~'i~inc CT~2 Lrll :~it.e. t~s not~f.J l~ela.a, > ,()C„^C ,7pprnved ~~uch disnf~sal at t2:e C~'al ~zill Ss.te in 7.999, has~d an w~c int~~ral r~iatifn~~xip oaf t}ae mz_t~ mixa.nq Cacti:.i`y and the on-~•ite tirillin~ :- oper~,fion. ~- PhilZip~: rottl€~ la.ka Cc~ caz.tinuing pur.st<zt.c ~:,ice req~se~-t. ~i~tnifcan4~ Clear. ~ t?ut. off` 4~xk~ z:t tttc zntxd mixing facility mast octant :in prer,araCic,n foY thc~ ~ tc~:~Ep~a~ary use of oil k>aseci mud prr~cluct-s <~t~ ~ilpinp in the c~mzn~ rrGc~ntri~. l ^he a~~ailability a£ arntz:i.ar disposal a~ an op inn. far tank rinse f~uitx~ acid ~i:;ilar t~+ast.Q> *,~az_zl~} rrY~3tly facilita~c~ ts,i^ prc~cGs~:. t,'iyi~ic~xlly, rr~utine 'r r.atz~~~s are t~c.r_efi~ially_-ausc.~, 2ic~.ve~.r~er, l}:ere .s a c~c~nC~.xn ak~c~ut tt}r potential cuantiCy of fZaicl t}~at eoul~~ ~e <~~norratarY dtz~'in~ this lame sC~tle clean •ap prt,re~s. ) ~ '?'ar.k~ ar_ the z~ud r*.aixin~ facility rna.y cargi_a:.n ~itl'r~r new axzd used mtid > products. i2itxugYz r:~ses in Concaet r~ith ,ts~d pYaclucr.s may iro i:-ij~•ted in ~- the permitt~Cl class 1.? cta..aZ~c~s~l. ~,~e1h (fir?l'9~? . r-in.~es of ne~~ products would ~ Y~ot_enLially ~C rota~d to r__Y;~ cZa_~> I disp•?:7a7 ~reZl {-{}2} , wYxero there is ex r_3iLfi.tulty znararxirc~ solielT cQr_tent. TY~ class I ~~,~~11 is a criGacal } I:i.f'r~7 n€~ for zacility infrast~`ucture, Y~eir.g ttwe di~pa~a~- lacr~t.ann f~,r all > c3rzr>cr.~tic effltx~ntj and i'~ U a prioxbCy tez pre~fen~ ,env cc~m}~~ami. r to this > disFsosal f~icilit~y. ?~nnul_ar c~i;~pas~al, prasezir..s a pr~z*or?-ed ;waste managernerrt :~ dlvernat`,re in u:xis c<~~c~. ~- • - i .e 'I`~ar'~c y~,z v~_y such far yflu_ ~arzs-iGe_~!'4ivrA cif Gt-~is :nc~Za~st. ~lcase can nc~t > k~esi~.ate t;~ ~~n~~r~~ zt!e ~ rr.~ ~iC~~naC:~ t~ia coil ar pY~~.rze at {~J?} 6';~-~I2G~ > if y*~u Yz~t%~~ c~t~~stS ~r:~ ar n~~c~ ~ clc~ i. c~na inforrr~tiorz o t Shaman ~onrfelly } ~~pire ?ie=G ~nvis~f.~rataerital Cc~o_a.zYaLC~r` ~ __- _~ ~~ax-~~*arde~~i ~'d ~Lf~ Wn~,~ ~t3t~rd1`~'P~'~i cn 2ZIG2IG1 ~~. ~~1 I'~ __ ~~~ ^Y r f1L,P Exz'e ~`~t?~ci r' ~,~,: Ln zn~GUnr.Y~x'C?~zeimtl. }t~~~.~.us .. ~c _ ~~ S~:zhjc~ct: IZ~~ruBSt. tc~ Tz~~er'~ G~ri~rt cin.s~~.~ aY. ~~2 ~ Dear I~L-. R~urZCiez , Ir:.j~{~ti~n cif €z~m~rt r.~z~:~t~ ,-and clean-~.i~ fluids Lr~m nltzd azit3 ~~x~r1~ ntixinc& > o}7crata~?ns ~t t:~z~ ~lpinc mud. plant f~t;il.tCy irL'c3 ~-~k~Y~xvti~cri annular clispo~~37 uperat icir~s t;as ~rt~z~~ ~ci Y~y ~~~ ,e=el c~s~a t).l r'Lzid C;~N Conses ~~~at ivn i:~xiuni~;5ic~n > t~C~CC? i-z the March i 1, 1~3~ letter from ~'~C~GC~ to i3c>uc7 ~i~~stex~ of: PkC:~ r'tla~ka, Fria., r:o,~ FhilLips ~lla~ka, 2nc. {~'~~?. `I'h~ appra~fal ~;~~ ~rarzt~d ~~_ P~:i t~~c.ifi.eally for A:ll,t7~. I3ri?l Site C'D1 gar>ci aatYz~~rix~tz yr>1u;7e_~. u~} ~.n > ~3~, C7~(? I~arrr,Is thrraugri thL a-znalar sv~:c~. ~~,' request that. tYais a~pr©val h~ extt?rzc9ea tc> c:r'~~ 11 az~r~ c~:~c~rat~.~n:-~ a' t:l.~iir.~'- r- I~2_11 Site C~2. Getaert mixincv «p~raCl~ns fc~r s~:ttz.nc~ surfa~~ ct~nctuctc~rs wa °,. 1. he taking plac~_ at thr* tarind end ~rjec~t fac9 lxty s.~iii~~i i~ c.~.zr~er~tly ~ atta~l:eo try Lh~ clrillz~zg rir_7 at CL2. {Jpan c.nr!a~~1 i.~.i.e~r. cat~.:hr~ cemc~n`ii3c~ in > of the cur~du~t~r.~, r};~ 1~;-zes <~nc~ mixing tank y:ill na~.;~ t~ T_» z~zzsed and •~he } rinsa`e disposed v.f. P7aI r.~~~s" aL~pru~~al i.c~ _rY~~~t; r.}~i:; r.an:saT.c?, end ~~ a::Yrer u.leza:l-u~ K~c~~! tYz~ r1~ac t,rc3 t?x~.ne mixing at~~_xatioz°~, irztc-a tl:e annual '~ space of apprr»F~d ..yells located ~t Drill SitY ~IJ2.. ~f ,t,~u ais~vc~ any questions 7lcasc~ rantact mc: Gt G7G-4~QG. ~ ~'~:~. txaz~st~rz ~- Alpine ~'io3d Ezzvir©nmenta3 e.~a.lian~e torn~na~n~9or.vcf x Fluids Authorized for Annular Disposal Subject: Fluids Authorized for Annular Disposal From: Thomas Maunder <tom_maunderwadmin.state.ak.us> Date: Tue, 20 Mar 2007 09:04:55 -0800 ~I'o: ~'et~ Johnsen °"Vern. I~~hn~en~i cuni~cc~~~hilli~~s.cen2>. Liz (_~aliunas ~r<aliueccrconocc~l~hilli~~.cem~ CC: Randy Thom~~s ~ -f~zu~dv.L.l~h<~nr~>> u`cen~~~:~_~~~I~i11iE~s.cum>_ Jcrem~ I~:~~~~~~cnlc~~- -J~remc.C.Eggei7~c}~r u'c~~noce~C~hilli~~~.rem~, Jim Re~`~~ '-lim r~s~~~"~i=~tcinlin.sta[c.~~k.us' , ~~IliE~ rllvor~i --Chip.All~or~l~~r:een~~cophillips.co~n Vern, et al, I am finishing an application for AD on CD3-113. This is one of 2 applications (CD3-ll 1}submitted in mid February. CD3-111 was approved and returned. These applications follow what has become the standard format for at CRU. The issue that has slowed down the processing and return of this particular application has to do with the final statement in block 15 "Fluids to be disposed:". The specific words are, " ... and any other fluids associated with drilling a well." A literal read of this statement is that by approving the application, in addition to the fluids listed previously, "any other fluids associated with drilling a well" are approved as well. This wording is pretty similar to 20 AAC 25.080 (h}(3), however the requirement of a Commission determination has been removed. In order to assure that the Commission has an opportunity to make any needed determinations, it is probably appropriate to revise the final clause to that of (h)(3). I am not aware of there being any issues arising from AD activities approved with the "standard" wording. However, it is probably best for all to revise the wording. Please discuss with your colleagues. I look forward to your reply. Call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 3/20/2007 9:05 AM • Note to File CD3-113 (207-004...307-067} Colville River Unit (Fiord-Nechelik) ConocoPhillips Alaska, Inc ConocoPhillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. No problems were reported. Approximately 145 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 78% XS of the calculated hole volume. -- On the initial leak off test, there are two pressure slopes. The slope change is not sharp. The inflection occurs at about 14.7 EMW. With continued pumping an ultimate FIT of 18.0 EMW was reached. Two slopes are not unusual and have been seen on other CD3 wells. Minimal fluid was pumped in. The pressure declined during the observation period to about 14.6 EMW. The initial leak off indicates that the surface casing shoe is well cemented. --No problems are reported drilling the intermediate hole. The 7" casing was run -and successfully cemented. Full returns were noted and the casing was reciprocated. Sufficient cement was pumped to place cement above the shallower Kuparuk sand. A 2"d stage was pumped via a port collar to isolate the shallower Qannik sand. --An infectivity test down 9-5/8" x 7" annulus was conducted. Pressure steadily increases until the break at 16.3 EMW. The pressure declined with additional pumping to 15.7 EMW. During the observation period, the pressure declined to 14.0 EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. --CPA provided a listing of all surface casing shoes within '/4 mile radius of CD3-113. The surface shoe of CD3-112 is about 500' distant. CD3-112 was recently recommended for annular disposal. There are 2 other wells 840' and 1280' distant. Examination of the cementing information did not reveal anything to preclude granting CPAI's request. Based on examination of the submitted information,. I recommend approval of ConocoPhillips' request for the subject well. '"( Tom Maunder, PE Sr. Petroleum Engineer February 22, 2007 G:\common\tommaunder\Well Information\By Subject\Annular Disposal\070222--CD3-113.doc • • Note to File CRU CD3-113 (PTD 2070040) February 21, 2007 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well Colville River Unit CD3-113 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the annulus of CD3-113. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9-5/8" surface casing shoe is set at 2,619' measured depth ("MD") and 2,438' true vertical depth subsea ("TVDSS"), near the base of a 400- to 500-foot thick claystone and siltstone interval that persists throughout the area This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of siltstone and sandy siltstone open to the annulus of Colville River Unit ("CRU") CD3-113 to accept the proposed injected fluids. 3. The lower confining layers are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal intervals. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed annular injection activities will be limited to a radius of about 120' from the wellbore. Discussion CPAI's application was reviewed along with records from nearby wells Nechelik No. 1 ("Nechelik 1"), CD3-111, CD3-112, CD3-108, and Fiord No. 5 ("Fiord 5"). The discussion that follows is based on well logs from these wells and on mud logs recorded in Nechelik 1 and Fiord 5. An index map and a structural cross-section are provided, below. The proposed injection interval in CRU CD3-113 lies in the Seabee formation in the southern portion of Section 5, T12N, RSE, UM and about 2-1/4 miles from the current boundary of the CRU. The 9-5/8" surface casing shoe of CD3-113 lies at a depth of about 2,438' TVDSS, near the base. of a 400' to 500' thick interval that is dominated by claystone and is continuous throughout the area. This interval will provide upper confinement for fluids disposed in the annulus of the well. The annulus proposed for disposal of drilling wastes extends downward from the surface casing shoe to the top of cement for the 7" casing string, which is estimated to be at about 3,641' TVDSS. The most likely portion of the open annulus that will accept injected waste is an 18' thick interval of silty sandstone that lies between 2,504' and 2,522' TVDSS, which is just below the surface casing shoe. This sandstone is part of a 180' thick interval of siltstone, sandy siltstone and silty sandstone interval that extends from 2,483' to 2,663' TVDSS. Two underlying siltstone and sandy siltstone zones may also accept some of the injected fluids. These zones lie between 2,726' and 2,806' TVDSS and 2,844' and 3,023' TVDSS. • CRU CD3-113 February 21, 2007 Note to File Page 2 of 4 The aggregate thickness of all of these potential injection zones is about 440'. These three potential injection zones are separated by two claystone/ siltstone intervals that are, in descending order, 64' and 38' thick. Beneath the injection zones are thick intervals of thinly interbedded siltstone and claystone that appear to be continuous throughout the area. These interbedded siltstone and claystone layers will provide lower confinement for any injected wastes. ox Unit ~RD ~ CD'3-10~ _ _ _ boundary cos-1os ~'--"' ~ CD3-110 4a~ CD3-1 1 L1 CD3-301~CONF CD3-1 1 q 5}-~ / a ~ I / U~UPS- ~ ~ ~ F10 5 ~ pCD3-302 PROP 0 ~ I {tiT } ' /I \ D3-302FB''CD3-307 ~ - ~-- - - - D3-302PB1 - - ~~ ~~NIGLI ' \ ~ ~' I 1 -107 CONF ~ CD3-1`13 '' ~ ~ '' N ~ _ _ _ _ _ Injection_ _ ~ Nechelik 1 Interval ~ ~~ _~ CHE~Ih'. 1 .. tx t=F ~ IORD 2 Index Map The operator's application reports the base of permafrost occurs at about 1,550' TVDSS in this area. Inspection of the well logs from Nechelik 1 and Fiord 5 indicates that precise determination of the base of permafrost is difficult here. The geologic section is frozen through about 1,100' TVDSS in Nechelik 1, which lies 2-1/4 miles southwest, and about 1,400' TVDSS in Fiord 5, which lies 1-3/4 miles northeast. The base of permafrost lies more than 1,100' above the top of the proposed injection intervals. The shallow geologic section in the area surrounding CD3-113 likely contains methane gas. Records from Nechelik 1 and Fiord 5 indicate that traces of methane were first measured 245' and 80' TVDSS, respectively. Both wells were drilled through the shallow geologic section using somewhat similar drilling mud weights (range: 9.7 to 10.2 pounds per gallon). The shallowest occurrence of more significant amounts of methane encountered in these wells (arbitrarily placed at 20 units of gas on the mudlog) were 890' and 1,325' TVDSS, respectively. So, the entire proposed disposal zone likely contains methane gas. Supporting documentation to ConocoPhillips' annular disposal application states: "There are no USDW aquifers in the Colville River Unit." This is correct. Conclusion 3 of Area injection Order No. 30, which governs the Fiord Oil Pool, states "There are no underground sources of drinking water beneath the permafrost within the proposed affected area" which includes the area that will be influenced by annular • • CRU CD3-113 February 21, 2007 Note to File Page 3 of 4 disposal operations in CD3-I 13. In addition, Area [njection Order 18B, which governs the CRU also states that there are no USDWs beneath the permafrost within the area. The shallowest oil shows occur in Fiord 5 from about 4,000' to 4,080' and from 4,130' to 4,250' TVDSS, well below the likely injection zones for any waste injected into the annulus of CD3-I 13. In Nechelik 1, the shallowest oil show was encountered at about 2,330' TVDSS, and it was rated as fair by the mud- Permafrost oil Most Likely Zone Surface of Injection rya eh~P Southwest to Northeast Structural Cross-section logging geologist. Additional trace amounts of oil were observed at about 2,725,' 3,000,' 3,375' to 3,575,' 3,800' to 3,875,' 3,950' to 4,000,' and 4,075' to 4,350' TVDSS. Examination of well logs from u CRU CD3-113 Note to File • February 21, 2007 Page 4 of 4 Nechelik 1 and CD3-113 do not indicate the presence of commercial oil or gas reservoirs in the intervals that will be influenced by the proposed annular disposal operations. The following chart provides an estimate of the affected area surrounding the CD3-113 wellbore. Assuming an 18' thick injection zone with 25% porosity and a maximum of 35,000 barrels of injected waste, the area most strongly impacted by the proposed annular injection activities will be limited to a radius of about 120' from the wellbore. Injected Fluid vs Affected Distance from CD3-113 Wellbore (assumes 18' thick zone having 25% porosity) 150 °~i 0 100 a E 0 m v :°. a O ~ 50 v w Q 0 ,.r-.. , ..-r _-~= ,. ,_" +_.. ~ ,. =` - -- -~-r -i- -~ -- - - - i ~, I ~'~ I i ~ I ~ i I ~ i ~ 'I r ~ ___ ~ i i ~~ I 5,000 10,000 15,000 20,000 Amount of Injected Fluid (barrels) 0 I i I I 25,000 30,000 35,000 The limited volume of rock that will be affected by this proposed disposal injection program contains methane gas, is situated beneath more than 1,000' of permafrost, and is bounded above and below by continuous layers of claystone. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbon accumulations. The proposed injection zone lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. I recommen approval of this annular disposal project. t Steve Davies Senior Petroleum Geologist • • 06-Mar-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD3-113 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 36.69' MD Window /Kickoff Survey ' MD (if applicable) Projected Survey: 9,374.00' 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 ~ ~ ~~ a~'4~ Signed D Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) a~~^ our( CD3-30? Update Subject: CD3-307 Update From: "Galiunas, .Elizabeth C" <Elizabeth.C.Galiunas@conocophillips.com> Date: Mon, 22 Tan 2007'08:39:27 -0900 To: ~fhonr,~s ~~taundcr <=tong mauncler~~i'admin.state.ak.us= Tom, Operations for CD3-307 began 1/10/2007 when we accepted the rig. After two failed chemical cuts inside our packer to release the entire completion, we jet cut the tubing above the packer. We proceeded to lay down the upper completion and attempted to mill the tubing pup joint above the packer. After 7 days of milling and no notable progress, the decision was made to suspend the well to be returned to at a later date (probably next winter season). The next well is 0©3-193. T rig is currently working to suspend the welf and shauid be moving off C{33-307 some time tomorrow evening. Verbal approval to suspend the well was given 1/21/07 and a sundry is to follow in the next day. Regards, Liz Galiunas Drilling Engineer Alpine Drilling Team Office: (907)-265-6247 Cell: (907)-441-4871 1 of 1 1/22/2007 9:14 AM • ~~p~~ 0~ CO1~T5ERQA Chip Alvord WNS Drilling Team Lead ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Fiord Oil Pool, CRU CD3-113 ConocoPhillips (Alaska), Inc. Permit No: 207-004 Surface Location: 3955' FNL, 914' FEL, Sec. 5, T12N, RSE, UM Bottomhole Location: 1125' FNL, 2821' FEL, Sec. 36, T13N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The decision. as to whether or not the Qannik sandstone contains a significant hydrocarbon accumulation that must be cemented per 20 AAC 25.030(d)(5) must be made in conjunction with AOGCC technical staff. When logging information is available, please have your engineer contact the Commission. The proposed pilot hole intended to establish the top of the Nechelik will open between 300' and 500' of reservoir and it will not be plugged with cement. Since the Nechelik interval is being developed open hole it is unlikely that this penetration will collapse. Per 20 AAC 25.990(74), this pilot hole must be considered a well branch (lateral), and per 20 AAC 25.005(e) it requires a separate Permit to Drill. Production from the pilot hole well branch should be reported against CRU CD3-113. The Commission requires that a mudlog and cuttings samples be obtained in one well from each drill site. Our records indicate that no mudlog or cuttings samples have been acquired at Pad CD3. If reasonable, a mud log and cuttings samples should be obtained in well CRU CD3-113. If this is reasonable, given the short time frame, a mudlog and cuttings samples should be acquired from the base of conductor pipe into the reservoir in the next well drilled from this pad. SARAH PAUN, GOVERNOR -7~~ O~ ~~7~,~r ~7 ~O~ CO~iI-~-7SI01~ 333 W. 7th AVENUE, SUITE 100 ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ConocoPhillips Well Name: CD3-113 Permit No. 207-004 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) 6~ 3607 (pager). DATED this .,~C,~jday of January, 2007 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ ~ ~E~wE® STATE OF ALASKA ~I ~3 JAN ~ ~ 207 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska Oil & Gas Gons. Commission 20 AAC 25.005 Anchorage 1a. Type of Work: 1 b. Current Well Class: Exploratory ^ Development Oil ^/ 1 c. Specify if well is proposed for: Drill ^/ Re-drill ^ Stratigraphic Test ^ Service ^ Development Gas ^ Coalbed Methane ^ Gas Hydrates ^ Re-entry ^ Multiple Zone^ Single Zone ^/ Shale Gas ^ 2. Operator Name: 5. Bond: / Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 CD3-113 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 17484' TVD: 6899' Colville River Field 4a. Location of Well (Governmental Section): 7. Property Designation: ~~yL (~ ~ b Surface: 3955' FNL, 914' FEL, Sec 5, T12N, R5E, UM ADL372105, 3x4471 ~•/G• Fiord Oil Pool ' Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2389' FNL, 866' FEL Sec 6, T12N, R5E, UM LAS2112 1123!2007 Total Depth: 9. Acres in Property: 14. Distance to 1125' FNL, 2821' FEL Sec 36, T13N, R4E, UM 2560 Nearest Properly:145o9' to CRU Boundary 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x- 388129 ~ y- 6003820 ~ Zone- 4 (Height above GL1: 37' RKB feet Well within Pool: CD3-112 , 2081 ft - 16. Deviated wells: Kickoff depth: 1000. ft. Maximum Hole Angle: 90° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3121 psig . Surface: 2438 psig 18. Casing Program ti S if Setting Depth Quantify of Cement Size pec ica ons T op 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' pFe-installed 12.25" 9-518" 40# L-80 BTC 2469 37 37 2506 2400 477 sx AS Lite3, 230 sx 15.8 G 8.75" 7" 26# L-80 BTCM 9439 37 37 9476 6919 232 sx 11 ppg litecrete lead, 287sx 15.8G 3.5" 9.3 L-80 EUE-M 8630 32 32 8662 6701 Tbg 119 I PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Stru ctu ra I Surface Intermediate Production 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 V. Johnson Printed Name /~ C. Alvord Title WNS Drilling Team Lead Signature / I- ~ /t , 0 Phone ZG S'- ~ l2o Date ~~(~ i(o ` Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: ~~' C~~ 50- ~U3 ~ Z.U,j ~~ ~~ Date: for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained ins '3J~~ Pg.` ,~~,^~ ~ ~~~'~ ~~y~ Samples req'd: Yes ^ No ['~ Mud to 'd: es No []' Other: H2S measures: Yes ^ No []~ Directional s req'd: No ^ DATE: , ~ ~ ~~/~~ Form 10-401 Revised 12/2005 ~ ~~ `~ COMMISSION Submit~pu{~li"< ,Qb f• /6.0 • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 9, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD3-113 &CD3-113PB1 Dear Sir or Madam: • ConocoPhilli s p ~c~E~V~® Jq ~ ~ ~ 2007 Alaska nil $ ~ as Cans, emission '~n~hora~a ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore producer well from the Fiord CD3 drilling pad. The intended spud date for this well is 01-23-2007 It is intended that Doyon Rig 19 be used to drill the well. / CD3-113 will be a horizontal open hole producer in the Nechelik reservoir. There is potentially low reservoir pressure in the Nechelik. Therefore after landing the well and setting 7" casing, if there is evidence of low reservoir pressure in the Nechelik, there will be a temporary shutdown of drilling operations. A circulation string will be run and a tubing hanger landed and tested and Doyon 19 with then rig down and move off CD3-113 to drill another CD3 well. Doyon 19 will return to CD3-113 later in the 2007 winter drilling season after the reservoir pressure has been increased to a more manageable level. It is planned to drill amid-lateral pilot hole, kicking off at +/- 13000 ft MD and drilling to +/- 13518 ft MD.f It is expected that the top of the Nechelik will be intersected at +/- 13300' MD, leaving +/-300 ft of open reservoir in the pilot hole (CD3-113PB1. The well will then be sidetracked and drilled to +/- 17484 ft MD. The pilot hole will provide reservoir thickness and cross section pro~yerties to aid future planning. At the end of the work program, the well will be closed in awaiting completion of well work and facilities connection that will allow the well to begin production. If the Qannik interval is interpreted as a significant hydrocarbon bearing zone it will be isolated with cement after setting 7" casing; either by a light weight primary cement slurry, or with the use of a stage tool. c,,Qpccx~c,.~ t-rc~~ot~o-~E~~~ ~~ ~/a ~ A waiver for the diverter requirement is requested. This will be the 8th well on the Fiord pad and there has been no indication of gas or shallow gas hydrates. 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 proposed completion diagram. 5. A drilling fluids program summary. 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. 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 is: 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. Riser setup • If you have any questions or require further information, please contact Vern Johnson at 265- 6081, or Chip Alvord at 265-6120. Sincer , , .~--~ Vern J son Drilling Engineer Attachments cc: CD3-113 Well File /Sharon Allsup Drake Chip Alvord Liz Galiunas Vern Johnson Jack Walker Jordan Wiess Lanston Chin ATO 1530 ATO 1700 ATO 1704 ATO 1702 ATO 1740 ATO-1782 Kuukpik Corporation • • CD3-113 Drilling Hazards Summary (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casin Interval 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 8-3/4" Hole / 7" Casing Interval 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 out 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 6-1/8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. Abnormal Reservoir Medium . BOPE drills, Keep mud weight above 8.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low / H2S drills, detection systems, alarms, standard well control ractices, mud scaven ers 0~!GIf~AL ~ • Fiord: CD3-113 Procedure 1. Move on Doyon 19. 2. Rig up riser, dewater cellar as needed. 3. Drill 12-'/" hole to the surface casing point as 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 Nechelik reservoir sand. (LWD Program: GR/RES/PWD) 10. Run and cement 7" casing as per program. Carry out a leak off test 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. If there is evidence of low reservoir pressure, temporarily shut down drilling operations. -~ S ~'n~ ~« 12. Pick up and run a +/- 2000 TVD circulation string, land and test hanger 13. Install 2 wa check and pressure test han er seals to 5000 psi. Nipple down BOP. G~"~-- rl a~ Y 9 14. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 15. Circulate tubing to diesel and install freeze protection in the annulus. 16. Set BPV and secure well. Move rig off to drill another CD3 well 17. Move in and RU with Doyon 19. 18. Dewater cellar as needed. 19. Install a two way check. 20. Nipple down the tree. Nipple up BOPE. 21. BOPE test to 5000 psi. 22. Displace well to brine and pull out of hole with circulation string. 23. Pick up 6-1 /8" drilling assembly. 24. Drill 6-1/8" horizontal section to+/- 13000' MD. Build angle and drill to pilot hole TD at +/-13518' MD (LWD Program: GR/RES/PWD). s'`NCt~ ~ti.5 ~j~-c,.~hvi~~~ t~c7 ~t b~_~`~5~~ CXSrc~CS.R~~c~~C~~ 25. Circulate hole clean and ull back to +/- 13000' MD. Perform an o en hole sidetrack, and drill 6-1/8" horizontal ~~ p p to well TD. (LWD Program: GR/RES/PWD) . ~~~ ~~~~~ :~ ~ t~aJ • 26. Circulate the hole clean and pull out of hole. 27. Run 3-%2, 9.3#, L-80 EUE Mod tubing with TRMAXX SSSV, gas lift mandrels, sliding sleeve, packer XN nipple, and wireline entry guide. Land hanger. 28. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 29. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 30. Circulate tubing to diesel and install freeze protection in the annulus. 31. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. 32. Set BPV and secure well. Move rig off. • • Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD3-114 is the nearest to the CD3-113 plan with 16.8' well to well separation at 550' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Nechelik reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD3-113 will be injected into a permitted annulus on CD3 or the class 2 disposal well on CD1 pad. The CD3-113 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 1500' TVD. The known significant hydrocarbon zones are the Nechelik and Kuparuk reservoirs and there will be more than 500' of cement fill above the top of the Kuparuk per regulations. If the Qannik interval is determined to be significant, it will be isolated with cement as well. Upon completion of CD3-113 form 10-403, Application for Sundry Operations -Annular Disposal, 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. 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-Mod 3090 psi 2626 psi 5750 psi 4888 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi ~~^~~,~ A .v= ~`~r ... ~ ~~ .. • • DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing oint - 12'/" Intermediate hole to 7" casing point - 8 %2" Production Hole Section - 6 1/8" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.0-9.3 ppg 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: 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 Nechelik 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 ± 30PPB 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. i , • CD3-113 Completion Schematic 16" Conductor to 114' 9-5/8" 40 ppf L-80 BTC-Mod Surface Casing @ 2506' MD / 2400' TVD cemented to surface TOC @ +/- 4296' MD 13698' ND L~ CD3-113P.B'( Well TD at X1,/1 Baker Premier Packer at +/_ 8600' MD 13518' MD / 6884' TVD I - l +/- 250 ND above Nechelik / I ` ~7 i ~ i ---_ -- -- ~ KOP @ 13000' MD - Well TD at Updated 01/09/07 Sperry Drilling Services Directional Plan WP03 Completion MD ND ', Qannik interval top +/- 4796' MD / 4058' TVD' Tubing Hanger 32' 32' 4-''/2" 12.6#/ft IBT-Mod Tubing (2 jts) Crossover 3-''/2' 9.3 #/ft EUE-Mod Tubing Camco TRMAXX-5E SSSV (2.812" ID) 2035' 2000' 3-1/2" 9.3 ppf L-80 EUE M 3-'/~' 9.3 #/ft EUE-Mod Tubing tubing run with Jet Lube Run'n'Seal Camco KBMG GLM (2.867" ID) 3882' 3400' pipe dope 3-'/" 9.3 #/ft EUE-Mod Tubing Camco KBMG GLM (2.867" ID) 6937 5600' 3-''/2' 9.3 #/ft EUE-Mod Tubing Camco KBMG GLM (2.867" ID) 8460' 6608' 3-''/2' tubing joints (2) Baker 3-1 /2" CMD sliding sleeve 8520' 6637' w/ 2.813" X Profile 3-''/2' tubing joints (2) Baker Premier Packer (63.5°) 8600' 6874' 3-''/i' tubing 1 joint HES XN 2.813" (2.75" NoGo)-64.6° inc 8650 6696' 3-1/2" 10' pup joint WEG 8662 6701' Top Kuparuk C 8919' MD / 6798' ND Top Nechelik 9446' MD / 6916' ND Packer Fluid mix: 9.4 pia KCI Brine with 1500' ND diesel cap 17484' MD / 6899' TVD , 7" 26 ppf L-80 BTC Mod Production Casing @ 9476' MD / 6919' ND @ 84° OR161~!:1L • CD3-113 PRESSURE INFORMATION (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 2506 / 2400 14.5 1086 1570 7" 9476 / 6919 16.0 3130 2438 N/A 17484 / 6899 16.0 3122 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) = 3130 - (0.1 x 6919) = 2438 psi 3. Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3122 - (0.1 x 6899') = 2432 psi QR!~~n~,~,~.. • Cementing Program: 9 5/8" Surface Casing run to 2506' MD / 2400' TVD. Cement from 2506' MD to 2006' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2006' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1263' MD). Lead slurry: (2006'-1504') X 0.3132 ft3/ft X 1.5 (50% excess) = 235.8 ft3 below permafrost 1504' X 0.3132 ft3/ft X 4 (300% excess) = 1884.2 ft3 above permafrost Total volume = 235.8 + 1884.2 = 2120 ft3 => 477 Sx @ 4.45 ft3/sk System: 477 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% BWOWI 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% S002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 9476' MD / 6919' TVD Cement from 9476' MD to 7976' MD with Class G + adds @ 15.8 PPG and from 7976' MD to 4296' MD (+/- 500' above the K2) with LiteCRETE @ 11.0 ppg. Assume 40% excess annular volume. Lead: (7976' - 4296') X 0.1503 ft3/ft X 1.4 (40% excess) = 774.3 ft3 annular volume Total volume = 774.3 ft3 => 231.2 Sx @ 3.35 ft3/sk System: 232 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: (9476' -7976') X 0.1503 ft3/ft X 1.4 (40% excess) = 315.6 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 315.6 + 17.2 = 332.8 ft3 => 287 Sx @ 1.16 ft3/sk System: 287 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D804 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk ' By Weight Of mix Water, all other additives are B~ ~ i ~~/r ,~ ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 1/10/2007 Time: 13:51:53 Page: 1 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: CD3-113, True North ~ Site: Alpine CD3 Vertical (TVD) Reference: Plan: CD3-11349.4 Well: Plan: CD3-113 Section (VS) Reference: Well (O.OON,O.OOE,302.50Azi) Wellpath: Plan; CD3-113PB1 Survey Calculation Method: Minimum Curvature , Db: Orate Plan Section Information MD Incl Azim TVD +N/-S +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 `1000.00 0.00 0.00 1000.00 0.00 0.00 0.00 0.00 0.00 0.00 2757.74 43.94 279.01 2590.41 100.49 -633.74 2.50 2.50 0.00 0.00 7601.74 43.94 279.01 6078.22 626.94 -3953.74 0.00 0.00 0.00 0.00 9475.69 84.00 324.85 6919.40 1567.42 -5237.00 3.00 2.14 2.45 59.14 CD3-113P61wp03 T1 9489.60 84.42 324.83 6920.80 1578.74 -5244.97 3.00 2.99 -0.19 -3:70 9690.29 84.42 324.83 6940.33 1742.01 -5360.02 0.00 0.00 0.00 0.00 9876.45 90.00 324.94 6949.40 1894.04 -5466.94 3.00 3.00 0.06 1.17 CD3-113P61wp03 T2 10076.45 92.00 324.94 6945.91 2057.72 -5581.80 1.00 1.00 0.00 0.00 10645.05 92.00 324.94 6926.07 2522.87 -5908.21 0.00 0.00 0.00 0.00 11600.03 90.00 324.94 6909.40 3304.42 -6456.67 0.21 -0.21 0.00 180.03 11800.03 88.00 324.94 6912.89 3468.10 -6571.53 1.00 -1.00 0.00 180.00 11889.03 88.00 324.94 6916.00 3540.90 -6622.62 0.00 0.00 0.00 0.00 13000.89 90.00 324.94 6935.40 4450.83 -7261.18 0.18 0.18 0.00 360.00 13303.59 98.00 316.86 6914.27 4684.85 -7451.22 3.75 2.64 -2.67 -45.00 13518.19 98.00 316.86 6884.40 4839.92 -7596.54 0.00 0.00 0.00 270.00 Plan: CD3-113PB1wp03 Date Composed: 12/8/2006 Version: 12 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 Geo Datum: NAD27 (Clarke 1866) Map Zone: Coordinate System: Alaska, Zone 4 Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: Alpine CD3 Site Position: Northing: 6003886.80 ft Latitude: 70 25 10.481 N From: Map Easting: 388488.10 ft Longitude: 150 54 30.391 W Position Uncertainty: 0.00 ft Ground Level: 0.00 ft North Reference: Grid Convergence: True -0.86 deg Well: Plan: CD3-113 Slot Name: Well Position: +N/-S -71.75 ft Northing: 6003820.41 ft ~ Latitude: 70 25 9.775 N +E/-W -357.63 ft Easting : 388129.47 ft~ Longitude: 150 54 40.878 W Position Uncertainty: 0.00 ft Wellpath: Plan: CD3-113PB1 Dril-ed From: Tie-on Depth: Well Ref. Point 36.30 ft Current Datum: Plan: CD3-113 Hei ght 49.40 ft Above System Datum: Mean Sea Level Magnetic Data: 12/2/2004 Field Strength: 57515 nT Declination: Mag Dip Angle: 23.88 deg 80.71 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.30 0.00 0.00 302.50 Survey Program for Definitive Wellpath Date: 12/8/2006 Validated: No V ersion: 5 Actual From To Survey T oolcode Tool Name ft ft ORIGINAL WELL DETAILS Name +N/-S +E/-W Northing Easting Latitude Longitude S-ot Plan: CD3-113 -71.75 -357.63 6003820.41 388129.47 70°25'09.775N 150°54'40.878W N/A WELLPATH DETAILS Plan: CD3-113PB1 Rig: Doyon 19 Ref. Datum: Plan: CD3-113 49.40ft V.Section Origin Origin Starting Angle +N/-S +E/-W From TVD 302.50° 0.00 0.00 36.30 T M Azimuths to True North Magnetic North: 23.88° Magnetic Field Strength: 57515nT Dip Angle: 80.71° Date: 12/2/2004 Model: bggm2006 SURVEY PROGRAM Depth Fm Depth To Survey/Plan Tool 36.30 1000.00 Planned: CD3-113PB1wp03 V9 CB-GYRO-SS 1000.00 13518.19 Planned: CD3-113PB1wp03 V9 MWD+IFR-AK-CAZ-SC a 0 a 2 F Vertical Section at 302.50° [2000ft/in] 1250 1000 750 o L CD3-113P B1 03 500 v I ~ I 250 ~ c ° ° , o h o c 7 M -250 -12500 -10000 -7500 -5000 -2500 0 2500 5000 West(-)/8as[(+) [SOOOft/in] PLAN DETAILS CD3-113PB1wp03 Version 9 12/8/2006 Start Point MD Inc Azi TVD 36.30 0.00 0.00 36.30 +N/-S +E/-W 0.00 0.00 HALLlBURTON Sperry DMlfing ser~ric~s Corx~coPhillips Alaska REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: Plan: CD3-113, True North Vertical (TVD) Reference: Plan: CD3-113 49.40 Section (VS) Reference: Slot - (O.DON,O.OOE) Measured Depth Reference: Plan: CD3-113 49.40 Calculation Method: Minimum Curvature • ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 1/10!2007 Time: 13:51:53 Page: 2 Field: Colville RiverUnit Co-ordinate(NE) Referenee: Well: Plan: CD3- 113, True North Site: Alpine CD3 Vertica l (TVD) Reference: Plan: CD3-113 49.4 Well: Plan: CD3-1 13 Section (VS) Reference: Well (O.OON,O.OOE,302.50Azi) Wellpatb: Plan: CD3-1 13PB1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inc! Azim TVD Sys TVD N/S E/W MapN MapE DLS VS Comme t ft deg deg ft ft ft ft ft ft deg/100ft ft 36.30 0.00 0.00 36.30 -13.10 0.00 0.00 6003820.41 388129.47 0.00 0.00 100.00 0.00 0.00 100.00 50.60 0.00 0.00 6003820.41 388129.47 0.00 0.00 200.00 0.00 0.00 200.00 150.60 0.00 0.00 6003820.41 388129.47 0.00 0.00 300.00 0.00 0.00 300.00 250.60 0.00 0.00 6003820.41 388129.47 0.00 0.00 400.00 0.00 0.00 400.00 350.60 0.00 0.00 6003820.41 388129.47 0.00 0.00 500.00 0.00 0.00 500.00 450.60 0.00 0.00 6003820.41 388129.47 0.00 0.00 600.00 0.00 0.00 600.00 550.60 0.00 0.00 6003820.41 388129.47 0.00 0.00 700.00 0.00 0.00 700.00 650.60 0.00 0.00 6003820.41 388129.47 0.00 0.00 800.00 0.00 0.00 800.00 750.60 0.00 0.00 6003820.41 388129.47 0.00 0.00 900.00 0.00 0.00 900.00 850.60 0.00 0.00 6003820.41 388129.47 0.00 0.00 000.00 0.00 0.00 1000.00 950.60 0.00 0.00 6003820.41 388129.47 0.00 0.00 KOP; 2.5 DLS, 1 i 1100.00 2.50 279.01 1099.97 1050.57 0.34 -2.15 6003820.78 388127.32 2.50 2.00 1200.00 5.00 279.01 1199.75 1150.35 1.37 -8.61 6003821.90 388120.88 2.50 8.00 1249.49 6.24 279.01 1249.00 1199.60 2.12 -13.40 6003822.74 388116.11 2.50 12.44 Base Permafrost 1300.00 7.50 279.01 1299.14 1249.74 3.07 -19.36 6003823.77 388110.15 2.50 17.98 1400.00 10.00 279.01 1397.97 1348.57 5.45 -34.39 6003826.38 388095.17 2.50 31.93 1500.00 12.50 279.01 1496.04 1446.64 8.51 -53.66 6003829.72 388075.95 2.50 49.82 1600.00 15.00 279.01 1593.17 1543.77 12.23 -77.13 6003833.79 388052.54 2.50 71.62 1700.00 17.50 279.01 1689.17 1639.77 16.61 -104.76 6003838.59 388024.98 2.50 97.28 1800.00 20.00 279.01 1783.85 1734.45 21.65 -136.51 6003844.10 387993.31 2.50 126.76 1900.00 22.50 279.01 1877.05 1827.65 27.32 -172.30 6003850.31 387957.61 2.50 160.00 2000.00 25.00 279.01 1968.57 1919.17 33.63 -212.08 6003857.21 387917.94 2.50 196.93 2100.00 27.50 279.01 2058.25 2008.85 40.56 -255.76 6003864.79 387874.37 2.50 237.49 2200.00 30.00 279.01 2145.92 2096.52 48.09 -303.26 6003873.03 387826.99 2.50 281.60 2300.00 32.50 279.01 2231.40 2182.00 56.21 -354.49 6003881.92 387775.89 2.50 329.17 2400.00 35.00 279.01 2314.54 2265.14 64.91 -409.36 6003891.44 387721.17 2.50 380.12 2430.00 35.75 279.01 2339.00 2289.60 67.63 -426.51 6003894.42 387704.06 2.50 396.05 C-40 2500.00 37.50 279.01 2395.18 2345.78 74.17 -467.76 6003901.58 387662.92 2.50 434.35 2506.08 37.65 279.01 2400.00 2350.60 74.75 -471.42 6003902.21 387659.26 2.50 437.75 9 5/8" 2600.00 40.00 279.01 2473.16 2423.76 83.97 -529.57 6003912.30 387601.26 2.50 491.75 2618.13 40.45 279.01 2487.00 2437.60 85.81 -541.13 6003914.31 387589.73 2.50 502.48 C-30 2700.00 42.50 279.01 2548.34 2498.94 94.30 -594.69 6003923.60 387536.31 2.50 552.21 2757.74 43.94 279.01 2590.41 2541.01 100.49 -633.74 6003930.38 387497.36 2.50 588.47 Sail; 44° inc for 1 2800.00 43.94 279.01 2620.84 2571.44 105.08 -662.70 6003935.40 387468.47 0.00 615.37 2900.00 43.94 279.01 2692.84 2643.44 115.95 -731.24 6003947.30 387400.11 0.00 679.01 3000.00 43.94 279.01 2764.85 2715.45 126.82 -799.78 6003959.19 387331.75 0.00 742.66 3100.00 43.94 279.01 2836.85 2787.45 137.69 -868.32 6003971.08 387263.39 0.00 806.30 3147.43 43.94 279.01 2871.00 2821.60 142.84 -900.83 6003976.72 387230.96 0.00 836.49 C-20 3200.00 43.94 279.01 2908.85 2859.45 148.56 -936.86 6003982.98 387195.02 0.00 869.94 3300.00 43.94 279.01 2980.85 2931.45 159.42 -1005.40 6003994.87 387126.66 0.00 933.59 3400.00 43.94 279.01 3052.86 3003.46 170.29 -1073.93 6004006.76 387058.30 0.00 997.23 3500.00 43.94 279.01 3124.86 3075.46 181.16 -1142.47 6004018.65 386989.94 0.00 1060.87 3600.00 43.94 279.01 3196.86 3147.46 192.03 -1211.01 6004030.55 386921.58 0.00 1124.52 3700.00 43.94 279.01 3268.86 3219.46 202.90 -1279.55 6004042.44 386853.21 0.00 1188.16 3800.00 43.94 279.01 3340.87 3291.47 213.76 -1348.09 6004054.33 386784.85 0.00 1251.80 3900.00 43.94 279.01 3412.87 3363.47 224.63 -1416.63 6004066.23 386716.49 0.00 1315.44 4000.00 43.94 279.01 3484.87 3435.47 235.50 -1485.16 6004078.12 386648.13 0.00 1379.09 4100.00 43.94 279.01 3556.87 3507.47 246.37 -1553.70 6004090.01 386579.77 0.00 1442.73 4200.00 43.94 279.01 3628.88 3579.48 257.24 -1622.24 6004101.90 386511.40 0.00 1506.37 4300.00 43.94 279.01 3700.88 3651.48 268.10 -1690.78 6004113.80 386443.04 0.00 1570.02 4400.00 43.94 279.01 3772.88 3723.48 278.97 -1759.32 6004125.69 386374.68 0.00 1633.66 4500.00 43.94 279.01 3844.88 3795.48 289.84 -1827.86 6004137.58 386306.32 0.00 1697.30 4554.32 43.94 279.01 3884.00 3834.60 295.74 -1865.09 6004144.04 386269.18 0.00 1731.88 K-3 ~~ ~~ ~ SAL ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Ina Date: 1/10/2007 Time: 13:51:53 Page: 3 Field: Colville Rive r Unit Co-ordi nate(NE) Reference: Welt:. Plan:. CD3- 113, True North Site: Alpine CD3 Vertical (TVD) Reference: Plan: CD3-113 49.4 Well: Plan: CD3-1 13 Section (VS) Reference: Weil{O.OON,O.OOE,302.50Azi) Wellpath: Plan: CD3-1 13PB1 Survey Caleulation Method: Minimum CuNature Db: OraGe Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DLS VS Comme t ft deg deg ft ft ft ft ft ft deg/100ft ft 4600.00 43.94 279.01 3916.89 3867.49 300.71 -1896.40 6004149.48 386237.96 0.00 1760.95 4700.00 43.94 279.01 3988.89 3939.49 311.58 -1964.93 6004161.37 386169.59 0.00 1824.59 4752.93 43.94 279.01 4027.00 3977.60 317.33 -2001.21 6004167.66 386133.41 0.00 1858.28 K-3 Basal 4794.59 43.94 279.01 4057.00 4007.60 321.86 -2029.77 6004172.62 386104.93 0.00 1884.79 K-2 4800.00 43.94 279.01 4060.89 4011.49 322.45 -2033.47 6004173.26 386101.23 0.00 1888.23 4900.00 43.94 279.01 4132.89 4083.49 333.31 -2102.01 6004185.16 386032.87 0.00 1951.88 4940.42 43.94 279.01 4162.00 4112.60 337.71 -2129.72 6004189.96 386005.24 0.00 1977.60 K-2 Basal 5000.00 43.94 279.01 4204.90 4155.50 344.18 -2170.55 6004197.05 385964.51 0.00 2015.52 5100.00 43.94 279.01 4276.90 4227.50 355.05 -2239.09 6004208.94 385896.15 0.00 2079.16 5200.00 43.94 279.01 4348.90 4299.50 365.92 -2307.63 6004220.83 385827.78 0.00 2142.81 5300.00 43.94 279.01 4420.91 4371.51 376.79 -2376.16 6004232.73 385759.42 0.00 2206.45 5400.00 43.94 279.01 4492.91 4443.51 387.65 -2444.70 6004244.62 385691.06 0.00 2270.09 5500.00 43.94 279.01 4564.91 4515.51 398.52 -2513.24 6004256.51 385622.70 0.00 2333.73 5600.00 43.94 279.01 4636.91 4587.51 409.39 -2581.78 6004268.41 385554.34 0.00 2397.38 5700.00 43.94 279.01 4708.92 4659.52 420.26 -2650.32 6004280.30 385485.97 0.00 2461.02 5800.00 43.94 279.01 4780.92 4731.52 431.13 -2718.86 6004292.19 385417.61 0.00 2524.66 5900.00 43.94 279.01 4852.92 4803.52 441.99 -2787.40 6004304.08 385349.25 0.00 2588.31 6000.00 43.94 279.01 4924.92 4875.52 452.86 -2855.93 6004315.98 385280.89 0.00 2651.95 6100.00 43.94 279.01 4996.93 4947.53 463.73 -2924.47 6004327.87 385212.53 0.00 2715.59 6200.00 43.94 279.01 5068.93 5019.53 474.60 -2993.01 6004339.76 385144.16 0.00 2779.24 6300.00 43.94 279.01 5140.93 5091.53 485.47 -3061.55 6004351.66 385075.80 0.00 2842.88 6400.00 43.94 279.01 5212.93 5163.53 496.33 -3130.09 6004363.55 385007.44 0.00 2906.52 6500.00 43.94 279.01 5284.94 5235.54 507.20 -3198.63 6004375.44 384939.08 0.00 2970.17 6600.00 43.94 279.01 5356.94 5307.54 518.07 -3267.16 6004387.34 384870.72 0.00 3033.81 6700.00 43.94 279.01 5428.94 5379.54 528.94 -3335.70 6004399.23 384802.35 0.00 3097.45 6800.00 43.94 279.01 5500.94 5451.54 539.81 -3404.24 6004411.12 384733.99 0.00 3161.10 6825.08 43.94 279.01 5519.00 5469.60 542.53 -3421.43 6004414.10 384716.85 0.00 3177.06 Albian 97 6900.00 43.94 279.01 5572.95 5523.55 550.67 -3472.78 6004423.01 384665.63 0.00 3224.74 7000.00 43.94 279.01 5644.95 5595.55 561.54 -3541.32 6004434.91 384597.27 0.00 3288.38 7100.00 43.94 279.01 5716.95 5667.55 572.41 -3609.86 6004446.80 384528.91 0.00 3352.02 7200.00 43.94 279.01 5788.95 5739.55 583.28 -3678.39 6004458.69 384460.54 0.00 3415.67 7300.00 43.94 279.01 5860.96 5811.56 594.15 -3746.93 6004470.59 384392.18 0.00 3479.31 7330.62 43.94 279.01 5883.00 5833.60 597.47 -3767.92 6004474.23 384371.25 0.00 3498.80 Albian 96 7400.00 43.94 279.01 5932.96 5883.56 605.01 -3815.47 6004482.48 384323.82 0.00 3542.95 7500.00 43.94 279.01 6004.96 5955.56 615.88 -3884.01 6004494.37 384255.46 0.00 3606.60 7600.00 43.94 279.01 6076.96 6027.56 626.75 -3952.55 6004506.26 384187.10 0.00 3670.24 7601.74 43.94 279.01 6078.22 6028.82 626.94 -3953.74 6004506.47 384185.90 0.00 3671.35 Build; 3 DLS 7700.00 45.51 282.56 6148.04 6098.64 639.90 -4021.64 6004520.45 384118.22 3.00 3735.58 7800.00 47.21 285.97 6217.05 6167.65 657.76 -4091.75 6004539.35 384048.39 3.00 3804.30 7900.00 49.01 289.20 6283.83 6234.43 680.27 -4162.69 6004562.93 383977.80 3.00 3876.22 8000.00 50.89 292.25 6348.17 6298.77 707.38 -4234.26 6004591.10 383906.65 3.00 3951.15 8100.00 52.85 295.14 6409.92 6360.52 739.01 -4306.26 6004623.80 383835.13 3.00 4028.87 8200.00 54.88 297.88 6468.89 6419.49 775.07 -4378.51 6004660.94 383763.44 3.00 4109.18 8300.00 56.96 300.49 6524.93 6475.53 815.47 -4450.80 6004702.42 383691.77 3.00 4191.85 8400.00 59.10 302.97 6577.88 6528.48 860.09 -4522.93 6004748.11 383620.33 3.00 4276.66 8425.76 59.66 303.59 6591.00 6541.60 872.26 -4541.46 6004760.55 383601.98 3.00 4298.83 Top HRZ 8500.00 61.28 305.34 6627.60 6578.20 908.82 -4594.70 6004797.90 383549.30 3.00 4363.38 8595.65 63.40 307.52 6672.00 6622.60 959.14 -4662.84 6004849.23 383481.93 3.00 4447.88 Base HRZ 8600.00 63.50 307.62 6673.95 6624.55 961.51 -4665.93 6004851.65 383478.88 3.00 4451.76 8700.00 65.75 309.81 6716.80 6667.40 1018.03 -4736.41 6004909.21 383409.26 3.00 4541.57 8700.49 65.77 309.82 6717.00 6667.60 1018.32 -4736.75 6004909.50 383408.92 3.00 4542.01 K-1 8800.00 68.04 311.92 6756.04 6706.64 1078.22 -4805.94 6004970.43 383340.64 3.00 4632.56 ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 1N0/2007 Time: 13:51:53 Page: 4 Field: Colville River Unit Co-ordinate(NE) Reference: .Well: Plan: CD3-113, True North Site:: Alpine CD3 Vertical (TVD) Reference: Plan: CD3-113 49.4 We1L• Plan: CD3-113 Section (VS) Reference: Welt {O.OON,O.OOE,302.50AzO Wellpatb: Plan: CD3-113PB1 Survey Calculation Methods AAinimum Curvature Db: Aracle Survey MD ft 8802.58 8900.00 8916.34 8922.43 9000.00 9100.00 9107.60 9200.00 9300.00 9400.00 9436.64 9475.69 9489.60 9500.00 9600.00 9690.29 9700.00 9800.00 9876.45 9900.00 10000.00 10076.45 10100.00 10200.00 10300.00 10400.00 10500.00 10600.00 10645.05 10700.00 10800.00 10900.00 11000.00 11100.00 11200.00 11300.00 11400.00 11500.00 11600.00 11700.00 11800.00 11889.03 11900.00 12000.00 12100.00 12200.00 12300.00 12400.00 12500.00 12600.00 12700.00 12800.00 12900.00 Incl Azim TVD Sys TVD N/S E/W deg deg ft ft ft ft 68.10 311.98 6757.00 6707.60 1079.81 -4807.72 70.35 313.97 6791.56 6742.16 1141.91 -4874.35 70.73 314.30 6797.00 6747.60 1152.64 -4885.41 70.87 314.42 6799.00 6749.60 1156.65 -4889.52 72.69 315.96 6823.26 6773.86 1208.93 -4941.44 75.04 317.89 6851.05 6801.65 1279.09 -5007.03 75.22 318.04 6853.00 6803.60 1284.55 -5011.95 77.41 319.79 6874.86 6825.46 1352.21 -5070.94 79.79 321.65 6894.63 6845.23 1428.09 -5132.99 82.18 323.48 6910.30 6860.90 1506.51 -5193.01 83.06 324.15 6915.00 6865.60 1535.83 -5214.46 84.00 324.85 6919.40 6870.00 1567.42 -5237.00 84.42 324.83 6920.80 6871.40 1578.74 -5244.97 84.42 324.83 6921.82 6872.42 1587.20 -5250.93 84.42 324.83 6931.55 6882.15 1668.55 -5308.26 84.42 324.83 6940.33 6890.93 1742.01 -5360.02 84.71 324.83 6941.25 6891.85 1749.91 -5365.59 87.71 324.89 6947.87 6898.47 1831.50 -5423.01 90.00 324.94 6949.40 6900.00 1894.04 -5466.94 90.24 324.94 6949.35 6899.95 1913.32 -5480.46 91.24 324.94 6948.07 6898.67 1995.17 -5537.90 92.00 324.94 6945.91 6896.51 2057.72 -5581.80 92.00 324.94 6945.09 6895.69 2076.99 -5595.32 92.00 324.94 6941.60 6892.20 2158.79 -5652.72 92.00 324.94 6938.11 6888.71 2240.60 -5710.13 92.00 324.94 6934.62 6885.22 2322.41 -5767.54 92.00 324.94 6931.13 6881.73 2404.21 -5824.94 92.00 324.94 6927.64 6878.24 2486.02 -5882.35 92.00 324.94 6926.07 6876.67 2522.87 -5908.21 91.88 324.94 6924.20 6874.80 2567.83 -5939.76 91.68 324.94 6921.10 6871.70 2649.64 -5997.17 91.47 324.94 6918.36 6868.96 2731.47 -6054.59 91.26 324.94 6915.98 6866.58 2813.30 -6112.02 91.05 324.94 6913.97 6864.57 2895.14 -6169.45 90.84 324.94 6912.32 6862.92 2976.98 -6226.88 90.63 324.94 6911.05 6861.65 3058.83 -6284.32 90.42 324.94 6910.13 6860.73 3140.68 -6341.76 90.21 324.94 6909.58 6860.18 3222.54 -6399.21 90.00 324.94 6909.40 6860.00 3304.39 -6456.65 89.00 324.94 6910.27 6860.87 3386.24 -6514.09 88.00 324.94 6912.89 6863.49 3468.07 -6571.51 88.00 324.94 6916.00 6866.60 3540.90 -6622.62 88.02 324.94 6916.38 6866.98 3549.88 -6628.92 88.20 324.94 6919.68 6870.28 3631.69 -6686.33 88.38 324.94 6922.66 6873.26 3713.51 -6743.75 88.56 324.94 6925.33 6875.93 3795.33 -6801.17 88.74 324.94 6927.69 6878.29 3877.16 -6858.60 88.92 324.94 6929.73 6880.33 3959.00 -6916.03 89.10 324.94 6931.46 6882.06 4040.84 -6973.47 89.28 324.94 6932.88 6883.48 4122.69 -7030.90 89.46 324.94 6933.98 6884.58 4204.54 -7088.34 89.64 324.94 6934.77 6885.37 4286.39 -7145.79 89.82 324.94 6935.24 6885.84 4368.25 -7203.23 MapN MapE DLS VS Comm ft ft deg/100ft ft 6004972.05 383338.88 3.00 4634.91 Top Kuparuk D 6005035.13 383273.20 3.00 4724.47 6005046.03 383262.30 3.00 4739.57 Top Kuparuk C 6005050.10 383258.25 3.00 4745.19 Top Nuiqsut 6005103.15 383207.12 3.00 4817.07 6005174.28 383142.60 3.00 4910.08 6005179.81 383137.77 3.00 4917.16 Base Nuiqsut 6005248.34 383079.80 3.00 5003.27 6005325.13 383018.90 3.00 5096.37 6005404.43 382960.06 3.00 5189.13 6005434.07 382939.06 3.00 5222.98 Top Nechelik 6005466.00 382917.00 3.00 5258.96 CD3-113P61w1 6005477.43 382909.20 2.99 5271.76 6005485.98 382903.37 0.00 5281.33 6005568.17 382847.27 0.00 5373.40 6005642.39 382796.61 0.00 5456.53 6005650.37 382791.17 3.00 5465.47 6005732.81 382734.98 3.00 5557.73 6005796.00 382692.00 3.00 5628.39 CD3-113P61w1 6005815.47 382678.76 1.00 5650.15 6005898.17 382622.56 1.00 5742.57 6005961.37 382579.61 1.00 5813.21 6005980.83 382566.39 0.00 5834.96 6006063.48 382510.22 0.00 5927.33 6006146.13 382454.05 0.00 6019.70 6006228.78 382397.88 0.00 6112.08 6006311.43 382341.71 0.00 6204.45 6006394.08 382285.54 0.00 6296.82 6006431.32 382260.23 0.00 6338.44 6006476.73 382229.37 0.21 6389.20 6006559.39 382173.19 0.21 6481.58 6006642.06 382117.01 0.21 6573.97 6006724.74 382060.82 0.21 6666.38 6006807.42 382004.63 0.21 6758.79 6006890.11 381948.43 0.21 6851.20 6006972.81 381892.23 0.21 6943.62 6007055.50 381836.03 0.21 7036.05 6007138.20 381779.82 0.21 7128.48 6007220.90 381723.62 0.21 7220.91 6007303.60 381667.41 1.00 7313.33 6007386.27 381611.23 1.00 7405.73 6007459.85 381561.22 0.00 7487.97 6007468.92 381555.06 0.18 7498.10 6007551.57 381498.88 0.18 7590.48 6007634.23 381442.70 0.18 7682.87 6007716.90 381386.52 0.18 7775.26 6007799.58 381330.33 0.18 7867.67 6007882.26 381274.13 0.18 7960.08 6007964.95 381217.94 0.18 8052.49 6008047.64 381161.74 0.18 8144.91 6008130.34 381105.53 0.18 8237.34 6008213.03 381049.33 0.18 8329.76 6008295.73 380993.13 0.18 8422.19 T1 r2 • ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Ina Date: 1/10/2007 Time: 13:51:53 Page: 5 Field: Colville River Unit Co-ord inate(NE) Reference: Well: Plan: CD3-113, True North. Site: Alpine CD3 Vertical (TVD) Reference: Plan: CD3-113 49.4 Well: Plan: CD3- 113 Section (VS) Reference: Well (O.OON,O.OOE,302.50Azi) Wellpatb: Plan: CD3- 113P61 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DLS VS Comme t ft deg deg ft ft ft ft ft ft deg/100ft ft 13000.00 90.00 324.94 6935.40' 6886.00 4450.10 -7260.67 6008378.43 380936.92 0.18 8514.62 6 1/8" OH 13100.00 92.63 322.31 6933.13 6883.73 4530.60 -7319.94 6008459.80 380878.87 3.72 8607.85 13200.00 95.27 319.65 6926.24 6876.84 4608.09 -7382.73 6008538.22 380817.25 3.75 8702.46 13300.00 97.91 316.96 6914.76 6865.36 4682.25 -7448.80 6008613.35 380752.31 3.75 8798.02 13303.59 98.00 316.86 6914.27 6864.87 4684.85 -7451.22 6008615.98 380749.92 3.75 8801.46 13400.00 98.00 316.86 6900.85 6851.45 4754.51 -7516.51 6008686.62 380685.70 0.00 8893.96 13500.00 98.00 316.86 6886.93 6837.53 4826.77 -7584.22 6008759.88 380619.08 0.00 8989.89 / 13518.19 '98.00 316.86 6884.40 ~ 6835.00 4839.92 -7596.54 6008773.20 380606.96 0.00 9007.34 TD Targets Map Map. <--- Latitude ----> <_- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft CD3-113wp03 T3 6899.40 8115.85 -9833.04 6012082.00 378420.00 70 26 29.529 N 150 59 29.531 W CD3-113P61wp03 T1 6919.40 1567.42 -5237.00 6005466.00 382917.00 70 25 25.172 N 150 57 14.477 W CD3-113P61wp03 T2 6949.40 1894.04 -5466.94 6005796.00 382692.00 70 25 28.383 N 150 57 21.228 W Annotation MD TVD ft ft 1000.00 1000.00 KOP; 2.5 DLS, 1000' MD 2506.08 2400.00 9 5/8" csg pt; 2506' MD, 2400' TVD 2757.74 2590.41 Sail; 44° inc for 1758' 7601.74 6078.22 Build; 3 DLS 9475.69 6919.40 7" csg pt; 9475' MD, 6919' TVD 13000.00 6935.40 Steep climb to 6835' ssTVD 13518.19 6884.40 TD Casing Points MD TVD Diameter Hole Size Name ft ft in in 2506.08 2400.00 9.625 12.250 9 5/8" 9475.69 6919.40 7.000 8.750 7" 13000.00 6935.40 6.125 6.125 6 1/8" OH Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 1249.49 1249.00 Base Permafrost 0.00 0.00 2430.00 2339.00 C-40 0.00 0.00 2618.13 2487.00 C-30 0.00 0.00 3147.43 2871.00 C-20 0.00 0.00 4554.32 3884.00 K-3 0.00 0.00 4752.93 4027.00 K-3 Basal 0.00 0.00 4794.59 4057.00 K-2 0.00 0.00 4940.42 4162.00 K-2 Basal 0.00 0.00 6825.08 5519.00 Albian 97 0.00 0.00 7330.62 5883.00 Albian 96 0.00 0.00 8425.76 6591.00 Top HRZ 0.00 0.00 8595.65 6672.00 Base HRZ 0.00 0.00 8700.49 6717.00 K-1 0.00 0.00 8802.58 6757.00 Top Kuparuk D 0.00 0.00 8916.34 6797.00 Top Kuparuk C 0.00 0.00 8922.43 6799.00 LCU 0.00 0.00 8922.43 6799.00 Top Nuigsut 0.00 0.00 ~~~ ~ ~ A ~. • • ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 1!10!2007 Time: 13:51:53 Pager. 6 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: CD3-113, True North Site: Alpine CD3 Vertical (TVD) Reference: Plan: CD3-113 49.4 Well: Plan: CD3-113 Section (VS) Reference: Well (O.OON,O.OOE,302.50Azi) Wellpath: Plan: CD3-Y13PB1 Survey Calcnlation Method: Minimum Curvature Dh: Oracle Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 9107.60 6853.00 Base Nuiqsut 0.00 0.00 9436.64 6915.00 Top Nechelik 0.00 0.00 . . ~. • • ConocoPhillips Alaska, Inc. Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 1/10/2007 Time: 13:01:59 Pager 1 Field: Colville River Unit Reference Site: Alpine CD3 Co-ordinate(NE) Reference: Well: Plan: CD3-113, True North Reference Well: Plan: CD3-113 Vertical (TVD) Reference: Plan: CD3-113 49.4 Reference Wellpath: Plan: CD3-113P61 Db: OraGe GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: CD3-113P61wp03 & NOT PLANN Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 36.30 to 1351 8.19 ft Scan Method: Trav Cylinder No rth Maximum Radius: 1548.19 ft Error Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft in in 2506.08 2400.00 9.625 12.250 9 5/8" 9475.69 6919.4 0 7.000 8.750 7" 13000.00 6935.40 6.125 6.125 6 1/8" OH Plan: CD3-1 13P61wp03 Date Composed: 12/8/2006 Version: 10 Principal: Yes Tied-to: From Well Ref. Point Summary <__w___________ Offset Wellpath -- ---------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Alpine CD3 CD3-108 CD3-108 V14 273.28 275.00 102.30 5.00 97.29 Pass: Major Risk Alpine CD3 CD3-109 CD3-109 V5 424.73 425.00 81.85 8.45 73.40 Pass: Major Risk Alpine CD3 CD3-110 CD3-110 V11 324.67 325.00 62.00 6.21 55.79 Pass: Major Risk Alpine CD3 CD3-111 CD3-111 V7 599.59 600.00 33.79 11.52 22.27 Pass: Major Risk Alpine CD3 CD3-111 CD3-111 L1 V1 599.59 600.00 33.79 11.52 22.27 Pass: Major Risk Alpine CD3 CD3-112 CD3-112 V3 549.55 550.00 16.76 9.37 7.39 Pass: Major Risk Alpine CD3 CD3-302 CD3-302P61 V11 249.00 250.00 221.00 4.53 216.46 Pass: Major Risk Alpine CD3 CD3-302 CD3-302P62 V6 249.00 250.00 221.00 4.53 216.46 Pass: Major Risk Alpine CD3 CD3-302 Plan: CD3-302 VO Plan: 249.00 250.00 221.00 4.64 216.36 Pass: Major Risk Alpine CD3 CD3-307 CD3-307 V4 374.81 375.00 123.76 7.45 116.31 Pass: Major Risk Alpine CD3 CD3-307 Plan: CD3-107 V4 Plan: 374.81 375.00 123.76 7.56 116.20 Pass: Major Risk Alpine CD3 Plan: CD3-106 Plan: CD3-106 V2 Plan: 250.79 250.00 141.00 5.13 135.86 Pass: Major Risk Alpine CD3 Plan: CD3-113 Plan: CD3-113 V4 Plan: 13074.92 13075.00 2.32 271.51 -269.19 FAIL: Major Risk Alpine CD3 Plan: CD3-114 Plan: CD3-114 V2 Plan: 650.80 650.00 20.08 13.73 6.35 Pass: Major Risk Alpine CD3 Plan: CD3-115 Plan: CD3-115 V1 Plan: 425.80 425.00 39.81 7.89 31.92 Pass: Major Risk Alpine CD3 Plan: CD3-116 Plan: CD3-116 V1 Plan: 225.80 225.00 59.81 4.14 55.67 Pass: Major Risk Alpine CD3 Plan: CD3-117 Plan: CD3-117 V1 Plan: 225.80 225.00 79.79 4.14 75.65 Pass: Major Risk Alpine CD3 Plan: CD3-301 Plan: CD3-301 V2 Plan: 374.58 375.00 241.03 7.88 233.16 Pass: Major Risk Alpine CD3 Plan: CD3-303 Plan: CD3-303 V5 Plan: 348.60 350.00 200.84 7.20 193.64 Pass: Major Risk Alpine CD3 Plan: CD3-303 Plan: CD3-303P61 V2 PI 348.60 350.00 200.84 7.09 193.74 Pass: Major Risk Alpine CD3 Plan: CD3-304 Plan: CD3-304 V3 Plan: 348.60 350.00 180.81 7.18 173.64 Pass: Major Risk Alpine CD3 Plan: CD3-305 Plan: CD3-205 V1 Plan: 250.79 250.00 160.86 4.56 156.30 Pass: Major Risk Alpine CD3 Plan: FN-21 Plan: FN-21 VO Plan: F 361.90 325.00 99.91 6.64 93.27 Pass: Major Risk PROGRA W ELI. DETAILS ~N'-S `E-W Northing Lading Latitude Loneiwde Slut Cll3-113 -]175 -357.63 G003a2001 3RR 12917 70`25'U97]SN I50`54'd0a78W N/A 75 50 0 10 ~~qq IU>~ 0 06 (Plan. CD3-106) 10 -305 (Plan: CD3-205) (??~3_-~)-107) 20 UnpN Fm DeOtM1 Ta Sw. ac Trot Plamkd I.:D1113PBIw~P03 a"I4 0 WFT.LYATH DET4dS Plan. CU3-113PB1 wg RA Deeun. Plan-. (9?-11? i9 i0fl \'Scctian Origin Qigin Slarlmg Angle +N~~S +£'-W' From T1D 30'!50° 004 0.00 36.30 From Colour To MD 36 250 250 500 '^^ 750 1000 1250 1500 1750 2000 16000 16250 16500 16750 18250 18500 18750 19000 25000 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Sepazation [30fUin] 50 75 ANCILOLLIStON 3BT"CMG3 COMPANY DETAILS Inlerpolmion MethodMD Interval-. 25 (81 Con«oPhilliPS Alaska Lu. Ueplh Range Frnm 3630 To. 13518.79 Eng~neenng Ma<imum Range 1148.19 RcCerrncr. Plan'. CU3-113PB1wI,t13 CD}-108 (CD3-I n8)_Malnr Risk CD3-109 (CD3-109). Major lLsk CD3-110 (CIl3-I III}.Mjor Risk CD3-111 (CDJ-111), Malor Risk CU}-111 (CD}-I IILI)_Fta)or Rlsk CDJ-112 (CD3-112), Major Risk CD3-J02 (CD3-302PBI). Mayor Risk CDJ-3o21CU3-}U2PB2), Mulor Risk CD}J02 (Plw. CD3-302). Major Risk CD.3-30] ICD3-3U7). Major Ri.+k CD3-30] (Plao CD3-107). Major Risk Plan CD3-106lPlmr. CU3-IU6). Major Wsk LEGEND Plan L'D1-114 (Plan CD3-114). M jor Risk Plan. CD3-115 (Plan- CD3-115), Major Risk Plan. CD3-116 (Plan. CD3-116). Major Risk Plar. C'D1-117 (Plan. CD3-117), Mayor Risk Plan CD3-301 (Plan. CD3-101). Major Risk PIm~_ CD3-3UJ (Plan CD3-303), Major Risk Plan CD1-301 (Plan .CD3-303PB I). Mayor Risk Plmr. CD3-3U4 (Plan. CU]-304). Malor Risk Plan CD3-105 (Plan. CUJ-205). Major Risk Plvr. PlJ-21 ]Plan'. EN-21). Major Risk Plan. CD3-113PB1 CD1-113PB Ix p03 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Sepazation [75ft/in] SECTION DETAILS Sec MD Ino Azi TVD +N/-S +Fi-W DLeg TFau VSee Target 1 36.30 0.00 0.00 3630 0.00 O,oO 000 000 tI.V(1 z woo 00 0 0o a oo looo 0o a ao Boo 000 nm noo 3 275].74 43.94 2]901 2590.41 IV019 -613.]4 250 000 sax 47 4 7601 ]4 43 Y4 279.01 60]8 22 G2fi 94 -3953 ]4 0 00 0 00 1671 15 5 947569 X400 32485 6919.4U 156'1.42 -5217.00 3.W 59.14 5258.96 CD3-113PB Iwp(13 T1 b ')489.60 84 42 324 83 6920.80 1578 74 -5244 97 3 00 -3.70 5271.76 7 9690.29 A4.42 ]24.83 fi940.33 174201 -536002 0.00 000 5456.53 9 9876.45 9000 }2494 694940 1894 Od -546694 3(NI 117 5628.39 CD3-113PBIavp03 T2 9 10076.45 92 UO 324.94 6945 Y I 205] 72 -5581.811 1.00 000 s81J 21 10 10645 OS 9200 32494 G92G 07 2522.8] -590821 000 000 631844 11 116UU Ol 90.00 324.94 fiJ0940 330412 -fi456 G7 0.21 18003 ]221194 12 1180001 8600 324.94 fi91289 346810 -657153 100 18000 ]405]6 13 IIRA9.03 88.00 324.94 6914.00 3540.90 -6622 G2 OOU O(IU 74A79] 14 13000.89 9000 32494 693510 445083 -]261.18 018 36000 851144 IS 1330359 98.00 316.86 6914.27 1684 A5 -7451.22 3.]5 -0500 880116 16 1351 R_I9 9800 JIG R6 6RRd 10 1A3992 -7596.54 0,00 27000 9007.34 Calalation MethoJ. Minimum CurvaNre Error Savtcm ISCWSA Sean Method-. Tras' Crlindar Noah W Error Surrace. ElBptical-Casing rh J l B J i M R o . u es au arn ng c From Colour To MD 36 250 250 500 500 750 750 1000 1000 1250 1250 1500 1500 1750 1750 2000 2000 16000 16000 16250 6 " '6500 6750 8250 40 8500 8750 9000 30 5000 CD3-111 CD3-111L1 CD3-I10 CD3 -110 CD3- 109 CD3-109 CD3-108 CD3-111 CD3- 1 CD3-112 CD3-112 Plan: CD3-113 Plan: CD3-113 . 8000 6000 ~ CD3-113PB1w 03 CD3-302 Plan: CD3 -302 , } O 4000 + CD3-109 CD3-109 CD3-302 CD3-302PB2 a-- - CD3-302 CD3-302PB1 ~ t - ,~~ N ,-, 2000 ! ' u ~i i E ~ CD3-307 Plan: CD3 -107 ~ , 0 i L.. -2000 1_ ,_ -14 000 -12 000 -10 000 -80 00 -60 00 -40 00 -20 00 0 2000 Wes t(-)/East(+) [2000ft/in] Closest in POOL Closest Approach: Reference Well: CD3-113 P61wp03 Plan Offset Well: CD3 -112 Coords. - Coords. - ASP ASP D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS Il~in. Dist. Depth Angle TRUE Azi. ND E(+)/W(-) (302.5°) Comments Depth Angle TRUE Azi. TVD E(+)/W(-) (302.5°) Comments POOL Min Distance POOL Min Distance (2080.93 ft) in POOL (2080.93 ft) in POOL (9475 - 13518 MD) to (9475 - 13518 MD) to CD3-113PB1wp03 ,/ CD3-112 (8511 - Plan (8511 - 16021 2080.93 ~ "at+ 12286 88.71 324.9 6877.873 6007786 381335.2 7855.379 16021 MD) 11361 88.92 325.6 6859.861 6008948 383060.9 7053.334 MD) ~.,. r'~ G .J CD3-113PB1wp03 POOLSummary.~ds 1/10/2007 1:41 PM ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 1/10/2007 Time: 14:23:44 Page: 1 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: CD3-113, True North Site: Alpine CD3 Vertical (TVD) Reference: Plan: CD3-113 49.4 WetL• Plan: CD3-113 Section (VS) References. Well (O.OON~O.OOE,302.50Azi) Wellpath: Plan: CD3-113 Survey Calwlation Method: Minimum Curvature Db: Oracle Plan: CD3-113wp03 Date Composed: 12/8/2006 Version: 5 Principal: Yes Tied-to: From: Definitive Path 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 CD3 Site Position: Northing: 6003886.80 ft Latitude: 70 25 10.481 N From: Map Easting: 388488.10 ft Longitude: 150 54 30.391 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.86 deg WeII: Plan: CD3-113 Slot Name: Well Position: +N/-S -71.75 ft Northing: 6003820.41 ft Latitude: 70 25 9.775 N +E/-W -357.63 ft Easting : 388129.47 ft Longitude: 150 54 40.878 W Position Uncertainty: 0.00 ft Wellpath: Plan: CD3-113 Drilled From: Plan: CD3-113P61 Tie-on Depth: 13000.00 ft Current Datum: Plan: CD3-113 Height 49.40 ft / Above System Datum: Mean Sea Level Magnetic Data: 12/2/2004 Declination: 23.88 deg Field Strength: 57515 nT Mag Dip Angle: 80.71 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.30 0.00 0.00 302.50 Survey Program for Definitive Wellpath Date: 12/8/2006 Validated: No Version: 4 Actual From To Survey Toolcode Tool Name ft ft Plan Section Information __ MD ft Incl deg Azim deg TVD ft +N/-S ft +E!-W ft DLS Build Turn deg/100ft deg/100ft deg/100ft TFO Target deg- 13000.00 90.00 324.94 6935.40 4450.10 -7260.67 0.00 0.00 0.00 0.00 13117.96 92.50 327.44 6932.83 4548.08 -7326.28 3.00 2.12 2.12 45.00 13372.96 92.49 332.55 6921.72 4768.63 -7453.63 2.00 0.00 2.00 90.00 14398.15 90.00 323.46 6899.40 5636.87 -7996.13 0.92 -0.24 -0.89 254.81 17483.53 90.00 323.46 6899.40 8115.85 -9833.04 0.00 0.00 0.00 89.98 CD3-113wp03 T3 Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DLS VS Commt t ft deg deg ft ft ft ft ft ft deg/100ft` ft 2506.08 37.65 279.01 2400.00 2350.60 74.75 -471.42 6003902.21 387659.26 0.00 437.76 9 5/8" 9475.69 84.00 324.85 6919.40 6870.00 1567.42 -5236.99 6005466.00 382917.00 0.86 5259.01 7" 13000.00 90.00 324.94 6935.40 6886.00 4450.10 -7260.67 6008378.43 380936.92 0.17 8514.63 KOP; 3 DLS, 13 13100.00 92.12 327.06 6933.55 6884.15 4532.98 -7316.57 6008462.13 380882.27 3.00 8606.31 13117.96 92.50 327.44 6932.83 6883.43 4548.08 -7326.28 6008477.37 380872.79 3.00 8622.61 13200.00 92.50 329.09 6929.25 6879.85 4617.78 -7369.39 6008547.71 380830.74 2.00 8696.41 13300.00 92.49 331.09 6924.89 6875.49 4704.37 -7419.21 6008635.03 380782.22 2.00 8784.96 13372.96 92.49 332.55 6921.72 6872.32 4768.63 -7453.63 6008699.78 380748.77 2.00 8848.51 13400.00 92.42 332.31 6920.56 6871.16 4792.57 -7466.14 6008723.91 380736.63 0.92 8871.92 13500.00 92.18 331.42 6916.54 6867.14 4880.68 -7513.25 6008812.71 380690.84 0.92 8959.00 13600.00 91.94 330.53 6912.94 6863.54 4968.07 -7561.74 6008900.80 380643.68 0.92 9046.84 M r ` ~ ~~~.. WELL DETAILS Name +N/-S +E/-W Northing Easting Latitude Longitude Slot Plan: CD3-113 -71.75 -357.63 6003820.41 388129.47 70°25'09.775N 150°54'40.878W N/A WELLPATH DETAILS Plan: CD3-113 Pazent Wellpath: Plan: CD3-113PB1 Tie on MD: 13000.00 Rig: Doyon 19 Ref. Datum: Plan: CD3-113 49.40ft V.Section Origin Origin Starting Angle +N/-S +E/-W From TVD 309.54° 0.00 0.00 36.30 T M Azimuths to True North Magnetic North: 23.88° Magnetic Field Strength:57515nT Dip Angle: 80.71 ° Date: 12/2/2004 Model: bggm2006 SURVEY PROGRAM Depth Fm Depth To Survey/Plan Tool 13000.00 17483.53 Planned: CD3-113wp03 V2 MWD+IFR-AK-CAZ-SC 0 2 F Vzrtical Section a[ 309 53° [SOOOft/inl - 1250 I 1000 ~ CD3-113 03 750 - o Plan : CD3-113 (Plan: CD3 -113PB1 _ 500 ~ I ~ 250 ~° o `° ~ ~ o0 0 ~ M I -250 I i -12500 -10000 -7500 -5000 -2500 0 2500 5000 Wcst(-)/East(+) 15000ft/in] PLAN DETAILS CD3-113wp03 Version 2 12/8/2006 Start Point MD Inc Azi TVD 13000.00 90.00 324.94 6935.40 +N/-S +E/-W 4450.10 -7260.67 HALLIBURTON Sperry Drilling Servkes Cono~oPhillips Alaska REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: Plan: CD3-113, True North Vertical (TVD) Reference: Plan: CD3-I 13 49.40 Section (VS) Reference: Slot - (O.OON,O.OOE) Measured Depth Reference: Plan: CD3-113 49.40 Calculation Method: Minimum Curvature • i ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Dste: 7/10/2007 . Time: 14:23:44 Page: 2 Field: Colville River Unit Co-ord inate(NE) Reference: Well: Plan: CD3-1.13, True North Site: Alpine CD3 Vertical (TVD) Referen ce: Pl an: CD3-113 49.4 WeIL• Plan: C D3- 113 Sec tion (VS) Reference: Well (O.OON,O. OOE,302.50Azi) WeRpath: Plan[ C D3- 113 Survey Calculation Method: M inimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DLS V5 Comme t ft deg tleg ft ft ft ft ft ft deg/100ft ft 13700. 00 91. 70 329. 65 6909.76 6860. 36 5054. 70 -7611. 57 6008988. 17 380595. 15 0.92 9135. 43 13800. 00 91. 46 328. 76 6907.01 6857. 61 5140. 57 -7662. 75 6009074. 79 380545. 27 0.92 9224. 72 13900. 00 91. 21 327. 87 6904.68 6855. 28 5225. 64 -7715. 26 6009160. 63 380494. 05 0.92 9314. 72 14000. 00 90. 97 326. 99 6902.77 6853. 37 5309. 90 -7769. 08 6009245. 68 380441. 50 0.92 9405. 38 14100. 00 90. 73 326. 10 6901.29 6851. 89 5393. 32 -7824. 20 6009329. 91 380387. 64 0.92 9496. 69 14200. 00 90. 48 325. 22 6900.24 6850. 84 5475. 89 -7880. 61 6009413. 30 380332. 48 0.92 9588. 63 14300. 00 90. 24 324. 33 6899.61 6850. 21 5557. 57 -7938. 29 6009495. 83 380276. 03 0.92 9681. 17 14398. 15 90. 00 323. 46 6899.40 6850. 00 5636. 87 -7996. 13 6009575. 99 380219. 39 0.92 9772. 56 14400. 00 90. 00 323. 46 6899.40 6850. 00 5638. 36 -7997. 23 6009577. 49 380218. 32 0.00 9774. 28 14500 .00 90. 00 323. 46 6899.40 6850. 00 5718. 70 -8056. 76 6009658. 71 380160. 00 0.00 9867. 66 14600 .00 90. 00 323. 46 6899.40 6850. 00 5799. 04 -8116. 30 6009739. 93 380101. 67 0.00 9961. 04 14700 .00 90. 00 323. 46 6899.40 6850. 00 5879. 39 -8175. 84 6009821. 15 380043. 35 0.00 10054. 43 14800 .00 90. 00 323. 46 6899.40 6850. 00 5959. 73 -8235. 38 6009902. 37 379985. 03 0.00 10147. 81 14900 .00 90. 00 323. 46 6899.40 6850. 00 6040. 08 -8294. 92 6009983. 59 379926. 71 0.00 10241. 19 15000 .00 90. 00 323. 46 6899.40 6850. 00 6120. 42 -8354. 45 6010064. 81 379868. 38 0.00 10334. 58 15100 .00 90. 00 323. 46 6899.40 6850. 00 6200. 77 -8413. 99 6010146. 03 379810. 06 0.00 10427. 96 15200 .00 90. 00 323. 46 6899.40 6850. 00 6281. 11 -8473. 53 6010227. 25 379751. 74 0.00 10521. 34 15300 .00 90. 00 323. 46 6899.40 6850. 00 6361. 46 -8533. 07 6010308. 47 379693. 42 0.00 10614. 72 15400 .00 90. 00 323. 46 6899.40 6850. 00 6441. 80 -8592. 60 6010389. 70 379635. 10 0.00 10708. 11 15500 .00 90. 00 323. 46 6899.40 6850. 00 6522. 15 -8652. 14 6010470. 92 379576. 78 0.00 10801. 49 15600 .00 90. 00 323. 46 6899.40 6850. 00 6602. 49 -8711. 68 6010552. 14 379518. 46 0.00 10894. 87 15700 .00 90. 00 323. 46. 6899.40 6850. 00 6682. 84 -8771. 21 6010633. 36 379460. 14 0.00 10988. 25 15800 .00 90. 00 323. 46 6899.40 6850. 00 6763. 19 -8830. 75 6010714. 58 379401. 82 0.00 11081. 63 15900 .00 90. 00 323. 46 6899.40 6850. 00 6843. 53 -8890. 28 6010795. 81 379343. 50 0.00 11175. 02 16000 .00 90. 00 323. 46 6899.40 6850. 00 6923. 88 -8949. 82 6010877. 03 379285. 18 0.00 11268. 40 16100 .00 90. 00 323. 46 6899.40 6850. 00 7004. 22 -9009. 36 6010958. 25 379226. 86 0.00 11361. 78 16200 .00 90. 00 323. 46 6899.40 6850. 00 7084. 57 -9068. 89 6011039. 47 379168. 54 0.00 11455. 16 16300 .00 90. 00 323. 46 6899.40 6850. 00 7164. 92 -9128. 43 6011120. 69 379110. 22 0.00 11548. 54 16400 .00 90. 00 323. 46 6899.40 6850. 00 7245 .26 -9187. 96 6011201. 92 379051. 90 0.00 11641. 93 16500 .00 90. 00 323. 46 6899.40 6850. 00 7325 .61 -9247. 50 6011283. 14 378993. 58 0.00 11735. 31 16600 .00 90. 00 323. 46 6899.40 6850. 00 7405 .96 -9307. 03 6011364. 36 378935. 26 0.00 11828. 69 16700 .00 90. 00 323. 46 6899.40 6850. 00 7486 .30 -9366. 57 6011445. 59 378876. 94 0.00 11922 .07 16800 .00 90. 00 323. 46 6899.40 6850. 00 7566 .65 -9426. 10 6011526. 81 378818. 62 0.00 12015 .45 16900 .00 90. 00 323 .46 6899.40 6850. 00 7647 .00 -9485. 64 6011608. 03 378760. 30 0.00 12108 .83 17000 .00 90. 00 323 .46 6899.40 6850. 00 7727 .34 -9545. 17 6011689. 26 378701. 98 0.00 12202 .21 17100 .00 90. 00 323 .46 6899.40 6850. 00 7807 .69 -9604. 70 6011770. 48 378643. 67 0.00 12295 .59 17200 .00 90. 00 323 .46 6899.40 6850. 00 7888 .04 -9664. 24 6011851. 70 378585. 35 0.00 12388 .98 17300 .00 90. 00 323 .46 6899.40 6850. 00 7968 .39 -9723. 77 6011932. 93 378527. 03 0.00 12482 .36 17400 .00 90. 00 323 .46 6899.40 6850. 00 8048 .73 -9783 .31 6012014. 15 378468. 71 0.00 12575 .74 X17483 .53 90. 00 323 .46' 6899.40 6850. 00 8115 .85 -9833 .04 6012082. 00 378420. 00 0.00 12653 .74 CD3-113wp03 T Targets Map Map <--- Latitude ----> <-- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min See Deg Min. Sec Dip. Dir. ft ft ft ft ft CD3-113wp03 T3 6899.40 8115.85 -9833.04 6012082.00 378420.00 70 26 29 .529 N 150 59 29.531 W ^R!GINAL ConocoPhillips Alaska, Inc. CPAI Report Company: Field: Site: Well: Wellpath: ConocoPhillips Alaska Inc. Colville River Unit Alpine CD3 Plan: CD3-113 Plan: CD3-113 Date: 1/10/2007 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Section (VS) Reference: Survey Calculation Method: Time: 14:23:44 Page: 3 Well: Plan: CD3-113, True North Plan: CD3-113 49.4 Well (O.OON,O.OOE,302.50Azi) Minimum Curvature Db: Oracle Annotation MD ft TVD ft 13000.00 17483.53 6935.40 KOP; 3 DLS, 13000' MD 6899.40 TD; 17484' MD, 6899' TVD Casing Points MD ft TVD Diameter ft in Hote Size Name in 2506.08 9475.69 17483.53 2400.00 9.625 6919.40 7.000 6899.40 6.125 12.250 9 5/8" 8.750 7" 6.125 6 1/8" OH Formations MD TVD Formations Lithology Dip Angle Dip Direction r ~ ~L_~ • ConocoPhillips Alaska, Inc. Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 1/10/2007 Time: .14:03:10 Page: 1 Field: .Colville River Unit Reference Site: Alpine CD3 Co-ordinate(NE) Reference: Well: Plan: CD3-113, True North Reference Well: Plan: CD3-113 Vertical (TVD) Reference: Plan: CD3-113 49.4 Reference Wellpath: Plan: CD3-113 Db: Orade GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: CD3-113wp03 & NOT PLANNED P Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 13000.00 to 17483.53 ft Scan Method: Trav Cylinder North Maximum Radius: 1944.72 ft Error Surface: Ellipse + Casing Casiug Points MD TVD Diameter Hole Size Name ft ft in in 2506.08 2400.00 9.625 12.250 9 5/8" 9475.69 6919.40 7.000 8.750 7" 17483.53 6899.40 6.125 6.125 6 1/8" OH Plan: CD3-113wp03 Date Composed: 12/8/2006 Version: 3 Principal: Yes Tied-to: From: Definitive Path Summary 4__~____________ Offset Wellpath ---------__W___~> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation ' Warning ft ft ft ft ft Alpine CD3 Plan: CD3-113 Plan: CD3-113P61 V5 PI 13025.00 13025.00 0.25 266.82 -266.57 FAIL: Major Risk )GRAM WELL DETAILS Name -N;-S tE~-W NoMing Eaxting Latitude LoneimJ< Slol Plen CD3-113 -71.75 -J 5763 600382D.01 38NI2977 70`25'09775N ISU"S4'40878W N/A 0 0 0 suRVPV rNrroxwt DerN Fm Ocpih To Sr >n Tool I ~rA11 nn I~~gr S] Plumed ~D ~Iliwpcl+tr lrhD GR.gK-MAJ. S. 0 PWr. N3-113 Varrn~U'ellpath %an: LDl-t 13P01 Tie oo Ate: 13180.00 wg. Ref Dawm: ro>~on 19 %an: CD: -I lv 1940R l'SccDnn Mgl< (higin DriBia Stanmg ~\~S -F/-N' From ILD ~a_so Duo D 90 ?630 From Colour To h1D 0 2S0 250 S00 `^^ 750 1000 1250 1500 1750 2000 16000 16250 16500 16750 18250 18500 18750 19000 25000 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [30fUin] SECTION DETAl1,S Sec MD Inc Azi TVD +N/-S tFJ-W DLeg 'CFncn VSec Tercet 1 13000 00 90 00 124 94 6935 40 4450.10 -7260.67 U OU O 0U R514.63 2 13117 96 92 SO 327 4J 6932.83 4548 OS -7326 28 3 00 4S 00 862261 3 1337296 92 d9 332.SS 6921.72 4768 G3 -745363 2.00 90.00 884 R.51 4 14398.15 90 00 323 46 6899 40 5636 87 -7996.13 0 92 254.81 9772 56 5 174fl]53 90.00 32346 6699 d0 811585 -9833.0d 0,00 N998 12653]4 CD3-113 wrA3l'J ANTI-(:OLLISiON StiTT[N(iS CGMPANY DETALS Interpolatinn MelhodMD Interval- 21.00 ConocoPhilli ps Al ACka Inc_ Ueplh Range Frnm 13UW.Ul1 To. 17483.53 Eng~neenng Mawmwn Range 1944.72 Reference Plan. CD3-I liap03 LEGEND Plan. CD3-111 ~ l'DJ-1 IIxp01 Calculation Methwl. Minimum Curvemre Error System. ISCWSA Swn Method. Tray Cylinder Nonh bl Error Surface Elliptical + C'asmg J i M h I R l B asc am ng ct « : u es From Colour To MD 0 2S0 250 S00 S00 7S0 7S0 1000 1000 1250 1250 1500 I S00 1750 1750 2000 2000 16000 16000 L6250 6 - 16500 - 16750 - 18250 40 i8S00 _ 18750 19000 30 25000 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [75fUin] I CD3- 110 CD3-110 CD3-109 CD3- 109 CD3-108 CD3-1 11 CD3-111L1 i I 10000 CD3-111 (CD3- 111 CD3-112 CD3-112 CD3-113 03 8000 n N 6000 + o I ~ ~ 4000 ~ ' ~/ CD3-302 Plan: CD3-302 '~ ~ i 2000 ~ ~ CD3-302 CD3-302P82 CD3-307 Plan: CD3-107 0 I -16 000 -14 000 -12 000 -10000 -80 00 -60 00 -40 00 -20 00 0 West(-)/Ea st(+) [2000ft /in] Closest in POOL • ~~ r .,,,~ , .. :~;s'." Closest Approach: Reference Well: CD3-113wp03 Plan Offset Well: CD3 -112 Coords. - Coords. - ASP ASP -D ctr-ctr _ Meas. Incl. Subsea N(+)/S(-) View VS Meas. Ind. Subsea N(+~S(-) View VS in. Dist. Depth Angle TRUE Azi. TVD E(+)/W(-) (302.5°) Comments Depth Angle TRUE Azi. TVD E(+)/W(-) (302.5°) Comments POOL Min Distance POOL Min Distance (2011.1 ft) in POOL (2011.1 ft) in POOL (9475 - 17483 MD) to (9475 - 17483 MD) to CD3-112 (8511 - CD3-113wp03 Ptan 2011.1 14411 90 323.4 6849.912 6009584 380207.6 9785.828 16021 MD) 13536 90.1 323.4 6850.36 6010750 381845.8 9059.02 (8511-16021 MD) CD3-113wp03 POOLSummary.xls 1/10/2007 2:21 PM • • _ - -- SHARON K. ALLSUP-DRAKE 1170 CONOCOPHILLIPS ATO 153 700 G 3T. DATE f ``r'~/ ~ ~ 5&1557/441 ANCHORAGE AK 99501/ ~ f~{ // ~ ~ PR1Y TO THE ~G~ Q~ ~v/ 1 ~~/T /~1 ~ 1. C `A t/V. ~ 7 ORD€R OF 1 ~ DOLLA S LJ ae..~,~. e JPMorganChase ~ ~ Valid Up To 5000 Dollars JPMorgan Chase Bank, N.A. Columbus, OH / ~ a~ _ //`~~ nr MEMO ~~3y ~~~ ~:044LL55L1~:528747L90792711'LL70 ~,~~„~~ ~ • TRANSMIT'T'AL LE'V'ER CFIECKLIST WELL NAME C~~- \\ ~ PTD# a ~ `~ - C~ C~ ~ Development Service Exploratory Stratigraphic 'l'est Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter I CHECK ~ ADD-ONS ! TEXT FOR APPROVAL LETTER WHAT ~ (OPTIONS) APPLIES ~ I MliLT[ LATERAL ~ The permit is for a new wellbore segment of existing ~ dwell ~ (If last two digits _ in I permit No. API No. 50- - - , I API number are between 60-69) ;Production should continue to be reported as a function of the original API number stated above. PILOT HOLE ~ In accordance with 20 A.4C 25.00~(f), all records. data and logs ;acquired for the pilot hole must be clearly differentiated in both ;well name ( PH) and API number I ' (50- - -_~ from records, data and logs acquired for well i SPACING The permit is approved subject to full compliance with 20 AAC I EXCEPTION ~ 2~.0». Approval to perforate and produce /inject is contingent I upon issuance of a conservation order approving a spacing j exception. assumes the ~ liability of any protest to the spacing exception that may occur. ~ DRY DITCH ~ AI[ dry ditch sample sets submitted to the Commtsston must be to SAMPLE I no greater than 30' sample intervals from below the permafrost or I 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 allowed j I Fell ~ for (name of well) until after (Company Name) has designed and I I ~ implemented a water well testing program to provide baseline data ~ j on water quality and quantity. (Com a~ny_Name) must contact the !Commission to obtain advance approval of such water well testing Rev: 1'25,"06 C:`jody~transmittal_checklist COLVILLE RIVER, FIORD OIL_120120 WELL P~iuai i CHECKLIST Field & Pool Well Name: COLVILLE RIV FIORD CD3-113 Program DEV ___ Well bore seg ^ - PTD#:2070040 Company CONOCOPHILLIPS ALASKA INC _ ___ -- In~ial Class(rype _ DEV 1 PEND__GeoArea 890_ Unit 50360 OnlOff Shore On Annular Disposal ^ Administration 1 PeCmit_feeattached_ Yes j 2 .Lease number appropriate_ No_ Correction made to_ 10-4.01:- Surface I_oc and_top prod interval_in ADL 372105; prod interval MAY pass through 3 Unique well_name and number - _ _ - _ _ _ - - - - -- - - - - - - - - - - - - - - -Yes - - _ - _ - ADL0364471 (wellbore will be close to the SW corner of this lease);_ rest of prod interval & TD in ADL 384215._ , _ 4 Well located in,a_defined.pool Yes Conservation Order No. 569 contains no spacing restrictions with r_espect_to drilling unit boundaries. 5 Well located proper distance_fromdrilling unit_boundary- Yes Conservation Order No. 5613 has no intervvell-spacing_restricti4ns, 6 Well located properdistance from other wells_ . Yes . - Conservation Order No. 569 has no intervvell_spacing-restrictions, Wellbore_will be_ more than 500' from 7 Sufficient acreage available in.drilling unit. _ Yes - - ..external property line_wh_ere_owne[ship or landownership,changes. Section 26,-13N, 4E UM lies_withn CRU, 8 If_deviated, is-wellbore plat-included . - .. - - - - - . Yes - ~I 9 Operator only affected party - Yes - - - - - - ~ 10 Ope[ator has_appropriate-bond inforce - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - !, 11 Permit_canbeissuedwithoutconserva_tionorder___-_ _Yes. ___.-___- ___--.__--------------- ___-__----..._- Appr Date 12 Permit_can be issued without administrative_approval _ _ _ . - - Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ... - - _ _ - - _ - - _ _ - _ _ - - - _ _ - _ _ - . _ - - - - 13 Can permit be approved before 15-day wait Yes SFD 1/1612007 1 114 Well located within area and_strata authorized by Injection Order # (put_1O# in_comments). (For NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ~15 All wells within 1/4_mile area of review identified (For service well only) _ _ _ _ _ _ _ - _ _ NA_ - - _ _ - _ '16 Pre-produced injector:. dur_at_ion_of pre production less than_ 3 months_ (For-service well only} NA_ - !17 t~onconuen, gas conforms to A$31,05.030(j.1_.A),0.2 A-l)) NA - _ - _- _ ____ Engineering '18 Conductor string provided Yes _ _ _ 19 Surface casing_protects allknow4 USDWs - . - NA.. Np aquifers,_per AIO.18A conclusion 3. 120 CMT_vol adequate_to circulate_on conductor_& surf_csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ Yes - ';21 CMT.vol_ adequate to tie-in long string to surf csg_ - - _ No_ - All hydrocarbons will be covered, Annular disposal may be proposed.. 122 CMT_will cover all known-productive horizon_s_ _ - . - - No_ Open_hold completion planned, - . ~~23 I Casing designs adequate for C,T,B&_permaf[ost -- Yes - -- ------------ ---- ------- -----------------------.- -------...-. 24 Adequate tankage or reserve pit Yes Rig is_equipped with steel-pits. -No rese_rve_pitplanned, All waste to_approved annuli._ 125 If_a_re-drill,has_a_10-403 for abandonment been approved_____________ _________ NA_ _____--.__--____-____-.--___ -..--- -- ---------- j26 Adequate wellbore separationproposed _ _ _ _ _ _ _ _ _ _ _ __ _ _ - - - _ Yes _ _ -- _ - - - -Proximity analysis performed, Traveling cylinder path calculated, Surface gyros possible._ - _ _ . _ _ _ - - _ _ .. _ !~27 If_diverter required, does it meet regulations_ - - NA _ - _ Diyerter waiver requested. No problems evident on other wells. Waiver is recommended, 20AAC 25.035jh)[2). - - Appr Date ~i28 Drilling fluid_program schematic & equip list adequate_ Yes - Maximum expected fo[mation pressure 8,7_EMW._ Planned MW up to 9,3 ppg, Underpressurepossible_ intone.. - TEM 1122/2007 X29 BOPES,_dotheymeet_regulation_______________ Yes__ _____.-______---__--__. ._--__----.__ __----.------- --.-_--------- ,h A 30 BOPE_press rating appropriate; test to (put psig in comments) Yes _ _ MASP calculated at 2438 psi, 3500_psi appropriate. CPAI normally tests to 5000_psi. ~ I ~ \ X31 Choke_manifold compliesw/APiRP-53 (May 84) Yes _ 132 Work will occur without operation shutdo_wn_ No_ _ Ifunder-pressure is encountered, operations_may be SD_to alfow_injection to increase formation_ pressure._ - ~i33 Is presence_of H2S gas probable _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ No_ _ , _ _ _ _ H2S has not_been reported at CD3. -Rig has sensors_a_nd alarms... _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ - .... - - . - - - ~134 Mechanical condition of wells withinAORyerified(Forservicewellonly~____- -____ - -NA___ _______ __________..--_-----.-___---..-_--__- i Geology 1,35 Permitcan be issued w/o-hydrogen sulfide measures. Yes None expected,-but H2S and-gas detectors will be used during drilling. Mityation measures in Hazards Summ_ary_ 1136 Data_presented on-potential overpressure zones _ Yes , _ - From ND and downhole pressure, expected gradient is 8.7_ppg EMW; will-be drilled with 9:0 - 9.3ppg mud.. - . Appr Date j37 Seismic analysis of shallow gas_zones . - . - - NA_ _ Nechelik reservoir maybe underpressured: discussed_in application cover letter and drillingprecedure. SFD 1!1612007 'x,38 Seabed condition survey-(if off_-shore) _ - - - - - - . - . NA_ 39 Contactnamelphoneforweekly_progressreports[exploratoryonly]____-_-_ __----_ NA- - -- --- - -------------- --------_..-------- --_------.-.---- - - Geologic Engineering Public D t Date Cover letter should state: "The decision as to whether or not the Qannik sandstone contains a significant oil accumulation that Commissioner: ~^ c+ O I J ~ a e Date: Commissioner: issioner 12 ~ ~, ~~~ ~ / ? l'"ZJ "~ must be cemented per 20 AAC 25.030(c)(5) must be made inconjunction with AOGCC technical staff." The proposed pilot hole intended to establish the top of the Nechelik will open between 300' and 500' of reservoir and it will not be plugged with cement. Per 20 AAC 25.990(74), this pilot hole must be considered a "well branch" and per 20 AAC 25.005(e) it requires a separate Permit to Drill. • • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. i~ cd3-113.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu May 03 15:13:35 2007 Reel Header Service name .............LISTPE Date . ...................07/05/03 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................07/05/03 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 Fiord - Necheli MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA !J scientific Technical Services scientific Technical services CD3-113 501032054100 ConocoPhillips Alaska, Inc. Sperry Drilling Services 03-MAY-07 MWD RUN 2 JOB NUMBER: W-0004878587 LOGGING ENGINEER: D. RICHARDSO OPERATOR WITNESS: L. HILL SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 5 12 5 E 1325 914 49.79 13.10 WELL CASING RECORD Page 1 2v°~--oo ~ ~ ~ 5ri3 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: cd3-113.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.750 9.625 2619.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AT-BIT GAMMA (ABG), GEOPILOT ROTARY STEERABLE BHA (GP), AND PRESSURE WHILE DRILLING (PWD). 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1,2 REPRESENT THE SURFACE AND INTERMEDIATE SECTIONS OF WELL CD3-113 WITH API#: 50-103-20541-00. THIS WELL SEGMENT HAS A TOTAL DEPTH (TD) OF 9374'MD/6911'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. ABG = AT-BIT GAMMA. 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.......07/05/03 Maximum Physical Record..65535 File Type ................L0 Page 2 • • cd3-113.tapx Previous File Name.......STSLI6.000 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 2593.0 9336.5 RPD 2610.0 9328.5 RPM 2610.0 9328.5 RPS 2610.0 9328.5 RPX 2610.0 9328.5 FET 2610.0 9328.5 GR 2626.0 9369.5 RoP 2630.5 9374.0 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 2593.0 9374.0 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 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 2593 9374 5983.5 13563 2593 RPD MWD OHMM 0.18 2000 7.33942 13438 2610 Page 3 Last Reading 9374 9328.5 cd3-113.tapx L~ RPM MWD OHMM 0.21 64.85 5.02672 13438 2610 9328.5 RPS MWD OHMM 0.37 67.85 4.93459 13438 2610 9328.5 RPX MWD OHMM 0.33 65.45 4.84274 13438 2610 9328.5 FET MWD HOUR 0.15 48.4 0.589798 13438 2610 9328.5 GR MWD API 45.54 412.14 117.516 13488 2593 9336.5 ROP MWD FT/H 0.22 1363.13 197.759 13488 2630.5 9374 First Reading For Entire File..........2593 Last Reading For Entire File...........9374 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/03 Maximum Physical Record..65535 File Type ................L0 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.......07/05/03 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2593.0 9336.5 RPD 2610.0 9328.5 RPM 2610.0 9328.5 RPS 2610.0 9328.5 RPX 2610.0 9328.5 FET 2610.0 9328.5 GR 2626.0 9369.5 ROP 2630.5 9374.0 LOG HEADER DATA DATE LOGGED: 30-JAN-07 SOFTWARE SURFACE SOFTWA RE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9374.0 TOP LOG INTERVAL (FT): 2630.0 BOTTOM LOG INTERVAL (FT): 9374.0 Page 4 • • cd3-113.tapx BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 42.7 MAXIMUM ANGLE: 83.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 157645 ABG AT-BIT GAMMA 225685 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 2619.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S): 35.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3): 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.680 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .790 152.0 MUD FILTRATE AT MT: 1.950 68.0 MUD CAKE AT MT: 1.750 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Di rection .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame spacing....... ............60 .lIN Max frames per record.............Undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service Order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 Page 5 • i cd3-113.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2593 9374 5983.5 13563 2593 9374 RPD MWD020 OHMM 0.18 2000 7.33942 13438 2610 9328.5 RPM MwD020 OHMM 0.21 64.85 5.02672 13438 2610 9328.5 RPS MWD020 OHMM 0.37 67.85 4.93459 13438 2610 9328.5 RPX MWD020 OHMM 0.33 65.45 4.84274 13438 2610 9328.5 FET MWD020 HOUR 0.15 48.4 0.589798 13438 2610 9328.5 GR MwD020 API 45.54 412.14 117.516 13488 2593 9336.5 ROP MWD020 FT/H 0.22 1363.13 197.7.59 13488 2630.5 9374 First Reading For Entire File..........2593 Last Reading For Entire File...........9374 File Trailer Service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/03 Maximum Physical Record..65535 File Ty e LO Next Fie Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/05/03 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer service name .............LISTPE Date . ...................07/05/03 Ori gin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF End Of LIS File writing Library. Page 6 Scientific Technical services Scientific Technical Services e cd3-113.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Apr 29 14:46:48 2008 Reel Header Service name .............LISTPE Date . ...................08/04/29 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. Tape Header Service name .............LISTPE Date . ...................08/04/29 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 MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: scientific Technical services scientific Technical services CD3-113 501032054100 ConocoPhillips Alaska Inc. Sperry Sun 23-APR-08 MWD RUN 3 MWD RUN 4 MW-000555621 MW-000555621 J. BOBBITT J. BOBBITT D. BURLEY D. BURLEY MWD RUN 2 MW-000555621 D. RICHARDSO L. HILL SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND .LEVEL: WELL CASING RECORD 5 12N 5E 3955 914 .00 49.90 13.10 Page 1 ~b'3~0~ ~ ~~~~/ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: cd3-113.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 16.000 114.0 8.750 9.625 2619.0 6.125 7.000 9364.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AT-BIT GAMMA (ABG), GEOPILOT ROTARY STEERABLE, DRILLSTRING DYNAMICS SENSOR (DDS) AND PRESSURE WHILE DRILLING (PWD). 5. MWD RUN 3-4 COMPRISED DIRECTIONAL, GAMMA MODULE (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AZMUTHAL DEEP RESISTIVITY (ADR), PRESSURE WHILE DRILLING (PWD), DRILLSTRING DYNAMICS SENSOR (DDSr), AND GEO-PILOT ROTARY STEERABLE. 6. NO RESISTIVITY DATA PRESENTED ON MWD RUN 4 DUE TO SENSOR MALFUNCTION. 7. AT-BIT GAMMA (ABG) DATA MERGED ONTO INTO SGRC AT THE END OF MWD RUN 2. 8. 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. 9. MWD RUNS 1-4 REPRESENT CD3-113 WITH API#: 50-103-20541-00. THIS WELL REACHED A TOTAL DEPTH OF 17338' MD, 6858' 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). Page 2 cd3-113.txt SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE TIME ARH16P = SMOOTHED COMPENSATED 2 MHZ PHASE RESISTIVITY (16 INCH SPACING). ARH32P = SMOOTHED COMPENSATED 2 MHZ PHASE RESISTIVITY (32 INCH SPACING). ARM48P = SMOOTHED COMPENSATED 500 kHZ PHASE RESISTIVITY (48 INCH SPACING). ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPS RPM RPD RPX ROP AH1P AH2P AM3P 1 clipped curves; all bit runs merged. .5000 START DEPTH 2593.0 2610.0 2610.0 2610.0 2610.0 2610.0 2630.5 9329.0 9329.0 9329.0 STOP DEPTH 17259.0 12652.0 9328.5 9328.5 9328.5 9328.5 17338.0 12652.0 12652.0 12652.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MwD 3 MWD 4 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2593.0 9374.0 9374.0 12706.0 12706.0 17338.0 Page 3 ~ M cd3-113.txt 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 AH1P MWD OHMM 4 1 68 4 2 AH2P MWD OHMM 4 1 68 8 3 AM3P MWD OHMM 4 1 68 12 4 RPD MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPS MWD OHMM 4 1 68 24 7 RPX MWD OHMM 4 1 68 28 8 FET MWD HOUR 4 1 68 32 9 GR MWD API 4 1 68 36 10 ROP MWD FT/H 4 1 68 40 11 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2593 17338 9965.5 29491 2593 17338 AH1P MWD OHMM 0.07 4603.35 16.8861 6647 9329 12652 AH2P MWD OHMM 0.07 5000 59.693 6647 9329 12652 AM3P MWD OHMM 0.02 2000 21.8599 6647 9329 12652 RPD MWD OHMM 0.18 2000 7.33942 13438 2610 9328.5 RPM MWD OHMM 0.21 64.85 5.02672 13438 2610 9328.5 RPS MWD OHMM 0.37 67.85 4.93459 13438 2610 9328.5 RPX MWD OHMM 0.33 65.45 4.84274 13438 2610 9328.5 FET MWD HOUR 0.15 9140.23 43.6535 20085 2610 12652 GR MwD API 26.93 412.14 77.4086 29333 2593 17259 RoP MwD FT/H 0.22 1363.13 151.38 29416 2630.5 17338 First Reading For Entire File..........2593 Last Reading For Entire File...........17338 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... Page 4 cd3-113.txt version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 2593.0 RPS 2610.0 FET 2610.0 RPx 2610.0 RPM 2610.0 RPD 2610.0 ROP 2630.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR Dual Gamma Ray EWR4 EWR Phase-4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): STOP DEPTH 9369.5 9328.5 9328.5 9328.5 9328.5 9328.5 9374.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL • header data for each bit run in separate files. 2 .5000 2 30-JAN-07 Insite 72.13 Memory 42.7 83.9 TOOL NUMBER 124724 157645 8.750 2619.0 Spud Mud 9.60 35.0 9.4 800 10.8 1.680 68.0 .790 152.0 1.950 68.0 1.750 72.0 Page 5 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): cd3-113.txt REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service Order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MwD020 OHMM 4 1 68 16 5 FET MWD020 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 2593 9374 5983.5 13563 2593 9374 RPD MWD020 OHMM 0.18 2000 7.33942 13438 2610 9328.5 RPM MWD020 OHMM 0.21 64.85 5.02672 13438 2610 9328.5 RPS MWD020 OHMM 0.37 67.85 4.93459 13438 2610 9328.5 RPX MWD020 OHMM 0.33 65.45 4.84274 13438 2610 9328.5 FET MwD020 HOUR 0.15 48.4 0.589798 13438 2610 9328.5 GR MWD020 API 34.13 412.14 117.147 13554 2593 9369.5 ROP MWD020 FT/H 0.22 1363.13 197.759 13488 2630.5 9374 First Reading For Entire File..........2593 Last Reading For Entire File...........9374 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF Page 6 ~ ~ cd3-113.txt File Header Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/29 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 AH1P 9329.0 12652.0 AH2P 9329.0 12652.0 AM3P 9329.0 12652.0 FET 9329.0 12652.0 GR 9370.0 12627.5 ROP 9374.5 12706.0 LOG HEADER DATA DATE LOGGED: 17-FEB-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 76.19 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.9 MAXIMUM ANGLE: 92.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Gamma Module 78012 ADR Azimuthal Deep Res 164412812 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 9364.0 BOREHOLE CONDITIONS MUD TYPE: Flo-Pro NT MUD DENSITY (LB/G): 8.90 MUD VISCOSITY (S): 44.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 23500 FLUID LOSS (C3): 4.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .120 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .061 143.6 MUD FILTRATE AT MT: .220 70.0 MUD CAKE AT MT: .160 70.0 Page 7 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: cd3-113.txt 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 AH1P MWD030 OHMM 4 1 68 4 2 AH2P MWD030 OHMM 4 1 68 8 3 AM3P MwD030 OHMM 4 1 68 12 4 FET MWD030 HOUR 4 1 68 16 5 GR MWD030 API 4 1 68 20 6 ROP MWD030 FT/H 4 1 68 24 7 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9329 12706 11017.5 6755 9329 12706 AH1P MWD030 OHMM 0.07 4603.35 16.8861 6647 9329 12652 AH2P MWD030 OHMM 0.07 5000 59.693 6647 9329 12652 AM3P MWD030 OHMM 0.02 2000 21.8599 6647 9329 12652 FET MwD030 HOUR 0.37 9140.23 130.714 6647 9329 12652 GR MWD030 API 26.93 56.1 42.6775 6516 9370 12627.5 ROP MWD030 FT/H 8.43 247.03 121.461 6664 9374.5 12706 First Reading For Entire File..........9329 Last Reading For Entire File...........12706 File Trailer service name... .......sTSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF Page 8 cd3-113.txt File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12628.0 RoP 12706.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 17259.0 17338.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Gamma Module ADR Azimuthal Deep Res BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: r header data for each bit run in separate files. 4 .5000 4 21-FEB-08 Insite 76.19 Memory 87.9 93.6 TOOL NUMBER 78012 164413812 6.125 9364.0 Flo-Pro NT 9.00 43.0 9.0 30000 4.2 .190 65.0 .080 161.6 .200 65.0 .280 65.0 Page 9 HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: cd3-113.txt Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~iny Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 • Name service order units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD040 API 4 1 68 4 2 ROP MWD040 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12628 17338 14983 9421 12628 17338 GR MWD040 API 28.34 97.56 43.6934 9263 12628 17259 ROP MWD040 FT/H 2.04 430.68 105.377 9264 12706.5 17338 First Reading For Entire File..........12628 Last Reading For Entire File...........17338 File Trailer Service name... .......STSLI6.004 service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/04/29 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/04/29 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Page 10 scientific Technical services • • cd3-113.txt Date . ...................08/04/29 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 Page 11
