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Home My WebLink About204-1231. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: RPPG Treatment-Offset Producer Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 12468'feet None feet true vertical 3394' feet None feet Effective Depth measured 12468'feet 7077', 7245'feet true vertical 3394' feet 3410', 3452' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 7062' MD 3406' TVD Packers and SSSV (type, measured and true vertical depth) 7040' MD 7077' MD 7245' MD N/A 3400' TVD 3410' TVD 3452' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: West Sak Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RPPG pumped down 1E-105L1 (Injector) (See details in Well Events.) Packer: Baker GBH-22 Seal Assembly Packer: LEM Production Packer Packer: ZXP Liner Top Packer SSSV: None Jan Byrne Jan.Byrne@conocophillips.com (907) 465-6471Staff Well interventions Engineer Alternating Slotted Liner: 7334-9768', 9893-12422' Alternating Slotted Liner:3472-3438', 3437-3397' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 108' ~~~ Well Remains Shut-In ~~ ~ measured TVD 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-123 50-029-23215-60-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025651, ADL0025660 Kuparuk River Field/ West Sak Oil Pool KRU 1E-126L1 Plugs Junk measured Length Production B Sand Liner 8061' 5153' Casing 3605' 5-1/2" 8088' 12456' 3395' 3765' 108'Conductor Surface Intermediate 20" 13-3/8" 82' 3795' 2304' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:09 am, Aug 25, 2025 Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2025.08.25 08:14:03-08'00' Foxit PDF Editor Version: 13.1.6 Jan Byrne DSR-9/11/25 RBDMS JSB 082825 J.Lau 11/4/25 DTTMSTART JOBTYP SUMMARYOPS 7/27/2025 REPAIR WELL MOVE CONTAINERS OF RPPG FROM 1J TO 1E, LAY LINER AND SPOT EQUIPMENT, SPOT TANK, RIG UP HARDLINE . FUNCTION TEST EQUIPMENT/CHECK COMMS 7/29/2025 REPAIR WELL STANDBY FOR OPS TO GET 1E-126 PRODUCER PAIR ONLINE (ICE PLUG) TO PUMP RPPG JOB ON 1E-105 7/30/2025 REPAIR WELL PUMP FULL BORE RPPG TO MBE IN THE B SAND LATERAL AT 9950'. PUMPED 6393.4 LBS OF DAQING RPPG PRODUCT AT .85 PPG FOR 183 BBL'S. STEADY INCREASE TO TARGET PSI OF 1252 PSI. CALLED FLUSH AT 345 JSV, AVG PSI 1102, AVG RATE 2.8 BPM. TOTAL JSV 471 BBL. WELL TO REMAIN SHUT IN FOR 48 HRS FOR RPPG TO FULLY CROSSLINK 1E-105/ 1E-126 RPPG Pumping Summary of Operations Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:1E-126 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Isosleeve out of well 1E-126 5/4/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: ESTIMATE TOP OF FISH @ 7860' CTMD 4/18/2008 lmosbor NOTE: TRI-LATERAL WELL: 1E-126(A-SAND), 1E-126L1(B/C-SAND), 1E-126L2(D-SAND) 9/8/2004 lmosbor 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 20 19.12 26.0108.0108.094.00 K-55 WELDED SURFACE 13 3/8 12.41 29.6 3,795.0 2,304.3 68.00 L-80 BTC INTERMEDIATE 9 5/8 8.84 27.0 8,088.0 3,605.3 40.00 L-80 BTC-M D-Sand Window 9 5/8 8.70 7,105.0 7,124.0 3,422.0 40.00 L-80 BTC-M B-Sand Window 9 5/88.70 7,305.0 7,321.03,469.2 40.00 L-80 BTC-M A-SAND LINER 5 1/2 4.95 7,412.8 12,607.0 3,572.4 15.50 L-80 DWC D-SAND LINER LEM 4 1/2 3.96 7,029.8 7,286.2 3,461.7 12.60 L-80 IBT B-SAND LINER LEM 4 1/2 3.96 7,245.2 7,457.5 3,495.0 12.60 L-80 IBT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.1 Set Depth… 7,062.4 Set Depth… 3,405.9 String Max No… 4 1/2 Tubing Description TUBING WO Wt (lb/ft) 12.60 Grade L-80 Top Connection 4.5 IBT ID (in) 3.83 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) 25.125.10.00 HANGER 13.500 TUBING HANGER 3.900 516.9 515.4 10.66 NIPPLE 5.380 CAMCO 3.875" DS Nipple @ 500' 3.875 4,101.92,409.8 70.00 GAS LIFT 6.880 CAMCO KBG-2- 1R 3.860 5,280.9 2,825.5 65.30 GAS LIFT 6.850 CAMCO KBG-2- 1R 3.860 6,972.13,382.7 75.56 NIPPLE 5.190 CAMCO 3.813" "DB" Nipple 3.813 6,987.3 3,386.5 75.40 XO 4.500 3.830 6,988.7 3,386.9 75.38 GAUGE 6.360 A-well Gauge Mandrel (Weatherford) 4 1/2" 8rd BxP 3.950 7,039.1 3,399.8 74.86 LOCATOR 5.200 LOCATOR SUB 3.890 7,040.2 3,400.1 74.85 SEAL ASSY 4.730 Baker GBH-22 Seal Assembly 3.890 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,970.0 2,005.8 69.23 Heat Trace HEAT TRACE 2970'-3063' 5/3/2007 0.000 7,860.0 3,565.7 79.90 FISH Toolstring including coil connector tagged 4/18/08 2/8/2008 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) 4,101.9 2,409.8 70.00 1 GAS LIFT OVBK 1 0.0 7/10/2012 0.250 5,280.9 2,825.5 65.30 2 GAS LIFT OVBK 1 0.05/22/2012 0.250 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,029.8 3,397.4 74.96 SLEEVE 8.280 'HR' LINER SETTING SLEEVE 7.500 7,038.1 3,399.5 74.87 XO BUSHING 7.070 4.880 7,062.4 3,405.9 74.73 XO BUSHING 6.060 3.960 7,076.7 3,409.7 74.78 PACKER 8.420 LEM PRODUCTION PACKER 3.870 7,245.2 3,452.3 76.32 PACKER 8.430 ZXP LINER TOP PACKER 6.278 7,263.8 3,456.6 76.69 XO BUSHING 7.670 CROSSOVER BUSHING 7"x5.5" 4.760 7,284.8 3,461.4 77.10 XO BUSHING 6.060 CROSSOVER BUSHING 5.5"x4.5" 3.910 7,327.3 3,470.6 77.95 NIPPLE 5.000 CAMCO 'DB' NIPPLE 3.562 7,412.8 3,487.2 79.64 PACKER 9.625 HRD ZXP LINER TOP PACKER 7.000 7,431.4 3,490.5 79.91 NIPPLE 6.070 'RS' PACKOFF SEAL NIPPLE 4.875 7,465.1 3,496.4 79.94 XO BUSHING 6.040 CROSSOVER BUSHING 3.930 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 8,056.0 8,148.0 3,600.1 3,614.2 WS A3, WS A2, 1E-126 8/15/2004 40.0 IPERF Alternating w/blank pipe, slots 2.5"x.125", 4 circumferential rows/ft - Applies to all Perfs 8,271.0 8,333.0 3,627.4 3,630.7 WS A2, 1E-126 8/15/2004 40.0 IPERF 8,799.0 8,984.0 3,622.3 3,611.8 WS A2, 1E-126 8/15/2004 40.0 IPERF 9,336.0 9,918.0 3,593.7 3,582.0 WS A2, 1E-126 8/15/2004 40.0 IPERF 10,087.0 10,761.0 3,591.7 3,581.0 WS A2, 1E-126 8/15/2004 40.0 IPERF 11,144.0 12,122.0 3,558.4 3,553.8 WS A2, 1E-126 8/15/2004 40.0 IPERF 12,378.012,574.03,566.13,571.8 WS A2, 1E-126 8/15/200440.0 IPERF 1E-126, 8/11/2025 2:31:50 PM Vertical schematic (actual) A-SAND LINER; 7,412.8- 12,607.0 IPERF; 12,378.0-12,574.0 IPERF; 11,144.0-12,122.0 IPERF; 10,087.0-10,761.0 IPERF; 9,336.0-9,918.0 IPERF; 8,799.0-8,984.0 IPERF; 8,271.0-8,333.0 IPERF; 8,056.0-8,148.0 INTERMEDIATE; 27.0-8,088.0 FISH; 7,860.0 B-SAND LINER LEM; 7,245.2- 7,457.5 B-Sand Window; 7,305.0- 7,321.0 B-SAND LINER; 7,302.6- 12,455.8 D-SAND LINER LEM; 7,029.8- 7,286.2 D-Sand Window; 7,105.0- 7,124.0 D-SAND LINER; 7,103.4- 12,435.0 NIPPLE; 6,972.1 GAS LIFT; 5,280.9 GAS LIFT; 4,101.9 SURFACE; 29.6-3,795.0 Heat Trace; 2,970.0 NIPPLE; 516.9 CONDUCTOR; 26.0-108.0 HANGER; 25.1 KUP PROD KB-Grd (ft) 33.71 RR Date 8/31/2004 Other Elev… 1E-126 ... TD Act Btm (ftKB) 12,611.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292321500 Wellbore Status PROD Max Angle & MD Incl (°) 94.07 MD (ftKB) 11,058.79 WELLNAME WELLBORE Annotation Last WO: End Date 5/3/2007 H2S (ppm) 80 Date 8/24/2012 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1E-126L1 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: WELL REVIEW 1E-126L1 10/23/2013 osborl Notes: General & Safety Annotation End Date Last Mod By NOTE: TRI-LATERAL WELL: 1E-126(A-SAND), 1E-126L1(B/C-SAND), 1E-126L2(D-SAND) 9/8/2004 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread B-SAND LINER 5 1/2 4.95 7,302.6 12,455.8 3,394.9 15.50 L-80 DWC Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,334.0 9,768.0 3,471.7 3,437.8 WS B, WS C, 1E -126L1 8/31/2004 40.0 IPERF Alternating w/blank pipe, slots 2.5"x.125", 4 circumferential rows/ft - Applies to all Perfs 9,893.0 12,422.0 3,437.4 3,396.9 WS B, 1E-126L1 8/31/2004 40.0 IPERF 1E-126L1, 8/11/2025 2:31:53 PM Vertical schematic (actual) B-SAND LINER; 7,302.6- 12,455.8 IPERF; 9,893.0-12,422.0 IPERF; 7,334.0-9,768.0 INTERMEDIATE; 27.0-8,088.0 B-Sand Window; 7,305.0- 7,321.0 B-SAND LINER LEM; 7,245.2- 7,457.5 D-SAND LINER LEM; 7,029.8- 7,286.2 D-Sand Window; 7,105.0- 7,124.0 D-SAND LINER; 7,103.4- 12,435.0 NIPPLE; 6,972.1 GAS LIFT; 5,280.9 GAS LIFT; 4,101.9 SURFACE; 29.6-3,795.0 Heat Trace; 2,970.0 NIPPLE; 516.9 CONDUCTOR; 26.0-108.0 HANGER; 25.1 KUP PROD KB-Grd (ft) 33.71 RR Date 8/31/2004 Other Elev… 1E-126L1 ... TD Act Btm (ftKB) 12,468.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292321560 Wellbore Status PROD Max Angle & MD Incl (°) 94.05 MD (ftKB) 9,260.53 WELLNAME WELLBORE1E-126 Annotation Last WO: End Date 5/3/2007 H2S (ppm) 80 Date 8/24/2012 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1E-126L2 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: WELL REVIEW 1E-126L2 10/23/2013 osborl Notes: General & Safety Annotation End Date Last Mod By NOTE: TRI-LATERAL WELL: 1E-126(A-SAND), 1E-126L1(B/C-SAND), 1E-126L2(D-SAND) 9/8/2004 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread D-SAND LINER 5 1/2 4.95 7,103.4 12,435.0 3,380.4 15.50 L-80 DWC Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,136.0 12,402.0 3,424.6 3,377.9 WS D, 1E-126L2 8/15/2004 40.0 IPERF Alternating w/blank pipe, slots 2.5"x.125", 4 circumferential rows/ft - Applies to all Perfs 1E-126L2, 8/11/2025 2:31:54 PM Vertical schematic (actual) D-SAND LINER; 7,103.4- 12,435.0 IPERF; 7,136.0-12,402.0 INTERMEDIATE; 27.0-8,088.0 D-Sand Window; 7,105.0- 7,124.0 D-SAND LINER LEM; 7,029.8- 7,286.2 NIPPLE; 6,972.1 GAS LIFT; 5,280.9 GAS LIFT; 4,101.9 SURFACE; 29.6-3,795.0 Heat Trace; 2,970.0 NIPPLE; 516.9 CONDUCTOR; 26.0-108.0 HANGER; 25.1 KUP PROD KB-Grd (ft) 33.71 RR Date 8/31/2004 Other Elev… 1E-126L2 ... TD Act Btm (ftKB) 12,457.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292321561 Wellbore Status PROD Max Angle & MD Incl (°) 94.45 MD (ftKB) 7,433.83 WELLNAME WELLBORE1E-126 Annotation Last WO: End Date 5/3/2007 H2S (ppm) 80 Date 8/24/2012 Comment SSSV: NIPPLE • • • pF,T THE STATE Alaska Oil and Gas o f/\ T A CKA Conservation Commission Mist 333 West Seventh Avenue / GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov John Pierce SCAMS) Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool,KRU 1E-126L1 Permit to Drill Number: 204-123 Sundry Number: 318-147 Dear Mr. Pierce: 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, Hollis S. French Chair +4- DATED this S day of April,2018. IRBDMSILL_ Aris 06 2MM, • • RECEIVED • STATE OF ALASKA AR 0 3 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION .- s APPLICATION FOR SUNDRY APPROVALS AO 20 AAC 25.280 1.Type of Request: Abandon E Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill E Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: MBE Gel TrtmnI 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ppf26,/ ConocoPhillips Alaska, Inc. Exploratory ❑ Development Q , 204-123 , 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 500292321560 " 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A, Will planned perforations require a spacing exception? Yes ❑ No ❑✓ ✓ KRU 1 E-126L1 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651,ADL 25660 Kuparuk River Field/West Sak 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): 12,468' 3,394' 12,468' 3,394' NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 82' 20" 108' 108' Surface 3,765' 13-3/8" 3,795' 2,304' Intermediate 8061' 9-5/8" 8,088' 3605' Production Liner 5153' 5-1/2" 12456' 3395' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7334'-9768' 3472'-3438' 4-1/2" L-80 7062' 9893'-12422' 3437'-3397' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): LEM Production Packer 7077'MD and 3410'TVD SSSV:Nipple 517'MD and 515'TVD 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 Statgafter proposed work: 5/1/2018 fMe Commencing Operations: OIL [S WINJ [J WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ] GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 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: John PeirceJohn Peirce Contact Name: Authorized Title: Sr.Wells Engineer Contact Email: John.W.Peirce@cop.com Contact Phone: (907)265-6471 Authorized Signature: �, �, .-.�� Date: M/2 /I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 313 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No Er Spacing Spacing Exception Required? Yes ❑ No L� Subsequent Form Required: /0 —4 0 ii- APPROVED BY I /16 Approved by: hCQ y COMMISSIONER THE COMMISSION Date: 5 OP;kb D('1 ORIGINAL RBDMS L.(Apii o 11..' and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in'upiicate 41, Proposed 1E-105L1 to 1E-126L1 B Sand MBE Retreatment with RPPG 1E-105 Tri-Lateral injector was drilled and completed in 2005 with West Sak A, B, & D Sand laterals. The 1E-105L1 B Lat has a 5.5", L-80 slotted liner. 3 MBE's (Matrix Bypass Event) have occurred in 1 E-105L1. The first was on 12/28/05 from 1 E-105 to 1E-126 producer. A 6/20/06 (PROF found a B MBE at 8750' RKB taking all PWI. On 9/4/11 a Crystal Seal job sealed this MBE, and the treatment lasted —2 years until 1E-126 rising WC% indicated a new MBE existed from 1E-105. An IPROF of 1/28/14 in 1E-105L1 showed a new MBE at 8950 - 9150' area. The MBE at 8950 - 9150' RKB was sealed by Crystal Seal job on 9/23/15 and lasted —1 year until the 1 E-126 WC% spiked again. An IPROF ran 1/29/17, found a new MBE in 1E-105L1 at 9950' RKB, but the two previously treated MBE's were not taking fluid. A 1E-105L1 B MBE RPPG job was pumped 5/1/17. Post-RPPG FCO, the `B Lat only' was BOI for 1 month with 1 E-126 showing lower WC% and rising BOPD, so the A Lat Plug & D Iso-Sly were pulled to get all Lats on injection, but this caused a spike in 1E-126 WC%. On 6/18/17, a mainbore IPROF saw 73% D, 26% B, 1% A (suggests a new D MBE). On 9/18/17, a D IPROF found all injection exiting the D Lat at —7260' RKB near the D LEM junction, and then injection was flowing down backside of D Liner to top of the first slotted liner —764' below the D LEM. The D MBE location is unknown, but the log suggests an MBE (or high perm thief) most likely exists behind 764' of blank liner section up hole of the first slots. The D MBE will be treated with MARCIT (per 2/26/18 AOGCC approval #318-068), but in the meantime, a Plug was set 2/2/18 at 7578' RKB to isolate A Lat, and a B Diverter was set, and a D Iso-Sly was set to reconfigure 1 E-105 for a B IPROF. The B Lat IPROF on 3/10/18 confirmed that the B MBE at —9950' RKB reopened again and requires a retreatment. 1 E-105 is currently configured for the B MBE retreatment. Thus, it is proposed (below) that the B MBE be retreated with RPPG and evaluated before reconfiguring for a D MBE MARCIT job. The D MBE treatment with MARCIT would be performed after a successful B MBE treatment. Proposed Procedure Coil Tubing: 1) RIH to shoot 5' of `big hole' add perforations at 9950 - 9955' RKB near the B MBE at —9950' RKB. These perfs are intended to double the number of perfs located near the B MBE to provide better passage of RPPG through the slotted liner to the MBE. 2) Verify 1E-126 producer is online and put 1E-105 BOI at —1500 BWPD at 12 - 24 hrs before CTU RU on 1E-105. Flow 1E-126 to 1E test separator to avoid CPF1 upset. This reestablishes flow through the MBE between wells to ensure MBE is open for RPPG, and pushes away the 'gas head' from 1 E-105 to the MBE. Ideally, we want the tubing `liquid packed' for pumping the RPPG treatment. RU CT with 2" CT on 1E-105. Request that 1E-126 be SI when CT is ready to RIH, but keep 1E-105 on PWI —1500 BWPD. RIH with a large single 'down port' Nozzle while displacing Diesel FP from CT by pumping —50 bbls of 2% KCL Water down CT at —0.5 bpm while warm 130°F PWI continues down CT x Tbg annulus. • I Park the Nozzle at `safety' (above all liner slots) at 7620' RKB, and then halt pumping down CT while checking the WHIP on CT x Tbg. Record starting WHIP on tubing. Any 'gas head' that may have been in the tubing earlier should have been fully displaced away from the tubing to the MBE, so expected WHIP on tubing should be less than 100 psi to start the RPPG treatment. SI PWI to 1 E-105 CT x Tbg annulus, and swap over to pumping warm 2% KCL Water from a full 290 bbl transport down CT x Tbg annulus at minimum rate (target 0.4 bpm), to keep well warm and keep CT x Tbg annulus flushed of any potential RPPG coming up CT backside during RPPG pumping as precaution to prevent stuck CT. More importantly, the 2% KCL Water pumped down CT backside from this point forward displaces away all PWI to MBE to eliminate presence of any residual hydrocarbons (which exist in PWI) that can negatively affect proper hydration and swell of RPPG in the MBE during treatment which might impact treatment success. Pump a short Step Rate Injection Test (SRIT) down CT with 2% KCL Water at 1 bpm, 1.5 bpm, and 2 bpm to record a stable CT treating pressure at each rate. Pick a steady treating rate between 1 to 2 bpm that yields a good starting CT treating pressure somewhere in range of 1000 - 2000 psi. After a steady pump rate is determined, start mixing 2% KCL Water from a transport with 1 - 4 mm mesh RPPG at 0.75 ppg concentration (31.5 lbs/bbl) in mixing van to make RPPG slurry on-the-fly while pumping it down CT at established steady rate. Pump 0.75 ppg RPPG slurry in 2% KCL Water until WHP on CT x Tbg annulus reaches -800 psi, then swap from RPPG slurry to pumping 1 CT volume of 2% KCL Water Spacer (-50 bbls) while maintaining the steady established rate down CT, followed by 47 bbls Diesel FP, followed by another full CT volume (-50 bbls for CT Diesel FP), followed by SD. During the treatment pumping schedule (above), CT will start POOH from `safety' to surface when the first Diesel FP starts entering CT. The 2% KCL Water pumping down CT x Tbg annulus will be halted when the nozzle reaches 7000' in 4.5" tubing, which should slow rate of WHP pressure rise as WHP climbs toward target Frac pressure of -1200 psi WHP. Pump rate down CT can be reduced to keep WHP < 1200 psi, if needed. However, a short duration of WHP > 1200 psi, if needed, to get all Diesel FP away is not considered to be detrimental to the RPPG MBE treatment. RD CTU. Wait 2 days for RPPG particles to fully crosslink in MBE before returning 1E-105L1 to PWI. Coil Tubing - FCO RPPG (optional, if needed): 3) RIH with jet swirl nozzle to tag RPPG in 1E-105L1. Jet down through RPPG with Diesel to as deep as possible while injecting away RPPG and Diesel to MBE &/or formation. POOH. RD CTU. Place 1E-105L1 on injection to evaluate results of B MBE treatment. Evaluate `B only' PWI performance and monitor offset producer 1E-126 performance to verify that the B MBE has been isolated. If B MBE treatment is evaluated as successful, then the previously approvedlE-105L2 D MBE treatment with MARCIT Gel will be executed, as per AOGCC Approval # 318-068 of 2/26/18. KUP PROD • 1E-126L1 ConocoPhillips il" Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status not(°) MD(ftKB) Act Btm(kKB) Lonocrinsuips 500292321560 WEST SAK PROD 94.05 9,260.53 12,468.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-126L1,1003/201311:52:17 AM SSSV:NIPPLE 80 8/24/2012 Last WO: 5/3/2007 33.71 8/31/2004 Vestal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date - ------- --- -- -- Last Tag: Rev Reason:WELL REVIEW osborl 10/23/2013 HANGER 25.1 1 if Casing Strings �� Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread IB-SAND LINER 5 1/2 4.950 7,302.6 12,455.8 3,394.9 15.50 L-80 DWC J Liner Details iiiNominal■ Top(kKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) 7,302.6 3,465.3 77.46 HANGER BAKER MODEL B-1 HOOK HANGER 4.760 -M"CONDUCTOR;26.6108.0Mill ''�' Perforations&Slots NIPPLE;516.9 Shot Dens Top(WD) Btm(WD) (ahots/f Heat Tran.;2,970.0 Top(ftKB) Btm(ftKB) (kKB) (ftKB) Zone Date t) Typo Com 7,334.0 9,768.0 3,471.7 3,437.8 WS B,WS C, 8/31/2004 40.0 (PERF Alternating w/blank pipe, 1E-126L1 slots 2.5"x.125",4 circumferential rows/ft- Applies to all Perfs 9,893.0 12,422.0 3,437.4 3,396.9 WS B,1E- 8/31/2004 40.0 IPERF • • SURFACE;29.63,795.0-w 126L1 Notes:General&Safety End Date Annotation GAS LIFT;4.101.9 9/8/2004 NOTE:TRI-LATERAL WELL:1E-126(A-SAND),tE-126L1(B/C-SAND),1E-126L2(D-SAND) I 2/23/2009 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT,5.280.9 NIPPLE,6,972.1 GAUGE;6,9887 ti I 1 LOCATOR;7,039.1 SEAL ASSY;7,040.2 1...M 0-SAND UNER;7,103.4 12,435.0 DSand Window;7.105.6 7,124.0 FISH;7,131.0 f®11 M D-SAND LINER LEM,7,0296- - - 7,286.2 B-Sand Window;7,305.6 1 7,321.0 ! INTERMEDIATE;27.08,088.0. B-SAND LINER LEM;7,245.2- 7.457.5 IPERF;7334.0-9.768.0 IPERF;9,893.0-12,422.0 BSAND LINER;7,302.8- 12,455.8 KUP PROD • 1 E-126 ConocoPhillips if Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Statusncl C) MD(ftKB) Act Btm(ftKB) tnr,acctwrsps 500292321500 WESTSAK PROD 1 94.07 11,058.79 12,611.0 -•- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1E-126,10/23201311:5115 AM SSSV:NIPPLE 80 8/24/2012 Last WO: 5/3/2007 33.71 8/31/2004 - Vertical schmalz(actual) _ Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:WELL REVIEW osborl 10/23/2013 HANGER,25.1 limit mai Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 1„I",""'^""'1P1,"'",","'"1, IIr I. CONDUCTOR 20 19.124 26.0 108.0 108.0 94.00 K-55 WELDED ,,,M,,,,f",,, i u i.,,,.Casing Description 0D(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;26.6108.0••• SURFACE 133/8 12.415 29.6 3,795.0 2,304.3 68.00 L-80 BTC Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread NIPPLE;516.9 Vg INTERMEDIATE 95/8 8.835 27.0 8,088.0 3,605.3 40.00 L-80 BTC-M I Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread Heat Trace;2,970.0 D-Sand Window 95/8 8.697 7,105.0 7,124.0 3,422.0 40.00 L-80 BTC-M Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread B-Sand Window 95/8 8.697 7,305.0 7,321.0 3,469.2 40.00 L-80 BTC-M Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread A-SAND LINER 51/2 4.950 7,412.8 12,607.0 3,572.4 15.50 L-80 DWC SURFACE;29.6-3,795.0 4 Liner Details ` Nominal ID GAS LIFT;4,1012 It T Top(ftKB) Top(ND)(ftKB) Top not C) Item Des Com (in) ,. 7,412.8 3,487.2 79.64 PACKER HRD ZXP LINER TOP PACKER 7.000 7,431.4 3,490.5 79.91 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4.875 I GAS UFT.5280.9 at 7,434.3 3,491.0 79.92 HANGER FLEXLOCK LINER HANGER 4.853 7,445.8 3,493.0 79.93 SEE 190-47 CASING SEAL BORE EXTENSION 4.750 NIPPLE;6,972.1 IllHt - 7,465.1 3,496.4 79.94 XO BUSHING CROSSOVER BUSHING 3.930 Casing Description IOD(in)1/2 IID lin3.958) 'Top(ttKB)7,029.8 ISet Depth(ftKB)7,286.2 I Set Depth(3,467ND)...7.I WtlLen(I.12.60..I GL -80 I Top IBT Thread GAUGE;6.988.7 D-SAND LINER LEM 4 Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inc!(°) Item Des Com (in) �■ 7,029.8 3,397.4 74.96 SLEEVE 'HR'LINER SETTING SLEEVE 7.500 I ® 7,038.1 3,399.5 74.87 XO BUSHING 4.880 LOCATOR,7,039.1 7,044.1 3,401.1 74.81 SBE 4.760 SEAL ASSY;7,0402 7,062.4 3,405.9 74.73 XO BUSHING 3.960 7,076.7 3,409.7 74.78 PACKER LEM PRODUCTION PACKER 3.870 7,093.4 3,414.1- 74.85 HANGER LEM HH ABOVE 3.950 7,105.5 3,417.2 74.89 HANGER LME HH BELOW 3.680 7,283.0 3,461.0 77.07 SEAL ASSY NON-LOCATING SEAL ASSEMBLY 3.890 - D-SAND LINER;7,103.4 1 I. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(1...Grade Top Thread 12.435.0\ t B-SAND LINER LEM I 4 1/21 3.958 7,245.21 7,457.51 3,495.01 12.601 L-80 I IBT DSend Window;7,105.0. 7,124.0 • Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 7,245.2 3,452.3 76.32 PACKER ZXP LINER TOP PACKER 6.278 FISH,7,131.0 7,263.8 3,456.6 76.69 XO BUSHING CROSSOVER BUSHING 7"x5.5" 4.760 7,265.6 3,457.0 76.72 SEE SEAL BORE EXTENSION 4.750 7,284.8 3,461.4 77.10 XO BUSHING CROSSOVER BUSHING 5.5"x4.5" 3.910 7,292.6 3,463.1 77.26 HANGER LEM ABOVE HOOK HANGER 4.020 7,302.5 3,465.3 77.46 HANGER LEM INSIDE HOOK HANGER 4.020 •eti 7,327.3 3,470.6 77.95 NIPPLE CAMCO'DB'NIPPLE 3.562 7,454.3 3,494.5 79.93 SEAL ASSY BAKER SEAL ASSEMBLY 3.875 D-SAND LINER LEM;7,029.6 =_ 7,286.2 Tubing Strings I I Tubing Description I String Me...1 ID 110) I Top(ftKB) 'Set Depth 19..'Set Depth(TVD)(...I Wt(Iblft) 'Grade I Top Connection B-SAND LINER;7,302.6 TUBING WO 41/2 3.830 25.1 7,062.4 3,405.9 12.60 L-80 4.5 IBT 12,465.81 e sand Window;7.305.6 Completion Details 7.321.0 I Nominal ID _ Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) 25.1 25.1 0.00 HANGER TUBING HANGER 3.900 516.9 515.4 10.66 NIPPLE CAMCO 3.875"DS Nipple @ 500' 3.875 6,972.1 3,382.7 75.56 NIPPLE CAMCO 3.813""DB"Nipple ' 3.813 ,if , 6,987.3 3,386.5 75.40 XO 3.830 i■ 6,988.7 3,386.9 75.38 GAUGE A-well Gauge Mandrel(Weatherford)4 1/2"8rd BxP 3.950 7,039.1 3,399.8 74.86 LOCATOR LOCATOR SUB 3.890 I. B-SAND LINER LEM;72452- 7,040.2 3,400.1 74.85 SEAL ASSY Baker GBH-22 Seal Assembly 3.890 7,457.5 - lilik Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top not FISH;7,860.0--4 Top(ftKB) (ftKB) C) Des Com Run Date ID(in) 2,970.0 2,005.8 69.23 Heat Trace HEAT TRACE 2970'-3063' 5/3/2007 0.000 _ f- 7,131.0 3,423.8 74.99 FISH TYPE 1 ISO SLEEVE STUCK IN D LEM 6/15/2010 0.000 INTERMEDIATE;27.0.8,089.0 _ 7,860.0 3,565.7 79.90 FISH Toolstong including coil connector tagged 4/18/08 2/8/2008 0.000 IPERF;8,056.05,148.0• Perforations&Slots Shot Dens IPERF;8,271.0-8.333.0---)_. Top(ftKB) Btm(ftKB) TopS) Bt KKKBD) Zone Date (shotslf Type Corn 8,056.0 8,148.0 3,600.1 3,614.2 WS A3,WS 8/15/2004 40.0 IPERF Alternating w/blank pipe, - - A2,1E-126 slots 2.5"x.125",4 IPERF;8.799.05,984.0 Circumferential rows/ft- Applies to all Perfs 8,271.0 8,333.0 3,627.4 3,630.7 WS A2,1E- 8/15/2004 40.0 IPERF IPERF;9,336.69,918.0--. 126 8,799.0 8,984.0 3,622.3 3,611.8 WS A2,1E- 8/15/2004 40.0 IPERF _ 126 IPERF;10,087.0.10,761.0_ _ 9,336.0 9,918.0 3,593.7 3,582.0 WS A2,1E- 8/15/2004 40.0 IPERF _ 126 IPERF:17,144.0-12,122.o _ _ 10,087.0 10,761.0 3,591.7 3,581.0 WS A2,1E- 8/15/2004 40.0 IPERF 126 IPERF;12,378.612,574.0 -ill A-SAND LINER;7,412.8- 12,507.0-N, ,412.612,607.0 H KUP PROD 1E-126 ConocoPhillips Alaska.Inc. a' ••••• 1 E-126,1023201311:51:16 AM Vertical schemata(actual) ...................................................................................................................... HANGER;25.1 `IJ Perforations&Slots Shot 11" I Dens ►- ^ Top(TVD) Btm(TVD) (shotarc Top(ftKB) Btn)mg) (te(B) (ftKB) Zone Date t) Type Com M7 CONDUCTOR;26.0108.0•'rI PIP 11,144.0 12,122.0 3,558.4 3,553.8 WSAZ21E- 8/15/2004 40.0 IPERF NIPPLE;516.9 126 12,378.0 12,574.0 3,566.1 3,571.8 WSA2,1E- 8/15/2004 40.0 IPERF ' Heal Trace;2.970.0 126 Mandrel Inserts st a6 c SURFACE;29.6-3,795.0—w : . on No Top(TVD) Valve Latch Port Size TRO Run 0 Top(ftKB) (ftKB) Make Model OD(In) Sery Type Type (in) (psi) Run Date In 1 4,101.9 2,409.8 CAMCO KBG-2- 1 GAS LIFT OV BK 0.250 0.0 7/10/2012 GAS LIFT;4,101.9 m 1R 2 5,280.9 2,825.5 CAMCO KBG-2- 1 GAS LIFT OV BK 0.250 0.0 5/22/2012 M 1R 1 GAS LIFT;5280.9 i Notes:General&Safety 1i End Date Annotation NIPPLE;6,972.1 — 9/8/2004 NOTE:TRI-LATERAL WELL:1E-126(A-SAND),1E-126L1(B/CSAND),1E-126L2(D-SAND) 4/18/2008 NOTE:ESTIMATE TOP OF FISH @ 7860'CTMD 1.1 GAUGE;6,988.7 we,w. 2/23/2009 NOTE:View Schematic w/Alaska Schematic9.0 SIB MI Iill■■551, LOCATOR,7,039.1 SEAL ASSY;7940.2 I D-SAND LINER;7,103.4- 12,4359 ,103.412,4350 D-Sand Window;7,105.0 , o 7,124.0 FISH;7,131.0 ma D-SAND LINER LEM;7,029.8 7,286 2 B-SAND LINER;7,302.8 ' 12,455.8\ 13-Sand Window;T305,0- 7.321.0 305.07.321.0 I er. I.I B-SAND LINER LEM;7,245.2- 7.4575 a FISH;7,860.0 INTERMEDIATE;27.0-8,088.01 I I IPERF;8,056.0-8,148.0 IPERF,8,271.05333.0 IPERF;8,799 0-8,984.0 IPERF;9,336.0-9,918 0—__ IPERF;10,087.010,761 0— IPERF;11,144.012,122.0—t IPERF,12.378.0-12,574.0 A-SAND LINER;7,412.8 12,607.0, yoF Ty //j, s THE STATE Alaska Oil and Gas tiiM of 1/� T /k S I /��1� Conservation Commission 111`1 j -t2 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �. � --• � t, 'L)\`�'� Main: 907.279.1433 ALAS1'' ` L� Fax 907 276 7542 G� \`�L www.aogcc alaska.gov John Peirce '0 ` I ° 3 Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E-126L1 Sundry Number: 315-364 Dear Mr. Peirce: 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, 1 Daniel T. Seamount, Jr. Commissioner g DATED this / 6 day of June, 2015 Encl. RECEIVED . STATE OF ALASKA } A ,KA OIL AND GAS CONSERVATION COMA, SION J U N 1 2 2015 ,a1►/ APPLICATION FOR SUNDRY APPROVALS � �� 20 AAC 25.280 AOGCC 1 Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other.Crystal Seal Treatment r'_ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. - Exploratory r Development r 204-123 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-23215-60 ' 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exceptions Yes r No 7 KRU 1 E-126L1 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651,25660 • Kuparuk River Field/West Sak 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): 12468 . 3394 • 12421' . 3396' , none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 20 108' 108' SURFACE 3765 13.375 3795' 2306' INTERMEDIATE 7283 9.625 8088' 3605' B-SAND LINER 5153 5.5 12456' 3395' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7334-9768,9893-12422 - 3472-3438,3437-3397 4.5 L-80 7039 Packers and SSSV Type. Packers and SSSV MD(ft)and TVD(ft) 2 PACKERS IN MAIN WELLBORE NIPPLE-CAMCO 3.875"DS NIPPLE @ 500' MD=517 TVD=515 12.Attachments: Description Summary of Proposal p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/8/2015 OIL ro • WINJ r WDSPL r Suspended r 16.Verbal Approval. Date. GAS r WAG r GSTOR r SPLUG r I Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Email: John.W.PeirceAconocophillips.com Printed Name John Peirce Title: Sr. Wells Engineer Signature Zkr: .t Phone.265-6471 Date 6"d/1/13— 7 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 315 ^ 3u2 4 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No LJ Subsequent Form Required: /li' - 4 G 4 Approved by: dIPCOMMISSIONER APPROVED BY THE COMMISSION Date: // 9'1 is VTI... 6,//G// Ape oved application Is valid for 12 months ro the date of approval. ��, , Submit Form and Form 10-403 Revised 5/2015 ORIGINAL A a ents in Duplicate 606,1 RBDM� JUN 2 5 2015 • Treatment Proposal for 1E-105L1 to 1E-126L1 B Sand MBE's 1E-105 tri-lateral injector was drilled & completed in 2005 with laterals in West Sak A, B, & D sands. 1E-105L1 B Sand lateral has 5.5", L-80 slotted liner. Two MBE's occurred in 1E-105L1. The first occurred 12/28/05 from 1E-105 to 1E-126 producer. A 6/20/06 IPROF found a B MBE in 105L1 at 8750' RKB taking all PWI at 2711 BWPD. On 9/4/11, a Crystal Seal job pumped in 105L1 to seal this MBE. The treatment lasted -2 years before rising WC% at 1E-126 indicated another MBE occurred from 1E-105. An (PROF 1/28/14 in 1E-105L1 shows the B MBE at 8750' RKB again taking some PWI, plus a new MBE now at 8950 - 9150' RKB area. 1E-105 lost PWI May 2014 due to 1E PWI line SI for repairs, then PWI resumed April 2015 to 1E-105L2 only (105L1 is Iso-Slv'd off due to B MBE's). A job procedure is now proposed to seal off the B MBE's to return 1E-105L1 lateral to PWI service: Slickline: 1) A 0.25" choke was set on 5/24/15 on a 3.81" DB Lock at 7164' RKB in a Camco Sliding Sleeve. RIH & pull this choke to enable CT access to 1E-105L1 B Sand lateral. RD SL. Coil Tubing: 2) RIH to pull the Iso-Sly set across the B LEM at 7524' RKB. 3) RIH to set a Diverter in the B LEM at 7524' RKB. 4) RIH to set a Iso-Sly across the D LEM at 7258' RKB. RD CTU. E-line: 5) RIH with 5' peri gun on dual tractors to shoot 6 spf, 60 deg ph large hole perfs at 8945 - 8950' RKB. This perfs 5.5" slotted liner at the lower new MBE at -8950' to allow CrystalSeal entry through slotted liner to the MBE. Fire gun. POOH. RD. Perfs were shot in 2011 at the upper MBE at -8750'RKB. Coil Tubing: 6) RIH with a large down port nozzle on CT. Park nozzle at 8700' RKB above both MBE's, and then pump a Step Rate Injection Test (SRIT) followed by a Crystal Seal treatment as follows: a) Pump SRIT with Seawater down CT to MBE's. Select a steady treatment rate (likely to be in the 1.5 - 2 bpm range) to be held constant during the treatment (steps b through e) to Flush (step f) to monitor MBE response to treatment and to watch Crystal Seal screenout develop during the slurry pumping. Use 2% KCL for making Crystal Seal slurry (or Seawater of adequate salinity), then pump: b) 2% KCL Water with 0.05 ppg Crystal Seal (using 4 mm mesh all stages b through e) down CT. Each stage volume TBD during pumping based on treating pressure seen during stage. Then pump, c) 2% KCL Water w/0.10 ppg Crystal Seal down CT, or go to Flush (step f) if screen out develops. d) 2% KCL Water w/0.15 ppg Crystal Seal down CT, or go to Flush if we see screen out develop. e) 2% KCL Water w/0.20 - 0.25 ppg Crystal Seal down CT, or go to Flush if we see screen out. Once Crystal Seal concentrations > 0.10 ppg starts exiting the nozzle, begin POOH with nozzle continuously at 5 - 10 fpm while pumping away all the remaining slurry to be pumped until the nozzle reaches a safe parking point just above the B LEM (7524' RKB). This practice is used now to help mitigate development of very sudden heavy PU weights that have been experienced during previous Crystal Seal treatments where the nozzle stayed parked at the MBE while pumping away all the Crystal Seal stages with only periodic weight checks. Continuously POOH allows for continuous monitoring of PU weight development to provide early warning re: rising PU weight issues. Once the nozzle reaches final parking location at the B LEM, Crystal Seal stacking behind CT cannot occur, since only CT x Tbg dead leg exists above the B LEM and pumping of at least 0.3 bpm will be kept down the CT backside. f) If screen out occurs, pump 1 CT volume Seawater Flush to displace Crystal Seal from CT to well while POOH and pumping 0.5 bpm 2% KCL down CT backside to mitigate Crystal Seal stacking behind CT (that can lead to excessive PU weight). Even if screen out is not seen prior to Flush, keep a minimum of 0.3 bpm of 2% KCL down the CT backside at all times to help keep Crystal Seal flushed away from CT backside to mitigate elevated PU weights. Pump 1 full CT volume of 2% KCL to displace remaining Crystal Seal Slurry from CT to liner while POOH, then swap to Diesel FP down CT, followed by 1 CT volume of Diesel to FP CT & displace Diesel FP to tubing, followed by SD. RD CTU. Wait at least 6 hours to let the Crystal Seal particles fully hydrate and swell in the MBE's before returning 1E-105L1 to PWI. 7) RIH with jet swirl nozzle and tag top of Crystal Seal in well, then jet down through Crystal Seal to as deep as possible to shear & mechanically break all Crystal Seal remaining in the liner. POOH w/CT. Place 1 E-105L1 on PWI to evaluate the results of the MBE treatment. 8) RIH with IPROF BHA. Memory log down & up passes to verify if the MBE's are sealed off or still taking PWI. Wait 2 hours, then log a cool back pass. POOH with CT. RD CTU. Return 1E-105L1 to PWI service. Leave 1E-105L1 on PWI to 'B sand only' for a few months to ensure that the B MBE's continue to appear to be sealed off. Depending on surveillance, evaluate retreatment options for the MBE's, if needed. If several months have passed without obvious indications of treatment failure, proceed to normal up the well to resume unobstructed PWI to the A sand and D sand laterals as follows: Coil Tubing: 9) RIH to pull the Iso-Sly across the D LEM at 7258' RKB. 10) RIH to pull the Diverter in the B LEM at 7524' RKB. Return 1 E-105 to PWI service to all 3 laterals. KUP PROD 1E-126L1 COI occ i hllllp5 " Well Attributes Max Angle&MD TD Alaska.Inc. - Wellbore API/UWI Field Name Wellbore Status net C) MD(ftKB) Act Btm(ftKB) c wr,: „tp, 500292321560 WEST SAK PROD 94.05 9,260.53 12,468.0 ... Comment H2S(ppm) Date Annotation End Date KB.Grd(ft) —Rig Release Date 1E-126L1,10123/201311:52'.17 AM SSSV.NIPPLE 80 8/24/2012 Last WO: 5/3/2007 33.71 8/312004 Vertical schematic jactual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ..._. ...._.... _ _. __ _._Last Tag: Rev Reason:WELL REVIEW osborl 10/23/2013 HANGER.25.1 -IF, Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 1 B-SAND LINER 5 1/2 4.950 7,302.6 12,455.8 3,394.9 15.50 L-80 DWC Liner Details Nominal ID — — Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (in) 7,302.6 3,465.3 77.46 HANGER BAKER MODEL B-1 HOOK HANGER 4.760 .n.tij CONDUCTOR,26.0-108.0-4• Perforations&Slots NIPPLE.516.9 Shot Dens Top(TVD) Btm(TVD) (shots/f Heat Trace.2,970.0 - Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date f) Type Com 7,334.0 9,768.0 3,471.7 3,437.8 WS B,WS C, 8/31/2004 40.0 IPERF Alternating w/blank pipe, 1E-126L1 slots 2.5".125",4 circumferential rows/ft- Applies to all Perfs 9,893.0 12,422.0 3,437.4 3,396.9 WS B,1E- 8/31/2004 40.0 IPERF 126L1 SURFACE,29.6-3795.0— + A, Notes:General&Safety End Date Annotation GAS LIFT,4,1019 9/8/2004 NOTE:TRI-LATERAL WELL:1E-126(A-SAND),1E-126L1(B/C-SAND),1E-1261.2(D-SAND) 2/23/2009 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT,5.280.9 NIPPLE,6.972.1 GAUGE,6,988.7 LOCATOR:7.039.1 '� SEAL ASSY,7,040.2 ■ • D-SAND LINER,7,103.4- 12435 0 -124350 D-Sand Window,7,105.0- 7,1240 FISH:7,131.0 ■M■ D-SAND LINER LEM,7,029.8- 7.286 2 B-Sand Window 7,305.0- 7,321.0 INTERMEDIATE:27.c-8.0880 BSAND LINER LEM,7,245.2- 7,457 5 ,245.2-7,457,5 IPERF,7,334.0-9,768 0 (PERF,9,8930-12,422.0 B-SAND LINER,7,3026- 12,455.8 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q Lf. - 1 ~ '3 Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 111111111I111111111 RESCAN ~olor Items: o Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Diskettes, No. D Other, Norrype: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: BY: ~ Date: U I g I Dfo I I 151 vY\p Project Proofing 1111111111111111111 x 30 = Is/ mP &3 BY: ~ Scanning Preparation + 3 = TOTAL PAGES (Count does not include cover sheet) /5/ BY: Date: Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: VYES NO BY: ~ Date: l il C6 / 0 k:, Is/ wt F Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO 1111111111111111111 BY: Maria Date: Is/ 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 111111111111111111I BY: Maria Date: /5/ Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 1 fl 'Z008 REPORT OF SUNDRY WELL OPEF~~as C°ns• Comml~sion 1. Operations Pertormed: Abandon ^ Repair Well ^ ^ Plug Perforations ^ ~~ ~~~ ^ et Li-LEM Stimulate Isolation Sleeve Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development 0 Exploratory ^ 204-123 • 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23215-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 1 E-126L1 8. Property Designation: 10. Field/Pool(s): ADL 25651 ~& 25660 • Kuparuk River Field !West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12468' feet true vertical 3394' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 3767' 13-3/8" 3795' 2304' INTERMEDIATE 8060' 9-5/8" 8088' 3605' L2 WINDOW 20' 9-5/8" 7125' 3422' L1 WINDOW 16' 9-5/8" 7321' 3469' LINER 5153' 5-1/2" 12455' 3394' Perforation depth: Measured depth: 7334'-9768', 9893'-12422' ~~I~NNE®JUN 2 ~ 2008 true vertical depth: 3472'-3438', 3437'-3397' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7062' MD. Packers &SSSV (type & measured depth) PKR= Baker PKR and ZXP Liner Top PKR PKR= 7067' and 7245' SSSV= NIP SSSV= 517' 12. Stimulation or cement squeeze summary: 1_ \ C Intervals treated (measured) N/A 4 ~ ~ ~ ~ T t d i ti i l l rl J~ t ~^ '~® ~~~ rea ment escr p ons nc uding vo umes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 387 ~ 168 29 1146 205 Subsequent to operation 818 126 908 863 219 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^ - Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: N/A contact Bob Christensen /Bob Buchholz 4 41 Printed Name Robert W. Buchholz Signature i~ ` ~ ~~~~'~r~~ Title Phone: 265-6471 1 Production Engineering Technicia Date ~~~ ~Q r~ ~ v ~ Pre aced b Sha n Allsu Drake 263-4612 ~~~~iVl`i~ ~ G,/4.b8 Form 10-404 Revised 04/2006 Submit~O,rw~ `aI~QQr>~~/ 1 E-126L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 5/14/2008 RUN TYPE 1 ISOLATION SLEEVE INTO B-SAND LEM.NOTIFY DSO THAT B-SAND HAS BEEN SHUT OFF AND WELL IS READY TO BRING ONLINE.JOB COMPLETE. MHA.(2.25" x 1.38' CTC)(2.13" x 1.38' DBPV)(2.13" x 1.58' DISCO)(2.72" x 1.0' XO){2.87" x 4.40' HIPP-TRIPPER)(3.13" x .86' XO)(3.50" x 1.86' GS SPEAR 4")(3.688" x 19.0' TYPE 1 ISO SLEEVE) OAL=31.46' KRU 1 E-126L1 ConocoPhillips Alaska, Inc. • • -.~.._ .~ ,~ - ~~, µ- . ~. ;" ~~ MICROFILMED 03!01 !2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc I \L.\.n...1 Vt::LJI . STATE OF ALASKA. t\1:I\'f.2--' 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Commission REPORT OF SUNDRY WELL OPERA TIONSAnchørage 1. Operations Performed: Abandon D Repair Well 0 Plug Perforations D Stimulate D Other D Alter Casing D Pull Tubing 0 Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 204-1231 , 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23215-60 r 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' < 1 E-126L 1 <",,' 8. Property Designation: 10. Field/Pool(s): ADL 25651'& 25660 ' Kuparuk River Field 1 West Sak Oil Pool ..- 11. Present Well Condition Summary: Total Depth measured 12468' / feet true vertical 3394' , feet Plugs (measured) Effective Depth measured 12421' feet Junk (measured) true vertical 3396' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 3767' 13-3/8" 3795' 2306' PRODUCTION 8060' 9-5/8" 8088' 3605' LINER 5154' 5.5" 12456' 3395' Perforation depth: Measured depth: 7334'-9768',9893'-12422' &.:;ANNED JUN 1 4 2007 true vertical depth: 3469'-3438',3438'-3397 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7062' MD (tubing in main wellbore) .. .................... Packers & SSSV (type & measured depth) Baker pkr @ 7076' in main wellbore, ZXP pkr @ 7245' in main well bore Cameo 'OS' nipple @ 517' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubina Pressure Prior to well operation SI Subsequent to operation 174 665 116 -- 467 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory D 0 - D Development Service Daily Report of Well Operations _X 16. Well Status after work: Oil0 GasD WAGD GINJD WINJD WDSPL D 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: Contact Jill Long @ 265-1102 Printed Name ¿JjQM!ìYI/JJ Title Wells Group Engineer / -{(ji- Signature Phone Date Ds If/07 PreDared bv Sharon AI/sun-Drake 263-4612 [/ o RfG'r RBDMS 8Ft JUN ] J 2007 ~ ~ 2.~.Þ7 Form 10-404 Revised 04/2006 ^ Sub riginal Only. NAL ~~ ~:r~¡G7 . . ConocoPhillips A.laska, Inc. KRU 1E-126L 1 ~ TUBING W API: 500292321560 Well Tvce: PROD Anale @ TS: dea @ (0-7062, SSSV Tvce: NIPPLE Oria ComDletion: 8/31/2004 AnQle @ TO: 93 deQ @ 12468 OD:4.500, Annular Fluid: Last W/O: 5/3/2007 Rev Reason: WORKOVER ID:3.958) Reference Loa: 28' RKB Ref Loa Date: Last UDdate: 1/5/2007 Last Taa: TD: 12468 ftKB Description Size Top Bottom TVD wt Grade Thread SURFACE 13.375 0 3795 2303 68.00 L-80 BTC PRODUCTION 9.625 0 8088 3457 40.00 L-80 BTC-M SURFACE I CONDUCTOR 20.000 0 108 108 94.00 K-55 WELDED (0-3795, W"DDW~ 70" "" <0.00 L·OD BT'" OD:13.375, WINDOW 9.625 7293 7294 3463 40.00 L-80 BTC-M Wt:68.00) ~~ III I_Ii ~7~m ¡~Iil~ B-SAND 3395 I ~ ¿,~~~ 4.500 0 12.60 L-80 IBT IQllllll:ìll'.": Interval TVD Zone Status Ft SPF Date TVDe Comment 7334 - 9768 3469 - 3438 WS B,wS C 2434 40 8/31/2004 IPERF Slatted liner, alternating w/blank pipe, slats 2.5"x.125", 4 circumferential rowslft 9893 - 12422 3438 - 3397 WS B 2529 40 8/31/2004 IPERF Slatted liner, alternating w/blank pipe, slots 2.5"x.125", 4 ,,1r;¡MD TVD Man Man Type V Mfr V Type V Latch Port Date Run Vlv Mfr Cmnt .188 1485 5/12/2007 2 5281 2826 CAMCO OV 1.0 0.313 0 ~2/2007 DeDth TVD TVDe DescriDtion ID 25 25 HANGER MCA 4.909 TUBING HANGER set 5/2/2007 3.900 517 515 NIP CAMCO 'DS' NIPPLE set 5/2/2007 3.875 2970 2006 Heat Trace HEAT TRACE 2970' TO 3063' set 5/2/2007 0.000 ,. 6972 3383 NIP CAMCO 'DB' NIPPLE set 5/1/2007 3.813 . 6989 3387 Gauge A-WELL GAUGE MANDREL (WEATHERFORD) set 5/2/2007 3.950 Mandrel 7038 3400 LEM L2 D-SAND LATERAL ENTRY MODULE (LEM), TOTAL LENGTH 248' - includes "HR" 3.870 Liner Setting Sleeve, ID 7.6", XO Brushing ID 4.88", Seal Bare Extension ID 4.75", Production Packer ID 3.87", LEM HH Above Hook ID 3.95", LEM HH Below Hook ID 3.68" Nan-Lacatina Seal Assemblv ID 3.89" SET 5/1/2007 7040 3400 SEAL BAKER GBH-22 SEAL ASSEMBLY set 5/212007 3.890 7103 3416 HANGER L2 BAKER MODEL B-1 HOOK HANGER FOR LEM. FOR D-SAND L2 6.200 7245 3452 LEML1 B-SAND LATERAL ENTRY MODULE (LEM), TOTAL LENGTH 52' - includes ZXP 3.680 Liner Tap Packer, ID 6.278", CSG Sealbore Receptcle 4.75", 15' Length, Orienting Profile, Seal Bare far Lateral Isolation 3.68" 10, Access Window VIA Thru Tubing Diverter, SEal Bare far Lateral Isolation 3.68" ID, 4.75" Isolation Seal Assembly 3.875" ID, 12' lenath _'i.~GERQ BAKER MODEL B-1 HOOK HANGER£9R LEM, FOR B-SAND L 1 6.200 I I Date I Note 8/31/2004 INOTE: TRI-LATERAL WELL: 1E-126/A-SANDJ, 1E-126L1IB/C-SAND). 1E-126L2/D-SAND) I "RODUCTION I (0-8088, OD:9.625, Wt:40.00) I r B-SAND I ..= LINER == = (7302-12455, == == OD:5.500, == == Wt: 15.50) ~ I I ..~ I I I · Conoc;Phillips We//vIew Web RepDrtlng Time Log Summary 04/17/2007 12:00 15:00 3.00 DEMOB MOVE DMOB P Move rig to let camp pass. Break down stack and secure On skid. Camp moved to 1 E. 15:00 00:00 9.00 DEMOB MOVE WOEQ T Waiting On cats for descent down hill between 2L & 2M 04/18/200700:00 03:00 3.00 MIRU MOVE WOEQ T Waiting on cats for descent down hill between 2L & 2M. Stage 2 Cats at 2L. 03:00 13:30 10.50 MIRU MOVE MOB P Move rig from 2N to hill, about 5 miles. ¥f7K X Tie Cats onto back of rig and move ~ù~'\~ down hill to bridge. Release Cats to tJ)~ ~(t)" load out back at 2L Pad. Move rig ð'\~ IX.\\~ " across bridge and continue moving to ~0þ.<""'·: l 2B Pad. iþ"~ ¡\\ ",I:. ...tJ 13:30 00:00 10.50 MIRU MOVE WOW T Wait On weather 1 storm to subside. ~i.:?) (¡oJ' -i'~ Equipment needed to clear way for rig. \Pv'õ Rig currently waiting On 2B pad. S~f- Roads & Pads equipment tied-up <J,\;'J\ù1 keeping spine roads open, will also need dozer to knock down drifts on both sides of road for ri to clear. 04/19/2007 00:00 00:00 24.00 MIRU MOVE WOW T Wait On weather 1 storm to subside. Equipment needed to clear way for rig. Rig currently waiting on 2B pad. Roads & Pads equipment tied-up keeping spine roads open, will also need dozer to knock down drifts on both sides of road for rig to clear. Winds subsiding around nOOn. Roads & Pads equipment catching-up to open roads, but equipment break downs (snow blower) limiting availability to clean out roadside drifts ahead of ri . 04/20/2007 00:00 12:00 12.00 MIRU MOVE WOW T Wait on weather 1 storm to subside. Equipment needed to clear way for rig. Rig currently waiting on 2B pad. Roads & Pads equipment tied-up keeping spine roads open, will also need dozer to knock down drifts On both sides of road for rig to clear. Roads & Pads equipment catching-up to open roads, but equipment break downs (snow blower) limiting availability to clean out roadside drifts ahead of ri . 12:00 13:00 1.00 MIRU MOVE MOB P Prep rig to move, warm up moving s stems Move rig from 2B pad to 2C pad. Rig catching up to road clearing e ui ment. 15:30 19:00 3.50 MIRU MOVE WOW Set rig down and standby. Roads & Pads clearing drifts and road ahead of ri . 19:00 00:00 5.00 MIRU MOVE MOB P Move rig from 2C pad to 1 E - turn oft spine onto 1 E access raod at midni ht. 04/21/200700:00 04:00 4.00 MIRU MOVE MOB P Continue move Nordic rig 3 from 1 E to 1 E pad. Arrive 1 E, cross pad, spot rig over well 1 E-126. 04:00 06:00 2.00 P PJSM, RU over 1 E-126, take fluids to pits, begin prep for ND tree, lay hard lines for kill tank, berm in selected equip. Accept Nordic rig 3 0400 hrs this date 4/21/07 06:00 08:00 2.00 P RU 2" circulating lines to manifold. Check hardlines to Tiger Tank. Bring seawater into pits and mix in 6% KCI. Brin in lubricator. 08:00 10:00 2.00 P PJSM. RU crane & hoist ESP spooler and empty spool onto rig floor. Set up s ooler. RD crane. 10:00 10:30 0.50 P RU Vetco Gray lubricator. Pull BPV. 10:30 13:30 3.00 P RU circulating lines & PT with rig air. Thaw frozen outside line and blow clear. Finish RU line to Tiger tank & PT with ri air. 13:30 14:00 0.50 P Check well pressures. Tubing & IA = 200 si. OA=100 si. 14:00 17:30 3.50 P PJSM. Circulate 8.8 ppg SeaWater/6% KCI down tubing, taking diesel returns from IA through choke to outside Tiger tank, 5 BPM. Had diesel returns until a full circulation, then got 8.8 ppg KCIISW returns with diesel cut. Circulated to 470 Bbls and had trace of diesel in 8.8 ppg KCIISW returns. Shut down 30 minutes to let diesel separate, circulated 15 Bbls, good 8.8 ppg KCIISW with trace diesel. Let set 30 minutes more, then reversed 5 Bbls, 8.8 ppg returns from tubin with no diesel. 17:30 20:30 3.00 COMPZ WELCT OWFF P Monitor well, bleed slight gas migration, monitor well, no gas, nO press build. Set BPV. 20:30 22:30 2.00 COMPZ WELCT NUND P PJSM, test packofts 1 seals, repair threads On test port cover cap. ND tree. 22:30 00:00 1.50 WELCT NUND P PJSM, NU BOPE. 04/22/2007 00:00 03:30 3.50 WELCT NUND P Cont NU BOPE. · 04/22/2007 03:30 08:00 4.50 COMPZr WELCT BOPE P PJSM, RU 1 test BOPE 250/2500 psi 08:00 09:30 1.50 COMPZr RPCOII. RURD P Rig down lines, pull balancing plug & back pressure valve 09:30 10:00 0.50 COMPZr RPCOII. RCST P PJSM, Make up landing joint BOLDs, pull hanger to floor, broke free at 150k. PU 95k. 10:00 11:30 1.50 COMPZr RPCOII. CIRC P Break circulation, lost 32 BBLS. Filled at 5.5 BPM 140 psi. 11:30 12:00 0.50 COMPZr RPCOII. OWFF P Monitor well, well static 12:00 14:30 2.50 COMPZr RPCOII. RURD P Rig up to spool ESP cable, lay down hanger and landinq ioint 14:30 22:00 7.50 COMPZr RPCOII. RCST P Pull completion, spooling ESP cable and laying down jewelry 22:00 23:30 1.50 COMPZr RPCOII. RCST P Drain, break down and lay down motor and seal. 23:30 00:00 0.50 COMPZI RPCOII. RURD P Clear floor 04/23/2007 00:00 02:00 2.00 COMPZI RPCOII. RURD P Continue clear rig floor, unload tools and equipment from rig. Bring in Baker equipment for cleanout BHA. Strap & caliper BHA. 02:00 02:30 0.50 COMPZI RPCOII. RURD P Set wear bushing. 02:30 04:30 2.00 COMPZI RPCOII. OTHR P Change elevators. PU & MU cleanout BHA #1: 4-11/16" smooth OD Shoe & Globe Basket (3-1/4" ID) + 2 XO + 8 Jts 2-718" PAC DP + 2 XO + 2 Boot Baskets + BS + Bumper + Oil Jar + Pump Out Sub + XO. 04:30 14:00 9.50 COMPZI RPCOII. TRIP P RIH PU 9 DC. RIH PU 4" DP. Tag fill at 6705' MD, set down to 6711' MD. 14:00 14:30 0.50 COMPZI RPCOII. OTHR P PU and MU head pin and hose. RU to reverse circulate and wash out fill. 14:30 16:00 1.50 COMPZI RPCOII. FCO P Close bag, reduce closing pressure. Reverse circulate and wash out fill from 6705' to 6718'. Reverse bottoms up, got very fine sand returns. 70 SPM, 4 BPM, 450 psi. 16:00 22:30 6.50 COMPZr RPCOII. FCO P COntinue washing down singles, reversing, 70 SPM, 4 BPM, 440 psi. Clean out fill from 6718' to 6861 ft. No further progress. Will not wash. 22:30 00:00 1.50 COMPZr RPCOII. FCO P PJSM, Press check, open BOPE, flow check, line up for conventional circ, commence wash, immediate success, cont wash to 7038 ft. 140 spm 1990 psi. Fine sands to shaker. 04/24/2007 00:00 04:00 4.00 COMPzr RPCOII. FCO P Wash to tag (btm SBR) at 7293 ft. Lose circ, 100% loss, no returns. Monitor well, no gas 1 wellbore not On vacuum. 04:00 05:30 1.50 COMPZr RPCOII. CIRC P Call DHD for fluid level shot. Pump sweep dn tbg and annulus for cleanout residual sands while wait on equip. / 04/24/2007 05:30 06:00 0.50 COMPZr RPCOr.. OWFF P PJSM, RU I shoot fluid level resulting in level at 420 ft. Hole will fill at surface at 6 bpm, immediately falling to 420 ft, but nO returns while pump dn DP or annulus. 06:00 07:30 1.50 COMPZr RPCOI\ TRIP P POOH from 7293' to 6369'. Overfill hole for trip volume. 07:30 09:00 1.50 COMPZr RPCOr.. OTHR P PJSM. RU crane. Remove old ESP cable spool. Bring in I-wire on spooler. Bring in clamps, etc. Set in heat trace cable and spooler. RD crane. 09:00 15:00 6.00 COMPZr RPCOr.. TRIP P Continue POOH from 6369' to 570'. Overfill hole for trip volume, pumping an extra 5 Bbls fill-up each 5 stands. 15:00 17:30 2.50 COMPZr RPCOr.. TRIP P LD 9 DC & cleanout BHA #1. All tools in good shape. Recovered only a few small pieces of thin metal from original window milling in globe basket. Only a small amount of fine sand in boot baskets. 17:30 18:30 1.00 COMPZI RPCOI\ OTHR P Clear floor. Pull wear bushing, verify LEM equipment will pass through WB, OK. Set test plug. 18:30 19:30 1.00 COMPZI WELC1 BOPE P Test variable PR with 4", retest annular, 250 psi & 2500 psi. 19:30 21:00 1.50 COMPZ WElC1 BOPE P RID and UD test equipment. Set Wewar Ring. 21:00 00:00 3.00 COMPZ RPCOI\ PULD P PIU and assembly LEM #2. Shoot fluid level at 2300 hrs, TOF @ 150 ft. 04/25/2007 00:00 01:00 1.00 COMPZr RPCOI\ PULD P M/U LEM. Orient wI MWD, RIH. 01:00 01:30 0.50 COMPZr RPCOI\ TRIP P Shuttle DC's and Drillstring for RIH. RIH w/5 stds DP. 01:30 02:00 0.50 COMPZr RPCOI\ OTHR P Shallow test MWD. 02:00 06:00 4.00 COMPZr RPCOI\ TRIP P RIH wI LEM Assembly. 06:00 09:00 3.00 COMPZ RPCOI\ TRIP P Cont RIH w/lEM Assembly. 09:00 11:00 2.00 COMPZ~ RPCOI\ HOSO P Locate and attempt to latch into hook hanger wI LEM. Orient and circulate, wash to 7283', unable to latch. Pump 50 bbls down annulus to flush seal bore. Pump addnl 50 bbls, attempt to set again. Unable to circulate, fluid level wI pumping just below bell nipple on stack. 11 :00 18:30 7.50 COM PZ~ RPCOr.. FCO T Continue attempting to set LEM wI alternate pumpingl rotating and recip. Unable to land and latch into Hook Hanger. Possible sand fill in wellbore. Decision made to POOH w/lEM as nO progress. 18:30 00:00 5.50 COMPZ~ RPCOr.. FCO T POOH w/lEM assy fl 7115' - 269'. . v POOH to LEM. Prepare to layout MWD and LEM com onents. 01:00 06:00 5.00 T While breaking out setting sleeve running tool, inner string backed off. Unable to extract inner string due to excessive sand pack-off. PJSM, begin break out inner string and LEM via individual component. Break out all. Extract MWD tools, inspect and prepare LEM I running equipment for shipment to shop for inspection and clean-up. Visual On Hanger and latch assembly revealed untouched paint so failure to set likely due to excessive sand in wellbore. 06:00 08:00 2.00 COMPZ RPCOr... FCO T Load and strap 27/8" PAC pipe and handling tools in pipe shed for CIO rUn. 08:00 12:00 4.00 COMPZ RPCOr... FCO T PJSM, RIH wI CIO 2 7/8" PAC pipe clean-out assembly On end of 4" DP work strin to 7071'. 12:00 14:30 2.50 COMPZ RPCOr... FCO T RU to pump down DP and annulus simultaneously. Pump at 3 bpm down annulus, 2 bpm dn DP wI annular SI fl 7071' - 7166'. 14:30 18:30 4.00 COMPZ RPCOr... FCO T Work pipe wI pumping f/7166' - 7324'. Hit obstruction at 7286 and work through wI tbg. At end of clean-out, located hook wI no-go collar at 7103'. Mule shoe de th 7324'. 18:30 20:30 2.00 COMPZ RPCOr... FCO T Blow dn top drive, and POOH wI 5 stands wI pumping. SD and wait for 1 hr to observe. 20:30 21:30 1.00 COMPZ RPCOr... FCO T RIH wlo pumping to determine fill, none detected, again locate and land On hook at 7103'. Pump 20 bbls wI pumping at 3 bblsl min dn annulus and 2.5 bbllmin dn DP. 21:30 00:00 2.50 COMPZ RPCOr... FCO T POOH f/7324' - 3078'. Overdisplace hole x 2 pipe displacement in attempt to minimise sand inflow. 04/27/2007 00:00 02:00 2.00 COMPZ RPCOr... TRIP T TOH, Top Drive developed probem. 02:00 03:00 1.00 COMPZ RIGMN RGRP T Work on Top Drive electrical problem. 03:00 03:30 0.50 COMPZ RIGMN SVRG P Service and lube rig. 03:30 06:00 2.50 COMPZ RPCOr... TRIP T POOH wI workstring and PAC clean-out strin . 06:00 06:30 0.50 RPCOr... TRIP T Finish wI Clean-out string. LD 2 7/8 PAC i e and XO's. 06:30 08:00 1.50 RPCOr... PULD T Make up LEM. 08:00 12:00 4.00 RPCOr... PULD T Wait on pups for inner string and make up bull nose shoe jt. Work On To Drive. 04/27/2007 12:00 15:00 3.00 COMPZr RPCO~ PULD T PJSM. Make up inner string tools for LEM run. Assemble inner string wI MWD and install in LEM Run In tool. 15:00 15:30 0.50 COMPZr RPCm TRIP T @ 320 psi. PU 45klbs, SO 46klbs 15:30 23:30 8.00 COMPZr RPCm TRIP T SO TO and RIH wI LEM f/473' - 7019'. PU 125 klbs, SO 58 klbs. 23:30 00:00 0.50 COMPZ RPCO~ SFTY T PJSM wI Drlr, Tool Hnd, Co Rep and rig crew. Discuss procedure and wash-in I set procedure for LEM. 04/28/2007 00:00 01:30 1.50 COMPZ~ RPCm CIRC T Break circulation, rate 52 spm @ 460 psi. Orient assembly wI MWD, pump wI slowly work in hole to 7264', near top of csg seal bore assv. 01:30 05:00 3.50 COMPZ~ RPCO~ RCST T Cut pump rate to 10 spm, 50 psi and cont RIH to land hook hanger. Stack out at 7279. Based on PU and SO, determine top SBE at - 7273' dd. Unable to land assy. PU and try alt LEM orientation. Noted pump press increase to 510 psi at 52 spm. Press same wI or wlo seals stabbed into Csg SBE, possible plugged hole On bullnose circ jt. Cont wI landing attempt by alternating LEM orientation and recip. Unable to proceed, noted stack-out depth same as original LEM rUn attempt. Decision made to POOH and alter lenth of seal spacer pups. 05:00 06:00 1.00 COMPZr RPCO~ TRIP T PJSM, POOH wI LEM assembly for modification. Pumping fld down backside at 16 - 20 bblsl hr. 06:00 07:00 1.00 COMPZr RPCO~ TRIP T Cont TOH to 6366'. 07:00 08:30 1.50 COMPZr RIGMN SVRG T PJSM, Slip and Cut Drill Line. 08:30 14:00 5.50 COMPZr RPCO~ TRIP T TOH wI LEM assembly. f/6366' - 0' 14:00 16:30 2.50 COMPZr RPCm PULD T Break out and lay down LEM assembly & MWD tools. 16:30 19:00 2.50 COMPZr RPCm WOEQ T Wait on composite bridge plug, clean floor and riQ upkeep. 19:00 00:00 5.00 COMPZr RPCO~ PULD T PU and MU Bridge Plug On 2 7/8" PAC DP. RIH to 7299' MD. 04/29/2007 00:00 01:30 1.50 COMPZr RPCO~ PACK T Set 4" Baker model 360 Quik-Drill composite bridge plug @ 7295' dd inside tubing below csg seal bore assembly. Test wI tag. OK. Break circulation at 2 bpm to monitor for returns, 100 %. 01:30 05:30 4.00 COMPZr RPCm TRIP T PJSM, POOH wI setting tool. Break out runninQ tool, LD 2 7/8" PAC strinQ. 05:30 06:00 0.50 COMPZr RPCO~ PULD T PJSM, PU LEM assembly wI wash string for hook hanger latch test. (Test only, to confirm latch possible) 06:00 08:00 2.00 COMPzr RPCO~ PULD T PU LEM assembly wI MWD, RIH 3 stds. Shallow test MWD @ 53 spm, 350 si, OK. 08:30 11 :30 3.00 Cont RIH wI LEM - 6888'. 11:30 12:30 1.00 T Circulate wI TIH wI LEM 6888' - 7107'. 65 spm @ 650 psi, 120 klbs up, 57 klbls dn I wash through collet lock area wI 'etted sub to remove debris. 12:30 19:30 7.00 T Multiple attempts to latch in LEM. Vary orientation, set weights, circulating, washing etc in attempt to set and latch LEM. Last 5 attempts to latch succesful. LEM set and Latch depth 7105.5'. Total TD BHA = DP 7133'. PU 125 klbs, SO 53 klbs. Last attempt after full pick-up and rotation of pipe to insure repeatability, OK. 19:30 21:30 2.00 COMPZ RPCOII. CIRC T Circulate hi-vis sweep, CBU and re are to POOH. 21:30 00:00 2.50 COMPZ RPCOII. TRIP T TOH wI LEM and MWD assembly. fl 7133' - 3559'. 04/30/2007 00:00 02:30 2.50 COMPZ RPCOII. TRIP T TOH wI LEM and MWD. Break out and LD LEM after inspection. No visible sign of damage or other. Inspection of collet latch and hook reveal latch OK. 02:30 03:00 0.50 COMPZ T Clear floor and prepare for BOPE test. 03:00 06:00 3.00 WELCT BOPE T PJSM, Test BOP equipment. / 06:00 09:00 3.00 WELCT BOPE T Finish BOPE test. Test all components 250 I 2500 psi, all ok. Pull test lu ,set wear bush in . 09:00 12:00 3.00 COMPZ RPCOII. PULD T PJSM, PU Globe baske on 2 7/8" PAC tail pip. RIH wI 4" DP U6440'. Calc dis 36 bbls, Acutal 34 bbls 12:00 15:30 3.50 COMPZ RPCOII. CIRC T Cont RIH f/6440' - 7203'. Attempt to reverse circulate, Pump 70 bbls, nO returns, no fluid observed at surface in well. Pump addnl 30 bbls, no returns. RIH tag bottom of SBE 7295' wI nO fill detected. PIUp 6', pump addnl 25 bbls, FL shot TOF @ 282' in DP. PU 125 klbs, SO 60 klbs. POOH 3 stds U 7010', shoot fluid level, TOF @ 282' in DP. 15:30 20:30 5.00 COMPZ T TOH wI clean-out assembly fl 7010' - 262'. 20:30 21:00 0.50 PULD T LD clean-out BHA. 21:00 00:00 3.00 PULD T PJSM. PU LEM assembly wI packer and seal ass . 05/01/200700:00 01:00 1.00 T Finish PU I MU of LEM-2 assy wI packer, seal assy & MWD for orientation. 01:30 09:00 7.50 T TIH wI LEM-2 assembly at max trip speed of 30 ftImin. Observe fluid loss while TIH to 7296 ft. Losses at rate of 24+ bbllhr, no returns. 09:00 10:30 1.50 T Work hook assy, orient to hook. In place at 18 deg to right. Pull up 10ft. partial rotation. set dn, confirm with return to 18 deg to right. No collet "snap" felt at surface after multiple attempts. Partial returns during rocedure. Up 140, Dn 70 10:30 11:30 1.00 T Circ with partial returns while mix I pump 1 % lube. Note Up I Dn wts. decreased to 132 U ,Dn 70. 11:30 12:00 0.50 P Service rig while circ lube. 12:00 13:30 1.50 P Latch LEM, Defined collet indicator. Confirmed "snap" in lout of position. Drop ball, pump dn to pkr. Build to 4030 psi, pkr set. PKR 7076 ft, Top hook 7105.5 ft. 13:30 15:30 2.00 P PJSM, test pkr (9-5/8 X 4" DP) to 2500 psi I 30 min and chart. Bleed and re-test 3 times to obtain final straight line test. (Aired I foamed fluids 15:30 16:00 0.50 P Blow down top drive, monitor well. takin fluid, PJSM. 16:00 00:00 8.00 P Continue POOH wI lay down 4" DP workstrin . POOH f/7076' - 1537'. 05/02/2007 00:00 03:30 3.50 P POOH lay down workstring. Lay down runnin tools, MWD and other. 03:30 04:30 1.00 P Clear floor. pull wear bushing and prepare for running of completion. Load remaining 4 1/2" IBT tubing in i eshed and stra . 04:30 06:00 1.50 RU to run completion on 41/2" IBT tbg. Pull wear ring, RU and Tec-wire and heat trace s oolers, fct test. 06:00 12:00 6.00 COMPZ RPCOII. PULD P PJSM, Connect TEC-wire U inst sub, RIH wI completion fl 0 - 2722'. Installing TEC-wire wI single channel Cannon clam s as er ro ram. 12:00 15:30 3.50 COMPZ RPCOII. PULD P Continue RIH wI completion fl 2722' - 4185'. 15:30 16:30 1.00 COMPZ RPCOII. RURD P RU fl start of Heat Trace installation. 16:30 00:00 7.50 COMPZ RPCOII. PULD P Cont RIH wI completion f/4185' - 6768' wI TEC-wire and heat trace attached wI dual channel Cannon clamps as er ro ram. Continue RIH wI 4 1/2" 1ST tubing to top of seal bore extension. Tag no go at 7041'. Fill annulus, monitor well. No losses. Determine PUlSO to insure tubing landed in tension wI locator at 7039ft, i.e. 2' off bottom. 06:30 10:00 3.50 P Space out, MU pups I tbg hgr Ildg jt. Total TEC-wire and Heat trace clamps used as follows: (131) Single channel Cannon @ 1ljt below heat trace. (455) 5' dual channel clamps, (9) 4' dual channel clamps, (9) 3' dual channel clamps, (9) 2' dual channel clamps, 89 Cplg dual channel clamps @ collars, 2 bands at hanger area. Heat trace start at 4092'. 10:00 14:00 4.00 COMPZ RPCOII. OTHR P Prep hngr, terminate TEC wire I heat trace to h r. Test all connections. 14:00 16:00 2.00 COMPZ RPCOII. CIRC P Attempt reverse CÎrc. No returns. Pump 170 bbls 1 % CRW32 inhibitor dn tbg to 4-1/2 X 9-5/8 annulus. Approx 30% returns to surface during circ. 16:00 17:00 1.00 RPCOII. HOSO P PJSM, land hgr, RILDS. Confirm hgr dn. 17:00 19:00 2.00 RPCOII. DHEQ P RU I test IA wI chart recorder. Build I hold 1000 psi, 30 min. OK. Build I hold 1500 psi 30 min, OK. Pressure / up to shear SOV. SOV sheared out at 1960 psi. Pump addnl18 bbls to insure clear. RD pressure sensors and clear floor for next task. 19:00 23:00 4.00 P PJSM. SET BPV, NO Stack wI service breaks for storage. Remove stack and clear area for settin tree. 23:00 00:00 1.00 P Test heat trace and TEC-wire OMS, OK. Prepare connections and wellhead for settin tree. 05/04/200700:00 03:00 3.00 P Finish prep of wellhead set in place. Install tree. Pull BPV, Set 2-way / check, pressure test pack-off 5000 psi OK. Test tree 250/5000 psi, OK. Pull 2-wa check, set BPV. 03:00 05:00 2.00 P Work On rig prep for move, while wait on hot oil for freeze protect. RU hard line, ull tar s etc.. 05:00 07:00 2.00 P RU, hot oil, PJSM, ptest lines 2500 psi. Freeze protect IA wI 160 bbls diesel, had 5 bbls total returns. Swap valves and freeze protect tbg by bullheading 60 bbls. ICP 100 psi, FCP 1375 wI pumping IA. ICP 150 psi, FCP 500 wI pumping tbg. Final static tbg press 200 psi, IA 400 psi. RD, release Hot Oil. 07:00 08:00 1.00 COMPZ RPCOII. RURD P PU lubricator, set BPV. Finish clean pits & prep rig for move, NORDIC RIG #3 RELEASED THIS DATE 1000 HRS. )Q~ DATA SUBMITTAL COMPLIANCE REPORT 9/11/2006 Permit to Drill 2041230 Well Name/No. KUPARUK RIV U WSAK 1E·126L 1 Operator CONOCOPHILLlPS ALASKA INC MD 12468 Completion Date 8/31/2004 Completion Status 1-01L Current Status 1-01L TVD 3394 -- REQUIRED INFORMATION 3,~o~_or!f::¡/:::o'1 UIC N Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GRlRes Well Log Information: (data taken from Logs Portion of Master Well Data Maint Logl Data Typ~ ~;t I~c I µD k ~ ~. Electr Digital Dataset MedlFrmt Number Received 9/22/2004 2/11/2005 Interval Start Stop 7305 12468 108 12468 Log Log Scale Media OHI CH Open Open Run No Name Directional Survey 13002 Induction/Resistivity 25 C Pds CAse 13002 LlS'Verification 108 12468 Open 2/1112005 Induction/Resistivìty 25 Blu 108 12468 Open 2/3/2005 25 Blu 108 12468 Open 2/3/2005 Induction/Resistivity Well CoreslSamples Information: Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMATION Well Cored? ~ Chips Received? ~ Daily History Received? WN ~N Formation Tops Analysis Received? ¥+I'r Comments: Comments MULTIPLE Propagation Resistivity/Gamma Ray/RWD MULTIPLE Propagation Resistivity/Gamma Ray/RWD multiple propagation resistivity/gr/rwd multiple propagation resistivity/gr/rwd . l I I I I I I I ------.J . DATA SUBMITTAL COMPLIANCE REPORT 9/11/2006 Permit to Drill 2041230 Well Name/No. KUPARUK RIV U WSAK 1E-126L1 Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-23215-60-00 MD 12468 TVD 3394 H Completion Date 8/31/2004 Compliance Reviewed By: ~ Completion Status 1-01L Current Status 1-0IL. ~ UIC N Date: ~ ~ ÅJ\-€O- ~ . . . Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason #1~Ù,D}- Reference: lE-t26, lE-126Ll, & lE-t26L2 2-0J - /Z'L . ~oLI- /¿'3 . a () f- /2 c¡ ~ ¡....m................... r'__=~~~~: -'IL5 ¡;.~~ii::::I Anchorage GEOScience Center ...... .. ..;""':;' .~.. _. ! .""",- ::~:........ : : Contains the following for each wellbore: I LDWG Compact Disc (Includes Graphic Image files) I LDWG lister summary I blueline - MPR Measured Depth Log 1 blue line - MPR TVD Log LAC Job#: 707446 Received Date: Feb 4, 2005 Date: ~~ j~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267..6612 FAX: (907) 267-6623 -~ -_..I . ..~~ ~'~~~~_.~ ~.; "...... ..... .. ~... ~--;¡'7W1-::;7:";~ --.. -,.. ~ .!"",,_.j ;....... ~~'" 0;, : ~...¡ __u _ .__~_~___.__________ .__. ~i~·<~ b::::k : " t..-- i I i""'''' i i---,~ ¡ ..~." t- ¡':~:'::1 .. ,. I I µ--.j~·~'i .,~: ¡tg ;:.~g ¡f~T~ ¡::( Ii ,~¡~n IfL-j r' ~ ....._, t'I;'f ~( ~'ij1'.' LirC.}, I ,~..:( i: ";~ :~;!i-:' ': ..,..-.::.:.....~.' ~ ~:' '. ..~._..,.. .. ).'''':'' ; ~ ' ( ! ~"..:. . .. .. . . ; ':~¡\'j; ::".. .-.:--" ,: c. ; ... ",' .,., r-:-,",--:-:---~ ¡-.~-:+~~--:-:--:-:--:- i : .-:a i~ ... I:~l~ i ¡.__..~"~_ _c··_____ "d__' t"" L_._....-l___.__ I STATE OF ALASKA .. ALAS OIL AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U Plugged U Abandoned U Suspended U WAG 0 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJ 0 WINJ 0 WDSPL 0 No. of Completions _ Other_ Service 0 Stratigraphic Test 0 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: / ConocoPhillips Alaska, Inc. or Aband.: August 31, 2004 204-123/ 3. Address: 6. Date Spudded: 17 />'$,,' t>'{ 13. API Number. P. O. Box 100360, Anchorage, AK 99510-0360 AugustX2004 50-029-23215-60 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: ,/ 1 E-126L1 Surface: 852' FSL, 631' FEL, Sec. 16, T11N, R10E, UM August 20, 2004 At Top Productive 8. KB Elevation (ft): 15. FieldlPool(s): Horizon: 1815' FNL, 1451' FEL, Sec. 22, T11N, R1OE, UM 28' RKB Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): West Sak Oil Pool 1639' FNL, 1948' FEL, Sec. 27, T11N, R1OE, UM 12421' MD / 3396' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 549890 y- 5960439 , Zone-4 , 12468' MD I 3394' TVD , ADL 25651 & 25660 , TPI: x-554373 y- 5957803 Zone- 4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 553921 y- 5952696 Zone- 4 none ALK 469 & 470 18. Directional Survey: Yes [2] NoU 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 1746' MD 21. Logs Run: T/~Dt..O '77JcY:; -' ""1> 1>1> GR/Res S¥¿:,t.ø/ fl/-Þ ",,~.tq 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD PULLED CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE 20"x34" 94# K-55 28' 108' 28' 108' 42" 348 sx AS1 13-3/8 " 68# L-80 28' 3795' 28' 2306' 16" 740 sx AS Lite, 210 sx DeepCrete 9-5/8" 40# L-80 28' 8088' 28' 3605' 12.25" 726 sx DeepCrete 5.5" 15.5# L-80 7302' 12456' 3465' 3395' 8.5" slotted liner 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 6093' 7413' slotted liner - 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. slots in liner from 7334'-9768', 9893'-12422' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED nla 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) September 20, 2004 Flowing (shares production with 1 E-126 and 1 E-126L2) Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 9/21/2004 6 hours Test Period --> 270 253 0 15% 998 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. o psi not available 24-Hour Rate -> 1045 1043 1 not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if nece~ ())~ t·~~ ,. !l~.~·· Submit core chips; if none, state "none". ,.._.__ ,.$)MS-Bfl . . rë'0¡.t,n, CT¡;;¡¡¡ . . . I -... L.,.. v" : RECEIVED [4P}~'o1 NONE _..~¿lD . ORIGINAL OCT 0 (; 2004 ~F Alask:¡ nil ¡¿ r.:!.í<; r"In" r'. " Form 10-407 Revised 12/2003 CONTINUED ON REVERSE Anchorage 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". 1 E-126L 1 West Sak B West Sak B 7304' 9865' 3465' 3432' N/A RECEIVED OCT 0 6 Z004 Alaska Oil & Gas CiJì1S" Commission Anchorage 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Shultz @ 263-4620 Printed Na~ Thomas Signature ~ Title: --=li'hone Kuparuk Drillina Team Leader 'c"tó>S- 6i?-s,o Date lc(s-íoy 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". Form 10-407 Revised 2/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: Blow down rig, Move pipe shed, Boilers, Motors, Pumps, Pits, Rockwasher & Sub complexes off 1 E-112. Spot Sub & all complexes over 1 E-126. Hook up Air, Water, Steam, Glycol, Mud lines, Prep. rig for accept. Accept rig @ 09:30 hrs 8/1/2004, Nipple up Diverter system, Take on water and mix Spud mud. Change out saver subs, Change to new drilling line spool. Pick up 50 stands 5" drill pipe and stand back in derrick. Note: Rig up on Injection well 1 E-34, Flush with 140 bbls Fresh water at rate of 1 bpm @ 1550 psi. Pick up 29 jts HWDP, Jars and stand back in derrick. Function test Diverter system, Test waived by AOGCC John Crisp. Service Top drive & Blocks. Pick up & Make up 16" BHA, Bit, Motor, Short NMDC, NM Stab, MPR, MWD, NMDC's, Orient & Program MWD tools, Flood Conductor and check for leaks. Spud well @ 05:00 hrs 8/2/04, Drill 16" hole fl 108' to 558' MD / 557' TVD, (450') ART = 1.5 hrs, AST = 3.2 hrs, WOB 20/35K, RPM 0/40, 570 gpm @ 1150 psi, UP 66K, DN 68K, 67K, Mud wt. 8.8 ppg, Vis 300+. Drill 16" hole f/ 558' to 2000 MD' / 1662' TVD, (1,442') ART = 0.0 hrs, AST = 9.1 hrs, 100% Sliding, WOB 40/45K, 607 gpm @ 2300 psi, UP 98K, DN 80K, Mud wt. 9.2 ppg, Vis 200+. Drilled 16" hole per directional plan from 2,000' to 3,331' MD/ 2,133' TVD (1,331') ART 3.4 hrs, AST 2.7 hrs, 5-45K wob, 80 rpm's, 175 spm, 740 gpm, off btm pressure 2,550 psi, on btm 2,700 psi, off btm torque 5K ft-Ibs, on btm 8K ft-Ibs, rot wt 84K, up wt 100K, dn wt 75K 1.00 RIGMNT RGRP SURFAC Changed out swab and liner on #2 mud pump 6.50 DRILL DRLG SURFAC Drilled 16" hole per directional plan from 3,331' to 3,802' MD/ 2,308' TVD (471'), surface csg point, ART 2.8 hrs, AST 1.3 hrs, 5-45K wob, 80 rpm's, 175 spm, 740 gpm, off btm pressure 2,500 psi, on btm 2,700 psi, off btm torque 8K ft-Ibs, on btm 10K ft-Ibs, rot wt 87K, up wt 125K, dn wt 65K, 9.4 ppg MW, began seeing gas hydrates after drilling below 3,792' Backreamed out of hole from 3,802' to 1,100', backreamed at 80 rpm's and 150 spm, 636 gpm at 1,700 psi, worked thru tight spots at 3,170', 2,550' and 1,100', gas hydrates stopped after backreaming out at 2,200' Pumped out of hole from 1,100' to 360', circ at 636 gpm at 1,600 psi, attempted to pull on elevators at 730' and 550' and was pulling tight, pumped out to 360' Stood back 2 stds HWDP and jars, LD 1-short NMDC and stabilizer, drained motor and broke out bit Downloaded MWD LD MWD, MPR and mud motor Made dummy run with hanger and landing jt with no problems RU Doyon's 13 3/8" csg equipment with Franks fill-up tool Held PJSM with rig crew and tong operator on running of surface csg PU 133/8" float shoe and jt #1 & RIH, PU float collar and jt #2 and attempted to MU float collar, was unable to get float collar to MU into shoe it, threads appeared ok, collar possibly egg shaped, LD float collar it and shoe it 1.50 WAlTON EQIP SURFAC Waited on new float shoe and float collar to be delivered to rig 8.00 CASE RUNC SURFAC Ran 133/8" 68#, L-80, BTC csg and landed same at 3,795', MU new 13 3/8" float shoe onto it #1, MU new float collar on Jt #2 then onto shoe jt, 02:00 - 08:00 MOVE 08:00 - 09:30 MOVE 09:30 . 13:30 SURFAC 13;30 - 18:30 5.00 RIGMNT RSRV SURFAC 18;30 - 00;00 5.50 DRILL PULD SURFAC 8/2/2004 00:00 - 01 :30 1.50 DRILL PULD SURFAC 01 :30 - 02:00 0.50 WELCT BOPE SURFAC 02:00 - 02;30 0.50 RIGMNT RSRV SURFAC 02:30 - 05:00 2.50 DRILL PULD SURFAC 05:00 - 12:00 7.00 DRILL DRLG SURFAC 12;00 - 00;00 12.00 DRILL DRLG SURFAC 8/3/2004 00:00 - 11 :00 11.00 DRILL DRLG SURFAC 11 :00 - 12:00 12;00 - 18:30 18:30 - 00:00 5.50 DRILL REAM SURFAC 8/4/2004 00;00 - 01 :30 1.50 DRILL TRIP SURFAC 01 ;30 - 02:45 1.25 DRILL PULD SURFAC 02;45 - 03:15 0.50 DRILL PULD SURFAC 03:15 - 04:00 0.75 DRILL PULD SURFAC 04:00 - 04;15 0.25 CASE OTHR SURFAC 04;15 - 06:00 1.75 CASE RURD SURFAC 06:00 - 06:30 0.50 CASE SFTY SURFAC 06:30 - 08:30 2.00 CASE RUNC SURFAC 08;30 - 10:00 10;00 - 18:00 Printed: 9/10/2004 9:19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/412004 10:00 . 18:00 8.00 CASE RUNC SURFAC thread locked connections below float collar and tack welded btm of collar below fit collar since float equipment was not bucked up at machine shop, RIH with Jt #3 and circ thru float equip and floats ck ok, cont to RIH with 90 jts 133/8" csg (93 jts total), MU landing jt and hanger and landed csg with float shoe at 3,795' MD/ 2,306' TVD and float collar at 3,756', ran 15 bow spring centralizers, worked thru tight spot at 800' then RIH, broke circ and washed down jts # 68 thru 71 due to heavy mud back and very little returns, after washing down had good returns and cont RIH to btm with no other problems, St wt when landed, Up Wt 225K, Dn Wt 115K 18:00 - 19:30 1.50 CEMEN CIRC SURFAC Circ btm's up with Frank's tool. Broke circulation at 2.5 bpm and staged pump rate up 7 bpm @ 300 psi. Reciprocated csg, St Up WI 205K, Dn Wt 110K. 19:30 - 20:00 0.50 CEMEN RURD SURFAC LD Franks fill-up tool and MU Dowell's cement head 20:00 - 23:00 3.00 CEMEN CIRC SURFAC Cont to circ and condition mud for cementing, circ at 7 bpm at 400 psi, reciprocated csg with 215K up wt and 115K dn wt, final MW, 9.3 ppg, 40 vis, 9 YP and 16 PV, held PJSM with Dowell, vac truck drivers and rig crew on cementing surface csg while circ hole 23:00 - 00:00 1.00 CEMEN PUMP SURFAC Began cementing 133/8" csg, Dowell pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped an additional 40 bbls of CW 100 (50 bbls total), then pumped 42 bbls of 10.5 ppg mudpush, began mixing and pumping Arcticset lead slurry, as of 24:00 hrs have mixed and pumped 100 bbls of lead cement at 10.7 ppg and 4.45 yield with additives, ave 4 bpm at 100 psi, reciprocating csg while pumping cement 8/5/2004 00:00 - 01 :45 1.75 CEMEN PUMP SURFAC Cont cementing 13 3/8" csg, finished mixing and pumping 485 bbls of lead cement at 10.7 ppg and 4.45 yield with additives, pumped a total of 585 bbls (740 sxs) of ArticSet Lite cmt, ave 6.5 bpm at 110 psi, followed with 93 bbls (210 sxs) of DeepCrete tail cmt at 12.1 ppg and 2.47 yield with add., ave 6 bpm at 110 psi, reciprocated csg and had full returns, shut down and dropped top plug 01 :45 - 03:30 1.75 CEMEN DISP SURFAC Dowell pumped 20 bbls fresh water then turned over to rig and rig displaced cement with 541 bbls of 9.4 ppg mud, displaced cmt at 7 bpm, initial circ pressure 400 psi, max pressure 850 psi, slowed rate to 4 bpm and bumped plug on calc displacement, pressured up to 1,350 psi, checked floats and held, CIP @ 03:15 hrs, had full returns during job and had 100 bbls of 10.7 ppg cmt back to surface, reciprocated csg till 02:00 hrs with approx 60 bbls of lead cmt around shoe 03:30 - 04:15 0.75 CASE SURFAC Tested 133/8" csg to 3,000 psi for 30 min, good test 04:15 - 05:30 1.25 CEMEN SURFAC RD cement head and LD landing jt, cleared rig floor 05:30 - 10:00 4.50 WELCT SURFAC ND 21 1/4" 2M divertor and lines, set out same 10:00 - 12:00 2.00 WELCT SURFAC NU & Orient Vetco Gray MB 222 Wellhead, Tested seals to 5,000 psi for 10 min. 12:00 - 15:00 3.00 WELCT SURFAC NU 135/8" 5M BOP stack 15:00 - 19:00 4.00 WELCT SURFAC RU and tested BOPE, tested rams, valves and choke manifold to 250 psi low and 5,000 psi high, tested annular to 250 psi and 3,500 psi, lower IBOP failed to test, NOTE: Lou Grimaldi W/AOGCC waived witnessing of test 19:00 - 21 :30 2.50 RIGMNT RGRP SURFAC Changed out lower IBOP on top drive and tested to 250 psi and 5,000 psi and tested ok 21 :30 - 22:00 0.50 WELCT OTHR SURFAC RD test equipment and installed wear bushing 22:00 . 00:00 2.00 DRILL PULD SURFAC Began MU 12 1/4" BHA #2 with AutoTrak and initialized same 8/6/2004 00:00 - 01 :00 1.00 DRILL TRIP SURFAC Fin MU 12 1/4" BHA #2 and RIH with HWDP to 1,055', surface tested Printed: 9/10/2004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/6/2004 00:00 - 01 :00 1.00 DRILL TRIP SURFAC MWD/Autotrak 01 :00 - 01 :30 0.50 RIGMNT RSRV SURFAC Serviced top drive and blocks 01 :30 - 03:15 1.75 DRILL TRIP SURFAC MU ghost reamer and RIH, PU 5' DP from pipe shed to 2,546' 03:15 - 04:15 1.00 DRILL DEaT SURFAC Shallow tested Autotrak downlink 04:15 - 05:30 1.25 DRILL TRIP SURFAC Cont RIH PU 5' DP from pipe shed to 3,746', washed down and tagged plugs above float collar at 3,753', had +/- 10' of soft cement on top of plugs 05:30 - 07:30 2.00 CEMEN DSHO SURFAC Drilled out cement plugs, float collar at 3,756', shoe jt and float shoe at 3,795', cleaned out to 3,802' then drilled 20' of new formation to 3,822' MD/ 2,314'TVD, 5-25K wob, 90 rpm's 700 gpm at 2,150 psi 07:30 - 08:45 1.25 DRILL CIRC SURFAC Circ hole clean and conditioned mud with 9.3 ppg MW in & out 08:45 - 09:15 0.50 DRILL LOT SURFAC RU and performed LOT to 13.4 ppg EMW, 492 psi, 9.3 ppg MW at 2,306' TVD 09:15 - 21:30 12.25 DRILL DRLG INTRM1 Drilled 121/4" hole W/Autotrak from 3,822' to 5,151' MD/ 2,773' TVD, (1,329') ADT 7.2 hrs, 10-25K wob, 120-150 rpm's 155 spm, 657 gpm, off btm pressure 1,900 psi, on btm 1,950 psi, off btm torque 9.5K ft-Ibs, on btm 11 K ft-Ibs, rot wt 99K, up wt 132K, dn wt 74K, 9.2 ppg MW, ... NOTE····Drilled hydrates section from shoe to 4,500', max gas 2,210 units, below 4,500' BGG ave 250-300 units 21 :30 - 22:45 1.25 DRILL CIRC INTRM1 Circ hole at a reduced rate evaluating Autotrak tool, unable to get desired turn rate from tool, decision made to POOH and PU mud motor, downlinked tool for ribs off on Autotrak 22:45 - 00:00 1.25 DRILL TRIP INTRM1 Pumped out of hole from 5,151' to 4,236', pumped out at 339 gpm at 600 psi, backreamed thru tight spot at 4,456' - 4,385' 8/7/2004 00:00 - 00:30 0.50 DRILL TRIP INTRM1 Fin pumping out of hole from 4,236' to 3,750', (inside csg shoe) 339 gpm at 600 psi with no problems 00:30 - 01 :15 0.75 DRILL CIRC INTRM1 Circ btms up from 3,750' and clean at shakers, circ at 613 gpm at 1,725 psi 01:15 - 01:30 0.25 DRILL OBSV INTRM1 Monitored well-static, pumped dry job 01 :30 - 02:45 1.25 DRILL TRIP INTRM1 POOH to BHA at 1,060' 02:45 - 03:00 0.25 DRILL OBSV INTRM1 Monitored well at BHA-static 03:00 - 05:15 2.25 DRILL PULD INTRM1 LD ghost reamer and POOH standing back HWDP and jars, LD stab and bit, downloaded MWD, found steering tool on AutoTrak had failed, found a seal leaking on one of the hatches on AutoTrak tool along with a 1 1/2" O-Ring found inside of bit, LD AutoTrak tool 05:15 - 08:45 3.50 DRILL PULD INTRM1 MU directional BHA #3, adjusted MM to 1.4 deg bend, MU short NMDC, MWD and programmed MWD, RIH with HWDP and jars to 1,100' 08:45 - 10:15 1.50 DRILL TRIP INTRM1 TIH with BHA #3 to 3,795' (csg shoe) 10:15 - 12:00 1.75 RIGMNT RSRV INTRM1 Slip and cut 58' of drlg line, serviced top drive, blocks and drawworks coupling 12:00 - 12:45 0.75 DRILL TRIP INTRM1 TIH from 3,795' to 5,002', 12:45 - 13:15 0.50 DRILL REAM INTRM1 Washed 149' to btm with no problems, took check shot survey at 5,095', circ at 420 gpm at 1,200 psi 13:15 - 22:45 9.50 DRILL DRLG INTRM1 Drilled 12 1/4' hole per directional plan from 5,151' to 5,850' MD/3,033' TVD (699') ART -0-, AST 5.4 hrs, 10-20K wob, -0- rpm's, 145 spm, 615 gpm, off btm pressure 1,900 psi, on btm 2,100 psi, off btm torque 10K ft-Ibs, rot wt 106K, up wt 141K, dn wt 76K, 9.2 MW, ave bgg 100 units 22:45 - 00:00 1.25 DRILL TRIP INTRM1 Backreaming out of hole to 5,268' at drlg rate, 615 gpm at 2,100 psi, POOH to PU AutoTrak tool 8/8/2004 00:00 - 01 :45 1.75 DRILL TRIP INTRM1 Backreamed out of hole at drlg rate from 5,268' to 5,002', pumped out of hole from 5,002' to 3,795', (csg shoe) 615 gpm at 2,100 psi 01 :45 - 02:30 0.75 DRILL CIRC INTRM1 Circ btms up and till clean at shakers, circ at 615 gpm, 1,800 psi and 40 rpm's, circ out large amount of sand, max gas 250 units and dropped Printed: 9/10/2004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/8/2004 01 :45 . 02:30 0.75 DRILL CIRC INTRM1 out to 50 units 02:30 - 02:45 0.25 DRILL OBSV INTRM1 Monitored well at shoe-static, pumped dry job 02:45 - 03:30 0.75 DRILL TRIP INTRM1 Began POOH from 3,609' to 3,516' had 25-30K overpull and well swabbing, had 7 bbl gain, ran back in hole to 3,700' 03:30 - 04:15 0.75 DRILL CIRC INTRM1 Circ 1 complete hole volume to circ out dry job and check gas at btms up, at btms had a max gas of 200 units and dropped right out to 50 units, circ at 615 gpm at 1,800 psi 04:15 - 06:00 1.75 DRILL TRIP INTRM1 Pumped out of hole 5 stds to 3,238' at 148 gpm at 300 psi with no problems, then pulled 3 stds wet and hole was taking calc fill, pumped dry job and POOH to BHA at 1,103' 06:00 - 08:45 2.75 DRILL PULD INTRM1 POOH standing back HWDP and jars, downloaded MWD and LD MWD, MPR and mud motor, cleared rig floor, BHA was clear, swabbing possibly due to sand inside csg 08:45 - 10:45 2.00 DRILL PULD INTRM1 MU 12 1/4" BHA #4 with AutoTrak tool, program AutoTrak and MWD, RIH with BHA #4 to 1,060' 10:45 - 13:15 2.50 DRILL TRIP INTRM1 TIH with BHA #4 from 1,060' to 5,400', tested AutoTrak tool at 1,895', filled pipe at 3,752' and tagged tight spot at 5,400' 13:15 - 13:45 0.50 DRILL TRIP INTRM1 Washed thru tight spot from 5,400' to 5,414', PU and went thru spot with pumps off and had no problems, cont RIH to 5,795' 13:45 - 14:00 0.25 DRILL REAM INTRM1 Washed 55' to btm at 5,850', circ at 678 gpm at 1,750 psi, no problems washing to btm 14:00 - 20:30 6.50 DRILL DRLG INTRM1 Drilled 12 1/4" hole with AutoTrak tool from 5,850' to 6,656' MD/ 3,303' TVD, (806') ADT 3.4 hrs, 5-25K wob, 120 rpm's, 720 gpm, off btm pressure 1,850 psi, on btm 1,900 psi, off btm torque 15K ft-Ibs, on btm 16K ft-Ibs, rot wt 109K, up wt 163K, dn wt 77K max gas at btms up from trip 80 units, ave BGG 50 units, max gas from Ugnu A, 325 units, screens blinding off, Top of Ugnu A @ 6,240' MD/ 3,170' TVD 20:30 - 21 :30 1.00 DRILL OTHR INTRM1 Changed out shaker screens due to blinding off from Ugnu A 21 :30 - 00:00 2.50 DRILL DRLG INTRM1 Drilled 12 1/4" hole with AutoTrak tool from 6,656' to 6,905' MD/3,366' TVD, (249') ADT 1.8 hrs, 5-25K wob, 120 rpm's, 720 gpm, off btm pressure 1,850 psi, on btm 1,900 psi, off btm torque 15K ft-Ibs, on btm 16K ft-Ibs, rot wt 109K, up wt 163K, dn wt 77K, ave BGG 75 units with 9.2 ppg MW 8/9/2004 00:00 - 11 :00 11.00 DRILL DRLG INTRM1 Drilled 12 1/4" hole with AutoTrak tool from 6,905' to 8,094' MD/ 3,607' TVD (1,189') 95/8" Csg Pt., ADT 7.1 Hrs, 10-25K wob, 120 rpm's, 720 gpm, off btm pressure 2,000 psi, on btm 2,000 psi, off btm torque 18K ft-Ibs, on btm torque 20K ft-Ibs, rot wt 11 OK, up wt 190K, dn wt 70K. While drlg West Sak sands, BGG ave 200-400 units, max gas 1,200 units with 9.3+ MW, Pumped 30 bbl weighted hi-vis sweep prior to T.D. 11 :00 - 12:00 1.00 DRILL CIRC INTRM1 Circ out wt'd hi-vis sweep, had 20% increase in cuttings back from sweep, circ hole at 720 gpm at 2,000 psi and 120 rpms, BGG ave 250 units, downlinked AutoTrak to Ribs Off 12:00 - 14:00 2.00 DRILL TRIP INTRM1 Monitored well-static, backreamed out of hole at drlg rate from 8,094' to 6,997', overlapping ghost reamer from point of last trip 14:00 - 18:30 4.50 DRILL TRIP INTRM1 Pumped out of hole from 6,997' to 3,752', (inside 133/8" csg) pumped out at 720 gpm at 1,800 psi 18:30 - 19:30 1.00 DRILL CIRC INTRM1 Pumped weighted hi-vis sweep and circ out of hole, had 10% increase in cuttings back from sweep, circ 1-add. btms up and was clean at shakers, circ hole at 720 gpm, 1,400 psi and 80 rpm's 19:30 - 19:45 0.25 DRILL OBSV INTRM1 Monitored well at shoe, well-static 19:45 - 21 :00 1.25 DRILL TRIP INTRM1 POOH wet 5 stds and hole took calc fill, pumped dry job and POOH to BHA at 1,060' 21 :00 - 00:00 3.00 DRILL PULD INTRM1 Monitored well at BHA-static, LD ghost reamer, POOH standing back Printed: 9/10/2004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: HWDP and Jars, downloaded MWD and LD BHA #4 with AutoTrak, cleared rig floor, calc fill on trip out 44 bbls, actual fill 52 bbls 8/10/2004 00:00 - 02:00 INTRM1 Pulled wear bushing, installed test plug, changed out upper set of VBR's to 9 5/8" csg rams, tested same to 250/3,000 psi, RD test jt and pulled test plug 02:00 - 03:30 1.50 CASE RURD INTRM1 RU Doyons 9 5/8" csg equipment with Franks fill up tool 03:30 - 03:45 0.25 CASE SFTY INTRM1 Held PJSM on running 9 5/8" csg with rig crew and tong operator 03:45 - 09:45 6.00 CASE RUNC INTRM1 MU 95/8" Float shoe, 2 jts csg, float collar, thread locked btm 3 conn's and circ thru float equip and ch ok, RIH with 93 add. jts along with pup jts for spacing out to 3,725', ran 65 tandem bowspring centralizers on 52 stop rings per well plan (avg MU - 8,000 ft-Ib) 09:45 - 10:45 1.00 CASE CIRC INTRM1 Circ a 9 5/8" csg cap at 13 3/8" shoe, staged pump rate up to 6.5 bpm at 350 psi, st wt up 140K, dn wt 87K, 10:45 - 17:00 6.25 CASE RUNC INTRM1 Cont RIH with 9 5/8" csg, worked thru tight spot at 5,738', RIH to btm, MU hanger and landed 9 5/8" csg at 8,088' MD/3,605' TVD with float collar at 8,010', ran a total of 207 jts 9 5/8",40#, L-80 BTC-M csg with 3-pup jts and hanger (Total 8,061 ') 17:00 - 18:45 1.75 CEMEN CIRC INTRM1 Circ btms up with fill up tool, circ and cond mud, staged pump rate up to 6 bpm at 400 psi, reciprocated csg with 285K up wt, 80K down wt, max gas while circ 178 units 18:45 - 19:15 0.50 CEMEN RURD INTRM1 RD Franks fill up tool and MU cement head 19:15 - 21:00 1.75 CEMEN CIRC INTRM1 Fin circ and condo mud for cementing, circ at 6 bpm at 400 psi, reciprocated pipe with 305K up wt and 75K down, conditioned mud to 9.2 ppg MW, 42 vis, 13 PV, 16 YP, Held PJSM with Dowell, APC vac truck drivers and rig crew while circ and conditioning mud 21 :00 - 22:30 1.50 CEMEN PUMP INTRM1 Dowell pumped 10 bbls CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped 30 add. bbls (40 total) of CW 100, pumped 57 bbls of MudPush at 10.5 ppg, dropped btm plug then pumped 290 bbls, (726 sxs) of DeepCrete cmt at 12.5 ppg, 2.26 yield with additives, ave 6 bpm at 275 psi, reciprocated pipe with full returns, shut down and dropped btm plug 22:30 - 00:00 1.50 CEMEN DISP INTRM1 Dowell pumped 3 bbls FW and turned over to rig and rig displaced cement with 9.1 ppg OBM, bumped plug after pumping 605.5 bbls OBM (95% pump eft.) (Calc Disp 607.75 bbls) ave 7 bpm while displacing cmt, max pressure 1,050 psi, slowed pump rate to 4 bpm with 15 bbls left to pump and bumped plug to 1,600 psi, ck floats and held CIP at 23:55 hrs, reciprocated pipe 1800 strokes into displacement when hole began getting tight and stopped reciprocating, had full returns throughout job, est TOC @ 4,170' 8/11/2004 00:00 - 01:15 1.25 CASE DEOT INTRM1 Tested 95/8" csg to 3,000 psi for 30 min, good test 01:15 - 02:45 1.50 CASE RURD INTRM1 RD cement head and 9 5/8" csg equipment, LD landing jl. 02:45 - 04:15 1.50 WELCT EORP INTRM1 Installed 9 5/8" pack-off, energized seals and tested both seals and pack-off to 250/5,000 psi for 10 min each 04:15 - 05:15 1.00 DRILL INTRM1 RU on 133/8" x 9 5/8" annulus, pressured up to 800 psi and was able to pumped 2.5 bbls into annulus (9.3 ppg mud in annulus) 05:15 - 07:30 2.25 WELCT EORP INTRM1 Installed test plug, changed out upper set of pipe rams F/9 5/8" to 3 1/2" x 6" VBR's, tested same to 250/ 5,000 psi, pulled test plug and installed wear bushing 07:30 - 08:00 0.50 RIGMNT RSRV INTRM1 Serviced top drive and blocks 08:00 - 10:30 2.50 DRILL PULD INTRM1 MU 8 1/2" BHA #5 W/Autotrak tool and programmed MWD tool, RIH with 3- flex Dc's, 2 stds of 5" HWDP and jars to 330' 10:30 - 15:00 4.50 DRILL PULD INTRM1 TIH with BHA #5, PU 21 jts of 5" DP from pipe shed, MU ghost reamer and cont TIH PU add 104 jts of DP, TIH to 4,703' Printed: 9/10/2004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/212004 End: 8/31/2004 Group: 8/11 12004 15:00 - 17:00 2.00 DRILL TRIP INTRM1 TIH from 4,703' to 7,860' with DP fl derrick 17:00 - 18:45 1.75 CEMEN DSHO INTRM1 RIH and tagged cement at 8,000', (top of fit Collar @ 8,010'), drilled out plugs and float collar at 8,010', firm cement in shoe jts and float shoe at 8,088', cleaned out to TD at 8,094', drilled at 5-15K wob, 100 rpm's, 509 gpm at 2,500 psi, rot wt 104K up wt 137K, dn wt 82K 18:45 - 19:30 0.75 DRILL DRLG INTRM1 Drilled 20' of new hole from 8,094' to 8,114' MDI 3,610' TVD for LOT, ADT .7 hrs 19:30 - 20:15 0.75 DRILL CIRC INTRM1 Circ btms up evening MW in and out at 9.1 ppg OBM, circ at 600 gpm at 3,000 psi 20:15 - 21 :15 1.00 DRILL LOT INTRM1 RU and performed LOT to 14.4 ppg EMW, 1,000 psi, at 3,605' TVD with 9.1 ppg OBM mud 21:15-23:00 1.75 DRILL DRLG PROD Drilled 8 1/2" hole with AutoTrak from 8,114' to 8,228' MDI 3,624' TVD, (114') ADT. 7 hrs, 5-18K wob, 120 rpm's, 140 spm, 600 gpm, off btm pressure 3,000 psi, on btm 3,050 psi, off btm torque 8K ft-lbs, on btm 9K ft-Ibs, 9.1 ppg OBM, rot wt 105K, up wt 140K, dn wt 79K 23:00 - 00:00 1.00 DRILL CIRC PROD Circ btms up and performed PWD baseline, with 9.1 ppg mud at 600 gpm and 120 rpms, clean hole ECD = 10.47 ppg 8/12/2004 00:00 - 09:30 9.50 DRILL DRLG PROD Drilled 8 1/2" hole with AutoTrak from 8,228' to 9,156' MDI 3,604' TVD, (928') ADT 5.2 hrs, 5-25K wob, 120 rpm's, 155 spm, 655 gpm, off btm pressure 3,600 psi, on btm 3,675 psi, off btm torque 10.5K ft-Ibs, on btm 1 0.5K ft-Ibs, 9.1 ppg OBM, rot wt 104K, up wt 157K, dn wt 67K, ave BGG 350 units, max gas 725 units. Elbow on #2 mud pump pulsation dampner washed out 09:30 - 20:15 10.75 RIGMNT RGRP PROD Changed out #2 mud pump pulsation dampner, backreamed slowly out of hole from 9,156' to 8,045' (csg Shoe) while working on mud pump, backreamed out at 80 rpm's, 339 gpm at 1,190 psi, changed out pulsation dampner and mud cross 90, found bladder to be bad and changed out also, tightened drive belts on on #2 pump, pressure tested pump to 3,500 psi and checked ok. TIH from 8,048' to 9156' with no problems 20: 15 - 00:00 3.75 DRILL DRLG PROD Drilled 81/2" hole with AutoTrak from 9,156' to 9,518' MD/ 3,584' TVD, (362') ADT 1.9 hrs, 5-20K wob, 120 rpm's, 155 spm, 655 gpm, off btm pressure 3,650 psi, on btm 3,675 psi, off btm torque 12K ft-Ibs, on btm 11 K ft-Ibs, 9.1 ppg OBM, rot wt 100K, up wt 161 K, dn wt 63K, ave BGG 250 units, max gas 675 units 8/13/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Drilled 81/2" hole with AutoTrak from 9,518' to 10,641' MDI 3,585' TVD, (1123') ADT 6.3 hrs, 5-25K wob, 120 rpm's, 155 spm, 655 gpm, off btm pressure 3,800 psi, on btm 3,810 psi, off btm torque 15K ft-Ibs, on btm 13K ft-Ibs, rot wt 101 K, up wt 173K, dn wt 63K, ave BGG 250-350 units, max gas 850 units, 9.0+ OBM, ave ECD 10.9 ppg NOTE: at 11 :45 a spill at the injection skid occured, 25 bbls of OBM was caught inside containment under the injection skid with 3-4 gals going onto the ground 12:00 - 00:00 12.00 DRILL DRLG PROD Drilled 8 1/2" hole with AutoTrak from 10,641' to 11,848' MDI 3,547' TVD, (1207') ADT 7.0 hrs, 5-20K wOb, 120 rpm's, 155 spm, 655 gpm, off btm pressure 3,850 psi, on btm 3,890 psi, off btm torque 14K ft-Ibs, on btm 15K ft-Ibs, rot wt 97K, up wt 175K, dn wt 45K, ave BGG 200-350 units, max gas 2000 units, 9.0+ OBM, ave ECD 11.0 ppg, max ECD 11.2 ppg 8/14/2004 00:00 - 06:45 6.75 DRILL DRLG PROD Drilled 8 1/2" hole from 11,848' to 12,394' (763') ADT 3.0 hrs 06:45 - 08:45 2.00 RIGMNT RGRP PROD Repaired top drive service loop, circ hole at a reduced rate and worked pipe slowly 08:45 - 10:30 1.75 DRILL DRLG PROD Drilled 81/2" hole with AutoTrak from 12,394' to 12,611' MD/3,573' Printed: 9/10/2004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/14/2004 1.75 DRILL DRLG PROD 08:45 - 10:30 10:30 - 11 :45 1.25 DRILL CIRC PROD 11 :45 - 12:00 0.25 DRILL OBSV PROD 12:00 - 20:30 8.50 DRILL REAM PROD 20:30 - 21 :45 1.25 DRILL CIRC PROD 21 :45 - 22:00 0.25 DRILL OBSV PROD 22:00 - 00:00 2.00 DRILL TRIP PROD 8/15/2004 00:00 - 02:30 2.50 DRILL TRIP PROD 02:30 - 05:00 2.50 DRILL TRIP PROD 05:00 - 06:00 1.00 DRILL PULD PROD 06:00 - 06:30 0.50 CASE RURD CMPL TN 06:30 - 06:45 0.25 CASE SFTY CMPL TN 06:45 - 11 :30 4.75 CASE PULR CMPL TN 11:30 - 12:45 1.25 CASE OTHR CMPL TN 12:45 - 13:00 0.25 CASE CIRC CMPL TN 13:00 - 15:15 2.25 CASE RUNL CMPL TN 15:15 - 16:00 0.75 CASE CIRC CMPL TN 16:00 - 19:15 3.25 CASE RUNL CMPL TN 19:15 - 20:30 1.25 CASE OTHR CMPL TN TVD, T.D. (546') ADT 1.3 hrs, 10-20K wOb, 120 rpm's, 150 spm, 635 gpm, off btm pressure 4,050 psi, on btm 4,100 psi, off btm torque 15K ft-Ibs, on btm 14K ft-Ibs, rot WI 112K, up WI 190K, dn WI 61K, ave BGG 250-350 units, max gas 1100 units, 9.0 OBM, ave ECD 11.2 ppg, max ECD 11.35 ppg, PU 8 stds of HWDP to TD well, pumped 30 bbl weighted hi vis sweep while drlg last std down Fin circ out WI'd hi vis sweep, had 10% increase in cuttings back from sweep, circ at 635 gpm, 4,050 psi at 120 rpm's, took survey on btm and slow pump rates Monitored well-static Backreamed out of hole from 12,611' to 8,041', inside 9 5/8" csg. Washed and reamed thru tight spot at 11,680', backreamed out at 120 rpm's, 135 spm, 572 gpm, initial circ pressure 3,425 psi, final circ pressure 2,700 psi, no other problems backreaming out Pumped 30 bbl weighted hi vis sweep and circ hole clean, had no increase in cuttings back from sweep, circ a total of 2X btms up, circ hole clean at 572 gpm, 2,700 psi at 80 rpm's, rot wt 96K, up wt 138K, dn wt 75K, off btm torque 9K ft-Ibs Monitored well at shoe-static, dropped 1 7/8" rabbit on wire and pumped dry job POOH with BHA #5 to 6,560', while POOH, installed 17 Lo-Tads onto DP (1/std) POOH 23 stds from 6,560' to 4,424' with BHA #5, MU 23 add. Lo-tads (40 total) POOH from 4,424' to 50', stood back HWDP and BHA to AutoTrak tool Downloaded MWD and stood back AutoTrak tool RU Doyon's 5 1/2" liner running equipment Held PJSM with rig crew and tong operator on running liner PU and ran 5 1/2" liner per well program, ran 5 1/2" ROT silver bullet guide shoe with no float, 159 jts, 5,139.10' of 5 1/2" 15.5#, L-80, DWC liner, placed blank liners across shale sections per geology, ran 69 jts (2,369') of blank liner and 90 jts (2,768') of slotted liner, ran 1- 51/2" x 8 1/4" spiralglide centralizers 1/jt to shoe (137 total) then ran 12 restrictor packers with 24 spacer rings placed on blank liner to isolate shale sections per geology. MU Baker 190-47 csg seal bore ext, 7" x 9 5/8" Flexlock liner hanger, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to 5,204' Est circ at 1.5 bpm at 30 psi, st wt up 85K, dn wt 64K, est rotation at 10 rpm's with 3K ft-Ibs torque and 70K rotating wt RIH with liner on 5" DP to 8,001' Circ 2 DP volumes at 9 5/8" csg shoe, circ at 2 bpm at 200 psi, st wt up 122K, dn wt 80K, rotated at 10 rpm'$ with 7K ft-Ibs torque and 95K rotating wt RIH with liner in open hole from 8,001' to TD at 12,611' with no problems, tagged btm and PU liner 4' to liner setting depth, 12,607' Dropped 29/32" ball and pumped down to seat, staged up pump rate to 4 bpm at 575 psi, slowed to 3 bpm at 400 psi, with ball on seat pressured up to 2,500 psi to set hanger, then pressure up to 3,500 psi to set packer, cont to set packer by PU and releasing dogs then setting 50K string wt down, then rotated at 10 rpms and set 80K down wlrotating, packer set with no problems, set lower lateral liner with TOL @ 7,413' and shoe at 12,607', st wt up after setting liner 110K Printed: 9/10/2004 9:19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig l=telease: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/15/2004 20:30 - 20:45 0.25 CASE DEOT CMPL TN Tested ZXP liner top packer to 1,000 psi for 5 min, good test 20:45 - 21 :45 1.00 CASE CIRC CMPL TN Circ hol13 with reconditioned 9.0 ppg OBM, circ at 339 gpm at 900 psi 21 :45 - 22:30 0.75 DRILL TRIP CMPL TN Monitomd well-static, pumped dry job and began POOH from 7,413', POOH to 6,184' when chain on drawworks broke 22:30 - 00:00 1.50 RIGMNT RGRP CMPL TN Began changing out chain on drawworks 8/16/2004 00:00 - 02:15 2.25 RIGMNT RGRP CMPL TN Finishec changing out chain on drawworks 02:15 - 05:00 2.75 DRILL TRIP CMPL TN POOH from 6,184' to 20' to liner running tool 05:00 - 05:30 0.50 DRILL PULD CMPL TN Made se rvice breaks and LD running tool 05:30 - 09:00 3.50 WINDO ULD CMPL TN PU Whipstock and mills to rig floor, MU Baker seal assembly, 2 jts of 5" DP for space out and 9 5/8" Baker btm trip whipstock, milling assembly with LWD/MWD, uploaded MWD and oriented BHA #6 09:00 - 13:00 4.00 WINDO CMPL TN TIH with whipstock assembly BHA #6, RIH with 9 stds HWDP and slick DP to 6,?05', shallow tested MWD at 2,345' and ck ok 13:00 - 13:45 0.75 WINDO CMPL TN Est Circ and made MAD pass to correlate DP to K-13 sand, Logged down from 6,705' to 6,742' (GR Depth 6,645' to 6,682') corrected MWD 2.5' to pL t on depth, circ at 510 gpm at 1,975 psi, st WI 142K, dn WI 81 K 13:45 - 14:15 0.50 WINDO CMPL TN TIH from 6,742' to 7,358' 14:15 - 14:45 0.50 WINDO CMPL TN Oriented whipstock and RIH, tagged top of liner at 7,413', set btm trip ,/ anchor and whipstock at (0 deg) high side, set top of whipstock at 7,305', worked 45K WI down and sheared bolt, no problems shearing bolt, str. Iv! up after setting whipstock 142K and 81K dn 14:45 - 18:00 Milled window in 95/8" csg, top of window at 7,305', btm of window at ,/ 7,321', drilled 8 1/2" hole to 7,343' MDI 3,474' TVD (38'), 2-6K wob, 60-100 rpm's, 510 gpm, 1,800 psi, rot WI 100K, up wt 142K, dn wt 81K, torque off btm 7K ft-Ibs, on btm 9-13K ft-Ibs 18:00 - 19:00 1.00 WINDO IRC CMPL TN Pumped hi.vis sweep and circ hole clean while working mills thru window, had no increase in cuttings back from sweep, circ at 510 gpm at 1,800 :si, ran mills thru window without any problems 19:00 - 19:15 CMPL TN Monitored well-static, pumped dry job and POOH from 7,343' to 7,151' 19:15 - 20:30 CMPL TN Slip and cut 123' of drlg line, serviced top drive and drawworks 20:30 - 22:30 CMPL TN POOH from 7,151' to HWDP at 936' 22:30 - 00:00 CMPL TN POOH to 10', LD 27 jts 5" HWDP and bumper sub, Note: HWDP to be sent in for inspection, and replacement HWDP is on location 8/17/2004 00:00 - 01 :00 1.00 WINDO CMPL TN Rack bac~. MWD in Derrick, Lay down Milling assembly, Jars & HWDP. 01 :00 - 09:45 8.75 WELCT PROD2 Pull wear bushing, Wash out stack, Rig & test BOPE to 250 psi low & 5000 psi high, Hydril to 250 low & 3500 psi high, Test witnessed by AOGCC Joff Jones, Install wear bushing. 09:45 - 11: 15 1.50 DRILL PULD PROD2 Pick up 29 jts. HWDP, Jars & stand back in derrick. 11:15-15:30 4.25 DRILL PULD PROD2 Pick up Bil, Motor, MWD tools, Orient & Program same, RIH wi HWDP, Jars, Drill pipe & Ghost reamer, Surface test tools. 15:30 - 18:30 3.00 DRILL TRIP PROD2 RIH to 7,206', Orient & slide thru window @ 7,305' with no problems, Ream down to 7,343' wi 510 gpm @ 2775 psi. 18:30 - 00:00 5.50 DRILL DRLH PROD2 Drill 8-1/2" hole f/7,343' to 7,943' MD/3,465' TVD (600') ART= 2.4 hrs, AST = 1.4 hrs, WOB 5/20K, 80/100 RPM, 550 gpm @ 2800 psi, UP 155K, DN' 04K, ROT 73K, BGG 275 units, Ave. ECD's 10.1 ppg wi 9.2 v ppg mud. 8/18/2004 00:00 - 12:00 12.00 DRILL DRLH PROD2 Drill 8-1/2" hole fl 7,943' to 9,093' MDI 3,446' TVD (1150') ART = 4.7 hrs, AST = :~.5 hrs, WOB 5/25K, 100 RPM, 550 gpm @ 2750 psi, UP 153K, DN ï6K, ROT 105K, TO on btm 1 0/15K off 11/12K ft/lb, Ave. BGG 400 units, Max gas 1302 units, Ave. ECD's 10.3 ppg wi 9.1 ppg " mud. 12:00 - 00:00 12.00 DRILL DRLH PROD2 Drill 8-1/2" hole fl 9,093' to 10,060' MDI 3,442' TVD (967') ART= 6.0 hrs, AST = ~~.2 hrs, WOB 5/25K, 90/110 RPM, 550 gpm @ 2800 psi, UP Printed: 9/10/2004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/18/2004 12:00 - 00:00 12.00 DRILL DRLH PROD2 160K, DN 70K, ROT 105K, TO on btm 10/11 K off 12K ftllb, Ave. BGG 450 units, Max gas 1022 units, Ave. ECD's 10.4 ppg wi 9.0 ppg mud. 8/19/2004 00:00 - 12:00 12.00 DRILL DRLH PROD2 Drill 8-1/2" hole fl 10,060' to 11,197' MDI 3,427' TVD (1,137') ART = 5.2 hrs, AST = 2.0 hrs, WOB 5/20K, 120 RPM, 550 gpm @ 2950 psi, UP 164K, DN 63K, ROT 100K, TO on btm 12/13K off 13/14K ftIIb, Ave. BGG 450 units, Max gas 912 units, Ave. ECD's 10.6 ppg wi 9.0 ppg ./ mud. 12:00 - 00:00 12.00 DRILL DRLH PROD2 Drill 8-1/2" hole f/11, 197' to 12,215' MDI 3,405' TVD (1,018') ART = 5.2 hrs, AST = 2.1 hrs, WOB 5/25K, 120 RPM, 550 gpm @ 3200 psi, UP 170K, DN 65K, ROT 108K, TO on btm 15K off 14/15K ftllb, Ave. BGG 410 units, Max gas 795 units, Ave. ECD's 10.8 ppg wi 9.0 ppg mud. Note; Last 24 hours, having extreme difficulty keeping sand content down below 2% due to fine sand. 8/20/2004 00:00 - 02:30 2.50 DRILL DRLH PROD2 Drill 8-1/2" hole fl 12,215' to 12,468' MDI 3,394' TVD (253') ART = 1.7 hrs, AST = 0.2 hrs, WOB 5/25K, 120 RPM, 550 gpm @ 3300 psi, UP 176K, DN 74K, ROT 115K, TO on btm 14K I off 14K ftllb, Ave. BGG 410 units, Max gas 738 units, Ave. ECD's 10.9 ppg wi 9.0 ppg mud, Pumped Hi-vis weighted sweep on last connection. 02:30 - 03:30 1.00 DRILL CIRC PROD2 Circ out sweep- had 10% increase in cuttings, Survey, Monitor well. 03:30 - 10:30 7.00 DRILL TRIP PROD2 Back ream out of hole to 7,200' at drilling rate, No problems - hole in good shape. 10:30 - 12:00 1.50 DRILL CIRC PROD2 Pump Hi-vis sweep & circ hole clean w/3 times btm's up. 12:00 - 13:30 1.50 DRILL TRIP PROD2 Monitor well, Dry pipe, POOH 11 stands to 6,177' (Hole not taking proper fill). 13:30 - 14:30 1.00 DRILL TRIP PROD2 RIH to 7,200', Circ btm's up. 14:30 - 17:30 3.00 DRILL TRIP PROD2 Pump out of hole fl 7,200' to 3,800' due to hole not taking proper fill. 17:30 - 20:30 3.00 DRILL TRIP PROD2 Monitor well, POOH on elevators to MWD. 20:30 - 22:00 1.50 DRILL PULD PROD2 Down load MWD tools, Lay down BHA. 22:00 - 00:00 2.00 DRILL TRIP CMPL TN Make up Fixed Lug whipstock retrieving tools, RIH wi HWDP. 8/21/2004 00:00 - 03:15 3.25 CMPL TN TRIP CMPL TN Continue RIH to 7,260', Break circ wi 253 bpm @ 600 psi, Record weights- UP 136K, DN 86K, Hook whipstock on third attempt @ 7,312', Pull up to 175K & bleed open Jars, Pull on up to 225K and whipstock released, Pull up to 7,260', Observed indicator weight of 142K. 03:15 - 04:00 0.75 CMPL TN CIRC CMPL TN Circ btm's up at rate of 630 gpm @ 2750 psi, Monitor well - Static, Drop rabbit. 04:00 - 09:30 5.50 CMPL TN TRIP CMPL TN Pull 2 stands and observe well for swabbing- OK, Pump dry job, POOH, Lay down whipstock tools to whipstock- No recovery of whipstock, Fixed lug retrieving tool showed damage to upper part of lug where whipstock slipped off. 09:30 - 10:30 1.00 CMPL TN PULD CMPL TN Make up whipstock retrieving BHA #2. 10:30 - 11 :30 1.00 RIGMNT RSRV CMPL TN Service rig, Drawworks, Top drive. 11 :30 - 15:00 3.50 CMPL TN TRIP CMPL TN Make up New Fixed lug retrieving tool, RIH to 7,260', Break circ wi 253 bpm @ 600 psi, Record weights- UP 136K, DN 86K, Hook whipstock @ 7,312', Pull up to 175K & bleed open Jars, Pull on up to 225K and whipstock released, Pull up to 7,260', Observed indicator weight of 142K. 15:00 - 15:30 0.50 CMPL TN TRIP CMPL TN Circ btm's up at rate of 510 gpm @ 1800 psi, Monitor well- Static. 15:30 - 21 :30 6.00 CMPL TN TRIP CMPL TN Pull 1 0 stands and observe well for swabbing- OK, Pump dry job, POOH, Lay down whipstock tools to whipstock- Recovered whipstock. 21 :30 - 23:00 1.50 CMPL TN PULD CMPL TN Lay down whipstock assembly and clear floor. 23:00 - 00:00 1.00 CASE RURD CMPL TN Rig to run 5-1/2" liner. 8/22/2004 00:00 - 04:00 4.00 CASE PUTB CMPL TN Pick up Total of 152 joints 5-1/2", 15.5#, L-80, DWC Slotted liner w/4 jts blank wi 2 Swell packers, Ran 150, 5-1/2"x 8-114" Centralizers Printed: 9/10/2004 9:19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n 1334@ ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/22/2004 00:00 - 04:00 4.00 CASE PUTB CMPL TN sliding on every jt., Btm joint blank and bent. 04:00 - 04:30 0.50 CASE PUTB CMPL TN Pick Baker 7"x 9-5/8" B-1 Hook Hanger for LEM. 04:30 - 12:00 7.50 CASE RUNL CMPL TN RIH wI liner, Work liner thru window @ 7,305' to 7,321' (Made thru on 2nd attempt), Continue to RIH to btm UP 170K, DN 88K, Hook liner in window @ 7,324.5' (3.5' low)- Rehook liner to comfirm, TOL @ 7,302.51' wi Shoe @ 12,455.80'. 12:00 - 13:00 1.00 CASE CIRC CMPL TN Drop ball, Circ down at rate of 5 bpm @ 800 psi, Release liner, Shear out ball wI 4800 psi, Circ btm's up. 13:00 - 16:00 3.00 CMPL TN TRIP CMPL TN Observe well, Dry pipe, POOH, Lay down Baker liner running tools. 16:00 - 18:00 2.00 CMPL TN RURD CMPL TN Clear floor, Rig & make up LEM assembly. 18:00 - 21 :30 3.50 CMPL T TRIP CMPL TN RIH wi LEM assembly to 7,300', RIH slow & Latch LEM in Hook hanger @ 7,302' wi ZXP liner top packer @ 7,245', Check for proper set w/10K over pull- OK. 21 :30 - 00:00 2.50 CMPL T CIRC CMPL TN Drop ball, Circ down at rate of 5 bpm @ 800 psi, Set ZXP Packer, Release fl running tool & Neutralizer push tool wI 3800 psi, Pressure test annulus & ZXP packer wi 1500 psi fl 5 min- OK, Rig & shear out ball wi 5100 psi, Circ btm's up, Observe well, Dry pipe. 8/23/2004 00:00 - 03:30 3.50 CMPL TN TRIP CMPL TN POOH & Lay down LEM running tools. 03:30 - 05:00 1.50 WINDO ULD CMPL TN Make up Whipstock & Milling assembly, Orient tools wI MWD tools. 05:00 - 09:30 4.50 WINDO RIP CMPL TN RIH wi Whipstock to 6,724'. 09:30 - 10:00 0.50 WINDO CIRC CMPL TN Circ & Madd pass fl 6,724' to 6,758'. 10:00 - 11 :30 1.50 WINDO SETW CMPL TN RIH to 7,220', Orient whipstock to 15 deg. Left, Tag top of ZXP packer @ 7,249' (3.5' low), Set Anchor, Shear off whipstock bolt wi top of whipstock @ 7,305'. 11:30 - 15:30 4.00 WINDO CMPL TN Mill window fl 7,105' to 7,143', (Window fl 7,105' to 7,121 '). 15:30 - 16:00 0.50 WINDO CMPL TN Pump Hi-vis sweep, Circ hole clean. 16:00 - 20:00 4.00 WINDO CMPL TN Observe well, Dry pipe, POOH & Lay down Mill assembly. 20:00 - 21 :00 1.00 WELCT PROD3 Rig & wash metal from stack. 21 :00 - 22:30 1.50 DRILL PROD3 Make up 8-1/2" BHA #8, Orient & Program same. 22:30 - 00:00 1.50 DRILL PROD3 RIH wi BHA to 1,850' 8/24/2004 00:00 - 02:00 2.00 DRILL TRIP PROD3 RIH wi 8-1/2" BHA #10 to 7,021' 02:00 - 03:30 1.50 RIGMNT RSRV PROD3 Cut & slip drilling line, Service rig. 03:30 - 04:15 0.75 DRILL TRIP PROD3 Break eire, Orient & slide thru window @ 7,105' to 7,121' (Window in good shape- No obstructions), Ream out of guage hole f/7, 126' to 7,143'. 04:15 - 12:00 7.75 DRILL DRLH PROD3 Drill 8-1/2" hole fl 7,143' to 7,870' MDI 3,407' TVD (727') ART = 2.3 hrs, AST = 2.7 hrs, WOB 2/15K, 120 RPM, 550 gpm @ 2850 psi, UP 146K, DN 70K, ROT 100K, TO on btm 10K I off 10K ft/Ib, Ave. BGG 300 units, Max gas 388 units, Ave. ECD's 10.4 ppg wi 9.0 ppg mud. 12:00 - 00:00 12.00 DRILL DRLH PROD3 Drill 8-1/2" hole fl 7,870' to 8,970' MDI 3,407' TVD (1,100') ART = 601 hrs, AST= 2.2 hrs, WOB 211 OK, 120 RPM, 550 gpm @ 2800 psi, UP 155K, DN 70K, ROT 100K, TO on btm 12K I off 13K ft/lb, Ave. BGG 300 units, Max gas 1230 units, Ave. ECD's 10.4 ppg wi 9.0 ppg mud. 8/25/2004 00:00 - 12:00 12.00 DRILL DRLH PROD3 Drill 8-1/2" hole fl 8,970' to 9,805' MDI 3,408' TVD (835') ART = 7.0 hrs, AST= 1.9 hrs, WOB 2/1 OK, 120 RPM, 550 gpm @ 2900 psi, UP 160K, DN 63K, ROT 102K, TO on btm 12/13K I off 13/14K ft/lb, Ave. BGG 250 units, Max gas 500 units, Ave. ECD's 10.5 ppg wi 9.0 ppg mud. 12:00 - 00:00 12.00 DRILL DRLH PROD3 Drill 8-1/2" hole fl 9,805' to 10,895' MDI 3,402' TVD (1,090') ART= 4.1 hrs, AST = 3.1 hrs, WOB 2I5K, 120 RPM, 550 gpm @ 3000 psi, UP 180K, DN 65K, ROT 105K, TO on btm 15K I off 15K ft/lb, Ave. BGG 520 units, Max gas 700 units, Ave. ECD's 10.6 ppg wI 9.0 ppg mud. 8/26/2004 00:00 - 06:30 6.50 DRILL DRLH PROD3 Drill 8-1/2" hole fl 10,895' to 11,469' ART = 1.8 hrs, AST = 1.6 hrs, WOB 5/10K, 120 RPM, 550 gpm @ 3350 psi, UP 195K, DN 60K, ROT 116K, Printed: 9/10/2004 9:19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/26/2004 00:00 - 06:30 6.50 DRILL DRLH PROD3 TO on btm 16K I off 17K ft/lb, Ave. BGG 500 units, Max gas 580 units, Ave. ECD's 10.8 ppg wi 9.0 ppg mud. Running out of weight to slide with. 06:30 - 07:45 1.25 DRILL TRIP PROD3 Monitor well, Backream out of hole to 11,101 " Pick up 12 its. HWDP. 07:45 - 17:00 9.25 DRILL DRLH PROD3 Drill 8-1/2" hole fl 11,469' to 12,115' ART = 3.6 hrs, AST = 1.8 hrs, WOB 5/10K, 120 RPM, 550 gpm @ 3400 psi, UP 207K, DN 55K, ROT 133K, TO on btm 17K I off 18K ftlb, Ave. BGG 400 units, Max gas 580 units, Ave. ECD's 10.8 ppg wi 9.0 ppg mud. Running out of weight to slide with. 17:00 - 18:00 1.00 DRILL TRIP PROD3 Monitor well, Backream out of hole to 11,654', Pick up 15 its. HWDP. 18:00 - 23:00 5.00 DRILL DRLH PROD3 Drill 8-1/2" hole fl 12,115' to TD 12,457' MD I 3,382' TVD ART = 2.3 hrs, AST= 0.3 hrs, WOB 2/5K, 120 RPM, 550 gpm @ 3400 psi, UP 225K, DN 65K, ROT 126K, TO on btm 18K I off 18K ft/lb, Ave. BGG 400 units, Max gas 648 units, Ave. ECD's 10.9 ppg wi 9.0 ppg mud, Pump Hi-vis weighted sweep on last connection. 23:00 - 00:00 1.00 DRILL CIRC PROD3 Circ Hi-vis sweep out of hole - 10% increase in cuttings. 8/27/2004 00:00 - 07:00 7.00 DRILL TRIP PROD3 Survey, Monitor well· Static, Back ream out of hole at drilling rate 550 gpm @ 3400 to 2500 psi, 120 RPM, Pulling at rate of 40/45 ft/min., No tight spots - Hole in very good shape. 07:00 - 08:30 1.50 DRILL CIRC PROD3 Pump Hi-vis weighted sweep, Circ hole clean wI 550 gpm @ 2500 psi, while rotating and reciprocating pipe, Monitor well. 08:30 - 13:00 4.50 DRILL TRIP PROD3 POOH to BHA. 13:00 - 14:00 1.00 DRILL PULD PROD3 Lay down NMDC's, Down load & lay down MWD/LWD, Lay down Motor & Bit. 14:00 - 20:30 6.50 DRILL PULD CMPL TN Lay down 60 stands 5" drill pipe from derrick in mouse hole. 20:30 - 00:00 3.50 WINDO RIP CMPL TN Make up Whipstock retrieving tools, RIH to 6,200'. 8/28/2004 00:00 - 00:15 0.25 WINDO RIP CMPL TN Continue RIH wi Whipstock retrieving tools to 7,111 '. 00: 15 . 00:45 0.50 WINDO RIP CMPL TN Break eire, Work & latch onto Whipstock, Jar same loose w/90K overpull, Pull whipstock up to 7,068' (Whipstock dragging 1 OK over) 00:45 - 01 :30 CMPL TN Circ btm's up at rate of 320 gpm @ 800 psi, Observe well- OK. 01:30 - 06:15 CMPL TN POOH slow due to mild swabbing and hole not taking proper fill, Work pipe up & down in order to make well take proper fill, Hole began taking proper fill after 15 stands, Dry pipe & continue to POOH to BHA slow wi whipstock. 06:15 - 09:45 CMPL TN Stand back HWDP, Lay down whipstock retrieving tools and whipstock tools, Clear & clean floor. 09:45· 15:30 5.75 CASE PULR CMPL TN Rig & run Baker 5-1/2" Guide shoe, 1 Bent Blank jt. 5-1/2", 15.5#, L-80, DWC liner, 129 its. Slotted 5-1/2",15.5#, L-80, DWC liner, Pick up Baker 7" x 9-5/8" Model B-1 Hook Hanger for LEM, Rig down casing tongs, Clean floor. 15:30 - 20:00 4.50 CASE RUNL CMPL TN RIH wi liner, Work liner thru window @ 7,105' to 7,121' (Took 3 attempts), Continue RIH wi liner with no restrictions until the last 25', Work liner to btm- OK. 20:00 - 20:30 0.50 CASE RUNL CMPL TN Run Hook Hanger down and Hooked window on first attempt @ 7,123', Turn Hook & run past window 7'- OK, Turn Hook & rehook window at a final depth (A definite solid hook- Checked 3 times) of 7,124.73', Top of liner @ 7,103.65', Shoe @ 12,435.24'. 20:30 - 22:00 1.50 CASE CIRC CMPL TN Drop & circ down ball on seat at rate of 5 bpm @ 800 psi, Release from liner hanger wI 3800 psi, Set back 1 stand HWDP, Rig & shear out ball wi 5300 psi using BOP test pump, Circ btm's up at rate of 510 gpm @ 1800 psi. 22:00 - 22:45 0.75 CMPL TN TRIP CMPL TN Monitor well, Dry pipe, POOH wi 6 stands HWDP, (Broke Hi gear chain in drawworks). Printed: 9/10/2004 9: 19:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-126 1 E-126 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/1/2004 Rig Release: 8/31/2004 Rig Number: Spud Date: 8/2/2004 End: 8/31/2004 Group: 8/28/2004 8/29/2004 8/30/2004 Replace Hi gear chain in drawworks. Continue Replacing Hi gear chain in drawworks. POOH, Lay down Baker liner running tools, Clean rig floor. Rig & RIH wi 17 stands HWDP, 7 stands drill pipe, Lay down 17 stands HWDP & 1 stand drill pipe- Pipe skate chain broke. Repair pipe skate chain. Finish laying down drill pipe. Rig & Pick up 192jts. 4-1/2",12.6#, L-80, IBTTubing. Circ hole clean at rate of 425 gpm @ 1200 psi, Reciprocate pipe while circ. Monitor well, Pump dry job, POOH & stand back tubing in derrick. Rig & Lay down remaining 5' drill pipe and Lo-Tad's from derrick in mouse hole. Finish laying down remaining 5' drill pipe and Lo-Tad's from derrick in mouse hole. Pull wear bushing, Rig to run 4-1/2" ESP Completion, Held PJSM with all personnel. Make up Motor centralizer to motor, Pump guage, Motor, Seal section, X/O, Screen Intake, Fill motor wi oil, Test & Clamp ESP wire, RIH installing clamps every other jt, Test ESP wire every 10 stands. Make up Vetco Gray hanger UP 85K, DN 60K, Install penetrator, Cut wire & splice same to penetrator. Cont to splice ESP wire and test same, landed tbg at 6,155' MD, RILDS, LD landing jt and tested upper and lower hanger seals to 5,000 psi for 15 min, ck ok, installed TWC ND BOP's NU Vetco Gray tree and adapter, tested adapter vòid to 5,000 psi for 15 min, ck ok, tested tree to 250 psi low and 5,000 psi high for 5 min each and tested ok, pulled TWC, check ESP penetrator continuity and checked ok 3.50 CMPL TN FRZP CMPL TN RU and displaced out 9.0 ppg OBM to diesel, pumped 460 bbls diesel down 9 5/8" x 4 1/2' annulus at 6,093', initial circ pressure 450 psi at 3 bpm, final circ pressure 875 psi at 3 bpm (thru willis choke) 1.00 WELCT EORP CMPL TN RU lubricator and installed BPV 2.00 CMPL TN OTHR CMPL TN Secured well, finished cleaning out mud pits, RD scaffolding around well and cleaned out cellar RELEASED RIG @ 12:00 hrs, 8/31/04 22:45 - 00:00 1.25 RIGMNT RGRP CMPL TN 00:00 - 01 :00 1.00 RIGMNT RGRP CMPL TN 01:00-04:15 3.25 CMPL TN TRIP CMPL TN 04:15 - 06:30 2.25 CMPL TN TRIP CMPL TN 06:30 - 07:30 CMPL TN 07:30 - 08:00 CMPL TN 08:00 - 15:30 CMPL TN 15:30 - 16:30 CMPL TN 16:30 - 20:30 CMPL TN 20:30 - 00:00 CMPL TN 00:00 - 03:45 3.75 CMPL TN PULD CMPL TN 03:45 - 07:30 3.75 CMPL TN RURD CMPL TN 07:30 - 21 :30 14.00 CMPL TN RUNT CMPL TN 21 :30 - 00:00 2.50 CMPL TN RURD CMPL TN 8/31/2004 00:00 - 02:30 2.50 CMPL TN RUNT CMPL TN 02:30 - 03:30 1.00 WELCT NUND CMPL TN 03:30 - 05:30 2.00 WELCT NUND CMPL TN 05:30 - 09:00 09:00 - 10:00 10:09 - 12:00 Printed: 9/10/2004 9: 19:43 AM Conoc~illips ConocoPhillips Alaslnc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska SURVEY LING Page 1 Wellbore: 126L 1 Wellpath: MWD w/Sag <7520-12468'> Date Printed: 16-Sep-2004 "~i. BAKER HUGHES INTEQ 1~lbørê 126L1 I creat~ 18-Au -2004 I Last R~Vised 29-Au -2004 IWéIl ~ I ~~~~~~~~\I~OO-OO I ~~~u~~;~;: Slot NarIe East Installation Pad 1E 550528.194 5959591.109 AK4 on NORTH AMERICAN DATUM 1927 datum True 1;1, R;,~ (Jo' I EaStin~ 87754 6208 INorth~ 48985 8206 I~=~ IN__~' I .. _" _ ERICAN OAnJM 1921"",~ True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8728.00 Feet on azimuth 152.86 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~Òv(-I:l~ ~/ ConocoPhillips ConocoPhillips Alas!nc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska . SURVEY LISTING Page 2 Wellbore: 126L 1 Well path: MWD w/Sag <7520-12468'> Date Printed: 16-Sep-2004 r&l. BAKER HUGHES INTEQ WellDath (Grid) Report MD[ft] 'nc[deg] Azi[deg] TVD[ft] Station Station Dogleg Severi~ Vertical Easting Northing Position(Y) Position(X) Sectionrftl T~O<; 00 77.51 183.76 3465.83 ?¡:;Rd O?~ 446R14F 0.00 2219.0!:¡ <;0<;7Rn;l <;1 7<;?0 ;10 QO 3;1 1 RR 00 3.4RR ¡:;O ,)R77 ARC 4444.16E 6.27 ?;l3? 7R <;Q<;7<;Q1 R3 7618.49 93.38 187.08 3485.41 2974.66S 4431.29E 3.24 2530.75 554340.11 5957494.58 7715.85 93.65 186.84 3479.44 3071128 .IlLI.10 ';?~ 0.37 262790 <;Q<;7<\QR 0<; 7R 11 7R Q<\ <;n 1M<;R 3.4 7<\ ;I¡:; 31¡:;¡:; <\¡:;~ ;I;IOQ QQ~ 2.36 2723.61 7C, 7907.61 93.59 184.08 3467.54 3261.75S 4402.77E 0.53 2819.26 554313.49 5957207.33 ROO<\ Q3 Q<\ ?? 182.10 3461.81 3357.768 4397591= 2.09 2915.31 <;Q<;7111 30 8100Q9 Q3Oð. 1RO.37 3.4<;¡:; <;1 <lAC,A ~C,C 4<\Q<;<;O~ 1.79 3011.95 <;Q<;701441 8195.99 91.14 180.88 3453.05 3549.578 4394.46E 2.07 3106.53 554307.10 5956919.48 R?Q.4.R1 Q1 10 180.14 3451.12 <I~AR <l7C ;I<\Q<\ <;Q~ 0.75 3204.94 839105 9163 179<;3 3.4;1R R3 374;1 <;RS 43Q3 RRI= OM 3300. R7 C,0e:.¡:;7?A e:.n 8486.52 92.64 179.74 3445.27 3839.98S 4394.47E 1.08 3395.56 554309.03 5956629.11 115R2QR Q071 17Q, QR 3.44?,;I<; 3936.40S 43Q.4 701= 2.02 3491.50 e:.0e:.~e:.<I')71 8679.49 90.86 1111,;12 3441.13 4n<l? RO~ ;1393.<;31= 1.50 3<;117 65 e:.Qe:.Rd<\¡:; ?? 8777.21 90.52 181.92 3439.95 4130.56S 4390.68E 0.62 3685.14 554307.17 5956338.55 111172113 IIRB1 1R1 77 3.4;1? 1R A??~ noc 'n.'~ nn~ 3RII 37RO <;1 e:.e:.A<lM7<1 e:.Oe:.~?A <I n1 8970.21 88. 74 17953 344596 .IIO:¡?O:¡ O:¡RC:: .IIO:¡A¡:;e:.n~ 303 3117745 ""A <If\A ')7 e:.Qe:.¡:;1;1<; 7? 9067.13 89.82 176.22 3447.18 4420.218 4390.09E 3.59 3973.48 554308.51 5956048.93 916257 91 Oð. 175 R? 3.4;1R ;lR Ae:.1e:. Af\C:: A<la~ AA~ 1 ;I? ;lOR7 <;R ~~.n' ~ nn e:.ae:.e:.oe:.o:¡ 70 9260.53 9405 174R7 344? 11 A¡:;1? a1C:: 317 4163113 e:.e:.A.O:¡?.II ¡:;Q e:.Qe:.e:.A<;¡:; 3.4 9358.03 89.42 175.08 3439.16 4709.978 4413.53E 4.75 4259.60 554333.86 5955759.36 9451 B7 9101 176 7n 3.43R R 1 ARno:¡ e:.~c:: AA')n ')e:.~ ?;I? ;l3<;? 10 <;!ið.341?1 e:.ae:.e:.¡:;¡:;e:.A? 9549.10 89.33 178.30 3438.52 AMn ¡:;Q~ 'n' ,n~ 239 4448.36 "O"""~R 7<1 9643.59 89.72 180.21 3439.30 4995.17S 4425.72E 2.06 4542.27 554347.95 5955474.28 9733.67 9129 179.5R 34311 <;1 <;OR<;?4S 4;1?<;RQI= 1.IIR ;lR31.QO e:.e:.A.<lA.A71 e:.Qe:.e:.O:¡M?1 9829.12 90.71 179.44 343684 5180678 4426 70F 0.63 4726BO "a""')RR Rf\ 9921.76 87.05 180.59 3438.65 5273.27S 4426.68E 4.14 4818.97 554350.75 5955196.21 8982 111?1<; 3441.15 e:.O:¡Rd e:.o:¡c 4ð.?4 ;lQI= 3 ;lR ;lQ10.01 5!ið.3491 8 e:.ae:.e:.1M CIA. 10107.67 92.09 184.15 343957 !ið.5R. 948 AA<o",m:: 320 5004.48 ""A<lAA ~< <;Q<;<;010 <;1 10199.24 89.51 185.98 3438.29 5550.14S 4411.22E 3.45 5096.03 554337.13 5954919.27 8926 111R55 3439 ?9 e:.Rd? 7~C ,n. n~~ o R7 51R9?0 e:.Qe:.A.A?¡:; ¡:;o 91.13 185.85 3438.97 <;7<\<; AQ~ ;lO:¡QO QO:¡~ 2.13 5282.88 ""'''AO "0 "0"A7<1<1 Ai 10479.27 90.49 184.29 3437.66 5828.688 4382.70E 1.81 5376.02 554310.47 5954640.58 < f\"7< "f\ 91.23 184.72 343627 e:.Q?n ¡:;1~ 'n~" ,~~ 093 !ið.6822 "" 'n"" n. <;Q<;;1<;;1A ¡:;1 QO Q? 185.51 3434.52 ¡:;n1 <\ 7¡:;~ 4367.121= 0.91 5561.74 ""A')a~ 1') "Oe:.AAe:.e:..II') 10756.22 88.83 184.85 3434.72 6104.56S 4358.89E 2.40 5652.91 554288.49 5954364.57 RQ ?O 182.86 3436.34 ¡:;1QA ;l7~ ;I<\<;? <;¡:;~ 2.15 5746.99 e:.0e:.A')7f\ ~<I 1nClA.O:¡ 10 91 QO 1R30Q 3.43<; ;1<; ¡:;?Q1 1¡:;~ A<lA77At: ? Q? <;R3Q 7? 11036.23 92.12 186.54 3432.18 6383.80S 4339.94E 3.71 5932.68 554271.40 5954085.24 111?712 Q1 Q3 1RR RR 3428.95 6474.42S 4327.83E 2.35 6024.05 e:.oe:.o:¡aCIA. e:.e:. 11220.511 9012 19037 34?7 ?Q R<;R<;.QRS ;l31? 471= ?R7 611RRß 5!ið.24514 e:.Q<;O:¡QO? M 11313.73 91.90 192.57 3425.64 6657.25S 4293.95E 3.04 6209.29 554227.23 5953811.52 11405.97 90 ()3 1 Q3 ?O 3.4?;I OQ 6747.15S .11')7<1 <lRt: 2.14 6300.77 <;Q<;3721 4Q 11496.33 9153 19590 34?2Rß ~A<IA. e:.oc .II?e:.n ~a~ 342 ß3QOOO e:.e:.A.1Ae:. 1<; e:.Qe:.o:¡¡:;<\<\ Q1 11590.19 93.77 196.88 3418.52 6924.53S 4224.23E 2.60 6482.08 554159.30 5953543.80 1168492 Q2R4 1QR.11 3.413.?? 7n1 <; ??S ;l1Q7.3RI= 1 .4;1 6<;74 Q<; 5!ið.133 05 'A"7"7' ""7 90.03 19557 341113 7101R2S ;l17?R1F 296 ßßR35? """",,,,,, "}f\ 11866.99 88.83 194.14 3412.04 7190.76S 4149.22E 2.03 6754.33 554086.06 5953277 .11 11961011 91;11 193 3<; 3411 M 7?1I? 1;1S ;l1?R R71= ? R7 ßM7 ;1<; ""Af\"A "''> e:.Q<;O:¡1Ae:. <;Q 1 ?n<;;1 1"1 91.50 19582 3409411 73721ßS A<f\'" A.II:: 2Bß R93931 5!ið.041.50 """"""" A" 12145.29 91.93 197.74 3406.75 7459.39S 4077.14E 2.16 7028.69 554015.77 5953008.03 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8728.00 Feet on azimuth 152.86 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Conoc;p.,illips ConocoPhillips Alaslnco,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska . SURVEY LISTING Page 3 Wellbore: 126L 1 Wellpath: MWD w/Sag <7520-12468'> Date Printed: 16-Sep-2004 "~i. BAKER HUGHES INTEQ Well MD[ft] Northing 7699.20S 5952767.76 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8728.00 Feet on azimuth 152.86 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Conoc~illips ConocoPhillips Alaslnco,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska . SURVEY LISTING Page 4 Wellbore: 126L 1 Wellpath: MWD w/Sag <7520-12468'> Date Printed: 16-Sep-2004 r&l. BAKER HUGHES INTEQ Hole Sections Start MDft Wellbore s All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 RKB 98.8ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8728.00 Feet on azimuth 152.86 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Bookl.xls -- PeD ¿)~-f~'-&- Content-Type: appIication/vnd.ms-excel Content-Encoding: base64 lofl 7/22/20043:24 PM e ren cfJ{)¿¡' - /cJá Total Depth 12.573- - 1:!:f126 þ :i ()¿) TVD 3571' ~. ~ /6---ltlh,¿ Effective MD 12535' ~ ilo-Id-<ßr6 7-~-f);/ Effective TVD 3574' Casing Length Size Cement Volume MD TVD Conductor 80' 20"X34" 260 cf Surface 3858' 13 3/8" 730 sx ASLite,200 sx Deepcrete 3886' 2300' Intermediate 8093' 9 5/8" 710 sx DeepCrete 8121' 3617' Production N/A N/A N/A N/A N/A Liner 4454' 51/2" Slotted Liner 12575' 3571' ~øfL '"~.. ,2 """ . ~~ ~Œ (ffi~ iÆ~iÆ~~ . FRANK H. MURKOWSKI, GOVERNOR A1tASHA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling T earn Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk 1 E-126L 1 ConocoPhiIlips Alaska, Inc. Permit No: 204-123 Surface Location: 4428' FNL, 631' FEL, SEe. 16, T11N, R1 OE, UM Bottornhole Location: 1636' FNL, 1961' FEL, SEe. 27, Tl1N, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1E-126, Permit No 204-122, API 50-029-23215-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or 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 Cornrnission 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 Cornrnission 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 Cornrnission 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 Cornrnission to witness any required test. Contact the Cornrnission's petroleum field inspector at (907) 659- 7 (pager). BY ORDER OF ¿HE COMMISSION DATED this.Y day of July, 2004 ee: Department ofFish & Game, Habitat Section w/o ene!. Department of Environmental Conservation w/o ene!. ConoccJhillips Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com 004 July 3, 2004 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 "'~ ì ¡ Re: Application for Permit to Drill, West Sak Produc r, Dear Commissioners: ConocoPhillips Alaska, Jne. hereby applies for a Permit to Drill for an onshore ~roduction well bore, the 61>. upper lateral well bore of a TJ.:I}tilateral horizontal well, in the West Sak "8" sand. The main bore of this / " ...f/' well will be designated 19;1,'¡~d has been permitted under a separate application, submitted on '1'''1 July 3,2004. This appliéation is for the upper lateral of that well, to be designated 1E-126Ll. The .... expected date that operations will begin on 1E-126L1 is August 11, 2004. Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of this well bore. Under separate cover, ConocoPhillips is applying for a spacing exception for this wellbore, under the terms of 20 MC 25.055 Please contact Steve Shultz at 263-4620 if more information is needed to issue a Permt to Drill for 1E- 126Ll. Sincerely, -.....--- ~~ ... ~'\ ~andY Thomas GKA Drilling Team Leader .~ . . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: Drill 8 Redrill U Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Á I~-:J- ExploratoryU Develqpm¡¡ntOiI.8] MultipJe20ne 0 Service 0 Development Gas 0 . Si/1gle Zone 0 5. Bond: ~ Blanket LJ Single Well 11. Well Name and Number: Bond No. 59-52-180 1E-126L1 6. Proposed Depth: 12. Field/PooJ(s): MD: 12438' /' TVD: 3401' / Kuparuk River Field 1b. Current Well Class: Stratigraphic Test 0 P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 4428' FNL, 631' FEL, Sec. 16, T11N, R10E, UM Top of Productive Horizon: 1841' FNL, 1448' FEL, Sec. 22, T11N, R10E, UM Total Depth: 1636' FNL, 1961' FEL, Sec. 27, T11N, R1OE, UM Surface: x- 549890 4b. Location of Well (State Base Plane Coordinates): y- 16. Deviated wells: Kickoff depth: 7300 18. Casing Program Size Hole Casing 42" 20"x34" 16" 13-3/8 " 12.25" 9-5/8" 8.5" 5.5" 19 Total Depth MD (ff): /r2,é'"7'é) ~ J Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments: Filing Fee Property Plat , / 5960439 7. Property Designation: ADL 25651 & 25660 8. Land Use Permit: ALK 469 & 470 9. Acres in Property: / 2560 10. KB Elevation Zone- 4 , (Height above Gl): 28 P Downhole: 1536 psig Setting Depth / ft. Maximum Hole Angle: feet Weight 94# 68# 40# 15.5# SDecifications Grade Coupling K-55 Welded L-80 BTC L-80 BTCM L-80 DWC 94° Top Bottom Length MD TVD MD TVD 80' 28' 28' 108' 108' 3858' 28' 28' 3886' 2300' 8093' 28' 28' 8121' 3617' 5138' 7300' 3475' 12438' 3401' ./ West Sak Pool 13. Approximate Spud Date: 8/11/2004 PRESENT WELL CONDITION SUMMARY Total Depth TVD (ff): Plugs (measured) 0~.57/~ Length Size ,L) .J ~ BOP SketchU o Diverter Sketch 0 14. Distance to Nearest Property: 8924' 15. Distance to Nearest Well within Pool: 1E-112 , 953' @ 7300' r Surface: 1154 psig Quantity of Cement c. f. or sacks (including stage data) 260 cf ArcticCrete 730 sx AS Lite, 200 sx DeepCrete 710 sx DeepCrete slotted liner (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (ff): Effective Depth TVD (ff): Junk (measured) 1..2 £~~:5, 677"'" ~ Cement Volume MD Perforation Depth TVD (ft): Drilling Program [.:2J Seabed Report 0 Time v. Depth Plot 0 Drilling Fluid Program 0 Date: 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature . \ Permit to Drill Number: ;2D l./ - /2 3 Randy Thomas ~4~ \ TVD Shallow Hazard Analysis 0 20 AAC 25.050 requirements 0 Contact Steve Shultz @ 263-4620 Title Kuparuk Drilling Team leader Phone US6'8 3 v Date '/ ('Y f¿) 'f p AJI~IIn-nff"k'" Commission Use Only Permit APpr¡val / I 50-62-'1 - Z3 2/5:'- leó Date:? / /;?-/ p DYes !EI No Mud log required -( 0 Yes Qg No DYes 1&1 No Directional survey required 'b(J Yes 0 No \S(Jt)"\<èS\-'\~\t~ \ ",..-.Lt- ~ '\c\f""\~~ \ ~ &'lS0 \ " '-Þ" J a., ?tC~, BY ORDER OF fI/I.;- J (~ I v THE COMMISSION Date: r /¡V/ IlLI" \,.../'" API Number: Conditions of approval: Saflplesrequired jJ' ,.fide mea,",", Other: )5'~' ~~ \?:PX'~\. App~ ~'f/t '-'" t' ' Form 10-401 R~12/2003 ORIGiNAL See cover letter for other requirements / S /b .. /D I· u mlt In up Icate · AP.n for Permit to Drill, Well 1 E-126 L 1 Revision No.O July 3, 2004 Permit It - West Sak Well #1E-126 L 1("8" Sand) Application for Permit to Drill Document Table of Contents 1. Well Name .....................................................................................................................2 Requirements of 20 MC 25.005 (f) .................................................................................................... 2 2. Location Sum mary ....................................................................................................... 2 Requirements of 20 AA C 25.005(c)(2) . ...... ..... .......... ...... ...... ............. ....... ........................ .................. 2 Requirements of 20 AA C 25.050(b) .... ...... ....... ........ ........ .... ....... ............. ........... ....... ...... ..... ......... ..... 3 3. Blowout Prevention Equipment Information ............................................................3 Requirements of 20 AAC 25.005(c)(3) ......... ........ ..... ....... ........ ..... ....... ....... ......... .......... ...... ........ ....... 3 4. Dri II i ng Hazards Information ...................................................................................... 3 Requirements of 20 AA C 25.005 (c)(4) ..... .............. .... ....... ......... ..... ........ ....... ..... ....... ..... .............. ..... 3 5. Procedure for Conducting Formation Integrity Tests ............................................. 3 Requirements of 20 AAC 25.005 (c)(5) ....... ...... ......... ............. ....... .............. ....... .......... ............ .......... 3 6. Casi ng and Ceme nti ng Prog ram................................................................·...·...··.····· 4 Requirements of 20 AAC 25.005(c)(6) ... ........ ........ ....... ..... .............. ...... ......... ........... ..... ....... ..... ........ 4 7. Diverter System Information ......................................................................................4 Requirements of 20 AAC 25.005(c)(7) .. ..... ...... ........ ................ ........... ....... ........... ............ .................. 4 8. Drilli ng Fluid Program................................................................................................. 5 Requirements of 20 AAC 25.005(c)(B) .... ...... ....... ....... ................... ....... ............. ............. ....... ............. 5 Lateral Mud Program (MI FloPro NT) .................................................................................................. 5 9. Abnormally Pressured Formation Information ........................................................5 Requirements of 20 AA C 25.005 (c)(9) .... ....... ........ ............. ....... ............. ........ ........... ....... ............. .... 5 1 O. Seism ic Analysis...................................................................................................·.··..· 5 Requirements of 20 AAC 25.005 (c)(10) ..... ....................... ..... ........ ............... .... ............. ............... ..... 5 11. Seabed Condition Analysis ................................................ ........................................ 5 Requirements of 20 AAC 25.005 (c){11) .. ....... ........ ............ ............... ...... ....... ............ ............. ........ ... 5 12. Evidence of Bonding ............................. ..... ................................................................. 6 Requirements of 20 AAC 25.005 (c)(12) ..... ........ ....... ...... ....... ........ .... ......... ............ ....... .......... .......... 6 f)!f""NAL r\~lJ!> L 1 PERMIT IT RevO.doc Page 1 0(6 Printed: July 3, 2004 · AP.n for Permit to Drill, Well 1 E-126 L 1 Revision No.O July 3, 2004 13. Proposed Drilling Program .........................................................................................6 Requirements of 20 AA C 25.005 (c)(13) ........ ............ ........ ................... .................... ..... ...... ........ ....... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal........................6 Requirements of 20 AAC 25.005 (c)(14) ..... ...... ............ ......... ..... .............. ........... ....... ..... ...... .... ......... 6 15. Attach ments.................................................................................................................. 6 Attachment 1 Directional Plan (8 pages) .............. ..... ....... ............ ................ ...................... ......... ........ 6 Attachment 2 Drilling Hazards Summary (1 page)............................................................................... 6 Attachment 3 Well Schematic (1 pages).... .............. ........ ........... ....... ....... ............ ....... ..... ...... ............ 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 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 the well by the commission. The well for which this Application is submitted will be designated as 1E-126 Ll. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation" and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration,,' (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface I ASP Zone 4 NAD 27 Coordinates Northings: 5,960,439 Eastings: 549,890 FNL:4428', FEL:631', Sec 16, TllN/RlOE, UM I RKB Elevation I 94.3' AMSL I Pad Elevation I 66.3' AMSL Location at Top of Productive Interval FNL:1841', FEL:1448', Sec 22, Tl1N/RlOE, UM (West Sak "B" Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth/ RKB: 7300' Northings:5,957,777 Eastings: 554,376 Total Vertical Depth RKB: 3475' Total Vertical Depth/55: 3380.7' Location at Total Depth I FNL:1636', FEL:1961', See 27,T11N/R10E, UM ASP Zone 4 NAD 27 Coordinates Measured Depth/ RKB: 12438' Northings: 5,952,699 EasUngs: 553,908 Total Vertical Depth/ RKB: 3401' Total Vertical Depth 55: 3306.7' and (D) other information required by 20 MC 25. 050(b); ORIGINAL L 1 PERMIT IT RevO.doc Page 2 of 6 Printed: July 3, 2004 · APpan for Permit to Drill, Well 1 E-126 L 1 Revision No.O July 3, 2004 Requirements of 20 AAC 25.050(b) Ifa well is to be intentionally deviate~ the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a sUitable scale, showing the path of the proposed wellbore¡ including all adjacent wellbores within 200 feet of any portion of the proposed well,' Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in publiC records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 MC 25.035, 20 MC 25.036, or 20 MC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete we1l1E-126 Ll. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items¡ except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient,· The expected reservoir pressures in the West Sak sands in the lE-126L1 area vary from 0.0.42 to 0.0.45 psi/ft, or 8.1 to 8.6 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak D sand formation is 1154.46 psi, calculated thusly: MPSP =(3414 ft)(O.0.45 - 0.11 psi/ft) =1154.46 psi / (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones¡ and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on 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 25. 030(f); The parent wellbore,lE-126, will be completed with 95/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance L 1 PERMIT IT RevO.doc Page 3 of 6 Printed: July 3, 2004 · AP.n for Permit to Drill, Well 1 E-126 L 1 Revision No.O July 3, 2004 with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items¡ except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted line~ pre- perforated line~ or screen to be installed; Casing and Cementing Program See also Attachment 3, APO for 1E-126: Cement Summa!) Hole Top Btm Csg/Tbg Size Weight Length MO/TVO MO/TVO 00 (in) (in) (Iblft) Grade Connection (riJ (ft) (ft) Cement Program 20 X 34 42 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCRETE 13 3/8 16 68 L-80 BTC 3858 28 / 28 3886 /2300 Cemented to Surface with 730 sx ASLite Lead, 200 sx OeepCRETE Tail 9 5/8 12 1/4 40 L-80 BTCM 8093 28 / 28 8121/ 3617 Cement Top planned @ 4266' MO / 2440' 1V0. Cemented w/ 710 sx OeepCRETE 51/2 8 1/2" "A" 15.5 L-80 OWC 4454 8121/3617 12575/3571 Slotted- no slotted Lateral (lE- cement .L. ~ 1?h' 51/2 81/2" 15.5 L-80 OWC 5138 7300/3475 12438/3401 Slotted- no slotted "B" Lateral cement --- l II:"" ~ ,w Ll T 51/2 81/2 15.5 L-80 OWC 5380 7054/3418 12434/3335 Slotted-no slotted "0" Lateral cement (lE-126 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items¡ except for an item already on file with the commission and identified in the application: (7) a diagram and description ofthe diverter system as required by 20 MC 25.03~ unless this requirement is waived by the commission under 20 MC 25.035(h)(2); No diverter system will be utilized during operations on 1E-126 uV ORIGINAL L1 PERMIT IT RevO.doc Page 40f6 Printed: July 3, 2004 · AP.n for Permit to Drill, Well 1 E-126 L 1 Revision No.O July 3, 2004 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8} An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system as required by 20 MC 25.033/ Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (VersaPro, Oil Base Mud) Properties Value Density (ppg) 9-9.2 Funnel 30 Viscosity (seconds) Yield Point 18-28 (cP) Electric Stability 650-900 Chlorides (mg/I) 40000 pH N/A API filtrate <4 (cc / 30 minJ **HTHP filtrate <10 (cc / 30 min) MBT (Ib / gal) <5 t" Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon 141 Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c){9) An application for a Permit to Doll must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test we/~ a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f}/ Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005 (c){10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test we/~ 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. 10. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c){11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up ria or floating drilling vesse~ an analysis of seabed conditions as required by 20 AAC 25.061(b)/ Not applicable: Application is not for an offshore well. ORIGINAL L 1 PERMIT IT RevO.doc Page 50f6 Printed: July 3, 2004 · AP.n for Permit to Drill, Well 1 E-126 L 1 Revision No.O July 3, 2004 11. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items,. except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25. 025 (Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items,. except for an item already on file with the commission and identified in the application: The proposed drilling program for 1E-126 L1 is listed below. Note: Previous operations are covered under the lE-126 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 7300' MD / 3475' TVD, the top of the B sand. 2. Mill 8 1/2" window. POOH. 3. Pick up 8 1/2" drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of "B" sand lateral at 12438' MD / 3401' TYD, as per directional plan. 5. POOH, back reaming out of lateral. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 5 1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. Displace liner annulus and liner to 9-9.2 ppg weighted brine. 10. POOH and PU lateral entry module 11. RIH with module and latch into the "B" sand hook hanger 12. POOH and prepare to drill the "D" sand lateral 1E-126 L~ ft.- ""'" ') I If") 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identi/ìed in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25. 080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on lE Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on lE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic r'l~lNAL' ,~ u 0, L1 PERMIT IT RevO.doc Page 6 of 6 Printed: July 3, 2004 · . lE-126Ll Drilling Hazards Summarï (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 8 1/2" Open Hole / 5 1/2" Liner Interval Low Miti ation Strate Stripping drills, Shut-in drills, Increased mud wei ht. Good hole cleaning, PWD Tools, Hole o ener, Decreased mud wei ht Reduced urn rates Mud rheolo LCM Trip speeds, Proper hole filling (use of trip sheets Pum in out Hazard Abnormal Reservoir Pressure Stuck Pipe Risk Level Low Lost Circulation Hole Swabbing on Trips Moderate High ORIGINÞ,L 1E-126 Drilling Hazards Summary prepared by Steve Shultz 5/27/2004 9:43 AM Tie-In 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 . . ",",' . ConocóPhillips ConocoPhillips Alaska, Inc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 1 Wel/bore: 126L 1 Wel/path: 126L 1 Ver#4 Date Printed: 29-Jun-2004 « 11\I1£Q 5948985.8206 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8722.22 Feet on azimuth 152.94 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . ConocÒPhillips ConocoPhillips Alaska, Inc.,Slot #126 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Well bore: 126L 1 Well path: 126L 1 Ver#4 Date Printed: 29-Jun-2004 ... 'Ii. INTEQ ........ .ú . > .. ........ .... ........ ..> .... ........ < .'. ........... I~b(ftl ...... yertica.lc 15t.atiøn ~t~tfon.. Oo~è9 V~rtiç~1 < ._,. ''''! "J~''''' ) Yl)tT1:j ." 1::~$ttTtJi ....... < < ...... ...... ..' INorth) ...... Eå$t\· ~'" t¡" < < 7300.08 80.00 185.57 3474.50 3375.50 2692.398 4469.47E 5957777.06 554376.40 0.00 2246.11 Too Whiostock Face End of Build Tie a 7316.58 82.24 185.57 3477.05 3378.05 2708.618 4467.89E 5957760.83 554374.93 13.60 2262.41 Base Whiostock Face End of Build 7336.58 82.24 185.57 3479.74 3380.75 2728.348 4465.96E 5957741.09 554373.14 0.00 2282.23 End Milled Openhole, KOP. End of Hold 7436.58 87.24 185.57 3488.90 3389.90 2827.428 4456.31E 5957641.96 554364.14 5.00 2381.78 7512.32 91.03 185.57 3490.04 3391.04 2902.78S 4448.96E 5957566.56 554357.30 5.00 2457.49 End of Build 7595.67 93.53 185.52 3486.73 3387. 73 2985.668 4440.92E 5957483.63 554349.80 3.00 2540.77 End of Build/Turn 7600.00 93.53 185.52 3486.46 3387.46 2989.978 4440.50E 5957479.33 554349.41 0.00 2545.09 7700.00 93.53 185.52 3480.30 3381.30 3089.328 4430.g0E 5957379.93 554340.47 0.00 2644.90 7767.85 93.53 185.52 3476.12 3377.12 3156.728 4424.39E 5957312.49 554334.41 0.00 2712.62 30J Kick off Point 7800.00 92.57 185.52 3474.41 3375.41 3188.688 4421.30E 5957280.51 554331.53 3.00 2744.73 7851.18 91.03 185.52 3472.80 3373.81 3239.608 4416.37E 5957229.57 5~26.95 3.00 2795.,89 End of DroofTurn 7900.00 91.03 185.52 3471.93 3372 93 3288.188 4411.68E 5957180.96 554322.57 0.00 284469 8000.00 91.03 185.52 3470.13 3371.13 3387.708 4402.06E 5957081.39 554313.61 0.00 2944.68 8062.66 91.03 185.52 346900 3370.00 3450.068 4396.03E 5957019.00 554308.00 0.00 3007.33 WS 1 E 05 B-MOPT#1 RV8D060204, 3DJ Kick off Point 8100.00 90.89 184.41 3468.37 3369.37 3487.258 4392.79E 5956981.79 554305.02 3.00 3044.66 8120.70 90.82 183.79 3468.06 3369.06 3507.90S 4391.31 E 5956961.13 554303.67 3.00 3065.36 9 518in Casina 8200.00 90.52 181.43 3467.14 3368.14 3587.108 4387.70E 5956881.91 554300.58 3.00 3144.53 8300.00 90.15 178.46 3466.55 3367.55 3687.098 4387.79E 5956781.94 554301.34 3.00 3244.04 8312.67 90.10 178.08 3466.52 3367.52 3699.768 438818E 5956769.28 554301.81 300 3256.61 End of OropfTurn .- ~8400. 00 90.10 178.08 3466 36 3367. 36 3787.038 4391.10E 5956682.03 554305.32 0.00 3343.19 -- 8500.00 90.10 178.08 3466.18 3367.18 3886.988 4394.45E 595658212 554309.33 0.00 3442.34 8600.00 90.10 178.08 3466.00 3367.00 3986.928 4397.81E 5956482.21 554313.35 0.00 3541.49 8700.00 90.10 178.08 3465.82 3366.82 4086.868 4401.16E 5956382.30 554317.36 0.00 3640.63 8800.00 90.10 178.08 3465.64 3366.64 4186.818 4404.51E 595628239 554321.37 0.00 3739 78 8900.00 90.10 178.08 3465.46 336649..... ~6.75.s. 4407.86E 5956182.48 554325.39 0.00 3838.93 9000.00 90.10 178.08 3465.28 3366.28 4386.708 4411.21E 5956082.57 554329.40 0.00 3938.08 9100.00 90.10 178.08 3465.10 3366.10 4486.648 4414.57E 595598267 554333.42 0.00 4037.22 9200.00 90.10 178.08 3464.92 3365.92 4586.588 4417.92E 5955882.76 554337.43 0.00 4136.37 9300.00 90.10 178.08 3464.74 3365.74 4686.538 4421.27E 5955782.85 554341.45 0.00 4235.52 9400.00 90.10 178.08 3464.56 3365.56 4786.478 4424.62E 5955682.94 554345.46 000 4334.66 9500.00 90.10 178.08 .3464.38 3365.38 4886.4.t.s. ..A12797E 5955583.03 554349.48 0.00 4433.81 9600.00 90.10 178.08 3464.20 3365.20 4986.36S 4431.32E 5955483.12 554353.49 0.00 4532.96 9700.00 90.10 178.08 3464.02 3365.02 5086.308 4434.68E 5955383.21 554357.51 0.00 4632.11 9712.22 90.10 178.08 346400 3365.00 5098.528 4435.09E 5955371.00 554358.00 0.00 4644.22 W8 1E 05 B-MOPT#2 RV80050504, 3DJ Kick off Point 9800.00 90.33 180.70 3463.67 3364.67 5186.288 4436.02E 5955283.25 554359.52 3.00 4731.48 9900.00 90.58 183.69 ...J.462.88 ~..87 5286.198 4432.18E 5955183.33 554356.35 3.00 4831.30 9935.21 90.67 184.74 3462.49 3363ÆL 5321.308 4429.60E 5955148.21 554353.99 3.00 4866.49 End of Build/Turn 10000.00 90.67 184.74 346173 3362.73 5385.878 4424.24E 5955083.61 554349.06 0.00 4931 .27 10100.00 90.67 184.74 3460.56 3361.56 5485.528 4415.97E 5954983.92 554341.45 0.00 5031.26 10200.00 90.67 184.74 3459.38 3360.38 5585.178 4407.69E 5954884.22 554333.84 000 5131.24 10300.00 90.67 184.74 3458.21 3359.21 5684.828 4399.42E 5954784.53 554326.23 0.00 5231.22 10400.00 90.67 184.74 345704 3358.04 5784.478 4391.15E 5954684.84 554318.63 0.00 5331.20 10500.00 90.67 184.74 3455.86 3356.86 5884.12.s' ~ß8E 5954585.14 554311.02 ......Q,.QQ... í~~ 10600.00 90.67 184.74 3454.69 3355.69 ....Qg8~n.s. _4.374.61E 5954485.45 554303.41 0.00 .. 5531.17 -~ 10700.00 90.67 184.74 3453.52 3354.52 6083.428 4366.34E 5954385.76 554295.80 0.00 5631.15 10800.00 90.67 184.74 3452.34 3353.34 6183.078 4358.07E 5954286.06 554288.19 0.00 573113 10900.00 90.67 18474 3451.17 3352.17 6282.72S 4349.80E 5954186.37 554280.58 0.00 5831.12 All data is in Feet unless otherwise stated Coordinates are from 810t MO's are from Rig and TVO's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8722.22 Feet on azimuth 152.94 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . ~illips ConocoPhillips Alaska, Inc.,Slot #126 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Well bore: 126L 1 Wellpath: 126L 1 Ver#4 Date Printed: 29-Jun-2004 ... 'ISLs INTEQ I.... c .... ..... ..... ..... ....... ..> ..... .... > .. ... > .. > ...... [MDtftl.... Ilnc[ôegl D/(>[ft] Vertical I NØrth[ft}. ". ~ast[ft .... I station . ""-., ...... [}þgle~ ~. .. .......'. ""'~"V"".' ......' ></ .... .... .. ..,"1-"-".'-'''''. .' Ë~st) .,. ...... Öttf fl I North) .' ....... 10999.68 90.67 184.74 3450.00 3351.00 6382.058 4341.55E 5954087.00 554273.00 0.00 5930.78 W8 1E D5 B-MDPT#3 RV8D050504, 3DJ Kick off Point 11000.00 90.67 184.75 3450.00 3351.00 6382.378 4341.52E 5954086.68 554272.98 3.00 5931.10 11100.00 91.05 187.73 3448.49 3349.50 6481.768 4330.65E 5953987.23 554262.76 3.00 6031.07 11200.00 91.42 190.71 3446.35 3347.35 6580.438 4314.64E 5953888.46 554247.40 3.00 6130.83 11300.00 91.78 193.69 3443.56 3344.56 6678.138 4293.52E 5953790.64 554226.94 300 6230.11 11400.00 92.14 196.67 3440.13 3341.13 6774.578 4267.35E 5953694.04 554201.42 3.00 632864 11404.78 9216 196.81 3439.95 3340.95 6779.158 4265.98E 5953689.45 554200.07 3.00 6333.33 End of BuildfTurn 11500.00 92.16 196.81 3436.36 3337.36 6870.238 4238.46E 5953598.20 554173.16 0.00 6426.65 11600.00 92.16 196 81 3432.59 3333.59 6965.89S 4209.56E 5953502.36 554144.90 0.00 6524.66 11700.00 92.16 196.81 3428.82 3329.82 7061.558 4180.66E 5953406.52 554116.64 0.00 6622.68 11800.00 92.16 196.81 3425.05 3326.06 7157.208 4151.76E 5953310.68 554088.38 0.00 6720.69 11900.00 92.16 J96.81 3421.29 3322.29 7252.868 4122.86E 5953214.84 554060.11 --º,lJO 6818.70 .-- 12000.00 92.1.~L 196.81 3417.52 3318.52 7348.525 4093.96E 5953119.00 554031.85 0.00 6916.71 12100.00 92.16 196.81 341375 3314.75 7444.188 4065.06E 5953023.16 554003.59 0.00 7014.72 12200.00 92.16 196.81 3409.98 3310.98 7539.848 4036.16E 5952927.32 553975.33 000 7112.73 12300.00 92.16 196.81 3406.21 3307.21 7635.508 4007.26E 5952831.48 55394707 0.00 7210.74 12400.00 92.16 196.81 3402.44 3303.44 7731.16S 3978.36E 5952735.65 553918.81 0.00 7308.75 . 12434.43 92.16 196.81 3401.14 3302.14 7764.098 3968.41 E 5952702.65 553909.08 0.00 7342.50 5 1/2in Liner 12438.24 92.16 196.81 3401.00 3302.00 7767.738 396731E 5952699.00 553908.00 0.00 7346.23 TD, 5 1/2in Liner All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8722.22 Feet on azimuth 152.94 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIG~Nt\ . . .,' ConocóPhillips ConocoPhillips Alaska, Inc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 4 Wel/bore: 126L 1 Wel/path: 126L 1 Ver#4 Date Printed: 29-Jun-2004 INTEQ '"" ... ....... ..... .. ..... ....... .. .... ...... ....... MOrftr JJtÖfftT f E'asffftl i < ......... ..... ..... ........ ......... < .. 300.00 300.00 O.OOE O.OON KOP 585.71 584.27 24.77E 2.178 BldfTrn 4/100 837.57 82724 89~14E 11.588 BldfTrn 5/100 -~~- 1916.89 1584.37 796.38E 179.95S EOC 4950.66 2686 54 3526.55E 911.498 Turn 4.5/100 579362 3004.49 414928E 1354.338 EOC 5906.07 3045.34 4208.12E 1441.02S 8tart 200' Purno Tanoent 6106.07 311800 4312.77E 1595.198 End 200' Pumo TanQent BldfTrn 4.5/100 6954.45 3392.12 4502.02E 2358.458 EOC 7133.41 3438.44 448525E 2530.498 BId 3/100 7300.06 3474.50 4469.47E 2692.378 EOC 7300.08 3474.50 4469.47E 2692.398 Too Whiœtock Face -~ 7316.58 3477.05 4467.89E 2708.618 Base Whiostock Face -~ 7336.58 3479.74 4465.96E 2728.348 End Milled Ooenhole KOP 12438.24 3401.00 3967.31E 7767.738 TO 5 1/2in Liner W8 1 E 05 B TOE 7767.73S 3967.31E 3401.00 N70 16 53.2966 W149 33 49.6690 553908.00 5952699.00 RV800060704 WS 1 E 05 5098.528 4435.09E 3464.00 N70 17 195456 W149 33 35.9984 554358.00 5955371.00 B-MOPT#2 RVS0050504 W8 1E 05 3450.068 4396.03E 3469.00 N70 17 35.7583 W149 33 37.1084 554308.00 5957019.00 B-MOPT#1 RV80060204 W8 1E 05 6382.058 4341.55E 3450.00 N70 17 6.9227 W149 33 38.7453 554273.00 5954087.00 B-MOPT#3 RV80050504 All data is in Feet unless otherwise stated Coordinates are from 810t MOos are from Rig and TVOos are from Rig ( Datum #1 99.0ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8722.22 Feet on azimuth 152.94 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORfGINAL . . c:onocñPmllips ConocoPhillips Alaska, Inc.,Slot #126 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 5 Well bore: 126L 1 Well path: 126L 1 Ver#4 Date Printed: 29..Jun-2004 INTEQ 647616 7300.08 3474.50 ISCWSA MWD MWD+SAG - ISCWSA - 28 Ja 03 OJH MWD+SAG -ISCWSA - 28 Ja 03 OJH 649024 ISCWSA MWD Planned Planned All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 185.57 degrees Bottom hole distance is 8722.22 Feet on azimuth 152.94 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated OR I G~ ~.J.AL ~aker Hughes Incorpora! Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 25.00 ft Depth Range: 7300.08 to 12438.19 ft Maximum Radius: 5280.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse Survey Program for Definitive Wellpath Date: 1/12/2004 Validated: No Planned From To Survey ft ft 0.00 7300.08 Planned: 1E-126 Vers#4 V29 (0) 7300.08 12438.19 Planned: 1 E-126L 1 Vers#4 V12 Version: Toolcode Tool Name MWD+SAG MWD+SAG MWD + Sag correction MWD + Sag correction Summary Pad 1 E 102 102 B-Lateral VO Plan: Out of range Pad 1 E 102 102 D-Lateral VO Plan: Out of range Pad 1 E 103 103 VO Plan: 1E-103 VE Out of range Pad 1 E 104 104 VO Plan: 1E-104 VE Out of range Pad 1 E 105 105 A2-Lateral VO Plan 9712.18 11225.00 1235.38 407.81 827.57 Pass: Major Risk Pad 1 E 105 105 B-Lateral VO Plan: 9712.18 11200.00 1215.50 399.37 816.13 Pass: Major Risk Pad 1E 105 105 D-Lateral VO Plan: 9712.18 11200.00 1214.15 402.23 811.92 Pass: Major Risk Pad 1 E 11 1E-11 VO Out of range Pad 1 E 112 1E-112V1 Out of range Pad 1 E 112 1 E-112L 1 VO Plan: 1 E-1 12438.15 10975.00 1067.02 475.82 591.20 Pass: Major Risk Pad 1 E 112 1E-112L2 VO Plan: 1E-1 12421.71 10950.00 1074.51 476.07 598.44 Pass: Major Risk Pad 1E 114 114 A2-Lateral VO Plan Out of range Pad 1 E 114 114 B-Lateral VO Plan: Out of range Pad 1 E 114 114 D-Lateral VO Plan: Out of range Pad 1 E 121 121 B-Lateral VO Plan: Out of range Pad 1 E 121 121 D-Lateral VO Plan: Out of range Pad 1E 12 1E-12 VO Out of range Pad 1E 123 1E-123 L1 V2 Out of range Pad 1E 123 1E-123V18 Out of range Pad 1 E 123 1E-123PB1 V1 Out of range Pad 1 E 168 168 A2-Lateral V3 Plan 7322.70 5975.00 657.74 199.90 457.84 Pass: Major Risk Pad 1 E 168 168 B-Lateral VO Plan: 7322.70 5975.00 657.74 199.90 457.84 Pass: Major Risk Pad 1 E 168 168 D-Lateral VO Plan: 7322.70 5975.00 657.74 199.90 457.84 Pass: Major Risk Pad 1 E 18 1E-18 VO Out of range Pad 1 E 19 1E-19 VO Out of range Pad 1 E 20 1 E-20 VO Out of range Pad 1 E 22 1 E-22 VO 7660.13 6150.00 1087.33 176.33 911.00 Pass: Major Risk Pad 1 E 3 1 E-03 V1 Out of range Pad 1E 33 1 E-33 VO 7300.06 8475.00 2710.92 185.65 2525.27 Pass: Major Risk Pad 1 E 33 1 E-33PB 1 VO 7300.06 8475.00 2710.92 185.65 2525.27 Pass: Major Risk Pad 1 E 34 1 E-34 VO 11374.87 11250.00 2619.73 150.30 2469.43 Pass: Major Risk Pad 1 E 35 1 E-35 VO 12408.28 9050.00 1971.01 314.36 1656.65 Pass: Major Risk Pad 1 E 35 35A VO Plan: 35A ST Ve 12429.40 9150.00 1952.94 285.64 1667.30 Pass: Major Risk Pad 1 E 5 1 E-05 VO Out of range Pad 1 E 6 1 E-06 VO Out of range Pad 1 E 7 1E-07 VO Out of range Pad 1 E 8 1 E-08 V1 Out of range Pad 1J 1 J-DU 1J-L3 A Lateral V1 Pia Out of range ORIGINAL --4 0,",~'~ \<,'- 01>'"'~ .....'!-, .~ ~ r' <'..,\<ò~ 9;,'?J. ~'.J ~e,",'- ,,\d~ I , ¢:< o rt:J II E (J <1> 13 Cf) _ 3040 ø .! ~ 3200 Q. eI) Q 3360 3680 (,e~'è-rß v;-0(( (,~ '~(,~ ~O\e' e v;-0(( . ~?.~~\'V,",'<iorve<' ¿1>rß~1>C;O:¡.e, ~'f,\~'<'I~ Ò *,' (,~ ~ "\ 0%1>,",~ ~~e; . ~\~\Q~\~'Vfo'Vef,\ f.\. ,,'~ è",£,~~e; 92.46 ~ __ "\ 0'<0.,0,<5 ò.~'_ 00 ~~ ~;.""~f,\.... ...... ................... ~es~J\~ 0 «,00~~ nÂ_4 - - "\ 0'V ~~ ~e,",'- 9;,'?J. ,,\0'V ë; ~ .~ 3520 ~ ~ I I V l 3840 1760 1920 2080 2240 2400 2560 2720 Seale 1 em = 80 ft ¢:< 0 rt:J II E (J () ~ Cf) _ 3040 ø eI) 3200 e- el) Q 3360 ë; . 90.3.5 C.) 90.33 :e 3520 ~ .66 eI) 3680 :;, ~ .... I V 3840 4160 4320 4480 4640 4800 4960 5120 Seale 1 em = 80 ft ConocoPhillips Alaska, Inc. ConocòPhillips Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot #126 Well: 126 Well bore: 126 reate y : anner Date plotted: 30-Jun-2004 lot re erence is 1 6. Ref well path is 126 Ver#4. Coordinates are in feet reference Slot #126. True Vertical Depths are reference Rig Datum. I Measured Depths are reference Rig Datum. I Rig Datum: Datum #1 Rig Datum to mean sea ievel: 99.00 ft. Plot North is aligned to TRUE North. 126L2 126L 1 90.52 Bid 4/100 84.00 92.60 EOC I -'__""."''':~ 2880 3040 3200 3360 3520 3680 3840 4000 4160 4320 4480 4640 4800 4960 5120 5280 Vertical Section (feet) -> Azimuth 185.57 with reference 0.00 N, 0.00 E from Slot #126 ¿ r r: ~'M' --" cr .., 91.68 91.78 126L2 TO, 5 1/2in Liner 126L 1 TO, 5 1/2in Liner 92.99 TO, 5 1/2 Liner PI. ~ 5280 5440 5600 5760 5920 6080 6240 6400 6560 6720 6880 7040 7200 7360 7520 7680 Vertical Section (feet) -> Azimuth 185.57 with reference 0.00 N, 0.00 E from Slot #126 8.. .... INTEQ --- . ConocoPhillips Alaska, Inc. Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Scale 1 em ::: 300 It -2400 -1800 -1200 -600 ~- SURFACE LOCATION: 852' FSL. 631' FEL SEC. 16. T11N. R10E Cono~illips Slot: Slot #126 Well: 126 Well bore: 126 Created by: Planner Date pl~ited: 30-Jun-2004 Plot reference is 126. Ref wellpath is 126 Ver#4 . Coordinates are in feet reference Slot #126. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 99.00 ft. Plot North is aligned to TRUE North. o 600 East (feet) -> 1200 ~800 2400 3000 3600 4200 4800 5400 6000 I¡,I'\R~\) fJ 5'- +-0« Áí\§'~(..~\'?>\~"\)~.s.<·.o <Q~Ò\Ò~~~{\ '«e~ ~ <Q'.¡<Q\~<Q~tOc,~.o\> ~, "S fPt?> ~ c,'ð ~.o\> ,?>\~p ,,'?> ~7 -----v TuraA.5GOO C lOp gnu Start 200' PumjJ Tangent End 200' Pump Tangent, BldfTrn 4.5/100 EOC Top Ugnu B Top Ugnu A 1E-126 TOP WEST SAK 0 LOCATION: 1603' FNL, 1424' FEL SEC. 22. T11N. R10E --- 1E-126 TOP WEST SAK B LOCATION: 1841' FNL, 1448' FEL SEC. 22, T11N, R10E 1E-126 TOP WEST SAK A2 LOCATION: 2634' FSL, 1528' FEL SEC. 22 T11N, R10E ~~--- 1E-126L1 & 1E-126l2 TO LOCATIONS: 1636' FNL.1961· FEL SEC. 27. T11N. R10E ORJG'NAL K-13 EOC Top West Sak D Bid 3/100 C EOC Top West Sak B A-4 A-3 Top West Sak A2, Int Csg. Pt. j L 9 5/8in Casing 1E-126 TO LOCATION: 1796' FNL. 1952' FEL SEC. 27, T11N, R10E 600 o -600 -1200 -1800 -2400 -3000 - -3600 ^ I -4200 Z o ;:¡ ~ - -4800 c;r ~ - -5400 -6000 -6600 -7200 -7800 -8400 en o OJ ëõ -9000 0 3 II -9600 g¡ o ~ KOP: 300' Build at 3-5 degrees/ 100' o :;cJ ~ ú-, ii·.~ Z » r Note: Intermediate and bottom lateral to be drilled with rotary steerable, upper laterals with motor 16" Hate (Spud Mud) 13 3/8" Casing Hydraulics: Surface: 900-1000 gpm Intermediate: 700-800 gpm Laterals: 500-600 gpm Pore Pressure TVOss TVO MWE 1530 psi 3340 ft 3435 ft 8.8 ppg . Top of Ugnu -.... // +/-4266 ' MO ./ Window @ 7054' MO "0" Sand (Oil Base Mud) 8 1/2" Hole 5 1/2" Liner Top of Cement MO " Sand (Oil Base 8 1/2" Hole 5 1/2" Line 12,438' MO 3401 'TVO . 121/4" Hole (LSNO) 9 5/8" Casing "A-2" Sand (Oil Base Mud) 8 1/2" Hole (Undulating) 5 1/2" Liner 12576' MO 3571' TVO 8121' MO 3617' TVO I . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER KRd /c~/2fo L( WELL NAME PTD# 2ò1-/23 ~ Development Service Exploration Stratigraphic CHECK WßA T ADD-ONS "CLUE". APPLIES (OPTIONS) MULTI The permit is for a new weJlboresegment of LATERAL existing weD t:¡:;z ~{. /6 -l Ú ~ vI/ Permit No,2ðê.{," ¡.Z~I No. .$Z)--ð7!J- 2-3 Z (If API Dum ber Production. should continue to be reported as last two (2) digits a function' of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (PH) records, data and logs acquired for the pilot hole must be clearly differentiated In both name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired for we)) (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of ;t conservation order approving a spa cing exception. (Company Name) assumes the liability of any protest to the spacing .exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater ·tban 30' sample intervaJs from below tbe permafrost or from where samples are first caught and 10' sample intervaJs through target zones. 1S-..ðO Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1 E-126L 1 _Program DEV Well bore seg ~ COPHILLlPS ALASKA INC Initial ClasslType _D.EV I PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal 0 - - Administration Permittee attache$:! NA_ Multilater_aI well~ fee waived per 20AAC 25_.Q05(e) - - - - - - 2 leas_e n!Jmber _apRropri¡¡tß _ , _ _ - - - - - - - - - - - ~ - - - Yes_ TQP_pJQduçtive interv.al in ADL 025651; TO in AD\.. 025660 , ~ - - - - 3 _U_niq!Jewelln_amß_and lJl!mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ ~ - - - - - - - - - - - - - - - 4 Well IQc¡¡ted in_a_ d_efioe$:!_ppol - - - - - - - - - - - - - - - - - Yes IŒU West Sak _Ojl Ppol, goyerl1ed_ byConserv.ation QrderNo, 4Q6A - - - - - 5 WelUQc¡¡ted p[oper $:!istance from driJling uoitb_ouodar}'- - - - - - - ..", _ _ _ Yes - - - - -- 6 Well IQc¡:¡ted proper _distance_ from ot/Jer wells_ _ _ _ - - - - - - Yes - - - - - - - - - - - - - - - - - - - 7 SJJfflcient ¡¡creage_aYail¡¡ble in,dJiUil1g l!njL Yes - - - - - - - - - - - - - - - - - - 8 Jtdeviated, js_ wellbQre platincJu$:!ed Yes - - - - - - - - - - - - - - 9 Operator onl}' affected party _ _ , , , , _ _ - - - - - - Yes - - - - - - - - - - - - - - - - - 10 _O-pe[ator /Jas_apprppriate_bond inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11 Permit c.al1 Þe iSSl!ed wjt/JQut conserva_tion order _ Yes - - - - - - - - - - - - - - - Appr Date 12 Permit c.al1 Þe issl!ed wit/JQut admioistratille_appr.oval _ - - - - - - Yes - - - - - - - - - - - - - - - - - - - SFD 7/9/2004 13 Can permit be approved before 15-day wait Yes . 14 WelllQc¡:¡ted withio area aod_strata ~uthorized byJl1jectipo Ord_er # (PuIlO# hc_ommel1tsJ-{For NA 15 _AJI wells_ withtn _1l4JIJile_are.a_of reyi~w jdelJt[fied (F.or servjee well çmly) _ _ _ _ _ _ _ _ _ _ _ _ _NA ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 16 Pre-produced il1j~ctor; .duratiQn_of pre-pro$:!uctipo lesS than 3 mont/Js_ (Forsel'Ytce welt QnJy) NA - - - - - - - - - - - - - - - - - 17 ACMPFjodin90f Consistency has Þee_nissuedJor tbis project NA Multilater_al weILbpr_e, . - - - - - - - - - - - - - - - - - - ~ Engineering 18 _C9nductor string_pJQvided _ _ , ' - - - - - - - NA CondUGtor iostaJled_ ill '1 E-J 26. _ . - - - - - - - - - - - - - - 19 _S!Jrfaee_casiogprotects alLkllown_ USQWs _ _ . _ _ _ _ _ ' NA 1:\/1 aq!Jifers exempted 40 cm :147.102(b)(3), . . 20 _CMT vOl adeQuateJo circ!Jlateoncçmd_uctpr & surtC$g _ ' NA Sl!rtaœ ça_sing inst~lJe_djn 1~-126, . - - - - - 21 _CMT vÞl adeQl!ateJo tie-in Jon9 _string to_surf csg_ _ _ . NA tntermediate_ c.asiog installed jn lE-126 _ _ . - - - - - - - 22 _CMTwill GoYer_aJl !<oownprod!Jc!iye bori¡wns_ - - - - - - No Slptted liner _completLol1 plal1oed._ Intermediate casing cement plaoned abo_ve aoy/a.lI_hYdrQc.arb_ol1s. . 23 C_asing de.sÏ9ns ad_equa!e f.or CJ, B _&_ permafr_ost Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 A.dequ¡¡tetankage_ or re_SeI'Ye pit _ _ . - - - - - - - - Yes Rig is_ e_quipped_with steelp]ts. _ NQ reseJ\1e_pjt-plaooe_d, All waste toan_apprOlledal1nuJusor CI¡¡ss_" wel 25 Jtue-.drilt bas a 10:403 fQr abandonme_nt be_eo aPPJoved _ NA - - - - - - - - - - - - - - - - - -- 26 _A$:!equ~tewellbore_ separatio_n_proposed _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _Yes I?r.o~imit}' an~IY$i$ performed, Only _ClOse. appro_ach is A_saod_ section _aÞwt :l10~ tvd Þelow. _ _ _ 27 Jtdiver:ter required, dQes iLmeet reguJa.tioos_ _ NA 601=' staGKwill alr.eady_bein plac.e, , _ _ _ _ _ _ _ Appr Date 28 _Drillil1g fJuid_ program sGhematic& eQ.uip Jistadequ¡¡te _ _ _Y_es 61:H::> ex-pected be1we_el1 8.1- ß.6_EMW. I?laoned MW 9.0- 9.2 jn West Salç. _ . TEM 7/12/2004 29 _BQPEs,_ d_o they meet regula.tion . - - - - - - Yes - - - - - - - - - - - - - - - - - - . - - - - - - - A~<1M~k} 30 _BOPE_press ra_ting appropriate; _test to (pu.t p$ig ill_comments) _ _ . Yes MI:\SI=' calGulatedat 1t54 psi, 35QOp,<>La-ppropriate_. _CPAJ plaosJo tesUo 50QOpst . 31 _CMkemanifold complies w/APIR::>-53 (May 84)_ . _Y_es - - - - - -- - - - - - - - - - - - - - 32 WQrlç will occur withouLoperatjon_s/Jutdown_ _ . - - - -- Yes - - - - -- - - - - - - - - - - - - - - - - - - - - - 33 Is. Rres.ence Qf H2S gas_ Rrobaþle _ - - - - - - - - - - - - No /:I2S is !Jl1likely. Mud_ s.hpuld preclude H2S_ o_n Jhe rÏ9, Hig is equjpped with_ sel1s.ors_ andalarms_. 34 Mec/Ja.n[caLcoodjtiol1.o{ w~lIs wtthio AOR yerified (for service welJ only) NA - - - - -- - - - - - - - - - - - - - - ~ - Geology 35 Permit c_al1 Þe iSSl!ed w/Q hydr9gen sUlfide meas_ures. _ _ _ _ . Yes IŒU WestSak welJs 112miJe_ to east meas.uredJess th_al1 JO ppm H2S in2003 and200~. 36 _D_ata_PJeseoted on pote_ntial pverRres_sure _zooes_ Yes I;xpected r_eservojr -pressure ts _8, 1-8,6ppg EMW; will be drilled wjtb 9.0 _- 9.2 -ppg mud. Appr Date 37 _Seismicanalysjs Qf sbaJlow gas_z.ol1es _ _ , _ _NA - - - - - SFD 7/9/2004 38 Sea.bedcQoditipo sl!rvey(if Off-$h_ore) , _ _ _ . . _ NA 39 _ CQnta_ct oamelphoneJorwee~ly prPgressreports [exp1oratpryonlyl NA - Geologic Date: Engineering Date Commissioner: Commissioner ùìCr 7/}~1- e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. **** REEL HEADER **** LDWG 05/02/02 AWS 01 **** TAPE HEADER **** LDWG 05/02/02 01 *** LIS COMMENT RECORD !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: . *** . ~eJC¡'-/G3 fÞJ36!J?- LDWG File Version 1.000 Extract File: LISTAPE.HED MWD RUN 1 1 G. SUTING D. GLADDEN MWD RUN 4 7 S. TUFTON P. WILSON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: OPEN HOLE BIT SIZE (IN) 16.000 12.250 8.500 lE-126Ll 500292321560 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 02-Feb-05 MWD RUN 2 2 S. TUFTON P. WILSON MWD RUN 7 MWD RUN 3 3 LABRECQUE D. GLADDEN MWD RUN C. WONG F. HERBERT 16 UN 10E 99.00 71.00 CASING SIZE (IN) 20.000 13.375 9.625 DRILLERS DEPTH (FT) 120.0 3795.0 7305.0 12468.0 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 18' 09.70" LONG: W149 DEG 35' 45.22" LOG MEASURED FROM D.F. AT 99.0 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: 1) Baker Hughes INTEQ run 1 utilized a directional tool with Gamma Ray to drill from 108 to 3802 feet MD (108 to 2306 feet TVD) completing the 16 inch hole section. 2) Baker Hughes INTEQ run 2 utilized an Autotrak G1.5 tool along with RNT (Reservoir Navigation Tool) Resistivity, and Gamma Ray services to drill from 3802 to 5151 feet MD (2306 to 2773 feet TVD). 3) Baker Hughes INTEQ run 3 utilized a directional tool with a Multiple Propagation Resistivity (MPR) and Gamma Ray to drill from 5151 to 5850 feet MD (2773 to 3034 feet TVD). 4) Baker Hughes INTEQ run 4 utilized an Autotrak G1.5 tool along with RNT Resistivity, and Gamma Ray to drill from 5850 to 8094 feet MD (3034 to 3606 feet TVD). This B-Sand Lateral was kicked off off the parent wellbore at 7305 feet MD. 5) Baker Hughes INTEQ run 7 utilized a Multiple Propagation Resistivity (MPR) with Annular Pressure from 7305 to 12468 (3465 to 3394 feet TVD) . REMARKS : 1) Depth of 13 3/8" Casing Shoe - Driller: 3795 feet MD (2303 feet TVD). Depth of 13 3/8" Casing Shoe - Logger: 3798 feet MD (2304 feet TVD). 2) Due to the change in Resistivity tool type on Run 3, the presentation goes from 2 curves (RPD & RPS) to 4 curves (RPD, RPM, RPS, & RPX). 3) This B-sand lateral (lE-126L1) was kicked off the parent wellbore (lE-126) through a window in the 9 5/8" casing. Top of Casing Window : 7305 feet MD (3465 feet TVD) . Bottom of Casing Window : 7321 feet MD (3469 feet TVD). 4) Due to the change in Resistivity tool type on Run 7, the presentation goes from 2 curves (RPD & RPS) to 4 curves (RPD, RPM, RPS, & RPX). 5) The interval from 12430 to 12468 feet (3396 to 3394 feet TVD) was not logged due to sensor offsets at TD. $ Tape Subfile: 1 95 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE001.HED FILE HEADER . . FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 234.0 STOP DEPTH 12468.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ BIT RUN NO 1 2 3 4 7 MERGE TOP 234.0 3752.0 5134.0 5802.0 7321. 0 MERGE BASE 3752.0 5134.0 5802.0 7321. 0 12468.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT 1e-126L1 5.xtf 150 ConocoPhillips Alaska, Inc. 1E-126Ll Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPCLM 0.0 RPM RPM RPCSLM 0.0 RPS RPS RPCHM 0.0 RPX RPX RPCSHM 0.0 ROP ROP ROPA 0.0 FET FET RPTH 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 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: 31 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 7 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAPI 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 ROP MWD 68 1 FPHR 4 4 7 FET MWD 68 1 HR 4 4 ------- 28 Total Data Records: 790 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 234.000000 12468.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 835 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILEOll.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 . log header data for each bit run in separate files. 1 .2500 START DEPTH 234.0 STOP DEPTH 3752.0 # 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) 03-AUG-04 MSB 18704 8.5 GAM MEMORY 3802.0 234.0 3752.0 o . MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL 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): # REMARKS: BIT RUN 1 (MWD Run 1). GR/Dir. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) ROPA - RATE OF PENETRATION (FPHR) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1e-126L1.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1E-126L1 FN Kuparuk River COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM ROPA 0.0 0.0 GRAM ROPA GRAM ROPA * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] . 0.0 70.8 TOOL NUMBER DHA 6437 SRIG 58017 16.000 120.0 SPUD 9.10 .0 .0 200 .0 .000 .000 .000 .000 80.0 .0 .0 .0 .00 .000 .0 o . . Number of frames per record is: 84 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 2 Curves: Name Tool Code Samples Units Size Length 1 2 GRAM MWD ROPA MWD 68 68 1 1 GAPI FPHR 4 4 4 4 ------- 8 Total Data Records: 168 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 234.000000 3752.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 241 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 log header data for each bit run in separate files. 2 .2500 START DEPTH 3752.0 STOP DEPTH 5134.0 # 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): 06-AUG-04 MSB 18704 8.5 ATK MEMORY 5151. 0 3752.0 5134.0 o . HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAV. TOOL 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): # . 67.8 70.4 TOOL NUMBER ATK 08 20067 20067 12.250 3795.0 LSND 9.25 .0 .0 200 .0 .000 .000 .000 .000 76.0 .0 .0 .0 .00 .000 .0 o BIT RUN 2 (MWD Run 2) . GR/RNT. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPA - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN le-126Ll.xtf LCC 150 CN ConocoPhìllips Alaska, I WN lE-126Ll FN Kuparuk River COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL RPCH ROPA RPTH GRAM RPCL RPCH ROPA RPTH 0.0 0.0 0.0 0.0 0.0 GRAM RPCLM RPCHM ROPA RPTHM . . * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 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: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth 10: F 5 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 ROPA MWD 68 1 FPHR 4 4 5 RPTH MWD 68 1 MINS 4 4 ------- 20 Total Data Records: 132 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 3752.000000 5134.000000 0.250000 feet **** FILE TRAILER **** Tape Sub file: 4 212 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .004 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! LDWG File Version 1.000 Extract File: FILE013.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 4 log header data for each bit run in separate files. 3 .2500 START DEPTH 5134.0 STOP DEPTH 5802.0 . # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO 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 GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY RES. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (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): # . 07-AUG-04 MSB 18704 8.5 MPR MEMORY 5850.0 5134.0 5802.0 o 66.2 70.8 TOOL NUMBER 6437 23579 58017 12.250 3031. 0 LSND 9.20 .0 .0 200 .0 .000 .000 .000 .000 90.0 .0 .0 .0 .00 .000 .0 o BIT RUN 3 (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) ROPA - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN le-126Ll.xtf LCC 150 CN ConocoPhillips Alaska, I WN lE-126Ll FN Kuparuk River COUN North Slope . . STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 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: 31 One depth per frame (value= 0) Datum Speci fication Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 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 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 ------- 28 Total Data Records: 87 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 5134.000000 5802.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 5 171 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .005 1024 . *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE014.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 5 . log header data for each bit run in separate files. 4 .2500 START DEPTH 5802.0 STOP DEPTH 7321. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO 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 RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAV. TOOL 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): # 09-AUG-04 MSB 18704 8.5 ATK MEMORY 8094.0 5802.0 7321. 0 o 68.2 80.1 TOOL NUMBER ATK 23702 2058 2058 12.250 3795.0 LSND 9.25 .0 .0 200 .0 .000 .000 .000 .000 96.0 .0 .0 .0 .00 .000 .0 o BIT RUN 2RR (MWD Run 4). GR/RNT. This B-sand lateral (lE-126L1) was kicked off the parent wellbore (lE-126) through a window in the 9 5/8" casing at 7321' MD. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) REMARKS: . . RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPA - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT le-126L1.xtf 150 ConocoPhillips Alaska, I lE-126Ll Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 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: 42 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 5 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 ROPA MWD 68 1 FPHR 4 4 5 RPTH MWD 68 1 MINS 4 4 ------- 20 Total Data Records: 145 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 5802.000000 7321.000000 0.250000 feet **** FILE TRAILER **** . Tape Subfile: 6 228 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .006 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! ! ! ! !! ! ! ! ! ! ! !! ! ! !! Extract File: FILEOI5.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 6 . log header data for each bit run in separate files. 7 .2500 START DEPTH 7321. 0 STOP DEPTH 12468.0 # 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 MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY RES. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL 20-AUG-04 MSB 18704 6.75 MPR MEMORY 12468.0 7321. 0 12468.0 o 77.5 93.3 TOOL NUMBER 6289 6010 6010 8.500 7321. 0 Oil Based 9.05 .0 .0 33000 .0 .000 .000 .000 .000 130.0 .0 .0 .0 . . MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 6 (MWD Run 7). 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) ROPA - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT le-126Ll.xtf 150 ConocoPhillips Alaska, I lE-126Ll Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 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: 31 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 7 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 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 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 ------- 28 Total Data Records: 665 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7321.000000 12468.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 7 749 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 05/02/02 01 **** REEL TRAILER **** LDWG 05/02/02 AWS 01 Tape Subtile: 8 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes