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212-083
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): Colville River / Alpine Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14120 3587 none None Casing Collapse Structural Conductor Surface 3180 Intermediate 1 3090 Intermediate 2 5410 Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Abby Warren Contact Email: Contact Phone:907-240-9293 Authorized Title: Drilling Engineer Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Tubing Grade: Tubing MD (ft): Packer:10722' MD/6813' TVD SSSV:2118' MD / 1997' TVD Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL025538 / ADL025558, ADL0025559 212-083 P.O. Box 100360, Anchorage, AK 99510 50-103-20659-00-00 ConocoPhillips Alaska Inc CRU CD1-47NA Length Size L80 TVD Burst 11056 7240 MD 5750 5830 114' 2327.5' 6828' 114' 2670' 69837" 9-5/8" 11413' Perforation Depth MD (ft): 10756' 20" 11-3/4" 80' 6974 abby.warren@conocophillips.com 10960-10974 Perf Pups: 11792-14067 807 4.5" 6894-6898 Perf Pups: 6981-6976' 1/20/2026 14090'2827 4-1/2" x 3-1/2" 6974 Packer: Baker Premier Packer SSSV: TRMAXX-5E SSV (flipper locked out/hydraulic sleeve open) 8233' 2630' approval: Notify AOGCC so that a representative may witness Sundry Number: BOP Test Mechanical Integrity Test Location Clearance ection MIT Req'd? Yes No ption Required? Yes No Subsequent Form Required: AOGCC USE ONLY Contact Name: Abby Warren Contact Email: Contact Phone:907-240-9293 e: Drilling Engineer certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. me and re with Date:abby.warren@conocophillips.com 15. Well Status after proposed work: OIL WINJ W DSPL Suspended GAS WAG GSTOR SPLUG GINJ Op Shutdown Abandoned proval: Date: esentative: Date for Operations: 13. Well Class after proposed work: Exploratory Stratigraphic Development Service nts: Proposal Summary Wellbore schematic ations Program BOP Sketch SSV Type: Packers and SSSV MD (ft) and TVD (ft):Packer:10722' MD/6813' TVD SSSV:2118' MD / 1997' TVDSSSV: TRMAXX-5E SSV (flipper locked out/hydraulic sleeve open) Tubing MD (ft): 11056 Tubing Grade: L80 Tubing Size: 4-1/2" x 3-1/2" Perforation Depth TVD (ft): 6894-6898 Perf Pups: 6981-6976' pth MD (ft): 2-14067 697414090'4.5"2827 54107240698311413'7"807te2 309057506828'10756'9-5/8"te 1 8233' 318058302327.5'2670'11-3/4"e 2630' 114'114'20"80'or al CollapseBurstTVDMDSizeLength Junk (MD): None Plugs (MD): none MPSP (psi): 3587 Effective Depth TVD:Effective Depth MD:Total Depth TVD (ft): 6974 D (ft): PRESENT WELL CONDITION SUMMARY 10. Field/Pool(s): Colville River / Alpine Pool signation (Lease Number): ADL025558, ADL0025559 8. Well Name and Number: CRU CD1-47 g: tion or Conservation Order governs well spacing in this pool? perforations require a spacing exception?Yes No NA 5. Permit to Drill Number: 6. API Number: 212-083 50-103-20659-00-00 4.Current Well Class: Exploratory Development Stratigraphic Service 360, Anchorage, AK 99510 ame: s Alaska Inc quest: Abandon Plug Perforations Fracture Stimulate Reppair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp W ell Alter Cas Other: _r Casing __________________ __ Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. 326-029 By Grace Christianson at 1:59 pm, Jan 14, 20262:00 pm, Jan 14, 2026 TS 1/15/26 DSR-1/16/26 10-404 VTL 1/22/2026 Initial BOP test to 5000 psig; Subsequent BOP test to 4200 psig. Provide CBL and interpretation to AOGCC prior to proceeding on 9-5/8" and 11-3/4" casing. 2 week BOP testing frequency on this sundry. JLC 1/22/2026 01/22/26 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 14th, 2025 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Application: Change approved program for CD1-47 (Sundry 325-763) Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a change to the approved program for CD1-47. The request is to go to a14 day BOPE test interval while under the approved sundry 325-763. Doyon 142 strongly supports the CPAI BOPE between well maintenance program and over the last year has had 26 full BOP tests with 20 passing tests for a 77% first time pass rate. There were 28 component failures over 754 components tested in these 26 tests equating to a 96% overall BOPE equipment effectiveness during BOPE testing in 2025. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-403 If you have any questions or require further information, please contact Abby Warren at 907-240-9293 (abby.warren@conocophillips.com) Sincerely, cc: CD1-47 Well File / Jenna Taylor ATO 1804 Will Earhart ATO 1552 Abby Warren Justin Cremer ATO 1548 Drilling Engineer Sarah Frey ATO 1778 C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\0O55OAKD\2026-01-14_23106_CRU_CD1-47_CoilFlag_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23106 CRU CD1-47 50-103-20659-00 Coil Flag 14-Jan-26 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 212-083 T41250 1/15/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.15 15:16:28 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): Colville River / Alpine Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14090 3587 none None Casing Collapse Structural Conductor Surface 3180 Intermediate 1 3090 Intermediate 2 5410 Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Abby Warren Contact Email: Contact Phone:907-240-9293 Authorized Title: Drilling Engineer Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 6974 abby.warren@conocophillips.com 10960-10974 Perf Pups: 11792-14067 807 4.5" 6894-6898 Perf Pups: 6981-6976' 1/20/2026 14090'2827 4-1/2" x 3-1/2" 6974 Packer: Baker Premier Packer SSSV: TRMAXX-5E SSV (flipper locked out/hydraulic sleeve open) 8233' 2630' Perforation Depth MD (ft): 10756' 20" 11-3/4" 80' 6828' 114' 2670' 69837" 9-5/8" 11413' Length Size L80 TVD Burst 11056 7240 MD 5750 5830 114' 2327.5' PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL025538 / ADL025558, ADL0025559 212-083 P.O. Box 100360, Anchorage, AK 99510 50-103-20659-00-00 ConocoPhillips Alaska Inc CRU CD1-47NA Tubing Grade: Tubing MD (ft): Packer:10722' MD/6813' TVD SSSV:2118' MD / 1997' TVD Perforation Depth TVD (ft): Tubing Size: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY P 2 6 5 6 t _ Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. 325-763 By Grace Christianson at 12:45 pm, Dec 16, 2025 10-407 X 14,120 CDW 12/24/2025 Initial BOP test to 5000 psig; Subsequent BOP test to 4200 psig. SFD 12/31/2025 DSR-12/19/25 SFD X Provide CBL and interpretation to AOGCC prior to proceeding X on 9-5/8" and 11-3/4" casing. VTL 1/2/2026 01/02/26 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 December 16th, 2025 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Application: Plug for Redrill for CD1-47 (PTD 212-083) Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to re-enter the CD1-47 well with the intention pull the upper completion, provide isolation to the C10, mill the existing 9-5/8 x 11-3/4 packer, pull ~400 of the existing 9-5/8 casing and pump a cement kick off plug. Future drilling operations include kicking off the cement plug, drilling and lining intermediate 1 & 2. Drill through the Sag and Ivishak and run the production liner. This will be a class 1 disposal well. The predicted start date for the re-entry and plug setting operations is 1/20/2026. Doyon Rig 142 will perform the work. The sidetrack and drilling procedure will be covered in a separate Application for a Permit to Drill for CD1-47A. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-403 2. A proposed re-entry and abandonment program 3. CD1-47 current schematic 4. CD1-47 set up for sidetrack schematic Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Abby Warren at 907-240-9293 (abby.warren@conocophillips.com) Sincerely, cc: CD1-47 Well File / Jenna Taylor ATO 1804 Will Earhart ATO 1552 Abby Warren Justin Cremer ATO 1548 Drilling Engineer Sarah Frey ATO 1778 g p g, g This will be a class 1 disposal well CRU CD1-47 AOGCC Sundry Saved: 16-Dec-25 Sundry, Well CRU CD1-47 Page 1 of 5 Printed: 16-Dec-25 CRU CD1-47 PTD# 212-083 Application for Sundry Approval Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) .............................................................. 2 2. Overview ..................................................................................................................... 2 3. Planned Operations ...................................................................................................... 2 4. BOPE Information ........................................................................................................ 2 5. Casing and Cementing In Place ...................................................................................... 3 6. Abandonment Cement ................................................................................................. 3 7. Discussion of Mud and Cuttings Disposal ....................................................................... 3 8. Schematics .................................................................................................................. 4 CRU CD1-47 AOGCC Sundry Saved: 16-Dec-25 Sundry, Well CRU CD1-47 Page 2 of 5 Printed: 16-Dec-25 1.Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted for is CRU CD1-47. 2.Overview The CD1-47 well was drilled and completed in November 2012 as an Alpine C Sand Producer. Perforations in the Kuparuk C were later added. A sundry was submitted for the pre-rig abandonment and a application to drill will be submitted for the subsequent sidetrack, kick off point will be directly below the surface casing shoe. 3.Planned Operations 1. MIRU Doyon 142. 2. Pull BPV. 3. Displace out diesel freeze protect with kill weight fluid through tree, taking returns to tiger tank. 4. Observe well for flow to confirm well is dead 5. Set and test BPV 6. Nipple down production tree. 7. Nipple up BOPE and test to 250/5000 psi. Test Annular to 250/2500 psi 8. Remove BPV. 9. Pull 4-1/2 x 3-1/2 tubing (pre-cut at ~10,600 MD). 10. RU and Pull the 7 production casing from tieback located at 10,566MD 11. RU Eline and perform USIT on 9-5/8 casing and 11-3/4 casing 12. Set plug ~50 MD below the C10/Halo and pressure test to 2500 psi 13. RIH with perf guns and perforate from 3863-4000 MD 14. RIH with cement stinger, and pump a 41 bbl balanced plug, pull above plug and perform a ~5-7 bbl squeeze to isolate the Halo, POOH 15. Perform a tag and test of the cement to 2500 psi 16. Set plug at ~400 below the surface casing shoe test to 2500 psi 17. Cut off existing wellhead and replace with StreamFlo wellhead 18. RIH with packer mill, mill 9-5/8x11-3/4 liner top packer. RIH with spear and back off extension. RIH and mill slips. POOH 19. RIH with multistring casing cutter; perform cut 400 below the surface casing shoe 20. PU a spear and run in to retrieve 9-5/8 casing 21. PU cement stinger and run in to set balanced. Pump a 16.0 ppg balanced plug into the surface casing. 22. Ready to move into drilling phase under new PTD. 4.BOPE Information Please reference BOPE schematics on file for Doyon 142 Provide log and interpretation to AOGCC prior to proceeding Qannik / K3 isolation contingency? SFD VTL perform USIT on 9-5/8 casing and 11-3/4 casing VTLState witness required. VTL State witness required. CRU CD1-47 AOGCC Sundry Saved: 16-Dec-25 Sundry, Well CRU CD1-47 Page 3 of 5 Printed: 16-Dec-25 5.Casing and Cementing In Place Casing and Cement in Place OD Hole Size Depth (MD) Weight Grade Connection Cement Program 20" 42" 114 65.5 H40 Welded 11-3/4" 2673' 60 L80 BTC 312bbls of 10.7 lead, 53.9 bbls of 15.8 tail 9-5/8" 11-3/4" 10756' 40 L80 H521 288 bbls of 12.2ppg lead, 85 bbls of 15.8ppg tail 7" 8.5" 11413' 26 L80 TenarisBlue 48.6 bbls of 15.8 tail 4-1/2" 6" 14090' 12.6 L80 H563/SLHT/ IBT-m - The 9-5/8 cement top for the CD1-47A well was originally planned to cover the Qannik. The cement reports do not mention losses during the job, as such cement top is expected above the Qannik but not covering the C10 (Halo). A cement evaluation log will be run to determine sufficient top of cement and inform for the rig C10 abandonment. 6.Abandonment Cement The CD1-47A abandonment will be done with the rig. A plug will be set ~50 below the base of the Halo, the plan is to then perforate the entire section of Halo + 50 above the zone. A balanced 15.8 ppg cement plug will be set from the mechanical plug, through the perforations and 200 above the perforations. Pressure will be applied to squeeze cement into the annulus through the perforations and leave 200 of cement in the 9-5/8 above the Halo. Cementing Calculations Halo Abandonment Total Volume = 41 bbls => 199 sx of 15.8 Class G + Add's + Add's @ 1.16 ft³/sk 7.Discussion of Mud and Cuttings Disposal Waste fluids and cuttings generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well at the 1B Facility. If needed, excess cuttings generated will be hauled to Milne Point or Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. Qannik / K3 isolation contingency? SFD From Well History File 212-083, p. 90 SFD cement top is expected above the Qannik 266 bbls SFD CRU CD1-47 AOGCC Sundry Saved: 16-Dec-25 Sundry, Well CRU CD1-47 Page 4 of 5 Printed: 16-Dec-25 8.Schematics Current Schematic CRU CD1-47 AOGCC Sundry Saved: 16-Dec-25 Sundry, Well CRU CD1-47 Page 5 of 5 Printed: 16-Dec-25 Abandonment Schematic Upper Completion: MD TVD 1) 4-½ 12.6#/ft IBT-M Tubing (2 jts) XO to 3-½ EUE tubing 2) 3-½ TRMAXX-5E SSSV 2110' 2000' 2.812 X Profile (5.176" OD) 3) 3-½ x 1" Camco KBMG GLM (42°) w/ DV 4555' 3400' 4) 3-½ x 1" Camco KBMG GLM (56°) w/ DV 8506' 5600' 5) 3-½ x 1 Camco KBMG GLM (58°) w/DCK2 10487' 6700' pinned for 2500 psi casing to tbg shear 6) SLB BHP Gauge, Encapsulated I-Wire 10881' 68xx' w/cannon clamps on every joint 7) Baker Premier Packer 3.5" x 7" 10,897 689x 8) 3-½ x 1 Camco KBMG GLM 10951' 69xx' 9) 4.09" Blast rings (30') with retaining rings and spring pack on 3-½ Hyd 563 joint 10953' 6892' 10) Baker CMD sliding sleeve 10997' 6912' 11) HES X nipple 2.813" ID 11010' 6813' 12) Baker 3-½ Bullet Tieback Seal Assembly 11011' 6813' (effective stroke = 18') Lower Completion: 13) Baker 5" x 7" ZXP Liner Top Packer 11015' 6814' XO Hydril 521 Box X Hydril 563 Box Flexlock Liner Hanger Baker 80-20 20' Seal Bore Extention XO 5" Hydril 563 Box X 4-½ TSH-563 pin 14) Freecap Swell packer Hyd 563 11502' 7005' 15) Freecap Swell Packer Hyd 563 11553' 7006 16) Pup Joint XO, 10', 4-½ 12.6#/ft L-80 11603' 6935' Hyd 563 Box X IBT-M Pin 17) 4 ½, 12.6#/ft, L-80 IBT-M Liner w/pre-perf TD pups (5') every 325' and 4 ½ IBT-M Orange Peel Shoe 7" 26# L-80 Tenaris Blue Liner to 11410' MD / 6998' TVD 16" 65# H-40 Welded Conductor to 114' 6 Hole, TD 3-1/2" 9.3# L-80 EUE 9 8 7 1 5 CD1-47 Pre Rig Abandonment Well Plan WP10 Proposed Schematic updated 12/17/2025 GL 11-3/4" 60# L-80 BTC Surface Casing 2670' MD / 2324' TVD @ 56° cemented to surface DB 14 9 5/8" 40# L-80 Hydril 521 Liner to 10753' MD / 6825' TVD Planned TOC in 9 5/8 ~ 5187' ft MD 7" x 9 5/8" Liner Top Packer @ 10566' MD / 6738' TVD Top Kuparuk C 10960' MD / 6890' TVD 2 3 4 6 All depths are Doyon 19 RKB. 4-½ 12.6# L-80 Liner Hydril 563 from liner hanger through swell packers, SLHT/IBT-M to TD 10 11 12 GL GL ~325' 13 Top Alpine C 11353' MD / 6990' TVD 15 16 18 17 Qannik 5687' MD/4031' TVD Halo 3912' MD/3031' TVD ~10,600 Pre-Rig Cut 3-½ Tubing From:Warren, Abby To:Loepp, Victoria T (OGC) Cc:Dewhurst, Andrew D (OGC); Wallace, Chris D (OGC); Davies, Stephen F (OGC); Earhart, Will C Subject:FW: [EXTERNAL]RE: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Plug for Redrill Questions Date:Monday, December 29, 2025 12:04:41 PM Attachments:image001.png image002.png Hi Victoria Please see answers in red to your questions with previous emails as well, let me know if you need further clarification on anything. Thanks Abby From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Friday, December 26, 2025 11:49 AM To: Warren, Abby <Abby.Warren@conocophillips.com>; Drake, Steve G <Steve.G.Drake@conocophillips.com>; Earhart, Will C <William.C.Earhart@conocophillips.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL]RE: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Plug for Redrill Questions Sorry about the multiple emails with questions/comments. As I review the sundry and PTD, I run across additional information. What type of CBL will you be running to evaluate the Int 1 and Int 2 cementing? We will be running an ultrasonic log. Base plan is the SLB IBC/USIT, pending unit availability but will pivot to another ultrasonic if we need to. Please provide kick tolerance calculations for the surface casing at kick off point and the Int 1. See Below Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Loepp, Victoria T (OGC) Sent: Friday, December 26, 2025 11:09 AM To: 'Warren, Abby' <Abby.Warren@conocophillips.com>; 'Drake, Steve G' <Steve.G.Drake@conocophillips.com>; 'Earhart, Will C' <william.c.earhart@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL]RE: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Plug for Redrill Questions The CD1-47A PTD requests a variance for the packer depth of greater that 200 above the top of the perforations. Please provide an approximate depth or range of depths for the packer placement. The approximate setting depth is 9,983-10,033 MD, this is based on the current INT2 shoe depth of 10,223 MD and a liner lap for the production liner of 150-200 placing the packer in the confining zone. The well will first be perforated in the Ivishak and the injection plan would be to then move up in formation over the life of the well with the Sag being the last to be perfd. Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Loepp, Victoria T (OGC) Sent: Friday, December 26, 2025 10:45 AM To: 'Warren, Abby' <Abby.Warren@conocophillips.com>; 'Drake, Steve G' <Steve.G.Drake@conocophillips.com>; Earhart, Will C <william.c.earhart@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL]RE: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Plug for Redrill Questions Another comment: The MPSP for the rig work prior to drilling the sidetrack is 3587 psi and during the drilling the sidetrack the MPSP is 3947 psi. The BOP test pressure of 4000 psi is not adequate. A BOP test pressure of 4200 psi for all the rig work is proposed. This is after the initial BOP test pressure of 5000 psi. Please comment. Thank you for catching that. I support 4200psi, that is most prudent Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Loepp, Victoria T (OGC) Sent: Friday, December 26, 2025 9:50 AM To: 'Warren, Abby' <Abby.Warren@conocophillips.com>; Drake, Steve G <Steve.G.Drake@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL]RE: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Plug for Redrill Questions CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Abby, Since the cement top behind the 9-5/8 liner was determined by calculation, it is uncertain that the Qannik has cement coverage until the cement log is run. Please provide information on the Qannik formation in this well and contingency plans for cementing if the TOC is below the Qannik. The Qannik reservoir is present and does look like it has reservoir quality. However, in this area the pay is primarily found in the gas cap (GOC is -4002 TVDSS) for the Qannik reservoir. Logs show that we are still in quality pay but far from the existing development, and closer to the reservoir edge. In the event we find the Qannik is not adequately isolated, we will employ the same remedial cementing concept as planned for the Halo. We have sourced enough 7 perforating guns to support this contingency Until the cement log is run, it is uncertain what is behind pipe at the Halo. If a balance plug is unsuccessful, are there contingency plans? CPAI is sourcing adequate perforating guns to repeat the perf-squeeze of the Halo and/or Qannik if necessary. We are also sourcing equipment to support section milling of the 9-5/8 casing if operationally required. What flow area per foot of perfs does the Gator provide versus the 7 guns at 15 SPF? The intended 7 TCP perf guns will produce 23.67 in2 TFA. The Gator tool would provide ~11.8 in2 of TFA per spec sheet Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Warren, Abby <Abby.Warren@conocophillips.com> Sent: Thursday, December 18, 2025 10:59 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Drake, Steve G <Steve.G.Drake@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL]RE: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Plug for Redrill Questions Victoria Yes, we will be running a USIT (step #11) to evaluate the cement behind pipe on the 9-5/8 liner. The original top of cement was estimated by cement calcs, as no log was run. Top of Halo is 3913 MD/ 3034 TVD and the bottom is 4000 MD / 3081 TVD. It is poorly developed in this area and is most likely a cemented stringer. The likelihood of cutting and pulling from 400 is decent, if we cannot pull from 400 the contingency would be to move up hole and recut. This is how most of our sidetracks below surface casings are performed and Conoco has a high success rate at it with multiple cuts. Current cement calc with pulling the casing 400 below SC and pumping the cement to 200 inside casing would be ~64 bbls of 16.0 ppg cement. In terms of the Gator perforator, we plan to run ~150 of 7 guns with 15spf. Flow area should be more than sufficient to get a proper squeeze to achieve isolation of the Halo. Pipe should be free in that area, as such Conoco does not believe there is any added benefit to perf and wash. I have attached the prerig abandonment Schematic. One thing to note on the sundry, is that section 7 for Discussion of Mud and Cuttings Disposal should read - Incidental fluids developed from drilling operations on well CD1-47A will be injected into the Class 1 disposal well on CD1. Please let me know if you have any questions. Thanks Abby From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Wednesday, December 17, 2025 12:01 PM To: Warren, Abby <Abby.Warren@conocophillips.com>; Drake, Steve G <Steve.G.Drake@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL]RE: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Plug for Redrill Questions CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Abby, Is a CBL planned to verify the TOC above the Qannik? How was the TOC estimated? Please provide log if logged. Please provide top/bottom of Halo. Please provide information on Halo development in this well. Have you considered Gator perforations across the Halo and potential perf and wash before cementing? How likely is it that the 9-5/8 casing can be cut and pulled from ~400 below the SC shoe? I dont see any cement calculations or height of cement on the SC shoe cement plug. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 _____________________________________________ From: Loepp, Victoria T (OGC) Sent: Wednesday, December 17, 2025 11:24 AM To: Abby.Warren@conocophillips.com; Drake, Steve G <steve.g.drake@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Abby & Steve, Please include in both sundries the well bore schematic post reservoir abandonment and pre-rig. You can email that to me. I would like the schematic modified from the 325-763 sundry. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Earhart, Will C To:Davies, Stephen F (OGC); Warren, Abby Cc:Dewhurst, Andrew D (OGC); Starns, Ted C (OGC); Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]FW: CRU CD 1-47 (PTD 212-083, Sundry 325-763) - Question Date:Monday, December 29, 2025 10:50:09 AM Attachments:image001.png Steve- consulting with the GGRE team, there is no further description on the Halo beyond the view of thin and likely cemented. Abby will be replying to Victorias other comments momentarily Thanks Will Will Earhart | Drilling Engineering Supv | ConocoPhillips Alaska O: 907.265.1077 | M: 540.448.1789 | 700 G Street, Anchorage, AK From: Earhart, Will C Sent: Wednesday, December 24, 2025 9:25 AM To: 'Davies, Stephen F (OGC)' <steve.davies@alaska.gov>; Warren, Abby <Abby.Warren@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Starns, Ted C (OGC) <ted.starns@alaska.gov> Subject: RE: [EXTERNAL]FW: CRU CD 1-47 (PTD 212-083, Sundry 325-763) - Question Steve- Attached is Abbys response to Victoria last week on a similar question for consistency. As noted, it is suspected that the Halo is a cemented stringer/ very poorly developed at this penetration We are continuing to use the thin bed models as developed during the prior CD1 gas event to ensure an overly conservative view on pay potential Apologies, weve got a thin crowd in the office today. Im reaching out for some better descriptors and will circle back to better answer your question if Ive missed anything Will Earhart | Drilling Engineering Supv | ConocoPhillips Alaska O: 907.265.1077 | M: 540.448.1789 | 700 G Street, Anchorage, AK From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Wednesday, December 24, 2025 8:34 AM To: Earhart, Will C <William.C.Earhart@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Starns, Ted C (OGC) <ted.starns@alaska.gov> Subject: [EXTERNAL]FW: CRU CD 1-47 (PTD 212-083, Sundry 325-763) - Question CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hello Will, Abby is out of the office, and she has indicated that I should forward the following question to you regarding CPAI's Sundry Application. Could CPAI please provide the measured depth for the base of the Halo in CRU CD1-47 and the reasoning behind selecting that specific depth? Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov From: Davies, Stephen F (OGC) Sent: Wednesday, December 24, 2025 8:25 AM To: Warren, Abby <abby.warren@conocophillips.com> Cc: Starns, Ted C (OGC) <ted.starns@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: CRU CD 1-47 (PTD 212-083, Sundry 325-763) - Question Hello Abby, CPAI's Sundry Application states in part: For clarity, could CPAI please provide the measured depth for the base of the Halo and the reason for selecting that depth? Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov 1 Dewhurst, Andrew D (OGC) From:Dewhurst, Andrew D (OGC) Sent:Thursday, 18 December, 2025 16:42 To:'Drake, Steve G'; Loepp, Victoria T (OGC) Cc:Roby, David S (OGC); Warren, Abby Subject:RE: [EXTERNAL]CRU CD1-47 Sundry (325-744): Question Steve, OK, this makes more sense. You are breaking the plug-for-redrill into two separate sundries. I understand now why this rst one was submitted as a reservoir abandonment. I will change it back to that. I will also attach the pre-rig schematic provided by Abby to this sundry. My questions about TOC, KOP, and Halo are addressed in the separate plug-for-redrill sundry 325-763 that we received from Abby. No further questions from me. Thanks, Andy From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Thursday, 18 December, 2025 13:04 To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Warren, Abby <Abby.Warren@conocophillips.com> Subject: RE: [EXTERNAL]CRU CD1-47 Sundry (325-744): Question Victoria/Andy, I held o a little bit on getting back to your questions knowing that Abby would be submitting her paperwork for the redrill with accompanying schematics. It looks like her latest email, earlier today, addresses the post well work/pre rig drilling schematic. The formations are also listed on there as per Andys request. Wanted to touch base with you to make sure all your questions have been answered or if there is something Im still missing that you need from me? Thanks, Steve From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Thursday, December 11, 2025 12:40 PM To: Drake, Steve G <Steve.G.Drake@conocophillips.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Warren, Abby <Abby.Warren@conocophillips.com> Subject: RE: [EXTERNAL]CRU CD1-47 Sundry (325-744): Question Steve, 2 Please provide a current schema c with all cemen ng as well as a post work schema c. If you can get a schema c of the sidetrack, that would be useful. The 10-401 for the sidetrack begins when the window is milled and drilling begins so generally on a plug for redrill sundry, the rig BOP test pressure is listed. Also show all HC forma on depths. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Wednesday, December 10, 2025 12:19 PM To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL]CRU CD1-47 Sundry (325-744): Question Hi Andy, Thanks for the quick response! To address your questions: Yes, we are preparing to redrill this well as it will be our new disposal well in Alpine. Old well name: CD1-47. New well name: CD1-47A. Its on our rig schedule to have the rig move over it on or around January 25, 2026. Abby Warren is the drilling engineer for the work. Just talked to her and she plans on submitting her sundry/permit shortly. That should have the planned KOP you are requesting as well as the TOC for the 9 5/8. With regards to this sundry, I guess box 1 would be more accurate if the Plug for Redrill was checked rather than the Other: Reservoir Abandon box. Also, I think you are referring to Box 15 for the well status after proposed work. I feel like with the upcoming redrill the oil and abandoned boxes are the ones we need checked? Wouldnt suspended indicate some sort of future utility of the reservoir in that well? Happy to go back and forth a little more on that one. Just want it to be the right one so that it doesnt show up in the future as a suspension that might be to be addressed. Please let me know if you have any other questions. Thanks! Steve From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Wednesday, December 10, 2025 11:47 AM To: Drake, Steve G <Steve.G.Drake@conocophillips.com> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: [EXTERNAL]CRU CD1-47 Sundry (325-744): Question CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 3 Steve, Im looking at the CRU CD1-47 reservoir abandonment sundry. It looks like you are preparing to redrill it. We have a speci c request type on 403 for Plug for Redrill. Its basically the same as a reservoir abandonment, just with the explicit intention of not returning to the wellbore. This would change Box 13 (well status after proposed work) to Suspended. Would you please con rm that this meets your intention? If so, Ill handle the change. Also, what is the planned KOP for the upcoming redrill and where is it with respect to the TOC for the 9-5/8? Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Warren, Abby To:Loepp, Victoria T (OGC); Drake, Steve G Cc:Dewhurst, Andrew D (OGC) Subject:RE: [EXTERNAL]RE: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Plug for Redrill Questions Date:Thursday, December 18, 2025 10:59:09 AM Attachments:CD1-47 Pre Rig Abandonment.pdf Victoria Yes, we will be running a USIT (step #11) to evaluate the cement behind pipe on the 9-5/8 liner. The original top of cement was estimated by cement calcs, as no log was run. Top of Halo is 3913 MD/ 3034 TVD and the bottom is 4000 MD / 3081 TVD. It is poorly developed in this area and is most likely a cemented stringer. The likelihood of cutting and pulling from 400 is decent, if we cannot pull from 400 the contingency would be to move up hole and recut. This is how most of our sidetracks below surface casings are performed and Conoco has a high success rate at it with multiple cuts. Current cement calc with pulling the casing 400 below SC and pumping the cement to 200 inside casing would be ~64 bbls of 16.0 ppg cement. In terms of the Gator perforator, we plan to run ~150 of 7 guns with 15spf. Flow area should be more than sufficient to get a proper squeeze to achieve isolation of the Halo. Pipe should be free in that area, as such Conoco does not believe there is any added benefit to perf and wash. I have attached the prerig abandonment Schematic. One thing to note on the sundry, is that section 7 for Discussion of Mud and Cuttings Disposal should read - Incidental fluids developed from drilling operations on well CD1-47A will be injected into the Class 1 disposal well on CD1. Please let me know if you have any questions. Thanks Abby From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Wednesday, December 17, 2025 12:01 PM To: Warren, Abby <Abby.Warren@conocophillips.com>; Drake, Steve G <Steve.G.Drake@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL]RE: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Plug for Redrill Questions CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Abby, Is a CBL planned to verify the TOC above the Qannik? How was the TOC estimated? Please provide log if logged. Please provide top/bottom of Halo. Please provide information on Halo development in this well. Have you considered Gator perforations across the Halo and potential perf and wash before cementing? How likely is it that the 9-5/8 casing can be cut and pulled from ~400 below the SC shoe? I dont see any cement calculations or height of cement on the SC shoe cement plug. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 _____________________________________________ From: Loepp, Victoria T (OGC) Sent: Wednesday, December 17, 2025 11:24 AM To: Abby.Warren@conocophillips.com; Drake, Steve G <steve.g.drake@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Abby & Steve, Please include in both sundries the well bore schematic post reservoir abandonment and pre-rig. You can email that to me. I would like the schematic modified from the 325-763 sundry. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the Abandon box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer 325-763 SFD 12/23/2025 CRU CD1-47 212-083 SFD 12/23/2025 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Reservoir Abandon 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 14120' None Casing Collapse Conductor Surface Intermediate #1 Intermediate #2 TieBack Intermediate #2 Lower Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 12/18/2025 14090'3073' 4-1/2" x 3-1/2" 6975' Packer: Baker Premier Packer Packer: HRD LT ZXP Packer SSSV: TRMAXX-5E SSSV (flipper locked out/ hydraulic sleeve open) Perforation Depth MD (ft): L-80 10329' 8260' 10363' 10960-10974' Perf Pups: 11792-14067' 1060' 4-1/2" 6894-6898' Perf Pups: 6981-6976' 7" Perforation Depth TVD (ft): 2670' 10753' 6983'11410' 78' 16" 11-3/4" 9-5/8" 2634' 7" 11056' MD 2325' 6825' 6645' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: 114' 114' PRESENT WELL CONDITION SUMMARY Alpine Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025538, ADL0025558, ADL0025559 212-083 P.O. Box 100360, Anchorage, AK 99510 50-103-20659-00-00 Colville River Field Alpine Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 10722' MD and 6813' TVD 11017' MD and 6909' TVD 2118' MD and 1997' TVD Steve Drake Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Steve.G.Drake@conocophillips.com (907) 263-4062 Senior Well Interventions Engineer CRU CD1-47 6974' 10655' 6786' 10655', 11118' (milled) CO 735 approval: Notify AOGCC so that a representative may witness Sundry Number: BOP Test Mechanical Integrity Test Location Clearance ons of Approval: ection MIT Req'd? Yes No Subsequent Form Required: Suspension Expiration Date: AOGCC USE ONLY Contact Name: Contact Email: Contact Phone: e: Steve Drake certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. me and ure with Date:Steve.G.Drake@conocophillips.com (907)263-4062 Senior Well Interventions Engineer quest: Abandon Plug Perforations Fracture Stimulate Reppair Well Operations shutdown Suspend Perforate Other Stimulate Pulll Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alteer Casing Other: Reservoir Abandon ame:4.Current Well Class:5. Permit to Drill Number: Exploratory Development Stratigraphic Service 6. API Number: g:8. Well Name and Number: ation or Conservation Order governs well spacing in this pool? Yes No esignation (Lease Number):10. Field: D (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD:Junk (MD): None g Collapse or e e #1 e #2 k e #2 SSSV Type:Packers and SSSV MD (ft) and TVD (ft): nts: Proposal Summary Wellbore schematic 13. Well Class after proposed work: ations Program BOP Sketch Exploratory Stratigraphic Development Service Date for 15. Well Status after proposed work: Operations:OIL WINJ WDSPL Suspended proval:Date:GAS WAG GSTOR SPLUG esentative: GINJ Op Shutdown Abandoned 12/18/2025 14090'3073' 4-1/2" x 3-1/2" 6975' Packer: Baker Premier Packer Packer: HRD LT ZXP Packer SSSV: TRMAXX-5E SSSV (flipper locked out/ hydraulic sleeve open) pth MD (ft): L-80 10329' 8260' 10363' 792-14067' 1060' 4-1/2" 6894-6898' Perf Pups: 6981-6976' 7" Perforation Depth TVD (ft): 2670' 10753' 6983'11410' 78'16" 11-3/4" 9-5/8" 2634' 7" 11056' MD 2325' 6825' 6645' s Alaska, Inc. Length Size Proposed Pools: 114'114' PRESENT WELL CONDITION SUMMARY Alpine Oil Pool TVD Burst 38, ADL0025558, ADL0025559 212-083 360, Anchorage, AK 99510 50-103-20659-00-00 Colville River Field Alpine Oil Pool Tubing Grade: Tubing MD (ft): 10722' MD and 6813' TVD 11017'MD and 6909' TVD 2118' MD and 1997' TVD quire a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): Tubing Size: CRU CD1-47 6974'10655'6786'10655', 11118'(milled) CO 735 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-744 By Grace Christianson at 7:51 am, Dec 08, 2025 VTL 12/23/2025 DSR-12/8/25 10-407 A.Dewhurst 18DEC25 A.Dewhurst 18DEC25 X 12/23/25 CD1-47 - Pre Rig Reservoir Abandonment Intervention Work Date Published: 12/04/2025 Version: 1 Procedural Information Written By:Steve Drake Job Scope:Drilling Support Date of Request:09/24/2025 WV Primary Job Type:Support Other Operations Budget Category:Capital WV Secondary Job Type:Abandonment WBS Element:WNS.00003.E.W047.WI.SU.A NOB:1000.0 BOPD Network:50067107 Job Duration:6-Days Functional Area:AK_WS_WELLWORK Risked NOB/Day:166 BOPD/Day Shut-in Code:--Network Description:CD1-47 Support Other Ops Well Information Well Type:Producer Last SBHP:4,288 psi 70° or Max Inc Depth:70° @ 10,851' MD Last SBHP Datum:7,000 SS Max Dogleg:6° @ 1,135' MD Last Tag:10652' MD Min ID:2.812"WH Category:None Found H2S:--Extra Space:Extra Space Background Information CD1-47 is a single leg Alpine producer that was drilled and completed in January of 2013. This well has been identified as the sidetrack/redrill candidate for the new disposal well at WNS. This WWR will outline the steps necessary to prepare the well for the arrival of D142 in January of 2026. Risks / Job Concerns Min ID of 2.812" @ 2,118' RKB TRMAX SSSV X profile (locked out) 4.5" to 3.5" XO @ 114' RKB Baker CMD sleeve CLOSED @ 10,803' RKB Version Notes V1: GWWR to P&A reservoir on CD1-47 with coil drakesg Phase 1: SL Dummy GLD/Pull RBP/SBHP (None) WSC Reviewed: No MIRU SL and associated equipment.1. MU and RIH with drift assembly for 2.72" RBP set @ 10,659' RKB. Note: SL has had issues drifting past the SSSV on previous jobs. 2. Pull GLVs @ 4,534' and 8,510' RKB.3. Set DMYs @ 4,534' and 8,510' RKB.4. Draw down IA to ensure GLVs are holding.5. Pull catcher @ 10,652' RKB.6. Pull RBP @ 10,659' RKB.7. MU and RIH with dual gauges for SBHP.8. Perform first station stop for 30 minutes @ 12,119' RKB (6,981' TVD)9. Perform 15 minute gradient stop @ 10,915' RKB (6,881' TVD)10. POOH. Ensure good pressure data. RDMO. Hand well over to CTU.11. Phase 2: CTU Cement reservoir (Active) WSC Reviewed: No Sundry Requirements: 10-403 10-403 SUNDRY REQUIRED for the following work.1. Contact Quadco to ensure cement retainer(s) and personnel are ready and available.2. Contact SLB cement to ensure equipment and personnel are available.3. Contact READ cased hole to ensure tools and personnel are available for correlation run.4. MIRU SLB CTU and associated equipment.5. MU and RIH with READ cased hole GR/CCL tools for depth correlation.6. Make as many passes as necessary from 11,100 to 10,400' RKB.7. Paint pipe flag.8. POOH and download tools to verify good data.9. MU and RIH with 3.5" FH-1 cement retainer making weight checks as necessary.10. RIH to pipe flag and make depth correction.11. Set FH-1 @ 10,993 ' RKB. Pressure up backside to ensure retainer is set and holding.12. Utilizing sea water, perform injectivity test at 0.5 bbl. increments from 0.5 bpm to 2 bpm to confirm slotted liner is open.13. Pump 58 bbl. of 15.8 ppg Class G cement through retainer. (46 bbl. volume of 4.5" liner from 10,993' RKB to 14,090' RKB. Total volume is 25% over.) 14. Unsting from retainer and perform one bottoms-up circulation with SW from top of retainer to surface to ensure no cement is on top of retainer. 15. POOH laying in diesel FP from 2500' to surface and lay down cement tools.16. MU and RIH with CMD shifting tool for Baker sliding sleeve @ 10,803' RKB.17. Shift sleeve UP into open position. POOH.18. MU and RIH with 3.5" FH-1 cement retainer making weight checks as necessary.19. Lightly tag FH-1 @ 10,993 RKB for depth correction.20. Set FH-1 retainer at 10,775' RKB.21. Utilizing sea water, perform injectivity test at 0.5 bbl. increments from 0.5 bpm to 2 bpm to confirm sliding sleeve is open and the Kuparuk C sands can take injection. 22. Pump 10 bbl. of 15.8 ppg Class G cement through retainer. (9.56 bbl. volume of 3.5" liner AND IA from 10,775' RKB to 10,993' RKB. Total volume is 25% over) 23. With tubing shut in, unsting from retainer lay in 0.5 bbl. on top of cement retainer, bringing cement top to 10,700' RKB.24. POOH laying in SW with diesel freeze protect from 2500' RKB to surface.25. RDMO. Hand well over to SL.26. Phase 3: SL Pressure test and tag cement top (None) WSC Reviewed: No Sundry Requirements: 10-403 Phase 4: EL Jet Cut Tubing (None) WSC Reviewed: No Contact AOGCC 24 hours in advance for state witness tag on top of cement.1. MIRU SL and associated equipment.2. Perform MIT on tubing to 2,500 psi.3. Perform MIT on IA to 2,500 psi.4. Make drift/tag run from surface to top of cement.5. Pull GLV @ 10,484' RKB.6. Circulate 279 bbl. of seawater down the IA followed by 88 bbl. of diesel for freeze protect.7. Jumper tubing to IA to allow u-tube.8. Set DMY in GLM @ 10,484' RKB.9. RDMO. Hand well over to EL for pre rig tubing cut.10. Contact SLB to ensure 3.5" tubing jet cutter is ready and available for tubing cut.1. MIRU SLB EL and associated equipment.2. MU and RIH with jet cutter for 3.5" tubing.3. Make correlation passes to tie into jewelry.4. Prior to jet cut make note of tubing and IA pressures and monitor post cut for communication.5. Jet cut tubing at 10,600' RKB. (NO 10-403 SUNDRY REQUIRED TO CUT TUBING. 10-404 Notification required after cut) 6. POOH. Apply pressure to tubing or IA and watch for pressure communication.7. RDMO. Well is ready for the rig.8. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CD1-47 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Scematic Update- added locked out TRDP & SSD closed CD1-47 6/28/2025 oberr 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 Insulated 34" 16 15.06 36.0 114.0 114.0 62.50 H-40 WELDED SURFACE 11 3/4 10.77 36.5 2,670.2 2,324.8 60.00 L-80 BTCM INTERMEDIATE #1 9 5/8 8.80 2,492.7 10,753.0 6,824.8 40.00 L-80 Hyd 521 INTERMEDIATE #2 Tie back. 7 6.28 33.5 10,362.6 6,645.3 26.00 L-80 BTC-M INTERMEDIATE #2 Lower 7 6.28 10,349.7 11,409.9 6,982.5 26.00 L-80 Tenaris Blue LINER 4 1/2 3.96 11,016.9 14,090.0 6,975.2 12.60 L-80 Hydril 563 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.1 Set Depth 11,055.8 Set Depth 6,917.1 String Max No 3 1/2 Tubing Description TUBING 4.5"x3.5" @114' Wt (lb/ft) 9.30 Grade L80 Top Connection EUE MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.1 31.1 0.00 HANGER 13.625 FMC TUBING HANGER FMC P100008 7918 3.900 114.7 114.7 0.29 XO - Reducing 4.500 Crossover 4-1/2" IBT-m box x 3-1/2" EUE-m pin 3.500 2,118.1 1,997.2 43.94 SSSV 5.176 3-1/2" TRMAXX-5E SSSV w/ 2.812" "X" profile w/ 1/4" control line (5.176" OD) **FLPPER LOCKED OUT 08/17/2017** ***HYDRAULIC SLEEVE OPENED 09/23/2017*** Schlumb erger TRMAX X-5-E, "X", pn: 1004692 29, Ser#C11 S-0067 2.812 4,534.5 3,389.1 54.93 GAS LIFT 5.390 Camco KBMG GLM 3-1/2" x 1" w/ dummy valve, BK-5 latch Camco KBMG 2.920 8,510.4 5,614.4 56.17 GAS LIFT 5.390 Camco KBMG GLM 3-1/2" x 1" w/ dummy valve, BK-5 latch Camco KBMG 2.920 10,483.9 6,707.7 60.84 GAS LIFT 5.390 Camco KBMG GLM 3-1/2" x 1" w/ DCK-2 BEK-latch pinned f/ 2500 psi csg to tbg Camco KBMG 2.920 10,699.3 6,804.0 66.50 GAUGE 5.062 SLB BHP Guage, 3-1/2" Schlumb erger NDPG, PN: 1006343 37, Ser # CYGM- 0232 2.992 10,722.3 6,813.0 67.25 PACKER 5.980 BAKER PREMIER PACKER Baker Premier, PN: H784-63 -0069, Control # 1038287 28 2.870 10,744.8 6,821.7 67.50 GAS LIFT 5.390 Camco KBMG GLM 3-1/2" x 1" w/ dummy valve, BK-5 latch Camco KBMG 2.920 10,803.7 6,843.8 68.58 SLEEVE-O 4.500 BAKER CMD SLIDING SLEEVE **CLOSED 08/14/2017** Baker CMD "BX", PN: H810-80 -4473, Control # 1031802 37 2.812 10,947.7 6,890.8 73.74 Blast Joint 4.090 BLAST JOINT (1) 2.867 11,007.2 6,906.3 76.12 NIPPLE 3.960 HES "X" LANDING NIPPLE 2.813" ID HES "X" 2.813 11,014.9 6,908.1 76.43 SEAL ASSY 5.000 BAKER3-1/2" GBH-22 LOCATING SEAL ASSEMBLY (39.65' to 5" OD locator) Baker GBH-22, PN:H45 0-01- 4081, Control # 1039161 69 2.970 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) 10,652.0 6,784.6 64.94 CATCHER AVA STYLE CATCHER (OAL=34") 10/20/2019 0.000 10,655.0 6,785.8 65.04 PLUG Quadco 3-1/2" PIIP Packer RBP (96" OAL) 10/19/2019 0.000 11,118.0 6,930.1 77.84 PLUG-Milled COMPOSITE BRIDGE PLUG - LEAKING IN LOWER COMPLETION - MILLED HOLE IN CIBP 2/1/2013 Baker 360 Quick Drill 12/28/2012 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) 4,534.5 3,389.1 54.93 1 GAS LIFT GLV BK 1 1,835.0 7/18/2014 0.188 HORIZONTAL, CD1-47, 7/28/2025 6:11:47 AM Vertical schematic (actual) LINER; 11,016.9-14,090.0 PERFP; 14,062.5-14,067.2 PERFP; 13,732.8-13,737.6 PERFP; 13,412.1-13,416.8 PERFP; 13,092.8-13,097.5 FRAC; 11,792.0 PERFP; 12,765.7-12,770.4 PERFP; 12,443.1-12,447.9 PERFP; 12,119.1-12,123.9 PERFP; 11,792.1-11,796.9 INTERMEDIATE #2 Lower; 10,349.7-11,409.9 PLUG-Milled; 11,118.0 IPERF; 10,960.0-10,974.0 INTERMEDIATE #1; 2,492.7- 10,753.0 GAS LIFT; 10,744.8 PACKER; 10,722.3 GAUGE; 10,699.3 PLUG; 10,655.0 CATCHER; 10,652.0 GAS LIFT; 10,483.9 INTERMEDIATE #2 Tie back.; 33.5-10,362.6 GAS LIFT; 8,510.4 GAS LIFT; 4,534.4 SURFACE; 36.5-2,670.2 SSSV; 2,118.1 CONDUCTOR Insulated 34"; 36.0-114.0 WNS PROD KB-Grd (ft) RR Date 1/10/2013 Other Elev CD1-47 ... TD Act Btm (ftKB) 14,120.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032065900 Wellbore Status PROD Max Angle & MD Incl (°) 93.08 MD (ftKB) 11,611.16 WELLNAME WELLBORECD1-47 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: K-VLV ASSY 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) 8,510.4 5,614.4 56.17 2 GAS LIFT GLV BK 1 1,726.0 8/14/2017 0.188 10,483.9 6,707.7 60.84 3 GAS LIFT DMY BK 1 0.0 10/24/2019 0.000 10,744.8 6,821.7 67.50 4 GAS LIFT DMY BK-5 1 0.0 1/6/2013 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 11,016.9 6,908.6 76.51 PACKER 5.960 HRD LINER TOP ZXP PACKER Baker RS 4.340 11,036.9 6,913.1 77.31 NIPPLE 5.250 'RS' PACKOFF SEAL NIPPLE Baker Flex Lock 4.250 11,049.0 6,915.7 77.79 SBR 5.260 SEAL BORE EXTENSION 4.000 11,669.9 6,985.7 93.02 Swell Packer 5.875 TAM FreeCap Swell packer FSC- 11 w/ 5.75" OD Cementralizer 3.958 11,726.3 6,982.8 92.49 Swell Packer 5.875 TAM FreeCap Swell packer FSC- 11 w/ 5.75" OD Cementralizer 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,960.0 10,974.0 6,894.2 6,898.0 K-1, KUP-C, CD1-47 1/3/2013 5.0 IPERF All shots fired 11,792.1 11,796.9 6,980.9 6,980.8 ALP-C, CD1-47 12/28/2012 1.0 PERFP SIX 1/2" HOLES PER PERF PUP 12,119.1 12,123.9 6,981.5 6,981.5 ALP-C, CD1-47 12/28/2012 1.0 PERFP SIX 1/2" HOLES PER PERF PUP 12,443.1 12,447.9 6,978.3 6,978.2 ALP-C, CD1-47 12/28/2012 1.0 PERFP SIX 1/2" HOLES PER PERF PUP 12,765.7 12,770.4 6,971.8 6,971.7 ALP-C, CD1-47 12/28/2012 1.0 PERFP SIX 1/2" HOLES PER PERF PUP 13,092.8 13,097.5 6,974.9 6,975.1 ALP-C, CD1-47 12/28/2012 1.0 PERFP SIX 1/2" HOLES PER PERF PUP 13,412.1 13,416.8 6,985.4 6,985.4 ALP-C, CD1-47 12/28/2012 1.0 PERFP SIX 1/2" HOLES PER PERF PUP 13,732.8 13,737.6 6,980.9 6,980.9 ALP-C, CD1-47 12/28/2012 1.0 PERFP SIX 1/2" HOLES PER PERF PUP 14,062.5 14,067.2 6,976.2 6,976.0 ALP-C, CD1-47 12/28/2012 1.0 PERFP SIX 1/2" HOLES PER PERF PUP Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 11,792.0 14,067.0 1 FRAC 3/1/2013 0.0 0.00 0.00 HORIZONTAL, CD1-47, 7/28/2025 6:11:48 AM Vertical schematic (actual) LINER; 11,016.9-14,090.0 PERFP; 14,062.5-14,067.2 PERFP; 13,732.8-13,737.6 PERFP; 13,412.1-13,416.8 PERFP; 13,092.8-13,097.5 FRAC; 11,792.0 PERFP; 12,765.7-12,770.4 PERFP; 12,443.1-12,447.9 PERFP; 12,119.1-12,123.9 PERFP; 11,792.1-11,796.9 INTERMEDIATE #2 Lower; 10,349.7-11,409.9 PLUG-Milled; 11,118.0 IPERF; 10,960.0-10,974.0 INTERMEDIATE #1; 2,492.7- 10,753.0 GAS LIFT; 10,744.8 PACKER; 10,722.3 GAUGE; 10,699.3 PLUG; 10,655.0 CATCHER; 10,652.0 GAS LIFT; 10,483.9 INTERMEDIATE #2 Tie back.; 33.5-10,362.6 GAS LIFT; 8,510.4 GAS LIFT; 4,534.4 SURFACE; 36.5-2,670.2 SSSV; 2,118.1 CONDUCTOR Insulated 34"; 36.0-114.0 WNS PROD CD1-47 ... WELLNAME WELLBORECD1-47 Comment K-VLV ASSY ((K-VLV/ SN: K32 Upper Completion: MD TVD 1) 4-½ 12.6#/ft IBT-M Tubing (2 jts) XO to 3-½ EUE tubing 2) 3-½ TRMAXX-5E SSSV 2110' 2000' 2.812 X Profile (5.176" OD) 3) 3-½ x 1" Camco KBMG GLM (42°) w/ DV 4555' 3400' 4) 3-½ x 1" Camco KBMG GLM (56°) w/ DV 8506' 5600' 5) 3-½ x 1 Camco KBMG GLM (58°) w/DCK2 10487' 6700' pinned for 2500 psi casing to tbg shear 6) SLB BHP Gauge, Encapsulated I-Wire 10881' 68xx' w/cannon clamps on every joint 7) Baker Premier Packer 3.5" x 7" 10,897 689x 8) 3-½ x 1 Camco KBMG GLM 10951' 69xx' 9) 4.09" Blast rings (30') with retaining rings and spring pack on 3-½ Hyd 563 joint 10953' 6892' 10) Baker CMD sliding sleeve 10997' 6912' 11) HES X nipple 2.813" ID 11010' 6813' 12) Baker 3-½ Bullet Tieback Seal Assembly 11011' 6813' (effective stroke = 18') Lower Completion: 13) Baker 5" x 7" ZXP Liner Top Packer 11015' 6814' XO Hydril 521 Box X Hydril 563 Box Flexlock Liner Hanger Baker 80-20 20' Seal Bore Extention XO 5" Hydril 563 Box X 4-½ TSH-563 pin 14) Freecap Swell packer Hyd 563 11502' 7005' 15) Freecap Swell Packer Hyd 563 11553' 7006 16) Pup Joint XO, 10', 4-½ 12.6#/ft L-80 11603' 6935' Hyd 563 Box X IBT-M Pin 17) 4 ½, 12.6#/ft, L-80 IBT-M Liner w/pre-perf TD pups (5') every 325' and 4 ½ IBT-M Orange Peel Shoe 7" 26# L-80 Tenaris Blue Liner to 11410' MD / 6998' TVD 16" 65# H-40 Welded Conductor to 114' 6 Hole, TD 3-1/2" 9.3# L-80 EUE 9 8 7 1 5 CD1-47 Pre Rig Abandonment Well Plan WP10 Proposed Schematic updated 12/17/2025 GL 11-3/4" 60# L-80 BTC Surface Casing 2670' MD / 2324' TVD @ 56° cemented to surface DB 14 9 5/8" 40# L-80 Hydril 521 Liner to 10753' MD / 6825' TVD Planned TOC in 9 5/8 ~ 5187' ft MD 7" x 9 5/8" Liner Top Packer @ 10566' MD / 6738' TVD Top Kuparuk C 10960' MD / 6890' TVD 2 3 4 6 All depths are Doyon 19 RKB. 4-½ 12.6# L-80 Liner Hydril 563 from liner hanger through swell packers, SLHT/IBT-M to TD 10 11 12 GL GL ~325' 13 Top Alpine C 11353' MD / 6990' TVD 15 16 18 17 Qannik 5687' MD/4031' TVD Halo 3912' MD/3031' TVD ~10,600 Pre-Rig Cut 3-½ Tubing CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Warren, Abby To:Loepp, Victoria T (OGC); Drake, Steve G Cc:Dewhurst, Andrew D (OGC) Subject:RE: [EXTERNAL]RE: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Plug for Redrill Questions Date:Thursday, December 18, 2025 10:59:09 AM Attachments:CD1-47 Pre Rig Abandonment.pdf Victoria Yes, we will be running a USIT (step #11) to evaluate the cement behind pipe on the 9-5/8 liner. The original top of cement was estimated by cement calcs, as no log was run. Top of Halo is 3913 MD/ 3034 TVD and the bottom is 4000 MD / 3081 TVD. It is poorly developed in this area and is most likely a cemented stringer. The likelihood of cutting and pulling from 400 is decent, if we cannot pull from 400 the contingency would be to move up hole and recut. This is how most of our sidetracks below surface casings are performed and Conoco has a high success rate at it with multiple cuts. Current cement calc with pulling the casing 400 below SC and pumping the cement to 200 inside casing would be ~64 bbls of 16.0 ppg cement. In terms of the Gator perforator, we plan to run ~150 of 7 guns with 15spf. Flow area should be more than sufficient to get a proper squeeze to achieve isolation of the Halo. Pipe should be free in that area, as such Conoco does not believe there is any added benefit to perf and wash. I have attached the prerig abandonment Schematic. One thing to note on the sundry, is that section 7 for Discussion of Mud and Cuttings Disposal should read - Incidental fluids developed from drilling operations on well CD1-47A will be injected into the Class 1 disposal well on CD1. Please let me know if you have any questions. Thanks Abby From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Wednesday, December 17, 2025 12:01 PM To: Warren, Abby <Abby.Warren@conocophillips.com>; Drake, Steve G <Steve.G.Drake@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL]RE: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Plug for Redrill Questions CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Abby, Is a CBL planned to verify the TOC above the Qannik? How was the TOC estimated? Please provide log if logged. Please provide top/bottom of Halo. Please provide information on Halo development in this well. Have you considered Gator perforations across the Halo and potential perf and wash before cementing? How likely is it that the 9-5/8 casing can be cut and pulled from ~400 below the SC shoe? I dont see any cement calculations or height of cement on the SC shoe cement plug. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 _____________________________________________ From: Loepp, Victoria T (OGC) Sent: Wednesday, December 17, 2025 11:24 AM To: Abby.Warren@conocophillips.com; Drake, Steve G <steve.g.drake@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: CD1-47(PTD 212-083, Sundries 325-744 & 325-763) Abby & Steve, Please include in both sundries the well bore schematic post reservoir abandonment and pre-rig. You can email that to me. I would like the schematic modified from the 325-763 sundry. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 1 Dewhurst, Andrew D (OGC) From:Dewhurst, Andrew D (OGC) Sent:Thursday, 18 December, 2025 16:42 To:'Drake, Steve G'; Loepp, Victoria T (OGC) Cc:Roby, David S (OGC); Warren, Abby Subject:RE: [EXTERNAL]CRU CD1-47 Sundry (325-744): Question Steve, OK, this makes more sense. You are breaking the plug-for-redrill into two separate sundries. I understand now why this rst one was submitted as a reservoir abandonment. I will change it back to that. I will also attach the pre-rig schematic provided by Abby to this sundry. My questions about TOC, KOP, and Halo are addressed in the separate plug-for-redrill sundry 325-763 that we received from Abby. No further questions from me. Thanks, Andy From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Thursday, 18 December, 2025 13:04 To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Warren, Abby <Abby.Warren@conocophillips.com> Subject: RE: [EXTERNAL]CRU CD1-47 Sundry (325-744): Question Victoria/Andy, I held o a little bit on getting back to your questions knowing that Abby would be submitting her paperwork for the redrill with accompanying schematics. It looks like her latest email, earlier today, addresses the post well work/pre rig drilling schematic. The formations are also listed on there as per Andys request. Wanted to touch base with you to make sure all your questions have been answered or if there is something Im still missing that you need from me? Thanks, Steve From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Thursday, December 11, 2025 12:40 PM To: Drake, Steve G <Steve.G.Drake@conocophillips.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Warren, Abby <Abby.Warren@conocophillips.com> Subject: RE: [EXTERNAL]CRU CD1-47 Sundry (325-744): Question Steve, 2 Please provide a current schema c with all cemen ng as well as a post work schema c. If you can get a schema c of the sidetrack, that would be useful. The 10-401 for the sidetrack begins when the window is milled and drilling begins so generally on a plug for redrill sundry, the rig BOP test pressure is listed. Also show all HC forma on depths. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Wednesday, December 10, 2025 12:19 PM To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL]CRU CD1-47 Sundry (325-744): Question Hi Andy, Thanks for the quick response! To address your questions: Yes, we are preparing to redrill this well as it will be our new disposal well in Alpine. Old well name: CD1-47. New well name: CD1-47A. Its on our rig schedule to have the rig move over it on or around January 25, 2026. Abby Warren is the drilling engineer for the work. Just talked to her and she plans on submitting her sundry/permit shortly. That should have the planned KOP you are requesting as well as the TOC for the 9 5/8. With regards to this sundry, I guess box 1 would be more accurate if the Plug for Redrill was checked rather than the Other: Reservoir Abandon box. Also, I think you are referring to Box 15 for the well status after proposed work. I feel like with the upcoming redrill the oil and abandoned boxes are the ones we need checked? Wouldnt suspended indicate some sort of future utility of the reservoir in that well? Happy to go back and forth a little more on that one. Just want it to be the right one so that it doesnt show up in the future as a suspension that might be to be addressed. Please let me know if you have any other questions. Thanks! Steve From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Wednesday, December 10, 2025 11:47 AM To: Drake, Steve G <Steve.G.Drake@conocophillips.com> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: [EXTERNAL]CRU CD1-47 Sundry (325-744): Question CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 3 Steve, Im looking at the CRU CD1-47 reservoir abandonment sundry. It looks like you are preparing to redrill it. We have a speci c request type on 403 for Plug for Redrill. Its basically the same as a reservoir abandonment, just with the explicit intention of not returning to the wellbore. This would change Box 13 (well status after proposed work) to Suspended. Would you please con rm that this meets your intention? If so, Ill handle the change. Also, what is the planned KOP for the upcoming redrill and where is it with respect to the TOC for the 9-5/8? Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 Originated: Delivered to:8-Oct-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 CD1-47 50-103-20659-00 910153881 Colville RiverElectromagnetic Pipe Xaminer Record (EPX-V)Field & Processed 29-Jul-25 0 12 CD4-209 50-103-20532-00 910213378 Colville RiverLeak Detect Log with IntelliscopeField & Processed 30-Jul-25 0 1345PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40982212-083206-065T40983Electromagnetic PipeCD1-4750-103-20659-00910153881Colville RiverXaminer Record (EPX-V)Field & Processed29-Jul-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.10.09 13:04:54 -08'00' RECEIVED * STATE OF ALASKA OCT 2 7 t0I7 ALAI/PA OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS ACC 1.Operations Abandon ❑ Plug Perforations U Fracture Stimulate LJ Pull Tubing LJ Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Set WRDP a 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips,Inc. Development ❑✓ Exploratory ❑ 212-083 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20659-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25558,25538,25559 CRU CD1-47 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 14120 feet Plugs measured feet true vertical 6974 feet Junk measured feet Effective Depth measured 14090 feet Packer measured 10722 feet true vertical 6975 feet true vertical 6813 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 114' 114' 1640 670 Surface 2634' 11.75" 2670' 2325' 5830 3180 Intermediate 8260' 9.625" 10753' 6825' 5750 3090 Production 11376' 7" 11410' 6983' 7240 5410 Liner 3073' 4.5" 14090' 6975' 8430 7500 Perforation depth Measured depth 10960'- 10974' feet pre-pert pup joints 11792'- 14067' MD True Vertical depth 6894'-6898' feet pre-pert pup joints 6981'-6976'TVD Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5"@ 114' L80 11056' 6917' Packers and SSSV(type,measured and true vertical depth) BAKER PREMIER 10722'MD 6813'TVD CAMCO TRMAXX-5E 2118'MD 1997'TVD WRDP 2042'MD 1933'ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED DEC 1 9 2017. Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 116 136 150 1115 322 Subsequent to operation: 142 370 345 1533 182 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil D Gas H WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-202 Authorized Name: ILNUR Mustafin Contact Name: ILNUR Mustafin Authorized Title: Production Engineer Contact Email:ilnur.mustafin@conocophillips.com 5-teket WeiVirdartil o bchq"11r 0 f I(fl 4� A lfArt c Authorized Signature: ,�� �jt/ . _doy4 Date: 10/26/2017 Contact Phone: 907-263-4039 VTC /2/71/7--- Form "Form 10-404 Revised 4/2017 ( f f 'x 7 REDS Li- NOV - 2 2317 Submit Original Only • •• • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS i 1.Operations Abandon U Plug Perforations U Fracture Stimulate LI Pull Tubing U Operations shutdown U Performed: Suspend 0 Perforate El Other Stimulate ❑ Alter Casing El Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well 0 Other: Set WRDP n 2.Operator ConocoPhlllips,Inc. 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development ❑r Exploratory 0 212-083 3.Address: Stratigraphic 0 Service❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20659-00 7.Property Designation(Lease Number): 8.Well Name and Number. CRU CD1-47 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 14120 feet Plugs measured feel true vertical 6974 feet Junk measured feet Effective Depth measured 14090 feet Packer measured 10722 feet true vertical 6975 feet true vertical 6813 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 7W 16" 114' 114' 1640 670 Surface 2634' 11.75" 2670' 2325' 5830 3180 Intermediate 8260' 9.625' 10753' 6825' 5750 3090 Production 11376' 7" 11410' 8983' 7240 5410 Liner 3073' 4.5" 14090' 6975' 8430 7500 Perforation depth Measured depth 10960'-10974' feet pre-pert pup joints 11792'-14067' MD True Vertical depth 6894'-6898' feet pre-perf pup Joints 6981'-6976'TVD Tubing(size,grade,measured and true vertical depth) 4.5"x 3.5"Cg?114' L80 11058' 6917' Packers and SSSV(type,measured and true vertical depth) BAKER PREMIER 10722'MD 6813'TVD CAMCO TRMAXX-5E 2118'MD 1997'TVD WRDP 2042'MD 1933'ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: '13. Representative Daily Average Production or Injection Data 011-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 116 136 150 1115 322 Subsequent to operation: 142 370 345 1533 182 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑.r Exploratory ❑ Development❑r Service 0 Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ ❑ WAG 0 GINJ 0 SUSP❑ SPLUG 0 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 Authorized Name: ILNUR Mustafin Contact Name: ILNUR Mustafin Authorized Title: Production Engineer Contact Email:Iinur.mustaMeconocoohlUlos.corrt • Authorized Signature: ^ t`/... / Date: 10/2012017 Contact Phone:907-263-4039 Form 10-404 Revised 4/2017 Submit Original Only `, "` WNS P OD CD1-47 ConocoPhillips Well Attribute Max Angles TD Alaska,Irk:. Wellbore API/DWI Field Name Wellbore Status 'ncl C) MD(ftKB) Act Btm(RKB) conocoF.hillips 501032065900 ALPINE PROD 93.08 11,611.16 14,120.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-CD1-47,10/25/20174:52'38 PM SSSV:K-VLV ASSY Last WO: 1/10/2013 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation last Mod By End Date HANGER;31.1--. .-sp, Last Tag: Rev Reason:PULLED TBG STOP,K-VLV,GLV pproven 10/23/2017 0/0,SET PARAGON 11 PACKER,SPACER Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR Insulated 16 15.062 36.0 114.0 114.0 62.50 H-40 WELDED 34„ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread '�SURFACE 11 3/4 10.772 36.5 2,670.2 2,324.8 60.00 L-80 BTCM CONDUCTOR Insulated 301; Casing Description OD(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth IND)... Wt/Len(I...Grade Top Thread 36.0-114.0 V INTERMEDIATE#1 9 5/8 8.799 2,492.7 10,753.0 6,824.8 40.00 L-80 Hyd 521 III Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth IND)... Wt/Len(I...Grade Top Thread in INTERMEDIATE#2 Tie 7 6.276 33.5 10,362.6 6,645.3 26.00 L-80 BTC-M SSSV;2,118.1., 11.1 , -. back. SSSV-WRDP;2,116.0 i Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...VA/Len(I...Grade Top Thread INTERMEDIATE#2 7 6.276 10,349.7 11,409.9 6,982.5 26.00 L-80 Tenaris Blue ii Lower Casing Description OD(in) ID(in) Top MKS) Set Depth(MB) Set Depth(ND)...WtlLen(I...Grade Top Thread LINER 41/2 3.958 11,016.9 14,090.0 6,975.2 12.60 L-80 Hydril 563 Liner Details I Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (in) SURFACE;36.5.2,670.2 11,016.9 6,908.6 76.51 PACKER HRD LINER TOP ZXP PACKER 4.340 GAS LIFT;4,534.4 I 11,036.9 6,913.1 77.31 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4.250 11,039.8 6,913.7 77.42 HANGER 'DG'FLEX LOCK LINER HANGER 4.350 11,049.0 6,915.7 77.79 SBR SEAL BORE EXTENSION 4.000 GAS LIFT;8,510.4 11,669.9 6,985.7 93.02 Swell Packer TAM FreeCap Swell packer FSC-11 w/5.75"OD 3.958 I Cementralizer 11,726.3 6,982.8 92.49 Swell Packer TAM FreeCap Swell packer FSC-11 w/5.75"OD 3.958 !� ii Cementralizer INTERMEDIATE e2 Tie back.; 33.5-10,362.6 IN Tubing Strings I/U E,) Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/It) Grade Top Connection �' �' TUBING 3 1/2 2.992 31.1 11,055.8 6,917.1 9.30 L80 EUE MOD a 4.5"x3.5"@114' Completion Details Nominal ID GAS LIFT;10,483.9 I Top(ftKB) Top(ND)(ftKB) Top Incl CI Item Des Com lin) 31.1 31.1 0.00 HANGER FMC TUBING HANGER 3.900 114.7 114.7 0.29 XO- Crossover 4-1/2"IBT-m box x 3-1/2"EUE-m pin 3.500 Reducing 2,118.1 1,997.2 43.94 SSSV 3-1/2"TRMAXX-5E SSSV w/2.812""X"profile w/1/4" 2.812 control line(5.176"OD) GAUGE;10,899.3 10,699.3 6,804.0 66.50 GAUGE SLB BHP Guage,3-1/2" 2.992 PACKER;10,722.3 1111 11. 10,722.3 6,813.0 67.25 PACKER BAKER PREMIER PACKER 2.870 10,803.7 6,843.8 68.58 SLEEVE-O BAKER CMD SLIDING SLEEVE(OPENED 7 23 14) 2.812 GAS LIFT;10.744 9 10,947.7 6,890.8 73.74 Blasi Joint BLAST JOINT(1) 2.867 INTERMEDIATE#1;2,492.7- L . 111001,:0980407731.277 1,007.2 6,906.3 76.12 NIPPLE HES"X"LANDING NIPPLE 2.813"ID 2.813 10,753.0-� 11,014.9 6,908.1 76.43 SEAL ASSY BAKER3-1/2"GBH-22 LOCATING SEAL ASSEMBLY 2.970 (39.65'to 5"OD locator) SLEEVE-0;10,8o3.7 In Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) . Top(ftKB) Top(ft(NKB)D) Top Incl Cl Des Corn Run Date ID(in) 2,118.0 1,997.2 43.94 SSSV-WRDP PARAGON II PACKER,SPACER PIPE,NO- 6/28/2017 IPERF;10,990.0.10,974.0 GO,WRDP(SN;C145-1074)OAL LEFT IN HOLE=13'-4" I 11,118.0 6,930.1 77.84 PLUG-Milled COMPOSITE BRIDGE PLUG-LEAKING IN 12/28/2012 0.000 LOWER COMPLETION-MILLED HOLE IN CIBP NIPPLE;11,007.1 . 2/1/2013 IIII SEAL &Slots ASSY;11,014.9 F Shot M Dens Top(TVD) Btm(ND) (shots/ Top(ftKB) Btm(NAB) MB) (ftKB) Zone Date ft) Type Corn PLUG-Milled;11.118.0 10,960.0 10,974.0 6,894.2 6,898.0 K-1,KUP-C, 1/3/2013 5.0 IPERF All shots fired CD1-47 11,792.1 11,796.9 6,980.9 6,980.8 ALP-C,CD1- 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER 47 PERF PUP INTERMEDIATE 42 Laver; 10,349.7-11,409.9 I 12,179.1 12,123.9 6,981.5 6,981.5 ALP-C,C01- 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER 47 PERF PUP 12,443.1 12,447.9 6,978.3 6,978.2 ALP-C,CD1- 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER 47 PERF PUP I 12,765.7 12,770.4 6,971.8 6,971.7 ALP-C,CD1- 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER 47 PERF PUP 13,092.8 13,097.5 6,974.9 6,975.1 ALP-C,CD1- 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER 47 PERF PUP PERFP;11,7921-11.798.9 1.11 13,412.1 13,416.8 6,985.4 6,985.4 ALP-C,CD1- 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER 47 PERF PUP PERFP;12,119.1-12,123.9 in 13,732.8 13,737.6 6,980.9 6,980.9 ALP-C,CD1- 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER ■ 47 PERF PUP PERFP;12,443.1-12.447.9 - Vii 14,062.5 14,0672 6,976.2 6,976.0 ALP-C,CD1- 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER III 47 PERF PUP PERFP;12765.7-12770.4 :LI: Stimulations&Treatments FRAC;11.792.0 I. Proppant Designed(Ib) Proppant In Formation(Ib) Date PERFP;13,092.813,097.5 iLE 3/1/2013 Stimulations&Treatments PERFP;13,412.1-13,416.8 :IIC Vol Clean Pump llStga Top(ftKB) Btm(ftKB) Date StimRreat Fluid (bbl) Vol Slurry(bbl) PERFP;13,732.813.7376 :Eli 1 11,792.0 14,067.0 3/1/2013 PERFP;14,062.5-14,067.2 Inin 1 LINER;11,016.9-14,080.0 WNS POD CD1-47 ConocoPhillips 1 • Ala'kA,If1c. ... Comment HORIZONTAL-CD1-47,10252017 4.52.39 PM K-VLV ASSY((K-VLV/SN:K32... Vertical schematic(acNal) HANGER;31.1-- I:7 Nir Mandrel Inserts st atl on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) MKS) Make Model 00(in) Sery Type Type (in) (psi) Run Date Com 1 4,534.5 3,389.1 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,835.0 7/18/2014 CONDUCTOR Insulated 34'; 36.0-114.0 T 2 8,510.4 5,614.4 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,726.0 8/14/2017 3 10,483.9 6,707.7 Camco KBMG 1 GAS LIFT OV BK 0.188 0.0 8/12/2017 4 10,744.8 6,821.7 Camco KBMG 1 GAS LIFT DMV BK-5 0.000 0.0 1/6/2013 SSSV;2,118.1 SSSV-WRDP;2,118.0 r.';I (1 3 I SURFACE;36.5-2,670.2 A` GAS LIFT;4,5344 f GAS LIFT;8,510.4 . ii, IV INTERMEDIATE 02 Tie back.; 33.5-10,362.6 aL Ell 7.' GAS LIFT,10,483.9 g - GAUGE;10,699.3 all PACKER;10,7223 M GAS LIFT;10,744.8 is INTERMEDIATE#1,2,4927- 10,7S3.0 SLEEVE-O;10,803.7 IPERF;10,960.0-10,974.0 II NIPPLE;11,007.1 a. REAL ASSY;11,014.9 F=. II PLUG-Milled;11,118.0 INTERMEDIATE Lower, '_ 10,349.7-11,40E9 0,3M-1 TE.021,o099 I. I PERFP,11,792.1-11.796.9 I 'I1. PERFP;12.119.1-12,123.9 • ■ PERFP;12,443.1-12,4479 iN PERFP',12,765.7-12,770.4 /l: FRAC,11,792.0 PERFP;13.092.8-13,097.5 PERFP;13,412.1-13,416.8 IP ■ PERFP;13,732.8-13,737.6 ME PERFP;14062.5-14.067.2 u• �t} LINER;11,016.9-14,090.0 C D 1 -47 DTTMSTART JOBTYP SUMMARYOPS 6/1/17 SSSV 0/0 OR GAUGE TBG TO 2.84"TO 2118' RKB. BRUSH AREA FROM 2050'-2118' RKB w/FB-BLB. SET K- STROKE VLV ASSY((K-VLV/SN: K322/264 psi @ 60 deg)& D-COLLAR PACK OFF (OAL=42.25"/G-FN) @ 2042' RKB. SET 3"TBG STOP @ SAME. "*FUNCTION TEST FAILED***. FLOW WELL OVERNIGHT. IN PROGRESS. 6/2/17 SSSV C/O OR PULL TBG STOP @ 2014' SLM. PULL K-VLV ASSY @ 2042' RKB (VLV STUCK OPEN WITH STROKE FRAC SAND). SET K-VLV ASSY("D"COLLAR LOCK PACK OFF& K-VLV(S/N: 22K-18/291 psi @ 60 DEG) @ 2042' RKB. SET 3"TBG STOP @ 2039' RKB. WELL TO FLOW—3 DAYS TO CLEAN UP BEFORE FUNCTION TEST. 6/22/17 GLV C/O TAG ICE PLUG @ 1524'RKB. JOB COMPLETE. (MAI NT) 6/27/17 GLV 0/0 JETTED ICE PLUG WITH HOT DIESEL FROM TAG AT 1500'TO TOP OF SLIPSTOP AT 2042' (MAINT) RKB. UNABLE TO INJECT INTO WELL. RETURN IN AM TO PULL SLIPSTOP AND K-VALVE TO CONTINUE JETTING ICE. IN PROGRESS. 6/28/17 GLV C/O WAITED ON TOOLS FROM DEADHORSE FROM 6 TO 2PM DUE TO FLIGHT DELAY. (MAINT) RETRIEVED SLIPSTOP UNABLE TO LATCH K-VALVE ON D-COLLAR LOCK FROM 2042' KB. JOB IN PROGRESS. 6/29/17 GLV 0/0 JETTED 240 BBLS 140* HOT DIESEL AND 100 BBLS OF 140*SEAWATER ON TOP ON INNER D- (MAINT) LOCK MANDREL AT 2042' KB IN AN ATTEPT TO THAW ICE PLUG BELOW K-VALVE. UNABLE TO SHIFT INNER MANDREL DOWN TO LATCH FISH NECK WITH MUTILPE JAR LICKS. WORK DEFERED FOR HIGHER PRIORITY WORK. IN PROGRESS 7/17/17 GLV C/O TAG ICE @ 1721'RKB w/SAMPLE BLR. IN PROGRESS... (MAINT) 7/23/17 FCO RIH PUMPING 140 DEGREE DIESEL DOWN THE COIL, TAG ICE AT 1758' RKB, MELT ICE DOWN TO K-VALVE AT 2042' RKB, POOH AND STANDBY FOR SLICKLINE TO PULL K-VALVE, JOB IN PROGRESS. 7/23/17 GLV 0/0 DRIFT TBG TO K VALVE @ 2042' RKB w/2.84"G-RING.ATTEMPTED TO PULL K VALVE @ (MAINT) SAME,ABLE TO LATCH FISHING NECK ON D COLLAR LOCK w/RELEASING PRONG ON PULLING TOOL WHICH INDICATES LOCK SHOULD BE RELEASED, SHEARED PULLING TOOL MULTIPLE TIMES ATTEMPTING TO PULL. IN PROGRESS 7/24/17 GLV 0/0 PULLED K VALVE (SN: K322) ON D COLLAR LOCK @ 2042' RKB. HYDRATES IN COLLAR LOCK, (MAINT) RUBBER ELEMENT ON D COLLAR LOCK IS MISSING. READY FOR COIL TO CONTINUE ICE PLUG REMOVAL. IN PROGRESS 7/24/17 FCO RIH TO REMOVE ICE PLUG, TAG ICE AT 2044' RKB, JET WITH 140 DEGREE DIESEL AND BREAK THROUGH AT 2110' RKB, PUMP 80 BBLS OF DIESEL DOWN THE 4 1/2"TBG AT 1 BPM (2500 WHP), JOB COMPLETE. 8/12/17 GLV 0/0 DRIFT TBG TO SSSV @ 2118' RKB w/2.84"G-RING, VERIFIED FULL STROKE DOWN ON SSSV (MAINT) FLOW TUBE w/DOGLESS LOCKOUT TOOL. DRIFT TBG TO 11064' RKB w/2.79"SWAGE. STALLED DUE TO DEV. (78 DEGREES). PULLED 1"OV @ 10483 RKB, OV APPEARS TO BE IN GOOD SHAPE. IN PROGRESS 8/13/17 GLV 0/0 SET OV @ 10,483 RKB. DRAWDOWN IA, STILL TXIA COMMUNICATION. WITH HOLEFINDER (MAINT) IDENTIFY LEAK @ STA#2 GLV. PULLED GLV @ 8510' RKB. LAY DOWN DUE TO WIND. IN PROGRESS 8/14/17 GLV C/O SHIFTED CMD @ 10803' RKB CLOSED, NO PRESSURE CHANGE . SET GLV @ 8510' RKB, IA (MAINT) DDT PASSED. TESTED UPPER POLISH BORE ON SSSV @ 2118' RKB w/FRUDENBERG PACKING, DID NOT HOLD PRESSURE. TESTED LOWER POLISH BORE ON SSSV @ SAME w/ 2.82" REGULAR PACKING. DID NOT HOLD PRESSURE. IN PROGRESS 8/15/17 GLV C/O TES LOWER POLISH BORE ON SSSV @ 2118' w/FRUDENBERG PACKING, PASSED (MAINT) MIT- 3000 PSI. LOCKED OUT FLAPPER ON S@ SAME w/DEFORMATION TOOL. UNABLE TO ESTABLISH HYDRAULIC COMMUNICATION w/SLOT TOOL ON FIRST ATTEMPT. IN PROGRESS. 8/16/17 GLV C/O MADE MULTIPLE ATTEMPTS TO SHEAR HYDRAULIC COMMUNICATION SLEEVE IN SSSV @ (MAINT) 2118' RKB. IN PROGRESS 8/17/17 GLV C/O ATTEMPTED TO SHEAR HYDRAULIC COMMUNICATION SLEEVE IN SSSV @ 2118' RKB. IN (MAINT) PROGRESS 8/18/17 GLV C/O ATTEMPTED TO SHEAR HYDRAULIC COMMUNICATION SLEEVE IN SSSV @ 2118' RKB. JOB (MAINT) POSTPONED FOR OTHER WORK. IN PROGRESS 9/9/17 PUMPING ICE PLUG/PUMPED .03 METHANOL DOWN TBG./PLUG HELD SOLID/JOB NOT COMPLETE TRACKING ONLY 9/12/17 FCO STANDBY ON SLB CREW CHANGE, JOB IN PROGRESS. 9/13/17 GLV CIO RIH WITH DOWN JET NOZZLE, TAG ICE AT 2813' RKB, BROKE THROUGH ICE AT 2903' RKB, (MAINT) CLOSE CHOKE AND PUMP 40 BBLS OF HEATED DIESEL INTO TBG, RIH WITH SLB SLOT SHIFTING TOOL, TAG POSSIBLE ICE ON TBG WALL AT 1481' RKB, RIH WITH MOTOR AND 2.80" MILL, MILL FROM 1400' RKB TO 2100' RKB, RIH WITH SHIFTING TOOL, NO GO OUT AT 2118' RKB, 8 JARLICKS AND NO INDICATION THE SLEEVE HAS SHIFTED, POOH AND TAKE RUNNING TOOL TO SHOP FOR DIAGNOSIS, JOB IN PROGRESS. 9/14/17 GLV C/O BRUSH AND FLUSHED TBG DWN TO 2150' RKB w/FULL BORE BRUSH, 2.78"G-RING. RAN EV (MAINT) VIDEO&CALIPER LOG THROUGH SSSV @ 2118' RKB. IN PROGRESS 9/23/17 GLV C/O RAN MODIFIED Z-5 TO 2118' RKB. ESTABLISH HYDRAULIC COMMUNICATION BETWEEN C/L (MAINT) &TBG. COMPLETE. 10/4/17 GLV CIO DRIFT TO SSSV @ 2118'RKB w/2.85"GAUGE RING. SET PARAGON II PACKER,SPACER (MAINT) PIPE,NO-GO,WRDP(SN; HTS-611, OAL=12'-11") @ SAME. NO CL INTEGRITY. IN PROGRESS... 10/5/17 GLV C/O PULL PACKER/WRDP ASSEMBLY @ 2118'RKB. STAND BY FOR TOOLS FROM KUPARUK& (MAINT) MACHINE SHOP. IN PROGRESS... 10/6/17 GLV CIO TEST LOWER POLISH BORE OF SSSV w/CAT SV ON ISO SLEEVE @ 2118'RKB. SET (MAINT) PARAGON II PACKER ON WRDP @ SAME. NO CL INTEGRITY. PULL WRDP. IN PROGRESS... 10/7/17 GLV C/O SET PACKER/WRDP ASSEMBLY @ 2118'RKB. NO CONTROL LINE INTEGRITY. PULL WRDP (MAINT) @ SAME. JOB SUSPENDED. IN PROGRESS... 10/8/17 GLV C/O ATTEMPT TO SET PACKER/WRDP ASSEMBLY @ 2118'RKB. DPU DID NOT STROKE. (MAINT) RETURN TO SURFACE w/PACKER WRDP. IN PROGRESS... 10/9/17 GLV CIO SET PACKER/WRDP ASSEMBLY @ 2118'RKB. NO CL INTEGRITY. TEST PACKER w/TTS (MAINT) TEST TOOL @ 2111'RKB. TBG APPEARS TO BE COMMUNICATING w/CL THROUGH PACKER. JOB SUSPENDED. IN PROGRESS... 10/11/17 GLV C/O SET PACKER/SPACER PIPE/WRDP @ 2118'RKB. PASSING CLOSURE TEST& DRAW DOWN (MAINT) TEST ON CL. HOLDING 3600PS1 MAX ON CL. IN PROGRESS... 10/12/17 GLV C/O PASSING CLOSURE TEST ON WRDP. DRAW TBG TO 500PSI. SET TTS TEST TOOL IN (MAINT) PARAGON PACKER @ 2100'RKB. PERFORM PASSING 3500PS1 MIT-T. PERFORM PPPOT ON TBG HANGER TO 5000PSI WHILE HOLDING 5000PSI ON CL. BLEED TBG ADAPTER VOID TO OPSI. CL HOLDING 5000PSI. FLOW TBG BACK TO LRS TRUCK @ 2300PS1. CL HOLDING. PULL TEST TOOL @ 2100'RKB. JOB COMPLETE. 10/13/17 PUMPING HOTFLUSHED TBG WITH 50 BBLS OF 180"CRUDE. TRACKING JOB COMPLETE. ONLY 10/17/17 ANNCOMM (AC EVAL) POST PATCH TIFL PASSED. • • p-ro ,212 -03 Loepp, Victoria T (DOA) From: Mustafin,Ilnur <Ilnur.Mustafin@conocophillips.com> Sent: Thursday, October 19, 2017 2:52 PM To: Loepp,Victoria T(DOA) Subject: RE: [EXTERNAL]RE:CD1-47 (PTD 212-083) SSSV repair Thanks Victoria, Will do! Regards, SCANNED FEB 2 12018 ILNUR From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday, October 19,2017 2:50 PM To: Mustafin, Ilnur<Ilnur.Mustafin@conocophillips.com> Subject: [EXTERNAL]RE:CD1-47(PTD 212-083)SSSV repair Ilnur, Please file a 10-404 outlining the change back to the original configuration including the well service reports and updated schematic. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppalaska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loew@alaska.gov From: Mustafin, Ilnur[mailto:llnur.Mustafin@conocophillips.comj Sent:Wednesday,October 18,2017 4:00 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject:CD1-47 (PTD 212-083)SSSV repair Victoria, Would like to inform you regarding the latest changes with CD1-47. 1 • CD1-47 is an Alpine C-Sand producer's The tubing sub surface safety valve was not operating properly after an extensive finishing operation in march 2017. K-valve was chosen to replace the non-functioning tubing sub surface safety valve since wireline retrievable safety valve could not be deployed since there were no access to the control lines.The approval to deploy K-valve was received on May 25th 2017.The K-valve was function tested on June 9th 2017. The well was shut in for the planned facility summer maintenance on June 15th 2017 when it developed an ice plug around K-valve and showed the sings of tubing by inner annulus communication.Through the extensive work the ice plug was removed and a leaking orifice valve was replace in kind. In addition,we were able to gain access to the control lines that allowed us to deploy the wireline retrievable safety valve on October 12th. The well was brought online on October 13tH Since CD1-47 is back to original configuration,w/a wireline retrievable SSSV in the original location,we believe there is no need to follow up CD1-47 with Form 10-404 since passing function test of the wireline retrievable safety valve was performed on October 12th and passing TIFL was performed on October 17tH Regards, ILNUR Ilnur Mustafin Production Optimization Engineer ConocoPhillips Alaska Phone: 907-263-4039 Email: ilnur.mustafin@conocophillips.com 2 pTD a1 —© 83 Loepp, Victoria T (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Saturday,July 01, 2017 9:41 AM To: Loepp,Victoria T(DOA) Cc: Senden, R.Tyler Subject: CD1-47 (PTD 212-083) report of IA SCP Attachments: CD1-47 90-day TIO plot 7-1-2017.docx Follow Up Flag: Follow up Flag Status: Flagged Victoria, Alpine well CD1-47(PTD 212-083)is a gas-lift producer that operations has been attempting to start-up after the plant shutdown. After recent work,operations bled the IA pressure down. However,the IA pressure later increased to above 2000 psi without operations applied pressure. Wellhead temperature has increased, so thermal pressure response could be the reason or a contributing factor. The well has 7", L-80,26 lb intermediate casing with a burst rating of 7240 psi. The pressure has not gone above 3258 psi (45%of the intermediate casing's burst rating). CPAI plans to continue to work on this well and identify the source of the pressure. Attached is a 90-day TIO plot. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 1 • • nura,HLrn P51 -- o,, 0 _. ", 8 A p — �n un `rIooa o Io o n n ^n nn n n 8 8 °' dFA • I I 1 I m m I1III III Z c'o l, I 1 r& 4r .," " n 0a` ,1 c ti m 0 o 4.1 4 / _ .... to I j 2 P • r` N OP i £ ' I1 II I I 1 I I 1 J _.. ...— I8 O 8 8 5 nl A b ry ._l _ _ n O O O degi 888888. O O[7[7 O_O U) -I XI N N ha N j N ji O W O A CI ID O O 1T InCWOOO_ hit W A Ia m 2 . � N IcIpwCny . rn 01 IT CO GI I),...1 U) O 0..a or O I ll `G O '�47J chiW IT W 0l f7'I OO IOONV,N zzzzzzm zzzz�. a mmmmmrn xx73XI73 G)G)0 C)0 G) r-rrrrrrri - 000000 = F m • pro > Z -o'S3 Loepp, Victoria T (DOA) From: Mustafin,Ilnur <Ilnur.Mustafin@conocophillips.com> Sent: Tuesday,June 20, 2017 10:51 AM To: Loepp,Victoria T(DOA) Subject: CRU CD1-47(PTD 212-083, Sundry 317-202)Set K-valve Attachments: CD1-47 Form 10-404 6.20.17.pdf;CD1 47_10-404_6 20_17.docx Follow Up Flag: Follow up Flag Status: Flagged Hello Victoria, The K-valve was successfully set in CD1-47 on June 2"d and State witnessed function tested on June 9th. Please,see attached Form 10-404 and supplement document with an updated well operations daily log. Do you want me to send two hardcopies to your office? Regards, ILNUR Ilnur Mustafin MS AUC 0 7 Z017, Production Optimization Engineer ConocoPhillips Alaska Phone: 907-263-4039 Email: ilnur.mustafin@conocophillips.com From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, May 23,2017 9:33 AM To: Mustafin, Ilnur<Ilnur.Mustafin@conocophillips.com> Subject: [EXTERNAL]CRU CD1-47(PTD 212-083,Sundry 317-202)Set K-valve Ilnur, Please include the calculation summary/printout for setting the K valve in the sundry. Also include well history and background that you previously communicated in emails in your submission. You may email this information to me. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp analaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoriaioepp@alaska.gov 1 • OF h�•\�\ lyy,', THE STATE Alaska Oil and Gas �,�►,"!•-d��� Of i0 TLSJC`.n 1CrT /� Conservation Commission n £=_ 333 West Seventh Avenue t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 A S Fax: 907.276.7542 www.aogcc.alaska.gov Ilnur Mustafin `/1117 Production Engineer S OE tyi'l '41 r '' ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field,Alpine Oil Pool, CRU CD 1-47 Permit to Drill Number: 212-083 Sundry Number: 317-202 Dear Mr. Mustafin: 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, Cathy '. Foerster Chair DATED this 2S day of May, 2017. RBDMS \/U P ryi 3 0 2017 • • STATE OF ALASKA ` ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Set K-valve El 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips, Inc. Exploratory ❑ Development E. 212-083 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20659-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NACRU CD164,7_, Will lannederforations require a spacinexce tion? Yes ❑ No � kj RECEIVED 9.Property Designation(Lease Number): 10.Field/Pool(s): Colville River Field/Alpine Oil PooIM1Y 1 7 2017 11. PRESENT WELL CONDITION SUMMARY Or 5/z,5 /? Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): i'. :, lylk(7' 14990- 613-79I 6075 ]HCFI 0 64?'S r 016 Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 114' 114' 1640 670 Surface 2634' 11.75" 2670' 2325' 5830 3180 Intermediate 8260' 9.625" 10753' 6825' 5750 3090 Production 11376' 7" 11410' 6983' 7240 5410 Liner 3073' 4.5" 14090' 6975' 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10960-10974 ' 6894-6898 4.5"x 3.5"@ 114' L80 11056' pre-pert pup joints 11792- 6981 -6976 14067 • Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER PREMIER PACKER MD=10722 TVD=6813 • SAFETY VLV-CAMCO TRMAXX-5E SSSV MD=2118 TVD=1997 . 12.Attachments: Proposal Summary Eil Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑� • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 5/25/2017 OIL ❑., • WINJ ❑ 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: ILNUR MUSTAFIN Contact Name: ILNUR MUSTAFIN Authorized Title: Production Engineer Contact Email: ilnur.mustafint conocophillips.com Contact Phone: 263-4039 Authorized Signature: Date:5/16/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 61`7-ZoZ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ wSF 5 Ize I 1 Other: Post Initial Injection MIT Req'd? Yes ❑ No Er- Spacing Exception Required? Yes ❑ No Z' Subsequent Form Required: /C A A 2017 RBDI611S � h,e-:Y 3 0 APPROVED BY Approved by: �� COMMISSIONER THE COMMISSION Date: -S"-- — �uLn.lt re....enJ Form 10-�033 R ised 4 / U1icr4vtIJ for 12 months frrom the date of approval. Attachments in Duplicate • 110 Alpine Well CD1-47(PTD 212-083) CD1-47 is a Colville River Unit production well.The well was closed due to a fish stuck at the subsurface safety valve in February 2015.After multiple attempts the fish was retrieved in March 2017, but the tubing retrievable subsurface safety valve is not operating properly and damaged preventing setting a wireline-retrievable surface controlled subsurface safety valve. A downhole pressure operated valve or "K-valve"should satisfy the requirements of Industry Guidance Bulletin No. 10-004 with the attached information. Well Status CRU well CD1-47(PTD 212-083)was originally completed in December 2012 as a development well. On March 15th2017,during an attempt to repair the tubing-retrievable valve,the flow tube appears to be stuck in down position.The following video camera log showed the flapper pinched behind the flow tube, preventing its movement and setting a WRDP in the SSSV profile.A K-valve installation is currently planned upon approval from AOGCC. With AOGCC approval the well was brought on production on March 20th,2017 till April 1st, 2017 without an operating subsurface safety valve to obtain pressure and temperature data to calibrate the K-valve setting. Proposed Operating Plan 1. Keep the well shut in till K-valve is installed. 2. Provide information to the AOGCC as per Industry Guidance Bulletin No. 10-004. ✓ 3. Set the closing pressure of the valve and install the valve. 4. Stabilize well with K-valve installed and perform witnessed closure test.--- 5. Incorporate the K-valve test frequency into the current SVS testing cycle at CD1 pad. • • -2- K-valve Data The K-valve will be set in the 2.812"X nipple of the TRMAXX-5E at 2118' MD. Stone Choke K Safety Valves Storm Chokes K safety valves are ambient-type,wireline retrievable valves with the largest flow area of all direct • - controlled safety valves on the market They are ideally suited for high-volume,low-pressure wells.These valves are normally closed and precharged with a set dome pressure. When the well flowing pressure drops below the .l predetermined dome-pressure charge due to a rupture in flowline or surface equipment,the dome pressure and main valve spring dose the valve,shutting in the well below the *' earth's surface.This valve contains a detent mechanism to provide a positive snap-action closure at the predetermined disaster rate of the valve.Its bore is not restricted by a flow bean.The valve is designed to resist pressure surges.A metal- to-metal(MTM)poppet valve and seat comprise the valve's primary closure mechanism. The K valve is ideal for protecting wells with declining bottomhole pressure.This valve closes in situations where a pressure decline would not activate a valve with a flow bean. To reopen the valve,the operator must fully equalize pressure either by applying pressure in the tubing from the surface or by an equalizing prong.The valve will reopen when the • tubing pressure acting on the internal piston area overcomes the dome charge. • Applications • Wells with declining bottomhole pressure • High-volume,low-pressure wells :z • Wells with no provisions for surface-controlled valves Features.i • Poppet closure • Large ports with capacity for high-volume wells • Designed to resist pressure surges Benefits 5 . installed and retrieved under pressure by wireline methods Storrn Choke' • Adaptable to any Halliburton lock mandrel KSaf y Valve • Can be located in any Halliburton landing nipple • Can also be located on large bore intervention packers • 40 -3- Pressure/Temperature Gauge Data The plot below shows the temperature and pressure at the SSSV during the flow period.The red line is the targeted closure pressure of 317 psig. CD1-47's last unchoked production test was 154 BOPD at 57%watercut, with 354 Mscfd of formation gas and 1378 MScfd of lift gas. The downhole temperature and the targeted closing Tubing Pressure at Valve (gauge), psig 317 pressure of 317 psi at the SSSV were used in accordance PBT, psia 331 with the Winkler and Eads method to calculate a test rack Temperature at Valve, degF dome pressure of 264 psi.This pressure should allow for testing of the K-valve by opening the choke to the full Temp. Corr. Factor to 60 degF open position,which will drop the WHP by 25-30 psi and Pb @ 60 degF, psia = 331.4000 cause the valve to go closed. Volume Ratio for Valve Size = Test Rack Pressure, psia = 264 CRU well CD1-34(PTD 200-043) and CD2-75 (PTD 208-064) have a similar SSSV and testing procedure. Pressure/Temperature Graph 700 8_ 90 000 80 1' • 70 BCC 4 a 60 0 L ,Lf V If m 600 d, 50 0 Y ,.:1` ii. m �( 40 c E u 400 y11y 30 200Opthauwimisimmiposimmomovoindeammummimmemommownsimoommilkiimmaimmimic 20 • 10 0• S 0 1 4"' 'h4 !1�.144' 4, '4' .. !''6 ."/ ".C,,,"‘ 'c4.;\ 4 h?'A0..'' 00 t' ^'�r'. p' 4'4'."h\, 0 4'.'40 ..4' Orb%e 5' 'Y'3 OW 4^', .'L'" 00 y'"!,b 4' ''h'7 ^i0 'L'h.# h" 4'.'l'' 1,11,ti.1,ti•1n'• 1P1P 14 14 11 1•14 1` '',tio.'}•Y. "ti.y4.'tin'.'YP.'ti4. YrO. Y�. "1.,4.'', '4_moo.1�• ''.ryb"'1o.1,y1•'.1,ti1"'1p.^.14.10.11.11.14.1'.'tio 'Y,. 'ti.,ti. ''' "' ''' ''' '''' 4 '' "' 'y\n'~�4';'''' "\n'~h, h, h, h, ~ h, h,�1\h, ~\",~\~ h, h,, h,\~ hP4h, (y~�,\�R\~1'' '.\ \\ \~'\• ~\tib~,,�\~\\ \~P\~�,.\''''\;P\1\~''\1 Axis Title f.flowing Tubing Pressure .— —Downhde Pressure at Valve depth Valve Closure Pressure �.Down hde temperature at Valve depth Production choke • • -4- Well History since the fish left in the hole on 2/21/15 ConocoPhilliPS C D 1-47 : 501032065900 : 5/24/2017 4/23/2017 RIH RECOVERED FLOW THROUGH PLUG AND GAUGES, RIH TO PERFORM FCO, TAGGED AT 11,004', 13,518' CTMD MADE IT DOWN TO 13730' CTMD, PULLED HEAVY ALL THE WAY UP TO 9,550'. OVER PULL AT 3500', ( JOB IN PROGRESS) 4/12/2017 GAUGE TBG TO 2.83"TO 2118' RKB. STICKY FROM 2010' -2088' SLM. ATTEMPT TO PULL LOCK w/GAUGES @ 2118' RKB. UNABLE TO LATCH. PRESSURED TBG TO 3500 psi. **MAY HAVE HYDRATES ABOVE GAUGES**. IN PROGRESS. 3/30/2017 SET 2.81"XX PLUG @ 2118'RKB. ATTEMPT PT. FAILED. PULL PLUG. SET DUAL SPARTEK GAUGES ON X-LOCK& FLOW THROUGH SUB @ SAME.(OAL=80"). GAUGES SET FOR 1 SECOND INTERVALS. JOB COMPLETE. 3/30/2017 CUT PARAFFIN f/SURFACE TO 900' SLM, CLEAR TO SSSV @ 2118' RKB wl 2.83"G-RING. ATTEMPT TO GET PASSING PRESSURE TEST ON UPPER POLISH BORE IN SSSV @ 2118' RKB, LOCKING PROFILE APPEARS TO BE WORKING BUT UNABLE TO ACHIEVE PRESSURE TEST w/2.385" PACKING ON TEST TOOL. CHANGE OUT TO NIGHT CREW. IN PROGRESS 3/18/2017 RAN EVDHV TO 2118' RKB. GOOD DATA. COMPLETE. 3/17/2017 PUMPED 20 BBLS METHANOL DWN TBG, (JOB COMPLETE) 3/15/2017 ATTEMPT TO EXERCISE FLOW TUBE @ 2118' RKB w/3" BLB. UNABLE TO GET MOVEMENT. ABLE TO PASS THRU TRDP WITH C/L DUMPED & NOT CATCH FLAPPER. FLOW TUBE APPEARS TO BE STUCK IN DOWN POSITION. IN PROGRESS. 3/14/2017 RAN 2.46" MAGNET TO 2102' SLM. **RECOVERED '-4' PIECE OF WIRE & METAL SHAVINGS. RAN 2.80" LIB TO 2093' SLM. **2 MARKS ON OUTSIDE OF G.RING WHERE SD IN RESTRICTION**. IN PROGRESS. 3/13/2017 Ran Weatherford 2.125 motor, 2.63"Venturi and burnover shoe (2.80" OD x 2.0" ID). Dry tagged nipple at 2107' CTMD (2117' RKB). Burnover gauge ring until able to move down 1 ft freely. Ran Venturi w/mule shoe to bottom of SSSV, lightly touch closed flapper at 2110.2' CTMD (2120' RKB), recovered more broken SL wire and metal cuttings. Ran 2.80" D331 slick gauge diamond mill, attempt to drift nipple, sat down at 2108.2' (2118' RKB). Attempt to mill out tight spot grabbing and stalling, suggest tapered mill. Job suspended to spool new CT for CD5-20. 3/12/2017 Ran Weatherford 2.65"overshot w/ 1.75" catch to 2117' RKB. Did not engage fish. POOH, inspect Overshot, one grapple is bent over up inside the housing. Ran LIB to 2117' RKB, got perfect picture of a male QC centerd in the tubing. Ran a 2.125" motor, 2.625"Venturi, and burnover shoe (2.80 OD x 2.0 ID), burnover fish for 4 hours. POOH to check Venturi, recovered male QC and the top half of the gauge ring that was burned over. Make up BHA for Venturi run in the AM. 3/11/2017 Ran Weatherford 2.625" OS w/ 1.75"catch. Latched fish at 2117' RKB, coil free after 4 jar hits. Recovered female QC. Re-ran OS and attempted to latch fish, unable to latch. Made two runs with 2.625"x 2.0" burnover shoe w/Venturi basket. Recovered 4 lugs from the male QC, SL wire, and metal shavings. Made-up fishing BHA; 2.625" OS w/ 1.75"catch for the AM. 3/10/2017 Ran Weatherford Burnover Shoe w/Venturi basket. Dry tagged top of fish at 2117' RKB each time. Made three runs, burned over for approximately 30 min, each run, Runs 1 and 2, recovered small amount of broken bits of 0.125" SL wire and metal shavings. Run 3, Venturi was empty. Cut 150 ft of CT between Run 2 & 3, Made up fishing BHA for AM. • • -5- 3/9/2017 Ran Weatherford hydraulic overshot w/ 1.75"catch. Dry tagged fish at 2117' RKB, latched up first time. Cycled pipe 20 times, got 8 jar hits up at 40K over and 6 hits down, trying to re-cock the jars. Pulled out and changed jars. Ran back in to 2117', got one overpull then could not latch. Pulled out to inspect, ***3 BROKEN DOGS LEFT IN HOLE ***. Ran 2.625"Venturi basket, nothing recovered. Ran 2.60" magnet. Recovered fine metal shavings, no dogs. Ran 2.625" slick catch overshot w/ 1.63"to 1.75" catch. Not able to latch fish with slick catch. 3/8/2017 Rig down from 3H-04. Mobilize CTU 4 to Alpine. MIRU to CD1-47, Make-up fishing BHA. 2/28/2017 Ran BHA#1 with 2.125" motor and 2.80"x 1.9" burnover shoe. Dry tagged fish at 2098'. Mill/burnover fish for 45 min. Coil became stuck at 2075', pull 44K and got free. POOH to inspect BHA. Observed marks/scares on 2.875"XO near coil connector. Cut off 2-7/8" CTC, sized down to a 2.125"connector and re-ran the remaining BHA. Mill/burnover fish for approximately 2 hours. POOH to inspect BHA#2. The carbide shows rounding and wear on the ID of the burnover shoe. Make-up and run BHA#3 with new burnover shoe and 2-5/8"venturi basket. Recovered 1/4 cup of fine metal shavings with a dozen or more larger pieces of wire and metal. Job suspended for higher priority rig prep 2/27/2017 PERFORM WEEKLY BOP TEST, RIH WITH FISHING BHA, LATCH FISH AT 2118', GET 50 JAR LICKS, PUMP OFF, COME OUT OF HOLE, CHANGE PACKOFFS, STACK BACK FOR THE NIGHT (JOB IN PROGRESS) 2/25/2017 RIH WITH MOTOR, VENTURI AND BURN OVER ,TAG FISH PICK UP KICK ON PUMP, BURN OVER FISH AND RECIP UP AND DOWN FOR 30 MIN, POOH CHECK VENTURI, GOT ABOUT 13" OF WIRE BACK, MAKE ANOTHER RUN WITH THE VENTURI, TAG FISH AND RECIP WITH PUMP ON LINE, POOH CHECK VENTURI, GOT SOME METAL SHAVINGS AND SOME SMALL CHUNKS OF WIRE BACK, MADE UP OVERSHOT RIH, LATCHED UP START JARRING, DID NOT COME FREE, POOH CUT 150' PIPE, MAKE UP 2 7/8" FISHING TOOLS, RIH LATCH FISH, JAR FOR 38 JAR LICKS, JARS STOPPED WORKING, PUMP OFF, POOH, SHUT DOWN FOR PHASE II CONDITIONS. (JOB IN PROGRESS) 2/24/2017 RIH TRY AND RECOVER GAUGE RING LEFT IN HOLE, FINALLY GOT LED IMPRESSION OF 1.75" FISH NECK WITH WIRE MARKS ON FISH NECK. RETURN IN AM ( JOB IN PROGRESS) 2/23/2017 RIH WITH MULTIPLE TOOL STRINGS TO TRY AND RECOVER GAUGE RING @ 2118', HAD NO SUCCESS, RETURN IN MORNING. ( JOB IN PROGRESS) 2/22/2017 STAND BY FOR WEATHER COIL#4 2/21/2017 RIH TO LATCH FISH AT 2074', ON THE 7TH JAR HIT @ 42k OVER OUR UP WT, SOMETHING CAME FREE, POOH COULD NOT SHUT THE MASTER OR THE SWAB, RBIH PUMP OFF FISH, POOH, AT SURFACE BREAK TOOL STRING DOWN TO JUST CC, DFCV AND 3" GS, RIH TO RECOVER FISH, RECOVERED EVERYTHING BUT THE GAUGE RING. 13" GAUGE RING STILL IN HOLE. ( JOB IN PROGRESS) 3/2/2016 RIH TO LATCH FISH AT 2075' CTMD, 45 JARLICKS WITH NO MOVEMENT FROM FISH, TRIM 140' OF COIL, RIH TO LATCH FISH AT 2076' CTMD, 45 JARLICKS WITH NO MOVEMENT FROM FISH, F/P TBG TO 2000' CTMD, JOB COMPLETE. 3/1/2016 RIG UP CTU, WAIT ON CPAI WELDERS, UNABLE TO GET WELDERS TO WELD COIL CONNECTOR, PERFORM WEEKLY BOP TEST, TRIM 200' OF COIL, RIG UP BHA, JOB IN PROGRESS. 7/3/2015 INJECTIVITY TEST, PUMPED 2 BBLS METH SPEAR FOLLOWED BY A TOTAL OF 40 BBLS OF CRUDE DOWN TBG AT 1 TO 2 BPM, 1ST 20 BBLS CRUDE TO BE PUMPED AT 1 BPM INCREASEING RATE TO 2 BPM FOR 2ND 20 BBLS OF CRUDE. TBG PRESSURE DID NOT STABLIZE AND CONTINUED TO RISE THROUGH THE JOB. JOB COMPLETE 6/20/2015 RIH AND LATCHED FISH AT 2077' CTMD, GOT 71 JARLICKS (50 UP + 21 DOWN), POOH CUT 100' OF CT, RUN#2 LATCH INTO FISH, GET 100 JARLICKS (50 UP + 50 DOWN), NO MOVEMENT FROM THE FISH AT ALL, JOB COMPLETE. • -6- 6/19/2015 RUN #1 RIH WITH HIPP TRIPPER, LATCH FISH AT 207T CTMD, VIBRATE FOR 3 HOURS & POOH, CUT 100' OF CT AND CHANGE PACKOFFS, RIH WITH TEMPRESS ADJITATOR AND VIBRATE FOR 3 HOURS, NO MOVEMENT ON FISH, JARS ARRIVE AT 5 PM, RESTART IN THE AM WITH JARS, JOB IN PROGRESS. 6/18/2015 LATCHED INTO FISH AT 2077' CTMD, HIPP TRIPP FOR 1.5 HOURS WITH NO MOVEMENT, RUN#2 WE WERE ABLE TO GET 15 JARLICKS BEFORE THE JARS QUIT FIRING (HAVING ANOTHER SET FLOWN OVER), RUN#3 HIPP TRIPP FOR ANOTHER 2 HOURS WITH NO SUCCESS, JOB IN PROGRESS. 6/17/2015 WAIT ON VAC TRUCK TO SUCK OUT SUMPS FROM CONTAINMENT BEFORE MOVING UNIT, RIG UP CTU, PERFORM WEEKLY BOP TEST, CHANGE PACKOFFS AND DO A CHAIN INSPECTION, JOB IN PROGRESS. 6/16/2015 MOBILIZE CREW TO ALPINE 5/25/2015 (SPECIAL OLGOONIK GS REQUIRED TO LATCH DISCONNECT 1.81") LATCHED INTO FISH AT 2077' CTMD, A TOTAL OF 163 JARLICKS IN 4 RUNS WERE HIT WITH NO MOVEMENT AT ALL, ON RUN #2 THE COLETTES OF THE GS WERE BENT AND ROLLED AS IF WE GOT ALONG SIDE OF THE FISH NECK, PUMPED 60 BBLS OF 180 DEGREE DIESEL DOWN THE BACKSIDE ON RUN#2 WITH NO HELP IN MOVEMENT, JOB IN PROGRESS. 5/24/2015 MIRU CTU#5, WAIT ON TOOLS TO ARRIVE, RU BHA, TOO LATE IN THE DAY TO START, JOB IN PROGRESS. 5/23/2015 STANDBY FOR FISHING TOOLS, JOB IN PROGRESS 5/17/2015 LATCHED FISH @ 2080' CTMD. GET 21 JAR LICKS ON FISH WHEN JARS STARTED FAILING. ATTEMPT TO PUMP OFF FISH BUT UNABLE TO. APPEARS THAT THERE IS NOT ADEQUATE FLOW THRU GS PORT. DROPPED BALL TO DISCONNECT LEAVING 4.7' OF COIL TOOLS. JOB SUSPENDED UNTIL MORE TOOLS ARE SENT OVER TO ALPINE. ***COIL FISH; DISCONNECT W/ 1.81" G F/N LOOKING UP, XO&2.70" G SPEAR **** 4.7' OAL. SEE COMMENT SECTION &ATTACHMENTS FOR DETAILS OF THE 3 DIFFERENT SECTIONS OF THE FISH. 4/22/2015 SET BAITED BOWAN OVERSHOT ON TOP OF FISH @ 2069' SLM, JARRED ON OVERSHOT TO CONFIRM SET, READY FOR COIL 4/21/2015 RAN BELL GUIDE W/ 1.92" ID &TTL PINS TO VERIFY GRAPPLE & HOUSING ARE CLEAR, ATTEMPTED TO SET BOWAN OVERSHOT W/ 1.875" GRAPPLE ON FISH @ 2069' SLM, GRAPPLE APPEARS TO BE TO BIG. BODY OF ROPE SOCKET LESS THAN 1.875"OD. JOB IN PROGRESS 4/8/2015 ATTEMPT TO SET BAKER OVERSHOT ON FISH @ 2067' SLM, UNABLE TO GET OVERSHOT TO ENGAGE 1.875" BODY ON ROPE SOCKET. JOB SUSPENDED FOR PRIORITY WORK. IN PROGRESS 4/6/2015 ATTEMPT TO FISH TOOLSTRING @ 2067' SLM. SHUT DOWN DUE TO WIND. IN PROGRESS 4/5/2015 ATTEMPT TO FISH TOOLSTRING @ 2067' SLM, VERIFIED APPROX. 7" OF CLEARANCE f/TOP OF ROPE SOCKET TO TOP OF GRAPPLE PIECE LEFT ON FISH. IN PROGRESS 3/23/2015 RAN 2.5" G-SPEAR ON COIL, ENGAGED BAITED FISH AT 2079' CTMD, HIT 2 JAR LICKS AND CAME FREE. PARTED THE BOWEN OVERSHOT GRAPPLE AT THE TOP OF THE BOWL, LEAVING MOST OF THE BOWL HOUSING AND THE 1.75" SPIRAL GRAPPLE ON THE FISH 2/25/2015 ATTEMPT TO PULL FISH @ 2063' SLM. PULLED 52 GO @ 2063' SLM (DOGS BROKEN). SET 1.75" GRAPPLE (1.81" FN/2.33" OD/OAL = 23") @ 2064' SLM. IN PROGRESS. 2/22/2015 ATTEMPTED TO PULL TOOL STRING @ 2064' SLM, JOB IN PROGRESS 2/21/2015 ATTEMPTED TO GAUGE TUBING TO SAFETY VALVE WITH 2.83" GAUGE RING, HUNG UP @ 1100' SLM, LOST SPANGS, PRESSURED UP TUBING, BLOWN DOWN HOLE, PARTED WIRE, ATTEMPTED TO FISH TOOL STRING, JOB IN PROGRESS Regards, • • -7- Ilnur Mustafin WNS Production Optimization Engineer ConocoPhillips Alaska, Inc. Phone: 907-263-4039 Email: ilnur.mustafin@conocophillips.com WNS •OD . CD1-47 ConocoPhillips :.: Alaska,Inc. CuacliPhillips HORIZONTAL-CD1-47,5/17/2017 11:53:46 AM Vertical echerneto(actial) HANGER,31.1- q C=+ Mandrel Inserts st ati Top(ND) Valve Latch Port Size TRO Run N Top(RKB) (1tKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 3 10,483.9 6,707.7 Camco KBMG 1 GAS LIFT OV BK 0.250 0.0 7/15/2014 CONDUCTOR Insulateo-dn 4.34; • 3s. o 4 10,744.8 6,821.7 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/6/2013 3$SV;2,118.1 in I Or ydy SURFACE;38.5-2,670.2 GAS LIFT;4,534.4 GAS LIFT,8,510.4 -IN Br INTERMEDIATE#2 TR back., 33.510.362.6 =J 11 GAS LIFT,10,483.9 1 GAUGE;10, 8.3 PACKER;10,722.3 GAS LIFT;10,744.8 _. 111 INTERMEDIATE#1;2,492.7- 10,753.0 SLEEVE-0,10,803.7 a AIM IPERF;10,980.0-10,974.0 NIPPLE;11,007.1 SEAL ASSY;11,014.9 F- �-_{ 1S PLUG-Milled;11,118.0 INTERMEDIATE#2 Lover; 10,349.7-11,409.9 PERFP;11,792.1-11,798.9 ''-):11 PERFP;12,119.1-12,123.9 I 1 ■ PERFP;12,443.1-12,447.9 J:1', ■ PERFP;72,78.5.7-72,770.4 FRAC;11,792.0 ■ PERFP;13,092.8-13,097.5 :11 ■ PERFP;13,472.7-13,478.8 ■ PERFP;13,732.8-13,737.6 --1 i'. PERFP,14,082.514,067.2 I }} LINER;11,018.9-14,090.0 r • Alpine Well CD1-47(PTD 212-083) Proposed Operating Plan 1. Keep the well shut in till K-valve is installed. 2. Set the closing pressure of the K-valve based on pressure and temperature survey from March 2017 and install the valve 3. Stabilize well with K-valve installed and perform witnessed closure test. 4. Incorporate the K-valve test frequency into the current SVS testing cycle at CD1 pad. S 1� • • -2- Storm Chokes K Safety Valves Storm Chokes K safety valves are ambient-type,wireline- retrievable valves with the largest flow area of all direct- t s controlled safety valves on the market They are ideally suited CUM for high-volume,low-pressure wells.These valves are normally closed and precharged with a set dome pressure. 'When the well flowing pressure drops below the predetermined dome-pressure charge due to a rupture in flovdine or surface equipment,the dome pressure and main valve spring dose the valve,shutting in the well below the earths surface.This valve contains a detent mechanism to 111 provide a positive snap-action closure at the predetermined disaster rate of the valve.Its bore is not restricted by a flow bean.The valve is designed to resist pressure surges.A metal 11 - to-metal(MTM)poppet valve and seat comprise the valve's primary closure mechanism. The K valve is ideal for protecting wells with declining bottornhole pressure.This valve doses in situations where a ft. pressure decline would not activate a valve with a flow bean. 1 To reopen the valve,the operator must fully equalize pressure . either by applying pressure in the tubing from the surface or i`: by an equalizing prong.The valve will reopen when the tubing pressure acting on the internal piston area overcomes the dome charge. Applications S.� • Wells with declining bottomhole pressure • High-volume,low-pressure wells . Wells with no provisions for surface-controlled valves III Features IFt . Poppet closure • Large ports with capacity for high-volume wells • Designed to resist pressure surges Benefits • Installed and retrieved under pressure by wireline ` 4 methods Storm Choke` • Adaptable to any Halliburton lock mandrel tcSafety trdM ( � • Can be located in any Halliburton landing nipple �LI) • Can also be located on large bore intervention packers WNS •OD . CD1-47 ConocaPh'Mips Well Attributes Max Angle&MD TD Alaska-Inc y' Wellbore APEUWI Field Name Wellbore Status -rid(°) MD(ftKB) Act Btm(ftKB) Carmaihigipa 501032065900 ALPINE PROD 93.08 11,611 16 14,120.0 ...• ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-CD1-47,5/17/201711.53.46 AM SSSV:TRDP Last WO: 1/10/2013 Vertical schematic.(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,31.1-, i4:n4+... Last Tag: Rev Reason:GLV C/O,PULLED FRAC SLEEVE lehallf 7/24/2014 Com' asing rings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...•.WtlLen(I...Grade Top Thread CONDUCTOR Insulated 16 15.062 36.0 114.0 114.0 62.50 H-40 WELDED ._ .. ....,.34„ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 11 3/4 10.772 36.5 2,670.2 2,324.8 60.00 L-80 BTCM CONDUCTOR Insulated 34", Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(1...Grade Top Thread 3fi.0.114.0 +��- INTERMEDIATE#1 9 5/8 8.7.9.9 2,492.7 10,753.0 6,824.8 40.00 L-80 Hyd 521 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMEDIATE#2 Tie 7 6.276 33.5 10,362.6 6,645.3 26.00 L-80 BTC-M sssv.2.116.1 1111 . -_ back. _ Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread INTERMEDIATE#2 7 6.276 10,349.7 11,409.9 6,982.5 26.00 L-80 Tenaris Blue (E L Lower Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 41/2 3.958 11,016.9 14,090.0 6,975.2 12.60 L-80 Hydril 563 Liner Details Nominal ID SURFACE;36.5-2,670.2 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 11,016.9 6,908.6 76.51 PACKER HRD LINER TOP ZXP PACKER 4.340 GAS LIFT;4,534.411,036.9 6,913.1 77.31 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4.250 11,039.8 6,913.7 77.42 HANGER 'DG'FLEX LOCK LINER HANGER 4.350 11,049.0 6,915.7- 77.79 SBR SEAL BORE EXTENSION 4.000 GAS LIFT;8,510.4 11,669.9 6,985.7 93.02 Swell Packer TAM FreeCap Swell packer FSC-11 w/5.75"OD 3.958 Cementralizer 11,726.3 6,982.8 92.49 Swell Packer TAM FreeCap Swell packer FSC-11 w/5.75"OD 3.958 11:1 wC Cementralizer INTERMEDIATE l2 T back.; I I -„ 33.5-10,362.6 Tubing Strings "I Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection [! ITS TUBING 31/2 2.992 31.1 11,055.8 6,917.1 9.30 L80 EUE MOD 4.5"03.5"@114' II Completion Details GAS LIFT;10,483.9 - Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 31.1 31.1 0.00 HANGER FMC TUBING HANGER 3.900 ; A 1 114.7 114.7 0.29 XO- Crossover 4-1/2"IBT-m box x 3-1/2"EUE-m pin 3.500 Reducing 2,118.1 1,997.2 43.94 SSSV 3-1/2"TRMAXX-5E SSSV w/2.812""X"profile w/1/4" 2.812 GAUGE;10,899.3 control line(5.176"OD) 10,6993 6,804.0 66.50 GAUGE SLB BHP Guage,3-1/2" 2.992 PACKER;10,7223 M 10,722.3 6,813.0 67.25 PACKER BAKER PREMIER PACKER 2.870 -ill- 10,803.7 6,843.8 68.58 SLEEVE-0 BAKER CMD SLIDING SLEEVE(OPENED 72314) 2.812 GAS LIFT;10,7448 (y: 10,947.7 6,890.8 73.74 Blast Joint BLAST JOINT(1) 2.867 INTERMEDIATE at; - 7 2,4 . 11,007.2 6,9063 76.12 NIPPLE HES"X"LANDING NIPPLE 2.813"ID 2.813 10,753.092957- 11,014.9 6,908.1 76.43 SEAL ASSY BAKER3-1/2"GBH-22 LOCATING SEAL ASSEMBLY 2.970 MI (39.65'to 5"OD locator) SLEEVE-O;10.803.7 1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl ill Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) L 11,118.0 6,930.1 77.84 PLUG-Milled COMPOSITE BRIDGE PLUG-LEAKING IN 12/28/2012 0.000 PERF,10,960.0.10,974.0 1 LOWER COMPLETION-MILLED HOLE IN CIBP 2/1/2013 Elli Perforations&Slots NIPPLE;11,007.1 Shot .. Dens Top(TVD) Btm(ND) (shots/ SEAL ASSY;11,014.9 "--` Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 1=1 10,960.0 10,974.0 6,894.2 6,898.0 K-1,KUP-C, 1/3/2013 5.0 IPERF All shots fired ` CD1 47 ■- 11,792.1 11,796.9 6,980.9 6,980.8 ALP-C,CD1- 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER PLUG-Milled,11,118.0 47 PERF PUP 12,119.1 12,123.9 6,981.5 6,981.5 ALP-C,CD1- 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER 47 PERF PUP INTERMEDIATE 42 Lower; 12,443.1 12,447.9 6,978.3' 6,978.2 ALP-C,CD1- 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER 10,349.7-11,409.9 47 PERF PUP 12,765.7 12,770.4 6,971.8 6,971.7 ALP-C,CD1- 12/28/2012 1.0 PERFP 'SIX 1/2"HOLES PER a'liiir 47 PERF PUP 13,092.8 13,097.5 6,974.9 6,975.1 ALP-C,CD1- 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER 47 PERF PUP jiiiiiie 13,412.1 13,416.8 6,985.4 6,985.4 ALP-C,CD1- 12/28/2012 1.0 PERFP �SIX 1/2"HOLES PER I 47 PERF PUP I13,732.8 13,737.6 6,980.9 6,980.9 ALP-C,CD1- 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER PERFP;11,792.1-11,798.8 1'' 47 PERF PUP 14,062.5 14,067.2 6,976.2' 6,976.0 ALP-C,CD1- 12/28/2012 1.0 PERFP 'SIX 1/2"HOLES PER PERFP;12,119.1-12,123.9 47 PERF PUP PERFP;12,443.1-12,447.9 Stimulations&Treatments Proppant Designed(lb) Proppant In Formation(lb) Date 3/1/2013 PERFP;12,765.7-12,770.4 FRAC;11,792.0 Stimulations&Treatments Vol Clean Pump PERFP;13,092.8-13,0925 Stg A Top(ftKB) Wm(ftKB) Date StimfTreat Fluid (bbl) Vol Slurry(bbl) • 1 11,792.0 14,067.03/1/2013 PERFP;13,412.1-13,416.8 IT Mandrel Inserts St PERFP;13,732.8-13,737.6 I Er alt on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com PERFP;14,082.5-14,087.2 It 1 4,534.5 3,389.1 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,835.0 7/18/2014 2 8,510.4 5,614.4 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,726.0 7/18/2014 LINER;11,016.9-14,090.0 I I • i Loepp, Victoria T (DOA) From: Mustafin,Ilnur <Ilnur.Mustafin@conocophillips.com> Sent Wednesday, May 24,2017 12:48 PM To: Loepp,Victoria T(DOA) Subject: RE:CRU CD1-47(PTD 212-083, Sundry 317-202) Set K-valve Attachments: CD1-47 Form 10-403 5.16.17.pdf;CD1_47_10-403_5_16_17.docx Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thanks for your reply and time reviewing the well case. Please,see an attached document with requested information. Just for reference, I also attached the Sundry application previously sent by mail. Regards, ILNUR From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, May 23, 2017 9:33 AM To: Mustafin, Ilnur<llnur.Mustafin@conocophillips.com> Subject: [EXTERNAL]CRU CD1-47(PTD 212-083,Sundry 317-202)Set K-valve Ilnur, Please include the calculation summary/printout for setting the K valve in the sundry. Also include well history and background that you previously communicated in emails in your submission. You may email this information to me. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCcilalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov 1 S S •Loepp, Victoria T (DOA) From: Mustafin,Ilnur <Ilnur.Mustafin@conocophillips.com> Sent: Wednesday, May 17, 2017 10:46 AM To: Loepp,Victoria T(DOA) Subject: RE:CD1-47 (PTD 212-083) SSSV repair Follow Up Flag: Follow up Flag Status: Completed I'll do! Thanks Victoria. Regards, ILNUR From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday, May 17, 2017 10:44 AM To: Mustafin, Ilnur<Ilnur.Mustafin@conocophillips.com> Subject: [EXTERNAL]RE:CD1-47(PTD 212-083)SSSV repair Two hardcopies are required to our office- Thx, Victoria From:Loepp,Victoria T(DOA) Sent:Tuesday, May 16,2017 4:54 PM To:Mustafin, Ilnur<Ilnur.Mustafin@conocophillips.com> Subject: Re: CD1-47(PTD 212-083)SSSV repair Please submit a sundry for continued use of the k valve. Thanx, Victoria Sent from my iPhone On May 16,2017,at 3:57 PM, Mustafin, Ilnur<Ilnur.Mustafin@conocophillips.com>wrote: Victoria, CD1-47 is an Alpine C-Sand producer.The well was closed due to a fish stuck at the subsurface safety valve in January 2015. Multiple attempts were made to retrieve the fish. It was retrieved in March 2017, but the tubing retrievable subsurface safety valve is not operating properly. The plan is to set a K-valve to operate as the subsurface safety valve. With your approval the well was brought on production on March 20th 2017 without an operating subsurface safety valve for a period of 2 weeks to obtain pressure and temperature data in order to calibrate properly the K-valve. 1 • S Please, see an attached Application for setting a K-valve. In summary,our plan forward will be as follows: 1. Keep the well shut in till K-valve is installed. 2. Set the closing pressure of the K-valve based on pressure and temperature survey from March 2017 and install the valve 3. Stabilize well with K-valve installed and perform witnessed closure test. 4. Incorporate the K-valve test frequency into the current SVS testing cycle at CD1 pad. Please, let me know if you have any questions. Regards, ILNUR Ilnur Mustafin Production Optimization Engineer ConocoPhillips Alaska Phone: 907-263-4039 Email: ilnur.mustafin@conocophillips.com <CD1-47 Form 10-403 5.16.17.pdf> 2 • • PIPJ 2J2 —O ' 3 Loepp. Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday, March 22, 2017 10:07 AM To: NSK Well Integrity Supv CPF3 and WNS Subject: RE:CRU CD1-47 (PTD#212-083) Subsurface Safety Valve Request Rachel, Approval is granted for flowing CD1-47 for two weeks without a SSSV to obtain data for calibrating the k-valve. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission �� f ,p, c 4 sli` 't.: 333 W.7th Ave Anchorage,AK 99501 S1a� Work: (907)793-1247 Victoria.Loec oaalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From: NSK Well Integrity Supv CPF3 and WNS [mailto:n2549@conocophillips.com] Sent:Wednesday, March 22, 2017 10:02 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject:CRU CD1-47(PTD#212-083)Subsurface SafetyValve Request 1 q Victoria, I just wanted to touch base to see ifyou had the chance to review the proposal sent on Monday, regarding flowing p p g g producer CD1-47 without a working subsurface safety valve for two weeks to allow production to stabilize so we can obtain data with gauges to calibrate a K-valve for the well. CPAI would like to move forward with the work soon, if approval is granted. Please let us know if you need any further information or have any questions. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 From: NSK Well Integrity Supv CPF3 and WNS Sent: Monday, March 20,2017 1:56 PM To:'Loepp,Victoria T(DOA)'<victoria.loepp@alaska.gov> 1 • • Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject:CRU CD1-47(PTD#212-083)Subsurface Safety Valve Request Victoria, CRU CD1-47(PTD#212-083) is a producer that has been shut-in due to a fish that was stuck at the subsurface safety valve. The fish was recently recovered, but the tubing retrievable subsurface safety valve is not operating properly. The plan is to set a K-valve to operate as the subsurface safety valve; however,the K-valve needs to be designed to operate at the temperature and pressure conditions it will see during stabilized production at the depth it will be set. CPAI is requesting permission to bring the well on production without an operating subsurface safety valve for a period of 2 weeks to allow production to stabilize to obtain pressure and temperature data for properly calibrating the K- valve. Gauges will be set near the tubing retrievable subsurface safety valve during the 2 week period to obtain the stabilized pressure and temperature data. CPAI intends to test the surface safety valve system within the normal testing time frame after the well is brought on production. Please let me know if you agree with this plan or have any questions. Also, please advise me if you are not the correct person at AOGCC to contact for this request. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 2 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. ai cZ- 0 9 3 Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RES AN: OVERSIZED: NOTES: Col r Items: ❑ Maps: rayscale Items: Logs: ❑ Poor Quality Originals: gher: sf''E•RABLE pLLtNG- Litslark sl srem .C;D. ❑ Other: Li5y...6fl Sl2E )BY: Maria Date: `1l 04 /s/ Project Proofing BY: di= Date: ` i `g l� /s/ � Scanning Preparation Co x 30 = IOD + (:> 2o (Count does not include cover sheet) BY: AIM Date: I I I v 1 /s/ ii Production Scanning Stage 1 Page Count from Scanned File: c2 0 I (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: i., :'ES NO BY: deD Date: i I I g t I it+ /s/ 0410 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc o o 0 6 4- ..- N 15 N_ N O .-7:', ()co a• �i co '.- :.0 a7 • y (II Zas N ,- E E as E E _1 o o U C6E E E rn rn N. ¢ r5 as 0 OI N. 0) 01 • U U N "' - } U d d U N N a> ai co ai 0) H N O J W n- v v H o Z E g E g .E . Z E N >. > v v QI I I Z I CO .O.. co vi C N MI NI = C V D 2I 2I 2 2 N N >_ a) (n W W W Q I C @ Il Z Il WZ LUL a' j�O u) I 2 2 2 �2 2 Fc u3 0 O II 2 -� -0 , 0 W 'c0 N > N 0 W 0 a JI 11 N N N'- 0 N 0'- J N N c _ J ! i O wIu)O1 co I (n MI UO QMI J co CO wI it 2 2 2 P F- J U O C fa O coo N O m o J � a) as N a) as N a) J W Z o d'D D'� LE '� i� O it it it it it it it O C N E u o c c U� cs 10 0 000 U� E o O 0 0 0 0 0 0 0 0 18 o W o 0 0 0 0 0 0 0 0 E N c15 J U z 5U tU tU oQ it2 0 0 U 0 0 0 0 oQ 0 I— J _ � ,I ^I �nl �nl NILuNNa) N a) LO a) a) a) N W U Ce €:( c E W sr W W W a N I W 2 W W W W W W W N 2 �' 4 I S I O. 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Q .3 �/�/ Q m ��ppjj O Ce Q J O cn a 5 To co CL D W LL d m m U LL E O co MI Z m vi N -J m0 n V v o E 3 E zco N w co a0+ O N N I _< f0 u) n c J o. c = 0 5 I 0 aU U I C c I G O . 1 N a I I O r EO I 4 N V /� a I o LJ } O E N Q I pra0. r U E j E ! U II 1I 6 = F c- O 1 I z otz — z I 1 i'I 2 `° CO > m co I I o F— E Il L/1 U) J III C• .�n O E U L TH Z o v H 0 E 0 o 0 III H 1 co I TD co N 3 v ¢n ! N. N N co _ >" p N H N w C O t co ''i d c ce n 12 I ui y Z N N Y w m Q' o _O C m 0 a ui C I N H C C Z c f0 C o 2 r 0 g 11 J '� d d 1a U E O n vD o n c 0 E t E ` N LL O O` u) O O u) d ' O O a M 1 ? U a 0 0 c) C 1U U l'Z-V 3 BAKER PRINT DISTRIBUTION LIST DATA LOGGED X201 HUGHES :rl. K BENDER COMPANY ConocoPhillips Alaska Inc. INTERMEDIATE FINAL Yes (mandatory` WELL NAME CD1-47 ST01 RUN NUMBER (mandatory) FIELD Colville River BH SALESMAN Christian Klotz (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: December 26,2012 TODAYS DATE: 12-Aug (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Paul Canizares HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY FIELD FINAL (digitalCD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #UI-PRIN I S #OF COPIES #OF COPIES n v v J J v 1 ,State of Alaska -AOGCC _ [, I 1 Attn:•Makana Bender 1333 W.7th Ave,Suite 100 'Anchorage,Alaska 99501 %4�°lc+~(�C�'^�on-17 WV 01.",1 I `i 2z.I,—o A �C.`O``\—' t� 2 ��� - } AZ V Ci�M.GiL.,.K\.... I AUG ' 2 2014 I %1tZ A4, ) ; 3 ACK4CC I I 1 I 4 7 I I I I I 5i — - - I I I I 6; I I I I I TOTALS FOR THS PAGE: 0 1 1 0 0 0 ' • STATE OF ALASKA ALAS! IL AND GAS CONSERVATION COMM IN REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon r Repair w ell r Rug Perforations r Perforate rOther r Perforation Alter Casing r Pull Tubing r Stimulate-Frac Waiver r Breakdown r r Time Extension Change Approved Program rOperat Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: _ConocoPhillipsAlaska, Inc. Development r Exploratory r 212-083-0 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service f 50-103-20659-00 7.Property Designation(Lease Number): 8.Well Name and Number. ADL 25558,25538,25559 CD1-47 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 14120 feet Plugs(measured) 11118 true vertical 6974 feet Junk(measured) none Effective Depth measured 14090 feet Packer(measured) 10722, 11017 true vertical 6975 feet (true vertical) 6813, 6909 Casing Length Size MD ND Burst Collapse CONDUCTOR IN: 78 16 114 114 SURFACE 2634 11.75 2670 2325 INTERMEDIATE 8260 9.625 10753 6825 INTERMEDIATE 1060 7 11410 6982 RECEIVED LINER 3073 4.5 14090 6975 AUG 0 1 2 +y Perforation depth: Measured depth: from 10960'-14067' ,{4Q(3CC True Vertical Depth: 6894'-6976 Tubing(size,grade,MD,and TVD) 4.5 x 3 5, L-80, 11056 MD,6917 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PACKER @ 10722 MD and 6813 TVD PACKER-HRD LINER TOP ZXP PACKER @ 11017 MD and 6909 TVD SSSV-CAMCO TRMAXX-5E SSSV @ 2118 MD and 1997 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10960'-10974' Treatment descriptions including volumes used and final pressure: 720 bbls seawater 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 163 1228 11 -- 139 Subsequent to operation 234 1497 48 -- 151 14.Attachments 15 Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16 Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt 314-344 Contact Michael Dammeyer @ 265-6548 Email Michael.Dammeyer@conocophillips.com Printed Name Michael Dammeyer Title Senior Production Engineer Signature Phone:265-6548 Date Co�� — 7/71)19 l/L/=- RBCMS AUG - 1 k.6k fdI� i4- Form 10-404 Revised 10/2012 / //��j Submit Original Only NS PROD CD1-47 ConocoPhillips ell Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl I') MD(ftKB) Act Btm(ftKB) 501032065900 ALPINE PROD 93.08 11,611.16 14,120.0 ... Comment H2S(ppm) Date Annotation End Date KB•Grd(ft) 1 Rig Release Date HORIZONTAL-CD1-47,724201411.10.26 AM SSSV:TRDP Last WO: I 1/10/2013 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER:31.1- ,.4,ArA, Last Tag: Rev Reason:GLV CIO,PULLED FRAC SLEEVE lehallf 7/24/2014 =. Casing Strings Casing Description OD(in) ID(in) Top(ftKB) I Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread • • CONDUCTOR Insulated 16 15.062 36.0 114.0 114.0 62.50 H-40 WELDED • • Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1...'Grade Top Thread CONDUCTOR Insulated 34'; • SURFACE 113/4 10.772 36.5 2,670.2 2,324.8 60.00 L-80 BTCM 36.0.114.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread am INTERMEDIATE#1 95/8 8.799 2,492.7 10,753.0 6,824.8 40.00 L-80 Hyd 521 in Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(L..Grade Top Thread 1.1 INTERMEDIATE#2 Tie 7 6.276 33.5 10,362.6 6,645.3 26.00 L-80 BTC-M SSSV;2.118.1 43k. back. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(L..Grade Top Thread INTERMEDIATE#2 7 6276 10,349.7 11,409.9 6,982.5 26.00 L-80 Tenaris Blue Lower Casing Description OD(in) ID(in) Top(ftKB) -Set Depth(kKB) Set Depth(ND)... WtlLen 0...Grade Top Thread LINER 41/2 3.958 11,016.9 14,090.0 6,975.2 12.60 L-80 Hydril 563 Liner Details SURFACE:36.5.2,670.2 Nominal ID . Top(ftKB) Top(ND)(ftKB) Top Incl yl Item Des Com (in) GAS LIFT,4,534.4 11,016.9 6,908.6 76.51 PACKER HRD LINER TOP ZXP PACKER 4.340 11,036.9 6,913.1 77.31 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4.250 11,039.8 6,913.7 77.42 HANGER 'DG'FLEX LOCK LINER HANGER 4.350 GAS LIFT,8,510.4 • I, MI 11,049.0 6,915.7 77.79 SBR SEAL BORE EXTENSION 4.000 11,669.9 6,985.7 93.02 Swell Packer TAM FreeCap Swell packer FSC-11 w/5.75"OD 3.958 ss. Ass Cementralizer L. W 11,726.3 6,982.8 92.49 Swell Packer TAM FreeCap Swell packer FSC-11 w/5.75"OD 3.958 INTERMEDIATE i2 Tie back.; I. 33.5-10,362.6 = Cementralizer i •i Tubing Strings �' Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection AI K TUBING 31/2 2.992 31.1 11.055.8 6.917.1 9.30 L80 EUE MOD 4.5"x3.5"@114' Completion Details GAS LIFT,10,483.9 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl p) Item Des Corn (in) 31.1 31.1 0.00 HANGER 'FMC TUBING HANGER 3.900 • 114.7 114.7 0.29 XO-Reducing Crossover 4-1/2"IBT-m box x 3-1/2"EUE-m pin 3.500 2,118.1 1,997.2 43.94 SSSV 3-1/2"TRMAXX-5E SSSV w/2.812""X"profile w/1/4" 2.812 GAUGE;10,699.3 - control line(5.176"OD) 11 10,699.3 6,804.0 66.50 GAUGE SLB BHP Guage,3-12" 2.992 PACKER;10,722.3 4 10,722.3 6,813.0 67.25 PACKER BAKER PREMIER PACKER 2.870 GAS LIFT;10744.6 10,803.7 6,843.8 68.58 SLEEVE-0 BAKER CMD SLIDING SLEEVE(OPENED 7 23 14) 2.812 INTERMEDIATE 91;1264;797.0-_2. 10,947.7 6,890.8 73.74 Blast Joint BLAST JOINT(1) 2.867 • 11,0072 6,906.3 76.12 NIPPLE HES"X"LANDING NIPPLE 2.813"ID 2.813 11,014.9 6,908.1 76.43 SEAL ASSY BAKER3-12"GBH-22 LOCATING SEAL ASSEMBLY 2.970 SLEEVE-O;10.603.7 (39.65'to 5"OD locator) Mi Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) IIITop(TVD) Top Inc! Top(ftKB) (kKB) 1') Des Com Run Date ID(in) (PERF;10960.0-10.974.0-_ II 11.118.0 6.930.1 77.84 PLUG-Milled COMPOSITE BRIDGE PLUG-LEAKING IN LOWER 12/28/2012 0.000 = COMPLETION-MILLED HOLE IN CIBP 2/1/2013 NIPPLE;11,007.1 ' Perforations&Slots Shot SEAL ASSY;11,014.9 : S Dens Top(ftKB) Btm(ftKB) T op(TV D) Rim(ftK(B D) Zone Date lshlt(oType Corn 10,960.0 10,974.0 6,894.2 6,898.0 K-1,KUP-C, 1/3/2013 5.0 IPERF Alt shots fired CD1-47 PLUG-Milled;11,118.0 11,792.1 11,796.9 6,980.9 6,980.8 ALP-C,CD1- 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER Iii 47 PERF PUP 12,119.1 12,123.9 6,981.5 6,981.5 ALP-C,CD1- 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER T'r-- 47 PERF PUP INTERMEDIATE 92 Lower; 10349.741,409.9 12,443.1 12,447.9 6,978.3 6,978.2 ALP-C,CD1- 1225/2012 1.0 PERFP SIX 1/2"HOLES PER 47 PERE PUP 12,765.7 12,770.4 6,971.8 6,971.7 ALP-C,CD1- 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER 47 PERF PUP 13,092.8 13,097.5 6,974.9 6,975.1 ALP-C,CD1- 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER 47 PERF PUP 13,412.1 13,416.8 6,985.4 6,985.4 ALP-C,CD1- 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER 47 PERF PUP PERFP;11,792.1-11,796.9 13,732.8 13,737.6 6,980.9 6,980.9 ALP-C,CD1- 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER 47 PERF PUP PERFP;12.119.1-12423.9- 14,062.5 14,067.2 6,976.2 6,976.0 ALP-C,CD1- 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER 47 PERF PUP ll • PERFP;12.443.1-12,447.9 ititi Stimulations&Treatments Min Top Max Elm Depth Depth Top(TVD) Bim(TVD) PERFP;11765.7-12,770.4 '.:C i (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com FRAC;11.792.0 11,792.0 14,067.0 6,980.9 6,976.0 FRAC 3/1/2013 ALPINE C-SAND FRAC with a three-stage fracturing PERFP;13,092.9-13,097.5 treatment using bioballs to obtain diversion.Pumped 2-7 ppa 1620 Carbolate stages in 25#crosslink gel at 20- bpm.Placed total of 428,306#proppant(106%design) PERFP;13.412.1-13.4168 I with 4055.0-bbl total slurry volume. Mandrel Inserts PERFP;13.732.8-13.737.6 St II ■ ata on Top(ND) Valve Latch Port Sian TRO Run PERFP;14,062.5-14.067.2 N Top(ftKB) (ftKB) Make Model OD(in) Seri/ Type Type (In) (psi) Run Date Corn -{ 4,534.5 3,389.1 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,835.0 7/18/2014 LINER;11.016.9-14.090.0 $ WNS PROD CD1-47 ConocoPhillips 04' Alaska.Inc. Lanasint1yfs HORIZONTAL-CD1-47,7/24/2014 11.10.26 AM Vertical schematic(actua8 HANGER',31 1— w.__tl;Jx .14 Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run i's-4``N Top(flKB) (ttKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com CONDUCTOR Insulated 34'; l 2 8,510.4 5,614.4 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,726.0 7/18/2014 36.0-114.0 '= 3 10,483.9 6,707.7 Camco KBMG 1 GAS LIFT OV BK 0.250 0.0 7/15/2014 s4 10,744.8 6,821.7 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/6/2013 III SSSV;2,118.1 :—, a. SURFACE,36.5-2,670.2 GAS LIFT,4.534.4 imi 1... GAS LIFT;8510.4 Ir .. •1 INTERMEDIATE 62 Tie back., 33.5-10,362.6 � ■i 15 12! a GAS LIFT,10.483.9 I GAUGE;70,899.3 - g PACKER;10,722.3 - GAS LIFT;10,744.8 1111 INTERMEDIATE#1;2,492.7- _ 10,753.0 II SLEEVE-O;10,803.7 it Mil IPERF;10,960.0.10.974.0— I. ait 1111 NIPPLE;11,007.1 _ 0 SEAL ASSY;11,014.9 i I PLUG-Milled;11,118.0 ii INTERMEDIATE 49Lower; , 10,3497-11,409.9 0,3 TE.#2 o0 9 9 U. I PERFP;11,792.1-11.796.9 '■'III I/CE 1 PERFP;12,119,1-12,123.9 • :tiE':U ■ PERFP;12,443.1-12,447.9 ?Eli ■ PERFP;12,765.742,770.4 hili FRAC;11,792.0 ■ PERFP;13,092.8-13,097.5 3-1i I PERFP;19412.1-13,416.8 rili PERFP;13,732.8-13,737.6 11-1 PERFP;14,062514,067.2 gi7 LINER;11,016.9-14090.0 CD1-47 perforation breakdown on 7/14/2014 The Alpine was plugged off and the Kuparuk opened prior to the HPBD. 720 bbl SW was pumped into the Kuparuk at' 3,500 psig in four stages. A maximum of 3,707 psig recorded. When BOL the Kuparuk showed initial production. The Alpine was then restored to production. 7>, ,. 1//7''e� 'ATE STATE ./- _,1 E' 1.,_. = T21EE _ ?yam=K .- � 333 West Seventh A cn�e 'q Anchorage C l)1'LI�\OR SI:.1\ FAIZ\F.LI_ Anchorage, AlasKo 9951-3572 main 967 2_75 1433 Michael Dammeyer Senior Production Engineer ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD1-47 Sundry Number: 314-344 Dear Mr. Dammeyer: 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, P44-4-41&-. Cathy P oerster Chair DATED this 4-tday of June, 2014. Encl. • STATE OF ALASKA RECEIVED AL,_.KA OIL AND GAS CONSERVATION COMM-_SON APPLICATION FOR SUNDRY APPROVALS MAY 3,0 2,o 14 20 AAC 25.280 67S 6/3 //N4— 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change l O , r Suspend r Rug FFrforations r FFrforate r Pull Tubing r Time Extension 17 Operational Shutdow n r Re-enter Susp Well r Stimulate F • Alter casing r P r,--r 1:tT v` Other: b,-��t-lcdo...., 2.Operator Name. 4.Current Well Class: 5.Permit to Drill Number: f,U` + ConocoPhillips Alaska, Inc. , Development F , Exploratory r 212-083-0 • 5,3 3.Address: Stratigraphic r Service r 6 API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20659-00• 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception") Yes r No r , CD1-47 • 9.Property Designation(Lease Number). 10.Field/Pool(s). ADL 25558,25538,25559 • Colville River Field/Alpine 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): 14120 • 6974 ' 14090' " 6975' • 11118' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114' 114' SURFACE 2634 11.75 2670' 2325' INTERMEDIATE 8260 9.625 10753' 6825' INTERMEDIATE 1060 7 11410' 6982' LINER 3073 4.5 14090' 6975' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft). from 10960'-14067' 6894'-6976 4.5 x 3.5 L-80 11056 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER PREMIER PACKER MD=10722 TVD=6813 PACKER-HRD LINER TOP ZXP PACKER MD=11017 TVD=6909 SSSV-CAMCO TRMAXX-5E SSSV MD=2118 TVD=1997 12 Attachments: Description Sunrnary of Proposal F.-.7, 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic f Development Service r 14.Estimated Date for Commencing Operations. 15. Well Status after proposed work: 6/6/2014 Oil T.-.7 • Gas r WDSPL r Suspended 1--- 16. 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Michael Dammeyer @ 265-6548 Email. Michael.Dammever[7a conocophillips.con Printed Name Michael Dammeyer Title: Senior Production Engineer Signature —Wiz_ -- Phone:265-6548 Date zr/2.0401/ Commission Use Only SundryNumber: 3i-V4 of approval: Notify Commission so that a representative may witness �" Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: RBDM _ JUN 0 6 2(14 Spacing Exception Required? Yes ❑ No V Subsequent Form Required: /0 —4 o 4- APPROVED BY / c(----/(f / Approved by: f19COMMISSIONER THE COMMISSION Date: (L !�/ Approved appllcatlpr�s TN0Atonths trom the date of approval. p Form 10-403(Revised 10/2012) ORI (�J� Ph 5130 Submit Form and Attachments in Duplicate VLA'�/3/l4 . ,,-- ,y ,-- WNS CD1-47 CCMOCOPhillipS ' a , Well Attributes Max Angle&MD TD ,�Inc. Wellbore APUUWI Field Name Well Status Incl(") MD(ftKB) Act Btm(ftKB) Alask , 501032065900 ALPINE PROD 93.08 11,611.16 14,120.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date •••Well ConS9 HORIZONTAL-CD1-47.32120139:10:58 AM SSSV:TRDP Last WO: 1/10/2013 Schematic-Auual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date _Last Tag: Rev Reason:ADD PERF ZONES osborl 3/21/2013 HANGER,31---mr _j - Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 36.0 114.0 114.0 62.50 H-40 WELDED Insulated 34" ,________ _7 I _ I -Casing Description String 0... String ID...Top(RKB) Set Depth(f...Sat Depth(TVD)_.String WL..String...String Top Thrd SURFACE 113/4 10.772 36.5 2,670.2 2,325.0 60.00 L-80 BTCM CONDUCTOR Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String_.String Top Thrd Insulated 31'. INTERMEDIATE#1 95/8 8.799 2,492.7 10,753.0 6,824.6 40.00 L-80 Hyd 521 36-114 1=11 Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)_.String Wt..String_.String Top Thrd INTERMEDIATE#2 7 6.276 33.5 10,362.6 6,645.0 26.00 L-80 BTC-M NUM SSSV,2,118 IIIIIN Tie back. FRAC SLEEVE. (-� I Cuing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(ND)...String WL..String...String Top Thrd 2,118 INTERMEDIATE#2 7 6.276 10,349.7 11,409.9 6,982.4 26.00 L-80 Tenaris Blue - Lower Casing Description String 0... String ID. Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd LINER 41/2 3.958 11,016.9 14,090.0 6,975.0 12.60 L-80 Hydril 563 r Liner Details Top Depth SURFACE, (TVD) Top Inet Nomi... 37.2.670 -- Top(ftKB) (RKB) I") Item Description Comment ID(In) NM GAS LIFT. � 11,016.9 6,909.3 78.40 PACKER HRD LINER TOP ZXP PACKER 4.340 1.53/ 11,036.9 6,913.3 78.29 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4.250 III11,039.8 6,913.9 78.28 HANGER 'DG'FLEX LOCK LINER HANGER 4.350 GAS LIFT,_.. 11,049.1 6,915.8 78.22 SBR SEAL BORE EXTENSION 4.000 8,510 I (. 11,669.9 6,985.7 93.02 Swell Packer TAM FreeCap Swell packer FSC-11 w/5.75"OD Cementralizer 3.958 11,726.3 6,983.5 92.09 Swell Packer TAM FreeCap Swell packer FSC-11 w/5.75"OD Cementralizer 3.958 4 INTERMEDIATE Tubing Strings 112 To back., Z.ri Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...StringString... StringTop Wt... Thrd 34.10.383 TUBING 3 1/2 2.992 31.1 11,055.8 6,917.1 9.30 L80 EUE MOD I . L 4.5"x3.5"@114' -L7 Completion Details Top Depth OEN (ND) Top Incl Nomi... GAS LIFT, t Top(ftKB)., MKS/ (") Item Description Comment ID(In) 10'� N31.1 31.1 -0.02 HANGER FMC TUBING HANGER 3.900 I I1 114.7 114.7 -0.41 XO-Reducing Crossover 4-12"IBT-mbox x3-12"EUE-mpin 3.500 1 2,118.1 1,996.6 43.96 SSSV 3-1/2"TRMAXX-5E SSSV w/2.812""X"profile w/1/4"control line(5.176" 2.812 _ OD) GAUGE.10899-. 10,699.3 6,803.9 66.50 GAUGE SLB BHP Guage,3-1/2" 2.992 IMO 10,722.3 6,813.0 67.25 PACKER BAKER PREMIER PACKER 2.870 PACKER. RIM_ 10,722 10,803.7 6,841.8 67.81 SLEEVE-C BAKER CMD SLIDING SLEEVE(CLOSED 2/152013) 2.812 GAS LIFT, 10,947.7 6,890.7 73.74 Blast Joint BLAST JOINT(i) 2.867 10,745 11,007.2 6,907.4 78.46 NIPPLE HES"X"LANDING NIPPLE 2.813"ID 2.813 INTERMEDIATE e1•- • 11,014.9 6,908.9 78.41 SEAL ASSY BAKER3-1/2"GBH-22 LOCATING SEAL ASSEMBLY(39.65'to 5"OD 2.970 2.49310,753 locator) SLEEVE-C, { Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) • 10,804 s e Top Depth • (TVD) Top not '-' Top(ftKB) (RKB) (") Description Comment Run Date ID lin) (PERF, - i .I 2,118.1 1,996.6 43.97 FRAC SLEEVE 2.81"FRAC SLEEVE(OAL=80")SET IN SSSV 3/18/2013 10.96x10.9741,�j_-- Li 11,118.0 6,929.7 77.18 PLUG-Milled COMPOSITE BRIDGE PLUG-LEAKING IN LOWER 12/28/2012 0.000 COMPLETION-MILLED HOLE IN CIBP 2/12013 NIPPLE.11,007 Ca Perforations&Slots Shot SEAL ASSY, Top(ND) Btm(TVD) Dens 11.015 Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (eh- Type Comment 10,960.0 10,974.0 6,894.2 6,901.1 K-1,KUP•C, 1/42013 5.0 IPERF All shots fired 1 l CD1-47 PLUG-Milled, I I 11,792.1 11,796.9 6,980.9 6,980.8 ALP-C,CD1-47 12/28/2012 1.0 PERFP SIX 12"HOLES PER PERF PUP 11.116 -111111 12,119.1 12,123.9 6,981.7 6,981.6 ALP-C,CD1-47 12282012 1.0 PERFP SIX 12"HOLES PER PERF PUP D iiini 12,443.1 12,447.9 6,978.3 6,9782 ALP-C,CD1-47 12/28/2012 1.0 PERFP SIX 12"HOLES PER PERF PUP INTERMEDIATE 12,765.7 12,770.4 6,972.3 6,972.2 ALP-C,CD1-47 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER PERF PUP #2 Lower, 10,35611,410 13,092.8 13,097.5 6,975.9 6,975.9 ALP-C,CD1-47 12/28/2012 1.0 PERFP SIX 12"HOLES PER PERF PUP 1104111 13,412.1 13,416.8 6,985.4 6,985.4 ALP-C,CD1-47 12282012 1.0 PERFP SIX 1/2"HOLES PER PERF PUP 13,732.8 13,737.6 6,980.9 6,980.9 ALP-C,CD1-47 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER PERF PUP 14,062.5 14,0672 6,976.2 6,976.0 ALP-C,CD1-47 1228/2012 1.0 PERFP SIX 1/2"HOLES PER PERF PUP 61111 PERFP, 17,792-11.797 12,11a72R 24 ATM Mandrel Details Top Depth Top Port PERFP, S... (ND) Incl OD Valve Latch Size TRO Run 12,44312,448 ICU N...Top(ftKB) (RKB) 1°) Make Model (in) Sew Type Type (in) (pal) Run Date Com... PERFP, - 1 4,534.5 3,389.2 55.01 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,835.0 3/13/2013 12,76612,770 MOM 2 8,510.4 5,614.3 56.12 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,726.0 3/12/2013 FRAC.11.792 PERFP, 3 10,483.9 6,707.0 60.66 Camco KBMG 1 GAS LIFT OV BK 0.250 0.0 3/12/2013 73,093-73.099 4 10,744.8 6,821.3 66.91 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/6/2013 PERFP, 13,412-13.417 MEM PERFP, 13,73313,738 LEM PERFP, �- 14,062-14,067 I LINER. 11617-14690 [ TD(CD1-47). a 11.120 ` WNS CD1-47 ConocoPhillips ,3 Alaska,Inc. Cacewtwaps KB-Grd(1t) Rig Release Date ••• _ 1/10/2013 Well Conry:HORIZONTAL matic- dual /101394C.SB AM _.. ._ Schematic-Actual HANGER,31 '�. Stimulations&Treatments Illlllll� Bottom B` Min Top Max Btm Top Depth Depth Depth Depth (NO) (TVD) _ _ (RKB) (RKB) (RKB) (KKB) Type Dab Comment _ _ - - _-- 11,792.0 14,067.0 6,980.9 6,976.0 FRAC 3/12013 ALPINE CSAND FRAC with a three-stage fracturing CONDUCTOR treatment using bioballs to obtain diversion. Pumped Insulated 34. I 2-7 ppa 16/20 Carbolate stages in 25#crosslink gel at 38.114 wrs 20-bpm.Placed total of 428,306#proppant(106% design)with 4055.0-bbl total slurry volume. MIS SSSV,2,118 NMI FRAC SLEEVE, e 4 I 2,118 ( SURFA37-2 ,670 CE._ J GAS LIFT,_ " 4,534 _ GAS LIFT, INN 8,510 A INTERMEDIATE s2 Tie back., ►�� errol 3x10,363 D-1 1 1-0 I .1 GAS LIFT, _ 10,484 GAUGE,10,699— PACK,772ER, _ 10 GAS LIFT,__ 10,745 INTERMEDIATE sL— 2,493-10,753 t)• SLEEVE-C._ {e • 10,804 (PERF, L r--�I 10,960.10,974--- E` NIPPLE,11,007 SEAL A1S,01SY, 1 $ PLUG-Milled, 11.118 INTERMEDIATE 1.1 02 Lox 10,350.11,410 tining PERFP, ■! 11,792-11,797 PERFP, _1r 12,119.12,124 PERFP, CLIP 12,443-12.448 PERFP, 12.766-12.770 S :. FRAC.11,792 PERFP, s� 13,093-13,098 PERF 13,412-13,417P, PERFP, 13,73313,738 14,062-14,087PERFP, LINER, 11,017-14,090 TD(CD1.47), ` • 14.120 ConocoPhillips Alaska, Inc. is requesting a sundry for a perforation breakdown in the Kuparuk reservoir on well CD1-47. Background: The Kuparuk does not seem to be contributing to the Alpine production on CD1-47.A perforation breakdown is proposed to verify nothing is blocking production in the near wellbore. Procedure: 1) Set plug in XN nipple(to close off the Alpine). 2) Inject up to 1000 bbl of seawater or dead crude at a surface pressure below 4000 psig. Flow rate to be maximized within the surface pressure limit. 3) Flow the Kuparuk, and then pull the plug from the XN nipple. This procedure is not unusual and would be considered normal oilfield practice in many areas. ['7-0 Z Z --Uk3 Ferguson, Victoria L (DOA) From: Ferguson, Victoria L(DOA) Sent: Thursday, March 27, 2014 11:30 AM To: 'Allsup-Drake, Sharon K' Cc: Dammeyer, Michael (Michael.Dammeyer@conocophillips.com) Subject: CD1-47 (PTD 212-083, Sundry 313-196) Michael, The addition of injecting seawater is fine. Another sundry will have to be submitted if procedure is planned for after 5/2/14. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 victoria.ferquson aa..alaska.gov From: Allsup-Drake, Sharon K mailto:Sharon.K.Allsu -Drake@conoco hillips.com P [ P P ] Sent: Thursday, March 27, 2014 8:38 AM To: Ferguson, Victoria L(DOA) Cc: Dammeyer, Michael Subject: FW: approved sundry for CD1-47 Victoria — We have a question about a sundry for CD1-47 which was originally approved on 5/2/2013, sundry approval #313-196. We are planning to do this job before the one-year deadline but we would like to make an addition. Should we submit a new sundry or is this email sufficient to make the change? Thank you, Sharon From: Dammeyer, Michael Sent: Tuesday, March 25, 2014 6:42 AM To: Allsup-Drake, Sharon K Subject: RE: approved sundry for CD1-47 Sharon, Would it be possible to make additions to this sundry: a) Extend for another month b) Update the language from "Inject up to 1000 bbl dead crude" to read "Inject up to 1000 bbl dead crude or seawater" I suppose we would have to request a new sundry, but I hoped minor updated like this could be done by email. Note we might make the current sundry deadline, so we don't want to void it,just update. Thanks, Michael From: Allsup-Drake, Sharon K Sent: Monday, May 06, 2013 11:15 AM To: Dammeyer, Michael Subject: FW: approved sundry for CD1-47 Michael— Let me know when this work is completed so we can send in the follow-up paperwork to AOGCC. Sharon From: Allsup-Drake, Sharon K Sent: Monday, May 06, 2013 11:11 AM To: Allsup-Drake, Sharon K Subject: 2 r:OF I%% THE STATE Alaska 011and Gas - ALASKA Conservation Commission ==_ GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Michael Dammeyer Senior Production Engineer ConocoPhillips Alaska, Inc. a I a_ ©$3 P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD 1-47 Sundry Number: 313-196 Dear Mr. Dammeyer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, . ' Daniel T. Seamount, Jr. Commissioner In141 DATED this 2 day of May, 2013. Encl. • STATE OF ALASKA RECEIVED A KA OIL AND GAS CONSERVATION COMI :ION APR 2 4 2013 • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 A G 1.Type of Request: Abandon I— Plug for Redrill r Perforate New Pool E Repair well E Change�ippr�dProg am r Suspend E Rug Frforations r P rlorate E Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well E Stimulate I✓ • Atter casing r Other: t- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Development (✓, Exploratory r 212-083-0 ' _ 3.Address: Stratigraphic r Service r 6.API Number: ✓ P.O. Box 100360,Anchorage,Alaska 99510 50-103-20659-00, 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? ✓ Will planned perforations require spacing exception? Yes r No 1✓ CD1-47 - 9.Property Designation(Lease Number): 10.Field/Pool(s): ✓ ADL 25558,25538,25559 Colville River Field/Alpine 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): • 14120 6974 + 14090' 6975' .11118' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114' 114' SURFACE 2634 11.75 2670' 2325' INTERMEDIATE 8260 9.625 10753' 6825' INTERMEDIATE 1060 7 11410' 6982' LINER 3073 4.5 14090' 6975' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): from 10960'-14067'• 6894'-6976 4.5 x 3.5 L-80 11056 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-BAKER PREMIER PACKER . MD=10722 TVD=6813 PACKER-HRD LINER TOP ZXP PACKER , MD=11017 TVD=6909 SSSV-CAMCO TRMAXX-5E SSSV • MD=2118 TVD=1997 12.Attachments: Description Summary of Proposal IW 13. Well Class after proposed work: Detailed Operations Program Iv BOP Sketch r Exploratory r Stratigraphic r Development 9—. Service r 14.Estimated Date for Commencing Operations. 15. Well Status after proposed work: 5/1/2013 Oil 1✓• Gas r WDSPL E Suspended E 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned F Commission Representative: GSTOR E SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Michael Dammeyer @ 265-6548 Email: Michael.Dammevereconocophillips.con Printed Name Michael Dammeyer Title: Senior Production Engineer /I Signature .�,L C� 'Pei-AJC--94° Ali• Phone:265-6548 Date `t 1 t 3 Commission Use Only f Sundry Number:3(3l R kL/ Conditions of approval: Notify Commission so that a representative may witness Plug Integrity E BOP Test E Mechanical Integrity Test E Location Clearance r RBDMS MAY — 2 201 0% Other. Spacing Exception Required? Yes ❑ No 1 Subsequent Form Required: //i —4 0 4- di i APPROVED BY �/21 Approved by: I COMISSIONER THE COMMISSION Date: �� Approved application is valid for 12 months trom the date of approval. �, Form 10-403(Revised 10/2012) 1 l / 3 Submit Form and Attachments in Duplicate za) \� cwcwc? 6\1\i3 ORIGINAL Y`1- °\�� # WNS41.01 CDI-47 ConocoPhillips Well Attributes Max Angie&MD TD •�, il,. Wellbore API/UWI Field Name Well Status Incl C) MD(ftKB) Act Btm(ftKB) Cu..i. ;pt,Dp," 501032065900 ALPINE PROD 93.08 11,611.16 14,120.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Rebase Date •••Well Conrg.HORIZONTAL-CD147,3/21/20139'40'.58 AM Well TRDP Last WO: 1/10/2013 Schematic-Acta, Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:ADD PERF ZONES osborl 3/21/2013 HANGER,31 '' Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 36.0 114.0 114.0 62.50 H-40 WELDED Insulated 34" Casing Description String 0... String ID...Top(ftKB) Set Depth(L..Set Depth(ND)...String Wt..String...String Top Thrd SURFACE 113/4 10.772 36.5 2,670.2 2,325.0 60.00 L-80 BTCM CONDUCTOR Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd Insulated 34., INTERMEDIATE#1 95/8 8.799 2,492.7 10,753.0 6,824.6 40.00 L-80 Hyd 521 36414 r Casing Description String 0... String ID...Top(ftKB) Set Depth(/...Set Depth(ND)...String Wt...String...String Top Thrd INTERMEDIATE#2 7 6.276 33.5 10,362.6 6,645.0 26.00 L-80 BTC-M SSSV,2,1 FRAC SLEEVE,18\ ({{t r l 1 Casing Description String 0... String ID...Top(11K13) Set Depth(0...Set Depth(ND)...String Wt...String...String Top Thrd 2.118 INTERMEDIATE#2 7 6.276 10,349.7 11,409.9 6,982.4 26.00 L-80 Tenaris Blue L_1 y, Lower Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Tired T LINER 41/2 3.958 11,016.9 14,090.0 6,975.0 12.60 L-80 Hydril 563 Liner Details Top Depth SURFACE. L (ND) Top Incl Noon... 37-2,870 Top(ftKB) (ftKB) CI Item Description Comment ID(in) GAS LIFT. _ 11,016.9 6,909.3 78.40 PACKER HRD LINER TOP ZXP PACKER 4.340 4,534 II "T* 6,913.3 78.29 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4.250 11,039.8 6,913.9 78.28 HANGER 'DG'FLEX LOCK LINER HANGER 4.350 GAS LIFT. "• .,-o 11,049.1 6,915.8 78.22 SBR SEAL BORE EXTENSION 4.000 8510 _ 11,669.9 6,985.7 93.02 Swell Packer TAM FreeCap Swell packer FSC-11 w/5.75"OD Cementralizer 3.958 11,726.3 6,983.5 92.09 Swell Packer TAM FreeCap Swell packer FSC-11 w/5.75"OD Cementralizer 3.958 INTERMEDIATE Tubing Strings 82 Te back., Tubing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(ND)... String Wt...String... String Top Thrd 34-10.363 TUBING 3 1/2 2.992 31.1 11,055.8 6,917.1 9.30 L80 EUE MOD --61 4.5"x3.5"@114' Completion Details Top Depth (TVD) Top Incl Nomi... GAS LIFT, {i Top(ftKB) (ftKB) C) Item Description Comment ID(In) 1°'484 31.1 31.1 -0.02 HANGER FMC TUBING HANGER 3.900 114.7 114.7 -0.41 XO-Reducing Crossover 4-1/2"IBT-m box x 3-1/2"EUE-m pin 3.500 2,118.1 1,996.6 43.96 SSSV 3-12"TRMAXX-5E SSSV w/2.812'"X"profile w/1/4"control line(5.176" 2.812 OD) GAUGE.10699 - {m I 10,699.3 6,803.9 66.50 GAUGE SLB BHP Guage,3-1/2' 2.992 .72 10,722.3 6,813.0 67.25 PACKER BAKER PREMIER PACKER 2.870 PACKER, - -,- 10,803.7 6,841.8 67.81 SLEEVE-C BAKER CMD SLIDING SLEEVE(CLOSED 2/15/2013) 2.812 GAS LIFT, 10,947.7 6,890.7 73.74 Blast Joint BLAST JOINT(1) 2.867 10.745 11,007.2 6,907.4 78.46 NIPPLE HES"X"LANDING NIPPLE 2.813"ID 2.813 INTERMEDIATE 81. 11,014.9 6,908.9 78.41 SEAL ASSY BAKER3-12"GBH-22 LOCATING SEAL ASSEMBLY(39.65'to 5"OD 2.970 2693.16753 locator) SLEEVE-C, Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 10,804 Top Depth INN (ND) Top Incl Top(ftKB) (ftKB) ('I Description Comment Run Date ID fin) (PERF, -7 2,118.1 1,996.6 43.97 FRAC SLEEVE 2.81"FRAC SLEEVE(OAL=80")SET IN SSSV 3/18/2013 19986-16974 ) '° 11,118.0 6,929.7 77,18 PLUG-Milled COMPOSITE BRIDGE PLUG-LEAKINGINLOWER 12/28/2012 0.000 MIN COMPLETION-MILLED HOLE IN CIBP 2/12013 AIM NIPPLE,11,007 Q Perforations&Slots Shot SEAL ASST, Top(ND) Btm(TVD) Dens 11,015 t Top(ftKB)Btm(RKB) (ftKB) (ftKB) Zone Date (oh-. Type Comment 10,960.0 10,974.0 6,894.2 6,901.1 K-1,KUP-C, 1/3/2013 5.0 IPERF All shots fired t CD1-47 PLUG-Milled. .-.-.-- 11,792.1 11,796.9 6,980.9 6,980.8 ALP-C,CD1-47 12/28/2012 1.0 PERFP SIX 12"HOLES PER PERF PUP 71,118 12,119.1 12,123.9 6,981.7 6,981.6 ALP-C,CD1-47 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER PERF PUP ;r< 12,443.1 12,447.9 6,978.3 6,978.2 ALP-C,CD1-47 12/28/2012 1.0 PERFP SIX 1/2"HOLES PER PERF PUP INTERMEDIATE 12,765.7 12,770.4 6,972.3 6,972.2 ALP-C,CD1-47 12/28/2012 1.0 PERFP SIX 1/2'HOLES PER PERF PUP #2 Lower, 10,350-11,410 13,092.8 13,097.5' 6,975.9 6,975.9 ALP-C,CD1-47 '12/28/2012 1.0 PERFP SIX 1/2"HOLES PER PERF PUP 13,412.1 13,416.8 6,985.4 6,985.4 ALP-C,CD1-47 12/28/2012 1.0 PERFP SIX 12"HOLES PER PERF PUP 13,732.5 13,737.6 6,980.9 6,980.9 ALP-C,CD1-47 12/28/2012 1.0 PERFP SIX 12"HOLES PER PERF PUP 14,0625 14,067.2 6,976.2 6,976.0 ALP-C,CD1-47 '12/28/2012 1.0 PERFP SIX 12"HOLES PER PERF PUP PERFP, .. 11.792-11,797 1111 PERFP. (ill 1' Mandrel Details 12,179-12.124 - Top Depth Top Port PERFP, 5... (TVD) Incl OD Valve Latch Size TRO Run 12.443-12.448 i� N...Top(ftKB) (ftKB) (1 Make Model (in) Sera Type Type (in) (psi) Run Date Com... PERFP, 1 4,534.5 3,389.2 55.01 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,835.0 3/132013 12,76612,n6 t IN i 2 8,510.4 5,614.3 56.12 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,726.0 3/122013 FRAC,11,792 _ PERFP, -. 3 10,483.9 6,707.0 60.66 Camco KBMG 1 GAS LIFT OV BK 0.250 0.0 3/122013 13,093-13,0811 • 11111 4 10,744.8 6,821.3 66.91 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/6/2013 PERFP, 1 MI i IIII13,412-73.417 PERFP, 11.1 13,73313,738 111 PERFP, Al I 14.082-14,087 LINER. 11617-14990 TD(C01-47L 14,120 t WNS CD1-47 ConocoPhillips i4 Alaska,frit. Conoco PMupa _... KB-Ord(it) Rig Release Date "' 1/10/2013 Well Confl9:HORIZONTAL-C01-47,3/21/2013 9 40.58 AM Schematic-Actual HANGER.31 {,. AWN— Stimulations&Treatments '� Bottom Min Top Max Btm Top Depth Depth Depth Depth (ND) (ND) _ _ _ _ (RKB) 1(476 (RKB) (5KB) Type Date Comment -- - _- 11,792.0 14,067.0 6,980.9 6,976.0 FRAC 3/1/2013 ALPINE CSAND FRAC with a three-stage fracturing cotl0 CTOR treatment using bioballs to obtain diversion. Pumped Insulated 34', 2-7 ppa 16/20 Carbolite stages in 25#crosslink gel at 36-114 5 .. 20-bpm.Placed total of 428,306#proppant(106% design)with 4055.0-bbl total slurry volume. SSSV.2,118 –� FRAC SLEEVE, N. 4 a,a 2,118 I I T ',,. SURFACE, L 37-2,870 GAS LIFT, 4,534 GAS LIFT, 2 _ 8510 ¢r F.. INTERMEDIATE 92 lie W 3470,383383 Pr–' f I GAS LIFT, I 10,484 GAUGE.10.699 {ml PACKER. ,.. 10,722 I GAS LIFT, 10,745 INTERMEDIATE it, 2,493-10,753 SLEEVE-C. s 10.804 PERF, r_ 10,960-10,974— t rL--1 '' l 1 NIPPLE.11.007 4711 LLL SEAL ASSY, 11,015 PLUG-Milled 111,118118 INTERMEDIATE, • I 92 10,350-11,41011,410 3i PERFP, III11,792-11,797 ' I•I PERFP, �-.. 12,119-12,124 al PERFP, I iii 1 12,443-12,448 -. PERFP, 1 in 1 12.766-12,770 FRAC,11,792 - PERFP, 1■I 13,093.13.098 13,412-7 PERF3,117 P, 1 IN I IIIN PERFP, �'1 f 1 13,733-13.738 • MI PERFP, __II f. LINER, 11,017-14,090 TD(CD1.7), 14,120 ConocoPhillips Alaska is requesting a sundry for a perforation breakdown in the Kuparuk reservoir on well CD1-47. Background: The Kuparuk does not seem to be contributing to the Alpine production on CD1-47.A perforation breakdown is proposed to verify nothing is blocking production in the near wellbore. Procedure: 1) Set plug in XN nipple (to close off the Alpine). 2) Inject up to 1000 bbl of dead crude at a surface pressure below 4000 psig. Flow rate to be maximized within the surface pressure limit. 3) Flow the Kuparuk, and then pull the plug from the XN nipple. This procedure is not unusual and would be considered normal oilfield practice in many areas. ■ ■G.A.P ,IIvl .A STATE OF ALASKA ?.'','-' ,';31.3 AL, A OIL AND GAS CONSERVATION COM. JSION • REPORT OF SUNDRY WELL OPERATIONS AOGCC 1 Operations Performed Abandon E Repair w ell f— Rug Perforations [ Perforate f Other E Alter Casing E Pull Tubing E Stimulate-Frac (✓ Waiver E Time Extension (— Change Approved Program EOperat. Shutdown E Stimulate-Other E Re-enter Suspended Well I" 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development (;� Exploratory f` 212-083 3.Address: 6.API Number: Stratigraphic f— Service P. O. Box 100360,Anchorage,Alaska 99510 - 50-103-20659-00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL 25558,25538,25559 -' CD1-47 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Colville River Field/Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 14120 feet Plugs(measured) 11118' true vertical 6974 feet Junk(measured) none Effective Depth measured 14090 feet Packer(measured) 10722, 11017 true vertical 6975 feet (true vertical) 6813,6909 Casing Length Size MD TVD Burst Collapse CONDUCTOR 114 16 114 114 SURFACE 2634 11.75 2670 2325 INTERMEDIATE 8260 9.625 10753 6825 INTERMEDIATE 1060 7 11410 6982 LINER 3073 4.5 14090 6975 Perforation depth: Measured depth: from 10960'-14067' True Vertical Depth: 6894'-6976' Tubing(size,grade,MD,and ND) 4.5 x 3.5, L80, 11056 MD,6917 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PACKER @ 10722 MD and 6813 TVD PACKER-BAKER PREMIER PACKER @ 11017MD and 6909 TVD SSSV-CAMCO TRMAXX-5E SSSV @ 2118 MD and 1997 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 11792'-14067' Treatment descriptions including volumes used and final pressure: pumped 428306#proppant 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 341 1025 1 -- 149 Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory E Development f� .. Service I— Stratigraphic 1 16.Well Status after work: Oil Fi Gas f— WDSPL E Daily Report of Well Operations XXX GSTOR E WINJ E WAGE GINJ E SUSP E SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C O.Exempt 313-050 Contact Robert Blaknev(a.265-6417 Email Robert.G.Blakney(a conocophillips.com Printed Name Robert Blakney Title Completions Engineer Signature e Phone:265-6417 Date 5 4.6;43 Form 10-404 Revised 10Ops AR 21 2013 • t2 VN- Submit Original Only CD1-47 Frac Summary DATE SUMMARY 1/29/2013 'LRS PUMP 370 BBLS CIRC OUT, INADVERTENTLY PULLED DMY f/STA#4. IN PROGRESS. 1/30/2013 SET 1" DV IN STA#4, PULLED SOV FROM STA#3, SET.25" OV IN STA#3. IN PROGRESS. 1/31/2013 PULLED 2.81"XX PLUG FROM CMD @ 10,804' RKB. READY FOR COIL. 2/1/2013 RIH TO TAG CBP @ 11090' CTMD, MILLED THROUGH CBP AND SEEMED TO BE PUSHING DOWNHOLE TO 11180' CTMD, PUH TO T/T WITH 5K OVERPULL @ 11090' CTMD, IT APPEARS THAT WE HAVE MILLED A HOLE THROUGH CBP, F/P TBG WHILE POOH, JOB IN PROGRESS. 2/8/2013 ATTEMPT TO SET XX PLUG, COULD NOT GET PAST TRDP @ 2118' RKB. BRUSH TRDP. IN PROGRESS. 2/9/2013 OPEN CMD @ 10,803' RKB. 2/15/2013 GAUGE TBG TO 2.78"TO 11020' SLM. CLOSE CMD @ 10804' RKB. SET 2.81"XX PLUG w/23" FILL EXT(OAL=48.5") @ 11007' RKB. PULLED OV @ 10484' RKB. **TOOLS COMING BACK WITH PARAFFIN** READY FOR CIRC OUT. 2/16/2013 CIRC OUT 300 BBLS WATER TBG X IA FOLLOWED BY 85 BBLS CRUDE FOR FREEZE PROTECT. THEN U-TUBE. SET DV @ 10484' RKB. MITT& MITIA TO 3500 psi **PASSED**. PULLED 2.81"XX PLUG ASSY @ 11007' RKB. SET FRAC SLEEVE (OAL= 80"/2.85" NO-GO) @ 2118' RKB. DRIFT TREE WITH 3.90" G.RING TO TBG HANGER. DRIFT TBG TO 10'WITH 3.88"SWAGE. **READY FOR FRAC**. 2/28/2013 Finished heating seawater in frac tanks. Rigged-up 2" IA line, PRV, and companion; pressure/function tested same. Erected scaffolding and installed tree-saver[1.5-hr Stinger NPT; had to replace missing flange bolts for Grayloc clamp]. Completed the rig-up to frac. Planned 05:00 re-start. 3/1/2013 Stimulated Alpine C-sand with a three-stage fracturing treatment using bioballs to obtain diversj_9_9. Pumped 2-7 ppa 16/20 Carbolate stages in 25#crosslink gel at 20-bpm. Placed total of 428,306#proppant (106% design)with 4055.0-bbl total slurry volume. WNS CD1-47 ConocoPhillips 011.11 Well Attributes Max Angle&MD ,CTO ° Alaska.hu:. Wellbore APWWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) 501032065900 ALPINE PROD 93.08 11,611.16 14,120.0 `"" Comment HIS(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date -°° SSSV:TRDP Last WO: 1/10/2013 Well Confla'HORIZONTAL-CD1-47 3/7/2013 3 10 37 PM Schematic-Actual _ Annotation Depth(ftKB) End Date Annotation Last Mod...End Date _Last Tag: Rev Reason:GLV C/O,FRAC SLV,FRAC osborl 3/7/2013 HANGER,31 S 1 r Casing Strings alliZ■': LA Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd CONDUCTOR 16 15.062 36.0 114.0 114.0 62.50 H-40 WELDED Insulated 34" .--- - - Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd sm SURFACE _ 113/4 10.772 36.5 2,670.2 2,325.0 60.00 L-80 BTCM CONDUCTOR Cuing Description String 0... String ID...Top(MB)- Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd Insisted 34-, INTERMEDIATE#1 95/8 8.799 2,492.7 10,7510 6,824.6 40.00 L-80 Hyd 521 38-114 Casing Description String 0... String ID...Top(MB) Set Depth If...Set Depth(ND)...String WL..String...String Top Thrd INTERMEDIATE#2 7 6276 33.5 10,362.6 6,645.0 26.00 L-80 BTC-M SSSV,2,118 Tie back. FRAC SLEEVE, ( 4 e I Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd 2,1113 t INTERMEDIATE#2 7 6.276 10,349.7 11,409.9 6,982.4 26.00 L-80 Tenaris Blue Lower T ' Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd LINER 41/2 3.958 11,016.9 14,090.0 6,975.0 12.60 L-80 Hydril 563 Liner Details Top Depth SURFACE, 11 & (ND) Top Incl - Nami... 37-2.670 r Top(ftKB) (ftKB) (°) Item Description Comment _ID(N OAS LIFT, {` 11,016.9 6,909.3 78.40 PACKER HRD LINER TOP ZXP PACKER 4.340 4,534 11,036.9 6,9133 78.29 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4.250 III 11,039.8 6,913.9 78.28.HANGER 'DG'FLEX LOCK LINER HANGER 4.350 GAS LIFT, • 11,049.1 6,915.8 78.22 SBR SEAL BORE EXTENSION 4.000 8,510 e 11,669.9 6985.7 93.02 Swell Packer TAM FreeCap Swell packer FSC-11 w/5.75"OD Cementralizer 3.958 11,726.3 6,983.5 9209 Swell Packer TAM FreeCap Swell packer FSC-11 w/5.75"OD Cementralizer ' 3.958 INTERMEDIATE Tubing Strings #2 Tle back., ,._ -.,-? TubingDescription 0... String ID...TopftKB Set Depth f Set Depth ND StringWt...StringStringTopThrd 34-10.383 "'� String 9 ( ) P ( P (TVD) TUBING 3 1/2 2.992 31.1 11,055.8 6,917.1 9.30 L80 EUE MOD Iii- ,-a 4.5"x3.5"@114' Completion Details _ Top Depth (ND) Top Incl Nomi... GAS Ogen - { -a Top(ftKB) OMB) (°) Item Description Comment ID(in) 31.1 31.1 -0.02 HANGER FMC TUBING HANGER 3.900 114.7 114.7 -0.41 XO-Reducing'Crossover 4-1/2'IBT-m box x 3-1/2'EUE-m pin 3.500 2,118.1 1,996.6 43.96 SSSV 3-1/2"TRMAXX-5E SSSV w/2.812""X"profile w/1/4"control line(5.176" 2.812 OD) GAUGE.10,899--- -- -{m 10,699.3 6,803.9 66.50 GAUGE SLB BHP Guage,3-1/2' 2992 10,722.3 6,813.0 67.25 PACKER BAKER PREMIER PACKER 2.870 PACKER, 10,722 10,803.7 6,841.8 67.81 SLEEVE-C BAKER CMD SLIDING SLEEVE(CLOSED 2/15/2013) 2.812 GAS LIFT, 10,947.7 6,890.7 73.74 Blast Joint BLAST JOINT(1) 2.867 10.745 11.1 11,007.2 6,907.4 78.46 NIPPLE HES"X"LANDING NIPPLE 2.813"ID 2.813 INTERMEDIATE 81, 11,014.9 6,908.9 78.41 SEAL ASSY BAKER3-1/2"GBH-22 LOCATING SEAL ASSEMBLY(39.65 to 5"OD 2.970 2.493-10753 locator) SLEEVE-c, Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 10,804 • Top Depth (ND) Top Incl Top(MB) (ftKB) (°I Description Comment Run Date ID(in) (PERF, I 1 2,118.1 1,996.6 43.97 FRAC SLEEVE 2.81"FRAC SLEEVE(OAL=80")SET IN SSSV 2/16/2013 1o,98o-10,e74 ;`I 11,: 11,118.0 6,929.7 77.18 PLUG-Milled COMPOSITE BRIDGE PLUG-LEAKING IN LOWER 12/28/2012 0.000 COMPLETION-MILLED HOLE IN CIBP 2/1/2013 NIPPLE.11,007 -ikii Perforations&Slots - Shot SEAL ASSY, Top(ND) B5r1(TVD) Dens 11,015 Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date WI.-; l TypeComment 10,960.0 10,974.0 6,894.2 6,901.1 1/3/2013 5.0 IPERF All shots fired 11,792.1 11,796.9 6,980.9 6,980.8 12/28/2012 1.0 PERFP SIX 12"HOLES PER PERF PUP PLUG-MIINd, Iii ----I12,119.1 12,123.9 6,981.7 6,981.6 12/28/2012 1.0 PERFP SIX 12"HOLES PER PERF PUP 11,11a ---- 12,443.1 12,447.9 6,978.3 6,978.2 12/28/2012 1.0 PERFP SIX 1/2'HOLES PER PERF PUP f INTERMEDIATE 12,765.7 12,770.4 6,972.3 6,972.2 12/28/2012 1.0 PERFP SIX 12"HOLES PER PERF PUP n Lower, �'' 13,092.8 13,097.5 6,975.9 6,975.9 12/28/2012 1.0 PERFP SIX 12"HOLES PER PERF PUP 10350-11,410 13,412.1 13,416.8 6,985.4 6,985.4 12/28/2012 1.0 PERFP SIX 12"HOLES PER PERF PUP 13,732.8 13,737.6 6,980.9 6,980.9 12/28/2012 1.0 PERFP SIX 12"HOLES PER PERF PUP 14,062.5 14,067.2 6,976.2 6,976.0 12/28/2012 1.0 PERFP SIX 12"HOLES PER PERF PUP LAMB PERFP, HMI 11.792-11.797 PERFP, ECU Mandrel Details 12,119-12.124 Top Depth Top Port PERFP, linEn5,,. (ND) Incl OD Valve Latch Size TRO Run 12.443-12,448 N...Top(ftKB) (RKB) (°) Make Model (in) Sere Type TSP. lin) (Psi) Run Date Corn... PERFP, 1 4,534.5 3,389.2 55.01 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/7/2013 127513-12770 2 8,510.4 5,614.3 56.12 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/6/2013 FRAC,11,792 PERFP. gEn3 10,4819 6,707.0 60.66 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 2/16/2013 13,09313.098 4 10,744.8 6,821.3 66.91 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/6/2013 PERFP, IBM 13,412-13.417 PERFP, ICU 13,73313,739 PERFP, 14,082-14087 I 1E11 LINER, 11,017-14,090N TD(CD147), e e 14,120 WNS CD1-47 ConocoPhillips l= Alaska,lrtc, can000F+4 KB-Gr0(R) Rig Release Date 1/10/2013 Well Confq'.HORIZONTAL-CD1-47,3/72013 3'1037 PM Schematic-Actual HANGER,31—AIL Stimulations&Treatments easizir Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) - ____ (RKB) (RKB) (RKB) (RKB) Type Date Comment 11,792.0 14,067.0 6,980.9 6,976.0 FRAC 3/1/2013 ALPINE C-SAND FRAC with a three-stage fracturing CONDUCTOR treatment using bioballs to obtain diversion. Pumped Insulated1116/20 a428,306#es in 25# link atel 4 20-bpm.Placed total of ite poppant(106% r At design)with 4055.0-bbl total slurry volume. SSSV.2.118 FRAC SLEEVE. \ )41 11 2,118 L_- 9 n n SURFACE. L 37-2.670 -� GAS LIFT, —r 4,534 GAS LIFT, _ fi X10 ( 11 '7-1 INTERMEDIATE N2 Tie beck., 34-10.383 I i GAS LIFT. }) 10.484 ) GAUGE,10,899 m PACKER. 10,722 GAS LIFT, 10.745 INTERMEDIATE H, 2,493-10.753 SLEEVE-C. _ a ei 10.804 (PERF, . I � 10,960-10,974 NIPPLE,11.007 SEAL ASSY, 11.015 I PLUG-Milled, I----` 11,118 INTERMEDIATE *2 Low 10.350-11.410 PERFP, 111 11,792-11,797 1 PERFP, 12.119-12,124 4 dli PERFP. t'1- 12,443-12,448 PERFP,- 12,788-12,770 ■ S FRAC,11,792 PERFP, 13,093-13,098 PERFP, 1(♦1.. 13,412-13,417 PERFP, )NI t 13,733-13,738 PERFP, (� 14,082-14,087 1 LINER, 11,017-14,090 TD(CD1-47), 14,120 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS .oN WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil 0 Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b.Well Class' 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ Other ❑ No.of Completions Service ❑ Stratigraphic Test ---- 2 Operator Name. 5.Date Comp,Susp., 12.Permit to Dnll Number ConocoPhillips Alaska, Inc. or Aband.: January 9,2013 212-083/ 3 Address. 6 Date Spudded 13.API Number. P.O. Box 100360,Anchorage,AK 99510-0360 November 2,2012 50-103-20659-00&50-103-20659-70 4a Location of Well(Governmental Section): 7.Date TD Reached 14.Well Name and Number Surface: 552'FNL,2251'FWL,Sec.5, T11N, R5E, UM December 26,2012 CD1-47&CD1-47PB1 Top of Productive Horizon: 8. KB(ft above MSL): 56'RKB 15.Field/Pool(s) 926'FSL, 1613'FEL,Sec.30,T12N, R5E, UM GL(ft above MSL): 19.5'AMSL Colville River Field Total Depth 9.Plug Back Depth(MD+TVD) 1587'FNL, 1748'FWL,Sec.30,T12N, R5E,UM 14090'MD/6975'TVD Alpine Oil Pool 4b Location of Well(State Base Plane Coordinates,NAD 27) 10.Total Depth(MD+TVD): 16 Property Designation Surface: x-385675 y- 5975580 Zone-4 14120'MD/6974'TVD ADL 25558,25538 TPI: x-381893 y- 5982396 Zone-4 11.SSSV Depth(MD+TVD) 17 Land Use Permit: Total Depth: x-380441 y- 5985187 Zone-4 2118'MD/1997'TVD Tobin 932102,932100 18.Directional Survey Yes Q No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1578'MD/1556'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 MC 25 071): 22 Re-drill/Lateral Top Window MD/TVD GR/Res not applicable 23 CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 36' 114' 36' 114' 42" 88 bbls Type II 11.75" 60# L-80 36' 2670' 36' 2325' 14" 717 sx AS Lite,260 sx Alpine 9.625" 40# L-80 2493' 10753' 2231' 6825' 11.75" 659 sx Class G,411 sx Class G 7" 26# L-80 10350' 11410' 6638' 6983' 8.5" 234 sx Class G 4.5" 12.6# L-80 11017' 14090' 6908' 6975' 6" slotted liner 24.Open to production or injection? Yes ❑ No ❑ If Yes,list each 25 TUBING RECORD Interval open(MD+TVD of Top&Bottom,Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 10960'-10974'MD 6894'-6901'TVD 4.5"x 3.5" 11056' 10722'MD/6813'TVD, pre-pert pup joints from 11792'-14067'MD 6981'-6976'TVD 11017'MD/6909'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC RECEIVEDWas hydraulic fracturing used during completion? Yes❑ No❑ DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED ` e.r FEB 1 1 2D13 cement plug @ 11006' 267 sx Class G It i�' AOGCC . 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc) waiting on facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF 'WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed) Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 MC 25 071 NONE REZMS FEB 121013 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE t)k- 4 10Z/Ill Submit original only VHF 7/3/ /1� Arc � � a Ci- 29. GEOLOGIC MARKERS(List all formations and market cantered): 30 FORMATION TESTS NAME MD TVD Well tested? Yes Q✓ No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1578' 1556' needed,and submit detailed test information per 20 MC 25.071 Kuparuk C 10962' 6895' Alpine C 11353' 6974' CD1-47PB1 N/A total depth 11010' 6914' Formation at total depth: Alpine C 31 LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 32 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact: J.G.Samuell @ 265-6309 Email: John.G.Samuellta'�.conocophillips.com -S'S Printed Name G. L.AllvvoordQ Title Alaska Drilling Manager Signature A L.�_ti(.✓� Phone 265-6120 Date 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 * Name Depth (feet) Depth [TVD] Depth [TVDSS] C-30 2771.4 2379.4 2323.2 C-20 3442.9 2761.3 2705.0 C-10 3911.3 3030.6 2974.4 K-3 5271.8 3810.8 3754.5 K-3_BSL 5614.2 4002.4 3946.1 K-2 5670.7 4034.0 3977.7 ALB 97 8716.3 5729.2 5672.9 ALB 96 9386.0 6102.4 6046.1 HRZ 10405.0 6667.4 6611.1 HRZ_BASE 10591.2 6757.6 6701.3 K-1 10701.2 6804.4 6748.1 KUP_C 10961.8 6894.6 6838.3 LCU 10980.6 6899.2 6843.0 ALP_D 11259.7 6958.9 6902.6 ALP_C 11353.5 6974.8 6918.5 UJU 11383.9 6978.7 6922.5 WNS CD1-47 ConocoPhillips 011 ell Attributes �x Angle&MD TD A!,ltik>:,INC Wellbore APOUWI Field Name Wellbore Status Incl("I MD OMB) Act Btm(RKB) �, Ngfirs 501032065900 ALPINE PROD 93.08 11,611.16 - 14,120.0 Comment H2S(ppm) Date Annotation End Date KB-Gra(R) Rig Release Date Wet Conlis'.HORIZONTAL-CD147,1/25/20132'35'38 PM -SSSV:TRDP Last WO: 1/10/2013 Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod By End Date HANGER.31-1ir Last Tag: Rev Reason:NEW WELL osborl 1/22/2013 t� Casing Strings �' Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)... String Wt..String... String Top Thrd CONDUCTOR 16 15.062 36.0 114.0 114.0 62.50 H-40 WELDED I Insulated 34" Casing Description 'String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 113/4 10.772 36.5 2,670.2 2,325.0 60.00 L-80 BTCM CONDUCTOR Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd Insulated 3d 34". INTERMEDIATE#1 95/8 8.799 2,492.7 10,753.0 6,824.6 40.00 L-80 Hyd 521 Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(ND)...String Wt..String._-String Top Thrd - INTERMEDIATE#2 7 6.276 33.5 10,362.6 6,645.0 26.00 L-80 BTC-M - Tie back. SSSV,2.118 -i '-`, Casing Description String 0... String ID...Top(MB) Set Depth(t..Set Depth(ND)...String Wt..String...String Top Thrd INTERMEDIATE#2 7 6.276 10,349.7 11,409.9 6,982.4 26.00 L-80 Tenaris Blue Lower Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd LINER 41/2 3.958 11,016.9 14,090.0 6,975.0 12.60 L-80 Hydril 563 Liner Details Top Depth SURFACE, (TVD) Top Incl Nomi... 37-2,070 Top IRKS) (RKB) El Item Description Comment ID(In) GAS LIFT, f 4 11,016.9 6,909.3 78.40 PACKER HRD LINER TOP ZXP PACKER 4.340 4,534 11,036.9 6,913.3 78.29 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4.250 11,039.8 6,913.9 78.28 HANGER 'DG'FLEX LOCK LINER HANGER 4.350 GAS LIFT. - 11,049.1 6,915.8 78.22 SBR I SEAL BORE EXTENSION 4.000 8,510 11,669.9 6,985.7 93.02 Swell Packer TAM FreeCap Swell packer FSC-11 w/5.75"OD Cementralizer 3.958 11,726.3 6,983.5 92.09 Swell Packer TAM FreeCap Swell packer FSC-11 w/5.75"OD Cementralizer 3.958 INTERMEDIATE Tie back., _•e Tubing Strings N2 Sat 0,383 `W A Tubing Description String 0... String ID...Top(CAB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd 0TUBI{ NG 3 1/2 2.992 31.1 11,055.8 6,917.1 9.30 L80 EUE MOD - 4.5"x3.5"@117 1 Completion Details 1 Top Depth 1 (ND) Top Incl Nomi... GAS LIFT, (L 4 Top(RKB) MKS) (") Item Description Comment ID(in) 10.484 �I 31.1 31.1 -0.02 HANGER FMC TUBING HANGER 3.900 1 114.7 114.7 -0.41 XO-Reducing Crossover 4-1/2 IBT-m box x 3-1/2"EUE-m pin 3.500 I 2,118.1 1,996.6 43.96 SSSV 3-1/2'TRMAXX-5E SSSV w/2.812"X"profile w/1/4"control line(5.176" 2.812 OD) GAUGE,10.899 - m 10,699.3 6,803.9 66.50 GAUGE SLB BHP Guage,3-1/2' 2.992 10,7223 6,813.0 67.25 PACKER BAKER PREMIER PACKER 2.870 PA 0.722 10,803.7 6,841.8 67.81 SLEEVE BAKER CMD SLIDING SLEEVE 2.812 MII GAS LIFT, 10,947.7 6,890.7 73.74 Blast Joint BLAST JOINT(1) 2.867 10.745 11,007.2 6,907.4 78.46 NIPPLE HES"X"LANDING NIPPLE 2.813"ID 2.813 INTERMEDIATE St 11,014.9 6,908.9 78.41 SEAL ASSY BAKER3-1/2"GBH-22 LOCATING SEAL ASSEMBLY(39.65'to 5"OD 2.970 2.493-10,753 locator) SLEEVE. PLUG.10.804 }N, Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (TVD) Top Incl _ Top(RKB) (RKB) ("I Description Comment Run Date ID(In) 10,803.7 6,841.8 67.81 PLUG )0(PLUG wf'X"lock w/equalizing end cap SET IN CMD 1/9/2013 0.000 (PERF, SLEEVE 2.81"profile."'COULD BE PRESSURE BELOW to.seo-to.974 • I-I PLUG*** 11,118.0 6,929.7 77.18 PLUG COMPOSITE BRIDGE PLUG-LEAKING IN LOWER 12/28/2012 0.000 NIPPLE,11.007 COMPLETION SEAL ASSY. Perforations&Slots 11,016 shot Top(ND) Stem(TVD) Dens Top(RKB)Btm(RKB) (RKB) (RKB) Zone Date lah... Type Comment I 10,960.0 10,974.0 6,894.2 6,901.1 1/3/2013 5.0 IPERF All shots fired PLUG,11,118 I 11,792.1 11,796.9 6,980.9 6,980.8 12/28/2012 1.0 PERFP 12,119.1 12,123.9 6,981.7 6,981.6 12/28/2012 1.0 PERFP 12,443.1 12,447.9 6,978.3 6,978.2 12/282012 1.0 PERFP INTER02 Lower,MEDIATE 12,765.7 12,770.4 6,972.3 6,972.2 12/28/2012 1.0 PERFP 10,350-11.410 13,092.8 13,097.5 6,975.9 6,975.9 12282012 1.0 PERFP 13,412.1 13,416.8 6,985.4 6,985.4 12/282012 1.0 PERFP 11112333::740973612225....88: 3,732.8 11112333.:,740973:7670....4685 3,737.6 6666::9809998575....9493 ,980.9 6666::999980877255....9492 ,980.9 1228/2012 1.0 PERFP i 1 14,062.5 14,067.2 6,976.2 6,976.0 12/28/2012 1.0 PERFP PERFP, 11.792.11.797 PERFP, Mandrel Details 12,119.12,12{ Top Depth Top Port S... (ND) Incl OD Valve Latch Size TRO Run PERFP. MOM N...Top(RKB) ME/ Il Make Model (In) Sere Type Type (in) (psi) Run Date Com... 12.443.12.448 i�•�E 1 4,534.5 3,389.2 55.01 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/7/2013 PERFP, Mal 2 8,510.4 5,614.3 56.12 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/6/2013 12,75802,770 3 10,483.9 6,707.0 60.66 Camco KBMG 1 GAS LIFT SOV BEK 0.000 0.0 1/6/2013 DCK2 PERFP, 13.093-13.098 4 10,744.8 6,821.3 66.91 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/6/2013 PERFP, SEMI 13.412-13.417 SEMI PERFP, REM 13,733.13,738PERFP, }i.� PERFP. 14,002-14.067 LINER, 11.017.14,090- TD(CD147), 4 a 14.120 ConocoPhiIIips Time Log & Summary WeOwew Web Reporting Report Well Name: CD1-47 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 10/31/2012 11:59:00 PM Rig Release: 1/10/2013 8:00:00 AM Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 10/31/2012 24 hr Summary Move rig f/CD1-01A to CD1-47,spot over well,spot pits&motor complex,spot ball mill, pull high line cable. Rig Accepted 2400hrs 00:00 01:00 1.00 0 0 MIRU MOVE MOB P Prep rig f/move t/CD1-47 Blow down steam,water&mud lines. Disconnect service lines. Pre move check list 01:00 01:15 0.25 0 0 MIRU MOVE SFTY P Pre JOb safety Meeting on Moving Rig 01:15 02:00 0.75 0 0 MIRU MOVE MOB P Back out Ball mill, pits&motors. 02:00 03:00 1.00 0 0 MIRU MOVE MOB P Skid floor into move position. 03:00 04:00 1.00 0 0 MIRU MOVE MOB P Lift wind walls&cellar feet, (New hands on crew took time to mentor on the old wind walls) 04:00 09:30 5.50 0 0 MIRU MOVE MOB P Move Sub offf well stage outr of way, fork lift moving mats, Pad operator installing gaurds and freeze protecting CD1-48 prior to moving the rig over. 09:30 14:15 4.75 0 0 MIRU MOVE MOB T Trouble shoot sub cat, No power to move sub,Simops continue preping well for sub. 14:15 14:30 0.25 0 0 MIRU MOVE SFTY P Pre Job Safety Meeting on moving the rig. 14:30 17:30 3.00 0 0 MIRU MOVE MOB P Spot sub over well, Level sub. 17:30 18:30 1.00 '0 0 MIRU MOVE MOB P Set feet. Lower cellar walls. 18'30 19:15 0.75 0 0 MIRU MOVE SFTY P Pre Job Safety Meeting on skidding floor. 19:15 20:15 1.00 0 0 MIRU MOVE MOB P Skid rig floor into drilling position. 20:15 22:15 2.00 0 0 MIRU MOVE MOB P Spot&level pits and motor complex, spot ball mill. 22:15 22:30 0.25 0 0 MIRU MOVE SFTY P Pre Job safety Meeting on pulling high line cable. 22:30 00:00 1.50 0 0 MIRU MOVE MOB P Pull high line cable from CD1-01 t/ CD1-47,finish walkways around rig, hook up interconnects,get steam, air&water going. 11/01/2012 Nipple up riser w/bypass hoses, R/U MWD&Directional, Break&Retorque Dp in derrick, P/U HWDP, Slip &Cut Drill Line service rig, Fill hole check for leaks, P/U Surface BHA 00:00 01:30 1.50 114 114 MIRU DRILL RURD P Continue rig up service lines. 01:30 0445 3.25 114 114 MIRU DRILL NUND P PJSM. NU surface riser. 04:45 06.00 1.25 114 114 SURFAC DRILL OTHR P Change out saver sub from 4"XT-39 to 4 1/2"IF. Page 1 of 75 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 06:00 08:15 2.25 114 114 SURFA( DRILL RURD P Reposition in cellar to reduce trip hazards. Install BHI transducer on standpipe gooseneck and string cable. 08:15 09:45 1.50 114 114 SURFA( DRILL RURD P MU by-pass hoses on riser.Change dies in iron roughneck. 09:45 10:30 0.75 114 114 SURFA( DRILL OTHR P PJSM.Transfer 12 stds 5"DP from DS to ODS. 10:30 14:00 3.50 114 114 SURFA( DRILL OTHR P Break connections on 5"DP. Dope connections and torque to 31k ft lbs. 14:00 14:15 0.25 114 114 SURFA( DRILL SFTY P PJSm on picking up 5"HWDP 14:15 16:00 1.75 114 114 SURFA( DRILL PULD P PU&stad back 29 jts HWDP&7 _ 1/2"drilling jars 16:00 16:30 0.50 114 114 SURFA( DRILL PULD P PU&std back 6.5/8"NM flec DC's 16:30 16:45 0.25 114 114 SURFA( DRILL SFTY P PJSm on slip&cut drill line 16:45 19:15 2.50 114 114 SURFA( DRILL SLPC P Slip&cut drill line 52'-Service brakes,grease&inspect TD 19:15 20:15 1.00 114 114 SURFA( DRILL PULD P PU BHA compoenets to rig floor(bit, stab float sub, UBHO sub 20:15 21:15 1.00 114 114 SURFA( DRILL PRTS P Fill hole&check for leaks-Pressure test mud line to mud manifold to check weld on bumper hose in pit room 21:15 21:45 0.50 114 114 SURFA( DRILL SFTY P Pre Spud Meeting w/all parties 21:45 22:00 0.25 114 114 SURFA( DRILL OTHR P Calibrate Baker Block Height 22:00 00:00 2.00 114 114 SURFA( DRILL PULD P M/U BHA(14"bit MXL-1X, Baker motor 8",Stab,MWD)Orient motor w/MWD 11/02/2012 M/U BHA, R/U Gyro, Fill lines check for leaks&Pressure Test, Begin Drilling f/114'Gyroing until 820' Continue drilling w/MWD V 1754'(Driller Observed Higher Flow&pit gain @ 1311'Weight up system V 9.2 ppg)Observe well static slight loss. 00:00 00:30 0.50 114 114 SURFA( DRILL PULD P Continue t/P/U Surface BHA 00:30 01:30 1.00 114 114 SURFA( DRILL RURD P R/U Gyro Equipment, hang sheave in derrick. 01:30 01:45 0.25 114 114 SURFA( DRILL PRTS P Fill Lines pressure test mud lines V 3500 psi test good 01:45 12:00 10.25 114 725 SURFA( DRILL DDRL P Drilled 14"directional hole from 114' to 725'.ND-724'. ADT=3.5 hrs. ART=.8 hrs AST=2.7 WOB-25 RPM-40/60 GPM 450 @ 1230 psi Torque on/off=5k/5.5k.ft/lbs String wt. PU= 108k SO=103k Rot= 105k Gyro every stand. 12:00 20:45 8.75 725 1,514 SURFA( DRILL DDRL P Drilled 14"hole w/motor f/725'V 1513.9'Driller observed flow increse &pit gain @ bottoms up from connection, Last Gyro Survey @ 820' 20:45 21:30 0.75 1,514 1,514 SURFA( DRILL OWFF P Observe Well Flow Static Loss, Stand Back Stand V 1473'Circ& Reciprocate Pipe @ 400 gpm 920 psi. Page2of75 TTime Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 00:00 2.50 1,514 1,754 SURFA( DRILL DDRL P Drilled 14"hole w/motor f/1513.9't/ 1754'.TVD-1705'.ADT=6.5 ART= 2.5 AST=4.0 WOB-10/20K GPM 575 @ 1970 psi RPM-75 Torque on /off 7.5/5k ft.lbs String wt. PUW- 143Sow-131 ROT-142 11/03/2012 Drilling 11.75 hole f/1754'U 2685',CBU x 3, BROOH U 1252', hole unloaded packing off the flow line, Break flow line apart&clear, reassemble&continue BROOH U 1095'Flow Check Static RIH U 2036' 00:00 12:00 12.00 1,754 2,601 SURFA( DRILL DDRL P Drilled 14"hole w/motor f/1754'U 2601'.ND-2290'.ADT=8.0 ART= 3.5 AST=4.5 WOB-25/30K GPM 625 @ 2400 psi RPM-75 Torque on /off 11/8k ft.lbs String wt. PUW- 150 Sow-132 ROT-143 12:00 13:00 1.00 2,601 2,685 SURFA( DRILL DDRL P Drilled 14"hole w/motor f/2601'to 2685'MD 2332'ND ADT-.9 hrs- ART-.9 hrs WOB 30 RPM 100 GPM 625 @ 2350 psi String wt. PU 150 SO 132 ROT 143 Torque on/off btm. 11/8 k ft/lbs 13:00 15:00 2.00 2,685 2,685 SURFA( CASING CIRC P Circ 3X btms up @ 625 gpm @ 100 rpm w/8 k torque-Std back 1 std every 30 mins f/2685'to 2417' 15:00 18:15 3.25 2,685 1,252 SURFA( CASING REAM P BROOH f/2417'U 1252'@ 625 gpm 2150 psi 100 rpm slow pumps U 500 gpm @ base of perfafrost 1577',flow increased, large ammount of cuttings returning on bottoms up,flow line packed off unable to circ. 18:15 21:45 3.50 1,252 1,252 SURFA( CASING CIRC T Break apart flow line&clear packed off sections of flow line, Blow down top drive&mud line, reassemble flow line establish circ. 21:45 22:45 1.00 1,252 1,095 SURFA( CASING REAM P Continue BROOH f/1252'U 1095' 450 gpm 1180 psi 30 rpm 22:45 23:00 0.25 1,095 1,095 SURFA( CASING OTHR P Orient Motor high side &blow down top drive. Flow check well static. 23:00 00:00 1.00 1,095 2,036 SURFA( CASING TRIP P RIH f/1095'U 2036' 11/04/2012 RIH U 2685'Circ. Bottoms up,Weight up U 10 ppg,Condition hole,Observe well static, POOH UD BHA, R/U tesco unit, Run 11 3/4 surface casing,ck floats(good)RIH U 975',take weight work through tight spot, continue running casing U 1824' 00:00 00:30 0.50 2,036 2,685 SURFA( CASING TRIP P Continue RIH from 2036'to 2685'. 00:30 02:15 1.75 2,685 2,412 SURFA( CASING CIRC P Circulate and condition mud. Increase MW to 10.0 ppg.625 gpm- 2260 psi. Hole unloading.Slow pumps to 500 gpm-1500 psi.Std back 3 stds while circulating to 2412'. Note: Day light saving time. Actual time was 2 hrs and 45 min. 02:15 04:15 2.00 2,412 172 SURFA( CASING TRIP P POH on elevators from 2412'to 172'. No hole problems. Page 3 of 75 7 Time Logs I Date From To Dur S.Death E. Depth Phase Code Subcode T Comment 04:15 07:00 2.75 172 0 SURFA(ICASINGIPULD P POH and LD NMFC's and BHA#1. 07:00 09:00 2.00 0 0 SURFA( CASING OTHR P Clear and clean rig floor.Clean out drip pan under rotary table. 09:00 10:30 1.50 0 0 SURFA( CASING OTHR P Remove doughnut from top of riser. MU hanger to landing jt and make a dummy run. Mark landing jt. 10:30 13:15 2.75 0 0 SURFA( CASING RURD P PJSM. RU Tesco csg running tools. 13:15 13:30 0.25 0 0 SURFA( CASING SFTY P PJSM with all personnel on running 11 3/4"csg. 13:30 18:30 5.00 0 975 SURFA( CASING RNCS P Ran 11 3/4"60#L-80 BTCM casing as follows: Float shoe(silver bullet)2 jts csg-Float collar(Halliburton Super Seal)2 jts. csg to 173'(first 4 connections made up w/BakerLoc- Filled pipe&checked floats) Installed bow spring cemtralizers on shoe jt 10'up w/stop ring-jt#2- 30'up w/stop collar-Collar on jts 3 &4-Cont. RIH w/11 3/4"csg f/173' to 975',Take weight 18:30 21:30 3.00 975 1,019 SURFA( CASING RNCS T Work through tight spot w/pumps and rotation,work casing with repeated down weight applied to bridge. Broke through,Circ. bottoms up no visible debris on shakers.Worked pipe down f/975'to 1019' 21:30 00:00 2.50 1,019 1,824 SURFA( CASING RNCS P Continue RIH w/11 3/4"f/1019 U 1824'Install bow spring centrilizers on jt 1-13 and every other jt.t/jt.# 31 (43 jts.total in hole) 11/05/2012 Circ @ 1824'-Cont. RIH f/1824'to 2635',Attempt U M/U hanger, Hanger pulled thread,c/o landing jt. RIH U 2674'circ&condition mud, R/D tesco, R/U Cement head,Circ. &cond.Mud f/cement job,perform cement job as per dowel!. Blow Down Lines, Lift riser,center casing,WOC 00:00 00:30 0.50 1,824 1,824 SURFA( CASING CIRC P Circulate and condition mud at 4 bpm-260 psi. 00:30 01:45 1.25 1,824 2,635 SURFA( CASING RCST T MU hanger to stump with Tesc CDT. MU landing jt to hanger by hand. Torque to 1000 psi with top drive. PU on hanger. Landing jt pin jumped the box. 01:45 03:15 1.50 2,635 2,635 SURFA( CASING CIRC T Stage pumps to 4 bpm at 370 psi while hanger was being worked on at the Alpine machine shop. 03:15 03:45 0.50 2,635 2,670 SURFA( CASING RCST T RIH with 1 jt 11 3/4"csg to 2670'. 03:45 07:45 4.00 2,670 2,670 SURFA( CASING CIRC T Circ and reciprocate pipe at 3 bpm- 450 psi while waiting on hanger. It was decided to not attempt to reuse the hanger due to thread damage. 07:45 09:45 2.00 2,670 2,670 SURFA( CASING RURD P RD Tesco CDT Blow down top drive. 09:45 10:45 1.00 2,670 2,670 SURFA( CEMEN.RURD P RU long bails,xo and cement head. 10:45 14:45 4.00 2,670 2,670 SURFA(CEMEN'CIRC P Circulate and condition mud for cement job.Stage pumps slowly from 3-bpm Page 4 of 75 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 14:45 18:00 3.25 2,670 2,670 SURFA(CEMEN"CMNT P Pump 101 bbls nut plug spacer,35.5 bbls biozan nut plug marker,swap U dowell,5 bbls H2O, PT lines U 3000 psi, Drop bottom wiper plug,52 bbls 10.5 ppg mud push,312 bbls 10.7 ppg lead cement,53.9 bbls 15.8 ppg `t i cernenf,Drop top plug,20 bbls of H2O, Rig displace w/216.6 bbls WBM 9.8 ppg,bump plug, Pressure up U 1150 psi 500 psi over FCP, bleed off check floats,floats_held. CIP @ 1715 hrs.Total of 125 bbls cement to surface. Recip pipe 15' stroke until after cement returns to surface. 18:00 00:00 6.00 2,670 2,670 SURFA(CEMEN"WOC P Blow down lines,Clean up equipment from cement job,flush stack&by pass, Nipple down flow line,valves&hoses on surface riser, lift riser¢er casing,Wait on cement. 11/06/2012 WOC, Rig down cement head,pull riser,cut 11-3/4"casing, UD cut off jt,nipple down surface adapter, remove bypass valves, prepare and weld FMC transition nipple to cuttoff jt,while transition nipple cooling- PU/Standback 80 stands of 5"drill pipe. Checked conductor @ 2100 hrs-too hot to touch. Checked transition @ 2345 hrs-too hot to touch. 00:00 05:00 5.00 2,670 2,670 SURFA( CEMEN"WOC P Waiting on cement to cure. Clean up in the cellar. Prepare to nipple down, cleaning pits.Change out kill line. 05:00 07:00 2.00 2,670 2,670 SURFA( CEMEN"RURD P Rig down cement head, pull riser, prepare to cut 11-3/4"60ppf L-80 BTC-m casing. 07:00 07:45 0.75 2,670 0 SURFA( CEMEN"OTHR P Cut casing 34.53'below rig floor. Lay down cut off joint(landing joint#63). 07:45 09:00 1.25 0 0 SURFA(CEMEN"NUND P Nipple down surface adapter. Remove bypass valves f/cement job. 09:00 14:45 5.75 0 0 SURFA(CEMEN"OTHR T Removed the FMC landing ring from the top of the conductor,conductor @ 37.03'below rig floor.Make final cut on the 11-3/4"casing(Jt#62 was 43.13'-cut 1.64'total off of the joint, leaving 41.49'in the hole. Final cut was made 36.51'below rig floor. Prep and weld FMC transition nipple to the 11-3/4"casing(4-1/4"of the transition slips over the cut joint,2" gap between the 16"conductor and the bottom of the transition. Pre heated to 450 deg, post heated to 575 deg,then insulated. Note: FMC transition was finished and wrapped @ 1200 hrs. Welder removed(2)outlets and welded patches on the 16"conductor. Page 5 of 75 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 14:45 16:45 2.00 0 0 SURFA( CEMEN-OTHR T Allow FMC mandrel to cool. Pick up and stand back 5"drill pipe via the mouse hole. Note: Lost Hi-Line rig power F/1345 hrs to 1425 hrs. Back on Hi-Line @ 1425 hrs. 16:45 17:15 0.50 0 0 SURFA( RIGMNT SVRG T Service rig. 17:15 23:15 6.00 0 0 SURFA(CEMEN"OTHR T Continue to allow transition to cool. Continue to PU/MU/Stand back 5" drill pipe. Note:Checked conductor @ 2100 hrs-too hot to touch. 80 stands total picked up and stood back in the derrick. 23:15 0000 0.75 0 SURFA( CEMEN"OTHR T Continue to allow transition to cool. Lay down mouse hole. Prepare for nipple up.Checked transition @ 2345 hrs-too hot to touch. 11/07/2012 Allow FMC transition nipple to cool down prior to testing,test to 2050 psi w/nitrogen-good,fabricate support plate on top of 16"conductor, Install FMC wellhead, nipple up BOPE, RU to test w/lower test plug,test annular to 250 psi low and 2500 psi high.Witness of test by AOGCC inspector John Crisp. 00:00 07:00 7.00 0 0 SURFA( CEMEN"OTHR T Continue to allow transition to cool. Checked transition @ 0300 hrs-too hot to touch.Checked transition nipple @ 0500 hrs-too hot to touch. Checked @ 0630 hrs @ 147°, unwraped,checked @ 0700 hrs @ 117°. Perform derrick inspection.Work on removing DSA on BOP while on stump. 07:00 07:30 0.50 0 0 SURFA( CEMEN"DHEQ T Rig up to test weld on the FMC transition nipple to 2050 psi w/ nitrogen.Tested inside and outside weld f/10 minutes-good. Rig down test hose. 07:30 08:45 1.25 0 0 SURFA( CEMEN-OTHR T Wait on final decision for support plate under transition nipple. 08:45 10:30 1.75 0 0 SURFA( CEMEN"OTHR T Weld 1"donut plate on top of conductor,then weld 2"wide shim plates(beveled)to allow load to carry from transition nipple to"C"plate. Note: No part of the support plates or shims were welded to the transition nipple or to the 11-3/4"60 ppf L-80 BTC-m casing. 10:30 11:30 1.00 0 0 SURFA(WHDBO NUND P Nipple up FMC wellhead to FMC 11-3/4"transition nipple. 11:30 14:30 3.00 0 0 SURFA(WHDBO NUND P Nipple up dulling spool. 14:30 14:45 0.25 0 0 SURFA(WHDBO SFTY P Pre job safety meeting on nippling up BOPE. 14:45 20:15 5.50 0 0 SURFA(WHDBO NUND P Nipple up BOPE.Torque drilling spool w/EZ Torque. 20:15 21:45 1.50 0 0 SURFA(WHDBO RURD P Make up FMC 13.08"OD lower test plug and 5"test joint. Page 6 of 75 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 21:45 23:15 1.50 0 0 SURFA(WHDBO RURD P 1Rig up testing equipment. Fill stack and lines w/water. 23:15 00:00 0.75 0 0 SURFA(WHDBO BOPE P Test BOPE.Witness of test by AOGCC inspector John Crisp.All tests charted.All tests held 5 min each.Tested Annular to 250 psi low and 2500 psi high. 11/08/2012 Finish testing BOPE,test witnessed by AOGCC inspector John Crisp, RD test equipment, install wear bushing, PJSM, PU/MU BHA#2,CBU @ 2385',Test 11-3/4"60 ppf L-80 BTC-m casing to 3500 psi f/30 min-good, RIH to 2478',wash to 2556,ream stringers to wiper rubbers on top of FC @ 2582.77',drill wiper plugs, FC, cement, FS @ 2667.84'. 00.00 04:45 4.75 0 0 SURFA(WHDBO BOPE P Finish testing BOPE.Witness of test by AOGCC inspector John Crisp.All of the following tests were 250 psi low and 3500 psi high. Each test held f/5 minutes,charted tests.Test with 5"test joint and lower test plug (13.08"OD).Test Top(3-1/2"x 6" VBR)and bottom(3-1/2"x 6"VBR) pipe rams,blind rams,all valves in choke manifold, all kill line and choke line valves,4"demco valve on kill line.Test floor safety valve, Dart valve,top drive IBOP manual and automatic.Test accumulator: Initial 2950 psi,after closure 1500 psi,200 PSI build up in 43 seconds,full charge in 309 seconds. Rig Electrician tested all methane and H2S alarms. Function tested Totco PVT. Pumped through choke manifold testing both manual and actuated choke for operation pumped 1.5 bpm through chokes to 1500 psi). 04:45 06:00 1.25 0 0 SURFA(WHDBO RURD P Blow down choke manifold, kill and choke lines.Test run 2-7/8"test joint (top of test joint was 3.8'above the floor). Pull FMC lower test plug. Install FMC wear bushing(3'long, 12-7/16"ID x 13.42"OD. 06:00 06:30 0.50 0 0 SURFA( RIGMN1SVRG P Service rig 06:30 06:45 0.25 0 0 SURFA( CEMEN"SFTY P Pre job saafety meeting on making up 10-5/8"--with 11-3/4"Weatherford Rip Tide underreamer BHA. BHA#2. 06:45 08:45 2.00 0 63 SURFA( CEMEN"PULD P Make up BHA#2 per Baker directional driller:Steering Head G3, NM Flex stab W/X-over, On Trac LWD/MWD,Copilot,Mod Stab/BCPM/Top Stop,MU 10 5/8" Bit 08:45 09:30 0.75 63 63 SURFA( CEMEN"OTHR P Plug in, upload and check communications of tool string Page7of75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 1030 1.00 63 135 SURFA(CEMEN-PULD P Continue to MU BHA-NM Float sub w/6R FV, NM Filter Sub, NM XO, NM Stab,CSNMDP,WFD Rip Tide Reamer 10:30 12:00 1.50 135 135 SURFA(CEMEN'DHEQ P Staged pumps up to 550 gpm/600 psi-Reamer arms fully extended- shallow test tools-pumped down RFID closing chips and cycled pumps until tool locked closed with 600 gpm/740 psi-remove blank jets and install 3-9/32 jets in reamer 12:00 13:15 1.25 135 1,164 SURFA( CEMEN-PULD P Continue to PU/MU BHA#2 f/135'to 1164'. 13:15 15:15 2.00 1,164 2,385 SURFA( CEMEN"TRIP P Trip in the hole w/BHA#2 f/1164'to 2385'. 15:15 15:45 0.50 2,385 2,385 SURFA( CEMEN"CIRC P Circulate bottom's up pumping 600 gpm w/1310 psi, rotate 30 rpm w/ 11k ft lbs of torque. PU wt 130k,SO wt 140k. 15:45 16:00 0.25 2,385 2,385 SURFA( CEMEN'SFTY P Pre job safety meeting on rig up to test 11-3/4"60 ppf L-80 BTC-m casing. 16:00 16:15 0.25 2,385 2,385 SURFA( CEMEN'RURD P Rig up to test. Remove bell guide f/ top drive. 16:15 17:00 0.75 2,385 2,385 SURFA( CEMEN'DHEQ P Test 11-3/4"casing to 3500 psi f/30 minutes. Chart test. 17:00 17:30 0.50 2,385 2,385 SURFA( CEMEN'RURD P Bleed off pressure. Blow down the kill line and cement hose. Rig down testing equipment. 17:30 17:45 0.25 2,385 2,478 SURFA( CEMEN'TRIP P Trip in the hole f/2385'to 2478'. 17:45 18:15 0.50 2,478 2,582 SURFA( CEMEN"COCF P Wash down f/2478'to 2556', pumping 550 gpm w/1160 psi. Observed cement stringers @ 2556'. Ream f/2556'to 2582',pumping 550 gpm w/1200 psi, rotate 35 rpm w/ 12k ft lbs of torque.Tag wiper plug @ 2582'. 18:15 22:00 3.75 2,582 2,585 SURFA(CEMEN-DRLG P Drill cement wiper plugs and float collar,pumping 550 to 300 gpm w/ 1280-400 psi, rotate 50-80 rpm w/ 12.5-13.5k ft lbs of torque. 22:00 00:00 2.00 2,585 2,667 SURFA( CEMEN"DRLG P Ream out float collar.Continue to drill cement f/2585'to Silver Bullet Float Shoe @ 2667.84'to 2670.19'. PU wt 165k,SO wt 130k, Rot wt 150k. Rotate 60 rpm w/11k ft lbs on and 12.5k off. Pumping 550 gpm w/ 1280 psi. 11/09/2012 Drill float shoe f/2667.84'to 2670.19',drill rat hole to 2685',20'new hole to 2705',circ,displace to new 9.6 ppg LSND mud,perform LOT-17 ppg,drill f/2705'to 2807',open Weatherford rip tide underreamer, Ream to final hole size of 11-1/2"starting f/2672'(Reamer is 117'behind bit),then continue to drill 10-5/8"hole f/2807' to 3697'(11-1/2"to 3580').. Page 8 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00.30 0.50 2,667 2,670 SURFA( CEMEN"DRLG P Drill Silver Bullet Float Shoe f/ 2667.84'to 2670.19'. Drill w/4 to 6k WOB. Rotate 60 rpm w/11k ft lbs on and 12.5k off. Pumping 550 gpm w/1280 psi. 00:30 00:45 0.25 2,670 2,685 SURFA( CEMEN"DRLG P Drill cement and rat hole f/2670'to 2685'. Rotate 60 rpm w/12.5 to 13k ft lbs of torque. Pumping 558 gpm w/ 1050 psi. 00:45 01:00 0.25 2,685 2,705 INTRM1 CEMEN"DRLG P Drill 20'of new hole f/2685'to 2705' (ND 2343'). ADT.3 hrs. Rotate 60 rpm w/12.5 to 13k ft lbs of torque. Pumping 558 gpm w/1050 psi. 01:00 01:45 0.75 2,705 2,705 INTRM1 CEMEN"CIRC P Circ BU, pumping 550 gpm w/1220 psi, rotate 40 rpm w/12.5k ft lbs, then displace to new 9.6 LSND mud. Pump spacer ahead of new mud. Rotate 60 rpm w/12k ft lbs of torque. 01:45 02:45 1.00 2,705 2,705 INTRM1 CEMEN"CIRC P Displace to new 9.6 LSND mud. Pump spacer ahead of new mud. Rotate 40 rpm w/11.5k ft lbs of torque. Pump 550 gpm w/900 psi. 02:45 03:15 0.50 2,705 2,705 INTRM1 CEMEN"RURD P Rig up for FIT/LOT @ 2705'(2343' ND). 03:15 03:30 0.25 2,705 2,705 INTRM1 CEMEN"LOT P Perform LOT to 17.0 EMW.9.6 ppg mud,shoe ND 2327', leak off at 890 psi applied surface pressure. 03:30 03:45 0.25 2,705 2,705 INTRM1 CEMEN"RURD P Rig down testing equipment. Blow down kill line. 03:45 06:45 3.00 2,705 2,807 INTRM1 DRILL DDRL P Drill 10 5/8"hole f/2705'to 2807'MD /2399'ND ADT=2.3 hrs. WOB 10-15K 800 gpm/1800 psi 80-120 rpm Torque on/off 12.5k/ 10.6k PUW 164K SOW 127K Rot Wt. 142K ECD 10.2 ppg Page 9 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 07:45 1.00 2,807 2,807 INTRM1 DRILL DDRL P Pick up and attempt to straight pull reamer back into shoe-tagged shoe with reamer 5K overpull-drop down and pull against shoe with 2K-rotate string two rotations and lost over pull -reamer pull cleanly into shoe afterwards-repeated this two more times with same results-RIH to reamer 10'below shoe-pumped down RFID chips to unlock blades- increased pumps to 800 gpm/1470 psi-pressure loss indicating tool opened-cut out-stop rotating and pulled up to shoe 2K overpull at same depth(mark on pipe as earlier) rotated pie two rounds and overpull dropped off-picked up a few inches and pulled 2K against tool put one round into string with torque increasing much quicker-dropped down 2'and engaged rotary to 80 rpm-800 gpm/1470 psi-ream to bottom-no increase in rotary torque -had 5-10K WOB last 10'to bottom. 07:45 12:00 4.25 2,807 3,044 INTRM1 DRILL DDRL P Drill 10 5/8"hole f/2807'to 3044'MD /2532'TVD ADT=2.8 hrs. WOB 10-15K Pumping 900 gpm/1970 psi 80-120 rpm Torque on/off 12.5k/ 10.6k PUW 174K SOW 133K Rot Wt. 149K ECD 10.51 ppg Note: Pumped weighted sweep (11.6 ppg w/5 ppb nut plug)@ 2950' --Sweep back on time. 12:00 00:00 12.00 3,044 3,697 INTRM1 DRILL DDRL P Drill 10 5/8"hole f/3044'to 3697'MD /2907'ND ADT=9 hrs. WOB 10-15K Pumping 900 gpm/2280 psi 120-130 rpm Torque on/off 12.k/ 12kPUW175KSOW139K Rot Wt. 155K ECD 10.24 ppg Note: Performed 1st dilution of 275 bbls while drilling @ 3611'. Pumped weighted sweeps(11.6 ppg w/5 ppb nut plug)@ 3232'and 3514'--First sweep back on time w/a little larger cuttings in returns, second arrived 20 bbls early. 11/10/2012 Drill 10-5/8"hole f/3697'to 5024'(11-1/2"to 4907'). Page 10 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 3,697 4,364 INTRM1 DRILL DDRL P Drill 10 5/8"X 11 3/4"hole f/3697'to 4364'MD/3292'TVD ADT=8.6 hrs. WOB 10-18K Pumping 900 gpm/ 2380 psi 140 rpm Torque on/off 13.5k/13k PUW 185K SOW 145K Rot Wt. 163K ECD 10.55 ppg Note: Performed 2nd dilution of 275 bbls while drilling @ 3894'. Pumped 45 bbl HI Vis sweep(9.6 ppg w/5 ppb nut plug)@ 3800'--Sweep back about 19 bbls early. Pumped 60 bbl weighted sweep @ 4090'(11.6 ppg w/5 ppb nutplug)moderate increase in fine cuttings with sweep back 15 bbls early. 12:00 00:00 12.00 4,364 5,024 INTRM1 DRILL DDRL P Drill 10 5/8"X 11 3/4"hole f/4364'to 5024'MD/3670'ND ADT=8.4 hrs. WOB 16-18K Pumping 900 gpm/ 2630 psi 140 rpm Torque on/off 14k/9k PUW 184K SOW 162K Rot Wt. 171K ECD 10.28 ppg Note: Performed 3nd dilution of 275 bbls while drilling @ 4365',4th dilution of 275 bbls while drilling @ 4900'. Pumped 40 bbl HI Vis sweep(9.6 ppg w/5 ppb nut plug)@ 4365' - moderate increase in fine solids with sweep back 25 bbls early. Pumped 60 bbl Weighted sweep (11.6 ppg w/5 ppb nut plug)@ 4836' -2 x increase in cuttings-Still seeing large clay patties in sweep returns,sweep back 27 bbls early. 11/11/2012 Drill 10-5/8"hole f/5024'to 6153'(11-1/2"to 6036').Circ a BU,circ around a 56 bbl weighted sweep,circ another BU*2. Drop de-activation RFID chips-pump down to de activate Weatherford reamer-no change in pump pressure, repeat with indication of deactivation the second time(300 psi increase), POOH on elevators f/6153'to 4100'. Page 11 of 75 Time Logs Date From To Dur S.Depth E. Death Phase Code Subcode T Comment 00:00 12:00 12.00 5,024 5,714 INTRM1 DRILL DDRL P Drill 10 5/8"X 11 3/4"hole f/5024'to 5714'MD/4058'ND ADT=9 hrs. WOB 15-21K Pumping 900 gpm/ 2750 psi 140 rpm Torque on/off 12.5k/10.5k PUW 192K SOW 164K Rot Wt. 178K ECD 10.28 ppg Note: Performed 5th dilution of 275 bbls while drilling @ 5,316'. Performed 6th dilution of 275 bbls while drilling @ 5,871'. Pumped 60 bbl high vis sweep w/5 ppb nut plug @ 5,117' -2.5 X increase in fine cuttings, 39 bbls early. Pumped 60 bbl weighted sweep (11.6 ppg w/5 ppb nut plug)@ 5,496'-2 X increase in fine cuttings, 45 bbls early. Pumped 60 bbl weighted sweep (11.6 ppg w/5 ppb nut plug)@ 5,871'-1.5 X increase in fine cuttings,50 bbls early. 12:00 18:15 6.25 5,714 6,153 INTRM1 DRILL DDRL P Drill 10 5/8"X 11 3/4"hole f/5714'to 6153'MD/4304'ND ADT=5.1 hrs. WOB 16-19K Pumping 900 gpm/ 2690 psi 130 rpm Torque on/off 14k/12.5k PUW 194K SOW 168K Rot Wt. 180K ECD 10.24 ppg Note: Performed 7th dilution of 275 bbls while drilling @ 5817'. Pumped 60 bbl weighted sweep (11.6 ppg w/5 ppb nut plug)@ 6153' -1.5 X increase in fine cuttings, 57 bbls early. 18:15 20:00 1.75 6,153 6,153 INTRM1 DRILL CIRC P Circa BU pumping 900 gpm w/2680 psi, rotate 140 rpm w/13k ft lbs of torque.Circ around a 56 bbl weighted sweep(11.6 ppg w/5 ppb nut plug), circ another BU*2. Pumping 900 gpm w/2680 psi. 20:00 21:30 1.50 6,153 6,153 INTRM1 DRILL OTHR P Monitor well-static. Drop(4) de-activation RFID-pump down @ 800 gpm w/2210 psi. Did not de-activate. Pump(4)more de-activation RFID chips,saw a increase in pump pressure of 350 psi. (Initial 2000 psi,final 2350)to close Weatherford reamer. 21:30 21:45 0.25 6,153 6,059 INTRM1 DRILL OTHR P Pump out f/6153'to 6059'. Blow down the top drive. 21:45 22:00 0.25 6,059 6,059 INTRM1 DRILL OWFF P Blow down the top drive.Monitor well-static. Page 12 of 75 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 22:00 00:00 2.00 6,059 6,059 INTRM1 DRILL WPRT P Short trip: POOH on elevators f/ 6059'to 4100', monitor well on the trip tank. Observed 10-15k overpull @ 5775'and 4700'-work through-OK. 11/12/2012 Continue wiper trip f/4100'to 1300', RIH to 2667',slip&cut drill line,trip in f/2667'to 2807',confirm reamer was de-activated,drop RFID chips to activate,test-ok,continue wiper trip to 6059', precautionary ream f/ 6059'to 6153'. Drill 10-5/8"x 11-3/4"hole f/6153'to 6625'. 00:00 01:00 1.00 6,059 2,948 INTRM1 DRILL WPRT P Continue to pull out of the hole f/ 4100'to 2931'. Overpull of 15-20k @ 3597'&3066'.Overpull of 30k @ 2968'&2931'. PU wt 160k,SO wt 130k. 01:00 01:45 0.75 2,948 2,855 INTRM1 DRILL WPRT P Backream out of the hole f/2948'to 2855',pumping 800 gpm w/2170 psi, rotate 80 rpm w/11k ft lbs of torque. Rotating weight 145k. 01:45 02:00 0.25 2,855 2,763 INTRM1 DRILL WPRT P Pull out of the hole w/pumps 400 gpm w/540 psi, rotate 80 rpm w/9k ft lbs of torque. Pull out w/o pumps to 2763'. PU wt 150k. Rotated ghost reamer into casing shoe. 02:00 02:30 0.50 2,763 2,636 INTRM1 DRILL WPRT P Monitor well,blow down the top drive. Pull out of the hole ft 2763'to 2606'. Swabbing w/overpull @ 2606'. 02:30 05:45 3.25 2,636 1,348 INTRM1 DRILL WPRT P Pump out of the hole f/2636'to 1300'. Pumping 700 gpm w/1690 psi. Pumped 50 bbl weighted sweeps (11.6 ppg w/5 ppb nut plug)every 5 stands(2291', 1820'& 1348') 05:45 06:00 0.25 1,348 1,348 INTRM1 DRILL OTHR P Flow check well,static-Blow down the top drive. 06:00 07:00 1.00 1,348 2,667 INTRM1 DRILL WPRT P Trip in the hole f/1300'to 2667'-fill pipe-blow down top drive. 07:00 07:15 0.25 2,667 2,667 INTRM1 DRILL OWFF P Monitor well for 10 minutes-static/ PreJob safety meeting for slip&cut drilling line 07:15 08:30 1.25 2,667 2,667 INTRM1 RIGMNT SLPC P Slip and cut 45'of drilling line-visual inspection of cut off line showed normal wear patterns 08:30 09:30 1.00 2,667 2,667 INTRM1 RIGMNT SVRG P Service Top Drive and Drawworks- adjusted brake band rollers and linkage-perform calibration steps for MD Totco display 09:30 10:45 1.25 2,667 2,807 INTRM1 DRILL OTHR P RIH from 2667'to 2807'-PUW 153K SOW 140K-Circulate with 800 gpm /2050 psi-pulled reamer into casing shoe to confirm blades locked closed - down pumps load RFID chips in pipe-with reamer @ 2670-pumped chips down W/300 gpm/350 psi- incresed rate to 800 gpm/2120psi initial--1760 psi after activated-pulled 5K against shoe to confirm blades open -shut down pumps-Blow down top drive Page 13of75 Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 10:45 12.00 1.25 2,807 4,459 INTRM1 DRILL TRIP P RIH from 2807'to 4459', no problems -fill pipe-blow down top drive 12:00 13:00 1.00 4,459 6,059 INTRM1 DRILL TRIP P RIH from 4459'to 6059'-hole appears in good condition. Observed some drag @ 5501'. 13:00 14:00 1.00 6,059 6,153 INTRM1 DRILL CIRC P Staged pumps up to 800 gpm/2400 psi -Wash down from 6059'to 6153' -140 rpm @ 13K ft/lbs PUW 200K SOW 166K-After 300 bbls pumped ECD's were stable @ 10.58 ppg- started seeing heavy cuttings over shakers after 150 bbls pumped- increased rate to 900 gpm/2880 psi. Pumped sweep. Pumped 60 bbls weighted sweep @ 6153'(11.6 ppg w/nutplug marker)- Cuttings over shaker stayed heavy through BU-shakers cleaned up during lag-very heavy returns with sweep back 18 bbls late. 14:00 00:00 10.00 6,153 6,625 INTRM1 DRILL DDRL P Drill 10 5/8"X 11 3/4"hole f/6153'to 6625'MD/4566'TVD ADT=6.8 hrs. WOB 14 to 16K Pumping 900 gpm /2250 psi 120 rpm Torque on/off 14.5k/12k PUW 205K SOW 169K Rot Wt. 186K ECD 10.18 ppg Note: Performed 8th dilution: Total of 500 bbls while drilling @ 6153'. 11/13/2012 Drill 10-5/8"x 11-3/4"hole f/6625'to 8039'. Pumped 3 sweeps.Adding 50 BBLS an hour water to mud system.One dilution of 275 BBLS. 00:00 12:00 12.00 6,625 7,332 INTRM1 DRILL DDRL P Drill 10 5/8"X 11 3/4"hole f/6625'to 7332'MD/4958'TVD ADT=8.7 hrs. WOB 18 to 22K Pumping 900 gpm /2520 psi 140 rpm Torque on/off 18.5k/12k PUW 215K SOW 175K Rot Wt. 195K ECD 10.26 ppg Pumped 60 bbl weighted sweep (11.6 ppg w/5 ppb nut plug)@ 6626' -1.5 X increase in fine cuttings,9 bbls early. Pumped 60 bbl weighted sweep (11.6 ppg w/5 ppb nut plug)@ 7000' -slight increase in fine cuttings, 14 bbls early. Page 14of75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 7,332 8,039 INTRM1 DRILL DDRL P Drill 10 5/8"X 11 3/4"hole f/7332'to 8039'MD/5351'TVD ADT=8.8 hrs. WOB 18 to 20K Pumping 900 gpm /2680 psi 140 rpm Torque on/off 20.5k/14.5k PUW 228K SOW 181K Rot Wt. 205K ECD 10.26 ppg Pumped 60 bbl weighted sweep (11.6 ppg w/5 ppb nut plug)@ 7474' -1.5 X increase in fine cuttings,25 bbls early. Pumped 60 bbl weighted sweep (11.6 ppg w/5 ppb nut plug)@ 7850' -slight increase in fine cuttings,26 bbls early. Note: Performed 9th dilution: Total of 275 bbls while drilling @ 7980'. 11/14/2012 Drill 10-5/8"x 11-3/4"hole f/8039'to 9513'. Pumped 3 weighted sweeps for hole cleaning.One 27 BBL LCM pill pum.ed @ 9235: MD.Added 30 BBLS an hour water to mud system.One dilution of 250 BBLS. 00:00 12:00 12.00 8,039 8,820 INTRM1 DRILL DDRL P Drill 10 5/8"X 11 3/4"hole f/8039'to 8820'MD/5785'TVD ADT=8.7 hrs. WOB 20 to 25K Pumping 900 gpm /2650 psi 150 rpm Torque on/off 20k/13.5k PUW 238K SOW 190K Rot Wt. 213K ECD 10.33 ppg Pumped 60 bbl weighted sweep @ 8320'MD.(11.6 ppg w/5 ppb nut plug) -minimal increase in fine cuttings,30 bbls early. Page 15of75 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 12:00 00:00 12.00 8,820 9,513 INTRM1 DRILL DDRL P Drill 10 5/8"X 11 3/4"hole f/8820'to 9513'MD/6173'TVD ADT=8.5 hrs. WOB 20 to 25K Pumping 900 gpm /2680 psi 150 rpm Torque on/off 24k/15k PUW 250K SOW 190K Rot Wt. 218K ECD 10.22 ppg. Pumped 60 bbl weighted sweep @ 8890'MD. (11.6 ppg w/5 ppb nut plug) -minimal increase in fine cuttings,40 bbls early. Loss zone seen @ 9235'MD. Loss rate 1 BBUMin for 15 mins. (60 BBUHr.)Slowed pumps down fr 900 gpm to 800 gpm. Pumped 27 BBL LCM pill. Loss rate decreased to 8 BBUHr. Brought pump rate back up to 900 gpm. Pumped 60 bbl weighted sweep @ 9374'MD. (11.6 ppg w/5 ppb nut plug) -minimal increase in fine cuttings,20 bbls early. 11/15/2012 Drill 10-5/8"x 11-3/4"hole f/9513'to 9920', perform Glydril dilution @ 9920',continue to drill 10-5/8"x 11-3/4"hole f/9920'to 10673. Top of HRZ 10,414'MD. Base of HRZ 10,593'MD. 00:00 05:15 5.25 9,513 9,920 INTRM1 DRILL DDRL P Drill 10 5/8"X 11 3/4"hole f/9513'to 9920'MD/6399'TVD ADT=4.1 hrs. WOB 20 to 25K Pumping 900 gpm /2790 psi 150 rpm Torque on/off 21k/15k PUW 255K SOW 198K Rot Wt. 225K ECD 10.21 ppg. 05:15 05:30 0.25 9,920 9,920 INTRM1 DRILL SFTY P Monitor well, Pre job safety meeting on Glydril mud dilution. 05:30 07:00 1.50 9,920 9,920 INTRM1 DRILL DDRL P Perform Glydril dilution @ 9920': Pump 37 bbls LCM pill w/20 ppb LCM ahead of dilution,pumping 8 bpm w/400 psi. Increase pump rate to 870 gpm w/2780 psi,then 900 gpm w/3230 psi. PU wt 265k, SO wt 194k, Rot wt 224k. Pumped 40 bbl LCM pill @ 9920' MD,prior to Glydrill dilution. (11.6 ppg w/20 ppb LCM) -minimal increase in fine cuttings, 70 bbls early. 07:00 12:00 5.00 9,920 10,119 INTRM1 DRILL DDRL P Drill 10 5/8"X 11 3/4"hole f/9920'to 10119'MD/6510'TVD ADT=3.1 hrs. WOB 20 to 25K Pumping 900 gpm/3450 psi 150 rpm Torque on/off 24k/16.5k PUW 267K SOW 192K Rot Wt. 225K ECD 11.03 ppg. Page 16 of 75 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 12:00 00:00 12.00 10,119 10,673 INTRM1 DRILL DDRL P Drill 10 5/8"X 11 3/4"hole f/10119' to 10673'MD/6794'TVD ADT=8.9 hrs. WOB 20 to 25K Pumping 900 gpm/3750 psi 150 rpm Torque on/off 26k/16.5k PUW 275K SOW 188K Rot Wt. 226K ECD 11.03 ppg. 11/16/2012 Drill 10-5/8"x 11-3/4"hole fr 10673'to 10758'. K-1 marker seen @ 10702'MD. Drilled 56 feet past K-1 for shoe depth. Place liner running pill from 10,758'to 10,100'MD.CBU 4x's. Pump 2 weighted sweeps. Pull out of the hole on elevators to 6342'MD. Encounter cuttings beds.Stuck pipe for one hour.Circulation retained. Back ream out to 6240'MD. Back reaming at crew change. 00.00 01:15 1.25 10,673 10,758 INTRM1 DRILL DDRL P Drill 10 5/8"X 11 3/4"hole f/10673' to 10758'MD/6827'TVD ADT=1.1 hrs. WOB 20 to 25K Pumping 900 gpm/3750 psi 150 rpm Torque on/off 26k/16.5k PUW 275K SOW 188K Rot Wt. 226K ECD 11.03 ppg. Saw the K-1 marker @ 10702'MD. Drilled 56 feet past the marker. 01:15 02:15 1.00 10,758 10,758 INTRM1 DRILL CIRC P Close Weatherford reamer.30 RPM 16.5 ft/lbs TQ.300 GPM, 590 PSI, 325 GPM,680 PSI, 900 GPM,3730 PSI before closing. Dropped 5 RFID chips.Circulated down. Pumped 200 BBLS. Pumped @ 900 GPM. No Good.still open. 02:15 03:15 1.00 10,758 10,758 INTRM1 DRILL CIRC P 2nd attempt to close Weatherford reamer. Dropped 5 more RFID chips. 900 GPM 3730 PSI before.900 GPM, 3730 PSI after. No Go. 03:15 04:00 0.75 0 10,758 INTRM1 DRILL CIRC P 3rd attempt to close Weatherford reamer.900 GPM,3750 PSI before. 4050 PSI afterwards.Tool verified to be closed. 04:00 04:30 0.50 10,758 10,758 INTRM1 DRILL OWFF P Obtain SPR's, Monitor the well for 30 mins.Wellbore static to a slow loss of mud. 04:30 07:00 2.50 10,758 10,675 INTRM1 DRILL REAM P Perform quadrant reaming with Baker steerable rotary tool. Ream straight left,straight right,and lowside. From 10758 to 10641'MD. Pumping 900 gpm/3830 psi-120 rpm W/18.5 ft./lbs.torque-PUW 217K SOW 212K 07:00 08:15 1.25 10,675 10,109 INTRM1 DRILL TRIP P Pump 100 bbls of casing running pill to bit-Pump out from 10,675'to 10,109'spotting pill into open hole 3 bpm/300 psi-PUW 270/280K • Page 17 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 12:00 3.75 10,109 9,825 INTRM1 DRILL CIRC P Circulate 4 X BU-900 gpm/3820 psi-120 rpm 22K initial-18K ft/lbs final torque-275K PUW 190K SOW -Set back 3 stands to 9825'while conditioning mud. Pumped 37 bbl weighted sweep @ 10,095'MD.(12.5 ppg w/5 ppb nut plug) -4 x increase in cuttings,back 27 bbls early. Pumped 37 bbl weighted sweep @ 9,920'MD. (12.5 ppg w/5 ppb nut plug) -minimal increase in cuttings, back 28 bbls early. 12:00 12:15 0.25 9,825 9,825 INTRM1 DRILL OWFF P Observe well. Static. 12:15 15:45 3.50 9,825 7,000 INTRMI DRILL TRIP P Trip out on elevators from 9825 to 7000'MD. Mud running over DP. Stop to pump dry job. 15:45 16:30 0.75 7,000 7,000 INTRM1 DRILL OWFF P Observe well.Gas breaking out,fluid column static to a slow loss. Pump dry job. 16:30 17:45 1.25 7,000 6,342 INTRMI DRILL TRIP P Trip out on elevators on trip tank. Good hole fill.Calculated fill 27.58 BBLS.Actual fill 39 BBLS.6342' MD.20k over pull seen. 17:45 18:00 0.25 6,342 6,435 INTRM1 DRILL TRIP P Trip back in one stand. 18:00 20:00 2.00 6,435 6,342 INTRM1 DRILL REAM P Back ream out.(6435-6342') Pump a 30 BBL weighted sweep. Minimal excess cuttings returns.800 GPM, 120 RPM,2510 PP, 15 to 17k torque. 20:00 20:15 0.25 6,342 6,310 INTRM1 DRILL REAM P Back ream out.(6342-6310') 900 GPM, 120 RPM,3050 PP, 15 to 17k torque. Encountered tight hole. Stalled the top drive. Brief pack off. 20:15 21:15 1.00 6,310 6,310 INTRM1 DRILL JAR T Regain circulation. Began working string down using down jars.Pull up to 225k,come down to top drive weight.Cock the jars up and attempt to fire down. Freed up by slump and dump method with torque trapped in the string. Circulated 300 to 450 GPM during the freeing activities. 21:15 00:00 2.75 6,310 6,240 INTRM1 DRILL REAM P Back ream out.(6342-6240') 900 GPM, 120 to 140 RPM,3050 PP, 15 to 17k torque. Seeing 5 to 10k up drag. 11/17/2012 Back ream f/6240'to 4960', packed off(Max ECD of 12.45 ppg)(lost 100 bbl of mud), Monitor well breathing, RIH to 5230',pump 60 bbls LCM pill w/20 ppb LCM, RIH to 5308',pump another 60 bbl LCM pill, stage pumps up to 700 gpm by midnight w/normal seepage losses of 5-10 bph. Back reamed out f/5308'to 5118'@ midnight. Page 18 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 6,240 5,496 INTRM1 DRILL REAM P Back ream from 6240'to 5,496' - 900 GPM/2870 psi- 130 RPM, Free torque @ 12K-reaming with 0-7K overpull- torque @ 14-19K ft.lbs.torque. PU wt 190k,SO wt 155k, Rot wt 173k. Performed a 240 bbls dilution(10.4 ppg, Glydril)@ 6210'. Weighted up f/10.5 to 10.7 ppg @ 5610',then to 10.8 ppg @ 5578' increased vis f/36 to 40. 6235': Pumped 36 bbls of 12.5 ppg wt.sweep w/5 ppb NPM- returned 45 bbls late-no significant increase in cuttings returned. 6240': Pumped 37 bbls of 12.6 ppg wt. (High Vis)sweep w/5 ppb NPM -returned 30 bbls late-slight increase in cuttings returned. 6059': Pumped 37 bbls of 12.6 ppg wt. (High Vis)sweep w/5 ppb NPM- returned 60 bbls late-2*increase in cuttings returned. 5496': Pumped 37 bbls of 12.6 ppg wt.(Low Vis)sweep w/5 ppb NPM- returned 65 bbls late-1.5*to 2.5* increase in cuttings returned. 12:00 17:00 5.00 5,496 4,960 INTRM1 DRILL REAM P Back ream from 5496'to 4960' -900 GPM/2850 psi- 140 RPM, Free torque @ 12K torque seen as high as 19k-reaming with 0-7K overpull- torque @ 12-19K ft.lbs.torque. PU wt 190k,SO wt 155k, Rot wt 173k. Packed off @ 4960',torqued up. Lost circulation. 17:00 17:45 0.75 4,960 4,960 INTRM1 DRILL REAM P Packed off @ 4960',torqued up. Lost circulation(ECD max 12.45 ppg). Loss rate of 375 bph for a short time. Total loss of 100 bbls.Shut down pumps,flow of 14%on Totco, decreasing with time(Wellbore breathing). 17:45 18:00 0.25 4,960 5,024 INTRM1 DRILL CIRC T Work string f/4960'to 5024', pumping 123 gpm w/260 psi, 16% Totco flow out, rotating 60 rpm w/ 10k ft lbs of torque. PU wt 190k,SO wt 165k, Rot wt 173k. Loss rate of 52 bph. Page 19 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 21:30 3.50 5,024 5,250 INTRMI DRILL CIRC T RIH f/5024'to 5230'. Pump a 60 bbl LCM pill(20 ppb total:25%each of dyna red fine and med, nut plug fine and med). Pumping @ 230 gpm w/ 450 psi w/16%Totco flow out, staging pumps up to 550 gpm w/ 1420 psi w/25%Totco flow out. Rotate 100 rpm w/10-12k ft lbs of torque.MWD now working while pumping 550 gpm and showing 11.3 ppg ECD's. Normal losses of 5 to 10 bph w/pump rate to 550 gpm.. 21:30 22:30 1.00 5,250 5,308 INTRM1 DRILL CIRC T Make a connection,work string f/ 5230'to 5308'. Pump another 60 bbl LCM pill(20 ppb total:25%each of dyna red fine and med, nut plug fine and med).After pumping pill, increase pump rate from 550 gpm w/ 1420 psi w/25%Totco flow out to 680 gpm w/1940 psi w/29%Totco flow out. Rotate 120 rpm w/12k ft lbs of torque. Normal losses of 5 to 10 bph.MWD ECD's 11.16 ppg. 22:30 0000 1.50 5,308 5,118 INTRMI DRILL REAM T Back ream out of the hole f/5308'to 5118'. Pumping 600 gpm w/1980 psi,working up to 700 gpm w/2090 psi. Rotate 140 rpm w/13.5k ft lbs of torque. Pulling speed 140 fph. Normal losses of 5 to 10 bph. Total losses this tour was 182 bbls measured with pumps off. 11/18/2012 Continue to back ream out of 11-1/2"hole w/BHA#2 f/5118'to 3421'. Pumped 9 sweeps to aid in hole cleaning.5110',5023',4930,4836,4793,3695,3590,3560,3514 8 of the sweeps were 35 to 40 BBLS in volume, high vis pills with 5 ppb Nut plug med.One 2 lbs/BBL over weighted sweep was pumped.They were all effective in cleaning the hole, bringing large quantities of fines and up to 4" in diameter clay balls. Flow rate 800 GPM/140 RPM. ECD's 11.15 PPG to 11.5 PPG. No Mud Losses this tour. 00:00 01:30 1.50 5,118 4,960 INTRM1 DRILL REAM T Back ream out of the hole f/5118'to 4960'. Initially pumping 700 gpm w/ 2090 psi,staged up to 750 gpm w/ 2210 psi,then 800 gpm w/2480 psi. Rotate 140 rpm w/11.5 to 14k ft lbs of torque. Pulling speed 35 to 65 fph. PU wt 180k,SO wt 152k, Rot wt 165k. 5718': Pumped 33 bbl low vis nut plug sweep—returned 70 bbls late. 5023': Pumped 33 bbl low vis nut plug sweep--returned 55 bbls late. Page 20 of 75 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 01:30 08:00 6.50 4,960 4,765 INTRM1 DRILL REAM P Back ream out of the hole f/4960'to 4765'. Initially pumping 800 gpm w/ 2480 psi,final of 850 gpm w/2640'. Rotate 140 rpm w/12 to 14k ft lbs of torque Pulling speed 35 to 115 fph. PU wt 185k,SO wt 150k, Rot wt 160k. Tight/Slow reaming 4900',4777', 4775'and 4771'. 4930': Pumped 36 bbl low vis nut plug sweep—returned 53 bbls late. 4839': Pumped 37 bbl Hi vis nut plug sweep--returned 40 bbls late. 4836': Dilution of 250 bbls of 10.7 ppg mud. 08:00 12:00 4.00 4,765 4,082 INTRM1 DRILL REAM P Back ream out of the hole f/4765'to 4082'. Pumping 800 gpm w/2270 psi. Rotate 120 rpm w/11k ft lbs of torque. PU wt 175k,SO wt 145k, Rot wt 155k. Tight/Slow reaming 4520'. Drop 2.71" Hollow drift on stand#32. Page 21 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 4,082 3,421 INTRM1 DRILL REAM P Back ream out of the hole f/4082'to 3421'. Pumping 800 gpm w/2270 psi. Rotate 120 rpm w/12k to 17k ft lbs of torque. PU wt 175k,SO wt 145k, Rot wt 155k. 3695: Pumped 40 bbl low vis nut plug sweep--returned 1.5 PPB Desco. Hole unloaded prior to sweep returns. Saw large amount of clay Y balls, shale up to 4"in diameter before,during and after sweep. Came back on time. 3590': Pumped 40 bbl Hi vis nut plug, 1 PPB Desco.On time. Large quantities of fine, mushy clay cuttings with some large clay balls. 3560: Pumped 40 bbl Hi Vis nut plug sweep. . Large quatities of fines, and clays.One time. 3514' :Pumped 40 bbl 12.7 PPG,w/ 5 PPB nut plug med..On time. Large quantities of fine,mushy clay cuttings with some large clay balls. After this sweep waves of fine cuttings began to come over the shakers,every 10 to 15 mins we'd see 5 mins of fines running over. ECD's spikes up to 11.5 PPG from 11.15 PPG. One mud dilution 250 BBLS @ 3485' MD. 11/19/2012 Continue to back ream out of 11-1/2"hole w/BHA#2 f/3421'to 2720'. Work ghost reamer, reamer,stabilizers into the casing. Pump 6 sweeps in aid in hole cleaning. Sweeps @ 3415'MD.40 BBL 12.7 PPG.3411'MD.40 BBL Hi-Vis. 3323'MD.40 BBL Hi-Vis. 3276'MD.40 BBL 12.7 PPG.3195'MD.40 BBL 12.7 PPG.3039'MD.40 BBL 12.7 PPG. Page 22 of 75 Time Logs Date From To Dur S. Death E.Death Phase Code Subcode T Comment 00:00 06:30 6.50 3,421 3,288 INTRM1 DRILL REAM P Back ream out of the hole f/3421'to 3288'. Pumping 800 gpm w/2200 psi,850 gpm w/2440 psi. Rotate 140 rpm w/10k to 19k ft lbs of torque while pulling 3 to 10k over rotating weight. PU wt 155k,SO wt 140k, Rot wt 145k. 3411': Pumped 40 bbl high vis nut plug sweep w/1.5 PPB Desco. Large increase in larger cuttings/ clay balls.Came back 60 bbls late. 3415': Pumped 40 bbl weighted(12.7 ppg) nut plug sweep. Large increase in larger cuttings/clay balls.Came back 40 bbls late. 3323': Pumped 40 bbl Hi-vis nut plug sweep w/1.5 PPB Desco. Large increase in larger cuttings/ clay balls.Came back 46 bbls late. One mud dilution 250 BBLS @ 3310' MD. 06:30 07:00 0.50 3,288 3,288 INTRM1 DRILL TRIP P Attempt to POOH with pumps f/ 3228'. Pulled f/3288'to 3271'. PU wt 154,SO 140k. Pumping 320 gpm w/ 400 psi. Pulled up to 205k—No good. 07:00 12:00 5.00 3,288 3,125 INTRM1 DRILL REAM P Back ream out of the hole f/3288'to 3125'. Pumping 800 gpm w/2120 psi,900 gpm w/2600 psi. Rotate 120 rpm w/8k to 20k ft lbs of torque while pulling 3 to 10k over rotating weight. 3276': Pumped 40 bbl weighted(12.7 ppg)nut plug sweep. Large increase in larger cuttings/clay balls.Came back 90 bbls late. 3195': Pumped 37 bbl weighted(12.7 ppg) nut plug sweep. Slight increase in larger cuttings/clay balls. One mud dilution 250 BBLS @ 3315' MD. 12:00 12:45 0.75 3,125 3,105 INTRM1 DRILL REAM P Back ream out of the hole f/3125'to 3105'. Pumping 900 gpm w/2320 psi w/32%Totco flow out. Rotate 140 rpm w/10k to 15k ft lbs of torque. Slight packoff-partial loss of returns. ECD spike of 13.09 ppg. 12:45 13:00 0.25 3,105 3,137 INTRM1 DRILL CIRC P Drop down to 3137',then circulate with full returns pumping 500 gpm w/ 1200 psi, rotate 80 rpm w/8k ft lbs of torque. Page 23 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 17:45 4.75 3,137 2,955 INTRM1 DRILL REAM P Back ream out of the hole f/3137'to 2955'. Pumping 850 gpm w/2200 psi,900 gpm w/2320 psi w/31% Totco flow out. Rotate 140 rpm w/ 12k to 15k ft lbs of torque while pulling 3 to 10k over rotating weight. 3039': Pumped 37 bbl weighted(12.7 ppg)nut plug sweep. Large increase in larger cuttings/clay balls. Came back 20 bbls late. One mud dilution 250 BBLS while Reaming from 3023'to2928'MD. 17:45 19:45 2.00 2,955 2,955 INTRM1 DRILL RGRP T Shut down back reaming operations. Wait on MI Swaco ball mill to repair a 3"fitting and clean up a spill of 40 gallons of mud.Total of 1 gallon estimated outside of building on a rig mat. Note: Monitor well,pump every 15 minutes to keep things f/freezing. 19:45 21:30 1.75 2,955 2,787 INTRM1 DRILL REAM P Back ream out of the hole f/2955'to 2787'. Pumping 850 gpm w/2250 psi. Rotate 8 rpm w/9k ft lbs of torque while pulling 3 to 10k over rotating weight. Observed ghost reamer enter 11-3/4"casing shoe.Observed overpull trying to get the Weatherford reamer into the shoe. 21:30 22:00 0.50 2,787 2,787 INTRM1 DRILL REAM P Attempt to pull reamer into the shoe, pumping 800 gpm w/2000. No go. Pulled 25k over.Turn pumps off, attempt to pull w/no pump, no rotary,pulled 30k over and entered casing. 22:00 23:00 1.00 2,787 2,761 INTRM1 DRILL CIRC P Stand back a stand to 2761'. Drop 4 RFID tags. Pump down @ 250 gpm w/250 psi. No pressure increase indicating the tool responded to the antennae. Decide not to rotate due to the uncertainty of the position and condition of the reamer. 23:00 00:00 1.00 2,761 2,720 INTRM1 DRILL CIRC P Begin pulling the BHA into the surface casing.800 GPM 2100 PSI. No rotation. Each stabilizer required wiping into and out of the casing to remove the clay balls. 11/20/2012 Pump BHA into shoe.CBU 2x's.2667'MD.Monitor well. Static. Pull 4 stds. Improper hole fill.TIH.C&C mud system.Monitor well. Static.Pump out to the BHA.800 GPM. Pump 3 weighted nut plug sweeps 40 BBLS each to aid in hole cleaning. Monitor well every 5 stands.Static. L/D BHA#2.All tools retreived, and in good shape. Bit grade 1-1. Rig up to test BOPE. Begin test. 00:00 01:15 1.25 2,720 2,667 INTRM1 DRILL CIRC P POOH with pump @ 800 GPM,2050 PSI,fr 2720 to 2667'MD. 155k Up, 130k Dn. Page 24 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 02:30 1.25 2,667 2,667 INTRM1 DRILL CIRC P Circulate a weighted sweep.2#'s over. 12.7 PPG 40 BBL 5#BBL nutplug.800 GPM 1980 PSI, up to 900 GPM 2350 PSI. Good returns of cobble size sdtsone/mudsone and clay cuttings. Some increase in fine cuttings. ECD drop from 11.5 PPG down to 11.15 PPG after two bottoms up. 02:30 03:15 0.75 2,667 2,667 INTRM1 DRILL OWFF P Blow down top drive. Line up on trip tank. Monitor well. Slight flow for 8 mins. Unmeasurable volume to trip tank.Observe well 30 mins.Static. 03:15 04:15 1.00 2,667 2,290 INTRMI DRILL TRIP P Pump out 4 stands.2667'to 2290' MD.800 GPM, 1930 PSI. Improper hole fill.Mud balance weight out of spec.Stop. 04:15 04:30 0.25 2,290 2,290 INTRM1 DRILL SFTY P Prejob. Prepare to trip back to the shoe. Discuss the need to keep good track of hole fill. 04:30 05:00 0.50 2,290 2,667 INTRM1 DRILL TRIP P Pump 4 stands back to the shoe. 300 GPM,310 PSI. 05:00 06:00 1.00 2,667 2,667 INTRM1 DRILL CIRC P Condition mud.Add screen clean and defoamer to obtain 10.5 PPG mud balance in and out. 10.7 PPG pressure scale in and out. 06:00 06:30 0.50 2,667 2,667 INTRM1 DRILL OWFF P Blow down top drive.Monitor well. Static. 06:30 11:45 5.25 2,667 1,254 INTRMI DRILL TRIP P POOH pumping 800 to 900 GPM. 1960 PSI to 2490 PSI.500 to 600 GPM, 1050 PSI to 1240 PSI. Pump 12.7 PPG 40 BBL nutplug sweeps @ 2197, 1726, 1254. Flow check every 5 stands.Static. Large increase in cuttings on each sweep seen on shakers. 11:45 12:00 0.25 1,254 1,254 INTRM1 DRILL OWFF P Observe wellbore at top of HWDP. Static. 12:00 14:15 2.25 1,254 261 INTRM1 DRILL TRIP P Pump out of the hole from 1254'to 261'MD.800 GPM, 1000 PSI. 14:15 14:30 0.25 261 261 INTRM1 DRILL SFTY P Observe well. Prejob meeting on laying down BHA with Baker DD& MWD hands.Well static. 14:30 17:00 2.50 261 0 INTRM1 DRILL PULD P Lay down BHA components. Retrieve large piece of silver bullet shoe from surface casing on top of ghost reamer blades. 1700 17:30 0.50 0 0 INTRM1 DRILL PULD P Plug in and down load MWD string. Clean and clear rig floor. 17:30 18:30 1.00 0 0 INTRM1 DRILL PULD P Complete laying down BHA#2. 18:30 19:00 0.50 0 0 INTRM1 DRILL RURD P Remove BHA components from rig floor. Clear and clean. 19:00 20:15 1.25 0 0 INTRM1 DRILL BOPE P Flush out stack. 10 BPM 50 RPM. Blow down top drive. 20:15 20:45 0.50 0 0 INTRM1 DRILL BOPE P Pull wear bushing with FMC hand. Set lower test plug. Page 25 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 21:00 0.25 0 0 INTRM1 DRILL SFTY P PJSM. Rig up and test BOPE. Discuss all hazards 21:00 22:00 1.00 0 0 INTRM1 DRILL RURD P Rig up to test BOPE. Fill lines,get air out of all lines. 22:00 00:00 2.00 0 0 INTRM1 DRILL BOPE P Perform BOPE test with water. Monitor annulus during test.Test annular preventer to 250 PSI low/ 2500 PSI high 5 mins.Charted.Test Choke room valves, 1,2,3,5,6,7,8,9,10,11,12,13,14,15,16, HRC Kill, Upper IBOP, Lower IBOP, Upper pipe rams,dart valve, FOSC, needle valve on choke manifold.All tests to 250 PSI low/3500 PSI high. All tests charted for 5 mins each. Annulus was monitored during test. One barrel lose for 3 hours. AOGCC Inspector Chuck Scheve waived witness of test on 11/19/2012 @ 09:26 HRS via email. 11/21/2012 Test BOPE.All components tested to 250 PSI low/3500 PSI high.Charted for 5 mins each test.Annular tested to 250 PSI low/2500 PSI high Charted for 5 mins each test. Bi-weekly test.AOGCC Inspector waived witness. Complete test.Change out upper rams to 9.625"for liner run. Replace upper rams and test. Rig up and run 9 5/8"40#L-80 Hydril 521 liner to 3815'MD,with Tesco system installed on top drive. 00:00 01:45 1.75 0 0 INTRM1 DRILL BOPE P PJSM.Crew change.Testing BOPE. Test HCR choke,4"DEMCO on kill side, manual choke,manual kill, lower Pipe Rams, Blind Rams, choke valve#4,Test to 250 PSI low, 3500 PSI high.charted for 5 mins each test. 01:45 02:00 0.25 0 0 INTRM1 DRILL BOPE P PJSM,pull test plug,drain stack, blow down lines. 02:00 03:30 1.50 0 0 INTRM1 DRILL RURD P PJSM,Change out upper pipe rams to 9 5/8". 03:30 04:30 1.00 0 0 INTRM1 DRILL BOPE P PJSM, Install test plug with FMC Service Hand. Fill stack with water, rig up to test 9 5/8"rams in upper ram cavity. 0430 05:15 0.75 0 0 INTRM1 DRILL BOPE P PJSM,Test 9.625"Rams.250 PSI low/3500 PSI high.Charted 5 mins each test.Test annular preventer. 250 PSI low/2500 PSI high. Charted 5 mins each test. Rig down test equipment. 05:15 05:45 0.50 0 0 INTRM1 DRILL RURD P Pull test plug.Set wear ring. 05:45 08:45 3.00 0 0 INTRM1 CASING RURD P PJSM, Rig up Tesco eqipment. 08:45 09:15 0.50 0 0 INTRM1 CASING SFTY P PJSM. Running 9.625"L-80 40# Liner as per detail. 09:15 10:45 1.50 0 245 INTRM1 CASING RNCS P Run casing as per detail to 245'.6 joints.Torque to 17k on topdrive equals 14k on the Tesco system. 10:45 12:00 1 25 245 245 INTRM1 CASING CIRC P Circulate @ 3 BPM,50 PSI. Rig up casing tongs to calibrate Tesco torque sensors Page 26 of 75 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 12:00 18:45 6.75 245 2,660 INTRM1 CASING RNCS P Run casing as per detail to 2660'.63 joints in the hole. Running speed 700'/hr.Calculated displacement=38 BBLS,Actual displacement=30 BBLS. 18:45 20:00 1.25 2,660 2,660 INTRM1 CASING CIRC P Circulate @ shoe. Stage pumps up from 1 BPM to 7 BPM. ICP=160 PSI. FCP=380 PSI. Circulate 2800 strokes. MW in 10.7,MW out 10.8 PPG. Circulate in and out of pit 5. 20:00 00:00 4.00 2,660 3,815 INTRM1 CASING RNCS P Run casing as per detail to 3815'.90 joints in the hole. Running speed 700'/hr.to 3360'MD.Appears to be pushing away 2 barrels each 10 joints. Slow running speed to 500'/hr. Joint#79 was taken out/replaced with#215. Flat spot.Calculated displacement=55 BBLS,Actual displacement=40 BBLS.Pushed 15 barrels away since start of run. 11/22/2012 Run 9 5/8"40#L-80 Hydril 521 liner from 3815'MD to 8242'MD.Circulate and condition mud 3.5 BPM. Rig down Tesco system.(20 mins)Become differentially stuck for 1.5 hours. Free liner using slump and dump method. C&C mud before picking up Baker liner hanger. 00:00 06:00 6.00 3,815 5,470 INTRM1 CASING RNCS P Run casing as per detail to 5470'MD. 129 Joints in the hole. Running speed 500'/hr to 550'/hr. 06:00 08:15 2.25 5,470 5,470 INTRM1 CASING CIRC P Circulate and condition mud.Stage pump up to 4.5 BPM,310 PSI,215k Up, 160k Dn weights. Positioned 200 feet above the Quannik. 08:15 12:00 3.75 5,470 6,669 INTRM1 CASING RNCS P Run casing as per detail from 5470'MD to 6669'MD. 158 Joints in the hole. Running speed 500'/hr to 550'/hr. 170k Dn weight. 12:00 16:15 4.25 6,669 8,242 INTRM1 CASING RNCS P Run casing as per detail from 6669 'MD to 8242'MD. 197 Joints in the hole. Running speed 500'/hr to 700'/hr. 16:15 19:15 3.00 8,242 8,242 INTRM1 CASING CIRC P Circulate and condition the mud. Stage pumps up. 1 BPM 320 ICP, 3.5 BPM 440 FCP. Fluid loss 2.4 ml. MW In and out 10.7 PPG.300k Up/170k Dn.SIMOPS: Prejob safety meeting in the Dog House, Rig down Tesco Equipment,and Rig up Baker Liner Hanger. 19:15 19:30 0.25 8,242 8,242 INTRM1 CASING RURD P Rig down Tesco system. 19:30 20:00 0.50 8,242 8,242 INTRM1 CASING CIRC T Make up top drive to 9.625"liner. Pick up to normal up weight of 350, would not move,slack off to 75k, no movement. Bring up weight up to 500k, no movement. Pumping 1.5 BPM 200 PSI. 20:00 20:30 0.50 8,242 8,242 INTRM1 CASING RURD T Rig up bails and elevators to pick up a single to work liner free. Pick up 5" DP single from pipe shed. Page 27 of 75 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 20:30 21:15 0.75 8,242 8,242 INTRM1 CASING CUTP T Work 4 wraps into liner with 20k ft/lbs of torque. Pull up to 300k,and slack off to 100k as the torque moved down hole.After 20 mins of this activity,the torque was brought up to 25k,4 more wraps were put in the string,and the string broke free while slacking off and holding the torque.Appeared to be stuck at Quannik using stretch data.Approx. 4500'to 6400'stuck point.One full wrap returned, 7 stayed downhole. 21:15 00:00 2.75 8,242 8,242 INTRM1 CASING CIRC P Begin to work pipe from 8280 up to 8240'.Circulate and condition the mud. Prepare to add 250 BBLs of fresh mud,4 lbs/barrel nut plug, lower fluid loss,add lubricants. Pump 5 BPM,435 PSI. Up Wt 300k, Dn WT 150k.Some over pull to 325k. 11/23/2012 Circulate and condition the mud @ 8242'MD.Spot 5.5 lbs/bbl LCM in open hole to reduce differential sticking. Perform 20 min static test. Broke free with 140k down 50k extra down drag.Make up Baker hanger. Trip in the hole to bottom.Circulate and condition the mud system for cement job. Pump cement job as per details. Pump 30 BBLS Chemcial Wash. Pump 48 BBLS 11.5 PPG Mud push. Pump 266 BBLS 12.2 PPG Lead cement. Pump 85 BBLS 15.8 PPG Tail cement Drop Dart. End of tour. 00:00 03:30 3.50 8,242 8,242 INTRM1 CASING CIRC P Circulate and condition mud @ 5 BPM,380 PSI,290k Up, 175k Dn. Pump 4 lbs/BBL med nut plug, 1.5 lbs/BBL DynaRed fine over 350 BBLS. Place this volume into open hole up to shoe. Reciprocate pipe through out job. 03:30 04:15 0.75 8,242 8,242 INTRM1 CASING RURD P PJSM.Static test for 20 mins to verify good hole conditions to pick up hanger.SIMOPS: Install bell guide. After 20 mins,broke free going down with 140k, normal down weight 190k. Passed test. 04:15 05:45 1.50 8,242 8,242 INTRM1 CASING RURD P PJSM,picking up Baker liner hanger. Make up hanger as per Baker rep. Work pipe as needed.Mix 15 gals pal mix. Let set up for 30 mins.Work pipe and pump @ 2 BPM,250 PSI, 310K Up, 190k Dn. Break over coming up out of slips @ 350k, 125k down. 05:45 06:45 1.00 8,242 8,639 INTRM1 CASING RUNL P Trip in the hole with liner on 5"DP. 06:45 12:00 5.25 8,639 10,323 INTRM1 CASING RUNL P Wash down each stand w/1.5 BPM, 390 PSI.from 8639'to 10323'MD. Good hole conditions. 12:00 16:00 4.00 10,323 10,758 INTRM1 CASING RUNL P Wash down each stand w/1.5 BPM, 370 PSI,from 10323'to TD. 10,758' MD.Work string through the last 117'of 10 5/8"hole. Some extra drag while reciprocating. Page 28 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 19:15 3.25 10,758 10,758 INTRM1 CASING CIRC P Circulate and condition mud, reciprocate.Stage pump up to 7 BPM. 530 FCP.SIMOPS: Prejob on picking up the cement head. 19:15 20:00 0.75 10,758 10,758 INTRM1 CEMEN"RURD P Rig up Baker cement head. Pick up and connect hoses. 20:00 22:00 2.00 10,758 10,758 INTRM1 CEMEN"CIRC P Circulate and condition mud to 10.5 PPG in and out.SIMOPS: Prejob Meeting,Cement job in Dog House with all parties. 22:00 00:00 2.00 10,758 10,753 INTRM1 CEMEN"CMNT P Begin Cement job. Pump 1.5 BBLS CW100. Pressure test lines to 4000 PSI. Good. Pump 28.5 BBLS CW100 @ 4 BPM/440 PSI. Pump 48 BBLS 11.5 PPG Mud push @ 4.5 BPM/450 PSI. Pump 266 BBLS 12.2 PPG Lead cement @ 4.5 BPM/ ICP=285 PSI/FCP0 PSI. Purnp 85 BBLS 15.8 PPG Tail cement @ 4.8 BPM/ICP=90 PSI/FCP=150 PSI. Drop Dart. End of tour. 11/24/2012 Bump plug with 20 barrels water&631.2 BBLS mud.Set hanger,check floats,set packer. Pick up to circulate.CBU. POOH 3 stands. Pressure test to 1000 PSI, 10 mins,charted. POOH to lay down running tool.Change out upper pipe rams to 4%"x 7"VPR's, change out lower pipe rams to 2 7/8"x 5". Begin testing with 4 test joint.Test lower pipe rams,and annular. Pick up 5"test joint,test upper/lower pipe rams and annular. Pick up 2 7/8"test joint. No test. Begin trouble shooting annular preventer. Decide to change out the element of the annular preventer. 00:00 02:00 2.00 10,753 2,492 INTRM1 CEMEN"CMNT P Pump with rig pump to bump plug on 9.625"L-80 40#HYD 521 liner. Pump @ 7 BPM/ICP=390 PSI, FCP=1110 PSI,displace 600 barrels and slow down to 3 BPM/ICP=730 PSI. Plug landed @ 652.2 barrels. Calculated displacement=652.15 barrels. Pressure up to 3500 PSI. Set hanger. Bleed down to 500 PSI. Slack off to 100k,Verify tool in compression. Bleed pressure to zero.Floats holding. Rotate 20 turns. Release. Pick up with 130k. Liner set in place.Shoe depth 10753'MD. Top of hanger @ 2492'MD. 02:00 02:45 0.75 2,492 2,472 INTRM1 CEMEN"RURD P Blow down cement line, rig down and lay down cement head, pick up joint from shed and pull out of liner hanger to 2472. 02:45 03:00 0.25 2,472 2,472 INTRM1 CEMEN"CIRC P Circulate bottoms up to clear liner top and look for cement.800 GPM/ 1170 PSI. No mud push seen on surface. 03:00 03:30 0.50 2,472 2,241 INTRM1 CEMEN"TRIP P Trip out 3 stands.Observe well, static. 03:30 04:15 0.75 2,241 2,241 INTRM11 CEMEN"PRTS P Rig up and test casing to 1000 PSI. 10 mins. Charted Good test 04:15 05:30 1.25 2,241 0 INTRM1CEMEN"TRIP P Trip out on elevators to liner running tool. Good hole fill. Page 29 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 06:00 0.50 0 0 INTRM1 CEMEN'OWFF P Observe well for 30 mins.Static. 06:00 06:15 0.25 0 0 INTRMI CEMEN'PULD P Pick up cement head,and break off pup joint. 06:15 06:45 0.50 0 0 INTRM1 WHDBO SFTY P Prejob safety meeting. Discuss how to change out top and bottom rams, followed by how to change out the saver sub. 06:45 11:00 4.25 0 0 INTRM1 WHDBO BOPE P Change out top rams to 4W x 7", Bottom rams to 2 7/8"x 5'variable pipe rams.Change out saver sub. 11:00 11:30 0.50 0 0 INTRM1 WHDBO RURD P Pull wear bushing with FMC service hands. Install upper test plug. 11:30 12:00 0.50 0 0 INTRM1 WHDBO BOPE P Pick up 5"test joint.Test annular preventer.250 PSI low/2500 PSI high.Charted 5 mins each test. 12:00 12:45 0.75 0 0 INTRM1 WHDBO BOPE P Tighten Driller side top pipe ram doors. Leak. 12:45 13:00 0.25 0 0 INTRM1 WHDBO NUND P Safety meeting on'Replacing ram door seals". 13:00 14:30 1.50 0 0 INTRM1 WHDBO NUND P Replace seal on upper pipe ram door, Driller's side. 14:30 18:00 3.50 0 0 INTRM1 WHDBO BOPE P Test w/4"test joint.Annular preventer 250 PSI low/2500 PSI high, Lower VPR's to 250 PSI low/3500 PSI high, all tests charted for 5 mins. Test with 5"test joint.Annular preventer 250 PSI low/3500 PSI high, Lower VPR's and Upper VPR's, 250 PSI low 3500 PSI high,all tests charted for 5 mins.Test with 2 7/8" test joint,Test Lower VPR's 250 PSI low/3500 PSI high,attempt test with Annular Preventer. No test.Vary closing pressures, no test. 18:00 21:00 3.00 0 0 INTRM1 WHDBO BOPE T Trouble shoot Annular Preventer. Using 2 7/8"test joint.Could not get a 2500 PSI high pressure test. Decide to change out the element. 21:00 21:30 0.50 0 0 INTRM1 WHDBO PULD T Pull test plug. 21:30 21:45 0.25 0 0 INTRM1 WHDBO SFTY T Pre job on changing out the Annular element. 21:45 00:00 2.25 0 0 INTRM1 WHDBO RURD T Pull mouse hole, nipple down riser flow line,pick up'potato masher', torque on 5"DP single,make up to top of annular. 11/25/2012 Brake annular cap,change out annular element. Nipple back up.Nipple up adapter flange riser,flow line,and all turn buckles. Install test plug.Test new element with 2 7/8",4",5",7"test joints.250 PSI low/2500 PSI high, charted for 5 mins each test.Test upper variable pipe rams(4W x 7")with 7"test joint,250 PSI low/ 3500 PSI high, charted for 5 mins each test.Test lower variable pipe ram(2 7/8"x 5")with 2 7/8"test joint, 250 PSI low/3500 PSI high,charted for 5 mins each test. Rig down test equipment. Lay down HWDP.24 joints. Pick up BHA#3. Rotary clean out assembly.Single in the hole. 00:00 12:00 12.00 0 0 INTRM1 WHDBO NUND T Brake off and remove annular cap. Remove old annular element, install new element. Nipple up. Page 30 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:15 0.25 0 0 INTRM1 WHDBO SFTY T Prejob meeting about the hazards of installing the riser,flow line and turn buckles.Also testing BOPE. 12:15 14:00 1.75 0 0 INTRM1 WHDBO NUND T Nipple up adapter flange, riser,flow line, re-installed all turn buckles. 14:00 14.30 0.50 0 0 INTRM1 WHDBO RURD P Install test plug with FMC service rep. 14:30 19:15 4.75 0 0 INTRM1 WHDBO BOPE P Test the annular preventer with 4 sizes of test joints.2 7/8",4",5",7", test to 250 PSI low/2500 PSI high, charted for 5 mins.each test.Test upper variable pipe rams with 7"test joint.250 PSI low/3500 PSI high, charted for 5 mins each test.Test lower variable pipe rams with 2 7/8" test joint.250 PSI low/3500 PSI high. Charted for 5 mins.each test. 19:15 19:45 0.50 0 0 INTRM1 WHDBO RURD P Rig down test equipment. Install wear bushing with FMC Rep. 19:45 20:15 0.50 0 0 INTRM1 CEMEN"PULD P Blow down top drive and all lines. 20:15 20:30 0.25 0 0 INTRM1 CEMEN"SFTY P PJSM. Lay down 8 stands of 5" HWDP from derrick into pipe shed. Also discuss picking up the next BHA. 20:30 21:45 1.25 0 0 INTRM1 CEMEN"PULD P Lay down 8 stands of 5"HWDP from derrick into pipe shed. 21:45 23:00 1.25 0 256 INTRM1 CEMEN'PULD P PJSM, Pick up Baker BHA#3. Rotary clean out and rat hole assembly. Bit/HTC mill tooth, NB stab, 1 spiral collar, 1 stand HWDP, jars, 1 stand HWDP,to 5"DP. 23:00 23:15 0.25 256 256 INTRM1 CEMEN"SFTY P PJSM,picking up Western Well Tools non-rotating sleeves on drill pipe. Discussed pinch points. 23:15 00:00 0.75 256 256 INTRM1 CEMEN"TRIP P Assemble the WVVf'super sliders', parts,tools needed to begin the job. Air hose hook up,stock pile 200 sleeves on rig floor. 11/26/2012 Trip in the hole. Install 378'super sliders on drill string'.One per joint on all stands,except stands#90 to #105 have two super sliders per joint. 113 stds of 5"DP.Trip to top of landing collar. 10619'MD.CBU. Perform casing_test. 3500 PSI 30 mins.Good. Slip and cut DL.60'. Drill landing collar. 00:00 00:30 0.50 256 256 INTRM1 CEMENT PULD P Continue to stockpile the WVVf non-rotating protectors on the rig floor. 00:30 00:45 0.25 256 256 INTRM1CEMEN'SFTY P PJSM with VWVT Reps.on installation of protectors. 00:45 02:00 1.25 256 822 INTRM1 CEMEN'TRIP P Trip in hole with singles, placing the non-rotating protectors on each single. RIH with 18 joints out of the pipeshed 02:00 03:30 1.50 822 2,137 INTRM1 CEMEN'TRIP P Trip out of the derrick,placing non-rotating protectors on each single.Trip in 20 stands. Page 31 of 75 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 03:30 04:00 0.50 12,137 2,137 INTRM1 CEMEN'CIRC P Fill pipe.Confirm proper displacement. 16 BBLS. Blow down tiop drive. Prepare to continue in the hole picking up the'super sliders' 04:00 12:00 8.00 2,137 8,919 INTRM1 CEMEN'TRIP P Trip in the hole from derrick. Installing'super sliders'one per single to stand#90. Install 3 per stand to stand#105.All super sliders were the standard blue style, except for stands#77 to#89 have the orange style. Fill pipe every 20 stands. Proper mud displacement. 12:00 15:00 3.00 8,919 10,425 INTRM1 CEMEN'TRIP P Trip in the hole installing'super sliders'from 8919'to 10425'MD. 15:00 15:45 0.75 10,425 10,619 INTRM1 CEMEN"WASH P Wash down from 10425'to 10619'. 400 GPM, 1200 PSI,40 RPM, 12k TQ. 15:45 16:45 1.00 10,619 10,619 INTRM1 CEMEN"CIRC P CBU.600 GPM,2200 PSI,80 RPM, 13k TQ. 16:45 18:45 2.00 10,619 10,619 INTRM1 CEMEN"PRTS P Rig up to test casing.Test to 3500 PSI for 30 mins. Blow down lines, rig down test equipment. 18:45 19:00 0.25 10,619 10,619 INTRM1 CEMEN"SFTY P Prejob safety meeting.Slip and cut drilling line. Discussed hazards,and dropped objects potentials during job. 19:00 20:15 1.25 10,619 10,619 INTRM1 CEMEN"SLPC P Slip and cut 60 feet of line. Inspect. 20:15 21:30 1.25 10,619 10,619 INTRM1 CEMEN"SVRG P Service rig.Top drive. Draw works. SIMOPS: Rig electrician and Tesco hands trouble shooting electronic torque readouts. 21:30 00:00 2.50 10,619 10,645 INTRM1 CEMEN"DRLG P Drill landing collar.Tag up @ 10636' MD.600 GPM/2200 PSI/100 RPM/ 13k on bottom TQ. 11/27/2012 Drilled out shoe track&20'new hole to 10,778'-Circ&perform FIT to 12.5 ppg EMW-Drill 8 1/2"hole f/ 10,778'to 10,815'-Circ hole clean-POOH to 346-RIH to 2325-Circ&condition mud-RIH to 2796'-Circ btms u D(mud wt out 10.5 ppg)POOH to 1384' 00:00 01:15 1.25 10,645 10,675 INTRM1 CEMEN"DRLG P Drill out cement from 10,645'to 10,675'at 600 gpm-2070 psi-100 rpm-13k Torque-12-14k bit wt. 01:15 03:30 2.25 10,675 10,757 INTRM1 CEMEN'DRLG P Drill out float collar and cement from 10,675'to 10,757'at 600 gpm-2070 psi-100 rpm-13k Torque-12-14k bit wt. 03:30 04:00 0.50 10,757 10,758 INTRM1 CEMEN-DRLG P Drill out float shoe from 10,757'to 10,758'at 600 gpm-2130 psi-100 rpm-13k Torque-12-14k bit wt. 04:00 05:00 1.00 10,758 10,778 INTRM2 DRILL DRLG P Drill 20'of 8 1/2"new hole from 10,758'to 10,775.ADT-1.0 hr. 05:00 05:45 0.75 10,778 10,778 INTRM2 DRILL CIRC P Circulate and condition mud at 600 gpm-2000 psi-100 rpm-12.5-16k torque. Flow check well. Static. 05:45 06:45 1.00 10,778 10,778 INTRM2 DRILL FIT P Perform 12.5 ppg FIT with 10.5 ppg mud,6826'TVD and 710 psi surface pressure. Page 32 of 75 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 06.45 08:15 1.50 10,778 10,815 INTRM2 DRILL DRLG P Drill new formation from 10,778'to 10,815'.6846'TVD.ADT 1.3 hrs. 08:15 09.30 1.25 10,815 10,778 INTRM2 DRILL CIRC P Circulate and condition mud for SDL run at 600 gpm-2000 psi-100 rpm- 12.5-16k torque Flow check well. Static. 09:30 10.00 0.50 10,778 10,237 INTRM2 DRILL TRIP P POH on trip tank from 10,778'to 10,237'. Hole taking proper fill. Flow check well. Static. 10:00 10:30 0.50 10,237 10,237 INTRM2 DRILL OTHR P Pump 30 bbl dry job for trip. 10:30 12:00 1.50 10,237 8,355 INTRM2 DRILL TRIP P POH on trip tank from 10.237'to 8355/Dropped 2.70"rabbit on stand #86. 12:00 16:30 4.50 8,355 818 INTRM2 DRILL TRIP P Cont. POOH on TT f/8355'to 818' 16:30 16:45 0.25 818 818 INTRM2 DRILL OWFF P Flow ck well static in 5 mins. 16:45 17:30 0.75 818 346 INTRM2 DRILL TRIP P Cont. POOH on TT f/818'to 346' 17:30 18:00 0.50 346 346 INTRM2 DRILL OWFF P Flow ck well-static in 5 mins. Note-On the trip out,the trip was mistakenly filled with light mud(10.0 ppg)w/50 stds DP still in hole 18:00 20:00 2.00 346 2,325 INTRM2 DRILL TRIP T RIH f/346'to 2325'-Filled pipe @ 2137' 20:00 20:45 0.75 2,325 2,325 INTRM2 DRILL CIRC T Circ&condition mud back to 10.5 ppg(first mud wt back was 10.3 ppg)@ 350 gpm @ 420 psi-PU wt 115k SOwt115k 20:45 21:30 0.75 2,325 2,796 INTRM2 DRILL TRIP T RIH f/2325'to 2796' 21:30 22:45 1.25 2,796 2,796 INTRM2 DRILL CIRC T Circ btms up @ 300 gpm @ 400 psi -Btms up wt @ 2796'was 10.5 ppg- Blow down TD-Flow ck well static 22:45 00:00 1.25 2,796 1,384 INTRM2 DRILL TRIP T POOH on TT f/2796'to 1384'-Hole taking proper fill 11/28/2012 Finish POOH w/5"DP-LD clean out assembly-RU&PU&std back 9 stds 4'DP-MU lower section of inner string-RU&ran 7"liner to 1013'-MU&check 4"floor safety assembly-PU lower section of inner string&ran into 7"liner to 90' 00:00 01:00 1.00 1,384 256 INTRM2 DRILL TRIP P Finish POOH w/5"DP-Flow ck- well static 01:00 02:00 1.00 256 0 INTRM2 DRILL PULD P LD HWDP-jars-XO-DC-NB stab &bit 02:00 03:00 1 00 0 0 INTRM2 DRILL OTHR P Clean up&clear rig floor-Change elevtors to 4"-prep to PU 4"DP 03:00 04:30 1.50 0 0 INTRM2 DRILL PULD P PU&std back 27 jts.(9 stds)4"DP f/pipe shed 04:30 04:45 0.25 0 0 INTRM2 DRILL SFTY P Held PJSM on making up lower section of Baker SDL BHA 04:45 08:00 3.25 0 134 INTRM2 DRILL PULD P MU SLD BHA(inner string)as follows:6"bit-4 3/4"GT steering head-Mod Stab-On Trak-CoPilot- Mod stab-reamer drive sub-4 3/4" X-Treme/Mod-Plug in&check tools-MU BCPM-Smart barrery w/ XO-Plug in&check tools- Page 33 of 75 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 08:00 08:45 0.75 134 134 INTRM2 DRILL CIRC P Shallow test MWD tools @ 300 gpm @ 1570 psi 08:45 09:15 0.50 134 0 INTRM2 DRILL TRIP P Blow down TD-Change elevators- LD BCPM&Smart battery in shed- Stand back remaining BHA in derrick 09:15 10:00 0.75 0 0 INTRM2 DRILL PULD P MU thruster-float sub-filter sub& XO- LD in pipe shed 10:00 11:30 1.50 0 0 INTRM2 DRILL PULD P MU Well Commander&1 std 5"DP -Test BPA lines to 3500 psi- Dropped ball&open well commander @ 1780 psi-Closed @ 1770 psi- Std back 5"DP-MU EMS&LD in pipe shed 11:30 12:00 0.50 0 0 INTRM2 DRILL OTHR P Clear floor-LD drilling bails& elevators-Remove bell guide 12:00 12:45 0.75 0 0 INTRM2 DRILL PULD P PU Thruster assembly&break out EMS tool-LD thruster assembly& EMS tool-PU 7"XO safety valve assembly 12:45 13:00 0.25 0 0 INTRM2 DRILL SFTY P PJSM on rigging up Tesco tools 13:00 14:00 1.00 0 0 INTRM2 DRILL RURD P RU Tesco CDS equipment 14:00 14:15 0.25 0 0 INTRM2 DRILL SFTY P PJSM on running 7"liner 14:15 18:00 3.75 0 1,013 INTRM2 CSGDRI RUNL P Ran 7"26#L-80 Tenaris Hydril liner as follows: Baker reamer shoe w/ pup jt.-24 jts liner-Baker Quick connect-Installed Hyrdo-Form centralizers in the middle of jts 1 thru 13&jts. 16,19,&22 thru 24 w/PESI crimping tool-total liner length 1013' -Break out Quick connect running tool 18:00 18:15 0.25 1,013 1,013 INTRM2 CSGDRISFTY P Held PJSM on rigging down Tesco equipment 18:15 20:00 1.75 1,013 1,013 INTRM2 CSGDRI RURD P RD Tesco casing running equipment 20:00 20:15 0.25 1,013 1,013 INTRM2 CSGDRI SFTY P PJSM on rigging up stack tongs& work platform 20:15 22:30 2.25 1,013 1,013 INTRM2 CSGDRI RURD P PU&RU double stack tongs and work platform 22:30 22:45 0.25 1,013 1,013 INTRM2 CSGDRISFTY P PJSM on running inner string BHA 22:45 23:30 0.75 1,013 1,013 INTRM2 CSGDRI OTHR P PU and install kick stand to check efficiency. LD same 23:30 00:00 0.50 1,013 1,013 INTRM2 CSGDRI OTHR P PU BHA smart tools from derrick and RIH inside 7"liner to 90'. 11/29/2012 Plug in&check tool string-RIH w/SLD inner string-RIH w/SLD inner string on 4"DP-Land out reamer drive sub-aquire space out measurements-Ld 1 jt 4"DP-PU 6.61'4"pup-MU liner setting tool&land inner string-MU quick connect-PU Well Commander tool-RIH w/SLD system on 5"DP to 10810', engauce reamer shoe,drill from 10815'to 10875' 00:00 00:30 0.50 1,013 1,013 INTRM2 CSGDRI OTHR P Upload MWD tool. 00:30 01:00 0.50 1,013 1,013 INTRM2 CSGDRI PULD P MU lower BHA tools. 01:00 01:30 0.50 1,013 1,048 INTRM2 CSGDRI TRIP P RIH lower BHA on 28 jts 4"DP inside 7"liner. Page 34 of 75 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 01:30 02:15 0.75 1,048 1,061 INTRM2 CSGDRI OTHR P PU single. Locate out in reamer shoe landing spline. Space out DP with 6.61'pup jt. 02:15 02:45 0.50 1,061 1,061 INTRM2 CSGDRI RURD P MU liner setting tool. RD false rotary table and tongs. 02:45 03:30 0.75 1,061 1,183 INTRM2 CSGDRI TRIP P MU Well Commander.Change roughneck dies. RIH with 1 std 5"DP to 1183'. 03:30 04:00 0.50 1,183 1,183 INTRM2 CSGDRI OTHR P Clean and clear rig floor. 04:00 12:00 8.00 1,183 6,277 INTRM2 CSGDRI TRIP P RIH with SDL system on 5"DP from 1183'to 6277'. Fill pipe every 20 stds. Did not break circulation to prevent motor rotation. PUW=197K, SOW=130K 12:00 20:15 8.25 6,277 10,810 INTRM2 CSGDRI TRIP P RIH with SDL system on 5"DP from 6277'to 10810'. Fill pipe every 20 stds. Did not break circulation to prevent motor rotation. Drifted DP f/derrick f/std#87 w/ 2.5"drift 20:15 20:45 0.50 10,810 10,815 INTRM2 CSGDRI REAM P Obtain parameters,270 gpm,2120 psi,32 rpm, 14K tq. Downlink and engauge reamer drive sub, ream to bottom at 10815' 20:45 00:00 3.25 10,815 10,875 INTRM2 CSGDRI DCSG P Drill 6"x 8.5"hole with SDL assy from 10815'to 10875'MD/6870'TVD ADT=2.2 hrs. WOB 3 to 25K Pumping 300 gpm/2520 psi 32 rpm Torque on/off 15k/14k PUW 290K SOW 165K Rot Wt. 180K ECD 11.45 ppg. 11/30/2012 Drilled 6"x 8 1/2"hole w/Baker SLD system f/10,875'to 11,003'-Steering tool failure-Release from liner - Open circ sub-CBU-Pump OOH to 7971'-Flow check static-POOH on trip tank 10 stds-Pump dry job- POOH on trip tank to 5145' 00:00 09:30 9.50 10,875 11,003 INTRM2 CSGDRI DCSG P Drilled 6"x 8 1/2"hole w/Baker SLD assembly f/10,875'to 11,003'MD/ 6911'TVD ADT=8.1 hrs. WOB 20K Pumping 300 gpm/2600 psi 30 rpm Torque on/off 14.5k/14k PUW 290K SOW 165K Rot Wt. 180K ECD 11.61 ppg. 09:30 10:15 0.75 11,003 11,003 INTRM2 CSGDRI CIRC T Send downlink and disengauge casing drive sub,wait 10 min to retract,confirm retraction with MWD 10.15 10:30 0.25 11,003 10,981 INTRM2 CSGDRI PULD T Stand back 1 stand,blow down top drive, MU single.285K PU wt. 10:30 11:30 1.00 10,981 11,003 INTRM2 CSGDRI TRIP T RIH,tag bottom with 5K WOB with-out pump,wait 60 min to test liner for sticking. 162K dwn wt. 11:30 11:45 0.25 11,003 11,003 INTRM2 CSGDRI TRIP T PU liner confirm free,285K PU wt. 160K dwn wt.Set back on bottom with 25K WOB Page 35 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:45 12:30 0.75 11,003 11,003 INTRM2 CSGDRI CIRC T Drop 1.75"release ball,pump down with 3 bpm,760 psi reducing to 2 bpm, 550 psi. Ball seated at 60 bbls, increase pressure, release and blow ball with 3610 psi. PU and confirm HRD release with 273K PU wt. 7"liner left in hole w/top @ 9928' 12:30 13:00 0.50 11,003 11,003 INTRM2 CSGDRI CIRC T Drop 2.125"ball to Well Commander circ sub, pump down with 2 bpm, 560 psi for 42 bbls, reduce rate to.7 bpm. Ball seated at 48 bbls, pressure up to shear tool open with 3170 psi 13:00 13:45 0.75 11,003 11,003 INTRM2 CSGDRI CIRC T Circulate bottoms up at 750 gpm, 1640 psi. 90%flow out circ sub, 10% flow thru inner string. 13:45 14:00 0.25 11,003 10,981 INTRM2 CSGDRI PULD T LD single 14:00 14:30 0.50 10,981 10,889 INTRM2 CSGDRI TRIP T POOH 1 stand, pumping 400 gpm, 700 psi,20 rpm, 13.5K tq until pilot bit up inside liner shoe,continue POOH slow/pumping 400 gpm to stand out at 10889', no rotary. 14:30 20:30 6.00 10,890 7,971 INTRM2 CSGDRI TRIP T Pump OOH from 10889'to 7971'at 750 gpm, 1050 psi. (No pump while bit pulled through liner top PBR, 9950'to 9900'±)(Liner top at 9929) Observe well static 20:30 21:00 0.50 7,971 7,971 INTRM2 CSGDRI OWFF T Observe well static,blow down top dive. 21:00 22:00 1.00 7,971 7,027 INTRM2 CSGDRI TRIP T POOH on trip tank from 7971'to 7027'with proper hole fill 22:00 22:15 0.25 7,027 7,027 INTRM2 CSGDRI CIRC T Pump dry job,22 bbls, 12.0 ppg, blow down top drive. 22:15 00:00 1.75 7,027 5,145 INTRM2 CSGDRI TRIP T POOH on trip tank from 7027'to 6556'-Flow ck static-Cont.to POOH on TT f/6556'to 5145' 12/01/2012 Cont. POOH on TT to 1189'-Close Well Commander-Recover balls from catcher&LD WC tool-LD Baker Liner setting tool-RU f/4"pipe-LD 4"space out pup and single-Std back 9 stds 4"DP-LD thruster and BCPM-CO steering head/stab-MU bit-plug in and test ok-Rack back-RU and test BOPE-MU inner string drilling assy 00:00 03:15 3.25 5,145 1,185 INTRM2 CSGDRI TRIP T POOH on trip tank from 5145'to 1185'. PUwt=90K,SOwt=90K 03:15 03:45 0.50 1,185 1,185 INTRM2 CSGDRICIRC T Drop ball and close Well Commander with 2300 psi 03:45 04:15 0.50 1,185 1,095 INTRM2 CSGDRI TRIP T POOH, rack last stand 5"DP, LD Well Commander, recover balls 04:15 04:45 0.50 1,095 1,056 INTRM2 CSGDRI TRIP T LD liner setting tool,make breaks per Baker rep 04:45 05:45 1.00 1,056 1,056 INTRM2 CSGDRI RURD T CO iron roughneck dies,elevators and mud bucket rubbers to 4". (Observe well static 1 hr while RU for 4") 05:45 07:00 1.25 1,056 158 INTRM2 CSGDRI TRIP T LD 4"DP space out pup with joint 4" DP to shed, cont POOH and rack 9 stds 4"DP from 1056'to 158' Page 36 of 75 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 07:00 09:00 2.00 158 90 INTRM2 CSGDRI PULD T LD thruster and BCPM 09:00 10:00 1.00 90 90 INTRM2 CSGDRI PULD T Break bit, change out steering head and stab, MU bit 10:00 10:45 0.75 90 0 INTRM2 CSGDRIOTHR T Plug in and test steering head, rack back. 10:45 11:45 1.00 0 0 INTRM2 CSGDRI RURD T Pull wear ring,install test plug per FMC rep 11:45 13:00 1.25 0 0 INTRM2 CSGDRI RURD T RU to test BOPE 13:00 21:15 8.25 0 0 INTRM2 CSGDRI BOPE T Tested BOPE as follows:w/5"test jt.tested Annular to 250&2500 psi- Tested upper 4-1/2"x 7"pipe rams, TD IBOP's,5"and 4"Floor safety& dart valves, Choke&kill line valves, Choke manifold valves# 1,2,3,4,5,6,7,8,9,10,11,12,13,14,15, &16 and needle valve to 250&3500 psi-HCR choke and Kill-4"Demco on kill line-manual kill&choke valves-Lower 2-7/8"x 5"pipe rams to 250&3500 psi-Performed accumulator recovery test,3000 psi start, 1300 psi end,30 sec to 200 psi,210 sec to 3000 psi, Isolate bottles/function all rams-94 sec air pump recovery,82 sec electric pump recovery -Tested Blind rams 250/3500 psi-Tested gas alarms- Tested rig evacuation alarm-With the 2-7/8",4"and 7"test joint tested annular, 250 PSI low/2500 PSI high, upper and lower variable pipe rams 250 PSI low/3500 PSI high. Annulus open and monitored during test.All tests charted,5 min/test. John Crisp(AOGCC)waived witnessing tests. 21:15 21:30 0.25 0 0 INTRM2 CSGDRI RURD T Pull test plug,drain stack,blow down choke and kill lines 21:30 21:45 0.25 0 0 INTRM2 CSGDRI RURD T Set 12.25"ID wear ring as per FMC rep 21:45 22:45 1.00 0 0 INTRM2 CSGDRI PULD T PJSM,MU SDL inner string BHA as per Baker reps 22:45 23:15 0.50 0 133 INTRM2 CSGDRI OTHR T Plug in&check tools 23:15 00:00 0.75 133 1,049 INTRM2 CSGDRI PULD T PU&RIH w/ thruster,float sub, fliter sub,XO,28 jts 4"DP&liner setting tool 12/02/2012 RIH w/inner string from 1049'to 1082'-Torque liner setting tool subs-Shallow test MWD-MU Well Commander-RIH-Latch into liner top-Gradualy establish sufficient pump rate for MWD(Packing off)to determine casing drive position 00:00 00:45 0.75 1,049 1,082 INTRM2 CSGDRI TRIP T RIH from 1049'to 1082'. Picking up liner setting tool.Torqueing subs on same. 00:45 01:15 0.50 1,082 1,082 INTRM2 CSGDRI TRIP T MU TD-Test tools @ 300 gpm @ 1580 psi Page 37 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 01:30 0.25 1,082 1,095 INTRM2 CSGDRI PULD T Blow down TD-MU well commander(circ tool)f/1082'to 1095'-PU&SO wt 90 k 01:30 12.00 10.50 1,095 9,572 INTRM2 CSGDRI TRIP T RIH f/1095'to 9572'w/SLD inner BHA-Checking Super sliders& filling pipe every 20 stds 12:00 16:45 4.75 9,572 10,959 INTRM2 CSGDRI TRIP T Cont. RIH f/9572'to 10.959'w/SLD inner BHA-Checking super sliders &filling hole every 20 stds. 16:45 17:00 0.25 10,959 10,981 INTRM2 CSGDRI TRIP T String took wt @ 10,959'-Pump @ 1 bbl/min @ 570 psi&wash down f/ 10959'to 10,981'-PU wt 260 SO wt 155 Rot wt 17:00 18:00 1.00 10,981 11,003 INTRM2 CSGDRI TRIP T PU single of 5"DP f/shed-RIH f/ 10981'to 11,003'-SO wt 140 - Slowly rotate string&engage 7"liner w/liner setting tool-PU to 280 k to verify 7"liner is engaged 18:00 00:00 6.00 11,003 11,003 INTRM2 CSGDRICIRC T Gradualy establish sufficient pump rate(Packing off)to obtain MWD detection.Worked rate up to 210 gpm, 1550 psi while rotate at 10 rpm, 14K tq.Just starting to get MWD detection. PU wt=282K,SO wt= 165K 12/03/2012 Circ&work pipe attempting to get confirmation f/Hall sensor to engage reamer drive sub-Pulled pilot assembly up into 8 1/2"hole-increased pump rate to 340 gpm SLD position still @ 0-made several more attempts to down link to engage reamer shoe-POOH w/pump to 10,700'-Flow ck(slight drop)Cont POOH w/pump to 5993'-Flow ck(slight drop)POOH on TT to 5521'-Flow ck(slight drop)Pump dry&cont. POOH on TT to 2882' 00:00 04:00 4.00 11,003 11,003 INTRM2 CSGDRI CIRC T Gradually stage pumps up while working numerous pack-offs to 306 gpm-2400 psi-30 rpm-14k torque. Hall sensor still reading 0 position. 04:00 07:30 3.50 11,003 11,003 INTRM2 CSGDRI CIRC T Circulate and rotate pipe at 340 gpm -2400 psi-30 rpm-14k torque. Slow pump to 1 bpm. Pull bit out of pilot hole to 10,950'. Increase flow rate to 340 gpm to get maximum BHA movement in the 8 1/2"hole. No change in hall sensor location. 07:30 08:30 1.00 11,003 11,003 INTRM2 CSGDRI CIRC T Pump 20 bbls hi-vis gel pill at 300 gpm-2060 psi in an attempt to increase pump open force on thruster assembly. Had 100 psi increase when pill crossed tools. 08:30 09:00 0.50 11,003 11,003 INTRM2 CSGDRI CIRC T Downlink to tools and engage pads on steering head with bit on bottom. Pull bit out of 6"hole slowly in an attempt create drag and extend the thruster sub. No change in hall sensor. 09.00 09'30 0.50 11,003 11,003 INTRM2 CSGDRICIRC T Pump 23 bbls 12.0 ppg hi-vis sweep at 340 gpm-2350 psi. Had 400 psi pressure increase when pill crossed the tools. Page 38 of 75 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 09:30 10:45 1.25 11,003 11,003 INTRM2 CSGDRI CIRC T PU on pipe.Slack off and stop pipe quickly several times.. No change in hall sensor.Stack 50k on assembly with no pump. PU on pipe.Circulate at 340 gpm. No change in hall sensor. 10:45 12:00 1.25 11,003 10,700 INTRM2 CSGDRI TRIP T Flow check well.Static. POH with pump and rotary from 11,003'to 10,700'at 30 gpm-1960 psi-30 rpm-14k torque. 12:00 12:30 0.50 10,700 10,700 INTRM2 CSGDRI OWFF T Flow check well-stight drop-Clean shaker screens while monitoring well 12:30 20:45 8.25 10,700 5,993 INTRM2 CSGDRI TRIP T POOH w/pump @ 300 gpm @ 1890 psi f/10,700'to 5993' 20:45 21:00 0.25 5,993 5,993 INTRM2 CSGDRIOWFF T Blow down TD-Flow ck well-(slight drop) 21:00 21:45 0.75 5,993 5,521 INTRM2 CSGDRI TRIP T POOH on TT f/5993'to 5521' 21:45 22:00 0.25 5,521 5,521 INTRM2 CSGDRIOWFF T Flow ck(slight drop)Pumped 23 bbls 12.1 ppg mud for dry job-Blow down TD 22:00 00:00 2.00 5,521 2,882 INTRM2 CSGDRI TRIP T Cont. POOH on TT f/5521'to 2882'- PU wt. 145 SO wt 125 12/04/2012 Cont. POOH f/2882'to to 1095'-Observe well slight ooze-RIH 1 std-Circ to even MW-Observe well,slight drop-LD WC tool-Check space out f/reamer drive sub(OK)Circ&check Hall sensor(OK)RU&LD inner string-RU&LD 7"liner-LD inner BHA f/derrick-PU&break down inner string tools f/pipe shed- 00:00 01:45 1.75 2,882 1,095 INTRM2 CSGDRI TRIP T Cont.POOH on TT f/2882'to 1095'- PUwt115k 01:45 02:45 1.00 1,095 1,095 INTRM2 CSGDRI OWFF T Flow ck(slight flow)-Held PJSM on rigging up to pull HD running tool Mud appears to be aired up 02:45 03:15 0.50 1,095 1,185 INTRM2 CSGDRI CIRC T RIH w/1 std 5'DP to 1185'-Circ btms. up @ 3.5 bbls/min @ 530 psi No indication of any gas @ btms up 03:15 03:30 0.25 1,185 1,185 INTRM2 CSGDRI OWFF T Flow ck(slight drop) 03:30 04:00 0.50 1,185 1,082 INTRM2 CSGDRI TRIP T Pull out&std back 1 std 5"DP-- Flush&LD Well Commander tool f/ 1185'to 1082' 04:00 05:15 1.25 1,082 1,082 INTRM2 CSGDRI OTHR T Break quick connect&pull up w/HD running tool to space out pup below tool-PU&MU 12'pup jt-confirm space out of reamer drive sub(OK)- PU&LD 12'pup jt 05:15 05:45 0.50 1,082 1,082 INTRM2 CSGDRIOTHR T Lower HD running tool back down& MU to Quick connect-Pump @ 285 gpm @ 1420 psi to check for SDL position-Hall sensor showed 3 on SDL position confirming drive sub in position 05:45 06:15 0.50 1,082 1,056 INTRM2 CSGDRI PULD T Disconnect f/HD quick connect- Blow down TD-Pull up&LD HD running tool 06:15 06:30 0.25 1,056 1,056 INTRM2 CSGDRI PULD T Change elevators to 3 1/2"-PU work platform&well control assembly for pulling inner string Page 39 of 75 Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 06:30 06:45 0.25 1,056 1,056 INTRM2 CSGDRIISFTY T Held PJSM on RU to pull inner string 06:45 09:15 2.50 1,056 1,056 ,INTRM2 CSGDRI RURD T LD space out pup-RU work platform &stack tongs-Change mud bucket rubbers 09:15 13:45 4.50 1,056 0 INTRM2 CSGDRI TRIP T Pull inner BHA out of 7"liner-LD 1 jt 4"DP-Std back 9 stds 4"DP-LD thruster assembly&BCPM/Smart battery(upper BHA section)Pull& Std back X-Treme/Mod stab-reamer drive sub,Mod Stab,CoPilot, On Trak,Mod Stab,GT Steering head (Lower BHA section)-break off bit • 13:45 14:45 1.00 0 0 INTRM2 CSGDRI RURD T RD equipment f/LD inner string- Change elevators-Clean up rig floor -RU to pull 7"liner 14:45 18:45 4.00 0 0 INTRM2 CSGDRI PUTB T MU quick connection running tool- Pull&LD quick connect assembly- Pull&LD 24 jts 7"26#L-80 Tenaris Blue Hydril-LD reamer shoe assembly-All connections broke clean&threads all good condition 18:45 19:45 1.00 0 0 INTRM2 CSGDRIOTHR T Change elevators-clean up rig floor 19:45 22:00 2.25 0 0 INTRM2 CSGDRI PULD T PJSM-PU lower section of inner string f/derrick-Attempt to drain motor(frozen)apply steam to thraw- drain motor 22:00 22:30 0.50 0 0 INTRM2 CSGDRI OTHR T Plug in&down MWD data 22:30 00:00 1.50 0 0INTRM2 CSGDRI PULD T Break&LD BHA(lower section of inner string) 12/05/2012 Finish LD BHA tools-Test lower rams and annular with 3.5"test joint-PU 953'of 3.5"cement stinger-RIH on 5"DP to 10,747'-Slip and cut drilling line-Change out disc brake pads-RIH-wash to and tag btm- Stage pump rate to 7 bpm OK-LD single-POOH 3 stds into 9-5/8"shoe-Circ and cond mud to even MW- RIH 3 stds-PU pup-RU to cement-Pump and balance 47.5 bbls 17 ppg cement-POOH to 194'into 9-5/8" casing-Circ out excess cement-Observed no cement returns @ btms up 00:00 00:30 0.50 0 0 INTRM2 CSGDRI PULD T Break out and Layd Thruster,filter sub, Float sub and XO sub-Flow check well,static 00:30 01:00 0.50 0 0 INTRM2 WHDBO BOPE T Drain BOP stack-pull wear ring and install test plug 01:00 01:30 0.50 0 0 INTRM2 WHDBO BOPE T RU to test BOPE-fill stack with water 01:30 02:00 0.50 0 0 INTRM2 WHDBO BOPE T With 3 1/2"test joint-test Annular preventor to 250/2500 psi -lower pipe rams(2 7/8"x 5"VBR's) 250/3500 psi-each test held solid for five minutes 02:00 02:30 0.50 0 0 INTRM2 WHDBO BOPE T Pull test plug-drain stack-Install wear ring(12.25"ID) 02:30 03:30 1.00 0 0 INTRM2 PLUG RURD T Rig up to run 3 1/2"tubing 03:30 03:45 0.25 0 0 INTRM2 PLUG SFTY T Prejob safety meeting on running 3 1/2"Tubing 03:45 05:45 2.00 0 948 INTRM2 PLUG PULD T MU 3 1/2"mule shoe-pick up 30 joints of 3 1/2"tubing and RIH to 948' Page 40 of 75 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 05:45 06:45 1.00 948 948 INTRM2 PLUG OTHR T RD&LD tubing tongs-MU xo's to 4 1/2"IF-change dies in iron roughneck-change elevators to 5". 06:45 12:00 5.25 948 8,488 INTRM2 PLUG TRIP T RIH with 5"drill pipe from 948'to 8488'-monitor displacement volumes on pit#6. 12:00 13:45 1.75 8,488 10,747 INTRM2 PLUG TRIP T RIH with 5"drill pipe from 8488'to 10,747'-monitor displacement volumes on pit#6. 13:45 14:00 0.25 10,747 10,747 INTRM2 RIGMNT SFTY P Pre-job Safety meeting on procedures involved with slipping and cutting drilling line-Reviewed OLS& PREP Alaska checklist with crew. 14:00 15:30 1.50 10,747 10,747 INTRM2 RIGMNT SLPC P Slip and cut drilling line-Service Top Drive and Drawworks 15:30 16:30 1.00 10,747 10,747 INTRM2 RIGMNT RGRP T Replace pads on Drawworks Disc Brake 16:30 16:45 0.25 10,747 10,840 INTRM2 PLUG TRIP T RIH w/5"DP from 10747'to 10840'. PU wt=260K,SO wt=160K @ 10747' 16:45 17:45 1.00 10,840 11,015 INTRM2 PLUG TRIP T Precautionary wash down from 10840'at 4 bpm,390 psi.Tag bottom at 11015' 17:45 18:30 0.75 11,015 10,715 INTRM2 PLUG TRIP T Stage up pump rate to 7 bpm,620 psi with-out problem(LD single) Pump OOH to 10715'(into 9-5/8" casing) 18:30 19:45 1.25 10,715 10,715 INTRM2 PLUG CIRC T Circulate and condition mud to even MW for cement.Attempt 750 gpm, losing mud over shakers. Reduce rate to 300 gpm,600 psi. Seen some 11.1 ppg MW out. 19:45 20:00 0.25 10,715 10,715 INTRM2 PLUG RURD T Blow down TD, Remove bell guide (Observe well static) 20:00 20.15 0.25 10,715 11,006 INTRM2 PLUG TRIP T RIH from 10715'to 11006', PU 8'pup jt 20:15 20:30 0.25 11,006 11,006 INTRM2 PLUG RURD T RU cement line, head pin 20:30 21:00 0.50 11,006 11,006 INTRM2 PLUG CIRC T Circ thru cement line while mix mud push. 7 bpm,650 psi 21:00 22:00 1.00 11,006 11,006 INTRM2 PLUG CMNT T Dowell flood lines with 13 ppg Mud Push-Test lines to 2500 psi-Pump 25.7 bbls total 13.0 ppg Mud Push into pipe at 7 bpm-insert nerf seperator ball into DP-flush spacer from surface lines with cement- Dowell pump 47.5 bbls(267 sx)(1.0 yield)17.0 ppg cement at 4.5 bpm followed by 4.3 bbls 13.0 ppg Mud Push spacer into pipe-Rig displace and balance with 163.8 bbls 10.5 ppg mud at 7 bpm(ICP= 150 psi, FCP= 820 psi)-full returns-CIP at 2200 Hrs- 22:00 22:15 0.25 11,006 10,998 INTRM2 PLUG RURD T RD cement line, LD pup jt, PU single 22:15 22:45 0.50 10,998 10,559 INTRM2 PLUG TRIP T POOH from 10998'to 10559' Page 41 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 00:00 1.25 10,559 10,559 INTRM2 PLUG CIRC T Insert Nerfwiper ball,stage pump rate to 620 gpm, 1600 psi-circ btms up-Observed no cmt @ btms up 12/06/2012 Circ-Observe well static-POOH on trip tank-LD 3.5"cmt stinger-MU Baker 8.5"kick-off assy-RIH 486'- Shallow test tools-RIH to 9903' 00:00 00:15 0.25 10,559 10,559 INTRM2 PLUG CIRC T Circ and condition mud to even mud wt at 10.5 ppg 00:15 00:45 0.50 10,559 10,559 INTRM2 PLUG OWFF T Observe well static-SIMOPS Blow down top drive, install top drive bell guide 00:45 01:15 0.50 10,559 10,086 INTRM2 PLUG TRIP T POOH on trip tank from 10559'to 10086'. PU wt=237K,SO wt= 155K.Observe well static. 01:15 01:30 0.25 10,086 10,086 INTRM2 PLUG CIRC T Pump 20 bbls, 12.2 ppg dry job 01:30 08:00 6.50 10,086 953 INTRM2 PLUG TRIP T POOH on trip tank from 10086'to 953' 08:00 08:30 0.50 953 953 INTRM2 PLUG OWFF T Observe well to static for 5 min 08:30 09.15 0.75 953 953 INTRM2 PLUG RURD T PJSM,MU safety valve and XO's. RU to LD 3.5"tubing 09:15 11:00 1.75 953 0 INTRM2 PLUG PULD T LD 3 5"cement stinger(30 its and mule shoe)Calc fill=83.3,Act fill= 103.5 bbls 11:00 12:00 1.00 0 0 INTRM2 PLUG RURD T CO elevators, RD power tongs,Clr floor, RD safety valve and XO's, wash out drip pan 12:00 12:45 0.75 0 0 INTRM2 DRILL PULD T PU Baker drilling tools to floor 12:45 14:30 1.75 0 79 INTRM2 DRILL PULD T MU 8.5"Baker kick-off assy 14:30 15:15 0.75 79 79 INTRM2 DRILL OTHR T Upload MWD 15:15 16:30 1.25 79 486 INTRM2 DRILL PULD T Continue MU Baker 8.5"BHA 16:30 16:45 0.25 486 486 INTRM2 DRILL CIRC T Shallow test MWD at 450 gpm,820 psi. 16:45 00.00 7.25 486 9,903 INTRM2 DRILL TRIP T RIH f/486'to 9903'-filling pipe every 20 stds 12/07/2012 RIH w/kick off assembly to 10,467'-Wash down to top of Cmt @ 10,563'-Drill cmt to 10,783'-Kick-off sliding to 10,820'-CBU-Displace out cmt contaminated mud with new mud-flow check static-Cont circ to clean hole-Drop 2.7"rabbit-flow check static-POOH on trip tank to 2556'-Pull thru 9 5/8'liner top w/ pump-Pump sweep&Circ-Cont. POOH-LD clean out/kick-off BHA 00:00 00:30 0.50 9,903 10,467 INTRM2 DRILL TRIP T RIH w/kick-off assembly f/9903'to 10,467' -PUI wt 263 SO wt 163 00:30 01:00 0.50 10,467 10,563 INTRM2 DRILL WASH T Wash down f/10,467'to 10,563' (tagged top of cmt plug)@ 500 gpm @ 2010-1900 psi 01:00 03:45 2.75 10,563 10,783 INTRM2 CEMEN"DRLG T Drill out firm/hard cmt f/10,563'to 10,783'-w/500 gpm/1880 psi-30 rpm @ 16 K ft/lbs tq.-15K WOB- 253K PUW 144K SOW 03:45 05:45 2.00 10,783 10,820 INTRM2 DRILL DDRL T Drill 8 1/2"hole from 10,783'to 10,820'MD/6,850'TVD-slide 75-90 degrees LHS to sidetrack well-500 gpm/1950-2080 psi-1.4 Hrs ADT- 15-25K WOB- Page42of75 Time Logs ,Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 06:30 0.75 10,820 10,820 INTRM2 DRILL CIRC T Circ btms up @ 600 gpm @ 2290 psi w/90 rpm's w/16 k torque 06:30 08:45 2.25 10,820 10,820 INTRM2 DRILL CIRC T Made xxx bbls whole mud swap @ various pump rates-600 to 350 gpm @ 2290 to 1100 psi w/90 rpm's w/ 14 k torque 08:45 09:15 0.50 10,820 10,820 INTRM2 DRILL OWFF T Flow ck(slight drop)-clean shaker screens hwile flow checking 09:15 10:45 1.50 10,820 10,820 INTRM2 DRILL CIRC T Circ&cond. mud-stage pumps to 625 gpm @ 2560 psi w/90 rpm's w/ 13.5 k torque -PU wt 280 SO wt. 165 10:45 11:15 0.50 10,820 10,749 INTRM2 DRILL OTHR T Std back 1 std DP to 10,749'- dropped 2.7"OD rabbit on Std#109- Blow down TD&flow ck(slight drop) 11:15 12:00 0.75 10,749 9,808 INTRM2 DRILL TRIP T POOH on TT f/10,749'to 9808' 12:00 12:15 0.25 9,808 9,808 INTRM2 DRILL OWFF T Flow ck(slight drop) 12:15 12:45 0.50 9,808 9,808 INTRM2 DRILL CIRC T Pumped 26 bbls( 12.3 ppg)mud for dry job-Blow down TD 12:45 17:30 4.75 9,808 2,556 INTRM2 DRILL TRIP T POOH on TT f/9808'to 2556' 17:30 17:45 0.25 2,556 2,461 INTRM2 DRILL TRIP T Pump out f/2556'w/no rotation f/ 2556'to 2461'(through 9 5/8"liner top)@ 650 gpm @ 1780 psi 17:45 18:45 1.00 2,461 2,461 INTRM2 DRILL CIRC T Pumped weighted sweep @ 650 gpm @ 1710 psi w/90 rpm's w/6 k torque (observed sweep come back w/very little increase in drill cuttings,mostly nut plug)-Pumped 15 bbls(12.3 ppg)dry job-Blow down TD 18:45 20:00 1.25 2,461 486 INTRM2 DRILL TRIP T Cont. POOH on TT f/2461'to 486' 20:00 20:15 0.25 486 486 INTRM2 DRILL OWFF T Flow check static 20:15 20:45 0.50 486 179 INTRM2 DRILL TRIP T POOH on TT f/486'to 179', Laying down HWDP and jars 20:45 21:15 0.50 179 83 INTRM2 DRILL PULD T PJSM-LD Baker 8.5"Mtr assy as per DD.Total calc hole fill=94.3, Total actual hole fill= 111 bbls 21:15 21:45 0.50 83 83 INTRM2 DRILL OTHR T Download MWD 21:45 22:45 1.00 83 0 INTRM2 DRILL PULD T Continue LD BHA as per DD 22:45 23:30 0.75 0 0 INTRM2 DRILL OTHR T Clean&clear floor of BHA#6 components 23:30 00:00 0.50 0 0 INTRM2 DRILL SFTY T PJSM on picking up BHA#7 SDL inner string 12/08/2012 MU BHA and std back-Test BOPE-Cont MU Baker inner string and test-RU Tesco CDS-PJSM to Run 7"Liner 00:00 01:30 1.50 0 55 INTRM2 CSGDRI PULD T MU SDL lower section of inner string -bit-GT steering head-Mod Stab- On Trak-CoPilot-Mod Stab- Reamer drive sub-to 55' 01:30 02:30 1.00 55 55 INTRM2 CSGDRI OTHR T Plug in&up load MWD tools Page 43 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:45 1.25 55 133 INTRM2 CSGDRI PULD T Cont. MU lower section of inner string-X-Treme/Mod stab-BCPM- Smart battery to 133'-While attempting to remove the dump port hatch on Smart Battery one of the bolts head broke off. 03:45 04:15 0.50 133 0 INTRM2 CSGDRI PULD T LD Smart battery and BCPM-stand back remainer of BHA in the derrick 04:15 05:00 0.75 0 0 INTRM2 CSGDRI PULD T MU Thruster, Float sub&filter sub- LD complete to pipe shed. 05:00 05.30 0.50 0 0 INTRM2 WHDBO OTHR T PJSM-Pull FMC wear ring and drain stack 05:30 05:45 0.25 0 0 INTRM2 WHDBO SFTY T PJSM. Rig up and test BOPE. Discuss hazards and mitigations associated with tasks 05:45 06:30 0.75 0 0 INTRM2 WHDBO RURD T Set upper test plug w/5"test joint- fill stack and lines with water-work air out of lines 06:30 16:45 10.25 0 0 INTRM2 WHDBO BOPE T Tested BOPE as follows:w/5"test jt.tested Annular to 250&2500 psi- Tested upper 4-1/2"x 7"pipe rams, TD IBOP's,5"and 4"Floor safety& dart valves,Choke&kill line valves, Choke manifold valves# 1,2,3,4,5,6,7,8,9,10,11,12,13,14,15, &16 and needle valve to 250&3500 psi-HCR choke and Kill-4"Demco on kill line-manual kill&choke valves-Lower 2-7/8"x 5"pipe rams to 250&3500 psi-Performed accumulator recovery test,3000 psi start, 1300 psi end,34 sec to 200 psi, 192 sec to 3000 psi-Tested Blind rams 250/3500 psi-Tested gas alarms -With the 2-7/8",4"and 7"test joint tested annular, 250 PSI low/2500 PSI high, upper and lower variable pipe rams 250 PSI low/3500 PSI high.Annulus open and monitored during test.All tests charted, 5 min/test. Chuck Scheve (AOGCC)waived witnessing tests. 16:45 17:00 0.25 0 0 INTRM2 WHDBO RURD T RD test equip and pull test plug 17:00 17:15 0.25 0 0 INTRM2 WHDBO OTHR T Set 12.5"ID wear ring per FMC 17.15 17:30 0.25 0 0 INTRM2 WHDBO OTHR T Blow down choke and kill lines 17:30 18:00 0.50 0 0 INTRM2 CSGDRI PULD T PU tools&safety valves to rig floor 18:00 19:00 1.00 0 130 INTRM2 CSGDRIOTHR T PJSM,MU BCPM and battery w/ lower BHA assy 19:00 20:15 1.25 130 130 INTRM2 CSGDRIOTHR T Plug In&check MWD tool string- Shallow test tools at 300 gpm, 1320-1420 psi 20:15 20:30 0.25 130 130 INTRM2 CSGDRIOTHR T Blow down top drive and mud line 20:30 21:00 0.50 130 0 INTRM2 CSGDRI OTHR T LD Battery assembly,drain motor, stand back lower BHA assembly Page 44 of 75 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 21:00 22:00 1.00 0 0 INTRM2 CSGDRI RURD T PU long kick stand, change out 4"lift sub to 5"pup jt and MU lower quick connect 22:00 23:45 1.75 0 0 INTRM2 CSGDRI RURD T PJSM, RU Tesco CDS 23:45 00:00 0.25 0 0 INTRM2 CSGDRI SFTY T PJSM on MU 7"Liner 12/09/2012 Ran 7"26#L-80 Tenaris Blue liner-Ran inner string-Space out-MU liner setting tool and Well Commander -RIH with SDL system on 5"DP to 10,524'-Slip and cut drilling line 00:00 03:30 3.50 0 1,011 INTRM2 CSGDRI RUNL T Ran 7"26#L-80 Tenaris Hydril liner as follows: Baker reamer shoe w/ pup jt.- 1 pup jt-24 jts liner-Baker Quick connect-Hyrdo-Form centralizers in the middle of jts 1 thru 13&jts. 16,19,&22 thru 24 w/ crimped on stop rings-total liner length 1012.37'-Break out modified Quick connect running tool 03:30 04:15 0.75 1,011 1,011 INTRM2 CSGDRI RURD T PJSM-Rig down Tesco CDS tools- Install bails and DP elevators 04:15 04:30 0.25 1,011 1,011 INTRM2 CSGDRI RNCS T PU Lower Quick connect assembly with Long Kick stand(primary running tool not back from Deadhorse due to mechanical problems with DC 6) 04:30 05:30 1.00 1,011 1,011 INTRM2 CSGDRI RURD T Move Double Stack tongs onto rig floor-RU tongs 05:30 05:45 0.25 1,011 1,024 INTRM2 CSGDRI RNCS T MU lower Quick connect assembly- set string low in rotary table and install dog collar 05:45 06:15 0.50 1,024 1,024 INTRM2 CSGDRI PULD T Disconnect Long kickstand from liner -Break out 5"lift sub and install and MU 4"lift sub into long kickstand for well control readiness 06:15 06:45 0.50 1,024 1,024 INTRM2 CSGDRI RURD T Rig up work platform and false table- change elevators to 3 1/2" 06:45 07:00 0.25 1,024 1,024 INTRM2 CSGDRI SFTY T PJSM-discuss exposures and mitigations for running inner string BHA-good communication needed throughout 07:00 08:45 1.75 1,024 1,024 INTRM2 CSGDRI PULD T PU BHA smart tools from derrick and RIH inside 7"liner-PU BCPM& Smart battery from shed-plug in and confirm all Corns working-PU Thruster,float sub and filter sub(157' total)-change elevators to 4" 08:45 10:15 1.50 1,024 1,024 INTRM2 CSGDRI TRIP T Run 28 joints of 4"drill pipe inside 7" liner 10:15 11:30 1.25 1,024 1,024 INTRM2 CSGDRI OTHR T PU single-locate out in ream shoe landing spline-mark pipe-measure out to confirm space out needed-LD single-PU 2 pup joints(6.61'& 12.61')for Thruster space out.- change elevators to 5"-PU Liner setting tool&MU inner string connection 11:30 11:45 0.25 1,024 1,024 INTRM2 CSGDRI RURD T RD work platform and false table Page 45 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:45 12:00 0.25 1,024 1,092 INTRM2 CSGDRI PULD T Land inner string-MU Liner running Quick connect assemblies-Thruster opening=2.32'-Lower assembly to table-set slips on 5"top sub 12:00 12:15 0.25 1,092 1,092 INTRM2 CSGDRI OTHR T Move Double Stack tongs off of rig floor-organize tools on rig floor 12:15 12:30 0.25 1,092 1,105 INTRM2 CSGDRI PULD T PU&MU Well Commander tool 12:30 23:00 10.50 1,105 10,525 INTRM2 CSGDRI TRIP T RIH with SDL system per'Trip In" running speed schedule from 1105'to 10525'-275K up, 170K dwn. Fill pipe every 20 stands-did not break circulation to prevent motor rotation 23.00 00:00 1.00 10,525 10,525 INTRM2 CSGDRISLPC T Slip and cut 68'drilling line 12/10/2012 Service rig-RIH 10,525'to 10,815'-Stage pump up to 300 gpm-confirm RDS position-engage reamer shoe - drill 10'of 6"hole-initiate AutoTrak-Drill 6"hole to 10,868'-Drill 6"x 8.5"hole to 11,200'. 00:00 00:30 0.50 10,525 10,525 INTRM2 CSGDRI SVRG P Service rig,calibrate block height 00:30 01:45 1.25 10,525 10,815 INTRM2 CSGDRI TRIP T RIH from 10525'to 10815'at 400'/hr. No excess drag observed.275K up, 170K dwn. 01:45 03:00 1.25 10,815 10,815 INTRM2 CSGDRI CIRC T Stage pump rate up to 275 gpm, 1880 psi. MWD verify RDS position good,send downlink to engage RDS, bad MWD detection,switch pump, still bad detection, increase rate to 300 gpm,2060 psi,send downlink again ok. 03:00 03:15 0.25 10,815 10,820 INTRM2 CSGDRIOTHR T Pump off 13 minutes to engage RDS to reamer shoe 03:15 03:30 0.25 10,820 10,830 INTRM2 CSGDRI DCSG T Ream 5'to bottom,drill 10'of 6"hole at 30 rpm, 14.5K tq, 195K Rot wt, 300 gpm,2100 psi,5K wob-Down link to engage steering head 03:30 12:00 8.50 10,830 10,995 INTRM2 CSGDRI DCSG T Drilled 6"x 8 1/2"hole w/Baker SLD assembly f/10,830'to 10,995'MD/ 6904'TVD ADT=7.2 hrs. WOB 8-16K Pumping 300 gpm/2200 psi 30 rpm Torque on/off 15.5k/15k PUW 225K Rot SOW Wt.200K ECD 11.41 ppg. 12:00 00:00 12.00 10,995 11,200 INTRM2 CSGDRI DCSG P Drilled 6"x 8 1/2"hole w/Baker SLD assembly f/10,995'to 11,200'MD/ 6947'ND ADT= 10.4 hrs. WOB 15-20K Pumping 300 gpm/2120 psi 30 rpm Torque on/off 15.5k/14k PUW 230K(w/pump and rot) Rot SOW Wt. 180K ECD 11.38 ppg. 12/11/2012 Drilled 6"x 8 1/2"hole w/Baker SLD assembly f/11,200'to 11,458'MD/6986'ND.Total Depth.7"shoe placed @ 11409.93'MD. ADT=22 hrs.WOB 12-18K Pumping 300 gpm/2330 psi 30 rpm Torque on/off 15.5k/14.5k PUW 230K(w/pump and rot) Rot SOW Wt. 185K ECD 11.29 ppg. P/U Wt=265K,S/O Wt= 165k. Page 46 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 11,200 11,278 INTRM2 CSGDRI DCSG P Drilled 6"x 8 1/2"hole w/Baker SLD assembly f/11,200'to 11,278'MD/ 6965'TVD ADT=10.3 hrs.WOB 3-18K Pumping 300 gpm/2130 psi 30 rpm Torque on/off 15.5k/14.5k PUW 230K(w/pump and rot) Rot SOW Wt. 185K ECD 11.29 ppg. 12:00 00:00 12.00 11,278 11,458 INTRM2 CSGDRI DCSG P Drilled 6"x 8 1/2"hole w/Baker SLD assembly f/11,278'to 11,458'MD/ 6986'ND ADT= 11.8 hrs.WOB 12-18K Pumping 300 gpm/2320 psi 30 rpm Torque on/off 15.5k/14.5k PUW 230K(w/pump and rot) Rot SOW Wt. 185K ECD 11.37 ppg. 12/12/2012 Circulate 3 x's annular volume of liner lap. Release HRD tool,with 20k down weight on liner.Open MI Swaco circ sub. BROOH to 7984'MD. Pump out to 6852'MD. POOH on trip tank to 3648'MD. BROOH to 2801'MD. Circulation rate 900 GPM, 80 RPM.Wellbore static. POOH on elevators. 00:00 00:15 0.25 11,458 11,458 INTRM2 CSGDRI DCSG P Circulate liner annular volume 3x's @ 315 GPM,2240 PSI,35 RPM. 00:15 01:30 1.25 11,458 11,458 INTRM2 CSGDRI CIRC P Down link. Retrack Auto track pads, and deactivate reamer drive sub. Shut down 10 mins. B/D top drive. Pump 265 GPM to confirm all tools retracked. Good. 01:30 02:15 0.75 11,458 11,458 INTRM2 CSGDRICIRC P PJSM Set 20k extra down on liner. Drop 1.75"bronze liner setting ball. Pump @ 3 BPM,670 PSI,slow down to 2 BPM,430 PSI after 40 barrels. Ball landed @ 64 barrels. String volume=177 BBLS.Shear ball seat @ 3570 PSI.286k up weight before setting.275k up weight after releasing. 02:15 02:45 0.50 11,458 11,458 INTRM2 CSGDRICIRC P PJSM. Drop MI Swaco Well Commander 2.125"opening ball. Pump @ 2 BPM,430 PSI. Ball on seat @ 50 BBLS. Open @ 2570 PSI. 02:45 03:15 0.50 11,458 11,458 INTRM2 CSGDRI REAM P Slow back ream out of the hole from 11458'MD to 11371'MD.400 GPM, 700 PSI,20 RPM,275k Up Wt, 165k Dn Wt. 185 Rot Wt. 03:15 03:30 0.25 11,458 11,371 INTRM2 CSGDRI OWFF P Blow down top drive.Observe well for flow.Static. 03:30 04:00 0.50 11,371 11,371 INTRM2 CSGDRI CIRC P Obtain slow pump rates. Prepare to begin pumping out of the hole. 04:00 09:30 5.50 11,371 9,678 INTRM2 CSGDRI CIRC P Pump out of the hole.750 GPM, 1790 PSI,248k Up Wt. From 11371' MD to 9678'MD. POOH from 10403 to 10340 with no pump. 09:30 12:00 2.50 9,678 8,737 INTRM2 CSGDRI REAM P Back ream out of the hole fr 9678' MD to 8737'MD.900 GPM, 1860 PSI,60 RPM, 11 k TQ. Minimal cuttings seen on shakers. 12:00 14:00 2.00 8,737 7,984 INTRM2 CSGDRI REAM P Continue to back ream out of the hole.8737'MD to 7984'MD. 900 GPM, 1490 PSI,60 RPM,9k TQ. Page 47 of 75 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 14:00 15:00 1.00 7,984 7,984 INTRM2 CSGDRICIRC P Circulate bottoms up. Pump nut plug sweep.Minimal returns seen at shakers.900 GPM, 1500 PSI, 100 RPM, 9.5k TQ. 15:00 16:00 1.00 7,984 7,984 INTRM2 CSGDRI OWFF P Observe wellbore.Slight flow diminished to static over 45 mins. 16:00 18:15 2.25 7,984 6,852 INTRM2 CSGDRI CIRC P Pump out of the hole. From 7984' MD to 6852'MD. 3 BPM, 130 PSI. Good hole fill. 18:15 18:30 0.25 6,852 6,852 INTRM2 CSGDRI TRIP P Blow down top drive. Observe well bore.Static. 18:30 21:15 2.75 6,852 3,648 INTRM2 CSGDRI TRIP P Trip out of the hole on the trip tank. 6852'MD to 3648'MD. 21:15 23:45 2.50 3,648 2,801 INTRM2 CSGDRI REAM P Begin back reaming with commander sub circulating across the liner top of the 9.625 x 11.75. 900 GPM,600 PSI,80 RPM,6k TQ.Minimal cuttings seen at shakers.Stop reaming after the commander reaches 1800'MD. 23:45 00:00 0.25 2,801 2,801 INTRM2 CSGDRI OWFF P Observe the well bore. Static.Crew change. 12/13/2012 POOH on the trip tank to 1198'MD with SDL assembly. Flow check. Static. L/D commander tool. POOH to BHA and lay down all tools.All tools safely retrieved and in good shape. Bit grade 1-1. Pick up cement retainer,29 joints 2 7/8"PH6 inner string,and hanger and packer.TIH with 5"DP to 8980'MD. 00:00 01:00 1.00 2,801 1,198 INTRM2 CSGDRI TRIP P PJSM. POOH on trip tank from 2801' MD to 1198'MD.Top of BHA. 01:00 01:30 0.50 1,198 1,198 INTRM2 CSGDRI OWFF P Observe well bore. Static. 01:30 02:00 0.50 1,198 1,168 INTRM2 CSGDRI PULD P Lay down MI Swaco circ.sub&liner setting tool. 02:00 02:30 0.50 1,168 1,168 INTRM2 CSGDRI PULD P Change out elevators and handling equipment from 5"to 4". 02:30 03:30 1.00 1,168 158 INTRM2 CSGDRI TRIP P POOH on the trip tank from 1168' MD to 158'MD. Calculated fill 91.3 BBIs.Actual fill= 117 BBIs. 03:30 03:45 0.25 158 158 INTRM2 CSGDRI OWFF P Observe well bore at top of collars. Static. 03:45 04:00 0.25 158 158 INTRM2 CSGDRISFTY P PJSM.Change out elevators from 4" to3'/z'. 04:00 05:15 1.25 158 90 INTRM2 CSGDRI PULD P Lay down Baker BHA. 05:15 06:00 0.75 90 90 INTRM2 CSGDRI PULD P Down load data from MWD system. 06:00 07:00 1.00 90 0 INTRM2 CSGDRI PULD P Continue to lay down bottom hole assembly. 07:00 07:30 0.50 0 0 INTRM2 CSGDRI RURD P Clean and clear rig floor of BHA components and tools. 07:30 08:00 0.50 0 0 INTRM2 CEMEN'PULD P PJSM. Rig up to run cement retainer. 08:00 10:30 2.50 0 940 INTRM2 CEMEN"TRIP P PJSM.Trip in the hole with the cement retainer and 2 7/8"PH6 string to 940'. 10:30 12:00 1.50 940 970 INTRM2 CEMEN'PULD P PJSM.Change out elevators.Make up liner hanger and swivel,mix up pal mix, and let set for 30 mins. 12:00 12:30 0.50 970 1,060 INTRM2 CEMEN'TRIP P Make up the bumper sub and trip in the hole to 1060'MD. Page 48 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 13:00 0.50 1,060 1,060 INTRM2 CEMEN'PULD P PJSM Make up the head pin and cement hose. Pump 1/2 BPM 40 PSI. 6.5 BBLS pumped. 13:00 13:15 0.25 1,060 1,060 INTRM2 CEMEN'RURD P Blow down top drive and mud line. 13:15 21:00 7.75 1,060 7,091 INTRM2 CEMEN'TRIP P Trip in the hole @ 2000'/hr to 6500'. Slow down to 1400'/hr to 7091'MD. 21:00 21:30 0.50 7,091 7,091 INTRM2 CEMEN'SVRG P Service top drive. Draw works. 21:30 00:00 2.50 7,091 8,980 INTRM2 CEMEN'TRIP P Trip in the hole @ 1400'/hr from 7091 to 8980'MD. Calculated displacement=67.2 BBLS.Actual displacement=61.5 BBLS. 12/14/2012 Trip in hole with cement retainer/liner packer assembly from 8980'MD to 10359'MD.Wash down to 11302' MD.Set hanger with 30k down weight. Drop 1.5"bronze ball and pressure up to 2800 PSI to release HRD running tool.Attempt to shear 1.5"bronze ball through ST landing sub Pressure up to 4200 PSI. Did not shear. Bleed off. Pressure up a second time to 4200 PSI Did not shear.Attempting to shear the 1.5"ball through the ported ST landing sub down to the solid ball seat so we could set the retainer. No Go. POOH to pick up Spear stop sub with PBR packoff. 00:00 01:30 1.50 8,980 10,359 INTRM2 CEMEN"TRIP P Trip in hole with cement retainer assembly on 2 7/8"inner string. From 8980'to 10359'MD. 160k Dn Wt. 01:30 02:00 0.50 10,359 10,387 INTRM2 CEMEN"CIRC P Establish circulation above liner top. 220 PSI @ 1 BPM.240 PSI @ 1 5 BPM.280 PSI @ 2 BPM. 320 PSI @ 2.5 BPM. 380 PSI @ 3 BPM.235K up and 160K DN and wash from 10359'to 10387'@ 3 BPM. B/D T/D. 02:00 03:45 1.75 10,387 11,139 INTRM2 CEMEN'TRIP P Trip in the hole from 10387'MD to 11139'MD. Calculated displacement=87.4.Actual displacement=86 BBLS. 03:45 04:45 1.00 11,139 11,302 INTRM2 CEMEN'WASH P Wash down last two stands. From 11139'to 11302'MD. 1.5 BPM,290 PSI,2 BPM, 320 PSI. 160k Dn Wt. 255k Up Wt.Seal assembly tag @ 11302'MD. 04:45 05:15 0.50 11,302 11,302 INTRM2 CEMEN'PULD P Pick up 5'. PJSM. Lay down top single of stand 110. Blow down top drive. Make up pup joints to cement head. 05:15 05.45 0.50 11,302 11,302 INTRM2 CEMEN'PULD P PJSM. Flow check well.Static. Pick up cement head. Rig up cement lines. Make up to top drive. 0545 06:00 0.25 11,302 11,302 INTRM2 CEMEN'TRIP P Locate top of 7"@ 11302'MD. Set 30k down. 135k. Pull up 10k over. 265k.Verify the hanger was set. 06:00 09:30 3.50 11,302 11,302 INTRM2 CEMEN'CIRC P PJSM. Pressure test lines to 3500 PSI. Establish circulation.Good returns. Stage pump up as follows. .5 BPM/160 PSI. 1 BPM 290 PSI. 1.5 BPM/310 PSI.2 BPM/360 PSI. 2.5 BPM/410 PSI.3 BPM/480 PSI. Total volume pumped 415 barrels. Page49of75 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 09:30 10:15 0.75 11,302 11,302 INTRM2 CEMEN'CIRC P PJSM. Drop lower setting ball. 1.5" bronze ball. Pump @ 3 BPM for 600 strokes.490 PSI.Slow down to 2 BPM,350 PSI. Land @ 730 strokes. Calculated volume=1837 stokes. Pressure up to 2000 PSI. Slack off to 135k from 258k.Set 30k down weight. Pressure up to 2800 PSI. Bleed to zero. Pick up 2.5 to confirm released form liner. Release HRD-E running tool. Slack off to 130k.To keep assembly in compression. 10:15 10:30 0.25 11,302 11,302 INTRM2 CEMEN'CIRC P Pressure up to 4200 PSI. Did not shear. Bleed off. Pressure up a second time to 4200 PSI. Did not shear.Attempted to shear the 1.5" ball through the ported ST landing sub down to the solid ball seat so we could set the retainer. No Go. 10:30 11:00 0.50 11,302 11,302 INTRM2 CEMEN'CIRC T PJSM. Blow down cement lines. Prepare to rig up Dowell SLB cementers.Test lines to 5000 PSI. Good. Pressure up to 5000 PSI to attempt to shear the 1.5"ball through the ported ST landing sub down to the solid ball seat so we could set the retainer. No Go.While pumping @.6 BPM the pressure held @ 4800 PSI. Indicating a leak.With the pump shut down the pressure bled quickly. Begin to discuss options with the Drilling Team. 11:00 12:45 1.75 11,302 11,302 INTRM2 CEMEN'OWFF T Blew down top drive.Observe well bore. Discuss options with Drilling Team. Rig up to send drilling mud to Dowell SLB cementers. 12:45 13:00 0.25 11,302 11,302 INTRM2 CEMEN'SFTY T PJSM with new crew:Subject- shearing out the ball, and current operations.Cold weather concerns. 13:00 13:30 0.50 11,302 11,302 INTRM2 CEMEN'CIRC T Pressure test Dowell SLB lines to 5000 PSI.Good. Line up to go downhole.Attempted 2 times to shear the ball through bringing the pressure up to 5000 PSI each time. No Go. Required.8 BPM to maintain pressure. Picked up and changed the position of the cup.Attempted to blow ball seat. Brought the pressure up to 3300 PSI using 2.4 BPM. Still leaking off quickly.Continue discussing options with Drilling Team. Page 50 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 14:15 0.75 11,302 11,302 INTRM2 CEMEN''RURD T Blow down lines. Rig down cementers. Lay down Baker cement head. Pick up single and place back in string. Prepare to trip out of the hole for Spear Stop Sub with PBR packoff to use for location during cement job. 14:15 14 30 0.25 11,302 11,223 INTRM2 CEMEN-CIRC T Pump out with 2 BPM,420 PSI. From 11302'to 11223'MD. 14:30 14:45 0.25 11,223 11,223 INTRM2 CEMEN"OWFF T Observe well bore. Static. 14:45 15:30 0.75 11,223 11,223 INTRM2 CEMEN'CIRC T 11223'MD. Circulate with 2 BPM. 400 PSI. Steam air lines on top drive. Thaw out rig equipment.Ambient temp=42 below.62 below WC. 15:30 16:00 0.50 11,223 11,223 INTRM2 CEMEN'OWFF T Observe well bore. Static. Blow down top drive. 16:00 17:45 1.75 11,223 10,292 INTRM2 CEMEN-TRIPT Trip out of the hole on the trip tank. From 11223'MD to 10292'MD.Good hole fill. 17:45 18:30 0.75 10,292 10,292 INTRM2 CEMEN'CIRC T Flow check well.Static. Pump dry job. Blow down top drive,mud lines. 18:30 22:45 4.25 10,292 4,549 INTRM2 CEMEN'TRIP T Trip out of the hole.On the trip tank. From 10292'MD to 4549'MD. 22:45 00:00 1.25 4,549 4,549 INTRM2 CEMEN"RGRP T Rig repair. Hydraulic leak.4 gallons into containment. Hose leak going to off Driller side tugger. 12/15/2012 Trip out of the hole. Inspect Baker assembly. Discover the cement retainer was set on bottom. Inspect all tools. Make up new cement assembly with spear stop sub and PBR packoff.Trip in the hole. Establish circulation rates above the seal bore. Locate. Establish circulation rates while located. 1 BPM/350 PSI.2 BPM/420 PSI.3 BPM/570 PSI.4 BPM/730 PSI.Circulate bottoms up to obtain even mud weights in and out. 00:00 01:00 1.00 4,549 4,549 INTRM2 CEMEN-RGRP T PJSM.Troubleshoot hydraulic leak and remove blown hose's. 01:00 02:30 1.50 4,549 3,321 INTRM2 CEMEN"TRIP T PJSM. POOH from 4549'to 3321' with 133K up and 125 K down. 02:30 03:00 0.50 3,321 3,321 INTRM2 CEMEN"CIRC T Flow check and no flow. Pump 1 bbl dry job. B/D T/D and mud line 03:00 05:00 2.00 3,321 970 INTRM2 CEMEN"TRIP T Continue POOH on trip tank from 3321'to 970' 05:00 05:30 0.50 970 970 INTRM2 CEMEN'OWFF T Flow check. Static. PJSM. UD bumper sub. 05:30 06:30 1.00 970 970 INTRM2 CEMEN'RURD T PJSM. R/U tubing tongs and L/D liner running tool. 06:30 07:45 1.25 970 19 INTRM2 CEMEN"PUTB T C/O elevators to tubing elevators R/U belly rope and stand back 2 7/8"tubing. Calculated fill 89.9 bbls. Actual fill 106.5 bbls. 07:45 08:00 0.25 19 0 INTRM2 CEMEN"PULD T L/D circulating running tool 08:00 09:00 1.00 0 0 INTRM2 CEMEN"RURD T Clean and clear rig floor. R/U M/U 2 7/8"tubing. 09:00 09:30 0.50 0 0 INTRM2 CEMEN-PULD T Bring up cement BHA components to rig floor. Remove rupture disk from BHA. 09:30 10:30 1.00 0 909 INTRM2 CEMEN'TRIP T PJSM. RIH with 2 7/8"tubing from 0' to 909'. Page 51 of 75 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 10:30 1045 0.25 909 909 INTRM2 CEMEN"RURD T PJSM.C/O tubing elevators for 5" DP elevators. R/D belly rope and R/D tubing tongs. 10:45 11:15 0.50 909 919 INTRM2 CEMEN"PULD T M/U seal assembly until 919'. 11:15 12:00 0.75 919 1,860 INTRM2 CEMEN-TRIPT PJSM. RIH from 919'to 1860'.85K up and 85K down. 12:00 20:30 8.50 1,860 11,249 INTRM2 CEMEN"TRIP T Trip in the hole from 1860'MD to 11249'MD.Calculated displacement=85.9 BBLS.Actual displacement= 103 BBLS. 20:30 21:15 0.75 11,249 11,249 INTRM2 CEMEN"PULD P Pick up cement head from pipe shed. Rig up to pump down cement lines. 21:15 00:00 2.75 11,249 11,272 INTRM2 CEMEN"CIRC P Establish pump rates above seal assembly. %BPM/170 PSI, 1 BPM=210 PSI, 1%BPM/240PSI,2 BPM=280 PSI,2%BPM/330 PSI 3 BPM=400 PSI. Locate top of liner on depth. 10350'Liner top. 10353'tally depth.11272'=depth of current bull nose. Pick up 2 feet. Establish rates:%BPM/260 PSI, 1 BPM/340 PSI, 1%BPM/370 PSI,2 BPM/420 PSI,2%BPM/490 PSI,3 BPM/550 PSI,3%BPM/655 PSI,4 BPM/750 PSI. 12/16/2012 Circulate and condition mud system in preparation for cement job. Pump cement job. Dowell pumps 20 bbls of 8.3 PPG CW100 @ 4 BPM. Pump 30 bbls of 12.5 PPG MP-II @ 4 BPM. Pump 48.6bbls of 15.8 PPG Alpine Int.Tail cement slurry @4 BPM. Drop dart and pump 5.2 bbls of 12.5 PPG MP-II @ 4 BPM. Switch to rig pump and pump 176 bbls of 10.5 PPG drilling mud @2-4 BPM. Flapper in cement retainer appeared to have failed.After bleeding the pressure to zero on surface,the pressure would build back to 300 PSI in 2 mins.This indicates a failed flapper. Pump out of the liner. Circulate the residual mud push and cement out of the hole.Trip out laying down 5"DP,and the torque reduction sleeves,"Super Sliders". 00:00 02:00 2.00 11,272 11,272 INTRM2 CEMEN"CMNT P Circulate and condition mud @ 4 BPM until mud weight was even with 10.5 PPG in and 10.5 PPG out. Circulated 910 bbls. 730 PSI ICP. 650 PSI FCP Page 52 of 75 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 02:00 04:15 2.25 11,272 11,272 INTRM2 CEMEN-CMNTP PJSM.Cement liner. Dowell pump with 5 bbls of CW 100.Shut down and pressure test lines to 3000 PSI. Pump 15 bbls of CW 100. Pump 25 bbls of 12.5 PPG mud push @ 4.8 BPM with 870 pump PSI.Clean tank. Pump 48.6 bbls of 15.8 PPG ` cement @ 4.2 BPM with 620 pump PSI. Drop dart. Pump 5.2 bbls of 12.5 PPG mud push.Switch to rig pump.Chase with 176 bbls of 10.5 PPG mud @ 4 BPM with 440 PSI. Notice a loss in returns at 475 strokes and slow down to 3 BPM with 730 pump PSI.At 800 strokes slow down to 2.5 BPM with 710 pump PSI.At 1190 strokes slow down to 2 BPM with 800 pump PSI. At 1440 strokes slow down to 1.5 BPM with 870 PSI. Lost 4 bbls of cement with 21 bbls of fluid loss total.The flapper inside the retainer did not hold. Pressure up to 300 PSI. 04:15 04:30 0.25 11,272 11,260 INTRM2 CEMEN"CMNT P Set liner packer. Set down 65K to 100K total. P/U to 255K.Set back down to 100K. Set back down to 100K total. Pull up to 11,260'. 04:30 05:00 0.50 11,260 11,260 INTRM2 CEMEN"CMNT P Circulate and condition mud @ 4 BPM with 650 PSI. 116.6 bbls total. Slight back flow when broke out of the top drive. 05:00 05:30 0.50 11,260 11,260 INTRM2 CEMEN"RURD P Break off single joint and cement head. B/D R/D cement lines. L/D cement head. P/U single. 05:30 07:30 2.00 11,260 10,373 INTRM2 CEMEN"CIRC P Flow check. Static. Pump out of the hole. From 11260'to 10373'MD. Start @ 1.5 BPM/350 PSI,3 BPM/ 400 PSI, 5 BPM/620 PSI.Circulate @ 5 BPM while pulling through the liner top 100'/hr. 07:30 10:15 2.75 10,373 10,338 INTRM2 CEMEN"CIRC P Circulate and condtion the mud above the liner.On stand 100. Reciprocating.5 BPM/600 ICP,5 BPM 440 FCP. 10:15 11:00 0.75 10,338 10,338 INTRM2 CASING OWFF P Flow check.Static. Pump 28 BBL 1.5 lb over dry job. Blow down top drive and all mud lines. 11:00 12:00 1.00 10,338 9,961 INTRM2 CASING TRIP P Trip out of the hole from 10338'to 9961'MD. Monitor the wellbore with the trip tank. Laying down singles and removing super sliders. 12:00 19:00 7.00 9,961 5,631 INTRM2 CASING TRIP P Trip out of the hole. Monitoring the wellbore vta the trip tank. Lay down 5"DP into the pipeshe. Remove Super Sliders. From 9961'to 5631' MD. 19.00 19:15 0.25 5,631 5,631 INTRM2 CASING OWFF P Observe wellbore. Slight flow Out of balance from the dry job. Page 53 of 75 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 19:15 20:00 0.75 5,631 6,854 INTRM2 CASING TRIP P Trip in the hole with 13 stands of 5" DP. Observe well bore. Static. 20:00 00:00 4.00 6,854 2,802 INTRM2 CASING TRIP P Trip out of the hole. Monitoring the wellbore via the trip tank. Lay down 5"DP into the pipeshed. Remove Super Sliders. From 6854'to 2802' MD.Caluculated disp=71.1 BBLS. Actual disp=70.5 BBLS. 12/17/2012 Trip out of the hole on trip tank. Fr 2802'to 952'MD. Remove all"Super Sliders", lay down 5"DP. Slip and cut drill line. Lay down 30 Jts.2 7/8"PH6 work string.Test liner top packer/casing to 1980 PSI.Conduct 'dummy'run with landing joint and casing hanger. rig up Tesco and begin to run the upper 7"26#L80 BTC-M tie-back casing string. Joints 1-90. 00:00 05.00 5.00 2,802 952 INTRM2 CASING TRIP P POOH from 2802'to 952'. Remove super sliders and UD drill pipe to pipe shed.Calculated 98 BBLS. Actual Displacement=123 BBLS.At top of 2 7/8"string.One Jt.5"DP hanging. 05:00 05:30 0.50 952 952 INTRM2 CASING OWFF P Observe well.Static. Clean clear rig floor. 05:30 08:00 2.50 952 952 INTRM2 CASING SLPC P PJSM.Slip and cut drill line.Slip and cut 60' 08:00 08:15 0.25 952 902 INTRM2 CASING PULD P Lay down 5"single. Lay down Spear Stop Sub with no go and PBR seal. 08:15 08.45 0.50 902 902 INTRM2 CASING SFTY P PJSM. Rig up tubing tongs and elevators. Discuss possible dropped objects. . Pinch points. Procedures. 08:45 10.00 1 25 902 0 INTRM2 CASING PULD P Lay down 2 7/8"PH6 work string. 10:00 10:45 0.75 0 0 INTRM2 CASING RURD P Clear and clean rig floor and pipe shed of tubing equipment and Baker equipment that was not needed. Send equipment down the beaver slide for shipment out. 10:45 11:15 0.50 0 0 INTRM2 CASING RURD P Pull wear ring with FMC hand. 11:15 12:00 0.75 0 0 INTRM2 CASING PRTS P PJSM. Rig up to test casing/liner top/cement in hole.Close blind rams. Pressure test to 1980 PSI. Charted 14 mins.Good. Rig down. Blow down lines. 12:00 12:15 0.25 0 0 INTRM2 CASING SFTY P PJSM.Conducting the 7"hanger dummy run to obtain the actual landing distance. 12:15 13:00 0.75 0 0 INTRM2 CASING RURD P Perform dummy run. Measure 33.52' Rig floor to upper lock downs. Lay down LJ and hanger. 13:00 13:15 0.25 0 0 INTRM2 CASING SFTY P PJSM. Discuss rigging up the Tesco casing running equipment. 13:15 13:45 0.50 0 0 INTRM2 CASING PULD P Mobilize equipment to rig floor. Organize to rig up Tesco. 13:45 15:15 1.50 0 0 INTRM2 CASING RURD P Rig up Tesco equipment. Pick up tools to run casing. 15:15 15:30 0.25 0 0 INTRM2 CASING SFTY P PJSM. Running 7"26#L-80 BTC-M casing. 15:30 22:30 7.00 0 3,567 INTRM2 CASING RNCS P Run 7"casing.Joints#1 to#82. 3567'MD.Torque connections to 16k on top drive. Page 54 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 22:45 0.25 3,567 3,567 INTRM2 CASING SFTY P PJSM. Repair Service Tesco unit. 22:45 23:30 0.75 3,567 3,567 INTRM2 CASING SVRG P Service Tesco unit.Change out grapple. 23:30 00:00 0.50 3,567 3,911 INTRM2 CASING RNCS P Run 7"casing.Joints#83 to#90. 3911'MD.Torque connections to 16k on top drive. 12/18/2012 Run the upper 7"26#L80 BTC-M tie-back casing string.Joints 90-239. Land out @ 10363.67 mule shoe depth.Space out to land 1.09 feet located out.Make up 7"casing hanger. Displace outer annulus, reverse out. 35 BBLS 10.5 PPG spacer,4 BPM/550 PSI.275 BBLS 10 PPG inhibited brine,6 BPM/ICP=540 PSI, FCP=980 PSI. 5 BBLS water, 108 BBLS diesel,3 5 BPM 730 PSI ICP,880 PSI FCP. Flush lines with water. Set hanger into bowl. Mule shoe depth 10362.58'MD.Top of liner 10352.45. UD landing joint.Set pack off. Test to 5000 PSI for 10 mins.Witnessed by Rig Supervisor.Tested annulus 30 mins,2500 psi.Tested 7" casing 30 mins.3500 PSI. Both tests were charted. 00:00 00:45 0.75 3,911 4,340 INTRM2 CASING RNCS P Run 7"26#L-80 BTC-M casing. From joint#90 to joint#100. 1000'/hr.Mud began to flow over the top. 00:45 01:15 0.50 4,340 4,340 INTRM2 CASING CIRC P Observe well. Pump dry job to assist in casing run. Blow down top drive. 01:15 11:15 10.00 4,340 10,331 INTRM2 CASING RNCS P Run 7"26#L-80 BTC-M casing. From joint#100 to joint#239. 1800'/hr. 11:15 11:45 0.50 10,331 10,363 INTRM2 CASING RNCS P Wash down to find top of seals.Shut down pump. NO GO out @ 10363' MD 11:45 12:00 0.25 10,363 10,363 INTRM2 CASING CIRC P PJSM. on how to blow down top drive with Tesco tool in the hole. 12:00 12:15 0.25 10,363 10,363 INTRM2 CASING SFTY P PJSM on how to blow down the top drive with the Tesco tool rigged up. 12:15 13:00 0.75 10,363 10,322 INTRM2 CASING PULD P Back out joint#240.(Used to locate, not in string). Blow down top drive 13:00 14:30 1.50 10,322 10,322 INTRM2 CASING HOSO P Lay down joints#240,249,238. Pick up#249 instead of#238. Pick up# 258 instead of#239. Space out 1.09 feet up from fully located. 14:30 14:45 0.25 10,322 10,322 INTRM2 CASING PULD P Make up 7"hanger, and landing joint. 14:45 15:00 0.25 10,322 10,340 INTRM2 CASING SFTY P PJSM. Laying down Tesco. 15:00 15:30 0.50 10,340 10,340 INTRM2 CASING RURD P Rig down Tesco system. 15:30 16:00 0.50 10,340 10,340 INTRM2 CASING PULD P Pick up the short bales. Side door casing elevators 16:00 16:30 0.50 10,340 10,350 INTRM2 CASING RURD P Make up cement swedge and XO. Connect hose to'GeoPilot' hose which dumps into the flow line. Prepare to displace well by reversing. Position the seals 4 feet out. 16:30 17:00 0.50 10,350 10,350 INTRM2 CASING SFTY P PJSM on displacing inhibited brine and diesel to the backside. Page 55 of 75 Time Logs _ Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 19:15 2.25 10,350 10,350 INTRM2 CASING CIRC P Close annular preventer. Reverse circulate. Displace the outer annulus. The rig pumped: 35 BBLS 10.5 PPG spacer @ 4 BPM/550 PSI.275 BBLS 10 PPG inhibited brine @ 6 BPM/540 ICP, 980 FCP.Then 5 BBLS water flush. Dowell pumped: 108 BBLS 6.9 PPG diesel @ 3.5 BPM, 730 ICP,880 FCP.Shut down. Flush lines with water. 19:15 19:30 0.25 10,350 10,363 INTRM2 CASING HOSO P Set hanger into well head bowl,with 550 PSI,stripping through the annular preventer.Tagged out 3.8' deep to original tally. Found TOL @ 10353.54. 19:30 20:15 0.75 10,363 10,363 INTRM2 CASING RURD P Blow down lines. Rig down cement head,cement line, lay down landing joint. 20:15 21:45 1.50 10,363 10,363 INTRM2 CASING OTHR P Set pack off in well head.Tighten glan nuts and lock down screws to 450 ft/lbs. Rig up and test pack off to 5000 PSI for 10 mins.Witnessed by Rig Supervisor. 21:45 22:00 0.25 10,363 10,363 INTRM2 CASING SFTY P PJSM. Pressure testing the OA and the casing. 22:00 23:00 1.00 10,363 10,363 INTRM2 CASING PRTS P Rig up to test annulus. Pressure up to 2500 PSI.30 mins.Charted.5.9 BBLS pumped. Bled back 5 BBLS into tote in cellar.Shut in.Good test. 23:00 00:00 1.00 10,363 10,363 INTRM2 CASING PRTS P Rig up to test casing. Pressure up to 3500 PSI. 30 mins.Charted.6.4 BBLS pumped.6.4 BBLS bled back. 12/19/2012 PJSM,change top pipe rams f/7"to 3-1/2"x 6"VBR's,test top pipe and annular w/4"test joint, install FMC wear bushing,stand back 5 stands of 4"dp, PU/MU cleanout BHA to 353', PU/MU/RIH w/4"drill pipe f/pipe shed to 10365'MD.Wash and ream with stands from 10365'to 11303'MD.Tag up on cement retainer @ 11303'MD. Begin drilling up retainer. 00:00 02:00 2.00 0 0 INTRM2 WHDBOOTHR P PJSM.Change upper pipe rams to 3 1/2"X 6"VBR's.Change saver sub on top drive to 4"XT-39. 02:00 03:15 1.25 0 0 INTRM2 WHDBO BOPE P Test upper pipe rams with 4"test jt to 250-3500 psi.l Test annular to 250-2500 psi. Pull test plug. 03:15 03:45 0.50 0 0 INTRM2 WHDBO OTHR P Install wear bushing with 8.75"ID. 03:45 05:15 1.50 0 0 INTRM2 CEMEN"PULD P PJSM. PU and stand back 5 stds 4" DP via the mousehole. 05:15 06:00 0.75 0 0 INTRM2 CEMEN"OTHR P Mobilze BHA components to rig floor. 06:00 07:45 1.75 0 353 INTRM2 CEMEN"PULD P MU BHA#8 to 353'. 07:45 12:00 4.25 353 3,592 INTRM2 CEMEN-TRIP P Single in hole with 4"DP from 353'to 3592'. Fill pipe every 20 stds. 12:00 18:45 6.75 3,592 10,365 INTRM2 CEMEN"TRIP P Single in the hole with 4"DP from 3592'to 10365'MD. Fill pipe every 20 stands. Kelly up on stand 105. Page 56 of 75 Time Logs . Date From To Dur S. Death E. Death Phase Code Subcode T Comment 18:45 22:15 3.50 10,365 11,303 INTRM2 CEMEN"REAM P Begin reaming on stand 105. Ream with 50 RPM,300 GPM/1900 PSI, 14k TQ. Up Wt=220k, Dn Wt=125k, Rot Wt=158. Locate cement retainer @ 11303'MD. 22:15 00:00 1.75 11,303 11,304 INTRM2 CEMEN"REAM P Grind on cement retainer. 300 GPM, 1800 PSI,70 RPM, 10k WOB, 16k TQ on, 15.5k TO off. Drill up approx. 8 inches. lenght of retainer 2.10'. 12/20/2012 Drill out the cement retainer, landing profile inside shoe joint,shoe,clean out to TD 11458'MD.CBU. Perform FIT to 12.5 PPG EMW. POOH from 11319 to 10173'. Improper hole fill.TIH.CBU.Well bore static. Pump out of hole from 11319'MD to 9697'MD.Service rig.Change out swivel packing.Continue to pump out of the hole from 9697'MD to 9507'MD. 00:00 00:45 0.75 11,304 11,305 INTRM2 CEMEN"REAM P Drill up cement retainer.from 11304 to 11305'MD.300 GPM, 1800 PSI, 70 RPM, 16 to 17k TQ on, 15.5k TQ off. 00:45 05:45 5.00 11,305 11,409 INTRM2 CEMEN"REAM P Drill out cement and landing profiles inside shoe joint of drilling liner. Drill cement from 11305'MD to to 11410' MD. Depth of shoe.Soft cement from 11305'to 11369'MD. Hard cement from 11369'to 11379'.Soft cement from 11379'to 11389'MD. Hard cement from 11389 to 11410'MD. 300 GPM, 1900 PSI, 100 RPM, 18k TQ. Bit weight from 5 to 20k.240k Up Wt, 135k Dn Wt, 168k Rot Wt. 05:45 06:45 1.00 11,409 11,458 INTRM2 CEMEN"REAM P Clean out rathole from 11409'MD to 11458'MD.@ 300 GPM, 100 RPM, 1960 PSI. 06:45 07:30 0.75 11,458 11,458 INTRM2 CEMEN-CIRC P Circulate and condition mud for FIT @ 300 GPM, 1980 PSI, 100 RPM, 17k TQ off bottom. 240k UP/135k DN/168k ROT. 07:30 08:00 0.50 11,458 11,319 INTRM2 CEMEN"TRIP P POOH to 11319'MD. Blow down top drive. 08:00 08:30 0.50 11,319 11,319 INTRM2 CEMEN"PRTS P PJSM. Flow check.Static. Rig up for FIT. Perform FIT to 12.5 PPG EMW. 726 PSI. Using 10.5 PPG mud. Blow down lines. 08:30 10:45 2.25 11,319 10,365 PROD1 DRILL CIRC P Flow check well bore.Static. Pump out of the hole 10 stands. 11319'MD to 10365'MD. Pump 5 BPM, 1260 PSI,240k Up/135k Dn. 10:45 11:00 0.25 10,365 10,365 PROD1 DRILL OWFF P Blow down top drive. Flow check. Static. 11:00 11:30 0.50 10,365 10,173 PROD1 DRILL TRIP P Trip out on the trip tank. Pull 2 stands. 11365'to 10173'MD. Improper hole fill.Gain 1.5 BBLS Calculated hole fill=1.25 BBLS 11:30 12:00 0.50 10,173 9,888 PROD1 DRILL CIRC P Begin pumping out.5 BPM, 1090 PSI. From 10173'MD to 9888'MD. 12:00 13:30 1.50 9,888 9,221 PROD1 DRILL CIRC P Continue to pump out of the hole. From 9888'MD to 9221'MD.210 GPM, 1020 PSI Page 57 of 75 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 13:30 14:00 0.50 9,221 9,221 PROD1 DRILL OWFF P Bow down top drive.Observe well for flow. Slight flow. Prepare to trip back to the shoe. 14:00 15:15 1.25 9,221 11,319 PROD1 DRILL TRIP P Trip back in the hole to the 7"shoe. Good displacement. 15:15 16:15 1.00 11,319 11,319 PROD1 DRILL CIRC P Circulate bottoms up.300 GPM. 1800 PSI. No gas or gas cut mud at bottoms up. 16:15 16:45 0.50 11,319 11,319 PROD1 DRILL OWFF P Observe wellbore. Static. 16:45 20:00 3.25 11,319 9,887 PROD1 DRILL CIRC P Pump out 15 stands. From 11319' MD to 9887'MD.210 GPM, 20:00 20:30 0.50 9,887 9,887 PROD1 DRILL OWFF P Observe well bore. Static. 20:30 20:45 0.25 9,887 9,791 PROD1 DRILL CIRC P Pull on elevators.500'/hr. Improper hole fill. Mud in trip tank had en trained air. Decide to add defoamer to trip tank,and pump out while the mud in trip tank settles out. 20:45 21:00 0.25 9,791 9,791 PROD1 DRILL OWFF P Observe well bore. Static. Mud in trip tank recieved 5 gallons of defoamer. 21:00 21:15 0.25 9,791 9,697 PROD1 DRILL CIRC P Pump out one stand.Good displacement. 21:15 23:00 1.75 9,697 9,697 PROD1 DRILL SVRG P Notice swivel packing was leaking. Blow down top drive. Line up on trip tank.Change out swivel packing. Monitor the well on the trip tank. No loss, no gain. 23:00 23:15 0.25 9,697 9,697 PROD1 DRILL OWFF P Observe well for flow.Static. 23:15 23:30 0.25 9,697 9,697 PROD1 DRILL CIRC P Presssure test the new swivel packing to 3500 PSI. Good 23:30 00:00 0.50 9,697 9,507 PROD1 DRILL CIRC P Pump out. From 9697'MD to 9507' MD.210 GPM, 1000 PSI. 12/21/2012 Pump out of the hole from 9507'MD to 6835'MD.Trip out on the trip tank to surface Lay down BHA. 12 lbs. metal on the magnets. Pull wear bushing. Rig up and conduct full Bi-weekly BOPE test with 3%",4",4'/z' test joints. Pull test plug,set wear bushing. 00:00 04:00 4.00 9,507 7,409 PROD1 DRILL CIRC P POOH with pump from 9507'MD to 7409'MD. 5 BPM, 1000 PSI. 04:00 04:15 0.25 7,409 7,409 PROD1 DRILL OWFF P Blow down top drive. Flow check well.Static. 04:15 04:30 0.25 7,409 7,409 PROD1 DRILL TRIP P Attempt to pull on elevators. Swabbed up a barrel in 60 feet. 180k Up, 127k Dn. 04:30 05:30 1.00 7,409 6,835 PROD1 DRILL CIRC P POOH with pump from 7409'MD to 6835'MD.5 BPM, 1000 PSI. 05:30 05:45 0.25 6,835 6,835 PROD1 DRILL OWFF P Blow down top drive. Flow check well.Static. 05:45 12:00 6.25 6,835 634 PROD1 DRILL TRIP P POOH on the trip tank. From 6835' MD to 634'MD. Pulled 5 stands and filled.This worked versus running constant hole fill. 12 00 12:15 0.25 634 634 PROD1 DRILL SFTY P Observe well. Static. PJSM on laying down BHA. 12:15 12:45 0.50 634 190 PROD1 DRILL TRIP P POOH on trip tank. Calculated displacement=71.3 BBLS.Actual displacement=75 BBLS. Page 58 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12 45 14:00 1.25 190 0 PROD1 DRILL PULD P Lay down BHA. Magnets had 12 lbs of metal.The boot baskets were empty. 14:00 14:30 0.50 0 0 PROD1 DRILL RURD P Clear and clean rig floor. 14:30 15:00 0.50 0 0 PROD1 DRILL RURD P Pull wear bushing.Set test plug. 15:00 15:15 0.25 0 0 PROD1 DRILL SFTY P PJSM.Testing BOPE. 15:15 16:45 1.50 0 0 PROD1 DRILL BOPE P Rig up for BOPE test. Service accumulator bottles. 16:45 23:30 6.75 0 0 PROD1 DRILL BOPE P Tested BOPE as follows:w/4"test jt.tested Annular to 250&2500 psi- Tested upper 3%x 6"pipe rams,TD IBOP's,4"Floor safety&dart valves, Choke&kill line valves,Choke manifold valves# 1,2,3,4,5,6,7,8,9,10,11,12,13,14,15, &16 and needle valve to 250&3500 psi-HCR choke and Kill-4"Demco on kill line-manual kill&choke valves-Lower 2-7/8"x 5"pipe rams to 250&3500 psi-Performed accumulator recovery test,opened one of the rams simulate closing a blind ram.3000 psi start, 1400 psi end,40 sec to 200 psi,220 sec to 3000 psi-Also isolated the accumulators and tested each pump system. For each pump(electric, air),two pipe rams were closed and the hydraulic choke was opened. Electric pump: 1 min 10 secs to operating pressure.Air pump: 1 min 35 secs. Operated all remote panels. Tested Blind rams 250/3500 psi- Tested gas alarms -With the 3%", 4"and 4W test joint tested annular, 250 PSI low/2500 PSI high, upper and lower variable pipe rams 250 PSI low/3500 PSI high.Annulus open and monitored during test.All tests charted,5 min/test.John Crisp (AOGCC)waived witnessing tests. 23:30 00:00 0.50 0 0 PROD1 DRILL BOPE P Pull test plug. Set wear bushing. 12/22/2012 Pick up BHA#9. Baker 43/4'rotary steerable system.6"PDC bit. Single in the hole 55 stands. Fill pipe every 20 stands.Trip to the 7"shoe @ 11410'MD.Slip and cut drilling line.Change out water base mud to production fluid,(Oil Base). 10.5 PPG in and out. 00.00 00:30 0.50 0 0 PROD1 DRILL RURD P Blow down lines. Blow down top drive,poor boy,choke,clear rig floor. 00:30 02:30 2.00 0 63 PROD1 DRILL PULD P PJSM. Pick up Baker rotary steerable system BHA#9,as per DD. 02:30 03:00 0.50 63 63 PROD1 DRILL PULD P Upload MWD tools. 03:00 04:15 1.25 63 102 PROD1 DRILL PULD P Continue to pick up BHA#9. as per DD. From 63 0'MD to 102.0'MD. Page 59 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 05:00 0.75 102 420 PROD1 DRILL TRIP P Trip in the hole. Run in the HWDP, Jars,HWDP to first single out of the pipeshed. 05:00 05:15 0.25 420 420 PROD1 DRILL CIRC P Shallow test MWD @ 200 GPM,650 PSI.Weak signal. Decide to trip further. 05:15 08:00 2.75 420 2,292 PROD1 DRILL TRIP P Trip in the hole with singles out of the pipe shed from 420'MD to 2292'MD. 08:00 08:45 0.75 2,292 2,292 PROD1 DRILL CIRC P Shallow pulse test MWD system. 200 GPM, 1100 PSI.Good test. 08:45 12:00 3.25 2,292 4,296 PROD1 DRILL TRIP P Trip in the hole. Picking up single. From 2292'MD to 4296'MD. Fill pipe every 20 stands. 12:00 14:00 2.00 4,296 5,637 PROD1 DRILL TRIP P Trip in the hole. Picking up single. From 4296'MD to 5637'MD. Fill pipe every 20 stands. 14:00 20:30 6.50 5,637 11,453 PROD1 DRILL TRIP P Trip in the hole. Running in stands. From 5637'MD to 11453'MD. Fill every 20 stands. 20:30 22:30 2.00 11,453 11,453 PROD1 DRILL CIRC P Circulate and condition the mud. SIMOPS: Hold 2 prejob safety meetings about the upcoming displacement job. 22:30 22:45 0.25 11,453 11,453 PROD1 DRILL OWFF P Observe wellbore.Static 22:45 00:00 1.25 11,453 11,453 PROD1 DRILL CIRC P Pump 39 BBL oil base spacer. 10.5 PPG.220 GPM,2040 PSI. Followed by 390 BBLS of 10.5 PPG oil base mud @ 220 GPM. ICP=2190. FCP=2620 PSI. 12/23/2012 Finish 10.5 ppg MOBM displacement,monitor well-(slight drop,slip and cut drill line,MAD pass Log f/11415' to 11458', Drill 6"hole with 4'/,"rotary steerable tools f/11458'to 12311'MD. 00:00 00:15 0.25 11,453 11,453 PROD1 DRILL CIRC P Circulate and condition mud 220 GPM,2450 PSI. 00:15 00:30 0.25 11,453 11,358 PROD1 DRILL CIRC P Record slow pump rates. Stand back stand 116. 00:30 02:00 1.50 11,358 11,358 PROD1 DRILL OWFF P Observe wellbore after displacement. Static.SIMOPS: Clean shakers,trip tank, possum belly. 02:00 04:15 2.25 11,358 11,358 PROD1 RIGMN1SLPC P Slip and cut 60'of 1-3/8"drill line. Service top drive.Adjust brakes. Monitor well on trip tank. 04:15 05:45 1.50 11,358 11,458 PROD1 DRILL TRIP P Make a top drive connection. RIH f/ 11358', Log f/11415'to 11458'. Pumping 220 gpm w/2500 psi. Rotate 30 rpm w/13k ft lbs of torque. 05:45 12:00 6.25 11,458 11,759 PROD1 DRILL DDRL P Directional drill 6"hole from 11458'to 11759'(TVD=6981'). ADT 4 8 hrs. ECD 12.19 to 12.25 ppg Footage-301' WOB 12/15 k RPM 100 GPM 220 @ 2540 psi String wt-PU 240 SO 120 ROT 163 Torque on/off btm.-15.5/14 Page 60 of 75 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 12:00 00:00 12.00 11,759 12,311 PROD1 DRILL DDRL P Directional drill 6"hole from 11759'to 12311'(TVD=6978'). ADT 8.0 hrs. ECD 12 30 ppg Footage-552' WOB 12 k RPM 120 GPM 220 @ 2540 psi String wt-PU 240 SO 125 ROT 174 Torque on/off btm.-14k/15.5k ft/lbs 12/24/2012 Directional drill 6"hole with 4%' Baker Hughes rotary steerable tools from 12311'to 13197'(TVD=6977'). 00:00 12:00 12.00 12,311 12,884 PROD1 DRILL DDRL P Directional drill 6"hole from 12311 to 12884'(TVD=6971'). ADT 9.2 hrs. ECD 12.43 ppg Footage-573' WOB 8-12 k RPM 130 GPM 215 @ 2490 psi String wt-PU 230 SO 130 ROT 170 Torque on/off btm.-15k/14k ft/lbs OA pressure 1480 psi @ 0820 hrs. 12:00 18:30 6.50 12,884 13,097 PROD1 DRILL DDRL P Directional drill 6"hole from 12884'to 13097(TVD=6979'). ADT 4.98 hrs. ECD 12.39 ppg Footage-213' WOB 12 k RPM 120 GPM 220 @ 2540 psi String wt-PU 230 SO 130 ROT 170 Torque on/off btm.-15k/14k ft/lbs OA pressure 1000 psi @ 18:30 hrs. 18:30 20:30 2.00 13,097 13,076 PROD1 DRILL CIRC P Stand one stand back to CBU for Geology. CBU 2 x's.220 GPM, ICP=2730 PSI, FCP=2520 PSI, 130 RPM, 15k TQ. Decide to continue drilling after confering with the town Geologist. 20:30 21:00 0.50 13,076 13,097 PROD1 DRILL REAM P Wash/Ream back to bottom. Downlink set up tool to build angle. Extend ribs out on Baker tool.215 GPM,2490 PSI,60 RPM, 13.5k TQ. 21:00 00:00 3.00 13,097 13,197 PROD1 DRILL DDRL P Directional drill 6"hole from 13097'to 13197(TVD=6977'). ADT 2.02 hrs. ECD 12.39 ppg Footage-100' WOB 12 k RPM 120 GPM 220 @ 2540 psi String wt-PU 230 SO 130 ROT 170 Torque on/off btm.-15k/14k ft/lbs OA pressure 1160 psi @ 22:15 hrs. 12/25/2012 Directionally drilled 6"hole w/Baker Hughes rotary steerable system f/13,595'to 13,870' Page 61 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 13,197 13,595 PROD1 DRILL DDRL P Directional drill 6"hole from 13,197' to 13,595(TVD=6983'). ADT 9.6 hrs. ECD 12.52 ppg Footage-398' WOB 16/18 k RPM 120 GPM 200 @ 2380 psi String wt-PU 230 SO 130 ROT 172 Torque on/off btm.-16k/15k fUlbs OA pressure 1230 psi @ 11:00 hrs. 12:00 00:00 12.00 13,595 13,870 PROD1 DRILL DDRL P Directional drilled 6"hole f/13,595'to 13,870'MD 6978'TVD ADT-8.8 hrs. ECD-12.55 ppg Footage-275' WOB 8-18 k RPM 120 GPM 200 @ 2450 psi String wt PU 245 SO 130 Rot 170 Torque on/off btm.-16/15 k ft/lbs 0/A 1280 psi @ 2215 hrs 12/26/2012 Directionally drilled 6"hole w/Baker RSS f/13,870'to 14,120'MD-6974'ND(TD of section)Circ 3 X btms up-POOH w/pump @ 200 gpm-No rotation f/14,029'to 11,358'-Flow ck(static)Circ 2 X btms up @ 200 gpm w/130 rpm's w/14 k torque 00:00 06:45 6.75 13,870 14,030 PROD1 DRILL 'DDRL P Directional drilled 6"hole f/13,870'to 14,030'MD 6977'TVD ADT-6.1 hrs. ECD-12.62 ppg Footage-160' WOB 18 k RPM 135 GPM 200 @ 2460 psi String wt PU 240 SO 125 Rot 172 Torque on/off btm.-17/16 k ft/lbs 06:45 08:30 1.75 14,030 14,030 PROD1 DRILL CIRC P Down-lync and close ribs on steering head. Backream one std slow at 200 gpm-2490 psi-130 rpm-16k tq. Only lowered ECD from 12.66 to 12.62. 08:30 12:00 3.50 14,030 14,120 PROD1 DRILL DDRL P Directional drilled 6"hole f/14,030'to 14,120'MD 6974'TVD ADT-3 hrs. ECD-12.62 ppg Footage-90' WOB 18 k RPM 135 GPM 200 @ 2460 psi String wt PU 240 SO 125 Rot 172 Torque on/off btm.-17/16 k ft/lbs 0/A 1380 psi @ 10:00 hrs 12:00 16:00 4.00 14,120 14,029 PROD1 CASING CIRC P Pull back f/14,120'to 14.029'-Circ 3 X btms up @ 215 gpm @ 2700 psi w/130 rpms w/15 k torque 16:00 16:15 0.25 14,029 14,029 PROD1 CASING OWFF P Flow ck-well static 16:15 22:00 5.75 14,029 11,358 PROD1 CASING TRIP P POOH w/pump @ 210 gpm @ 2580 psi-No rotation f/14,029'to 11,358' -PUwt210k Page 62 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 11,358 11,358 PROD1 CASING CIRC P Flow ck(static)Circ 2 X btms up @ 200 gpm w/130 rpm's @ 14 k torque to clean up 7"casing OA 1040 psi @ 2200 hrs. 12/27/2012 Flow ck well for 30 mins.(static)-Run in 1 std DP to 11,453'-Drop 2.37'drift-POOH w/pump f/11,453'to 3,246'-POOH on trip tank to 389'-Flow check static-LD BHA-Clear floor-PJSM-RU and run 4.5"Liner 00:00 00:45 0.75 11,358 11,358 PROD1 CASING OWFF P Blow down TD-Monitor well for 30 mins.-static 00:45 01:00 0.25 11,358 11,453 PROD1 CASING TRIP P RIH f/11,358'to 11,453'(116 stds in hole)dropped 2.37"drift 01:00 06:30 5.50 11,453 8,114 PROD1 CASING TRIP P POOH w/pump f/11,453'to 8,114 at 200 gpm, 1810 psi, 170K up wt( Attempt to pull on elevators) 06:30 12:00 5.50 8,114 4,773 PROD1 CASING TRIP P POOH w/pump f/8,114'to 4,773 at 3 bpm, 590 psi(Attemptet to pull on elevators at 6,205')) 12:00 13:30 1.50 4,773 3,246 PROD1 CASING TRIP P POOH w/pump f/4,773'to 3,246 at 3 bpm,570 psi 13:30 13:45 0.25 3,246 3,246 PROD1 CASING OWFF P Observe well static, blow down top drive 13:45 17:00 3.25 3,246 389 PROD1 CASING TRIP P POOH on trip tank from 3,246'to 389' 17:00 17:15 0.25 389 389 PROD1 CASING OWFF P Observe well static, PJSM on LD BHA 17:15 18:00 0.75 389 100 PROD1 CASING TRIP P POOH on trip tank from 389'to 100' racking HWDP 18:00 20:00 2.00 100 0 PROD1 CASING PULD P Lay down BHA as per Baker DD and MWD 20:00 21:00 1.00 0 0 PROD1 CASING PULD P Clean and Clear floor-LD and PU tools VIA beaver slide and otter slide 21:00 21:45 0.75 0 0 PROD1 CASING RURD P RU to run 4.5"liner 21:45 22:00 0.25 0 0 PROD1 CASING SFTY P PJSM on running 4 1/2"liner 22:00 00:00 2.00 0 319 PROD1 CASING RUNL P Ran 4 1/2"liner as follows:4 1/2" Orange peel shoe(SLHT)-(2)4 1/2" 12.6#L-80 SLHT pup jts.-(1)4 1/2" 12.6#L-80 SLHT perf pup-7 jts.4 1/2"12.6#L-80 SLHT liner to 319' 12/28/2012 Cont.to run 4 1/2'liner-RIH w/4 1/2"Hiner on 4"DP to 14090'-Set liner hanger&ZXP liner top packer- Change well over f/10.5 ppg MOBM to 10.5 ppg brine-POOH on TT f/11,000'to 10,782' 00.00 02:00 2.00 319 3,041 PROD1 CASING RUNL P Cont. running 4 1/2'liner f/319'to 3041'-ran total of 56 jts 4 1/2"12.6# L-80 SLHT liner w/8-4 1/2"SLHT 12.6#L-80 perf pumps-(2)4 1/2' 12.6#L-80 SLHT pup jts-XO(SLHT) p X Hydril 563 b-1 jt 4 1/2"12.6# L-80 Hydril 563 liner- Free Cap swell packer assembly-1 jt.4 1/2" 12.6#L-80 Hydril 563 liner-Free cap swell packer assembly-14 jts 4 1/2" 12.6#L-80 Hydril 563 liner-Baker Seal Bore assembly 02:00 03:45 1.75 3,041 3,073 PROD1 CASING RUNL P CO elevators, PU Liner Hgr/Pkr assy and MU. Mix and pour Pal mix. Let set 30 min. Page 63 of 75 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 03:45 12:00 8.25 3,073 9,565 PROD1 CASING RUNL P RIH with 4-1/2"liner on 4"DP from 3073'to 9565. 190K up, 130K dwn. 12:00 18:00 6.00 9,565 14,090 PROD1 CASING RUNL P RIH with 4-1/2"liner on 4"DP from 9565'to 14090', LD single. 235K up, 130K dwn. 18:00 18:30 0.50 14,090 14,090 PROD1 CASING OWFF P Observe well static 30 min(PJSM on fluid displacement) 18:30 19:30 1.00 14,090 14,090 PROD1 CASING RUNL P Drop ball,pump down @ 3 bpm, 900 psi,on seat at 93 bbls,set Hgr with 2900 psi,set 35k on Hgr to confirm set,pressure up to 3500 psi to release, bleed to zero, PU 5'and confirm released,slack off dogs on ZX Pkr to 100K on indicator(seen set at 110K), rotate on Pkr with 10 rpm, 12K tq 19:30 19:45 0.25 14,090 14,090 COMPZ RPCOM OTHR P Blow down TD 19:45 20:15 0.50 14,090 14,090 COMPZ RPCOM PRTS P Line up on kill line&pressure IA(4" DP x 7"csg to 1000 psi to test Z X (liner top packer(Good test) 20:15 20:45 0.50 14,090 11,000 COMPZ RPCOM TRIP P Pull up 65'to bring liner running tool above liner top @ 11,000'(liner top @ 11,016.89'-Liner shoe @ 14,090') 20:45 23:00 2.25 11,000 11,000 COMPZ RPCOM CIRC P Displace well f/10 5 ppg MOBM to 10.5 ppg completion brine as follows. pumped 46 bbls 12.0 ppg Viscosified transition spacer w/5% DEEPCLEAN followed by 34 bbls cleaning spacer w/10% DEEPCLEAN @ 10.5 ppg-followed by 43 bbls viscosified spacer @ 10.5 ppg followed by 407 bbls 10.5 ppg brine-pumped @ 4 bbls/min @ 930 psi-full returns 23:00 23:15 0.25 11,000 11,000 COMPZ RPCOM OWFF P Flow ck-well static 23:15 23:30 0.25 11,000 11,000 COMPZ RPCOM OTHR P Blow down TD&mud line back to mud pumps 23:30 00:00 0.50 11,000 10,782 COMPZ RPCOM TRIP P POOH on TT w/liner running tool& 4"DP f/11,000'to 10,782' 12/29/2012 POOH-LD running tool-MU 4.5"composite plug/7"scraper assy-RIH-Tag liner top with no-go at 11,017'- Drop ball-PU stretch+5'-Circ ball-Set and release 4.5"plug-Tag plug at 11,118'-Test plug to 2000 psi for 10 min-Dropped 3/4"ball&pump down to open circ sub 00:00 07:30 7.50 10,782 1,715 COMPZ RPCOM TRIP P Cont. POOH w/liner running tool& 4"DP on TT f/10,782'to 1715' PU wt 95k 07:30 07:45 0.25 1,715 1,715 COMPZ RPCOM OWFF P Flow ck-well static 07:45 09:00 1.25 1,715 0 COMPZ RPCOM TRIP P Cont. POOH w/liner running tool& 4"DP f/1715'-liner running tool (Calc.fill 71.3 bbls/Actual-71 5 bbls 09:00 09:15 0.25 0 0 COMPZ RPCOM PULD P LD liner running tool 09:15 10:00 0.75 0 0 COMPZ RPCOM OTHR P PJSM on making up plug setting assembly-Clean up rig floor-PU BHA components to rig floor Page 64 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 11:30 1.50 0 137 COMPZ RPCOM PULD P MU Composite plug&scraper assembly to 137' 11:30 12:00 0.50 137 610 COMPZ RPCOM TRIP P RIH w/Composite plug/scraper assembly on 4"DP f/137'to 610' 12:00 21:30 9.50 610 11,125 COMPZ RPCOM TRIP P RIH w/Composite plug/scraper assembly on 4"DP f/610'to 11,125' Tag TOL with no-go at 11,017' 21:30 22:45 1.25 11,125 11,118 COMPZ RPCOM CIRC P Drop 1/2"ball-PU stretch plus 5'to -Circ ball down at 2 bpm 450 psi- on seat at 53 bbls-Set and release 4.5"composite plug with 2800 psi- PU verify shear-SO and tag plug with 5K at 11,118' 22:45 23:15 0.50 11,118 11,118 COMPZ RPCOM PRTS P Test 4.5"composite plug to 2000 psi for 10 minutes(Good test) 23:15 00:00 0.75 11,118 11,118 COMPZ RPCOM CIRC P LD single of DP-Dropped 3/4"ball& pump down to open circ sub- pumped @ 3 bbls/min @ 500 psi 12/30/2012 Pump Hi-vis brine sweep-POOH on TT to 10,056'-Slip&cut drlg line-POOH on TT f/10056'to surface- LD scraper/running tool-MU perf assy-RIH to 8917'-Flush mud system with caustic wash -Cont. RIH f/ pert gun assembly to 10,951' 00:00 00:45 0.75 11,106 11 COMPZ RPCOM CIRC P Pumped 23 bbls viscosified brine sweep @ 10 bbls/min @ 2830 psi- stood back 1 std to 11,010'-Flow ck -well static 00.45 02:00 1.25 11,010 10,056 COMPZ RPCOM TRIP P POOH w/plug setting BHA&4"DP on TT f/11,010'to 10,056'-PU wt 230 SO wt 125(Flow ck well static )Pulled tight @ 10,492' 02:00 04 00 2.00 10,056 10,056 COMPZ RPCOM SLPC P Cut&slip drill line-Service TD- Adjust brakes 04:00 10:30 6.50 10,056 137 COMPZ RPCOM TRIP P POOH on TT f/10056'to 137'. 10:30 11:00 0.50 137 0 COMPZ RPCOM PULD P LD scraper and running tool as per Baker rep 11:00 11:15 0.25 0 0 COMPZ PERF SFTY P PJSM w/Halliburton reps on _handling perfguns 11:15 12:00 0.75 0 25 COMPZ PERF PULD P MU pert gun assy 12:00 12:15 0.25 25 25 COMPZ PERF SFTY P PJSM w/Halliburton reps on handling pert guns with new crew 12:15 13:30 1.25 25 143 COMPZ PERF PULD P MU pert gun assy as per Halliburton reps 13:30 21:00 7.50 143 8,917 COMPZ PERF TRIP P RIH with pert gun assy on 4"DP to 8917' 21:00 22:15 1.25 8,917 8,917 COMPZ PERF OTHR P Flush MP's, hole fill and kill line with caustic wash in prep for well clean-up(PJSM held at 19:30 Hrs)- Blow down kill&mud lines 22:15 00:00 1.75 8,917 10,951 COMPZ PERF TRIP P Cont. RIH w/pert gun assembly on 4' DP f/8917'to 10,951' 12/31/2012 Rih to 10,984.71'-RU HES E-line-Ran TCP correlation log-set packer-displace drillstring to seawater- perform negative test on plug and liner top-Attempt to open Omni valve with no success-Consult town- Decision made to POOH-Release packer-Reverse circ out seawater with 10.5 brine-POOH 00:00 01:30 1.50 10,951 10,984 COMPZ PERF TRIP P Position guns w/pups f/10951'to 10984'for wireline Page 65 of 75 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 01:30 02:30 1.00 10,984 10,984 COMPZ PERF RURD P PJSM with Halliburton, RU E-line 02:30 04:30 2.00 10,984 10,984 COMPZ PERF ELOG P RIH w/E-line,perform gamma ray log and correlate depth, POOH with wireline 04:30 05:00 0.50 10,984 10,984 COMPZ PERF RURD P RD E-line 05:00 05:30 0.50 10,984 10,975 COMPZ PERF TRIP P C/O pup its,MU TIW valve and single,position string at 10975' 05:30 06:00 0.50 10,975 10,975 COMPZ PERF OTHR P Set packer with 6 wraps and 25K down.Close bag,pressure up to 500 psi on annulus,pull up to open packer bypass,pressure drop to 0 psi 06:00 07:30 1.50 10,975 10,975 COMPZ PERF CIRC P Flush lines with seawater,pump 106 bbls seawater(String vol)to packer bypass at 1.9 bpm,850 psi. 8.5 ppg in DP, 10.5 ppg in annulus. Pump off,700 psi differential pressure. Slack off and close bypass valve. 07:30 08:15 0.75 10,975 10,975 COMPZ PERF CIRC P RU and bleed back pressure in 200 psi increments to 0 psi. 08:15 10:45 2.50 10,975 10,975 COMPZ PERF OWFF P Perform negative test on plug and liner top,monitor well static while clean shakers/pits and surface equipment 10:45 11:15 0.50 10,975 10,975 COMPZ PERF SFTY P PJSM on fluid displacement 11:15 13:15 2.00 10,975 10,975 COMPZ PERF OTHR P Pressure up DP to 600 psi,close top pipe rams,attempt to function Omni valve open by applying 1500 psi to annulus and bleeding off 8 times,did not open,attempt to open again using 1800 psi 7 times, unsuccessful 13:15 14:00 0.75 10,975 10,975 COMPZ PERF OTHR P Consult town,decision made to POOH and LD perf assy 14:00 14:15 0.25 10,975 10,975 COMPZ PERF RURD T Release packer,225K up, 130K dwn 14:15 14:30 0.25 10,975 10,975 COMPZ PERF RURD T Blow down TD, LD single 14:30 14:45 0.25 10,975 10,975 COMPZ PERF RURD T RU to reverse circulate 14:45 15:30 0.75 10,975 10,975 COMPZ PERF RURD T Bring 10.5 ppg brine into pits 15:30 16:45 1.25 10,975 10,975 COMPZ PERF CIRC T Reverse circulate out seawater with 10.5 ppg brine at 2 bpm 150 psi (pumped 134 bbls 10.5 ppg brine) 16:45 17:00 0.25 10,975 10,975 COMPZ PERF RURD T RD hose, headpin. Blow down kill line, hose and manifold,flow check, static 17:00 17:15 0.25 10,975 10,925 COMPZ PERF TRIP T LD single and pup jts 17:15 00:00 6.75 10,925 4,336 COMPZ PERF TRIP T POOH on trip tank f/10,925'to 4336' 01/01/2013 Cont. POOH on TT w/pert gun assembly-LD perfs gun assembly-MU mule shoe&RIH on 4"DP to 11,006' -Circ-PJSM and pump pills: hi vis,caustic wash,seawater,surfactant and hi vis-Pump seawater at 6 bbls/min @ 950 psi(pumped 2454 bbls) lowest turbidity seen w/seawater 139 NTU's-Load pits w/filtered 9.5 ppg 6%KCUNaCI brine-Displaced seawater f/well w/filtered 9.5 ppg 6%KCINaCL brine @ 8 bbls/min @ 1330 psi w/80 rpm's-Final turbidity reading 52 NTU's-POOH f/11,006'to 10,401' Page 66 of 75 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 03:00 3.00 4,336 141 COMPZ PERF TRIP T Cont. POOH on TT w/perf gun assembly f/4336'to 141'-Flow ck- well static-Calc fill 69.1 bbls- Actual 78 bbls 03:00 04:00 1.00 141 0 COMPZ PERF PULD T PJSM on laying down pert gun assembly-LD pert gun assembly as per Halliburton Rep. 04:00 09:15 5.25 0 11,006 COMPZ PERF TRIP T MU mule shoe&XO-RIH on 4"DP to 11016'.250K up, 127K dwn 09:15 10:00 0.75 11,006 11,006 COMPZ PERF CIRC T Circulate and prep seawater line/pits for displacement.8 bpm, 1560 psi, 30 rpm, 16K tq 10:00 12:00 2.00 11,006 11,006 COMPZ PERF CIRC T PJSM,pump load/pills consisting of 37.6 bbls fresh water high vis pill, 64.7 bbls caustic wash,39.8 bbls seawater, 57.8 bbls surfactant and 34.9 bbls high vis pill at 5 bpm, 1200 psi, 120 rpm, 15K tq 12:00 18:45 6.75 11,006 11,006 COMPZ PERF CIRC T Pump 2454 bbls seawater at 6 bpm (header supply rate),950 psi, 120- 90 RPM, 14.5-17.5K tq. FCP 880 psi No gain/No loss while pumping- final NTU- 18:45 22:00 3.25 11,006 11,006 COMPZ PERF OWFF T Blow down TD-Monitor well(static) while loading 9.5 ppg brine in pits 22:00 23:00 1.00 11,006 11,006 COMPZ PERF CIRC T Displace 8.5 ppg sea water w/ filtered 9.5 ppg 6%KCUNaCI brine @ 8 bbls/min @ 1330 psi w/80 rpm's w/16 k torque-FCP 1650 psi -Final turbidity 52 NTU's 23:00 23:15 0.25 11,006 11,006 COMPZ PERF OWFF T Blow down TD-Flow ck static 23:15 00:00 0.75 11,006 10,401 COMPZ PERF TRIP T POOH on TT f/11,006'to 10,401' 01/02/2013 Cont. POOH on TT f/10,401'-LD mule shoe-MU pert gun assembly to 120.79'-RIH w/PG assembly on 4" DP-Set string in tension w/tail @ 10,985'-RU&run correlatioin log-Set gun on depth-RU displace drill string w/diiesel to packer by-pass valve(104 bbls) 00:00 04:45 4.75 10,401 0 COMPZ PERF TRIP T Cont. POOH on TT f/10401'-LD mule shoe&XO(flow ck well static) Calc.fill 71.3 bbls-Actual 71 bbls 04:45 05:30 0.75 0 120 COMPZ PERF PULD T PJSM on making up Perf gun assembly-MU assembly as per Halliburton Rep.to 120' 05:30 12:00 6.50 120 6,416 COMPZ PERF TRIP T RIH w/pert assembly f/120'to 6416' -PUwt170 SOwt115 12:00 16:30 4.50 6,416 10,898 COMPZ PERF TRIP T Cont RIH w/pert gun assembly on 4"DP f/6416'to 10,898' 16:30 17:15 0.75 10,989 10,985 COMPZ PERF TRIP T PU 2 singles DP-(2)10'pup jts set string in tension w/tail of pert assembly @ 10,985' 17:15 18:15 1.00 10,985 10,985 COMPZ PERF ELOG T PJSM w/Halliburton on rigging up wireline 18:15 20:15 2.00 10,985 10,985 COMPZ PERF ELOG T RIH w/GR&CCL-correlate deth for perf gun placement-POOH w/ wireline-RD Halliburton Page 67 of 75 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 20:15 21:00 0.75 10,985 10,875 COMPZ PERF OTHR P Remove bell guide-PU 11'to get pelf guns on depth-LD 10'pup-MU 5'pup TIW valve&5'pup-MU TD to string-Set packer(5 turns to right w/string)slack off w/30 k to confirm packer set 21:00 22:00 1.00 10,875 10,875 COMPZ PERF RURD P MU head pin&5'pup-Close annular -Pressure up annulus to 500 psi- PU to open packer by-pass valve 22:00 22:30 0.50 10,875 10,875 COMPZ PERF CIRC P Obtain slow pupm rates @ 1,2,&3 bbls/min 22:30 23:00 0.50 10,875 10,875 COMPZ PERF SFTY P PJSM on displacing drill string w/ diesel&perfing 23:00 23:15 0.25 10,875 10,875 COMPZ PERF PRTS P Pressure test lines w/Dowell to 4000 psi 23:15 00:00 0.75 10,875 10,875 COMPZ PERF CIRC P Displace drill pipe to diesel to packer by pass valv @ 3.2 bbls/min ICp 550 FCP 1360 psi 01/03/2013 Slack off wt to 95 k to shut by-pass valve-Bleed drill pipe&observed well for Neg test on plug/liner packer w/diesel-Pressure up to fire guns-DPP 860 psi-Flow back 10 bbls to tank-Shut in-close Hydril-open by pass valve-Reverse circ&kill well w/9.5 ppg brine-Shut down monitor well(static)-unset packer and CBU-Observe well static-Slip and cut drilling line-POOH on TT f/to 7559'- 1 bbl behind on fill-Observe well static 55 min-RIH to 10,925' with good displacement- Flow check some gas breaking out-CBU- observed gas breaking out-Weight up from 9.5 to 9.9 ppg-Flow check static-POOH on TT 00:00 00:30 0.50 10,975 10,975 COMPZ PERF OTHR P Slack off string wt to 95 k to shut by pass valve-950 psi on DP-Bleed down DP to 0 psi in 250 psi stages- moniior well for 10 mins for Neg.test on plug&liner top packer w/diesel 00:30 00:45 0.25 10,975 10,975 COMPZ PERF SFTY P Held PJSM w/new crew on perfing& well kill Ops. 00:45 01:00 0.25 10,975 10,975 COMPZ PERF OTHR P Pressure up on drill pipe w/Dowell to 3500 psi-Bleed off drill pipe to tiger tank&shut in-Observed guns fired w/6 min delay-monitor DP pressure 850 psi 01:00 01:30 0.50 10,975 10,975 COMPZ PERF OTHR P Open well&flow back 10 bbls to tiger tank through choke house- Shut in well-Close annular preventer -pick up to open packer bypass valve 01:30 03:00 1.50 10,975 10,975 COMPZ PERF CIRC P Reverse circulate and displace diesel from drill pipe(106 bbls)-followed back pressure schedule @ 2 bpm- total of 164 bbls of 9.5 ppg brine pumped 03:00 03:15 0.25 10,975 10,975 COMPZ PERF OWFF P Shut in and monitor pressures-zero psi on DP and Csg.for 15 minutes 03:15 03:45 0.50 10,975 10,975 COMPZ PERF OTHR P Open Annular preventer-observed well,static-Blow down lines to Tiger tank 03:45 04:00 0.25 10,975 10,975 COMPZ PERF OTHR P Unset packer-RD head pin and lines 04:00 05:15 1.25 10,975 10,975 COMPZ PERF CIRC P MU top drive-CBU @ 4 bpm/520 psi-9.5 ppg In&Out. 05:15 05:30 0.25 10,975 10,975 COMPZ PERF OWFF P Monitor well-fluid level in annulus dropped 1"in 15 minutes Page 68 of 75 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 05:30 06:00 0.50 10,975 10,898 COMPZ PERF PULD P POOH to 10,898'-Laid down two joints of DP& 1 pup jt. 06:00 08:00 2.00 10,898 10,898 COMPZ RIGMNT SLPC P Slip and cut drilling line-service Top Drive-adjust Drawworks brakes Monitor well on trip tank-lost 0.5 bbls in two hours 08.00 11:00 3.00 10,898 7,559 COMPZ PERF TRIP P POOH from 10,898'to 7559'-five stand hole fill volumes at 3.0 bbls- calculated 3.1 bbls/5 stands-35 stands calculated 21.7 bbls/actual 20.6 bbls 11:00 12:00 1.00 7,559 7,559 COMPZ PERF OWFF P Monitor well for thirty minutes static- contacted engineering support and discussed well statis and observations-over balance calculations-concluded return to bottom and evaluate as plan forward- well static after 50 minutes-some gas breaking out of annulus 12:00 14:00 2.00 7,559 10,925 COMPZ PERF TRIP T RIH from 7559'to 10,925' Monitor trip tank closely -Calc. displacement=21.7 bbls.-Actual disp.20.5 bbls 14:00 15:45 1.75 10,925 10,925 COMPZ PERF CIRC T Flow check,some gas breaking out, Circulate at 4 bpm,450 psi. Observed gas breaking out,begin weight up to 9.9 ppg 15:45 16:00 0.25 10,925 11,012 COMPZ PERF TRIP T RIH 87'from 10,925'to 11,012'tail depth, 10955'circ port depth. 16:00 18:00 2.00 11,012 11,012 COMPZ PERF CIRC T Continue weight up from 9.5 ppg to 9.9 ppg circulating at 5 bpm,660 psi 18:00 18:45 0.75 11,012 11,012 COMPZ PERF OWFF T Observe well static 42 min, Blow down TD, LD single 18:45 00:00 5.25 11,012 5,842 COMPZ PERF TRIP P POOH on TT f/10994'to 5842'-Hole taking proper fill 01/04/2013 Pooh w/perf gun assembly f/5842'to 211' -Flow ck-slight drop in fluid level-LD perf assy-flow check static-Test BOPE witnessed by AOGCC Bob Noble-RD/Blow down-Found line froze up-Re-test choke manifold-MU scraper assembly&RIH to 2798' 00:00 04:30 4.50 5,842 211 COMPZ PERF 'TRIP P Cont. POOH on TT w/pert gun assembly f/5842'to 211' -Hole took proper fill 04:30 04:45 0.25 211 211 COMPZ PERF OWFF P Observed well-slight drop in fluid level-Calc.fill 70.68 bbls. Actual fill 72.5 bbls 04:45 05:30 0.75 211 0 COMPZ PERF PULD P PJSM,Std back stand and LD pert assy as per Halliburton reps,all shots fired 05:30 06:00 0.50 0 0 COMPZ PERF PULD P Clear floor, LD mud bucket 06:00 06:30 0.50 0 0 COMPZ WHDBO RURD P Pull wear ring and install test plug 06:30 07:30 1.00 0 0 COMPZ WHDBO RURD P RU to test BOPE,fill lines, RU hole fill line Page 69 of 75 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 07:30 17:15 9.75 0 0 COMPZ WHDBO BOPE P Tested BOPE as follows:w/5"test jt.tested Annular to 250&2500 psi- Tested upper 4-1/2"x 7"pipe rams, TD IBOP's,5"and 4"Floor safety& dart valves,Choke&kill line valves, Choke manifold valves# 1,2,3,4,5,6,7,8,9,10,11,12,13,14,15, &16 and needle valve to 250&3500 psi-HCR choke and Kill-4"Demco on kill line-manual kill&choke valves-Lower 2-7/8"x 5"pipe rams to 250&3500 psi-Performed accumulator recovery test,3000 psi start, 1450 psi end,23 sec to 200 psi, 178 sec to 3000 psi,Tested Blind rams 250/3500 psi-Tested gas alarms-With the 3-1/2"and 4-1/2"test joint tested annular, 250 PSI low/2500 PSI high, upper and lower variable pipe rams 250 PSI low/ 3500 PSI high.Annulus open and monitored during test.All tests charted, 5 min/test. Bob Noble (AOGCC)witnessed tests. 17:15 17:30 0.25 0 0 COMPZ WHDBO RURD P Drain stack, pull test plug, blow down,discovered ice plug in choke line to gas buster 17:30 18:15 0.75 0 0 COMPZ WHDBO RURD T Thaw choke line to gas buster and check heat trace 18:15 18:45 0.50 0 0 COMPZ WHDBO RURD T RU to re-test choke manifold 18:45 20:00 1.25 0 0 COMPZ WHDBO BOPE T Re-test manual choke, HCR choke, Manifold valves#1,5,and 16 to 250/3500 psi for 5 min --Witness of re-test waived by Bob Noble 20:00 20:30 0.50 0 0 COMPZ WHDBO RURD T Pull test plug,set wear ring 20:30 22:00 1.50 0 131 COMPZ PERF PULD P PJSM,MU Baker scraper assy to 131'. (SIMOPS,continue test choke manifold valves#2 thru 6 and#7 thru 15 to 250/3500 psi for 5 min) 22:00 00:00 2.00 131 2,798 COMPZ PERF TRIP P RIH w/Baker scraper assembly f/ 130'to 2798' 01/05/2013 Cont. RIH w/scraper assembly f/2798'to 11,009' -wash down to 11,082'mule shoe depth-tagged top of liner @ 11,015.5' -Circ 2 X btms up working scraper across pefrs-Observed gas break out @ surface-wt up brine to 10.1 ppg-POOH w/pump f/11,082'to 6043' 00:00 08:00 8.00 2,798 11,009 COMPZ PERF TRIP P RIH w/scraper assembly f/2798'to 11,009'-slowed running speed from 7000'due to fluid running over drill pipe-PUW 245K SOW 130K Calculated steel disp.70.7 bbl/ Actual disp. =57 bbls.-Observe well-gas breaking out in annuls- fluid level dropping slowly 08:00 08:30 0.50 11,009 11,082 COMPZ PERF CIRC P Wash down w/3 bpm/370 psi from 11,009'to 11,082'-tagged TOL with no go@11015.5' Page 70 of 75 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 08:30 11:30 3.00 11,082 11,082 COMPZ PERF CIRC P CBU @ 4 bpm/540 psi-observed gas breaking out at bell nipple throughout BU+50 bbls- reciprocated scraper across perfs while circulating-increased pump rate to 5 bpm/860 psi-circulate and increase brine wt.to 10.1 ppg (saturated) 11:30 12:30 1.00 11,082 11,082 COMPZ PERF OWFF P Shut down pumps and flow check well,observed fluid level dropping slowly-no gas -Blow down top drive-monitor well for 30 minutes- fluid level dropped—1 bbl-pumps off 55 minutes total 12:30 15:15 2.75 11,082 11,082 COMPZ',PERF CIRC P Circulate BU @ 5 bpm/880 psi-no gas observed through BU.-Circulate and condition brine-confer with Developement Team on plan forward 15:15 00:00 8.75 11,082 6,043 COMPZ PERF TRIP P Flow ck-(static)-POOH w/pump @ 4 bbls/min f/11082'to 6043'-PU wt 160 SO wt. 118 w/pump 01/06/2013 Cont. POOH w/pump f/6043'to 5280'-Flow ck(static)POOH on TT f/5280'-Flow ck(static)-POOH on TT to 222'-Flow ck(static)-LD scraper BHA-Clear floor-Pull wear ring-PU tbg equip-RU-PJSM, Run 3-1/2"tubing completion to 5,500' 00:00 01:15 1.25 6,043 5,280 COMPZ PERF TRIP P Pump OOH f/6043'to 5280'at 4 bpm, 340 psi 01:15 01:30 0.25 5,280 5,280 COMPZ PERF OWFF P Blow down TD,flow check static 01:30 07:00 5.50 5,280 222 COMPZ PERF TRIP P POOH on trip tank f/5280'to 222'. Calc fill=70.6 bbls, actual fill=97 bbls 07:00 07:15 0.25 222 131 COMPZ PERF OWFF P Flow check static, rack last std DP 07:15 08:30 1.25 131 0 COMPZ PERF PULD P LD scraper BHA as per Baker 08:30 09:00 0.50 0 0 COMPZ PERF PULD P Clean and clear floor 09:00 09:15 0.25 0 0 COMPZ WHDBO PULL P PJSM,pull wear ring 09:15 11:00 1.75 0 0 COMPZ RPCOM RURD P PU control line spools,Tbg equip and RU to run tubing 11:00 12:00 1.00 0 111 COMPZ RPCOM RCST P Ran 3 1/2"9 3#L-80 EUE 8rd completion as follows: Baker seal assembly w/3 1/2"pup jt-HES 2.813"X nipple-1 jt 3 1/2"9.3#L-80 EUE 8rd tbg-1 jt 3 1/2"9.3#L-80 Hyd 563 with 25'of 4.09"blast rings and XO's to 3 1/2"EUE Page 71 of 75 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 12:00 00:00 12.00 '111 5,500 COMPZ RPCOM'RCST P Ran 4 jts 3 1/2"9.3#L-80 EUE 8rd tbg-Baker 3 1/2"CMD sliding sleeve w/pups-1 jt 3 1/2"9.3#L-80 EUE 8rd tbg-Camco KBMG GLM w/DV, BK-5 latch w/pups-Baker 3.5"x 7"Premier packer w/pups- SLB Gauge Mandrel NDPG w/pups w/I-wire-6 jts 3 1/2"9.3#L-80 EUE 8rd tbg-Camco KBMG GLM w/ DCK-2 SOV w/pups- 62 jts 3 1/2" 9.3#L-80 EUE 8rd tbg- Camco KBMG GLM w/DV, BK-5 latch w/ pups-100 jts 3 1/2"9.3#L-80 EUE 8rd tbg-to 5500'----Test I-wire every 30 jts ok--Flow check at 4616', static and calm 01/07/2013 Run 3-1/2"tubing completion to 8,546'-Repair hydraulic leak under rig floor-Run 3-1/2"tubing completion to 8,923'-Flow ckeck static-MU SSSV control line and test ok-Run 3-1/2"tubing completion to 10,990'-flow check static-CBU-Flow check-RIH-locate seals and and no-go-attempt pressure test seals-bleeding off-consult with town engineers-Monitor tbg and annulus with seals engaged-no losses to annulus-losing 1 to 1.5 bph down tubing-LD 2 Jts Tbg-CBU-small amount of gas back-MU jt and RIH 14'to TOL 00:00 04:30 4.50 5,500 8,546 COMPZ RPCOM RCST P Continue running 3 1/2 completion equipment-Ran 26 jts 3 1/2"9.3# L-80 EUE 8rd tbg-Camco KBMG GLM w/DV- 62 jts 3 1/2"9.3#L-80 EUE 8rd tbg to 8546'-Install Cannon clamps on each joint 04:30 05:00 0.50 8,546 8,546 COMPZ RIGMNT SVRG P Service Rig 05:00 06:00 1.00 8,546 8,546 COMPZ RIGMNT RGRP T Welder repaired 2"hydraulic line leak under the rig floor-clean up 1/2 gallon of oil from secondary containment 06:00 07:00 1.00 8,546 8,923 COMPZ RPCOM RCST P Ran 12 jts 3 1/2"9 3#L-80 EUE 8rd tbg-3 1/2"TRMAXX-5E SSSV w/ pups to 8923'-flow check well, static, calm-Install Cannon clamps on each joint 07:00 07:30 0.50 8,923 8,923 COMPZ RPCOM OTHR P MU 1/4"SS tubing to SSSV- pressure test line and valve to 5000 psi for 15 minutes 07:30 11:45 4.25 8,923 10,990 COMPZ RPCOM RCST P Ran 65 jts 3 1/2"9 3#L-80 EUE 8rd tbg to 10,990'-Install Cannon clamps on each joint-Test I-wire every 30 jts ok 11:45 12:00 0.25 10,990 10,990 COMPZ RPCOM OWFF P Flow check static 12:00 14:15 2.25 10,990 10,990 COMPZ RPCOM CIRC P Circulate at 3 bpm,300 psi.Seen some gas 80 bbls before BU and cleaned up 40 bbls after. Flow check ok Page 72 of 75 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 14:15 16:00 1.75 10,990 11,054 COMPZ RPCOM TRIP P MU Jt#342, RIH to 11021', RU XO/TIW/Pup to Jt#343, MU TD, wash down at 1 bpm,50 psi, saw pressure increase at 11041.9', pump off and cont slack off and locate on no go at 11059'tail depth, both depths 8.5 high, PU to tension at 11054',attempt to test seals to 500 psi,bleeding off, RD TD and RU headpin,attempt test seals again, bleeding off. 16:00 18:00 . 2.00 11,054 11,054 COMPZ RPCOM OWFF T Consult town engineers 18:00 20.45 2.75 11,054 11,054 COMPZ RPCOM OWFF T Appears once seals stung in, no longer have losses in annulus. Remove headpin,observe losses down pipe,gauge at approx 1.5 bbl/hr. 20:45 21:15 0.50 11,054 11,054 COMPZ RPCOM TRIP P LD 2 jts 3-1/2"tubing to 10991' 21:15 23:15 2.00 11,054 11,054 COMPZ RPCOM CIRC P RU and CBU plus 30 bbls at 3 bpm, 320 psi. Seen little gas 23:15 00:00 0.75 11,054 11,008 COMPZ RPCOM RURD P PJSM,blow down circ hose, RD headpin,CO elevators, MU XO,TIW, DP pup to jt tubing, RIH to 11008' 01/08/2013 Spot 10.1 ppg inhibited brine. Make up space out pup.Make up hanger and terminate control lines.Test to 5000. Land tubing. Halliburton slick line run X plug to 10809'MD. Pressure tubing up to 4000 PSI. Set packer. Test annulus to 3500 psi.Shear out DCK-2 valve. Install and test TWC. Monitor annulus for 30 mins.Static. Nipple down BOPE. Nipple up tree. 00:00 00:45 0.75 11,008 11,008 COMPZ RPCOM CIRC P PJSM-From 11008'(tbg. measurement adj.TOL)Pumped 29.5 bbls of 10.1 ppg corrosion inhibited brine-displaced 25 bbls into annulus 00:45 01:30 0.75 11,008 10,928 COMPZ RPCOM PULD P Flow check well,static-Laid down 1 jt.tbg.-B/O crossovers and pup jt.- change elevators to 3 1/2"-laid down 3 jts.of 3 1/2"(339 jts.total in hole) 01:30 02:15 0.75 10,928 11,020 COMPZ RPCOM RCST P MU 8.14'3 1/2"pup-change elevators to 4 1/2"-MU 3 1/2"eue x 4 1/2"IBTm xo-2 joints of 4 1/2" IBTm tubing-MU FMC hanger w/ 2.31'pup 02:15 03:30 1.25 11,020 11,020 COMPZ RPCOM OTHR P Strip I-wire and sssv control line through hanger-RU and test tie back fittings to 5000 psi for 10 minutes,good 03:30 04:15 0.75 11,020 11,056 COMPZ RPCOM OTHR P Drain stack-Land tubing hanger into wellhead-RILDS 04:15 07:00 2.75 11,056 11,056 COMPZ RPCOM SLKL T PJSM-RU HES Slickline unit to rig floor-Thread slickline through packoff components,xo subs, pump in sub, to 4 1/2"IBTm-MU tool string Page 73 of 75 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 10:15 3.25 11,056 11,056 COMPZ RPCOM SLKL T RIH with 2.81"X lock w/equalizing end cap(XX Plug)-locate and set plug in CMD x profile @ 10,812' (SLM)-POOH with slickline 10:15 10:45 0.50 11,056 11,056 COMPZ RPCOM PRTS T RU and test tubing/plug to 500 psi for 10 minutes,good 10:45 11:15 0.50 11,056 11,056 COMPZ RPCOM RURD T PJSM-RD HES slickline-remove HES equipment from rig floor 11:15 12:00 0.75 11,056 11,056 COMPZ RPCOM RURD T LD mousehole-RU circulating manifold and lines 12:00 12:30 0.50 11,056 11,056 COMPZ RPCOM RURD T Continue to rig up squeeze manifold. 12:30 13:00 0.50 11,056 11,056 COMPZ RPCOM SFTY T PJSM. Pressure testing line and setting the downhole packer. 13:00 13:15 0.25 11,056 11,056 COMPZ RPCOM PRTS T Pressure test lines to 4500 W/ Dowell SLB. 13:15 15:15 2.00 11,056 11,056 COMPZ RPCOM PRTS T Pressure tubing to 4000 PSI to set packer. Bleed tubing to 2200 PSI. Pressure up annulus to 3500 PSI, bleed tubing to shear DCK-2 valve. Observe shear take place with 500 PSI on tubing. 15:15 16:15 1.00 11,056 0 COMPZ RPCOM RURD T PJSM. Lay down landing joint, install two way check. 16:15 16:45 0.50 0 0 COMPZ RPCOM PRTS P Dowell cement unit pressure test 3000 PSI,down annulus to test TWC. 10 MINS.Good. 16:45 17:15 0.50 0 0 COMPZ RPCOM OWFF P Observe well. Static. 17:15 21:45 4.50 0 0 COMPZ RPCOM NUND P PJSM. FMC/Camco SLB. Nipple down BOPE.Terminate the control line. 21:45 00:00 2.25 0 0 COMPZ RPCOM NUND P Nipple up production tree.SIMOPS: Change out saver sub from 4"to 5". 01/09/2013 Nipple up production tree.Test adapter flange to 5000 PSI. Freeze protect wellbore. Displace 78 barrels of diesel into annulus,take returns up tubing into trip tank. Install BPV. Secure well. Begin to lay down drill pipe out of the derrick. SIMOPS,clean pits,prepare to move rig slot to slot. 00:00 02:00 2.00 0 0 COMPZ WHDBO NUND P PJSM. Nipple up tree with sweeney wrench.Test hanger seals.250 PSI 5 mins.5000 PSI 10 mins.Verified by CoMan. 02:00 03:15 1.25 0 0 COMPZ WHDBO NUND P Fill tree with diesel. Make up FMC lubricator. 03:15 04:00 0.75 0 0 COMPZ WHDBO PRTS P Test lubricator and adapter flange to 250 PSI low 5 mins, 5000 PSI high, charted for 10 mins.Good. 04:00 04:45 0.75 0 0 COMPZ WHDBO PULL P Pull the two way check, and rig down lubricator. 04:45 05:15 0.50 0 0 COMPZ WHDBO RURD P PJSM. Rig up hard lines to displace diesel. Page 74 of 75 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 05:15 08:00 2.75 0 0 COMPZ WHDBO FRZP P PJSM. Perform freeze protection with Dowell SLB cement unit. Pressure test lines to 2000 PSI.good. Pump 78 barrels diesel @ 3 BPM. 1950 PSI.06:35 allow to U-Tube from tubing and annulus. Initial pressure on both sides=350 PSI.After fluid was stabilized,zero pressure both sides. Flush and blow down all lines. Rig down squeeze manifold and lines. 08:00 09:15 1.25 0 0 COMPZ WHDBO DHEQ P Install FMC lubricator.Test to 1000 PSI. Install PBV. Rig down FMC lubricator. 09:15 10:00 0.75 0 0 COMPZ WHDBO RURD P Secure well. Clear rig floor of misc. tools and equipment. 10:00 10:30 0.50 0 0 COMPZ MOVE DMOB P PJSM. Laying down drill pipe via the mouse hole. Install mouse hole,and 4"elevators. 10:30 17:00 6.50 0 0 COMPZ MOVE PULD P Lay down 4"drill pipe via the mouse hole. 17:00 17:30 0.50 0 0 COMPZ MOVE SVRG P Service rig. Draw works,iron roughneck,top drive. 17:30 00:00 6.50 0 0 COMPZ MOVE PULD P Lay down 4"drill pipe via the mouse hole. 01/10/2013 Complete laying down the 4"drill pipe. Remove iron roughneck from tracks,clear rig floor of 4"handling equipment. Clean under rig floor around rotary table. Prepare to move ri•. 00:00 04:15 4.25 0 0 COMPZ MOVE RURD P Lay down 4"DP via the mouse hole into the pipeshed.43 stands. Derrick clear. 04:15 05:00 0.75 0 0 COMPZ MOVE RURD P PJSM. Remove iron roughneck from tracks.Clear floor of 4"handling equipment. 05:00 08:00 3.00 0 0 COMPZ MOVE RURD P Clean under rig floor to allow the rotary table locking mechanism to engage. Page75of75 e2!- i-7- Cement Detail Report CDI-47 cor,ocoPhilhps String: Conductor Cement Job: DRILLING ORIGINAL, 10/31/2012 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 4/26/2003 08:00 4/27/2003 08:00 CD1-47 Comment Cemented 16"conductor w/conductor cement(88 bbls)w/ready mix truck pouring cement from surface down casing by hole annulus Cement Stages Stage*1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Conductor Cement 42.0 114.0 No 88.0 No No Q Pump hilt(bbl/m...12 Pump Final(bbl/...0 Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(pal) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'Isack) Mix H2O Ratio(gallsa... Free Water(%) Density(Iblgal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 7/10/2014 col - 4 F • : r 2.12-0 g 3 r, Cement Detail Report CD1-47 ConocoPhil lips String: Surface Casing Cement Job: DRILLING ORIGINAL, 10/31/2012 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 11/5/2012 14:45 11/5/2012 17:15 CD1.47 Comment Pump 101 bbls nut plug spacer,35.5 bbls biozan nut plug marker,swap t/dowel!,5 bbls H2O,PT lines t/3000 psi,Drop bottom wiper plug,52 bbls 10.5 ppg mud push,312 bbls 10.7 ppg lead cement,53.9 bbls 15.8 ppg tail cement,Drop top plug,20 bbls of H2O,Rig displace w/216.6 bbis WBM 9.8 ppg,bump plug, Pressure up 1/1150 psi 500 psi over FCP,bleed off check floats,floats held.CIP @ 1715 hrs.Total of 125 bbls cement to surface.Recip pipe 15'stroke until after cement returns to surface. Cement Stages Stage*1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement..Top Plug? Btm Plug? Surface Casing Cement 40.0 2,670.2 Yes 125.0 Yes Yes Q Pump Unit(bbUm...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 3 8 650.0 1,150.0 Yes 15.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(In) 2,582.0 Drill Bit 10 5/8 Comment Pump 101 bbis nut plug spacer,35.5 bbls biozan nut plug marker,swap U dowel!,5 bbls H2O,PT lines U 3000 psi,Drop bottom wiper plug,52 bbis 10.5 ppg mud push,312 bbls 10.7 ppg lead cement,53.9 bbls 15.8 ppg tail cement,Drop top plug,20 bbls of H2O,Rig displace w/216.6 bbls WBM 9.8 ppg,bump plug, Pressure up 1/1150 psi 500 psi over FCP,bleed off check floats,floats held.CIP©1715 hrs.Total of 125 bbls cement to surface. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud-Nut plug Spacer 101.0 Yield(fNlsack) Mix H2O Ratio(gaUsa... Free Water(%) Density(ib/gal) Plastic Viscosity(Paas) Thickening Time(hr) CmprStr 1(psi) 10.00 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Eat Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Biozan spacer-w/nut 35.5 plug Yield(ft'/sack) Mix H2O Ratio(gallsa... Fres Water(%) Density(Ib/gal) Plastic Viscosity(Pains) Thickening Time(hr) CmprStr 1(psi) 10.00 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push 50.0 Yield(Wisack) Mix H2O Ratio(gailss... Free Water(%) Density(Ib/gal) Plastic Viscosity(Paas) Thickening Time(hr) CmprStr 1(psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead 40.0 2,031.9 717 ASL 313.0 Yield(ft/sack) Mix H2O Ratio(galha... Free Water(%) Density(Iblgal) Plastic Viscosity(Paas) Thickening Time(hr) CmprStr 1(psi) 2.45 11.51 10.70 6.00 Additives Additive Type Concentration Conc Unit label B809 ASlite III Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbi) Tail 2,031.9 2,670.0 260 Alp Tail 53.9 Yield(Wised() Mix H2O Ratio(gaUsa... Free Water(%) Density(ib/gal) Plastic Viscosity(Paas) Thickening Time(hr) CmprStr 1(psi) 1.17 5.13 15.80 4.25 Additives Additive Type Concentration Conc Unit label S002 Accelerator 0.8 %BWOC Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Page 112 Report Printed: 7/10/2014 Cement Detail Report 0/tel ,, CD1-47 ConocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL,10/31/2012 00:00 Additives Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Page 2/2 Report Printed: 7/10/2014 CPI--lc? `{'' Cement Detail Report 2,12 - 3 CD1-47 ConocoPhillips String: Intermediate#1 Casing Cement Job: DRILLING ORIGINAL, 10/31/2012 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate*1 Casing Cement 11/23/2012 21:50 11/24/2012 01:30 CD1-47 Comment Begin Cement job.Pump 1.5 BBLS CW100.Pressure test lines to 4000 PSI.Good.Pump 28.5 BBLS CW100 @ 4 BPM/440 PSI.Pump 48 BBLS 11.5 PPG Mud push©4.5 BPM/450 PSI.Pump 266 BBLS 12.2 PPG Lead cement @ 4.5 BPM/ICP=285 PSU FCP=90 PSI.Pump 85 BBLS 15.8 PPG Tail cement @ 4.8 BPM/ICP=90 PSI/FCP=150 PSI.Drop Dart.Pump 20 BBLS water.Pump 631.2 BBLS of 10.5 PPG mud with rig pump @ 7 BPM ICP=390/7 BPM FCP=1110 PSI,slow pump to 3 BPM bump plug with 730 PSI.(Calculated BBLS to bump=652.15) Bring pump pressure to 3500 PSI.Set hanger.Release from hanger, floats held.Well static.Circulate BU.No cement or mud push seen on surface. Cement Stages Stage*1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) -Full Retum? Vol Cement..Top Plug? Btm Plug? Intermediate*1 Casing Bring cement to 500' 5,187.0 10,758.0 No 0.0 Yes Yes Cement above Quannik Q Pump mit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 5 4 150.0 780.0 Yes 30.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbi) Mud Push II 48.0 Yield(fN/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Iblgal) Plastic Viscosity(Pas) Thickening Time(hr) CmprStr 1(psi) 11.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbi) CW100 30.0 Yield(fP/sack) Mix H2O Ratio(gallsa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa's) Thickening Time(hr) CmprStr 1(psi) 8.34 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Alpine intermediate 649 G 266.0 Lead Yield(fNlsack) Mix H2O Ratio(gallss... Free Water(%) Density(iblgal) Plastic Viscosity(Pas) Thickening Time(hr) CmprStr 1(pal) 2.30 13.55 12.20 0.0 4.90 Additives Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Cone Unit label D079 Extender 3.0 %BWOC Additive Type Concentration Conc Unit label D110 Retarder 0.35 gaUsx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Alpine intermediate 411 G 85.0 Tail Yield(ft'Isack) Mix H2O Ratio(gal/ss... Free Water(%) Density(113/gal) Plastic Viscosity(Pas) Thickening Time(hr) CmprStr 1(psi) 1.16 5.08 15.80 0.1 5.75 Additives Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label 0065 Dispersant 0.3 %BWOC Additive Type Concentration Conc Unit label D79 Extender 3.0 %BWOC Additive Type Concentration Conc Unit label D167 Fluid Loss 0.4 %BWOC Page 112 Report Printed: 7/10/2014 0:.*p;,-_;:!: Cement Detail Report ,..: '.,*:.::f:: CD1-47 o ConocoPhillips String: Intermediate#1 Casing Cement Job: DRILLING ORIGINAL, 10/31/2012 00:00 Additives Additive Type Concentration Conc Unit label B155 Retarder 0.11 %BWOC Additive Type Concentration Conc Unit label D110 Retarder 0.4 gal/sx Page 212 Report Printed: 7/10/2014 coI 4 21 2 -013 Cement Detail Report ;.>ry.. _. ._ CD1-47 ConocoPhiilips String: Cement Plug Job: DRILLING ORIGINAL, 10/31/2012 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Plug 12/4/2012 21:00 12/4/2012 22:00 CD1-47 Comment Dowell flood lines with 13 ppg Mud Push-Test lines to 2500 psi-Pump 25.7 bbis total 13.0 ppg Mud Push into pipe at 7 bpm-insert nerf seperator ball into DP -flush spacer from surface lines with cement-Dowell pump 47.5 bbls(267 sx)(1.0 yield)17.0 ppg cement at 4.5 bpm followed by 4.3 bbis 13.0 ppg Mud Push spacer into pipe-Rig displace and balance with 163.8 bbls 10.5 ppg mud at 7 bpm(ICP=150 psi,FCP=820 psi)-full returns-CIP at 2200 Hrs-POOH to 10559'and circulated out Mud Push,no excess cement seen at surface Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement..Top Plug? Btm Plug? Cement Plug Plug back for sidetrack 10,559.0 11,006.0 Yes 0.0 Yes No Q Pump Unit(bbllm...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Reclp? Stroke(ft) Rotated? Pipe RPM(rpm) 4 7 6 820.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(NKB) Drill Out Diameter(in) 8 1/2 Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 10,559.0 11,006.0 267 G 47.5 Yield(ftlsack) Mix H2O Ratio(gailsa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.00 3.87 17.00 0.2 4.75 Additives Additive Type Concentration Conc Unit label Antifoam 0046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant 0065 1.0 %BWOC Additive Type Concentration Cone Unit label Fluid Loss Control D167 0.2 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.04 gal/sx Page 111 Report Printed: 7/10/2014 r Detail Report CD1-47 ,2IZ 3 ConocoPhillips . String: Intermediate#2 7 Inch Liner Cement Job: DRILLING ORIGINAL, 10/31/2012 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate#2 7 Inch Liner Cement 12/15/2012 02:13 12/15/2012 04:18 CD1-47 Comment Dowell pumps 20 bbls of 8.3 PPG CW100 @ 4 BPM.Pump 30 bbls of 12.5 PPG MP-II @ 4 BPM.Pump 48.6bbls of 15.8 PPG Alpine Int.Tail cement slurry @4 BPM.Drop dart and pump 5.2 bbls of 12.5 PPG MP-II @ 4 BPM.Switch to rig pump and pump 176 bbls of 10.5 PPG drilling mud @2-4 BPM. Cement Stages Stage#<Stage Number?> Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...'Top Plug? Btm Plug? Intermediate#2 7 Inch Pump Alpine slurry up to 10,349.7 11,458.0 No 1.0 No No Liner Cement liner hanger©10,349' Q Pump!nit(bbilm...Q Pump Final(bbi/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 1 3 1,030.0 No 0.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) CW100 20.0 Yield(ft/sack) Mix H2O Ratio(gaUaa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pan) Thickening Time(hr) CmprStr 1(psi) 8.33 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Eat Btm(ftKB) Amount(sacks) Class Volume Pumped(bbi) MP-II 35.0 Yield(ft'Isack) Mix H2O Ratio(gaUsa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 12.50 Additives Additive Type Concentration Conc Unit label Retarder B155 0.11 %BWOC Additive Type Concentration Cone Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Fluid Fluid Type Fluid Description Estimated Top(ftKB) Eat Btm(ftKB) Amount(sacks) Class Volume Pumped(bbi) Alpine Intermediate 234 G 48.5 Tail Yield(ftlsack) Mix H2O Ratio(galisa... Free Water(%) Density(lb/gal) Plastic Viscosity(Paps) Thickening Time(hr) CmprStr 1(psi) 1.16 5.08 15.80 0.1 6.65 Additives Additive Type Concentration Conc Unit label Additive 'Type Concentration Cone Unit label Retarder B155 0.11 %BWOC Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Cone Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Page 1/1 Report Printed: 7/10/2014 ---- -71 qg I ConocoPhillips(Alaska) Inc. Western North Slope CD1 Alpine Pad CD1-47 501032065900 ii Sperry Elriliu 4111 Definitive Survey Report , - 10 January, 2013 ry !!! ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-47 Project: Western North Slope TVD Reference: Rig:19.5+36.78 @ 56.28ft(Doyonl9) Site: CD1 Alpine Pad MD Reference: Rig:19.5+36.78 @ 56.28ft(Doyonl9) Well: CD1-47 North Reference: True Wellbore: CD1-47 Survey Calculation Method: Minimum Curvature Design: CD1-47 Database: CPAI EDM Production Project Western North Slope Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD1-47 Well Position +N/-S 0.00 ft Northing: 5,975,579.96 ft Latitude: 70°20'31.677 N I +EI-W 0.00 ft Easting: 385,674.75 ft Longitude: 150°55'40.224 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.50ft 1 Wellbore CD1-47 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2011 12/5/2012 19.71 80.85 57,598 Design CD1-47 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,780.44 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (ft) (ft) (ft) (°) 36.78 0.00 0.00 331.00 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 114.00 820.00 CD1-47PB1 Gyro(CD1-47PB1) GYD-GC-SS Gyrodata gyro single shots 11/1/2012 12:C 856.00 2,629.00 CD1-47PB1 (CD1-47PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/2/2012 12:C 2,630.00 10,722.58 CD1-47PB1 (CD1-47PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/2/2012 12:C 10,722.58 10,780.44 CD1-47PB1 (CD1-47PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/2/2012 12:C 10,783.00 14,120.00 CD1-47(CD1-47) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/10/2012 12: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/10(y) (ft) Survey Tool Name 36.78 0.00 0.00 36.78 -19.50 0.00 0.00 5,975,579.96 385,674.75 0.00 0.00 UNDEFINED 114.00 0.29 235.81 114.00 57.72 -0.11 -0.16 5,975,579.85 385,674.58 0.38 -0.02 GYD-GC-SS(1) 175.00 0.19 246.37 175.00 118.72 -0.24 -0.38 5,975,579.73 385,674.36 0.18 -0.02 GYD-GC-SS(1) 268.00 1.11 162.86 267.99 211.71 -1.16 -0.26 5,975,578.80 385,674.47 1.19 -0.89 GYD-GC-SS(1) 300.00 1.67 161.42 299.98 243.70 -1.90 -0.02 5,975,578.06 385,674.70 1.75 -1.65 GYD-GC-SS(1) 330.00 1.93 152.75 329.97 273.69 -2.76 0.35 5,975,577.19 385,675.06 1.25 -2.59 GYD-GC-SS(1) 359.00 2.25 148.97 358.95 302.67 -3.68 0.87 5,975,576.26 385,675.56 1.20 -3.64 GYD-GC-SS(1) 390.00 2.58 150.23 389.92 333.64 -4.81 1.53 5,975,575.12 385,676.20 1.08 -4.95 GYD-GC-SS(1) 420.00 2.81 148.88 419.89 363.61 -6.03 2.25 5,975,573.90 385,676.90 0.80 -6.36 GYD-GC-SS(1) 450.00 3.16 153.40 449.85 393.57 -7.39 3.00 5,975,572.52 385,677.63 1.41 -7.92 GYD-GC-SS(1) 1/10/2013 12:19:32PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-47 Project: Western North Slope TVD Reference: Rig:19.5+36.78 @ 56.285(Doyonl9) Site: CD1 Alpine Pad MD Reference: Rig:19.5+36.78 @ 56.28ft(Doyonl9) Well: CD1-47 North Reference: True Wellbore: CD1-47 Survey Calculation Method: Minimum Curvature Design: CD1-47 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name • 483.00 3.55 157.91 482.79 426.51 -9.15 3.79 5,975,570.75 385,678.39 1.43 -9.84 GYD-GC-SS(1) 513.00 4.22 159.90 512.72 456.44 -11.05 4.52 5,975,568.84 385,679.09 2.28 -11.86 GYD-GC-SS(1) 543.00 4.70 159.42 542.63 486.35 -13.24 5.33 5,975,566.64 385,679.87 1.60 -14.16 GYD-GC-SS(1) 575.00 4.63 161.55 574.53 518.25 -15.69 6.20 5,975,564.17 385,680.70 0.58 -16.73 GYD-GC-SS(1) 605.00 4.47 164.90 604.43 548.15 -17.97 6.88 5,975,561.89 385,681.35 1.03 -19.05 GYD-GC-SS(1) 635.00 4.07 167.94 634.35 578.07 -20.14 7.41 5,975,559.71 385,681.85 1.53 -21.21 GYD-GC-SS(1) 667.00 3.06 173.03 666.29 610.01 -22.10 7.75 5,975,557.75 385,682.16 3.30 -23.09 GYD-GC-SS(1) • 697.00 2.10 182.97 696.25 639.97 -23.44 7.82 5,975,556.40 385,682.21 3.52 -24.29 GYD-GC-SS(1) 727.00 1.33 197.99 726.24 669.96 -24.32 7.68 5,975,555.52 385,682.06 2.95 -25.00 GYD-GC-SS(1) 760.00 0.96 222.05 759.23 702.95 -24.89 7.38 5,975,554.96 385,681.75 1.81 -25.35 GYD-GC-SS(1) 790.00 1.02 250.38 789.23 732.95 -25.17 6.96 5,975,554.69 385,681.32 1.63 -25.39 GYD-GC-SS(1) 820.00 1.34 281.18 819.22 762.94 -25.19 6.37 5,975,554.68 385,680.73 2.33 -25.12 GYD-GC-SS(1) 856.00 1.83 299.64 855.21 798.93 -24.82 5.45 5,975,555.06 385,679.82 1.95 -24.35 MWD+IFR-AK-CAZ-SC(2) 949.00 3.80 307.55 948.09 891.81 -22.21 1.72 5,975,557.73 385,676.13 2.15 -20.26 MWD+IFR-AK-CAZ-SC(2) ' 1,041.00 8.25 312.96 1,039.56 983.28 -15.85 -5.53 5,975,564.19 385,668.97 4.87 -11.18 MWD+IFR-AK-CAZ-SC(2) 1,135.00 14.22 315.06 1,131.72 1,075.44 -3.07 -18.63 5,975,577.17 385,656.07 6.36 6.35 MWD+IFR-AK-CAZ-SC(2) 1,229.00 18.59 316.20 1,221.87 1,165.59 15.93 -37.17 5,975,596.45 385,637.83 4.66 31.95 MWD+IFR-AK-CAZ-SC(2) 1,324.00 21.46 318.18 1,311.12 1,254.84 39.81 -59.24 5,975,620.66 385,616.12 3.10 63.54 MWD+IFR-AK-CAZ-SC(2) 1,418.00 21.57 316.72 1,398.57 1,342.29 65.20 -82.55 5,975,646.41 385,593.20 0.58 97.05 MWD+IFR-AK-CAZ-SC(2) 1,513.00 22.76 319.01 1,486.55 1,430.27 91.79 -106.58 5,975,673.35 385,569.58 1.55 131.95 MWD+IFR-AK-CAZ-SC(2) 1,605.00 24.37 322.00 1,570.88 1,514.60 120.18 -129.94 5,975,702.10 385,546.66 2.18 168.11 MWD+IFR-AK-CAZ-SC(2) 1,699.00 26.58 326.44 1,655.74 1,599.46 153.00 -153.51 5,975,735.26 385,523.60 3.11 208.24 MWD+IFR-AK-CAZ-SC(2) 1,792.00 29.98 328.40 1,737.63 1,681.35 190.14 -177.20 5,975,772.76 385,500.48 3.79 252.21 MWD+IFR-AK-CAZ-SC(2) 1,886.00 34.05 331.51 1,817.32 1,761.04 233.29 -202.07 5,975,816.28 385,476.27 4.67 302.01 MWD+IFR-AK-CAZ-SC(2) 1,981.00 38.20 333.79 1,894.05 1,837.77 283.04 -227.74 5,975,866.42 385,451.37 4.59 357.97 MWD+IFR-AK-CAZ-SC(2) 2,075.00 42.28 334.74 1,965.79 1,909.51 337.74 -254.08 5,975,921.51 385,425.86 4.39 418.58 MWD+IFR-AK-CAZ-SC(2) • 2,169.00 45.91 335.03 2,033.28 1,977.00 396.96 -281.84 5,975,981.13 385,399.02 3.87 483.83 MWD+IFR-AK-CAZ-SC(2) 2,264.00 49.54 335.21 2,097.18 2,040.90 460.72 -311.40 5,976,045.33 385,370.43 3.82 553.92 MWD+IFR-AK-CAZ-SC(2) 2,358.00 53.54 335.21 2,155.63 2,099.35 527.53 -342.26 5,976,112.60 385,340.60 4.26 627.32 MWD+IFR-AK-CAZ-SC(2) 2,452.00 57.08 332.74 2,209.13 2,152.85 596.95 -376.19 5,976,182.52 385,307.73 4.34 704.48 MWD+IFR-AK-CAZ-SC(2) 2,547.00 58.25 331.49 2,259.94 2,203.66 667.89 -413.74 5,976,254.02 385,271.28 1.66 784.73 MWD+IFR-AK-CAZ-SC(2) 2,630.00 58.30 332.02 2,303.59 2,247.31 730.08 -447.15 5,976,316.71 385,238.82 0.55 855.32 MWD+IFR-AK-CAZ-SC(3) 2,726.07 57.38 331.12 2,354.72 2,298.44 801.60 -485.86 5,976,388.81 385,201.20 1.24 936.65 MWD+IFR-AK-CAZ-SC(3) 2,819.44 56.62 330.95 2,405.58 2,349.30 870.11 -523.78 5,976,457.88 385,164.33 0.83 1,014.95 MWD+IFR-AK-CAZ-SC(3) ' 2,912.84 55.81 330.93 2,457.51 2,401.23 937.97 -561.49 5,976,526.30 385,127.67 0.87 1,092.58 MWD+IFR-AK-CAZ-SC(3) 3,007.35 55.25 331.25 2,511.00 2,454.72 1,006.17 -599.16 5,976,595.07 385,091.05 0.65 1,170.50 MWD+IFR-AK-CAZ-SC(3) 3,101.98 54.91 332.01 2,565.17 2,508.89 1,074.45 -636.03 5,976,663.89 385,055.23 0.75 1,248.08 MWD+IFR-AK-CAZ-SC(3) 3,196.07 54.87 332.13 2,619.29 2,563.01 1,142.45 -672.08 5,976,732.43 385,020.22 0.11 1,325.04 MWD+IFR-AK-CAZ-SC(3) 3,291.01 54.87 332.90 2,673.92 2,617.64 1,211.33 -707.91 5,976,801.84 384,985.45 0.66 1,402.66 MWD+IFR-AK-CAZ-SC(3) 3,385.12 54.88 333.18 2,728.07 2,671.79 1,279.94 -742.81 5,976,870.97 384,951.60 0.24 1,479.58 MWD+IFR-AK-CAZ-SC(3) 1/10/2013 12:19:32PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-47 Project: Western North Slope TVD Reference: Rig:19.5+36.78 @ 56.28ft(Doyonl9) Site: CD1 Alpine Pad MD Reference: Rig:19.5+36.78 @ 56.28ft(Doyonl9) Well: CD1-47 North Reference: True Wellbore: CD1-47 Survey Calculation Method: Minimum Curvature Design: CD1-47 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NL-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100) (ft) Survey Tool Name 3,480.19 54.93 333.37 2,782.73 2,726.45 1,349 42 -777.79 5,976,940.96 384,917.69 0.17 1,557.31 MWD+IFR-AK-CAZ-SC(3) 3,575.49 54.93 333.32 2,837.48 2,781.20 1,419.13 -812.78 5,977,011.19 384,883.77 0.04 1,635.24 MWD+IFR-AK-CAZ-SC(3) 3,668.80 54.88 331.94 2,891.13 2,834.85 1,486.92 -847.88 5,977,079.51 384,849.71 1.21 1,711.55 MWD+IFR-AK-CAZ-SC(3) 3,763.24 54.90 329.00 2,945.46 2,889.18 1,554.13 -885.95 5,977,147.28 384,812.67 2.55 1,788.79 MWD+IFR-AK-CAZ-SC(3) 3,858.34 54.88 328.95 3,000.15 2,943.87 1,620.80 -926.05 5,977,214.55 384,773.60 0.05 1,866.54 MWD+IFR-AK-CAZ-SC(3) 3,952.70 54.87 329.30 3,054.45 2,998.17 1,687.04 -965.65 5,977,281.38 384,735.01 0.30 1,943.67 MWD+IFR-AK-CAZ-SC(3) 4,046.68 54.88 329.87 3,108.52 3,052.24 1,753.33 -1,004.57 5,977,348.25 384,697.12 0.50 2,020.52 MWD+IFR-AK-CAZ-SC(3) 4,140.54 54.85 330.54 3,162.54 3,106.26 1,819.94 -1,042.71 5,977,415.43 384,660.00 0.58 2,097.27 MWD+IFR-AK-CAZ-SC(3) 4,234.05 54.85 331.05 3,216.37 3,160.09 1,886.67 -1,080.01 5,977,482.72 384,623.72 0.45 2,173.72 MWD+IFR-AK-CAZ-SC(3) 4,328.64 54.90 331.02 3,270.80 3,214.52 1,954.36 -1,117.48 5,977,550.97 384,587.29 0.06 2,251.09 MWD+IFR-AK-CAZ-SC(3) 4,423.16 54.88 331.19 3,325.16 3,268.88 2,022.06 -1,154.84 5,977,619.22 384,550.97 0.15 2,328.41 MWD+IFR-AK-CAZ-SC(3) 4,519.15 54.92 330.99 3,380.35 3,324.07 2,090.81 -1,192.81 5,977,688.53 384,514.06 0.18 2,406.95 MWD+IFR-AK-CAZ-SC(3) 4,612.32 54.97 330.54 3,433.87 3,377.59 2,157.36 -1,230.06 5,977,755.64 384,477.83 0.40 2,483.21 MWD+IFR-AK-CAZ-SC(3) 4,706.42 54.92 330.64 3,487.91 3,431.63 2,224.46 -1,267.88 5,977,823.31 384,441.04 0.10 2,560.24 MWD+IFR-AK-CAZ-SC(3) 4,800.32 54.91 329.24 3,541.89 3,485.61 2,290.96 -1,306.37 5,977,890.38 384,403.57 1.22 2,637.06 MWD+IFR-AK-CAZ-SC(3) 4,893.89 54.92 329.04 3,595.67 3,539.39 2,356.69 -1,345.65 5,977,956.69 384,365.31 0.18 2,713.59 MWD+IFR-AK-CAZ-SC(3) 4,987.25 54.88 328.93 3,649.35 3,593.07 2,422.15 -1,385.00 5,978,022.74 384,326.95 0.11 2,789.93 MWD+IFR-AK-CAZ-SC(3) 5,082.18 54.91 329.00 3,703.95 3,647.67 2,488.70 -1,425.04 5,978,089.89 384,287.94 0.07 2,867.54 MWD+IFR-AK-CAZ-SC(3) 5,176.55 56.01 329.24 3,757.45 3,701.17 2,555.41 -1,464.94 5,978,157.20 384,249.07 1.18 2,945.23 MWD+IFR-AK-CAZ-SC(3) 5,271.76 55.95 330.52 3,810.72 3,754.44 2,623.67 -1,504.54 5,978,226.04 384,210.52 1.12 3,024.13 MWD+IFR-AK-CAZ-SC(3) 5,366.13 55.97 330.91 3,863.55 3,807.27 2,691.88 -1,542.79 5,978,294.82 384,173.31 0.34 3,102.33 MWD+IFR-AK-CAZ-SC(3) 5,460.54 55.96 330.41 3,916.39 3,860.11 2,760.08 -1,581.12 5,978,363.59 384,136.03 0.44 3,180.56 MWD+IFR-AK-CAZ-SC(3) 5,554.27 55.95 329.97 3,968.86 3,912.58 2,827.46 -1,619.73 5,978,431.55 384,098.45 0.39 3,258.22 MWD+IFR-AK-CAZ-SC(3) 5,649.28 56.01 329.92 4,022.02 3,965.74 2,895.63 -1,659.17 5,978,500.30 384,060.06 0.08 3,336.95 MWD+IFR-AK-CAZ-SC(3) 5,743.95 55.96 329.70 4,074.98 4,018.70 2,963.45 -1,698.63 5,978,568.71 384,021.64 0.20 3,415.41 MWD+IFR-AK-CAZ-SC(3) 5,835.15 55.98 329.95 4,126.02 4,069.74 3,028.79 -1,736.62 5,978,634.62 383,984.66 0.23 3,490.97 MWD+IFR-AK-CAZ-SC(3) 5,928.80 55.97 330.04 4,178.42 4,122.14 3,096.01 -1,775.44 5,978,702.41 383,946.87 0.08 3,568.58 MWD+IFR-AK-CAZ-SC(3) 6,023.07 55.98 330.44 4,231.17 4,174.89 3,163.83 -1,814.22 5,978,770.82 383,909.13 0.35 3,646.70 MWD+IFR-AK-CAZ-SC(3) 6,117.17 55.93 330.50 4,283.85 4,227.57 3,231.67 -1,852.65 5,978,839.23 383,871.75 0.07 3,724.67 MWD+IFR-AK-CAZ-SC(3) 6,211.67 56.15 331.10 4,336.64 4,280.36 3,300.09 -1,890.89 5,978,908.22 383,834.56 0.58 3,803.05 MWD+IFR-AK-CAZ-SC(3) 6,305.50 56.15 330.89 4,388.90 4,332.62 3,368.25 -1,928.67 5,978,976.94 383,797.82 0.19 3,880.97 MWD+IFR-AK-CAZ-SC(3) 6,398.83 56.18 330.83 4,440.87 4,384.59 3,435.96 -1,966.42 5,979,045.21 383,761.11 0.06 3,958.50 MWD+IFR-AK-CAZ-SC(3) 6,493.52 56.31 329.75 4,493.49 4,437.21 3,504.34 -2,005.44 5,979,114.17 383,723.14 0.96 4,037.22 MWD+IFR-AK-CAZ-SC(3) 6,588.37 56.35 328.86 4,546.07 4,489.79 3,572.21 -2,045.74 5,979,182.65 383,683.89 0.78 4,116.12 MWD+IFR-AK-CAZ-SC(3) 6,682.41 56.33 328.67 4,598.20 4,541.92 3,639.14 -2,086.32 5,979,250.18 383,644.33 0.17 4,194.33 MWD+IFR-AK-CAZ-SC(3) 6,776.02 56.31 328.92 4,650.11 4,593.83 3,705.77 -2,126.68 5,979,317.41 383,605.00 0.22 4,272.17 MWD+IFR-AK-CAZ-SC(3) 6,870.08 56.32 329.42 4,702.28 4,646.00 3,772.97 -2,166.79 5,979,385.21 383,565.92 0.44 4,350.40 MWD+IFR-AK-CAZ-SC(3) 6,963.97 56.28 329.84 4,754.37 4,698.09 3,840.37 -2,206.29 5,979,453.19 383,527.46 0.37 4,428.49 MWD+IFR-AK-CAZ-SC(3) 7,058.59 56.34 329.88 4,806.86 4,750.58 3,908.45 -2,245.82 5,979,521.87 383,488.98 0.07 4,507.20 MWD+IFR-AK-CAZ-SC(3) 7,152.95 56.29 330.22 4,859.19 4,802.91 3,976.48 -2,285.02 5,979,590.48 383,450.83 0.30 4,585.71 MWD+IFR-AK-CAZ-SC(3) 1/10/2013 12.19:32PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-47 Project: Western North Slope TVD Reference: Rig:19.5+36.78 @ 56.28ft(Doyonl9) Site: CD1 Alpine Pad MD Reference: Rig:19.5+36.78 @ 56.28ft(Doyonl9) Well: CD1-47 North Reference: True Wellbore: CD1-47 Survey Calculation Method: Minimum Curvature Design: CD1-47 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (1 (1 (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,248.58 56.32 330.18 4,912.24 4,855.96 4,045.53 -2,324.56 5,979,660.12 383,412.34 0.05 4,665.27 MWD+IFR-AK-CAZ-SC(3) 7,342.10 56.39 330.11 4,964.06 4,907.78 4,113.05 -2,363.31 5,979,728.22 383,374.63 0.10 4,743.11 MWD+IFR-AK-CAZ-SC(3) 7,436.72 56.38 330.32 5,016.44 4,960.16 4,181.44 -2,402.46 5,979,797.19 383,336.53 0.19 4,821.90 MWD+IFR-AK-CAZ-SC(3) 7,530.39 56.16 330.48 5,068.45 5,012.17 4,249.17 -2,440.94 5,979,865.49 383,299.10 0.27 4,899.80 MWD+IFR-AK-CAZ-SC(3) 7,623.69 56.10 330.41 5,120.45 5,064.17 4,316.56 -2,479.15 5,979,933.45 383,261.92 0.09 4,977.26 MWD+IFR-AK-CAZ-SC(3) 7,719.28 56.19 329.79 5,173.70 5,117.42 4,385.38 -2,518.72 5,980,002.86 383,223.41 0.55 5,056.63 MWD+IFR-AK-CAZ-SC(3) 7,813.37 56.14 328.31 5,226.09 5,169.81 4,452.40 -2,558.91 5,980,070.48 383,184.24 1.31 5,134.74 MWD+IFR-AK-CAZ-SC(3) 7,907.73 56.12 329.56 5,278.68 5,222.40 4,519.51 -2,599.34 5,980,138.19 383,144.85 1.10 5,213.04 MWD+IFR-AK-CAZ-SC(3) 8,002.32 56.07 328.15 5,331.45 5,275.17 4,586.70 -2,639.94 5,980,205.99 383,105.28 1.24 5,291.48 MWD+IFR-AK-CAZ-SC(3) 8,095.54 56.17 327.29 5,383.42 5,327.14 4,652.13 -2,681.27 5,980,272.03 383,064.95 0.77 5,368.75 MWD+IFR-AK-CAZ-SC(3) 8,190.40 56.17 328.28 5,436.23 5,379.95 4,718.79 -2,723.28 5,980,339.33 383,023.97 0.87 5,447.42 MWD+IFR-AK-CAZ-SC(3) 8,283.77 56.20 329.26 5,488.19 5,431.91 4,785.13 -2,763.50 5,980,406.26 382,984.77 0.87 5,524.94 MWD+IFR-AK-CAZ-SC(3) 8,376.69 56.13 331.44 5,539.93 5,483.65 4,852.20 -2,801.68 5,980,473.90 382,947.62 1.95 5,602.11 MWD+IFR-AK-CAZ-SC(3) 8,472.36 56.21 332.57 5,593.20 5,536.92 4,922.37 -2,838.98 5,980,544.63 382,911.40 0.98 5,681.57 MWD+IFR-AK-CAZ-SC(3) 8,566.91 56.11 331.96 5,645.85 5,589.57 4,991.88 -2,875.53 5,980,614.68 382,875.92 0.55 5,760.08 MWD+IFR-AK-CAZ-SC(3) 8,659.79 56.10 330.81 5,697.65 5,641.37 5,059.56 -2,912.45 5,980,682.91 382,840.03 1.03 5,837.17 MWD+IFR-AK-CAZ-SC(3) 8,754.70 56.15 330.08 5,750.55 5,694.27 5,128.10 -2,951.32 5,980,752.03 382,802.22 0.64 5,915.97 MWD+IFR-AK-CAZ-SC(3) 8,849.02 56.19 329.59 5,803.06 5,746.78 5,195.84 -2,990.69 5,980,820.36 382,763.89 0.43 5,994.30 MWD+IFR-AK-CAZ-SC(3) 8,943.17 56.11 329.32 5,855.50 5,799.22 5,263.18 -3,030.43 5,980,888.29 382,725.19 0.25 6,072.46 MWD+IFR-AK-CAZ-SC(3) 9,037.31 56.10 329.64 5,908.00 5,851.72 5,330.50 -3,070.11 5,980,956.20 382,686.54 0.28 6,150.58 MWD+IFR-AK-CAZ-SC(3) 9,131.68 56.14 330.00 5,960.61 5,904.33 5,398.22 -3,109.50 5,981,024.51 382,648.19 0.32 6,228.91 MWD+IFR-AK-CAZ-SC(3) 9,224.74 56.11 330.09 6,012.48 5,956.20 5,465.17 -3,148.07 5,981,092.03 382,610.64 0.09 6,306.16 MWD+IFR-AK-CAZ-SC(3) 9,319.30 56.07 330.04 6,065.24 6,008.96 5,533.17 -3,187.24 5,981,160.62 382,572.52 0.06 6,384.63 MWD+IFR-AK-CAZ-SC(3) 9,412.97 56.11 330.14 6,117.49 6,061.21 5,600.56 -3,226.00 5,981,228.58 382,534.80 0.10 6,462.35 MWD+IFR-AK-CAZ-SC(3) 9,507.26 56.13 330.25 6,170.06 6,113.78 5,668.48 -3,264.91 5,981,297.09 382,496.93 0.10 6,540.63 MWD+IFR-AK-CAZ-SC(3) 9,601.83 56.14 331.22 6,222.75 6,166.47 5,736.99 -3,303.29 5,981,366.16 382,459.60 0.85 6,619.15 MWD+IFR-AK-CAZ-SC(3) 9,694.97 56.12 331.07 6,274.66 6,218.38 5,804.72 -3,340.62 5,981,434.45 382,423.32 0.14 6,696.49 MWD+IFR-AK-CAZ-SC(3) 9,788.46 56.16 330.28 6,326.75 6,270.47 5,872.40 -3,378.64 5,981,502.70 382,386.33 0.70 6,774.12 MWD+IFR-AK-CAZ-SC(3) 9,883.41 56.11 329.36 6,379.66 6,323.38 5,940.56 -3,418.27 5,981,571.44 382,347.75 0.81 6,852.94 MWD+IFR-AK-CAZ-SC(3) 9,978.29 56.31 329.75 6,432.43 6,376.15 6,008.54 -3,458.23 5,981,640.02 382,308.84 0.40 6,931.77 MWD+IFR-AK-CAZ-SC(3) 10,070.26 56.34 330.27 6,483.43 6,427.15 6,074.83 -3,496.48 5,981,706.88 382,271.60 0.47 7,008.29 MWD+IFR-AK-CAZ-SC(3) 10,166.12 56.31 330.49 6,536.58 6,480.30 6,144.18 -3,535.91 5,981,776.82 382,233.23 0.19 7,088.06 MWD+IFR-AK-CAZ-SC(3) 10,260.96 56.30 330.86 6,589.19 6,532.91 6,212.97 -3,574.56 5,981,846.19 382,195.65 0.32 7,166.97 MWD+IFR-AK-CAZ-SC(3) 10,354.18 56.59 330.95 6,640.72 6,584.44 6,280.86 -3,612.33 5,981,914.63 382,158.91 0.32 7,244.65 MWD+IFR-AK-CAZ-SC(3) 10,448.00 60.06 330.70 6,689.98 6,633.70 6,350.56 -3,651.25 5,981,984.91 382,121.06 3.71 7,324.49 MWD+IFR-AK-CAZ-SC(3) 10,542.14 62.10 330.35 6,735.50 6,679.22 6,422.29 -3,691.80 5,982,057.25 382,081.62 2.19 7,406.88 MWD+IFR-AK-CAZ-SC(3) 10,636.64 64.44 329.64 6,778.00 6,721.72 6,495.37 -3,734.01 5,982,130.96 382,040.54 2.57 7,491.26 MWD+IFR-AK-CAZ-SC(3) 10,722.58 67.26 330.52 6,813.16 6,756.88 6,563.33 -3,773.11 5,982,199.50 382,002.48 3.41 7,569.66 MWD+IFR-AK-CAZ-SC(3) 10,780.44 67.89 330.91 6,835.23 6,778.95 6,609.98 -3,799.27 5,982,246.54 381,977.03 1.25 7,623.14 MWD+IFR-AK-CAZ-SC(4) 10,783.00 67.96 330.93 6,836.19 6,779.91 6,612.06 -3,800.42 5,982,248.63 381,975.91 2.83 7,625.52 MWD+IFR-AK-CAZ-SC(5) 1/10/2013 12:19:32PM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-47 Project: Western North Slope TVD Reference: Rig:19.5+36.78 @ 56.28ft(Doyonl9) Site: CD1 Alpine Pad MD Reference: Rig:19.5+36.78 @ 56.28ft(Doyonl9) Well: CD1-47 North Reference: True Wellbore: CD1-47 Survey Calculation Method: Minimum Curvature Design: CD1-47 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting OLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 10,872.37 70.64 328.78 6,867.78 6,811.50 6,684.33 -3,842.41 5,982,321.53 381,935.03 3.75 7,709.09 MWD+IFR-AK-CAZ-SC(5) 10,964.00 74.41 330.80 6,895.30 6,839.02 6,759.85 -3,886.37 5,982,397.71 381,892.24 4.62 7,796.45 MWD+IFR-AK-CAZ-SC(5) 11,058.66 78.17 331.33 6,917.73 6,861.45 6,840.32 -3,930.85 5,982,478.84 381,848.99 4.01 7,888.39 MWD+IFR-AK-CAZ-SC(5) 11,153.47 77.64 331.30 6,937.59 6,881.31 6,921.65 -3,975.35 5,982,560.83 381,805.75 0.56 7,981.10 MWD+IFR-AK-CAZ-SC(5) 11,246.25 78.83 331.10 6,956.51 6,900.23 7,001.24 -4,019.10 5,982,641.08 381,763.21 1.30 8,071.93 MWD+IFR-AK-CAZ-SC(5) 11,340.63 80.89 332.07 6,973.13 6,916.85 7,082.95 -4,063.31 5,982,723.44 381,720.26 2.41 8,164.82 MWD+IFR-AK-CAZ-SC(5) 11,427.49 84.20 332.07 6,984.40 6,928.12 7,159.03 -4,103.64 5,982,800.13 381,681.09 3.81 8,250.92 MWD+IFR-AK-CAZ-SC(5) 11,514.98 88.41 331.27 6,990.03 6,933.75 7,235.87 -4,145.07 5,982,877.57 381,640.85 4.90 8,338.20 MWD+IFR-AK-CAZ-SC(5) 11,611.16 93.08 331.22 6,988.78 6,932.50 7,320.16 -4,191.32 5,982,962.55 381,595.89 4.86 8,434.34 MWD+IFR-AK-CAZ-SC(5) 11,705.88 92.98 331.30 6,983.78 6,927.50 7,403.09 -4,236.80 5,983,046.16 381,551.69 0.14 8,528.93 MWD+IFR-AK-CAZ-SC(5) 11,801.58 90.68 331.19 6,980.72 6,924.44 7,486.94 -4,282.81 5,983,130.70 381,506.96 2.41 8,624.58 MWD+IFR-AK-CAZ-SC(5) 11,895.08 88.93 330.98 6,981.04 6,924.76 7,568.78 -4,328.02 5,983,213.21 381,463.01 1.89 8,718.07 MWD+IFR-AK-CAZ-SC(5) 11,991.94 90.03 332.85 6,981.92 6,925.64 7,654.23 -4,373.61 5,983,299.34 381,418.73 2.24 8,814.91 MWD+IFR-AK-CAZ-SC(5) 12,086.87 90.25 335.45 6,981.68 6,925.40 7,739.65 -4,415.00 5,983,385.37 381,378.65 2.75 8,909.69 MWD+IFR-AK-CAZ-SC(5) 12,182.49 90.68 336.72 6,980.91 6,924.63 7,827.06 -4,453.76 5,983,473.35 381,341.23 1.40 9,004.93 MWD+IFR-AK-CAZ-SC(5) 12,278.07 90.68 333.73 6,979.77 6,923.49 7,913.83 -4,493.81 5,983,560.71 381,302.52 3.13 9,100.23 MWD+IFR-AK-CAZ-SC(5) 12,373.53 90.37 330.94 6,978.90 6,922.62 7,998.36 -4,538.12 5,983,645.91 381,259.50 2.94 9,195.65 MWD+IFR-AK-CAZ-SC(5) 12,468.99 90.71 332.81 6,978.00 6,921.72 8,082.54 -4,583.12 5,983,730.76 381,215.80 1.99 9,291.09 MWD+IFR-AK-CAZ-SC(5) 12,565.05 91.32 332.12 6,976.30 6,920.02 8,167.71 -4,627.52 5,983,816.58 381,172.71 0.96 9,387.10 MWD+IFR-AK-CAZ-SC(5) 12,660.32 91.35 328.16 6,974.08 6,917.80 8,250.29 -4,674.93 5,983,899.87 381,126.56 4.16 9,482.32 MWD+IFR-AK-CAZ-SC(5) 12,754.92 91.14 328.68 6,972.02 6,915.74 8,330.86 -4,724.46 5,983,981.18 381,078.27 0.59 9,576.80 MWD+IFR-AK-CAZ-SC(5) 12,851.68 90.34 330.25 6,970.77 6,914.49 8,414.19 -4,773.61 5,984,065.24 381,030.40 1.82 9,673.51 MWD+IFR-AK-CAZ-SC(5) 12,946.57 89.60 330.85 6,970.82 6,914.54 8,496.82 -4,820.27 5,984,148.57 380,985.01 1.00 9,768.40 MWD+IFR-AK-CAZ-SC(5) 13,042.51 87.70 331.76 6,973.08 6,916.80 8,580.95 -4,866.32 5,984,233.38 380,940.26 2.20 9,864.30 MWD+IFR-AK-CAZ-SC(5) 13,138.16 88.40 331.93 6,976.34 6,920.06 8,665.23 -4,911.42 5,984,318.34 380,896.44 0.75 9,959.89 MWD+IFR-AK-CAZ-SC(5) 13,232.30 86.25 332.84 6,980.73 6,924.45 8,748.55 -4,955.01 5,984,402.30 380,854.14 2.48 10,053.89 MWD+IFR-AK-CAZ-SC(5) 13,327.74 88.86 333.26 6,984.80 6,928.52 8,833.54 -4,998.22 5,984,487.93 380,812.23 2.77 10,149.17 MWD+IFR-AK-CAZ-SC(5) 13,422.98 90.52 331.82 6,985.32 6,929.04 8,918.04 -5,042.14 5,984,573.09 380,769.61 2.31 10,244.37 MWD+IFR-AK-CAZ-SC(5) 13,518.82 90.77 330.84 6,984.24 6,927.96 9,002.13 -5,088.11 5,984,657.86 380,724.93 1.06 10,340.20 MWD+IFR-AK-CAZ-SC(5) 13,614.57 90.95 329.64 6,982.80 6,926.52 9,085.24 -5,135.63 5,984,741.68 380,678.68 1.27 10,435.93 MWD+IFR-AK-CAZ-SC(5) 13,709.41 90.86 328.36 6,981.30 6,925.02 9,166.52 -5,184.47 5,984,823.69 380,631.09 1.35 10,530.70 MWD+IFR-AK-CAZ-SC(5) 13,805.24 90.98 329.12 6,979.76 6,923.48 9,248.43 -5,234.19 5,984,906.33 380,582.63 0.80 10,626.44 MWD+IFR-AK-CAZ-SC(5) 13,900.02 91.26 329.49 6,977.91 6,921.63 9,329.91 -5,282.57 5,984,988.54 380,535.51 0.49 10,721.16 MWD+IFR-AK-CAZ-SC(5) 13,996.23 89.79 334.06 6,977.03 6,920.75 9,414.65 -5,328.05 5,985,073.96 380,491.33 4.99 10,817.33 MWD+IFR-AK-CAZ-SC(5) 14,059.95 91.63 335.20 6,976.24 6,919.96 9,472.22 -5,355.35 5,985,131.93 380,464.91 3.40 10,880.92 MWD+IFR-AK-CAZ-SC(5) 14,120.00 93.00 335.20 6,973.81 6,917.53 9,526.69 -5,380.52 5,985,186.77 380,440.58 2.28 10,940.75 MWD+IFR-AK-CAZ-SC(5) 1/10/2013 12:19:32PM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips(Alaska) Inc. Western North Slope CD1 Alpine Pad CD1-47PB1 501032065970 perry Dr llinc Definitive Survey Report 10 January, 2013 HALLIBURTON 11 ! t Sperry Drilling ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-47 Project: Western North Slope TVD Reference: Rig:19.5+36.78 @ 56.28ft(Doyonl9) Site: CD1 Alpine Pad MD Reference: Rig:19.5+36.78 @ 56.28ft(Doyonl9) Well: CD1-47 North Reference: True Wellbore: CD1-47PB1 Survey Calculation Method: Minimum Curvature Design: CD1-47PB1 Database: CPAI EDM Production Project Western North Slope Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD1-47 Well Position +N/-S 0.00 ft Northing: 5,975,579.96 ft Latitude: 70°20'31.677 N +EI-W 0.00 ft Easting: 385,674.75 ft Longitude: 150°55 40.224 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.50ft Wellbore CD1-47PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) (°) (nT) BGGM2011 10/25/2012 19.77 80.84 57,599 Design ,CD1-47PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.78 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 36.78 0.00 0.00 331.00 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 114.00 820.00 CD1-47PB1 Gyro(CD1-47PB1) GYD-GC-SS Gyrodata gyro single shots 11/1/2012 12:C 856.00 10,950.60 CD1-47PB1 (CD1-47PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/2/2012 12:C 2,630.00 10,722.58 CD1-47PB1 (CD1-47PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/2/2012 12:C 10,722.58 10,950.60 CD1-47PB1 (CD1-47PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/2/2012 12:C Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.78 0.00 0.00 36.78 -19.50 0.00 0.00 5,975,579.96 385,674.75 0.00 0.00 UNDEFINED 114.00 0.29 235.81 114.00 57.72 -0.11 -0.16 5,975,579.85 385,674.58 0.38 -0.02 GYD-GC-SS(1) 175.00 0.19 246.37 175.00 118.72 -0.24 -0.38 5,975,579.73 385,674.36 0.18 -0.02 GYD-GC-SS(1) 268.00 1.11 162.86 267.99 211.71 -1.16 -0.26 5,975,578.80 385,674.47 1.19 -0.89 GYD-GC-SS(1) 300.00 1.67 161.42 299.98 243.70 -1.90 -0.02 5,975,578.06 385,674.70 1.75 -1.65 GYD-GC-SS(1) 330.00 1.93 152.75 329.97 273.69 -2.76 0.35 5,975,577.19 385,675.06 1.25 -2.59 GYD-GC-SS(1) 359.00 2.25 148.97 358.95 302.67 -3.68 0.87 5,975,576.26 385,675.56 1.20 -3.64 GYD-GC-SS(1) 390.00 2.58 150.23 389.92 333.64 -4.81 1.53 5,975,575.12 385,676.20 1.08 -4.95 GYD-GC-SS(1) 420.00 2.81 148.88 419.89 363.61 -6.03 2.25 5,975,573.90 385,676.90 0.80 -6.36 GYD-GC-SS(1) 450.00 3.16 153.40 449.85 393.57 -7.39 3.00 5,975,572.52 385,677.63 1.41 -7.92 GYD-GC-SS(1) 483.00 3.55 157.91 482.79 426.51 -9.15 3.79 5,975,570.75 385,678.39 1.43 -9.84 GYD-GC-SS(1) 1/10/2013 12:21:14PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-47 Project: Western North Slope TVD Reference: Rig:19.5+36.78 @ 56.28ft(Doyonl9) Site: CD1 Alpine Pad MD Reference: Rig:19.5+36.78 @ 56.28ft(Doyonl9) Well: CD1-47 North Reference: True Wellbore: CD1-47PB1 Survey Calculation Method: Minimum Curvature Design: CD1-47P81 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 513.00 4.22 159.90 512.72 456.44 -11.05 4.52 5,975,568.84 385,679.09 2.28 -11.86 GYD-GC-SS(1) 543.00 4.70 159.42 542.63 486.35 -13.24 5.33 5,975,566.64 385,679.87 1.60 -14.16 GYD-GC-SS(1) 575.00 4.63 161.55 574.53 518.25 -15.69 6.20 5,975,564.17 385,680.70 0.58 -16.73 GYD-GC-SS(1) 605.00 4.47 164.90 604.43 548.15 -17.97 6.88 5,975,561.89 385,681.35 1.03 -19.05 GYD-GC-SS(1) 635.00 4.07 167.94 634.35 578.07 -20.14 7.41 5,975,559.71 385,681.85 1.53 -21.21 GYD-GC-SS(1) 667.00 3.06 173.03 666.29 610.01 -22.10 7.75 5,975,557.75 385,682.16 3.30 -23.09 GYD-GC-SS(1) 697.00 2.10 182.97 696.25 639.97 -23.44 7.82 5,975,556.40 385,682.21 3.52 -24.29 GYD-GC-SS(1) 727.00 1.33 197.99 726.24 669.96 -24.32 7.68 5,975,555.52 385,682.06 2.95 -25.00 GYD-GC-SS(1) 760.00 0.96 222.05 759.23 702.95 -24.89 7.38 5,975,554.96 385,681.75 1.81 -25.35 GYD-GC-SS(1) 790.00 1.02 250.38 789.23 732.95 -25.17 6.96 5,975,554.69 385,681.32 1.63 -25.39 GYD-GC-SS(1) 820.00 1.34 281.18 819.22 762.94 -25.19 6.37 5,975,554.68 385,680.73 2.33 -25.12 GYD-GC-SS(1) 856.00 1.83 299.64 855.21 798.93 -24.82 5.45 5,975,555.06 385,679.82 1.95 -24.35 MWD+IFR-AK-CAZ-SC(2) I 949.00 3.80 307.55 948.09 891.81 -22.21 1.72 5,975,557.73 385,676.13 2.15 -20.26 MWD+IFR-AK-CAZ-SC(2) 1,041.00 8.25 312.96 1,039.56 983.28 -15.85 -5.53 5,975,564.19 385,668.97 4.87 -11.18 MWD+IFR-AK-CAZ-SC(2) i I 1,135.00 14.22 315.06 1,131.72 1,075.44 -3.07 -18.63 5,975,577.17 385,656.07 6.36 6.35 MWD+IFR-AK-CAZ-SC(2) 1,229.00 18.59 316.20 1,221.87 1,165.59 15.93 -37.17 5,975,596.45 385,637.83 4.66 31.95 MWD+IFR-AK-CAZ-SC(2) 1,324.00 21.46 318.18 1,311.12 1,254.84 39.81 -59.24 5,975,620.66 385,616.12 3.10 63.54 MWD+IFR-AK-CAZ-SC(2) 1,418.00 21.57 316.72 1,398.57 1,342.29 65.20 -82.55 5,975,646.41 385,593.20 0.58 97.05 MWD+IFR-AK-CAZ-SC(2) 1,513.00 22.76 319.01 1,486.55 1,430.27 91.79 -106.58 5,975,673.35 385,569.58 1.55 131.95 MWD+IFR-AK-CAZ-SC(2) 1,605.00 24.37 322.00 1,570.88 1,514.60 120.18 -129.94 5,975,702.10 385,546.66 2.18 168.11 MWD+IFR-AK-CAZ-SC(2) 1,699.00 26.58 326.44 1,655.74 1,599.46 153.00 -153.51 5,975,735.26 385,523.60 3.11 208.24 MWD+IFR-AK-CAZ-SC(2) 1,792.00 29.98 328.40 1,737.63 1,681.35 190.14 -177.20 5,975,772.76 385,500.48 3.79 252.21 MWD+IFR-AK-CAZ-SC(2) 1,886.00 34.05 331.51 1,817.32 1,761.04 233.29 -202.07 5,975,816.28 385,476.27 4.67 302.01 MWD+IFR-AK-CAZ-SC(2) 1,981.00 38.20 333.79 1,894.05 1,837.77 283.04 -227.74 5,975,866.42 385,451.37 4.59 357.97 MWD+IFR-AK-CAZ-SC(2) 2,075.00 42.28 334.74 1,965.79 1,909.51 337.74 -254.08 5,975,921.51 385,425.86 4.39 418.58 MWD+IFR-AK-CAZ-SC(2) 2,169.00 45.91 335.03 2,033.28 1,977.00 396.96 -281.84 5,975,981.13 385,399.02 3.87 483.83 MWD+IFR-AK-CAZ-SC(2) 2,264.00 49.54 335.21 2,097.18 2,040.90 460.72 -311.40 5,976,045.33 385,370.43 3.82 553.92 MWD+IFR-AK-CAZ-SC(2) 2,358.00 53.54 335.21 2,155.63 2,099.35 527.53 -342.26 5,976,112.60 385,340.60 4.26 627.32 MWD+IFR-AK-CAZ-SC(2) 2,452.00 57.08 332.74 2,209.13 2,152.85 596.95 -376.19 5,976,182.52 385,307.73 4.34 704.48 MWD+IFR-AK-CAZ-SC(2) 2,547.00 58.25 331.49 2,259.94 2,203.66 667.89 -413.74 5,976,254.02 385,271.28 1.66 784.73 MWD+IFR-AK-CAZ-SC(2) 2,630.00 58.30 332.02 2,303.59 2,247.31 730.08 -447.15 5,976,316.71 385,238.82 0.55 855.32 MWD+IFR-AK-CAZ-SC(3) 2,726.07 57.38 331.12 2,354.72 2,298.44 801.60 -485.86 5,976,388.81 385,201.20 1.24 936.65 MWD+IFR-AK-CAZ-SC(3) 2,819.44 56.62 330.95 2,405.58 2,349.30 870.11 -523.78 5,976,457.88 385,164.33 0.83 1,014.95 MWD+IFR-AK-CAZ-SC(3) 2,912.84 55.81 330.93 2,457.51 2,401.23 937.97 -561.49 5,976,526.30 385,127.67 0.87 1,092.58 MWD+IFR-AK-CAZ-SC(3) 3,007.35 55.25 331.25 2,511.00 2,454.72 1,006.17 -599.16 5,976,595.07 385,091.05 0.65 1,170.50 MWD+IFR-AK-CAZ-SC(3) 3,101.98 54.91 332.01 2,565.17 2,508.89 1,074.45 -636.03 5,976,663.89 385,055.23 0.75 1,248.08 MWD+IFR-AK-CAZ-SC(3) 3,196.07 54.87 332.13 2,619.29 2,563.01 1,142.45 -672.08 5,976,732.43 385,020.22 0.11 1,325.04 MWD+IFR-AK-CAZ-SC(3) 3,291.01 54.87 332.90 2,673.92 2,617.64 1,211.33 -707.91 5,976,801.84 384,985.45 0.66 1,402.66 MWD+IFR-AK-CAZ-SC(3) 3,385.12 54.88 333.18 2,728.07 2,671.79 1,279.94 -742.81 5,976,870.97 384,951.60 0.24 1,479.58 MWD+IFR-AK-CAZ-SC(3) 3,480.19 54.93 333.37 2,782.73 2,726.45 1,349.42 -777.79 5,976,940.96 384,917.69 0.17 1,557.31 MWD+IFR-AK-CAZ-SC(3) 1/10/2013 12:21:14PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-47 Project: Western North Slope TVD Reference: Rig:19.5+36.78 @ 56.28ft(Doyonl9) Site: CD1 Alpine Pad MD Reference: Rig:19.5+36.78 @ 56.28ft(Doyonl9) Well: CD1-47 North Reference: True Wellbore: CD1-47PB1 Survey Calculation Method: Minimum Curvature Design: CD1-47PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,575.49 54.93 333.32 2,837.48 2,781.20 1,419.13 -812.78 5,977,011.19 384,883.77 0.04 1,635.24 MWD+IFR-AK-CAZ-SC(3) 3,668.80 54.88 331.94 2,891.13 2,834.85 1,486.92 -847.88 5,977,079.51 384,849.71 1.21 1,711.55 MWD+IFR-AK-CAZ-SC(3) 3,763.24 54.90 329.00 2,945.46 2,889.18 1,554.13 -885.95 5,977,147.28 384,812.67 2.55 1,788.79 MWD+IFR-AK-CAZ-SC(3) 3,858.34 54.88 328.95 3,000.15 2,943.87 1,620.80 -926.05 5,977,214.55 384,773.60 0.05 1,866.54 MWD+IFR-AK-CAZ-SC(3) 3,952.70 54.87 329.30 3,054.45 2,998.17 1,687.04 -965.65 5,977,281.38 384,735.01 0.30 1,943.67 MWD+IFR-AK-CAZ-SC(3) 4,046.68 54.88 329.87 3,108.52 3,052.24 1,753.33 -1,004.57 5,977,348.25 384,697.12 0.50 2,020.52 MWD+IFR-AK-CAZ-SC(3) 4,140.54 54.85 330.54 3,162.54 3,106.26 1,819.94 -1,042.71 5,977,415.43 384,660.00 0.58 2,097.27 MWD+IFR-AK-CAZ-SC(3) 4,234.05 54.85 331.05 3,216.37 3,160.09 1,886.67 -1,080.01 5,977,482.72 384,623.72 0.45 2,173.72 MWD+IFR-AK-CAZ-SC(3) 4,328.64 54.90 331.02 3,270.80 3,214.52 1,954.36 -1,117.48 5,977,550.97 384,587.29 0.06 2,251.09 MWD+IFR-AK-CAZ-SC(3) 4,423.16 54.88 331.19 3,325.16 3,268.88 2,022.06 -1,154.84 5,977,619.22 384,550.97 0.15 2,328.41 MWD+IFR-AK-CAZ-SC(3) 4,519.15 54.92 330.99 3,380.35 3,324.07 2,090.81 -1,192.81 5,977,688.53 384,514.06 0.18 2,406.95 MWD+IFR-AK-CAZ-SC(3) 4,612.32 54.97 330.54 3,433.87 3,377.59 2,157.36 -1,230.06 5,977,755.64 384,477.83 0.40 2,483.21 MWD+IFR-AK-CAZ-SC(3) 4,706.42 54.92 330.64 3,487.91 3,431.63 2,224.46 -1,267.88 5,977,823.31 384,441.04 0.10 2,560.24 MWD+IFR-AK-CAZ-SC(3) 4,800.32 54.91 329.24 3,541.89 3,485.61 2,290.96 -1,306.37 5,977,890.38 384,403.57 1.22 2,637.06 MWD+IFR-AK-CAZ-SC(3) 4,893.89 54.92 329.04 3,595.67 3,539.39 2,356.69 -1,345.65 5,977,956.69 384,365.31 0.18 2,713.59 MWD+IFR-AK-CAZ-SC(3) 4,987.25 54.88 328.93 3,649.35 3,593.07 2,422.15 -1,385.00 5,978,022.74 384,326.95 0.11 2,789.93 MWD+IFR-AK-CAZ-SC(3) 5,082.18 54.91 329.00 3,703.95 3,647.67 2,488.70 -1,425.04 5,978,089.89 384,287.94 0.07 2,867.54 MWD+IFR-AK-CAZ-SC(3) 5,176.55 56.01 329.24 3,757.45 3,701.17 2,555.41 -1,464.94 5,978,157.20 384,249.07 1.18 2,945.23 MWD+IFR-AK-CAZ-SC(3) 5,271.76 55.95 330.52 3,810.72 3,754.44 2,623.67 -1,504.54 5,978,226.04 384,210.52 1.12 3,024.13 MWD+IFR-AK-CAZ-SC(3) 5,366.13 55.97 330.91 3,863.55 3,807.27 2,691.88 -1,542.79 5,978,294.82 384,173.31 0.34 3,102.33 MWD+IFR-AK-CAZ-SC(3) 5,460.54 55.96 330.41 3,916.39 3,860.11 2,760.08 -1,581.12 5,978,363.59 384,136.03 0.44 3,180.56 MWD+IFR-AK-CAZ-SC(3) 5,554.27 55.95 329.97 3,968.86 3,912.58 2,827.46 -1,619.73 5,978,431.55 384,098.45 0.39 3,258.22 MWD+IFR-AK-CAZ-SC(3) 5,649.28 56.01 329.92 4,022.02 3,965.74 2,895.63 -1,659.17 5,978,500.30 384,060.06 0.08 3,336.95 MWD+IFR-AK-CAZ-SC(3) 5,743.95 55.96 329.70 4,074.98 4,018.70 2,963.45 -1,698.63 5,978,568.71 384,021.64 0.20 3,415.41 MWD+IFR-AK-CAZ-SC(3) 5,835.15 55.98 329.95 4,126.02 4,069.74 3,028.79 -1,736.62 5,978,634.62 383,984.66 0.23 3,490.97 MWD+IFR-AK-CAZ-SC(3) 5,928.80 55.97 330.04 4,178.42 4,122.14 3,096.01 -1,775.44 5,978,702.41 383,946.87 0.08 3,568.58 MWD+IFR-AK-CAZ-SC(3) 6,023.07 55.98 330.44 4,231.17 4,174.89 3,163.83 -1,814.22 5,978,770.82 383,909.13 0.35 3,646.70 MWD+IFR-AK-CAZ-SC(3) 6,117.17 55.93 330.50 4,283.85 4,227.57 3,231.67 -1,852.65 5,978,839.23 383,871.75 0.07 3,724.67 MWD+IFR-AK-CAZ-SC(3) 6,211.67 56.15 331.10 4,336.64 4,280.36 3,300.09 -1,890.89 5,978,908.22 383,834.56 0.58 3,803.05 MWD+IFR-AK-CAZ-SC(3) 6,305.50 56.15 330.89 4,388.90 4,332.62 3,368.25 -1,928.67 5,978,976.94 383,797.82 0.19 3,880.97 MWD+IFR-AK-CAZ-SC(3) 6,398.83 56.18 330.83 4,440.87 4,384.59 3,435.96 -1,966.42 5,979,045.21 383,761.11 0.06 3,958.50 MWD+IFR-AK-CAZ-SC(3) 6,493.52 56.31 329.75 4,493.49 4,437.21 3,504.34 -2,005.44 5,979,114.17 383,723.14 0.96 4,037.22 MWD+IFR-AK-CAZ-SC(3) 6,588.37 56.35 328.86 4,546.07 4,489.79 3,572.21 -2,045.74 5,979,182.65 383,683.89 0.78 4,116.12 MWD+IFR-AK-CAZ-SC(3) 6,682.41 56.33 328.67 4,598.20 4,541.92 3,639.14 -2,086.32 5,979,250.18 383,644.33 0.17 4,194.33 MWD+IFR-AK-CAZ-SC(3) 6,776.02 56.31 328.92 4,650.11 4,593.83 3,705.77 -2,126.68 5,979,317.41 383,605.00 0.22 4,272.17 MWD+IFR-AK-CAZ-SC(3) 6,870.08 56.32 329.42 4,702.28 4,646.00 3,772.97 -2,166.79 5,979,385.21 383,565.92 0.44 4,350.40 MWD+IFR-AK-CAZ-SC(3) 6,963.97 56.28 329.84 4,754.37 4,698.09 3,840.37 -2,206.29 5,979,453.19 383,527.46 0.37 4,428.49 MWD+IFR-AK-CAZ-SC(3) 7,058.59 56.34 329.88 4,806.86 4,750.58 3,908.45 -2,245.82 5,979,521.87 383,488.98 0.07 4,507.20 MWD+IFR-AK-CAZ-SC(3) 7,152.95 56.29 330.22 4,859.19 4,802.91 3,976.48 -2,285.02 5,979,590.48 383,450.83 0.30 4,585.71 MWD+IFR-AK-CAZ-SC(3) 7,248.58 56.32 330.18 4,912.24 4,855.96 4,045.53 -2,324.56 5,979,660.12 383,412.34 0.05 4,665.27 MWD+IFR-AK-CAZ-SC(3) 1/10/2013 12:21:14PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-47 Project: Western North Slope TVD Reference: Rig:19.5+36.78 @ 56.28ft(Doyonl9) Site: CD1 Alpine Pad MD Reference: Rig:19.5+36.78 @ 56.28ft(Doyonl9) Well: CD1-47 North Reference: True Wellbore: CD1-47PB1 Survey Calculation Method: Minimum Curvature Design: CD1-47PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (ft) (°I100') (ft) Survey Tool Name 7,342.10 56.39 330.11 4,964.06 4,907.78 4,113.05 -2,363.31 5,979,728.22 383,374.63 0.10 4,743.11 MWD+IFR-AK-CAZ-SC(3) 7,436.72 56.38 330.32 5,016.44 4,960.16 4,181.44 -2,402.46 5,979,797.19 383,336.53 0.19 4,821.90 MWD+IFR-AK-CAZ-SC(3) 7,530.39 56.16 330.48 5,068.45 5,012.17 4,249.17 -2,440.94 5,979,865.49 383,299.10 0.27 4,899.80 MWD+IFR-AK-CAZ-SC(3) 7,623.69 56.10 330.41 5,120.45 5,064.17 4,316.56 -2,479.15 5,979,933,45 383,261.92 0.09 4,977.26 MWD+IFR-AK-CAZ-SC(3) 7,719.28 56.19 329.79 5,173.70 5,117.42 4,385.38 -2,518.72 5,980,002.86 383,223.41 0.55 5,056.63 MWD+IFR-AK-CAZ-SC(3) 7,813.37 56.14 328.31 5,226.09 5,169.81 4,452.40 -2,558.91 5,980,070.48 383,184.24 1.31 5,134.74 MWD+IFR-AK-CAZ-SC(3) 7,907.73 56.12 329.56 5,278.68 5,222.40 4,519.51 -2,599.34 5,980,138.19 383,144.85 1.10 5,213.04 MWD+IFR-AK-CAZ-SC(3) 8,002.32 56.07 328.15 5,331.45 5,275.17 4,586.70 -2,639.94 5,980,205.99 383,105.28 1.24 5,291.48 MWD+IFR-AK-CAZ-SC(3) 8,095.54 56.17 327.29 5,383.42 5,327.14 4,652.13 -2,681.27 5,980,272.03 383,064.95 0.77 5,368.75 MWD+IFR-AK-CAZ-SC(3) 8,190.40 56.17 328.28 5,436.23 5,379.95 4,718.79 -2,723.28 5,980,339.33 383,023.97 0.87 5,447.42 MWD+IFR-AK-CAZ-SC(3) 8,283.77 56.20 329.26 5,488.19 5,431.91 4,785.13 -2,763.50 5,980,406.26 382,984.77 0.87 5,524.94 MWD+IFR-AK-CAZ-SC(3) 8,376.69 56.13 331.44 5,539.93 5,483.65 4,852.20 -2,801.68 5,980,473.90 382,947.62 1.95 5,602.11 MWD+IFR-AK-CAZ-SC(3) 8,472.36 56.21 332.57 5,593.20 5,536.92 4,922.37 -2,838.98 5,980,544.63 382,911.40 0.98 5,681.57 MWD+IFR-AK-CAZ-SC(3) 8,566.91 56.11 331.96 5,645.85 5,589.57 4,991.88 -2,875.53 5,980,614.68 382,875.92 0.55 5,760.08 MWD+IFR-AK-CAZ-SC(3) 8,659.79 56.10 330.81 5,697.65 5,641.37 5,059.56 -2,912.45 5,980,682.91 382,840.03 1.03 5,837.17 MWD+IFR-AK-CAZ-SC(3) 8,754.70 56.15 330.08 5,750.55 5,694.27 5,128.10 -2,951.32 5,980,752.03 382,802.22 0.64 5,915.97 MWD+IFR-AK-CAZ-SC(3) 8,849.02 56.19 329.59 5,803.06 5,746.78 5,195.84 -2,990.69 5,980,820.36 382,763.89 0.43 5,994.30 MWD+IFR-AK-CAZ-SC(3) 8,943.17 56.11 329.32 5,855.50 5,799.22 5,263.18 -3,030.43 5,980,888.29 382,725.19 0.25 6,072.46 MWD+IFR-AK-CAZ-SC(3) 9,037.31 56.10 329.64 5,908.00 5,851.72 5,330.50 -3,070.11 5,980,956.20 382,686.54 0.28 6,150.58 MWD+IFR-AK-CAZ-SC(3) 9,131.68 56.14 330.00 5,960.61 5,904.33 5,398.22 -3,109.50 5,981,024.51 382,648.19 0.32 6,228.91 MWD+IFR-AK-CAZ-SC(3) 9,224.74 56.11 330.09 6,012.48 5,956.20 5,465.17 -3,148.07 5,981,092.03 382,610.64 0.09 6,306.16 MWD+IFR-AK-CAZ-SC(3) 9,319.30 56.07 330.04 6,065.24 6,008.96 5,533.17 -3,187.24 5,981,160.62 382,572.52 0.06 6,384.63 MWD+IFR-AK-CAZ-SC(3) 9,412.97 56.11 330.14 6,117.49 6,061.21 5,600.56 -3,226.00 5,981,228.58 382,534.80 0.10 6,462.35 MWD+IFR-AK-CAZ-SC(3) 9,507.26 56.13 330.25 6,170.06 6,113.78 5,668.48 -3,264.91 5,981,297.09 382,496.93 0.10 6,540.63 MWD+IFR-AK-CAZ-SC(3) 9,601.83 56.14 331.22 6,222.75 6,166.47 5,736.99 -3,303.29 5,981,366.16 382,459.60 0.85 6,619.15 MWD+IFR-AK-CAZ-SC(3) 9,694.97 56.12 331.07 6,274.66 6,218.38 5,804.72 -3,340.62 5,981,434.45 382,423.32 0.14 6,696.49 MWD+IFR-AK-CAZ-SC(3) 9,788.46 56.16 330.28 6,326.75 6,270.47 5,872.40 -3,378.64 5,981,502.70 382,386.33 0.70 6,774.12 MWD+IFR-AK-CAZ-SC(3) 9,883.41 56.11 329.36 6,379.66 6,323.38 5,940.56 -3,418.27 5,981,571.44 382,347.75 0.81 6,852.94 MWD+IFR-AK-CAZ-SC(3) 9,978.29 56.31 329.75 6,432.43 6,376.15 6,008.54 -3,458.23 5,981,640.02 382,308.84 0.40 6,931.77 MWD+IFR-AK-CAZ-SC(3) 10,070.26 56.34 330.27 6,483.43 6,427.15 6,074.83 -3,496.48 5,981,706.88 382,271.60 0.47 7,008.29 MWD+IFR-AK-CAZ-SC(3) 10,166.12 56.31 330.49 6,536.58 6,480.30 6,144.18 -3,535.91 5,981,776.82 382,233.23 0.19 7,088.06 MWD+IFR-AK-CAZ-SC(3) 10,260.96 56.30 330.86 6,589.19 6,532.91 6,212.97 -3,574.56 5,981,846.19 382,195.65 0.32 7,166.97 MWD+IFR-AK-CAZ-SC(3) 10,354.18 56.59 330.95 6,640.72 6,584.44 6,280.86 -3,612.33 5,981,914.63 382,158.91 0.32 7,244.65 MWD+IFR-AK-CAZ-SC(3) 10,448.00 60.06 330.70 6,689.98 6,633.70 6,350.56 -3,651.25 5,981,984.91 382,121.06 3.71 7,324.49 MWD+IFR-AK-CAZ-SC(3) 10,542.14 62.10 330.35 6,735.50 6,679.22 6,422.29 -3,691.80 5,982,057.25 382,081.62 2.19 7,406.88 MWD+IFR-AK-CAZ-SC(3) 10,636.64 64.44 329.64 6,778.00 6,721.72 6,495.37 -3,734.01 5,982,130.96 382,040.54 2.57 7,491.26 MWD+IFR-AK-CAZ-SC(3) 10,722.58 67.26 330.52 6,813.16 6,756.88 6,563.33 -3,773.11 5,982,199.50 382,002.48 3.41 7,569.66 MWD+IFR-AK-CAZ-SC(3) 10,780.44 67.89 330.91 6,835.23 6,778.95 6,609.98 -3,799.27 5,982,246.54 381,977.03 1.25 7,623.14 MWD+IFR-AK-CAZ-SC(4) 10,858.46 69.89 331.60 6,863.33 6,807.05 6,673.79 -3,834.27 5,982,310.87 381,943.01 2.69 7,695.92 MWD+IFR-AK-CAZ-SC(4) 10,950.60 70.81 330.52 6,894.31 6,838.03 6,749.73 -3,876.26 5,982,387.43 381,902.19 1.49 7,782.69 MWD+IFR-AK-CAZ-SC(4) 1/10/2013 12:21:14PM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD1-47 Project: Western North Slope TVD Reference: Rig:19.5+36.78 @ 56.28ft(Doyonl9) Site: CD1 Alpine Pad MD Reference: Rig:19.5+36.78 @ 56.28ft(Doyonl9) Well: CD1-47 North Reference: True Wellbore: CD1-47PB1 Survey Calculation Method: Minimum Curvature Design: CD1-47PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,010.00 70.81 330.52 6,913.84 6,857.56 6,798.57 -3,903.87 5,982,436.68 381,875.33 0.00 7,838.79 PROJECTED to TD 1/10/2013 12:21:14PM Page 6 COMPASS 2003.16 Build 69 0 w\�\711//7 ,711!,t, THE STATE Alaska Oil and Gas ���`' � '� °fALAS� Conservation Commission , tits GOVERNOR SEAN PARNELL 333 West Seventh Avenue OSP Anchorage, Alaska 99501-3572 AL Main: 907.279.1433 Fax: 907.276.7542 Robert Blakney Completions Engineer ConocoPhillips Alaska, Inc. I 2, © 0 3 P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD 1-47 Sundry Number: 313-050 Dear Mr. Blakney: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ,-)0-( V-L---- Cathy P oerster Chair DATED this? day of February, 2013. Encl. n RECEIVED STATE OF ALASKA , ALASKA OIL AND GAS CONSERVATION COMMISSION V FEB 0 1 2013 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request Abandon r Plug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend r Plug Perforations r Perforate r Rill Tubing r lime Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate w Aker casing r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r . Exploratory r 212-083-0 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20659-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Witt planned perforations require spacing exception? Yes r No t7, CD1-47• 9.Property Designation(Lease Number): \100 10.Field/Pool(s): ADL 25558,25536, 2cssq ).\1.11 Colville River Field/Alpine 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): 14120 6974 •10804' ' 11118' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 78' 16 114' SURFACE 2634 11.75 2670' INTERMEDIATE#1 8260 9.625 10753' INTERMEDIATE#2 1060 7 11410' LINER 3073 4.5 14090' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): from 10960'-14067' 3.5 L80 _ 11056 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKERS-BAKER PREMIER PACKER 3.5"X 7" • MD=10722 TVD=6813 SSSV-CAMCO TMAXX-5E • MD=2118 TVD=2118 12.Attachments: Description Summary of Proposal r . 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development F. Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/15/2013 Oil w . Gas r WDSPL r Suspended r i 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing Is true and correct to the best of my knowledge. Contact: Robert Blakney @ 265-6417 Email: Robert.G.Blaknev(8rconocoohillios corn Printed Name ertTitle: Completions Engineer Signature Phone:265-6417 Dale //3i/8 Commission Use Only Sundry Number 3...r^ n Conditions of approval: Notify Commission so that a representative may witness Q�J Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r RSr .vsb FEB 0 7 2013 Other: G;lpp Spacing Exception Required? Yes ❑ No a Subsequent Form Required: //6 — 4 z i( APPROVED BY `7" ad? Approved by: /-.rte`4COMMISSIONER THE COMMISSION Date: -1 l� Approved application is valid for 12 months from the date of approval. Form 10-403(Revised 10/2012) Submit Form and Attachments In Duplicate 17Z— \fib 013 ORIGINAL �, 1 ORIGINAL z/57/3 ' , . ,�`NJ CD1 - 47 Sundry Application Drilling for CD1 -47 was completed in January of 2013 targeting the Alpine C formation. The well was completed with 3.5" tubing. We will stimulate the Alpine C formation with a 5 stage fracture treatment using bioballs to obtain diversion and placing -600,000#'s of CarboLite 16/20. If a successful stimulation is achieved we expect the increased production to be 150 bpd in 2013. Proposed Procedure: Schlumberger Pumping Services: (Alpine C Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 11 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater(approx. 4950 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 8,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 240 bbl breakdown stage (25# linear gel, WF125) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 40 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 7500 psi. Stage 1 • 280 bbls YF130FX-D Pad • 92 bbls YF130FX-D w/2 ppa 16/20 Carbolite • 170 bbls YF130FX-D w/4 ppa 16/20 Carbolite • 153 bbls YF130FX-D w/4 ppa 16/20 Carbolite • 199 bbls YF130FX-D -D w/ 7 ppa 16/20 Carbolite • 15 Spacer • Bioball diversion Stage 2 • 280 bbls YF130FX-D Pad • 92 bbls YF130FX-D w/2 ppa 16/20 Carbolite • 170 bbls YF130FX-D w/4 ppa 16/20 Carbolite • 153 bbls YF130FX-D w/4 ppa 16/20 Carbolite • 199 bbls YF130FX-D -D w/7 ppa 16/20 Carbolite RB • 15 Spacer • Bioball diversion Stage 3 • 280 bbls YF130FX-D Pad • 92 bbls YF130FX-D w/2 ppa 16/20 Carbolite • 170 bbls YF130FX-D w/4 ppa 16/20 Carbolite • 153 bbls YF130FX-D w/4 ppa 16/20 Carbolite • 199 bbls YF130FX-D -D w/ 7 ppa 16/20 Carbolite • 15 Spacer • Bioball diversion Stage 4 • 280 bbls YF130FX-D Pad • 92 bbls YF130FX-D w/ 2 ppa 16/20 Carbolite • 170 bbls YF130FX-D w/4 ppa 16/20 Carbolite • 153 bbls YF130FX-D w/4 ppa 16/20 Carbolite • 199 bbls YF130FX-D -D w/7 ppa 16/20 Carbolite • 15 Spacer • Bioball diversion Stage 5 • 280 bbls YF130FX-D Pad • 92 bbls YF130FX-D w/2 ppa 16/20 Carbolite • 170 bbls YF130FX-D w/4 ppa 16/20 Carbolite • 153 bbls YF130FX-D w/4 ppa 16/20 Carbolite • 199 bbls YF130FX-D -D w/ 7 ppa 16/20 Carbolite • Flush with 71 bbls of linear fluid (WF130) and freeze protect • Total Sand: Approx. 600,000 lbs 16/20 Carbolite 12. Monitor the surface pressure fall-off at the end of the job for 30 minutes, if the well does not screen out. 13. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 14. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). 15. Flowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (initial flowback fluids to be taken to CD1-01 disposal well until they are clean enough for production.) Cement Evaluation of CD1 -47 and wells within 1/4 mile of CD1 -47 CD1 -47: 7" Casing cement job was pumped on 12/15/2012. The cement pumped was 15.8 ppg Class G cement, displaced by 10.5 ppg mud at 2-4 bpm. A pressure test was performed at 1980 psi for 14 minutes and was deemed good. Data indicates a competent cement Job. RB CD1 - 35: 7" Casing cement job was pumped on 5/14/1999 as designed, indicating competent cement operations. The cement was pumped and displaced by 9.2 ppg brine. A pressure test was performed at 3500 psi for 30 minutes and deemed good. Summary Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect wells within a % mile radius or any other nearby well. RB iy. . , t WNS CD1-47 C.011000PFUiiips /$ Well Attributes Max Angle&MD TD Inc. Wellbore APAWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) Alaska, ips 501032065900 ALPINE PROD 93.08 11,611.16 14,120.0 Cianoci(Pl -'-° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:TRDP Last WO: 1/10/2013 Well Confet HORIZONTAL-CD1-47,1/25/2013 2:35:38 PM - - Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:NEW WELL osborl 1/22/2013 HANGER,31 ' 2 Casing Strings '-• Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...(String Top Thrd CONDUCTOR 16 15.062 36.0 114.0 114.0 62.50 H-40 WELDED Insulated 34" Casing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 113/4 10.772 36.5 2,670.2 2,325.0 60.00 L-80 BTCM CONDUCTOR Casing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(ND)...String Wt...String...String Top Thrd Insulated 34•, INTERMEDIATE#1 9 5/8 8.799 2,492.7 10,753.0 6,824.6 40.00 L-80 Hyd 521 36-114 11•111 Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd INTERMEDIATE#2 7 6.276 33.5 10,362.6 6,645.0 26.00 L-80 BTC-M IMMO IIIII!. Tie back. .SSSV.2.118 .1 - Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd INTERMEDIATE#2 7 6.276 10,349.7 11,409.9 6.982.4 26.00 L-80 Tenads Blue Ii . Lower Casing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(ND)...String WE..String... String Top Thrd LINER 41/2 3.958 11,016.9 14,090.0 6.975.0 12.60 L-80 [ Hydril 563 TI finer Details Top Depth SURFACE, (TVD) Top Incl Nomi... 37-2,870 Top(ftKB) (ftKB) (°) Item Description Comment ID(in) GAS LIFT, 11,016.9 6,909.3 78.40 PACKER HRD LINER TOP ZXP PACKER 4.340 4.534 INN11,036.9 6,913.3 78.29 NIPPLE 'RS'PACKOFF SEAL NIPPLE 4.250 . 11,039.8 6,913.9 78.28 HANGER 'DG'FLEX LOCK LINER HANGER 4.350 GAS LIFT, _ il EA 11,049.1 6,915.8 78.22 SBR SL BORE EXTENSION 4.000 8,510 - 11,669.9 6,985.7 93.02 Swell Packer TAM FreeCap Swell packer FSC-11 w/5.75"OD Cementralizer 3.958 11,726.3 6,983.5 92.09 Swell Packer TAM FreeCap Swell packer FSC-11 w/5.75"OD Cementralizer 3.958 INTERMEDIATE ' , Tubing Strings a2 T beck., . .ol Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd 3410,363 ITUBING 3 1/2 2.992 31.1 11,055.8 6,917.1 9.30 L80 EUE MOD j-I --0 4.5"x3.5"@117' I I Completion Details Top Depth L (ND) Top Incl Noml... GAS LIFT,_ (. Top(ftKB) (RKB) (°) Item Description Comment ID(In) 10'4x4 31.1 31.1 -0.02 HANGER FMC TUBING HANGER 3.900 114.7 114.7 -0.41 XO-Reducing Crossover 4-1/2"IBT-m box x 3.1/2'EUE-m pin 3.500 I I 2,118.1 1,996.6 43.96 SSSV 3-1/2'TRMAXX-5E SSSV w/2.812""X"profile w/1/4"control line(5.176" 2.812 OD) GAUGE,10,699 10,699.3 6,803.9 66.50 GAUGE SLB BHP Guage,3-1/2' 2.992 10,722.3 6,813.0 67.25 PACKER BAKER PREMIER PACKER 2.870 PACKER, 10,80a7 6,841.8 67.81 SLEEVE BAKER CMD SLIDING SLEEVE 2.812 GAS LIFT, 10,947.7 6,890.7 73.74 Blast Joint BLAST JOINT(1) 2.867 10,745 f 11,007.2 6,907.4 78.46 NIPPLE HES"X"LANDING NIPPLE 2.813"ID 2.813 INTERMEDIATE Cl. 11,014.9 6,908.9 78.41 SEAL ASSY BAKER3-1/2"GBH-22 LOCATING SEAL ASSEMBLY(39.65'to 5"OD 2.970 2,493-10.753 locator) SLEEVE, Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PLUG.10,804 -Top Depth (ND) Top Incl Top(MB) (ftKB) (°) Description Comment Run Date ID(in) 10,803.7 6,841.8 67.81 PLUG XX PLUG wf'X"lock w/equalizing end cap SET IN CMD 1/9/2013 0.000 (PERF, SLEEVE 2.81"profile."'COULD BE PRESSURE BELOW 10,960-10.974 I , PLUG* 11,118.0 6,929.7 77.18 PLUG COMPOSITE BRIDGE PLUG-LEAKING IN LOWER 12/28/2012 0.000 NIPPLE,11,007 COMPLETION SEAL i0ASSY,,Perforations&Slots shoe 011 Top(ND) Btm(TVD) Dans Top(ftKB)Btm(ftKB) (RKB) (RKB) zone Date (eh.- Type Comment 1 10,960.0 10,974.0 6,894.2 6,901.1 1/3/2013 5.0'IPERF All shots fired t PLUG.11,118 SIFifilii 11,792.1 11,796.9 6,980.9 6,980.8 12/28/2012 1.0 PERFP 12,119.1 12,123.9 6,981.7 6,981.6 12/28/2012 1.0 PERFP ` 12,443.1 12,447.9 6,978.3 6,978.2 12/28/2012 1.0 PERFP INTERMEDIATE e2 100Lower, 12,765.7 12,770.4 6,972.3 6,972.2 12/28/2012 1.0 PERFP 10,350-11,410 13,092.8 13,097.5 6,975.9 6,975.9 12/28/2012 1.0 PERFP 13,412.1 13,416.8 6,985.4 6,985.4 12/28/2012 1.0 PERFP ` 13,732.8 13,737.6 6,980.9 6,980.9 12/28/2012 1.0 PERFP 14,062.5 14,067.2 6,976.2 6,976.0 12/28/2012 1.0 PERFP PERFP, 1 El I 11,792-11.797 Mandrel Details PERFP, 12119-12124 I I. Top Depth Top Port 5,.. (TVD) Incl OD Valve Latch Size TRO Run PERFP, i•I N...Top(MB) (ftKB) CI Make Model (in) Sery Type Type (in) (psi) Run Date Corn... 12.443-12.448 1 4,534.5 3,389.2 55.01 Camco'KBMG 1 GAS LIFT DMY BK-5 0.000 0.01/7/2013 PERFP. I ii 12 8,510.4 5,614.3 56.12 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/6/2013 12,766-12.770 3 10,483.9 6,707.0 60.66 Camco KBMG 1 GAS LIFT SOV BEK 0.000 0.0 1/6/2013 DCK2 PERFP, I■I 4 10,744.8 6,821.3 66.91 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0'1/6/2013 13,093-13.098 13,412-1 PERFP,3.417 I IN I PERFP, 1 IN I 13,733-13.738 PERFP, 14,082-14.087 Ii LINER, 11,017-14.090-\ TD(C0147), 14,120 a) mO0 2 0 c co 0 LL m U E a) fi, c a, . .... 0_ p Q N lt7 ti 0 • N - Od000v' r Min ,n is ,:r.U H'VI N M c' if) i3O . do oda, -i-) -.-1 = r kJ N d ,::r.VI H s-1 s-1 e-I .-i N i l 2 . , O O N Ni in CD to if) d M NJ NJ s--1 d N a ¢ LI) tr) U 1 Ln LC) .1., IA 131 01N 1,13 cam*. fl O .4 O t0 -i r I N in in 0) U a r* M M y o '� ■ - in co CD N N Cna) CE. ao_ M 0' Ln ECD�i Q) 41 d M Lf i d O .w) } > cp o 4., 1+ .--1N �7' 07 M Cl) H a) U) Di co, NJ N SD N 2 5, 4-1 in o O o o r U Q CO V �+ o 0000; Ln. ~ C W ° •-I sCa � CD 0 CO OD03 L 3 coQ V �-i O M v' r a1 '� N Q o U A � ' s-, s� O) D Cl) N CV CO 11 W14 N aaaooLn co •i- co O Lim � � o opo O o tit M s1NINNir1 co cNi LL 'OCD NJ r-4 CI .., 9 OD s-I 01 q" D' ,i) _. rt N 01 Cr lD LO s-1 •-1 O 171 '4' 03 r Tr. 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Rz:I VVV • Minimum pressure rating on all surface treating lines r.. ›XL718:110,000 psi • Main treating line PRV is set to 95%of max treating pressure . • IA parallel PRV set to 3500 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV y, • Tree saver used on all fracs rated for 15,000 psi. 4 AS N 1.0411. rs Y A N )121.11{Stand 0 I Pop-Off Tar& `m ' -, t N Pump Truct Pop-On Tank gm nVS:R`"' -7vr *? F- 'l r e da sl y m O Lam A Frac Pump P'- --{.a">. Pr 1 F'd.:Pump 0 Frac Pump h-el '®}� N [..c:J.: It J Frac Pump Frac Pump [-AI '- f ilr.l Frac Pump RB . . Stimulation Tree Saver OPEN POSITION CLOSED POSITION IF,m,..,;: io % , - ,-.-.- ' -..„Ri., ;.v...v.-,„•,-) FRAC CONNECTEDAE . . , i I c''' ,,, '' , : / 4,- ,, .,.;. ,/_,_- . - , , , - • , %. -1,- . %-r- . , / . . REMOTE OPERATED ""'. .,,, •, / 4\i DOE,„ 1. ,,.MANUAL OPERAtt b . , ,i Stinger Stinger N, 7 , , 4 ir 17- , , , , ..... .„..., • ....._ VENT Nik S:'.1.if: *'.r:1:!44':'::\I: . / %. .• :',;,‘, k• -,. Y AND ..'''. •r ' VENT VALVE WELLHEAD VAt VIS 30 : ®,. • , , • t: WELLHEAD VALVES CLOSED • -,,, k: It .,4' • QUAD RACKOFF ASSEMBLY IN • vat i- MACE IN rueiNG s_,.,..,. ......`,.,A TUSONG 1 • The universal tool is rated for 15,000 psi and has 84” of stroke. • Tool ID 2.25" down 4 '/2 tubing and 1.75" down 3 '/2 tubing. • Max rate with 2.25"mandrel is 60 bpm and with 1.75"mandrel 36 bpm RB 0A w p Q (I) C 12 Qz — w' _ 0 �1 a � a � Zzzzz 'sv •MIMI� 63 a E U o �n � a t'3 -1; _ U . 0 `6 0 0 0 o LLi W LLI W W N cam) /yam N Q1 U g > > > > > m /� z m �1 m '2. Q Z e a0i a0i a0i 9. 1- 1- 1- I- F- Q 3 o / U w o a) e -o . UUUUU 0 c '0- C) SSV) a co o = QQQQQ0 CLL ca a LL ti 2 0 } + +• • 1 4 1 1 • ❑ 0 cov m U 0. J Z (.. 7••! • , o3 03 N C•1 N CV ---r — • mw a• .. ...:‘,......‘i .......r. • • •'..• ,y + , h. 0 ' • m M CO M 0 . • U E. • .•. • •oU • • M • P..)D / m U•'' O-3 a a a M b • • o - ff ..•••• ... U+ r • • • • Ca Q 4_. 0- CO •4. • o 7 U+, o, N. .... :5:. U U.'• • •py-�• _. WELL LOG TRANSMITTAL Z� z•o$3 To: Alaska Oil and Gas Conservation Comm. January 4, 2013 Attn.: Makana Bender 2-e-e-45( ) IV' 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 C) RE: Correlation Logs (x2): CD1-47 Run Date: 12/31/2012 & 01/02/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline& Perforating, 6900 Arctic Blvd.,Anchorage, AK 99518 CD 1-47 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20659-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 Klinton Wood@halliburton.com Date: Signed: PARNELL,GOVERNOR ALASKA OIL AND GASslillGE oF R, /SEAN 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSIONANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 Chip Alvord FAX (907)276-7542 Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Alpine Oil Pool, CD 1-47 ConocoPhillips Alaska, Inc. Permit No: 212-083 Surface Location: 551.39' FNL, 3028.91' FEL, Sec. 5, T11N, R5E, UM Bottomhole Location: 4685.47' FNL, 4251.08' FEL, Sec. 19, T12N, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, P9t )(4^ . Cathy P. Foerster Chair, Commissioner DATED this day of June, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA A OIL AND GAS CONSERVATION COM'. )ION JUN 1 9 2012 PERMIT TO DRILL 20 AAC 25.005 AOGCC 1 a Type of Work. 1 b. Proposed Well Class: Development-Oil Q • Service- Winj ❑ Single Zone Q 1 c.Specify if well is proposed for. Drill ❑� • Redd] ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name 5. Bond: Blanket 2 Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No 59-52-180 • CD1-47 • 3 Address: 6. Proposed Depth: 12.Field/Pool(s): P 0 Box 100360 Anchorage,AK 99510-0360 MD: 16612' TVD: 6960' Colville River Field 4a. Location of Well(Governmental Section): 7 Property Designation(Lease Number): . , Alpine Pool , Surface: 551.39'FNL,3,028.91'FEL,Sec 5,T11 N, R5E, UM AO_�-S5 ADL 25558,25538/(,4.$ Top of Productive Horizon: 8 Land Use Permit: 13.Approximate Spud Date. 4014.15'FNL, 1798.35'FEL,Sec 30,T12N,R5E, UM Tobin#'s 932102,932100 8/1/2012 Total Depth: 9 Acres in Property- 14 Distance to Nearest Property. 4685.47'FNL,4251.08'FEL,Sec 19,T12N,R5E, UM 4907 3 miles 4b Location of Well(State Base Plane Coordinates-NAD 27). 10. KB Elevation above MSL: 55 8 feet• 15 Distance to Nearest Well Open Surface. x- 385675 . y- 5975580 . Zone- 4 GL Elevation above MSL. 19 5 feet• to Same Pool• CD1-35,1012._ ft. 16. Deviated wells: Kickoff depth. 250 feet - 17 Maximum Antics ted ressures in psig(see 20 AAC 25.035) 2 br`'�- 15� L.G�.it Maximum Hole Angle. 90 degrees . Downhole:..3690' /s Surface: _2462r ..7,‘460 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 16" 65# H-40 Weld 81' 37' 37' 114' 114' Pre-installed 14" 11.75" 60# L-80 BTCM 2634' 37' 37' 2670' 2350' 801 sx ASL,246 sx Class G 11.75" 9.625" 40# L-80 Hyd.521 8166' 2530' 2211' 10766' 6822' 684 sx"G"12.2 ppg,328 sx @15.8 8.5" 7" 26# L-80 Tenaris B. 11346' 37' 37' 11383' 6980' 152 sx Class G 15.8 ppg to Inr.Top j 3.5" 9.3# L-80 EUE 11346' 37' 37' 11183' 6960' Production Tubing 1 6 7 4 5" 12.6# L-80 IBT-M 5429' 11183' 6960' 16612 6960 Uncemented ,,,LF:� 19 PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) bade— Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effect.Depth MD(ft): Effect. Depth TVD(ft). Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact 0%6,44LcL.c-N4-) - — Printed Name .�,`/� , / 'FJ(L GH-7 0 S�,�c+ �a S'N c' i)K t l l�N c cN c,i n I E7� Title PTL-yMW4 J Signature Phone 2(c (-2_4-1 }- Date (e. 1I E 1/2 Commission Use Only Permit to Dnll ��Q API Number: Permit Approval j _ I See cover letter for other Number: 2 50-�/ tn '�� ' Date: `/j/_ �/1 requirements. Conditions of approval: If box is checked,well not be used to explore for,test,or produce coalbed ethane,gas hydrates,or gas contained in shales: L t Other: A 3 500 ps 130(3les 1 Samples req'd: Yes❑ No Fi' Mud log req'd. Yes ❑ No 2' Art"' J T,54" C ) HZS measures: Yes❑ No[✓7 Directional svy req'd: Yes 10 No ❑ •s- 2 500 /Osi, �"`•� — I)i✓c.r+c4- w c„.:a c.9 (,..e-� Z o AAG ZS:O 3 5 ( 4)Cz) APPROVED BY THE COMMISSION DATE. G _213 -?2_ Cf?s__. 6,-77.a, ji. COMMISSIONER Form 10-401(Revised 7/2009) This permit is valid for-24 months frbLtie date of approval(20 AAC 25.005(g)) Subma in Duplicate ConocoPhillips Alaska,Inc. Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 June 18th,2012 RECEIVED Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue,Suite 100 1 202 2 Anchorage,Alaska 99501 Re: Application for Permit to Drill CD1-47 AOGCC Dear Sir or Madam: ConocoPhillips Alaska,Inc.hereby applies for a Permit to Drill an onshore production well from the CD1 drilling pad. The intended spud date for this well is 08/01/12. It is intended that Doyon Rig 19 be used to drill the well. CD1-47 is planned to be a horizontal Alpine C sand producer. The intermediate hole will be drilled in 2 sections to mitigate shale instability. The 10-5/8"hole—underreamed to 11-3/4"will be drilled to the upper Kalubik and landed at an inclination of 68 deg.and cased with a 9-5/8"liner.The Qannik sands will need to be cemented through a single stage cement job to ensure that cement is brought to 500 feet above the top of the reservoir. The second intermediate will be drilled with a 6 x 8-1/2"steerable drilling liner system down to the Alpine C sand.This interval will build from 68 to 80 deg. inclination,at which point,the inner BHA will be pulled out and the 7"liner cemented in place.After setting and cementing the 7" intermediate liner,a tie back liner to surface will be run to complete the intermediate casing string. The 6"horizontal section will be geo steered in the Alpine C sand at 90 deg.inclination and the well completed as a producer with blank/perforated liner. It is requested that a waiver of the diverter requirement under 20 AAC 25.035(h)(2)is granted. At CD1,there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. — A a Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005(a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035(a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact J.G. Samuell at 265-6309 (John.G.Samuell@conocophillips.com)or Chip Alvord at 265-6120. Sincerely, cc: CD1-47 Well File/Sharon Allsup-Drake ATO 1530 ` Rob Stinson ATO 1728 Chip Alvord ATO 1570 J.G. Samuell Jack Walker ATO 1740 Drilling Engineer Lanston Chin Kuukpik Corp / lion for Permit to Drill,Well CD1-47 Saved: 18-Jun-12 CD1-47 Application for Permit to Drill Document Drilling &Wells ConocoPhillips Table of Contents 1. Well Name 3 Requirements of 20 AAC 25.005(f) 2. Location Summary 3 Requirements of 20 AAC 25.005(c)(2) Requirements of 20 AAC 25.050(b) 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 4. Drilling Hazards Information 4 Requirements of 20 AAC 25.005(c)(4) 5. Procedure for Conducting Formation Integrity Tests 5 Requirements of 20 AAC 25.005(c)(5) 6. Casing and Cementing Program 5 Requirements of 20 AAC 25.005(c)(6) 7. Diverter System Information 5 Requirements of 20 AAC 25.005(c)(7) 8. Drilling Fluid Program 6 Requirements of 20 AAC 25.005(c)(8) 9. Abnormally Pressured Formation Information 7 Requirements of 20 AAC 25.005(c)(9) 10. Seismic Analysis 7 Requirements of 20 AAC 25.005(c)(10) 11. Seabed Condition Analysis 7 Requirements of 20 AAC 25.005(c)(I 1) 12. Evidence of Bonding 7 Requirements of 20 AAC 25.005(c)(12) CD 1-47 APD Page 1 of 15 Printed: 18-Jun-12 tion for Permit to Drill,Well CD1-47 Saved: 18-Jun-12 13. Proposed Drilling Program 7 Requirements of 20 AAC 25.005(c)(13) 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 8 Requirements of 20 AAC 25.005(c)(14) 15. Attachments 8 Attachment 1 Directional Plan 10 Attachment 2 Drilling Hazards Summary 11 Attachment 3 Well Schematic 13 Attachment 4 Cement Summary 14 CD 1-47 APD Page 2 of 15 Printed: 18-Jun-12 L. tion for Permit to Drill,Well CD1-47 Saved: 18-Jun-12 1. Well Name (Requirements of 20 AAC 25.005(f)) The well for which this application is submitted will be designated as CD1-47. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This well is planned for Location at Surface 551.39' FNL, 3,028.91' FEL, Sec 5, T11N,R5E,UM NAD 1927 RKB Elevation 55.8' AMSL - Northings: 5,975579.96 Eastings:385,674.75 Pad Elevation 19.5' AMSL . Location at Top of Productive Interval 4014.15'FNL, 1798.35' FEL, Sec 30,T12N,R5E,UM (Heel) NAD 1927 Measured Depth, RKB: 11,383.1' Northings:5,982,738.94 Eastings:381,711.51 Total Vertical Depth, RKB: 6,980.8' Total Vertical Depth, SS: 6925.0' Location at Total Depth 4685.47' FNL, 4251.08' FEL, Sec 19,T12N,R5E,UM (Toe) NAD 1927 Measured Depth,RKB: 16,612.90' Northings: 5,987,386.09 Eastings: 379,314.70 Total Vertical Depth,RKB: 6,960.8' Total Vertical Depth, SS: 6905.0' Requirements of 20 AAC 25.050(b) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) It is requested that a waiver of the diverter requirement under 20 AAC 25.035(h)(2)is granted. At CD1,there has not been a significant indication of shallow gas or gas hydrates above the C30 where casing will be set. �--� PLor c..q � S S; , Please reference BOP schematics on file for Doyon 19. 6 rfs . (t Sctr t. c4-S;� ft- CA 6 Z7/z,, '� Iv 6/7- CD1-47 APD Page 3 of 15 �. rN Printed: 18-Jun-12 Won for Permit to Drill,Well CD1-47 Saved: 18-Jun-12 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure(ASP)during drilling of this well: Casing Csg Setting Depth Fracture Pore pressure ASP Drilling Size(in) MD/TVD(ft) Gradient(ppg) (psi) (psi) 16 114/114 10.9 52 53 11.75 2,670/2,350 14.5 1,063 1,537 9.625 10,766/6,822 12.5 3,087 2,460 7 11,383/6,980 13.0 3,158 2,453 ii'44" N/A 16,613 6,960 16.0 t 49) N/A PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE(ASP) ASP is determined as the lesser of 1)surface pressure at breakdown of the formation casing seat with a gas gradient to the surface,or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP= [(FG x 0.052)-0.1]D Where: ASP=Anticipated Surface pressure in psi FG=Fracture gradient at the casing seat in lb/gal 0.052=Conversion from lb./gal to psi/ft 0.1 =Gas gradient in psi/ft D=true Vertical depth of casing seat in ft RKB OR 2) ASP=FPP-(0.1 x D) Where: FPP=Formation Pore Pressure at the next casing point FPP=0.4525 x TVD 1. ASP CALCULATIONS 1. Drilling below conductor casing(16") ASP= [(FG x 0.052)-0.1] D _ [(10.9 x 0.052)-0.1] x 114=53 psi OR ASP=FPP-(0.1 x D) = 1063-(0.1 x 2350')=828 psi 2. Drilling below surface casing(11-3/4") ASP= [(FG x 0.052)-0.1] D = [(14.5 x 0.052)-0.1] x 2350= 1537 psi OR ASP=FPP-(0.1 x D) =3087-(0.1 x 6822')=2405 psi 3. Drilling below intermediate liner(9-5/8") ASP= [(FG x 0.052)-0.1]D = [(12.5 x 0.052)-0.1]x 6822=3752 psi OR ASP=FPP-(0.1 x D) =3158-(0.1 x 6980')=2460 psi 4. Drilling below intermediate casing(7") CD 1-47 APD Page 4 of 15 Printed: 18-Jun-12 f \ ation for Permit to Drill,Well CD1-47 Saved: 18-Jun-12 ASP= [(FG x 0.052)—0.1] D = [(13.0 x 0.052)—0.1] x 6980=4020 psi OR ASP=FPP—(0.1 xD) =3149—(0.1 x 6960')=2453 psi; t/ (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. (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)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementing Program Csg/Tbg Hole Weight Length Top MD/TVD Btm MD/TVD OD(in) ���� (lb/ft) Grade Conn. aft) (h) (ft) Cement Program 16 42 65 H-40 Welded 81 Surf 114/114 Cemented 4/26/03 Cement to Surface with c� 11-3/4 14 60 L-80 BTCM 2,634 Surf 2,670/2,350 801 sx ASLite Lead 10.7 ppg, 5� 246 sx Class"G"Tail Slurry 15.8 ppg 10-5/8 684 sx Class G Lead at 12.2 ppg w/TOC at T. 9-5/8 x 11- 40 L-80 HYD 521 166 2,520/2,211 10,766/6,822 5233'MD(Qannik Isolation) 3/4 521 328 sx Class G Tail at 15.8 ppg 1i 6 x 8- 1/2 26 L 80 Tenaris 153 sx Class G 15.8 ppg cemented to liner 7 Blue 11346 Surf 11,383/6,980 top at 10,383'MD 3 1/2 6 9.3 L-80 8R�M 11,196 Surf 11,233/6,960 n/a 4 1/2 6 12.6 L-80 IBT-M 5,429 11,183/6,960 16,612/6,960 Open hole uncemented liner w/pre perf pups 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) It is requested that a waiver of the diverter requirement under 20 AAC 25.035(h)(2)is granted. This will be the 14th drilling season of drilling on CD1 pad and there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. CD1-47APD Page 5 of 15 Printed: 18-Jun-12 t L. ation for Permit to Drill,Well CD1-47 Saved: 18-Jun-12 8. Drilling Fluid Program (Requirements of 20AAC 25.005(c)(8)) Surface Intermediate#1 Intermediate#2 Production Hole 14"Hole 10.625"x11.75"hole 6"x 8.5"SDL 6„ 11.75"Casing 9.625"Liner 7"Casing Density 8.8—10.0 ppg 9.6—10.5 ppg 10.5 ppg 10.0-10.6 ppg PV 10-25 10-25 15-22 YP 20-60 15-25 15-25 10- 15 Funnel Viscosity 100—200 Initial Gels 4—8 6—10 9- 12 10 minute gels <18 <20 12-20 API Filtrate NC— 10cc/30 4-12cc/30 min 4-12cc/30 min <2 cc/30 min HPHT Fluid Loss at 160 min 8.0—10.0 2-4 cc/30 min PH 8.5—9.0 9.0— 10.0 9.0-10.0 n/a %by wt CaC12 n/a n/a n/a 25 Oil/Water Ratio n/a n/a n/a 80/20 Surface Hole: A standard high viscosity fresh water/gel spud mud is recommended for the surface interval. Keep flow line viscosity at±200 sec/qt while drilling and running casing.Reduce viscosity prior to cementing.Maintain mud weight<9.6 ppg by use of solids control system and dilution where necessary. Intermediate#1: Fresh water gel/polymer mud system.Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation,particularly after the reservoir is penetrated. Maintain mud weight at or below 10.5 ppg and be prepared to add loss circulation material.Good filter cake quality,hole cleaning and maintenance of low drill solids(by diluting as required)will all be important in maintaining wellbore stability. Intermediate#2: The intermediate sidetrack section will be drilled with the same fresh water gel/polymer mud system used in the intermediate#1 section.Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation,particularly after the reservoir is penetrated. Maintain mud weight at 10.5 ppg and be prepared to add loss circulation material.Good filter cake quality,hole cleaning and maintenance of low drill solids(by diluting as required)will all be important in maintaining wellbore stability. Production Hole: The horizontal production interval will be drilled with M-I SWACO's Versapro MOBM drill-in fluid. Sized calcium carbonate will be used as a bridging agent for proper filter cake building and fluid loss control.Micronized barite will be on location if higher than expected reservoir pressures are encountered. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. CD 1-47 APD Page 6 of 15 Printed: 18-Jun-12 L ation for Permit to Drill,Well CD1-47 Saved: 18-Jun-12 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 MC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 MC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska,Inc.is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. �� L) ff - a3S 1. MIRU Doyon 19 onto CD1-47. 2. Rig up and test riser,dewater cellar as needed. 3. Drill 14"hole to the surface casing point as per the directional plan. (Directional only). 4. Run and cement 11-3/4"surface casing. sem 5. Install and test BOPE to 3500 psi. tM 6. Pick up and run in hole with 10-5/8"drilling BHA with 11-3/4"under reamer to drill intermediate#1. Pressure test casing to 3500 psi. /C4a rf- 30 7. Drill out 20' of new hole and perform FIT to 18.0 ppg. 8. Drill 10-5/8" hole to just above the HRZ.Under ream to 11-3/4"while drilling.(LWD Program: GR/RES/PWD). ��J � S 9. Run 9-5/8"liner with hanger and liner top packer. 10. Pump single stage cement job to cover the Nanuq and the Qannik sands. 11. BOPE test to 3500 psi. 12. Pick up and run in hole with 8.5"clean out assembly. 13. Drill out shoe track and 20 feet of new formation.Perform FIT to 12.5 ppg. C ) 14. Drill an additional 40' of new formation with the 8.5"assembly to accommodate steerable drilling liner BHA. .SLD. 15. Pick up and run in hole with 7"steerable liner lliig system with 6"pilot bit and 8-1/2"reamer. 16. Drill 6"X8-1/2" hole to intermediate casing point in the Alpine C sand. (LWD Program: GR/RES/PWD) • 17. Pull out of hole with inner string drilling assembly. 18. RIH with cement retainer and 7"tie-back assembly. . 14 4., ,, 19. Cement 7"liner and set liner hanger and packoff. 20. Test BOPE to 3500 psi. 21. Pick up RIH with 6"drilling assembly.(LWD Program: GR/RES/PWD/AZI.RES.). Test casing to 3500 psi. CD 1-47 APD Page 7 of 15 t A Printed: 18-Jun-12 ration for Permit to Drill,Well CD1-47 Saved: 18-Jun-12 22. Drill out and perform formation integrity test to 13.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 13.0 ppg EMW. 23. Drill 6"horizontal section to TD. 24. Circulate the hole clean and pull out of hole. 25. Run lower completion of 4-1/2"liner with pre-perf pups,liner top hanger/packer and swell packers for zonal isolation. 26. Run upper completion of 3-1/2,9.3#,L-80 tubing with SSSV DB profile, 3 GLM,BHP gauge,XN profile and wireline entry guide. 27. Space out and land hanger. 28. Install 2 way check and pressure test hanger seals to 5000 psi.Nipple down BOP. 29. Install tubing head adapter assembly.Pressure test adapter assembly to 5000 psi.Remove 2 way check. 30. Test tubing and tubing-casing annulus separately to 3500 psi/30 mins. 31. Drop ball and rod. Shear circulation valve in GLM. 32. Circulate tubing to diesel and install freeze protection in the annulus. 33. Set BPV and secure well.Move rig off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005(c)(14)) Incidental fluids developed from drilling operations on well CD1-47 will be injected into a permitted annulus on the CD1 pad,or the class 1 disposal well on CD1 pad. CD1-47 will not be a viable candidate for annular injection due to the three string casing design. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Cement Summary CD 1-47 APD Page 8 of 15 t. r Printed: 18-Jun-12 R I Ui '! l ation for Permit to Drill,Well CD1-47 Saved: 18-Jun-12 Attachment 1 —Directional Plan CD 1-47 APD Page 9 of 15 �.. r^' ! f I Printed: 18-Jun-12 .{ t 6 3 �_ ConocoPhillips(Alaska) Inc. Western North Slope CD1 Alpine Pad Plan: CD1-47 Plan: CD1-47 Plan: CD1-47wp03 Reduced dogleg to Alpine C, 80' straight section near and below the Intermediate I casing. Casina MDs have chanaed. Standard Proposal Report Largerife Do NOT Print 13 June, 2012 perm It pa cfc {{ g HALLIBURTON MIME i Sperry Drilling Services I I ii ORIGINAL Northing (5000 ft/in) JIJIIIiiiiIiiiiIiiiilmiliiiiIiiiiIiiiiIiiiiliiiiliiiiliiiilitiilliiilii N - r O _ N N — C O = o - Ci _ ill (� — — co Q. Ii �J vm o — m r p d - d m o U ro _ co o a o o n ` ❑ U o U co ❑ _ o — ❑ o ❑� to U CO'- ❑ p v U7 - ❑ / I U ❑ Lo U N _T••• 6 a ❑ J CQ i - — . ,_ .. .. _. ,- N a- NO17 N CL ❑ C 411 m U N ❑ 2 _ - p�•:r ,& lit .I a CN a 0 co •11\ el .4 I U m N U U a171a /U-�. co U pin � U N ` V -U to in ` W— CSj3 m _ U ',1"•• ❑ —W i.i aco v1:. UU M M c� �•:40 �� U tp ❑ N - Q O N ■�� ,� - U r co U Uy ` N N o N- ❑ - ` ❑ N 3 p r CV .�. 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V I N PI (u!/110096 41de Ie38JOA emu " - E l t `.- i t tl ,..t O O O a) ._ -O O O N CI. O I! 00 "Al O ir 00 00 s 00 °° c o ° X o 6 00 000 Cr N o O O O° 0° 0 O! + O 0 O ✓ co '3 °0 � O ! '✓ - O W r 0 0� y !OJ 00 a! - CD O O`1 NX 0 O cfl 03 O 00' ! ! X O COD 1• CV, .e CO xO N CO Pill" e lilt , O t. O - O CI O r V O O O N O O O O O O O N O CO C, N (uiM 0002) (+)4JoN/(-)4mos 6 \ • W.w' ' ' i. • a 4..• 0 0 —to C D 1-47wp03 X613 43 coX 1'6000 N 4 o O N CD 15000 T ■ ' � • X00 0 Ln 0 O T 1-3000 WO //^^ O V ) rn 006 _ 1 000 c S 000ii 1 . c) 0 N O Ln O 009 7' , 0 O O ,.-....4� AX O I T M CO O0 CO T 6 x O c� O C 00 - O .0 coLn U O°°8 6 a) U 44 E Ln Of) 00 CD 09 CL 00 09 N co °0415 1 CI 00o X 00 0"°C1 l o 0 I 1 o T z14 - o - .. -- --r l 0 0 0 0 0 0 0 0 0 0 0 in o in O to r co d' (0 N. (u!/14 0091) LndeG !eo! eA anal 1'i1GINAiL ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-47 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-47 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-47 Design: CD1-47wp03 Project Western North Slope Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site CD1 Alpine Pad Site Position: Northing: 763.85ft Latitude: 53°45'41.218 N From: Map Easting: -1,140,666.14ft Longitude: 157°35'23.503 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -6.11° Well Plan:CD1-47 Well Position +N/-S 0.00 ft Northing: 5,975,579.96ft Latitude: 70°20'31.677 N +E/-W 0.00 ft Easting: 385,674.75ft Longitude: 150°55'40.224 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.50ft Wellbore Plan:CD1-47 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 6/12/2012 15.65 79.79 57,338 Design CD1-47wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 36.30 0.00 0.00 331.00 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +El-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 36.30 0.00 0.00 36.30 -19.50 0.00 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 194.20 0.00 0.00 0.00 0.00 0.00 0.00 600.49 5.26 160.00 600.00 544.20 -15.10 5.50 1.50 1.50 0.00 160.00 900.84 2.50 308.69 900.00 844.20 -23.94 5.08 2.50 -0.92 49.51 170.00 1,203.43 11.58 308.69 1,200.00 1,144.20 -0.78 -23.84 3.00 3.00 0.00 0.00 2,511.26 56.16 333.00 2,261.84 2,206.04 597.37 -392.71 3.50 3.41 1.86 28.50 3,477.66 56.16 333.00 2,800.00 2,744.20 1,312.57 -757.13 0.00 0.00 0.00 0.00 3,726.83 56.16 330.00 2,938.78 2,882.98 1,494.42 -855.86 1.00 0.00 -1.20 -90.84 10,364.25 56.16 330.00 6,635.00 6,579.20 6,268.83 -3,612.37 0.00 0.00 0.00 0.00 10,747.00 67.62 330.82 6,815.04 6,759.24 6,561.97 -3,778.69 3.00 2.99 0.21 3.80 10,827.00 67.62 330.82 6,845.50 6,789.70 6,626.55 -3,814.76 0.00 0.00 0.00 0.00 11,383.18 84.12 331.88 6,980.80 6,925.00 7,098.32 -4,072.29 2.97 2.97 0.19 3.73 11,403.18 84.12 331.88 6,982.85 6,927.05 7,115.87 -4,081.67 0.00 0.00 0.00 0.00 11,558.50 90.34 331.84 6,990.35 6,934.55 7,252.60 -4,154.79 4.00 4.00 -0.03 -0.38 16,612.90 90.34 331.84 6,960.80 6,905.00 11,708.77 -6,539.90 0.00 0.00 0.00 0.00 6/13/2012 1:27:56PM Page 2 COMPASS 2003.16 Build 69 CG1NAL ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-47 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-47 Survey Calculation Method: Minimum Curvature _ Wellbore: Plan:CD1-47 Design: CD1-47wp03 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (0) (0) (ft) ft (ft) (ft) (ft) (ft) -19.50 36.30 0.00 0.00 36.30 -19.50 0.00 0.00 5,975,579.96 385,674.75 0.00 0.00 100.00 0.00 0.00 100.00 44.20 0.00 0.00 5,975,579.96 385,674.75 0.00 0.00 200.00 0.00 0.00 200.00 144.20 0.00 0.00 5,975,579.96 385,674.75 0.00 0.00 . 250.00 0.00 0.00 250.00 194.20 0.00 0.00 5,975,579.96 385,674.75 0.00 0.00 KOP:DLS 1.5 TFO 160 300.00 0.75 160.00 300.00 244.20 -0.31 0.11 5,975,579.65 385,674.85 1.50 -0.32 400.00 2.25 160.00 399.96 344.16 -2.77 1.01 5,975,577.18 385,675.71 1.50 -2.91 500.00 3.75 160.00 499.82 444.02 -7.69 2.80 5,975,572.23 385,677.42 1.50 -8.08 600.00 5.25 160.00 599.51 543.71 -15.06 5.48 5,975,564.82 385,679.99 1.50 -15.83 600.49 5.26 160.00 600.00 544.20 -15.10 5.50 5,975,564.78 385,680.01 1.50 -15.87 Start DLS 2.50 TFO 170.00 700.00 2.84 168.75 699.25 643.45 -21.80 7.54 5,975,558.04 385,681.95 2.50 -22.72 800.00 0.93 228.25 799.20 743.40 -24.77 7.41 5,975,555.07 385,681.78 2.50 -25.26 900.00 2.48 308.51 899.16 843.36 -23.97 5.11 5,975,555.92 385,679.49 2.50 -23.44 900.84 2.50 308.69 900.00 844.20 -23.94 5.08 5,975,555.94 385,679.46 2.50 -23.41 Start Build 3.00 1,000.00 5.48 308.69 998.91 943.11 -19.63 -0.30 5,975,560.33 385,674.14 3.00 -17.02 1,100.00 8.48 308.69 1,098.16 1,042.36 -12.04 -9.78 5,975,568.07 385,664.78 3.00 -5.79 I 1,200.00 11.48 308.69 1,196.64 1,140.84 -1.21 -23.31 5,975,579.10 385,651.43 3.00 10.24 1,203.43 11.58 308.69 1,200.00 1,144.20 -0.78 -23.84 5,975,579.54 385,650.90 3.00 10.88 Start DLS 3.50 TFO 28.50 1,300.00 14.64 315.08 1,294.04 1,238.24 13.92 -40.03 5,975,594.49 385,634.94 3.50 31.58 1,400.00 17.93 319.39 1,390.02 1,334.22 34.56 -58.97 5,975,615.41 385,616.31 3.50 58.82 1,500.00 21.28 322.39 1,484.22 1,428.42 60.63 -80.07 5,975,641.79 385,595.62 3.50 91.84 1,577.54 23.91 324.16 1,555.80 1,500.00 84.51 -97.86 5,975,665.95 385,578.20 3.50 121.36 Base Permafrost 1,600.00 24.67 324.61 1,576.27 1,520.47 92.02 -103.24 5,975,673.54 385,572.93 3.50 130.54 1,700.00 28.09 326.31 1,665.85 1,610.05 128.64 -128.39 5,975,710.53 385,548.34 3.50 174.75 1,800.00 31.52 327.67 1,752.61 1,696.81 170.33 -155.44 5,975,752.62 385,521.94 3.50 224.33 1,900.00 34.97 328.79 1,836.23 1,780.43 216.94 -184.27 5,975,799.66 385,493.82 3.50 279.08 2,000.00 38.42 329.73 1,916.40 1,860.60 268.30 -214.79 5,975,851.48 385,464.09 3.50 338.80 2,100.00 41.88 330.54 1,992.82 1,937.02 324.22 -246.89 5,975,907.88 385,432.85 3.50 403.26 2,200.00 45.35 331.24 2,065.21 2,009.41 384.49 -280.43 5,975,968.65 385,400.24 3.50 472.24 2,300.00 48.82 331.87 2,133.29 2,077.49 448.88 -315.29 5,976,033.56 385,366.36 3.50 545.46 2,400.00 52.29 332.43 2,196.81 2,141.01 517.16 -351.35 5,976,102.37 385,331.35 3.50 622.65 2,500.00 55.77 332.95 2,255.53 2,199.73 589.06 -388.47 5,976,174.82 385,295.33 3.50 703.54 2,511.26 56.16 333.00 2,261.84 2,206.04 597.37 -392.71 5,976,183.20 385,291.22 3.50 712.86 Start 966.40 hold at 2511.26 MD 2,600.00 56.16 333.00 2,311.25 2,255.45 663.05 -426.18 5,976,249.37 385,258.77 0.00 786.53 2,669.58 56.16 333.00 2,350.00 2,294.20 714.54 -452.41 5,976,301.25 385,233.32 0.00 844.28 11-3/4"x 14" 2,700.00 56.16 333.00 2,366.94 2,311.14 737.05 -463.88 5,976,323.93 385,222.19 0.00 869.54 2,724.89 56.16 333.00 2,380.80 2,325.00 755.47 -473.27 5,976,342.49 385,213.09 0.00 890.19 C-30 2,800.00 56.16 333.00 2,422.63 2,366.83 811.06 -501.59 5,976,398.50 385,185.62 0.00 952.54 6/13/2012 1:27:56PM Page 3 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips HALLIEURTC3 NI Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-47 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-47 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-47 Design: CD1-47wp03 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +EI-W Northing Easting DLS Veil Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 2,422.52 2,900.00 56.16 333.00 2,478.32 2,422.52 885.07 -539.30 5,976,473.07 385,149.05 0.00 1,035.55 3,000.00 56.16 333.00 2,534.00 2,478.20 959.07 -577.01 5,976,547.63 385,112.48 0.00 1,118.56 3,100.00 56.16 333.00 2,589.69 2,533.89 1,033.08 -614.72 5,976,622.20 385,075.90 0.00 1,201.57 3,200.00 56.16 333.00 2,645.38 2,589.58 1,107.09 -652.43 5,976,696.77 385,039.33 0.00 1,284.58 3,300.00 56.16 333.00 2,701.07 2,645.27 1,181.09 -690.13 5,976,771.33 385,002.76 0.00 1,367.59 3,400.00 56.16 333.00 2,756.75 2,700.95 1,255.10 -727.84 5,976,845.90 384,966.19 0.00 1,450.60 3,407.26 56.16 333.00 2,760.80 2,705.00 1,260.47 -730.58 5,976,851.32 384,963.53 0.00 1,456.63 C-20 3,477.66 56.16 333.00 2,800.00 2,744.20 1,312.57 -757.13 5,976,903.81 384,937.79 0.00 1,515.06 Start Turn-1.20 3,500.00 56.16 332.73 2,812.44 2,756.64 1,329.08 -765.59 5,976,920.45 384,929.58 1.00 1,533.61 3,600.00 56.15 331.53 2,868.14 2,812.34 1,402.50 -804.41 5,976,994.44 384,891.88 1.00 1,616.64 3,700.00 56.16 330.32 2,923.84 2,868.04 1,475.09 -844.77 5,977,067.63 384,852.64 1.00 1,699.69 3,726.83 56.16 330.00 2,938.78 2,882.98 1,494.42 -855.86 5,977,087.12 384,841.85 1.00 1,721.97 Start 6637.43 hold at 3726.83 MD 3,800.00 56.16 330.00 2,979.53 2,923.73 1,547.05 -886.25 5,977,140.21 384,812.27 0.00 1,782.74 3,900.00 56.16 330.00 3,035.21 2,979.41 1,618.98 -927.78 5,977,212.76 384,771.84 0.00 1,865.79 4,000.00 56.16 330.00 3,090.90 3,035.10 1,690.91 -969.31 5,977,285.31 384,731.42 0.00 1,948.84 4,100.00 56.16 330.00 3,146.59 3,090.79 1,762.85 -1,010.84 5,977,357.86 384,690.99 0.00 2,031.88 4,200.00 56.16 330.00 3,202.28 3,146.48 1,834.78 -1,052.37 5,977,430.41 384,650.57 0.00 2,114.93 4,300.00 56.16 330.00 3,257.96 3,202.16 1,906.71 -1,093.90 5,977,502.96 384,610.14 0.00 2,197.98 4,400.00 56.16 330.00 3,313.65 3,257.85 1,978.64 -1,135.43 5,977,575.51 384,569.72 0.00 2,281.02 4,500.00 56.16 330.00 3,369.34 3,313.54 2,050.57 -1,176.96 5,977,648.06 384,529.29 0.00 2,364.07 4,600.00 56.16 330.00 3,425.03 3,369.23 2,122.50 -1,218.49 5,977,720.61 384,488.87 0.00 2,447.12 I 4,700.00 56.16 330.00 3,480.71 3,424.91 2,194.44 -1,260.02 5,977,793.16 384,448.44 0.00 2,530.16 1 4,800.00 56.16 330.00 3,536.40 3,480.60 2,266.37 -1,301.55 5,977,865.72 384,408.02 0.00 2,613.21 4,900.00 56.16 330.00 3,592.09 3,536.29 2,338.30 -1,343.08 5,977,938.27 384,367.60 0.00 2,696.26 5,000.00 56.16 330.00 3,647.78 3,591.98 2,410.23 -1,384.61 5,978,010.82 384,327.17 0.00 2,779.31 5,100.00 56.16 330.00 3,703.47 3,647.67 2,482.16 -1,426.14 5,978,083.37 384,286.75 0.00 2,862.35 5,200.00 56.16 330.00 3,759.15 3,703.35 2,554.09 -1,467.67 5,978,155.92 384,246.32 0.00 2,945.40 5,300.00 56.16 330.00 3,814.84 3,759.04 2,626.03 -1,509.19 5,978,228.47 384,205.90 0.00 3,028.45 5,301.72 56.16 330.00 3,815.80 3,760.00 2,627.27 -1,509.91 5,978,229.72 384,205.20 0.00 3,029.88 K-3 5,400.00 56.16 330.00 3,870.53 3,814.73 2,697.96 -1,550.72 5,978,301.02 384,165.47 0.00 3,111.49 5,500.00 56.16 330.00 3,926.22 3,870.42 2,769.89 -1,592.25 5,978,373.57 384,125.05 0.00 3,194.54 5,600.00 56.16 330.00 3,981.90 3,926.10 2,841.82 -1,633.78 5,978,446.12 384,084.62 0.00 3,277.59 5,624.96 56.16 330.00 3,995.80 3,940.00 2,859.77 -1,644.15 5,978,464.22 384,074.54 0.00 3,298.31 K-3_Basal 5,687.81 56.16 330.00 4,030.80 3,975.00 2,904.98 -1,670.25 5,978,509.82 384,049.13 0.00 3,350.51 K-2(Qannik) 5,700.00 56.16 330.00 4,037.59 3,981.79 2,913.75 -1,675.31 5,978,518.67 384,044.20 0.00 3,360.63 5,800.00 56.16 330.00 4,093.28 4,037.48 2,985.68 -1,716.84 5,978,591.22 384,003.77 0.00 3,443.68 5,885.34 56.16 330.00 4,140.80 4,085.00 3,047.07 -1,752.28 5,978,653.13 383,969.28 0.00 3,514.55 K-2_Basal 5,900.00 56.16 330.00 4,148.97 4,093.17 3,057.62 -1,758.37 5,978,663.77 383,963.35 0.00 3,526.73 6/13/2012 1:27:56PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips r''-11.4,, k ,Li 6 is. liStandard Proposal Report Li �.�� � , � Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-47 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-47 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-47 Design: CD1-47wp03 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Veil Section (ft) (0) (0) (ft) ft (ft) (ft) (ft) (ft) 4,148.85 6,000.00 56.16 330.00 4,204.65 4,148.85 3,129.55 -1,799.90 5,978,736.32 383,922.93 0.00 3,609.77 6,100.00 56.16 330.00 4,260.34 4,204.54 3,201.48 -1,841.43 5,978,808.87 383,882.50 0.00 3,692.82 6,200.00 56.16 330.00 4,316.03 4,260.23 3,273.41 -1,882.96 5,978,881.42 383,842.08 0.00 3,775.87 6,300.00 56.16 330.00 4,371.72 4,315.92 3,345.34 -1,924.49 5,978,953.97 383,801.65 0.00 3,858.92 6,400.00 56.16 330.00 4,427.40 4,371.60 3,417.27 -1,966.02 5,979,026.52 383,761.23 0.00 3,941.96 6,500.00 56.16 330.00 4,483.09 4,427.29 3,489.21 -2,007.55 5,979,099.07 383,720.80 0.00 4,025.01 6,600.00 56.16 330.00 4,538.78 4,482.98 3,561.14 -2,049.08 5,979,171.62 383,680.38 0.00 4,108.06 6,700.00 56.16 330.00 4,594.47 4,538.67 3,633.07 -2,090.61 5,979,244.17 383,639.95 0.00 4,191.10 6,800.00 56.16 330.00 4,650.15 4,594.35 3,705.00 -2,132.14 5,979,316.72 383,599.53 0.00 4,274.15 6,900.00 56.16 330.00 4,705.84 4,650.04 3,776.93 -2,173.67 5,979,389.28 383,559.10 0.00 4,357.20 7,000.00 56.16 330.00 4,761.53 4,705.73 3,848.87 -2,215.20 5,979,461.83 383,518.68 0.00 4,440.24 7,100.00 56.16 330.00 4,817.22 4,761.42 3,920.80 -2,256.73 5,979,534.38 383,478.26 0.00 4,523.29 7,200.00 56.16 330.00 4,872.90 4,817.10 3,992.73 -2,298.26 5,979,606.93 383,437.83 0.00 4,606.34 7,300.00 56.16 330.00 4,928.59 4,872.79 4,064.66 -2,339.79 5,979,679.48 383,397.41 0.00 4,689.39 7,400.00 56.16 330.00 4,984.28 4,928.48 4,136.59 -2,381.32 5,979,752.03 383,356.98 0.00 4,772.43 7,500.00 56.16 330.00 5,039.97 4,984.17 4,208.52 -2,422.85 5,979,824.58 383,316.56 0.00 4,855.48 7,600.00 56.16 330.00 5,095.65 5,039.85 4,280.46 -2,464.38 5,979,897.13 383,276.13 0.00 4,938.53 7,700.00 56.16 330.00 5,151.34 5,095.54 4,352.39 -2,505.91 5,979,969.68 383,235.71 0.00 5,021.57 7,800.00 56.16 330.00 5,207.03 5,151.23 4,424.32 -2,547.44 5,980,042.23 383,195.28 0.00 5,104.62 7,900.00 56.16 330.00 5,262.72 5,206.92 4,496.25 -2,588.97 5,980,114.78 383,154.86 0.00 5,187.67 I 8,000.00 56.16 330.00 5,318.40 5,262.60 4,568.18 -2,630.50 5,980,187.33 383,114.43 0.00 5,270.71 8,100.00 56.16 330.00 5,374.09 5,318.29 4,640.11 -2,672.03 5,980,259.88 383,074.01 0.00 5,353.76 8,200.00 56.16 330.00 5,429.78 5,373.98 4,712.05 -2,713.56 5,980,332.43 383,033.58 0.00 5,436.81 8,300.00 56.16 330.00 5,485.47 5,429.67 4,783.98 -2,755.09 5,980,404.98 382,993.16 0.00 5,519.85 8,400.00 56.16 330.00 5,541.15 5,485.35 4,855.91 -2,796.62 5,980,477.53 382,952.74 0.00 5,602.90 8,500.00 56.16 330.00 5,596.84 5,541.04 4,927.84 -2,838.15 5,980,550.08 382,912.31 0.00 5,685.95 j 8,600.00 56.16 330.00 5,652.53 5,596.73 4,999.77 -2,879.68 5,980,622.63 382,871.89 0.00 5,769.00 8,700.00 56.16 330.00 5,708.22 5,652.42 5,071.70 -2,921.21 5,980,695.18 382,831.46 0.00 5,852.04 8,767.49 56.16 330.00 5,745.80 5,690.00 5,120.25 -2,949.24 5,980,744.15 382,804.18 0.00 5,908.09 Albian 97 8,800.00 56.16 330.00 5,763.90 5,708.10 5,143.64 -2,962.74 5,980,767.73 382,791.04 0.00 5,935.09 8,900.00 56.16 330.00 5,819.59 5,763.79 5,215.57 -3,004.27 5,980,840.29 382,750.61 0.00 6,018.14 9,000.00 56.16 330.00 5,875.28 5,819.48 5,287.50 -3,045.80 5,980,912.84 382,710.19 0.00 6,101.18 9,100.00 56.16 330.00 5,930.97 5,875.17 5,359.43 -3,087.33 5,980,985.39 382,669.76 0.00 6,184.23 9,200.00 56.16 330.00 5,986.66 5,930.86 5,431.36 -3,128.86 5,981,057.94 382,629.34 0.00 6,267.28 9,300.00 56.16 330.00 6,042.34 5,986.54 5,503.29 -3,170.39 5,981,130.49 382,588.91 0.00 6,350.32 9,400.00 56.16 330.00 6,098.03 6,042.23 5,575.23 -3,211.92 5,981,203.04 382,548.49 0.00 6,433.37 9,431.91 56.16 330.00 6,115.80 6,060.00 5,598.18 -3,225.17 5,981,226.19 382,535.59 0.00 6,459.87 Albian 96 9,500.00 56.16 330.00 6,153.72 6,097.92 5,647.16 -3,253.45 5,981,275.59 382,508.07 0.00 6,516.42 9,600.00 56.16 330.00 6,209.41 6,153.61 5,719.09 -3,294.98 5,981,348.14 382,467.64 0.00 6,599.46 9,700.00 56.16 330.00 6,265.09 6,209.29 5,791.02 -3,336.51 5,981,420.69 382,427.22 0.00 6,682.51 9,800.00 56.16 330.00 6,320.78 6,264.98 5,862.95 -3,378.04 5,981,493.24 382,386.79 0.00 6,765.56 9,900.00 56.16 330.00 6,376.47 6,320.67 5,934.88 -3,419.57 5,981,565.79 382,346.37 0.00 6,848.61 10,000.00 56.16 330.00 6,432.16 6,376.36 6,006.82 -3,461.10 5,981,638.34 382,305.94 0.00 6,931.65 6/13/2012 1:27:56PM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-47 Company: ConocoPhillips(Alaska)Inc. ND Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-47 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-47 Design: CD1-47wp03 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (0) (ft) ft (ft) (ft) (ft) (ft) 6,432.04 10,100.00 56.16 330.00 6,487.84 6,432.04 6,078.75 -3,502.63 5,981,710.89 382,265.52 0.00 7,014.70 10,200.00 56.16 330.00 6,543.53 6,487.73 6,150.68 -3,544.15 5,981,783.44 382,225.09 0.00 7,097.75 10,248.97 56.16 330.00 6,570.80 6,515.00 6,185.90 -3,564.49 5,981,818.97 382,205.30 0.00 7,138.41 Top HRZ 10,300.00 56.16 330.00 6,599.22 6,543.42 6,222.61 -3,585.68 5,981,855.99 382,184.67 0.00 7,180.79 10,364.25 56.16 330.00 6,635.00 6,579.20 6,268.83 -3,612.37 5,981,902.61 382,158.69 0.00 7,234.15 Start DLS 3.00 TFO 3.80 10,400.00 57.23 330.08 6,654.63 6,598.83 6,294.71 -3,627.29 5,981,928.71 382,144.17 3.00 7,264.02 10,500.00 60.22 330.31 6,706.53 6,650.73 6,368.87 -3,669.76 5,982,003.51 382,102.84 3.00 7,349.48 10,593.13 63.01 330.51 6,750.80 6,695.00 6,440.12 -3,710.21 5,982,075.36 382,063.48 3.00 7,431.40 Base HRZ 10,600.00 63.22 330.52 6,753.90 6,698.10 6,445.45 -3,713.23 5,982,080.73 382,060.55 3.00 7,437.53 10,700.00 66.21 330.73 6,796.61 6,740.81 6,524.24 -3,757.58 5,982,160.18 382,017.41 3.00 7,527.93 10,710.45 66.53 330.75 6,800.80 6,745.00 6,532.59 -3,762.25 5,982,168.60 382,012.86 3.00 7,537.51 K-1 10,747.00 67.62 330.82 6,815.04 6,759.24 6,561.97 -3,778.69 5,982,198.22 381,996.88 3.00 7,571.17 Start 80.00 hold at 10747.00 MD 10,766.70 67.62 330.82 6,822.54 6,766.74 6,577.87 -3,787.57 5,982,214.26 381,988.24 0.00 7,589.39 9-5/8"x 11-3/4" 10,800.00 67.62 330.82 6,835.22 6,779.42 6,604.75 -3,802.58 5,982,241.37 381,973.64 0.00 7,620.18 10,827.00 67.62 330.82 6,845.50 6,789.70 6,626.55 -3,814.76 5,982,263.34 381,961.80 0.00 7,645.14 Start DLS 2.97 TFO 3.16 10,827.79 67.64 330.82 6,845.80 6,790.00 6,627.19 -3,815.11 5,982,263.99 381,961.46 2.97 7,645.88 Top Kuparuk D 10,900.00 69.79 330.97 6,872.01 6,816.21 6,685.97 -3,847.84 5,982,323.26 381,929.63 2.97 7,713.15 10,950.38 71.28 331.07 6,888.80 6,833.00 6,727.52 -3,870.85 5,982,365.15 381,907.26 2.97 7,760.65 Top Kuparuk C 10,956.64 71.47 331.08 6,890.80 6,835.00 6,732.72 -3,873.72 5,982,370.39 381,904.47 2.97 7,766.58 LCU 11,000.00 72.75 331.17 6,904.12 6,848.32 6,768.85 -3,893.65 5,982,406.82 381,885.10 2.97 7,807.85 11,100.00 75.72 331.36 6,931.29 6,875.49 6,853.23 -3,939.91 5,982,491.88 381,840.13 2.97 7,904.07 11,200.00 78.69 331.55 6,953.43 6,897.63 6,938.88 -3,986.50 5,982,578.23 381,794.85 2.97 8,001.58 11,300.00 81.65 331.73 6,970.50 6,914.70 7,025.58 -4,033.30 5,982,665.62 381,749.39 2.97 8,100.09 11,339.21 82.82 331.80 6,975.80 6,920.00 7,059.81 -4,051.68 5,982,700.13 381,731.53 2.97 8,138.94 Top Alpine C 11,383.10 84.12 331.88 6,980.79 6,924.99 7,098.25 -4,072.26 5,982,738.87 381,711.55 2.97 8,182.54 Start 20.00 hold at 11383.10 MD-7"x 8-1/2" 11,383.18 84.12 331.88 6,980.80 6,925.00 7,098.32 -4,072.29 5,982,738.94 381,711.51 2.97 8,182.62 CD1-35North 16Jan12 Heel 11,400.00 84.12 331.88 6,982.52 6,926.72 7,113.08 -4,080.18 5,982,753.82 381,703.85 0.00 8,199.35 11,403.10 84.12 331.88 6,982.84 6,927.04 7,115.80 -4,081.63 5,982,756.56 381,702.44 0.00 8,202.43 Start DLS 4.00 TFO 1.11 11,403.18 84.12 331.88 6,982.85 6,927.05 7,115.87 -4,081.67 5,982,756.63 381,702.40 0.00 8,202.51 11,500.00 88.00 331.86 6,989.50 6,933.70 7,201.03 -4,127.20 5,982,842.47 381,658.18 4.00 8,299.07 11,558.50 90.34 331.84 6,990.35 6,934.55 7,252.60 -4,154.79 5,982,894.46 381,631.38 4.00 8,357.55 6/13/2012 1:27:56PM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-47 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-47 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-47 Design: CD1-47wp03 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +EI-W Northing Easting DLS Vert Section (ft) (°) (0) (ft) ft (ft) (ft) (ft) (ft) 6,934.55 11,558.56 90.34 331.84 6,990.35 6,934.55 7,252.66 -4,154.82 5,982,894.51 381,631.35 0.00 8,357.61 Start 5054.22 hold at 11558.56 MD 11,600.00 90.34 331.84 6,990.11 6,934.31 7,289.19 -4,174.38 5,982,931.33 381,612.36 0.00 8,399.05 11,700.00 90.34 331.84 6,989.53 6,933.73 7,377.36 -4,221.57 5,983,020.20 381,566.52 0.00 8,499.04 11,800.00 90.34 331.84 6,988.94 6,933.14 7,465.52 -4,268.75 5,983,109.07 381,520.69 0.00 8,599.02 11,900.00 90.34 331.84 6,988.36 6,932.56 7,553.68 -4,315.94 5,983,197.93 381,474.85 0.00 8,699.01 12,000.00 90.34 331.84 6,987.77 6,931.97 7,641.85 -4,363.13 5,983,286.80 381,429.02 0.00 8,799.00 12,100.00 90.34 331.84 6,987.19 6,931.39 7,730.01 -4,410.32 5,983,375.66 381,383.19 0.00 8,898.99 12,200.00 90.34 331.84 6,986.60 6,930.80 7,818.18 -4,457.51 5,983,464.53 381,337.35 0.00 8,998.97 12,300.00 90.34 331.84 6,986.02 6,930.22 7,906.34 -4,504.70 5,983,553.39 381,291.52 0.00 9,098.96 12,400.00 90.34 331.84 6,985.43 6,929.63 7,994.50 -4,551.89 5,983,642.26 381,245.68 0.00 9,198.95 12,500.00 90.34 331.84 6,984.85 6,929.05 8,082.67 -4,599.07 5,983,731.13 381,199.85 0.00 9,298.94 12,600.00 90.34 331.84 6,984.26 6,928.46 8,170.83 -4,646.26 5,983,819.99 381,154.01 0.00 9,398.92 12,700.00 90.34 331.84 6,983.68 6,927.88 8,259.00 -4,693.45 5,983,908.86 381,108.18 0.00 9,498.91 12,800.00 90.34 331.84 6,983.09 6,927.29 8,347.16 -4,740.64 5,983,997.72 381,062.34 0.00 9,598.90 12,900.00 90.34 331.84 6,982.51 6,926.71 8,435.32 -4,787.83 5,984,086.59 381,016.51 0.00 9,698.89 13,000.00 90.34 331.84 6,981.93 6,926.13 8,523.49 -4,835.02 5,984,175.46 380,970.67 0.00 9,798.87 13,100.00 90.34 331.84 6,981.34 6,925.54 8,611.65 -4,882.21 5,984,264.32 380,924.84 0.00 9,898.86 13,200.00 90.34 331.84 6,980.76 6,924.96 8,699.82 -4,929.39 5,984,353.19 380,879.00 0.00 9,998.85 13,300.00 90.34 331.84 6,980.17 6,924.37 8,787.98 -4,976.58 5,984,442.05 380,833.17 0.00 10,098.84 13,400.00 90.34 331.84 6,979.59 6,923.79 8,876.14 -5,023.77 5,984,530.92 380,787.33 0.00 10,198.82 13,500.00 90.34 331.84 6,979.00 6,923.20 8,964.31 -5,070.96 5,984,619.78 380,741.50 0.00 10,298.81 13,600.00 90.34 331.84 6,978.42 6,922.62 9,052.47 -5,118.15 5,984,708.65 380,695.66 0.00 10,398.80 13,700.00 90.34 331.84 6,977.83 6,922.03 9,140.64 -5,165.34 5,984,797.52 380,649.83 0.00 10,498.79 13,800.00 90.34 331.84 6,977.25 6,921.45 9,228.80 -5,212.53 5,984,886.38 380,603.99 0.00 10,598.77 13,900.00 90.34 331.84 6,976.66 6,920.86 9,316.96 -5,259.72 5,984,975.25 380,558.16 0.00 10,698.76 14,000.00 90.34 331.84 6,976.08 6,920.28 9,405.13 -5,306.90 5,985,064.11 380,512.33 0.00 10,798.75 14,100.00 90.34 331.84 6,975.49 6,919.69 9,493.29 -5,354.09 5,985,152.98 380,466.49 0.00 10,898.74 14,200.00 90.34 331.84 6,974.91 6,919.11 9,581.46 -5,401.28 5,985,241.84 380,420.66 0.00 10,998.72 14,300.00 90.34 331.84 6,974.32 6,918.52 9,669.62 -5,448.47 5,985,330.71 380,374.82 0.00 11,098.71 14,400.00 90.34 331.84 6,973.74 6,917.94 9,757.78 -5,495.66 5,985,419.58 380,328.99 0.00 11,198.70 14,500.00 90.34 331.84 6,973.15 6,917.35 9,845.95 -5,542.85 5,985,508.44 380,283.15 0.00 11,298.69 14,600.00 90.34 331.84 6,972.57 6,916.77 9,934.11 -5,590.04 5,985,597.31 380,237.32 0.00 11,398.67 14,700.00 90.34 331.84 6,971.99 6,916.19 10,022.28 -5,637.22 5,985,686.17 380,191.48 0.00 11,498.66 14,800.00 90.34 331.84 6,971.40 6,915.60 10,110.44 -5,684.41 5,985,775.04 380,145.65 0.00 11,598.65 14,900.00 90.34 331.84 6,970.82 6,915.02 10,198.60 -5,731.60 5,985,863.91 380,099.81 0.00 11,698.64 15,000.00 90.34 331.84 6,970.23 6,914.43 10,286.77 -5,778.79 5,985,952.77 380,053.98 0.00 11,798.62 15,100.00 90.34 331.84 6,969.65 6,913.85 10,374.93 -5,825.98 5,986,041.64 380,008.14 0.00 11,898.61 15,200.00 90.34 331.84 6,969.06 6,913.26 10,463.10 -5,873.17 5,986,130.50 379,962.31 0.00 11,998.60 15,300.00 90.34 331.84 6,968.48 6,912.68 10,551.26 -5,920.36 5,986,219.37 379,916.47 0.00 12,098.59 15,400.00 90.34 331.84 6,967.89 6,912.09 10,639.42 -5,967.54 5,986,308.23 379,870.64 0.00 12,198.57 15,500.00 90.34 331.84 6,967.31 6,911.51 10,727.59 -6,014.73 5,986,397.10 379,824.80 0.00 12,298.56 15,600.00 90.34 331.84 6,966.72 6,910.92 10,815.75 -6,061.92 5,986,485.97 379,778.97 0.00 12,398.55 15,700.00 90.34 331.84 6,966.14 6,910.34 10,903.92 -6,109.11 5,986,574.83 379,733.13 0.00 12,498.53 15,800.00 90.34 331.84 6,965.55 6,909.75 10,992.08 -6,156.30 5,986,663.70 379,687.30 0.00 12,598.52 6/13/2012 1:27:56PM Page 7 COMPASS 2003.16 Build 69 r ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-47 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-47 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-47 Design: CD1-47wp03 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 6,909.17 15,900.00 90.34 331.84 6,964.97 6,909.17 11,080.24 -6,203.49 5,986,752.56 379,641.46 0.00 12,698.51 16,000.00 90.34 331.84 6,964.38 6,908.58 11,168.41 -6,250.68 5,986,841.43 379,595.63 0.00 12,798.50 16,100.00 90.34 331.84 6,963.80 6,908.00 11,256.57 -6,297.87 5,986,930.29 379,549.80 0.00 12,898.48 16,200.00 90.34 331.84 6,963.21 6,907.41 11,344.74 -6,345.05 5,987,019.16 379,503.96 0.00 12,998.47 16,300.00 90.34 331.84 6,962.63 6,906.83 11,432.90 -6,392.24 5,987,108.03 379,458.13 0.00 13,098.46 16,400.00 90.34 331.84 6,962.04 6,906.24 11,521.06 -6,439.43 5,987,196.89 379,412.29 0.00 13,198.45 16,500.00 90.34 331.84 6,961.46 6,905.66 11,609.23 -6,486.62 5,987,285.76 379,366.46 0.00 13,298.43 16,600.00 90.34 331.84 6,960.88 6,905.08 11,697.39 -6,533.81 5,987,374.62 379,320.62 0.00 13,398.42 16,612.78 90.34 331.84 6,960.80 6,905.00 11,708.66 -6,539.84 5,987,385.98 379,314.76 0.00 13,411.20 TD at 16612.78-4-1/2"x 6" 16,612.90 90.34 331.84 6,960.80 6,905.00 11,708.77 -6,539.90 5,987,386.09 379,314.71 0.00 13,411.32 CD1-35North 16Jan12 Toe • Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +EI-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) CD1-35North 16Jan121oa 0.00 0.00 6,960.80 11,708.77 -6,539.90 5,987,386.09 379,314.71 -plan hits target center -Circle(radius 100.00) CD1-35North 16Jan12 Heel 0.00 0.00 6,980.80 7,098.32 -4,072.29 5,982,738.94 381,711.51 -plan hits target center -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (•') 2,669.58 2,350.00 11-3/4"x 14" 11-3/4 14 10,766.70 6,822.54 9-5/8"x 11-3/4" 9-5/8 11-3/4 11,383.10 6,980.79 7"x 8-1/2" 7 8-1/2 16,612.78 6,960.80 4-1/2"x 6" 4-1/2 6 6/13/2012 1:27:56PM Page 8 COMPASS 2003.16 Build 69 r) r) � �^�j l A ,, i `Y. fL ConocoPhillips LII Lii va .4t ` "�" ' Standard Proposal Report ?'# #i"`'w!,t..arm ,zea .,'^ Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan:CD1-47 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Project: Western North Slope MD Reference: Plan: 19.5+36.3 @ 55.80ft(Doyon 19) Site: CD1 Alpine Pad North Reference: True Well: Plan:CD1-47 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD1-47 Design: CD1-47wp03 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (0) (0) 10,710.45 6,800.80 K-1 5,624.96 3,995.80 K-3_Basal 0.00 8,767.49 5,745.80 Albian 97 10,827.79 6,845.80 Top Kuparuk D 1,577.54 1,555.80 Base Permafrost 0.00 5,301.72 3,815.80 K-3 0.00 5,687.81 4,030.80 K-2(Qannik) 0.00 11,339.21 6,975.80 Top Alpine C 2,724.89 2,380.80 C-30 0.00 5,885.34 4,140.80 K-2_Basal 10,593.13 6,750.80 Base HRZ 3,407.26 2,760.80 C-20 0.00 10,956.64 6,890.80 LCU 10,248.97 6,570.80 Top HRZ 10,950.38 6,888.80 Top Kuparuk C 9,431.91 6,115.80 Albian 96 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 250.00 250.00 0.00 0.00 KOP:DLS 1.5 TFO 160 600.49 600.00 -15.10 5.50 Start DLS 2.50 TFO 170.00 900.84 900.00 -23.94 5.08 Start Build 3.00 1,203.43 1,200.00 -0.78 -23.84 Start DLS 3.50 TFO 28.50 2,511.26 2,261.84 597.37 -392.71 Start 966.40 hold at 2511.26 MD 3,477.66 2,800.00 1,312.57 -757.13 Start Turn-1.20 I 3,726.83 2,938.78 1,494.42 -855.86 Start 6637.43 hold at 3726.83 MD 10,364.25 6,635.00 6,268.83 -3,612.37 Start DLS 3.00 TFO 3.80 10,747.00 6,815.04 6,561.97 -3,778.69 Start 80.00 hold at 10747.00 MD 10,827.00 6,845.50 6,626.55 -3,814.76 Start DLS 2.97 TFO 3.16 11,383.10 6,980•.79 7,098.25 -4,072.26 Start 20.00 hold at 11383.10 MD 11,403.10 6,982.84 7,115.80 -4,081.63 Start DLS 4.00 TFO 1.11 11,558.56 6,990.35 7,252.66 -4,154.82 Start 5054.22 hold at 11558.56 MD 16,612.78 6,960.80 11,708.66 -6,539.84 TD at 16612.78 6/13/2012 1:27:56PM Page 9 COMPASS 2003.16 Build 69 ZN m F::• .I L 0• C) 3 W L J J '' L L 4 a U) COa N♦ m Z /w w N c ' O E O U f6 C I— M a d ✓ M ) C LO a, _� U din L c a ° E LU 00 �� � „_o O O r f6 r• U Z o i M t 'Z v o m ,-- + Cl) ,n - m c o ra U M C O O c c — CO O N Q a• c N 3 r r) y o w `t✓ e E N q w c a 3 d N Or j, QO U N ° a w 3 3 U c 0 -_ a ■� U c E m ■� L o a o o Cm •_ Q 0 0 cn a Z i ti a IO 0 I IX O _O.N M N N O F. 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Q O U) r = C T T c 0 IE 0 0 0 T T C ? icy E � c2 .- ° ~ f- Q) Q 03 al Q > N — 7 c c 'O v, c c V c� aa v 1- cc › ocn � o > EnN 1. k. , 4..r f \ f U i.. un N co o CL I C 0 I. • CO 0 Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y N 4 CO Cl) CO CO _l) CO CO CO_ V) _CO CO _CO _o CO co_ CO co CO co U) CI) C/) V) Cl)_ N_ CO CO CO_ U) C)) , F� C E E E E E E E E E E 2 E E E R E E FeE rcE2 FeiE Ec ii E E E EE 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O O O O y 0 m F To Ts.'F's 'Fa'@ 'F F la 'F F 'm'F.a 'gyp 'm m cs .Fa 'm'a et .F @ 'm m m m Fri c ctst cn co. 22222 222222 222222 222222 22222 22 0w to CO CO CO CO CO co CO CO CO CO CO CO CO CO 0 CO CO CO 0) CO CO CO co CO co co Cl) CO CO CO CO CO CO V) CO CO 0 CA CO CO CO CO CO CO Cl) U) Cl) CO CO CO CO (/) Cl) CO V) It) CO 0 U) CO CO (0 CO as CO It CO CO CO CO 01 CO CO CO 01 CO CO CO CO CO CO 05 CZ CO m m CO CO CO CO t2. 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Ci) O CO O CO CO 0) CD C) CO c0 0 O 0 t0 CO L/) O ‘- ‘- .- 01 ‘- 0) 00 0 O) U) M CO V O) Tr co co L/) co U) 0 'd' co N CO N h N co co co c0 co co co V u) >_ r V r V 0) V C) CD 0) 0) co 0) co 0 C) CD CO CO CO 0 N 0 CO Is: N. N r N CO N to ..0 O. O O) M CO M c0 M O O N O O N V V V V O M O O 06 66 c0 c0 s. 0 CO O V O V O N N- N T M N Nu U -0 00000 000000 000000 000000 00000 00 y 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 t t0 O t0 O tf) O )f) O 10 t0 t0 to t0 to O u) O t0 O LO t0 t0 O O O u7 O u) O O 0 N 0 N. 0 N 0 N 0 N ti N N. N N. 0 N. 0 1. O N N. N 0 0 U) h U) n 0 0 al O.=+ V Cn CM A- N A- N A- N V t0 V t0 co, co co V' co, 4 N CO CO 0) 0 0 t0 1.0 t0 CO O) V C M 0 N N. CO O COO N. CMO N COO N COO C0 C 0 C 0 m CO n O CD 0 I IMC) N. t() 01-0 a) C (Ni 4 V CO O O O N OI--; co N O 6 c0 CO In CO t0 Lci 4 —: O O CN . 0 O ct V co co co co co co t0 to CO t0 N N CT) O O 01 CO CO 7 T — 0) m 0) Cn CO CO (0 W O. a) to N. •0 0 w -O CO CO t0 t0 V IC) V 0 Cn h V I. 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O _O �+ O N N N N N N N M M M M M M M M M M M f7 M M M M M M M M M N nnt� •0 Z °C ' C 00000 ❑ ❑ 0 000 000000 000000 00000 ❑ ❑ N _ No !^ a) N 00000 00C 0 00 000000 000000 00000 00 E .tttttl -2 p tU L O A O N. CO CO CO CO CO 00 0 0 0 0 N N N N CO M V V to CO CO O CO a- c C = Z O. N N N N N N N N N M M M M M M M C? M M C`7 M M M ? C'? ? ? ? M M 4- o c-.30000 000000 00000m 000000 0000m 00 > 650 00000 000000 000000 000000 00000 00 h D N Co ,, zcc V] c 0 -O = 0 ca C 0 3 y _Y y Y y Y y .Y y y Y - �C y y y y Y Y y y Y y y y y Y .) y 1 1 .1 'Z V) V) CO V) LO CO V) V) V) LO V) N_ V) CO V) V) V) V) CO CO V) V) V) N to CO V) V) V) V) Cet r .m `o `o o `o o `0 `o `0 `0 0 0 0 0 0 0 0 0 0 `o `o o `0 0 0 `o `0 0 `o `0 0 z CO 'CO 'C 'CO 'CO 'CO CO' 'CO CO' 'CO 'co '(a CO .CO CO CO CO .@ ca 'co CO 'CO CO CO co (o CO ca (a CO RI v) o. 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 ^Q, 0 0 (/) CO V) CO CO V) V) CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO V) V) CO (/) CO CO CO CO CO U) CO V) V) (/) CO CO V) CO (1) CO CO V) CO CO CO CO CO CO CO CO CO CO CO co (O CO CO CO CO CO CO CO CO CO CO CO CO CO 0 CO CO 0 CO CO 0 CO CO CO CO CO Cr aaaaaa aaaaa aaaaaa aaaaaa aaaaaa a s ° G. d E (00 (00 (00 (000 (00 (00 (00 (00 0 0 0 `O 0 0 (00 (000) 0 0 O m E o r 0 0 5 0 t .) 0 o 0 5 0 t 0 t 0 o t 0 t . 0 0 0 0 0 CJ C CO C CO C CO C CO CO C CO C CO C CO C co C CO C CO C CO C @ C CO C CO C O CO COWCOWCOWmLLa m W 03a Loa @a Lu u_ LL @a ma CZ O •C N 0 N 0 0 0 0 N C N 0 0 a) V) 0 0 0 0 a) 0 0 0 0 0 0 0 0 0 0 0 0 6 0 ❑ 0 0 0 0 ❑ 0 000 0 a00 0 00a 0 ❑ O 2 co C C C C C C C C C C C C C C U E a) 2 a) m m CO CO co m 2 m a) CO CO CO 2 m 0 m 0 0 CO 0 m (O m cO a) cO 2 E (O t (O • co C 0 (0 • (0 t (a L. (O C CO t Ca C (0 C CO co t co t co C D N 0 0 a) a) a) 0 a) a) CO2 0 a) 0 0 0 CD 00 o CU 00 0 0 0 0 a) N 0 0) 000000 00000 U U U U U U 0 -00 (7.) (..) -0 000000 U 6) O O) O (-.- 6) N- 0) N- Cb Cr) W 0) CO '- NO M N N N N N 0) r' 6) O N a) Ln O Ln O Lf) co Ln co Lo 71- N d' N CO L) ,- CO N Ln N Ln d' d' d' d' N- d' O V O 0) O 0) 1- CO d- Co d' «) Ln Ln L() N O N- CO CO dr CO d' C? 0) O O 0) LU r- Ln ca �O Ln d' Ln d' n d' n d' .- (fl LU M M M M N N r- 6) ,- N N L.. U r' Ca Ca CO LL. U -O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O N 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0010000 O Oto O to Ln O LU O to O Ln O (t) O O O LC) Ln O u) O Ln O Ln O (fl 6 Ln O Ln N Ln N- Ln N n LC) n Ln N O N O N Ln O LU N- N Ln N Ln n 0 t- O CO N. N O N Ca Q.=. co oo N Co N O N O Co d' d' d' d' 'Cr Ln CD CO d' d' d- d' d' In 'Cr LC) d' N d' N V Lc) N- Ln N- Ln CO In CO 0) O CD O (D N 'CrCO d' O d' In In M 7 O d. n d' Ln C CO ,- CO O Ln O Ln O CO .- CO CO .- n N N O N O 0) Cfl 0) M CO M CO d' CO a) .9 Ln Ln L) Ln n N N Co Co n N- co CJ M W n n L4 d' M@ LO (D M M N- CO n CO .- .- .- M M a - cc E to N. ° 2' CO CO N n Co n CO n n N- Ln V CO O 0) CO d' CO d 0) CO 0) CO O Ln O) CO 'Crdt NV N- d' n nN n 6) n n N- n ,— O N O n dn dn n N- LoM 6 N COE CO _ o _ n Nn n CO n Co n N N co M O M co M CCo M (o a) C O d' co n d' N- v CO O N O N V 6) dt� N d' N dn mr n) co N- CO 0 CO COC Q v Co (o Co CO N ON O CO dd' dV V MM d' dd74 d' d' ddN dN _ adr ) 2 Q M o g O a .17,5' -1- co O O d n N-Co Co 0) O) CO 0) O d d' COM -Co `- CO COCO CO O O O Oo o? oo Co N- 'Cr N- d' Ln - N <- N o) co O CD .- ,- d' Co Co coCD Co O) co R E U CD CO (O (a 6) N (P N N 4 d' d' d' Ln O M (oLn to Ln to 6 Ln u) 6 m M M O 6) N. 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Iv •c t' o 3 ffr:2, s, U F III CO co C ' m O , d N 1ff Q ) 0) V N f- M ORIG1Nt HALLIBURTON ConocoPhillips CD 1 -47wp03 Alaska Sperry Drilling; ANTI-COLLISION SETTINGS 14:02,JUNE 12 2012 Interpolation Method: MD, interval:25.00 Depth Range From: 36.30 To 16612.78 Results Limited By: Centre Distance: 1857.65 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 36.30 1600.00 CD1-47wp03(Plan:CD1-47) GYD-GC-SS 1600.00 2669.58 CD1-47wp03(Plan: CD1-47) MWD+IFR-AK-CAZ-SC 2669.58 10766.70 CD1-47wp03(Plan: CD1-47) MWD+IFR-AK-CAZ-SC 10766.70 11383.10 CD1-47wp03(Plan: CD1-47) MWD+IFR-AK-CAZ-SC 11383.10 16612.78 CD1-47wp03 (Plan: CD1-47) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2350.00 2669.58 11-3/4" x 14" 11-3/4 6822.54 10766.70 9-5/8" x 11-3/4" 9-5/8 6980.80 11383.10 7"x 8-1/2" 7 6960.80 16612.78 4-1/2"x 6" 4-1/2 E o 71, P2 M m 3 m a a ++ ,n U)owl.) V 0 `U,' 0 300- Mr r I i -`-� wllf �l�i� o - I �I' I I U) ifP1'� ' 150- - I1iii U +,l 0 ,12 c ' �',,ro� o Ii 0 - : I 1 1 1 1 1 I 1 1 I 1 I i 1 I I I 1 I I 1 I I 1 1 I I I 0 2000 4000 6000 8000 10000 Measured Depth LEGEND -9- CD1-18,CD1-18,CD1-18 V2 --A- CD1-28,CD1-28PB1,CD1-28PB1 V1 -X- CD140,C01-40,CD140 V1 - CD1-21,CD1-21,CD1-21 V1 -e- CD1-28,Plan:CD1-28A.CD1-28Awp02 V0 -e- CD1-41,CD1-41,CD141 V1 -66- CD1-21,CD1-21L1,CD1-21L1 V1 -.- CD1-30,CD1-30,CD1-30 V1 $ CD141,CD1-41PB1,CD141PB1 V1 -X- CD1-21,CD1-21PB1,CD1-21PB1 V1 -e- CD1-30,CD1-30PB1,CD1-30PB1 V1 -i- CD142,CD142,CD1-42 VI - CD1-22,CD1-22,CD1-22 V6 --x- CD1-31,CD1-31,CD1-31 V6 -4- CD143,CD143,CD1-43 V1 - CD1-22,CD1-22A,CD1-22A V6 -El- CD1-32,021-32,CD1-32 V1 -X- CD144,CD144,CD144 V1 - CD1-22,Plan:CD1-22B,CD1-22Bwp04 VO -e- C01-32,CD1-32PB1,CD1-32PB1 V3 -00- CD144,CD1-44PB1,CD144PB1 V1 -X- CD1-229(aka N01),CD1-229,CD1-229 V1 -e- CD1-33,CD1-33,CD1-33 V1 -A- CD145,CD145,CD745 V1 CD1-229(aka Nal),CD1-229PB1,CD1-229PB1 V1 -i- CD1-34,CD1-34,CD1-34 V1 -X- CD145,CD145PB1,CD145PB1 V1 - 001-229(aka NO1),Plan:CD1-229A,CD1-229Awp04 VO -0- CD1-35,CDi-35,CD1-35 V1 $- CD1-46,CD146,CD1-46 V4 -X- CD1-23,CD1-23,CD1-23 V3 -0- CD1-36,CD1-36,CD1-36 V1 -X- CD1-48,CD1-48,CD148 VO - CD1-24,CD1-24,CD1-24 V4 $ CD1-36,CD1-36PB1,CD1-36PB1 V1 -A- CD148,CD1-48A,CD1-48A VO CD1-25,CD1-25,CD1-25 V1 _e_ CD1-37,CD1-37,CD1-37 V5 $ Plan:CD1-50,Plan:CD1-50,CD1-50wp06 VO - CD1-26,CD1-26,CD1-26 V1 -A- CD1-38,CD1-38,CD1-38 V1 -9- Plan:CD1-50,Plan:CD1-50PB1,CD1-50PB1w4)06 VO -e- CD1-26,CD1-26PB1,CD1-26PB1 V1 -T-- CD1-38,C01-38PB1,CD1-38PB1 V1 -9- CD147wp03 -9- CD1-27,CO1-27,CD1-27 V1 ---I-- C01-39,CD1-39,CD1-39 V1 -X- CD1-28,C01-28,CD1-28 V1 -- CD1-39,CDi-39PB1,CD1-39PB1 V1 .a.11 11/4..) 1l ' i L. ConocoPhillips CD 1-47w 03 HALLIBURTON Alaska P Sperry Drilling ANTI-COLLISION SETTINGS 14:02,JUNE 12 2012 Interpolation Method: MD,interval: 25.00 Depth Range From: 36.30 To 16612.78 Results Limited By: Centre Distance: 1857.65 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 36.30 1600.00 CD1-47wp03 (Plan:CD1-47) GYD-GC-SS 1600.00 2669.58 CD1-47wp03(Plan:CD1-47) MWD+IFR-AK-CAZ-SC 2669.58 10766.70 CD1-47wp03 (Plan:CD1-47) MWD+IFR-AK-CAZ-SC 10766.70 11383.10 CD1-47wp03 (Plan: CD1-47) MWD+IFR-AK-CAZ-SC 11383.10 16612.78 CD1-47wp03 (Plan: CD1-47) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2350.00 2669.58 11-3/4" x 14" 11-3/4 6822.54 10766.70 9-5/8" x 11-3/4" 9-5/8 6980.80 11383.10 7"x 8-1/2" 7 6960.80 16612.78 4-1/2"x 6" 4-1/2 0 a a a m Mo a v ra a U U U U U 1' C 60— ). ►11, I ,1I�' a)30 .l'ill '.,” 110711)1110', -E 'Ll •'1111000,, �I i Ili iii 611411,II10�� ! �IIIi 0 ITT T T f 1 " r I I I I I 1 I T I I I I I r I 1 I I I I 1 I I 0 500 1000 1500 2000 2500 3000 3500 Measured Depth LEGEND -9- CDI-18,CDl-18,CDI-18 V2 —A— CDI-28,CDl-28PB1.CDI-28PB1 VI —eCD1-40,CD1-40,CDI-40 VI -e- CD1-21,CDI-21.CDI-21 VI -e— CDI-28,Plan:CDl-28A,CDI-28Awp02 VO —e— CDl-41,CDI-41,CDI-41 VI -e- CDI-21,CD1-21L1,CDI-21L1 VI —0— CDl-30,CDI-30,CDI-30 VI -8- CD1-41,CDl-41PB1,CDI-41PBI VI —X- CDI-21,CD1-21PB1,CD1-21PBI VI -e- CDI-30.CD1-30PB1,CD1-30PB1 VI —I— CD1-42,CDI-42,CDI-42 V1 -e- CD1-22,CD1-22,CDI-22 V6 --T-- CD1-31.CD1-31,CDI-31 V6 —i— CDl-43,CDI-43,CDI-43 VI - CDI-22,CDI-22A,CDI-22A V6 $ CDI-32,CDI-32.CD1-32 VI —X— CDI-44.CDI-44.CDI-44 VI — CD1-22,Plan:CDI-22B,CDI-22Bwp04 VO -e- CDI-32.CDI-32PB1,CDI-32PB1 V3 —0— CDI-44.CD1-44PB1.CDI-44PB1 VI — - CDI-229(aka NQI).CD1-229,CDI-229 VI —e— CDI-33,CDI-33,CD1-33 VI —A— CDI.45.CD1-45.CDI-45 VI CDI-229(aka NQ1),CDI-229PB1.CD1-229PB1 VI —I— CD1-34,CDI-34,CDI-34 VI —X— CDI-45,CDI-45PB1,CDI-45PB1 VI -e- CD1-229(aka NQI),Plan:CD1-229A,CD1-229Awp04 VO -€.- CDl-35,CDI-35,CDI-35 VI $ CDl-46,CDI-46.CD1-46 V4 --X— CDI-23.CDI-23,CDl-23 V3 —e— CDl-36,CD1-36.CDI-36 VI ' —X— CDI-48,CDI-48,CDI-48 VO - CDI-24,CDI-24.CDI-24 V4 -e- CD1-36.CDl-36PB1,CDI-36PBI VI -,g- CDI-48,CDI-48A.CDI-48A VO CDI-25.CDI-25.CDI-25 VI -e- CD1-37,CDI-37,CDI-37 V5 --e- Plan:CDI-50,Plan:CDI-50.CDI-50wp06 VO - CDI-26.CDI-26,CDI-26 VI —A— CDI-38.CDI-38,CDI-38 VI -8- Plan:CDl-50,Plan:CDI-50PB1,CD1-50PB1wp06 VO -e- CDI-26,CD1-26P81,CDI-26PB1 VI -i— CD1-38,CD1-38PB1.CD1-38PB1 VI -8- CD1-47wp03 -g- CD1-27.CD1-27.CDl-27 VI —I— CDI-39,CDl-39,CDI-39 VI --X— CD1-28,CDi-28.CDl-28 VI —A— CM-39,CDI-39PB1,CDI-39PBI VI ODIGI 'i L Northing (5000 ft/in) I ii I I I I i I i I I I I I I I I 1 J 1 1 1 1 1 1 LJ I I I I 1 1 1 1 1 1 1 1 1 1 1 I I l l 1 1111111 1 1 1 I l l l l l I l 1 1 1 1 1 N _ O N _ — N - 1.4 — L — _ © Ie) - .. 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(N) Long. (W) SFNLLineFWL Gnd Pad CD1-1 5,975,904.92 385,999.99 70' 20' 34.922" 150' 55' 30.868" 222' 2,572' 13.0' 19.5' CD1-2 5,975,897.89 385,992.91 70' 20' 34.852" 150' 55' 31.071" 229' 2,565' 13.0' 19.5' CD1-3 5,975,890.99 385,985.82 70' 20' 34.783" 150' 55' 31.275" 236' 2,558' 13.1' 19.5' CD1-4 5,975,883.83 385,978.79 70' 20' 34.711" 150' 55' 31.478" 243' 2,551' 13.2' 19.5' CD1-5 5,975,876.67 385,971.58 70' 20' 34.640" 150' 55' 31.685" 251' 2,544' 13.3' 19.5' CD1-6 _ 5,975,869.89 385,964.83 70'_20' 34.572" 150' 55' 31.879" 258' 2,538' 13.4' 19.5' CD1-7 5,975,862.73 385,957.33 70' 20' 34.501" 150' 55' 32.095" 265' 2,530' 13.3' 19.5' CD1-8 5,975,855.21 385,950.60 70' 20' 34.426" 150' 55' 32.288" 272' 2,523' 13.2' 19.5' CD1-9 5,975,848.42 385,943.41 70' 20' 34.358" 150' 55' 32.495" 279' 2,517' 13.1' 19.5' CD1-10 5,975,841.34 385,936.18 70' 20' 34.287" 150' 55' 32.703" 286' 2,510' 13.0' 19.5' CD1-11 5,975,834.23 385,929.27 70' 20'_34.216"1.50' 55' 32.902" 294' 2,502' 12.9' 19.5' CD1-12 5,975,827.15 385,922.42 70' 20' 34.145" 150' 55' 33.099" 301' 2,496' 12.8' 19.5' CD1-13 5,975,820.00 385,915.06 70' 20' 34.074" 150' 55' 33.311" 308' 2,489' 12.7' 19.5' CD1-14 5,975,812.97 385,908.00 70' 20' 34.004" 150' 55' 33.514" 315' 2,482' 12.6' 19.5' CD1-15 5,975,805.80 385,901.08 70' 20' 33.932" 150' 55' 33.713" 323' 2,474' 12.5' 19.5' CD1-16 5,975,798.86 385,894.08 70' 20' 33.863" 150' 55' 33.914" 330' 2,468' 12.4' 19.5' CD1-17 5,975,791.81 385,886.84 70' 20' 33.793" 150' 55' 34.123" 337' 2,461' 12.3' 19.5' CD1-18 5,975,784.91 385,879.88 70' 20' 33.724" 150' 55' 34.323" 344' 2,454' 12.2' 19.5' CD1-19 5,975,777.92 385,872.81 70' 20' 33.654" 150' 55' 34.526" 351' 2,447' 12.1' 19.5' CD1-20 5,975,770.66 385,865.67 70' 20' 33.581" 150' 55' 34.732" 358' 2,440' 12.0' 19.5' CD1-21 5,975,763.76 385,858.49 70' 20' 33.512" 150' 55' 34.938" 365' 2,433' 11.9' 19.5' *CD1-22 5,975,756.46 385,851.10 70' 20' 33.440"_ 150' 55' 34.151" 373' 2,426' 11.9' 19.5' CD1-23 5,975,749.31 385,844.44 70' 20' 33.368" 150' 55' 35.342" 380' 2,419' 12.0' 19.5' CD1-24 5,975,742.40 385,837.30 70' 20' 33.299" 150' 55' 35.548" 387' 2,412' 12.2' 19.5' CD1-25 5,975,735.34 385,830.26 70' 20' 33.229" 150' 55' 35.750" 394' 2,405' 12.4' 19.5' CD1-26 5,975,728.10 385,823.14 70' 20' 33.156" 150' 55' 35.955" 401' 2,398' 12.6' 19.5' CD1-27 5,975,721.21 385,816.08 70' 20' 33.088" 150' 55' 36.158" 408' 2,391' 12.8' 19.5' CD1-28 5,975,714.15 385,809.10 70' 20' 33.017" 150' 55' 36.359" 416' 2,384' 13.0' 19.5' CD1-29 5,975,707.14 385,802.20 70' 20' 32.947" 150' 55' 36.558" 422' 2,377' 13.2' 19.5' CD1-30 5,975,700.17 385,794.75 70' 20' 32.877" 150' 55' 36.772" 430' 2,370' 13.4' 19.5' CD1-31 5,975,692.73 385,787.40 70' 20' 32.803" 150' 55' 36.984" 437' 2,362' 13.3' 19.5' CD1-32 5,975,685.92 385,780.68 70' 20' 32.735" 150' 55' 37.177" 444' 2,356' 13.2' 19.5' CD1-33 5,975,678.67 385,773.79 70' 20' 32.663" 150' 55' 37.375" 452' 2,349' 13.1' 19.5' CD1-34 5,975,671.88 385,766.54 70' 20' 32.595" 150' 55' 37.584" 459' 2,342' 12.9' 19.5' CD1-35 5,975,664.72 385,759.63 70' 20' 32.524" 150' 55' 37.782" 466' 2,335' 12.9' 19.5' CD1-36 5,975,657.49 385,752.52 70' 20' 32.451" 150' 55' 37.987" 473' 2,328' 12.8' 19.5' CD1-37 5,975,650.51 385,745.40 70' 20' 32.381" 150' 55' 38.191" 480' 2,321' 12.7' 19.5' CD1-38 5,975,643.79 385,738.44 70' 20' 32.315" 150' 55' 38.391" 487' 2,314' 12.6' 19.5' CD1-39 5,975,636.34 385,731.37 70' 20' 32.240" 150' 55' 38.595" 495' 2,307' 12.5' 19.5' CD1-40 5,975,629.19 385,724.32 70' 20' 32.168" 150' 55' 38.797" 502' 2,300' 12.4' 19.5' CD1-41 5,975,622.37 385,717.40 70' 20' 32.101" 150' 55' 38.997" 509' 2,293' 12.3' 19.5' CD1-42 5,975,615.01 385,710.21 70' 20' 32.027" 150' 55' 39.204" 516' 2,286' 12.2' 19.5' CD1-43 5,975,607.63 385,702.97 70' 20' 31.954" 150' 55' 39.412" 523' 2,279' 12.1' 19.5' CD1-44 5,975,600.75 385,696.00 70' 20' 31.885" 150' 55' 39.613" 531' 2,272' 12.1' 19.5' CD1-45 5,975,593.74 385,689.04 70' 20' 31.815" 150' 55' 39.813" 538' 2,265' 12.0' 19.5' CD1-46 5.975.586.84 385.681.76 70' 20' 31.746" 150' 55' 40.022" 545' 2.258' 12 2' 19.5' CD1-47 5,975,579.96 385,674.74 70' 20' 31.677" 150' 55' 40.224" 552' 2,251' 12.1' 19.5' J CD1-48 5,975,572.62 385,667.53 70' 20' 31.604" 150' 55' 40.432" 559' 2,244' 12.0' 19.5' CD1-49 5,975,565.51 385,660.62 70' 20' 31.533" 150' 55' 40.630" 566' 2,237' 12.0' 19.5' * CD1-22 CONDUCTOR WAS AS-BUILT 2/11/98. ALPINE MODULE:CD10 UNIT: CD ConocoPhillips ALPINE PROJECT CD1 WELL CONDUCTORS Alaska, Inc. ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK663D1 3/5/99 CE-CD10-663D1 2 OF 3 7 ORIGINAL ICD1-47wp03 Surface Location CL CPAI Cool dinate Converter l`_ qiii ,-From: - To: Qat NAD83 v 1 Region: Ialaska .� Datum: INAD27 Region: lalaska :LI C" Latitude/Longitude DegreesC Latitude/Longitude DegreesJ 9 � Decimal • 9 Decimal • C UTM Zone: South C UTM Zone: True 1 South ( State Plane Zone: 4 w Units: us-ft • C State Plane Zone: 4 Units: 'us-ft J C Legal Description INAD27 only) a Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 11525707.53 Township: 011 IN J Range: J005 11-E V 15975327.25 Meridian: IU J Section:I 1FNL _1 1551.39442 'FEL .=J3029.9140 Transform Qi_uit Help I CD1-47wp03 Intermediate Casing I J In CPAI Coordinate Converter ❑ From: -To: Datum: NAD 83 Region: �alaska L.LI Datum: INAD27 ..1 Region: ialaska • f Latitude/LongitudeDecimal Degrees • C Latitude/Longitude ;Decimal DegreesJ C UTM Zone: I- South C UTM Zone: True r Sao a State Plane Zone: 14 jJ Units: us-ft-E State Plane Zone: .4 ., Units: 1us-ft w t Legal[iescription INAD27 only) ( Legal Description(NAD27 only) Starting Coordinates: -- - Legal Description - X: 1522021.37E -- Township: 012 N � Range: 005 E Y: 15981961.74 ; Meridian: ;U ,1 Section: 30 1FNL T 4534.0436 FEL + .1514.6927 Transform Quit Help 1 OR1G1N1L 1 L CD1-47wp03 Intermediate Casing II J L1 CPAI Coordinate Converter From: —To: Datum: NAD83 +1 Region: alaska J Datum: INAD27 ._1 Region: alaska +(` Latitude/Longitude 1Deamal Degrees • r Latitude/Longitude Decimal Degrees • UTM Zone: I r South C UTM Zone: True South i• State Plane Zone: 14 Units: I _IdC State Plane Zone: ;4 , Units: us4t r* Legal Description INAD27 only' 4 Legal Description(NAD27 only) Starting Coordinates: ---- Legal Description X: 11521744.00 Township: 012 N + Range: (-005 IE Y. 15982486.00 Meridian: (U Section: 30 IFNL +1 14014.1498 IFEL J 11798.3500 Transform Quit I Help 1 CD1-47wp03 TD � CL CPAI Coordinate Converter ,,.: !101,1 From: To: Datum 1NAD83 1 Region: Ialaska Datum: NAD27 Region: alaska +j r- Latitude/Longitude !Decimal Degrees r'' Latitude/Longitude Decimal Degrees +' UTM Zone: South C UTM Zone: Tr ' True r South State Plane Zone: '4 Units: lus-ft _I State Plane Zone: 14 .J Units: 'us-ft + i C Legal Description INAD27 nnlyl 6 Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 11519347.00 Township: 012 N Range: ;005 IE j Y: 15987133.00 Meridian: IU Section: 19 FNL + 4685.4779 FEL + ,4251.0875 Transform Quit _ Help I ORIGINAL E tion for Permit to Drill,Well CD1-47 Saved: 18-Jun-12 Attachment 2—Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) ' 14" Hole/11-3/4"Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Gyro single shots,traveling cylinder diagrams Monitor well at base of permafrost,increased mud weight,decreased Gas Hydrates Low - mud viscosity,increased circulating times,controlled drilling rates, low mud temperatures Running Sands and Gravel Low Maintain planned mud parameters,Increase mud weight,use weighted sweeps. Abnormal Pressure in Surface Formations>2000' TVD Low Increased mud weight Lost Circulation Low Reduced pump rates,mud rheology,lost circulation material,use of low density cement slurries 10-5/8 x 11-3/4"Hole-9-5/8"Liner Interval Event Risk Level Mitigation Strategy Abnormal Pressure in Surface BOPE drills,Keep mud weight above 9.6 ppg.Check for flow Formations>2000' TVD Low during connections and if needed,increase mud weight. Reduced pump rates,reduced trip speeds,real time equivalent Lost circulation Low circulating density(ECD)monitoring,mud rheology,lost circulation material Reduced trip speeds,mud properties,proper hole filling,pumping Hole swabbing on trips Moderate out of hole,real time equivalent circulating density(ECD) monitoring, weighted sweeps. Abnormal Reservoir Pressure Low Well control drills,increased mud weight.No mapped faults occur _ across the path of the planned wellbore. Hydrogen Sulfide gas Low H2S drills,detection systems,alarms,standard well control practices, mud scavengers 6 x 8-1/2"Steerable Drilling Liner Section-7"Liner w/Tieback Event Risk Level Mitigation Strategy Reduced pump rates,reduced trip speeds,real time equivalent Lost circulation Low circulating density(ECD)monitoring,mud rheology,lost circulation material Reduced trip speeds,mud properties,proper hole filling,pumping Hole swabbing on trips Moderate out of hole,real time equivalent circulating density(ECD) monitoring,weighted sweeps. Abnormal Reservoir Pressure Low Well control drills,increased mud weight.No mapped faults occur across the path of the planned wellbore. Hydrogen Sulfide gas Low H2S drills,detection systems,alarms,standard well control practices, mud scavengers 6"Hole/Horizontal Production Hole Event Risk Level Mitigation Strategy Reduced pump rates,reduced trip speeds,real time equivalent Lost circulation Moderate circulating density(ECD)monitoring,mud rheology,lost circulation material CD 1-47 APD Page 10 of 15 Printed: 18-Jun-12 / tion for Permit to Drill,Well CD1-47 Saved: 18-Jun-12 Reduced trip speeds,Pump out to 9-5/8"shoe,mud properties, Hole swabbing on trips Moderate proper hole filling,pumping out of hole,real time equivalent circulating density(ECD)monitoring, weighted sweeps. BOPE drills,Keep mud weight above 9.9 ppg.Check for flow Abnormal Reservoir Pressure Medium during connections and if needed,increase mud weight.Well control drills,increased mud weight. Hydrogen Sulfide gas Low H2S drills,detection systems,alarms,standard well control practices, mud scavengers Well Proximity Risks: Directional drilling/collision avoidance information as required by 20 ACC 25.050(b)is provided in the following attachments. CD1-48 is the closest existing well with a clearance factor close to 1.487. Ellipse to ellipse separation is 3.54' @ 433' MD. Drilling Area Risks: Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted. Although this is unlikely,the rig will be prepared to weight up if required. Lower Shale Stability:HRZ/Kalubik and instability in the intermediate will require higher mud weights to stabilize these formations. A steerable drilling liner will be used in conjunction with a 3 string casing design to mitigate shale instability in the aforementioned formations.Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. V CD 1-47 APD Page 11 of 15 Printed: 18-Jun-12 I .tion for Permit to Drill,Well CD1-47 Saved: 18-Jun-12 Attachment 3—Well Schematic CD1-47 Well Plan WP03 Pro.osed Schematic updated 6!15/2012 by J.Samuel) 16"65#H-40 Welded All depths are Doyon 19 RKB. MD TVD A Conductor to 114' Upper Completion: O 1)4-%"12.6#/ft IBT-M Tubing(2 its) X0 to 3-'/z'EUE tubing 10i 0 2)3-1/2'TRMAXX-5E SSSV 2110' 2000' 2.812"X Profile(5.176"OD) 3)3-'/"x 1"Camco KBG-2 GLM (56.161 w/DV 4555' 3400' 11-314"60#L-80 BTC 4)3-'/"x 1"Camco KBG-2 GLM(56.16°)w/DV 8506' 5600' Surface Casing 2670'MD/2350'TVD @ 56 5)3-'/"x 1"Camco KBG-2 GLM(56.16°)w/DCK2 10487' 6700' cemented to surface pinned for 2500 psi casing to t_1.2.9 shear --Ii G 6)SLB BHP Gauge,Encapsulated I-Wire 11160' 6945' wlcannon clamps on every joint Planned TOC in 9 5/8-5233'ft MD 7)Baker 3-%]"Bullet Tieback Seal Assembly 11206' 6954' Top Qannik (seal length=15') 5733'MD/ Lower Completion: 4000'TVD 3-1/2" 9.3#L-80 EUE 8) Baker 5"x 7"ZXP Liner Top Packer 11183' 6950' X0 Hydril 521 Box X Hydril 563 Box Flexlock Liner Hanger Baker 80-20 20'Seal Bore Extention Top HRZ �I X0 5"Hydril 563 Box X 4-'%"TSH-563 pin 10249'MD I Q 9)HES XN 2.813"(2.75"NoGo) (791 11240' 6960' 6571'TVD .= 7"x 9 518"Liner Top Packer To be run w/RHC plug body - - @ 10383 MD/6645'TVD K-1 10)Freecap Swell packer 11483' 6988' 10710 MD/ (-100 ft MD into Alpine C) 6801'TVD , 9 518"40#L-80 Hydril 521 Liner 11)Freecap Swell Packer 11572' 6990' Top Kuparuk C to 10766'MD/6822'TVD 10950'MD/ 12)Pup Joint XO,10',4-'14"12.6#/ft L-80 11582 6990' 6889'TVD Hyd 563 Box X IBT-M Pin 0L 10C MD/ d 957 13)4'/z',12.6#/ft,L-80 IBT-M Liner w/pre-perf 16610 6960' 6891'TVD ; Oo pups(5)every 325'. e r-7-1 _ 14)4 W IBT-M Orange Peel Shoe 16612' 6960' so 1 • 00 O 0 L� ® 0,0 0 0 O o O o 0 0 0 0 �/ 4- Top Alpine C 0°0 000 0°o a°o 000 0°0 ��t.-✓f!"'r L� 11339'MD!X76'TVD / au O 4-%"12.6#L-80 Liner 6"Hole,TD at �r "� 7"26#L-80 Tenaris Blue Liner Hydril 563 from liner hanger through swell packers, t 16612'MD/6960'TVD 1 to 11383'MD 16980'TVD IBT-M to 16612'MD/6960'TVD CD 1-47 APD Page 12 of 15 Printed: 18-Jun-12 OR ( GIN ' i tion for Permit to Drill,Well CD1-47 Saved: 18-Jun-12 Attachment 4—Cement Summary CD1-47 Proposed Cementing Schematic J I 16"65#H-40 Welded Conductor to 114' 9-518"In Line Hanger Packer-2,520'MD 11-314"60#L-80 BTC 2670'MD/2350'TVD @ 56 TOC -5233 ft MD(500' above Qannik) Qannik 5,733'MD 4,000'TVD T'x 9 5/8"Liner Top Packer -10,383'MD 9 5/8"40#L-80 Hydril 521 Liner ` to 10,766'MD/6822'TVD @ 67.6 Top Kuparuk C 10950'MD/6889'TVD Top Alpine C 7"26#L-80 Tenaris Blue Liner wl 11339'MD/6.976'TVD Tieback A 11,383'MD/6,980'TVD @ 84 6"Hole,TD at 16612'MD/6960'TVD @ 90.3'= CD 1-47 APD Page 13 of 15 Printed: 18-Jun-12 ortGtNPL lion for Permit to Drill,Well CD1-47 Saved: 18-Jun-12 CD1-47 Cementing Program: 11.75"Surface Casing run to 2670'MD/2350'TVD. Cement from 2670'MD to 2170'(500'of fill)with Class G+Adds. @ 15.8 PPG,and from 2170'to surface with 10.7 ppg Arctic Set Lite 3.Assume 250% excess annular volume in permafrost and 50% excess below the permafrost(1580'MD),zero excess in 16"conductor. Lead slurry: (114')X 0.5155 ft3/ft X 1.0(0%excess)=58.8 ft3 (1580'-114')X 0.3161 ft3/ft X 3.5(250%excess)= 1621.9 ft3 above permafrost (2170'- 1580')X 0.3161 ft3/ft X 1.5 (50%excess)=279.7 ft3 below permafrost Total volume=58.8+ 1621.9+279.7= 1960.4 ft3=>801 Sx @ 2.45 ft3/sk System: 801 Sx ArcticSet Lite 3 @ 10.7 PPG Tail slurry: 500' X 0.3161 ft3/ft X 1.5(50%excess)=237.1 ft3 annular volume 80' X 0.6329 ft3/ft=50.6 ft3 shoe joint volume Total volume=237.1 +50.6=287.7 ft3=>246 Sx @ 1.17 ft3/sk System: 246 Sx Class G+0.2%D046 antifoamer,0.3%D065 dispersant and 0.8%S002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 9.625"Intermediate liner run to 10766'MD/6822'TVD Top of slurry is designed to be at 5233'MD,which is 500'above the top of the Qannik.Assume 40% excess annular volume. Lead Slurry: (9766-5233')X 0.2478 ft3/ft X 1.4(40%excess)= 1572.6 ft3 annular vol. Total volume= 1572.6 ft3=>684 Sx @ 2.3 ft3/sk System: 684 Sx Class G+3%D79,0.2%D46,0.35 gps D110 @ 12.2 ppg yielding 2.30 ft3/sk Tail Slurry: (10766-9766')X 0.2478 ft3/ft X 1.4(40%excess)=346.9 ft3 annular vol. 80' X 0.4176 ft3/ft=33.4 ft3 shoe joint volume Total volume=346.9+33.4=380.3 ft3=>328 Sx @ 1.16 ft3/sk System: 328 Sx Class G+0.4%D167,0.3%D65,0.11%B155,0.2%D046 @ 15.8 ppg yielding 1.16 ft3/sk 7"Intermediate liner run to 11383'MD/6890' TVD Top of slurry is designed to be at liner top at 10383'MD,which will isolate the Alpine C and Kuparuk. Assume 40% excess annular volume. Lead Slurry: (11383'-10766')x 0.1268 ft3/ft x 1.40(40%excess) = 109.5 ft3 annular vol. (10766'-10383')x 0.1585 ft3/ft x 1.00(no excess)= 60.7 ft3 liner lap vol. (10766'-10736')x 0.2148 ft3/ft x 1.00(no excess)= 6.4 ft3 shoe track vol.below cement z/ retainer Total volume= 109.5+60.7+6.4= 176.6 ft3=> 153 Sx @ 1.16 ft3/sk System: 153 Sx Class G+0.4%D167,0.3%D65,0.11%B155,0.2%D46 @ 15.8 ppg yielding 1.16 ft3/sk CD 1-47 APD Page 14 of 15 Printed: 18-Jun-12 • Page 1 of 3 Schwartz, Guy L (DOA) From: Samuell, John G [John.G.Samuell@conocophillips.com] Sent: Wednesday, June 27, 2012 7:21 AM To: Schwartz, Guy L (DOA) Subject: RE: Diverter Waiver CD1-47 (PTD 212-083) Attachments: CD1-47 7 in. Cementing and Tieback Assembly.pdf; CD1-47 -Steerable Drilling Liner Kick Stands.xls Guy, Answers below to your questions concerning the procedure. I have attached a few schematics of the equipment that we will be using on this well The steerable drilling liner(SDL) system is comprised of mostly off-the-shelf components; however, it is difficult to describe it's function through email. Ryan Robertson and I are working on this project together. He is the owner of the planning and execution of the SDL section of the well. We would be more than happy to come over to your office and run you through the assembly and answer any other operational questions you may have. We have a scaled model of the drilling assembly that helps visualize how everything goes together that we can also bring over. Ryan is available until 2 p m. tomorrow. After that he will be out of town for the next two weeks, so let me know if you would like to meet before then J.G. Samuell nihnq Engine,! Conocc,PHIlips Alaska Direct (907,265-6.309! Mobile (832)4b5-F14r; From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, June 26, 2012 2:46 PM To: Samuell, John G Subject: [EXTERNAL]RE: Diverter Waiver CD1-47 (PTD 212-083) JG, Couple more things.... 1) in step 5 what is the initial Ram BOP configuration? Pipe size , VBR range etc. 5" drill pipe Annular. 13-5/8" 5M Hydril GK Ram 1. 13-5/8" 5M Hydril (Double) Safety w/Variable 3-1/2"-6" Ram 2: 13-5/8" 5M Hydril (Double) Blind Rams Ram 3; 13-5/8" 5M Hydril Safety w/Variable 3-1/2"-6" 2) Step 7 ... what is min FIT to drill ahead. Minimum FIT to drill ahead in the intermediate#1 hole section is 12.5 ppg. 3) Step 9. Need to spell out changing Rams to 9 5/8" ... & Safety joint with FOSV on floor. Change out upper VBR rams with 9-5/8" Hydril 521 Pin crossover and make up with TIW valve for well control purposes during casing running 4) Step 13 .. is 12.5 the min FIT? Yes, 12 5 ppg will be the minimum FIT. 5) Step 18 doesn't quite make sense to me, can you explain how you are doing this... Is there another step to run tieback? Not used to liner drilling systems.... I have attached schematics of what the cementing / liner hanger/ liner top packer assembly looks like Also, if you can access You Tube from your office, Baker Hughes has a video that shows how the entire steerable drilling liner system operates. There is 45 seconds of marketing propaganda at the beginning of the video that you can skip over. The path to the video is http;//youtu.be/5v2HXGGEcS8 6/27/2012 Page 2 of 3 A brief description of how the process to cement tie-back the 7" is as follows: After tripping the BHA out of the liner, we trip in with a cement retainer, seal assembly liner hanger, liner top packer and an HRD setting tool. The seal assembly stabs into the PBR that is on top of the 7" liner used to drill to TD. Circulation is established, the liner hanger is set, the cement retainer is set 60 feet from the shoe, and cement is pumped. Once the cement is in place, we sting out of the cement retainer and set the liner top packer. The work string is then pulled out of the hole and a 7" seal assembly is run in the hole on the 7" tie-back assembly. The seal assembly then stings into a second PBR that was run into and left in the hole when running the cement string. 6) Need to spell out safety joint as in step 9 above. I have also attached schematics of the floor safety valves and the appropriate crossovers that we will have on the rig floor when running the outer and inner string of the SDL BHA. These will allow for the rig to shut in the well around the 7" casing while the inner string is being run Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Samuell, John G [mailto:John.G.Samuell@conocophillips.com] Sent: Tuesday, June 26, 2012 2:08 PM To: Schwartz, Guy L (DOA) Subject: RE: Diverter Waiver CD1-47 (PTD 212-083) Guy, They are buried down on the last page of the application with the cement calculations, but to summarize 11 75" Surface Casing Lead slurry -2.45 ft3/sk Tail Slurry - 1 17 ft3/sk 9.625" Intermediate Liner Lead Slurry -2.3 ft3/sk Tail Slurry - 1.16 ft3/sk 7" Intermediate liner w/tieback Lead Slurry - 1.16 ft3/sk J.G. Samuell Dnlhnq L=nyineei I ConocnPhill ps Alaska I Dirac[ (5071)265-6305 I Mobile (8,2)465 8148 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, June 26, 2012 2:01 PM 6/27/2012 Page 3 of 3 To: Samuell, John G Subject: [EXTERNAL]RE: Diverter Waiver CD1-47 (PTD 212-083) JG, Can you supply yield values for your cement in section 6? Can't calc volume.... Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Samuell, John G [mailto:John.G.Samuell@conocophillips.com] Sent: Tuesday, June 26, 2012 1:47 PM To: Schwartz, Guy L (DOA) Subject: RE: Diverter Waiver CD1-47 (PTD 212-083) Guy, Please find the attached spider map showing the surface casing point for CD1-47 J.G. Samuell Dn!I n) Enyu ev Conicol'htllips Alaska Uuoc± (007)203-0700 I Mobile (832)405-514.7 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, June 25, 2012 4:39 PM To: Samuell, John G Subject: [EXTERNAL]Diverter Waiver CD1-47 (PTD 212-083) JG, A spider map showing the proposed surface casing point in relation to the other SC points in the area ( much like a Annular Disposal map) is required for us to consider the diverter waiver. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 6/27/2012 � N I SLI H 11111.11111_-_ 111111_111111II � 1 I r 1111III' II• •1 IT' , _ c3) • Cf) 11 cs) e • m L %I, C Q cao CI- � oto •c J E _Ne a) = Q J Q s V 0o- a A •- = NLL &n � 5 0 I I I °v , r ' N V , v ' i.,_4.: V , ,-.-----daiit-5— — --*: , , , , , , ,___. �_ ; '•l1R: '! 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NC38 3.00 26.00 NC38 IF XO CPAI NC38 T2 Mod 3.00 29.00 CPAI NC38 XT-39 3.00 29.00 SaM Step 3 - Make Up Short Kick Stand Name Supplier Box Pin Length Cum dib NC50 Lifting Eye CPAI NA NC50 0.50 0.50 I5" NC50 TIW Valve ✓ CPAI NC50 NC50 3.00 3.50 a 1 7" BTC Pin x 5" NC50 XO Baker NC50 BTC 5.00 8.50 7" BTC Box x 7"TSH Pin Baker BTC TSH 5.00 13.50 5 4)4) A'4- South(-)/North(+) x,500 ft/in) 1 N 1 6„ cn o cn o ° 60 0 o 0 0 0 0 0 0 0 0 0 aa __ _L___ L ro N 0- 01- O ^' O N O - O 0 O CU n v W �. CTI - \ N n4 • (D C 0 — ,� _■ W I \il' w ,0O ODd w R7We ; a Pi, -,,,,, N N 1101014....\16, t -e-E1 Iw101110‘ ,,00.-114...1. 6j/.°441110111 e. fft.'.‘ Po __ N +. ,, .. __,- doei 1\ CD / ' 4 i4 k9g3 3D Urn° 517 , rty r_n, 2:4 r7r,1 O ` N d o O ( b :-!..24" oz* N amZ 7a O— I Ilk ON i'g i': 1 o gym' i m 4 7771 CC $$ bb Page 1 of 2 Schwartz, Guy L (DOA) From: Samuell, John G [John.G.Samuell@conocophillips.com] Sent: Tuesday, June 26, 2012 2:08 PM To: Schwartz, Guy L (DOA) Subject: RE: Diverter Waiver CD1-47 (PTD 212-083) Guy, They are buried down on the last page of the application with the cement calculations, but to summarize. 11.75" Surface Casing Lead slurry -2.45 ft3/sk Tail Slurry - 1 17 ft3/sk 9.625" Intermediate Liner Lead Slurry -2 3 ft3/sk Tail Slurry - 1 16 ft3/sk 7" Intermediate liner w/tieback Lead Slurry - 1.16 ft3/sk J.G. Samuell [idling Engineer I ConocoPhdhps Alaska Direct 9071 265-6309 Mobile (832r 46' 314`; From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, June 26, 2012 2:01 PM To: Samuell, John G Subject: [EXTERNAL]RE: Diverter Waiver CD1-47 (PTD 212-083) JG, Can you supply yield values for your cement in section 6? Can't calc volume.... Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Samuell, John G [mailto:John.G.Samuell@conocophillips.com] Sent: Tuesday, June 26, 2012 1:47 PM To: Schwartz, Guy L (DOA) Subject: RE: Diverter Waiver CD1-47 (PTD 212-083) Guy, Please find the attached spider map showing the surface casing point for CD1-47. 6/26/2012 Page 2 of 2 J.G. Samuel) Dnlhng Eng,neec ;CcnocoPhrIlipa Alaska , Diroct 1907)263 6309 Mobile 1332)485-6143 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, June 25, 2012 4:39 PM To: Samuell, John G Subject: [EXTERNAL]Diverter Waiver CD1-47 (PTD 212-083) JG, A spider map showing the proposed surface casing point in relation to the other SC points in the area (much like a Annular Disposal map) is required for us to consider the diverter waiver. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 6/26/2012 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME a2 a e if 7 PTD# 2—/Z-og.3 Development Service Exploratory Stratigraphic Test Non-Conventional/L) Well FIELD: p ! �l 70-A- POOL: ( tsc-c-- 6/'/ Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 C II O) 0 o c,- 0 r0 N a cn J O N 0 - - N c 'O , 2 , a a e CO N' to_ cM 0 C' 4) N > a ' No' o .m' o. 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