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Home My WebLink About202-243Originated: Delivered to:26-Aug-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1L-09 50-029-22025-00 910180917 Kuparuk River Plug Setting Record Field- Final 15-Jul-25 0 12 1R-33 50-029-22529-00 910219407 Kuparuk River Leak Detect Log Field- Final 19-Aug-25 0 13 1R-33 50-029-22529-00 910218799 Kuparuk River Multi Finger Caliper Field & Processed 5-Aug-25 0 14 1Y-06A 50-029-20958-01 910277376 Kuparuk RiverLeak Detect Log with IntelliScopeField & Processed 23-Aug-25 0 15 1Y-06A 50-029-20958-01 910180481 Kuparuk River Leak Detect Log Field- Final 22-Jul-25 0 16 1Y-06A 50-029-20958-01 910180481 Kuparuk River Plug Setting Record Field- Final 22-Jul-25 0 17 2B-02 50-029-21154-00 910151022 Kuparuk River Packer Setting Record Field- Final 3-Jul-25 0 18 2G-17 50-029-23134-00 910157884 Kuparuk River Leak Detect Log Field- Final 14-Aug-25 0 19 2K-23 50-103-20125-00 910180916 Kuparuk River Plug Setting Record Field- Final 12-Jul-25 0 110 2X-12A 50-029-21189-01 910262801 Kuparuk River Plug Setting Record Field- Final 24-Aug-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:190-034194-156197-134184-122202-243190-014195-176T40827T40828T40828T40829T40829T40829T40830T40831T40832T408338/27/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.08.27 12:51:45 -08'00'184 122202-243190 01482G-1750-029-23134-00 910157884Kuparuk RiverLeakDetect LogField- Final14-Aug-2501 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: Patch 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): 14768' 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 07/01/205 14768'920' 3-1/2" 6403' Packer: Baker ZXP LT Packer Packer: Baker GBH-22 80-40 Seal Assmbly SSSV: None Perforation Depth MD (ft): L-80 5725' 14280-14292' 14001' 3-1/2" 6116-6123' 7" Perforation Depth TVD (ft): 110' 5753' 5973'14027' 16" 9-5/8" 82' 13889' MD MD 110' 3135' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025666, ADL0025667 202-243 P.O. Box 100360, Anchorage, AK 99510 50-029-23134-00-00 Kuparuk River Field Kuparuk River Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 13848' MD and 5870' TVD 13851' MD and 5871' TVD N/A Jaime Bronga 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: Jaime.Bronga@conocophillips.com (907) 265-1053 Senior Well Integrity Engineer KRU 2G-17 6403' 13918' 5910' 13918' 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 Digitally signed by Jaime Bronga DN: OU=Conoco Phillips Alaska, CN=Jaime Bronga, E=jaime.bronga@conocophillips.com Reason: I am the author of this document Location: Date: 2025.06.23 08:40:02-08'00' Foxit PDF Editor Version: 13.1.6 Jaime Bronga 325-378 By Grace Christianson at 12:13 pm, Jun 23, 2025 DSR-6/23/25A.Dewhurst 23JUN25JJL 6/24/25 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.25 12:10:35 -08'00'06/25/25 RBDMS JSB 062625 KRU 2G-17 Caliper and LDL Steps: First Relay or Eline Rig up 1. Conduct an STP style LDL from the top of ll above the RBP to surface. 2. Log a baseline pass while RIH to the plug. 3. Perform a dynamic pass by pumping down the tubing, taking returns from the IA from the plug to surface. The LLR was very high, plan to pump at a high enough rate to observe the spinner data in 3-1/2" tubing. 4. RBIH and perform station stops above and below any anomalies to conrm depths of leak within 5 ft. 5. Pull caliper from top of ll to surface. 6. Assuming CMU sleeve is identied as the only leak, review the caliper data and troubleshoot closing the CMU sleeve. 7. If get the CMU to move, try some MIT-Ts with a hole nder. (ENGAGED CMU 13,764' RKB, JD 15X TO CLOSE SLEEVE, MADE MULTIPLE PASSES THRU CMU AFTER, UNABLE TO RE ENGAGE CMU) . Second Rig Up 1. Conrm have received the 10-403 for patch setting. 2. Pull RBP from 13920' rkb. Will likely have to bail ll to do so. 3. Set two trip patch across TxIA leak. WIE will update depths after reviewing caliper and LDL. 4. MIT-T each section of the patch with the hole nder to conrm good set. 5. Conduct IA DDT from 100 psi for 30 minutes to conrm good set. 6. Have DHD start a 7 day IA DDT when Relay is complete. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag RKB 14,256.0 2G-17 1/14/2018 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: TAG 2G-17 1/15/2018 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: ADD LATERALS L1, L1-01 (off the main wellbore) 11/22/2013 haggea NOTE: View Schematic w/ Alaska Schematic9.0 10/22/2010 ninam 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 28.0 110.0 110.0 62.50 H-40 WELD SURFACE 9 5/8 8.83 28.0 5,752.8 3,134.7 40.00 L-80 BTCM PRODUCTION 7 6.28 26.0 14,027.4 5,972.9 26.00 L-80 BTCM WINDOW L1-01 3 1/2 2.99 14,280.0 14,286.0 6,119.6 9.20 L-80 LINER 3 1/2 2.99 13,847.9 14,768.0 6,403.4 9.30 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.2 Set Depth … 13,889.4 Set Depth … 5,893.7 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd 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) 23.2 23.2 0.06 HANGER 7.000 FMC GEN V TUBING HANGER 3.500 502.0 502.0 1.42 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO D 2.875 4,081.2 2,581.8 70.51 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG-M 2.920 7,961.7 3,841.5 71.39 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG-M 2.920 10,742.3 4,730.6 71.38 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG-M 2.920 12,808.8 5,390.3 71.62 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG-M 2.920 13,737.3 5,806.5 54.99 GAS LIFT 5.968 CAMCO MMG CAMCO MMG 2.920 13,789.2 5,836.3 55.00 SLEEVE 5.750 BAKER CMU-ELASTOMER SLIDING SLEEVE w/2.81" DS PROFILE BAKER CMU 2.810 13,805.2 5,845.4 55.02 NIPPLE 4.540 CAMCO D NIPPLE MILL FROM 2.75 TO 2.80 7/1/13 CAMCO D 2.800 13,849.1 5,870.6 55.06 LOCATOR 5.000 BAKER G-22 LOCATOR BAKER G-22 3.000 13,850.5 5,871.4 55.06 SBE 3.980 BAKER GBH-22 80-40 SEAL ASSEMBLY BAKER GBH-22 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) 13,917.5 5,909.8 54.99 RBP 2.72" TTS RBP W/ FILL EXT (MIDDLE ELEMENT @ 13,920' RKB) TTS RBP CPP3 5376 6/10/2025 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) 4,081.2 2,581.8 70.51 1 GAS LIFT DMY BK 1 0.0 5/7/2016 0.000 7,961.7 3,841.5 71.39 2 GAS LIFT DMY BK 1 0.0 5/7/2016 0.000 10,742.3 4,730.6 71.38 3 GAS LIFT DMY BK 1 0.0 5/7/2016 0.000 12,808.8 5,390.3 71.62 4 GAS LIFT DMY BK 1 0.0 4/21/2013 0.000 13,737.3 5,806.5 54.99 5 GAS LIFT DMY RK 1 1/2 0.0 4/4/2003 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 13,847.9 5,869.9 55.06 PACKER 5.970 BAKER ZXP LINER TOP PACKER w/TIE BACK SLEEVE (OD 5.79", ID 5.25") 4.420 13,866.8 5,880.7 55.04 NIPPLE 5.580 BAKER RS NIPPLE 4.250 13,900.0 5,899.8 55.01 XO BUSHING 5.000 X-OVER BUSHING 3.500 14,668.1 6,342.1 52.38 LANDING COLLAR 3.500 BAKER LANDING COLLAR BAKER 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 14,280.0 14,292.0 6,116.2 6,123.0 C-4, 2G-17 2/4/2003 6.0 CMT SQZ 2.25" HSD 2306 PJ HMX, 60 Deg Phasing Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 14,280.0 14,292.0 1 FRAC 3/10/2003 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 13,870.3 14,768.0 5,882.8 6,403.4 CMT SQZ 1/24/2003 4,419.8 5,752.8 2,691.9 3,134.7 OA CMT 9/27/2013 2G-17, 6/19/2025 3:22:05 PM Vertical schematic (actual) LINER; 13,847.9-14,768.0 CMT SQZ; 13,870.3 ftKB CMT SQZ; 14,280.0-14,292.0 FRAC; 14,280.0 WINDOW L1-01; 14,280.0- 14,286.0 PRODUCTION; 26.0-14,027.4 RBP; 13,917.5 GAS LIFT; 13,737.3 GAS LIFT; 12,808.8 GAS LIFT; 10,742.3 GAS LIFT; 7,961.7 SURFACE; 28.0-5,752.8 OA CMT; 4,419.8 ftKB GAS LIFT; 4,081.2 NIPPLE; 502.0 CONDUCTOR; 28.0-110.0 KUP INJ KB-Grd (ft) 27.60 RR Date 1/27/2003 Other Elev… 2G-17 ... TD Act Btm (ftKB) 14,768.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292313400 Wellbore Status INJ Max Angle & MD Incl (°) 72.97 MD (ftKB) 2,566.99 WELLNAME WELLBORE2G-17 Annotation Last WO: End DateH2S (ppm) 30 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag SLM 14,257.0 2G-17L1 9/15/2014 hipshkf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: REMOVE GAUGES 2G-17L1 1/7/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADD LATERALS L1, L1-01 (off the mainbore) 11/22/2013 haggea Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread LINER L1 (off L1-01) 2 3/8 1.99 14,472.0 18,465.0 6,202.0 4.70 L-80 ST-L 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) 14,472.0 6,128.7 91.76 BILLET 2.625 ANCHORED ALUMINUM BILLET BAKER 1.000 15,033.4 6,128.4 88.76 SLEEVE 2.625 SHORTY DEPLOYMENT SLEEVE BAKER 1.920 17,255.3 6,179.8 89.71 SLEEVE 2.625 SHORTY DEPLOYMENT SLEEVE BAKER 1.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 14,483.3 14,610.0 6,128.5 6,130.8 C-4, 2G-17 11/22/2013 SLOTS Slotted Liner 14,624.3 15,033.0 6,131.0 6,128.4 C-4, 2G-17 11/22/2013 SLOTS Slotted Liner 15,034.3 16,298.9 6,128.4 6,163.1 C-4, 2G-17 11/22/2013 SLOTS Slotted Liner 16,306.1 17,254.9 6,162.8 6,179.8 C-4, 2G-17 11/22/2013 SLOTS Slotted Liner 17,256.1 18,013.2 6,179.8 6,183.5 C-4, 2G-17 11/22/2013 SLOTS Slotted Liner 18,020.4 18,464.6 6,183.7 6,202.0 C-4, 2G-17 11/22/2013 SLOTS Slotted Liner 2G-17L1, 6/19/2025 3:22:05 PM Vertical schematic (actual) LINER L1 (off L1-01); 14,472.0- 18,465.0 SLOTS; 18,020.4-18,464.6 SLOTS; 17,256.1-18,013.2 SLOTS; 16,306.1-17,254.9 SLOTS; 15,034.3-16,298.9 SLOTS; 14,624.3-15,033.0 SLOTS; 14,483.3-14,610.0 LINER L1-01 (off the main wellbore); 14,291.9-16,510.0 SLOTS; 14,375.0-14,597.0 LINER; 13,847.9-14,768.0 CMT SQZ; 13,870.3 ftKB PRODUCTION; 26.0-14,027.4 RBP; 13,917.5 GAS LIFT; 13,737.3 GAS LIFT; 12,808.8 GAS LIFT; 10,742.3 GAS LIFT; 7,961.7 SURFACE; 28.0-5,752.8 OA CMT; 4,419.8 ftKB GAS LIFT; 4,081.2 NIPPLE; 502.0 CONDUCTOR; 28.0-110.0 KUP INJ KB-Grd (ft) 27.60 RR Date 1/27/2003 Other Elev… 2G-17L1 ... TD Act Btm (ftKB) 18,490.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292313460 Wellbore Status INJ Max Angle & MD Incl (°) 99.80 MD (ftKB) 14,410.40 WELLNAME WELLBORE2G-17 Annotation Last WO: End DateH2S (ppm) 30 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag SLM 14,257.0 2G-17L1-01 9/15/2014 hipshkf Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: REMOVE GAUGES 2G-17L1- 01 1/7/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADD LATERALS L1, L1-01 (off the mainbore) 11/22/2013 haggea Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread LINER L1-01 (off the main wellbore) 2 5/8 1.92 14,291.9 16,510.0 6,146.8 4.70 L-80 ST-L 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) 14,291.9 6,122.5 60.30 SLEEVE 2.625 SHORTY DEPLOYMENT SLEEVE Baker 1.920 15,370.7 6,150.0 88.19 SLEEVE 2.625 SHORTY DEPLOYMENT SLEEVE Baker 1.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 14,375.0 14,597.0 6,138.9 6,137.7 C-4, 2G-17 12/2/2013 SLOTS Slotted Liner 14,611.3 15,370.3 6,137.8 6,149.9 C-4, 2G-17 12/2/2013 SLOTS Slotted Liner 15,371.6 15,842.5 6,150.0 6,153.9 C-4, 2G-17 12/2/2013 SLOTS Slotted Liner 15,849.7 16,509.6 6,153.6 6,146.8 C-4, 2G-17 12/2/2013 SLOTS Slotted Liner 2G-17L1-01, 6/19/2025 3:22:06 PM Vertical schematic (actual) LINER L1-01 (off the main wellbore); 14,291.9-16,510.0 SLOTS; 15,849.7-16,509.6 SLOTS; 15,371.6-15,842.5 SLOTS; 14,611.3-15,370.3 SLOTS; 14,375.0-14,597.0 LINER; 13,847.9-14,768.0 CMT SQZ; 13,870.3 ftKB PRODUCTION; 26.0-14,027.4 RBP; 13,917.5 GAS LIFT; 13,737.3 GAS LIFT; 12,808.8 GAS LIFT; 10,742.3 GAS LIFT; 7,961.7 SURFACE; 28.0-5,752.8 OA CMT; 4,419.8 ftKB GAS LIFT; 4,081.2 NIPPLE; 502.0 CONDUCTOR; 28.0-110.0 KUP INJ KB-Grd (ft) 27.60 RR Date 1/27/2003 Other Elev… 2G-17L1-01 ... TD Act Btm (ftKB) 16,889.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292313461 Wellbore Status INJ Max Angle & MD Incl (°) 99.80 MD (ftKB) 14,410.40 WELLNAME WELLBORE2G-17 Annotation Last WO End DateH2S (ppm) 30 Date 11/22/2015 Comment SSSV: NIPPLE Originated: Delivered to:18-Jun-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2B-02A 50-029-21154-01 910106459 Kuparuk River Multi Finger Caliper Field & Processed 14-Jun-25 0 12 2B-03B 50-029-21151-02 n/a Kuparuk River Radial Bond Record Field- Final 8-Mar-25 0 13 2F-09 50-029-21090-00 910080198 Kuparuk River Plug Setting Record Field- Final 23-May-25 0 14 2F-09 50-029-21090-00 910010602 Kuparuk River Radial Bond Record Field- Final 2-May-25 0 15 2G-17 50-029-23134-00 910106461 Kuparuk River Plug Setting Record Field- Final 9-Jun-25 0 16 2K-23 50-103-20125-00 910099510 Kuparuk River Multi Finger Caliper Field & Processed 2-Jun-25 0 17 2K-34 50-103-20688-00 910096425 Kuparuk River Multi Finger Caliper Field & Processed 15-Jun-25 0 18 2M-08 50-103-20184-00 910027001 Kuparuk River Multi Finger Caliper Field & Processed 9-May-25 0 19 2M-25 50-103-20152-00 910106929 Kuparuk River Plug Setting Record Field- Final 12-Jun-25 0 110 2M-25 50-103-20152-00 910106929 Kuparuk River Tubing Cut Record Field- Final 13-Jun-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:216-087223-080184-036202-243190-014214-026192-101191-021T40589T40590T40591T40591T40592T40593T40594T40595T40596T405966/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.20 08:42:29 -08'00'2G-1750-029-23134-00 910106461Kuparuk RiverPlugSetting RecordField- Final9-Jun-2501202-243 CAUTION: This email originated from outside the State of Alaska mail system. 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From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: AOGCC Notification: KRU: 2G-17 (PTD: 202-243) IA Exceeded OPL Date:Thursday, June 5, 2025 9:20:29 AM Attachments:AnnComm Surveillance TIO for 2G-17.pdf From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Thursday, June 5, 2025 9:17 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: AOGCC Notification: KRU: 2G-17 (PTD: 202-243) IA Exceeded OPL Well Name: 2G-17 Facility: CPF2 PTD: 22-243 Well Type: Inj AA Number (if applicable): AIO 2C.070 Internal Waiver (Yes/No if applicable): Type of Issue: IA Exceeded OPL Maximum Pressure (if applicable): 2010 psi Date of Occurrence (if applicable): 6/5/2025 Hi Chris, KRU 2G-17 (PTD 202-243) is an injection well with an AA (AIO 2C.070) for water only injection due to TxIA on gas injection. The IA pressure exceeded the well’s IA operation pressure limit of 2000 psi on 6/5/2025. The IA reached 2010 psi. Operations shut in the well and bled the IA pressure to 600 psi. CPAI intends to conduct integrity diagnostics with the well shut in. Proper notifications for continued injection or corrective action will be submitted once diagnostics have been completed and a plan forward is determined. CPAI intends to keep the IA pressure below 2000 psi during diagnostics but will notify the AOGCC if this is not feasible. The TIOs, schematic, and bleed logs are attached. Please let me know if you have any questions or disagree with the plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2G-17 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 28.0 Set Depth (ftKB) 110.0 Set Depth (TVD) … 110.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELD Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.835 Top (ftKB) 28.0 Set Depth (ftKB) 5,752.8 Set Depth (TVD) … 3,134.7 Wt/Len (l… 40.00 Grade L-80 Top Thread BTCM Casing Description PRODUCTION OD (in) 7 ID (in) 6.276 Top (ftKB) 26.0 Set Depth (ftKB) 14,027.4 Set Depth (TVD) … 5,972.9 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description WINDOW L1-01 OD (in) 3 1/2 ID (in) 2.992 Top (ftKB) 14,280.0 Set Depth (ftKB) 14,286.0 Set Depth (TVD) … 6,119.6 Wt/Len (l… 9.20 Grade L-80 Top Thread Casing Description LINER OD (in) 3 1/2 ID (in) 2.992 Top (ftKB) 13,847.9 Set Depth (ftKB) 14,768.0 Set Depth (TVD) … 6,403.4 Wt/Len (l… 9.30 Grade L-80 Top Thread SLHT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 13,847.9 5,869.9 55.06 PACKER BAKER ZXP LINER TOP PACKER w/TIE BACK SLEEVE (OD 5.79", ID 5.25") 4.420 13,866.8 5,880.7 55.04 NIPPLE BAKER RS NIPPLE 4.250 13,870.3 5,882.8 55.04 HANGER BAKER FLEX-LOCK HYDRUALIC LINER HANGER 4.450 13,880.0 5,888.3 55.03 SBE SEAL BORE EXTENSION 4.000 13,900.0 5,899.8 55.01 XO BUSHING X-OVER BUSHING 3.500 Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 23.2 Set Depth (ft… 13,889.4 Set Depth (TVD) (… 5,893.7 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.2 23.2 0.06 HANGER FMC GEN V TUBING HANGER 3.500 502.0 502.0 1.42 NIPPLE CAMCO DS NIPPLE 2.875 13,789.2 5,836.3 55.00 SLEEVE BAKER CMU-ELASTOMER SLIDING SLEEVE w/2.81" DS PROFILE 2.810 13,805.2 5,845.4 55.02 NIPPLE CAMCO D NIPPLE MILL FROM 2.75 TO 2.80 7/1/13 2.800 13,849.1 5,870.6 55.06 LOCATOR BAKER G-22 LOCATOR 3.000 13,850.5 5,871.4 55.06 SBE BAKER GBH-22 80-40 SEAL ASSEMBLY 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 14,280.0 14,292.0 6,116.2 6,123.0 C-4, 2G-17 2/4/2003 6.0 CMT SQZ 2.25" HSD 2306 PJ HMX, 60 Deg Phasing Stimulations & Treatments Proppant Designed (lb) Proppant In Formation (lb) Date 3/10/2003 Stimulations & Treatments Stg # Top (ftKB) Btm (ftKB) Date Stim/Treat Fluid Vol Clean Pump (bbl) Vol Slurry (bbl) 1 14,280.0 14,292.0 3/10/2003 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 13,870.3 14,768.0 5,882.8 6,403.4 CEMENT 1/23/2003 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 4,081.2 2,581.8 CAMCO KBUG- M 1 GAS LIFT DMY BK 0.000 0.0 5/7/2016 2 7,961.7 3,841.5 CAMCO KBUG- M 1 GAS LIFT DMY BK 0.000 0.0 5/7/2016 3 10,742.3 4,730.6 CAMCO KBUG- M 1 GAS LIFT DMY BK 0.000 0.0 5/7/2016 4 12,808.8 5,390.3 CAMCO KBUG- M 1 GAS LIFT DMY BK 0.000 0.0 4/21/2013 5 13,737.3 5,806.5 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/4/2003 Notes: General & Safety End Date Annotation 10/22/2010 NOTE: View Schematic w/ Alaska Schematic9.0 11/22/2013 NOTE: ADD LATERALS L1, L1-01 (off the main wellbore) Comment SSSV: NIPPLE2G-17, 1/15/2018 12:34:17 PM Vertical schematic (actual) LINER; 13,847.9-14,768.0 CMT SQZ; 13,870.3 ftKB CMT SQZ; 14,280.0-14,292.0 FRAC; 14,280.0 WINDOW L1-01; 14,280.0- 14,286.0 PRODUCTION; 26.0-14,027.4 SBE; 13,850.5 LOCATOR; 13,849.1 NIPPLE; 13,805.2 SLEEVE; 13,789.2 GAS LIFT; 13,737.3 GAS LIFT; 12,808.8 GAS LIFT; 10,742.3 GAS LIFT; 7,961.7 OA CMT; 4,419.8 ftKB SURFACE; 28.0-5,752.8 GAS LIFT; 4,081.2 NIPPLE; 502.0 CONDUCTOR; 28.0-110.0 HANGER; 23.2 Annotation Last Tag RKB Depth (ftKB) 14,256.0 End Date 1/14/2018 Annotation Rev Reason: TAG Last Mod By pproven End Date 1/15/2018 KUP INJ KB-Grd (ft) 27.60 Rig Release Date 1/27/2003 Annotation Last WO: End Date 2G-17 H2S (ppm) 30 Date 11/22/2015 ... TD Act Btm (ftKB) 14,768.0 Well Attributes Wellbore API/UWI 500292313400 Field Name KUPARUK RIVER UNIT Wellbore Status INJ Max Angle & MD Incl (°) 72.97 MD (ftKB) 2,566.99 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, June 12, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2G-17 KUPARUK RIV UNIT 2G-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/12/2024 2G-17 50-029-23134-00-00 202-243-0 W SPT 5870 2022430 3000 2738 2739 2738 2739 15 15 15 15 REQVAR P Adam Earl 5/1/2024 Tested as per AIO 2C.070 to MAIP 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2G-17 Inspection Date: Tubing OA Packer Depth 620 3280 3170 3160IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240501201554 BBL Pumped:6.2 BBL Returned:6 Wednesday, June 12, 2024 Page 1 of 1 9 9 9 9 9 9 99 9 9 9 9 9 9 AIO 2C.070 James B. Regg Digitally signed by James B. Regg Date: 2024.06.12 12:33:04 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2G-17 KUPARUK RIV UNIT 2G-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 2G-17 50-029-23134-00-00 202-243-0 W SPT 5870 2022430 3000 2780 2750 2750 2750 75 172 165 158 REQVAR P Adam Earl 5/4/2022 MIT IA to max ant. Inj. Psi. per 2C.070 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2G-17 Inspection Date: Tubing OA Packer Depth 1120 3360 3280 3250IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220509133520 BBL Pumped:5.5 BBL Returned:5.4 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 MIT IA 2C.070 James B. Regg Digitally signed by James B. Regg Date: 2022.06.13 14:22:53 -08'00' MEMORANDUM TO: Jim Regg " 1 P.I. Supervisor FROM: Guy Cook Petroleum Inspector Well Name KUPARUK RIV UNIT 2G-17 IInsp Num: mitGDC200508163858 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 11, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2G-17 KUPARUK RIV UNIT 2G-17 Src: Inspector Reviewed By: P.I. Supry y�t� Comm API Well Number 50-029-23134-00-00 Inspector Name: Guy Cook Permit Number: 202-243-0 Inspection Date: 5/8/2020 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 2G-17 Type In W TVDp j 5870 Tubing 2730 - 2730 ' 2730 2730 2022430 IT a Test:1 SPT Test SLI 0 - — - -- Well YP J _ _ P'j'j) � 3000 IA 320 3490 ' � 3390 3380 BBL Pumped: T 7.8 'BBL Returned: 7A OA 23 29 29 29 Interval REQvAR P/F P Notes' MITIA every 2 years to maximum anticipated injection pressure per AIO 2C.070. Testing performed with a Little Red Services pump truck and calibrated gauges. /- Monday, Monday, May 11, 2020 Page 1 of 1 i1 Zia -17 Regg, James B (CED) Grb ZOZ24-30 From: Brooks, Phoebe L (CED) Sent: Friday, May 17, 2019 3:30 PM� To: Regg, James B (CED) Subject: FW: Report of multiple bleeds of IA on 2G-17 (PTD 202-243) update 4-17-19 Attachments: MIT KRU 2G-17 diagnostic MITIA 4-10-19.xlsx Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.g_ov. From: Wallace, Chris D (CED) Sent: Friday, May 17, 2019 3:16 PM To: Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov> Subject: FW: Report of multiple bleeds of IA on 2G-17 (PTD 202-243) update 4-17-19 Another MIT for a well I am preparing the AA for. Note the test date was actually 4/15/2019. From: NSK Well Integrity Supv CPFi and 2 <n1617@conocophillips.com> Sent: Wednesday, April 17, 2019 10:53 AM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: RE: Report of multiple bleeds of IA on 2G-17 (PTD 202-243) update 4-17-19 Chris, After 2G-17 continued to display signs of TxIA communication while on gas injection, the well was WAG'ed to water injection on April 10`^. Passing packoff tests, MITIA and drawdown test were performed. The well is now on a 30 -day water -only monitor in anticipation of an AA submittal. Please let us know if you disagree with the path forward. Kelly Lyons / Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 From: NSK Well Integrity Supv CPF1 and 2 Sent: Wednesday, March 20, 2019 10:19 AM To: Wallace, Chris D (DOA) <chris.wallace @alaska.aov> Cc: CPA Wells Supt <nl030@conocophillips.com> Subject: Report of multiple bleeds of IA on 2G-17 (PTD 202-243) 3-20-19 Chris, 2G-17 (PTD 202-243) has had the IA bled a couple of times over the last couple of weeks, as well as a longer trend, slow build-up in IA pressure over the last several months. At this time, the pressure fluctuations are still being attributed to thermal responses. However, there is enough of an anomalous behavior to warrant heightened scrutiny. Therefore we will be put the well on a 30 day monitor. If the well becomes more strongly suspected of displaying annular communication, we will pursue DHD diagnostics to include packoff testing and MITIA. The well has been on MI injection September 2018. An update will be provided at the conclusion of the monitor period. Let us know if you disagree with the path forward. Attached is a 90 -day TIO plot. Kelly Lyons / Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: lim.reoo(dialaska.00v: AOGCC.Insoectors0alaska.cov: ohoebe.brooks0alaska.00v, OPERATOR: ConocoPhillips Alaska Inc, FIELD / UNIT I PAD: Kuparuk / KRU / 2G Pad DATE: 04/15/19 OPERATOR REP: Duffy / Weimer AOGCC REP: 60 Min. chns.wallace(r7)alaska. cov Well 2G-17 - INTERVAL Codes Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 4 = Four Year Cycle F = Fail PTD 2022430 Type Inj W Tubing 2133 2133 2133 - 2133 N = Not Injecting Type Test P Packer TVD 5870 - BBL Pump 6.5 - IA 459 3000 - 2970 2970 - Interval O Test psi 1500 BBL Return 6.8 - OA 35 44 44 44 Result P Notes: Diagnostic MITIA Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD 6131- Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas 0 = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = St., V = Required by Variance 1= Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting - Form 10-426 (Revised 01/2017) 201&0410 MIT KRV_2G-17 Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophiIIips.com> Sent: Wednesday, March 20, 2019 10:19 AM To: Wallace, Chris D (DOA) Cc: CPA Wells Supt Subject: Report of multiple bleeds of IA on 2G-17 (PTD 202-243) 3-20-19 Attachments: 2G-17 90 day TIO 3-20-19.PNG Chris, 2G-17 (PTD 202-243) has had the IA bled a couple of times over the last couple of weeks, as well as a longer trend, slow build-up in IA pressure over the last several months. At this time, the pressure fluctuations are still being attributed to thermal responses. However, there is enough of an anomalous behavior to warrant heightened scrutiny. Therefore we will be put the well on a 30 day monitor. If the well becomes more strongly suspected of displaying annular communication, we will pursue DHD diagnostics to include packoff testing and MITIA. The well has been on MI injection September 2018. An update will be provided at the conclusion of the monitor period. Let us know if you disagree with the path forward. Attached is a 90 -day TIO plot. Kelly Lyons / Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,June 29,2016 TO: Jim Regg ��' 7l 011C, SUBJECT: Mechanical Integrity Tests P.I.Supervisor 7 g tY CONOCOPHILLIPS ALASKA INC 2G-17 FROM: Jeff Jones KUPARUK RIV UNIT 2G-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry r�- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2G-17 API Well Number 50-029-23134-00-00 Inspector Name: Jeff Jones Permit Number: 202-243-0 Inspection Date: 6/28/2016 Insp Num: mitJJ160628163239 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2G-17 - Type Inj E W TVD 5870 . Tubing 2170 - 2195 - 2197 - 2205- PTD 2022430 - Type Test SPT Test psi 1500 IA 940 2900- 2850 , 2850 . Interval INITAL / P/F P ✓ OA 371 . 567 556 . 550 - Notes: 4 BBLS diesel pumped. 1 well inspected,no exceptions noted. SCA NEED NOV 2 2 2010 Wednesday,June 29,2016 Page 1 of 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate E Rill Tubing r Operations shutdown r Performed. Suspend r Perforate r Other Stimulate Casing�'" Change Approved Program Rug for Redrill r Fbrf orate New Pool r Repair Well r Re-enter Susp Well r Other: PROD to WAG p" 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p' Exploratory r 202-243 — 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-23134-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25666 KRU 2G-17 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 14768' feet Plugs(measured) 2751 true vertical 6403' feet Junk(measured) None Effective Depth measured 14668 feet Packer(measured) 13805, 13849, 13851 true vertical 6342 feet (true vertical) 5845, 5871, 5871 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 110 110' SURFACE 5725 12 5753 3135' PRODUCTION 14001 10 14027 5973' WINDOW L1-01 6 3.5 14286 6119' LINER 920 5.97 14768 6403' RECEWED Perforation depth: Measured depth: 14280-14292 �{ OCT JUN 2 O, True Vertical Depth: 6116-6123 SCANNED C t 3 12016 AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 13889 MD, 5894 TVD Packers&SSSV(type,MD,and ND) NIPPLE-CAMCO DS NIPPLE @ 502 MD and 502 TVD NIPPLE-CAMCO D NIPPLE MILL FROM 2.75 TO 2.80 7/1/13 @ 13805 MD and 5845 TVD LOCATOR-BAKER G-22 LOCATOR @ 13849 MD and 5871 TVD SBE-BAKER GBH-22 80-40 SEAL ASSEMBLY @ 13851 MD and 5871 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 399 1099 25 627 153 Subsequent to operation 0 0 7649 275 1709 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p' Exploratory r Development r Service 17 Stratigraphic r Copies of Logs and Surveys Run r' 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR E WINJ r WAG ' GINJ r SUSP r SPLUG E 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: 316-075 Contact Darrell Humphrey/Bob Christensen Email: n1139(C7conocophillips.com Printed Name Darrell Humphrey Title: NSK Production Engineering Specialist Signature14\ Phone:659-7535 Date ...D. ...y...e4.AAForm 10-404 Revised 5/2015ri `I / 2 1 6- RgpMS LLAUi', 2016 Submit Original Only , , • • 2G-17 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/12/16 Well brought online, converted to WAG service KUP PROD • 2G-17 ConocoPhillips aI Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ft60) ccr«owlups 500292313400 KUPARUK RIVER UNIT PROD 72.97 2,566.99 14,768.0 -.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 23-17,5/1012016111.37 PM SSSV:NIPPLE 30 11/22/2015 Last WO: 27.60 1/27/2003 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ._. ........... Last Tag SLM 14,277.0 2/23/2016 Rev Reason:PULLED C-LOCK,H2S,CLOSED pproven 5/10/2016 DANGER•23.2 ® 111r CMU,GLV C/O Casing Strings t1F Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread �_1:11-,.....-... 14.3 CONDUCTOR 16 15.062 28.0 110.0 110.0 62.50 H-40 WELD i Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread SURFACE 95/8 8.835 28.0 5,752.8 3,134.7 40.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 26.0 14,027.4 5,972.9 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread WINDOW L1-01 31/2 2.992 14,280.0 14,286.0 6,119.6 9.20 L-80 J✓s/CONDUCTOR;28.0-110.0 - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER 31/2 2.992 13,847.9 14768.0 6,403.4 9.30 L-80 SLHT NIPPLE;502.0 Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 11 13,847.9 5,869.9 55.06 PACKER BAKER ZXP LINER TOP PACKER w/TIE BACK 4.420 SLEEVE(00 5.79",ID 5.25") GAS LIFT;4,081.2 - 13,866.8 5,880.7 55.04 NIPPLE BAKER RS NIPPLE 4.250 13,870.3 5,882.8 55.04 HANGER BAKER FLEX-LOCK HYDRUALIC LINER HANGER 4.450 13,880.0 5,888.3- 55.03 SBE 'SEAL BORE EXTENSION 4.000 • 13,900.0 5,899.8 55.01 XO BUSHING X-OVER BUSHING 3.500 Tubing Strings SURFACE;28.0-5,752.8-4i ° Tubing Description I String Ma...I ID(in) 'Top(ftKB) I Set Depth(ft..'Set Depth(TVD)(...I Wt(lb/ft) (Grade 'Top Connection TUBING 31/2 2.992 23.2 13,8894 5,8937 9.30 L-80 EUE-8rd Completion Details GAS LIFT;7,961.7 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°)_ Item Den Com (in) 23.2 23.2 0.06 HANGER FMC GEN V TUBING HANGER 3.500 502.0 502.0 1.42 NIPPLE CAMCO DS NIPPLE 2.875 13,789.2 5,836.3 55.00 SLEEVE BAKER CMU-ELASTOMER SLIDING SLEEVE w/2.81" 2.810 DS PROFILE GAS LIFT;10,742.3 • - 13,805.2 5,845.4 55.02 NIPPLE CAMCO D NIPPLE MILL FROM 2.75 TO 2.80 7/1/13 2.800 13,849.1 5,870.6 55.06 LOCATOR BAKER G-22 LOCATOR 3.000 I 13,850.5 5,871.4 55.06 SBE BAKER GBH-22 80-40 SEAL ASSEMBLY 3.000 Perforations&Slots GAS LIFT;12808.8 Shot Den Top(ND) Btm(ND) (shots/f Top((tKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 14280.0 14,292.0 6,116.2 6,123.0 C-4,2G-17 2/4/2003 6.0 CMT 2.25"HSD 2306 PJ SQZ HMX,60 Deg Phasing GAS LIFT,13,737.3 Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Btm(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 14,280.0 14,292.0 6,116.2 6,123.0 FRAC 3/10/2003 40#X-LINKED GEL©20 BPM WITH 16/20 CERAMIC PROPPANT;45,228#OF PROPPANT SLEEVE;13,789.2 1_ 1 BEHIND PIPE W/6 PPA AT PERFS Cement Squeezes Top(ND) Btm(ND) NIPPLE;13,8052 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date I Com 13,870.3 14,768.0 5,882.8 6,403.4 CEMENT 1/23/2003 Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run `I Kr N Top(ftKB) _ (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com LOCATOR;13,849.1 4' 1 4,081.2 2,581.8 CAMCO KBUG- 1 GAS LIFT DMY BK 0.000 0.0 5/7/2016 r M 1 ci /t 2 7,961.7 3,841.5 CAMCO KBUG- 1 GAS LIFT DMY BK ' 0.000 0.0 5/7/2016 M SBE;13.850 S - 3 10,742.3 4,730.6 CAMCO KBUG- i GAS LIFT DMY BK 0.000 0.0 5/7/2016 pi ros Pt M 'i_:I .I I, 4 12,808.8 5,390.3 CAMCO KBUG- 1 GAS LIFT DMY BK 0.000 0.0 4/21/2013 a Air D M M 6 5 13,737.3 5,806.5 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.0001 0.0 4/4/2003 Notes:General&Safety 1 End Date Annotation 10/22/2010 NOTE:View Schematic w/Alaska Schematic9.0 ith .✓ 11/22/2013 NOTE:ADD LATERALS L1,L1-01(off the main wellbore) 4, ;✓ PRODUCTION;26.0-14.027.4- t ;✓ ;✓ `V; ;✓ V; V; ti WINDOW L1-01;14,280.0- y/ 14,286.0 i FRAC;14.280.0 ( . CMT SQZ;14,280.0-14,292.0 'tr. 4 LA LINER;13,847.9-14,768.0 • • OF Ty • IP.I//7; .‘v THE STATE Alaska Oil and Gas tv - 7� ALASKA Conservation Commission _ 333 West Seventh Avenue ' 7# '. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �'' Main: 907.279.1433 ofd ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Darrell Humphrey NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. SCA4� P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2G-17 Permit to Drill Number: 202-243 Sundry Number: 316-075 Dear Mr. Humphrey: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P4‘-'75& Cathy . Foerster Chair DATED this 2- day of March, 2016. RBDMS Lt- MAR 0 4 2016 RECEIVED • ! Co{ ,t�� STATE OF ALASKA 54/. �� FEB 2 5 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION it APPLICATION FOR SUNDRY APPROVALS REVISED �1OGCsC 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other: PROD to WAG P. 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development i' 202-243 3.Address. Stratigraphic r Service 6.API Number. P.O. Box 100360,Anchorage,Alaska 99510 50-029-23134-00 7.If perforating, NAr 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 0143 Will planned perforations require spacing exception? Yes r No po KRU 2G-17 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25666 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 14768' 6403' 14668' 6342' 2751 None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 110' 110' SURFACE 5725 9.625 5753' 3135' PRODUCTION 14001 7 14027' 5973' WINDOW L1-01 6 3.5 14286' 6119' LINER 920 3.5 14768' 6403' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 14280-14292 6116-6123 3.5 L-80 13889 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV-CAMCO DS NIPPLE MD=502 TVD=502 NIPPLE-CAMCO D NIPPLE MD=13805 TVD=5845 PACKER-BAKER ZXP LINER TOP MD=13848 TVD=5870 SBE-BAKER GBH-22 80-40 SEAL ASSEMBLY MD=13851 TVD=5871 12.Attachments: Proposal Summary r WellBore schematic Fre 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:3/15/2016 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17.I hereby certify that the foregoing is true Contact: Darrell Humphrey/Bob Christensen Printed Name Darrell Humphrey Phone:659-7535 Email: n1139@conocophillips.com Title: NSK Production Engineering Specialist Signature Date: c,.2.79; //P Commissio Use Only / ` Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ` — o76 � Rug Integrity r BOP Test r Mechanical Integrity Test IV Location aearance r Other: • 4 w'4IVer /5 9ra. ftc� /dawpacker" lacrc/ 43o 4b0v-c. fie top Pe ( 4A-14-e 25. 4/z (L.) ) . Post Initial Injection MIT Req'd? Yes r 2 No r Spacing Exception Required? Yes r No F7 Subsequent Form Required: lo — 40 Lk APPROVED BY Approved byVIL 3/I go : (87 COMMISSIONER, I THE COMMISSION Date:3_2 „// A Submit Form and Form 10-403 Revised 11/2015 for 12 months from the date of approval. Attachments in Duplicate RBDMS L� M � 0 4 2016 RECEIVED FEB 0 3 2016 STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION AOG�'+VVC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other: PROD to WAG • 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Exploratory r Development p", 202-243 3.Address: Stratigraphic r Service 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-23134-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? ('1A, Will planned perforations require spacing exception? Yes r No V KRU 2G-17 - 9.Property Designation(Lease Number): hia 10.Field/Pool(s): ADL 25666t Q.6(44,7" Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP{pei)`- Plugs(MD): Junk(MD): ' 14768' 6403' . 14668' ' 6342' {l/, 1597' None None Casing Length Size MD Burst Collapse CONDUCTOR 82 16 110' 110' SURFACE 5725 9.625 5753' 3135' PRODUCTION 14001 7 14027' 5973' WINDOW L1-01 6 3.5 14286' 6119' LINER 920 3.5 14768' 6403' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 14280-14292 4 6116-6123 3.5 L-80 13889 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV-CAMCO DS NIPPLE ' MD=502 TVD=502 NIPPLE-CAMCO D NIPPLE s MD=13805 TVD=5845 PACKER-BAKER ZXP LINER TOP • MD=13848 TVD=5870 SBE-BAKER GBH-22 80-40 SEAL ASSEMBLY MD=13851 TVD=5871 12.Attachments: Proposal Summary r WellBore Schematic ry 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r " 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:3/15/2016 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG rz' GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17.I hereby certify that the foregoing is true Contact: Darrell Humphrey/Bob Christensen Printed Name Darrell Humphrey Phone:659-7535 Email: n1139(a�conocophillips.com Title: NSK Production Engineering Specialist Signature + \ I Date: ,2. z. . Ito Commis ion Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3)(AO ` Vr7 5 Rug Integrity r BOP Test .Aechanical Integrity Test cation Gearance r Other: Post Initial Injection MIT Req'd? Yes No r Spacing Exception Required? Yes r No (� Subsequent Form Required: j 0— Q.Q /1 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 914b Oi)1(s. nIL IN(�A � Submit Form and Form 10-403 Revised 11/2015 Approved applicati/� aR d t ro date of approval. Attachments in Duplicate • • Loepp, Victoria T (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Friday, February 19, 2016 2:07 PM To: Loepp,Victoria T (DOA) Subject: RE: KRU 2G-17(PTD 202-243); 2G-17L1(PTD 213-073);2G-17L1-01(213-074) Conversion to WAG Attachments: 2G-17 Final CTD Schematic.pdf;2G-17L1 Prod to WAG 10-403 01-29-16.xlsm; 2G-17L1-01 Prod to WAG 10-403 01-29-16.xlsm; 2G-17 Prod to WAG 10-403 01-29-16.xlsm Follow Up Flag: Follow up Flag Status: Flagged Victoria-Below are the responses to your questions regarding the sundry application for 2G-17, L1& L1-01. I have attached a new schematic and also revised sundry documents to show the new value for the MPSP. This was recalculated using an initial pressure. Due to a formatting error a 'attached to the psi value.This has been eliminated to correctly reflect the psi value. Let me know if I need to resubmit a new sundry or if this will suffice. Also let me know how to proceed with filing a variance if one is still needed. Thanks, Darrell Humphrey / Bob Christensen ConocoPhillips Alaska, Inc. Production Engineering Specialist Office(907) 659-7535 NSK-69 Pager(907)659-7000 (924) From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, February 18, 2016 7:36 AM To: NSK Prod Engr Specialist Cc: Kanady, Randall B Subject: [EXTERNAL]KRU 2G-17(PTD 202-243); 2G-17L1(PTD 213-073); 2G-17L1-01(213-074) Conversion to WAG Darrell, This well and the laterals were originally permitted as producers. Several issues: 1. The TOC is indicated at 13890' MD. Is this the TOC for the 3-1/2" liner or for the 7" production casing?What is the TOC for the 7" production casing? How was this TOC determined? The the 4/30/2013 nd Log of the 3. 5" liner was found to be 13, 890' . The 7" production casing did not have a CBL completed. The TOC was calculated based on a conservative excess cement factor and determined to be at 13, 675' . This information is noted (including calculations) in the 2G-17 of Review word dor- 2G-17 CBL and interpretation of the cement quality of the subject well The 9-5/8" 401b/ft L-80 surface casing of 2G-17 was cemented with 495 bbls AS Lite and 248 bbls LiteCRETE. 170 sacks of Class G cement were used for the 7" 26 lb/ft L-80 production casing.The 3-1/2" 9.3 lb/ft L-38 liner, present from 13,847'MD to 14,768'MD,was cemented with 35 bbls of Class G cement. 1 • • , A Radial Cement Bond Log was run on April 30, 2013 to determine the cement job quality prior to drilling CTD laterals from the 2G-17 wellbore.The casing bond log request specified investigation over the 3.5" liner interval of 14,000'- 14,400'MD—per the radial cement bond log report, good cement bond was observed over the interval of 14,000'- 14,400'MD. Estimated top of cement was determined to be at 13,890'MD.The estimated top of cement accounts for 382' of good quality cement above the producing zone. The 7" production casing, set at a depth of 14,027'MD, overlaps with the 3.5" liner, set from 13,848'MD to 14,768'MD, by 179'.The radial cement bond log run on April 30, 2013 shows that at least 137' of the 179' overlap has a good cement bond.The 137' of good cement bond exceeds the 20 AAC 25.030 (6) requirement of 100' overlap between outer and inner strings when the production string is a liner. The 7" production casing cement job was designed to pump 170 sacks of Class G cement based on a planned 75%excess and desired 800' cement shoe track. Following the 7" production casing cement job the decision was made to drill ahead and attempt to log the cement job at a later time due to the logging tools not working.The cement bond log of the production casing was not completed at a later date. From the drilling report on 1/14/2003: • CMT 7"" Csg- Pumped 5 bbls CW 100,Test CMT lines 3000psi, Pumped 35 bbls CW 100, Drop bttm plug, pump 50 bbls Mudpush, pump 36.5 bbls 15.8 ppg G Slurry,Drop Top Plug, Kick out plug w/20 bbls wash up-Try over to rig for displacement • Rig displace @ 6 bpm,600 psi - Bumped plug to 1500psi (900 psi over pump rate) Slowed pump rate to 3 bpm to bump plug-CIP @ 11:30- Floats held (Shoe @ 14027' MD- 5972'TVD) From the drilling report on 1/17/2003: • TIH to 13905 -Tag CMT @ 13,905'-Std bk 1 std ****NOTE****** With only the Rec,Dir,Gama & Pressure portions of the logging tools working the decision was made to drill ahead and attempt to get the logs at a later time (Mad pass or E-line logs) Calculated top of cement as follows: • Cement pumped =36.5 bbls 15.8 ppg Class G cement slurry • Top of cement in production casing= 13,905' MD • Production casing shoe = 14,027' MD • Volume of cement in 7" (ID =6.276") production casing: (14,027'—13,905')*(rt*6.276iz)/4=26.21 ft3-÷ 26.21 ft3(1bb1/5.615 ft3) =4.67 bbls • Cement displaced into annulus=36.5 bbls—4.67 bbls= 31.83 bbls • Height of 31.83 bbls of cement in the annular space between 8.5" hole and 7" 261b/ft casing assuming 75% excess factor r31.83bb1*0.25\(44.28 ft` =352 ft 1 lbbl • Calculated top of cement= 14,027' MD—352'of cement= 13,675' MD Per the 3.5" liner radial cement bond log 382' of cement is present above the producing zone.The 7" production casing and 3.5" liner overlap for 179',of this 137'was shown to have good cement bond.Assuming an excess factor of 75%,the top of cement behind the 7" production casing is 13,675'MD,yielding a minimum of 352'of cement behind pipe.Total cement above the C sand producing zone (14,272'—13,675') is 597', meeting the required 500' minimum above production zones. 2. The packer depth of 13847' MD is 432'above the top perforation which does not meet regulation 20 AAC 25.412(b).A variance must be requested. Please let me know what needs to be done to request a variance as I have not done one of these before. 2 • • • 3. The MPSP on each of the 10-403 forms is listed as 1597' which does not make sense This has been corrected 27c1 nci ,using an initial well nrpccure 4. There is a well bore schematic in the 10-407 for the laterals drilled in 2013 which shows the motherbore as well as the laterals. I would recommend you include this schematic with the sundry applications when they are available for clarity. CTD Multi Lat schematic is attached. Please get with the production engineer to address these issues. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loenn@alaska.gov 3 • 0 /B §§ 7Q \$ »a f„- \ c �� 3'- F-: co � N NN \% / _0 . . .. 00 I ( a csic e,-, e k O - E '1 \ o_ \ # \ # Ri :t D _ /o ^ ® o o ƒ a a\ Gt \ ° \ 3 ems = - I ^ � I- \ // \ 0 b - N- ) N. / I \ - \o a ¥\ - co \q �, ��, \ 7 © ( , � O 0 \� - \ / © �� III :I1 = 2 $ /g E G 6 i ` ° } k E - - U) } \ I, ,I� \ � 3£ / /e � 0-c I` � 0 o. \• co \\ \ e� § § % \ II f2 1— og a7 / � � / III , 5 m u /� 02 , + EQu \ i � E / 2 00 0o20 ( jL /ƒ I, |1 b S0 0 _ I , E # EE � ( kk #« ` I _~ o § CO 0300 2g : * i / ) /a - I i[ »ƒ • 2 2N § § ` b - �E /k n n n n r 3 ) \ ) ) 2 \$ �I �7 co ®% aR �) ° i ®G / 2 % \i © 0 0'7> \ \ T. ) v, ~ �( \ /6 d- §7 § IA of ci d ._ 0 : k ] . ( | ! ) o £ , , :, .� . . . . 01 1 , -- _ III CO . . � k q Q 1 q § o o °o \} \ o °0 \ \§ f -J § 1 }§ k� 2§ ai \\ 2ZO _ *a N- Q f & CSI \\ \\ • 2G-17 • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 2G-17 (PTD# 202-243) from Oil Production service to Water Alternating Gas Injection service. Area of Review: Kuparuk well 2G-17 was drilled in 2002 to test the C Sand southeast of the 2G-pad. In 2003 the C sand was hydraulically fractured. A seven day production test showed rates to be uneconomic to justify permanent tie- in to Drillsite 2G facilities. 2G-17 was suspended at this time due to poor economic outlook. In 2013 two CTD laterals, 2G-17L1 and 2G-17L1-01, were drilled in the C sand. CTD producer 2G-17 was placed on production (POP) 2/24/2014. Encouraging production rates led to the approval and drilling of grassroots rotary horizontal injector 2F-22 in late 2014. 2F-22 was POP'd in February of 2015 for a flowback period but strong performance resulted in the decision to_permanently tie-in 2F-22 as aproducer and convert 2G-17 to an injection well. The top of the Kuparuk C sand was found at 14274' and /6113' tvd The top of the Kuparuk A sand was found at 14390' and /6178' tvd Area Map with 1/4 mile radius around target injection zone (see attached): The map attached shows that the Kuparuk well 2G-17 is located to the southeast of drillsite 2G Kuparuk development, directly south of drillsite 2F. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 2G-17 is good and classified as a "Normal Well". A proactive TIFL was performed on 5/20/2015 pre CPF2 Turnaround and passed. A pre-CTD MIT-OA passed on 9/23/2013 to 1820psi. An MIT-IA will be performed once well 2G-17 is converted to water injection, online, and stabilized. The injection tubing/casing annulus is isolated via a Baker ZXP Liner Top Packer located at 13848' and (5870' tvd). The 9-5/8" 401b/ft L-80 surface casing of 2G-17 was cemented with 495 bbls AS Lite and 248 bbls LiteCRETE. 170 sacks of Class G cement were used for the 7" 26 lb/ft L-80 production casing. The 3-1/2" 9.3 lb/ft L-38 liner, present from 13,847'MD to 14,768'MD, was cemented with 35 bbls of Class G cement. CBL and interpretation of the cement quality: The CBL interpretation was completed on the PTD's. Co,,,n/s o4 o� The c1i��ccf Wel/ ,f ffcrr ,( Q tc),-tot ro es-/Q.4435 coAcvr. �{ h 1eCtOr pQi'r �h 74,'J /S OIQr� so./ 64, Yi'r4 7:4e t://r4r ff(jcIvicer. // -j f`i1 f r Ove- (/ �( lh 01. I e core• 1 L a v�3aoy -Na m 3 N a g o 3— 3 w F4o �m F 3 �o, c-o N U 9 W O= O t O H O g a CO Q 9 N ei L O W 1-< . d C 1'j y n E N� � � $ • QI O a a 0 0 a U N '!II- - I a a -+ • rg-o . m « ? C N O v � ' O � E N E m m °,v $ a H o 5 3-O m E U' j z. n `o . 3 -.. 3mN o 3u . « o N a `m O o e ry r FR-22, E 01 �t,a q T` '_° ti.mc u r 6 3� ti s A `- � a R. o zN z.' :58 5a 72 ¢ m Y � Rl „ WO Y 2 U Q w E ' tLq o v n et5 ' i a) c m J L 9 .0. u I a F N V p co G 2 coH 6 0. a p, h50 m 1,--g .... 0 F Ta 2g. m c m . F O 7 F o a C5W Z N a ' m F., gid N O, O N aF O a • ACLO2f,2t7 . ADLO2Ee 7 ADL025e6 h. CS Kuparuk i River Unitilk 1 i 1 i NilNIP" i i i i t w r 1. ADL`J2 .a e3 . 1 18Jan16 01x'4 Mi.2G-17 Radius ConocoPhillips 01/4 Mi.2G-17L1 Radius Alaska, Inc. 01/4 Mi_2G-17L1-01 Radius _KRU Boundary 2G-17 N 10-403 Sundry Map .:KuparukPABoundary i' Pad Outline 0 0.15 0.3 0.45 0.6 LJ CPAI Lease Miles KUP PROD • 2G-17 Conoc Phillips '& , Well Attributes Max Angle&MD TO • Alaska Inc Wellbore API/UWI Field Name Wellbore Status ncI(°) MD IftKB) Act Btm(ftKB) 500292313400 KUPARUK RIVER UNIT PROD 72.97 2,566.99 14,768.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2G-17.1/71201542622 PM SSSV:NIPPLE 10 3/16/2014 Last WO: 27.60 1/27/2003 V®tical schematic(actual) Annotation Depth(ftKB( End Date Annotation Last Mod By End Date Last Tag SLM 14,257.0 9/15/2014 Rev Reason:REMOVE GAUGES lehallf 1/7/2015 HANGER.23.2 __� -- _ Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread `� CONDUCTOR 16 15.062 28.0 110.0 110.0 62.50 H-40 WELD i�f g sa, Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread SURFACE 95/8 8.835 28.0 5,752.8 3,134.7 40.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Tap Thread PRODUCTION 7 6.276 26.0 14,027.4 53((:9173:24))....97.. ,9729 26.00 L-80 BTCM Casing Description OD(in( ID(ie) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WOLen(I...Grade Top Thread WINDOW L1 01 31/2 2992 142800 14,286.0 6,119.6 9.20 L-80 MAI CONDUCTOR,280-1100 J Casing Description OD(e) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade lop Thread I LINER y� 31/2 2.992 13,847.9 14,768.0 6,403.4 9.30 L-80 SLHT NIPPLE;602.0 Liner Details ,t - Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com Nominal ID I ✓13,847.9 5,869.9 55.06 PACKER BAKER ZXP LINER TOP PACKER w/TIE BACK 4.420 SLEEVE(OD 5.79",ID 5.25") GAS LIFT;4.081.2 - 13,866.8 5,880.7 55.04 NIPPLE BAKER RS NIPPLE 4.250 13,870.3 5,882.8 55.04 HANGER BAKER FLEX-LOCK HYDRUALIC LINER HANGER 4.450 13,880.0 5,888.3 55.03 SBE SEAL BORE EXTENSION 4.000 I` 13,900.0 5,899.8 1 55.01 XO BUSHING X-OVER BUSHING 3.500 Tubing Strings SURFACE;28.0-5.752.8- Tubing Description String Ma...ID tin) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(11o/ft) Grade Top Connection TUBING 3112 2.992 23.2 13,889.4 5.893.7 9.30 L-80 EUE-Ord Completion Details Nominal ID GAS LIFT;7,961.7 Top(ftKB) Top(TVD)(ftKB) Top Incl NI Item Des Com On) 23.2 23.2 0.06 HANGER FMC GEN V TUBING HANGER 3.500 502.0 502.0 1.42 NIPPLE CAMCO DS NIPPLE 2.875 13,789.2 5,836.3 55.00 SLEEVE BAKER CMU-ELASTOMER SLIDING SLEEVE w/2.81" 2.810 DS PROFILE GAS LIFT;10,742.3 13,8052 5,845.4 55.02 NIPPLE CAMCO D NIPPLE MILL FROM 2.75 TO 2.80 7/1/13 2.800 13,849.1 5,870.6 55.06 LOCATOR BAKER G-22 LOCATOR 3.000 13,850.5 5,871.4 55.06 SBE BAKER GBH-22 80-40 SEAL ASSEMBLY 3.000 Perforations&Slots GAS LIFT;12,808.8 Shot Dens Top(ND) Bra(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 14,280.0 14,292.0 6,116.2 6,123.0 C-4,2G-17 2/4/2003 6.0 CMT 2.25"HSD 2306 PJ SQZ HMX,60 Deg Phasing GAS LIFT;13,737.3 IStimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 14,280.0 14,292.0 6,116.2 6,123.0 FRAC 3/10/2003 40#X-LINKED GEL @ 20•BPM WITH 16/20 CERAMIC PROPPANT;45,2284 OF PROPPANT Squeezes PIPE W/6 PPA AT PERFS SLEEVE;13,789.2 '[ Cement Squeezes [` 1t, ITop(ND) Btm(ND) Top(ftKB( Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn NIPPLE;13.8052 13,870.3 14,768.0 5,882.8 6,403.4 CEMENT 1/23/2003 II Mandrel Inserts St ati N Top(ND) Valve Latch Port Sae TRO Run Q Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com L71 .�3 V�, e 4,081.2 2,581.8 CAMCO KBUG- 1 GAS LIFT GLV BK 0.156 1,390.0 1/14/2014 M LO TOR;13.849.1 ;.� 2 7,961.7 3,841.5 CAMCO KBUG- 1 GAS LIFT GLV BK 0.188 1,406.0 1/15/2014 _ 9, f M 5 '� 3 10,742.3 4,730.6 CAMCO KBUG- 1 GAS LIFT OV BK 0.250 0.0 1/13/2014 /\ SBE;13.850.5 �i M 4 12,808.8 5,390.3 CAMCO KBUG- 1 GAS LIFT DMY BK 0.000 0.0 4/21/2013 `� la 01 M ' � ` 5 13,737.3 5,806.5 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/4/2003 )� 1114 " ? Notes:General&Safety Q1�� , End Date Annotation tn)cl t:-.:=1: 10/22/2010 NOTE:View Schematic w/Alaska Schematic9.0 v1 it 11/22/2013 NOTE:ADD LATERALS L1,L1-01(off the main wellbore) -fit; PRODUCTION; 6.0414,027.4-'V. t Li onP(1 w WINDOW L1-01;14,280.0- 1O, 14,286.0 l FRAC;14,280.0 t CMr SOZ;14,280.0-14,292.0 Ail Vr g; Itl .l ila LINER;13,847.9-14,768.0 Or *ill. * 4111 I r - p in a)co Q 2tD mu? ov co cool�r in'"c N 0 N h 76 �7 O ch -1c �Q ) C h J n J r i (`J N N \ N N O co csi 'I I - N i till I n , l i'. in "rt3 h.cO c —Ei 3I1� O co- Q E , I 1{� co inp p g II IIi g C) N h o ,1:.. .da.._ CO N- cv Er) J c., corhi n. p in oh m h II Icn I! H N �+ N o h a 2 m N N N H 1 I cci I 0 -a- co- Crp) p as II 11 °' 3 �� Ua — g'4- 0 0 II II m p a v a @) w H II lir u_ n — 1 N• cD c as c a g aE ssei m t O ii Ii O F `o o E w°' a ro n as I l 1 1 'di v� — r c ."� w o c b II II, ro Y N I i o_ ul Om @ �ON G J � II O co p w co D m d x W 1- iI II o � ` 2 � to_ 11 o °J o o U 8 0 0 vo 1I I I b EE °� N nhm `° I i mh Y E x x o v 1 -I 03 � m m to �� 1 i v m U Oi U U CO U' A o in in cn m© 1 I 1 I /��v N (V N N N (V n N N N V�` Y O Y Y Y _-cr V I .-- CO C 00 CO t6 Qmj r M CO% ch M CO CO ch CO CO CO CO F"co (1 I Q 0~ it �l co ....„L--� A •.,. .--- S Off11 ;,. C 12 F.,l,} H O —�m-.Y (-----i _i _ 2°8 Q C'� U(15 \ F-cv)i l - ,a . L a _ 60 ty [7 r v 1\V\\ Ii v m p 2 CVviL a Q) N n O O C N o0 N N a)'V' J .c mp n� #p O M S� H J C1 J_ �00 /I 't p O CO#N N(D 4- NI N O Co"" t`a - co • Roby, David S (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Monday, February 29, 2016 4:24 PM To: Roby, David S (DOA) Cc: Autry, Sydney Subject: RE:Sundry application to convert KRU 2G-17 to a WAG injector Dave-see comments below. Let us know if you need anything else. Darrell Humphrey/Bob Christensen ConocoPhillips Alaska, Inc. Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager(907) 659-7000 (924) From: Roby, David S (DOA) [mailto:dave.robyOalaska.gov] Sent: Monday, February 29, 2016 3:18 PM To: NSK Prod Engr Specialist Subject: [EXTERNAL]Sundry application to convert KRU 2G-17 to a WAG injector Darrell/Bob; I'm reviewing your application to convert the subject well,and its laterals,from a producer to a WAG injector and I just want to make sure I am understanding what your plan is. If I'm reading it correctly,you originally intended for the 2F-22 well to be an injector to support the 2G-17 well,but during pre-production of 2F-22 it performed better than expected so the decision was made to swap the two wells and keep 2F-22 as a producer and make 2G-17 the injector,is this correct? Your understanding is correct. Due to the performance of 2F-22 it was decided to swap the service of the two wells. Also,are there any other wells in the fault block containing this producer/injector that will be impacted by the proposed swap in service,and if so what is the service of the other impacted wells? 2F-22 and 2G-17 are the only two wells in the C sand (isolated C sand lobe). Thanks in advance, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 CONFIDENTIALITY NOTICE This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Dave Roby at(907)793-1232 or dave.robvCalaska.aov. 1 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. J D 9( - ~ (!t.;;s Well History File Identifier Organizing (done) tÞ wo-sided 11I111111111111111 o Rescan Needed RESCAN DIGITAL DATA OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Color Items: o Greyscale Items: o Diskettes, No. D Other, No/Type: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: , Helen ~ Date: Ô &If D5 I Datð~~ b5>- 151 ~ IS/¥14 BY: Helen~ Project Proofing BY: rvvP Scanning Preparation BY: Helen (Maria___J ~ X 30 = qð+ to = TOTAL PAGES IDO , (Count do ~s not irclu<iµover sheet) ~^/);D Date:L"1. av'f. óð 151 , r l, . I Production Scanning Stage 1 Page Count from Scanned File: 10 I (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES NO Helen,[ Maria~ Date: 3 IH, ()!;' 151 tfV1,'"' If NO in stage 1, page(s) discrepancies were found: YES NO Stage 1 BY: BY: Helen Maria Date: 151 I III I Scanning is complete at this point unless rescanning is required. ReScanned 1111111 I BY: Helen Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 STATE OF ALASKA ALSA OIL AND GAS CONSERVATION COMOSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate Other SC Cement Shoe Alter Casing fi Pull Tubing fl Stimulate-Frac r Waiver Time Extension fl Change Approved Program fOperat. Shutdown r Stimulate-Other fi Re-enter Suspended Well fi 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Ri Exploratory _ 202-243 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23134-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25666 2G-17 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 14770 feet Plugs(measured) none true vertical 6405 feet Junk(measured) none Effective Depth measured 14668 feet Packer(measured) 13849 true vertical 6342 feet (true vertical) 5871 Casing Length Size MD ND Burst Collapse CONDUCTOR 82 16 110 110 SURFACE 5725 9.625 5753 3135 I 0PRODUCTION 14001 1 920 6403 027 E D LINER 0 7.5 OCT 17 2013 Perforation depth: Measured depth: 14280'-14292' S(ANNE) NOV 1 3 2013 AOGCC True Vertical Depth: 6117'-6123' smite) Tubing(size,grade,MD,and ND) 3.5, L-80, 13889 MD, 5871 ND Packers&SSSV(type,MD,and ND) PACKER-BAKER ZXP LINER TOP PACKER @ 13849 MD and 5871 TVD NIPPLE-CAMCO DS NIPPLE @ 502 MD and 502 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run - Exploratory fi Development 17 Service fl Stratigraphic 16.Well Status after work: Oil Pr Gas fl WDSPL Daily Report of Well Operations XXX GSTOR WIND r WAG r GINJ r SUSP r 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: 313-487 Contact Tyson Wiese 263-4250 Email Tyson.M.Wiese(a�conocophillips.com Printed Name T so iese Title Wells Engineer Signature Phone:263-4250 Date 1b/lb/3013 yL.i=- ,,,e/9. RBDMS OCT 1 /of/7/ i 3 Form 10-404 Revised 10/2012 Submit Original Only 2G-17 Pre-Rig Well Work Summary • DATE SUMMARY • 4/14/2013 (PRE-CTD)ALL T& IC LDSs FUNCTION PROPERLY AND TORQUED TO 450 FT/LBS. T-POT PASSED, T-PPPOT PASSED, IC-POT PASSED, IC- PPPOT PASSED. SCLD IN PROGRESS. OA FL DEPRESSED FROM 102'TO 228'. 4/17/2013 GAUGED TBG TO 2.79"TO D NIPPLE @ 13805' RKB. IN PROGRESS. 4/18/2013 MEASURED BHP @ 14286' RKB: 3333 PSI. TAGGED @ 14497' SLM WITH 2-5/8" DUMMY WHIPSTOCK. SET 2.75"CA-2 PLUG @ 13805' RKB; TESTED PLUG 2000 PSI, GOOD. DEPLOYED CATCHER. PULLED GLV @ 10742' RKB. IN PROGRESS. 4/19/2013 PULLED GLVs @ 7961', 4080' RKB. IN PROGRESS. 4/20/2013 SET DVs @ 4080', 7961', & 10742' RKB; GOOD PT ON DVs. PULLED OV @ 12808' RKB. IN PROGRESS. 4/21/2013 LOADED IA WITH 445 BBL DSL. SET DV @ 12808' RKB. MIT IA 2500 PSI, PASSED. PULLED CATCHER @ 13786' SLM. PULLED EQ-PRONG @ 13805' RKB. IN PROGRESS. 4/22/2013 PULLED 2.75 CA-2 PLUG BODY @ 13805' RKB. READY FOR CALIPER/CBL. 4/30/2013 PERFORMED RCBL. OBSERVED GOOD CEMENT DURING REQUESTED LOGGING INTERVAL OF 13,900'- 14,280'AND 14,412'- 14,450' 5/2/2013 INITIAL TI/IA/OA: 1200/500/700 FINAL TI/IA/OA: 1200/500/700 5/4/2013 (PRE-CTD) PT& DD TEST MV- PASSED; SSV- PASSED; SV-PASSED 6/30/2013 RIH, tag D nipple at 13812' CTMD. Attempted to mill through D nipple with 2.80" BOT MM step mill. After multiple stalls POOH and rack back for the night. Job in progress. 7/1/2013 Mill D nipple @ 13805' MD from 2.75"to 2.80"with BOT stepped MM mill. Freeze protect well with diesel to surface. Job complete. 7/5/2013 DRIFTED TBG TO 14300' RKB W/BAKER DMY WHIP STOCK. READY FOR E-LINE. 8/1/2013 (PRE-CTD): SCLD IN PROGRESS. 8/2/2013 (PRE CTD)OA FL @ SF. BUBBLING DETECTED IN THE CONDUCTOR AT THE 1 O'CLOCK POSITION. T/I/O= 1200/820/600. 8/3/2013 (PRE CTD)OA FL @ SF. BUBBLING STILL DETECTED IN THE CONDUCTOR AT THE 1 O'CLOCK POSITION. T/I/O= 1200/810/520. 8/4/2013 (PRE CTD) : FOUND HYDROCARBON SHEEN ON WATER IN CELLAR BOX. VACCED WATER& FOUND A WELD THAT ATTACHES CELLAR TO CONDUCTOR IS BROKEN IN TWO PLACES (2:00-5:00&7:00-9:00 O'CLOCK POSITIONS). WATER BEGAN INFLOWING AS SOON AS VAC WAS SI. DID NOT OBSERVE ANY HYDROCARBONS INFLOWING W/WATER. 8/5/2013 SET A BAKER HUGHES 2.63", 3 1/2 MONOBORE WHIPSTOCK ON 2G-17 USING A 2.5" DPU2-I SETTING TOOL. TOP OF WHIPSTOCK SET AT 14280'. CCL TO TOP OF WHIPSTOCK IS 19'. CCL STOP DEPTH IS 14261'. WHIPSTOCK SET 3.5 DEGREES ROHS. JOB COMPLETE. 8/5/2013 (PRE-CTD): Extremely intermittent bubbling observed in flutes at the 1 &3 o'clock positions. Cellar contains—1 ft clear fluid in cellar, with no sheen of hydrocarbons. 8/6/2013 (PRE CTD)VAC CELLAR AND TAKE PHOTOS. 8/7/2013 (PRE CTD)OA FL, MONITOR CELLAR. 8/8/2013 (PRE CTD)OA-FL, MONITOR CELLAR, 15"WATER IN CELLAR WITH VERY LIGHT SHEEN. 8/9/2013 (PRE-CTD): SCLD (IN PROGRESS). 8/10/2013 (PRE-CTD) : SCLD (IN PROGRESS). 8/21/2013 (PRE-CTD) : SCLD (PASS). 9/27/2013 Pumped OA shoe. Placed 40 bbls of 15.8 ppg cement in OA with 124.6 bbls displacement leaving estimated 1333'column of cement in the OA No returns to surface. - In progress. 9/29/2013 (PRE-CTD)MIT-OA PASSED TO 1820 PSI. NO FLUID OR GAS RETURNS IN CONDUCTOR WERE PRESENT DURING TEST KUP PROD 0 2G-17 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) 1 ,,,, s 500292313400 KUPARUK RIVER UNIT PROD 72.97 2,566.99 14,768.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 2G-17,9/30/20139-.55.13 AM SSSV:NIPPLE I I Last WO: 27.60 1/27/2003 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'SLM 14,497.0 1 4/18/2013 Rev Reason.CEMENT SURF/PROD OA osborl 9/30/2013 HANGER 23.2 •- Casing Strings _ Casing Description OD(in) ID(in) Top(SOB) Set Depth(MOB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 11 CONDUCTOR 16 15.062 28.0 110.0 110.0 62.50 H-40 WELD 11 f l Cooing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread `' i SURFACE 95/8 8.835 28.0 5,752.8 3,134.7 4000 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...'Wt/Len(I...Grade 'Top Thread PRODUCTION 7 6.276 26.0 14,027.4 5,972.9 26.00 L-80 BTCM(ft Casing Description OD(in) ID(in) Top(ftKB) Set Depth KB) Set Depth(ND)... Wt/Len(I...Grade Top Thread LINER 31/2 2.992 13,847.9 14,768.0 6,403.4 9.30 L-80 SLHT ,n.A/CONDUCTOR;28.0-110.0 Liner Details Nominal ID NIPPLE;502.0 Top(ftKB) Top)ND)(ftKB) Top Intl(°) Item Des Corn (in) I 13,847.9 5,869.9 55.06 PACKER BAKER ZXP LINER TOP PACKER w/TIE BACK 4.420 SLEEVE(OD 5.79",ID 5.25") 13,866.8 5,880.7 55.04 NIPPLE BAKER RS NIPPLE 4.250 GAS LIFT;4,0812 13,870.3 5,882.8 55.04 HANGER BAKER FLEX-LOCK HYDRUALIC LINER HANGER 4.450 13,880.0 5,888.3 55.03 SBE SEAL BORE EXTENSION 4.000 13,900.0 5,899.8 55.01 XO BUSHING X-OVER BUSHING 3.500 i•] = Tubing Strings ;] Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 23.2 13,889.4 5,893.7 9.30 L-80 EUE-8rd SURFACE;28.0-5752.8 Completion Details OA CMT;4,419.8-") Nominal ID >t Top(ftKB) Top(ND)(ftKB) Top Intl(°) Item Des Com (in) 23.2 23.2 0.06 HANGER FMC GEN V TUBING HANGER 3.500 1 502.0 502.0 1.42•NIPPLE CAMCO DS NIPPLE 2.875 GAS LIFT;7,961.7 4 13,789.2 5,836.3 55.00 SLEEVE BAKER CMU-ELASTOMER SLIDING SLEEVE w/2.81" 2.810 DS PROFILE 13,805.2 5,845.4 55.02 NIPPLE CAMCO D NIPPLE MILL FROM 2.75 TO 2.807/1/13 2.800 13,849.1 5,870.6 55.06 LOCATOR BAKER G-22 LOCATOR 3.000 GAS LIFT;10,742.3 a 13,850.5 5,871.4 55.06 SBE BAKER GBH-22 80-40 SEAL ASSEMBLY 3.000 1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) I Top(ND) Top Intl Top(ftKB) (ftKB) )°) Des Corn Run Date ID(in) 14.280.0 6.1)6.2 55.52 WHIPSTOCK BAKER HUGHES 2.63",3 1/2 MONOBORE 8/5/2013 2.630 WHIPSTOCK GAS LIFT,12,808.8 I Perforations&Slots Shot Dens Top(ND) Btm(ND) (shotstt Top(ftKB) Btm(ftKB) (ftKB) (RKB) Zone Date t) Type Corn 14.280.0 14.292.0 6,116.2 6,123.0 0-4,2G-17 2/4/2003 6.0 CMT 2.25"HSD 2306 PJ SQZ HMX,60 Deg Phasing GAS LIFT;13,737.3 illl I Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) ' Type Date Corn II 14,280.0 14,292.0 6,116.2 6,123.0'FRAC 3/10/2003 406 X-LINKED GEL @ 20 BPM WITH 16/20 SLEEVE;13,789.2 191 CERAMIC PROPPANT;45,2288 OF PROPPANT BEHIND PIPE W/6 PPA AT PERFS Cement Squeezes NIPPLE;13,805.2 Top(ND) Btm(ND) I Top(ftKB) Btm(ftKB) )ftKB) (RKB) Des Start Date Corn 14,768-0 5,882.8 6,403.4 CEMENT 1/23/2003 Mandrel Details I at / tt' C .��I No Top(ND) Valve Latch Port Size TRO Run LOCATOR;13,8491 Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (Psi)0.0 Run Date m 1 4,081.2 2,581.8 CAMCO KBUG- 1 GAS LIFT DMY BK 0.000 4/20/2013 i M 1]j 1 7,961.7 3,841.5 CAMCO KBUG- 1 GAS LIFT DMY BK 0.000 0.0 4/20/2013 SEE;13,850.5 M ,• 3 10,742.3 4,730.6 CAMCO KBUG- 1 GAS LIFT DMY BK 0.000 0.0 4/20/2013 • 4. M 4' 12,808.8 5,390.3'CAMCO KBUG- 1 GAS LIFT DMY BK 0.000 0.0 4/21/2013 •illi ti. M 5 13,737.3 5.806.5 CAMCO MMG 1 1/2 GAS LIFT DMY RE 0.000 0.0 4/4/2003 Notes:General&Safety J. End Date Annotation v. `v„ 10/22/2010 NOTE:View Schematic w/Alaska Schematic9.0 '1 ✓. v, 0 v PRODUCTION;26.0-14,027.4 WHIPSTOCK;14,2800 FRAC;14,280.01 CMT SOZ,14,280.0-14,292.0 CMT SOZ;13,870.3 ' LINER;13,847.&11,768.0 ' tiOFT,y� • • �w IV7 At THE STATE Alaska Oil and Gas of-�,; ALAS Conservation commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF P Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 SN 6 a Tyson Wiese Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 ZC) Re: Kuparuk River Field, Kuparuk River Oil Pool, 2G-17 Sundry Number: 313-487 Dear Mr. Wiese: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /3444 .54....__ Cathy P. Foerster Chair DATED this i day of September, 2013. Encl. STATE OF ALASKA it RECEIVED AIWA OIL AND GAS CONSERVATION COM ION e 0 �,1� EP 12013 APPLICATION FOR SUNDRY APPROVALS q o s 7/i' 113 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool fl Repair w ell fl Change AppAWCfq Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate fl Alter casing r Other:SC Cement Shoe P.,. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory Development 202-243 j 3.Address: Stratigraphic r Service 6.API Number: • P.O. Box 100360,Anchorage,Alaska 99510 50-029-23134-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 17 2G-17 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25666 ' Kuparuk River Field/Kuparuk River 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): 14770 6405 14668' 6342' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 110' 110' SURFACE 5725 9.625 5753' 3135' PRODUCTION 14001 7 14027' 5973' LINER 920 3.5 14768' 6403' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 14280'-14292' 6117-6123' 3.5 L-80 13889 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER ZXP LINER TOP PACKER MD=13848 TVD=5870 NIPPLE-CAMCO DS NIPPLE MD=502 TVD=502 12.Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory fl Stratigraphic Development Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 9/25/2013 Oil PT • Gas r- WDSPL fl Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and corre t to the best of my knowledge. Contact: Tyson Wiese @ 263-4250 Email: Tyson.M.Wiesenconocophillips.com Printed Name Tyson Wies" Title: Wells Engineer a/ID q�, Signature (//� Phone:263-4250 Date / /'oI3 Commission Use Only Sundry Number: L.17 Conditions of approval: Notify Commission so that a representative may witness 31 t 3 — ` Plug Integrity r BOP Test r Mechanical Integrity Test it Location Clearance r 1 Other: R BDMS OCT 10 2013-1 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: / ± 0 0 ' APPROVED BY // /� Approved by: / �, ‘ ��r COMMISSIONER THE COMMISSION Date:9-/ (o / pproved application is valid for 1Z months trom the date of approval. Form 10-403(Revised 10/2012) Submit Form and Attachments in Duplicate il t(' VI- F "1/13/13 ORIGINAL ,, N, 2G-17 OA Cement Shoe Permit to Drill #: 202-243 9/10/2013 The objective of the proposed 2G-17 OA Cement shoe is to allow for pressure testing of the 9 5/8" Surface Casing Annulus. The cement shoe will provide a base for ConocoPhillips to pressure test against, in order to locate and estimate the size of a suspected shallow surface casing leak. A surface casing cement shoe was not pumped at the time of original completion in 2003. Proposed OA Cement Shoe Procedure: Schlumberger Pumping Services: (OA cement shoe) 1. Bleed IA to 100 psi, Bleed OA to 0 psi. 2. RU 1502 X-over and hardline to the OA prior to the job. 3. RU SLB Cement Pump and Equipment. PT lines. 4. Monitor Wellhead during all pumping, looking for signs of fluid returns from the conductor. 5. Pump 30 bbls of diesel to establish injectivity and ensure rates are adequate for cementing. 6. Pump 175 bbls of 100 deg F Freshwater to flush out the outer annulus of potential debris/mud. 7. Pump 20 bbls of 12# MudPush Spacer 8. Pump 44 bbls of 15.8 Class G cement (50% squeeze volume), utilizing lost circulation materials and additives to prevent gas migration through the plug. 9. Displace the cement plug with 20 bbls of 12# MudPush Spacer, 86 bbls of 10.8# CaCl2 Brine, and 28 bbls of Diesel F.P., leaving a 1,000' cement plug in the OA. 10. Shutdown pumps and WOC for 48 hours. RDMO. DHD: (MIT-OA) 1. MIT-OA to 1,500 psi. 2. If MIT-OA fails, record the estimated LLR w/diesel. Perform SCLD to locate leak. 3. RDMO. Submit 10-404 to AOGCC. p 0 1C ■ 28, Z bh is (p7_92_ h10 /5 j / 2 ' -bli TW • a KUP PROD • 2G-17 ----- --- -- COf1000P�'lillipS Well Attributes Max Angle&MD TD INC Wellbore API/UWI Field Name Wellbore Status Inca(°) MD(ftKB) Act Btm(ftKB) Alaska, 500292313400 KUPARUK RIVER UNIT PROD 72.97 2,566.99 14,768.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date ••• Well Coptic -20-17,8/820138:05:59 AM SSSV:NIPPLE Last WO: 27.60 7/ Schematic-Actual -Annotation Depth(ftKB) End Date Annotation t Mod By End Date Last Tag:SLM I 14,497.0 1 4/182013 Rev Reason:SET WHIPSTOCK I Lashaggea I 8/8/2013 HANGER,23- !...pp. 4 moo Casing Strings ,lit pp r Casing Description String 0... String ID...Top(ftKB) Set Depth(L..Set Depth(TVD)...String WE String...String Top Thrd CONDUCTOR 16 15.062 28.0 110.0 110.0 62.50 H-40 WELD Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 95/8 8.835 28.0 5,752.8 3,134.6 40.00 L-80 BTCM Casing Descriptlon String 0... String ID.,.Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt,.,String...String Top Thrd --` PRODUCTION 7 6.276 26.0 14,027.4 5,973.0 26.00 L-80 BTCM ill I I Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd cor4DUCroR,� LINER 31/2 2.992 13,847.9 14,768.0 6,403.4 9.30 L-80 SLHT z511° Liner Details Ws;;`i5�� u, ,.,�,��; ., ,` �\ ," V .. �0\\ �,,.0 Top Depth NIPPLE,502 - (:. (ND) Top Intl Nomi... Top(ftKB) (ftKB) (1 Item Description Comment ID(in) 13,847.9 5,870.0 55.08 PACKER BAKER ZXP LINER TOP PACKER w/TIE BACK SLEEVE(OD 5.79",ID 4.420 5.25") GAS upr, 13,866.8 5,880.8 55.06 NIPPLE BAKER RS NIPPLE 4.250 4,081 13,870.3 5,882.8 55.05 HANGER BAKER FLEX-LOCK HYDRUALIC LINER HANGER 4.450 t-----' 13,880.0 5,888.3 55.04 SBE SEAL BORE EXTENSION 4.000 13,900.0 5,899.8 55.02 XO BUSHING X-OVER BUSHING 3.500 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE. TUBING 31/2 2.992 23.2 13,889.4 5,893.7 9.30 I L-80 EUE-8rd 28-5,753 Completion Details Top Depth -_ (ND) Top Ind Nomi... GAS LIFT___ Top(ftKB) (wEB) (°) Rem Description Comment ID(in) T 23.2 23.2 0.95 HANGER FMC GEN V TUBING HANGER 3.500 502.0 501.9 -0.29 NIPPLE CAMCO DS NIPPLE 2.875 13,789.2 5,836.2 55.00 SLEEVE BAKER CMU-ELASTOMER SLIDING SLEEVE w/2.81"DS PROFILE 2.810 III GAS LIFT, 13,805.2 5,845.4 55.02 NIPPLE CAMCO D NIPPLE MILL FROM 2.75 TO 2.80 7/1/13 2.800 10.742 13,849.1 5,870.7 55.08 LOCATOR BAKER G-22 LOCATOR 3.000 13,850.5 5,871.5 55.07 SBE BAKER GBH-22 80-40 SEAL ASSEMBLY 3.000 NI Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) Top Depth GAS LIFT, (ND) Top Intl 12,809 Top(ftKB) (ftKB) (°) Description Comment Run Date ID(in) 14,280.0 6,116.8 56.20 WHIPSTOCK BAKER HUGHES 2.63",3 1/2 MONOBORE WHIPSTOCK 8/5/2013 2.630 Perforations&Slots Shot Top(ND) Btm(TVD) Dens Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (oh... Type Comment GAS LIFT, 14,280.0 14,292.0 6,116.8 6,123.4 C-4,2G-17 2/4/2003 6.0 CMT 2.25"HSD 2306 PJ HMX,60 Deg 13737 SQZ Phasing - Stimulations&Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (ND) (TVD) SLEEVE, (ftKB) (ftKB) (ftKB) (ftKB) Type Data Comment 13,789 14,280.0 14,292.0 6,116.8 6,123.4 FRAC 3/10/2003 40#X-LINKED GEL @ 20 BPM WITH 16/20 III CERAMIC PROPPANT;45,228#OF PROPPANT NIPPLE,13,906 .17 BEHIND PIPE W/6 PPA AT PERFS SU Notes:General&Safety End Date Annotation it 10/22/2010 NOTE:View Schematic w/Alaska Schematic9.0 q LOCATOR, ini 13,849 ♦ .4 III SBE.13,851 I ii i.A il IOU 1. Mc x PRODUCTION, ,, ,� Mandrel Details 2514,027 Top Depth Top Port g,,, (ND) Inc! OD Valve Latch Size TRO Run N...Top(ftKB) (ftKB) 1°) Make Model lin) Sery Type Type ON (poll Run Date Com... WHIPSTOCK, 1 4,081.2 2,583.0 72.03 CAMCO KBUG-M 1 GAS LIFT DMY BK 0.000 0.0 4202013 14.280 ik Ai CMT soz, I 2 7,961.7 3,841.5 71.32 CAMCO KBUG-M 1 GAS LIFT DMY BK 0.000 0.0 4/20/2013 14,280-14,292 FRAC.14,280 3 10,742.3 4,730.671.40 CAMCO KBUG-M 1 GAS LIFT DMY BK 0.000 0.0 4202013 rx` 4 12,808.8 5,390.3 71.73 CAMCO KBUG-M 1 GAS LIFT DMY BK 0.000 0.0 4212013 1 5 13,737.3 5,806.5 54.93 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 4/4/2003 CMT soz, . 13,870 NR. 1I8 '...° 13,848-14,768 IP TO,14,768 FELL LOG TRANSMITTAL 2-4 225�t� To: Alaska Oil and Gas Conservation Comm. May 1, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 R C T E D RE: Radial Cement Bond Log: 2G-17 MAY 10 2013 Run Date: 4/30/2013 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage,AK 99518 matthew.cook@halliburton.com 2G-17 Data in LAS format, Digital Log Image files 1 CD Rom 50-029-23134-00 Cement Bond Log 1 Color Log 50-029-23134-00 SCANNED MAR 1 3 2014 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: S(\CP(\ Signed: ��Gk8f2a-041 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc L( ('1 0\..,-- ^--u-~") DATA SUBMITTAL COMPLIANCE REPORT 3/7/2005 Permit to Drill 2022430 Well Name/No. KUPARUK RIV UNIT 2G-17 Operator CONOCOPHILLlPS ALASKA INC MD 14768-' TVD 6403 .,,,/ Completion Date 2/4/2003,,/' Completion Status 1-01L Current Status 1-01L REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GRlRes,Dens/Neut Well Log Information: Log/ Data 11/pr fipt .;--tog ~D ~Log , !-tog .{og Æ~g <1::og (..kog Digital Med/Fnnt C 5f1 "- ¿ ) Ó {~ ~~ '- . API No. 50-029-23134-00-00 UIC N Directional Survey Q (data taken from Logs Portion of Master Well Data Maint) Electr Dataset Log Log Run Number Name Scale Media No LIS Verification 1 Directional Survey Gamma Ray 25 Blu ~84 LIS Verification I nd uction/Resistivity 25 Blu Neutron 25 Blu Induction/Resistivity 25 Blu Neutron 25 Blu v'Gamma Ray 25 Blu L.-Pérforation 5 Blu Interval OH / Start Stop CH Received 1 08 14768 Casê' 2/12/2003 Open 2/12/2003 çasé 2/12/2003 Casé" 2/12/2003 çpse 2/12/2003 Gas~ 2/12/2003 Ga'Sé 2/12/2003 ~ 2/12/2003 ~e 2/12/2003 Case 2/14/2003 0 14768 108 14768 108 14768 108 14768 108 14768 108 14768 108 14768 108 14768 13653 14384 Well Cores/Samples Infonnation: Name Interval Start Stop Sent Received Sample Set Number Comments - Comments A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 12/16/2002. An H2S Measurement is required to be submitted. This record automatically created from Permit to Drill Module on: 12/16/2002. ~' Permit to Drill 2022430 MO 14768 TVO 6403 ADDITIONAL INFORMATION Well Cored? Y /'8) Chips Received?~ Analysis Received? ~ Comments: ---- Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 3/7/2005 Well Name/No. KUPARUK RIV UNIT 2G-17 Operator CONOCOPHILLlPS ALASKA INC Completion Date 2/4/2003 Completion Status 1-01L Current Status 1-01L Daily History Received? ~: Formation Tops ~ Date: API No. 50-029-23134-00-00 UIC N - ;;(-- { Ml'v,,",- ÀJJ~ ~ ~' '! .... . ' .. '~ ConocóP'hillips Alaska \ t)O~·-~43 ',¡ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 21, 2004 RECEIVED· SEP 2 8 2004 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Alaska Oil & Gas Cons. v-.dlmls$ion Anchorage Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the circulation ports in the conductor. 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 top-fill operation was completed on September 19, 2004. Dowell-Schlumberger batch- mixed Tail System cement at 15.8 ppg in a blender tub. The cement was poured into the conductor from the top to fill the small void. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volume used on each conductor. Please call Jerry Dethlefs or myself at 907-659-7224, if you have any questions. Sincerely, tJf~ ;£ø~ Marie McConnell ConocoPhillips Problem Well Supervisor Attachment - ConocoPhillips Alaska, Inc. . Surface Casing by Conductor Annulus Cement Top-off Kuparuk and Tarn Fields September 19, 2004 WELL NAME 2G-02 2G-17 PTD# SERVICE CEMENT TOP VOLUME REASON TYPE ft bbl Producer 1 0.12 Cmt placed on 9/14/04 dropped below surface. ~~/ Producer 1 0.12 Cmt not at surface, dispose of extra cmt product 1841210 2022430 All cement pumped was Schlumberger IITail Systemll 15.8 PPG Cement This report is submitted in substitution for Sundry 10-404, Report of Sundry Operations .~ NSK Problem Well Supervisor ) ) Randy Thomas . Kuparuk Drilling Team Leader Drilling & Wells ConocJP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 April 21 ,2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 2G-17 (APD # 202-243) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the Kuparuk weIl2G-17. If you have any questions regarding this matter, please contact me at 265-6830. Sincerely, .~ ' ·t~\t-~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT /skad RECEIVED APR 2 3 2003 Alaska Oil & Gas Cons. Commission Anchorage ORIG 'NA_ ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U Plugged D Abandoned 0 20AAC 25.105 GINJ D WINJ D WDSPL D ~q."9U~9mpJeJlQ~s_ 2. Operator Name:: ,,';~ " ConocoPhillips Alaska, Inc. ¡ ;;¿::?j:03. ¡ 3. Address: \¡ V[;~¡iìD ~ P. O. Box 100360, Anchorage, AK 99510-0360 '! .-.-.-;l:......---J 4a. Location of Well (Governmental Section): ~"~",."..~..._,.,...",..".,, Surface: 203' FNL, 272' FWL, Sec. 5, T10N, R9E, UM At Top Productive Horizon: 940' FSL, 2460' FWL, Sec. 9, T1 ON, R9E, UM Total Depth: 609'FSL,2599'FEL,Sec.9,T10N,R9E,UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 508970 y- TPI: x- 516481 y- Total Depth: x- 516703 y- 18. Directional Survey: Yes 0 NoD 21. Logs Run: GR/Res, Dens/Neut 22. CASING SIZE WT. PER FT. 16" 62.5# 9.625" 40# 7" 26# 3.5" 9.3# GRADE B L-80 L-80 L-80 5943385 5933982 5933652 Zone- 4 Zone-4 Zone-4 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 14280' -14292' MD 6116' - 6123' TVD 6 spf Suspended 0 WAG D 20AAC 25.110 Other 1 b. Well Class: Development 0 Exploratory D Service D Stratigraphic Test D 12. Permit to Drill Number: 5. Date Comp., Susp., çe,Í:.- t¿ tJ3 or Aband.: JanuEIIY 27, £OO~4'" 202-2431 6. Date Spudded: ./' 13. API Number: December 30,2002 50-029-23134 7. Date TD Reached: 14. Well Name and Number: January 19, 2003 8. KB Elevation (ft): RKB 28' 9. Plug Back Depth (MD + TVD): 14668' MD 1 6342' TVD 10. Total Depth (MD + TVD): 14768' MD 1 6403' TVD 11. Depth where SSSV set: Land Nipple @ 502 feet MD 2G-17 15. Field/Pool(s): Kuparuk River Field Kuparuk Oil Pool 16. Property Designation: ADL 25666 17. Land Use Permit: ALK 2587 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: HOLE SIZE 1606' MD 42" 30 sx ArcticCrete CEMENTING RECORD AMOUNT PULLED 495 bbls AS Lite, 248 bbls LiteCrete 170 sx Class G 12.25" 8.5" 6.125" 35 bbls Class G CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 110' Surface 5756' Surface 14027' 13847' 14768' 24. SIZE 3.5" TUBING RECORD DEPTH SET (MD) 13889' PACKER SET (MD) 13858' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 14280' - 14292' 45,2281bs of 16/20 proppant 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 26, 2003 Gas Lift Date of Test Hours Tested Production for OIL-BBL GAS-MCF W A TER-BBL 3/30/2003 24 Test Period --> 196 783 17 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL press. 130 psi not available 24-Hour Rate -> 196 783 17 27. CORE DATA CHOKE SIZE GAS-OIL RATIO 176 823 OIL GRAVITY - API (corr) not available Submit core chips; if none, state "none". Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). NONE Form 10-407 Revised 2/2003 \RBDMS BFL OR~G NA_ APR 3 0 1003 CONTINUED ON REVERSE SIDE RECEIVED APR 2 3 2003 Alaska Oil & Gas Cons. Commission Anchorage C~I~ Submit in duplicate 28. ) 29. ) GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Kuparuk C Base Kuparuk 14274' 14309' 6113' 6133' Annulus left open - freeze protected with diesel. RECEIVED APR 2 3 2003 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Alaska Oil & Gas Cons. Commission Auct\orayt Contact: Shane Cloninger 265-6829 Printed Name R. Thomas Signature ~~~ Title: Kuparuk Drilling Team Leader Prone Date €.~l (2 l/O\~ Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". ORIGINAL Form 10-407 Revised 2/2003 ) ') Legal Well Name: 2G-17 Common Well Name: 2G-17 Spud Date: 12/29/2002 Event Name: ROT - DRILLING Start: 12/28/2002 End: Contractor Name: n1334@ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number: ··Öate From-"To . Hours ·Code Sub Phase COde 12/28/2002 12:00 - 15:30 3.50 MOVE MOVE MOVE Hook up trucks to pipe sheds-rockwasher-boilers-motors-pumps-pit modules & sub. 15:30 - 17:30 2.00 MOVE MOVE MOVE Move from 1 C pad to 2G pad. 17:30 - 00:00 6.50 MOVE RURD MOVE Spot sub-pits-pumps-motors-boiler modules-rockwasher & pipe sheds-hook up air-water-& steam lines. 12/29/2002 00:00 - 03:00 3.00 MOVE RURD RIGUP Rig up pump lines & pits N/U diverter. (Accept rig @ 0300 hrs. 12-29-02) 03:00 - 08:00 5.00 DRILL RIRD SURFAC Rig up bell nipple-flow line & load pipe shed wi 5" dp & bha. 08:00 - 19:00 11.00 DRILL PULD SURFAC Mix spud mud-pick up 150 jts. 5" dp & stand in derrick-pick up 29 jts. 5" hwdp-jars-3 nmdc,s & stand back in derrick. 19:00 - 19:30 0.50 DRI LL OTHR SURFAC Diverter function test-Annular closed in 16 sec,s.-Knife valve opened fully in 22 sec,s. (Witness function test waived by John Crisp Aogcc.) Service top drive-blocks & drawworks. 19:30 - 00:00 4.50 DRILL PULD SURFAC Pick up Auto Trak-circulate thru Auto Trak-Pull out-make up bit-float sub & stab-rih wi 1 stand hwdp-tag @ 93'. 12/30/2002 00:00 - 01 :00 1.00 DRILL SFTY SURFAC Pre Spud meeting wi Phillips Co. Man-Mud Engineer-All Baker Inteq Hands-Drill site operator & lead Tech & Doyon rig crew. 01 :00 - 04:30 3.50 DRILL DRLG SURFAC Clean out conductor from 93' to 110' & drill new hole to 261'. No Reading or performance out of auto trak-Stabilizer rotating. 04:30 - 09:30 5.00 DRILL PULD SURFAC Stand back dc,s-Iay down auto trak-pick up motor set @ 1.4 deg. & rih. 09:30 - 00:00 14.50 DRILL DRLG SURFAC Drlg. & surveys from 261' to 1540'. (1492' TVD) AST 7.1 ART .6 hrs. WOB 18/30 RPM 50 SPM 140 GPM 593 PP 1350 Hrs. on bit 9.8 PU 95k SO 90k RW 90k TQ on 3k Off 2k MW 9.0 Vis 135. (Angle not building-will have to trip for correction.) 12/31/2002 00:00 - 00:30 0.50 DRILL CIRC SURFAC Circ. hole clean @ 1540' for trip out. 00:30 - 02:00 1.50 DRILL TRIP SURFAC Observe well-blow down top drive-poh to mwd. 02:00 - 04:00 2.00 DRILL PULD SURFAC Down load mwd-reset 2 deg. lay down stab & orient. 04:00 - 05:30 1.50 DRILL TRIP SURFAC RIH to 1540'. 05:30 - 09:00 3.50 DRILL DRLG SURFAC Drlg. from 1540-1720'. ast-1.8 hrs. all sliding for hole correction. 09:00 - 10:30 1.50 DRILL TRIP SURFAC Observe well & poh. 10:30 - 14:30 4.00 DRILL PULD SURFAC Lay down bha #3-Pick up & program autotrak #2-shallow test autotrak-pick up & contract ribs in-make up bha #4-change out jars. 14:30 - 16:00 1.50 DRILL TRIP SURFAC RIH wash 80' to bottom-5' fill. 16:00 - 17:30 1.50 DRILL DRLG SURFAC Drlg. from 1720' to 1798'. 17:30 - 18:30 1.00 DRILL OTHR SURFAC Filter signal noise on mwd-attempt to remedy pulser. 18:30 - 20:00 1.50 DRILL OTHR SURFAC POH to check auto trak-pulse failure. 20:00 - 22:30 2.50 DRILL OTHR SURFAC Lay down autotrak #2-break bit-stab & filter sub. Pick up & program stand by-initial autotrak #1-shallow test-contract ribs in & make up bha #5. 22:30 - 23:30 1.00 DRILL TRIP SURFAC RIH-wash 50' to bottom-no fill. 23:30 - 00:00 0.50 DRILL OTHR SURFAC Down link & reset tool-survey. 1/1/2003 00:00 - 01 :00 1.00 DRILL DRLG SURFAC Drlg. from 1798 to 1882. (hole dropping angle.) 01 :00 - 02:00 1.00 DRILL CIRC SURFAC Circ. hole clean & checking surveys. 02:00 - 03:30 1.50 DRILL TRIP SURFAC POH & lay down autotrak. 03:30 - 05:30 2.00 DRILL PULD SURFAC Make up bha #6-orient & initialize mwd. 05:30 - 06:30 1.00 DRILL TRIP SURFAC RIH wash to bottom-no fill. 06:30 - 08:30 2.00 DRILL DRLG SURFAC Drlg. from 1882 to 2000-wob 5k spm 130 pp 1200 puw 97k sow 90k rw 95k slide 1882 to 2000. 08:30 - 10:30 2.00 DRILL OTHR SURFAC Circ. hole clean while waiting on orders. 10:30 - 12:00 1.50 DRILL DRLG SURFAC Drlg. from 2000 to 2035'. 12:00 - 13:00 1.00 DRILL CIRC SURFAC Circ.-observe well. 13:00 - 14:00 1.00 DRILL TRIP SURFAC POH for bha change. 14:00 - 15:00 1.00 DRILL PULD SURFAC Lay down bha #6 wi 2 deg. motor. Printed: 1/31/2003 2:40:46 PM } ) Legal Well Name: 2G-17 Common Well Name: 2G-17 Spud Date: 12/29/2002 Event Name: ROT - DRILLING Start: 12/28/2002 End: Contractor Name: n1334@ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number: . Date From..;To HoUrs Code· Sub Code 1/1/2003 15:00 - 16:30 1.50 DRILL PULD SURFAC Pick up bha #7 wI new motor set @ 1.4 deg.-stab-#2 bit-orient-down & up load-shallow test @ 260'. 16:30 - 17:30 1.00 DRILL TRIP SURFAC RIH (check shot survey @ 1775') wash 60' to bottom no fill. 17:30 - 00:00 6.50 DRILL DRLG SURFAC Drlg. & surveys from 2035 to 2550 md 2070' tvd-ast 2.4 art .9 puw 107k sow 80k rw 89k tq on 6k tq off 5k. (full gauge string stab @ 2194'.) 1/2/2003 00:00 - 20:30 20.50 DRILL DRLG SURFAC Drlg. & surveys from 2550 to 4115'. (2593 TVD) PU-105k SO-80k RW-92k TO on 7k TO off 5k Bit wt 5/10k PP 1500 SPM 134 AST 5.0 ART 8.0 GPM 563. 20:30 - 21 :30 1.00 DRILL CIRC SURFAC Pump sweep & circ. hole clean for wiper trip. 21 :30 - 22:30 1.00 DRILL WIPR SURFAC 15 stand wiper trip-hole is smooth no tight spots. 22:30 - 23:30 1.00 DRILL CIRC SURFAC Pump sweep & cbu-check sweep-very little trash on returns. 23:30 - 00:00 0.50 DRILL DRLG SURFAC Drlg. from 4115 to 4150' (TVD 2605') 1/3/2003 00:00 - 20:30 20.50 DRILL DRLG SURFAC Drlg. & surveys from 4150 to 5765' (3139 TVD) ART 11.5 AST 2.8 PU 125k SO 85k RW 95k TO 7/10 on 5/7 off PP 1860 SPM 140. 20:30 - 22:00 1.50 DRILL CIRC SURFAC Pump sweep & circ. hole clean for wiper trip. 22:00 - 23:30 1.50 DRILL WIPR SURFAC Wiper trip to 4100' & back to bottom (no hole problems) 23:30 - 00:00 0.50 DRILL CIRC SURFAC Pump weighted sweep & circ. condition mud & hole for 9 5/8" csg. 1/4/2003 00:00 - 01 :30 1.50 DRI LL CIRC SURFAC Circ. condition mud & hole for 9 5/8" csg. Observe well & pump dry job. 01 :30 - 05:00 3.50 DRILL TRIP SURFAC POH to bha-no hole problems. 05:00 - 06:30 1.50 DRILL PULD SURFAC Lay down dc,s-mwd & motor. 06:30 - 08:00 1.50 CASE RURD SURFAC Clear floor & rig up to run 9 5/8" csg. 08:00 - 12:00 4.00 CASE RUNC SURFAC Run 76 jts. 9 5/8" 40# L-80 Buttress mod csg. 12:00 - 13:30 1.50 CASE CIRC SURFAC Circ. capacity of csg. @ 6 bpm. 13:30 - 16:00 2.50 CASE RUNC SURFAC Run remainder of csg. -Total 143 jts. 95/8" 40# L-80 Butt Mod 16:00 - 17:00 1.00 CASE RURD SURFAC Lay down circ. tool-make up cement head-tag on landing ring wI hanger. (head loaded wI both plugs.) 17:00 - 19:30 2.50 CASE CIRC SURFAC Circ. condition mud & hole for cementing. 19:30 - 22:30 3.00 CEMENT PUMP SURFAC Pump 10 bbl. CW100 Test lines to 3500#-pump 40 bbls. CW100-drop bottom plug- pump 50 bbls. mud push wI red dye @ 10.5# followed wI 495 bbls. arctic set lite @ 10.7# followed wI 248 bbls. 12.# tail slurry as per cemecade program. Kick plug out wI 20 bbls. water. 22:30 - 00:00 1.50 CEMENTDISP SURFAC Displace cement wI treated mud-hole sticky-land csg. hanger on landing ring. Displace cement @ 5 bpm-full returns-had 119 bbls. lead cement returns-bump plug on calculated strokes Pressure 500# over. Bleed off-floats held. CIP @ 2400 hrs. 1/5/2003 00:00 - 01 :00 1.00 CEMENT PULD SURFAC Lay down landing jt. & clear floor of csg. handling tools. 01 :00 - 03:30 2.50 WELCTL NUND SURFAC Nipple down diverter. 03:30 - 05:00 1.50 WELCTL NUND SURFAC Nipple up adapter flange & speed head. 05:00 - 08:00 3.00 WELCTL NUND SURFAC Nipple up 13 5/8" X 5k bope & change out saver sub. 08:00 - 12:30 4.50 WELCTL BOPE SURFAC Rig up & test bope-annular 250-3500 Rams,valves,safety valves & choke manifold 250-5k. Accumulator 2900 initial 1950 bled off. 200 psi-39 secs. total 3 mins. 15 secs. 5 bottles @ 2050 psi. {Pull test plug-install wear ring & rilds. 12:30 - 13:00 0.50 DRILL PULD SURFAC Move 5" hwdp from left to right derrick bank. 13:00 - 16:30 3.50 DRILL PULD SURFAC Pick up 5" dp wI mule shoe to +- 5000'. 16:30 - 18:00 1.50 DRILL CIRC SURFAC Circulate & clear drill pipe & balance mud colume. 18:00 - 20:00 2.00 DRILL TRIP SURFAC POH stand dp in derrick-slm. 20:00 - 23:00 3.00 DRILL PULD SURFAC Pick up 5" drill pipe wI mule shoe to 3400'. 23:00 - 00:00 1.00 DRILL CIRC SURFAC Circulate & clear dp as precaution for auto trak-service rig. 1/6/2003 00:00 - 01 :30 1.50 DRILL PULD INTRM1 Pick up 139 jts. 5" dp-circ. clean & rack in derrick. 01 :30 - 05:00 3.50 DRILL PULD INTRM1 Pick up autotrak,mwd,bha-program & shallow test. 05:00 - 06:00 1.00 DRILL TRIP INTRM1 RIH to 3400'. 06:00 - 07:00 1.00 DRILL OTHR INTRM1 Slip & cut drlg. line. Printed: 1/31/2003 2:40:46 PM } ') ConpcoPb i llips·. Aléiska Opøratiol1sSul11l11ary RepQrt RIH to 5640'. Circ. condition hole for csg. test. Test 9 5/8" csg. to 2500#-hold & record for 30 mins. OK. Tag firm cement @ 5641'. Drill cement-float collar & float shoe-drill out to 5765'. Drill new hole from 5765 to 5785'. ADT .2. Displace hole wI new mud 9.1 Circ. & balance same. Perform & record LOT Formation broke wI 15 strokes 14.3 EMW-pump 3 bbls. @ 650# shut in bled back 3 bbls. Service rig-top drive-adjust brakes-bop drill 0-1. Establish downlink & ecd base line parameters. Drlg. & surveys wI autotrak from 5785' to 6161' (TVD 3267')ADT 3.4 PU 177k SO 70k RW 103k TO on 10-16k OFF 12k WOB 10-15k RPM 120 SPM 140 GPM 590 PP 1700. Drlg. & surveys wI autotrak from 6161' to 6997' (TVD 3533')ADT 8.2 hrs, PU 138k, SO 90k, RW 103k, TO on bttm 7-15k, OFF bttm 8k, WOB 10-15k, RPM 150, SPM 140, GPM 588, PP 2000. Drlg. & surveys wI autotrak from 6997' to 7756' (TVD 3776')ADT 7.4 hrs, PU 140k, SO 96k, RW 104k, TO on bttm 8-15k, OFF bttm 6-9k, WOB 5-13k, RPM 150, SPM 140, GPM 590, PP 2100. Repair Top Drive - The lube oil safety lock-out inguaged after sensor failed to read signal. Doyon electrician (Tony Jordan)service checked system and found TO lube system pumping wI 25 psi operating pressure.His thought was the -30? ambient tempreature was making the lube oil lock-out detector mal-fuction. Tourpusher had him bypass lube oil lock-out detector until weather warms up. ** NOTE** NO Safety Devices were by-passed (this is lube oil service only) 0.50 DRILL DRLG INTRM1 Drlg. & surveys wI autotrak from 7756' to 7800' (TVD 3790')ADT 0.2 hrs, PU 140k, SO 96k, RW 104k, TO on bttm 8-15k, OFF bttm 6-9k, WOB 5-13k, RPM 150, SPM 140, GPM 590, PP 2150, ECDs 10.9 -11.0 ppg. Pump Hi density sweeps as needed to maintain clean hole. 12.00 DRILL DRLG INTRM1 Drlg. & surveys wI autotrak from 7800' to 8684' (TVD 4072')ADT 7.7 hrs, PU 160k, SO 95k, RW 106k, TO on bttm 1 0-15k, OFF bttm 8-12k, WOB 10-12k, RPM 180, SPM 148, GPM 630, PP 2500., ECDs 11.4 ppg 12.00 DRILL DRLG INTRM1 Drlg. & surveys wI autotrak from 8684' to 9700' (TVD 4397')ADT 9.1 hrs, PU 162k, SO 103k, RW 105k, TO on bttm 12k, OFF bttm 10k, WOB 3-12k, RPM 180, SPM 148, GPM 630, PP 2550., ECDs 11.45 ppg, Pump Hi density sweeps as needed to maintain clean hole. 3.00 DRILL DRLG INTRM1 Drlg & surveys wI autotrak from 9700' to 9969' MD(TVD 4483')ADT 2.3 hrs, PU 162k, SO 103k, RW 106k, TO on bttm 12k, OFF bttm 10k, WOB 3-12k, RPM 180, SPM 148, GPM 630, PP 2550., ECDs 11.6 ppg, Pump Hi density sweeps as needed to maintain clean hole. 2.00 DRILL CIRC INTRM1 Pump 30 bbl Hi density (12.0 ppg) sweep & Circu 2X BU - Circu Rate 630 BPM , Rotate 60 RPMs Max perl Baker Inteq (John Mapes) set limit. Recip string slowly at all times,Set Bk 1 std per hr. 5.00 DRILL WIPR INTRM1 TOH 5 stds - Monitor well (Static) - Pump dry job - Con't TOH to 1986' MD **Note**( Tight hole 7337' to 7055' 25-35k overpull) worked until clean. 0.50 RIGMNT RSRV INTRM1 Serv Rig & Top Drive 1.00 DRILL PULD INTRM1 P/U 1 jt HWDP,Ghost reamer,1 jt HWDP & 1 jt DP (1 Std total) Ghost reamer is located between 2 jts of HWDP (2020' above Bit) 3.50 DRILL WIPR INTRM1 TIH tJ 9889' MD (No tight hole) - Wash 80' to Bttm 9969' Legal Well Name: 2G-17 Common Well Name: 2G-17 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From.. To Hours Code Sub Phase Code· 1/6/2003 07:00 - 08:00 1.00 DRILL TRIP INTRM1 08:00 - 09:00 1.00 DRILL CIRC INTRM1 09:00 - 10:00 1.00 DRILL DEOT INTRM1 10:00 - 13:00 3.00 DRILL DRLG INTRM1 13:00 - 13:30 0.50 DRILL DRLG INTRM1 13:30 - 14:30 1.00 DRILL CIRC INTRM1 14:30 - 15:30 1.00 DRILL FIT INTRM1 15:30 - 16:30 1.00 RIGMNT RSRV INTRM1 16:30 - 17:30 1.00 DRILL OTHR INTRM1 17:30 - 00:00 6.50 DRILL DRLG INTRM1 1/7/2003 00:00 - 12:00 12.00 DRILL DRLG INTRM1 12:00 - 22:30 10.50 DRILL DRLG INTRM1 22:30 - 23:30 1.00 RIGMNT RGRP INTRM1 23:30 - 00:00 1/8/2003 00:00 - 12:00 12:00 - 00:00 1/9/2003 00:00 - 03:00 03:00 - 05:00 05:00 - 10:00 10:00 - 10:30 10:30 - 11 :30 11 :30 - 15:00 Þage3 Qf .10 Start: 12/28/2002 Rig Release: Rig Number: Spud Date: 12/29/2002 End: Group: Printed: 1/31/2003 2:40:46 PM ) ) Legal Well Name: 2G-17 Common Well Name: 2G-17 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Sub Code 1/9/2003 15:00 - 16:00 1.00 DRILL CIRC INTRM1 16:00 - 00:00 8.00 DRILL DRLG INTRM1 Start: 12/28/2002 Rig Release: Rig Number: Spud Date: 12/29/2002 End: Group: Circu BU to Minimize ECDs - Max ECDs on BUs 11.79 ppg, After BUs 11.1 ppg Drlg. & surveys wI autotrak from 9969' to 10,700'MD (TVD 4717') ADT 5.7 hrs, PU 190k, SO 102k, RW 117k, TO on bttm 17k, OFF bttm 15k, WOB 5-1 Ok, RPM 180, SPM 148, G PM 630, PP 2600., ECDs 11.15 ppg, Pump Hi density sweeps as needed to maintain clean hole. 12.00 DRILL DRLG INTRM1 Drlg. & surveys wI autotrak from 10,700' to 11 ,387'MD (TVD 4936') ADT 9.2 hrs, PU 195k, SO 105k, RW 120k, TO on bttm 16k, OFF bttm 15k, WOB 3-12k, RPM 180, SPM 148, GPM 630, PP 2600., ECDs 10.88 ppg, Pump Hi density sweeps as needed to maintain clean hole. 12.00 DRILL DRLG INTRM1 Drlg. & surveys wI autotrak from 11,387' to 12,250'MD (TVD 5212') ADT 9.1 hrs, PU 237k, SO 97k, RW 142k, TO on bttm 18-22k, OFF bttm 15-21k, WOB 4-12k, RPM 180, SPM 148, GPM 630, PP 2660., ECDs 10.64 ppg, Pump Hi density sweeps as needed to maintain clean hole. 12.00 DRILL DRLG INTRM1 Drlg. & surveys wI autotrak from 12,250' to 12947'MD (TVD 5433') ADT 7.4 hrs, PU 210k, SO 112k, RW 135k, TQ on bttm 15-18k, OFF bttm 15-20k, WOB 4-12k, RPM 180, SPM 148, GPM 630, PP 2750., ECDs 10.64 ppg, Mud wt 9.3ppg) Pump Hi density sweeps as needed to maintain clean hole. 12.00 DRILL DEOT INTRM1 Drlg. & surveys wI autotrak from 12947' to 13650'MD (TVD 5756') ADT 9.3 hrs, PU 196k, SO 121k, RW 149k, TO on bttm 17-21k, OFF bttm 15-18k, WOB 5-10k, RPM 135, SPM 136, GPM 572, PP 2950, ECDs 12.0 (Mud wt 10.6ppg) ppg, Pump Hi density sweeps as needed to maintain clean hole. ....Note.... Weight up 9.2ppg to 10.6ppg @ 13,200' MD. Used 300 bbls 15.8 ppg Spike fluid from Bariod Mud Plant treated with Aldacide G for bacteria controle. Weight up completed @ 13,320' = Mud wt 10.6ppg , ECDs 12.0ppg 9.00 DRILL DRLG INTRM1 Drlg. & surveys wI autotrak from 13,650' to 13,999'MD(5957 TVD ') ADT 6.8 hrs, PU 216k, SO 125k, RW 158k, TO on bttm 17-20k, OFF bttm 19-22k, WOB 4-12k, RPM 180, SPM 140, GPM 588, PP 2800., ECDs 11.96 ppg, Mud wt 10.6ppg) Pump Hi density sweeps as needed to maintain clean hole. ........NOTE...... Weekly BOP Test Due AOGCC was notified concerning weekly BOP test. Rep (Chuck Scheve) waived weekly test until after 7" csg is set, unless we have to make a HO trip. If a HO trip is nessessary we will test BOPs while OOH. 0.50 DRILL CIRC INTRM1 Circu & Condition - Geologist evaluate logs & pick TD 0.50 DRILL DRLG INTRM1 Drlg. & surveys wI autotrak from 13,999' to 14,035'MD(5978' TVD) TD 8? hole, ADT 0.3 hrs, PU 216k, SO 125k, RW 158k, TO on bttm 17-20k, OFF bttm 19-22k, WOB 4-12k, RPM 180, SPM 140, GPM 588, PP 2800., ECDs 12.01 ppg, Mud wt 10.6ppg) Pump Hi density sweeps as needed to maintain clean hole. Pump Sweep - Circu & Condition - Pump sweep to surface + 2X BUs (23,700 total stks) Pump rate 580 gpm, RPMs 100, Recip DP, UD 1 std/hr. Wiper Trip 22 stds t/ 11,950 (Above Ghost reamer point @ TD) - No excess drag - No swab TIH to 14,035' - No tight hole Pump Sweep - Circu & Condition - Pump sweep to surface + 2X BUs (23,700 total stks) - Added 4 bbls "Torq Trim II" to last circulation and displace to bit to enhance lower hole lubricity for csg run. Pump rate 1/1 0/2003 00:00 - 12:00 12:00 - 00:00 1/11/2003 00:00 - 12:00 12:00 - 00:00 1/12/2003 00:00 - 09:00 09:00 - 09:30 09:30 - 10:00 10:00 - 13:00 3.00 DRILL CIRC INTRM1 13:00 - 15:00 2.00 DRILL WIPR INTRM1 15:00 - 16:00 1.00 DRILL WIPR INTRM1 16:00 - 18:30 2.50 DRILL CIRC INTRM1 Printed: 1/31/2003 2:40:46 PM " ) 580 gpm, RPMs 100, Recip DP, UD 1 std /hr. Observe well - Pump dry job - Blow dn TD - TOH to 5700' - Tight spots @ 6108' & 6014' ,25K overpull - Work until clean. RIH f/5700' to 6200' (thru tight spots) POOH to BHA. No hole problems encountered. PJSM. Lay down HWDP & BHA. Down load LWD info in pipe shed. Drain stack & pull wear bushing, set test plug. Remove 3-1/2" x 6" variable rams & install 7" rams for casing run. Fill stack with water Test 7" rams to 250 psi / 5000 psi. Pull test plug. Rig up to run 7" casing. PJSM. Run 7", 26#, L-80 BTC-Mod casing. Install centralizers as per well plan. Maintain casing running speed @ 45 FPM. Baker-lock first 3 joints of casing. Run 7", 26#, L-80 BTC-Mod casing. Running speed 45 FPM. Good displacement while running casing. Repair hydraulic leak on lay down machine pipe skate. Run 7", 26#, L-80 BTC-Mod casing. Running speed 45 FPM. Good displacement while running casing. Circulate one casing volume. Stage pump rates up to 5 BPM. No losses. Up weght 108k, Dn weight 75k. Pump pressure 480 psi. Run 7",26#, L-80 BTC-Mod casing. Running speed 45 FPM. Good displacement while running casing. Circulate Bottoms up. Stage pump rates up to 5 BPM. Up weght 140k, Dn weight 80k. Pump pressure 600 psi. Lost 21 bbls while circulating. Run 7",26#, L-80 BTC-Mod casing. Running speed 45 FPM. Good displacement while running casing. Circulate Bottoms up. Stage pump rates up to 5 BPM. Up weght 198k, Dn weight 88k. Pump pressure 650 psi. CBU @ 10,790' - Mud loss rate 65 bph while pumping - Pump rate 60 spm (252 gpm), PP 700 psi Run 7" 26# L-80 BTCM csg - Full returns while RIH Circu & Condition - Stage pumps up slowly to 6.0 bpm, loss rate during first circu 14 bpm, No losses thereafter. Total circu 12,444 stks (3.6 X BUs) - Hold CMT PJSM - Pre Circu mud properties, MW 10.5+ppg, Vis 43, PV 13, YP 13, Gels 5/12/14, Post Circu MW 10.4 ppg, Vis 40, PV 11, YP 13, Gels 4/8/11 0.50 CEMENT PUMP INTRM1 CMT 7" Csg - Pumped 5 bbls CW 100, Test CMT lines 3000psi, Pumped 35 bbls CW 100, Drop bttm plug, pump 50 bbls Mudpush, pump 36.5 bbls 15.8 ppg G Slurry,Drop Top Plug, Kick out plug w/ 20 bbls wash up- Try over to rig for displacement Rig displace @ 6 bpm, 600 psi - Bumped plug to 1500psi (900 psi over pump rate) Slowed pump rate to 3 bpm to bump plug - CIP @ 11 :30 - Floats held (Shoe @ 14027' MD - 5972' TVD) RID all CMT tools UD Landing jt - Clear Rig floor MU Packott setting tool & set packott - Test to 5000 psi - Hold 10 min "OK" - Install test plug Install 3?" X 6" VBRs in Top BOP & 4" rams in lowerbops- Change out Top drive to 4" XT Slip & Cut drill line (110' cut) R/U & Test BOPs - Test Annular 250psi/3500psi , BOPs & Choke Manifold 250psi/ 5000psi Legal Well Name: 2G-17 Common Well Name: 2G-17 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date· From-To Hoürs·Code Sub· Phase· COde 1/12/2003 16:00 - 18:30 2.50 DRILL CIRC INTRM1 18:30 - 00:00 5.50 DRILL TRIP INTRM1 1/13/2003 00:00 - 03:00 3.00 DRILL TRIP INTRM1 03:00 - 05:00 2.00 DRILL PULD INTRM1 05:00 - 05:30 0.50 WELCTL OTHR INTRM1 05:30 - 06:30 1.00 WELCTL EQRP INTRM1 06:30 - 07:00 0.50 WELCTL BOPE INTRM1 07:00 - 09:00 2.00 CASE RURD INTRM1 09:00 - 12:00 3.00 CASE RUNC INTRM1 12:00 - 14:00 2.00 CASE RUNC INTRM1 14:00 - 14:30 0.50 RIGMNT RGRP INTRM1 14:30 - 16:30 2.00 CASE RUNC INTRM1 16:30 - 17:30 1.00 CASE CIRC INTRM1 17:30 - 20:00 2.50 CASE RUNC INTRM1 20:00 - 21 :00 1.00 CASE CIRC INTRM1 21 :00 - 23:30 2.50 CASE RUNC INTRM1 23:30 - 00:00 0.50 CASE CIRC INTRM1 1/14/2003 00:00 - 00:30 0.50 CASE CIRC INTRM1 00:30 - 04:30 4.00 CASE RUNC INTRM1 04:30 - 09:30 5.00 CEMENTCIRC INTRM1 09:30 - 10:00 10:00 - 11 :30 1.50 CEMENT DISP INTRM1 11 :30 - 12:00 0.50 CEMENT PULD INTRM1 12:00 - 12:30 0.50 CEMENT PULD INTRM1 12:30 - 13:30 1.00 WELLSR SEQP INTRM1 13:30 - 16:30 3.00 WELCTL NUND INTRM1 16:30 - 18:00 1.50 RIGMNT RSRV INTRM1 18:00 - 00:00 6.00 RIGMNT RGRP INTRM1 Start: 12/28/2002 Rig Release: Rig Number: Spud Date: 12/29/2002 End: Group: Printed: 1/31/2003 2:40:46 PM ') ) Legal Well Name: 2G-17 Common Well Name: 2G-17 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 From -To Hours Code .... .. Sub .. Phase .... .. .... Code 1/15/2003 00:00 - 00:30 0.50 WELLSR NUND INTRM1 00:30 - 08:30 8.00 DRILL PULD INTRM1 08:30 - 13:30 5.00 RIGMNT RGRP INTRM1 13:30 - 15:00 1.50 DRILL PULD INTRM1 15:00 - 16:30 1.50 DRILL PULD INTRM1 16:30 - 17:30 1.00 DRILL PULD INTRM1 17:30 - 18:00 0.50 DRILL PULD INTRM1 18:00 - 23:00 5.00 DRILL PULD INTRM1 23:00 - 00:00 1.00 DRILL PULD INTRM1 1/16/2003 00:00 - 01 :30 1.50 DRILL PULD PROD 01 :30 - 02:00 0.50 DRILL CIRC PROD 02:00 - 04:00 2.00 DRILL PULD PROD 04:00 - 04:30 0.50 DRILL CIRC PROD 04:30 - 06:30 2.00 DRILL PULD PROD 06:30 - 07:00 0.50 DRILL CIRC PROD 07:00 - 08:00 1.00 DRILL TRIP PROD 08:00 - 10:30 2.50 DRILL TRIP PROD 10:30 - 12:00 1.50 DRILL TRIP PROD 12:00 - 17:00 5.00 DRILL TRIP PROD 17:00 - 20:30 3.50 DRILL TRIP PROD 20:30 - 22:30 2.00 DRILL CIRC PROD 22:30 - 00:00 1.50 DRILL CIRC PROD 1/17/2003 00:00 - 03:00 3.00 DRILL TRIP PROD 03:00 - 04:30 1.50 DRILL CIRC PROD 04:30 - 05:30 1.00 CASE MIT PROD 05:30 - 07:00 1.50 DRILL DRLG PROD 07:00 - 07:30 0.50 DRILL SFTY PROD 07:30 - 08:30 1.00 DRILL DRLG PROD 08:30 - 10:00 1.50 DRILL CIRC PROD 10:00 - 11 :00 1.00 DRILL FIT PROD 11 :00 - 12:00 1.00 DRILL DRLG PROD 12:00 - 12:30 0.50 DRILL DRLG PROD Start: 12/28/2002 Rig Release: Rig Number: Spud Date: 12/29/2002 End: Group: Description of Operations Install wear bushing -RILDS UD 5" DP out of derrick (360 jts) Hyd. cyclinder failed on LS (Rig End) of pipe elevator. Replaced Hyd Cyclinder. UD 5" DP out of derrick (60 jts) C/O handling equip - P/U & TIH wI 42 jts (14 stds) XT39 DP C/O Stabbing guide on Top Drive TOH & Std back 14 stds XT DP in derrick (DP for drill out) P/U BHA # 9 - M/U Bit - Turbo bk stab ,Navi Drill Mach 1 XL motor( AKO 1.2?) ,NM stab,MAP,SRIG,MPR,Den. Neutron,MWD. Orient Motor, Program MWD. Hold PJSM on Rad scources-Install scorces- Pulse test tools "OK" - P/U 3 NM CSDP,XO, 6 SPWTDP,Jars, 23 SPWTDP TIH P/U 4" DP singles out of pipe shed - Fill DP every 25 stds TIH P/U 4" DP singles out of pipe shed to 4200' - Fill DP every 25 stds Fill DP - Pulse test tools TIH P/U 4" DP singles out of pipe shed to 6650' - Fill DP every 25 stds Fill DP - Pulse test tools TIH P/U 4" DP singles out of pipe shed to 9220' - Fill DP every 25 stds Fill DP - Pulse test tools - **NOTE** Tool failed - Lost resistivity & pressure sub - Trouble shoot tool - NO success. Mix & Pump dry job - Blow dn Top Drive TOH to HWDP Std bk HWDP & 1 std NMDCs UD BHA - Drain Motor & MWDs, Held PJSM fl rad. sources - Pull sources - C/O MWDs & Orient motor- Program MWDs - Load sources - TIH wI HWDP - Pulse test tools "OK" TI H to 9191' - Fill DP & Pulse test tools every 25 stds Tool failed #2 - Tool will pulse but will not communicate with Nuke tool- Trouble shoot tools - Discuss options with Team leader, Well Engineer, Well and on site Geologists. TIH P/U 4" DP singles out of pipe shed to 10,593' - Fill DP every 25 stds TIH to 13905 - Tag CMT @ 13,905' - Std bk 1 std ****NOTE****** With only the Rec,Dir,Gama & Pressure portions of the logging tools working the decision was made to drill ahead and attempt to get the logs at a later time (Mad pass or E-line logs) Fill Dp -Circu air from system Rate 6 bpm, 2700 psi, Recip DP all times. Test Csp 3500 psi - Chart & hold 30 min (10 psi lost after 30 min) Drlg CMT,FC, shoe tract to top FS Hold PJSm - Review Interval Risk & objectives with rig crew and all contractors. Drlg FS,rat hole CMT + 20' new hole 14,025' to 14,055' MD (5989') Rate 200 gpm, PP 2100, Up wt 215k, Dn wt 75k, Rot wt 115k, Torq on bttm 19k, off bttm 16k Circu hole clean - Rate 200 gpm, PP 2100, Up wt 215k, Dn wt 75, Rot wt 115k, T orq on bttm 19k, off bttm 16k . Perform FIT test to 15.3 EMW - 10.5 ppg mud wt @ 5972' TVD (Broke @ 1500 psi) Preform FIT test to 15.3 EMW ( Form. broke @ 1500 psi) 10.5 ppg mud wt @ 5972' TVD. Pumped 5.6 bbls, bled back 2.4 bbls Drlg 61/8" hole 14,055' to 14,100' MD (6015' TVD) - Rate 200 gpm, PP 2100, Up wt 215k, Dn wt 75, Rot wt 115k, Torq on bttm 19k, off bttm 16k. ADT 0.8 hrs Drlg 6 1/8" hole 14,100' to 14,116' MD (6024' TVD) - Rate 200 gpm, PP Printed: 1/31/2003 2:40:46 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2G-17 2G-17 ROT - DRILLING n1334@ppco.com Doyon 141 Date From-To · Hours Code SUb·· Phase Code· 1/17/2003 12:00 - 12:30 0.50 DRILL DRLG PROD 12:30 - 14:00 1.50 DRILL CIRC PROD 14:00 - 18:00 4.00 DRILL TRIP PROD 18:00 - 18:30 0.50 RIGMNT RSRV PROD 18:30 - 20:00 1.50 DRILL TRIP PROD 20:00 . 23:30 3.50 DRILL TRIP PROD 23:30 - 00:00 0.50 DRILL TRIP PROD 1/18/2003 00:00 - 01 :00 1.00 DRILL TRIP PROD 01 :00 - 07:00 6.00 DRILL TRIP PROD 07:00 - 07:30 0.50 DRILL DRLG PROD 07:30 - 08:30 1.00 DRILL DRLG PROD 08:30 - 09:30 1.00 DRILL CIRC PROD 09:30 - 10:30 1.00 DRILL CIRC PROD 10:30 . 12:00 1.50 DRILL DRLG PROD 12:00 . 15:00 3.00 DRILL DRLG PROD 15:00 - 18:00 3.00 DRILL CIRC PROD 18:00 - 19:00 1.00 DRILL DRLG PROD 19:00 - 20:30 1.50 DRILL CIRC PROD 20:30 - 23:00 2.50 DRILL DRLG PROD 23:00 - 00:00 1.00 DRILL CIRC PROD 1/19/2003 00:00 - 06:30 6.50 DRILL DRLG PROD 06:30 - 12:00 5.50 DRILL CIRC PROD 12:00 - 00:00 12.00 DRILL CIRC PROD Start: 12/28/2002 Rig Release: Rig Number: Spud Date: 12/29/2002 End: Group: 2100, Up wt 215k, Dn wt 75, Rot wt 115k, Torq on bttm 19k, off bttm 16k. ADT 0.5 hrs Note"**" Logging tools failed completely. Lost Dir. portion of tool is all that remains working. Circu hole clean - Rate 220 gpm, PP 2100 psi, 60 RPMs, Recip DP at all times.- Pump dry job - Blow dn Top Drive TOH to 4894' - Monitor for flow per CPAI policy Service Rig & Top Drive - Monitor well TOH to BHA BHA - Std Bk HWDP & Jars, 1 std NMCSDP - Held PJSM on Rad. sources - Remove sources - C/O MWDs - Re-Orient Motor - Load sources TIH w/ BHA & NMCSDP PJSM - TIH -C/O elevators - P/U std DP - Pulse test MWD tools"OK" TIH to 14,027' - Fill DP & Pulse test MWD every 2500' MAD Pass for logs f/14,053' to 14,116', ART 0.5 hrs , PRate 200 gpm ,P stks 47 spm, PP 2050, RPMs 80, Torq 14K, Up wt 180, Dn wt 83, Rot wt 113 - Log @ 120' /hr Drlg 61/8" hole 14,116' to 14,142' MD - Rate 200 gpm, PP 2100, Up wt 185k, Dn wt 80, Rot wt 114k, Torq on bttm 17k, off bttm 16k. Mud wt 10.6 ppg , ART 0.5 hrs, AST 0.0 hrs Circu hole clean - Rate 200 gpm, PP 2100, Up wt 185k, Dn wt 80, Rot wt 114k, Torq off bttm 16k. Mud wt 10.5+ Preform MAP Base line test & record data for Engineer plot Drlg 6 1/8" hole 14,142' to 14,190' MD - Rate 200 gpm, PP 2150, Up wt 186k, Dn wt 85, Rot wt 115k, T orq on bttm 15k, off bttm 13k. Mud wt 10.5+ , ECDs 11.62 ppg, ART 1.0 hrs, AST 0.0 hrs Drlg 61/8" hole 14,190' to 14,330' MD (6145' TVD) - Rate 200 gpm, PP 2200, Up wt 186k, Dn wt 84, Rot wt 116k, Torq on bttm 17k, off bttm 15k. Mud wt 10.6 ppg , ECDs 12.01 ppg, ART 2.0 hrs, AST 0.0 hrs *** NOTE"*** Conn. Gas to surface Max 2484 units Circu & condition - Raise mud wt f/1 0.5+ to 11.0 ppg Drlg 61/8" hole 14,330' to 14,395' MD (6181' TVD) - Rate 200 gpm, PP 2150, Up wt 186k, Dn wt 86, Rot wt 117k, Torq on bttm 17k, off bttm 14k. Mud wt 11.0 ppg , ECDs 11.89 ppg, ART .4 hrs, AST 0.0 hrs Circu & Condition - Circu BU conn Gas· Max gas 2164 units Drlg 61/8" hole 14,395' to 14,500' MD (6242' TVD) - Rate 200 gpm, PP 2200, Up wt 188k, Dn wt 85, Rot wt 117k, Torq on bttm 17k, off bttm 14k. Mud wt 11.0 ppg , ECDs 11.99 ppg, ART 2.3 hrs, AST 0.0 hrs Circu BU for sample, PRate 200 gpm , PP 2200, Mud wt 11.0 ppg , ECDs 11.80 Drlg 61/8" hole 14,500' to 14,768' MD (6403' TVD) "Well TD"· Rate 200 gpm, PP 2200, Up wt 195k, Dn wt 85, Rot wt 129k, Torq on bttm 15k, off bttm 16k. Mud wt 11.0 ppg , ECDs 12.0 ppg, ART 5.6 hrs, AST 0.0 hrs - Drlg rate 75 ft/hr to minimize ECDs from cutting load & inheance log quaility Circu & Condition - Raise Mud wt from 11.0 ppg to 11.6 ppg. After 0.4 ppg increase stop circulation for +/- 5 min - Circu BU & resume circulating. @ 8:00AM, 11.0 ppg, BUG 2200 units, MW cut to 7.4ppg, @11 :OOAM, 11.4 ppg, BUG 2150 units, MW cut 7.8 ppg Circu & Condition - PRate 200 gpm, Raise Mud wt from 11.6 ppg to 12.2 ppg After ea. 0.3 ppg increase stop circulation for +/- 5 min - Circu BU & resume circulating. PR 200 gpm, @ 13:30 PM ,MW 11.6 ppg, Printed: 1/31/2003 2:40:46 PM ) ') CqnocòPhilliþ$· Alaska Operé:}tions $urnmaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2G-17 2G-17 ROT - DRILLING n1334@ppco.com Doyon 141 Sub From-To Hours<Gode COde Phase 1/19/2003 12:00 - 00:00 12.00 DRILL CIRC PROD 1/20/2003 00:00 - 03:00 3.00 DRILL CIRC PROD 03:00 - 07:00 4.00 DRILL CIRC PROD 07:00 - 10:30 3.50 DRILL CIRC PROD 10:30 - 12:00 1.50 DRILL CIRC PROD 12:00 - 16:00 4.00 DRILL CIRC PROD 16:00 - 00:00 8.00 DRILL CIRC PROD 1/21/2003 00:00 - 05:30 5.50 DRILL CIRC PROD 05:30 - 06:00 0.50 DRILL OBSV PROD 06:00 - 10:30 4.50 DRILL CIRC PROD 10:30 - 14:00 3.50 DRILL CIRC PROD 14:00 - 17:00 3.00 DRILL WIPR PROD 17:00 - 20:30 3.50 DRILL OBSV PROD 20:30 - 00:00 3.50 DRILL REAM PROD 1/22/2003 00:00 - 02:30 02:30 - 07:00 2.50 DRILL REAM PROD 4.50 DRILL CIRC PROD Start: 12/28/2002 Rig Release: Rig Number: Spud Date: 12/29/2002 End: Group: Description of Operations BUG 2190 units, MW cut to 8.8 ppg, @ 16:30 PM, MW 11.9 ppg, BUG 2187 units, MW cut 8.8 ppg, Shut down 20 min, Ck @ 23:45, MW 12.2 ppg, BUG 832 units,. MW cut 9.1 ppg. Slowly Rot & Recip DP at all times. PRate 200 gpm , Up wt 195 K, Dn wt 85 K, Rot wt 129. Circu & Condition - Weight up from 12.2 ppg to 12.5 ppg. Pump Rate 38 SPM , ECDs 13.80 (Baker MAP). @ 80 stks past the bit with 12.5 ppg mud we lost partial returns. Calculated ECD by Baroid program showed 14.6 ppg wi 12.5 ppg mud @ 1.8 bpm @ Bit Reduce pump rate to 20 SPM (2 bbls) wi a loss of 50-60% returns. The pump rate was reduced to 15 SPM (1.5 bbls) wi a loss of 30-40% returns, Pump rate reduced to 12 spm (1.2 bbls)wl 20-25% losses **NOTE** Confered with on site drilling engineer & team leader about use of LCM. Con't pumping @ 1.2 bpm - Mixing Baro-fiber (fine) @ 4 Ibs/bbl - Losses 20% (14 bbls Ihr) Con't pumping & mixing baro-fiber- 1420 stks into LCM going dn hole showed losses slowing .The baro-fiber mix was increased to 10 Ibs Ibbl and cont to circu & mix @ 1.2 bpm. Total mud loss this tour 197 bbls. Con't pumping @ 1.2 bpm - Well stable (Minimal losses) - Stage pumps up slowly to 2.2 bpm - Monitor G/L - Well Stable(Minimalloss) Circu & Condition hole Decrease pump rate to 1.8 bpm - Increase mud weight very slowly from 12.3ppg to Max of 12.5 ppg. Con't mixing baro-fiber 10 min/sx Monitor for losses. Total losses this tour 28 bbls. Up wt 170k, Dn 92k, Torq 16-18 ftllbs Mud wt @ midnight 12.5 ppg in , 12.4 ppg out. Con't Circu & Condition - Bring mud wt up slowly to 12.5 ppg - Out & In . Monitor G/L - (Well static) , PR 1.8 bpm, Rot 35 RPMs, Rotate & Recip DP very slowly at all times. Stop Pumps - Monitor well for 30 min. (Very slight weep) Circu BU (No losses - Monitor for Gas influx - BU Max Gas 2130 units- PR 1.4 bpm, Rot 35 RPMs - Con't Circu & Condition - Raise mud wt very slowly from 12.5 ppg to 12.6 ppg - String in barofiber 10 min I sx - Monitor G/L - Well static - PR 1.4 bpm, Rot 35 RPMs - Spot 30 bbl LCM pill on Bttm(15Ibs/bbl, barofiber fine) (Pill covers +1- 740' hole) Wiper Trip to 7" Csg shoe - Up wt 195-200K -TOH - pump out hole to 14,419' -Tight @ 14,419' 50k overpull , 14,339' 100k overpull, Bk Ream 14,245' to 14,038' - Ream up wt 120-125k, 80 RPMs, PR 10 spm, PP 900 psi. Circu BU, PR 1.5 bpm, PP 1000 psi, G/L stable,( Minimal Gas to surface 25-30 units) Slip & Cut drill line (91' cut) Slowly Wash & Ream (150 ftlhr) 14,035' to 14,426' , PR 1.5 bpm, Rot 80 RPMs, Fluid loss reaming 40 -42 bbl/hr until past 14,350'. Losses showed steady decrease from 14,350 thru 14,426' . @ 14,426 losses Av 8 bbl/hr. ** Note*** @ 10:00PM ,1110 stks after starting to ream, the MW out increased to 13.1 -13.2 ppg. This continued thru the end of tour @ 1877 stks. Total mud loss for day 81 bbls. Wash & ream 14426 to 14768-no fill. CBU-monitor gain-Ioss-max. gas units 150. Printed: 1/31/2003 2:40:46 PM .) ) COhocoPhillipsAlélska :Operati()ns ßUl11rnârYR~port Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2G-17 2G-17 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 12/28/2002 Rig Release: Rig Number: Spud Date: 12/29/2002 End: Group: 1/22/2003 From-To· Hours Code . Sub Code 07:00 - 09:00 2.00 DRILL TRIP PROD 09:00 - 15:00 6.00 DRILL CIRC PROD 15:00 - 16:00 1.00 DRILL OBSV PROD 16:00 - 19:30 3.50 DRILL CIRC PROD 19:30 - 00:00 4.50 DRILL TRIP PROD 00:00 - 01 :00 1.00 DRILL TRIP PROD 01 :00 - 02:30 1.50 DRILL CIRC PROD 02:30 - 05:30 3.00 DRILL TRIP PROD 05:30 - 08:00 2.50 DRILL CIRC PROD 08:00 - 08:30 0.50 DRILL TRIP PROD 08:30 - 09:30 1.00 DRILL CIRC PROD 09:30 - 10:30 1.00 DRILL TRIP PROD 10:30 - 13:30 3.00 DRILL CIRC PROD 1/23/2003 13:30 - 18:00 4.50 DRILL TRIP PROD 18:00 - 19:00 1.00 DRILL OTHR PROD 19:00 - 22:00 3.00 DRILL TRIP PROD 22:00 - 22:30 0.50 DRILL OTHR PROD 22:30 - 00:00 1.50 DRILL TRIP PROD 1/24/2003 00:00 - 02:30 2.50 DRILL TRIP PROD 02:30 - 03:30 1.00 DRILL PULD PROD 03:30 - 04:30 1.00 CASE PULR PROD 04:30 - 06:00 1.50 CASE PULR PROD 06:00 - 17:30 11.50 CASE RUNL PROD 17:30 - 20:30 3.00 CASE CIRC PROD 20:30 - 21 :00 0.50 CASE RUNL PROD 21 :00 - 00:00 3.00 CASE CIRC PROD 1/25/2003 00:00 - 05:00 5.00 CASE CIRC PROD 05:00 - 06:00 1.00 CEMENT PUMP PROD 06:00 - 07:30 1.50 CEMENT DISP PROD 07:30 - 08:30 1.00 CEMENT OTHR PROD 08:30 - 09:00 0.50 CEMENT PULD PROD 09:00 - 10:00 1.00 CEMENTOTHR PROD 10:00 - 21 :00 11.00 CEMENT OTHR PROD 21 :00 - 22:00 1.00 CEMENT PULD PROD 22:00 - 00:00 2.00 CEMENTOTHR PROD 1/26/2003 00:00 - 00:30 0.50 CMPL TN OTHR CMPL TN POH to shoe-pumped out-no problems. CBU-monitor gain-loss & gas-max. units 2000. Mud wt. out 11.0# continue circ. & monitor well. Build mud wt. 12.7#. Shut down pumps-observe well for 1 hr.-well stable. CBU-monitor gain/loss-max. gas units 402. Pump out of hole @ 2.5 BPM from 14027 to 10315'. Continue pump out of hole to 10034' @ 2.5 bpm. Observe well-cbu-no gas-slight flow 1/2". RIH t014027'. CBU-monitor gain/loss & gas units-max. gas 250 units. RIH to 14768 TD-no problems. Circ. monitor gain/loss & gas. Pump out of hole to 14040'. CBU-monitor gain/loss & gas-lost 163 bbls. to formation-no gas. Very SPM F/15 to 25 W/ bottoms up @ 3000' from surface started getting 13 to 13.9 ppg returns at surface. Losses @ 40% at time Pump out of hole to 10315' @ 2.5 to 4.0 bpm. Observe well-Pencil stream flow. Pump out of hole @ 3.0 to 4.0 bpm to 7518'. Observe well-pump dry job-blow down top drive. POH to run 3.5" liner. (Trip tank fill) Continue pulling to bha for 3.5" liner. Lay down bha-down load sources-lay down mwd & motor. PJSM=clear floor & rig up to run 3.5" liner. Pick up 27 jts. 3.5" 9.3# L-80 eue 8rd liner -liner hanger & packer-circ. capacity of liner. RIH w/liner on 4" dp slow to 13955'. CBU @ 2.5 bpm-slight fluid loss @ 3 bpm-no gas-no losses @ 2.5 bpm-establish torque & drag.Static torque 8000# Rotating torque up 7000# @ 130k 15 rpm-down 5000# 85k 15 rpm. Non rotating wt. 150k up 75k down. Rih to bottom @ 14768' no problems. Make up cement head & cbu @ 2.5 bpm. Started @ 25 spm fluid losses 25% slow rate to 1.8 spm losses 10 - 15% continue to circulate till return full. Lost 79 bbl's Continue circulating & condition mud for cementing. (hole taking 20+- bbls. mud per hr. @ 2 bpm. pumping.) Hole stabilized @ 0400-not taking fluid. PJSM-Pump 10 bbls. cw100-test lines to 4500# ok-pump 20 bbls. cw100-30 bbls. mud push @ 13.5#-35 bbls. 15.8# Class 'G' cement followed w/2 bbls. water. Pump @ 2.5 bpm. Kick out plug & displace cement w/ mud @ 2.5 bpm-bump plug on calculated strokes-full circulation while displacing-set hanger & packer. (liner top @ 13842' dpm.) Reverse circ. out cement-recovered 30 bbls. cw100-30 bbls. mud push & 6.4 bbls. cement Lay down cement head & 3 jts. 4' dp. Circulate hole & pipe @ 13700' (70 spm @ 3000#) Observe well-pump dry job-poh laying down 4" dp. Service baker running tool-pick up-service & break down cement manifold. Run in hole w/1 0 stands hwdp & jars. Lay down same. Finish laying down hwdp. Printed: 1/31/2003 2:40:46 PM ) ') Legal Well Name: 2G-17 Common Well Name: 2G-17 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From.;.·Tô . .. Sub . HOUrs.. C?de Code 1/26/2003 00:30 - 05:00 4.50 CMPL TN OTHR CMPL TN 05:00 - 19:00 14.00 CMPL TN RUNT CMPL TN 19:00 - 20:30 1.50 CMPL TN OTHR CMPL TN 20:30 - 23:00 2.50 CMPLTN CIRC CMPL TN 23:00 - 00:00 1.00 CMPL TN SOHO CMPL TN 1/27/2003 00:00 - 01 :00 1.00 CMPL TN DEOT CMPL TN 01 :00 - 01 :30 0.50 CMPL TN OTHR CMPL TN 01 :30 - 03:00 1.50 CMPL TN NUND CMPL TN 03:00 - 04:00 1.00 CMPL TN NUND CMPL TN 04:00 - 04:30 0.50 CMPL TN SEOT CMPL TN 04:30 - 05:00 0.50 CMPL TN OTHR CMPL TN 05:00 - 06:30 1.50 CMPL TN FRZP CMPL TN 06:30 - 08:30 2.00 CMPL TN FRZP CMPL TN 08:30 - 10:30 2.00 CMPL TN OTHR CMPL TN 10:30 - 12:00 1.50 CMPL TN OTHR CMPL TN PaQe100110 Start: 12/28/2002 Rig Release: Rig Number: Spud Date: 12/29/2002 End: Group: Dêscription <of Operations Pull wear ring-install test plug-test bope 300-5000k-Witness test waived by John Spalding AOGCC. Rig up & run completion assembly wI 439 jts. 3.5" 9.3# L-80 EUE 8rd Mod tbg. Tag up wI locator-rig up & test Csg. to 3500k 30 mins.-chart same. Displace well to 8.4# seawater. Make up tbg. hanger & space out pup-land hanger & rilds. Test 3.5" tbg. & annulus 5 mins. each-chart same-shear rp valve. Lay down landing jt. & install two way check. Nipple down bope. Nipple up adapter flange & tree. Test flange & tree to 5000# 10 mins. ok. Perform PIT on 9 5/8" X 7" annulus 15.4#. Freeze protect well wI 90 bbls. diesel 3.5" tbg. & annulus. 'U' tube 3.5" tbg. Freeze protect 9 5/8" X 7" annulus wI 70 bbls. diesel. Set BPV & secure well. Clean mud tanks & rockwasher. (Release rig from 2G-17 @ 1200 hrs. 1/27/03) Printed: 1/31/2003 2:40:46 PM Date 01/31/03 02/02/03 02/04/03 02/08/03 02/12/03 02/19/03 03/07/03 03/10/03 03/11/03 03/13/03 03/17/03 03/19/03 03/20/03 03/22/03 03/23/03 04/03/03 04/04/03 ) 2G-17 Event H ¡story ) Comment PERFORMED A FCO I MUD SWAP TO 14,642' CTMD. REVERSED OUT ON THE LAST RUN FROM TD TO SURFACE. UTILIZED 200 BBLS SLICK SEA WATER, 500 BBLS SLICK DIESEL, 100 BBLS 2# BIOZAN. REVERSED OUT TO SURFACE FROM 14642' CTMD. [FCO] DRIFTED TBG 2.735" & TAGGED @ 14657' RKB. UNABLE TO PASS 12847' RKB WI 22' X 2.6" HC DMY GUN, MUD IN TBG. PULLED SHEARED RP SOV @ 13737' RKB, POCKET OPEN. [TAG, GLV, PTTBG- CSG] PERFORATED 14280-14292 FT MD WITH 2.25" HSD @ 6 SPF (2306 POWERJETS). TIED INTO GR ON BAKER HUGHES RESISTIVITY/GR LOG DATED 24-JAN-03. LOGGED A JEWELRY PASS AND A MID- PERF STATION AT 14286 FT MD, 2489 PSI. DID NOT TAG TD. DID NOT HAVE TO PUMP TO GET TOOLS DOWNHOLE TO 14390 FT MD. SET 1.5" LIGHT DV @ 13,737' RKB, PT IIA TO 2500# [GLV, PTTBG-CSG, MIT] OBTAINED SBHP OF 3363 PSI & BHT OF 153 DEG @ 14,287' RKB, MADE GRADIENT STOP @ 13867' RKB. JOB COMPLETE! [PRESSURE DATA] TAG @ 14645' SLM.EST 353' OF RATHOLE.OBTAIN SAMPLE OF OILY FLUID & MUD. [TAG] PULLED 1-1/2" LIGHT DV @ 13,737' RKB AND INSTALLED 1-1/2" PETREDAT SPG, PT II A TO 3500# HELD, PULLED CATCHER @ 13,808' RKB [GLV, PT TBG-CSG] PUMPED FRACTURE TREATMENT USING 40# X-LINKED GEL @ 20 BPM WITH 16/20 CERAMIC PROPPANT. SCREENED OUT WITH A TOTAL OF 74,432 # OF PROPPANT PUMPED AND PLACED A TOTAL OF 45,228# OF PROPPANT BEHIND PIPE WITH 6 PPA AT PERFS. RECOVERED HALF THE TREESA VER RUBBER. CLEANED OUT TO TAG @ 14,630' CTM WI SEAWATER J313, 1-1/2# BIOZAN 3%KCL, AND SLICK DIESEL (EST. 300'+ OF RATHOLE) USING 1.75" SLIM BHA/JETSWIRL NOZZLE. RTNS 1:1 THROUGHOUT JOB. WELL SHUT IN AND FREEZE PRT'D TO 2500' WI DIESEL. [FCO] TAGGED FILL @ 14,195'RKB, MADED SEVERAL ATTEMPTS TO RUN 2.78" CATCHER SUB, UNABLE TO GET GET CATCHER PASSED 2552'WLM, UNABLE TO PUMP INTO WELL WITHOUT PRESSURING UP TUBING. [GLV] CLEANED OUT TO 14,620' CTMD WI SEAWATER WI J313 & 2# BIOZAN USING 1.75" JETSWIRL NOZZLE. RTNS 1:1 THROUGHOUT JOB. LOST COIL UNIT PUMP 2500' FROM SURFACE ON WAY OOH DUE TO PUMP HYDRAULIC FILTER SWIVELING OFF CASE. RIH TO CATCH SOLIDS; CALLED OUT HOT OIL PUMP TO FINISH JOB. TAG @ 14595' SLM, EST 303' OF RATHOLE. IN PROGRESS. [TAG] SET 2.75" CATCHER SUB @ 13805' RKB. REPLACED 1" DV @ 12809' RKB WI 1" X .1875" OV. IN PROGRESS. REPLACE DV'S @ 4081',7962', & 10742' RKB WI GLV'S PER DESIGN. IN PROGRESS. [GLV] CHANGED OUT PETREDAT SPG @ 13737' RKB. PULLED CATCHER. ***** NOTE: GAUGE RECORDS 5 SECOND SAMPLES FI 12:00 HRS. 3/24/03 UNTIL 2400 HRS. 4/2103. PBU MUST BE COMPLETED WITHIN THIS INTERVAL.***** [GLV, PRESSURE DATA] SET 2.78" CATCHER SUB @ 13,805' RKB, IN PROGRESS. [PRESSURE DATA] PULLED PETRADAT SPG & SET 1.5" DV @ 13,737' RKB, PULLED CATCHER @ 13,805' RKB. [PRESSURE DATA] Page 1 of 1 4/21/2003 ') ConocoPhillips Alaska, Inc. Pad 2G 17 slot #17 Kuparuk River Unit North Slope, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref Our ref License MWD <0-14768'> svy6826 Date printed Date created Last revised 6-Feb-2003 1-Jan-2003 20-Jan-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 15 25.530,w149 55 46.967 Slot location is n70 15 23.532,w149 55 39.026 Slot Grid coordinates are N 5943385.004, E 508969.928 Slot local coordinates are 203.15 S 272.97 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ) ConocoPhillips Alaska, Inc. Pad 2G,l7 Kuparuk River Unit,North 5lope, Alaska Measured Inclin Depth Degrees 0.00 192.00 295.00 380.00 470.00 562.00 653.00 743.00 835.00 925. 00 1015.00 1108.00 1202.00 1295.00 1387.00 1478.00 1571.00 1657.00 1720. 00 1762.00 1851.00 1945.00 2009.00 2101.00 2192.00 2290.00 2383.00 2477.00 2567.00 2662.00 2753.00 2846.00 2939.00 3032.00 3126.00 3218.00 3311.00 3405.00 3498.00 3592.00 3684.00 3777 . 00 3871 . 00 3962.00 4058.00 4147.00 4238.00 4330.00 4426.00 4518.00 2.51 6.75 9.06 11. 01 13.75 16.34 19.49 19.64 21.33 24.98 27.83 33.32 38.89 40.28 41. 25 42.34 47.53 54.37 59.21 65.16 68.30 67.40 68.07 72.97 70.70 68.86 69.82 71.42 71. 65 69.64 69.62 70.29 69.79 70.30 71.84 70.14 70.39 69.62 69.90 70.22 71.35 70.41 71.28 71.65 71. 01 Az imu th Degrees 0.00 0.47 0.18 0.61 0.84 0.00 311.34 285.65 88.75 122.53 True Vert Depth 0.00 192.00 295.00 379.99 469.99 561.95 652.63 741.77 832.36 920.26 1007.16 1095.64 1184.22 1271.34 1355.92 1437.41 1517.46 1586.92 1635.47 1667.28 1733.63 1800.15 1840.46 1890.83 1933.28 1971.99 2007.05 2042.67 2072 . ~8 2102.30 2133.75 2166.56 2197.42 2226.88 2258.03 2290.06 2321.93 2354.02 2385.76 2416.26 2446.23 2477.63 2509.78 2541.26 2574.00 2603.29 2633.10 2663.29 2693.81 2723.26 ) 5URVEY LI5TING Page 1 Your ref MWD <0-14768'> Last revised : 20-Jan-2003 R E C TAN G U L A R Dogleg Vert COO R DIN ATE 5 Deg/100ft 5ect O.OON 0.52N 0.84N 0.89N 0.54N 0.595 4.295 11.315 20.675 31.875 45.545 63.105 83.145 104.815 130.575 160.485 196.325 236.115 267.775 289.335 335.905 387.095 424.395 480.595 537.695 600.455 661.025 722.425 784.225 852.335 917.235 983.615 1051.135 1120.545 1190.975 1258.975 1328.275 1398.245 1466.335 1535.505 1604.485 1674.735 1744.075 1810.235 1880.405 1946.245 2014.665 2084.835 2158.415 2227.815 O.OOE 0.59W 1.06W 0.74W 0.29E 2.72E 9.04E 19.23E 32.24E 47.95E 66.89E 89.46E 113.73E 138.00E 163.37E 190.62E 221. 46E 252.79E 277.47E 294.41E 331.14E 373.38E 406.17E 458.73E 515.39E 579.92E 641.16E 702.79E 760.85E 820.08E 875.57E 931.84E 987.85E 1042.28E 1096.17E 1149.22E 1202.42E 1256.36E 1311 . 18E 1367.04E 1420.01E 1472.24E 1526.96E 1580.92E 1637.67E 1689.89E 1741.96E 1793.22E 1846.79E 1899.52E 0.00 0.24 0.31 0.92 0.53 0.00 -0.78 -1.32 -1.16 -0.24 G RID Easting 508969.93 508969.34 508968.86 508969.19 508970.22 508972.65 508978.97 508989.17 509002.19 509017.91 509036.87 509059.46 509083.75 509108.04 509133.43 509160.71 509191. 59 509222.96 509247.68 509264.64 509301.42 509343.72 509376.55 509429.17 509485.89 509550.48 509611.79 509673.48 509731.61 509790.91 509846.47 509902.81 509958.89 510013.40 510067.36 510120.49 510173.76 510227.78 510282.67 510338.61 510391.65 510443.96 510498.74 510552.78 510609.60 510661.90 510714.04 510765.37 510819.03 510871.83 COO R D 5 Northing 5943385.00 5943385.52 5943385.85 5943385.89 5943385.55 5943384.42 5943380.72 5943373.72 5943364.38 5943353.20 5943339.54 5943322.01 5943302.00 5943280.36 5943254.64 5943224.76 5943188.96 5943149.21 5943117.58 5943096.04 5943049.52 5942998.38 5942961.12 5942904.99 5942847.97 5942785.28 5942724.79 5942663.47 5942601.74 5942533.71 5942468.88 5942402.57 5942335.12 5942265.78 5942195.42 5942127.49 5942058.26 5941988.36 5941920.34 5941851.24 5941782.32 5941712.14 5941642.88 5941576.79 5941506.69 5941440.91 5941372.56 5941302.45 5941228.94 5941159.61 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #17 and TVD from Est RKB (D-14l) (131.20 Ft above mean sea level). Bottom hole distance is 12432.51 on azimuth 141.60 degrees from wellhead. Vertical section is from wellhead on azimuth 141.56 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 112.49 123.34 125.41 126.00 125.07 126.48 129.05 130.05 133.35 137.22 138.08 140.32 143.07 141.07 142.59 140.90 140.09 137.40 136.46 134.04 134.37 135.00 134.78 138.74 139.24 139.70 139.73 140.91 142.88 142.28 141.79 143.19 141 . 54 140.79 141.36 143.61 143.13 140.31 141.28 140.80 142.35 143.11 144.60 143.28 142.27 1. 84 4.74 2.59 2.12 3.05 2.16 8.98 20.81 36.24 54.77 2.91 3.49 0.39 2.20 4.30 77 .26 105.04 135.83 167.89 203.84 3.16 6.03 6.74 2.99 3.30 244.21 291.45 342.10 382.24 409.66 1. 76 5.55 11.17 5.33 6.95 468.97 535.32 584.93 661.62 741. 57 3.22 1.15 0.74 6.84 2.44 830.85 916.37 1002.77 1087.28 1177.45 2.08 1. 03 2.10 2.02 2.22 1262.78 1349.75 1437.46 1525.66 1614.33 0.50 1. 59 1. 73 0.94 1. 74 1700.57 1787.92 1876.27 1963.68 2052.59 2.96 0.56 2.94 1. 05 0.58 2139.55 2227.04 2315.37 2400.74 2490.98 2.08 1. 30 1. 80 1. 36 1.25 2575.02 2660.98 2747.81 2838.75 2925.88 ) ) ConocoPhillips Alaska, Inc. 5URVEY LI5TING Page 2 Pad 2G,17 Your ref MWD <0-14768'> Kuparuk River Unit,North 5lope, Alaska Last revised : 20-Jan-2003 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID C o 0 R D 5 Depth Degrees Degrees Depth COORD I N ATE 5 Deg/100ft 5ect Easting Northing 4611 . 00 70.68 139.87 2753.78 2296.155 1954.71E 2.46 3013.72 510927.10 5941091.34 4798.00 70.40 142.43 2816.08 2433.455 2065.31E 1.30 3190.02 511037.83 5940954.19 4890.00 69.54 141.46 2847.60 2501.515 2118.58E 1.36 3276.45 511091.19 5940886.19 4982.00 70.33 139.79 2879.16 2568.305 2173.40E 1. 91 3362.85 511146.08 5940819.47 5077 . 00 70.57 140.21 2910.95 2636.885 2230.95E 0.49 3452.34 511203.70 5940750.96 5169.00 69.84 139.89 2942.11 2703.245 2286.53E 0.86 3538.87 511259.35 5940684.67 5262.00 71. 37 136.62 2973.00 2768.675 2344.94E 3.70 3626.43 511317.82 5940619.32 5355.00 70.93 135.43 3003.05 2832.015 2406.04E 1.30 3714.03 511379.00 5940556.06 5448.00 71.27 137.21 3033.17 2895.645 2466.81E 1.85 3801.65 511439.83 5940492.50 5540.00 70.73 139.33 3063.13 2960.555 2524.70E 2.26 3888.49 511497.80 5940427.67 5633.00 70.11 138.81 3094.29 3026.755 2582.11E 0.85 3976.02 511555.27 5940361.54 5704.00 70.27 137.01 3118.36 3076.325 2626.88E 2.40 4042.68 511600.10 5940312.03 5848.00 70.89 138.52 3166.24 3176.875 2718.16E 1. 08 4178.19 511691.48 5940211.59 5941.00 71.40 141.40 3196.30 3244.245 2774.77E 2.98 4266.15 511748.16 5940144.29 6034.00 71.41 143.00 3225.96 3313.895 2828.79E 1. 63 4354.29 511802.26 5940074.72 6128.00 71.30 144.20 3256.01 3385.575 2881.64E 1.22 4443.30 511855.19 5940003.10 6219.00 71.28 14 6 . 53 3285.20 3456.485 2930.63E 2.43 4529.29 511904.25 5939932.25 6314.00 71.47 143.79 3315.55 3530.365 2982.05E 2.74 4619.13 511955.76 5939858.44 6404.00 71.38 145.91 3344.22 3600.115 3031.16E 2.24 4704.29 512004.94 5939788.75 6498.00 71.48 145.00 3374.16 3673.515 3081.69E 0.92 4793.19 512055.55 5939715.42 6592.00 71.44 145.88 3404.05 3746.905 3132.25E 0.89 4882.11 512106.19 5939642.10 6684.00 71.44 144.07 3433.33 3818.325 3182.30E 1. 87 4969.16 512156.32 5939570.74 6774.00 71.48 142.86 3461.95 3886.885 3233.10E 1.28 5054.44 512207.19 5939502.25 6869.00 71. 44 141.00 3492.16 3957.785 3288.63E 1. 86 5144.51 512262.80 5939431.42 6967.00 71.44 141.38 3523.35 4030.175 3346.86E 0.37 5237.41 512321.10 5939359.10 7058.00 71.35 142.52 3552.39 4098.095 3400.01E 1.19 5323.65 512374.33 5939291.25 7149.00 71.35 141. 74 3581.49 4166.155 3452.94E 0.81 5409.86 512427.33 5939223.26 7242.00 71.22 141.94 3611.33 4235.415 3507.37E 0.25 5497.94 512481.83 5939154.07 7335.00 71.30 141.91 3641.21 4304.74S 3561.68E 0.09 5586.01 512536.22 5939084.81 7427.00 71.28 142.63 3670.72 4373.665 3615.00E 0.74 5673.14 512589.61 5939015.96 7521.00 71.37 141.97 3700.82 4444.115 3669.46E 0.67 5762.19 512644.15 5938945.57 7614.00 71.28 142.21 3730.60 4513.635 3723.59E 0.26 5850.29 512698.36 5938876.13 7708.00 71.41 140.48 3760.67 4583.175 3779.22E 1.75 5939.34 512754.06 5938806.66 7800.00 71.37 140.46 3790.03 4650.425 3834.71E 0.05 6026.52 512809.62 5938739.48 7893.00 71.50 141.88 3819.64 4719.105 3889.99E 1.45 6114.67 512864.97 5938670.87 7986.00 71.35 143.73 3849.26 4789.325 3943.28E 1.89 6202.80 512918.34 5938600.72 8079.00 71.47 144.20 3878.91 4860.605 3995.13E 0.50 6290.87 512970.27 5938529.51 8171.00 71. 44 143. 60 3908.17 4931.075 4046.53E 0.62 6378.02 513021.74 5938459.10 8265.00 71.34 144.21 3938.17 5003.065 4099.01E 0.62 6467.03 513074.30 5938387.18 8358.00 71.37 143.79 3967.90 5074.345 4150.80E 0.43 6555.07 513126.17 5938315.96 8450.00 71.31 144.79 3997.34 5145.125 4201.68E 1.03 6642.13 513177.12 5938245.25 8542.00 71.31 146.25 4026.82 5216.965 4251.01E 1.50 6729.07 513226.54 5938173.48 8632.00 71.41 145. 91 4055.59 5287.725 4298.60E 0.37 6814.08 513274.20 5938102.78 8729.00 71.27 145.56 4086.62 5363.675 4350.34E 0.37 6905.74 513326.03 5938026.89 8822.00 71.28 145.06 4116.48 5436.095 4400.47E 0.51 6993.63 513376.23 5937954.54 8914.00 71.54 144.58 4145.81 5507.375 4450.71E 0.57 7080.69 513426.55 5937883.33 9007.00 71.31 145.21 4175.43 5579.485 4501.41E 0.69 7168.69 513477.32 5937811.28 9101.00 71.31 144.80 4205.56 5652.435 4552.47E 0.41 7257.57 513528.47 5937738.40 9192.00 71.31 144.50 4234.72 5722.745 4602.35E 0.31 7343.65 513578.42 5937668.16 9285.00 71.38 143.87 4264.46 5794.195 4653.91E 0.65 7431.67 513630.06 5937596.77 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #17 and TVD from Est RKB (D-l41) (131.20 Ft above mean sea level) . Bottom hole distance is 12432.51 on azimuth 141.60 degrees from wellhead. Vertical section is from wellhead on azimuth 141.56 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) ) ConocoPhillips Alaska, Inc. 5URVEY LI5TING Page 3 Pad 2G, 17 Your ref MWD <0-14768'> Kuparuk River Unit,North 5lope, Alaska Last revised : 20-Jan-2003 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COO R D 5 Depth Degrees Degrees Depth COO R D I N ATE 5 Deg/100ft 5ect Easting Northing 9379.00 71.41 142.87 4294.45 5865.685 4707.06E 1. 01 7520.71 513683.29 5937525.35 9472.00 71. 25 142.50 4324.23 5935.755 4760.47E 0.41 7608.80 513736.77 5937455.34 9564.00 71. 31 142.92 4353.75 6005.075 4813.26E 0.44 7695.91 513789.64 5937386.09 9655.00 71.41 142.29 4382.84 6073.585 4865.63E 0.67 7782.13 513842.08 5937317.65 9749.00 71.41 141.81 4412.80 6143.835 4920.42E 0.48 7871.22 513896.94 5937247.47 9842.00 71.31 141.83 4442.53 6213.105 4974.89E 0.11 7959.34 513951.49 5937178.27 9935.00 71.31 141.38 4472.33 6282.155 5029.60E 0.46 8047.43 514006.28 5937109.29 10034.00 71.50 140.64 4503.90 6355.085 5088.64E 0.73 8141. 26 514065.39 5937036.44 10127.00 71.21 141.26 4533.63 6423.515 5144.15E 0.70 8229.37 514120.98 5936968.08 10218.00 71.37 141.45 4562.82 6490.835 5197.98E 0.26 8315.56 514174.88 5936900.83 10312.00 71.34 141.31 4592.88 6560.425 5253.57E 0.14 8404.63 514230.55 5936831.31 10404.00 71.12 142.54 4622.48 6628.995 5307.29E 1.29 8491.73 514284.34 5936762.81 10498.00 71.44 143.13 4652.65 6699.935 5361.07E 0.69 8580.74 514338.19 5936691.94 10592.00 71.41 144.47 4682.59 6771.835 5413.69E 1. 35 8669.77 514390.90 5936620.10 10684.00 71.34 145.05 4711.98 6843.045 5464.00E 0.60 8756.82 514441.28 5936548.96 10777 . 00 71.41 143.75 4741.68 6914.695 5515.30E 1. 33 8844.83 514492.66 5936477.37 10870.00 71. 44 143.96 4771.30 6985.885 5567.30E 0.22 8932.92 514544.73 5936406.25 10962.00 71. 28 145.04 4800.71 7056.855 5617.92E 1.13 9019.98 514595.43 5936335.35 11056.00 71. 41 143.62 4830.78 7129.205 5669.85E 1.44 9108.93 514647.44 5936263.07 11149.00 71.18 143.92 4860.60 7200.265 5721.91E 0.39 9196.95 514699.58 5936192.08 11238.00 71.35 146.21 4889.19 7269.355 5770.17E 2.44 9281.07 514747.91 5936123.05 11332.00 71.47 142.59 4919.17 7341. 785 5822.03E 3.65 9370.04 514799.85 5936050.69 11428.00 71.48 142.28 4949.67 7413.935 5877.52E 0.31 9461.05 514855.42 5935978.61 11518.00 71.35 141.71 4978.35 7481.155 5930.05E 0.62 9546.36 514908.02 5935911.46 11611.00 71.48 142.03 5007.99 7550.495 5984.48E 0.35 9634.51 514962.52 5935842.19 11706.00 71.32 140.04 5038.30 7620.495 6041.09E 1. 99 9724 .54 515019.21 5935772.26 11799.00 71. 38 140.46 5068.04 7688.245 6097.44E 0.43 9812.63 515075.63 5935704.58 11889.00 71. 35 140.53 5096.80 7754.045 6151.69E 0.08 9897.90 515129.95 5935638.85 11984.00 71.34 140.66 5127.18 7823.595 6208.83E 0.13 9987.89 515187.16 5935569.37 12078.00 71.35 140.94 5157.25 7892.605 6265.12E 0.28 10076.95 515243.53 5935500.43 12170.00 71.44 139.25 5186.61 7959.495 6321.05E 1. 74 10164.11 515299.53 5935433.62 12263.00 71.51 139.54 5216.15 8026.435 6378.44E 0.31 10252.22 515356.99 5935366.74 12357.00 71.31 139.66 5246.12 8094.285 6436.18E 0.24 10341.27 515414.81 5935298.97 12449.00 71.32 140.76 5275.59 8161.255 6491. 96E 1.13 10428.39 515470.66 5935232.07 12543.00 71.41 139.82 5305.63 8229.775 6548.87E 0.95 10517.44 515527.64 5935163.62 12633.00 71.34 140.00 5334.38 8295.025 6603.79E 0.20 10602.69 515582.63 5935098.45 12725.00 71.41 140.71 5363.76 8362.155 6659.41E 0.74 10689.86 515638.33 5935031.39 12819.00 71.64 139.49 5393.55 8430.545 6716.60E 1.26 10778.98 515695.59 5934963.06 12911 . 00 70.82 139.01 5423.15 8496.535 6773.46E 1.02 10866.02 515752.52 5934897.15 13006.00 69.02 139.97 5455.77 8564.365 6831.42E 2.12 10955.18 515810.55 5934829.39 13099.00 67.27 140.19 5490.38 8630.565 6886.81E 1. 89 11041.46 515866.01 5934763.26 13192.00 65.30 140.53 5527.79 8696.125 6941.13E 2.14 11126.59 515920.40 5934697.77 13284.00 63.07 139.70 5567.85 8759.675 6994.23E 2.56 11209.37 515973.56 5934634.29 13377 . 00 60.46 140.45 5611 . 84 8822.495 7046.81E 2.89 11291.27 516026.22 5934571.53 13470.00 58.67 139.94 5658.95 8884.095 7098.14E 1. 98 11371.43 516077.61 5934510.00 13564.00 57.11 139.45 5708.91 8944.815 7149.64E 1.72 11451.01 516129.17 5934449.34 13655.00 55.36 141.13 5759.49 9003.005 7197.97E 2.46 11526.63 516177.57 5934391.22 13748.00 54.94 142.52 5812.63 9062.995 7245.15E 1. 31 11602.95 516224.81 5934331.29 13841.00 55.07 142. 99 5865.97 9123.645 7291.25E 0.44 11679.12 516270.98 5934270.70 13931.00 54.98 143.80 5917.56 9182.845 7335.23E 0.74 11752.82 516315.02 5934211 .56 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #17 and TVD from Est RKB (D-141 ) (131.20 Ft above mean sea level) . Bottom hole distance is 12432.51 on azimuth 141.60 degrees from wellhead. Vertical section is from wellhead on azimuth 141.56 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) ) ConocoPhillips Alaska, Inc. SURVEY LISTING Page 4 Pad 2G,17 Your ref MWD <0-14768'> Kuparuk River Unit,North Slope, Alaska Last revised 20-Jan-2003 Measured Inclin Azimuth True Vert R E C TAN GULAR Dogleg Vert G RID COO R D S Depth Degrees Degrees Depth COO RDINATES Deg/l00ft Sect Easting Northing 13999.00 54.90 144.62 5956.62 9227.99S 7367.78E 0.99 11808.42 516347.62 5934166.45 14063.00 55.51 144.48 5993.14 9270.80S 7398.26E 0.97 11860.91 516378.15 5934123.67 14116.00 55.45 143.88 6023.18 9306.21S 7423.82E 0.94 11904.53 516403.74 5934088.30 14158.00 55.41 143.40 6047.01 9334.06S 7444.32E 0.95 11939.09 516424.28 5934060.47 14248.00 55.46 144.94 6098.07 9394.15S 7487.70E 1.41 12013.12 516467.73 5934000.45 14343.00 55.64 144.05 6151.81 9457.92S 7533.20E 0.80 12091.36 516513.29 5933936.73 14438.00 54.79 148.17 6206.03 9522.66S 7576.70E 3.67 12169.11 516556.86 5933872.05 14529.00 54.13 145.45 6258.93 9584.62S 7617.23E 2.54 12242.83 516597.45 5933810.15 14623.00 52.97 145.54 6314.78 9646.92S 7660.06E 1.24 12318.26 516640.35 5933747.89 14686.00 52.15 147.42 6353.08 9688.62S 7687.68E 2.70 12368.10 516668.02 5933706.23 14768.00 52.15 147.42 6403.39 9743.18S 7722.55E 0.00 12432.51 516702.95 5933651.72 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #17 and TVD from Est RKB (D-141) (131.20 Ft above mean sea level). Bottom hole distance is 12432.51 on azimuth 141.60 degrees from wellhead. Vertical section is from wellhead on azimuth 141.56 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ConocoPhillips Alaska, Inc. Pad 2G,17 Kuparuk River Unit, North Slope, Alaska Comments in wellpath -------------- ------- - Me Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- TVD ) SURVEY LISTING Page 5 Your ref MHD <0-14768'> Last revised : 20-Jan-2003 14768.00 6403.39 9743.18S 7722.55E Projected Data - NO SURVEY Casing positions in string 'A' ------------------- - -- Top Me Top TVD Rectangular Coords. Bot Me Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00 3135.82 6403.39 5972.67 ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 O.OON O.OON O.OON O.OOE 5756.00 O.OOE 14768.00 O.OOE 14027.00 3112.30S 9743.18S 9246.69S Target name T.V.D. Targets associated with this well path Rectangular Coordinates Revised ------------------- -- ------------ Geographic Location 2660.11E 7722.55E 7381.08E 9 5/8" Casing 3 1/2" LINER 7" Casing 2G-17 C4 TGT RVSD 7N 516473.000,5933956.000,0.0000 2G-17 Hardline Pt#2 516773.000,5934036.000,0.0000 2G-17 Hardline Pt#l 516173.000,5934036.000,0.0000 6151.20 6151.20 6151.20 ----------------------------------------------------------------------------------------------------------- 9438.60S 9358.94S 9358.25S 7492.93E 7793.05E 7192.99E 30-Sep-2002 19-Nov-2002 19-Nov-2002 Schlumbepgep Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Well 1 B-11 2B-10 2G-17 3N-18 3S-07 3S-14 3S-26 3S-14 ~ a Od-a 10 Job# Log Description Date I ~ J.. J?1ft, LDL J~-O~GJ STATIC BHP SURVEY I~(),~-ac. ~ PERF RECORD & SBHP J~/n" r:A.~ STATIC BHP SURVEY ~- I 'XÎ PRODUCTION PROFILE ~rH-dJO CROSSFLOW DETERMINATION LOG aOJ-oLJ 0 PRODUCTION PROFILE ,:¿ 3 ò&';( SCMT 01/26/03 01/30/03 02104/03 01/28/03 02102103 02101/03 01/24/03 01/31/03 Sl~ U OOQr) DATE: 02/12/03 NO. 2655 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Sepia Color CD 1 1 1 1 1 1 1 1 r~ RECEIVED Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. FEB 1 4 2003 AIaIka Oil & Gas Cons. CommiaIion AnchonIge Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 2G-17 II Contains the following: p 111 LDWG Compact Disc I ¡ (Includes Graphic Image files) , I LDWG lister summary ¡ ,I II II II I' II Ii Ii !i LAC Job#: 407610 IL- -----~-~- -- Received - W1°f~ Q)Dd-dcJ3 115?;'.t¡ r&l. II~;;~~;~~~~;¡;~- BAKER · ;"',' :__r"Ol! OWIIIIm ..~ _,ft n...:.. HUGHES Anchorage GEOScience Center :~~-~:;¡~.-~~-_:~----~: Ii Ii I: II I, II II '! I ,I ! J Ii Ii Ii ,I I' ______________J Date: Feb 10, 2003 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 1 blueline - MPR Measured Depth Log 1 blueline - MPR TVD Log 1 blueline - Density/Neutron Measured Depth Log 1 blueline - Density/Neutron TVD Log Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 RECEIVED fEB 1 2 2003 AlaIka on & Gel Cons. CommiIIion Anchcnge .. ,..'...."..., .............- -...:- i----ª~-,~------ :þ¡Q)''fI: ,'-In .'11II,.( ,<0,......' ""_"0' .. ~--------,~:::_,-_:__:= ¡."1"'··'" ~....,.u ._ ..~ ..,_.. -, .... :_.,~ -- ~ -,,- - -' Typo on 2G-17 Permit ) ?Nl-"""2.43 ) Subject: Typo on 2G-17 Permit Date: Tue, 14Jan 2003 13:28:29 -0900 From: "Shane D Cloninger" <Shane.Cloninger@conocophillips.com> To: winton_aubert@admin.state.ak.us Winton, As we discussed on the phone yesterday, the typos on the 28-17 permit are as follows: The 7" casing weight listed on the permit is 29 lb/ft, but we will actually be running 26 lb/ft. The hole size through the Kuparuk listed on the permit is 6-3/4", but we will actually be drilling out a 6-1/8" hole. If you have any questions, or need additional information, please call. Thanks, Shane D Cloninger ConocoPhillips Alaska Inc. (907) 265-6829 OFFICE (907) 240-5654 CELL ATO-1578 ~T!Æ~E ~ ) f !Æ~!Æ~~~!Æ ) ~ FRANK H. MURKOWSKI, GOVERNOR AI/A~KA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7fH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Unit 20-17 ConocoPhillips (Alaska), Inc. Permit No: 202-243 Surface Location: 203' FNL, 272' FWL, Sec. 5, T10N,R9E, UM Bottomhole Location: 581 ' FSL, 2570' FEL, Sec. 9, Tl ON, R9E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and· approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms. and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~- ~-/ ¿;z- ~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this 13 ~ day of December, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ) \lJl;A-· i 2-/1 3/" L- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ) PERMIT TO DRILL 20 AAC 25.005 1b. Type of well. Exploratory U Stratigraphic Test Service 0 Development Gas 0 Single Zone 5. Datum elevation (DF or KB) 131' AMSL 1 a. Type of work: Drill ~ Redrill U Re-entry DDeepen 0 2. Name of Operator ConocoPhillips Alaska, 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 203' FNL, 272' FWL, Sec. 5, T10N, R9E, UM At top of productive interval 913' FSL, 2452' FWL, Sec. 9, T10N, R9E, UM At total depth 581' FSL, 2570' FEL, Sec. 9, T10N, R9E, UM 12. Distance to nearest property line 13. Distance to nearest well / 581' @ TO feet 2G-10 @ 21' @ 350' 16. To be completed for deviated wells Kickoff depth: 300 MD 18. Casing program size Maximum hole angle 70.76° Hole Casing Weight 42" 16" 62.5# 12.25" 9.625" 40# 8.5" 7" 29# 6.75" 3.5" 9.3# Specifications Grade Coupling H-40 Weld L-80 BTC L-80 BTCM L-80 BTC Length 80' 5632' 13928' 860' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Effective Depth: measured true vertical feet feet Casing Conductor Surface Intermediate Length Size Cemented Perforation depth: measured true vertical U o Development Oil ~ Multiple Zone 0 10. Field and Pool Kuparuk River Field / Kuparuk Oil Pool 6. Property Designation ADL 25666 ALK 2587 7. Unit or property Name Kuparuk River Unit 8. Well number 2G-17 / 11. Type Bond (see 20 AAC 25.0251) Statewide Number #59-52-180 feet 9. Approximate spud date Amount December 26, 2002 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 14769' MD 1 6446' TVD 17. Anticipated pressur:;See 20 AAC 25.035 (e)(2)) Maximum surface 3359 psig At total depth (TVD) 4000 psig Setting Depth Top Bottom Quantity of Cement MD TVD MD TVD (include stage data) 28' 28' 108' 108' Pre-Installed 28' 28' 5763' 3101' 530 sx AS Lite & 580 sx LiteCrete .,/ 28' 28' 14059' 6039' 170 sx Class G 13909' 5953' 14769' 6446' 230 sx GasBlok w/Class G ./' Plugs (measured) Junk (measured) Measured depth True Vertical depth RECEIVED DEC 1 2 2002 Maska Oil & Gas Cons. Commissiofl , Anchorage 20. Attachments Filing fee [2] Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program [2] Drilling fluid program [2] Time vs depth plot Qefraction analysis 0 Seabed report 020 AAC 25.050 requirements [2] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Pat Heilly 265-6048 ~\ _' \ - l'2 (l¿.( 0<: Signed \ ~~ \ 'vC.~ Title: Kuparuk Team Leader Date Randy Thomas \. PrAnArArl hv 8hAmn AII~I m-nrAkp. Commission Use Only Perm~umber ~ . I API number 1 ') I Approval date. n\\1. 0,' Isee cover letter "-0 2- -. .L- If "3 50- (j 2-9' - 2..:1 /.:5 'i \ (t\ ~) I 1\ for other reguirements Conditions of approval Samples required 0 Yes ~ No Mud log required U Yes .Qg No Hydrogen sulfide measures ~ Yes 0 No Directional survey required ~ Yes 0 No Required working pressure for BOPE D2M; 0 3M; 0 5M; 0 10M; 0 0 Other: Tis t "'goPE f-e> ç ~'J C L'? r sl . Approved by ORIGINAL SIGNED BY M l. Dill Form 10-401 Rev. 12/1/85· Commissioner by order of the commission Date 1 ~ \ô (;';;l I I ,,I \J j i M ~, ~ J.J i -... Submit in triplicate ) Apn;ytion for Permit to Drill, We1l2G-17 Saved: 11-Dec-02 Permit It - Kuparuk 2G-17 Application for Permit to Drill Document MaximizE Well "IglUI; Table of Contents 1. Well Name.... ......... ....................... ..... ... .... ..... ............. ..... ....... ...... ........ ...... ...... ..... .... 3 Requirements of 20 AAC 25.005 (f).................... .................................................................................... 3 2. Location Sum mary ......................... ...... ...... ... .......... ........... ... ....... ..... ......... ... ...... ..... 3 Requirements of 20 AAC 25.005(c)(2) .. ....................... .............. .......... ..... ...... ............ ............ ........ ....... 3 Requirements of 20 AAC 25. 050(b)........... .......................................... ....... ..... ...... .......................... ....... 3 3. Blowout Prevention Equipment Information ......................................................... 4 Requirements of 20 AAC 25. 005(c)(3) ............. ....... ............................................................................... 4 4. Dri II i ng Hazards Information......... .......... ............... ... ..... ... ............... ......... .... .... ...... 4 Requirements of 20 AAC 25.005 (c)( 4) ...... ................................................ ................ ............................4 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................... .............................................................................. 4 6. Casi ng and Cementi ng Prog ram. ........................ ..... ... ...... ... ........ ..... ........ .... ... ....... 5 Requirements of 20 AAC 25.005(c)(6) ........ ....................... ................................ ..................... ...............5 7. Diverter System Information. .... ... ....... ....... ...... .... ...... .... ..... ....... ......... ..... ....... ........ 5 Requirements of 20 AAC 25.005(c)(7) .................................................................... ............................... 5 8. Drill i ng FI uid Program ..... ............ ......... ............. ....... ..... .......... ..... ............ ........ ... .... 6 Requirements of 20 AAC 25.005(c)(B) ............ ........... .................... .............. .................... ...................... 6 9. Abnormally Pressured Formation Information ...................................................... 7 Requirements of 20 AAC 25.005 (c)(9) .................................................................. ....... ................... ...... 7 1 o. Se ism i c An a I ys is...................................................................................................... 7 Requirements of 20 AAC 25.005 (c)(10) ...... ..................... .............. ............. ........ ......... ................... ...... 7 11. Seabed Condition Analysis ..................................................................................... 7 Requirements of 20 AAC 25.005 (c)(11) ........... ............................................. ........................................ 7 12. Evidence of Bond i ng ..... .............. ..... ... .... ... ...... ... ...... ........ .... ...... ........ ............. ... .... 8 Requirements of 20 AAC 25.005 (c)(12) ........................................................... ..................................... B JìHJi',J¡4~ 2G-17 PERMIT IT 121002.doc Page 1 of 9 Printed: 11-Dec-02 ) Apn1i)ation for Permit to Drill, We1l2G-17 Saved: 11-Dec-02 13. Proposed Dri Iii ng Program . ..................... ... ... ...... ... ... ........... .... ............ ....... .... ... .... 8 Requirements of 20 AAC 25.005 (c)(13) .... ........................... ........... ................................................. ..... 8 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 9 Requirements of 20 AAC 25.005 (c)(14) ..... ................ .......... ........ .................... .......... ...... .......... ...... ..... 9 15. A tta c h m e nts ............................................................................................................. 9 Attachment 1 AOGCC Form 10-401 (Front of permit package) ............................................................ 9 Attachment 2 Directional Plan............................................................................................................... 9 Attachment 3 Drilling Hazards Summary..................... .......... ....... ..................................... .................... 9 Attachment 4 Well Schematic.... ...... ...................... ......... ...... ........ ...... .................... ........... ....... ........ ..... 9 Attachment 5 Cement Details ................................................. .......... ........................................ ............. 9 2G-17 PERMIT IT 121 002. doc Page 2 of 9 : i I G I IV A ~ Printed: 11-Doo-02 ') Apr>li1ation for Permit to Drill, We1l2G-17 , Saved: 11-Dec-02 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number as.t;igned by the t.:vmmlssion uoder 20 MC 25~040(b), For a well with multiple well branches~ each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to tfle well by the commission. The well for which this Application is submitted will be designated as 2G-17. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for c1 Permit to Drill must be aŒompanied by ec1ch of the following /tem.5¡ except for an item c1lready 017 file with the t.:vmmis.t;ion and identified in the application: (.7) a plat identifying the property and the property~ owners and showing (A)the coordinates of the proposed location of the well at the surface¡ at the top of eaä7 objective formation/ and at total depth referenced to govemmental section lines, (B) the cvordli7ates of the proposed location ot" the well at the ::J1Jrf¿¡ce/ referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmo:;,-pheric Administration' (C) the proposed depth of the well at the top of each of?jective formation and at total depth/ Location at Surface NGS Coordinates Northings: 5943385.10 203' FNL, 272' FWL, See 5, Tl0N, R9E, UM RKB Elevation: 131.2 ft AMSL Eastings: 508969.90 Pad Elevation: 104.2ft AMSL Location at Top of Productive Interval (Bermuda Formation) NGS Coordinates Northings: 5933956.00 Eastings: 516473.00 913' FSL, 2452' FWL, See 9, Tl0N, R9E, UM Measured Depth (RKB feet): True Vertical Depth (55 feet): True Vertical Depth (RKB feet): 14255' 6020' 6151 ' Location at Total Depth NGS Coordinates Northings: 5933624.76 581' FSL, 2570' FEL, See 9, Tl0N, R9E, UM Measured Depth (RKB feet): 14769' Eastings: 516732.62 True Vertical Depth (55 feet): 6315' True Vertical Depth (RKB feet): 6446' and (D) other /ì7formation required by 20 AAC 2.'i.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Dr/II (Form 10-401) must (1) inäude a plat drawn to a sUItable 5'Cale¡ showing the path of the proposed wellbore¡ inäuding a/I adjacent wellbores within 200 feet of any pOltion of the propos-ed we/I,' Please see Attachment 2: Directional Plan and (2) for a/I wells w/thti7 200 feet of the proposed wel/bore (A) list the names of the operators of those well~ to the extent that those names are known or discoverable /ì7 public record~ and show that each named operator has been furnished a copy of the application by certified mail,' or (B) state tlJat tl7e applicant is the only affected owner. The Applicant is the only affected owner. --- IJ r (, ", 1 ~L.~ ~r . ,~ t ~. ." "11¡ ~d9\111'·".~ 2G-17 PERMIT IT 121002.doc Page 3 of 9 Printed: 11-Dec-02 ') Apl""t)ation for Permit to Drill, We1l2G-17 . Saved: 11-Dec-02 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Pelmìt to 01111 must be accompanied by each of tl1e following Item.'i¡ except for an Item already on file with the commission and identified in the application: (3) a diagram and descniJtion of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035; 20 AAC 25.036, or 20 AAC 25031, ,..15 applicable; ¡ Please refer to Doyon Rig 141 BOP Schematic currently on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Pel717ìt to Drill must be accompanied by each at the following Items¡ except for an item already on file with the commission and identified in the applicatìon: (4) infòrmation on drilll/7g hazardS¡ inc/udìng (A) the maxìmum downhole pressure that may be encollnterect crJteria used to determlÌ7e it and maximum potential SlIrk1ce pressure based on a methane gradient~· The eXPl'é..1Jreservoir pressures in the Kuparuk sands in the 2G-17 area vary from 0.52 to 0.6~ pSi/ft, or 10,0 to 2'1,"ppg EMW (equivalent mud weight). These are pressures obtained from analysis of surroun' 9 bottom hole pressures. MPSP Based on Formation Pressure The maximum potential surface pressure (MPSP) based on the the above maximum pressure gradient, a methane gradient (0.11) and the vertical depth of the expected Kuparuk A6 sand is 3359 psi, calculated as follows: MPSP =(6221 ft)(0.6~ - 0.11 psi/ft) =3359 psi / MPSP Based on LOT Results Assuming a leak off of 13.8 - 14.4 ppg (0.72 - 0.75 psi/ft) based on open hole intermediate casing LOT results from offset 2F wells, formation breakdown at the intermediate casing shoe (6038' TVD) can be expected to occur between 4347 and 4528 psi. Therefore, the MPSP may be based on the formation pressure calculation of 3359 psi. (B) data on potential gas zones/' While drilling 2G-05 at 3397 TVD with 9.1 ppg mud, took 42 bbl gain. Circulated on choke (gas to surface) and increased mud weight to 10.0 ppg. and (C) data concerning potential causes of 110le problems such as abnormally geo-pressured strata, lost circulation zones¡ and zones that have a propensity for differential sticking; Please see Attachment 3: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a PermIt to Dnll must be accompanied by each of tl7e following Items, except for a/7 Item already 0/7 file with the commission and Identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 MC 25030(f)/' A formation integrity test will be performed after drilling out below surface in accordance with the Phillips Alaska LOT / FIT procedure, currently on file with the Commission. OR~~,~g"ø~ :~¡ l :. ,\ ;1;\ J J '1 ¡ l:~ i ¡ V þ- _ 2G-17 PERMIT IT 121002.doc Page 4 of 9 Printed: 11-Dec-02 ) Apl"',õ)ation for Permit to Drill, Well 2G-17 -' Saved: 11-Dec-02 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application lor a PermIt to Drill must be accompanied by each of the fbllowing Items, except for £1/7 item already on file with the commi.<isiol7 and identified in the applicatìon: (6) a complete proposed casìng and cementli7g program as required by 20 AAC 25.030, and a descriptio/7 of any !:J1otted liner, pre- peñvrated liner, or screen to be fi7stalled; Casing and CementinCl PrOClram Hole ./ / Top Btm CsglTbg Size Weight Length MD/TVD MD/TVD 00 (in) (in) (/blft) Grade Connection (ft) (ft) (ft) Cement Program 30 X 16 42 62.5 H-40 Welded 80 30 / 30 110/ 110 9 cy High Insulated ~IY 9-5/8 12-1/4 40.0 L-80 BTC,AB 5733 30 / 30 5763/ 3101 ø 10.7 Modified . "AS3 Lead, 580 sx 12.0 ppg LiteCrete Tail Planned Top of Cement: Surface 7 8-1/2 26.0 L-80 BTC,AB 14029 30 / 30 14059 / 6039 170 sx 15.8 Modified ppg Class 'G' Planned Top of Cement: 13259' MD 3-1/2 6-1/8 9.3 L-80 SLHT 860 13909 / 5952 14769/6446 230 sx 15.8 ppg Class 'G' Planned Top of Cement: 13709' MD Circulated out to 13909' MD (Liner Top) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Penmt to Drill must be accompanied by each of the following Items, except for £1/7 Item already 0/7 file with the (.'vmmission and identified in the application: (1) a dI~7gram and description of the diverter system as required by 20 AAC 25. 03~ unless this requirement is waived by tile commission under 20 AAC 25.035(h)(2),· Please refer Doyon Rig 141 Diverter Schematic currently on file with the Commission. JR; r /"1 i~:~ JI ~,t '. "oJ' ,., if !~ I j I ~~i . S ':~: l'\: Írœ 2G-17 PERMIT IT 121 002. doc Page 5 of 9 Printed: 11-Dec-02 ) Ar"'li)ation for Permit to Drill, Well 2G-17 . Saved: 11-Dec-02 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Olill must be accvmpanled by each of the fvllowing item~~ except fvr an item already on file with tile commission and Identified In the application: (8) a drilling flUId program¡- Including a diagram and descliptlon of the dn//íng fluid system¡- as required by 20 MC 25. 033; Water based drilling fluid systems will be utilized to drill this well from spud to TD. These systems will be built and maintained to the following specifications: Surface (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Total Depth Initial Value Final Value Initial Value Final Value Density (ppg) 8.5 <9.4 /" <9.4* <9.4* Funnel Viscosity 120-150 120-150 120 65-75 (seconds) Yield Point 30-60 30-60 20-40 18-30 (cP) Plastic Viscostiy 8-15 11- 22 15-30 15-30 (lb1100 sf) 10 second Gel 10-30 10-25 10-25 10-25 Strength (lb1100 sf) 10 minute Gel 25-55 25-55 20-40 20-40 Strength (lb1100 sf) pH 8-9 8-9 8-9 8-9 API Filtrate(cc) 8-15 <10 <10 <10 Solids (%) 5-8 5-8 5-8 6-11 *9.8 ppg if hydrates are encountered Intermediate (LSND) Initial Value Final Value Density (ppg) 9.1 10.6 ./ Funnel Viscosity 40-55 40-55 (seconds) Yield Point 5-8 18- 26 (cP) Plastic Viscostiy 6-13 14- 25 (lb1100 sf) 10 second gel 3-7 4-7 10 minute gel 6-13 6-14 pH 9-10 9-10 API filtrate <10 <6 HTHP filtrate NC <10 Solids % 4-10 6-12 2G-17 PERMIT IT 121 002. doc Page 6 of 9 O /ï"""'..' .''1 .,,~C.ì .4 ..~!.. .~ . .~... L Printed: 11-Dec-02 .:' }: jI' , 1 ¡ M Il1 ; .iiJ i'"'" ) ApI"j,ation for Permit to Drill, We1l2G-17 . Saved: 11-Dec-02 Production Interval LSND fluid from previous section Initial Value Final Value I¡J.~ Density (ppg) 10.5 .1:0';-5" i l· -¡ ,-- Funnel Viscosity 44-59 44-59 (seconds) Yield Point 18-26 18-26 (cP) Plastic Viscostiy 10-21 10-21 (lb1100 sf) 10 second gel 4-7 4-7 10 minute gel 6-14 6-14 pH 9-10 9-10 API filtrate <6 <6 HTHP filtrate <10 <10 Solids % 5-11 5-11 Please refer to Doyon Rig 141 Fluid System Components currently on file with the Commission. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An applicatio/7 for a Permit to Dlill must be acc:vmpanied by each of the following item~ except for an ib'?m already on file with the commission and Identifïed in the application: (9) for an exploratory or stratigraphic test we/~ a tabulation !:>""etting out the depths of predicted abnormally geo-pre'!:''''Sured strata as required by 20 AAC 2.'i.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An applk<''7tion for a Permit to Drill must be accompanied by each of the fallowing item~ except far an item already on file wIth the commission m7d Idenbfïed in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a PermIt to Dnll must be accompanied by each of the following item~ except for an item already on file wIth the commission and Identified in the application: (11) for a well dnlled from an offshore platfonn, mobile bottom-founded stmcture{ jack-up rif}¡ or floating dnlling vessel, a/7 analysis of seabed conditions as required by 20 MC 25.061(b); Not applicable: Application is not for an offshore well. 2G-17 PERMIT IT 121002.doc Page 7 of 9 J R' .~ ," I~ .' .' ..1\.. L Printed: 11-0ec-02 11>/' ij ,/ "i1 ~';' I'; f.J ~ ~ ~ "'j ~ p, ,/.,.-. , ! , ~"II .n ~ '}!i I, ~.j~ ) Ar""i)ation for Permit to Drill, We1l2G-17 Saved: 11-Dec-02 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a PermIt to Drill must be accompanied by ead7 of the following item.'ir except for an item already on file with the commi'ision and identified in the application: (12) evidence showing that the requirement'i of 20 AAC 25:025 {Bonding}have been me~' Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An applkotian lor a Pem7lt to Drill must be accompanied by each al the following Iterns~ except for an item already on flle with the commis'Sion and identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 4: Well Schematic: 1. Excavate cellar, install cellar box, set and cement 16" x 30" insulated conductor to +/- 110' RKB. Weld landing ring on conductor. /' 2. Move in / rig up Doyon 141. Install diverter & function test same. /" 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (+/- 5763 MD') according to directional plan. Run MWD, LWD, GR logging tools in drill string for directional monitoring and formation data gathering. / 4. Run and cement 9-5/8" 40.0# L-80 BTCM casing to surface using ArcticSet 3 lead slurry and LiteCrete tail to assure cement returns to the surface. Adequate tail cement will be pumped to ensure cement reaches the surface. Displace cement with mud. /' 5. Nipple down diverter and install wellhead. Nipple ~þ BOPE and test to 5000 psi. Record results. 6. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 7. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. / 8. Directionally drill 8-1/2" hole to intermediate casing depth (+/- 14059' MD) according to directional plan. Run MWD, LWD, GR, Resistivity logging tools in drill string for directional monitoring and formation data gather~. Circulate and condition hole. POOH. 9. Run and cement 7" 26J# L-80 BTCM intermediate casing string. Displace cement with mud. 10. Test BOPE to 5000 psi. Record results. 11. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 12. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. / 13. Directionally drill 6-1/8" hole to total well depth (+/- 14769' MD) according to directional plan. Run MWD, LWD, GR, Resistivity, Density/Neutron logging tools in drill string for directional monitoring and formation data gathering. Circulate and condition hole. POOH. 14. Run open hole e-line or dri~ipe conveyed logs as needed. 15. Run and cement 3 V2" 9.3# L -80 SLHT liner with 150' liner overlap. 16. Run and land 3-1/2" tubing. Displace well to completion brine. 2G-17 PERMIT IT 121002.doc ''C' ,~ '. , Page 8 of 9 O f¡f. I'" t ~ t,~\ .$ .. i.n.... L.. Printed: 11-Dec-02 ¡. G~ ff Ir'l) :':1 ~iiÎfi ) Ar~I;}ation for Permit to Drill, Well 2G-17 . Saved: 11-Dec-02 17. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. /" 18. Freeze protect well. Set BPV. Release rig and turn well over to production. 19. Clean location and RDMO in preparation for coiled tubing cIeanout and perforating. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following Items, except for an item already on file with the c..'vmmission and identified in the application: (14) a general desaiption of how the operator p/amj to dispose of dnlling mud and cuttings and a statement of whether the ope/f.7tor intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well.; ./,/ Waste fluids and cuttings generated during the drilling process will be injected down a permitted annulus on 2G pad or hauled to a KRU Class II disposal well. 15. Attachments Attachment 1 AOGCC Form 10-401 (Front of permit package) Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Well Schematic Attachment 5 Cement Details 2G-17 PERMIT IT 121002.doc Page 9 of 9 O :r, r ,~ ¡ ,I~,' /1 L Printed: 11-Dec-02 .. i ~ t:~ "' , :u t1 i.. a ::Q -?...'" ~~'~) 10.7-=":'7>.. . ~t~: r~ 600 - 600 - 1200 - ........... -+- ~ 1800 - 4- '--/ ....c 2400 - -+- CL Q) o 3000 - o ü t 3600 - Q) > Q) 4200 - :1 L l- I 4800 - V 5400 - 6000 - 6600 - 7200 600 ConocoPhillips Alaska, Inc. -------- Created by bmichael For: P Reilly Date plotted: 6-0ec-2002 Plot Reference is 2G-17 Version#2. Coordinates ore in feet reference slot 117. True Vertical Depths ore reference Est RKB (D-141).: r&ílB . BAJŒIt , IlUGlES ! ~NT~L_ _ _ ___~ Structure : Pad 2G Well : 17 Field: Kuparuk River Unit Location: North Slope, Alaska! o - I 141.56 AZIMUTH 12051' (TO TARGET) RKB Elevation: 131.2' ***Plone of Propasal*** KOP 2.00 6.00 DLS: 3.00 deg per 100 ft 15.78 22.21 30.05 DLS: 4.00 deg per 100 ft 37.96 Base Permafrost 45.89 53.84 65.78 EOC Bose West Sak Casing C-80 K-10 TANGENT ANGLE 70.76 DEG ConocóPhillips "-- .~ DLS: 2.00 deg per 100 ft Begin Drop 69.56 C-35 61.56 55.56 C-20 ~ B<1(~1HRZ Kuparuk B TARGET ANGLE 55 DEG o 600 1200 3000 5400 7200 8400 7800 6000 6600 3600 4200 4800 1800 2400 Vertical Section (feet) -> Azimuth 141.55 with reference 0.00 N, 0.00 E from slot #17 End Drop-Top HRZ 7 Casing T orget - C4 K~?~r~:~5 ~uparuk A4 Miluveach TO - Csg pt. 9000 9600 10200 10800 11400 12000 12600 13200 ) ') ConocoPhillips Alaska, Inc. ./ ConocoPhillips For: P Reilly Dote plotlad: 6-Dac-2002 Plot Roforonce ill 2G-17 VarsionH2. Coordinotc~ era in feat reference ::lIot Nt? Trull V.rtlcal Dopth. or. r.f.rClnca E:lt RKB 600 600 600 - 1200 - 1800 - 2400 - 3000 - 3600 - ,,--., 4200 - ID Q) - ........... 4800 - -C - :J 0 5400 - tf) I V 6000 - 6600 - 7200 - 7800 - 8400 - 9000 - 9600 - 10200 - 10800 - Structure: Pad 2G Well: 17 Field : Kuparuk River Unit Location: North Slope, m¡¡ IIfBLs ¡:¡;¡:¡:w- 600 East (feet) - > 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 1200 SURFACE LOCATION: 203' FNL, 272' FWL SEC. 5, Tl0N, R9E 141. 5 6 AZIMUTH 12051' (TO TARGET) ".Plane of Proposal... , TRUE TARGET LOCATION: 913' FSL, 2452' FWL SEC. 9, T1 ON. R9E HARDLlNE: DO NOT PENETRATE TARGET CIRCLE TO NORTH OF THIS LINE C-35 End Drop-Top HRZ C-20 SQse HRZ K-1 ~sr~~~k- SC4 Ku8.muk ,1\4 Miluveach 17 TO - Csg PI. TO LOCATION: 581' FSL, 2570' FEL SEC. 9, T1 OE, R9E ,... JI ~ L~' ,A f ~ 1 Gt J ¡ I~; l~\;"ra ConocoPhillips Alaska, Inc. --~----------_._----------- Conoc~P-hillips Structure : Pad 2G Well: 17 Plot Reference is 2G-17 Versian#2. Field : Kuparuk River Unit Location : North Slope, Coordinates ore in feet reference slot 1/17. Vertical Depths ore reference Est RKB RilC BAKER HIJGIEö . ______.__._____m____~_________·m____._____________ --------..---------- ____________________________________nn_ c::::== = = == PROFILE COMMENT DATA ==== ----- Point ----- MD Inc Dir TVD North East V. Sect Deg/100¡ KOP 300.00 0.00 120.00 300.00 0.00 0.00 0.00 0.00, -- Base Permafrost 1605.73 38.18 137.41 1531.20 -232.01 267.39 347.96 --4.00, EOC 2425.05 70.76 141.98 2001.09 -736.97 688.58 1005.33 4.00: Top West Sak 3578.53 70.76 141 .98 2381.20 -1594.87 1 359.42 2094.35 O.OO¡ Base West Sak 5156.50 70.76 141 .98 2901.20 -2768.48 2277.15 3584.14 0.001 9 5/8 Casing 5763.41 70.76 141 .98 3101.20 -3219.88 2630.12 4157.13 0.001 C-80 6567.57 70.76 141 .98 3366.20 -3817.97 3097.80 491 6.35 O.OO¡ K-10 6764.82 70.76 141.98 3431.20 -3964.67 3212.52 5102.58 0.00, C-50 (K-5) 10740.09 70.76 141 .98 4741.20 -6921.28 5524.47 8855.70 0.00, C-40 11407.69 70.76 141.98 4961.20 -7417.82 5912.74 9486.00 0.001 ~~. Begin Drop 12839.79 70.76 141 .98 5433.13 -8482.94 6745.62 10838.06 O.OOj ,,"--,c' -. C-35 13283.62 61.88 141 .98 5611.20 -8802.82 6995.75 11244.11 2.001 _. End Drop-Top HRZ 13627.75 55.00 141.98 5791.20 -9033.68 7176.27 11537.16 2.001 f: C-20 13802.10 55.00 141.98 5891 .20 -9146.18 7264.24 11679.98 0.00' Base HRZ 13959.01 55.00 141.98 5981.20 -9247.44 7343.41 11808.51 0.00' --- ~;- ~ 7 Casing 14059.01 55.00 141.98 6038.56 -9311.97 7393.87 11890.42 0.00, b;~ - ¡-_n K-1 14115.92 55.00 141.98 6071 .20 -9348.70 7422.58 11937.04 0.00, Target - C4 14255.38 55.00 141.98 6151.19 -9438.69 7492.95 12051 .27 O.OOj Kuparuk B 14307.70 55.00 141 .98 6181.20 -9472.45 7519.35 12094.13 O.OO! Kuparuk A6 14377.44 55.00 141 .98 6221.20 -9517.45 7554.53 12151.25 0.001 Kuparuk A5 14412.31 55.00 141 .98 6241.20 -9539.95 7572.13 12179.81 O.OO! Kuparuk A4 14464.61 55.00 141 .98 6271.20 -9573.71 7598.52 12222.66 0.00, Miluveach 14569.22 55.00 141.98 6331.20 -9641.21 7651.30 1 2308.34 Q.OO: TO. ..........CsgPL . .. .._ .. _14ZQ9_ .22________.n _5_5.00 1 4 1 . 913.._n_n_n_nnn_9.1:.. 45 . 9 2 - _9.ZI.Qn" 2 7 7752.22 .__J_24Z2n,..Jn.7n._n _.nn_._.___º"º-Qj ) ) ConocoPhillips Alaska, Inc. Pad 2G 17 slot #17 Kuparuk River Uni t North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License 2G-17 Version#2 prop5304 Date printed Date created Last revised 6-Dec-2002 30-Sep-2002 6-Dec-2002 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 15 25.530,w149 55 46.967 Slot location is n70 15 23.533,w149 55 39.027 Slot Grid coordinates are N 5943385.100, E 508969.900 Slot local coordinates are 203.05 S 272.94 E Proj ection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North J1¡G¡NA.~ ORI f":"\ .!, ~ :~ I ~:,.~ ',J 11 . , ¡~ -¡ i :' j .:' .,~ I~I ~ f ~., .','. ,I ~ ., . " lrl>~ ~ t ,.1 .', ,,:ë.EI'1 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot *17 and TVD from Est RKB (D-141) (131.20 Ft above mean sea level). Bottom hole distance is 12472.17 on azimuth 141.57 degrees from wellhead. Total Dogleg for we11path is 87.33 degrees. Vertical section is from wellhead on azimuth 141.56 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ConocoPhi11ips Alaska, Inc. PROP05AL LI5TING Page 1 Pad 2G, 17 Your ref 2G-17 Version#2 Kuparuk River Unit, North 51ope, Alaska Last revised : 6-Dec-2002 Measured Inc1in Azimuth True Vert RECTANGULAR G RID COO R D 5 G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE 5 Easting Northing COO R DIN ATE 5 0.00 0.00 120.00 0.00 O.OON o .OOE 508969.90 5943385.10 n70 15 23.53 w149 55 39.03 300.00 0.00 120.00 300.00 O.OON o .OOE 508969.90 5943385.10 n70 15 23.53 w149 55 39.03 400.00 2.00 120.00 399.98 0.875 1.51E 508971.41 5943384.23 n70 15 23.52 w149 55 38.98 500.00 4.00 120.00 499.84 3.495 6.04E 508975.95 5943381.62 n70 15 23.50 w149 55 38.85 600.00 6.00 120.00 599.45 7.855 13.59E 508983.50 5943377.27 n70 15 23.46 w149 55 38.63 700.00 8.00 120.00 698.70 13.945 24.14E 508994.06 5943371.19 n70 15 23.40 w149 55 38.32 800.00 10.00 120.00 797.47 21. 765 37.69E 509007.61 5943363.38 n70 15 23.32 w149 55 37.93 900.00 12.87 124.48 895.47 32.415 54.39E 509024.33 5943352.76 n70 15 23.21 w149 55 37.44 1000.00 15.78 127.34 992.35 46.965 74.39E 509044.34 5943338.23 n70 15 23.07 w149 55 36.86 1100.00 18.73 129.32 1087.84 65.395 97.63E 509067.59 5943319.83 n70 15 22.89 w149 55 36.19 1143 .12 20.00 130.00 1128.52 74.515 108.63E 509078.61 5943310.72 n70 15 22.80 w149 55 35.87 1200.00 22.21 131. 51 1181. 59 87 .905 124.14E 509094.12 5943297.36 n70 15 22.67 w149 55 35.42 1300.00 26.12 133.57 1272.81 115.615 154.25E 509124.27 5943269.68 n70 15 22.40 w149 55 34.54 1400.00 30.05 13 5.13 1361. 01 148.545 187.87E 509157.93 5943236.79 n70 15 22.07 w149 55 33.56 1500.00 34.00 136.36 1445.78 186.535 224.85E 509194.94 5943198.84 n70 15 21.70 w149 55 32.49 1600.00 37.96 137.36 1526.69 229.405 265.00E 509235.13 5943156.02 n70 15 21.28 w149 55 31.32 U05.73 38.18 137.41 1531.20 232.015 267.39E 509237.53 5943153.43 n70 15 21.25 w149 55 31.25 1700.00 41. 92 138.19 1603 .35 276.945 308.12E 509278.31 5943108.54 n70 15 20.81 w149 55 30.06 1800.00 45.89 138.91 1675.38 328.925 354.00E 509324.25 5943056.62 n70 15 20.30 w149 55 28.73 1900.00 49.86 139.53 1742.44 385.085 402.43E 509372.73 5943000.52 n70 15 19.75 w149 55 27.32 2000.00 53.84 140.09 1804.20 445.155 453.16E 509423.53 5942940.52 n70 15 19.15 w149 55 25.85 2100.00 57.82 140 . 59 1860.36 508.835 505.94E 509476.38 5942876.90 n70 15 18.53 w149 55 24.31 2200.00 61.80 141. 05 1910.64 575.825 560.53E 509531. 04 5942809.98 n70 15 17.87 w149 55 22.72 2300.00 65.78 141. 48 1954.80 645.805 616.66E 509587.24 5942740.08 n70 15 17.18 w149 55 21. 09 2400.00 69.76 141.88 1992.63 718.415 674.04E 509644.70 5942667.54 n70 15 16.47 w149 55 19.42 2425.05 70.76 141.98 2001.09 736.975 688.58E 509659.26 5942649.00 n70 15 16.28 w149 55 19.00 2500.00 70.76 141.98 2025.79 792.715 732.17E 509702.91 5942593.31 n70 15 15.74 w149 55 17.73 3000.00 70.76 141.98 2190.55 1164.595 1022.96E 509994.10 5942221.81 n70 15 12.08 w149 55 09.27 3500.00 70.76 141.98 2355.32 1536.465 1313.75E 510285.29 5941850.31 n70 15 08.42 w149 55 00.82 3578.53 70.76 141.98 2381.20 1594.875 1359.42E 510331. 03 5941791.96 n70 15 07.85 w149 54 59.49 4000.00 70.76 141.98 2520.09 1908.345 1604.54E 510576.49 5941478.81 n70 15 04.76 w149 54 52.36 4500.00 70.76 141. 98 2684.86 2280.215 1895.34E 510867.68 5941107.30 n70 15 01.10 w149 54 43.91 5000.00 70.76 141. 98 2849.63 2652.095 2186.13E 511158.87 5940735.80 n70 14 57.45 w149 54 35.45 5156.50 70.76 141.98 2901.20 2768.485 2277 .15E 511250.01 5940619.52 n70 14 56.30 w149 54 32.81 5500.00 70.76 141.98 3014.40 3023.965 2476.92E 511450.06 5940364.30 n70 14 53.79 w149 54 27.00 5763.41 70.76 141.98 3101.20 3219.885 2630.12E 511603.47 5940168.58 n70 14 51.86 w149 54 22.55 6000.00 70.76 141.98 3179.16 3395.845 2767.71E 511741.25 5939992.80 n70 14 50.13 w149 54 18.55 6500.00 70.76 141.98 3343.93 3767.715 3058.50E 512032.45 5939621.30 n70 14 46.47 w149 54 10.10 6567.57 70.76 141.98 3366.20 3817.975 3097.80E 512071.80 5939571.09 n70 14 45.98 w149 54 08.96 6764.82 70.76 141.98 3431.20 3964.675 3212.52E 512186.67 5939424.54 n70 14 44.53 w149 54 05.62 7000.00 70.76 141.98 3508.70 4139.595 3349.30E 512323.64 5939249.79 n70 14 42.81 w149 54 01.65 7500.00 70.76 141. 98 3673.47 4511.475 3640.09E 512614.83 5938878.29 n70 14 39.15 w149 53 53.20 8000.00 70.76 141.98 3838.24 4883.345 3930.88E 512906.02 5938506.79 n70 14 35.49 w149 53 44.75 8500.00 70.76 141. 98 4003.01 5255.225 4221.67E 513197.22 5938135.29 n70 14 31.83 w149 53 36.30 9000.00 70.76 141. 98 4167.78 5627.095 4512.46E 513488.41 5937763.78 n70 14 28.18 w149 53 27.86 9500.00 70.76 141. 98 4332.54 5998.975 4803.26E 513779.60 5937392.28 n70 14 24.52 w149 53 19.41 10000.00 70.76 141.98 4497.31 6370.845 5094.05E 514070.79 5937020.78 n70 14 20.86 w149 53 10.97 10500.00 70.76 141.98 4662.08 6742.725 5384.84E 514361.98 5936649.28 n70 14 17.20 w149 53 02.52 10740.09 70.76 141.98 4741.20 6921.285 5524.47E 514501.81 5936470.89 n70 14 15.44 w149 52 58.47 11000.00 70.76 141.98 4826.85 7114.595 5675.63E 514653.18 5936277.77 n70 14 13.54 w149 52 54.08 ') ) h ¡ " ' . ' ~ I~ II .J 'Vi ij j ~" j ¡".A All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot l17 and TVD from Est RKB (D-141) (131.20 Ft above mean sea level). Bottom hole distance is 12472.17 on azimuth 141.57 degrees from wellhead. Total Dogleg for we11path is 87.33 degrees. Vertical section is from wellhead on azimuth 141.56 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ConocoPhi11ips Alaska, Inc. PROPOSAL LISTING Page 2 Pad 2G,17 Your ref 2G-17 Version#2 Kuparuk River Unit,North Slope, Alaska Last revised : 6-Dec-2002 Measured Inclin Azimuth True Vert RECTANGULAR G RID COO R D S G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE S Easting Northing COO R DIN ATE S 11407.69 70.76 141.98 4961. 20 7417.82S 5912.74E 514890.61 5935974.86 n70 14 10.55 w149 52 47.19 11500.00 70.76 141. 98 4991.62 7486.47S 5966.43E 514944.37 5935906.27 n70 14 09.88 w149 52 45.64 12000.00 70.76 141. 98 5156.39 7858.34S 6257.22E 515235.56 5935534.77 n70 14 06.22 w149 52 37.19 12500.00 70.76 141. 98 5321.16 8230.22S 6548.01E 515526.75 5935163.27 n70 14 02.56 w149 52 28.75 12839.79 70.76 141.98 5433.13 8482.94S 6745.62E 515724.64 5934910.80 n70 14 00.07 w149 52 23.02 12900.00 69.56 141.98 5453.57 8527.55S 6780.51E 515759.58 5934866.23 n70 13 59.63 w149 52 22.00 13000.00 67.56 141.98 5490.13 8600.87S 6837.84E 515816.99 5934792.99 n70 13 58.91 w149 52 20.34 13100.00 65.56 141. 98 5529.91 8673.14S 6894.35E 515873.57 5934720.79 n70 13 58.20 w149 52 18.70 13200.00 63.56 141.98 5572.87 8744.27S 6949.97E 515929.27 5934649.73 n70 13 57.50 w149 52 17.09 13283.62 61. 88 141. 98 5611.20 8802.82S 6995.75E 515975.11 5934591. 25 n70 13 56.92 w149 52 15.76 13300.00 61. 56 141. 98 5618.96 8814.18S 7004.64E 515984.01 5934579.90 n70 13 56.81 w149 52 15.50 13400.00 59.56 141. 98 5668.12 8882.77S 7058.27E 516037.72 5934511.37 n70 13 56.14 w149 52 13.94 13500.00 57.56 141. 98 5720.28 8949.98S 7110.82E 516090.34 5934444.23 n70 13 55.47 w149 52 12.42 13600.00 55.56 141.98 5775.39 9015.71S 7162.22E 516141.81 5934378.57 n70 13 54.83 w149 52 10.93 13627.75 55.00 141.98 5791.20 9033.68S 7176.27E 516155.88 5934360.61 n70 13 54.65 w149 52 10.52 13802.10 55.00 141.98 5891.20 9146.18S 7264.24E 516243.97 5934248.22 n70 13 53.54 w149 52 07.97 13959.01 55.00 141.98 5981.20 9247.44S 7343.41E 516323.25 5934147.07 n70 13 52.55 w149 52 05.67 14000.00 55.00 141.98 6004.71 9273.89S 7364.09E 516343.96 5934120.64 n70 13 52.29 w149 52 05.07 14059.01 55.00 141. 98 6038.56 9311.97S 7393.87E 516373.77 5934082.60 n70 13 51.91 w149 52 04.20 14115.92 55.00 141.98 6071.20 9348.70S 7422.58E 516402.53 5934045.91 n70 13 51. 55 w149 52 03.37 14255.38 55.00 141. 98 6151.19 9438.69S 7492.95E 516472.99 5933956.01 n70 13 50.66 w149 52 01.33 14255.40 55.00 141.98 6151.20 9438.70i:? 7492.96E 516473.00 5933956.00 n70 13 50.66 w149 52 01.33 14307.70 55.00 141.98 6181.20 9472.45S 7519.35E 516499.43 5933922.28 n70 13 50.33 w149 52 00.56 14377.44 55.00 141.98 6221.20 9517.45S 7554.53E 516534.66 5933877.33 n70 13 49.89 w149 51 59.54 14412.31 55.00 141.98 6241.20 9539.95S 7572 .DE 516552.28 5933854.85 n70 13 49.67 w149 51 59.03 14464.61 55.00 141. 98 6271.20 9573.71S 7598.52E 516578.71 5933821.13 n70 13 49.34 w149 51 58.27 14500.00 55.00 141. 98 6291.50 9596.54S 7616.38E 516596.59 5933798.31 n70 13 49.11 w149 51 57.75 14569.22 55.00 141.98 6331.20 9641. 21S 7651.30E 516631.56 5933753.69 n70 13 48.67 w149 51 56.73 ).4769.22 55.00 141. 98 6445.92 9770.27S 7752.22E 516732.62 5933624.76 n70 13 47.40 w149 51 53.81 ) ) JqIGiNA- 7492.96E 30-5ep-2002 7193.02E 19-Nov-2002 7793.08E 19-Nov-2002 9438.705 9358.355 9359.045 6151.20 6151.20 6151.20 2G-17 C4 TGT RV5D 7N 516473.000,5933956.000,0.0000 2G-17 Hardline pt#1 516173.000,5934036.000,0.0000 2G-17 Hard1ine Pt#2 516773.000,5934036.000,0.0000 ----------------------------------------------------------------------------------------------------------- Revised Rectangular Coordinates T.V.D. Geographic Location Target name -------- --- ------ --- -- ------------ --- - ----- ----------- ------ ------- --- ---- Targets associated with this we11path 2630.12E 9 5/8" Casing 7393.86E 7" Casing 3219.885 9311.965 O.OOE 5763.41 3101.20 O.OOE 14059.00 6038.55 O.OON O.OON 0.00 0.00 0.00 0.00 - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 300.00 300.00 o .OON O.OOE KOP 1605.73 1531.20 232.015 267.39E Base Permafrost 2425.05 2001.09 736.975 688.58E EOC 3578.53 2381.20 1594.87S 1359.42E Top West Sak 5156.50 2901. 20 2768.485 2277.15E Base West Sak 5763.41 3101.20 3219.885 2630.12E 9 5/8" Casing 6567.57 3366.20 3817.97S 3097.80E C-80 6764.82 3431.20 3964.675 3212.52E K-10 10740.09 4741.20 6921.28S 5524.47E C-50 (K-5) 11407.69 4961.20 7417.82S 5912.74E C-40 12839.79 5433.13 8482.94S 6745.62E Begin Drop 13283.62 5611.20 8802.82S 6995.75E C-35 13627.75 5791.20 9033.68S 7176.27E End Drop-Top HRZ 13802.10 5891.20 9146.185 7264.24E C-20 13959.01 5981.20 9247.445 7343.4lE Base HRZ 14059.01 6038.56 9311. 97S 7393.87E 7" Casing 14115.92 6071.20 9348.70S 7422.58E K-1 14255.38 6151.19 9438.69S 7492.95E Target - C4 14255.40 6151.20 9438.70S 7492.96E 2G-17 C4 TGT RVSD 7Nov02 14307.70 6181.20 9472.45S 7519.35E Kuparuk B 14377.44 6221.20 9517.455 7554.53E Kuparuk A6 14412.31 6241.20 9539.95S 7572 .13E Kuparuk A5 14464.61 6271.20 9573.71S 7598.52E Kuparuk A4 14569.22 6331.20 9641.21S 7651. 3 DE Mi1uveach 14769.22 6445.92 9770.27S 7752.22E TD - Csg Pt. Casing positions in string 'A' ---- ---------------- ------- --- - - - -- - - -- - -- - -- - -- - - -- -- - - - --- Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- Comment Rectangular Coords. TVD MD -------------------- -------------------- Comments in we11path PROPOSAL LISTING Page 3 Your ref 2G-17 Version#2 Last revised: 6-Dec-2002 ConocoPhi11ips Alaska, Inc. Pad 2G, 17 Kuparuk River Unit, North Slope, Alaska ) ) ) ) ConocoPhillips Alaska, Inc. Pad 2G 17 slot #17 Kuparuk River Unit North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License 2G-17 Version#2 prop5304 Date printed Date created Last revised 6-Dec-2002 30-Sep-2002 6-Dec-2002 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 15 25.530,w149 55 46.967 Slot location is n70 15 23.533,w149 55 39.027 Slot Grid coordinates are N 5943385.100, E 508969.900 Slot local coordinates are 203.05 S 272.94 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North C·:) Lf1 ~ ~ fA . , I {;, ¡" J~" L ) ) ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 1 Pad 2G,17 Your ref 2G-17 Version#2 Kuparuk River Unit,North Slope, Alaska Last revised 6-Dec-2002 Measured Inc lin . Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Degl100ft Sect 0.00 0.00 120.00 0.00 0.00 N 0.00 E 0.00 0.00 300.00 0.00 120.00 300.00 0.00 N 0.00 E 0.00 0.00 KOP 400.00 2.00 120.00 399.98 0.87 S 1. 51 E 2.00 1. 62 500.00 4.00 120.00 499.84 3.49 S 6.04 E 2.00 6.49 600.00 6.00 120.00 599.45 7.85 S 13.59 E 2.00 14.60 700.00 8.00 120.00 698.70 13.94 S 24.14 E 2.00 25.93 800.00 10.00 120.00 797.47 21.76 S 37.69 E 2.00 40.48 900.00 12.87 124.48 895.47 32.41 S 54.39 E 3.00 59.20 1000.00 15.78 127.34 992.35 46.96 S 74.39 E 3.00 83.04 1100.00 18.73 129.32 1087.84 65.39 S 97.63 E 3.00 111.91 1143.12 20.00 130.00 1128.52 74.51 S 108.63 E 3.00 125.90 1200.00 22.21 131. 51 1181.59 87.90 S 124.14 E 4.00 146.02 1300.00 26.12 133.57 1272 . 81 115.61 S 154.25 E 4.00 186.45 1400.00 30.05 135.13 1361. 01 148.54 S 187.87 E 4.00 233.15 1500.00 34.00 136.36 1445.78 186.53 S 224.85 E 4.00 285.90 1600.00 37.96 137.36 1526.69 229.40 S 265.00 E 4.00 344.44 1605.73 38.18 137.41 1531. 20 232.01 S 267.39 E 4.00 347.96 Base Permafrost 1700.00 41.92 138.19 1603.35 276.94 S 308.12 E 4.00 408.48 1800.00 45.89 138.91 1675.38 328.92 S 354.00 E 4.00 477.72 1900.00 49.86 139.53 1742.44 385.08 S 402.43 E 4.00 551.81 2000.00 53.84 140.09 1804.20 445.15 S 453.16 E 4.00 630.40 2100.00 57.82 140.59 1860.36 508.83 S 505.94 E 4.00 713.10 2200.00 61.80 141.05 1910.64 575.82 S 560.53 E 4.00 799.51 2300.00 65.78 141. 48 1954.80 645.80 S 616.66 E 4.00 889.20 2400.00 69.76 141. 88 1992.63 718.41 S 674.04 E 4.00 981.75 2425.05 70.76 141.98 2001. 09 736.97 S 688.58 E 4.00 1005.33 EOC 2500.00 70.76 141. 98 2025.79 792.71 S 732.17 E 0.00 1076.09 3000.00 70.76 141. 98 2190.55 1164.59 S 1022.96 E 0.00 1548.15 3500.00 70.76 141.98 2355.32 1536.46 S 1313.75 E 0.00 2020.21 3578.53 70.76 141. 98 2381.20 1594.87 S 1359.42 E 0.00 2094.35 Top West Sak 4000.00 70.76 141. 98 2520.09 1908.34 S 1604.54 E 0.00 2492.27 4500.00 70.76 141. 98 2684.86 2280.21 S 1895.34 E 0.00 2964.32 5000.00 70.76 141. 98 2849.63 2652.09 S 2186.13 E 0.00 3436.38 5156.50 70.76 141.98 2901. 20 2768.48 S 2277.15 E 0.00 3584.14 Base West Sak 5500.00 70.76 141.98 3014.40 3023.96 S 2476.92 E 0.00 3908.44 5763.41 70.76 141.98 3101. 20 3219.88 S 2630.12 E 0.00 4157.13 9 5/8" Casing 6000.00 70.76 141. 98 3179.16 3395.84 S 2767.71 E 0.00 4380.50 6500.00 70.76 141. 98 3343.93 3767.71 S 3058.50 E 0.00 4852.56 6567.57 70.76 141. 98 3366.20 3817.97 S 3097.80 E 0.00 4916.35 C-80 6764.82 70.76 141. 98 3431.20 3964.67 S 3212.52 E 0.00 5102.58 K-10 7000.00 70.76 141.98 3508.70 4139.59 S 3349.30 E 0.00 5324.62 7500.00 70.76 141.98 3673.47 4511. 47 S 3640.09 E 0.00 5796.68 8000.00 70.76 141.98 3838.24 4883.34 S 3930.88 E 0.00 6268.73 8500.00 70.76 141. 98 4003.01 5255.22 S 4221.67 E 0.00 6740.79 9000.00 70.76 141. 98 4167.78 5627.09 S 4512.46 E 0.00 7212.85 9500.00 70.76 141.98 4332.54 5998.97 S 4803.26 E 0.00 7684.91 10000.00 70.76 141.98 4497.31 6370.84 S 5094.05 E 0.00 8156.97 10500.00 70.76 141. 98 4662.08 6742.72 S 5384.84 E 0.00 8629.03 10740.09 70.76 141.98 4741.20 6921. 28 S 5524.47 E 0.00 8855.70 C-50 (K-5) 11000.00 70.76 141. 98 4826.85 7114.59 S 5675.63 E 0.00 9101. 09 All data is in feet unless otherwise stated. Coordinates from slot #17 and TVD from Est RKB (D-141) (131.20 Ft above mean sea level). Bottom hole distance is 12472.17 on azimuth 141.57 degrees from wellhead. Total Dogleg for wellpath is 87.33 degrees. Vertical section is from wellhead on azimuth 141.56 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ :,i'GINA,~ ) ) ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 2 Pad 2G,17 Your ref 2G-17 Version#2 Kuparuk River Unit, North Slope, Alaska Last revised 6-Dec-2002 Measured Inc lin . Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I NA T E S Deg/100ft Sect 11407.69 70.76 141. 98 4961.20 7417.82 S 5912.74 E 0.00 9486.00 C-40 11500.00 70.76 141. 98 4991.62 7486.47 S 5966.43 E 0.00 9573.15 12000.00 70.76 141.98 5156.39 7858.34 S 6257.22 E 0.00 10045.20 12500.00 70.76 141. 98 5321.16 8230.22 S 6548.01 E 0.00 10517.26 12839.79 70.76 141. 98 5433.13 8482.94 S 6745.62 E 0.00 10838.06 Begin Drop 12900.00 69.56 141.98 5453.57 8527.55 S 6780.51 E 2.00 10894.70 13000.00 67.56 141. 98 5490.13 8600.87 S 6837.84 E 2.00 10987.77 13100.00 65.56 141. 98 5529.91 8673.14 S 6894.35 E 2.00 11079.50 13200.00 63.56 141. 98 5572 . 87 8744.27 S 6949.97 E 2.00 11169.80 13283.62 61.88 141. 98 5611.20 8802.82 S 6995.75 E 2.00 11244.11 C-35 13300.00 61.56 141. 98 5618.96 8814.18 S 7004.64 E 2.00 11258.53 13400.00 59.56 141. 98 5668.12 8882.77 S 7058.27 E 2.00 11345.61 13500.00 57.56 141. 98 5720.28 8949.98 S 7110.82 E 2.00 11430.92 13600.00 55.56 141. 98 5775.39 9015.71 S 7162.22 E 2.00 11514.35 13627.75 55.00 141. 98 5791.20 9033.68 S 7176.27 E 2.00 11537.16 End Drop-Top HRZ 13802.10 55.00 141. 98 5891. 20 9146.18 S 7264.24 E 0.00 11679.98 C-20 13959.01 55.00 141. 98 5981.20 9247.44 S 7343.41 E 0.00 11808.51 Base HRZ 14000.00 55.00 141. 98 6004.71 9273.89 S 7364.09 E 0.00 11842.08 14059.01 55.00 141. 98 6038.56 9311.97 S 7393.87 E 0.00 11890.42 7" Casing 14115.92 55.00 141. 98 6071.20 9348.70 S 7422.58 E 0.00 11937.04 K-1 14255.38 55.00 141. 98 6151.19 9438.69 S 7492.95 E 0.00 12051. 27 Target - C4 14255.40 55.00 141. 98 6151. 20 9438.70 S 7492.96 E 0.00 12051. 28 2G-17 C4 TGT RVSD 7Nov02 14307.70 55.00 141. 98 6181.20 9472.45 S 7519.35 E 0.00 12094.13 Kuparuk B 14377.44 55.00 141. 98 6221. 20 9517.45 S 7554.53 E 0.00 12151. 25 Kuparuk A6 14412.31 55.00 141. 98 6241.20 9539.95 S 7572 .13 E 0.00 12179.81 Kuparuk A5 14464.61 55.00 141. 98 6271.20 9573.71 S 7598.52 E 0.00 12222.66 Kuparuk A4 14500.00 55.00 141. 98 6291.50 9596.54 S 7616.38 E 0.00 12251. 65 14569.22 55.00 141. 98 6331.20 9641. 21 S 7651.30 E 0.00 12308.34 Miluveach 14769.22 55.00 141. 98 6445.92 9770.27 S 7752.22 E 0.00 12472 .17 TD - Csg Pt. All data is in feet unless otherwise stated. Coordinates from slot #17 and TVD from Est RKB (D-141) (131.20 Ft above mean sea level). Bottom hole distance is 12472.17 on azimuth 141.57 degrees from wellhead. Total Dogleg for wellpath is 87.33 degrees. Vertical section is from wellhead on azimuth 141.56 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ "l; M l/ \Q~I"J: J j ¡ .~ !".I.~ ) -' ConocoPhillips Alaska, Inc. Pad 2G,17 Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 3 Your ref 2G-17 Version#2 Last revised: 6-Dec-2002 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 300.00 300.00 0.00 N 0.00 E KOP 1605.73 1531. 20 232.01 S 267.39 E Base Permafrost 2425.05 2001. 09 736.97 S 688.58 E EOC 3578.53 2381.20 1594.87 S 1359.42 E Top West Sak 5156.50 2901.20 2768.48 S 2277.15 E Base West Sak 5763.41 3101.20 3219.88 S 2630.12 E 9 5/8" Casing 6567.57 3366.20 3817.97 S 3097.80 E C-80 6764.82 3431.20 3964.67 S 3212.52 E K-10 10740.09 4741.20 6921. 28 S 5524.47 E C-50 (K-5) 11407.69 4961.20 7417.82 S 5912.74 E C-40 12839.79 5433.13 8482.94 S 6745.62 E Begin Drop 13283.62 5611.20 8802.82 S 6995.75 E C-35 13627.75 5791.20 9033.68 S 7176.27 E End Drop-Top HRZ 13802.10 5891.20 9146.18 S 7264.24 E C-20 13959.01 5981.20 9247.44 S 7343.41 E Base HRZ 14059.01 6038.56 9311.97 S 7393.87 E 7" Casing 14115.92 6071.20 9348.70 S 7422.58 E K-1 14255.38 6151.19 9438.69 S 7492.95 E Target - C4 14255.40 6151.20 9438.70 S 7492.96 E 2G-17 C4 TGT RVSD 7Nov02 14307.70 6181. 20 9472.45 S 7519.35 E Kuparuk B 14377.44 6221. 20 9517.45 S 7554.53 E Kuparuk A6 14412.31 6241. 20 9539.95 S 7572 .13 E Kuparuk A5 14464.61 6271.20 9573.71 S 7598.52 E Kuparuk A4 14569.22 6331.20 9641.21 S 7651.30 E Miluveach 14769.22 6445.92 9770.27 S 7752.22 E TD - Csg Pt. Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 O.OON O.OON O.OOE 5763.41 3101.20 O.OOE 14059.00 6038.55 3219.88S 9311.96S 2630.12E 9 5/8" Casing 7393.86E 7" Casing Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- 2G-17 C4 TGT RVSD 7N 516473.000,5933956.000,0.0000 2G-17 Hardline Pt#1 516173.000,5934036.000,0.0000 2G-17 Hardline Pt#2 516773.000,5934036.000,0.0000 6151. 20 6151.20 6151. 20 9438.70S 9358.35S 9359.04S 7492.96E 7193.02E 7793.08E 30-Sep-2002 19-Nov-2002 19-Nov-2002 0.: G/NAL } Baker Hughes INTEQ ) Error Ellipse Survey Report Company:ConocoPhillipsAlaska, Inc. Field: KuparukRiver Unit Site: Pad 2G Well: 17 WeHpa th :2G;.;17 Version#2 Field: Kuparuk River Unit North Slope, Alaska USA Map SystenlJS State Plane Coordinate System 1927 Geo DatumNAD27 (Clarke 1866) Sys Datum:Mean Sea Level Date: 12/9/2002 Time: 11:35:24 Page: 1 Co~ordinate(NE) Reference: Well: 17, True North . Vertical (TVD)Reference: Doyon 141(new) 131.2 Section (V&) Reference: Well (0.00N,0.00E,141.57Azi) SurveyCalculatión Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: Pad 2G North Slope, Alaska Site Position: Northing: 5943587.82 ft Latitude: 70 15 25.530 N From: Map Easting: 508696.75 ft Longitude: 149 55 46.967 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 102.50 ft Grid Convergence: 0.07 deg Well: 17 Slot Name: Well Position: +N/-S -203.05 ft Northing: 5943385.10 ft Latitude: 70 15 23.533 N +E/-W 272.94 ft Easting : 508969.90 ft Longitude: 149 55 39.027 W Position Uncertainty: 0.00 ft Wellpath: 2G-17 Version#2 Drilled From: Surface Tie-on Depth: 0.00 ft Current Datum: Doyon 141(new) Height 131.20 ft Above System Datum: Mean Sea Level Magnetic Data: 11/22/2002 Declination: 25.34 deg Field Strength: 57470 nT Mag Dip Angle: 80.65 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 141.57 Plan: 2G-17 Version#2 Date Composed: 12/9/2002 Version: 2 Pri ncipal: Yes Tied-to: From Surface Position uncertainty aDd bias at survey station All uncertainties aa.6 standarddeviatioilighside-----> Lateral-------> Vertical------> Magn. Semi-majoSemi-minor MD loci Azim TVD Unc. Bias Unc. Bias Unc. Bias of BiasUnc. Unc. Azimutll'ool ft deg deg ft ft ft ft ft ft ft ft ft ft deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE LINE 100.00 0.00 0.00 100.00 0.10 0.00 0.10 0.00 2.96 0.00 0.00 0.10 0.10 0.00 MWD 200.00 0.00 0.00 200.00 0.39 0.00 0.39 0.00 2.96 0.00 0.00 0.39 0.39 0.00 MWD 300.00 0.00 0.00 300.00 0.68 0.00 0.68 0.00 2.97 0.01 0.01 0.68 0.68 0.00 MWD 400.00 2.00 120.00 399.98 0.77 0.00 0.77 0.00 2.97 0.02 0.02 0.77 0.77 135.00 MWD 500.00 4.00 120.00 499.84 0.73 0.00 0.78 0.00 2.97 0.03 0.03 0.78 0.75 118.91 MWD 600.00 6.00 120.00 599.45 0.81 0.00 1.00 0.01 2.97 0.04 0.04 1.00 0.85 121.65 MWD 700.00 8.00 120.00 698.70 0.99 0.00 1.44 0.02 2.97 0.06 0.06 1.44 1.05 121.99 MWD 800.00 10.00 120.00 797.4 7 1.23 -0.01 2.03 0.03 2.97 0.08 0.08 2.04 1.31 121.93 MWD 900.00 12.87 124.48 895.47 1.48 -0.01 2.78 0.05 2.96 0.10 0.11 2.78 1.59 122.33 MWD 1000.00 15.78 127.34 992.35 1.77 -0.01 3.72 0.09 2.95 0.12 0.15 3.72 1.90 123.49 MWD 1100.00 18.73 129.32 1087.84 2.10 -0.01 4.86 0.13 2.93 0.15 0.20 4.87 2.25 124.91 MWD 1200.00 22.21 131.51 1181.59 2.48 -0.02 6.22 0.20 2.91 0.18 0.27 6.24 2.64 126.31 MWD 1300.00 26.12 133.57 1272.81 2.89 -0.02 7.83 0.29 2.91 0.20 0.36 7.86 3.04 127.82 MWD 1400.00 30.05 135.13 1361.01 3.34 -0.03 9.72 0.41 2.91 0.23 0.48 9.76 3.49 129.27 MWD 1500.00 34.00 136.36 1445.78 3.82 -0.04 11.88 0.56 2.95 0.26 0.63 11.94 3.96 130.61 MWD 1600.00 37.96 137.36 1526.69 4.32 -0.05 14.31 0.74 3.04 0.29 0.81 14.37 4.44 131.80 MWD 1700,00 41.92 138.19 1603.35 4.85 -0.07 17.00 0.96 3.21 0.32 1.03 17.06 4.93 132.86 MWD 1800.00 45.89 138.91 1675.38 5.39 -0.09 19.92 1.21 3.46 0.35 1.28 19.99 5.42 133.79 MWD 1900.00 49.86 139.53 1742.44 5.95 -0.11 23.06 1.50 3.80 0.37 1.57 23.14 5.91 134.60 MWD 2000.00 53.84 140.09 1804.20 6.52 -0.13 26.40 1.82 4.23 0.40 1.89 26.48 6.37 135.32 MWD 2100.00 57.82 140.59 1860.36 7.09 -0.16 29.90 2.17 4.76 0.42 2.24 29.99 6.82 135.96 MWD 2200.00 61.80 141.05 1910.64 7.66 -0.19 33.54 2.56 5.37 0.44 2.63 33.64 7.23 136.53 MWD 2300.00 65.78 141.48 1954.80 8.23 -0.22 37.29 2.97 6.05 0.46 3.04 37.40 7.60 137.04 MWD 2400.00 69.76 141.88 1992.63 8.79 -0.26 41.13 3.41 6.80 0.47 3.48 41.25 7.93 137.50 MWD or;; ..!~J ¡' .. ri ¡ L,1 j ¡V i-.._ Company:ConocoPhillips Alaska, Inc; Field: Kuparuk River Unit Site: Pad2G· Well: 17 Wëllpatb:2G~17 Version#2 } Baker Hughes INTEQ ) Error Ellipse Survey Report Date: 12/9/2002 Time: 11:35:24 Page: 2 Ço-ordinate(NE) Reference: Well: 17, True North Verticsl (TVD) Reference: Doyon 141 (new) 131.2 Section (VS) Reference: Well (0.00N,0.00E,141.57Azi) Survey Calculation Metbod:Minimum Curvatüre . Db: Oracle Position uncertainty and bias at surveystaticm All uncertahitieš aa.6 standard deviatioilighšide----.;.> Lateral----~.;.-> Vertical.;.-----> Magn. Semi-majoBerrii';'minor MD Incl Azim TVD Unc. Bias Unc. BiasUnc. Bias of Bias Unc. Uric.· Azimutl'i'ool ft deg · deg ft ft ft ft ft ft ft ft ft ft deg 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 3900.00 4000.00 4100.00 4200.00 4300.00 4400.00 4500.00 4600.00 4700.00 4800.00 4900.00 5000.00 5100.00 5200.00 5300.00 5400.00 5500.00 5600.00 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 6400.00 6500.00 6600.00 6700.00 6800.00 6900.00 7000.00 7100.00 7200.00 7300.00 7400.00 7500.00 7600.00 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 70.76 141.98 2025.79 141.98 2058.74 141.98 2091.69 141.98 2124.65 141.98 2157.60 141.98 2190.55 141.98 2223.51 141.98 2256.46 141.98 2289.41 141.98 2322.37 141.98 2355.32 141.98 2388.28 141.98 2421.23 141.98 2454.18 141.98 2487.14 141.98 2520.09 141.98 2553.04 141.98 2586.00 141.98 2618.95 141.98 2651.91 141.98 2684.86 141.98 2717.81 141.98 2750.77 141.98 2783.72 141.98 2816.67 141.98 2849.63 141.98 2882.58 141.98 2915.53 141.98 2948.49 141.98 2981.44 141.98 3014.40 141.98 3047.35 141.98 3080.30 141.98 3113.26 141.98 3146.21 141.98 3179.16 141.98 3212.12 141.98 3245.07 141.98 3278.03 141.98 3310.98 141.98 3343.93 141.98 3376.89 141.98 3409.84 141.98 3442.79 141.98 3475.75 141.98 3508.70 141.98 3541.66 141.98 3574.61 141.98 3607.56 141.98 3640.52 141.98 3673.47 141.98 3706.42 9.58 10.46 11.34 12.22 13.11 14.00 -0.27 14.89 -0.27 15.78 -0.27 16.67 -0.27 17.57 -0.27 18.46 19.35 20.25 21.14 22.04 22.94 23.83 24.73 25.62 26.52 27.42 28.32 29.21 30.11 31.01 31.91 32.81 33.70 34.60 35.50 -0.27 -0.27 -0.27 -0.27 -0.27 45.05 49.02 53.00 56.99 60.99 65.00 69.01 73.03 77.06 81.09 3.87 4.32 4.78 5.24 5.70 7.60 8.43 9.26 10.10 10.93 6.16 11.77 0.55 6.62 12.61 0.56 7.08 13.45 0.58 7.54 14.30 0.59 8.00 15.14 0.61 -0.27 85.12 8.45 15.98 -0.27 89.15 8.91 16.83 -0.27 93.19 9.37 17.67 -0.27 97.23 9.83 18.52 -0.27 101.27 10.29 19.37 -0.27 105.31 10.75 20.21 -0.27 109.35 11.21 21.06 -0.27 113.40 11.67 21.91 -0.27 117.44 12.13 22.75 -0.27 121.49 12.59 23.60 -0.27 125.54 13.04 24.45 -0.27 129.58 13.50 25.30 -0.27 133.63 13.96 26.14 -0.27 137.68 14.42 26.99 -0.27 141.73 14.88 27.84 -0.27 145.78 15.34 28.69 -0.27 149.84 15.80 29.54 -0.27 153.89 16.26 30.39 -0.27 157.94 16.72 31.23 -0.27 161.99 17.17 32.08 36.40 -0.27 166.05 17.63 32.93 37.30 -0.27 170.10 18.09 33.78 38.20 -0.27 174.16 18.55 34.63 39.09 -0.27 178.21 19.01 35.48 39.99 -0.27 182.27 19.47 36.33 40.89 41.79 42.69 43.59 44.49 45.39 46.29 47.19 48.09 48.98 49.88 50.78 51.68 52.58 53.48 54.38 55.28 -0.27 186.32 19.93 37.18 -0.27 190.38 20.39 38.03 -0.27 194.43 20.85 38.88 -0.27 198.49 21.30 39.72 -0.27 202.54 21.76 40.57 -0.27 206.60 22.22 41.42 -0.27 210.66 22.68 42.27 -0.27 214.71 23.14 43.12 -0.27 218.77 23.60 43.97 -0.27 222.83 24.06 44.82 -0.27 226.88 24.52 45.67 -0.27 230.94 24.98 46.52 -0.27 235.00 25.44 47.37 -0.27 239.06 25.89 48.22 -0.27 243.11 26.35 49.07 -0.27 247.17 26.81 49.92 -0.27 251.23 27.27 50.77 0.48 0.50 0.51 0.52 0.54 3.94 45.16 8.22 137.91 MWD 4.40 49.12 8.49 138.26 MWD 4.85 53.09 8.77 138.56 MWD 5.31 57.07 9.04 138.81 MWD 5.77 61.07 9.32 139.03 MWD 6.23 65.07 9.60 139.23 MWD 6.69 69.08 9.88 139.40 MWD 7.15 73.10 10.16 139.55 MWD 7.61 77.12 10.44 139.68 MWD 8.07 81.14 10.73 139.81 MWD 0.62 8.53 85.17 11.01 139.92 MWD 0.64 8.99 89.20 11.30 140.02 MWD 0.65 9.46 93.24 11.58 140.11 MWD 0.67 9.92 97.27 11.87 140.19 MWD 0.69 10.38 101.31 12.16 140.27 MWD 0.70 10.84 105.35 12.44 140.34 MWD 0.72 11.30 109.39 12.73 140.40 MWD 0.74 11.76 113.43 13.02 140.46 MWD 0.76 12.23 117.48 13.31 140.52 MWD 0.77 12.69 121.52 13.60 140.57 MWD 0.79 13.15 125.57 13.89 140.62 MWD 0.81 13.61 129.62 14.18 140.67 MWD 0.83 14.07 133.67 14.47 140.71 MWD 0.85 14.54 137.71 14.77 140.75 MWD 0.87 15.00 141.76 15.06 140.79 MWD 0.89 15.46 145.81 15.35 140.82 MWD 0.91 15.92 149.86 15.64 140.86 MWD 0.93 16.39 153.92 15.94 140.89 MWD 0.95 16.85 157.97 16.23 140.92 MWD 0.97 17.31 162.02 16.53 140.95 MWD 0.99 17.78 166.07 16.82 140.98 MWD 1.01 18.24 170.13 17.11 141.00 MWD 1.03 18.70 174.18 17.41 141.03 MWD 1.05 19.17 178.23 17.70 141.05 MWD 1.08 19.63 182.29 18.00 141.08 MWD 1.10 20.09 186.34 18.29 141.10 MWD 1.12 20.56 190.40 18.59 141.12 MWD 1.14 21.02 194.45 18.89 141.14 MWD 1.17 21.49 198.51 19.18 141.16 MWD 1.19 21.95 202.56 19.48 141.18 MWD 1.21 22.42 206.62 19.78 141.19 MWD 1.24 22.88 210.68 20.07 141.21 MWD 1.26 23.35 214.73 20.37 141.23 MWD 1.29 23.81 218.79 20.67 141.24 MWD 1.31 24.27 222.84 20.96 141.26 MWD 1.34 24.74 226.90 21.26 141.27 MWD 1.36 25.21 230.96 21.56 141.29 MWD 1.39 25.67 235.02 21.86 141.30 MWD 1.42 26.14 239.07 22.15 141.31 MWD 1.44 26.60 243.13 22.45 141.33 MWD 1.47 27.07 247.19 22.75 141.34 MWD 1.50 27.53 251.25 23.05 141.35 MWD OR'~~Pß'11 ..~ ~ ,,~. .~ :~ ¡ ..',.,~ .. ¡ L. ~ ~ ':' .V, .".c!it! ) Baker Hughes INTEQ ) Error Ellipse Survey Report Company:ConocoPhillipsAlaska, Inc. Date: 12/9/2002 Time: 11 :35:24 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 17, True North Site: Pad 2G Vertical (TVD) Reference: Doyon 141(new) 131.2 Well: 17 Section (VS) Reference: Well (O.OON,O.OOE, 141.57Azi) Wellpath:2G-17 Version#2 Survey Calculation Method:. .MinimumCUrvature Db: . Oracle Pösition uncertainty a~d bias at survey station Läteral---~---> V ertical,;.-~-~-> AlIuncert al 0 tiesa1, 6 stan dard deviatio ili gh s ide-----> Magl1~ .Semi,;maj oSemi~ mi 0 or MD Ind Azim TVD Uoc. Bias Uric~ BiasUoc; Bias of BiasVoc. U oc.Åzi mu tli'ool ft deg deg ft ft ft ft ft ft ft ft ft ft deg 7700.00 70.76 141.98 3739.38 56.18 -0.27 255.29 27.73 51.62 1.52 28.00 255.30 23.34 141.36 MWD 7800.00 70.76 141.98 3772.33 57.08 -0.27 259.35 28.19 52.47 1.55 28.47 259.36 23.64 141.37 MWD 7900.00 70.76 141.98 3805.28 57.98 -0.27 263.40 28.65 53.32 1.58 28.93 263.42 23.94 141.38 MWD 8000.00 70.76 141.98 3838.24 58.88 -0.27 267.46 29.11 54.17 1.61 29.40 267.48 24.24 141.39 MWD 8100.00 70.76 141.98 3871.19 59.78 -0.27 271.52 29.57 55.02 1.64 29.86 271.54 24.54 141.40 MWD 8200.00 70.76 141.98 3904.15 60.68 -0.27 275.58 30.02 55.86 1.67 30.33 275.59 24.84 141.41 MWD 8300.00 70.76 141.98 3937.10 61.58 -0.27 279.64 30.48 56.71 1.69 30.80 279.65 25.14 141.42 MWD 8400.00 70.76 141.98 3970.05 62.48 -0.27 283.70 30.94 57.56 1.72 31.26 283.71 25.43 141.43 MWD 8500.00 70.76 141.98 4003.01 63.38 -0.27 287.76 31 .40 58.41 1.75 31.73 287.77 25.73 141.44 MWD 8600.00 70.76 141.98 4035.96 64.28 -0.27 291.81 31.86 59.26 1.78 32.20 291.83 26.03 141.45 MWD 8700.00 70.76 141.98 4068.91 65.18 -0.27 295.87 32.32 60.11 1.81 32.67 295.89 26.33 141.46 MWD 8800.00 70.76 141.98 4101.87 66.07 -0.27 299.93 32.78 60.96 1.85 33.13 299.94 26.63 141.47 MWD 8900.00 70.76 141.98 4134.82 66.97 -0.27 303.99 33.24 61.81 1.88 33.60 304.00 26.93 141.47 MWD 9000.00 70.76 141.98 4167.78 67.87 -0.27 308.05 33.70 62.66 1.91 34.07 308.06 27.23 141.48 MWD 9100.00 70.76 141.98 4200.73 68.77 -0.27 312.11 34.15 63.51 1.94 34.54 312.12 27.53 141.49 MWD 9200.00 70.76 141.98 4233.68 69.67 -0.27 316.17 34.61 64.36 1.97 35.01 316.18 27.83 141.50 MWD 9300.00 70.76 141.98 4266.64 70.57 -0.27 320.23 35.07 65.21 2.00 35.47 320.24 28.13 141.50 MWD 9400.00 70.76 141.98 4299.59 71.47 -0.27 324.29 35.53 66.06 2.03 35.94 324.30 28.43 141.51 MWD 9500.00 70.76 141.98 4332.54 72.37 -0.27 328.35 35.99 66.91 2.07 36.41 328.36 28.73 141.52 MWD 9600.00 70.76 141.98 4365.50 73.27 -0.27 332.41 36.45 67.76 2.10 36.88 332.42 29.02 141.52 MWD 9700.00 70.76 141.98 4398.45 74.17 -0.27 336.47 36.91 68.61 2.13 37.35 336.48 29.32 141.53 MWD 9800.00 70.76 141 .98 4431.40 75.07 -0.27 340.52 37.37 69.46 2.17 37.82 340.53 29.62 141.54 MWD 9900.00 70.76 141.98 4464.36 75.97 -0.27 344.58 37.83 70.31 2.20 38.29 344.59 29.92 141.54 MWD 10000.00 70.76 141.98 4497.31 76.87 -0.27 348.64 38.29 71.16 2.24 38.76 348.65 30.22 141.55 MWD 10100.00 70.76 141.98 4530.27 77.77 -0.27 352.70 38.74 72.01 2.27 39.23 352.71 30.52 141.56 MWD 10200.00 70.76 141.98 4563.22 78.67 -0.27 356.76 39.20 72.86 2.30 39.70 356.77 30.82 141.56 MWD 10300.00 70.76 141.98 4596.17 79.57 -0.27 360.82 39.66 73.71 2.34 40.17 360.83 31.12 141.57 MWD 10400.00 70.76 141.98 4629.13 80.47 -0.27 364.88 40.12 74.56 2.37 40.64 364.89 31.42 141.57 MWD 10500.00 70.76 141.98 4662.08 81.37 -0.27 368.94 40.58 75.41 2.41 41.11 368.95 31.72 141.58 MWD 10600.00 70.76 141.98 4695.03 82.27 -0.27 373.00 41.04 76.26 2.45 41.58 373.01 32.02 141.58 MWD 10700.00 70.76 141.98 4727.99 83.17 -0.27 377.06 41.50 77.11 2.48 42.05 377.07 32.32 141.59 MWD 10800.00 70.76 141.98 4760.94 84.07 -0.27 381. 12 41.96 77.96 2.52 42.52 381.13 32.62 141.59 MWD 10900.00 70.76 141.98 4793.90 84.97 -0.27 385.18 42.42 78.81 2.56 42.99 385.19 32.92 141.60 MWD 11000.00 70.76 141.98 4826.85 85.87 -0.27 389.24 42.87 79.66 2.59 43.46 389.25 33.22 141.60 MWD 11100.00 70.76 141.98 4859.80 86.77 -0.27 393.30 43.33 80.51 2.63 43.93 393.31 33.52 141.61 MWD 11200.00 70.76 141.98 4892.76 87.67 -0.27 397.36 43.79 81.36 2.67 44.40 397.37 33.82 141.61 MWD 11300.00 70.76 141.98 4925.71 88.57 -0.27 401.42 44.25 82.21 2.71 44.87 401.43 34.13 141.62 MWD 11400.00 70.76 141.98 4958.66 89.47 -0.27 405.48 44.71 83.06 2.74 45.35 405.49 34.43 141.62 MWD 11500.00 70.76 141.98 4991.62 90.37 -0.27 409.54 45.17 83.91 2.78 45.82 409.55 34.73 141.63 MWD 11600.00 70.76 141.98 5024.57 91.27 -0.27 413.60 45.63 84.76 2.82 46.29 413.61 35.03 141.63 MWD 11700.00 70.76 141.98 5057.53 92.17 -0.27 417.66 46.09 85.61 2.86 46.76 417.67 35.33 141.63 MWD 11800.00 70.76 141.98 5090.48 93.07 -0.27 421.72 46.55 86.46 2.90 47.24 421.73 35.63 141.64 MWD 11900.00 70.76 141.98 5123.43 93.97 -0.27 425.78 47.00 87.31 2.94 47.71 425.79 35.93 141.64 MWD 12000.00 70.76 141.98 5156.39 94.87 -0.27 429.84 47.46 88.16 2.98 48.18 429.85 36.23 141.65 MWD 12100.00 70.76 141.98 5189.34 95.77 -0.27 433.90 47.92 89.01 3.02 48.65 433.91 36.53 141.65 MWD 12200.00 70.76 141.98 5222.29 96.67 -0.27 437.96 48.38 89.86 3.06 49.13 437.97 36.83 141.65 MWD 12300.00 70.76 141.98 5255.25 97.57 -0.27 442.02 48.84 90.71 3.10 49.60 442.03 37.13 141.66 MWD 12400.00 70.76 141.98 5288.20 98.47 -0.27 446.08 49.30 91.56 3.14 50.07 446.09 37.43 141.66 MWD 12500.00 70.76 141.98 5321.15 99.37 -0.27 450.14 49.76 92.41 3.18 50.55 450.15 37.73 141.67 MWD 12600.00 70.76 141.98 5354.11 100.27 -0.27 454.20 50.22 93.26 3.22 51.02 454.21 38.03 141.67 MWD 12700.00 70.76 141.98 5387.06 101.17 -0.27 458.26 50.68 94.11 3.27 51.50 458.27 38.33 141.67 MWD 12800.00 70.76 141.98 5420.02 102.07 -0.27 462.32 51.14 94.96 3.31 51.97 462.33 38.63 141.68 MWD 12900.00 69.56 141.98 5453.57 102.99 -0.07 466.20 51.59 95.76 3.35 52.44 466.20 38.92 141.68 MWD o ''"1 '"":' LI' H I·r "~ oiL I ;'~;¡l I..; /..) !w. ) Baker Hughes INTEQ ) Error Ellipse Survey Report Company:ConocoPhillips Alaska, Inc. Date: . 12/9/2002 Time: 11 :35:24 Page: 4 Field: Kuparuk River Unit Co~ordinate(NE) Reference: Well: .17, Trlje North Site: Pad 2G Verti¢al (TVD) Reference: . Doyon 141 (new) 131,2 Well: 17 Section (VS) Reference: Well. (O.()ON,O.QOE, 141.57Azi) Wellpath:2G-17 Version#2 SUrVeyCalctilådon Method:· Minirnum Curvature Db: Oracle Position uncertainty and bi~s at survey station All uncertainties 01.6 standard deviatioBighSide-----> Lateral-----..;;'> Vertical--;'-..;-> Magn.Semi:'msj 0 Bern i-Ini n o.r MD Incl Azirn TVD Unc. Bias Unc. Bias Une. Bias of Bias Unc. . Unc~ Azimutll'ool ft deg deg ft ft ft ft ft ft .ft ft ft ft deg 13000.00 67.56 141.98 5490.12 103.72 0.26 469.62 52.04 96.43 3.40 52.91 469.62 39.18 141.68 MWD 13100.00 65.56 141.98 5529.91 104.32 0.60 472.99 52.47 97.09 3.46 53.36 472.99 39.46 141.69 MWD 13200.00 63.56 141.98 5572.87 104.78 0.94 476.30 52.89 97.72 3.52 53.80 476.31 39.75 141.69 MWD 13300.00 61.56 141.98 5618.96 105.11 1.28 479.55 53.30 98.34 3.60 54.23 479.56 40.06 141.69 MWD 13400.00 59.56 141.98 5668.11 105.30 1.63 482.74 53.69 98.93 3.68 54.64 482.74 40.39 141.69 MWD 13500.00 57.56 141.98 5720.28 105.34 1.98 485.85 54.06 99.50 3.76 55.04 485.85 40.73 141.70 MWD 13600.00 55.56 141.98 5775.39 105.25 2.34 488.87 54.42 100.05 3.86 55.42 488.88 41.08 141.70 MWD 13700.00 55.00 141.98 5832.64 105.71 2.44 492.04 54.77 100.62 3.97 55.80 492.05 41.47 141.70 MWD 13800.00 55.00 141.98 5889.99 106.51 2.44 495.57 55.11 101.27 4.07 56.17 495.57 41.93 141.71 MWD 13900.00 55.00 141.98 5947.35 107.30 2.44 499.09 55.46 101.93 4.18 56.54 499.10 42.39 141.71 MWD 14000.00 55.00 141.98 6004.71 108.10 2.44 502.61 55.80 102.58 4.29 56.92 502.62 42.84 141.71 MWD 14100.00 55.00 141.98 6062.07 108.89 2.44 506.14 56.15 103.23 4.39 57.29 506.15 43.30 141.72 MWD 14200.00 55.00 141.98 6119.43 109.68 2.44 509.67 56.49 103.88 4.50 57.67 509.67 43.76 141.72 MWD 14300.00 55.00 141.98 6176.78 110.48 2.44 513.19 56.84 104.53 4.61 58.05 513.20 44.22 141.72 MWD 14400.00 55.00 141.98 6234.14 111.27 2.44 516.72 57.18 105.18 4.72 58.42 516.73 44.67 141.73 MWD 14500.00 55.00 141.98 6291.50 112.07 2.44 520.25 57.53 105.83 4.83 58.80 520.25 45.13 141.73 MWD 14600.00 55.00 141.98 6348.86 112.86 2.44 523.78 57.87 106.49 4.95 59.18 523.78 45.59 141.73 MWD 14700.00 55.00 141.98 6406.21 113.66 2.44 527.31 58.22 107.14 5.06 59.56 527.31 46.04 141.73 MWD 14769.22 55.00 141.98 6445.92 114.21 2.44 529.75 58.46 107.59 5.14 59.82 529.76 46.36 141.74 MWD o ) ~ ; i ,\ .~ ; ~:, 3 j IJ i~ L Company: ConocoPhillipsAlaska, Inc. Field: KuparukRiver Unit Reference Site: Påd2G Reference Well: 17 Reference Wellpatl2G:-17·Version#2 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method'sllD Interval: 50.00 ft Depth Range: 0.00 to 14769.22 ft Maximum Radius5000.00 ft ) Baker Hughes INTEQ ) Anticollision Report Date: >12/9/2002 Time: 11:33:41 1 Co:-ordinate(NE) Reference: Well: 17, True Nbrth Ver.tical (TVD) Reference: . Doyon 141 (new) 131.2 Reference: Error Model: Scan Method: Error Surface: Db: Oracle Plan: 2G-17 Version#2 & NOT PLANNED J~OGf ISCWSA Ellipse Trav Cylinder North Ellipse Principal: Yes Plan: 2G-17 Version#2 Date Composed: Version: Tied-to: 12/9/2002 2 From Surface Summary <-----.---~-~--~-~---.;.. ()ffset", ellpat h ~---.---.;---~~.~._~..:-.;> Site . Well Wellpath 10 11 12 1 13 14 15 16 2 3 4 5 6 7 8 9 2G-10 VO 2G-11 VO 2G-12 VO 2G-01 VO 2G-13 VO 2G-14 VO 2G-15 VO 2G-16 VO 2G-02 VO 2G-03 VO 2G-04 VO 2G-05 VO 2G-06 VO 2G-07 VO 2G-08 VO 2G-09 VO Reference Offset Ctr-Ctr No':'Go· . Aliowable MD 1\1D DistanceArea Deviation· Warning ft ft ft ft ft / 349.80 350.00 20.90 4.16 16.75 Pass: Major Risk 651.08 650.00 35.22 7.89 27.33 Pass: Major Risk 902.22 900.00 92.34 12.21 80.14 Pass: Major Risk 341.44 350.00 707.05 4.07 702.98 Pass: Major Risk 391.67 400.00 370.52 4.65 365.87 Pass: Major Risk 345.39 350.00 361.65 4.11 357.54 Pass: Major Risk 344.94 350.00 357.99 4.11 353.89 Pass: Major Risk 344.55 350.00 366.91 4.10 362.81 Pass: Major Risk 341.09 350.00 760.91 4.06 756.85 Pass: Major Risk 340.73 350.00 816.18 4.06 812.12 Pass: Major Risk 340.40 350.00 871.15 4.06 867.10 Pass: Major Risk 343.36 350.00 812.32 4.09 808.23 Pass: Major Risk 387.50 400.00 749.27 4.60 744.67 Pass: Major Risk 388.28 400.00 692.28 4.61 687.67 Pass: Major Risk 344.54 350.00 632.98 4.10 628.88 Pass: Major Risk 349.31 350.00 80.37 4.15 76.22 Pass: Major Risk Pad 2G Pad 2G Pad 2G Pad 2G Pad 2G Pad 2G Pad 2G Pad 2G Pad 2G Pad 2G Pad 2G Pad 2G Pad 2G Pad 2G Pad 2G Pad 2G OR' 11~ ~ P1 ~ ~ l ' & .i' ....)' :,1 /,1 ~ ..~I¡ ,. I ;' . , ..* ~~ :~ 6 V ë'~~ ¡~~¢ ) ) ConocoPhillips Alaska, Inc. Structure : Pad 2G Well : 17 .' ConocoPhillips i-ë·~~·~t;·~ï-bY-·b·;¡~h·~~ï "·.....··_·F-~;·;-..P··-R·~-iiï~ i Dote plotted: 6-Dec-2002 ¡ Plot Reference is 20-17 VClr!ilion~2. i Coordinates arc In feet rcferCIMco slot ~17. i I True VertIcal Depths ore rCl1oronca Est RKB (D-1+1).1 ~ ! Field : Kuparuk River Unit Lacation: North Slope, Alaska ......................................._._....................._...................................,1 IN'rEv ~ ~ '~\ \ 330 \\ 3io.,. \ \ \ \ \ "\ TRUE NORTH ~ c:::::::J 350 0 10 340 20 300 30 40 50 60 70 280 80 270 90 260 100 250 1 1 0 240 120 230 130 220 140 210 150 200 160 190 180 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well O ¡~~) n,¡:1:~ì n "~,~ '1 S .".,) 'I l¡' I I"ì " ¡~. .&: 4. \ , ,) i* ., 'I I" , , ] q (L ~i ;' ,i ,J -,',.¡ { - ~,~ .. ..' .\lor.! ) ) ~"ë;~~i~'d"bŸ"b;;;i~'h'~'~ï'" For'; ï~"'R'~iïi;'"'' Date platled: 6-Dec-2002 ConocoPhillips Alaska, Inc. Structure: Pad 2G Well : 17 "fp./ ConocoPhillips I Plot Reforenco 1s 2G-17 VerslonN2. ! Coordinotce orc in 'Clet reference slot *17. I ¡True Vartk:ol Depths ora referanc:ø Est RK8 (D-141).1 i IIi1I i ¡ IIfILs i Field : Kuparuk River Unit Location: North Slope, East (feet) - > 4800 5200 5600 7600 i i.... 1600 ~ 2400 4400 2000 2800 3200 3600 4000 '~~' 430'0 ,*\ 4500 , "" 2900\"".4700 '\ ."..", 4900 \ "·,5100 3100\,5300 \ . "".5500 , , "·,5700 , .'* 5900 3300' , ..'."" 6100 \ ·'-..6300 , ŒÐ , 3500ill. , , , \ 3700 'ill. , , , , 3900 \.. , , , , 4100 \, \ , , , 4300 \. , 4500 6000 6400 6800 7200 4700 , '<1\ , , \ , 4900 \. , , , , 51 00 \. , , , , 5300 \ ,JIt , , , , 5500 \. , , 5700 '.. \ 5900 '", , 6100 \ '" , \ 6300 '" \ 'till \\~~',.i 8000 8400 - 2400 - 2800 - 3200 - 3600 - 4000 - 4400 - 4800 - 5200 - 5600 (J') 0 c - 6000 -+ ::r ,......... -to, - 6400 ([) S. '--" - 6800 I V - 7200 - 7600 - 8000 - 8400 - 8800 - 9200 - 9600 - 1 0000 - 1 0400 ................................... For: P Reilly ¡ Cole plalled: 6-0eo-2002 Croatod by bmichaø! Pial Reference Is 2G-17 VersianN2. Caordinalð~ arð in fðal rafere.nce alal N17. True Vertical Deplhs arc referencCl Est RK8 (0-141).: 1IIii. BM.s INIEV "--.-...-. _...~_.._---_...- 500 I~ 600 700 800 % ~ 4100 \ \, 4300 . 4500 @ ') ) ConocoPhillips Alaska, Inc. Structure : Pad 2G Well : 17 '\t¥'~,/ ConocoPhillips Field : Kuparuk River Unit Location: North Slope, East (feet) -> 900 1000 1400 2100 , ~\ '''',1900 ~\,~1 ~? \ \. \ " '\ \ '\ \. , \ 5500"\\, \ 23~ " \, \\ ".', 5700\ \\" ',\. ,\2100 \\ 2s"'cJ<z" \. .'\', 590~ .".. " \. \ , , '\' , \ ,,\ " '*, 61 00""'\ 270o.~, \ \.' ,,"~. , , ", \ ~. ~ \ 6300 [J]] \~ 2900"'\\00 \ \-. \~ 31 00 ~ ," \~ ,., , ,\. '\ 3300 '\ , .\ ',\ , ,\. 2500*,,3500 " .'\ , ,.". , ,\.. " \.3700 " \ , " " \ " \ , , \. 3900 , \ " \ " " , \ 2700"-" ",\4100 " " , \ '~ ~ 1500 1600 1700 1800 1900 2000 1100 1200 1300 ib_._~~_ ...._--....~-~~-~--..__........ ...............~ ~ - 700 .~ O'i'GfI"'~l _ f;' ~.' ~ , ~" ,ð" ~ ~;~ !):.-:, ¡1 . I iA~,¡) ",,? 2200 - 500 - 600 - 800 - 900 - 1000 - 1100 - 1200 - 1300 (J') 0 1: - 1400 -+- :r ,--., ....... - 1500 CD ~ -...- - 1600 I V - 1700 - 1800 - 1900 - 2000 - 2100 - 2200 - 2300 - 2400 - 2500 ') ) ConocoPhillips Alaska, Inc. "'W"/ ConocoPhillips For: P Reilly Date plotted: 6-Dcc-2002 Plot RcfClrtll'lca i:s 2G- 1 7 Version*2. Coordinates orc in feet rafcrcncCl :slot *17. Deptho ora reference! Est RK8 (D-141). Structure : Pad 2G Well: 17 Field: Kuparuk River Unit Location: North Slope, I!Iiill 'f1IiLs ~ East (feet) -> 240 280 320 360 480 520 I 560 40 40 80 120 160 200 I 400 440 ~300 ""...!.:'~ ~...... ..).~.?,~..... ...........?.:~.~ ,~300 ~'~700 500 ' ,..::-:zoo 39~~ ,900 30~.. \\' , , ~\.. '.1100 900 410(jl\\ ..'" ~OO \' , "" 1 1 00 \. ' " 1700 "'-\\\, 430;' 1 300 \ \."\...., \ '".. \ \ ' , \ÌIt 1900 \. 1 306\ ' , \ "\.', \'\ ..\.,.~\\o"'" 1500 \ 21 00 \' , <1(, \', '\ 1500. \\ ' , \ . ...\. 4700 " \ "'" >\ ' , \, .~, ì \' '\ 2300 '\~ 1700 "" \, \~<,', 1700 \ \ , .... \ \ " " \ 4900\, " " \ '\ "" " \. \\'"",, '\, \ \\' \ , \ 2500 \ \ '*. ~OO , , \ \, \\ .'" ' , \ ' \5100 '" '... \ '" \ \\ " '\ \\ "'- " \ \ '... '\ \\ \ 1900 \\ " " \\ \. " \ \. 2100 ' " '\ " \.. 5300 '\ '... \ \ , , \ \ '\ \, ''\ % ~ ........... ............,.......?.~~.~.. ........,.......... ....................,...?~~~ ........ ................... .............. ........... .....,............... .......,~~.o.~ .........Q) , \ \ \ \\ \ \, \ ~ 2700 \§ ORg·~,o ,~ ,'1 ¡J I{ ~ '. ":1 'I '..... ;~I 1 ~~A ..~ 600 640 120 - 80 - 40 - 0 - 40 - 80 - 120 - 160 - 200 (J') - 240 0 C -+- ~ - 280 -----. ....... CD ~ - 320 '--" I V - 360 - 400 - 440 - 480 - 520 - 560 - 600 - 640 <ð- - 680 J1 f .,:I .j ) ) 2G-17 DrillinQ Hazards Summar v (to be posted in Rig Floor Doghouse Prior to Spud) Surface CasinQ Interval Event Conductor Broach Well Collision G ravel and sand sloughing Permafrost Hydrates Shoe Fracture/Lost Returns during cement job Risk Level Low Low Low Low Low Intermediate CasinQ Interval Event Shale Stability in HRZ Tight hole / Packoff problems Lost Circulation Hole cleaning in long, high angle tangent Risk Level High Low Low Moderate /1 Production CasinQ Interval Event Lost Circulation High ECD and swabbing if higher MW is required Stuck Pipe Risk Level High High Moderate M itiqation Strateqy Monitor cellar continuously during interval. Careful well planning and surveying, adherence to anti-collision policy Elevated mud viscosity from spud; Hi dens sweeps on high angle holes. Controlled drilling, reduced pump rates, higher mud weights, cold mix water and mud, lower viscosities, and lecithin additions as needed Reduced pump rates, and lightweight tail cement Mitiqation Strateqy Control with higher mud weight and proper drilling practices Good hole cleaning practices Good drilling practices. Stay within ECD hardlines Good drilling practices. High drill string RPM. Sweeps as needed. Careful PWD monitoring. /' Mitiqation Strateqy Good drilling practices. LCM as needed. Stay within ECD hardlines Bring pumps on slowly. RIH slowly to avoid j surge. Good drilling practices. Maintain tight mud tolerances for good wall cake. 2G-17 Drilling Hazards Summary. doc prepared by Pat Reilly 12/11/02 Page 1 of 1 ORI"'" r ..~ ¡1 ~~ f ¡ .'. ..' II 1 \..~ ,.J.':I . ' fJ f J ~l .', ,,' .. ~..A.:¥~· 1 Ü., ,1'0.1''' Kuparuk 2G-17 Pro ~)lcer Completion Schematic 3 %" Topset 16"x30" insulated conductor @ +/- 80' MD TAM 9-518" Port Collar Stnd Grade BTC Threads (+/- 1000' MDffVD) Surface csg. 9-5/8" 40.0# L-80 BTCM +/- 5763' MD /3101' TVD 200' TVD Below Base West Sak / ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ j ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ oIIIIIIIIt\ 12' Pup (Critical) Intermediate csg. I 7" 26.0# L-80 BTCM +/- 14059' MD /6039' TVD 100' MD Below Base HRZ -60' MD Above K1 (Stop Before K1 & Minimize Rat Hole) " ~ ..... · .)~ ·P·····h· ~I·I·· Conoco: i.l· ,IPS ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I 3-1/2" Baker 'CMU' sliding sleeve w/2.813" Cameo No-Go profile, EUE8RD ~ box x pin. 3-1/2" x 6' L-80 EUE8RD handling pups installed above I ~3.112" Cameo 'D' nipple w/2.75" No-Go profile. 3-112" x ;;:SO EUESRD ~ handling pup installed above. 3-1/2" x 6' L-80 EUE8RD handling pup below ~ 11III ~ I 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing ~ I 5.125" x 3" Baker locator sub ~ J - I Production Liner 3-1/2" 9.3# L-80 SLHT +/-14769' MD /6446' TVD .. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ '" ~ I ~ I ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ..... ~ r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ 3-1/2" FMC Gen V Tubing Hanger, 3-1/2" L-80 EUE8RD pin down Special Drift 2.91" 3-1/2" 9.3# L-80 EUE8RD Spaeeout Pups as Required Special Drift 2.91" 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface Special Drift 2.91" 3-1/2" Camco DS Landing Nipple with 2.875" ID No-Go profile set @ +/- 500' MD. Use of port collar at the discretion of the drilling team. GLM Placement: Valves #1-?: 3-Y:z" x 1" KBUG Place gas-lift mandrels at the following depths: TVD Approximate MD TBD TBD TBD TBD TBD TBD TBD TBD TBD TBD 3-1/2" x 1-1/2" 'MMG' GLM w/ DCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 4-1/2" Baker GBH-22 casing seal assembly w/12' stroke, 3-1/2" L-80 EUE8RD box up -Liner Assembly (run on drillpipeJ. 150' of liner overlap Baker 7" x 5" 'ZXP' Liner Top Isolation Packer with HR profile Baker 7" x 5" 'Flexlock Double Grip Liner Hanger Baker 80-40 17' Seal Bore Extension XO Sub, 5" BTC pin x 3-1/2" SLHT pin 3-1/2" 9.3# L-80 SLHT liner as needed 3-1/2" Baker Landing Collar 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Collar 1 jt 3-1/2" 9.3# L-80 SLHT tubing - 3-1/2" Baker Float ShoeO. R'~ .. ,:~ ../.~,;l'j , .t ·r)........I· !Ì I ,,", ,1 j b'J I~! .~I ':' .! ~ I,., ' i \'A ,f ij \ I t· :1.\"," PJR,12/10/02 Rig: Doyon 141 Location: Kuparuk Client: ConocoPhillips Alaska Revision Date: 12/10/2002 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6012 email: martin13@slb.com ~! ~ ~ ~. 1 ~ ~... I .' < Toe at Surface Previous Csg. < 16",62.6# casing at 80' MD < Base of Permafrost at 1,606' MD (1,531'lVD) < Top of Tail at 2,778' MD < 95/8",40.0# casing in 121/4" OH TO at 5,763' MD (3,101' lVD) Mark of Schlumberger Schlumberger ') P~n.·~~R·~i..·.·~:rélimf~~rY:9~p.·[;1~~¡gÔi· . .. ·.......1·· ~:5/a'~$ûr1áþèGas:il')g·· . Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 3500/0 excess in the permafrost and 45% excess below the permafrost. The top of the tail slurry is designed to be at 2,7781 MD. Lead Slurrv Minimum pump time: 330 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.28 ft3/sk 0.7632 fe/ft x (80') x 1.00 (no excess) = 61.1 fe 0.3132 ft3/ft x (1606' - 80') x 4.50 (3500/0 excess) = 2150.7 fe 0.3132 fe/ft x (2778' - 1606') x 1.45 (450/0 excess) = 532.3 fe 61.1 fe + 2150.7 fe+ 532.3 fe = 2744.1 fe 2744.1 ft3/ 4.28 fe/sk = 641.1 sks Round up to 650 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv Minimum pump time: 230 min. (pump time plus 90 min.) LiteCRETE @ 12.0 ppg - 2.40 ft3/sk 0.3132 fe/ft x (5763' - 2778') x 1.45 (45% excess) = 0.4257 fe/ft x 80' (Shoe Joint) = 1355.6 fe + 34.1 fe = 1389.7 ft3/ 2.4 ft3/sk = Round up to 580 sks 1355.6 fe 34.1 fe 1389.7 fe 579 sks BHST = 68°F, Estimated BHCT = 74°F. (BHST calculated using a gradient of 2.4°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5 50 10.0 10.0 Drop Bottom Plug 3.0 13.0 MudPUSH XL 5 50 10.0 23.0 Lead Slurry 5 495 99.0 122.0 Tail Slurry 5 248 49.6 171.6 Drop Top Plug 3.0 174.6 Displacement 5 411 82.2 256.8 Slow Rate 3 20 6.7 263.5 MUD REMOVAL Recommended Mud Properties: 9.4 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* XL, Pv:::::: 17-21, T y:::::: 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. OR ..11"'\~"'ï'1J , . ~ r ,,' ;Î j '.' " /:-.'1, '.. 'I ~, "",Ä# ~ .. ~,¡, Schlumbepgep ') · '~;~Æ~!~Î~~b~[~~~~jgñ;;' I Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: Kuparuk Client: ConocoPhillips Alaska Revision Date: 12/10/2002 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6012 email: martin13@slb.com I II I· ',;;, ! r Volume Calculations and Cement Systems Volumes are based on 75% excess. Tail slurry is designed for 800' shoe tack. Tail Slurrv Minimum thickening time: 210 min. (Pump time plus 90 min.) 15.8 ppg Class G + 0.2%046, 0.3%065, 0.1 %0800 - 1.17 ft3/sk (adjust retarder to give desired thickening time) 0.1268 fe/ft x 800' x 1.75 (75% excess) = 0.2086 fe/ft x 80' (Shoe Joint) = 177.5 fe + 16.7 fe = 194.2 ft3/ 1.17 ft3/sk = Round up to 170 sks 177.5 fe 16.7 fe 194.2 fe 166.0 sks I ~ Previous Csg. L < 9 5/8", 40.0# casing at 5,763' MD BHST = 138°F, Estimated BHCT = 108°F. (BHST calculated using a gradient of 2.4°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5 40 8.0 8.0 Drop Bottom Plug 3.0 11.0 MudPUSH XL 5 50 10.0 21.0 . Tail Slurry 5 35 7.0 28.0 Drop Top Plug 3.0 31.0 Displacement 5 499 99.8 130.8 Slow Rate 3 20 6.7 137.5 < Top of Tail at 13,259' MD MUD REMOVAL < 7",29.0# casing in 8 1/2" OH Recommended Mud Properties: 10.6 ppg, Pv < 20, T y < 20. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* XL, Pv::= 19-22, T y ::= 22-29 Centralizers: Recommend 1.5 per joint across zones of interest for proper cement placement. TO at 14,059' MD (6,039' lVD) Mark of Schlumberger '1''-\ .\.1' ~", ~ø 'I . Vljili ...,:,¡:/~ ) , ··1 Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: Kuparuk Client: ConocoPhillips Alaska Revision Date: 12/10/2002 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6012 email: martin13@slb.com Schlumbepgep Volume Calculations and Cement Systems Volumes are based on 60% excess. Displacement is calculated with a 3.5"- 13.3# drill string. Tail Slurrv Minimum thickening time: 150 min. (pump time plus 90 min.) GasBLOK wi Class G + 3% D53, 2 gps D600G, 0.1 % 0800, 0.2% D047, 0.6% D065 @ 15.8 ppg - 1.2 ft3/sk Top of Tail at < 13,709' MD Liner Cap: 0.2148 fe/ft x 200' x 1.00 (no excess) = Liner Lap: 0.1480 fe/ft x (14059' -13909') x 1.00 (no excess) = Annular Volume: 0.1817 fe/ft x (14769' - 14059') x 1.60 (60% excess) = Shoe Volume: 0.0488 fe/ft x 80' x 1.00 (no excess) = Totals: 43 ft3 + 22.2 fe + 206.4 ft3 + 3.9 fe = 275.5 fel 1.2 ft3/sk = Round up to 230 sks < Liner Top at 13,909' MD 43fe 22.2 fe 206.4 fe 3.9 fe 275.5 fe 229.6 sks BHST = 148°F, Estimated BHCT = 115°F. (BHST calculated using a gradient of 2.4°F/100 ft. below the permafrost) Previous Csg. 7",26.0# casing at 14,059' MD PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 3 30 10.0 10.0 MudPUSH XL 3 50 16.7 26.7 < 3 1/2", 9.3# casing Tail Slurry 3 49 16.3 43.0 in 6 3/4" OH Drop Top Plug 3.0 46.0 Displacement 3 100 33.3 79.3 Slow Rate 2 10 5.0 84.3 MUD REMOVAL Recommended Mud Properties: 10.5 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* XL, Pv ::= 19-22, T y ::= 22-29 Centralizers: Recommend 1 per joint from 13909' MD to TD for proper cement placement. ... TO at 14,769' MD (6,446' TVD) Mark of Schlumberger Or;) ,i' ¡: '.'; " ,:ì ¡ \~~ ~ ¡~ .~ 'bo"¡ ;; ~ ~ ') Randy Thomas ) Greater Kuparuk Team Leader < Drilling & Wells ConocriP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 December 12,2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Permit to Drill 2G-17 RECEIVED DEC 122002 I Dear Commissioner: Alaska Oil & Gas Cons. Commission Anchorage ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill and onshore development producer KRU 2G-17. The well will be drilled and completed using Doyon 141. Please utilize documents on file for this rig. Logs anticipated to be run on this well include real time MWD, LWD and Gamma ray in the surface hole, MWD, LWD, GR/Res in the intermediate hole and real time MWD, LWD, GR/Res, Den/Neutron in the production hole. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 2G, or hauled to an approved Prudhoe or GKA Class II disposal well. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report (20 AAC 25.070) Sharon Allsup-Drake, Drilling Technologist 263-4612 B) Geologic Data and Logs (20 AAC.25.071) Doug Knock, Geologist 265-6506 If you have any questions or require further information, please contact Pat Reilly at (907) 265-6048. Sincerely, Ç\ ~ ~ R.T~ Greater Kuparuk Team Leader CPAI Drilling " ,. . Î .~ __-"__-·0-____< - T 5000 Dollars ¡.' Manhattan Bank USA, N.A. V. aI. Id. Up.. 0... ... . ~'. /' _ U. SE Chase k.DE19711 2... ./ ...-- CHA ~.w"'. 0"" ~æ'O'_ .-., j /Í _ '" '/. '-, _t(¿lr[~c_dÉ-~'_' _~__ .. MEMO 00... 2 7 2 5 711' ~ 0 ~ 0 ':0:1 . .00 . ~ ~I: 2.aOO A s.c..v"",,,,., DOLLARS l.!J ~~_. 6~~~~6~E" 5tA1é cF AutstA !AcL~C - (,¡~ !14^l~d ckl!ãv; ¿~'þ~/;cC' I $ ¡CO. ex:) 1010 lìc//J" (., /' (. 2 "") ..-?'/"; ;> D~E ~éLµ~þ2r ~,-- ( 62-14/311 S. K. ALLSUP-DRAKE PHILLIPS PETROLEUM COMPANY 711 G ST. ANCHORAGE AK 99501 -~ !:'.í2S\<a Oil &. Gas Cons. Commission Þ,ncnoi89ß RECEíVED DEC \ 2 2002 ~-, 2 ~¡,~.. ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY . C P,A WELL NAME I)I<Vt 2 a. -/7 PROGRAM: Exp _ Dev.2S... Redrll _ Re-Enter _ Serv ~ Wellbore seg _ FIELD & POOL L¡ c¡ ~ / ó <:) INIT CLASS LJ~J/ / ... ð/I GEOL AREA f" 70 UNIT# /1/ ç ð ON/OFF SHORE ~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . Y N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. W ell located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. W ell located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N /.I) h), _ J 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N nI¿ ~ t;2-- 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . Y N (Service Well Only) 13. Well located wlin area & strata authorized by injection order #_ YY µ ( 19 ~ (Service Well Only) 14. All wells wlin ~ mile area of review identified. . . . . . . . .. 1: N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ~ N ; l.o Ii @ ; 0 ~ I . 16. Surface casing protects all known USDWs. . . . . . . N. 4- 17. CMT vol adequate to circulate on conductor & surf csg. . . . . . N Arll?Lh ,,,,..¿..I{ e eA-c.£çç. 18. Cfv1T vol adequate to tie-in long string to surf csg. . . . . . . . ~ v 19. CMT will cover all known productive horizons. . . . . . . .. . N 20. Casing designs adequate for C, T, B & permafrost. . . . . . . N D 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . @ N ~ ø.r- ;41, 22. If a re-drill, has a 10-403 for abandonment been approved. . . . ^' II+-- 23. Adequate wellbore separation proposed.. .... . . . . . . . . . N 24. If diverter required, does 'it meet regulations. .. . . . . ... . N JA.I 25. Drilling fluid program ,schematic & equip list adequate. . . . . N ~ yv(,þ..J (l,? Ptf11 ' 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . Np t. APPR DATE ~7.' BOPE press rating appropriate; test to 5'000 psig. N (Vl ~ '3 ~5q ff( , L @ fl.. ì¡~/oz.- 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N ~c II 29. Work will occur without operation shutdown. . . . .. . . . . . ~ N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~) 31. Mechanical condition of wells within AOR verified. . . . . . . . Y-N-¡vIA- W N· ¡q, APPR DATE (Service Well Only) GEOLOGY APPR DATE {I.I- 10~7- (Exploratory Only) Rev: 10/15/02 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . .. ...... 36. Contact namelphone for weekly progress reports. ...... GEOLOGY: RP~ PETROLEUM ENGINEERING: TEM RESERVOIR ENGINEERING JDH UIC ENGINEER JBR SFD_ WGA ./ MJW G:\geology\permits\checklist.doc COMMISSIONER: COT l7/~¿}- rl;( DTS MLB 12./I~¿ ( Comments/Instructions: ) Well History File APPENDIX Infornlation of detailed nature that is not particularly gemlane to the Well Pennitling Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding infomlation, 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. **** REEL HEADER **** LDWG 03/02/10 AWS 01 **** TAPE HEADER **** LDWG 03/02/10 01 *** LIS COMMENT RECORD *** (91:bì- ~ LJ 3 115~.11 !! !! !! !!!! !! !!!!!!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 1 2 3 T. DURING C. WONG F. WENDLER D. WESTER D. HEIM F. HERBERT MWD RUN 4 MWD RUN 5 MWD RUN 6 - -- -- - - - -- - -- _ _ -- _":[QJ;LNYl1~~B~_____ _____ _ _ _~_ _n__ -___________~____________ ___§___________ _____n_ LOGGING ENGINEER: S. TUFT ON T. DURING C. WONG OPERATOR WITNESS: D. HEIM F. HERBERT D. HEIM MWD RUN 7 MWD RUN 8 MWD RUN 9 7 8 9 F. WENDLER S. TUFT ON S. DRAKE F. HERBERT D. GLADDEN D. WESTER MWD RUN 10 MWD RUN 11 MWD RUN 10 11 S. TUFTON G. SUTING D. WESTER D. WESTER JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: - . - - -."- - - - - JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: 2G-17 500292313400 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 10-FEB-03 ---------- ----- # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: 5 10N 9E DERRICK FLOOR: GROUND LEVEL: 131.60 103.60 # WELL CASING RECORD OPEN HOLE BIT SIZE (IN) DRILLERS DEPTH (FT) 108.0 5743.0 14027.0 14768.0 CASING SIZE (IN) 30.000 9.625 7.000 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 12.250 8.500 6.125 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 15' 25.530" LONG: W149 DEG 55' 46.957" LOG MEASURED FROM D.F. AT 131.6 FT. ABOVE PERM. DATUM (M. S. L.) . COMMENTS: (1) Baker Hughes INTEQ run 1, utilized Autotrak RCLS (Rotary Closed Loop System) along with RNT (Reservoir Navigation Tool) Resistivity services from 108 feet to 265 feet MD (108 to 265 feet TVD) . (2) Baker Hughes INTEQ runs 2 and 3 utilized MPR (Multiple Propagation Resistivity) and Gamma Ray with Near Bit Inclination services from 265 to 1720 feet MD (265 to 1635 feet TVD) . (3) Baker Hughes INTEQ runs 4 and 5 utilized Autotrak RCLS (Rotary Closed Loop System) along with RNT Resistivity services from 1720 feet to 1882 feet MD (1635 to 1756 feet TVD). (4) Baker Hughes INTEQ runs 6 and 7 utilized MPR (Multiple Propagation Resistivity) and Gamma Ray with Near Bit Inclination services from 1882 to 5765 feet MD (1756 to 3139 feet TVD). (5) Baker Hughes INTEQ run 8 utilized Autotrak RCLS (Rotary Closed Loop System), along with RNT Resistivity and MAP (Modular Advanced Pressure) services from 5743 feet to 14035 feet MD (3131 to 5977 feet TVD) . (6) Baker Hughes INTEQ runs 9-11 utilized the slim Advantage Porosity Logging Service (APLS) which includes the optimized Rotational Density. (ORD) , Caliper Corrected Neutron (CCN) , along with MPR (Multiple Propagation Resistivity), MAP (Modular Advanced Pressure) and Gamma Ray with Near Bit Inclination services from 14035 to 14768 feet MD (5977 to 6403 feet TVD) . REMARKS: (1) Depth of 30" Conductor Shoe Logger: 108 feet MD (108 feet TVD) . Depth of 30" Conductor Shoe Driller: 108 feet MD (108 feet TVD) . (2) The interval from 247 to 265 feet MD (247 to 265 feet TVD) was logged up to 5.5 hours after being drilled due to a trip for motor. (3) The interval from 1496 to 1540 feet MD (1453 to 1491 feet TVD) was logged up to 6.3 hours after being drilled due to a trip for motor. (4) The interval from 1681 to 1720 feet MD (1606 to 1635 feet TVD) was logged up to 7.0 hours after being drilled due to a trip for Autotrak. Please note that due to the change in Resistivity tools, from MPR to RNT, that the presentation goes from 4 resistivity 1 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY clipped curves; all bit runs merged. .5000 LDWG File Version 1.000 Extract File: FILE001.HED *** *** LIS COMMENT RECORD 1024 LDWG .001 **** FILE HEADER **** 8 bytes 132 bytes Minimum record length: Maximum record length: 148 records... Tape Subfile: 1 curves to 2 resistivity curves over the interval from 1681 - 1782 feet MD (1606 to 1682 feet TVD) . (5) The interval from 1772 to 1790 feet MD (1675 to 1688 feet TVD) was logged up to 6.9 hours after being drilled due to a trip for Autotrak. (6) The interval from 1864 to 1882 feet MD (1743 to 1756 feet TVD) was logged up to 6.4 hours after being drilled due to a trip for motor. (7) The interval from 2000 to 2039 feet MD (1835 to 1858 feet TVD) was logged up to 6.6 hours after being drilled due to a trip for motor. (8) The interval from 4072 to 4116 feet MD (2579 to 2593 feet TVD) was logged up to 3.4 hours after being drilled due to a short trip. (9) The interval from 5721 to 5765 feet MD (3124 to 3139 feet TVD) was not logged due to 9 5/8" casing. (10) Depth of 9 5/8" Casing Shoe Logger: 5754 feet MD (3135 feet TVD) . Depth of 9 5/8" Casing Shoe Driller: 5754 feet MD (3135 feet TVD) . Please note that due to the change in Resistivity tools, from MPR to RNT, that the presentation goes from 4 resistivity curves to 2 resistivity curves over the interval from 5790 - 14017 feet MD (3147 to 5967 feet TVD). (11) The interval from 14017 to 14035 feet MD (5967 to 5977 feet TVD) was not logged due to 7" casing. (12) Depth of 7" Casing Shoe Logger: 14027 feet MD (5973 feet TVD). Depth of 7" Casing Shoe Driller: 14027 feet MD (5973 feet TVD). (13) No logging occurred on Run 9 due to an MWD failure (14) The interval from 14035 to 14116 MD (5977 to 6023 feet TVD) was logged with a mad pass on Run 11 up to 19.1 hours after being drilled. (15) The interval from 14724 to 14768 feet MD (6376 to 6403 feet TVD) was not logged due to sensor-bit offset at TD. $ 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 GRAM RPD RPM RPS RPX BDCM DRHM DPEM NPCKSM ROPS GR RPD RPM RPS RPX RHOB DRHO PEF NPHI ROP GR RPD RPM RPS RPX RHOB DRHO PEF NPHI ROP ---------------------------------------------------- ODEP *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM 2g-17 5.xtf 150 ConocoPhillips Alaska, Inc. 2G-17 Kuparuk River North Slope Alaska WDFN LCC CN WN FN COUN STAT ------------------------------------ *** INFORMATION TABLE: CONS MNEM VALU # $ MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. MERGE BASE 265.0 1540.0 1720.0 1790.0 1882.0 2039.0 5765.0 14035.0 14116.0 14768.0 MERGE TOP 108.0 265.0 1540.0 1720.0 1790.0 1882.0 2039.0 5765.0 14035.0 14116.0 BIT RUN NO 1 1 1 2 2 2 2 3 4 4 # REMARKS: BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- STOP DEPTH 247.0 1496.0 1681.0 1772.0 1864.0 2000.0 5721. 0 14017.0 14044.0 14768.0 START DEPTH 108.0 247.0 1496.0 1681. 0 1772.0 1864.0 2000.0 5721. 0 14017.0 14044.0 PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD $ FET MTEM FET MTEM RPTH TCDM 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 RHOB MWD 68 1 G/C3 4 4 7 DRHO MWD 68 1 G/C3 4 4 8 PEF MWD 68 1 BN/E 4 4 9 NPHI MWD 68 1 PU-S 4 4 10 ROP MWD 68 1 FPHR 4 4 11 FET MWD 68 1 HR 4 4 12 MTEM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 1544 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 108.000000 14768.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 1609 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** o .00 .000 58.0 .0 .0 .0 .000 .000 .000 .000 SPUD MUD 8.55 .0 .0 200 .0 12.250 108.0 TOOL NUMBER ASU 51312 RNT 20027 RNT 20027 .0 .5 MSB 18704 8.25 ATK MEMORY 265.0 64.0 247.0 o 30-DEC-02 BIT RUN 1 (MWD Run 1). GR/DPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) REMARKS: # .0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOTTOM) TOOL TYPE DIRECTIONAL DUAL PROP. RESIS. GAMMA RAY TOOL STRING (TOP TO VENDOR TOOL CODE DIR DPR GR $ # # 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 247.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ START DEPTH 64.0 log header data for each bit run in separate files. 1 .2500 2 ! ! ! ! ! ! !! !! ! ! ! ! ! !! !! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE011.HED RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 2g-17.xtf 150 ConocoPhillips Alaska, I 2G-17 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RACLM 0.0 RASL RASL RACSLM 0.0 RACH RACH RACHM 0.0 RASH RASH RACSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: MSB 18704 8.25 MPR MEMORY 1540.0 247.0 # 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): 30-DEC-02 STOP DEPTH 1496.0 START DEPTH 247.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 2 .2500 3 !! !!! !! ! ! !!!!! ! ! !!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILEOI2.HED *** LIS COMMENT RECORD *** 1024 LDWG .003 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 138 records... Tape Subfile: 3 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 64.000000 247.000000 0.250000 Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 39 BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GR $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY RES IS. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # 1496.0 o .5 38.1 TOOL NUMBER DAS 7050 MPR 35083 SRIG 58019 12.250 108.0 SPUD MUD 8.85 .0 .0 200 .0 .000 .000 .000 .000 64.0 .0 .0 .0 .00 .000 .0 o BIT RUN lRR (MWD Run 2) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU WDFN 2g-17.xtf Lce 150 -------------------------------- CN WN FN COUN STAT ConocoPhillips Alaska, I 2G-17 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RACLM 0.0 RASL RASL RACSLM 0.0 RACH RACH RACHM 0.0 RASH RASH RACSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (va1ue= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 263 Tape File Start Depth 247.000000 Tape File End Depth 1496.000000 Tape File Level Spacing 0.250000 SPUD MUD 9.05 .0 .0 200 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): # 12.250 108.0 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # TOOL NUMBER DAS 7050 MPR 35083 SRIG 58019 BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. RESIS. GAMMA RAY TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GR $ # 27.8 38.9 # 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: MSB 18704 8.25 MPR MEMORY 1720.0 1496.0 1681. 0 o 31-DEC-02 STOP DEPTH 1681.0 START DEPTH 1496.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 3 .2500 4 !! !! ! !!!!!! !!!!!! !! LDWG File Version 1.000 !! !! ! !!! !! ! !!!!!! !! Extract File: FILEOI3.HED *** LIS COMMENT RECORD *** 1024 LDWG .004 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 362 records... Tape Subfile: 4 **** FILE TRAILER **** Tape File Depth Units = feet FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .0 .000 .000 .000 .000 64.0 .0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN lRR2 (MWD Run 3) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 2g-17.xtf 150 ConocoPhillips Alaska, I 2G-17 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL RPSL RPCH RPSH RACL RASL RACH RASH RaPS RPTH TCDM GRAM RPCL RPSL RPCH RPSH RACL RASL RACH RASH RaPS RPTH TCDM GRAM RPD RPM RPS RPX RACLM RACSLM RACHM RACSHM ROPS RPTHM TCDM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 *** LIS COMMENT RECORD *** 1024 LDWG .005 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 138 records... Tape Subfile: 5 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 1496.000000 1681.000000 0.250000 ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 39 0.250 * F FRAME SPACE = Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 * FORMAT RECORD (TYPE# 64) BIT RUN 2 (MWD Run 4) . GR/DPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) o .00 .000 64.0 .0 .0 .0 .000 .000 .000 .000 SPUD MUD 9.05 .0 .0 200 .0 12.250 108.0 TOOL NUMBER ASU 37110 RNT 20034 RNT 20034 38.9 41.3 MSB 18704 8.25 ATK MEMORY 1790.0 1681. 0 1772.0 o 31-DEC-02 REMARKS: # .0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOTTOM) TOOL TYPE DIRECTIONAL DUAL PROP. RESIS. GAMMA RAY TOOL STRING (TOP TO VENDOR TOOL CODE DIR DPR GR $ # # 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 1772.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ START DEPTH 1681. 0 log header data for each bit run in separate files. 4 .2500 5 !!!!!!!!!!!!!!!!!!! Extract File: FILE014.HED TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 2g-17.xtf 150 ConocoPhillips Alaska, I 2G-17 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RACLM 0.0 RACH RACH RACHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 BOREHOLE AND CASING DATA # TOOL NUMBER ASU 51312 RNT 20027 RNT 20027 BOTTOM) TOOL TYPE DIRECTIONAL DUAL PROP. RES IS. GAMMA RAY TOOL STRING (TOP TO VENDOR TOOL CODE DIR DPR GR $ # 41.3 42.3 # 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: MSB 18704 8.25 ATK MEMORY 1882.0 1772.0 1864.0 o 01-JAN-03 STOP DEPTH 1864.0 START DEPTH 1772.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 5 .2500 6 ! ! ! !!!!! !!! !! !! ! !!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE015.HED *** LIS COMMENT RECORD *** 1024 LDWG .006 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 104 records... Tape Subfile: 6 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 1681.000000 1772.000000 0.250000 14 Total Data Records: 32 # OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 108.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # SPUD MUD 9.05 .0 .0 200 .0 .000 .000 .000 .000 64.0 .0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # .00 .000 .0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): o # REMARKS: # BIT RUN 2RR (MWD Run 5) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 2g-17.xtf LCC 150 CN ConocoPhillips Alaska, I WN 2G-17 FN Kuparuk River COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL RPSL GRAM RPCL RPSL GRAM RPD RPM 0.0 0.0 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RACLM 0.0 RASL RASL RACSLM 0.0 RACH RACH RACHM 0.0 RASH RASH RACSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 20 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 1772.000000 1864.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 7 119 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .007 o .0 .00 .000 68.0 .0 .0 .0 .000 .000 .000 .000 SPUD MUD 9.05 .0 .0 200 .0 12.250 108.0 TOOL NUMBER DAS 7050 MPR 35083 SRIG 58019 42.3 54.4 MSB 18704 8.25 MPR MEMORY 2039.0 1864.0 2000.0 o 01-JAN-03 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. RESIS. GAMMA RAY TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GR $ # # 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 2000.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ START DEPTH 1864.0 log header data for each bit run in separate files. 6 .2500 7 ! ! !! ! !! ! ! !!!! !! !!!! LDWG File Version 1.000 ! ! ! !! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILE016.HED *** LIS COMMENT RECORD *** 1024 # REMARKS: # BIT RUN 2RR2 (MWD Run 6) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 2g-17.xtf 150 ConocoPhillips Alaska, I 2G-17 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RACLM 0.0 RASL RASL RACSLM 0.0 RACH RACH RACHM 0.0 RASH RASH RACSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F # LOG HEADER DATA STOP DEPTH 5721. 0 START DEPTH 2000.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 7 .2500 8 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE017.HED *** LIS COMMENT RECORD *** 1024 LDWG .008 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 128 records... Tape Subfile: 8 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 1864.000000 2000.000000 0.250000 ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 29 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 VENDOR TOOL CODE DIR MPR GR $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. RES IS. GA.MJI1A. RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # 03-JAN-03 MSB 18704 8.25 MPR MEMORY 5765.0 2000.0 5721.0 o 54.4 70.3 TOOL NUMBER DAS 7050 MPR 35083 SRIG 58019 12.250 108.0 SPUD MUD 9.35 .0 .0 200 .0 .000 .000 .000 .000 78.0 .0 .0 .0 .00 .000 .0 o BIT RUN 2RR3 (MWD Run 7) . GR/MPR. CURVE GLOSSARY: GRAM - GA.MJI1A. RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 2g-17.xtf 150 ConocoPhillips Alaska, I 2G-17 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RACLM 0.0 RASL RASL RACSLM 0.0 RACH RACH RACHM 0.0 RASH RASH RACSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 8.500 5743.0 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # TOOL NUMBER ASU 026 RNT 20077 RNT 20077 BOTTOM) TOOL TYPE DIRECTIONAL DUAL PROP. RESIS. GA11MA RAY TOOL STRING (TOP TO VENDOR TOOL CODE DIR DPR GR $ # 54.9 71.5 # 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: MSB 18704 6 . 75 ATK MEMORY 14035.0 5721.0 14017.0 o 12-JAN-03 STOP DEPTH 14017.0 START DEPTH 5721. 0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 8 .2500 9 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE018.HED *** LIS COMMENT RECORD *** 1024 LDWG .009 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 883 records... Tape Subfile: 9 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2000.000000 5721.000000 0.250000 784 Total Data Records: # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # LSND 9.85 .0 .0 250 .0 .000 .000 .000 .000 136.0 .0 .0 .0 .00 .000 .0 o BIT RUN 3 (MWD Run 8) . GR/DPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 2g-17.xtf LCC 150 CN ConocoPhillips Alaska, I WN 2G-17 FN Kuparuk River COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL RPCH RACL RACH ROPS RPTH TCDM GRAM RPCL RPCH RACL RACH ROPS RPTH TCDM GRAM RPD RPS RACLM RACHM ROPS RPTHM TCDM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILE019.HED FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. *** LIS COMMENT RECORD *** 1024 LDWG .010 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 1276 records... Tape Subfile: 10 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 5721.000000 14017.000000 0.250000 1186 Total Data Records: ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 0.250 * F FRAME SPACE = Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 * FORMAT RECORD (TYPE# 64) BIT RUN NO: 10 DEPTH INCREMENT: .2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 14017.0 $ STOP DEPTH 14044.0 # 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 VENDOR TOOL CODE DIR CCN ORD MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY MULT. PROP. RESIS. GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 12-JAN-03 MSB 18704 4.75 SDN MEMORY 14116.0 14017.0 14044.0 o 54.9 54.9 TOOL NUMBER DAS 1363 SDN 59559 SDN 59559 MPR 1074 SRIG 5318 6.125 14027.0 LSND 10.55 .0 .0 250 .0 .000 .000 .000 .000 131.0 .0 .0 .0 SANDSTONE 2.65 .000 .0 o BIT RUN 4RR (MWD Run 10). GR/MPR/oRD/CCN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWÐ-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL. - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (G/CC) DRHM - DENSITY CORRECTION (G/CC) DPEM - PHOTOELECTRIC CROSS SECTION (B/E) REMARKS: NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 2g-17.xtf 150 ConocoPhillips Alaska, I 2G-17 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RACLM 0.0 RASL RASL RACSLM 0.0 RACH RACH RACHM 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCM 0.0 DRHM DRHM DRHM 0.0 DPEM DPEM DPEM 0.0 NPCK NPCK NPCKSM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 68 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 14 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE == 0.250 * F ONE DEPTH PER FRAME # STOP DEPTH 14768.0 START DEPTH 14044.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 11 .2500 11 ! !! !!! ! !!! !!! !!!!!! LDWG File Version 1.000 !!! !!!!!!!!! !!! !!!! Extract File: FILE020.HED *** LIS COMMENT RECORD *** 1024 LDWG .011 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 118 records... Tape Subfile: 11 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 14017.000000 14044.000000 0.250000 Tape depth ID: F 16 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 BDCM MWD 68 1 G/C3 4 4 11 DRHM MWD 68 1 G/C3 4 4 12 DPEM MWD 68 1 BN/E 4 4 13 NPCK MWD 68 1 PU-S 4 4 14 ROPS MWD 68 1 FPHR 4 4 15 RPTH MWD 68 1 MINS 4 4 16 TCDM MWD 68 1 DEGF 4 4 ------- 64 Total Data Records: 8 BIT RUN 4RR2 (MWD Run 11). GR/MPR/oRD/cCN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - S!{ALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (G/CC) DRHM - DENSITY CORRECTION (G/CC) DPEM - PHOTOELECTRIC CROSS SECTION (B/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR o SANDSTONE 2.65 .000 131. 0 .0 .0 .0 .000 .000 .000 .000 LSND 10.75 .0 .0 350 .0 6.125 14027.0 TOOL NUMBER DAS 12160 SDN 68110 SDN 68110 MPR 1150 SRIG 60365 52.2 55.6 MSB 18704 4.75 SDN MEMORY ,14768.0 14044.0 14768.0 o 19-JAN-03 REMARKS: # .0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOTTOM) TOOL TYPE DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY MULT. PROP. RES IS. GAMMA. RAY TOOL STRING (TOP TO VENDOR TOOL CODE DIR CCN ORD MPR GRAM $ # 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: THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 2g-17.xtf 150 ConocoPhillips Alaska, I 2G-17 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RACLM 0.0 RASL RASL RACSLM 0.0 RACH RACH RACHM 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCM 0.0 DRHM DRHM DRHM 0.0 DPEM DPEM DPEM 0.0 NPCK NPCK NPCKSM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 68 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 14 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 BDCM MWD 68 1 G/C3 4 4 11 DRHM MWD 68 1 G/C3 4 4 12 DPEM MWD 68 1 BN/E 4 4 13 NPCK MWD 68 1 PU-S 4 4 14 ROPS MWD 68 1 FPHR 4 4 15 RPTH MWD 68 1 MINS 4 4 16 TCDM MWD 68 1 DEGF 4 4 ------- 64 Total Data Records: 207 Tape File Start Depth Tape File End Depth Tape File Level spacing Tape File Depth Units 14044.000000 14768.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 12 317 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 03/02/10 01 **** REEL TRAILER **** LDWG 03/02/10 AWS 01 Tape Subfile: 13 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes