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Home My WebLink About210-111Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/10/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260210 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 224-34T 50283202050000 225044 1/30/2026 AK E-LINE Perf T41349 CLU 11RD 50133205590100 225013 1/24/2026 AK E-LINE Perf T41350 CLU 11RD 50133205590100 225013 1/27/2026 AK E-LINE Plug/Perf T41350 KU 24-07RD2 50133203520200 225126 1/14/2026 AK E-LINE CBL T41351 KU 24-07RD2 50133203520200 225126 1/20/2026 AK E-LINE IPFOF T41351 MPI 2-74 50029237850000 224024 1/25/2026 AK E-LINE Whipstock T41352 MPU 1-36 50029236770000 220047 2/1/2026 AK E-LINE Packer T41353 MPU R-110 50029238260000 225085 10/24/2025 YELLOWJACKET RCBL T41354 NFU 14-25 50231200350000 210111 12/29/2025 YELLOWJACKET CBL T41355 SDI 3-15 50029217510000 187094 1/23/2026 AK E-LINE Whipstock T41356 SRU 214A-27 50133101580100 225133 2/4/2026 YELLOWJACKET SCBL T41357 SRU 231-33 50133101630100 223008 7/31/2025 YELLOWJACKET PLUG-PERF T41358 SRU 242-16 50133204050000 188157 1/24/2026 YELLOWJACKET PLUG-PERF T41359 SU 43-10 50133207390000 225107 1/19/2026 YELLOWJACKET GPT-PLUG- PERF T41360 SU 43-10 50133207390000 225107 12/31/2025 YELLOWJACKET SCBL T41360 Please include current contact information if different from above. NFU 14-25 50231200350000 210111 12/29/2025 YELLOWJACKET CBL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.10 14:51:05 -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? 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): 11,700' See Schematic Casing Collapse Structural Conductor Surface 5,210psi 2,480psi Intermediate 2520/4790psi Production 7,480psi 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 907-564-4506 Noel Nocas, Operations Manager 907-564-5278 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: 2,992' PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY Tubing Grade: scott.warner@hilcorp.com Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 0391211 / 2095 210-111 50-231-20035-00-00 Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 10,840psi Size 178' 8-5/8" / 7-5/8"5,297' MD See Attached Schematic 2,992' Tubing Size: 10-3/4" 5717/6890psi 178' 4,714' 178' December 5, 2025 N/A 11,700' Perforation Depth MD (ft): 5,297' 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 North Fork Unit (NFU) 14-25CO 720 Same 10,311'5-1/2" ~1200 psi 11,700' See Schematic Length See Schematic See Schematic 11,002' 8,370' 7,673' North Fork Tyonek Gas 16" See Attached Schematic 2,786' m n P s 66 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.11.21 17:50:57 - 09'00' Noel Nocas (4361) 325-723 By Grace Christianson at 7:57 am, Nov 24, 2025 BOP test to 3000 psi. Test annular to 2500 psi Variance to 20 AAC 25.112 conditionally approved. See conditions of approval in attached variance request section. Provide 24 hrs notice for AOGCC opportunity to witness Tags and pressure tests to 1500 psi of both P&A plugs set at 5216' MD & above top of 5-1/2" casing stub. DSR-11/24/25TS 12/18/25 X X BJM 12/18/25 10-407 JLC 12/19/2025 12/19/25 Well Prognosis Well Name: NFU 14-25 API Number: 50-231-20035-00-00 Current Status: Producing Gas Well Permit to Drill Number: 210-111 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 1970 psi @ 7702 TVD Based on 0.1 psi/ft gas gradient to surface Max. Potential Surface Pressure: ~1200 psi Based on recent SITP Top of Applicable Gas Pool: 5480 MD/ 4902 TVD Well Status: SI Gas Producer/Milk Well Well Summary North Fork 14-25 is a vertical well drilled in 2010. In 2011, zones T-53, T-42, T-40, and T-39 were tested independently and were the only intervals to achieve sustained gas production. In 2014, the Hemlock was tested using an EZSV packer and coiled tubing; trace oil was recovered after swabbing but never flowed to surface. In 2017, a retrievable bridge plug (RBP) was set at 8,400 ft MD in an attempt to shut off water and add up hole perforations. Zones T-4 through T-35 were perforated but did not flow. Multiple attempts to retrieve the RBP failed, leaving a fish on top of the plug. Over subsequent years, CIBPs were set at 8,200 ft and 5,800 ft to test various zones from T-3 through T-7, but all perforations were unsuccessful. After Hilcorp acquired the asset in 2025, both CIBPs were milled out to allow additional perforations. New perforations were added from T-35 to T-2, but the well still could not sustain flow. The attached cross section of NFU 14-25 shows a total of 2,437 ft of tight rock within the Tyonek interval (gray shading in the depth track). A tight interval is defined as: DPHI 0.12 (shale or tight silt, based on 2.65 grain density) DPHI 0.30 (coal) The tight cutoff was established from no-flow tests in open perforations between 5,824 ft MD and 8,256 ft MD. Zones that produced gas include T2 and T39T53 (below the RBP), though T2 never achieved sustained production. Key observations supporting the proposed P&A plan: Continuous tight interval above the RBP from 8,400 ft MD to 7,380 ft MD (1,020 ft) Interbedded tight zones from 5,730 ft MD to 7,380 ft MD (710 ft total) No-flow tests in open perfs from 5,824 ft MD to 8,256 ft MD Consistent tight interval above T2 perfs from 5,475 ft MD to 5,540 ft MD (65 ft) Good cement bond throughout the wellbore These factors indicate adequate isolation for the proposed P&A plan. Superseded Well Prognosis The purpose of this Sundry is to abandon the current wellbore and pull tubing in prep for a rotary sidetrack. Notes Regarding Wellbore Deviation o Max deviation: 34° @ 2927 MD Min ID o 4.77 at 355 MD (chemical inj sub) Recent Tags o 9/3/25: EL perforated T-35 through T-2 intervals with 2-3/4 guns. Sustained flow was never encountered, and fluid level was never observed above ~7800 MD. o 8/31/25: CTU milled cement and CIBPs at 5800 and 8200. Pushed debris to 8365 CTM below T-35 perfs. o 6/2/25: SL RIH w/ 4.7 GR and tagged at 5743 RKB. Ran PT survey from 5733 to surface Variance Request to 20 AAC 25.112(c) A waiver is requested for setting a cement plug directly above the Hemlock interval, which was perforated at 11,24911,264 ft MD and 11,28411,294 ft MD. These perforations were made in 2014 using guns hung below an EZSV set at 11,235 ft MD, with coil tubing deployed to surface. Trace oil was encountered during testing, but the EZSV closed upon pulling out with coil, and no oil has been observed above the plug since. A CBL run on 10/10/10 confirms excellent cement isolation above the Hemlock perforations, across the EZSV setting depth, and through all Tyonek perforated intervals. In February 2017, a RBP was set at 8,400 ft MD. Subsequent flow tests after adding perforations above the plug yielded no gas, prompting attempts to retrieve the RBP. After three days of jarring without movement, the pulling tool, three crossovers, and a 3" G bait sub were left on top of the RBP. Hilcorp concludes that setting a cement plug above the Hemlock and other perforated intervals below the fish is not feasible due to the stuck RBP and fish on top. Cement will instead be placed above the fish/RBP to ensure isolation. Pre-Sundry Steps: 1. MIRU HAK Hot Oil Truck 2. Load wellbore/bullhead with freshwater to kill well 3. Ensure IA is loaded a. 9.6 ppg mud is in the annulus. Fluid level unknown 4. PT IA to 1500 psi 5. RDMO Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low /2,500 psi high 3. Dump bail 25 of cement on top of fish/RBP at ~8365 MD a. Est TOC @ 8,340 MD 4. Set CIBP at ~5600 to isolate perforations a. Notify AOGCC 24 hours ahead of plugging operation for opportunity to witness b. Pressure test plug to 1500 psi per 20 AAC 25.112.(g)(2) Superseded Well Prognosis 5. Dump bail 25 of cement on top of plug a. Est TOC @ 5,575 MD 6. Pull CBL to identify cement top in prep for tubing cut a. CBL is being run to confirm cement top and identify where to cut and pull tubing b. CBL ran on 10/10/2010 only logged to 4500 MD. Cement appears to be behind pipe at these depths. 7. RDMO EL 8. MIRU 401 workover rig 9. Install TWC, ND tree, NU BOP 10. Test BOPE Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. (Notify AOGCC 24 hours in advance of test to allow them to witness test). If the BOP is used to shut in on the well in a well control situation or if BOP equipment could be compromised, ALL BOP components utilized for well control or compromised must be tested prior to the next trip into the wellbore. BOPs will be closed as needed to circulate the well during this workover. 11. Pull TWC 12. Pick up on hanger with short joint 13. RU eline 14. RIH and cut tubing at ~X,XXX MD (this step may be performed pre-rig after step 6. with e-line) a. Depth to be determined based off cement top identified after running the CBL in step 6 15. Circulate well prior to pulling tubing a. 9.6 ppg mud is in the annulus. Fluid level should be at surface 16. Pull and lay down tubing 17. Eline set CIBP within 25 of the casing stub per 20 AAC 25.112(c)(2)(C) 18. Dump bail 25 of cement on top of plug a. Cement may be dump bailed post 401 RDMO 19. RDMO eline 20. MIT casing and plug to 1500 psi 21. ND BOP, NU dry hole tree 22. RDMO Rig 401 Attachments: 1) Actual Schematic. 2) Proposed Schematic 3) Rig 401 BOP Diagram 13-5/8 4) 14-25 Cross Section w/ CBL Superseded Well Prognosis Well Name: NFU 14-25 API Number: 50-231-20035-00-00 Current Status: Producing Gas Well Permit to Drill Number: 210-111 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O)(907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O)(907) 229-4824 (C) Maximum Expected BHP: 1970 psi @ 7702 TVD Based on 0.1 psi/ft gas gradient to surface Max. Potential Surface Pressure: ~1200 psi Based on recent SITP Top of Applicable Gas Pool: 5480 MD/ 4902 TVD Well Status: SI Gas Producer/Milk Well Well Summary North Fork 14-25 is a vertical well drilled in 2010. In 2011, zones T-53, T-42, T-40, and T-39 were tested independently and were the only intervals to achieve sustained gas production. In 2014, the Hemlock was tested using an EZSV packer and coiled tubing; trace oil was recovered after swabbing but never flowed to surface. In 2017, a retrievable bridge plug (RBP) was set at 8,400 ft MD in an attempt to shut off water and add up hole perforations. Zones T-4 through T-35 were perforated but did not flow. Multiple attempts to retrieve the RBP failed, leaving a fish on top of the plug. Over subsequent years, CIBPs were set at 8,200 ft and 5,800 ft to test various zones from T-3 through T-7, but all perforations were unsuccessful. After Hilcorp acquired the asset in 2025, both CIBPs were milled out to allow additional perforations. New perforations were added from T-35 to T-2, but the well still could not sustain flow. The attached cross section of NFU 14-25 shows a total of 2,437 ft of tight rock within the Tyonek interval (gray shading in the depth track). A tight interval is defined as: DPHI 0.12 (shale or tight silt, based on 2.65 grain density) DPHI 0.30 (coal) The tight cutoff was established from no-flow tests in open perforations between 5,824 ft MD and 8,256 ft MD. Zones that produced gas include T2 and T39T53 (below the RBP), though T2 never achieved sustained production. Key observations supporting the proposed P&A plan: Continuous tight interval above the RBP from 8,400 ft MD to 7,380 ft MD (1,020 ft) Interbedded tight zones from 5,730 ft MD to 7,380 ft MD (710 ft total) No-flow tests in open perfs from 5,824 ft MD to 8,256 ft MD Consistent tight interval above T2 perfs from 5,475 ft MD to 5,540 ft MD (65 ft) Good cement bond throughout the wellbore These factors indicate adequate isolation for the proposed P&A plan. Well Prognosis The purpose of this Sundry is to abandon the current wellbore and pull tubing in prep for a rotary sidetrack. Notes Regarding Wellbore Deviation o Max deviation: 34° @ 2927 MD Min ID o 4.77 at 355 MD (chemical inj sub) Recent Tags o 9/3/25: EL perforated T-35 through T-2 intervals with 2-3/4 guns. Sustained flow was never encountered, and fluid level was never observed above ~7800 MD. o 8/31/25: CTU milled cement and CIBPs at 5800 and 8200. Pushed debris to 8365 CTM below T-35 perfs. o 6/2/25: SL RIH w/ 4.7 GR and tagged at 5743 RKB. Ran PT survey from 5733 to surface Variance Request to 20 AAC 25.112(c) A waiver is requested for setting a cement plug directly above the Hemlock interval, which was perforated at 11,24911,264 ft MD and 11,28411,294 ft MD. These perforations were made in 2014 using guns hung below an EZSV set at 11,235 ft MD, with coil tubing deployed to surface. Trace oil was encountered during testing, but the EZSV closed upon pulling out with coil, and no oil has been observed above the plug since. A CBL run on 10/10/10 confirms excellent cement isolation above the Hemlock perforations, across the EZSV setting depth, and through all Tyonek perforated intervals. In February 2017, a RBP was set at 8,400 ft MD. Subsequent flow tests after adding perforations above the plug yielded no gas, prompting attempts to retrieve the RBP. After three days of jarring without movement, the pulling tool, three crossovers, and a 3" G bait sub were left on top of the RBP. Hilcorp concludes that setting a cement plug above the Hemlock and other perforated intervals below the fish is not feasible due to the stuck RBP and fish on top. Cement will instead be placed above the fish/RBP to ensure isolation. Pre-Sundry Steps: 1. MIRU HAK Hot Oil Truck 2. Load wellbore/bullhead with freshwater to kill well 3. Ensure IA is loaded 9.6 ppg mud is in the annulus. Fluid level unknown 4. PT IA to 1500 psi 5. RDMO Procedure: 1. MIRU 401 workover rig 2. Install TWC, ND tree, NU BOP 3. Test BOPE Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. (Notify AOGCC 24 hours in advance of test to allow them to witness test). Well Prognosis If the BOP is used to shut in on the well in a well control situation or if BOP equipment could be compromised, ALL BOP components utilized for well control or compromised must be tested prior to the next trip into the wellbore. BOPs will be closed as needed to circulate the well during this workover. 4. Pull TWC 5. PU workstring, trip in hole, set cement retainer at ~5216, and pump cement Notify AOGCC 24 hours ahead of plugging operation for opportunity to witness Estimated cement volume is 73 bbls 8356 (100 below bottom T-35 interval) to 5216 (cement retainer depth) o 3140 x 0.0232 bbl/ft = 73 bbls Pump cement until all 73 bbls is away and/or lock up 5. TOOH while circulating clean and laying down workstring 6. RU Eline 7. Tag top of cement retainer at ~ 5216. Pull CBL from top of cement retainer to identify cement top on the backside in prep for tubing cut CBL is being run to confirm cement top and identify where to cut and pull tubing CBL ran on 10/10/2010 only logged to 4500 MD. Cement appears to be behind pipe at these depths. 8. MIT tubing/plug to 1500 psi 9. Pick up on hanger with short joint 10. RIH and cut tubing at ~X,XXX MD Depth to be determined based off cement top identified after running the CBL 11. Circulate well prior to pulling tubing 9.6 ppg mud is in the annulus. Fluid level should be at surface 12. Pull and lay down tubing 13. Eline set CIBP within 25 of the casing stub per 20 AAC 25.112(c)(2)(C) Tag and log off plug 14. Dump bail 25 of cement on top of plug Cement may be dump bailed post 401 RDMO 15. RDMO Eline 16. MIT casing and plug to 1500 psi 17. ND BOP, NU dry hole tree 18. RDMO Rig 401 Attachments: 1) Actual Schematic. 2) Proposed Schematic 3) Rig 401 BOP Diagram 13-5/8 4) 14-25 Cross Section w/ CBL Updated by SRW 09-23-25 SCHEMATIC North Fork Unit NFU 14-25 PTD: 210-111 API: 50-231-20035-00-00 PBTD = 11,690 / TVD = 10,992 TD = 11,700 / TVD = 11,002 RKB to GL = 21 Max deviation 34° @ 2,927 MD OPEN HOLE / CEMENT DETAIL 13-1/2" Est. TOC @ Surface. 40 bbl 11 ppg spacer followed by 397 bbl 12 ppg cement. 9-7/8Est. TOC @ Surface. 17 bbl 10 ppg spacer followed by 183 bbl 10.5 ppg lead cement and 27 bbl 15.8 ppg tail cement. 6-3/4 CBL TOC @ ~4500. 41 bbl 12.5 ppg spacer followed by 167 bbl 13.5 ppg cement. CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16Conductor Driven to Set Depth 84 N-80 Weld 15.01 Surf 153 10-3/4"Surf Csg 45.5 L-80 BTC 9.95Surf 2,992 8-5/8" Intermediate Csg 32 L-80 Hydril 521/511 7.796 Surf 2,412 7-5/8"Intermediate Csg 29.7 L-80 BTC-M 6.8752,4125,297 5-1/2Production Csg 17 P110 Hydril 513 4.892Surf 11,700 16 Conductor 7-5/8 Csg 13-1/2 hole 5-1/2 Csg JEWELRY DETAIL No. Depth ID OD Item 1 3554.7676.812Chemical Injection Sub ¼ SS 0.049 wall injection line 2 8,365Milled CIBP Remnants- did not tag (9/2/25) 2a 8,370TOF (pulling tool, 3 XOs, 3 G bait sub on top) 3 8,400-4.892RBP @ +/- 8,400 4 8,7574.005.500Casing patch 8,757-8,778 (set 6/27/14) 5 11,2354.892EZSV 6-3/4 hole 1 10-3/4 Csg 9-7/8 hole 2/2a3 T5-T6 5 PERFORATION DETAIL Sand Top MD Btm MD Top TVD Btm TVD Amt Date Comments T-2 5,6165,6305,0005,0121410/01/22 Open T-2 5,630'5,661'5,012'5,039'31'09/07/25 Open T-2 5,703'5,717'5,076'5,088'14'09/07/25 Open T-3 5,8245,8445,1805,2182011/30/21 Open T-3 5,8245,8445,1805,2182009/07/25 Open T-3 5,871'5,881'5,224'5,233'10'09/07/25 Open T-3 5,8755,8885,2285,2391311/30/21 Open T-4 5,8955,9035,2455,253811/29/21 Open T-4 5,9145,9425,2625,2872802/06/17 Open T-4 5,9145,9345,2625,280'2809/07/25 Open T-4 5,934'5,943'5,280'5,289'9'09/07/25 Open T-5 6,020 6,040 5,358 5,376 2002/06/17 Open T-5 6,020' 6,040' 5,358' 5,377' 20' 09/07/25 Open T-6 6,141' 6,155' 5,470' 5,483' 14' 09/07/25 Open T-6 6,170 6,180 5,497 5,506 1011/29/21 Open T-6 6,170 6,180 5,497 5,506 1009/07/25 Open T-7 6,353' 6,357' 5,669' 5,673' 4' 09/07/25 Open T-7 6,357' 6,388' 5,673' 5,703' 31' 09/06/25 Open T-7 6,358 6,360 5,674 5,676 211/29/21 Open T-7 6,370 6,380 5,685 5,695 1011/29/21 Open T-7 6,397 6,400 5,711 5,714 311/28/21 Open T-7 6,401 6,403 5,715 5,717 211/28/21 Open T-7 6,410 6,440 5,733 5,752 3002/06/17 Open T-7 6,410 6,440 5,733 5,752 3009/06/25 Open T-7 6,440' 6,465' 5,752' 5,776' 25' 09/06/25 Open T-9 6,689' 6,695' 5,995' 6,000' 6' 09/05/25 Open T-10 6,709' 6,715' 6,014' 6,020' 6' 09/05/25 Open T-13 6,790' 6,810' 6,094' 6,114' 20' 09/05/25 Open T-14 6,834' 6,844' 6,138' 6,148' 10' 09/05/25 Open T-15 6,892' 6,898' 6,195' 6,201' 6' 09/05/25 Open T-15 6,944' 6,954' 6,247' 6,257' 10' 09/05/25 Open T-16 6,978' 6,998' 6,281' 6,301' 20' 09/05/25 Open T-20 7,320' 7,340' 6,623' 6,643' 20' 09/04/25 Open T-30 7,930' 7,934' 7,233' 7,237' 4' 09/04/25 Open T-30 7,934' 7,965' 7,237' 7,268' 21' 09/03/25 Open PERFORATION DETAIL Continued on Following Page Hemlock T2-T4 T53 4 T42 T39 T40 T35 T20-T30 T10-T16 T7-T9 Updated by SRW 09-23-25 SCHEMATIC North Fork Unit NFU 14-25 PTD: 210-111 API: 50-231-20035-00-00 PERFORATION DETAIL Continued from Previous Page Sand Top MD Btm MD Top TVD Btm TVD Amt Date Comments T-35 8,236 8,256 7,539 7,558 20 9/3/2025 Open T-35 8,250 8,256 7,552 7,558 6 2/5/2017 Open RBP 8,400 7,703' 10,537' 2/5/2017 T-39 8,536 8,548 7,838 7,851 12 3/7/2011 Isolated T-40 8,620 8,640 7,923 7,943 20 3/7/2011 Isolated T-42 8,760 8,776 8,063 8,079 6 3/1/2011 Isolated T-53 9,536 9,552 8,838 8,854 16 2/9/2011 Isolated EZSV 11,235 6/27/2014 Hemlock 11,249 11,264 10,551 10,566 15 6/27/2014 Isolated Hemlock 11,284 11,294 10,586 10,596 10 6/27/2014 Isolated Updated by SRW 11-20-25 Proposed North Fork Unit NFU 14-25 PTD: 210-111 API: 50-231-20035-00-00 PBTD = 11,690 / TVD = 10,992 TD = 11,700 / TVD = 11,002 RKB to GL = 21 Max deviation 34° @ 2,927 MD CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16Conductor Driven to Set Depth 84 N-80 Weld 15.01 Surf 153 10-3/4" Surf Csg 45.5 L-80 BTC 9.95Surf 2,992 8-5/8" Intermediate Csg 32 L-80 Hydril 521/511 7.796Surf 2,412 7-5/8" Intermediate Csg 29.7 L-80 BTC-M 6.875 2,412 5,297 5-1/2Production Csg 17 P110 Hydril 513 4.892Surf 11,700 16 Conductor 7-5/8 Csg 13-1/2 hole 5-1/2 Csg JEWELRY DETAIL No. Depth ID OD Item 1 3554.7676.812Chemical Injection Sub ¼ SS 0.049 wall injection line 2 ~3,130 --CIBP w/ 25 cement Est. TOC @ ~3,105 3 ~5,600CIBP w/ 25 cement Est. TOC @ 5,575 4 ~8,34025 cement Est. TOC @ 8,340 5 8,365Milled CIBP Remnants- did not tag (9/2/25) 6 8,370TOF (pulling tool, 3 XOs, 3 G bait sub on top) 7 8,400-4.892RBP @ +/- 8,400 8 8,7574.005.500Casing patch 8,757-8,778 (set 6/27/14) 9 11,2354.892EZSV 6-3/4 hole 1 10-3/4 Csg 9-7/8 hole 56/7 T5-T6 9 PERFORATION DETAIL Sand Top MD Btm MD Top TVD Btm TVD Amt Date Comments T-2 5,6165,6305,0005,0121410/01/22 Isolated T-2 5,630'5,661'5,012'5,039'31'09/07/25 Isolated T-2 5,703'5,717'5,076'5,088'14'09/07/25 Isolated T-3 5,8245,8445,1805,2182011/30/21 Isolated T-3 5,8245,8445,1805,2182009/07/25 Isolated T-3 5,871'5,881'5,224'5,233'10'09/07/25 Isolated T-3 5,8755,8885,2285,2391311/30/21 Isolated T-4 5,8955,9035,2455,253811/29/21 Isolated T-4 5,9145,9425,2625,2872802/06/17 Isolated T-4 5,9145,9345,2625,280'2809/07/25 Isolated T-4 5,934' 5,943' 5,280' 5,289' 9' 09/07/25 Isolated T-5 6,020 6,040 5,358 5,376 2002/06/17 Isolated T-5 6,020' 6,040' 5,358' 5,377' 20' 09/07/25 Isolated T-6 6,141' 6,155' 5,470' 5,483' 14' 09/07/25 Isolated T-6 6,170 6,180 5,497 5,506 1011/29/21 Isolated T-6 6,170 6,180 5,497 5,506 1009/07/25 Isolated T-7 6,353' 6,357' 5,669' 5,673' 4' 09/07/25 Isolated T-7 6,357' 6,388' 5,673' 5,703' 31' 09/06/25 Isolated T-7 6,358 6,360 5,674 5,676 211/29/21 Isolated T-7 6,370 6,380 5,685 5,695 1011/29/21 Isolated T-7 6,397 6,400 5,711 5,714 311/28/21 Isolated T-7 6,401 6,403 5,715 5,717 211/28/21 Isolated T-7 6,410 6,440 5,733 5,752 3002/06/17 Isolated T-7 6,410 6,440 5,733 5,752 3009/06/25 Isolated T-7 6,440' 6,465' 5,752' 5,776' 25' 09/06/25 Isolated T-9 6,689' 6,695' 5,995' 6,000' 6' 09/05/25 Isolated T-10 6,709' 6,715' 6,014' 6,020' 6' 09/05/25 Isolated T-13 6,790' 6,810' 6,094' 6,114' 20' 09/05/25 Isolated T-14 6,834' 6,844' 6,138' 6,148' 10' 09/05/25 Isolated T-15 6,892' 6,898' 6,195' 6,201' 6' 09/05/25 Isolated T-15 6,944' 6,954' 6,247' 6,257' 10' 09/05/25 Isolated T-16 6,978' 6,998' 6,281' 6,301' 20' 09/05/25 Isolated T-20 7,320' 7,340' 6,623' 6,643' 20' 09/04/25 Isolated T-30 7,930' 7,934' 7,233' 7,237' 4' 09/04/25 Isolated T-30 7,934' 7,965' 7,237' 7,268' 21' 09/03/25 Isolated PERFORATION DETAIL Continued on Following Page OPEN HOLE / CEMENT DETAIL 13-1/2" Est. TOC @ Surface. 40 bbl 11 ppg spacer followed by 397 bbl 12 ppg cement. 9-7/8Est. TOC @ Surface. 17 bbl 10 ppg spacer followed by 183 bbl 10.5 ppg lead cement and 27 bbl 15.8 ppg tail cement. 6-3/4 CBL TOC @ ~4500. 41 bbl 12.5 ppg spacer followed by 167 bbl 13.5 ppg cement. Hemlock T2-T4 T53 8 T42 T39 T40 T35 T20-T30 T10-T16 T7-T9 3 2 4 Superseded Updated by SRW 11-20-25 Proposed North Fork Unit NFU 14-25 PTD: 210-111 API: 50-231-20035-00-00 PERFORATION DETAIL Continued from Previous Page Sand Top MD Btm MD Top TVD Btm TVD Amt Date Comments T-35 8,236 8,256 7,539 7,558 20 9/3/2025 Isolated T-35 8,250 8,256 7,552 7,558 6 2/5/2017 Isolated RBP 8,400 7,703' 10,537' 2/5/2017 T-39 8,536 8,548 7,838 7,851 12 3/7/2011 Isolated T-40 8,620 8,640 7,923 7,943 20 3/7/2011 Isolated T-42 8,760 8,776 8,063 8,079 6 3/1/2011 Isolated T-53 9,536 9,552 8,838 8,854 16 2/9/2011 Isolated EZSV 11,235 6/27/2014 Hemlock 11,249 11,264 10,551 10,566 15 6/27/2014 Isolated Hemlock 11,284 11,294 10,586 10,596 10 6/27/2014 Isolated Superseded Updated by SRW 12-15-25 Proposed North Fork Unit NFU 14-25 PTD: 210-111 API: 50-231-20035-00-00 PBTD = 11,690 / TVD = 10,992 TD = 11,700 / TVD = 11,002 RKB to GL = 21 Max deviation 34° @ 2,927 MD CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16Conductor Driven to Set Depth 84 N-80 Weld 15.01 Surf 153 10-3/4" Surf Csg 45.5 L-80 BTC 9.95Surf 2,992 8-5/8" Intermediate Csg 32 L-80 Hydril 521/511 7.796Surf 2,412 7-5/8" Intermediate Csg 29.7 L-80 BTC-M 6.875 2,412 5,297 5-1/2Production Csg 17 P110 Hydril 513 4.892Surf 11,700 16 Conductor 7-5/8 Csg 13-1/2 hole 5-1/2 Csg JEWELRY DETAIL No. Depth ID OD Item 1 3554.7676.812Chemical Injection Sub ¼ SS 0.049 wall injection line 2 ~3,130 --CIBP w/ 25 cement Est. TOC @ ~3,105 3 ~5,216Cement Retainer 4 8,365Milled CIBP Remnants- did not tag (9/2/25) 5 8,370TOF (pulling tool, 3 XOs, 3 G bait sub on top) 6 8,400-4.892RBP @ +/- 8,400 7 8,7574.005.500Casing patch 8,757-8,778 (set 6/27/14) 8 11,2354.892EZSV 6-3/4 hole 1 10-3/4 Csg 9-7/8 hole 45/6 T5-T6 8 PERFORATION DETAIL Sand Top MD Btm MD Top TVD Btm TVD Amt Date Comments T-2 5,6165,6305,0005,0121410/01/22 Isolated T-2 5,630'5,661'5,012'5,039'31'09/07/25 Isolated T-2 5,703'5,717'5,076'5,088'14'09/07/25 Isolated T-3 5,8245,8445,1805,2182011/30/21 Isolated T-3 5,8245,8445,1805,2182009/07/25 Isolated T-3 5,871'5,881'5,224'5,233'10'09/07/25 Isolated T-3 5,8755,8885,2285,2391311/30/21 Isolated T-4 5,8955,9035,2455,253811/29/21 Isolated T-4 5,9145,9425,2625,2872802/06/17 Isolated T-4 5,9145,9345,2625,280'2809/07/25 Isolated T-4 5,934' 5,943' 5,280' 5,289' 9' 09/07/25 Isolated T-5 6,020 6,040 5,358 5,376 2002/06/17 Isolated T-5 6,020' 6,040' 5,358' 5,377' 20' 09/07/25 Isolated T-6 6,141' 6,155' 5,470' 5,483' 14' 09/07/25 Isolated T-6 6,170 6,180 5,497 5,506 1011/29/21 Isolated T-6 6,170 6,180 5,497 5,506 1009/07/25 Isolated T-7 6,353' 6,357' 5,669' 5,673' 4' 09/07/25 Isolated T-7 6,357' 6,388' 5,673' 5,703' 31' 09/06/25 Isolated T-7 6,358 6,360 5,674 5,676 211/29/21 Isolated T-7 6,370 6,380 5,685 5,695 1011/29/21 Isolated T-7 6,397 6,400 5,711 5,714 311/28/21 Isolated T-7 6,401 6,403 5,715 5,717 211/28/21 Isolated T-7 6,410 6,440 5,733 5,752 3002/06/17 Isolated T-7 6,410 6,440 5,733 5,752 3009/06/25 Isolated T-7 6,440' 6,465' 5,752' 5,776' 25' 09/06/25 Isolated T-9 6,689' 6,695' 5,995' 6,000' 6' 09/05/25 Isolated T-10 6,709' 6,715' 6,014' 6,020' 6' 09/05/25 Isolated T-13 6,790' 6,810' 6,094' 6,114' 20' 09/05/25 Isolated T-14 6,834' 6,844' 6,138' 6,148' 10' 09/05/25 Isolated T-15 6,892' 6,898' 6,195' 6,201' 6' 09/05/25 Isolated T-15 6,944' 6,954' 6,247' 6,257' 10' 09/05/25 Isolated T-16 6,978' 6,998' 6,281' 6,301' 20' 09/05/25 Isolated T-20 7,320' 7,340' 6,623' 6,643' 20' 09/04/25 Isolated T-30 7,930' 7,934' 7,233' 7,237' 4' 09/04/25 Isolated T-30 7,934' 7,965' 7,237' 7,268' 21' 09/03/25 Isolated PERFORATION DETAIL Continued on Following Page OPEN HOLE / CEMENT DETAIL 13-1/2" Est. TOC @ Surface. 40 bbl 11 ppg spacer followed by 397 bbl 12 ppg cement. 9-7/8Est. TOC @ Surface. 17 bbl 10 ppg spacer followed by 183 bbl 10.5 ppg lead cement and 27 bbl 15.8 ppg tail cement. 6-3/4 CBL TOC @ ~4500. 41 bbl 12.5 ppg spacer followed by 167 bbl 13.5 ppg cement. Hemlock T2-T4 T53 7 T42 T39 T40 T35 T20-T30 T10-T16 T7-T9 3 2 Updated by SRW 12-15-25 Proposed North Fork Unit NFU 14-25 PTD: 210-111 API: 50-231-20035-00-00 PERFORATION DETAIL Continued from Previous Page Sand Top MD Btm MD Top TVD Btm TVD Amt Date Comments T-35 8,236 8,256 7,539 7,558 20 9/3/2025 Isolated T-35 8,250 8,256 7,552 7,558 6 2/5/2017 Isolated RBP 8,400 7,703' 10,537' 2/5/2017 T-39 8,536 8,548 7,838 7,851 12 3/7/2011 Isolated T-40 8,620 8,640 7,923 7,943 20 3/7/2011 Isolated T-42 8,760 8,776 8,063 8,079 6 3/1/2011 Isolated T-53 9,536 9,552 8,838 8,854 16 2/9/2011 Isolated EZSV 11,235 6/27/2014 Hemlock 11,249 11,264 10,551 10,566 15 6/27/2014 Isolated Hemlock 11,284 11,294 10,586 10,596 10 6/27/2014 Isolated The picture can't be displayed.The picture can't be displayed.The picture can't be displayed.The picture can't be displayed. 13-5/8"Spherical Annular Height: 46" Weight: 12,806 13-5/8"LWS Double BOP Height: 37" Width: 93" Weight 9,900 lbs. TOP RAMS 2-7/8" TO 5-1/2" MULTI- RAMS BOTTOM RAMS BLIND RAMS 13-5/8"Mud Cross W/ 4- 1/16" outlets Height:28.5" Width 31" Dual 4-1/16" Manual Gate valves W/ DSA to 2-1/16" 4-1/16" Manual Gate valve & 4-1/16" HCR W/ DSA to 2-1/16" Full Mud Cross Assy. width w/ valves installed Width: 98.5" Weight: 2200 lbs. Kill side Choke side Height Addition for Ring Gaskets: 0" BOP Total Height: 111.5" BOP Total weight: 24,906 lbs. 13-5/8" 5m BOP Package W/ 4-1/16" Valves N FORK U 14-25 8/2010 12,000203,764 N FORK U 14-25 0 1 MGN_NF_TIGHT 0 1 MGN_NF_COAL 0 100 GR 5 20 CALI 1 100 RDEEP 1 100 RMEDI 1 100 RSHAL 150 50 DTC 0.6 0 NPHI 0.6 0 DPHI 60 0 TNPS 0 100 AMP3FT NF_T25 NF_T30 NF_T31 NF_T32 NF_T33 NF_T35 NF_T34 NF_T36 NF_T40 NF_T39 NF_T38 NF_T37 NF_T41 NF_T42 NF_T43 NF_T44 NF_T5 NF_T6 NF_T9 NF_T8 NF_T7 NF_T4 NF_T11 NF_T12 NF_T13 NF_T14 NF_T15 NF_T16 NF_T17 NF_T19 NF_T18 NF_T20 NF_T21 NF_T22 NF_T23 NF_T24 NF_T3 NF_T2 NF_T1 NF_T45 NF_T46 NF_T47 NF_T48 NF_T49 NF_T50 NF_T51 NF_T52 NF_T53 NF_T29 NF_T28 NF_T27 NF_T26 NF_T7A NF_T6A NF_T3A NF_T2A NF_T59 NF_T58 NF_T57 NF_T56 NF_T55 NF_T54 NF_TYONEK NF_T25 NF_T30 NF_T31 NF_T32 NF_T33 NF_T35 NF_T34 NF_T36 NF_T40 NF_T39 NF_T38 NF_T37 NF_T41 NF_T42 NF_T43 NF_T44 NF_T5 NF_T6 NF_T9 NF_T8 NF_T7 NF_T4 NF_T11 NF_T12 NF_T13 NF_T14 NF_T15 NF_T16 NF_T17 NF_T19 NF_T18 NF_T20 NF_T21 NF_T22 NF_T23 NF_T24 NF_T3 NF_T2 NF_T1 NF_T45 NF_T46 NF_T47 NF_T48 NF_T49 NF_T50 NF_T51 NF_T52 NF_T53 NF_T29 NF_T28 NF_T27 NF_T26 NF_T7A NF_T6A NF_T3A NF_T2A NF_T59 NF_T58 NF_T57 NF_T56 NF_T55 NF_T54 NF_TYONEK-4200(5475) -4300 (5591) -4400 (5706) -4500 (5820) -4600 (5932) -4700 (6042) -4800 (6151) -4900 (6257) -5000 (6363) -5100 (6467) -5200 (6571) -5300 (6673) -5400 (6774) -5500 (6875) -5600 (6976) -5700 (7076) -5800 (7176) -5900 (7276) -6000 (7376) -6100 (7476) -6200 (7576) -6300 (7676) -6400 (7776) -6500 (7876) -6600 (7976) -6700 (8076) -6800 (8176) -6900 (8276) -7000 (8376) -7100 (8476) -7200 (8576) -7300 (8676) -7400 (8776) -7500 (8876) -7600 (8976) -7700 (9076) -7800 (9177) -7900 (9277) -8000 (9377) -8100 (9477) -8200 (9577) -8300 (9677) -8400 (9777) -8500 (9877) -8600 (9977) 8500 8000 ( )(9277) (8876) 7500 (8776) 7400 6500 (6875) (6673) ( ) 5000 (6151) 4600 4400 (5591)(5591) (5475)4200 (9377) ( ) 4900 (5932) -4200420042005)(5475)(5475) -4300-430043004300 (5591)(5591)(5591)( ) -4400 ( ) 004500 (5820)(( ) 460046004600 (5932)(5932)(5932)( ) (6042)(6042)(6042)(6042)(6042)(6042) -48004800 (6151)(6151) 0 (6257)(6257)(6257)(6257) 5000 (6363)(6363) -5100 (6467)(6467)(6467)(6467) 52005200-52005200 (6571)(6571)( )( ) 5300530053005300-5300 (6673)(6673)(6673) 54005400 (6774)(6774)(6774)(6774)( ) 5500-55005500 (6875)(6875)( )( ) 5600-5600-5600 (6976)(6976)(6976)( ) 5700-57005700 5800 (7176)(7176)(7176)(7176)(7176)(7176)(7176) 5900-5900-5900 (7276)(7276)(7276)( )( ) 60006000 (7376) -6100 (7476)(7476) -6200 (7576)( ) 6300 (7676)(7676)(7676)(7676) -64006400 (7776)(7776) 6500-6500 (7876)(7876)(7876) -6600 (7976)(7976) -6700 (8076) 680068006800 (8176) 6800 6900-6900690069006900 (8276) -7000 (8376) 7000 -71007100 (8476)(8476) -7200 (8576) 200 7300-7300 (8676) -7300 0074007400 (8776)( )(8776) 75007500-75007500 (8876)(8876)(8876)( )( ) 7600-76007600 (8976) -77007700 (9076)(9076)(9076) -7800-7800 (9177)(9177)(9177)(9177) 7900-7900790079007900 (9277)(9277)(9277)(9277)(9277)(9277) 8000 (9377)( ) -8100-81008100 (9477)(9477) -82008200 (9577) 830083008300 (9677) -84008400 ( )(9777)(9777)(9777)(9777) -8500-8500 (9877)(9877) -86008600 -6900 63006300 (7376) 5900 5800 5500 ( ) (6151)(61 1) (5591) 4200-4200420042004200(5475)(5475(5475)(5475)(5475)(5475) 43004300-430043004300 (5591)(5591)(5591)(55(5591)( ) 44004400440044004400-4400 ( ) 45004500 (5820)(5820)( )(( ) 4600460046004600 (5932)(5932)(5932)(5932)( ) (6042)(6042)(6042)(6042)(6042)( )( ) 48004800 ((6151)(6151)(6151)(6151)(6151) 4900490049004900 (6257)(6257)(6257)(6257)(6257)(6257)(6257)(6257)( ) 50005000-5000-5000-5000 (6363) 5100-5100 (6467)(6467)(6467)(6467)(6467)(6467)(6467)( ) 5200-5200 (6571)(6571)( )( )( )( ) 530053005300-53005300 (6673)(6673)(6673)(6673)(6673) 54005400 (6774)(6774)(6774)(6774)(6774)(6774)( ) 5500-5500-5500 (6875)(6875)( )( )( ) 5600-5600 (6976)(6976)(6976)(6976)( ) 5700570057005700-5700 58005800 (7176)(7176)(7176)(7176)(7176)(7176)(7176)( ) 5900-5900-5900 (7276)(7276)( )( ) 6000-6000 (7376)(7376)( ) (7476)(7476) 6200 6300-63006300 (7676)(7676)(7676) -6400-64006400 (7776)( )(7776) 6500650065006500 (7876)(7876)(7876) -660066006600 (7976) 6800680068006800 6900-6900-69006900 ( )( )( ) 70007000 (8476) 7100 (8476)(8476) 200 7300-7300 740074007400 (8776)(8776) -7500-7500-7500 (8876)(8876)(8876)(8876)( ) 76007600 (8976) 77007700 (9076)(9076)(9076)(9076)(9076)(9076) -7800-7800 (9177)(9177)(9177) 79007900-79007900 (9277)(9277)(9277)(9277)( )(9277)(9277)( ) -800080008000 (9377)( ) -8100-81008100 (9477)(9477)(9477) 82008200 83008300830083008300 8400 (9777) 8400 (9777)(9777)(9777)(9777)(9777)(9777)(9777) 85008500 (9877)(9877)(9877) (5475)(5475) (5706)(5706)(5706) (5932)(5932) 4900 5200 (6875)(6875)(6875) 5600 (7076) -58005800 (7476)(7476) (7676) 6400 ( )( ) (7876) ( )( ) -6800 (8476)(8476) 7600 (9076)( ) 7800 (9177)(9177)(9177) (9377)(9377)(9377)(9377)(9377) (9477) -83008300 (9877)(9877)(9877) -8300 (7876) 64006400 (5475)(5475)(5475)(54 (5706)(5706) (5932)(5932) 490049004900-4900 52005200 (6875)(6875) 56005600 (7076)(7076) -5800 (7476)(7476) (7676)(7676) 64006400-6400-6400 ( )( ) (7876) ( )( ) 6800-68006800 (8476)(8476)(8476) 7600 (9076)( ) 780078007800 (9177)(9177)(9177)(9177) (9377)(9377)(9377)(9377)(9377)(9377) 8100 (9477)(9477)(9477) 8300-8300-830083008300-8300 84008400 ( ) 8500 (9877)(9877) A A' CBL 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 TS 12/18/25 TS 12/18/25 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/02/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251002 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 11A 50133205210100 224123 9/23/2025 YELLOWJACKET PERF T40937 BCU 13 50133205250000 203138 8/18/2025 YELLOWJACKET GPT-PERF T40938 BCU 13 50133205250000 203138 8/26/2025 YELLOWJACKET GPT-PERF T49038 BCU 13 50133205250000 203138 8/21/2025 YELLOWJACKET GPT-PLUG T40938 BCU 23 50133206350000 214093 9/10/2025 YELLOWJACKET PERF T40939 BCU 24 50133206390000 214112 9/16/2025 YELLOWJACKET PLUG-PERF T40940 BRU 212-35T 50283200970000 198161 9/18/2025 AK E-LINE Perf T40941 BRU 224-34T 50283202050000 225044 7/29/2025 AK E-LINE CBP/Punch T40942 BRU 224-34T 50133207170000 225044 9/19/2025 AK E-LINE GPT/Perf T40942 END 1-05 50029216050000 186106 9/25/2025 YELLOWJACKET IPROF T40943 END 2-08 50029217710000 188004 8/11/2025 YELLOWJACKET PERF T40944 END 4-50 50029219400000 189044 9/8/2025 YELLOWJACKET P-PROF T40945 KBU 11-08Z 50133206290000 214044 9/15/2025 AK E-LINE Perf T40946 KU 33-08 50133207180000 224008 7/1/2025 YELLOWJACKET PERF T40947 KU 41-08 50133207170000 224005 8/28/2025 YELLOWJACKET PERF T40948 KU 41-08 50883201990100 224005 9/16/2025 AK E-LINE Perf T40948 MPU R-108 50029238210000 225062 8/14/2025 YELLOWJACKET SCBL T40949 MRU K-06RD2 50733200880200 216131 9/12/2025 AK E-LINE CBL T40950 MRU M-01 50733203880000 187046 9/20/2025 AK E-LINE Perf T40951 MRU M-25 50733203910000 187086 9/21/2025 AK E-LINE Perf T40952 NCIU A-21A 50883201990100 225075 8/21/2025 AK E-LINE CBL T40953 NFU 14-25 50231200350000 210111 9/3/2025 YELLOWJACKET PERF T40954 PBU PTM P1-08A 50029223840100 202199 9/13/2025 YELLOWJACKET SCBL T40955 PBU W-35A 50029217990200 225076 9/17/2025 YELLOWJACKET SCBL T40956 SRU 241-33 50133206630000 217047 9/17/2025 AK E-LINE Perf T40957 SRU 32A-33 50133101640100 191014 9/23/2025 AK E-LINE Perf T40958 SRU 32A-33 50133101640100 191014 9/21/2025 AK E-LINE Perf T40958 Please include current contact information if different from above. NFU 14-25 50231200350000 210111 9/3/2025 YELLOWJACKET PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.03 09:00:56 -08'00' 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:N2, Mill CIBPs 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): 11,700'See Schematic Casing Collapse Structural Conductor Surface 5,210psi 2,480psi Intermediate 2520/4790psi Production 7,480psi 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 See Schematic See Schematic 11,002'11,566'10,177' North Fork Tyonek Gas 16" See Attached Schematic 2,786' 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 North Fork Unit (NFU) 14-25CO 720 Same 10,311'5-1/2" ~2568 11,700' See Schematic Length July 31, 2025 N/A 11,700' Perforation Depth MD (ft): 5,297'5717/6890psi 178' 4,714' 178'178' 8-5/8" / 7-5/8"5,297' MD See Attached Schematic 2,992' Tubing Size: 10-3/4" Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 10,840psi Size Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 391211 / 2095 210-111 50-231-20035-00-00 PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY Tubing Grade: scott.warner@hilcorp.com 907-564-4506 Noel Nocas, Operations Manager 907-564-5278 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: 2,992' m n P s R 66 t c N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:19 pm, Jul 22, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.07.22 12:33:39 - 08'00' Noel Nocas (4361) 325-434 X BOP test to 3000 psi BJM 7/23/25 SFD 7/22/2025 Perforate DSR-7/22/25 10-404 GKC for JLC 7/24/25 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.07.24 13:09:01 -08'00'07/24/25 RBDMS JSB 072425 Well Prognosis Well Name: NFU 14-25 API Number: 50-231-20035-00-00 Current Status: Producing Gas Well Permit to Drill Number: 210-111 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 3323 psi @ 7552’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure:2568 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.85 psi/ft using 16.4 ppg EMW LOT at the 7-5/8” int. casing shoe Shallowest Allowable Perf TVD: MPSP/(0.85-0.1) = 2568 psi / 0.75 = 3424‘ TVD (Will not perforate above top of pool @ 4902’ TVD) Top of Applicable Gas Pool: 5480’ MD/ 4902’ TVD Well Status: SI Gas Producer/Milk Well Well Summary North Fork 14-25 is a vertical well that was drilled in 2010. Over the years various zones were tested from the T- 2 through T-54 with minimal results. Currently 14-25 will not sustain flow. The purpose of this Sundry is to remove the two CIBPs that are in the well and add perforations in the T-2 through T-30. Notes Regarding Wellbore x Deviation o Max deviation: 34° @ 2927’ MD x Min ID o 4.77” at 355’ MD (chemical inj sub) x Recent SBHP o 1357 psi @ 5733’ MD- PT survey completed on 6/2/25 x Recent Tags o 6/2/25: SL RIH w/ 4.7” GR to 5743’ KB o 9/3/22: EL set CIBP at 5800’ MD and dumped 30’ of cement, est TOC at 5770’ MD o 11/27/21: EL set CIBP at 8200’ MD and perforated T4,T6, and T7 o 2/23/17: SL attempted to pull RBP at 8400’ MD. Unable to pull and left pulling tool on top of plug. Est. depth @ 8370’ MD Coil Procedure 1. MIRU Coil Tubing and pressure control equipment 2. PT BOPE to 250 psi low / 3,000 psi high a. Provide AOGCC 24hr notice for BOP test 3. RIH and mill cement and CIBP @ 5,770’ MD a. CIBP is set at 5800’ and TOC is estimated to be at 5700’ b. SL tagged at 5743’ KB on 6/2/25 with a 4.7” GR 4. Push CIBP to next CIBP at 8200’ MD a. Mill on CIBP remnants and POOH at WSL/OE discretion b. PU venturi junk basket as needed to remove CIBP remnants from top of CIBP at 8200’ MD , equivalent to 5,502' MD SFDWill not perforate above top of pool @ 4902’ TVD Well Prognosis 5. RIH, mill CIBP @ 8200’ MD and push to bottom a. Top of fish/ pulling tool for retrievable bridge plug is at 8370’ b. Bottom of T-35 perf is 8256’ MD 6. Reverse out wellbore with N2 a. 5” liner capacity – 194 bbls from top of fish 7. RDMO E-line Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low / 3,000 psi high 3. RIH and perforate T-2 – T-30 sands from bottom up: Below are proposed targeted sands in order of testing (bottom/up), but additional sand may be added depending on results of these perfs, between the proposed top and bottom perfs Zone Top MD Btm MD Top TVD Btm TVD Footage T2 ±5,630' ±5,661' ±5,012' ±5,039' ±31' T2A ±5,703' ±5,717' ±5,076' ±5,088' ±14' T3A ±5,824' ±5,844' ±5,182' ±5,200' ±20' T3A ±5,871' ±5,881' ±5,224' ±5,233' ±10' T4 ±5,914' ±5,943' ±5,262' ±5,289' ±29' T5 ±6,020' ±6,040' ±5,358' ±5,377' ±20' T6 ±6,141' ±6,155' ±5,470' ±5,483' ±14' T6 ±6,170' ±6,180' ±5,497' ±5,506' ±10' T7 ±6,353' ±6,388' ±5,669' ±5,703' ±35' T7A ±6,410' ±6,440' ±5,724' ±5,752' ±30' T7A ±6,440' ±6,465' ±5,752' ±5,776' ±25' T9 ±6,689' ±6,695' ±5,995' ±6,000' ±6' T10 ±6,709' ±6,715' ±6,014' ±6,020' ±6' T13 ±6,790' ±6,810' ±6,094' ±6,114' ±20' T14 ±6,834' ±6,844' ±6,138' ±6,148' ±10' T15 ±6,892' ±6,898' ±6,195' ±6,201' ±6' T15 ±6,944' ±6,954' ±6,247' ±6,257' ±10' T16 ±6,978' ±6,998' ±6,281' ±6,301' ±20' T19 ±7,181' ±7,211' ±6,484' ±6,514' ±30' T20 ±7,320' ±7,340' ±6,623' ±6,643' ±20' T30 ±7,930' ±7,965' ±7,233' ±7,268' ±35' T35 ±8,236' ±8,256' ±7,539' ±7,559' ±20' a. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation b. Use Gamma/CCL to correlate c. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) d. Pending well production, all perf intervals may not be completed Well Prognosis e. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. f. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO 5. If necessary, run cap string to aid with water production if encountered post perforating. Attachments: 1. Current schematic 2. Proposed Schematic 3. Coil Tubing BOP Schematic 4. Standard Well procedure – N2 Operations Updated by JKO 6-27-25 CURRENT SCHEMATIC North Fork Unit NFU 14-25 PTD: 210-111 API: 50-231-20035-00-00 PBTD = 11,690’ / TVD = 10,992’ TD = 11,700’ / TVD = 11,002’ RKB to GL = 21’ Max Deviation – 34 deg @ 2,927’ MD OPEN HOLE / CEMENT DETAIL 13-1/2"Est. TOC @ Surface. 40 bbl 11 ppg spacer followed by 397 bbl 12 ppg cement. 9-7/8”Est. TOC @ Surface. 17 bbl 10 ppg spacer followed by 183 bbl 10.5 ppg lead cement and 27 bbl 15.8 ppg tail cement. 6-3/4”CBL TOC @ ~4500’. 41 bbl 12.5 ppg spacer followed by 167 bbl 13.5 ppg cement. Sand Top MD Btm MD Top TVD Btm TVD Amt Date Comments T-2 5,616’5,630’14 10/1/2022 Open CIBP 5,800’ 9/30/22 T-3 5,824’5,844’5,180’5,218’20’11/30/21 Isolated T-3 5,875’5,888’5,228’5,239’13’11/30/21 Isolated T-4 5,895’5,903’5,245’5,253’8’11/29/21 Isolated T-4 5,914’5,942’5,262’5,287’28’2/6/17 Isolated T-5 6,020’6,040’5,358’5,376’20’2/6/17 Isolated T-6 6,170’6,180’5,497’5,506’10’11/29/21 Isolated T-7 6,358’6,360’5,674’5,676’2’11/29/21 Isolated T-7 6,370’6,380’5,685’5,695’10’11/29/21 Isolated T-7 6,397’6,400’5,711’5,714’3’11/28/21 Isolated T-7 6,401’6,403’5,715’5,717’2’11/28/21 Isolated T-7 6,410’6,440’5,733’5,752’30’2/6/17 Isolated CIBP 8,200’11/27/21 T-35 8,250’8,256’7,552’7,558’6’2/5/17 Isolated RBP 8,400’2/5/17 T-39 8,536’8,548’7,838’7,851’12’3/7/11 Isolated T-40 8,620’8,640’7,923’7,943’20’3/7/11 Isolated T-42 8,760’8,776’8,063’8,079’6’3/1/11 Isolated T-53 9,536’9,552’8,838’8,854’16’2/9/11 Isolated EZSV 11,235’6/27/14 Hemlock 11,249’11,264’10,551’10,566’15’6/27/14 Isolated Hemlock 11,284’11,294’10,586’10,596’10’6/27/14 Isolated CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 N-80 Weld 15.01”Surf 153’ 10-3/4"Surf Csg 45.5 L-80 BTC 9.95”Surf 2,992’ 8-5/8" Intermediate Csg 32 L-80 Hydril 521/511 7.796”Surf 2,412’ 7-5/8"Intermediate Csg 29.7 L-80 BTC-M 6.875”2,412’5,297’ 5-1/2”Production Csg 17 P110 Hydril 513 4.892”Surf 11,700’ 16” Conductor 7-5/8” Csg 13-1/2” hole 5-1/2” Csg JEWELRY DETAIL No.Depth ID OD Item 1 355’4.767”6.812”Chemical Injection Sub – ¼” SS 0.049” wall injection line 2 5,800’-4.24”CIBP @ 5,800’ w/ 30’ of cement. Est. TOC @ 5,770’ (set on 9/30/22) 3 8,200’-4.892”CIBP @ +/- 8,200’ (set 11/27/21) 4 8,370’TOF (pulling tool, 3 XO’s, 3” G bait sub on top) 5 8,400’-4.892”RBP @ +/- 8,400’ 6 8,757’4.00”5.500”Casing patch 8,757’-8,778’ (set 6/27/14) 7 11,235’4.892”EZSV 6-3/4” hole 3 1 10-3/4” Csg 9-7/8” hole 4 5 6 2 7 Updated by SRW 7-17-25 PROPOSED SCHEMATIC North Fork Unit NFU 14-25 PTD: 210-111 API: 50-231-20035-00-00 PBTD = 11,690’ / TVD = 10,992’ TD = 11,700’ / TVD = 11,002’ RKB to GL = 21’ Max deviation – 34° @ 2,927’ MD OPEN HOLE / CEMENT DETAIL 13-1/2"Est. TOC @ Surface. 40 bbl 11 ppg spacer followed by 397 bbl 12 ppg cement. 9-7/8”Est. TOC @ Surface. 17 bbl 10 ppg spacer followed by 183 bbl 10.5 ppg lead cement and 27 bbl 15.8 ppg tail cement. 6-3/4”CBL TOC @ ~4500’. 41 bbl 12.5 ppg spacer followed by 167 bbl 13.5 ppg cement. Sand Top MD Btm MD Top TVD Btm TVD Amt Date Comments T-2 5,616’5,630’5,000’5,012’14’10/1/2022 Open T2 5,630'5,661'5,012'5,039'31'TBD Proposed T2A 5,703'5,717'5,076'5,088'14'TBD Proposed T-3 5,824’5,844’5,180’5,218’20’11/30/21 Open T-3 5,875’5,888’5,228’5,239’13’11/30/21 Open T-4 5,895’5,903’5,245’5,253’8’11/29/21 Open T-4 5,914’5,942’5,262’5,287’28’2/6/17 Open T-5 6,020’6,040’5,358’5,376’20’2/6/17 Open T6 6,141'6,155'5,470'5,483'14'TBD Proposed T-6 6,170’6,180’5,497’5,506’10’11/29/21 Open T-7 6,358’6,360’5,674’5,676’2’11/29/21 Open T-7 6,370’6,380’5,685’5,695’10’11/29/21 Open T-7 6,397’6,400’5,711’5,714’3’11/28/21 Open T-7 6,401’6,403’5,715’5,717’2’11/28/21 Open T-7 6,410’6,440’5,733’5,752’30’2/6/17 Open T7A 6,440'6,465'5,752'5,776'25'TBD Proposed T9 6,689'6,695'5,995'6,000'6'TBD Proposed T10 6,709'6,715'6,014'6,020'6'TBD Proposed T13 6,790'6,810'6,094'6,114'20'TBD Proposed T14 6,834'6,844'6,138'6,148'10'TBD Proposed T15 6,892'6,898'6,195'6,201'6'TBD Proposed T15 6,944'6,954'6,247'6,257'10'TBD Proposed T16 6,978'6,998'6,281'6,301'20'TBD Proposed T19 7,181'7,211'6,484'6,514'30'TBD Proposed T20 7,320'7,340'6,623'6,643'20'TBD Proposed T30 7,930'7,965'7,233'7,268'35'TBD Proposed T-35 8,250’8,256’7,552’7,558’6’2/5/17 Open RBP 8,400’2/5/17 T-39 8,536’8,548’7,838’7,851’12’3/7/11 Isolated T-40 8,620’8,640’7,923’7,943’20’3/7/11 Isolated T-42 8,760’8,776’8,063’8,079’6’3/1/11 Isolated T-53 9,536’9,552’8,838’8,854’16’2/9/11 Isolated EZSV 11,235’6/27/14 Hemlock 11,249’11,264’10,551’10,566’15’6/27/14 Isolated Hemlock 11,284’11,294’10,586’10,596’10’6/27/14 Isolated CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor – Driven to Set Depth 84 N-80 Weld 15.01”Surf 153’ 10-3/4"Surf Csg 45.5 L-80 BTC 9.95”Surf 2,992’ 8-5/8" Intermediate Csg 32 L-80 Hydril 521/511 7.796”Surf 2,412’ 7-5/8"Intermediate Csg 29.7 L-80 BTC-M 6.875”2,412’5,297’ 5-1/2”Production Csg 17 P110 Hydril 513 4.892”Surf 11,700’ 16” Conductor 7-5/8” Csg 13-1/2” hole 5-1/2” Csg JEWELRY DETAIL No.Depth ID OD Item 1 355’4.767”6.812”Chemical Injection Sub – ¼” SS 0.049” wall injection line 2 5,800’-4.24”CIBP @ 5,800’ w/ 30’ of cement. Est. TOC @ 5,770’ (set on 9/30/22) 3 8,200’-4.892”CIBP @ +/- 8,200’ (set 11/27/21) 4 8,370’TOF (pulling tool, 3 XO’s, 3” G bait sub on top) 5 8,400’-4.892”RBP @ +/- 8,400’ 6 8,757’4.00”5.500”Casing patch 8,757’-8,778’ (set 6/27/14) 7 11,235’4.892”EZSV 6-3/4” hole 3 1 10-3/4” Csg 9-7/8” hole 4 5 6 2 7 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) 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I. Supervisor FROM:Matt Herrera SUBJECT: Wireline Lubricator Test Petroleum Inspector North Fork Unit 14-25 Vision Operating PTD 2101110; Sundry 321-556 11/23/2021: I traveled to the North Fork Unit Gas Field and met Vision Operating Lead Operator Sean Sullivan and All-American Company Man Joe Steiner to go over the planned well work – pressure and temperature log runs on slickline under lubricator in preparation for e-Line reperforating the well. The purpose of my visit was to witness the pressure test on wireline lubricator and well control equipment. Pollard Wireline was the contractor and were in the process of rigging up equipment when I arrived. They had the lubricator set on the tree cap would be utilizing a hydraulic pump for pressurization and monitor in the wireline operator cab. The lubricator was pressure tested at 3000 psi for 5 minutes and passed without issue. While on location inspected all well houses, production wells and custody transfer gas meters. Everything was in order – no issues/concerns. Attachments:Photos (4) 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.02.14 19:55:22 -09'00' 2021-1123_Wireline_Lubricator_NFU_14-25_mh Page 2 of 3 North Fork Unit 14-25 (PTD 2101110) E-line Lubricator; Site Inspection Photos by AOGCC Inspector M. Herrera 11/23/2021 Well sign Well hose and Pollard Wireline – rigging up 2021-1123_Wireline_Lubricator_NFU_14-25_mh Page 3 of 3 Lubricator test pump Wireline lubricator rigged up on NFU 14-25 P. 0. Box 92593 Lafayette, Louisiana 70509 February 15, 2022 Transmittal Letter Ms. Meredith Guhl AOGCC 333 W. 7th Ave., Ste 100 Anchorage, Alaska 99501 Ref: Document Filing – AOGCC 210-111 – Vision Operating 14-25 NFU Dear Ms. Guhl, Per our conversation accompanying this Transmittal Letter are the following files for the referenced well: 1. 502312003500 Vision Oper #14-25 NFU 26-4S-14W GR 5in.pdf 2. 502312003500 Vision Oper #14-25 NFU 26-4S-14W GR 5in.tif 3. 502312003500 Vision Oper #14-25 NFU 26-4S-14W GR.las 4. 502312003500 Vision Oper #14-25 NFU 26-4S-14W Perf Rec 2021.las 5. 502312003500 Vision Oper #14-25 NFU 26-4S-14W Perf Rec 2021.pdf 6. 502312003500 Vision Oper #14-25 NFU 26-4S-14W Perf Rec 2021.tif Please indicate receipt of the listed files by signing in the space provided below and returning one copy to Vision Operating at the address shown above. If you have any questions regarding this transmittal, please contact me at my e-mail address scott@sevendog.net or by phone at (713) 299-4665. Sincerely, Scott M. Daniel Consulting Geologist Received by: ___________________________________ Date: _____________ ____________________________________ Date::_______________By Meredith Guhl at 2:29 pm, Feb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y Samantha Carlisle at 12:51 pm, Jan 04, 2022 Claude Joseph Digitally signed by Claude Joseph Date: 2022.01.04 08:49:09 -06'00' DSR-1/4/22 ///& SFD 1/6/2022 RBDMS HEW 1/4/2021 3HUPLW WR 'ULOO 1XPEHU 1RUWK)RUN7\RQHN*DV 9LVLRQ2SHUDWLQJ 1RUWK)RUN8QLW 3HUIUURUDWH WCB 10-20-2023 188 W. Northern Lights Blvd - Suite 515 Anchorage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laude Joseph Digitally signed by Claude Joseph Date: 2022.01.04 08:48:38 -06'00' 188 W. Northern Lights Blvd - Suite 515 Anchorage, AK 99503 ͳȁʹ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± 5XQ ± 5XQ ± 5XQ ± 5XQ ± 5XQ ± :HOOZDVOLQHGXSWRSURGXFWLRQWKUXWKHQLJKW1RIORZ&XUUHQWO\SVL58 VOLFNOLQHWHVWOXEULFDWRUEOHHGZHOOWRSVL6ZDEZHOO WR 1RIORZ IW0'IW0'IW79'IW79' 7RS%DVH7RS%DVH SJ VHW&,%3# 7 : 7 : W J 7 : PT lubricator and PCE was required per the 10-403. -WCB 7 7 I 7HVWOXEULFDWRU SUHVVXUHFRQWURO\ HTXLSPHQWWSVL 188 W. Northern Lights Blvd - Suite 515 Anchorage, AK 99503 ʹȁʹ 1RUWK)RUN2SHUDWLRQV6XPPDU\ 6XQGU\ :HOOZDVOLQHGXSWRSURGXFWLRQWKUXWKHQLJKW1RIORZ&XUUHQWO\SVLDW KUV58VOLFNOLQHEOHHGZHOOWRSVL6ZDEZHOO WR 1RJDV 6KXWLQIRUKU1RSUHVVXUH5,+IOXLGOHYHO 6ZDEWR 6KXWLQ ZHOO5'VOLFNOLQH 0RQLWRU:HOO« ««SVL6KXWLQ0RQLWRUSUHVVXUH ««SVL6KXWLQ0RQLWRUSUHVVXUH ««SVL6KXWLQ0RQLWRUSUHVVXUH ««SVL6KXWLQ0RQLWRUSUHVVXUH ««SVL6KXWLQ0RQLWRUSUHVVXUH )LQDO5HSRUW NFU 14-25 Final Schematic Version: Final 16" 84# N-80HC 153' MD ID - 15" Driven 153' TVD Chemical Injection Sub - OD 6.812" / Drift ID 4.767" P110 @ 355' MD / 355' TVD 1/4" SS 0.049" wall chemical injection line 10 3/4" 45.5# L-80 2,992' MD 9.95" BTC 2,786' TVD TOC - documented returns to surface 8-5/8" 32# L-80 2,412' MD ID - 7.796" Hydril 521/511 2,312' TVD 7-5/8" 29.7# L-80 5,297' MD ID - 6.875" BTC-M 4,714' TVD TOC - documented returns to surface ft MD ft MD ft TVD ft TVD Top Base Top Base Work Conducted 5824 5844 5180 5218 321-556 5914 5942 5262 5287 6020 6040 5358 5376 6410 6440 5733 5752 5875 5888 5228 5239 5895 5903 5245 5253 6170 6180 5497 5506 6358 6360 5674 5676 6370 6380 5685 5695 6397 6400 5711 5714 RBP @ 8400' MD 6401 6403 5715 5717 (includes pulling tool, 3 XOs, 3" G bait sub on top) CIBP @ 8200' MD 8250 8256 7552 7558 r RBP @ 8400' MD 8536 8548 7838 7851 8620 8640 7923 7943 8760 (P) 8776 (P) 8063 (P)8079 (P) 9536 9552 8838 8854 5 1/2" x 4" ID Casing Patch @ 8757' - 8778' MD SV @ 11235' MD 11249 11264 10551 10566 11284 11294 10586 10596 * (P) indicates interval covered by casing patch Top of EZSV @ 11235' MD 5 1/2" 17# P110 11,700' MD ID - 3.920" Hydril 513 11,002' TVD PBTD: 11,690' MD / 10,992' TVD Cement above 4500' - CBL TD: 11,700' MD / 11,002' TVD 6 3/4" Hole December 5, 2021 16" Drive pipe 13 1/2" Hole 7-5/8" / 8-5/8" Intermediate Casing Max Dev - 34.24° @ 2927' MD / 2740' TVD CIBP @ ±8200' NFU 14-25 Perforations 8 7/8" Hole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Σ# 0' 79' 1)83HUIRUDWLRQV &,%3# ,QWHUYDOV3HUIRUDWHG 6XQGU\ This WBS has been superseded by a replacement WBS. -WCB 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: 188 W. Northern Lights Blvd Suite 515 Stratigraphic Service 6.API Number: Anchorage, AK 99503 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?CO 705 CO 720 25 Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): Tyonek Gas 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11700 11002 11566 10177 2500 8400 8370 Casing Collapse Structural Conductor N/A Surface 2480 Intermediate 2520 / 4790 Production 7480 Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): See WBD See WBD 12. Attachments: Proposal Summary Wellbore schematic 13. W ell 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:Tom Maunder, P.E. Claude Joseph Contact Email: stmaunder@aol.com Contact Phone: 907-529-1645 Authorized Title: VP Reserves, Vision Operating, LLC 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 See WBD 11700 See WBD None 5297 2992 11700 Perforation Depth MD (ft): 5297 16 10-3/4 178 4714 178 2992 103115-1/2 8-5/8.7-5/8 Length Size NA TVD Burst NA 10840 MD 5717 / 6890 N/A 5210 178 2786 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 391211 / 2095 North Fork 210-111 50-231-20035-00-00 Vision Operating, LLC North Fork Unit 14- Tubing Grade:Tubing MD (ft):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. By Samantha Carlisle at 1:17 pm, Oct 26, 2021 321-556 Claude Joseph Digitally signed by Claude Joseph Date: 2021.10.26 16:03:39 -05'00' DSr10/26/21SFD 10/26/2021 Pressure test wireline lubricator and pressure control equipment to 3000 psi minimum BJM 10/27/21 dts 10/27/2021 JLC 10/27/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.27 11:00:56 -08'00' RBDMS HEW 10/28/2021 188 W. Northern Lights Blvd - Suite 515 Anchorage, AK 99503 Well Name – NFU 14-25 (210-111) Well Summary Current Status: Well shut-in due to no flow. Well History: North Fork Unit (NFU) was drilled in 2010 and first produced in April 2011 and has not produced since January 2017. In total the well has produced slightly more than 200 BCF and a reported 90 bw. Since last produced, despite adding new perforations production has not been reestablished although it appears that all recently (2017) planned work was not accomplished. This work will include wellbore diagnostics designed to determine inflow to the wellbore, setting a CIBP to isolate the perforations proximate to the junk/fish at 8400’ md, and perforating/reperforating selected zones. Scope of Work Conduct SI production logs Set CIBP at ~8200’ Conduct Flowing production logs likely swabbing the well Add Perforations / Reperf Turn well over to production General Well Information Reservoir Pressure / TVD 2954 psi @ 7185’ MD / 6813’ TVD MASP 2269 psi Wellhead Type / Pressure Rating Vetco Gray – 5M Wellhead Assembly BOP Configuration Slickline / Eline WLV Well Type Gas Producer Estimated Start Date Later half November, 2021 188 W. Northern Lights Blvd - Suite 515 Anchorage, AK 99503 Operation Procedure 1. Drift monobore tubing to top of fish @ ±8400’MD. 2. RU and conduct SI production logs. 3. Set CIBP at ~8200’ md. 4. RU and conduct flowing production logs, swabbing as necessary. 5. Evaluate production logs. 6. Perforate / reperforate intervals as follows… ft MD ft MD ft TVD ft TVD Top Base Top Base 5875 5888 5228 5239 5895 5903 5245 5253 6170 6180 5497 5506 6358 6360 5674 5676 6370 6380 5685 5695 6397 6400 5711 5714 6401 6403 5715 5717 7. Swab as necessary 8. Rerun production logs as desired 9. Turn well over to Production. Pressure test wireline pressure control equipment to minimum 3000 psi. bjm NFU 14-25 Actual Schematic Version: Final 16" 84# N-80HC 153' MD ID - 15" Driven 153' TVD Chemical Injection Sub - OD 6.812" / Drift ID 4.767" P110 @ 355' MD / 355' TVD 1/4" SS 0.049" wall chemical injection line 10 3/4" 45.5# L-80 2,992' MD 9.95" BTC 2,786' TVD TOC - documented returns to surface 8-5/8" 32# L-80 2,412' MD ID - 7.796" Hydril 521/511 2,312' TVD 7-5/8" 29.7# L-80 5,297' MD ID - 6.875" BTC-M 4,714' TVD TOC - documented returns to surface ft MD ft MD ft TVD ft TVD Top Base Top Base 5914 5942 5262 5287 6020 6040 5358 5376 6410 6440 5733 5752 5875 5888 5895 5903 6170 6180 6358 6360 6370 6380 RBP @ 8400' MD 6397 6400 (includes pulling tool, 3 XOs, 3" G bait sub on top) 6401 6403 8250 8256 7552 7558 r RBP @ 8400' MD 8536 8548 7838 7851 8620 8640 7923 7943 8760 (P) 8776 (P) 8063 (P) 8079 (P) 9536 9552 8838 8854 5 1/2" x 4" ID Casing Patch @ 8757' - 8778' MD SV @ 11235' MD 11249 11264 10551 10566 11284 11294 10586 10596 * (P) indicates interval covered by casing patch Blue is proposed perfs dependent on production log analysis Top of EZSV @ 11235' MD 5 1/2" 17# P110 11,700' MD ID - 3.920" Hydril 513 11,002' TVD PBTD: 11,690' MD / 10,992' TVD Cement above 4500' - CBL TD: 11,700' MD / 11,002' TVD NFU 14-25 Perforations 6 3/4" Hole March 15, 2017 16" Drive pipe Max Dev - 34.24° @ 2927' MD / 2740' TVD 13 1/2" Hole 7-5/8" / 8-5/8" Intermediate Casing 9 7/8" Hole C T NFU 14-25 Proposed Schematic Version: Proposed 16" 84# N-80HC 153' MD ID - 15" Driven 153' TVD Chemical Injection Sub - OD 6.812" / Drift ID 4.767" P110 @ 355' MD / 355' TVD 1/4" SS 0.049" wall chemical injection line 10 3/4" 45.5# L-80 2,992' MD 9.95" BTC 2,786' TVD TOC - documented returns to surface 8-5/8" 32# L-80 2,412' MD ID - 7.796" Hydril 521/511 2,312' TVD 7-5/8" 29.7# L-80 5,297' MD ID - 6.875" BTC-M 4,714' TVD TOC - documented returns to surface ft MD ft MD ft TVD ft TVD Top Base Top Base 5875 5888 5228 5239 5895 5903 5245 5253 5914 5942 5262 5287 6020 6040 5358 5376 6170 6180 5497 5506 6358 6360 5674 5676 6370 6380 5685 5695 6397 6400 5711 5714 RBP @ 8400' MD 6401 6403 5715 5717 (includes pulling tool, 3 XOs, 3" G bait sub on top) 6410 6440 5733 5752 8250 8256 7552 7558 r RBP @ 8400' MD 8536 8548 7838 7851 8620 8640 7923 7943 8760 (P) 8776 (P) 8063 (P) 8079 (P) 9536 9552 8838 8854 5 1/2" x 4" ID Casing Patch @ 8757' - 8778' MD SV @ 11235' MD 11249 11264 10551 10566 11284 11294 10586 10596 * (P) indicates interval covered by casing patch Blue is proposed perfs dependent on production log analysis Top of EZSV @ 11235' MD 5 1/2" 17# P110 11,700' MD ID - 44.892" Hydril 513 11,002' TVD PBTD: 11,690' MD / 10,992' TVD Cement above 4500' - CBL TD: 11,700' MD / 11,002' TVD 6 3/4" Hole October 1, 2021 16" Drive pipe 13 1/2" Hole 9 7/8" Hole 7-5/8" / 8-5/8" Intermediate Casing Max Dev - 34.24° @ 2927' MD / 2740' TVD NFU 14-25 Perforations CIBP @ ±8200' PTD: 210-111 C T I.IGv STATE OF ALASKA MAR 2 8 2017 ALA OIL AND GAS CONSERVATION COM•ION REPORT OF SUNDRY WELL OPERATIONS , OGCC 1.Operations Abandon U Plug Perforations U Fracture Stimulate H Pull Tubing H Operations shutdown U Performed: Suspend ❑ Perforate Q Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑✓ Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Pull Velocity String,Set RBP❑� 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Cook Inlet Energy LLC Development H Exploratory ❑ 210-111 3.Address: 601 W.5th Ave.Suite 310,Anchorage,Ak Stratigraphic[II Service ❑ 6.API Number: 99501 50-231-20035-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 391211/2095 North Fork Unit#14-25 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): RPM Log North Fork,Tyonek Gas 11.Present Well Condition Summary: Total Depth measured 11700 feet Plugs measured 8400 feet true vertical 11002 feet Junk measured N/A feet Effective Depth measured 11566 feet Packer measured N/A feet true vertical 10868 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 178' 16" 178' 178' n/a n/a Surface 2992' 10 3/4" 2992' 2786' 5210 2480 Intermediate 5297' 8 5/8'/7 5/8" 5297' 4714' 5714/6890 2520/4790 Production 11700' 51/2" 11700' 10311' 10640 7480 Liner Perforation depth Measured depth 5914-9552 feet SCANNED APR 1 2 2017. True Vertical depth 5262-8854 feet Tubing(size,grade,measured and true vertical depth) n/a Packers and SSSV(type,measured and true vertical depth) n/a 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 5 0 275 275 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations EExploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Li Gas u WDSPL u 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: 316-583/316-620/317-043 Contact Amanda Dial Email adial@glacieroil.com i Printed Name Conr.:Ferry � / Title Drilling Manager Signature Phone 907-727-7404 Date 3/21/2017 / Form 10-404 Revised 5/2015 'j 7�f A n �+ 3 2017 �„ "!- DMS �v AP Submit Original Only ,, i'/1 GLACIER March 20, 2017 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 RECEIVED Anchorage, Alaska 99501 MAR 2 8 2017 Re: Report of Sundry Cook Inlet Energy, LLC: North Fork Unit 14-25 AOGCC Permit to Drill NO: 210-111 API No: 50-231-20035-00-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a Report of Sundry Well Operations for NFU 14-25. The work performed was covered under Approved Sundry's 316-583, 316-620 and 317-043 for pulling the coiled tubing velocity string, setting a retrievable bridge plug and adding perforations. If you have any questions, please contact me at(907) 727-7404. Sincer , Conrad P; Sr. Vice President Cook Inlet Energy, LLC (a Glacier Oil & Gas Corp. owned company) 10-404 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax lw—alr won.AIF iftI•11 MI • • • • NFU 14-25 Daily Operations Summary API: 50-231-20035-00-00 PTD#: 210-111 Date Activity 02 December 2016 RU Slickline. RIH with 1.25" bailer to 8499' WLM, unable to pass. POH. RIH with PXN plug to 8508' WLM and attempt to set in profile— �� unsuccessful. RIH with braided line brush and work through 8512'. RIH with PXN and attempt to set in profile again—no go. Reconfigure tools and RIH with PXN plug, work through to 8514' and attempt to set plug in profile—no go. RIH with bailer and hang up at 8502', work free and POH —spangs bent. RD Slickline. 28 January 2017 RU for well kill. Circulate down coil and up annulus, fluid returns after 70 bbls pumped. Circulate with full returns an additional 90 bbls. Shut down and monitor well. 29 January 2017 Monitor well. 30 January 2017 Monitor well. 31 January 2017 Monitor well. VS and annulus on vacuum. 01 February 2017 RU to circulate. Circulate down coil and up annulus, fluid returns after 17.75 bbls. Circulate with full returns for 360 bbls, no gas to surface. Shut down circulation. RU Coil Tubing and test BOPE to 3000 psi. Witness of test waived by AOGCC rep,Jim Regg. 02 February 2017 Finish RU coil. Continue to monitor well for additional 3 hours—well dead. RIH with Coil and latch velocity string. Pull hanger above coil BOPE. Close BOPE and monitor—well dead. Break lubricator above coil 0‘); BOPE and cut coil. Dress both ends and splice coil VS. Stab lubricator a� back onto BOPE, open BOPE and POH with velocity string. Blow down and RD coil. 03 February 2017 Continue RD Coil. ND 3 1/8"tree and NU 5 1/8"tree. Pressure test to 5000 psi. 04 February 2017 Finish RD Coil. RU Eline. Pressure test lubricator to 3000 psi. RIH with 4.72" GR and RIH to 8520',tag fluid at 3330'. RD Eline. 2IPage 18/ 05 February 2017 RU Slickline and N2 pumping. RIH with 4.72" GR and tag fluid at 3450'. Pump 129 gals of N2 @ 1400 psi. RIH and tag fluid at 6360', POH. RD Slickline and RU Eline. MU 5 %" retrievable bridge plug and RIH to _ 8400' and set. Increase wellhead pressure to 1650 psi using N2. PU Perf gun #1, 3 3/8" x 6 ft (6spf, 60 deg phase) and RIH to 8250'— 8256', all shots fired. 06 February 2017 PU Perf gun #2, 3 3/8" x 10 ft (6spf, 60 deg phase) and RIH to 6430'— 6440', all shots fired. PU Perf gun #3, 3 3/8" x 20 ft (6spf, 60 deg phase) and RIH to 6410'—6430', all shots fired. PU Perf gun #4, 3 3/8" x 20 ft (6spf, 60 deg phase) and RIH to 6020'—6040', all shots fired. RIH with spent gun and tag RBP at 8400'. PU Perf gun #5, 3 3/8" x 20 ft (6spf, 60 deg phase) and RIH to 5922'—5942', all shots fired. PU Perf gun #6, 3 3/8" x 8 ft (6spf, 60 deg phase) and RIH to 5914'—5922', all shots fired. No pressure change after any of the perf runs. RD Eline. 07 February 2017 Bleed down wellhead pressure to zero. RU slickline and RIH with 4.5" GR and tag fluid at 800'. RIH with 2.75" GR and tag fluid at 800'. RD Slickline. 20 February 2017 RU Slickline and pressure test lubricator to 3000 psi. RIH with 4.5" LIB and tag fluid at 736', tag RBP at 8371' (WLM), POH. MU 2.5" x 10' hydrostatic bailer and RIH. Work bailer and recover fill. RIH with bailer and recover additional fill. MU RBP pulling tool and RIH to RBP.Jai- down to open equalizing ports on RBP, fluid change of 32ft. 21 February 2017 RIH and engage baited G sub on RBP (fluid level at 810'). Jar up and pulled RBP pulling tool free from RBP, POH. RIH with 2" hydrostatic bailer, POH. RIH with RBP pulling tool and engage RBP (fluid level at 772'). Jar up on RBP—will not come free. 22 February 2017 Continue to Jar on RBP—unable to jar free. 23 February 2017 Contin Oar OP- -unable to jar free. RD Slickline. op of fish at 8370' WLM. ale 3IPage SU 14-25 Actual Schematic • Version: Final March 15,2017 GLACIER ; *', Tit -1 ►`; 5. y ' 16"Drive pipe ..hr'. .,a • 16" 84#N-80HC 153'MD '` r$s ID-15" Driven 153'TVD r 1 ' +, Chemical Injection Sub-OD 6.812"/Drift ID 4.767"P110 • @ 355'MD/355'TVD +;_. 1/4"SS 0.049"wall chemical injection line i h **y T:i r, Max Dev-34.24°@ 2927' `4* MD/2740'TVD T e�' e' 10 3/4" 45.5#L-80 2,992'MD 13 1/2"Hole ,�, 9.95" BTC 2,786'TVD '"" TOC-documented returns to surface .-f } ', ',1 , :,',, 7-5/8"/8-5/8"Intermediate Casing * 8-5/8" 32# L-80 2,412'MD ID-7.796" Hydril 5211511 2,312'TVD 7-518" 29.7# L-80 5, ' ID-6.875" BTC-M 4,729714'TVMDD ,r TOC-documented returns to surface T.. 9 7/8"Hole I [I' — • Perforations ft MD ft MD ft TVD _ ft TVD Top Base Top Base 5914 5942 5262 5287 6020 6040 5358 5376l LA 6410 6440 5733 5752 RBP @ 8400'MD \ 8250 8256 7552 7558 _ ' (includes pulling tool,3 XOs,3"G bait sub on top) Baker RBP @ 8400'MD --._.-- . 8536 8548 7838 7851 8620 8640 7923 7943 8760(P) 8776(P) 8063(P) 8079(P) =III[ lii 9536 9552 8838 8854 EZSV @ 11235'MD 11249 11264 10551 10566 5 1/2"x 4"ID Casing Patch @ 8757'-8778'MD 11284 11294 10586 10596 *(P)indicates interval covered by casing patch t_.- . t: °4.t i41 I~}' F -L14-4i Top of EZSV @ 11235'MD Y� 'i 5 1/2" 17#P110 11,700'MD 6 3/4"Hole -^ ID-3.920" Hydril 513 11,002'TVD PBTD:11,690'MD/10,992'TVD Cement above 4500'-CBL TD:11,700'MD/11,002'TVD • • vOF Tjrt 4b -- 4. THE STATE Alaska Oil and Gas i mss ��_ 4 ofALAS Conservation Commission -'".1170111 - it i— £t � __ 333 West Seventh Avenue " T r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 "4 Main: 907.279.1433 ALAS ..: , r,,..,.,5,.�,., .... Fax: '907.276.7542 www.aogcc.alaska.gov Stephen Ratcliff Sr. Drilling Engineer Cook Inlet Energy, LLC F , 601 W. 5th Ave., Ste. 310 scANN i ,, C L ti Anchorage, AK 99501 Re: North Fork Field, Tyonek Gas Pool,NFU 14-25 Permit to Drill Number: 210-111 Sundry Number: 317-043 Dear Mr. Ratcliff: 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 AOGCCgrants forgood cause shown,aperson affected byit mayfile 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, a/16 /CL.. Cathy P. Foerster Chair DATED this -ay of February, 2017. RBDMS (, FEB - 3 2017 RECEIVED • STATE OF ALASKA • . ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 2 I' 5 20 7 2. APPLICATION FOR SUNDRY APPROVALS D � f 7 20 AAC 25.280 AOG C 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 2 • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program Q- Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other:Vel.String Pull&Set RBP El- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Cook Inlet Energy LLC Exploratory ❑ Development ❑✓ 210-111 - 3.Address: ❑ 6.API Number: Stratigraphic ElService 601 W.5th Ave.Suite 310,Anchorage,Ak 99501 50-231-20035-00-00 - 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.720 North Fork Unit#14-25 - Will planned perforations require a spacing exception? Yes ❑ No 2 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 391211/2095 - North Fork, Tyonek Gas - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,700' • - j jpo2i 11,566' 10,177' 2500 psi n/a none Casing Length ,9> (1 Size MD TVD Burst Collapse Structural I, Conductor 178' 16" 178' 178' N/A N/A Surface 2,992' 10 3/4" 2,992' 2,786' 5210 2480 Intermediate 5,297' 8 5/8"/7 5/8" 5,297' 4,714' 5,714'6,890 2,520/4,790 Production 11,700' 5 1/2" 11,700' 10,311' 10,640 7,480 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8,536'to 9,552'(attached) 7,838'to 8,854'(attached) Coiled tubing VS 1.75" N/A 8520' Packers and SSSV Type: N/A Packers and SSSV MD(ft)and TVD(ft): N/A 12.Attachments: Proposal Summary U Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program ❑., BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑I Service ❑ 14.Estimated Date for 15.Well Status after proposed work: CommencingASAP Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 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. Contact Amanda Dial Email adial@glaieroil.com Printed Name Title Stephen Ratcliff Sr.Drilling Engineer Signature �` Phone Date Q `\ 907-433-3808 i` 4 in ^ — COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Testy Mechanical Integrity Test ❑ Location Clearance 111 P5F 2.I L' it; Other: .(- 3007 es; (-T 1 I" 1Zs-T- 3 L -- SG 3 c-444. L;ei -S ' r z. 4.pp l 4,..,4 4. ..5.- LC Post Initial Injection MIT Req'd? Yes ❑ No ❑ ,r „4-- 5,4 Exception Required? Yes ❑ Nod Subsequent Form Required: / ) U`1 �� « 317 trf3� 3tt, -s / ry APPROVED BY RBDIVIS LL'FEB 3 L01l7 Approved by:ex./67 p99„....0.14....,_ COMMISSIONER THE COMMISSION Date: z-2 - 1 7 Submit Form and Form 10-403 Revised 11/2015 Rico p t' valid for 12 months from the date of approval. Attachments in Duplicate 0II 02 -/ �sb • • RECEIVED GLACIER JAN 2 5 2017 January 24th, 2017 ,A0GCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 RE: Sundry Application Cook Inlet Energy, LLC: North Fork Unit 14-25 API: 50-231-20035-00-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a sundry for North Fork Unit 14-25, PTD: 210-111 requesting to modify the approved program under Sundry#316-583 &#316-620. Based on additional log analysis,the perforation intervals were re-evaluated. CIE is requesting to perforate 2 additional zones and adjust the top of a previously identified interval. Additionally, the retrievable bridge plug will be moved to 8400' MD. If you have any questions, please contact me at (907) 727-7404. Sincerely, Stephen Ratcliff Sr. Drilling Engineer Cook Inlet Energy, LLC (a Glacier Oil&Gas owned company) 601 W 5th Ave,Suite 310 Anchorage,AK 99501 1 • • • < GLACIER WELL NAME—North Fork Unit 14-25 Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is producing. Current Perforations MD TVD 8536' - 8548' • 7838' - 7851' 8620' - 8640' • 7923' - 7943' 8760' - 8776' • 8063' - 8079' 9536' - 9552' - 8838'- 8854' 11249' - 11264' • 10551' - 10566' 11284' - 11294' • 10586' - 10596' Scope of Work: • Completed: Attempt to set mechanical barrier in CT VS - unsuccessful o Extended flow check will be performed. o If flow is detected,blind shear rams will be utilized. )17 • Kill Well Rig up Coil. Test Coil BOPE to 3,000 psi. ear ' • Pull Coiled tubing velocity string. �'� �,� v �w ' • Remove VS hanger, NU tree. Tivo • Rig up Eline. Test Lubricator to 3,000 psi. r • Rig up N2 and pump specified volume. J • Set Retrievable Bridge Plug at 8400' MD. o� • Perforate selected intervals. -- 3(1'' • Rig down Eline. General Well Information: 3 Reservoir Pressure /TVD: 3,439 psi @ 8640' MD / 7943'TVD ` r ii MASP: 2,645 psi Wellhead Type/Pressure Rating: 13-5/8" 5K Wellhead BOP Configuration: Blinds in lower, coil rams in upper Well Type: Gas Well Estimated Start Date: ASAP Drilling Manager: Sr. Drilling Engineer: Production Manager: Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-9738 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com 2 . < • • GLACIER Program Phase 1 1. Completed:Attempt to set mechanical barrier in CT VS - Unsuccessful 2. Shut in well. 3. Kill Well. 4. Rig up Coil BOPE on top of 3-1/8" 5M flange 5. Test Coil tubing BOPE to 3000 psi. 6. Recover 1-3/4" coil velocity string. a. Extended flow check will be performed. b. If flow is detected,blind shear rams will be used. 7. RD coiled tubing unit. Phase 2 1. Close upper and lower master. 2. Remove Coiled tubing velocity string hanger and valves above (3 1/8" actuator, tee, swab, and wing valves). 3. RU Lubricator. 4. Open upper and lower master valves. 5. Set 2-way check. 6. Close Lower Master. 7. RD Lubricator. 8. Remove upper master and install 5-1/8" actuator,tee, swab valve, and wing valves. 9. Test seals. 10. RU Lubricator. 11. Pull 2-way check. 12. RD Lubricator. Phase 3 1. Cancelled: RU and test Eline Lubricator to 3,000 psi. 2. Cancelled: RIH with TDT tool to 9,700' MD and log to 5,200' MD. 3. Cancelled: Rig down lubricator and Eline. 4. Cancelled: Evaluate log. 5. Rig up and test Eline lubricator to 4,000 psi. 6. Rig up to pump N2. 3 . . < • • GLACIER 7. Pump specified volume of N2 to push fluid level to 6600' MD. 8. MU 51/2" retrievable brid e lu . 9. RIH with RBP and set t 8400' MD. Pi,- P�,ti�10. Perforate the following vals with 3-3/8" 6 spf, 6phase. a. Ensure shut-in wellhead pressure is minimum of 3000 psi. b. Report fluid level tag if indicated. c. Observe and report pressure increase, if any,after each interval is perforated. d. Consult with Production if pressure increase is seen to determine whether to suspend perforations and take well to production. , Proposed Perforations to Add: Top, MD Bottom, MD Top,ND Bottom,TVD New 5914' • 5942' 5262' 5287' " Sundry 316-620 6020' 6040' 5358' 5376' (),44 Top adjusted 6410' 6440' 5733' 5752' Cancelled 6448' 6465' 5759' 5776' New 8250' 8256' 7552' 7558' 11. Rig down lubricator and Eline. 12.Turn well over to production. Phase 4 If well has difficulty producing: 1. Rig up Slickline. 2. RIH and swab well. 3. Rig down Slickline. 4. Turn well over to production. Phase 5 If swabbing does not bring well online: 1. Rig up Coil BOPE on top of 5-1/8" 5M flange. 2. RU coiled tubing unit and flow back iron and N2. 3. Test Coil tubing BOPE to 3000 psi. 4. RIH in stages lifting well clean of water to diffuser tank. a. Repeat as needed to TD. 5. RD Coil. 6. Turn well over to production. 4 • • — Version: Current Permit#: 210 111 April/7/2015 Velocity Install API#: 231-20035-00-00 NFU #14-25 Prop. Des:ADL-391211/2095 KB elevation: 679' (21'AGL) ' FSL, ' FEL Latitude: 59`47'46.xxxx"N S26 T4S R14W S.M. Longitude: 151"37'45.xxxx"W Spud: _ Cook Inlet Energy_ TD: Rig Released: ^ Structural Pine-Driven 16" X-56 84 ppf I i Top Bottom 1 MD Surf 153' TVD Surf 153' TChemical Injection Nipple set @ Surface Casing 355'MD. Drift-4.767"ID P110 10-3/4" L-80 45.5ppf 6.812"OD Top Bottom MD 0' 2,992' • TVD 0' 2,786' i II* Jntermediate8 5/ " Casing-tapered string 8 5/8" L-80 26 ppf Hydril Top Bottom MD 0' 2,412' TVD 0' 2,312' 7 5/8" 29.7# L-80 BTC-M MD 2412' 5,297' -:- TVD 2312' 4,714' 1 3/4"Coil Velocity String . ID 1.482" Production Casing • 5 1/2" P-110 17 ppf Hydril 513 ID 4.892" Top Bottom ,. MD 0' 11,690' .. TVD 0' 10,992' !i End of tubing 8520'MD Perforation Intervals: 7822'TVD MD TVD 8,536'-8,548' 7838'-7851' (Stinger OD 1.38"ID.87" 8,620'-8,640' 7923'-7943' "7" 8,760'-8,776' 8063'-8079 9,536'-9,552' 8838'-8854' , 5 1/2"x 4"ID Casing Patch From 8757'to 8778' ' ITOP of EZSV @ 11235'MD Added Perforation Intervals T �, MD TVD 11,249'-11,264' 10,551'-10,566' 11,284'-11,294' 10,586'-10,596' IQ MID 11,700'MD 11,690'MD 11,002'TVD 10,992'TVD • Version: Proposed Permit#: 210 111 ' Wellbore Schematic API #: 231-20035-00-00 1/24/2017 Prop. Des:,ADL-391211/2095 NFU #14-25 KB elevation: 679' (21'AGL) ' FSL, ' FEL Latitude: 59*47'46.xxxx"N S26 T4S R14W S.M. Longitude: 151*37'45.xxxx"W Spud: Cook Inlet Ener TD: — Energy Released: — Structural Pipe-Driven '�. 16" X-56 84 ppf Top Bottom I MD Surf 153' ITVD Surf 153' — Chemical Injection Nipple set Surface Casing @ 355' MD. Drift-4.767"ID 10-3/4" L-80 45.5ppf Top Bottom MD 0' 2,992' • TVD 0' 2,786' '4111i*Ik -111111111111141141111 taered strip \®� Intermediate Casingp q I gre \ 8 5/8" L-80 26 ppf Hydril Top Bottom MD 0' 2,412' • TVD 0' 2,312' 7 5/8" 29.7# L-80 BTC-M MD 2412' 5,297' TVD 2312' 4,714' Production Casing 5 112" P-110 17 ppf Hydril 513 ID 4.892" Top Bottom = MD 0' 11,690' TVD 0' 10,992' Proposed Perf Intervals: MD TVD 5914'-5942' " 5262'-5287' 6020'-6040' . 5358'-5376' Set RBP @ 8400'MD 6410'-6440' . 5733'-5752' — = 8250'-8256' . 7552'-7558' Perforation Intervals: i" MD TVD 8,536'-8,548'. 7838'-7851' 5 1/2"x 4" ID Casing Patch 8,620'-8,640' - 7923'-7943' From 8757'to 8778' 8,760'-8,776' 8063'-8079 9,536'-9,552' 8838'-8854' TOP of EZSV @ 11235' MD <__--------- P-1erforation ry —.E I , MTVD 11,249D' 1,264' 10,551'-10,566' 11,284'-11,294' •10,586'-10,596' 1 TD PBTD 11,700'MD 11,690'MD 11,002'TVD 1 10,992'TVD • • OF 7'4 , .1,101/ 414s>, THE STATE Alaska Oil and Gas OfA AcKA Conservation Commission • x= 333 West Seventh Avenue GOVERNOR BILL WALKERAnchorage, Alaska 99501-3572 Main: 907.279.1433 OF ;� p. ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Conrad Perry Drilling Manager MAR (;1`t', Cook Inlet Energy, LLC ►��i�`N" 601 W. 5th Ave., Ste. 310 Anchorage,AK 99501 Re: North Fork Field, Tyonek Gas Pool,NFU 14-25 Permit to Drill Number: 210-111 Sundry Number: 316-620 Dear Mr. Perry: 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, CV()( Cathy . Foerster Chair DATED this l btay of December,2016. RBDMS DEC 2 2 2016 1 • R- EcFsv D STATE OF ALASKA • 1 ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 1 5 2016 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon ❑ Plug Perforations / Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate LI Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑., Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other:Vel.String Pull&Set RBP❑I 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: A(4 Cook Inlet Energy LLC • Exploratory ❑ Development Q. 210-111 ` Q�s®/k..4. , 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service 601 W.5th Ave.Suite 310,Anchorage,Ak 99501 50-231-20035-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.720• North Fork Unit#14-25 Will planned perforations require a spacing exception? Yes ❑ No ❑I ✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 391211/2095 ' North Fork, Tyonek Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total,Depthh Vp(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,700' II U 1100ah 11,566' 10,177' 2500 psi n/a none Casing Length '�� Size MD TVD Burst Collapse Structural Conductor 178' 16" 178' 178' N/A N/A Surface 2,992' 10 3/4" 2,992' 2,786' 5210 2480 Intermediate 5,297' 8 5/8"/7 5/8" 5,297' 4,714' 5,714'6,890 2,520/4,790 Production 11,700' 5 1/2" 11,700' 10,311' 10,640 7,480 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8,536'to 9,552'(attached) $ 7,838'to 8,854'(attached) Coiled tubing VS 1.75" N/A 8520' Packers and SSSV Type: N/A Packers and SSSV MD(ft)and TVD(ft): N/A 12.Attachments: Proposal Summary U 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: ASAP Commencing Operations: 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. Contact Conrad Perry Email cperry@glacieroil.com Printed Name Title Conrad Perry Drilling Manager Signature �� Phone Date 907-727-7404 /2//5(///b COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: CI Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: k 3 U Cs t, j 6 (�.3 ;� /f /�A . Ji /tC 1. aic k.y�1.3 �(o t f t /J 1+�1 614_4_ rc r/ Post Initial Injection MIT Req'd? Yes ❑ No ❑ T IZ.(t(,1).ta Spacing Exception Required? Yes ❑ No V/ Subsequent Form Required: ' 0,--L(0 e RBDMS ��- DEC 2 20'J y/I I(�/,, APPROVED BY Approved by: J '�// " COMMISSIONER THE COMMISSION Date: /, ..../L.../ Submit Form and Form 10-403 evised 11/2015 0 RiOe Ai valid for 12 mont s from the dale of approval. Attachments in Duplicate • • GLACIER RECEIVED December 15th, 2016 DEC 15 2010 Ms. Cathy Foerster, Chair AOGC Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 RE: Sundry Application Cook Inlet Energy, LLC: North Fork Unit 14-25 API: 50-231-20035-00-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a sundry for North Fork Unit 14-25, PTD: 210-111 requesting to modify the approved program under Sundry#316-583. Based on the log analysis completed in 2 neighboring wells,the perforation intervals were re-evaluated. CIE is requesting to perforate 2 additional zones and set a retrieva ug to isolate the lower zones with the option to use nitrogen to lower the fluid level in the well below the planned RBP set depth. If you have any questions, please contact me at(907) 727-7404. Sincerely, #1111° Conrad Perr Sr.Vice President/Drilling Manager Cook Inlet Energy, LLC (a Glacier Oil&Gas owned company) 601 W 5th Ave,Suite 310 Anchorage,AK 99501 1 • • GLACIER WELL NAME-North Fork Unit 14-25 Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is producing. Current Perforations MD TVD 8536'- 8548' 7838'- 7851' 8620'- 8640' 7923'- 7943' 8760'- 8776' 8063'- 8079' 9536'- 9552' 8838'- 8854' 11249' - 11264' 10551' - 10566' 11284' - 11294' 10586' - 10596' Scope of Work: • Completed: Attempt to set mechanical barrier in CT VS - unsuccessful o Extended flow check will be performed. o If flow is detected, blind shear rams will be utilized. • Kill Well • Rig up Coil. Test Coil BOPE to 3,000 psi. • Pull Coiled tubing velocity string. • Remove VS hanger, NU tree. • Rig up Eline. Test Lubricator to 3,000 psi. • Cancelled: Run TDT log across specified interval. • Cancelled: Evaluate log. • Rig up N2 and pump specified volume. • Set Retrievable Bridge Plug at 6500' MD. • Perforate selected intervals. • Rig down Eline. General Well Information: Reservoir Pressure /TVD: 3,439 psi @ 8640' MD / 7943' TVD MASP: 2,645 psi Wellhead Type/Pressure Rating: 13-5/8" 5K Wellhead BOP Configuration: Blinds in lower, coil rams in upper Well Type: Gas Well Estimated Start Date: ASAP 2 • < 0 • GLACIER Drilling Manager: Sr. Drilling Engineer: Production Manager: Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907)433-9738 (907)433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com Program Phase 1 1. Completed: Attempt to set mechanical barrier in CT VS - Unsuccessful 2. Shut in well. 3. Kill Well. 4. Rig up Coil BOPE on top of 3-1/8" 5M flange 5. Test Coil tubing BOPE to 3000 psi. 6. Recover 1-3/4" coil velocity string. a. Extended flow ch-e k will be performed. b. If flow is detected, blind shear rams will be used. 7. RD coiled tubing unit. Phase 2 1. Close upper and lower master. 2. Remove Coiled tubing velocity string hanger and valves above (3 1/8" actuator, tee, swab, and wing valves). 3. RU Lubricator. 4. Open upper and lower master valves. 5. Set 2-way check. 6. Close Lower Master. 7. RD Lubricator. 8. Remove upper master and install 5-1/8" actuator,tee, swab valve, and wing valves. 9. Test seals. 10. RU Lubricator. 11. Pull 2-way check. 12. RD Lubricator. Phase 3 f 1. Cancelled: RU and test Eline Lubricator to 3,000 psi. 2. Cancelled: RIH with TDT tool to 9,700' MD and log to 5,200' MD. 3. Cancelled: Rig down lubricator and Eline. 3 * < e • GLACIER 6. Rig up to pump N2. 7. Pump specified volume of N2 to push fluid level to 6600' MD. 8. MU 5 i" retrievable bridge plug. 9. RIH with RBP and set at 6500' MD. 10. Perforate the following intervals with 2-7/8" 6 spf, 60* phase. a. Ensure shut-in wellhead pressure is minimum of 3000 psi. b. Report fluid level tag if indicated. c. Observe and report pressure increase, if any, after each interval is perforated. d. Consult with Production if pressure increase is seen to determine whether to suspend perforations and take well to production. Proposed Perforations to Add: Top, MD Bottom, MD Top, TVD Bottom,TVD New 6020' 6040' 5358' 5376' Top adjusted 6420' 6440' 5733' 5752' New 6448' 6465' 5759' 5776' Cancelled 6795' 6810' 6099' 6114' 11. Rig down lubricator and Eline. 12.Turn well over to production. Phase 4 If well has difficulty producing: 1. Rig up Slickline. 2. RIH and swab well. 3. Rig down Slickline. 4. Turn well over to production. Phase 5 If swabbing does not bring well online: 1. Rig up Coil BOPE on top of 5-1/8" 5M flange. 2. RU coiled tubing unit and flow back iron and N2. 3. Test Coil tubing BOPE to 3000 psi. 4. RIH in stages lifting well clean of water to diffuser tank. a. Repeat as needed to TD. 5. RD Coil. 6. Turn well over to production. 4 • • Version: Current Permit#: 210 111 Apri1/7/2015 Velocity Install API#: 231-20035-00-00 NFU #14-255 prop.Des:ADL-391211/2095 KB elevation: 679' (21'AGL) i ' FSL, ' FEL Latitude: 59*47'46.xxxx"N S26 T4S R14W S.M. Longitude: 151*37'45.xxxx"W Spud: Cook Inlet Energy TD: Rig Released: .�' Structural Pine-Driven 1 1 I. L l 16" X-56 84 ppf F 1Top Bottom MD Surf 153' ITVD Surf 153' Chemical Injection Nipple set @ Surface Casino 355'MD. Drift-4.767"ID P110 10-3/4" L-80 45.5ppf 6.812"OD Top Bottom MD 0' 2,992' TVD 0' 2,786' • IR 1St aa., Intermediate Casing-tapered string 8 5/8" L-80 26 ppf Hydril t Top Bottom MD 0' 2,412' • TVD 0' 2,312' Yr I k'* L I. 7 5/8" 29.7# L-80 BTC-M ,�,,. MD 2412' 5,297' . , TVD 2312' 4,714' V. ' S 1 3/4"Coil Velocity String rt,. ID 1.482" Production Casing t 5 1/2" P-110 17 ppf Hydril 513 'e,. ID 4.892" Top Bottom ''�• MD 0' 11,690' TVD 0' 10,992' Ssy, �f' 'er ,' End of tubing 8520'MD Perforation Intervals: 7822'TVD MD TVD riial8,536'-8,548' 7838'-7851' (Stinger OD 1.38"ID.87" 8,620'-8,640' 7923'-7943' 8,760'-8,776' 8063'-8079 9,536'-9,552' 8838'-8854' 5 1/2"x 4"ID Casing Patch From 8757'to 8778' TOP of EZSV© 11235'MD Added Perforation Intervals Ems— MD TVD , , _. 11,249'-11,264' 10,551'-10,566' 11,284'-11,294' 10,586'-10,596' uw eiIIINE A 1,. 112 E@112 11,700'MD 11,690'MD 11,002'TVD 10,992'TVD III 0 Version: Proposed Permit#: 210 111 - 12/14/2016 Wellbore Schematic API #: 231-20035-00-00 Prop. Des: ADL-391211/2095 NFU #14-25 KB elevation: 679' (21'AGL) ' FSL, ' FEL Latitude: 59*47'46.xxxx"N S26 T4S R14W S.M. Longitude: 151*37'45.xxxx"W Spud: _ Cook Inlet Energy_ Rig Released: V S Structural Pipe-Driven . 0 . L _ 16" X-56 84 ppf Top Bottom MD Surf153' TVD Surf 153' Chemical Injection Nipple set Surface Casing @ 355' MD. Drift-4.767" ID 10-3/4" L-80 45.5ppf Top Bottom MD 0' 2,992' TVD 0' 2,786' l'4\11k.L1 �� Intermediate Casing-tapered string 8 5/8" L-80 26 ppf Hydril Top Bottom • MD 0' 2,412' TVD 0' 2,312' 7 5/8" 29.7# L-80 BTC-M MD 2412' 5,297' TVD 2312' 4,714' •I- : Production Casing 5 1/2" P-110 17 ppf Hydril 513 -. ost..,' �� ID 4.892" Top Bottom N MD 0' 11,690' TVD 0' 10,992' }— rroposea ren intervals: 'T MD TVD Set RBP @ 6500'MD 6020'-6040' 5358'-5376' f 6420'-6440' 5733'-5752' _ _ 6448'-6465' 5759'-5776' — — Perforation Intervals: = MD TVD = 8,536'-8,548' 7838'-7851' ' 8,620'-8,640' 7923'-7943' W5 1/2"x 4" ID Casing Patch=_- 8,760' 8,776' 8063'-8079 9,536'-9,552' 8838'-8854' From 8757'to 8778' = TOP of EZSV @ 11235' MD Perforation Intervals ^' ----------- MD TVD — < 11,249'-11,264' 10,551'-10,566' 11,284'-11,294' 10,586'-10,596' t"_ TD PBTD 11,700'MD 11,690'MD 11,002'TVD 10,992'TVD V Or Tit . we\�� yy.:• THE STATE Alaska Oil and Gas ti�, , � ofALASKA T e cKA Conservation Commission SfE= 333 West Seventh Avenue ' `- '. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 n ' Main: 907.279.1433 OF ALAS Y' Fax: 907.276.7542 www.aogcc.alaska.gov Conrad Perry Drilling Manager SCANNED ilAAH �, Cook Inlet Energy, LLC 601 W. 5th Ave., Suite 310 Anchorage, AK 99501 Re: North Fork Field, Tyonek Gas Pool,NFU 14-25 Permit to Drill Number: 210-111 Sundry Number: 316-583 Dear Mr. Perry: 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, Daniel T. Seamount, Jr. Commissioner DATED this 1 day of November, 2016. RBDMS 0- NOV 2 8 2016 SSTATE OF ALASKA • RECEIVED MQV ZO�� ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: _Velocity String Pull_Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: LT Cook Inlet Energy LLC Exploratory ❑ Development ❑✓ 210-111 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 601 W.5th Ave.Suite 310,Anchorage,Ak 99501 50-231-20035-00-00 7.If perforating: /7. 7 7 8.Well Name and Number: What Regulation or Conservation Ordergoverns well spacing in thispool? L% 9 p 9 20 AA 55 f«-i✓4, North Fork Unit#14-25 Will planned perforations require a spacing exception? Yes ❑ No ❑., 9.Property Designation(Lease Number): 10.Field/Pool(s): � m✓c.z-,4.. ADL 391211/2095 ' North Fork, ned Gas ,� >/(,'-11' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,700' 10,311' 11,566' 10,177' 2500 psi n/a none Casing Length Size MD TVD Burst Collapse Structural Conductor 178' 16" 178' 178' N/A N/A Surface 2,992' 10 3/4" 2,992' 2,786' 5210 2480 Intermediate 5,297' 8 5/8"/7 5/8" 5,297' 4,714' 5,714'6,890 2,520/4,790 Production 11,700' 51/2" 11,700' 10,311' 10,640 7,480 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8,536'to 9,552'(attached) 7,838'to 8,854'(attached) N/A N/A N/A Packers and SSSV Type: N/A Packers and SSSV MD(ft)and TVD(ft): N/A 12.Attachments: Proposal Summary kJ Wellbore schematic U 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: ASAP Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 2 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. Contact Conrad Perry Email cperry@glacieroil.com Printed Name Title Conrad Perry Drilling Manager \\ I t0 I'tv Q i Signature Phone Date 907-727-7404 COMMISSION USE ONLY Conditions of approval: N. ify Corn ion so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Er Mechanical Integrity Test ❑ Location Clearance ❑ Other: I--360o ,gins . Lege "7:--,_. .I- Cc. IT4 ) �4r� ei2 ,,,,_.2.4_1 4 zc) ,,¢,4 z5, z3.Sed)65J(A) �o ? 1 t�9P1 �c Post Initial Injection MITI q'd? Yes ❑ No ❑ (t'ii A.. Spacing Exception Required? Yes ❑ No Subsequent Form Required: / O 4/0 Li RBDMS �. --1OV202016 APPROVED BY Approved by.,/ COMMISSIONER THE COMMISSION Date:L f//7 //p Submit Form and Form 10-403 Revised 11/2015n v lid for 12 months from the date of approval. Attachmentsin Duplicate C� T �iti�f ,7 7.4 /e 41/�� . ,:; ,4 RECEIVED NOV102016 GLACIER AOGCC November 7th, 2016 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 RE: Sundry Application Cook Inlet Energy, LLC: North Fork Unit 14-25 API: 50-231-20035-00-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a sundry for North Fork Unit 14-25, PTD: 210-111 requesting to pull the current velocity sting and add perforations to the well. If swabbing . does not lift the well, coiled tubing and nitrogen may be utilized. AOGCC Regulation 20 AAC 25.235 Gas Disposition CIE is requesting permission to flare or vent in the unlikely event the well is difficult to bring online and has to be taken to atmospheric pressure to clean up. If well cleanup is normal, it will be flowed immediately into the North Fork production facility. CIE requests permission toper flare gas from the North Fork Unit 14-25 coiled tubing lifting operation for a period -041,1, of 3 total days according to 20 AAC 25.235 d (6). Maximum anticipated daily flaring is expected to be 0.5 MMSCF/D with a total expected not to exceed 1.0 MMSCF over the entire period. ,: If you have any questions, please contact me at (907) 727-7404. Sincerely, Conrad Perry Sr.Vice Preside t/ Drilling Manager Cook Inlet Energy, LLC (a Glacier Oil &Gas owned company) 601 W 5th Ave, Suite 310 Anchorage,AK 99501 1 . • • GLACIER WELL NAME—North Fork Unit 14-25 Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is producing. Current Perforations MD TVD 8536' - 8548' 7838' - 7851' 8620' - 8640' 7923' - 7943' 8760' - 8776' 8063' - 8079' 9536' - 9552' 8838' - 8854' 11249' - 11264' 10551' - 10566' 11284' - 11294' 10586' - 10596' Scope of Work: • Rig up Coil. Test Coil BOPE to 3,000 psi. •3 • • Pull Coiled tubing velocity string. Ai Va. S�r` • Remove VS hanger, NU tree. • Rig up Eline. Test Lubricator to 3,000 psi. • Run TDT log across specified interval. • Evaluate log. • Perforate selected intervals. • Rig down Eline. General Well Information: Reservoir Pressure /TVD: 3,493 psi @ 12,475' MD / 9,438' TVD MASP: 2,500 psi Wellhead Type/Pressure Rating: 13-5/8" 5K Wellhead BOP Configuration: Blinds in lower, coil rams in upper Well Type: Gas Well Estimated Start Date: ASAP 2 • • • GLACIER Drilling Manager: Sr. Drilling Engineer: Production Manager: Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-9738 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com Program Phase 1 -A-v) 1. Shut in well. `r ei„G /Vtcit LA."- 2. Rig up Coil BOPE on top of 3-1/8" 5M flange �j e ` JA 3. RU coiled tubing unit and flow back iron. f k V 4. Test Coil tubing BOPE to 3000 psi. 1)) ij? i 5. Kill Well with 8.4 ppg produced water. 51-r0 6. Recover 1-3/4" coil velocity string. 7. RD coiled tubing unit. Phase 2 -71--- //-/7-(4. 1. Close upper and lower master. 2. Remove Coiled tubing velocity string hanger. . Set 2-way checle) firit,t, 4. Remove upper master and install 5-1/8" actuator,tee,swab valve, and wing valves. 5. Test seals. / if T. L,L11 j h 2 vG p s_ 6. Pull 2-way check(? Phase 3 ``� 1. RU and test Eline Lubricator to 3,000 psi. 2. RIH with TDT tool to 9,700' MD and log to 5,200' MD. 3. Rig down lubricator and Eline. -I 4. Evaluate log. . 5. Rig up and test Eline lubricator to 3,000 psi. '.,„" 6. Perforate the following intervals with 2-7/8" 6 spf, 60* phase. C1 a. Report fluid level tag. b. Observe and report pressure increase, if any, after each interval is perforated. c. Consult with Production if pressure increase is seen to determine whether to suspend perforations and take well to production. 3 • • GLACIER Proposed Perforations to Add: Top, MD Bottom, MD Top,TVD Bottom,TVD 6420' 6440' 5733' 5752' 6795' 6810' 6099' 6114' 7. Rig down lubricator and Eline. 8. Turn well over to production. Phase 4 If well has difficulty producing: 1. Rig up Slickline. qt,, 2. RIH and swab well. 3. Rig down Slickline. 4. Turn well over to production. Phase 5 If swabbing does not bring well online: 1. Rig up Coil BOPE on top of 5-1/8" 5M flange. < 2. RU coiled tubing unit and flow back iron and N2. 3. Test Coil tubing BOPE to 3000 psi. 4. RIH in stages lifting well clean of water to diffuser tank. a. Repeat as needed to TD. 5. RD Coil. 6. Turn well over to production. 4 I • Version: Current Permit#: 210 111 Apri1/7/2015 Wellbore Schematic API#: 231-20035-00-00 Prop. Des:ADL-391211/2095 NFU #14-25 KB elevation: 679' (21'AGL) ' FSL, ' FEL Latitude: 59*47'46.xxxx"N S26 T4S R14W S.M. Longitude: 151*37'45.xxxx"W Spud: Cook Inlet Ener TD: Energy Released: �" Structural Pipe-Driven 16" X-56 84 ppf IL y , Jt To Bottom • MD Surf 153' ITVD Surf 153' Chemical Injection Nipple set Surface Casing @ 355' MD. Drift-4.767"ID 10-3/4" L-so 45.5ppf Top Bottom P110 6.812"OD MD o' 2,992' TVD 0' 2,786' ' 11 ..,, :14‘,1., 4* �x Intermediate Casing-tapered string 8 5/8" L-80 26 ppf Hydril Top Bottom MD 0' 2,412' TVD 0' 2,312' 7 5/8" 29.7# L-80 BTC-M MD 2412' 5,297' TVD 2312' 4,714' 1 3/4"Coil Velocity String ID 1.482" Production Casing 5 112" P-110 17 ppf Hydril 513 ID 4.892" Top Bottom MD 0' 11,690' TVD 0' 10,992' End of tubing 8520' MD Perforation Intervals: 7822'TVD MD TVD — -c4-77.-- 8,536'-8,548' 7838'-7851' (Stinger OD 1.38"ID .87" 8,620'-8,640' 7923'-7943' _ _ 8,760'-8,776' 8063'-8079 9,536'-9,552' 8838'-8854' 5 1/2"x 4" ID Casing Patch From 8757'to 8778' = = TOP of EZSV @ 11235' MD Added Perforation Intervals MD TVD ti 11,249'-11,264' 10,551'-10,566' . .... < 11,284'-11,294' 10,586'-10,596' ;4, TD PBTD 11,700'MD 11,690'MD 11,002'TVD 10,992'TVD _ 0 Version: Proposed Permit#: 210 111 11/7/2016 Wellbore Schematic API #: 231-20035-00-00 Prop. Des: ADL-391211/2095 NFU #14-25 KB elevation: 679' (21'AGL) ' FSL, ' FEL Latitude: 59*47'46.xxxx"N S26 T4S R14W S.M. Longitude: 151*37'45.xxxx"W Spud: Cook Inlet Ener - TD: — Energy Released: Structural Pipe-Driven "' ri i-�— 16" X-56 84 ppf r Top Bottom I MD Surf 153' TVD Surf 153' Chemical Injection Nipple set Surface Casing @ 355'MD. Drift-4.767"ID 10-314" L-80 45.5ppf Top Bottom P110 6.812"OD MD 0' 2,992' TVD 0' 2,786' N. ®® Intermediate Casing-tapered string 8 5/8" L-80 26 ppf Hydril Top Bottom MD 0' 2,412' ' TVD 0' 2,312' 7 5/8" 29.7# L-80 BTC-M MD 2412' 5,297' TVD 2312' 4,714' Production Casing 5 1/2" P-110 17 ppf Hydril 513 ID 4.892" Top Bottom _/ — MD 0' 11,690' TVD 0' 10,992' = Proposed Perf Inters-.. MD TVD 6420'-6440' 5733'-5752' — 6795'-6810' 6099'-6114' _ Perforation Intervals: ._. MD TVD — — 8,536'-8,548' 7838'-7851' 8,620'-8,640' 7923'-7943' 5 1/2"x 4" ID Casing Patch 8.760' 8,776' 8063'-8079 From 8757'to 8778' TOP of EZSV @ 11235' MD Perforation Intervals MD TVD 11,249'-11,264' 10,551'-10,566' • 11,284'-11,294' 10,586'-10,596' TD PBTD 11,700'MD 11,690'MD 11,002'ND 10,992'TVD ! • Cook Inlet Energy, L.L.C. +` j GE Oil&Gas NFU 14-25 As Built (07-22-14) 4 p 3-1/8"5M ercZ' I- 3-1/8"5M • •••• 3-1/8"51\ +� •� • silo** \ i j, 0 2-1/16"5M t4a,vi/C 3-1/8"5M 5-1/8"5M t /1 ' ',111111k . 5-1/8 5,000 5-1/8 10.000 (063 5-1/8 10,000 _ r6/ 13.5/8 5M c z . 135,8"51,1 .� I W. in 10- 00 CSG 6-sor OD CSG 5-1:2'OD 1bG • • 14e Cook Inlet Energy, L.L.C. GE Oil&Gas NFU 14-25 Proposed 11/02/16 T 5-1/8"5M ( 4 MINION 3-1/8"5M I AL 14/11 IA' I 5-1/8"5M Actuated Gate Valve I(• • lt••?,11 1/13 5.000 5-1A3 1OUW • Ait/t..5-Tra— "tt 5-1.0.3 "0,000 1111 ril -EA`o 5P+4 1111 '171/Fi 7•-74' 17) '11LI mr onci5o • • • Schlumberger Coiled Tubing Services Client: Glacier November November 7th, 2016 Drawn: Chad Barrett Pressure Category 1 BOP Configuration Revision: 0 (0-3,500 psi) Well Category: CAT I • .N\ Coiled Tubing HR580 Injector Head&Gooseneck ' Weight=12,850 lbs I l-u 1141 cP 4-1/16"10K Conventional Stripper �rI•�I -41 5K C062 Lubricator KillE WH PSI 2"1502 x 2-1/16 10K ^ Flanged Valve 4 5K C062 x 4-1/16"10K Flange (Manual) 2-1/16 10K x 2-1/16I1Cntl . ■; III• 10K Ranged Valve Ott'-' 0.�■ ■�. (Manual) '14 h•ar R.m e'_CO 4-1/16"10K Quad BOP 1 ■ y i R.m 1. :01 I 'peR.m".Ii11 '- -. 4-1/16"10K Flow Cross �--� Manual 2x2 Valve 1:2"1502 x 2-1/16"10K Range Manual 2x2 Valve 2:2-1/16"10K x 2-1/16"10K Range �1[O]1!1�®11!.!I�O�I!1[O�I! Manual 2x2 Valve 3:2-1/16"10K x2-1/16"10K Range Manual 2x2 Valve 4:2"1502 x 2-1/16"10K Range II I {j I I 40 4-1/16"10K x 3-1/8"5K Adapter Flange c o 101 1(41 )I IJ I= 4 Wellhead:3-1/8"5K t�l • • Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Thursday, November 17,2016 8:51 AM To: Amanda Dial Cc: Stephen Ratcliff;Conrad Perry Subject: RE: NFU 14-25 velocity string pull ..venting gas Amanda, In phase one my point is that the connection above the CT BOPE will be broken(pick up the lubricator.. not break BOP stack). I did not state that very well in my previous email. I believe Schlumberger then has to cut coil and weld new connector to strip through the injector head. All this time the Coil tubing is open to the reservoir thru the ID of the Coil while they are reconnecting the two ends. Make sure a mechanical barrier is set in the CT ID before breaking the lubricator off. KWF only not sufficient. The barrier does not have to be set in the XN profile of the CT..can be any kind of retrievable/permanent plug. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.aov). From:Amanda Dial [mailto:adial@glacieroil.com] Sent:Wednesday, November 16,2016 4:44 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Stephen Ratcliff<sratcliff@glacieroil.com>;Conrad Perry<cperry@glacieroil.com> Subject: RE: NFU 14-25 velocity string pull ..venting gas Guy, Conrad requested that I follow up with you on your questions below. In Phase 1:Schlumberger has confirmed the 3%"VS hanger can be stripped through the 4 1/16"Coil BOP stack without breaking the stack. However, prior to pulling the Velocity string,we will make our best effort to set a plug in the XN profile to provide the mechanical barrier. In the event that access to the IA of the velocity string is not gained,an extended flow check to ensure the well is dead will be performed once the CT latches into the VS and the hangar assembly is pulled the measured amount to ensure the hanger assembly is fully above the pipe and slip rams.The pipe and slip rams will then be manually locked closed around the VS.Once no flow is confirmed,only then will the VS be spooled. In Phase 2:The TWC in step 3 for the lower master cannot pass through the 3-1/8"tree ID restrictions.The intention is to remove the VS hanger and change the existing 5-1/8" manual valve for the 5-1/8"actuator and swap the 3-1/8"tee • and swab,etc,for the 5-1/8"sizes so the ID of the wellbore,5-1/2" monobore,is fully accessible rather than be restricted at the tree. Please let us know if you have additional questions. Thank you, Amanda Dial Office:(907)433-3818 Cell:(907)382-0124 From:Conrad Perry Sent:Tuesday, November 15, 2016 4:14 PM To:Amanda Dial<adial@glacieroil.com>;Stephen Ratcliff<sratcliff@gIacieroil.com> Subject: Fwd: NFU 14-25 velocity string pull ..venting gas conrad Begin forwarded message: From:"Schwartz,Guy L(DOA)"<guy.schwartz@alaska.gov> Date: November 15,2016 at 2:23:13 PM AKST To:"Conrad Perry(cperry@glacieroil.com)"<cperry@glacieroil.com> Cc:"Davies,Stephen F(DOA)"<steve.davies@alaska.gov> Subject:NFU 14-25 velocity string pull ..venting gas Conrad, In Phase 1 reviewing the sundry I did not see where you were installing a mechanical barrier in the 1 %" velocity string before pulling it. Loading well with KWF is not enough... BOP stack has to be split in order to start the Velocity string on a reel. Can you give me more details on this operation? In Phase 2 you are pulling the VS hanger. The current upper 5 1/8" 5000 psi MV appears to be going away. TWC can also be set as you detail as backup but the order appears to be wrong in your steps (Step 3 first..Set TWC first then close MV's). . You can close lower master and test the flange breaks and production tree internally by testing against it(positive pressure test to 2500 psi min) Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793- 1226) or(Guv.schwartz@alaska.gov). 2 • • _ Cook Inlet Energy September 17, 2015 SCANNED AUG 1 0 2016 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Report of Sundry Cook Inlet Energy, LLC: North Fork Unit# 14-25 Permit to drill NO: 210-111 API No: 50-231-20035-00-00 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits requested follow up information in regards to Sundry Completion for installing a 1 3/" velocity string in North Fork Unit # 14-25 well located on CIE lease#391211/2095. Attached are the requested daily reports as well as the original submitted 10-404. If you have any questions, please contact me at (907) 727-7404. Sincere �k ) Lt Conrad P rry /Zip,* Drilling Manager Cook Inlet Energy / r + 601 W.5'"Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax IPOOK INLET ENERGY, LLC • _Cook Inlet Energy DAILY DRILLING/WORKOVER REPORT 6/26/14 _EASE AND WELL NC) AFF NO r-5 Yti C, :ROGREss North Fork Unit 14-25 25 Present Operation FORMATION TOTAL PROJE;TE.:.LF Prep Pollard E-Line to RIH wr 4 70"Wire Brush Tool to clear any debris before RIH w'EZSV/Guns :AST CASING AND SHOE TEST LINERS-Of)TOP AND SHOE DEPTHS REPAIR(CANTIME r.month CONTRACTOR A': RiC NC BRIEF DESCRIPTION OF PRESENT OPERATIONS MIDNIGHT to 0300 hrs' 0000-0500 hrs. NOZZLES.TIA DEPTH FEET HOURS FT^+R w„AI RP.,' DULL CONDITION FS MUD PROPERTIES,MATERIALS ADDEO AND COSTS SAMPL MUD FUSEL Py YE t,i 5 PH IL' ..Ali( 16 1 Mal CHLORIDES El Mt 1 MUD COSTS TIME WT 515 SAND SOLIDS PPM DAILY TOTAL DIRECTIONAL SURVEYS MEASURED DRIFT OPEC COORDINATES DE '.. vt 'NI r- D E C "vRD.NATC1 - • ANGIE 110N ln_ SEiI EEIr',T A�G_E 1l�N 6.00 Safety Meeting RU Pollard E line )NO CHANGE(SEE PRIOR OPT. 12.03 Make repairs to E line unit.Unspool backlashed line from drum Cut&remove sections of line X NEW BHA 12:00 13.00 P/U 466'Gauge Cutler Assy Pressure test Lubricator V 3500 psi 13:00 16.30 RIH WE 4 66"Gauge Cutter,had to work thru 2 tight spots al 460&750'(wlm)work thru both spots 4 M 5 times before Continue RILE V 11420 TOOL OESCRIP 00 LENGTH 16 30 17.00 P051 encountered tight spots again at 700'and 450 work thio was.little easier on both spots 17.00 17 30 CIO Gauge Cutters E 4 WI/4 74"RIH V 1000',did not have to stop at tight spots,little bobble going thru but had Improved.POH 17 30 Confered wE CIE Management,decided to RIH with 4 70"Wire Brush Tool to clear debns before RIH w/EZSV 8 Perf Guns Pollard Supervisor Steve Barrow says it would take 2 hours min to make Brush to spec plus 1 1/2 hour travel time Descion to Secure Well for the Evening and 19.30 bnng Brush tool and weight bar to location at 0600 hrs Friday Sent Pollard Crews and Cruz Crane Operator to Anchor River Inn Well Secured for the Evening CIE Test Equipment arrived on location Move Empty 4 W bb'R 4 R defuser tank out of berm,waiting on XRS liner to arrive Removed fluid KCL fluid from Rain for Rent lank while making wire Ene repairs Note Smallest I D.m Produebon Tree a -„• Back Pressure valve h of l,-Mester Valves and Swab valve I D's=5 0525"6 5 125' 'mention Mend',- Air Liquide Transport on location contains 84,000 SCF of N2 Safety Observation:Heid meeting with crew concerning proper Order of well head valve operat,cn and assigned responsibinlies I I I I I I I �a foe.RC.J Prev'v,ir OO 06,Tore- I I Uses SIArn F,v- 1 DAILY COST I I f CUM TOTAL COST DAYS SINCE LAST LTA: `Personal: Crews Camp Total ILAS1 5PI,L cosi comments: 10 Mike Murray.Don Jones • COOK INLET ENERGY, LLC • Cook Inlet Energy DAILY DRILLING/WORKOVER REPORT .._ __.. GATE 6/27/14 i EASE AND VJELI NO 4FE NO OA+E V:. TVD PROGRESS North Fork Unit 14-25 26 Present Operation _ FORMATIOr. TOTAL PROJECTED DEPTH Pollard will RID in a .Vetco Gray will be on locator)to CO Wellhead&add C T.Hanger Head LA5T CASING AND SHOE TEST _INERS'OD TOP AND SHOE DEPTHS REPAIR DOWNTIME H month CONTRACTOR AND RIG NO BRIEF DESCRIPTION OF PRESENT OPERATIONS MIDNIGHT to 0300 hrs. 0000-0500 hrs Be SIZE I1:L N0221 ES e,TEA DEPTH FEET HOURS VTMR WOE RIM PS. MUD PROPERTIES,MATERIALS ADDED AND COSTS SAMPL MUD FUNS PV sE , CH EC CAO A. N M'+' CHLORIDES Pi M. ,.a' 5010 COSTS TIME WI VS CCI:13 32nas SAND SOL Os PPM DAILY TOTAL DIRECTIONAL SURVEYS MEASURED DRIFT DIREC (SOSO,.Ns-L'. CEPS- V MEASURED E.PE, 4.;10�. ANGLE TION vile SECT DEPTH 6 00 9 00 Safety Meeting RU Pollard E line R/U and test Lubncator to 3500 psi []NO CHANGE(SEE PRIOR RPn 9.00 11 00 RIM w.14.70"Wire Brush Tool Assy.Observed slight bobbles thru tight spots at 450'and 750'.continue RIM V 11420',POH,slight bobbles agar^ X NEW BHA 11 00 UD Wire Brush Assy MIU Halliburton 45'3 318"Pert Gun Assy. 6CP phase at 6 spf,on Halliburton EZSV 5 1/2"Squeeze Packer and 14.00 with Balser 20 setting tool and top I bottom 2-6 min delay and 1 lime delay bong head=18 nuns delay with Pollard ELme CCL&CR Tools TOOL DESCRIP 00 LENGTH 14 00 Stab on Lubricator,open well to 800 psi.no leaks RIH at 55 fpm until thru Tight Spots at 460'&750',(Note DA not see Indication of tlghf spots) RIH observed Fluid Level=2530'.RIH at 150 fpm 0 11315'(CCL Depth(and begin coorelation of Pert Depth using OR&CCL,sent correlation log to CIE Geologist Greg Kirkland to confer Top&Bottom Shot Depth's Once on depth found that EZSV packer element would be set In 5 112'Casing connection Greg allowed for us to pull up hole 1 5'above planned Top&Bottom Shot. Run down and log up Into position and pulled logger on Baker 020 setting tool and set 5 112"EZSV Packer and 3 318"Guns(WLM).Top of EZSV Pkr at 11235 02', Top Shol at 11248 5'Bottom Shot of top zone at 11263 5',20'Spacer,Top Shot of neat zone down at 11283 5',Bottom Shot of Pent zone down 17.00 at 11293.5'.bottom o1 Ported Sub,(bottom of Assy)at 11298 42' Note Good indication that Setting tool released from EZSV i Pert Assy 17.00 19.00 POH w;Baker#20 setting loo:shut In well and Pop off Well.LID Baker#20 setting Tool Assy 19.00 20 00 PIU 5 112"Casing Patch Assy 4 5"body,4 70'at 1'on both ends(Elements),4 0"I D.II top of Element to bottom of Element=21 75' 20.00 21 00 RIH,tagging up on 5 112"Tubing Hanger several times,work thru&continue RIH U 8820' 21.00 Correlate&send log to&confer w'Greg Kirkland Greg allowed us to split the ditterenc of 5 75'tolal overlap=3'overlap above and 2 75 22.00 overlap below Pulled Trigger on 3 114"Multi Stage Setting Tool&set 5 1/2"Casing Patch Top of Patch at 8757',Bottom of Patch at 8778 75' 22.00 23:30 Pick up 10'.slowly go in no'.e old stack out weight to confirm top of Patch is set&on depth.(Good). POH with Setting Tool Assy 23.00 0 00 Rig aside and MIU N,ghl Cap and secure well for the Evening Fluid Level at 2530'before setting 5 1M"Casing Patch Note No 5 1l2"Casing Joint connection behind Casing Patch Began Filtering 317 bbls of KCL Fluid al Noon cal Rain 4 Rent 4 Pot Filtering Unit using 25 micron filters to start before going to 10 micron XR5 Liner V Polar Supply(Anchorage)arrived at 1630 hrs began selling and bennmg in 400 bbl R 4 R Deluser Tank Air Ligwde Transport on location contains 63.000 SCf of N2 Safety Observation. Secure the folding ladders before Climbing and secure the towith piece of rope on 1st assent I 1 I I I I NoS e.cna CD CDnr To'a' 1 Used SIA-d.Ly Fun. DAILY COST I f ( W CUM ToTA1.COST DAYS SINCE LAST LTA: Personal Crews Camp Total LAST SPILL Cost Comments. Don Jones QOOK INLET ENERGY, LLC • Cook Inlet Energy DAILY DRILLING/WORKOVER REPORT GATE 6/28/14 LEASE AND WELL NO AFE NC DAYS M;1 TAD PROGRESS North Fork Unit 14-25 27 Present Operation FORMATON TOTAL PROJECTED DEPTH Schlumberger Crew returning in the A.M.to continue RIU test BOPE.Continue R/U CIE Test Equip LAST CASING AND SHOE TEST LINERS-OD TOP ANO SHOE DEPTHS REPAIR DOWNTIME tr nnonrn CONTRACTOR AND RIG ND BRIEF DESCRIPTION OF PRESENT OPERATIONS MIDNIGHT to 0300 hrs. 0000-0500 hrs: AI SIZE TYPE NOZZLES or TEA DEPTH FEET HOURS Ft/HR WOE RPM DULLCONDITION Pi', Leer Sro Si,vr SPM PSI MUD PROPERTIES,MATERIALS ADDED AND COSTS SAMPL MUD RAI PG TP GELS PH FIST CAKE N. N, MAT CHLORIDES PF MF HTHP MUD COSTS TIME WI' MS CUM 32'W SAND SOLIDS PPM DAILY TOTAL DIRECTIONAL SURVEYS MEASURES, DRIFT DIPEC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V ANGLE TION VKA SECT DEPTH ANGLE TION VNA SPOT 6'.00 7:30 PJSM. Continue rigging down Pollard E-Line equipment,depart location at 1000 hrs I I NO CHANGE(SEE PRIOR RPD 7:30 Veico Gray(G.E.0,11 Gas)arrived on location PJSM,close in bottom 1 lop Master Valves and begin nippling down 5'5K Production Tree X NEW DHA 1200 above Top Master Valve,dnfled entire new section of tree with Coil Tubing Hanger with 0.D.•3 04" 12:00 Begin installing new adapter 1/5 1/8"5K 0 0 1/8"5K,Coil tubing Hanger Head with 2 1116"5K wing valve.3 1/8"Block,3 1/8"5K Swab valve TOOL DESCRIP. OD LENGTH 13:30 and 3 ll&5K Wing valves. Hammer up flanges,prep to lest Tree 13:30 14,00 Shell Test body o1 new Wellhead components against Master Valve f/250 psi V 5000 psi,hold 10 minutes(Good). Rep's departed 1430 hrs 14:00 16.00 Continue setting CIE Test Equipment in place and continue filtering KCL fluid with 10 micron filter Pods 1600 Schlumberger Crew arrived with Nitrogen pump trader and adapter flange from top of tree 3 118"5K Swab Valve. Began setting equipment in place,maintenance/service equipment and systems. Halliburton and Schlumberger Tool Techs working BHA issues in Nikiski. N2 Transport arrived a1 1800 hrs and transferred 3001 gallons a 279,312 SCF to N2 trailer we have had on location w/39,094 SCF left in tank SLB removed night cap flange and installed nser flange,COPE,stnng out and connect BOPE control hoses,layout I hammer up NO hard lines,wt Crane set N2 Pump Skid inside berm Route and hammer up kill line from under BOP stack to choke manifold. 20.30 Secure Well for the Evening. Schlumberger Coil Tubing Crew staying at Anchor River Inn Note Fluid Level at 2530'before setting 5 1/2"Casing Patch. Filtering 317 bbls of KCL Fluid w:Rain 4 Rent 4 Pot Fdlenng Unit using 10 micron fillers.Shut down for 6 hours,start back up 1800 hrs Air Liquide Transport on location contains 319,406 SCF of N2 after transfer Safely Observation: Discussed in PJSM with Vetco Gray dear hand signals to Cra1ne Operator,be aware of overhead loads while C/0 Tree RigrueRevd Previous 00 OOnr Total Vsed I Stand-8y Fun DAILY COST CUM TOTAL COST DAYS SINCE LAST LTA: rersonal: Crews Camp Total BLAST SPILL Cmc Cononentr 9 Don Jones • COOK INLET ENERGY, LLC • Cook Inlet Energy DAILY DRILLING 1 WORKOVER REPORT —tl DATE 6/29/14 I EASE AND WELL NO ASPIC' CAKE rsr NO PROGRESS North Fork Unit 14-25 28 D Present Operation roe KAn55 TOTAL PROJECTED DEPTH Continue Rigging up Test Equipment Waiting on C.T.BHA components.Slide Stick and Shan Sub LAST CA5155 AND SHOE TEST LINERS•OD TOP AND SHOE DEPTHS REPAIR DOWNTIME V NENh CONTRACTOR AND RIG NO BRIEF DESCRIPTION OF PRESENT OPERATIONS MIDNIGHT to 0300 hrs. 0000-0500 hrs. e! Sii) Y NOZZLES of TEA DEPTH FEET ATLAS FTMRW 8 RPM MUD PROPERTIES.MATERIALS ADDED AND COSTS SAMPL MUD FUNL PV •.. ..,, Fri FILL CAKE N A Ma,. CHLORIDES Er - Ni HTTP MOD COSTS TIME W; AID C5+30 32ntls SANS SO:US PPM DAST TOTAL • DIRECTIONAL SURVEYS MEASURED DRIFT DREG COORDINATES DEPTH V MEASURED SRI;' DIREC 195)155 OF no• ANGLE 11014 VKB SECT DEPTH ANTION 001' 6 DO 13.00 PJSM. Continue R/U OLE Coil Tubing equipment,M U Coil Connector.pull test 20K,Stab on the Well.Test HOPE f.'250 psi a 5000 psi (j NO CHANGE SEE PRIOR MEL. 13 00 Set Nitrogen Tank,run N2 lines V Tank to N2 Manhold and to C T reel MIS Torq Tongs for making up BHA when it amves,check torq X NEW 850 calibration. SLS Tool Tech on location to confirm 1 30'drift(represents Pollards Plug!Prong)thru coil connector and Spacing Pups,ed Plan is to have SLB and Halliburton Toot Techs get with Vetco Gray in the a.m.and do a physical dnf Moth Pollards 1.25"plug thru all TOOL DESCRIP. DD LENGTH upper Coil Tubing hang off components Pulled berm apart to remove SLB's Tracor from Berm and move trailers and N2 Trailer.place bade in Berm and rebuild berm back Complete a hard line i hard line component inventory to call into PTS and(oh Weatherford Monday Morning. Continue RTU CIE Test Equipment,fill Test Separtator line heater bath with Fresh Water plumb Gas to Separtator Fire Bon,called and located Test Choke Skid Total Flow Meter Battenes at Kustatan Inventory all orifice plates for 2'and 3"Gas Meter Runs Set Flare Scrubber&Flare 18 30 Confirmed well is Secured for the Evening Air Liquide Transport on location contains 318 406 SCF of N2 atter transfer Safety Observation: S:mops Discussed R/U SLB Coil Tubing Equipment while RIO Test Equipment&Production Operations Communicate iAK f I _I R tie R,d I Onhi To, I Used StanC.Oy Fuel DAILY COST CUM TOTAL cost DAYS SINCE LAST LTA Personal Crews Camp Total ._AST SPILL Cosi Comments- 1 0 ommem:-10 Don Jones •OOK INLET ENERGY, LLC • Cook Inlet Energy DAILY DRILLING/WORKOVER REPORT DATE /� LEASE.AND WELL NO 6/30/14 ATE N0 DAYS MD TVD PROGRESS North Fork Unit 14-25 Y9 o Present Operation FORMATION TOTAL PROJECTED DEPTH Confirming Cut measurement.Hot Tap and Cut Coil to install Vetco Gray Hanger Assy. AST CASING AND SHOE TEST INE:RS SD.'CO AND SHOE DEPTHS REPAIR DOWNTIME f,morn" COFIT P.ACTOR AND R',G NO BRIEF DESCRIPTION OF PRESENT OPERATIONS MIDNIGHT to 0300 hrs. 0000-0100 hrs. Continued Strapping I Gathering I building 1 314"Coil Tubing BHA. Held PJSM WI all personnel on location 0100-0130 hrs Slab on the well,fluid pack lubricator and circ system,pressure test lubricator to 4500 psi,open up Well,check pressures 0130-0430 hrs. RIH 8 Circ slowly keeping Coil full,Note: Did not see 5 112"Casing Patch at 8757' 04.30-0500 firs: Tag Top of EZSV Pkr at 11233'180 psi increased immediately to 730 psi,shut off pump 8 bleed off. (no weight change) Mark C_T,W/O pump set 2000 lbs down=750 lbs on btm 11234' mark C T Pres.Up to 240 psi,SID pump.,pres Stable,slowly pullout of Pkr,pres dropped off,mark pipe 11230',86 ppg on 1 3l4"x 5 172"annulus and 8 4+ppg on inside Coil,allow to"U"tube,stabilize or SIZE TYPE NOZZLES or TEA DEPTH FEET HOURS FIMR WOO RPM DULL CONDITION Poop Line,Sire Stroxe SPM PSI MUD PROPERTIES,MATERIALS ADDED AND COSTS SAMPL MUD FUN'L PV VP GELS PH Fitt CAKE R 5 Mei CHLORIDES Pr Mr HTHF MUOCOSTS TIME WT VS CUBO OCras SAND SOLIDS PPM DAlLT IOTA( DIRECTIONAL SURVEYS MEASURED DRIFT OMREC COORDINATES DEPTH V MEASURED DRIFT DIREC COORCNNATES DEPTH V ANGLE TION PRO SECT DEPTH ANGLE TION Vito SECT 1 380 -6:00 PJSM. Continue Rill Test Equipment w/PTS Well Testing Tech,route and hammer up flow back von f;Line Heater ))NO CHANGE(SEE PRIOR RPT( V Flow Back R 4 R Detuser Tank. Build and set 55 DP CIE Gray Tank next to Well House for Sbckfine Swabbing efforts Checking Line 1-hr X NEW eros 12.00 Auto Dump valves,light Line Heater Fire Box and begin heating water bath in Line Healer Install Total Flow Batteries and check 1"orifice calib 1200 Continue gathenng Parts,Matenals and equipment for Swabbing and Testing efforts.M/U 3 118'flange x 1502 off Wing valve,install hand TOOL DESCRIP. 00 LENGTH 1800 choke off wing.MIU hardline from choke to inlet of Line Heater 1600 Line up Filter pump on return pit in preparation for when we circulate the well we can filter the retums,MVV steps to properly enter I exit Coil Connector 2 875 0.56 21 45 Tank Berns and Line Heater. XO 2875 0.35 21.45 Received call horn Schlumberger Tool Tech that he was departing 080 shop in Nikiski with BHA in hand,Tech had Pollard's 1 25"Plug 2-Slick Sticks 2.25 9.66' 23.00 to drift all Machined BHA components before departing shop. Tool Tech and BHA arrived on location at 2300 hrs X N Nipple 2.20 0.97 2300 0.00 Added lubricator piece and began building 1 314"Coil Tubing BHA Spacer Sub 225 0.88 XO 2.75 0.50 Bow Sprang Sub 4687 1.85 XO 2.630 0.61 EZSV Pkr Stinger 1.380 1.31 Pollard Sliddine Supervisor received 1.35"Swab Cups and Mandrels at 1400 hrs Air Liquide Transport on location contains 318;106 SCF of N2 after transfer Safety Observation: Discussed nol using 4"x 4"wood pieces for steps in l out of berms.They tend to roll if not directly on center BHA Length 16.70 I I 1 1 1 1 I )tip fuel ircva Arewo;ls DO DOrr Total I Used Stand-By Fuel p .. .. ___ DAILY COST I --- __ - CUM TOTAL COST DAYS SINCE LAST LTA: (Personal: Crews Camp Total 'LAST SPILL cosi Comments. 15 Don Jones •COOK INLET ENERGY, LLC • Cook Inlet Energy DAILY DRILLING/WORKOVER REPORT ..-... _..... DATE 7/1/14 LEASE AND WELL NO WE NO DAYS MD TVE PROGRESS North Fork Unit 14-25 30 D Present Operation FORMATION ToTAI PROJECTED DEPTH Continue Swabbing with 1 35"Swab Cups in 1 3+4"Coil Tubing from 3400' LAST CASING AND SHOE TEST LINERS OD.TOP AND SHOE DEPTHS REPAIR DOWNTIME I1 rno, CONTRACTOR AND RIS NO BRIEF DESCRIPTION OF PRESENT OPERATIONS MIDNIGHT to 0300 hrs: 0000-0500 los Continue Swabbing with 1,35'Swab Cups inside 1 314"C 7 Down to 3400',recovered 10.3 bbls,taking 600 V 1200'bites wI Swab Cups fr 1300'and have been down U 5200'swab depths,observing fluid bypass as pulling out of hole and when cup get up into Prod Tree Bo SIZE TYPE NOZZLES o.Tra DEPTH FEE, HOURS FTMR WOB RPM DULL CONDITION Pump Lone)Sloe Stroke 5PM PSI. MUD PROPERTIES,MATERIALS ADDED AND COSTS SAMPL MUD FUN I. PV VP GELS PH GAT CAKE % % MET CHLORIDES PF MF HTHP MIXT COSTS TIME WI V5 GC/30 32r4s SAND SOLIDS, PPM DAILY TOTAL DIRECTIONAL SURVEYS MEASURED DRIFT MEC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V ANGLE TION VKB SECT DEPTH ANGLE T,55 VKB SECT 0.00 1:00 Continued Strapping 1 Calipering/building 1 3/4"Coil Tubing BHA. Held PJSM wt all personnel on location )I NO CHANGE(SEE PRiDR RPTI 1.00 1.30 Stab on the well,fluid pack lubricator and circ system,pressure test lubncator to 4500 psi,open up Well,check pressures X NEW SHA 1.30 4 30 RIH&Ciro slowly keeping Coil full,Note Did not see 5 112"Casing Patch at 8757' 4:30 Tag Top of EZSV Pkr at 11233'180 psi increased immediately to 730 psi,SO pump 8 bleed off. (no weight change). Mark C.T,WIG pump TOOL DESCRIP 00 LENGTH set 2000 lbs gown=750 lbs on bottom=11234'mark C.T.pres.Up to 240 psi,SID pump,pres Stable.slowly pullout of Pkr,pres dropped off 6.30 mark pipe 11230',8 6 ppg on 1 3/4"C T x 5 1/5"and 8.40 ppg on inside C.T.,allow to"U"tube and stabilize while calculating cat depth Coil Connector 2 875 0.56 6.30 Once well is balanced f stablized,Mark pipe al Stripper head and space out. Hot Tap C.L Cut Coil.install GS profile on the C.T and install XO 2.875 0 35 10.00 Vetco Gray Coil Hanger on Stub being held secured with BOP Pipe Rams Engage GS Tool into top of GS profile on Vetco Gray C.T.Hanger 2-Slick Sticks 2.25 9.66' 10.00 P/U and open BOPE's,RIH wf 12000 lbs down weight,engage Stinger into EZSV Pkr w/5000 lbs down on Pkr cal Hanger 8"above lockdown's X N Nipple 2 20 0.97 10 30 Continue slacko8 and line up C.T hanger profile WI Lockdown studs w/9000 lbs weight down on Pkr=3000 lbs weight down hole on Pkr lop. Spacer Sub 2.25 0.88 10 30 11 00 Lora down Hanger and test between C.T.hanger Seals to 5000 psi,(Good)lest XO 2 75 0.50 11:00 Atterfpt to release GS Tool from C T.hanger with 300 psi pressure against a 3/8"S S Hall inside GS Tool Would not release,made many Bow Spnng Sub 4 687 1.85 12:30 attempts.called 01.8 Support. Finally after applying 1830 psi GS released Successfully POH and inspected,no marks or anomalies XO 2 630 0.61 12,30 14.00 RID SLB Equipment,Set Injector head onto Stub,leave BOPE made up on Riser EZSV Pkr Slinger 1.380 1.31 14.00 17:00 Set PWS Boom Truth in place.FLU PWS Slickline to make Dummy Run w/1 25"Tool Assy to"XN"nipple,fight leaks on P T of 3500 psi 17.00 19.00 RI H w/Dummy Run 1.25"Gauge Ring Assy to 11178'=47'short of tagging"XN"nipple Wm. Temporanly Stuck,work free after 8 pulls,POH 1900 20 30 RIH w/1.00"LIB with 1 20"centralizer,Tagged"XN"nipple at 11231',POH without over pull from previous fight spot 2030 0:00 RIH WI 1 35"Swab Cups and monitor a record fluid recovered fluid at surfaced to 1300',recovered 2 bits fluid Lon Wl ISSCO sieved to calibrate Test Skid choke manifold 2"&3"Total Flow's/Daniel Senor meter 5"&1.0"Orifice Plates Air Liquide Transport on location contains 316,106 SCF of N2 after transfer Safety Observation:Good communications wI the crane operator&SIB o rator.All hands on location understand what the task at hand is BHA Length 16.70 I 1 1 1 I I 1 dig fuel Rcvd Previous 0000nr Total Used Stand-By Fuel DAILY COST 1ICUM TOTAL COST DAYS SINCE LAST LTA: 'Personal: Crews Camp Total LAST SPILL Cost Comments, 19 Don Jones 400K INLET ENERGY, LLC • Cook Inlet Energy DAILY DRILLING/WORKOVER REPORT DATE 7/2/14 SASS AND WELL NO Alf NO DAYS MD TVD PROGRESS North Fork Unit 14-25 31 0 Present Operation FORMATION TGTA.PROJECTED DEPTH Continue Swabbing Fluid w/1 35"Swab Cups fi fluid level of 2402' LAST CASING AND SHOE TES T LINERS-OD TOPANO SHOE DEPTHS REPAIR DOVtITIME r,mInR, CONTRACTOR ANDRIG NO BRIEF DESCRIPTION OF PRESENT OPERATIONS MIDNIGHT to 0300 hrs' 0000-0200 hrs. Swab from depths of 227.5 U 2295'have not recovered Fluid 0200-0500 hrs. Swab from deeper depths of 3565'V 4402'average 1200'1/2000 bits recovered 0.66 bbls Er SIZE TYPE NOZZLES or TEA DEPTH FEET HOURS FTAIR WOO RPM DULL CONDITION Pump Liner Sue Woke GPO PS MUD PROPERTIES,MATERIALS ADDED AND COSTS SAMPL MUD FUN'L PV rF GELS PH TILT CARE % % MET CHLORIDES PF MA HTHP MUD COSTS TIME WI MS CCM 32rine SAND SOLIDS PPM DAILY I TOTAL DIRECTIONAL SURVEYS MEASURED DRIFT DIREC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH w ANGLE TICS VHS SECT DEPTH ANGLE TION VAS SECT 0.00" Continue Swabbing with 1.35"Swab Cups inside 1 3/4"C.T.Down to 3400 recovered 10.3 bbls,taking 600'V 1200 bites w/Swab Cups 1i No CHANCE(SEE PRIOR RPTI ft 1300 and have been down V 5200'swab depths,observing fluid bypass as pulling out of hole and when cup get up into Prod.Tree,due to X NEW BHA ' inside Coil having a fibbed seam down length of Coil string it make n difficult to see actual Fluid Level.swap to 1.25"gauge nng penodically 730 to observe proper Fluid Level.Al 0730 hrs Fluid Level at 4860',Swap back to 1.34"Swab Cup Assy and continue bailing efforts TOOL DESCRIP OD LENGTH 730 10 30 Continue Swabbing with 1.35"Swab Cups Inside 1 3/4"C.T. Recovered 10.4 bbls.Fluid Level at 4870'. Not recovennq water effectively 1030 RID Pollard E-Line and Prep U Pump N2 down the C.T.to detonate the 3 3/8"Halliburton Perf Guns. 60°phase a 6 SPE hanging below Coll Connector 2 875 056 11:30 the Halliburton EZSV 5 112"Squeeze Packer Perforations f/11293.5'U 11283,5'and II 11263.5'V 11248.5' XO 2.875 0.35 11 30 12.00.Test the Vetco Gray C hanger WI the SLB GS Hydraulic setting 1 release Tool,worked with 1800 psi 2-Slick Sticks 2.25 9.66' 12.00. PJSM WI all personnel on location including David Hall and Sean DillIon,Tested 15'run of 2"hard line to 2000 psi,SLB began warming up 142 X N Nipple 2.20 0.97 1430 having difficulty with keeping a prime on the N2 SLB pump,made a call to Air Liquide to use their N2 Trailer Charge Pump,permission granted Spacer Sub 2.25 0.88 14.30 Began banging up N2 pressure down the C.T applying pressure on Pert Gun delay firing heads,after running calculations our goal was to 50 2.75 0.50 15:00 apply 3900 psi surface pressure. We reached 3950 psi,shut down pumps and bled well and N2 system down to zero est Bow Spring Sub 4.687 1.85 1500 After for 18 min delay to fire guns we observed Guns bred at 16 mins,R/U Pollard Slickline to RIH w!1.30 Gauge Ring vii 1.20'Centralizer XO 2630 0.61 16.00 test PWS lubricator to 3500 psi,Stand by.Allow well to breath and monitor well for fluid at surface. EZSV Pkr Stinger 1..380 1.31 16.00 17:00 RIH and tag Fluid Level at 2350'vs at beginning fluid level al 4870'=5.3 bbl increase 17.00 Began making Fluid Level check runs w!Stickling at halt hour intervals,monitor&record Fluid Levels.Time,difference in depths.time&volume Plan is to continue checking Fluid Levels until leve stabilizes.Once stabilization is confirmed RIH wl Ball check Bailer to catch sample then 19.30 begin Swabbing efforts until 20.3 bbls are recovered and a sample of oil is recovered from behind pipe 19.30 As of 1930 hrs the Fluid Level has come up hole(14870 U'2300'=2570'.Since after pert guns initially shot and 1st level of 2350'was recorded level as of 1930 hrs=2300'=50'influx=0.106 bbls. Continue Fluid Level Checks.AI 2130 hrs Fluid Level=2288'total of 0.132 bbls 21 30 Abandon Fluid Checks end roll into Swabbing efforts as per David Hall. 21-30 23.00 CIO Slickline Tool Assy to 1.0"Ball Seat Bailer,RIH and recover sample 10'below fluid level,POH sample status KCL Fluid 20 00 0.00 RIH w1 1.35'Swab Cups&begin attempt to recover 20.3 bbls of fluid this is inside volume before sample can be recovered of fluid behind pipe We have a total of 35 new 1 35"Swab cups left,we have used t4 as of 2130 hrs Air Liquide Transport on location contains 164.000 SCF of N2 after transfer after Pert Gun Detonation Safety Observation:Discussed using caution tape both sides of Wireline ti unit to bottom sheeve to keg personnel out of danger zone BHA Length 16.70 I I +'t Ig foe!Itcvd Prnm,Ow OOP-TOW DC 00ToUsed I Stand-Dr FOCI DAILY COST CUM TOTAL COST DAYS SINCE LAST LTA !Personal. Crews Camp Total LAST SPILL civil Comments Don Jones 20 1 • 4111 COOK INLET ENERGY, LLC Cook Inlet Energy DAILY DRILLING/WORKOVER REPORT DATE ;.EASE ANO WELL NO 7/3/14 51€r:,t r-Ar", Mt, PROGRESS North Fork Unit 14-25 32 0 Present Operation rORsror . TOTAL PROJECTED DEP*H At 0600 hrs RI H with r bailer to fluid level to putt liquid sample LAST CA5.'i+;AND SHOE TEST L'.NERS 00.SOF AND SHOE DEPTHS REPAIR DOWNTIME V mores CONTRACTOR AND RIG NO BRIEF DESCRIPTION OF PRESENT OPERATIONS MIDNIGHT to 0300 hrs. DC/00-0430 Pollard swab mandrel being modified at the machine shop in order to run a four swab cup assemby 0430.0530 Tools arrive location.Rig up Pollard Test lubncator to 3000 psi 0530-0600 Run 1.35"gage nng to fluid tag at 2860' Fluid height gained horn 3000'to 2860'while making tool modi8cation POH with gage nng. Noted only bone water on oar ring when puled from 2860' TYPE Nr)22LES or'FA DEPTH FEET HOURS FTMR WOO RPM DULL CONDITION urs Lines Sue Muer SRI.' MUD PROPERTIES,MATERIALS ADDED AND COSTS SAMRL MOD FURL PY SF CS., PH Fla CAKE. N Se SIFT CHLORIDES RE nr ` MUD COSTS W TIME T V5 5510 J2ur SAND SOLIDS PPM DAILY TOTAL DIRECTIONAL SURVEYS MEASURED OR-F1 DIREC COORDINATES DE r,. U MEASURED DROT GIREG COORDINATES ANGLE, TION Vol SECT, DEPTH ANGLE TION S'rcS ',LE-01 1 0 00 2.00 Swab horn depths of 2275'V 2295'without recovenng any fluid Pulling increasing fluid depths of 200'up to 1500' No fluid recovered. (I No CHANGE(SEE PRIOR RPTI 2 00 11'00 Swab fluid level horn 2265'10 3030'pulling with Incresed pull depths up to 2500'of pull on fluid.Recovered 2 bbis fluid Plod weight 8 4+ppg X NEW BHA 11.00 13 30 Three consecutive swabs runs from fluld level al 3000'(+-)pulling 2500'of fluid does not return any Bud 113:30 15.30 Run 1"X 4'long ball type bailer tc 11229"to pith,up fluid sample.Unable to brine sample out with bailer. TOOL DESCRIP DD LENGTH 1530 Remove dual swab cup mandrel.Transport mandrel to machine shop in order to run a four swab cup system Coil annulus and Coll tubing are a a slight vaccum Last fluid tagged at 3000 al 1530 hrs Coil Connector 2 875 0 56 0 00 Pollard swab mandrel being modified at the machine shop In order to run a four swab cup assemby X0 2 875 0 35 2-Slick Sticks 2 25 9 66' X N Nipple 2.20 0 97 Spacer Sub 2 25 0.88 XO 2.75 0.50 how Spring Sub 4.687 1 85 80 2630 061 E2SV Pkr Stinger 1 380 1 31 +No have a tote!0112 new 1 35'Swab cups left.we nave used 36 as of 24 DO hrs Air Liquide Transpon on location contains 130.000 SCF as of 0530 7/4'14 Safety Observation:Discussed Road/Dnving Safety coming to/from work on North Fork1Road beware of winding road wi local fast clovers BHA Length 16.70 Rio rue'find Previous 00 00hr Total' Los, S5 F"ue• p_ _ .. I I Slane- DARY COST II _ CUR TOTAL COST DAYS SINCE LAST LTA: 'Personal' Crews Camp Total LAST SPILL. Cost Comments --. —• 16 Dor.Jones,Mike Murray —`---` —'— — 00K INLET ENERGY, LLC • Cook Inlet Energy DAILY DRILLING/WORKOVER REPORT DATE 7/4/14 _EASE AND WELL NO APE NO DAAS MD TUE PROGRESS North Fork Unit 14-25 33 0 Present Operation FOR.MATiON TDTA.PROJECTED DEPTH Circulate out gas at 8520' -AST CASING AND SHOE TEST LINERS-OD.TOP ANO SHOE DEPTHS REPAIR DOWNTIME 5 month CONTRACTOR AND RIO NO BRIEF DESCRIPTION OF PRESENT OPERATIONS MIDNIGHT to 0300 hrs 03 00•0200 Well static.Install spoolable connector.Connect lubricator 02.00-04.00 Circulate coil volume.Full returns with no gas shows.Spool coil al 50 ft/min 10 hanq off depth al 5520'.Circulate at.75 bbl/min coil while P014 Hole took 10 bbl while POH 04.00-0430 Monitor well.Coil static but noted gas in the annulus. 04:30.06:00 Circulate a1 1.5 bbllmin.Gas in returns. El SIZE TiPE NOZZLES or TEA DEPTH FEET HOURS FTMR WOO RPM DULL CONATION Pump Leer Sur S,aE.r 5PM PSI MUD PROPERTIES,MATERIALS ADDED AND COSTS SAMPL MUD PURL PV VP DES PH FILT CAKE h N: MOT CHLORIDES PP MF HTHP MUD CASTS TIME WI NS CCJ30 32Nos SAND SOLIDS PPM DAILY TOTAL DIRECTIONAL SURVEYS MEAS.IRED DRIFT DLREC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V ANGLE TION VEE SECT DEPTH ANGLE TION VAR SECT 000 4.30 Pollard swab mandrel being modified at the machine shop in order to run a four swab cup assemby 1 j NO CHANGE(SEE PRIOR RPT) -4:30 5-30 Tools arrive location.Safety meeting.Rig up Pollard Test lubricator to 3000 psi. X NEW enc 530 6.00 Run 1.35"gage ring to fluid tag al 2860'Fluid height gained horn 3000 to 2860 while making tool modification.POH with gage ring. ' 6.00 630 Sample run#1 with 1"bailer to fluid level and captured 112 cup of brine water. TOOL DESCRIP. OD LENGTH 630 j MU tour cup swab tool.Pulled 1500'of fluid 1st run and 500'fluid 2nd run without recovery Check cups 8 tool stnng-found sign of pude oil 12.00 Sample run#2 baler to FL 8 recovered 112 cup oil comtaminated water.Sample runs#3 8#4 bailer to FL at 2780 catching oily samples Coil Connector 2.875 0.56 12 00 Sample run*5 catch oily sample in adsorbent pad with bailer.The following run came up empty-Tag fluid with swab cups at 2760'. XO 2 875 0 35 Sample run*6 caught oily fluid from 2790'.Made another empty run.Ran four new swab cups with a 500'pull without fluid recovery. 2-Slick Sticks 2.25 9.66' 16.00 Sample run#7 caught oily fluid horn 2780'.End wire line operations.Rig down. X N Nipple 2.20 0.97 1600 17 D0 Safety meeting.RU Schlumberger coil. Spacer Sub 2.25 0 85 17:00 18.00 Unable to bull head into perforations at 4500 psi Pumped 8.5 bbls Bleed down. XO j 2.75 0.50 1800 RU injector.PT 250-5000 psi RU return line.Latch coil MGR.Pull to neutral wt at 11K Back out LDS.Set footage to 11,237. Bow Spring Sub 4.687 1.85 10.00 Pull 22'with 27500#up weighl.Close lower slip rams Push/pull test 0-35K#Annulus 8 coil static.Release G spear X0 2.630 0.61 10,00 10:30 Circulate 30 obis with retums to blow down tank at 1 bbm.Full returns after pumping 4 bbls.No gas shows in returns from IA. EZSV Pkr Stinger 1.380 1.31 10.30 11:30 Monitor well.Static. 11:30 0.00 Stnp off over the coil.Cul coil and begin installing spoolable connector Monitor well continously. Used a total of 42 swab cups with 6 remain new. Took delivery of 2950 gals of N2 Total on location 350K SCF. Safety Observation:Instructed all independent contractors to work closely with each other, BHA Length 18.70 I 1 1 I I I 1 IQig fuel Road 1Prev-ous 00 ODni Tota, I I Uses Stano•8E Fun' DAILY COST GUM TOTAL COST DAYS SINCE LAST LTA: _Personal: Crews Camp Total ®LAST SPILL cost D....kw 16 0I Mike Murray • COOK INLET ENERGY, LLC • Cook Inlet Energy DAILY DRILLING I WORKOVER REPORT ._ .. DATE 7/5/14 L EASE AND WELL NO ACLSO -,t 5_ WD I-RODRESS North Fork Unit 14-25 34 D Present Operation TIED/AT/ON TOTAL PROJECTED DEPTH Displace well with N2. _AST CASING AND SHOE TEST .INERS OD T05 AND SHOE DEPTHS REPAIR DOWNTIME h manias CONTRACTOR AND RIG NO BRIEF DESCRIPTION OF PRESENT OPERATIONS MIDNIGHT to 0300 hrs 00.00-03.00 Wait on Schlumberger nitrogen pump truck. 033'00-04 30 Nitrogen pump truck on location Blow down Schlumberger coil spool on coil unit. 04.30-0530 RD coal injector from well head 05 30-06.00 Remove fluid from well with N2 with returns from call annulus Returns to blow down tank EI SIZE TVP! NOZZLES o--TEA DEG LH FEET 110URS !'MR w'08 RIM DULL CONDITION _ PSmp L..-n5F Sioke I MUD PROPERTIES,MATERIALS ADDED AND COSTS SAMPL MVO FUNL PV vP 1,1 IS pH PIET CAKE N. 1k Nn* CHLORIDES pm MF HIE, MUD COSTS TIME VP EmS CC,. nods SANE` SOLIDS PPM DAILY TOTAL DIRECTIONAL SURVEYS MEASURED DRIFT CARES COORDINATES OE^IL V MEASURED DR='- DIREC COORDINATES DEESE ANGLE TICS UF.H SECT DEPTH A.NC,i TION SEA , 0.00 2 03 Well static.Install spoolable connector.Connect lubricator NO CHANGE 1566 PRIOR REG Circulate coil volume Full returns with no gas shows Spool coil al 50 ft/min to hang o8 depth at 8520 Circulate at 75 bbllmin cols Willie P01-1 Hale took 10 bbl while 2.00 400 POH X NEW BHA 4.00 4.30 Monitor well.Coll static but noted gas In the annulus 430 6.30 Circulate at 1,5 bbl.imin Gas In returns TOOL DESCRIP OD LENGTH 6 30 730 Monitor well.Static 7 30 930 Separate lubncator,Cold tap coil,cut cod 8 MU hanger Coal Connector 7 875 0 56 930 t0:30 Land cod tubing with 17,0009 on hanger Test hanger seals to 5000 psi for 5 nunutes Tail pipe located at 6520. X0 2 875 0 35 10.30 12.00 Release horn coal hanger.Set injector aside Secure well 2-Stick Stacks 2.25 5.66' 12:00 20.00 Crew at rest. X N Nipple 2.20 0 97 20 00 23.00 Safety meeting Slab coil on ROPE RU for NI trogen Space-Sub 2.25 0.68 23 00 0 D0 Schlumberger nitrogen dyno pump tailed with broken hthog.Call for anomer nitrogen pump truck XO 2.75 0.50 Bow Spnng Sub 4.687 1.85 XO 2.630 0.61 EZSV Pkr Stinger -1.380 1.31 a Safety Observation:Notified local authonbes of pending well test flare. BHA Length 16.70 I 1 I I I I I R,9 fde C,/ t PrP, r;',C011 l oa t IStant-EG E..,t. ,__[J __ DAILY CAST II I I CUM.TOTAL COST DAYS SINCE LAST LTA. 'Personal. Crews Camp Total LAST SPILL cost Comment, r 13 Mike Murray 41POOK INLET ENERGY, LLC Cook Inlet Energy DAILY DRILLING/WORKOVER REPORT LEASE AND SNELL NC 7/6114 AFF NO 001 TVD P20G4rSc North Fork Unit 14-25 35 Present Operation FORMATIGr. TOTAL PROJECTED DEPTH Monitor well ,AST CAS'NG AND.SHOE TES` IN-RS-OD TOP AND SHOE DEPTHS REPAIR DOwmTIME ft morn.". CONTRACTOR AND RIG ND BRIEF DESCRIPTION OF PRESENT OPERATIONS MIDNIGHT 10 0300 hrs 00 00-06 00 Monitor well pressures.Coil annulus a1260 psi Coil tubing shut in with zero pressure eel >ii1 T,PL NOZZLES0,1'4 DEPTH FEET HOURS FP, WOE HEM DULLCOND:TtON Fmp l-rH Sur Stio,. SPM PSi MUD PROPERTIES,MATERIALS ADDED AND COSTS SAMA. MUD FUNt Pv yr .A,_ In. FILT CAKE N % MIT %tt,DRiSPO P- MF HTHP MUD COSTS OWL NI MS GCfJG 32,4, SAND COIL. F'vM DAILY TOTAL DIRECTIONAL SURVEYS i.IFASLiet Ti CR-CT DIREC C,,,DINLES DEPTH V MEASURED DP,+! ()AEC COORDINATES ANGLE TION VAR SECT DEPTH AO. L TON OLE buil I 0 00 3 00 Wait on Schlumberger nitrogen pump truck I]NO CHANGE,SEE PROM RPI, 3 00 4 30 Nitrogen pump truck on location Blow down Schlumberger coil spool on coil unit X NEW[;HA 4.30 5.30 RD coil infector from well head ' 5 30 Safety meeting Remove fluid from well with NO with returns from coil annulus Returns to blow down tank Pump rate 500 SCFM TOOL DESCRIP. OD LENGTH At 100K SCF of N2 pumped and 100 bbts of fluid returned to blow back returns changed to a majority of N2 Stop N2 displacement 9 00 Maximum pressure reached 2700 psi. Coil Connector 2 575 0 56 9 00 Change to pumping N2 into the annulus with returns from the coil velocity string Pump rate 500 SCFM 00 2 875 0 35 AI 1850 psi of N2 on the annulus gained returns from the coil 2-Slick Sticks 2.25 9 66' Continue pumping N2 iotr the annulus End pumping al 2560 psi without bring gas up through the coil velocity string X N Nipple 2.20 0.97 18.00 Pumped a total 01370.000 SCF on the job Total fluid returned 174 Obis Used all available nitrogen on location Spacer Sub 2 25 0.88 18 00 21 00 Shut in IA at 2560 psi RU and bleed nitrogen from IA Shut in IA at 250 psi Monitor Coil while bleeding down•static XO 275 0.50 21 00 000 Coil annulus monitored-starling pressure at 250 psi Coil tubing shut in with zero presure Bow Spring Sub 4 687 1 85 XO 2 630 0.61 EZSV PMStinger 1360 1.31 Discussed working in tight areas swinging hammers. BHA Length 76.70 1 I 1 I 1 1 I dig tun Bend 1 Previous 00 00nr Total 1 I 1 :fano-by Fuca - l DAILY COST II tr CUM TOTAL COST DAYS SINCE LAST LTA- JJPersonat Crews Camp Total LAST SPILL. Cast comewes: 13 Mike Murray COOK INLET ENERGY, LLC Cook Inlet Energy DAILY DRILLING/WORKOVER REPORT DATE 7/7/14 LEASE AND WELL NO PROGRESS North Fork Unit 14-25 36 Present Operation FORMA'SON TOTAL PROJECTED DEPTH Monitor well LAST CASING AND SHOE 11 Sr LINERS OD TOP AND SHOE DEPTHS REPAIR DOWNTIME V moot, CONTRACTOR AND RIG NO BRIEF DESCRIPTION OF PRESENT OPERATIONS MIDNIGHT to 0300 hrs DC 00-0590 Well Shut BY for pressure readings IA al 28 psi Coil tubing velooly stung at 12 psi as of 05 00 hrs Ei' L E 1vPE NOZZLES.TPA DEPTH FEE' H^,4$ FT/1.02 WOB RUM DULL CONDITION Purv.F Lim Sr S tETE SEM Es MUD PROPERTIES,MATERIALS ADDED AND COSTS 3AMPL MUD FUN.. PV VP GELS P., r.. LOU S 9( MB' CHLORIDES Pr M` HTH1 MUD COSTS TIME V✓i 1A5 _ r_ 3;�n� SAND SOLIDS PPM DAILY TOTAL DIRECTIONAL SURVEYS MEASURED DRIFT DREG COORDINATES nEi'U M=ASUREC DPIFI nE. ANGLE tips VAT S[-;` PEEL 5Ni,l E 0.00 7.00 Monitor well Annulus built from 250 to 260 psi as o107.00 his Tubing shut In.10 psi increase as or U/CD hrs ()NO CHANGE r SEE PRIOR RPT, 7 00 Bleed annulus off from 260 psi to zero Open tubing to blow down lank S NEW 0110 Monitor well Tubing open to blow down lank Annulus shut in and building pressure Annulus building pressure slowly Bleed annulus-12 psi at 14.00 hrs TOOL DESCRIP OD LENGTH Put annulus and cod tubing velocity string on continous vent to blow down tanks 18 00 Both 1.75"cod tubing and coil annulus venting slightly to blow down tanks 18.00 RU Pollard 125"sliCV.line with swab Cup mandrel on 1"tool slnng.Continue venting wet', 11 30 PT to 3000 psi RIH with swab cup assembly Tag fluid al 7100.PON Rig down 11.30 0 00 Shut well in for pressure readings Rain for Rent lank volume 216 bb15. Atigun tank volume 238 bbls Discussed working with coil RD operations and flow line changes Simuttaneously. BHA Length 16.70 Prcv:ousCOOth- S I I Il l l i _ 1 DAILY COSI 1 _ CUM TOTAL COST DAYS SINCE LAST LTA: 'Personal: Crews Camp Total LAST SPILL Con Comments 3 Mike Murray litOOK INLET ENERGY, LLC Cook Inlet Energy DAILY DRILLING I WORKOVER REPORT DATE 7/8/14 LEASE AND WELL NO OFF ND DADS TVD PRUGRE55 North Fork Unit 14-25 37 Present Operation roRMATIon TATA:PROJECTED DEPTH Monitor well pressure build Up LAW CASING AND SHOE TEST LNERD•05.TOE AND SHOE DEPTHS REPAIR DOWNTIME P,non;, CONTRACTOR AND RIG NO BRIEF DESCRIPTION OF PRESENT OPERATIONS MIDNIGHT to 0300 hrs As et 06 00 hrs Coll vetoer}tubing built pressure to 83psi and coil annulus built to 245 ps b, Si•:E. ,- h Cl Fc. DEPTH PELT HOURS FT/MR Y.KD5 RF,J DU)I.CONDITION c SEe S/a,, SPY Pj MUD PROPERTIES,MATERIALS ADDED AND COSTS SAMPL MUD FOOL PV vi GODS PH FILO CAKE - 4E, HLOR,OES F. '-'SIF MVO COSTS TIM) WT vs DC/JO 32 S, - ',PEE :. $/ PFM 00I1V OCTAL DIRECTIONAL SURVEYS MEASURED ORirr DREG COORDINATES DEPTH V MEADLOE'' 5 DREG /'1AT:> DEP', H.� ANGLE T,ON VKB SECT C)P"l i pDI F TION 4 Vr.S SiC' 0 00 j Well shut for pressure readings )NO CHANGE(SEE PRIOR RPM Velocity slnng pressure built at the rate of 2-3 psi per hr to 62 as of 24 00 hrs S NEW BRA 0 00 Cod tubing annulus pressure built at the rate of 0-10 ps per hr to ISO as of 24 00 hrs TOOL DESCRIP 00 LENGTH Made arrangements for nitrogen pumping operations to mobilize ASAP • • Rain for Rent tank volume 21B bbls Atigun tank volume 238 bbis Held PJSM on proper burner lighting with regards to pilot 8 main burner operation. BHA Length I - ) I I k,c reel+.w_ r'•E�:ov,.�,"DOM To'') J ,e�- A,F,;e SAILS COST CUM TOTAL COST DAYS SINCE LAST LTA_ ,Personal: Crews Camp Total •LAST SPILL Cost Comments 5 Mike Murray - II COOK INLET ENERGY, LLC • Cook Inlet Energy DAILY DRILLING/WORKOVER REPORT _._ DATE 7/9/14 LEASE AND WELL NO AFE NO DAYS MD TVD PROGRESS North Fork Unit 14-25 38 0 Present Operat ion FORMATION ''GTA_PROJECTED DEALT Prepare to flow well to test separator. .AST CASINO AND SHOE TEST LINERS OD TOPAND SHOE DEPTHS REPAIR DOWNTIME F mnnih CONTRACTOR AND RIG NO BRIEF DESCRIPTION OF PRESENT OPERATIONS MIDNIGHT to 0300 hrs: Well shut in with 2636 psi on the annulus and 2735 psi on the coil tubing velocity stung as of 06.00. FT WE TYPE NOZZLES or LEA DEPTH FEET HOURS FTMR Wile RPM DULL CONDTiON rymy Luer Size SINAs SAM PS MUD PROPERTIES,MATERIALS ADDED AND COSTS SAMPI. MUD FUNL PU 1P GEIS PH TILT CAKE % N MAT CHLORIDES PF Mr CLAP MUD COSTS TIME WY NS COf30 32nds SAND SOLIDS PPM DAILY TOTAL DIRECTIONAL SURVEYS MEASURED DRIFT (TREC COORDINATES DEPTH V MEASURED DRIFT DIRCC GOOROiNATES DEPTH y ANGLE TION VKa SECT DEPTH ANGLE TION VKe SECT 0.00 10:00 Well shut for pressure readings while fringing in nitrogen pumping unit NO CHANGE(SEE PRIOR RPT, 1000 12 00 RU Schlumberger N2 pumping unit and Air Liquide transport X NEW RHA 12.00 13.00 End well pressure build up.Coil at 109 psi-Annulus at 317 psi.Test lines to 4500 psi. 113:00 15'30 Bleed down coil to blow down tank.Cool down&prime up NO pump.Having trouble priming N2 pump.Boost unit with transport pump. TOOL DESCRIP OD LENGTH 15.30 Pump N2 into annulus at 500 SCFM Infect 1 gal Baker Petrolite RFO-01728 foarner with 20 gals water mixed. Building pressure on annulus. Relums lined up to blow down lank showing vapor from 1.75 velocity stung 19:15 hrs-Gained fluid returns Pump presure 2450 psi Reduced rate to 400 SCFM.19:45 hrs-reduced rate to 300 SCFM.Pressure steady al 2550 psi.20:00 hrs reduced rate to 300 SCFM.Returns 8 pressure steady 20:15 hos Gained 14 bbls in one hour 20:45 hrs-Returns slowing down.Increased rate to 350 SCFM.Pressure steady at 2550 psi. 21:15 hrs-Returns changed to 100%nitrogen at blow down tank.Shut in coil tubing and recorded 2500 psi on coil.Continue pumping N2 Pump pressure 2500 psi Increased rate to 500 SCFM with returns shut in.N2 pump pressure 2500 psi. 22:15 Drs-End operation when empty of nitrogen.Pumped 1 hr 150 minutes)at 500 SCFM after shutting the return line in=30,000 SCF 22.30 Final pump pressure on annulus and coil 2800 psi.Secure well 22:30 000 Monitor well pressures 23:00 hrs Tubing at 2905 psi Annulus at 2786 psi. Observed a small amount of foam at end on blow down.Total fluid recovered 3525 bbl. • Air Liquide filled transport with 3087 gals(287316 SCF)of N2 and made delivery to location. Rain for Rent lank volume 218 bMts. Atigun tank volume 238 bbls. _Reviewed MSDS information on foamer 8 defoamer. BHA Length I 1 I ( 1 I 1 'tlg ICA Rcv: Previous 07 00nr T01a, Used Grand-By Kue, DAILY COST _ CUM TOTAL COST DAYS SINCE LAST LTA: rersonal: Crews Camp Total ,LAST SPILL con cenvsem,_ 7 Mike Murray •OOK INLET ENERGY, LLC Cook Inlet Energy DAILY DRILLING I WORKOVER REPORT a_ _... DATE 7/10/14 LEASE AND WELL NO AFE NO DAYS MD TVD PROGRESS North Fork Unit 14-25 39 0 Present Operation F[AMC ION TOTAL PROJECTED DEPTH Monitor 1 3/4"C T.Surface Pressure and 1 3/4'X 5 1/2"Annulus Surface Pressure 8 record hourly LAST CASING AND SHOE TEST LINERS''CO TOP AND SHOE DEPTHS REPAIR DOWNTIME f+month CONTRACTOR ANC RIG NO BRIEF DESCRIPTION OF PRESENT OPERATIONS MIDNIGHT 10 0300 hrs 0000-0500 hrs.Monitor 1 3/4"Coil Tubing Surface Pressure and 1 3/4"X 5 1/2"Annulus Surface Pressure and record hourly Pr SIZE TYPE NOZZLES co TEA DEPTH FEET HOURS FT/HR WOa RPM DULL CONDITION Pump Lin.Sae SooRe 5PM PSI MUD PROPERTIES,MATERIALS ADDED AND COSTS SAMPL MUD FUN, PV YP GELS PH FLIT CASE 96 N MET CHLORIDES PF ALF STOP MUD COSTS TIME NT 515 CC/30 32,515 SAND SOLIDS PPM DAILY TOTAL DIRECTIONAL SURVEYS MEASURED DRIFT DIREC COORDINATES DEPTH V MEASURED DRIFT DIREC COORDINATES DEPTH V ANGLE TION VAS SECT, DEPTH ANGLE TION VAR SECT 0.00 6.00 Well shut in with 263e psi on the annulus and 2735 psi on the coil tubing velocity string 05 0106:00 (]NO CHANCE(SEE PRIOR RAT) 6:00 Safety meeting Test flow lines to separator to 3500 psi Pump one gallon of toamer with one barrel of water into annulus. X NEW,BHA 9 30 Stan methanol pumps.RU remote operated SSV Strap tanks.Move out Schlumberger unit.Notify local authonties of pending flare 19'.30 Well on test. Open well to Test Separator,w/choke set at 48l64th's,drop 1"orifice into service on 3"Meter Run,decrease choke to 10/64ths, TOOL DESCRIP OD LENGTH 10:30 increase Line Heater temp ft 120 V 140°,WHP ff 2250 psi V 1670 psi,average flow rale. 1,25 mmscf 10.30 11:30 Increase choke size L'1216415s,WHP 0 1670 psi,V 1010 psi,average flow rate.125 mmscf 11:30 12-00 All N2 at surface WHP II 1010 psi V 600 psi,average flow rate: 1.23 mmscf 12 00, 13 30 Adjust choke 1/18/64ths to FULL OPEN,WHP 1f 800 psi V 80 psi,average flow rale. 1.0 mmsd 13.30 14:30 W4h choke Full Open,WHP f/80 psi V 14 psi,average flow rale 500 msef 5-7 LEL Gas readings 14.30 16:30 With choke Full Open,WHP 1/14 psi V zero psi,flow rale 11500 msd V zero mscf,15 LEL 16:30 18'.00 Pollard Slichine arrived,RIU and! r r 1 ; POH and R/D departed al 1830 hrs, 18.00 Monitor 1 record 1 314"Coil Tubing surface pressures and CTAS 112"Annulus Pressures hourly.Tubing Pressure stayed a1 zero_Esi. End of 1 3/4"Coil Tubing =8521'. Top Gas Ped al 8536',Bottom Gas Pert at 9552' Nole-at beginning of Flow Test 0930 hrs,Tubing 8 Annulus Pressure=2250 psi at end of test 1800 psi Tubing=zero psi.annulus=170 psi Baker Treatofie reps arrived and delivered 5 gallons of"Foam"Surfactant at 1900 hrs and recovered some oil skimmed off samples to lake back to their lab to run centrifuge for oil analysis Rain for Rent tank volume 256 bbls. Atigun tank volume 277 bbls. Held PJSM for flow testin. BHA Length 1 _ I I I I kig iuel Rvvd ( Previous OO 00hr Total USIA Stand-8 Fue: I _ ,DAILY COST CUM TOTAL COST DAYS SINCE LAST LTA: !Personal: Crews Camp Total rST SPILL Cast Comments: 7 Don Jones/Mike Murray • • e . COOK INLET ENERGY, LLC Cook Inlet Energy DAILY DRILLING I WORKOVER REPORT -- DATE 7111114 ,EASE AND WELL NO A,f ND ,.E95 m, IVO PROGRESS North Fork Unit 14-25 40 0 Present Operation :'Ea+c D; TOTAL PROJECTED DEPTH Monitor 1 3/4"C.'0 Surface Pressure and 1 314"X 5 1/2"Annulus Surface Pressure,RID Test Equip :AST CASING AND SHOE TEST IWE.R5.00.TOPAND SHOE DEPTHS 0(5018 DOWNTIME S r,nntn CONTRACTOR ANO RIG NO BRIEF DESCRIPTION OF PRESENT OPERATIONS MIDNIGHT to 0300 hrs' 0000.0500 hrs 1 3'4"X 5 1/2"Annulus Pressure al 0500 hrs=648 psi Average Pressure increase per hour from 2100 hrs to 0500 hrs E.19 psi I hr TYPE NOZZLES OT TEA DEATH, FEET HOURS FTRIP 0106 FEN DULL CONDITION EA o L rm Sre SNORT SPM FS. MUD PROPERTIES,MATERIALS ADDED AND COSTS SAMPL RISE FUND PV Y .,i.,, AH GILT CAKE N A. MFT CHLORIDES PR Mr HTHP MUD COSTS TIME WI VIS 00,30 32nd, SAND SOi IDS FES' OMIT TOTAL DIRECTIONAL SURVEYS MEASURES' DRIFT DIREC COORDINATES DEPTH V MEASURED Dl-" _."/. C00R0LNATES G;l'ID. ANC-LE TICS VK6 SECT ULPIN ANG'.E T.i, HAP 0 DD– Monitor 1 314"Coil Tubing Surface Pressure and 1 3/4"X 5 1/2"Annulus Surface Pressure and record hourly C.T pressure stayed at zero psi, [[NO CHANGE(SEE PRIOR RPT, Annulus Pressure built 1 222 psi at 2400 hrs 0 271 psi Al 0500 hrs. Thursday Ii 1800 hrs 1./2400 hrs annulus built 8 psi/hour,2400 hrs G X NEW BHA 5 00 0500 NS annulus pressure built 10 psi/hour 5 00 14 00 Continue monitoring I recording 1 3/4"Coil Tubing pressure build and 1 3/4"X 5 1/2"annulus pressure build.ft 0500 hours 271 ps TOOL DESCRIP 00 LENGTH 1400 18.0D Continue monitonng/recording 1 3/4"Coil Tubing pressure build and 1 3/4"X 5 112"annulus pressure build 11 1400 hours 400 ps 18.00 Continue rnonitonng I recording 1 3/4"Coil Tubing pressure build and 1 3/4"X 5 1/2"annulus pressure build.G 1800 hours,453 psi 221 00 Continue monitonng/recording 1 3/4"Coil Tubing pressure build and 1 3/4"X 5 1/2"annulus pressure build.f12100 hours,495 psi Note While continuing to monitor i record pressure build,received direction to RID Flow Test Equipment and prep for demob to Trading Bay Also Iransfenng Workover Fluid from Rain 4 Rent and Atigun Defuser Tanks to Demob fluid to Trading Bay PTS Techs departed at 1630 hrs IDA Reps departed at 2100 hrs Safety Observation, Discussed road safety,slay toe speed limit and be aware of fast moven local residence BHA Length I I 1 1 1 1 Le R-,d I Fie N70 con,Total. I 1 Useo Slane-ay F:,,1 DAILY COST l— 1 ' `CUM TOTAL COST DAYS SINCE LAST LTAi 'Personal. Crews Camp Total .LAST SPILL cesrCon,ments. 7 Don Jones • •OQK INLET ENERGY, LLC , Cook Inlet Energy DAILY DRILLING!WORKOVER REPORT .EASE AND WELL NO 7112114 AiR °ROGRE SS North Fork Unit 14-25 41 o Present Operation IORMATION TCTAL PROJECTED DEPTH Monitor 1 314"C T Surface Pressure and 1 3'4"X 5 1/2 Annulus Surface Pressure ..AST CASINO AND SHOE TEST L1NERS OD.TOP AND SHOE DEPTHS REPAIR DOWNTIME V mom!. CONTRACTOR AND RIO No BRIEF DESCRIPTION OF PRESENT OPERATIONS MIDNIGHT to 0300 hrs: 0000-0500 hrs 1 314"X 5 112"Annulus Pressure=1053 psi,C T pressure=303 ps at 050D hrs N,IZZ,E&&o=''-t0 DCET0 EEE1 HOURS FTIHR WCS REM 00E1 CONDITION rump lm^.e•.S:e 511,1* SPH Fes. MUD PROPERTIES,MATERIALS ADDED ANC COSTS SANER_ MUD FOWL PP CEI S .r CAKE 'k 0 Mrs' CHtOH'CrES F' a HTHP MUD COSTS TICS WT 010 DCt0 32Ms SAN' SCL.CS PPM DART TOTAL DIRECTIONAL SURVEYS MEASURE S 70,rT DREG CC Ryna*f[ DEPTH *T DRIED COORDINATES DEFi1- Ar.L.F TION IMS SECT L:LPIH ANG.: TION SECT 0 O 5 00 Continue monitoring 1 3/4"Coli Tbq pressure build&1 314"X 5 1/2"annulus pressure hard{tl 0500 hrs,644 psi on Annulus&125 psi on C I)NO CHANGE SEE PRIOR ROT, 5.00 12.00 Continue monitoring 1 314"Coil Tbg pressure build&1 3/4"X 5 1/2"annulus pres build.CV 1200 hrs 775 psi on Annulus&160 psi on C T X NEWerw 12 00 18.00 Continue monitoring 1 314"Coil Tbg pressure build 8 1 314"X 5 112"annulus pressure build.ii 1800 hrs,872 psi on Annulus&212 psi on C T 16 00 21 00 Continue monitonng 1 3;4"Coil Tbq pressure build&1 364"X 5 112"annulus pres build(4i 12100 hrs,915 psi on Annulus&233 psi on C T TOOL OESCRIP, OD LENGTH Note WhIe continuing to monitor./record pressure build,we continued to R/0&Load out Flow Test Equipand prep for demob to Trading Bay Also transfennq Workover Fluid from Rain 4 Rent and Atigun Detuser Tanks to WBI ISO Tanks bound for Trading fay last ISO departed from NFU 1715 firs Loaded all 3 trailers w/Test Equipment. Will road to OSK in the a in IDA Reps departed at 1800 hrs Avg Annulus Pressure Increase per hour 1/0500 his Saturday ti 0500 hrs Sunday=17 psi!hr=405 psi increase on Annulus.178 ps Increase on Coil Tubing Pressure in 24 hrs D 8 0 Welding Services ordered&picked up pans today for Production Flow line Manifold, weld out,10%X-Ray Hydro Test at NFU Pao Estimated install Tuesday Safety Observation: Ripg:n clown equipment and transtenng fluids, rye clear hand signals,communicate clearly check hoses for leaks BHA Length '631st F;.I I E". ,=Ci'GTS Gh.' •atl Stal, I I.lcel nt-Oy Fuel DAaT COST CUM TOTAL.COST DAYS SINCE LAST LTA Personal Crews Camp Total LAST SPILL cost Comments. 4 Don Jones • COOK INLET ENERGY, LLC • Cook Inlet Energy DAILY DRILLING/WORKOVER REPORT DATE 7/13/14 TEASE AND WELL NO 4IF DL TVD PROGRESS North Fork Unit 14-25 42 0 Present Operation FORMAT,ON TOTAL PROJECTED DEPTH Survey area for Rig 191 camp base,then depart Beluga in route to Trading Bay .AST CAS'NG AND SHOE TES' LINERS OO TOP AND SHUF DEPTHS REPAJR DOWNTIME k matin CONTRACTOR AND RIG NO BRIEF DESCRIPTION OF PRESENTGPER1 IONS MiDNIGHTto 0300 hrs. -327 psi 13,1 SIZE -.I, NOZZLES or TFA LITH r ET.I HOITOE ETMR WOO RPM OLRLCONOITION MUD PROPERTIES,MATERIALS ADDED AND COSTS SAWN. MUD FUND PV HP CTL.. PY. Cost % % MET ,.Y,. J.`, DI PF ,,.,. MUD COSTS _< TIME WT VS -_, a, SAND SOLIDS DES DAILY TOTAL DIRECTIONAL SURVEYS MEASURED DR,ET DREG COORONATES DEET' V MEASURE L COORDINATES DE Pr ANGLE TION Urn SECT OF Fu so L. 0 00 5.00 Continue rnonitonog 1 314"Coil Tbg pressure build&1 314"X 5 1/2"annuals pressure build a 0500 hrs,1053 psi on Annulus&303 psi on C T I)NO CHANGE TSEE PRIOR RPD _5 DO 13.30 Continue momtonng 1 3/4"Coll Tbg pressure build&1 314"X 5 112'annulus pressure build©1200 hrs 1151 psi on Annulus&358 psi on C X NEW BHA 13 30 15 00 Last Test Equipment WBI trader and 500 bbl Atigun Defuser lank departed NFU bound for OSK for 0400 hrs callout to Trading Bay 15OD 1 amved at CIE Nikiski yard to drop ort materials and caught a shared plane to Beluga to meet with Tim McKeiman We surveyed the road TOOL DESCRIP. 00 LENGTH system to Olson Creek Padlook and sent pid of road washout 4 miles past Pretty Creek Staging Area Talked to Mike Bnnkmeyer about best set up for 80'x 230'camp In the Olson road Gravel Pit He is contenng with Barney Mahoney and will get back with me on which direction gravel excavation Is continuing in pd arid where best place the camp will efllcently set Survey area where pad expansion will occur on '9 00 Nortn end of Olson Creek Dulling Pad,checked effective bennng around perimeter of Pad I plan to depart for Trading Bay in the morning At Pretty Creek staging area we counted 76"Full"Plywood Boxes of Drill Cuttings in berm Note While continuing to monitor pressure build we prep for and demobbed Test Equipment to OSK Docks bound for Trading Ea, What is left on NFU location is 1-Rain 4 Pent 400 bbl Defuser Tank and High Pressure Hose/Hard line 8 NFU 14-25 F R 4 P tank and Large Lined/Berm Avg Annulus Pre"-. L 14 psi!hr=327 psi increase on Annulus 199 PSI mere.:• ter.1,01:ivLlny kie>suie in 21 hrs Safety Observation. Dswssed benefits of clean up'organize around location.puttingparts I equipment back into their proper area BHA Length 1 I I I i l Used Stand.Hy P se' DAILY COSI II r I C.TOTAL COST _ DAYS SINCE LAST LTA Personal. Crews Camp Total LAST SPILL Com Comments 1 Don Jones • Cook Inlet Energy_ . ,its 1) '1 20={ January 07, 2015 ' Ms. Cathy Foerster,Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Report of Sundry Cook Inlet Energy, LLC: North Fork Unit# 14-25 Permit to drill NO: 210-111 API No: 50-231-20035-00-00 Dear Ms. Foerster, Cook Inlet Energy(CIE)hereby submits a Sundry Completion for installing a 13/,"velocity string in this well of North Fork Unit# 14-25 well located on CIE lease#391211/2095. Attached is the current wellbore schematic. Schlumberger CTU was used to complete this work, commencing on June 18,2014. If you have any questions,please contact me at(907)727-7404. Sincerely, Conra• °e• Drilling Manager Cook Inlet Energy 10-403 Of '%.5'Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LJ Repair Well U Plug Perforations ❑ Perforate Li Other U Coil DSTNelocity Performed Alter Casing ❑ Pull Tubing Stimulate•Frac ❑ Waiver ❑ Time Extension E] Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other U Re-enter Suspended Well❑ 2.Operator Cook Inlet Energy,LLC 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development [] Exploratory u 210-111 3.Address: 601 W.5th Avenue,Suite 310,Anchorage,AK Stratigraphic❑ Service 0 6.API Number: 99501 50-231-20035-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 391211/2095 North Fork Unit a 14-25 , 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): ` / North Fork 11.Present Well Condition Summary: Total Depth measured 11700 feet Plugs measured N/A feet'' 1 s', true vertical 11002 feet Junk measured N/A feet Effective Depth measured 11690 feet Packer measured N/A feet true vertical 10992 feet true vertical NIA feet Casing Length Size MD TVD Burst Collapse Structural Conductor 178' 16` 178' 178" N/A N/A Surface 2992' 10 3/4" 2992' 2786' 5210 2480 Intermediate 5297' 8 5/8"/7 5/8" 5297' 4714' 5714/6890 2520/4790 Production 11700' 5 112" 11700' 10311' 10640 7480 Liner Perforation depth Measured depth 8536'to 9552' feet True Vertical depth 7838'to 8854' feet Tubing(size,grade,measured and true vertical depth) 1 3/4" 17# 8520' 7822' Packers and SSSV(type,measured and true vertical depth) 12.Stimulation or cement squeeze summary; Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A 170 '0 1 209 Subsequent to operation: N/A 203 0 —251 251 14.Attachments: 16.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service Q Stratigraphic ❑ Daily Report of Well Operations 16.Well Status after work: Oil p Gas U WDSPL LT 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: 314-333 Contact Tyler Wagner Email Tyler.wagner@cookinlet.net Printed Name Conrad erry Ai Title DRLG Manager Signature 9 14$I1______ ' __ phone 907-727-7404 Dale 1!7/2015 41 Form 10-404 Revise. a 26 2 Submit Original Only • • PROPOSED Velocity Install Permit#: 210111 NFU #14-25 Apish 231-20035-0 I i p Prop.Des:AOL-391211/2095 _ Cook Inlet Energy ' FSL, 'FEL. KB elevation: 679' (21'AGL) S26 T4S R14W S.M. Latitude: 59'47'46.xxxx"N Lonslitude: 151'37'45.xxxx"W Spud: x: X Rig Released: Structural Five.Driven 1 16" X-56 64 ppf Top Bottom MD Surf 153' TVD Surf 153' 2 Vi Chemical Injection Nipple set @ surface Casing 355'MD. Drift-4.767"ID P110 10414" Leo 45.sppt � Top rill: 6.812"OD MQ o'e.. . ,44 WO0 lePdermediate ming-tapered string 8 518" L40 26 ppf Hydril Top Bottom MD 0' 2,412' TVD 0' 2,312' i,• 7 518" 29.71 L40 BTC-M I ,. MD 2412' 5,297' ri,t' 4 ND 2312' 4,714' „ 1 3/4"Coil VelocityString ID 1.482" Production Casing 5112" P-1117 ppf Hydric 513 - Top Bottom x MD 0' 11,690' ,; WD 0' 10,992' ut Y ,.F End of tubing ;$?: ' 8520'MD Perforation Intervals: " 7822'TVD 8,536'-8,548' 8,620'-8,640' a (Stinger OD 1.38"ID.87" -8 8,760' ,776' 9,536'-9,552' "` ' +a 5 1/2"x 4"ID Casing Patch From 8757'to 8778' w IP PBTD 11,700'MD I 11,690'MD I 11,002'TVD ; 10,992'WD Well Name&Number: North Fork Unit 114-25 lease: Kenai Loop County or Parish: Kenai Penieula Borough State: Alaska ' Country.' USA Perforations(MD): Pert(TVD): Angle©KOP and Depth. Angle©Perls: KOP TVD: Date Completed: Ri03: 21' Prepared By. Conrad Reny Last Revision Date. April 29,2014 OF T� w Alaska Oil and Gas \ jTHE STATE THE ofALA�KAConservation Commission # itx_,_ 333 West Seventh Avenue \Tti GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279 1433 O� ALAS� Fax 907 276.7542 www.aogcc alaska.gov Conrad Perry Q, JO - 1 I 1 Drilling Manager Cook Inlet Energy, LLC 601 W. 5th Ave., Suite 310 Anchorage, AK 99501 Re: North Fork Field, Undefined Gas Pool,NFU 14-25 SCANNED Sundry Number: 315-465 Dear Mr. Perry: 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 P. oerster Chair DATED this I day of August, 2015 Encl. RECEWED STATE OF ALASKA in L 3 0A1'4,- ALASKA OIL AND GAS CONSERVATION COMMISSION 07'S '/C is APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program Suspend❑ Plug Perforations❑ Perforate 2 • Pull Tubing❑ Time Extension 0 Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Cook Inlet Energy,LLC Exploratory ❑ Development Q • 210-111 • 3.Address: Stratigraphic ❑ Service El6.API Number: 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 50-231-20035-0000 7.If perforating: CI"v, 33 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC25.055 — North Fork Unit#14-25 • Will planned perforations require a spacing exception? Yes ❑ No ❑� 1:3v & 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 391211/2095 North Fork, Undefined Gas 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): 11,700' • . 11,002 11,566' 10,177' none none Casing Length Size MD TVD Burst Collapse Structural Conductor 178' 16" 178' 178' N/A N/A Surface 2,992' 10 3/4" 2,992' 2,786' 5210 2480 Intermediate 5,297' 8 5/8"/7 5/8" 5,297' 4,714' 5,714'6,890 2,520/4,790 Production 11,700' 5 1/2" 11,700' 10,311' 10,640 7,480 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8,536'to 11,294'(attached) 7,838'to 10,596'(attached) 5 1/2" 17#Hydril 513 P-110 11690' Packers and SSSV Type: N/A Packers and SSSV MD(ft)and TVD(ft): N/A EZSV @ 11235'MD 12.Attachments: Description Summary of Proposal 2 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑✓ Service ❑ 14.Estimated Date for 15-Apr-15 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑., • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 0 Abandoned ❑ Commission Representative: GSTOR 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Conrad Perry Email conrad.Derry@cookinlet.net Printed Name Con. Perry _ . Title Drilling Manager Signature •hone 907-727-7404 Date -7.2j o-Lv l S COMMISSION USE ONLY Conditions of approval: Notify .m '-s.n so that . _•resentative may witness Sundry Number: er L_ 315 - Ll�S Plug Integrity EI Test Mechanical Integrity Test ❑ Location Clearance ❑ Other x- Lis-0 0 os,, 4 Detest (, 4se - 2_550,$.,-) Spacing Exception Required? Yes ❑ No L`J Subsequent Form Required: /0--LI o y APPROVED BY / Approved by COMMISSIONER THE COMMISSION Date: - —/J 8 •101 oRtepicNnAt, Subs inDupliateForan 10a,85.1.5" 3(Revised 10/2012) for 12 months fro a date of approval. Attachments in Duplicate �' RBDM AUG 142015 ',. 7 -3C�•d _ Cook Inlet Energy_ RECEIVED JUL 3 0 2015 AOGCC July 30th, 2015 Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry (( Cook Inlet Energy, LLC: North Fork Unit#14-25 (PTD 210-4-1t Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a completed Form 10-403 and Application for Sundry Approval to perforate two additional zones in this well. These perforations would be in addition to those previously approved under Sundry#315-209 dated 4-14-15. a. 6020' —6376' MD ADDITIONAL PERFS • b. 6364' —6376' MD ADDITIONAL PERFS Work on Approved Sundry#315-209 has not commenced. If you have any questions, please contact me at(907) 727-7404. Sincer y, Conrail! Drilling Manager Cook Inlet Energy 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax The following is identical to Approved Sundry Application 315-209 with the addition of two new sets of perforations as noted. NFU 14-25 -Well Summary- Current Status: NFU 14-25 is currently on production Scope of Work: • Recover velocity string • Perforate/re-perforate zones General Well Information: MASP: 2500 psi (Does not change with additional shallower perforations) Reservoir Pressure/TVD: 3,493 psi @ 12,475' MD/9,438' TVD-February 2007 This zone has been partially depleted. Wellhead Type/Pressure Rating: Vetco Grey 13-5/8"- 5M BOP Configuration: Blinds in lower, coil rams in upper TIFL/MIT-IA/MIT-OA: TIFL - N/A MIT-IA - drilled 2010 MIT-OA - drilled 2010 Well Type: Producer Estimated Start Date: September 15t, 2015 Drilling Manager: Sr. Drilling Engineer: Production Manager: Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-9738 (907) 433-3822 conrad.perry@CookInlet.net Stephen.Ratcliff@Cooklnlet.net David.Kumar@CookInlet.net 3 NFU 14-25 Work Over Program c XN P rL Stage 1 S/1-- 2. RU coil BOPE on top of 3-1/8" 5M flange 3. RU coiled tubing unit and flow back iron 11;.`1- 4. Test Coil tubing BOPE to 36tirpsi L5'V 5. Kill Well with 8.6 ppg KCL 6. Recover 1-3/4"coil velocity string 7. RD coiled tubing unit 8. Change Velocity string spool to Coil tubing spool 9. Rig up coil/N2 10. RIR in stages lifting well clean of water to diffuser tank a. Repeat as needed to TD 11. R/D coil, get Schlumberger off location 12. Test Well 13. If well does not produce at commercial rates,then re-perforate with 2 7/8"guns a. Pressure up WHP to 1000 psi underbalance if possible b. 6020' —6376' MD ADDITIONAL PERFS - c. 6364' —6376' MD ADDITIONAL PERFS d. 8,536'-8,548' MD S' e. 8,620'-8,640' MD £2" f. 9,536'-9,552' MD 14. RU and Re-install velocity string if need dependent on flowrates 15. Release to production. Note: Coil head is not removed 4 Proposed Wellhead/Tree w/Coil Hanger 'CM/� Cook Inlet Energy, L.L.C. GE Oil&Gas NFU 14-25 Proposed 3-1/8"5M ■ 3-1/8'SM 3.1/8'SM is Coil Hanger !IJF ' 2-1/16"5M I 3.1/8"sM s-1/e"sM • 5-1/8 5.000 5-1/810.000 • War 5-1/810.000 I 3-ve SM ID 5723'51%1 i I 1 — -RS'OO[SG 5 Current Condition Version: Curren Aprill7/2015 Velocity Install Permit/I; 210 111 NFU #14-25 APL.L 231-20035-00-00 Prop.Des;ADL-391211/2095 'FSL, 'FEL KB elevation: 679' (21'AGL) S26 T4S R14W S.M. Latitude: 59*47'46.xxxx"N Longitude: 151'37 45.xxxx"W —— — — Spud: Cook Inlet Energy- TD: Rig Released: Structural Pipe-Driven 16" X-56 84 ppf I Top Bottom I MD Surf 153' TVD Surf 153' Chemical Injection Nipple set Surface Gas pg @ 355' MD. Drift4.767" ID 10-31" L-80 45.5ppf Top Bottom P110 6.812"OD MD 0' 2,997 • TVD 0' 2,786' • Intermediate Cas irg-tapered string 8 518"L-80 26 ppf Hydril Top Bottom MD 0' 2,417 TVD 0' 2,317 7 518" 29.76 L-80 BTC-M MD 2412' 5,297' ND 2312' 4,714' 13/4" Coil VeloatyString ID 1.482" Production Casing 5 112' P-110 17 ppf Hydri 513 Top Bottom MD 0' 11,690' TVD 0' 10,992' End of tubing 8520 MD Perforation Intervals: 7822'TVD MD TVD 8,536'-8,548' 7838'-7851' Stinger OD 1.38"ID.87" 8,620'-8,640 7923'-7943' 8,760-8,776' 8063'-8079 9,536'-9,552' 8838'-8854' 5 1/2"x 4" ID Casing Patch From 8757' to 8778' TOP of EZSV @ 11235'MD Added Perforation Intervals MD TVD 11,249'-11,264' 10,551'-10,566' 11,284'-11,294' 10,586'-10,596 • TD 11,700'MD 11,690'MD 11,002'TVD 10,992'TVD 6 Proposed Well Schematic Version: proposed Phase 1 July 30,2015 PROPOSED Permit#: 210 111 NFU #14-25 ` 231-20035-00-00 Prop.Des;ADL-391211/2095 'FSL, 'FEL KB elevation; 679' (21'AGL) S26 T4S R14W S.M. Latitude: 59'47'46_xxxx"N Longitude: 15V 3T 45.xxxx"W Cook Inlet Energy IR Rig Released. — ^. Structural Pipe-Driven 16" X-56 84 ppf I i'1 11,17L l Top Bottom MD Surf 153' \ TVD Surf 153' Chemical Injection Nipple set Surface Cas iv @ 355' MD. Drift-4.767" ID 10-314 L-80 45.5ppf Top Bottom P110 6.812"OD MD 0' 2,992' ' TVD 0' 2,786' kite rmectate Cas kg-tapered sting 8 518-L-80 26 ppf Hydra Top Bottom MD Cr 2,417 TVD 0' 2,317 7 5/8" 29.76 1-80 BTC-M • MD 2412' 5,297' • 13/4"Coil VelodtyString TVD 2312' 4,714 ID 1.482" (,1'11( Production Cas Mg 51? P-110 17 ppf Hydril 513 Top Bottom ' MD 0' 11,890' ' TVD 0' 10,997 End of tubing _ 6,020'MD _ = 5,358'ND Perforation Intervals: MD ND 8,536'-8,548' 7838'-7851' 8,6211-8,640' 7923'-7943' 8,76(7-8,776' 8063'-8079 9,536'-9,552' 8838'-8854' — =' b151/2"x 4" ID Casing Patch From 8757 to 8778' 6020'—6376' MD ADDITIONAL PERFS 6364'—6376' MD ADDITIONAL PERFS '),..r.= TOP of EZSV @ 11235'MD Perforation Intervals 11-I Iii—�� MD ND 11,249'-11,264' 10,551'-10,566' �< 11,284'-11,294' 10,586'-10,596'1 jp l 11,700'MD 11,� 890'MD 11,007 TVD 10,997 TVD 7 COIL BOP Arrangement Annular Shear Z451 Pipe i-cr) G""14— hof E 2-1/16"5M 3-1/8" 5M 5-1/8" 5M IC — •q' 5-1/8 5,000 i 1 5-1/8 10,000 , 111011110. Pi EFF 5-1/8 10.000 13-5/8 5M Hui _ in maw 13-5+8'5M .t '• ' . ' a - L Num ll - QAte, 10'3ra'Oo CSG `,- -1 8-5/8'00 CSG 18 5-1tr OD G- 8 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday,August 04, 2015 1:36 PM To: 'Conrad Perry' Cc: Davies, Stephen F(DOA) Subject: RE: NFU 14-25 perf and pull velocity string. (PTD 315-465) Conrad, I am amending the procedure to require setting a plug in the velocity string XN profile. There are no other barriersv besides KWF) while the coil is cut to re head thru the injector head. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz ai (907-793-1226)or(Guv.schwartz@alaska.gov). From: Conrad Perry [mailto:Conrad.PerrOcookinlet.net] Sent: Monday, August 03, 2015 4:21 PM To: Schwartz, Guy L(DOA) Cc: Davies, Stephen F(DOA) Subject: RE: NFU 14-25 perf and pull velocity string. (PTD 315-465) Guy, I will check with SLB, but I have this listed as my BHA. Not looking forward to setting a check in the XN through coil, but will if we need to. conrad Coil Connector 2.875 0.56 XO 2.875 0.35 2-Slick Sticks 2.25 9.66' X N Nipple 2.20 0.97 Spacer Sub 2.25 0.88 XO 2.75 0.50 Bow Spring Sub 4.687 1.85 XO 2.630 0.61 EZSV Pkr Stinger 1.380 1.31 From:Schwartz,Guy L(DOA) (mailto:guy.schwartz@alaska.gov] Sent: Monday,August 3,2015 3:57 PM To:Conrad Perry<Conrad.Perry@cookinlet.net> 1 Cc:Davies,Stephen F(DOA)<stevt...avies@alaska.gov> Subject: RE: NFU 14-25 perf and pull velocity string. (PTD 315-465) Conrad, You have blind shears on the BOPE but better to have the velocity string sealed though... you will be placing on a spool anyway and not cutting it. I think I read Tyler's email wrong a while back(april 10`h) ... I thought there wasn't a profile in CT velocity string. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793-1226)or(Guv.schwartz@alaska.gov). From: Conrad Perry [mailto:Conrad.Perry©cookinlet.net] Sent: Monday, August 03, 2015 3:14 PM To: Schwartz, Guy L(DOA) Cc: Davies, Stephen F(DOA) Subject: RE: NFU 14-25 perf and pull velocity string. (PTD 315-465) Guy, I slipped the wrong diagram into the sundry. It's exactly like the one in the approved Sundry. We do have a XN profile just above the end of the coil, however, by killing the well,we weren't planning on installing a check in it. Thoughts? conrad 2 . • &ill Mil IW Coil Tubing Services Pressure Category 0 BOP Configuration c4,e-7----7cook illeiENny We, Not-, on(Urrt 14-25 A211 b.2015 (3,501 to 0,500 psi) Drawn, Brencibn Webb .4 1.---'' ' -- •. -- t ----- - : . 7.•.r... , Iiiiket*r Bond&Gooseneck L ' •l .* - 1 .., ,,, c-t; • E_____ 4_05-104 Strqapor ,..---1 FL i ell fr t i i 1 t 1 1 t fr , / tit .411 kker illeK Lubncalor L . , 0 , is I ii 4., ki I 4444 A , e , ii oa-101K Goad BOP .4, ! Mil ihtti fikt?-1 341 77. ,,‘k .46.... .........—. --'t f I! i m maw 1 -______ ____I 1 . kl_.exxxithear Ram pi r-- _ - t - ' • 4-06-10K C4471bF BOP , --' 1-14 _Sk44.40.Ito- 4 Or ntrii x Weghearil CrOSSOvirr Reeve 1 Revision 0 Not Drawn To Scale— For Reference Only --- — From:Schwartz,Guy L(DOA) imailto:guy.schwartz@alaska.gov] Sent: Monday,August 3,2015 2:46 PM To:Conrad Perry<Conrad.Perry@cookinlet.net> 3 .Cc:Davies,Stephen F(DOA)<steve.uavies@alaska.gov> Subject: NFU 14-25 perf and pull velocity string.(PTD 315-465) Conrad, In looking at the procedure how are you pulling the velocity string without have some kind of check valve in the CT velocity string? Also the BOP equipment should be standard CT equipment with Blind/Shear and pipe slip rams. Can you verify BOPE?? Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). 4 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday,August 04, 2015 1:36 PM To: 'Conrad Perry' Cc: Davies, Stephen F (DOA) Subject: RE: NFU 14-25 perf and pull velocity string. (PTD 315-465) Conrad, I am amending the procedure to require setting a plug in the velocity string XN profile. There are no other barriersv besides KWF)while the coil is cut to re head thru the injector head. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793-1226) or(Guy.schwartz©alaska.gov). From: Conrad Perry [mailto:Conrad.Perry(a)cookinlet.net] Sent: Monday, August 03, 2015 4:21 PM To: Schwartz, Guy L(DOA) Cc: Davies, Stephen F(DOA) Subject: RE: NFU 14-25 perf and pull velocity string. (PTD 315-465) Guy, I will check with SLB, but I have this listed as my BHA. Not looking forward to setting a check in the XN through coil, but will if we need to. conrad Coil Connector 2.875 0.56 XO 2.875 0.35 2-Slick Sticks 2.25 9.66' X N Nipple 2.20 0.97 Spacer Sub 2.25 0.88 XO 2.75 0.50 Bow Spring Sub 4.687 1.85 XO 2.630 0.61 EZSV Pkr Stinger 1.380 1.31 From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday,August 3,2015 3:57 PM To:Conrad Perry<Conrad.Perry@cookinlet.net> 1 ' Cc:Davies,Stephen F(DOA)<steve.davies@alaska.gov> Subject: RE: NFU 14-25 perf and pull velocity string. (PTD 315-465) Conrad, You have blind shears on the BOPE but better to have the velocity string sealed though...you will be placing on a spool anyway and not cutting it. I think I read Tyler's email wrong a while back (april 10th) ... I thought there wasn't a profile in CT velocity string. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Conrad Perry [mailto:Conrad.Perry@cookinlet.net] Sent: Monday, August 03, 2015 3:14 PM To: Schwartz, Guy L(DOA) Cc: Davies, Stephen F(DOA) Subject: RE: NFU 14-25 perf and pull velocity string. (PTD 315-465) Guy, I slipped the wrong diagram into the sundry. It's exactly like the one in the approved Sundry. We do have a XN profile just above the end of the coil, however, by killing the well,we weren't planning on installing a check in it. Thoughts? conrad 2 Coil Tubing Services �,, „ CoakinielEnerBY UMWPressure Category 11 BOP Con guration `� North Fork Unit 14-25 Date (3501 to 8,SQ0 i Drawn April 6,2015 P3 Drawby 8rendOn Webb Y ! 4. f c. --k ...7-1'.....e& .1' -41----, Injector Howl&G009lAPCk 4 4.06"10k Stapp' or to al Ce$ t 3 a.c I "a .41 4.114-10K Lubricator f `n C, C r 1..- Rtlf PM j' - �T_4 4.05'10K Quad BOP 4 C bW0°hear Nin ,:..... Ili _ - , 4 4.06'1 OK carob,HOP L `'i 4 06-'pr x Wellhead CfLKfOruN Flange i i C i Revision 0 Not Drawn To Scale— For Reference Only From:Schwartz,Guy L(DOA) [ma ilto:guy.schwartz@alaska.gov] Sent: Monday, August 3,2015 2:46 PM To:Conrad Perry<Conrad.Perry@cookinlet.net> 3 Cc:Davies,Stephen F(DOA)<steve.davies@alaska.gov> Subject: NFU 14-25 perf and pull velocity string.(PTD 315-465) Conrad, In looking at the procedure how are you pulling the velocity string without have some kind of check valve in the CT velocity string? Also the BOP equipment should be standard CT equipment with Blind/Shear and pipe slip rams. Can you verify BOPE?? Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226)or(Guy.schwariz@alaska.gov). 4 OF T�� w\��\�7j,�s� THE STATE Alaska Oil and Gas F -s� �, of Conservation Commission -._ ____. . ALASIc:A t#= 333 West Seventh Avenue Anchorage,e, Alaska 99501-3572 :1� ti '� GOVERNOR BILL WALKER 9 Op Main 907 279 1433 ALAS Fax. 907.276 7542 www.aogcc.alaska.gov Conrad Perry `�� Drilling Manager Cook Inlet Energy, LLC d) 0 -'1 601 W. 5th Ave., Suite 310 Anchorage, AK 99501 Re: North Fork Field, Undefined Gas Pool,NFU#14-25 Sundry Number: 315-209 Dear Mr. Perry: 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, j‘)/ Daniel T. Seamount, Jr. /i Commissioner DATED this //day of April, 2015 Encl. RECEIVED STATE OF ALASKA• APR 0 S 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well LI Change Approved Program ❑ Suspend❑ Plug Perforations❑ ge _Perforate Q• Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: Remove-VS`Liz-1 o) "j 02.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: f Cook Inlet Energy,LLC Exploratory ❑ Development Q . 210-111 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 50-231-20035-0000 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?" LZ'4/-/(1 L - ''-• S North Fork Unit#14-25 • Will planned perforations require a spacing exception? f,yku 4,;"r 'es CI1�V No 9.Property Designation(Lease Number): 10.Field/Pool(s): / ii ADL 391211/2095 • North Fork L� e-I/al.�-� �-� C �',!:-, r /.< (6 '' 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): 11,700' • . 11,00211,566' 10,177' none none Casing Length Size MD TVD Burst Collapse Structural Conductor 178' 16" 178' 178' N/A N/A Surface 2,992' 10 3/4" 2,992' 2,786' 5210 2480 Intermediate 5,297' 8 5/8"/7 5/8" 5,297' 4,714' 5,714'6,890 2,520/4,790 Production 11,700' 51/2" 11,700' 10,311' 10,640 7,480 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8,536'to 11,294'(attached) 7,838'to 10,596'(attached) 5 1/2" 17#Hydril 513 P-110 11690' Packers and SSSV Type: N/A Packers and SSSV MD(ft)and TVD(ft): N/A EZSV @ 11235'MD 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: • Detailed Operations Program ❑., BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑., Service ❑ 14.Estimated Date for 15-Apr-15 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑✓ • WDSPL ❑ Suspended 0 16.Verbal Approval: Date. WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tyler Wagner Email Tyler.Wagner(a�cookinlet.net Printed Name Conrad Pe • 907-727-7404 Title Drilling Manager-4-08-2015 Signature . ill • one Date i, / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: SIS - 2_09_ 2oc1 Plug Integrity 0 BOP Test Lit Mechanical Integrity Test ❑ Location Clearance ❑ Other: if LIS D;' r$- S O f t"5 f --c---r Q,1,43p = Zs-e.) `i c.J Spacing Exception Required? Yes ❑ No II Subsequent Form Required: / —(—DUH APPROVED BY 4/141 '� Approved by: (74- COMMISSIONER THE COMMISSION Date: � 4 4-1Y-AT Submit Form and Form 10-403(Revised 10/2012) p r vRa p^c t s li for 12 months r m the date of approval. Attachments in Duplicate _ BDMSJ APR 1 8 2045e.91* -7°' v 'S Cook Inlet Energy_ RECEIVED APR 0 8 2015 AOGCC April 8, 2015 Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Cook Inlet Energy, LLC: North Fork Unit#14-25 (PTD 210-11) Dear Ms. Foerster, Cook Inlet Energy(CIE)hereby submits a completed Form 10-403 and Application for Sundry Approval for the NFU 14-25 work-over to pull the current velocity string and re-perforate the well. We plan on unloading the water in stages using coil tubing and nitrogen. The velocity string could be reinstalled if needed. If you have any questions, please contact me at(907) 727-7404. Sincerely, (r, --)/// 4/9 Conr.• Perry Drilling Manager Cook Inlet Energy 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax Perforations MD TVD 8536'-8548' 7838'-7851' 8620'-8640' 7923'-7943' 8760'-8776' 8063'-8079' 9536'-9552' 8838'-8854' 11249'-11264' 10551'-10566' 11284'-11294' 10586'-10596' NFU 14-25 -Well Summary Current Status: NFU 14-25 is currently on production with a velocity string Scope of Work: • Recover velocity string • Perforate/re-perforate zones General Well Information: MASP: 2500 psi Reservoir Pressure/TVD: 322si @ 12,475' MD / 9,438' TVD Wellhead Type/Pressure Rating: Vetco Grey 13-5/8"-5M BOP Configuration: Blinds in lower, coil rams in upper Well Type: Producer Estimated Start Date: April 15, 2015 Drilling Manager: Conrad Perry (907) 727-7404 Conrad.Perry@CookInlet.net Drilling Engineer: Tyler Wagner (907) 433-3831 Tyler.Wagner@CookInlet.net Production Manager: David Kumar (907) 433-3822 David.Kumar@CookInlet.net 2 • NFU 14-25 Work Over Program Stage 1 1. RU coil BOPE on top of 3-1/8" 5M flange 2. RU coiled tubing unit and flow back iron �� t. 3. Test Coil tubing BOPE to MI6-psi Lis�`�c el: 6` c.?./s-- 4. Kill Well with 8.6 ppg KCL 5. Recover 1-3/4"coil velocity string 6. RD coiled tubing unit 7. Change Velocity string spool to Coil tubing spool 8. Rig up coil/N2 9. RIH in stages lifting well clean of water to diffuser tank a. Repeat as needed to TD 10. R/D coil,get Schlumberger off location 11. Test Well 12. If well does not produce at commercial rates,then re-perforate with 2 7/8" guns % a. Pressure up WHP to 1000 psi underbalance if possible b. 8,536'-8,548' MD c. 8,620'-8,640' MD d. 9,536'-9,552' MD 13. RU and Re-install velocity string if need dependent on flowrates 14. Release to production. 3 Current Condition Version: Curren 1 Velocity Install Peit#: 210111 ApriIR/2015 rm NFU #14-25 A2L ; 231-20035-00-00 Prop.Des;ADL-391211/2095 'FSL, 'FEL KB elevation: 679' (21'AGL) S26 T4S R14W S.M. Latitude: 59"47'46.xxxx"N Longitude: 151'37'45.xxxx"W _ Cook Inlet Energy_ Rig Released: Structural Pipe-Driven 16' X-56 84 ppf l Top Bottom MD Surf 153' TVD Surf 153' Chemical Injection Nipple set Surface Gas ilp 355' MD. Drift4.767" ID 10-3/4" L-80 45.5ppf Top Bottom P110 6.812"OD MD 0' 2,997 TVD 0' 2,786' Ml4k I 111, ®111 Ince rmediate Cas ig-tapered siring 8 5/8'L-80 26 ppf Hydril Top Bottom S. MD 0' 2,417 TVD 0' 2,317 7 518" 297#1-80 BTC-M 4k, MD 2412' 5,297' [,y TVD 2312' 4,714' 13/4"Coil Velocity String ID 1.482" Prod uction Cas inq y'• 5 1/2' P-110 17 ppf Hydra 513 a ♦ ' Top Bottom f MD 0' 11,690' TVD 0' 10,992' "p End of tubing • • 8520'MD Perforation Intervals: �✓ 7822'ND MD ND _ 8,536'-8,548' 7838'-7851' =, Stinger OD 1.38"ID.87" 8,620'-8,640' 7923'-7943' 8,760-8,776' 8063'-8079 9,536'-9,552' 8838'-8854' 5 1/2"x 4" ID Casing Patch From 8757' to 8778' • TOP of EZSV @ 11235'MD Added Perforation Intervals Erb- MD ND 11,249'-11,264' 10,551'-10,566' 11,284'-11,294' 10,586'-10,596' TD PBro 11,700'MD 11,690'MD 11,007 TVD 10.692'TVD 4 Proposed Well Schematic Version: Curren Velocity Install I m 210111 April/7/2015 it8: NFU #14-25 MI is 231-20035-00-00 IPmp.Des ADL-391211/2095 FSL, 'FEL 109 elevation' 679' (21'AGL) S26 T4S R14W S.M. Lain; 59*4T 46.xxxx"N Longitude: 151*3T 45.xxxx"W Sinst Cook Inlet Energy_ Rig Released- Structural Pioe-Driven — 16- X-56 84 ppf I I L Top Bottom MD Surf 153 TVD Surf 153' Chemical Injection Nipple set SwtaceCasino X355'MD. Drift-4.767" ID 10-314' L-80 45.5ppf Top Bottom P110 6.812"OD MD 0' 2,992' _. TVD 0' 2,786' .41144401 Intermeate Casing-tapered string ' ® di8518"L-80 26ppf Hydra Top Bottom ti• 1, MD Q 2417 • TVD 0' 2,312' 7518"29.7*L-80 BFC-M MD 2417 5,29T TVD 2312' 4,714' • 1 3/4"Coil Velodty String ID L482" Production Casing 512' P-110 17 ppf Hydril 513 ti Top Bottom .14 MD 0' 11,690' • a?' TVD 0' 10,997 4. r: End of tubing 8520'MD Perforation Intervals: 7822'TVD MD 7VD 8,536'-8,548' 7838'-7851' Stinger OD 1.38"ID.87" 8,620._8,640' 792r-7943' 8,767-8,776' 8063'-8079 9,536'-9,552' 8838'-88.54' cI ` 5 1/2"x 4"ID Casing Patch From 8757'to 8778' TOP of EZSV @ 11235'MD Added Perforation Intervals MD 1VD — 11,249'-11,264' 10,551'-10,566' 11,284'-11,294' 10,586'-10.596' • ID PD 11,700'MD 11,690'MD 11,002 TVD 10,997 TVD 5 1,0----;\ Cook Inlet Energy, L.L.C. t) GE Oil &Gas NFU 14-25 Proposed Effeffinn 3-1/8"5M PA4 11 z, 3-1/8"5M stassen• IF • 3-1/8"SIN % • • • ••• TN wi 11 !! - ' 2-1/16"5M "' 3-1/8"5M 5-1/8"5M ./! ( ) ..: - 5-1/8 5.000 5-1/8 10.000 p p) 5-1/8 10,000 II 13-5/8 SM i■ iia, Ertl Aii,--frAl i 4sli " J S 13-5,8-SMm i '" ' psi r1 •1• ■'. ItAn al .t ,-8,05.,_3,..4-0000::: 5',2'OD MG — COIL TUBING Coiled Tubing Services Client: Cook Inlet Energy ell NFU 14-25 SERVICES Pressure Category 1 BOP Configuration Well: Date: April 10, 2015 (0 t0 3,500 psi) Drawn b Brendon Webb A Schlumberger Company y rl Er CAMII I \ I� �- I` r Y 11 !ale U - 4 Injector Head&Gooseneck t 411441 4.06"10K Conventaional Stripper rn I,r.41 x &..LL rn N c C062 Riser ar c a F- a 0 U u � v � L r y d � a> u r; CLL 0 4 C062 x 4-1116"10K Flange •u' Blind/Shear Ram ,ln��<;� 4 4.06"10K Quad BOP Kill Port ;� °I i D84 Fluid Returns to Surface Handling System Flanged Full Bore us • Full Bore Plug UII, '.PlI Ram. U plug Val ve (Manual) 4.06"10K Flanged Flow Tee 7 V (Manual) (Valve#1 =2.06"15K Manual Full Bore Plug Valve) (Valve#2=2.06"Flanged 15K Manual Full Bore Plug Valve) 0 0 I , O O (Valve#3=2.06"Flanged 15K Manual Full Bore Plug Valve) 01004 (Valve#4= 2.06"15K Manual Full Bore Plug Valve) lS r' I l I 4.06"10K x Wellhead Adapter Flange 4.4 Wellhead Needa Revision 0 Not Drawn To Scale--- For Reference Only Schwartz, Guy L (DOA) From: Tyler Wagner <Tyler.Wagner@cookinlet.net> Sent Friday,April 10,2015 12:45 PM To: Schwartz, Guy L(DOA) Subject: RE: NFU 14-25 (PTD 210-111) -CT Velocity string Attachments: NFU 14-25 drawing asbuilt 072214.pdf;CIE NFU 14-25 Revised CT BOP Stack Drawing 4-10-15.pdf Guy, I have attached a new coil tubing bop stack configuration for the sundry for 14-25. I also attached a wellhead diagram. The plan for killing would be to pump down the velocity string and there is a no profile to put a plug in. From:Schwartz,Guy L(DOA) Finailto:guy.schwartz@alaska.gov] Sent: Friday,April 10,2015 9:32 AM To:Tyler Wagner Subject: RE: NFU 14-25 (PTD 210-111)-CT Velocity string Also,when you kill well will you pump down the velocity string?? Does it have a profile to set plug in at bottom? Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Schwartz, Guy L(DOA) Sent: Friday,April 10, 2015 9:30 AM To:Tyler Wagner Subject: NFU 14-25 (PTD 210-111) - CT Velocity string Tyler, Do you have a sketch of the wellhead showing the velocity string hanger etc. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226)or(Guv.schwartz@alaska.gov). 1 • STATE OF ALASKA ALA. .OIL AND GAS CONSERVATION COMM,,.,ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well H Plug Perforations H Perforate U Other U Coil DSTNelocity Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator Cook Inlet Energy,LLC 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development ❑✓ Exploratory ❑ 210-111 3.Address: 601 W.5th Avenue,Suite 310,Anchorage,AK Stratigraphic❑ Service ❑ 6.API Number: 99501 50-231-20035-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 391211/2095 North Fork Unit#14-25 RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): North Fork JAN 0 7 2015 11.Present Well Condition Summary: AOGCC CC Total Depth measured 11700 feet Plugs measured N/A feet true vertical 11002 feet Junk measured N/A feet Effective Depth measured 11690 feet Packer measured N/A feet true vertical 10992 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 178' 16" 178' 178" N/A N/A Surface 2992' 10 3/4" 2992' 2786' 5210 2480 Intermediate 5297' 8 5/8"/7 5/8" 5297' 4714' 5714/6890 2520/4790 Production 11700' 51/2" 11700' 10311' 10640 7480 Liner Perforation depth Measured depth 8536'to 9552' feet 4 True Vertical depth 7838'to 8854' feet SC 144" Tubing(size,grade,measured and true vertical depth) 1 3/4" 17# 8520' 7822' Packers and SSSV(type,measured and true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A 170 0 1 209 Subsequent to operation: N/A 203 0 251 251 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory III Development Service ❑, Stratigraphic ❑ Daily Report of Well Operations 16.Well Status after work: Oil ❑ Gas Q WDSPL❑ 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: 314-333 Contact Tyler Wagner Email Tyler.wagner@cookinlet.net Printed Name Conrad erry Title DRLG Manager Signature / .--Z1./..-- phone 907-727-7404 Date 1/7/2015 Form 10-404 Revise 2 2 /'e-7"/,5 Submit Original Only 24' /fie©> • • Cook Inlet Energy_ RECEIVED JAN 072015 January 07, 2015 AOGC�o Ms. Cathy Foerster, Chair �o Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Report of Sundry Cook Inlet Energy, LLC: North Fork Unit# 14-25 Permit to drill NO: 210-111 API No: 50-231-20035-00-00 Dear Ms. Foerster, Cook Inlet Energy(CIE)hereby submits a Sundry Completion for installing a 1 3/4"velocity string in this well of North Fork Unit# 14-25 well located on CIE lease#391211/2095. Attached is the current wellbore schematic. Schlumberger CTU was used to complete this work, commencing on June 18, 2014. If you have any questions, please contact me at(907) 727-7404. Sincerely, op Conra. P e•' Drilling Manager Cook Inlet Energy 10-403 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax • • b. PROPOSED Velocity Install Permit#: 210111 NFU #14-25 API#: 231-20035-00-00 Prop. Des:ADL-391211/2095 Cook Inlet Energy_ ' FSL, ' FEL KB elevation: 679' (21'AGL) S26 T4S R14W S.M. Latitude: 59`47'46.xxxx"N Longitude: 151*37'45.xxxx"W Spud: s TD: Riq Released: Structural Pine-Driven I I 16" X-56 84 ppf Top Bottom MD Surf 153' TVD Surf 153' Chemical Injection Ni�Dple set @ Surface Casing • 355'MD. Drift 4.767" ID P110 10-3/4" L-80 45.5ppf Top Bottom 1111: 6.812"OD MD 0' 2,992' TVD 0' 2,786' �� Intermediate Casing-tapered string 8 5/8" L-80 26 ppf Hydril Top Bottom MD 0' 2,412' TVD 0' 2,312' 7 5/8" 29.7# L-80 BTC-M MD 2412' 5,297' TVD 2312' 4,714' 1 3/4"Coil Velocity String ID 1.482" Production Casing 5 1/2" P-110 17 ppf Hydril 513 Top Bottom MD 0' 11,690' . a TVD 0' 10,992' End of tubing • 8520'MD Perforation Intervals: 7822'TVD 8,536'-8,548' 8,620'-8,640' ._ -_.. Stinger OD 1.38" ID.87" 8,760'-8,776' _ - 9,536'-9,552' s y .;". 5 1/2"x 4" ID Casing Patch �r From 8757'to 8778' TD PBTD 11,700'MD 11,690'MD 11,002'TVD 10,992'TVD Well Name&Number: North Fork Unit#14-25 Lease: Kenai Loop County or Parish: Kenai Penisula Borough State: Alaska Country: USA Perforations(MD): Peri(TVD): Angle @KOP and Depth: Angle @ Perfs: KOP TVD: Date Completed: RKB: 21' Prepared By: Conrad Perry Last Revision Date: April 29,2014 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. 071 0 - J I I Well History File Identifier Organizing(done) ❑ Two-sided III II III ❑ Rescan Needed III 111111 IIIIIII RE/SCAN DIGITAL DATA OVERSIZED (Scannable) C for Items: ❑ Diskettes, No. ❑ Maps: Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: cg, 7 'y /s/ IfY P Project Proofing 1111111 II III BY: Maria Date: a, /s/ u 1 Scanning Preparation (.0 x 30 = I q`0 + a S = TOTAL PAGES © S (Count does not include cover sheet) 1 BY: Maria Date: a /s/ u Production Scanning I Stage 1 Page Count from Scanned File: cO W (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: AO. Date: DI 7/iLf /s/ nip Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. iii II11111111111 III ReScanned II 11111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked iii IIIII 1111111 III . �evl',A1%%% 0� I iE AI' P. 1 , 0:,,t-7.--::77:"±:::_ft-:::de. __ — ----- 33 We + S venfh F enue A ,-,OVERNOR S .A \R LI.i. A choroce Ackc, yr�U 3572 u 1/0 1,, vu i.2;9 433 CANNED JUN I 12011 Conrad Perry Drilling Manager11 �} °.- Cook Inlet Energy, LLC p� 601 W 5th Ave., Suite 310 Anchorage, AK 99501 Re: North Fork Field, Undefined Oil Pool, North Fork Unit#14-25 Sundry Number: 314-333 Dear Mr. Perry: 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, ... ia4,e_ L_ Cathy P. r oerster Chair DATED this 3O day of May, 2014. Encl. � r� � RECEIVED OF ALASKA � ` MAY 2 7 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑✓ • Repair Well❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing Q Other. Coil DST/Velocit Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Cook Inlet Energy,LLC Exploratory ❑ Development Q 210-111 . 3.Address: Stratigraphic ❑ Service ❑ 6.API Number 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 50-231-20035-0000 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? North Fork Unit#14-25 • Will planned perforations require a spacing exception? Yes ❑ No Q 9.Property Designation(Lease Number): - 10.Field/Pool(s): ADL 391211/2095 North Fork 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): 11,700' .. 341 // 11,566' •,90r T7./U a-5'-))/ 8,720' none Casing Length 1..; Size MD27 ie.y7 VD Burst Collapse Structural i 1-1 Conductor 178'J 16" 178' 178' N/A N/A Surface 2,992' 10 3/4" 2,992' 2,786' 5210 2480 Intermediate 5,297' 8 5/8"/7 5/8" 5,297' 4,714' 5,714'6,890 2,520/4,790 Production 11,700' 51/2" 11,700' 10,311' 10,640 7,480 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8,536'to 9,552'(attached) 7,838'to 8,854'(attached) N/A Packers and SSSV Type: N/A Packers and SSSV MD(ft)and TVD(ft): N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program U BOP Sketch U —Exploratory U Stratigraphic Li Development U Service U 14.Estimated Date for 1-Jun-14)5.Well Status after proposed work: Commencing Operations: - "Oil ❑ Gas Q • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stephen Ratcliff Email stephen.ratcliff@cookinlet.net Printed Name Conrad Perry 907-727-7404 Title DrIg Manager-4-29-2014 Signature / Phone Date (-- COMMISSION USE ONLY Conditions of approval: Notify Commission so tha epresentative may witness Sundry Number: \i-t_ • Plug Integrity ❑ BOP Test 6 Mechanical Integrity Test ❑ Location Clearance ❑ Other: 6 0 P 1-z'S f• i--o 21-5-O 0 p S t Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: JO -4 c 4 APPROVED BY Approved by: ,204.44,......._ CLVCOMMISSIONER THE COMMISSION Date: ,s - 3,9 /V nn nh Submit Form and Form 10-403(Revised 10/2012) App vc p catvi� r iA r 2 months from the date of approval. Attachments in Duplicate Vl d= 5/2'q if I 1 RBDMS MAY 3 0 211 ,,e-,57, -- s- .i( Cook Inlet Energy RECEIVED MAY 2 7 2014 AOGCC May 27, 2014 Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 Re: Application for Sundry 210 1 1 Cook Inlet Energy, LLC: North Fork Unit#14-25 (PTD 2 100 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a completed Form 10-403 and Application for Sundry Approval for the perforation and short flow test of the Hemlock zone with a 1 3/4" coil completion in this well from approximately 11,242'to 11,268'. The Hemlock will be isolated with a cement retainer at the conclusion of the test. CIE then requests to install a 1 3/4" velocity string in order to effectively keep water off of the Tyonek Gas perforations. This Sundry application replaces the two previous applications for NFU#14-25 dated April 29th and May 12th If you have any questions, please contact me at(907) 727-7404. Sincerely, ‘'ij Conrad Drilling Manager Cook Inlet Energy 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax • NFU 14-25 —Well Summary Current Status: NFU 14-25 is currently on gas production Scope of Work: • Remove Retrievable Bridge Plug from 8720'. • Set Halliburton TCP Drill Guns at approximately 11,242'to 11,268' • Set Pollard 5'/z"casing patch across perforations from 8,760'to 8,776' • Install Vetco Gray Coil Head • RIH with SLB 1'/<"coil,stab into Drill Gun packer,and hang off in Coil head • Pressure up with N2 and fire TCP guns • Attempt to flow well through coil tubing for an estimated 12-24 hours,depending on results,may be extended if further cleanup is needed to obtain sufficient test. • Pull coil/closing packer valve • RIH with 1'/a"velocity string,hang off in Coil hanger. • Nipple down coil General Well Information: MASP: 4267 psi Reservoir Pressure/TVD: Hemlock 4742 psi estimated based on a .45 psi/ft gradient in 10,537'TVD Tyonek Gas 3,493 psi @ 12,475' MD/9,438' TVD—February 2007 This zone has been partially depleted. Wellhead Type/Pressure Rating: Vetco Grey 13-5/8"—5M BOP Configuration: Blinds in lower, coil rams in upper, plus annular TIFL/MIT-IA/MIT-OA: TIFL — N/A MIT-IA — drilled 2010 MIT-OA — drilled 2010 Well Type: Producer Estimated Start Date: June 1, 2014 Production Engineer: Shawn Dillon (907) 342-7386 Shawn.Di llon@CookInlet.net Drilling Engineer: Stephen Ratcliff (907)433-9738 Stephen.Ratcliff@CookInlet.net Drilling Manager: Conrad Perry (907) 727-7404 Conrad.Perry@CookInlet.net 3 • NFU 14-25 Coil Hemlock Test Procedures 5-22-14 • WireLine Work 1. Rig up E-Line. 2. Test Lubricator to 2500 psi. 3. Lock and Tag out SSV. 4. Make gauge ring run to top of bridge plug. Note fluid level. 5. Recover retrievable bridge plug from 8,720'. 6. Make gauge ring run to 11,300' 7. PU Halliburton Drill Gun(EZSV)with TCP perforations approximately 11,242'to 11,268' (10,537' to 10,553' TVD) 8. RIH, correlate and set EZSV. 9. Set Pollard casing patch across perforations from 8760' to 8776'. Confirm location with GR. 10. Rig Down E-Line. Put well back to production. • WellHead Work 11. Lock and Tag out SSV. 12. Close lower master. Check for flow. 13. Close upper master. 14. Nipple down T and swab valves. 15. Install and Test 3 '/2"VetcoGray Coil hanger assembly with crossovers to 5"5M upper master. 16.Nipple up 3 '/2" flow cross and swab valve. Test to 5000 psi • Coil Work 4-��°hs' 1. Nipple up and test Coil and BOPs (double gate and annular)t7.„,3,560 psi 572 /ll- 2. Lock out SSV. Open up well. C- 3. 3. Pick up EZSV stinger on Coil BHA. YL I 4. Strip in hole to 11,242'. Stab into EZSV. Set down 2000#. 5. Pull out, install coil hanger and re-sting into EZSV. Test Coil to 1500 psi to confirm engagement 6. Release from coil string. 7. Nipple down Coil 8. Rig up surface lines and test equipment. 9. Pressure up on coil with N2 to XXXX psi. Hold for 5 minutes then bleed back to 2500 psi. 10. Guns should fire with 18 minute delay. 11. After firing, open well for approximately 12-24 hours flow period. Swab well if necessary. 12.Nipple up and test Coil BOPs (double gate and annular)to 2500 psi 13. Engage coil hanger. 14. Pull out of EZSV closing sleeve and shutting in Hemlock. 15. Pull out of hole with coil. Pull Coil BHA above upper master. Close upper master 16. Bleed off coil taking any returns back to test skid. 17. Run 1 3/4" coil to top perforation at 8,536' and hang off in VetcoGray Coil Assembly. 18. Test Hanger to 5000 psi. 19.Nipple down coil 20. Fit flow line to new height. Test Flowline welds. 21. Release well to production 4 • • Wellhead Cook Inlet Energy,L.L.C. 1. GE Oil&Gas NFU 14-25 Proposed ._. T 3-1/8"5M *11.1. I- 1\r1 3-1/8"5M rJr 3-1/8"5M `1 10,501 .1111111111111 y 1.1 11 '7 F 2-1/16"5M Ilia 3-1/8"SM 5-1/8"SM Uen/ 5-1/8 5.000 NOMMIIN 5-1/8 10.000 T 5-1/8 10.000 L. --- 13.5/8 5M w 11111-1 ' r um 140,41 1111 )11 - 135/8'SM _ � u, i■ r . s . 1 ,o�r0o Esc 5.vTUG iii LI-V00CSG 5 • Current Condition Permit#: 210 111 NFU #14-25 API#: 231-20035-00-00 Cook Inlet Energy Prop.Des:ADL-391211/2095 ' FSL, 'FEL KB elevation: 679' (21'AGL) S26 T4S R14W S.M. Latitude: 59*47'46.xxxx"N Longitude: 151*37'45.xxxx"W Spud: . --,----t TD: ` '. Rig Released: Structural Pipe-Driven • l 16" X-56 84 ppf F Top Bottom MD Surf 153' TVD Surf 153' Chemical Injection Nipple set @ Surface Casing 355'MD. Drift-4.767"ID P110 10-3/4" L-80 45.5ppf Top Bottom 6.812"OD MD 0' 2,992' TVD 0' 2,786' •. Iht Intermediate Casing-tapered string ;, 8 5/8" L-80 26 ppf Hydril Top Bottom -�: MD 0' 2,412' -' "�'� TVD 0' x,xxx' ' ' ';; 7 5/8" 29.7# L-80 BTC-M `•�'� +, . , MD 2412' 5,297' ri f „y TVD XXXX' 4,714' k•`;-' ''''' Production Casing 1,-,..' 17:' 5 1/2" P-110 17 ppf Hydril 513 .. , ;`y: Top Bottom 7� V MD 0' 11,690' r,.:+ .M.! TVD 0' 10,992' ./.1 ?' Perforation Intervals: r. =; 8,536'-8,548' �- - 8,620'-8,640' _ 8,760'-8,776' 9,536'-9,552' a _ Baker 5 1/2"Wireline Retreivable Bridge Plug set at 8720'MD 8-3-2013 l -4— T t I12 PBTD 11,700'MD 11,690'MD 11,00r TVD 10,992'TVD Well Name&Number: North Fork Unit#14.25 Lease: Kenai Loop County or Parish: Kenai Penisula Borough State: Alaska I Country:) USA Perforations(MD): Pert(TVD):_ Angle @KOP and Depth: Angle @ Peru KOP T✓G Date Completed. RKB: 21' Prepared By'. Craig Rang Last Revision Date: August 13,2013 6 Proposed Hemlock Test Schematic Hemlock Test Permit#: 210111 API231-392515 Cook Inlet Energy_ Prop..Des:ADL-391211/2095 NFU #14-25 KB elevation: 679' (21'AGL) FSL, 'FEL Latitude: 59*47'46.xxxx"N Longitude: 151`37'45.xxxx"W S26 T4S R14W S.M. Spud: LTD: Rig Released: Structural Pipe-Driven 16" X-56 84 ppf i Top Bottom MD Surf 153' I,. ',' TVD Surf 153' . Chemical Injection Nipple set @ Surface Casing 355'MD. Drift-4.767"ID P110 10-3/a' L-80 45.5ppf • Top Bottom _ 6.812"OD MD 0' 2,992' TVD 0' 2,786' IL F.0 Intermediate Casing-tapered string Fb'i►t � � 8 5/8" L-80 26 ppf Hydril '� Top Bottom ye; MD 0' 2,412' TVD 0' x,xxx' 7 5/8" 29.7# L-80 BTC-M .S MD 2412' 5,297' w„ 1 3/4"Coil String TVD XXXX' 4,714' Ate. �•t�� Production Casing 0_„„.7. 5 1/2" P-110 17 ppf Hydril 513 ,44. Top Bottom lt; MD 0' 11,690' TVD 0' 10,992' 1.1y • dS!: �x Perforation Intervals: 8,536'-8,548' 8,620'-8,640' 8,760'-8,776' ,,e 9,536'-9,552' 1..- T ,,_..F 1 ,..." s Ilk. tLL, k Hallibuirton 5 1/2"drill gun Hemlock Perforations11,242'to 11,268' I PBTD 11,700'MD 11,690'MD 11,002'nip , 10,992'TVD Well Name&Number North Fork Unit#14-25 Lease: Kenai Loop County or Parish: Kenai Penisula Borough State: Alaska I Country.I USA Perforations(MD): Pert(TVD): Angle @KOP and Depth Angle @ Perfs KOP TVD. Date Completed: RKB: 21' Prepared By. Conrad Perry Last Revision Date. April 29,2014 7 • G PROPOSED Velocity Install Permit#: 210111 NFU #14-25 API#: 231-20035-00-00 Cook Inlet Energy Prop.Des:ADL-391211/2095 ' FSL, ' FEL KB elevation: 679' (21'AGL) S26 T4S R14W S.M. Latitude: 59*47'46.xxxx"N Longitude: 151*37'45.xxxx"W Spud: TD: . S* Rig Released: tiStructural Pipe-Driven ' 16" X-56 84 ppf F Top Bottom y MD Surf 153' .2:-.....„.„,,,,,,..,......,..„,....,... TVD Surf 153' Chemical Injection Nipple set @ Surface Casing 355'MD. Drift-4.767"ID P110 10-3/4" L-80 45.5ppf Top Bottom 6.812"OD MD 0' 2,992' - TVD 0' 2,786' 61;1 Intermediate Casing-tapered string p 8 5/8" L-80 26 ppf Hydril Top Bottom t.,, t, MD 0' 2,412' 0' x,xxx' 4 ND 7 518" 29.7# L-80 BTC-M , ►',• MD 2412' 5,297' f"" re?.; ND XXXX' 4,714' 1 3/4"Coil Velocity String 't _� Production Casing -' V7'•• 5 1/2" P-110 17 ppf Hydril 513 {,:,�y N';‘', Top Bottom '�- MD 0' 11,690' 4 ND 0' 10,992' y, Perforation Intervals: r,i 8,536'-8,548' • _ 8,620'-8,640' 8,760'-8,776' ...e- ! -i 9,536'-9,552' 5 1/2"x 4"ID Casing Patch From 8757'to 8778' s� IQPBTD 11,700'MD 11,690'MD 11,002'ND l 10,997 TVD Well Name&Number: North Fork Unit#14-25 Lease: Kenai Loop County or Parish: Kenai Penisula Borough State: Alaska I Country:I USA Perforations(MD): Perf(TVD): Angle©KOP and Depth. Angle @ Perfs. KOP TVD: Date Completed: RKB: 21' Prepared By: Conrad Perry Last Revision Date: April 29,2014 8 COIL BOP Arrangement 1 ) Annul „-----N, 1--,. p 0 01 rounamisi Shear IrAwl Pipe . 1.1 1,,.i.+1 5-1/8"5M ,0*40\1 111.4 5-1/8 5.000 5-1/8 10.000 ('4) 5-1/8 10.000 II 13-518 5M lir _ •U S1 _. .G - , r : , , 5 1 w_ 13-5'8'5M 1' '1. in - gennommo9 Ferguson, Victoria L (DOA) From: Conrad Perry <Conrad.Perry@cookinlet.net> Sent: Thursday, May 29, 2014 1:14 PM To: Ferguson,Victoria L(DOA) Cc: Schwartz,Guy L(DOA); Stephen Ratcliff;Courtney Rust Subject: NRFU-14-25 Sundry Application Cook Inlet Energy Victoria, CIE requests the AOGCC to cancel or rescind approved Sundry 314-279 for the installation of a velocity string. We also wish to recall our Sundry application dated May 12th for NFU 14-25 to test the Hemlock. These have both been replaced by the Sundry Application Dated 5/27/2014 that you are currently reviewing. As discussed,we agree that the BOP test in Coil Work step#1 should be 4,500 psi (not 3,500 psi). Conrad Drilling Manager Cook Inlet Energy, LLC 601 W. 5th Avenue STE 310 Anchorage, AK 99501 (907)433-3816—Office (907) 727-7404-Cell (907) 344-0584- Home (907) 260-5356-Cabin conrad.perry@cookinlet.net CONFIDENTIALITY NOTICE:This e-mail transmission and any document,files or previous e-mail messages attached to it,are confidential.If you are not the intended recipient, or a person responsible for delivering it to the intended recipient,you are hereby notified that any review,disclosure, copying,dissemination,distribution or use of any of the information contained in, or attached to this e-mail transmission is STRICTLY PROHIBITED. If you have received this transmission in error, please notify us immediately by forwarding this message to the original sender or by telephone at 907.433.3816 and then delete this message and its attachments from your computer. 1 Davies, Stephen F (DOA) From: Stephen Ratcliff <stephen.ratcliff@cookinlet.net> Sent: Wednesday, May 28, 2014 10:18 AM To: Davies, Stephen F (DOA) Cc: Conrad Perry; Stephen Ratcliff;Tim Jones Subject: NFU 14-25 (PTD 210-111): Proposed Hemlock Perforations/Testing Stephen, Please see comments below from our land department. Let me know if you have any further questions. Regards, Stephen Ratcliff Stephen, The proposed perforation,testing and possible production of the Hemlock oil zone within the NFU 14-25 will conform with the regulatory spacing requirements found in 20 AAC 25.055(a)(2) and 20 AAC 25.055(a)(4). CIE anticipates finding only oil in the proposed zone. However,even if CIE discovers gas in the Hemlock, the testing and production of this gas still conforms with regulation. The proposed zone is 4,244' from the nearest property line where ownership or landownership changes. (20 AAC 25.055(a)(2)) There are no other wells open to or capable of producing from the Hemlock within the governmental section, or within 3,000' of the wellbore (the NFU 41-35 well tested the Hemlock in the 1960's, but was plugged back and no longer is open to or capable of producing from the Hemlock).The nearest well open to or capable of producing from the Hemlock is over four miles from the NFU 14-25. (20 AAC 25.055(a)(4)) The proposed perforation,testing and possible production of the Hemlock oil zone also conforms with 20 AAC 25.055(a)(1) and 20 AAC 25.055(a)(3) for the same reasons stated above. Tim Jones Staff Landman Cook Inlet Energy, LLC 601 W. 5th Ave., Suite 310 Anchorage, AK 99501 Office: (907) 433-3811 Cell: (907) 350-7426 Cook Inlet Energy 1 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, May 27, 2014 5:02 PM To: stephen.ratcliff@cookinlet.net Cc: Schwartz, Guy L (DOA); Roby, David S (DOA); Ferguson, Victoria L(DOA) Subject: NFU 14-25 (PTD 210-111): Proposed Hemlock Perforations/Testing Stephen, AOGCC Conservation Order No. 633 grants a spacing exception for the North Fork Unit 14-25 well. That order—and Armstrong's application for that order—discuss only gas reservoirs within the Tyonek Formation, so perforating, testing and regular production of the Hemlock Formation is governed by statewide spacing regulations. Will the planned Hemlock operations in NFU 14-25 conform to the requirements of 20 AAC 25.055(a)(2)and (a)(4)? Please justify why a spacing exception is not required for this planned operation. Thank you, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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(aalaska.gov. 1 /.TD ,2 10 —Ill Ferguson, Victoria L (DOA) From: Conrad Perry <Conrad.Perry@cookinlet.net> Sent: Thursday, May 29, 2014 1:14 PM To: Ferguson,Victoria L(DOA) Cc: Schwartz, Guy L(DOA); Stephen Ratcliff;Courtney Rust Subject: NRFU-14-25 Sundry Application Cook Inlet Energy Victoria, CIE requests the AOGCC to cancel or rescind approved Sundry 314-279 for the installation of a velocity string. We also wish to recall our Sundry application dated May 12th for NFU 14-25 to test the Hemlock. These have both been replaced by the Sundry Application Dated 5/27/2014 that you are currently reviewing. As discussed, we agree that the BOP test in Coil Work step#1 should be 4,500 psi (not 3,500 psi). conrad G d Drilling Manager Cook Inlet Energy, LLC �j� 601 W. 5th Avenue STE 310 6 Civ Anchorage,AK 99501 �✓ G �1/40\ (907)433-3816–Office 'Cv V (907) 727-7404-Cell v�& , / �(r (907) 344-0584- Home / (907) 260-5356-Cabin � ) � conrad.perry@cookinlet.net CONFIDENTIALITY NOTICE:This e-mail transmission and any document,files or previous e-mail messages attached to it,are confidential. If you are not the intended recipient, or a person responsible for delivering it to the intended recipient,you are hereby notified that any review,disclosure, copying,dissemination,distribution or use of any of the information contained in,or attached to this e-mail transmission is STRICTLY PROHIBITED.If you have received this transmission in error, please notify us immediately by forwarding this message to the original sender or by telephone at 907.433.3816 and then delete this message and its attachments from your computer. SCANNED JUN 1 9 2014 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, May 13, 2014 12:07 PM To: 'stephen.ratcliff@cookinlet.net' Subject: NFU 14-25: Proposed Perforations (Permit No. 210-111; Sundry No. 314-311) Stephen, Cook Inlet Energy(CIE) proposes to perforate a new pool (Hemlock) in gas development well NFU 14-25. Conservation Order No. 633 (CO 633)was issued by the AOGCC, and it allows evaluation and production from gas reservoirs in the Tyonek Formation. Because CO 633 does not address the Hemlock Formation, statewide spacing regulations of 20 AAC 25.055 govern CIE's proposed perforations. What is the distance from the planned perforations to the nearest property line where landownership or ownership changes? What is the distance from the planned perforations to the nearest well open to the Hemlock? Please review 20 AAC 25.550 and provide justification as to why a spacing exception is NOT required for the planned perforations in NFU 14-25. Please let me know if you have any questions. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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 Davies, Stephen F (DOA) From: Stephen Ratcliff <Stephen.Ratcliff@cookinlet.net> Sent: Thursday, May 15, 2014 1:20 PM To: Davies, Stephen F (DOA) Cc: Tim Jones; Greg Kirkland Subject: Re: NFU 14-25: Proposed Perforations (Permit No. 210-111; Sundry No. 314-311) Stephen, The 14-25 is 4,244' from the nearest line where ownership or landownership changes, and there are no wells producing from or open to the Hemlock within a 5 mile radius. Let me know if you need any further information. Regards, Stephen Ratcliff Senior Drilling Engineer Cook Inlet Energy 601 W. 5th Avenue, Suite 310 Anchorage,AK 99501 0- (907)433-3808 C- (907)433-9738 From:<Davies>, "Stephen F (DOA)" <steve.davies@alaska.gov> Date:Tuesday, May 13, 2014 at 12:06 PM To:Stephen Ratcliff<stephen.ratcliffPcookinlet.net> Subject: NFU 14-25: Proposed Perforations(Permit No. 210-111;Sundry No. 314-311) Stephen, Cook Inlet Energy(CIE) proposes to perforate a new pool (Hemlock) in gas development well NFU 14-25. Conservation Order No. 633 (CO 633)was issued by the AOGCC, and it allows evaluation and production from gas reservoirs in the Tyonek Formation. Because CO 633 does not address the Hemlock Formation, statewide spacing regulations of 20 AAC 25.055 govern CIE's proposed perforations. What is the distance from the planned perforations to the nearest property line where landownership or ownership changes? What is the distance from the planned perforations to the nearest well open to the Hemlock? Please review 1 20 AAC 25.550 and provide justification as to why a spacing exception is NOT required for the planned perforations in NFU 14-25. Please let me know if you have any questions. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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. 2 �! Ii Roby, David S (DOA) From: Stephen Ratcliff <Stephen.Ratcliff@cookinlet.net> Sent: Wednesday, May 14, 2014 1:55 PM To: Roby, David S (DOA) Cc: Conrad Perry Subject: Re: Sundry application for North Fork Unit#14-25 (PTD 210-111) David, This is correct. Let me know if you have any further questions. Regards, Stephen Ratcliff Senior Drilling Engineer Cook Inlet Energy 601 W.5`"Avenue,Suite 310 Anchorage,AK 99501 O-(907)433-3808 C-(907)433-9738 From:<Roby>,"David S(DOA)"<dave.roby@alaska.gov> Date:Tuesday, May 13, 2014 at 2:58 PM To:Stephen Ratcliff<stephen.ratcliff@cookinlet.net> Subject:Sundry application for North Fork Unit#14-25 (PTD 210-111) Stephen, I just want to confirm that I am reading your sundry application to perf and test the Hemlock formation in the subject well correctly. As I read it you're proposed operations will not result in downhole commingling of production from the Hemlock and Tyonek formations since the perforating guns will be hung from a packer set beneath the Tyonek perforations that will act as a check valve to prevent production from the Hemlock when the coiled tubing is not stung into the packer. Is this correct,or am I misreading your application? Thanks, Dave Roby 1 i L ,• Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Dave Roby at(907)793-1232 or dave.robyvi alaska.gov. 2 RECEIVED 4 ' ' ' STATE OF ALASKA MAY 12 2014 • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25,280 1.Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool Q • Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing Q •Other. Coil SDT Q • 2.Operator Name: 4.Current Well Class: 5. ermit to Drill Number. Cook Inlet Energy,LLC Exploratory ❑ Development Q • 0-111 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 50-231-20035-0000 • 7.If perforating: • Wel. =me and Number. What Regulation or Conservation Order governs well spacing in this pool? (.,`• b• 3 North Fork Unit#14-25 • Will planned perforations require a spacing exception? Yes ❑ No Q 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 391211/2095 North Fork Gt., 0 .i ric'_j 5. / s• il, /47 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Deth TVD(ft): Effective Depth MD(ft): Effective Depth .0 r ft): Plugs sured): Junk(measured): 11,700' • 1 ,3117.--121:27)z...„ 11,566' 10,177' 8,7 I none Casing Length-lit 7l Size MD ( Il ' Burst Collapse Structural Conductor 178' 16" 178' ` 1,:' N/A N/A Surface 2,992' 10 3/4" 2,992' 2, :6' 5210 2480 Intermediate 5,297' l 8 5/8"/7 5/8" 5,, 4,714' - 5,714'6,890 2,520/4,790 7 1 Production 11, 00' 5 2"/ 11, 10,311' 10,640 7,480 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing ize: \ \Tubing Grade: Tubing MD(ft): 8,536'to 9,552'(attached) 7,838'to 8,854'(attached) N/A / Packers and SSSV Type: N/A / Pa 'e-and SSSV MD(ft)and ND(ft): N/A 12.Attachments: Description Summary of Proposal I 13. • -II Class after proposed work: Detailed Operations Program U BOP Sketch ✓ . x.oratory U Stratigraphic U Development U U Service 14.Estimated Date for 6-May-14 f5.Well Status after proposed work: Commencing Operations: ` Oil ❑ Gas ❑., . WDSPL ❑ Suspended ❑ 1 16.Verbal Approval: Date: ' WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and co\t ..the best of my knowledge. Contact Stephen Ratcliff Email stephen.ratcliffgcookinlet.net Printed Name Conrad Perry • '7-7404 Title Drlg Manager-4-29-2014 Signature ____Ire,„,.....1 /IPhone Date COMMISSION USE ONLY Conditions of approval: Notify Com ' - ion -.that a rfsentative may witness Sundry Number: -- \`*-3\\ Plug Integrity ❑ BOP T--t ❑ Mechanical Integrity Test ❑ Location Clearance ❑ r /� Other: (�i� -k (4,7,,r---'•'41 4/& r ,/ sato ,!UN I ,9 ?D14 ,-6)/47- Spacing Exception Required? Yes ❑ NoSubsequent Form Required: /( - (1L ` K-d „_W ) s6, 5- c) APPROVED BY Approved by: --.-----COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-403(Revised 10/2012) Ap rov pR I a i co I a or 2 onths from t e date of approval. Attachments in Duplicate RBCMS MAY 3 010 .,//pr2!) CA,, ii?‘ EGctv ED _ • • Cook Inlet Energy_ SAY 12 2U14 A0600 May 9th, 2014 Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Cook Inlet Energy, LLC: North Fork Unit#14-25 (PTD 210-11) Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a completed Form 10-403 and Application for Sundry Approval for the perforation and short flow test of the Hemlock zone with a 1 3/4" coil completion in this well from approximately 11,242' to 11,268'. This operation is slated prior to previously approved Sundry 314-2-75 for installation of a velocity string. 271 7:4 The goal is to establish a flow rate from the Hemlock. If you have anyquestions, please contact me at(907) 727-7404. Sincerely, Conrad Perry Drilling Manager Cook Inlet Energy 601 W.5`h Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax ' NFU 14-25 -Well Summary Current Status: NFU 14-25 is currently on gas production Scope of Work: • Remove Retrievable Bridge Plug from 8720'. • Set Halliburton TCP Drill Guns at approximately 11,242'to 11,268' • RIH with SLB 1 %"coil and stab into packer • Pressure up with N2 and fire TCP guns • Attempt to flow well through coil tubing for an estimated 12-24 hours,depending on results,may be extended if further cleanup is needed to obtain sufficient test. • Pull coil(packer acts as a check valve) General Well Information: MASP: 4267 psi J Reservoir Pressure/TVD: Hemlock 4742 psi estimated based on a .45 psi/ft gradient in 10,537'TVD Tyonek Gas 3,493 psi @ 12,475' MD/9,438' TVD-February 2007 This zone has been partially depleted. Wellhead Type/Pressure Rating: Vetco Grey 13-5/8"-5M BOP Configuration: Blinds in lower, coil rams in upper, plus annular TIFL/MIT-IA/MIT-OA: TIFL - N/A MIT-IA - drilled 2010 MIT-OA - drilled 2010 Well Type: Producer Estimated Start Date: May 16, 2014 Production Engineer: Shawn Dillon (907) 342-7386 Shawn.Dillon@CookInlet.net Drilling Engineer: Stephen Ratcliff (907)433-9738 Stephen.Ratcliff@CookInlet.net Drilling Manager: Conrad Perry (907) 727-7404 Conrad.Perry@CookInlet.net 3 - NFU 14-25 Coil Hemlock Test Procedures • WireLine Work A. Rig up E-Line. B. Test Lubricator to 2500 psi. C. Lock and Tag out SSV. D. Make gauge ring run to top of bridge plug. Note fluid level. E. Recover retrievable bridge plug from 8720'. (note: this step was approved in Sundry 314-275) F. Make gauge ring run to 11,300' G. PU Halliburton Drill Gun(EZSV)with TCP perforations approximately 11,242'to 11,268' (10,537' to 10,553' TVD) H. RIH, correlate and set EZSV. I. Rig Down E-Line. Put well back to production. • Coil Work 1. Nipple up and test Coil and BOPs (double gate and annular)to 3500 psi 2. Lock out SSV. Open up well. 3. Pick up EZSV stinger on Coil BHA. 4. Strip in hole to 11,242'. Stab into EZSV. Set down 500#. 5. Rig up surface lines and test equipment. 6. Pressure up on coil with N2 to XXXX psi. Hold for 5 minutes then bleed back to 2500 psi. 7. Guns should fire with 18 minute delay. 8. After firing open well for approximately 12-24 hours flow period. 9. Pull out of EZSV closing sleeve and shutting in Hemlock. v 10. Pull out of hole with coil. Bleed any returns back to test skid. 11. Shut well in and nipple down BOPs and Injector Head. 12. Proceed to Velocity string installation covered under Sundry 314-275. 4 Wellhead rte, Cook Inlet Energy, L.L.C. k ',, GE Oil&Gas NFU 14-25 Proposed ill .1r 3-]/8"5M 1 Arll I-1 j`Y'3-1/8"5M 3-1/8"5M A...,... . _ . . y . ii ,,.,2-1/16"5M 3-1/8"5M 15-1/8"5M ( r) AGO'-, 5-1/8 5.000 5-1/8 10.000 ( ) • 5-1/8 10,000 ■ ■1. 13-5/8 SM u - M I I " ". _ = : nq 13-W SA i ill' i. Ink_ir id Kg IN IP St 10 34'00 CSG }+2-OD TBG - l' - `--859'CO CSG 5 • - Current Condition Permit#: 210 111 NFU #14-255 API#: 231-20035-00-00 Cook Inlet Energy Prop,Des:ADL-391211/2095 'FSL, 'FEL KB elevation: 679' (21'AGL) S26 T4S R14W S.M. Latitude: 59*47 46.xxxx"N Longitude: 151"37 45.xxxx"W Spud: it TD: Rig Released: Structural Pipe-Driven • t I. l 16" X-56 84 ppf Top Bottom d MD Surf 153' TVD Surf 153' • Chemical Injection Nipple set @ Surface Casing 355'MD. Drift-4.767"ID P110 10.3/4" L-80 45.6ppf Top Bottom 6.812"OD MD 0' 2,992' ND 0' 2,786' • • 1 34 Intermediate Casing-tapered string 8 5/8" L-80 26 ppf Hydril • � Top Bottom MD 0' 2,412' ND 0' x,xxx' 7 5/8" 29.78 L-80 BTC-M h1 ,,{ MD 2412' 5,297' ?,ZJ 4,4 TVD XXXX' 4,714' ..4 - •• L'*1a Production Casing Y7•'. i,:-' 5 1/2" P-110 17 ppf Hydril 513 .. G,ry, Top Bottom lt, 1T MD 0' 11,690' G+.. TVD 0' 10,992' ,71 / ',..1' Perforation Intervals: 8,536'-8,548' y 8,620'-8,640' 8,760'-8,776' 9,536'-9,552' s • Baker 5 1/2"Wireline Retreivable Bridge Plug set at 8720'MD 8-3-2013 T • 7D PBTD 11,700'MD 11,690'MD 11,002'TVD 10,992'ND Well Name&Number: North Fork Unit#14.25 Lease: Kenai Loop County or Parish: Kenai Penisula Borough State. Alaska I Country.' USA Perforations(MD): Perf(TVD): Angle @KOP and Depth. Angle C Perfs KOP TVD- Date Completed: RKB: 21' Prepared By: Craig Rang Last Revision Date: August 13,2013 6 a Proposed Well Schematic Hemlock Test Permit#: 210 111 API#: 231-20035-00-00Cook Inlet Energy 5-9-14 Prop.Des:ADL-39191211/2095/2095 NFU #14-25 KB elevation: 679' (21'AGL) ' FSL, 'FEL Latitude: 59*47'46.xxxx"N Longitude: 151*37'45.xxxx"W S26 T4S R14W S.M. Spud: TD: TITIFt Riq Released: Strctural Pipe-Driven [.. Top Bottom r MD Surt 153' TVD Surf 153' ' Chemical Injection Nipple set @ Surface Casing • 355'MD. Drift-4.767"ID P110 10-3/4" L-80 45.5ppf Top Bottom 6.812"OD MD 0' 2,992' • I , TVD 0' 2,786' Blip lilt' 6�1 t Intermediate Casing-tapered string 7 8 5/8" L-80 26 ppf Hydril ISL ' Top Bottom ei. MD 0' 2,412' ." TVD 0' x,xxx' 7 5/8" 29.7# L-80 BTC-M a'"} 't MD 2412' 5,297' !y1' TVD XXXX' 4,714' ,, ,,y 1 3/4"Coil String t'�' E ':::1'.._-------- Production Casing :7' 7 5 1/2" P-110 17 ppf Hydril 513 W.. to, Top Bottom 1., 1 MD 0' 11,690' i1S�! � TVD 0' 10,992' i. `• n tVy . ice' t Perforation Intervals: -..7..! . 8,536'-8,548' > 8,620'-8,640' • `_' 8,760'-8,776' 9,536'-9,552' T est = 1,, - Hallibuirton 5 1/2"drill gun s' Hemlock Perforations11,242'to 11,268' z • IQ PBTD 11,700'MD 11,690'MD 11,002'TVD 10,992'TVD Well Name&Number North Fork Unit#14-25 Lease: Kenai Loop County or Parish: Kenai Penisula Borough State: Alaska I Country: USA Perforations(MD): Perf(TVD): Angle @KOP and Depth. Angle @ Perfs KOP TVD Date Completed: _ RKB: 21' Prepared By: Conrad Perry Last Revision Date: April 29,2014 7 t . COIL BOP Arrangement ( ) C= Annu p II � Shear `Arl Pipe *• ►.T'4 I. <,r 5-1/8"5M 01 5-1/8 5.000 5-1/810.000 i■ t ' IS1743/141''‘) • a.r_..a E 5-1/8 10.000 116 II uI ►v - - 13-5/8 5M[3:1.,, ..-1- ICI Ra--�i 1 M if I 141 19-518514 i In ile- 8 1 7:C-07 �A\I'/%�� Fit STATE i- 1.2 E_<: F � e K y - �' — 333 cs1 Seventh Avenue O GOVT Ry:(R Si-n\ t)?R I-1.I Anchorage, Alaska 99501-3572 .a �., 5',2/c ?2 SCANNED MAY 1 6 2014 Conrad Perry Drilling Manager Cook Inlet Energy, LLC / / 601 W. 5th Ave., Suite 310 j O — i Anchorage, AK 99501 Re: North Fork Field, Undefined Gas Pool,North Fork Unit#14-25 Sundry Number: 314-279 Dear Mr. Perry: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ,1 f Daniel T. Se., ount, Jr. 4/ Commissioner a DATED thisday of May, 2014. Encl. aSC ' 61( f , RECEIVED �I STATE OF ALASKA APR 30 2014 • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS �1QG�� 20 MC 25.280 1.Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing Q Other. Velocity String CAX:y t4,Q • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Nu er. Cook Inlet Energy,LLC Exploratory ❑ Development Q . 210-111 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 50-231-20035-0000 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? North Fork Unit#14-25 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 391211/2095 • North Fork aAdecik,.JaS re/.4,./, JZ 5/ 56>.1' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft):Ill) E ctive Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,700' • 1, �� LI'`�J 11,566' 10,177' 8,720' none Casing Length Size MD TVD Burst Collapse Structural Conductor 178' 16" 178' 178' N/A N/A Surface 2,992' 10 3/4" 2,992' 2,786' 5210 ' 2480 Intermediate 5,297' 8 5/8"/7 5/8" 5,297' 4,714' 5,714'6,890 2,520/4,790 Production 11,700' 5 1/2" 11,700' 10,311' 10,640 7,480 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8,536'to 9,552'(attached) 7,838'to 8,854'(attached) N/A Packers and SSSV Type: N/A Packers and SSSV MD(ft)and TVD(ft): N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program U BOP Sketch U Exploratory LI Stratigraphic Lf Development U Service U 14.Estimated Date for 6-May-14 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas Q - WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stephen Ratcliff Email stephen.ratcliffa(�cookinlet.net Printed Name Conrad Perry 40,404 Title Drlg Manager-4-29-2014 ,- Signature /''hone Date COMMISSION USE ONLY Conditions of approval: Notify Co • ssi.n so that a r:1'sentative may witness Sundry Number: Plug Integrity ❑ BOP Test aiVMechanical Integrity Tye-sttom❑ Location Clearance ❑ RBDMS MAY 1 3 2014. Other: ii, 3 coo rS� Lic3" / �1--C— Spacing Exception Required? Yes ❑ No EY Subsequent Form Required: /O–V 01 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:37///9---- Submit 5'S /1 ^/'� n /� A Form and Form 10-403(Revised 10/2012) Approved applicae i yRIFGII 4ttrlm the date of approval. Attachments inAuplicate • _ Cook Inlet Energy_ RECEIVED APR 3 0 2014 AOGCC April 29, 2014 Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Z I U l I f17 Cook Inlet Energy, LLC: North Fork Unit#14-25 (PTD 2 ) /), L 1 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a completed Form 10-403 and Application for Sundry Approval for the installation of a casing patch across perforated interval 8760' to 8776' and a 1 3/4" velocity string in NFU " 14-25 This well has been loading up with water and the velocity string will help it maintain consistent production rates. The casing patch will be across a suspected water production. In accordance with 20 AAC 25.265 (d) (4) CIE requests not to install subsurface safety valve due to the velocity(capillary) string. If you have any questions,please contact me at(907) 727-7404. Sincerely, Conrad Pe Drilling Manager Cook Inlet Energy 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax NFU 14-25 -Well Summary Current Status: NFU 14-25 is currently on production Scope of Work: • Remove Retrievable Bridge Plug from 8720' • Install Pollards 5'A"casing patch across perforations from 8760' to 8776'(wet zone) • Install Coil Hanger • Install 1 3/4"velocity string General Well Information: MASP: 2500 psi Reservoir Pressure/TVD: 3,493 psi @ 12,475' MD/9,438' TVD-February 2007 This zone has been partially depleted. Wellhead Type/Pressure Rating: Vetco Grey 13-5/8"-5M BOP Configuration: Blinds in lower, coil rams in upper TIFL/MIT-IA/MIT-OA: TIFL - N/A MIT-IA - drilled 2010 MIT-OA - drilled 2010 Well Type: Producer Estimated Start Date: May 6, 2014 Production Engineer: Shawn Dillon (907) 342-7386 Shawn.Dillon@CookInlet.net Drilling Engineer: Stephen Ratcliff (907) 433-9738 Stephen.Ratcliff@CookInlet.net Drilling Manager: Conrad Perry (907) 727-7404 Conrad.Perry@CookInlet.net 3 NFU 14-25 Casing Patch/Velocity String Installation Procedures • WireLine Work A. Rig up Wireline B. Test Lubricator to 2500 psi. C. Lock and Tag out SSV. D. Make gauge ring run to top of bridge plug. Note fluid level. i E. Recover retrievable bridge plug from 8720'. F. Make gauge ring run to 8800' for casing patch. G. Set Pollard casing patch across perforations from 8760' to 8776'. Confirm location with GR. H. Rig Down Wireline. Secure Well. • Coil Work 1. Lock and Tag out SSV:" 2. Close lower master. Check for flow. 3. Close upper master. p 4. Nipple down T and swab valves. (e ' 5. Install and Test 3 '/2"VetcoGray Coil hanger assembly with crossovers to 5" 5M upper master. 6. Nipple up and test Coil BOPs (double gate and annular) to280 psi 3 c r--- /c'/ 7. Run 1 3/4"coil to top perforation at 8536' and hang off in VetcoGray Coil Assembly. 8. Test Hanger to 5000 psi. 9. Nipple down coil 10. Nipple up 3 1/4" flow cross and swab valve. Test to 5000 psi 11. Fit flow line to new height. Test Flowline welds. 12. Release well to production 4 • Proposed Wellhead/Tree w/Coil Hanger Cook Inlet Energy, L.L.C. j, GE Oil&Gas NFU 14-25 Proposed r •_ mom 3-1'8"51.E 3-1/8'5M • -i Coil Hanger •� 2-1/16"SM 3-1/8"SM 5-1/8`5M 481/146. »fir• 5-11850(X1 r 5-1,8 10.000 5-1/8 10.000 136!•8M ■I ! ,)IIM a,. IO ' U G 111.44r CX)C IGr OD WOO - - ---- k 5 Current Condition Permit#: 210 111 t NFU #14-25 API#: 231-20035-00-00 FSL, 'FEL Prop.Des:ADL-391211/2095 Cook Inlet Energy KB elevation: 679' (21'AGL) S26 T4S R14W S.M. Latitude: 59*47'46.xxxx"N Longitude:, 151*37'45.xxxx"W Spud: TD: :;-.. ,'L Rig Released: Structural Pipe-Driven ^� 16" X-56 84 ppf I• (. Fi; Top Bottom ,i MD Surf 153' TVD Surf 153' Chemical Injection Nipple set @ Surface Casing 355'MD. Drift-4.767"ID P110 10-3/4" Leo 45.5ppf Top Bottom 6.812"OD MD 0' 2,992' TVD 0' 2,786' Intermediate Casing-tapered string SSIntermediate 5/8" L-80 26 ppf Hydril Top Bottom t; MD 0' 2,412' TVD 0' x,xxx' 7 5/8" 29.78 L-80 BTC-M t, MD 2412' 5,297' C;:' • TVD XXXX' 4,714' '� Production Casing 9-' 5 1/2" P-110 17 ppf Hydril 513 ' Top Bottom • - MD 0' ND 0' 11,690' 10,992' • 5:; Perforation Intervals: l" :" 8,536'-8,548' 8,620'-8,640' ' . _ 8,760'-8,776' y,r 9,536'-9,552' . b.a .0- is M1 T F -_, Baker 5 1/2"Wireline Retreivable Bridge •. Plug set at 8720'MD 8-3-2013 W` In n1"-''' T t(s PBTD 11,70000'MD 11,690'MD 11,002'TVD 10,992'TVD Well Name&Number: North Fork Unit#14-25 Lease. Kenai Loop County or Parish: Kenai Penisula Borough State. Alaska I Country:I USA Perforations(MD): Perf(TVD): Angle @KOP and Depth Angle @ Perfs_ Date Completed: RKB: 21' I Prepared By: Craig Rang Last Revision Date: August 13,2013 6 I Proposed Well Schematic PROPOSED 4-29-14 Permit#: 210 111 API231-3925100-00 Cook Inlet Energy NFU #14-25 Prop..Des:ADL-3911211/2095 _ ' FSL, ' FEL KB elevation: 679' (21'AGL) Latitude: 59*47'46.xxxx"N S26 T4S R14W S.M. Longitude: 151.37'45.xxxx"W ;'::L- :_ Spud: Rig TD: Released: Structural Pipe-Driven _ 16" X-56 84 ppf [ Top Bottom iii MD Surf 153' '''. TVD Surf 153' Chemical Injection Nipple set @ Surface Casing 355'MD. Drift-4.767"ID P110 10-3/4" L-80 45.5ppf • Top Bottom _ 6.812"OD MD 0' 2,992' -1 TVD 0' 2,786' 41\ 411S...' .. c,' IliIS Intermediate Casing-tapered string it ,. 1 8 5/8" L-80 26 ppf Hydril �� Top Bottom 3� MD 0' 2,412' TVD 0' x,xxx' 7 5/8" 29.7# L-80 BTC-M MD 2412' 5,297' TVD XXXX' 4,714' 1 3/4"Coil Velocity String Production Casing 5 1/2" P-110 17 ppf Hydril 513 Top Bottom ,),-. ,i.. MD 0' 11,690' y�:, ;.y ND 0' 10,992' 6' y;61 Yr. "7' Perforation Intervals: 8,536'-8,548' y 8,620'-8,640' =' 8,760'-8,776' 9,536'-9,552' 5 1/2"x 4"ID Casing Patch / From 8757'to 8778' ✓ Oi T. V\Z-0 r5 F '• —r 4 'ILL TD PBTD 11,700'MD 11,690'MD 11,002'ND 10,992'ND Well Name&Number: North Fork Unit#14-25 Lease. Kenai Loop County or Parish:_ - Kenai Penisula Borough - State. Alaska I Country:I USA Perforations(MD): Perf(ND): Angle @KOP and Depth A^,1=ris Peds KOP TVD Date Completed._ RKB. 21' Prepared By. Conrad Perry Last Revision Date. April 29,2014 7 . r COIL BOP Arrangement Annular ( ) i!= 001114111 .--/ Shear '"l ~ —�� d �- a Pipe i`•��7 II 1I ,a r," ? "r 12 1/16"5M 3-1/8" 5M 5-1/8" 5M ■.:` – 5-1/8 5.000 5-1/8 10.000 • ( ) p r 5-1/8 10.000 ■ rip", 13.518 5M S . MIM III MU * '0.1* 1 i I I- - 13-5/8'5M 4. to I u1 W 1. 1111fi.iIN ~6 a & ■i \' -_- 10-34'00 CSG 1 - --8-5/8'OD CSG 5.172-OD 7DG 8 p C J 0)- = _5 0)fa °o u_ p 0 d c a) g 2Z o= N m d p and p Z 0 3« 0- 8 a �U v.) m d m°tS OD 0 0o c 0 E g¢ E N 0 c tV Z 0 CC a(0 �O m a p CCU° cQvi C ∎ vi d > COco CI QJ f` c c co CV = 1111 N d J a) y =1.- O U(9 m C o o c� p .-0 .c j 0 t ¢ 0 O In m E U.� 3 offs o a y ->o.N 2 rn Q N} 2 N} o o Z o V m m c- 0 0 8 0 0 0 0 ° p2 oLL > cook O o m d C c O o) wo JO 2 2¢ 2 2<00. 2x00 1-200 2 MC_) Q c To C >I 0 0 a F 0 a) CC 0 9 p J J E o 2 0 c C 0 C C C C C C C_ = o a) a a a) a 0 a) a) a) a w m C OUa a a a) 0. a s a 0. a s Z IU 0 0 U O O O 0 0 0 0 ( CO et et et co 0 2 nntNNN O O O '00 .- •- t" •- •- o O O O 7, u co .- a U U w O co ...d4) t o o o o o o a co c) co t.. r-.. D-- CO ce 0 c . O to co Q1 o. N I- co et O) N 10 to to to w N • d ✓ a D Z C oI Q s zZ 0 y 7 J 0. a, a) 0 C)9 O O O O O O CL CN1 O O O ZI m 0 0 0 U U J 2 Na) o o O N n O a) g)N N LO N to to In In V U 1 E p J C 2 J Q` N 1 J 0 r v o 0 11""'_ I- o U 5 Z N 0 G m • o C) O 0 LL a) w = m 0 I-CC � � l O w Q Z O � Z o O a Q Z m a) > > ;> ;> o Q E 0 - (/) N v) .y co c O a) C a) a) a) Z C C O 02c). LL c m c c c ) y o o o > o 0 SO u' E o o t o 0 y 0 v u Z 0 o Z aa)) aa) v aa)) 'o ac) o -o v a) c H 0 U p co to V) 0 0 Z o ) N )n Co N O J r o .D CO CO CO I y y `.3 E o 0 0 0 Z r G W 0 co =Z N N N tY O N O Q ` R O LL p F. c . ''-° y co O 0o 0 O v c ED,,- -I d J \ 2 W a �' Og `U U \ \ \ \\ w ? W o ► 1 J • 0 (7 f- o rn.� o 0 0 0 m rn m m rn Cn CD rn d 0 I- 3 J 0 I- W W W 0 0 0 0 0 0 0 J Ce o 0 0 co M co Z N co• U_ N o , N O Z F. Q • c cr J I J 1— a .d. w m a Y OO ' p.++ 2 O Z Z Ow V U Eco E w 0 co z 0 Et re O W N 0 > o d V <re co 0 d O Z 8 U d I O Q O Z• H N 7 n) O J 0. 0 CL N m T E 2 � o � o u_ _o O a a 0o E V .%- 0 J Q to I— N 4 O O O r r H O CI) __ 2 2 z M Y +j W Y U) H m co c Q Z O a) C a Q Z o !i CI Z 1/• li 0 o r Y CO Z o � m I�o N r to y O. d C Z P• I d O m Z Q �.. . 2 N (s C O P T� E a V y° m E E• • O 3 0 2 0 QIX U 0 STATE OF ALASKA ALA, _OIL AND GAS CONSERVATION COMM, iN F " " - REPORT OF SUNDRY WELL OPERATIONS Or, 2220 ,. 1.Operations Abandon Li Repair Well Lj Plug Perforations U • Perforate U Other U Performed: Atter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver❑ lime Extension❑ AD-MC- Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Armstrong Cook Inlet,LLC Development El Exploratory ❑ 210-111 • 3.Address: Stratigraphic❑ Service ❑ 6.API Number. 1421 Blake St.,Denver,CO 80202 50-231-200350000 ' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL-391211/2095 • North Fork Unit No.14-25 . 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Undefined gas • 11.Present Well Condition Summary: Total Depth measured 11700 feet Plugs measured na feet Tbg Plug true vertical 11002 feet Junk measured na feet Effective Depth measured 10,589'est feet Packer measured na feet true vertical 9,377' feet true vertical na feet Casing Length Size MD TVD Burst Collapse Structural 153' 16 " 153' 153' na na Conductor 0 0 " 0 0 0 0 Surface 2992' 10 3/4" 2992' 2786' 5210 2470 Intermediate 5297' 7 5/8" 5297' 4714' 6890 4790 Production 11690 5 1/2" 11690 10992 10640 7480 Liner Perforation depth Measured depth see attached WBD feet True Vertical depth see attached WBD feet Tubing(size,grade,measured and true vertical depth) na na na Packers and SSSV(type,measured and true vertical depth) na na na na 12.Stimulation or cement squeeze summary: Intervals treated(measured): na 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: na 800 100 60 _ 300psi w/comp Subsequent to operation: na 700 3-Jan 31 209psi w/comp 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run na Exploratory❑ Development El . Service ❑ Stratigraphic ❑ Daily Report of Well Operations attached 16.Well Status after work: Oil ❑ Gas El. WDSPL El 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: 313-273 Contact Stephen Hennigan Ph: (337)849-5345 Email Shennigan(l�peiinC.COm Printed Name _ c _xi. :ibi,..s. Title Vice President-Engineering �� .i.nature filrRA:—'- - Phone (303)623-1821 Date "s ) ,,' VS 714-. "/4l) RECEIVED A OCT 222013 ARMSTRONG AOGCC Cook lip/et.LLC' October 9, 2013 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Enclosed 10-404 for Armstrong Cook Inlet, LLC NFU#14-25(PTD No. 210-111)Sundry 313-273 Dear Ms. Foerster, Armstrong Cook Inlet, LLC is providing the 10-404 for the above referenced well. Data provided includes the form, present WBS, and summary of activities. If you have any questions or require additional information, please contact me at(303)623-1821 or Stephen Hennigan at(337)849-5345, or Craig Rang at(907)252-6799. Sincerely, (---„_rsci—ze„..7, e Edward Teng Vice President-Engineering Armstrong Cook Inlet, LLC Enclosures Cc: Stephen Hennigan— Petroleum Engineers for Armstrong Cook Inlet, LLC 1421 Blake Street, Denver, CO 80202 (303)-623-1821 Ph (303)-623-3019 Fax FINAL 08 03 2013 Armstrong Cook Inlet,LLC North Fork Unit Kenai Borough,Alaska North Fork Well 614-25 Final Well Schematic itIXtIMMiX TVD Est Est. Cosine Formation Depths ii Sine Nil ..P FracG .,',11 I 16"Conductor ',t3 846,R3,N/80,PEB €i� ' '14 153' Orison 9.8 W (5-1/2"Chemical Injection Mandrel®355' jt ;:) 4.767 Drift ID,6.612"OD,P110 +pf ' r;1 j If4"SS 0.049"well chemical ' 13-112" ' Infection line Beluga Q 192' f 10-3/4"Surface Casing I(l , 45.56,R3,L80,BIC,SNITS :{" I,786'TVD(2,992'MD) 13.4 1 1 tic /j a Inter mediate casing swedge to 8-5/8"3261.80 ' Hydril 521 nod Hydril 511 connection,Boa OD machined to 8.889".Top 1500'is Hydril 521 and + bottom 1000'is Hydril 511. 1 The 8-5/8"casingmt at 2,412'MD 9-7/8" fil P Gh `A e TOC fad 4,470'TVD(5,000'MD)iii _ ggrsi✓/fs;lr".s.��?uY,�+,. '"" isr`'s.°1g F 7-5/8"Intermediate Casing H. '% M . 29.76,R3,L80,BTC-M,SMLS �'F. 4 . 4,714'TVD(5,297'MD) 16,4 V Tyocek Q 5,412' Iv f" 6 i 6-3/4" 3 Et OP . V Retrievable Peefora6oa laterrale: ��6h 8,5.26'-8548' Bridge Plug 8720' i' 8,620'-8,610' ��iiH" 8,760-8,776' 9 ., \9536'.9552' / 9 ilRN NIP @ 10,868'TVD(11,566'MD)Left with hall&rod 5-1/2"Production Casing T '1 4 FS @ 10,992'TVD(11,690'MD) 176,R3,Pl10,Hydril 513,SIlLS f'''.%a'',1,j-'%S 15.7 TD 11,002'TVD(11,700'MD) ARMSTRONG Cook Inlet LLC 1421 Blake Street, Denver, Colorado 80202 North Fork Unit #14-25 Sec 26-4S-14W PTD 210-111 Kenai Peninsula Borough, Alaska Sundry 313-273 3-Aug-13 PJSM. Make up BHI 5.5"tubing retrieveable plug,firing head, BOPs, and lubricator. Pressure test to 3500 psi,good. RIH, correlate and set plug at 8720'. POOH. Rig down. Reinstall tree cap and wellhouse hatch. Release crew. ,/\,t .jeso 2-Aug-13 PJSM. Make up tools, lubricator and BOP's.Test to 3500 psi,good. RIH,jar dwn to open equalizing ports. POOH and change to retrieving tool. RIH and retrieve BHI plug T at 9500'.Top of fluid at 5190'. Plug and all tools recovered. 1-Aug-13 PJSM. Make up tools, lubricator and BOP's. Pressure test failed. Leaking around BOP ram bonnet. Removed and sent to Pollard shop for repair. Installed tree cap and released crews. 12-Jun-13 PJSM Pollard/BHI. R/up eline. RIH w/4.65" OD Gage Ring and junk basket. RIH to 9620'. No issues. POOH. L/dwn GR/Jbasket. M/up Running tool/Retrievialable Bridge Plug. RIH,Correlate, set Bridge Plug at 9500'. P/up, slack off and confirm set. POOH. L/dwn tools, BOP, Lubricator. Install Night cap and secure well and location 11-Jun-13 PJSM Pollard/BHI. R/up eline. RIH w/4.75" OD Gage Ring and junk basket.Tight spot at 7216', hung up at 7660'.Worked free. POOH. • OF Tit 4,w I//j./ THE STATE Alaska LASKAConservation Commission x_= = �_ GOVERNOR SEAN PARNELL 333 West Seventh Avenue 1+.916j.' Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Edward Teng Vice President- Engineering _ I I Armstrong Cook Inlet, LLC 9 1 0 1421 Blake Street Denver, CO 80202 Re: Undefined Field, Undefined Pool,North Fork Unit No. 14-25 Sundry Number: 313-273 Dear Mr. Teng: 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 DATED this 3 day of June, 2013. Encl. • 4?ikl/t -,1 - ?-::: 6$'4...):: "',.?:M D • STATE OF ALASKA (9'3 Si\1,1-,‘f :' , 2', y; : ALASKA OIL AND GAS CONSERVATION COMMISSION �' APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 A.0 w,.�_ CC 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations el • Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Armstrong Cook Inlet,LLC Exploratory ❑ Development 0 • 210-111 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 1421 Blake St.,Denver,CO 80202 50-231-200350000 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 661 North Fork Unit No. 14-25 • Will planned perforations require a spacing exception? Yes ❑ No El 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL-391211/2095 Undefined gas 11. PRESENT WELL CONDITION SUMMARY Total Dept!)MD�): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 175°c 3/13 lie)U2 <' 3( l3 10,589'est 9,377' Casing Length Size MD TVD Burst Collapse Structural 153' 16" 153' 153' na na Conductor Surface 2992' 10 3/4" 2992' 2786' 5210 2470 Intermediate 5297' 7 5/8" 5297' 4714' 6890 4790 Production 11690' 5 1/2" 11690' 10992' 10640 7480 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): see attached WBD see attached WBD Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): NA NA 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: May 30,2013 Oil g pe ❑ Gas Q • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Craig Rang or Stephen Hennigan(337 849 5345) Email/pH crang @allanlericanoiIfleld.com (907)252-6799 Printed Name Edward Teng Title Vice President-Engineering :.• . u 4'„ :h Phone Date —jam � _ (303)623-1821 May 24,2013 -�� - _•%.,. _ COMMISSION USE ONLY Conditions of approval: Notify Commi -on so that a representative may witness Sundry Number: 2 2/ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ J Other: RBEMs JUN - 5 °ZOi Spacing Exception Required? Yes ❑ No [✓� Subsequent Form Required: /v—Y()Y / Approved by: APPROVED BY COMMISSIONER THE COMMISSION Date: e/�/ Submit Form and P Form 10-403(Revised 10/2012) A e rlja�(r°�� f alid for 12 months from the date of approval. Attachments, Duplicate PPr� I V rl a : ... PProval. / ■ �(\i s. A _ ARMSTRONG Fa 1 U `J L.0 Co)A'In/ct,,LLC AOGCC May 24, 2013 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Request for Sundry Approval Armstrong Cook Inlet, LLC NFU#14-25(PTD No. 210-111) Dear Ms. Foerster, Armstrong Cook Inlet, LLC is applying for a Sundry to isolate water in the above referenced well. The well was drilled in the third quarter of 2010, logged on the 27th day of September, 2010 and completed in the fourth quarter of 2010. Sixteen inch conductor pipe was driven to a depth of 153 feet measured depth and 10 s/." surface casing was set at 2,992' MD(2,786'ND). 7 5/8" Intermediate casing was set at 5,297' MD (4,714'TVD)and 5 W production casing set at 11,690' MD(10,992'TVD). • Four intervals were shot and production tested in the Tyonek interval. The intervals are 8536 — 8548' • MD, 8620 — 8640' MD, 8760 — 8776' MD and 9536 -9552' MD. Currently all four zones are open to production. The well is producing commercial quantities of gas and approximately 80 barrels of water per day. The bottom set of perforations or the interval above it are considered the intervals producing the water. Armstrong proposes to install a retrievable bridge plug above the lowest perforation in attempt to . minimize the water production. Should that be unsuccessful the process will continue until the source of water is identified. It may be necessary to install a straddle assembly or utilize a casing patch should the water source be in the middle perfs. If you have any questions or require additional information, please contact me at(303)623-1821 or Stephen Hennigan at(337)849-5345, or Craig Rang at(907)252-6799. Sincerely, 411401 Edward Teng Vice President-Engineering Armstrong Cook Inlet, LLC Enclosures Cc: Stephen Hennigan—Petroleum Engineers for Armstrong Cook Inlet, LLC Craig Rang—All American Oilfield 1 r"l Blukc /irc i, Dcnr'cr, ('0, ()202 (303)-623-1821 I'll (303)-623-3019 1 ax A ARMSTRONG Cook lirlet,LLC ARMSTRONG Cook Inlet LLC 1421 Blake Street, Denver, Colorado 80202 North Fork Unit#14-25 Sec 26-4S-14W PTD 210-111 Kenai Peninsula Borough, Alaska Current Status Well was drilled in the third quarter of 2010, logged on the 27th day of September, 2010 and completed in the fourth quarter of 2010. Sixteen inch conductor pipe was driven to a depth of 153 feet measured depth and 10✓" surface casing was set at 2,992' MD(2,786'TVD). 7 5/8" Intermediate casing was set at 5,297' MD(4,714'ND)and 5 1/2" production casing set at 11,690' MD(10,992'TVD). Four intervals were shot and production tested in the Tyonek interval. The intervals are 8536— 8548' MD, 8620 — 8640' MD, 8760 — 8776' MD and 9536 -9552' MD. Currently all four zones are open to production. The well is producing commercial quantities of gas and approximately 80 barrels of water per day. The bottom set of perforations or the interval above it are considered the intervals producing . the water. The intent of the workover is to block the water production by setting a retrievable bridge plug above the lowest set of perforations by wireline operations and continue to produce the upper three sets of perforations. If water production is sufficiently reduced or eliminated,continue with production. In the event water production is not sufficiently reduced or eliminated, it may be necessary to pull the plug, redress the plug if needed and move it above the next set of perforations. Continue monitoring the production to verify that the water production is sufficiently reduced or eliminated. Based upon results the plug can be left in place; removed and a straddle assembly set across 8760—8776' MD to eliminate that production/ produce the lower set of perforations with the uppermost two sets of perforations or removed to set above the next set of perforation above to isolate the interval producing the water. Or, the decision may be made to utilize a casing patch across the water producing zone. This procedure assumes a plug above the lower zone will be utilized and that a casing patch will be utilized on the next zone should water production continue. It will be modified as necessary as the operation proceeds. Procedure 1. Shut in well. Verify shut in wellhead pressure. 2. Rig up Pollard Wireline, mast unit and lubricator • 3. Pressure test wellhead, wireline BOP and lubricator to 1 % times estimated formation pressure(3750 psi). 4. RIH with gauge ring with 4.6" outside diameter(5 W—17#casing drift is 4.767"). Verify that gauge ring is greater than the maximum diameter of the retrievable bridge plug. (Haliburton will probably supply the retrievable bridge plug as Baker Oil Tools cannot supply the plug). Run gauge ring from surface to top of lowest set of perforations at 9536' MD. POOH 5. Make up retrievable bridge plug for 5%" 17#casing and run it into hole and set it within 50 feet of the top of the perforations at 9536' MD. Set it at 9500' MD unless there is a vf casing collar at that depth or+/-2 feet from collar. POOH 6. Rig down e-line unit 7. Place well back onto production through pad facilities. 8. Pad operator to monitor wells' production for minimum of three days. 9. If water has dropped off significantly, no further work on well is required if this is the lowest set of perforations, otherwise proceed to next step if water production has not dropped significantly or eliminated. If this is the second set of perforations from the bottom and the water volume has dropped off significantly or eliminated, got to step 11. If there is still significant water production,go to next step. 10. If water production is still above desired levels, shut in well and monitor wellhead shut in pressure as in step 1 above. Proceed using the same procedures (step 5 - 9) to the next set of perforations above after retrieving the bridge plug. 11. Assuming the zone producing the water has been identified, 12. RU slickline unit,mast unit and lubricator. 13. Pressure test wellhead and lubricator to 3750# 14. Pull retrievable plug 15. RU Pollard Wireline unit with mast truck,lubricator. 16. Pressure test wellhead and lubricator to 3750# 17. Run casing patch for 5 W 17#casing and set it across perforations isolated to produce the water. POOH 18. Rig down e-line unit. 19. Place well back onto production through pad facilities. 20. Secure wellhead. 21. Demobe equipment. - EXISTING Armstrong Cook Inlet,LLC North Fork Unit Kenai Borough,Alaska North Fork Well#14-25 Final Well Schematic March 10th,2011 TVD Est Est. Casing Fornaati'a _ Depths Hole Size MW PoreP FracG 16"Conductor i::1, Pi,, 84#,R3,N/80,PEB %1 is5 j "' 153' Driven 9.8 v ii 5-1/2'Chemical Injection Mandrel @ 355' f 4.767 Drift 1%6.812"OD,P110 55,, VI l raj.i E 1/4"SS 0.049"wall chemical 13-1/2" 1 t I. injection line Beluga @ 1,392' 'i 1 0 i' 10-3/4"Surface Casing 'l� 45.58,R3,L80,BTC,MILS ! 2,786'TVD(2,992'MD) 13.4 Inter mediate casing swedge to 8-5/8"32#L80 \ w Hydra 521 and Hydril 511 connection,Boo OD machined 108.889'.Top 1500'is Hydril 521 and 11'. bottom 1000'is Hydril SI I. V/ The 8-5/8"casing set at 2,412'MD H 9-7/8" 3 t, yid 14f: -`?)dg TOC 0 4,470'TVD(5,000'MD) )f 4. 0 Ai Aw B 7-5/8•Intermediate Casing i- s f 29.7#,R3,L80,BTC-M,SMLS ,n 4,714'TVD(5,297'MD) 16.4 �7S� 66g�n Tyonelc®5,412' 3�' Lj I; xr Y- 0. 6-3/4" N e :j _E. in'Y? Perforation Intervals: 1. 8,536•-8,548' f. 8,620'-8,640' r LA 8,760'-8,776' `9$36'-9,552' r f.. Y:. RN NIP @ 10,868'TVD(11,566'MD)Left with ball&rod :,,.04,1 .....„ ,5-1/2"Production Casing y; FS @ 10,992'TVD(11,690'MD) 176,R3,P110,Hydril 513,SAILS J%'.t' Yc.<C*'::, 15.7 TD 11,002'TVD(11,700'MD) POSSIBLE PROPOSED FINAL • Armstrong Cook Inlet,LLC North Fork Unit Kenai Borough,Alaska North Fork%Veil 614-25 Final Well Schematic March 10th,2011 TVD Est Est. Casing For„.tion Depths Hole Size MW PoreP Fred: 16"Conductor '- ` ., 846,R3,N/80,PEB 153' Driven 9.8 5-1/2"Chemical Injection Mandrel(0)355' ,!•?5, 4.767 Drift ID,6.812"OD,P110 1:.A.5�E k . t( 0 1/4"SS 0.049"wall chemical 13-1/2" i t /k injection line Beluga @ 1,392' /l hz j Ey. ■10.3/4"Surface Casing R;a/< `%; 45.56,R3,L80,BTC,SMLS f? 2.786'TVD(2,992'MD) 13.4 Intermediate casing swedge to 8-5/8"326180 . Hydra 521 and Hydril 511 connection,Boa OD machined to 8.889".Top 1500'is Hydril 521 and nr bottom 1000'is Hydril 511. E? 1' The 8-518"casing set at 2,412'MD d As 0 9-7/8" ii g Gt I x .r. • TOC Q 4,470'TVD(5,000'NW) :p- x{figs iii E'. 7-5/8"Intermediate Casing g' f' 4 29 7//R3,1.80,BTC-M,SAILS 'E �/ 4,714'TVD 5,297'MD 16.4 Tymek @5,412' P ✓ y rt f L 6-3/4" i t PA n iii _ _ ' ---a Perforation Intervals: -Th Retrievable 8,536'-11,548' Perforation 47,4 8,620'-8,640' • Bridge Plug 8,76D'-8,776' 3 9536'-9,552' o� e :i G4.5' � - ' RN NIP rat 10,868'TVD(11,566'MD)Left with ball&rod 5-1/2"Production Casing FS @ 10,992'TVD(11,690'MD) 176,R3,PI10,Hydril 513,SMLS r ; 15.7 TD 11,002'TVD(11,700'MD) 5, ?('l3 "1 a SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Ed Teng Vice President of Engineering Armstrong Cook Inlet, LLC 1 1421 Blake Street Denver, CO 80202 Re: North Fork Field, North Fork Pool, NFU #14-25 Sundry Number: 310-450 Dear Mr. Teng: 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. Chair DATED this t° day of January, 2011. Encl. . (pi STATE OF ALASKA /--f-// ALASKA.,tL AND GAS CONSERVATION COMMISSIOr4 •a� (I WG/r APPLICATION FOR SUNDRY APPROVALS �i�.b' flu/ZoII 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations❑ Perforate 0 Pull Tubing❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well lJ WGA' Stimulate❑ Alter Casing❑ !Test ErW6A- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Armstrong Cook Inlet,LLCM Development in Exploratory ❑ 210-111 ' 3.Address ❑ 6.API Number: Stratigraphic ❑ Service 1421 Blake Street,Denver CO 80202 50-231-20035-0000" 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Wet Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 15 NFU#14-25' 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL-391 2 1 1/2095• North Fork- 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): �IAlyk . WGA Gf N/A N/A Casing- Length Size MD TVD Burst Collapse Structural Conductor 178' 16" 178' 178' Surface 2,992' _._._.. 10-3/4 2,992' 2,786' 5,210 2,480 Intermediate 5,297' 8-5/8"/7-5/8" 5,297' 4,714' 5714/6,890 2,530/4,790 Production 11,700' 5-1/2" 11,700' 10,311' 10,640 7,460 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: N/A Packers and SSSV MD(ft)and TVD(ft): N/A 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program © BOP Sketch ❑ Exploratory ❑ Development fl - Service ❑ 14.Estimated Date for 1/5/2011 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas p - WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, Contact Printed Name Ed Teng Title Vice President Engineering Sig -Agir/areigiv Phone 303-623-1821 Date 12/30/2010 u — - COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 U)-(4 5 0 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ ✓✓✓! RECEIVED Other: DEC 3 0 2010 Alaska Oil & Gas Cons. Commiss on Anchorage Subsequent Form Required: i O — 407 APPROVED BY ` 11 � r Approved by: r' COMMISSIONER THE COMMISSION Date: ! L ` Form 10-403 r ` . 3u In Duplicate JAN 071011� RIGINAL Armstrong Coo. .et,LLC North Fork Unit Kenai Borough,Alaska North Fork Well#14-25 Proposed Well Schematic December 30th,2010 TVD Est Est. Casing Formation Depths Hole Size MW PoreP FracG 16"Conductor 84#,R3,N/80,PEB �, 153' Driven 9.8 5-1/2"Chemical Injection Mandrel @ 355' 4.767 Drift ID.6.812"OD,PI 10 , / 1/4"SS 0.049"wall chemical ■ 13-1/2" 4 injection line Beluga @ 1392' v i 10-3/4"Surface Casing 45.5#,R3,L80,BTC,SMLS 2,786'TVD(2,992'MD) 13.4 (Intermediate casing swedge to 8-5/8"329 L80 1 Hydril 521 and Hydril 511 connection,Box OD machined to 8.889".Top 1500'is Hydra 521 and bottom 1000'is Hydril 511. I The 8-5/8"casing set at 2,412'MD J 9-7/8" tr 1 s TOC @ 4,470'TVD(5,000'MD) li 5 1' 7-5/8"Intermediate Casing 29.7#,R3,L80,BTC-M,SMLS All `, 4,714'TVD(5.297'MD) 16.4 Tyonek @ 5,412' 6-3/4" Perforation Intervals: - 8,536'-8,548' 8,620'-8,640'- 8,760'-8,782" \,536'-9,552'- l RN NIP @ 10,868'TVD(11,566'MD)Left with ball&rod 1 5-1/2"Production Casing 4 , FS @ 10,992'TVD(11,690'MD) 174,R3,P110,Hydril 513,SMLS 15.7 TD 10,311'TVD(11,700'MD) 12/21/10 ARMSTRONG NFU #14-25 C'ookInlet i/C Testing Procedure Current Condition of Well See current Wellbore Diagram (Attached) Well is filled with 6% KC1 brine (9.5 ppg) This well was directionally drilled. Directional survey is attached. Tree cap connection is 6-1/2", 4 ACME-2G top thread Rig Up Testing Equipment 1. Make up the following Expro test equipment as indicated on attachment: Surface safety valve Variable choke manifold Combination heater/separator 50' flare boom 500 bbl frac tank The tree connection(wing valve) for the Expro test line is a 3-1/8", 5M flange. All hardline upstream of the separator should be rated for 10K psi service. The flare line, produced water line and relief line from the separator should be rated for 2K psi service. Run the flare line from the separator to the flare boom. Run both the produced water line and the relief line from the separator to the 500 bbl frac tank on location. Spot the tank as necessary to receive produced water from the separator. Ensure there remains access to the wellhead/tree by wireline and slickline units which will be utilized during this well test. Pressure-test all lines to their respective rated working pressures (0K,psi or 2K psi). Perforate and Test the Interval 9,536'1VID to 9,552'MD 2. Rig up Pollard slickline to swab. Swab brine from the well down to±3,800'MD. (Offsetting well NFU#34-26 was able flow from this interval with the fluid level swabbed to this depth.) Rig down Pollard but do not release. 3. Rig up Expro wireline tu perforate. Ensure lubricator is used as well may be live after perforating. 4. RIH with hollow carrier gun loaded with 6 SPF at 60° phasing. Tie in and perforate the interval 9,536'MD to 9,552'MD (16') with a single 20' gun run. Use the MD- GR curve on the attached log for correlation. Record stabilized wellhead pressure after perforating and POH with guns. R/D and release Expro wireline. 5. Open well to testing facilities. If/while the well is making water, limit rate to a maximum of one (1)bpm. If/when the well starts making gas set the choke at 10/64" and limit gas flow rate to a maximum of 3.5 MMSCFD. 6. If the well does not flow, R/U Pollard slickline on the well and commence swabbing operations. Continue swabbing until the well flows on its own. 7. Once the well has stabilized, shut it in. Management will determine data sampling settings for the downhole pressure gauges that will be run, gas rate adjustments and flow and shut-in period lengths. 8. Program two Pollard tandem quartz pressure bombs as instructed by management and run them in the hole on Pollard slickline, making 30-second gradient stops every 1,000'. Hang the gauges from an AD2 Stop in the 5-1/2" casing at±9,580' (28' below the bottom perforation at 9,552'). POH and release Pollard. Conduct Four-Point Test,Flow Period and Shut-In Period Important: Do not commence flowing the well per the steps below until verbally authorized. 9. With the downhole gauges in place, a four-point test will be conducted by gradually opening the well to flow at four discrete settings with Expro recording pressure and rate pairs at each setting. Armstrong management will determine the settings to be used and transmit them to the field. 10. With the four-point test concluded, the well will be flow tested for four days. Armstrong management will determine the rate or choke setting to be used. Expro will continuously monitor and record all pressure, rate, temperature and fluid fraction data during this time. 11. At the conclusion of the flow period, the well will be shut in for approximately five days. Move the Expro testing line from NFU#14-26 to NFU#32-35 for testing on that well during the 5-day shut-in on 14-26. 12. At the conclusion of the 5-day shut-in period, R/U Pollard slickline to retrieve the downhole gauges. Pollard is to download the data contents of the gauges in their Kenai shop and transmit the data to SolstenXP and/or Armstrong as instructed. 13. R/D and release Pollard. Perforate and Test the 8,760'MD to 8,782'MD 14. Rig up Expro wireline to perforate. 15. RIH with hollow carrier gun loaded with 6 SPF at 60° phasing. Tie in and perforate the interval 8,760'MD to 8,782'MD in a single 30' gun run. Use the MD-GR curve on the attached log for correlation. Record stabilized wellhead pressure after perforating and POH with guns. R/D but do not release Expro. 16. Open well to testing facilities. If/while the well is making water, limit rate to a maximum of one (1) bpm. If/when the well starts making gas set the choke at 10/64" P gg and limit gas flow rate to a maximum of 3.5 MMSCFD. Once the well has stabilized, contact management for four-point test parameters. 17. Conduct a four-point test by gradually opening the well to flow at four discrete settings with Expro recording pressure and rate pairs at each setting. Armstrong management will determine the settings to be used and transmit them to the field. 18. When open Management has determined that the test on the o perfs is complete, shut in g p p p well at the wellhead. Perforate and Test the Interval 8,620'MD to 8,640'MD 19. Rig up Expro wireline to perforate. 20. RIH with 3-3/8"hollow carrier gun loaded with 6 SPF at 60° phasing. Tie in and perforate the interval 8,620'MD to 8,640'MD (20') in a single 20' gun run. Use the MD-GR curve on the attached log for correlation. Record stabilized wellhead pressure after perforating and POH with guns. R/D but do not release Expro wireline. 21. Open well to testing facilities. If/while the well is making water, limit rate to a maximum of one (1) bpm. If/when the well starts making gas set the choke at 10/64" and limit gas flow rate to a maximum of 3.5 MMSCFD. Once the well has stabilized, contact management for four-point test parameters. 22. Conduct a four-point test by gradually opening the well to flow at four discrete settings with Expro recording pressure and rate pairs at each setting. Use the same choke settings used in Step 17 above unless otherwise instructed. When Management has determined that the test on the open perfs is complete, shut in well at the wellhead. Perforate and Test the Interval 8,536'MD to 8,548'MD p erforate.to wireline wir 23. Rig up Expro e 24. RIH with 3-3/8" hollow carrier gun loaded with 6 SPF at 60° phasing. Tie in and perforate the interval 8,536'MD to 8,548'MD (12') in a single 20' gun run. Use the MD-GR curve on the attached log for correlation. Record stabilized wellhead pressure after perforating and POH with guns. R/D and release Expro wireline. 25. Open well to testing facilities. If/while the well is making water, limit rate to a maximum of one (1)bpm. If/when the well starts making gas set the choke at 10/64" and limit gas flow rate to a maximum of 3.5 MMSCFD. Once the well has stabilized, contact management for four-point test parameters. 26. Conduct a four-point test by gradually opening the well to flow at four discrete settings with Expro recording pressure and rate pairs at each setting. Use the same choke settings used in Step 17 above unless otherwise instructed. When Management has determined that the test on the open perfs is complete, shut in well at the wellhead. Secure Well and Clear Location 27. Rig down and release all Expro testing equipment and personnel. 28. Set a back pressure valve in the tubing hanger and ensure all valves on the tree are closed. 29. Pump all fluid remaining in the 500 bbl frac tank down the 7" x 9-5/8" annulus of well #34-26. Maximum rate is 2 bpm and maximum pressure is-7-75-psi per z permit stipulation. too o t t6A- 30. Remove all the valve handles from the wellhead and tree and send to Inman's yard for storage in the Armstrong connex there. 31. 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J • ). - -� -- — • 1 OD I -1 _ r C� 1 r \\4 -r---t-•.s N________ NFU #14-25 Pert Interval 8,620' - 8,640' c 1 o '4.,,,....,................... . rC Me- ,, t, ? 1 ' ' i 1 < c L � › 1 1 f c I ,, • o ti -I- -, 1 --------------------- ------------- , — Ihil4 -' Normore- --- 1 L 4 . .. • 1 , I 1,... ....... ' I ,, , IHft-ii V 1 ... r, y ; r rt ,1 4 r r S 1 co ) rn c - 1 - 7 .. 1 - — ti NFU #14-25 ,, c I Perf Interval 8,760' - 8,776'h i --f �I o O z r .... ...? , i , r t • �--._--_ —f— I • , • 1 • • ., • I I OD a) ` i { I • ---- I — L �.--- E r rG 1 I c 1 ( ' 1 f 5 • i s,s • i--i O 1 O 1 `` ` ` Pj V (__------- • .nom. -- 1 Itt- _-_-- -- 4 .. _________I 1 CO •, c---___________ J _ - , (Ti —_.,,„ — - 1 If ti c `_ r 1.-' ' Fr-----;41- I1 I :,.. ■ Y; 1 - - I------ — - -- -� 1 •t- NFU #14-25 �_ Perf Interval 9,536' - 9,552' =iii �� , ___.r. —-- -t- 1 1 C13 cr cn • CD 7 . 1 -----. i r I -- -- r --------A........__,--, — -- -- • t t 1 - 1 I E • r I. S 1 II II I Cs I II 1 \..., , 1 CD C3 i; ...., ....,_____________,___1_ v , ... < ______ ..... i ___,....,___________-; _. ,..... • _ - l — e r I-I- It t; - J • t 1 CO —�— t = ` II � - - - f —--7-, �> - -_ L A ARMSTRONG (onX/n/e/, LLC December 30th,2010 Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7th,Ave., Suite 100 Anchorage, Alaska 99501 RE: Request for Sundry Approval Armstrong Cook Inlet NFU#14-25(PTD 210-111) Dear Mr. Seamount, Armstrong Cook Inlet, LLC hereby applies for Sundry Approval to perforate,test and place the North Fork#14-25 well into production. Armstrong proposes to perforate 4 intervals in the Tyonek formation,test the well and then put the well in to production. Attached please find a Form 10-403 Application for Sundry Approval and supporting documents for this work. If you have any questions or require additional information,please contact me at 303-623-1821 or Alexey Sachivichik at 264-6112. Sincerely, ARMSTRONG COOK INLET, LLC Ed Teng Vice President-Engineering Cc: Alexey Sachivichik—SolstenXP O R I G I N A L RECEIVED DEC 3 0 2010 Alaska Oil & Gas Cons. Commission Anchorage i NFU - 14-25 ('11) 210 it( Well Inner Outer Status Pressure Temp Annulus Annulus 4/1/2011 4/2/2011 4/3/2011 4/4/2011 4/5/2011 4/6/2011 4/7/2011 4/8/2011 4/9/2011 4/10/2011 4/11/2011 4/12/2011 4/13/2011 4/14/2011 4/15/2011 4/16/2011 4/17/2011 SI 2597 68 129 14 4/18/2011 SI 2610 55 131 14 4/19/2011 SI 2610 55 131 14 4/20/2011 SI 2642 47 136 14 4/21/2011 SI 2642 47 136 14 4/22/2011 SI 2687 65 136 14 4/23/2011 SI 2687 65 136 14 4/24/2011 Online 2687 65 136 14 4/25/2011 Online 2155 62 140 14 4/26/2011 Online 2155 62 140 14 4/27/2011 SI 2155 62 140 14 4/28/2011 2985 62 151 14 4/29/2011 2305 61 153 14 4/30/2011 2330 59 156 14 5/1/2011 2356 56 159 14 5/2/2011 2356 44 139 14 5/3/2011 2082 59 153 14 5/4/2011 2123 60 153 14 5/5/2011 2123 60 153 14 5/6/2011 2181 61 155 14 5/7/2011 2181 61 155 14 5/8/2011 2181 61 155 14 5/9/2011 2181 61 155 14 5/10/2011 2181 61 155 14 5/11/2011 2181 61 155 14 5/12/2011 2181 61 155 14 'fi- 4 14 (.4 14-,5- Well Inner Outer 2►C-(t ■ Status Pressure Temp Annulus Annulus 5/13/2011 2385 67 163 14 5/14/2011 2385 67 163 14 5/15/2011 2385 67 163 14 5/16/2011 2438 67 166 14 5/17/2011 2488 69 168 14 5/18/2011 2515 68 169 14 5/19/2011 2535 65 171 14 5/20/2011 2555 65 172 14 5/21/2011 2570 66 174 14 5/22/2011 2601 67 175 14 5/23/2011 2628 67 177 14 5/24/2011 2659 67 179 14 5/25/2011 2680 75 181 14 5/26/2011 2686 71 182 14 5/27/2011 2709 68 185 14 5/28/2011 2737 69 187 14 5/29/2011 2737 69 187 14 5/30/2011 2737 69 187 14 5/31/2011 2737 69 187 14 6/1/2011 2737 69 187 14 6/2/2011 2737 69 187 14 6/3/2011 2737 69 187 14 6/4/2011 2737 69 187 14 6/5/2011 2737 69 187 14 6/6/2011 2737 69 187 14 6/7/2011 2737 69 187 14 6/8/2011 SI 2737 69 187 14 I I 212_ « Arnistro._ook Inlet,LLC North Fork Unit Kenai Borough,Alaska Nontb-PM1C11 41-01 ti PLA- (.4-2.S (pit z o— 1(() Proposed Well Schematic February 3rd,2010 I t D Est Est. Est. Directional Casin¢ Forinalion 1).we. llakSu, A7AV PureP Traci: Information 16"Drive l'ipe 849,R3,N/80,PER 1 Pr I S IF Drip en 9,8 ' 33-112" 3 Ilsluga(n.1415' • \/ ;LI ++1 rT. )i_(tO T})a.3000 - ^Q tn,( 9 k t rt. ) 10-3/4"Surface Casing i� '}` 45.50,R3,L80,BTC.SMLS -/ 2.794'1'\'D(3,Otw'\1u) 13.2 1/ I/4"SS 0.049"wall chemical / 1s'' V injection line ?:' -. \ L O! 4 7��C A 1j/(l'•, 2 3 p� / /intermediate easing swedg to 8-5/8"32#LSO 1\ 5-i!2"Chemical Injection Sbb(a 41-2300' / Hydril 521 and Hydril 511 connection,Box OD 4.767 Drift ID,6.812"OD,PI IO machined to 8.889".Top 1500'will be Hydril l /i 521 and bottom 1000'will be Hydro 511.There / will be one full length crossover Joint from 521 to 511.Pin end will be 511.There will be a / crossoversub from 8-5/8"328 L80 511 box to 7- Tyonek fa 4775 / 5/8"29.78180 BTC-M pin. 9-7/8" , / The 8.5/8"will be down to pass the Injection r --- / Z. \�pple at around 2500'. \Veathertord xxax BTC'-M Hydraulic Stage Tool(n 3,000' i IOC•n 4.4711'T11)(5,000'MD) ?.Q71, s. i•-- , t t J� I �t 11�. • '• Y `' 47. ) ( (2 ) J 6� Cr L • 7-5/8"Intermediate Casing 29.70,R3.L80.BTC-M SMLS ' 4.009'I VD 35.500'MD) 14.7 et.( Ps; : 77/) P �(a:r = 4 0--, (-, ) i(1,71/- - pn\ - G'rir - 6-3/4" • 5-1/2"Production Casing 170.R3.P110,Ilydril 513,SAILS d 12.000'7'VD(12,711'5111) 16.8 TD 12,711'AID 12,000'TVD f STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS GAS WELL OPEN FLOW POTENTIAL TEST REPORT 1a.Test: H Initial L]Annual L Special lb.Type Test: Lf Stabilized U Non Stabilized U Multipoint ❑ Constant Time ❑ Isochronal ❑ Other 2.Operator Name: 5.Date Completed: 11.Permit to Drill Number: Armstrong Cook Inlet,LLC Mar. 13,2011 210-111 3.Address: 6.Date TD Reached: 12.API Number: 1421 Blake Street,Denver,Colorado 80202 September 26,2010 50-231-200350000 4a.Location of Well(Governmental Section): 7.KB Elevation(ft): 13.Well Name and Number: Surface: 649'FSL, 1600'FEL,Sec.26,T4S,R14W,SM 679'MSL North Fork Unit#14-25 Top of Productive Horizon: 8.Plug Back Depth(MD+TVD): 14.Field/Pool(s): 230'FSL, 1025'FWL,Sec.25,T4S,R14W,SM NA North Fork Total Depth: 9.Total Depth(MD+TVD): 230'FSL, 1025'FWL,Sec.25,T4S,R14W,SM 11700'MD, 10311'TVD 4b.Location of Well(State Base Plane Coordinates): 10.Land Use Permit: 15.Property Designation: Surface: x- 199811.1 y- 2121193.414 Zone- 4 NA ADL-391211/2095 TPI: x- 202427 y- 2120711 Zone- 4 16.Type of Completion(Describe): Total Depth: x- 202427 y- 2120711 Zone- 4 Initial Multi Zone Dry Gas Tubingless completion 17.Casing Size Weight per foot,lb. I.D.in inches Set at ft. 19.Perforations: From To 5-1/2" 17 4.892" 11700'MD 8536'-8548'MD,8620'-8640'MD,8760'-8776'MD, 18.Tubing Size Weight per foot,lb. I.D. in inches Set at ft. 9536'-9552'MD=7838'-7850'TVD,7922'-79427VD, None NA NA NA 8062'-80781VD,8838'-8854'TVD 20.Packer set at ft: 21.GOR cf/bbl: 22.API Liquid Hydrocardbons: 23.Specific Gravity Flowing Fluid(G): None None(no liquid) NA 0.565 24a.Producing through: 24b.Reservoir Temp: 24c.Reservoir Pressure: 24d.Barometric Pressure(Pa): ❑ Tubing El Casing 166 F° 2227 psia @ Datum 8350 TVDSS 14.73 psia 25.Length of Flow Channel(L): Vertical Depth(H): Gg: %CO2: %N2: %HZS: Prover: Meter Run: Taps: 9044' 8350' 0.565 0.355 0.973 0 NA 4" pipe 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice psig Hw F° psig F° psig F° Hr. Size(in.) Size(in.) 1. X 8/64 550 20 40 550 40 550 40 3.5 2. X 16/64 300 50 47 300 47 300 47 1 3. X 24/64 150 22 52 150 52 150 52 1 4. X 32/64 100 17 50 100 50 100 50 1 5. X Basic Coefficient Flow Temp. Super Comp. No. (24-Hour) h Pressure Factor Gravity Factor Factor Rate of Flow Fb or Fp Pm Ft Fg Fpv Q1 Mcfd 1. 12.28 54.7722 150 1.0198 1.3303 1.0278 487 2. 12.28 86.6025 150 1.0127 1.3303 1.0146 440 3. 12.28 49.1934 110 1.0078 1.3303 1.0071 248 4. 12.28 38.0131 85 1.0098 1.3303 1.0048 191 5. Temperature for Separator for Flowing No. Pr T Tr z Gas Fluid Gg G 1. 0.8246 500 1.4535 0.9466 2. 0.4498 507 1.4738 0.9714 3. 0.2249 512 1.4883 0.9859 Critical Pressure 667 667 4. 0.1499 510 1.4825 0.9904 Critical Temperature 344 344 5. Form 10-421 Revised 1/2004 CONTINUED ON REVERSE SIDE Submit in Duplicate ., Pc 1850 pct 3422500 Pf 2227 pf2 4959529 - No. Pt Pte Pc2-Pt2 Pw Pw2 Pc2-Pw2 Ps Ps2 Pf2-Ps2 1. 550 302500 3120000 667 444889 4514640 - 2. 300 90000 3332500 361 130321 4829208 3. 150 22500 3400000 180 32400 4927129 4. 100 10000 3412500 120 14400 4945129 5. 25. AOF (Mcfd) 191 Mcf/D n NA Remarks: This is not a good AOF test since the formation is so tight most of the points are gas flow via unloading the casing. However, the last flow point of 191 Mcf/D flowing at 100 psi is as close to an AOF as it is. I hereby certify that the for-••••• 's true and correct to the best of my knowledge. Si.,ed — lager rr Title V — j Date 26-Apr-11 DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfd/ - hwPm Fp Basic critical flow prover or positive choke factor Mcfd/psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air=1.000), dimensionless Gg Specific gravity of separator gas(air=1.00), dimensionless GOR Gas-oil ratio, cu. ft. of gas(14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet(ND) L Length of flow channel, feet(MD) n Exponent(slope)of back-pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia ��V Vv Pf Shut-in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia �S � ` Pr Reduced pressure, dimensionless 85�� Ps Flowing pressure at vertical depth H, psia � ��g.� Pt Flowing wellhead pressure, psia �� Pw Static column wellhead pressure corresponding to Pt, psia �a ego, 4 "° Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) ' 10 Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back-Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 Revised 1/2004 Side 2 O O 0 - - 0 0 p o o _ o U O N - e C N y • bD a o , o w u _ • • .� II Gr, - O • • O O 1 O O O O O O O O O O O O O O O O O O O O O O O O O O (zlsd)zsd-y{d STATE OF ALASKA q/1/2411 ALAShr,OIL AND GAS CONSERVATION COMMIS„ ION WELL C a MPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil❑ Gas 21 SPLUG ❑ Other ❑ Abandoned ❑ SuspendedL 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory❑ 1 GINJ ❑ WINJ❑ WAG ❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: Amstrong Cook Inlet,LLC Aband.: 10/11/2010 210-111 3.Address: 6.Date Spudded: 13.API Number: 1421 Blake St.,Denver,Colorado 80202 8/29/2010 50-231-200350000 % 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 649'FSL,1600'FEL,Sec 26 T4S R14W 9/26/2010 North Fork Unit#14-25 I Top of Productive Horizon: 8.KB(ft above MSL): 21' 15.Field/Pool(s): 230'FSL,1025'FWL,Sec 25,T45,R14W GL(ft above MSL): 715' North Fork Total Depth: 9.Plug Back Depth(MD+TVD): 230'FSL,1025'FWL,Sec 25,T4S,R14W N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 199811.1 y- 2121193.414 Zone- 4 11,700'MD/10,311'TVD ADL-391211/2095 TPI: x- 202427 y- 2120711 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 202427 y- 2120711 Zone- 4 N/A N/A 18.Directional Survey: Yes U 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) N/A 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: Multipole Array Acousticlog,Borehole Profile Log,Neutron,Density,GR,CCL,CBL,Mud Log. N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE HOLE SIZE CEMENTING RECORD FT. TOP BOTTOM TOP BOTTOM PULLED 16” 84# N-80HC 0 178' 0 178' Driven Driven 0 10-3/4" 45.5# L80 0 2,992' 0 2,786' 13-1/2" 397 bbl 0 8-5/8" 32# L80 0 1,389' 0 1,388'- 9-7/8" 183 bbl lead,27 bbl tail 0 8-5/8" 32# L80 1,389' 2,412' 1,388' 2,394'' 9-7/8" *** 0 7-5/8" 29.7# BTC-M 2,413' 5,297' 2,394' 4,714' 9-7/8" *** 0 5-1/2" 17# P110 0 11,700' 0 10,311'_ 6-3/4" 167 bbl 0 s 24.Open to production or injection? Yes 0 No❑ If Yes,list each 25. TUBING RECORD 1 All perforations were done using 3-3/8"6spf,60 deg guns. SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 1.8,536'-8,548'MD(7,838'-7,850'TVD);2.8,620'-8,640'MD(7,922'-7,942' TVD);3.8,760'-8,776'MD(8,062'-8,078'TVD);4.9,536-9,552 MD(8,838'- 8,854'TVD). 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 2/8/2011 Flowina Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 02/8-03/13/2011 150 Test Period 0 12,443.59 ' 0 32/64" 0 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 1,850 24-Hour Rate — 0 1,293.17 0 N/A 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No El Sidewall Cores Acquired? Yes ❑ No El 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 AAC 25.071. RECEIVED' 1 ' MAR 1 7 2011 RBDMS MAR 2 2011 Masks Oil&Gas Cons.Commission Anchorage Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes U No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Sterling 0' 0' needed,and submit detailed test information per 20 AAC 25.071. Beluga 1,392' 1,389' Tyonek 5,412 4,817' Hemlock 11,240' 10,529' West Foreland 11,272' 10,561' Mesozoic 11,446' 10,735' Formation at total depth:Mesozoic 31. List of Attachments:Baker HD Induction Log,X-Multipole Array AcoustiLog,Compensated Z-Densilog,Compensated Neutron Log,GR,CCL, Caliper Log,Baker Borehole Profile Log, Baker LWD Logs,Ex pro GR,CCL,CBL Log. 9 9 9 .P 9 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Alexey Sachivichik(907)264-6112 Printed Name: Edward Ten. 41 Title: Vice President-Engineering Phone: (303)623-1821 Date: 3/15/2011 INSTRUCTIONS General: This form is designed for subm' ing 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 1 b: 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 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: 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 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Armstrong Look Inlet,LLC North Fork Unit Kenai Borough,Alaska North Fork Well#14-25 Final Well Schematic March 10th,2011 P.1) Est Est. Casing Formation Ueoths Hole Size MW PoreP 1'racG 16"Conductor 84#,R3,N/80,PEB , ® Driven 9.8 5.1/2"Chemical Injection Mandrel @ 355' 4.767 Drift ID,6.812"OD,P110 1/4"SS 0.049"wall chemical 134/2" injection lice Beluga @ 1,392' Iv 10-3/4"Surface Casing 45.5#,R3,L80,BTC,SMLS 4 2,786'TVD(2,992'MD) 13.4 Intermediate casing wedge to 8-5/8"3281.80 Hydril 521 and Hydril 511 connection,Box OD machined to 8.889".Top 1500'is Hydril 521 and bottom 1000'is Hydril 511. The 8-5/8"casing set at 2,412'MD R 4p 9-7/8" TOC @ 4,470'TVD(5,000'MD) 1; 7-5/8"Intermediate Casing 29.7#,R3,L80,BTC-M,SMLS , 4,714'TVD(5,297'MD) 16.4 Tyonek @ 5,412' 6-3/4" Perforation Intervals: 8,536'-8,548' 8,620'-8,640' 8,760'-8,776' 9,536'-9552' J RN NIP @ 10,868'TVD(11,566'MD)Left with ball&rod 5-1/2"Production Casing , FS @ 10,992'TVD(11,690'MD) 178.R3,P110,Hydril 513,SMLS 15.7 TD 10,311'TVD(11,700'11D) A ARMSTRONG C"bnk lah I.I,/C' North Fork Unit #14-25 Operations Summary January 27th, 2011 Swab well to 400'. Cups hanging on casing connections and chemical injection mandrel. Take cups to shop to shave to smaller OD. January 28th, 2011 Swabbed well to 1,400'. Swab cups failed—getting shredded by something downhole. Bring out new cups and junk basket. January 29th, 2011 Run junk basket, stopped at 50'. Swabbed to 1,604' —progress stopped. RDMO Pollard,call out BJ coil. January 30th, 2011 Received coil tubing unit and set up except for injector(need crane). PJSM with coil crew. February 1 s`, 2011 RU coil tubing unit and pressure test with BOPE. Load well with brine. February 2nd, 2011 RU injector head and lines for circulation. MU mill/motor below BOPE. Stab BOPE on tree. Pressure test lubricator. RIB with mill assembly,hanging up in wellhead. Break BOPE from tree, unstab. LD milling assembly. Stab BOPE back on tree and secure well. February 3rd, 2011 MU 4.74" milling assembly. Stab on to well with BOPE/lubricator/coil. RIH to 300'. POOH,L/D milling assembly. RIH with coil to 3,300'. Displace 115 bbls of 9.4 ppg brine with nitrogen. Continue RIH to 4,500'. Displace brine. Total returns from well 146 bbls.POOH. Stop coil at tree,bleed nitrogen from coil. Secure well. February 8th, 2011 Move in Expro E line and testers and rig up. Make 4.767 guage ring, run to 10,755'. Complete rig up of Expro testers. Test flow lines. Repair leaking cap flange on well head. Attempt to make gamma ray and CCL perforating gun run.POH re-head and replace flow tubes. February 9th, 2011 Perforate interval 9,536' —9,552'. RD, move out Expro E-line. Flow well,total of 106 bbls of fluid recovered. February 10th, 2011 Shut well in for pressure build up. Flow well at various choke settings to unload brine and clean up,total of 1.7 bbls of brine recovered. February 11th, 2011 Flow well,run Pollard dynamic fluid level tool. Continue to flow well. February 12th, 2011 Flow well. Move Pollard wire line tools and equipment from well. Prep for coil tubing operation. February 13th, 2011 Flow well, move coil in,RU and test BOPE. Flow well. February 14th, 2011 Flow well.RU and jet well with coil to 9,553'. 6-7 bbl returned to surface. Spot 13 bbl methanol pill. Shut well in. POH and secure coil.Wellhead pressure at 00:00— 1,856 psi. February 15th, 2011 Monitor well. Shut in 1,890 psi wellhead pressure. Flow well. Jet out welibore from 9,374' to 11,000' — 38.5 bbls recovered. POH.Flow well at 10/64"choke WHP= 1,360 psi,WHT=37 deg, 1,072 mscf/d. February 16th, 2011 Flow well. Rig down BJ coil tubing unit. Run 4 point test. Flow well. February 17th, 2011 Flow test well. Run tandem pressure gauges on wireline, set below perfs. Flow test well. February 18th, 2011 Flow test well. Shut in for 5-day build-up. Move Expro testing line to NFU 34-26. Monitor pressure. February 22nd, 2011 Pull gauges and send to Kenai for downloading and reservoir calculations. Leave well shut in. February 23`d, 2011 Well shut in waiting on arrival of isolation packer/tailpipe. February 28th, 2011 RU Expro E-line. Pressure test all lines. Set 5.5"WRBP at 9,450'. March 1st, 2011 Confirm bridge plug set. RIH and perforate interval 8,760' —8,776'. Open well to testing. Pressure dropped from 1,450 psi to 1,300 psi. Shut-in well for pressure build up. March 2nd, 2011 Conduct 4-point test. RIH with slickline to retrieve WRBP. Shut well in for pressure build up. March 3`d, 2011 Increase wellhead pressure with nitrogen to 2,000 psi. Work WRBP with slickline. March 4th, 2011 Re-dress and set WRBP at 8,740'. RIH with 3-3/8"gun. March 5th, 2011 Perforate 8,620'-8,640' interval. Flow well at 8/64"choke. Shut in well at 1,000 psi. Let pressure build up. March 6`h, 2011 Conduct 4-point test. Pressure up well to 1,900 psi with nitrogen. RIH with magnet. Lost,fished and recovered magnet. March 7`h, 2011 Retrieve WRBP. Re-dress and set WRBP at 8,600'. Perforate 8,536' —8,548' interval. Flow well then shut in. March 8h, 2011 Flow well at various choke settings. 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G@ 0 S � q ■ § B q k § 2 o { § § § n B § E § Fa § $ t o u (3 /§ § a a CO #■ j CO G ■ § k § B B 8 B co B % 8 k B R 0 _ § � o E E K K K § § § § § § § § § 0 r, d _ 0 e e o d d o d d d § . / § § ,- § § E E E E E E 2 E § c - - - - - - ' a d o a a d �j \ Z § o. . . . ` ` cc . 0 R 01 0) ■ m g et B a ■ § S op- 3 a \ k 1 § ■ ■ ■ ■ 8 m co 8 a 01 N ; ca k k 2 § § 2 2 48888 :288 u, — § - k2 3 - _ U) U) U) e co e N a � 01 E0A - / k \ 0 r % / ■ ■ n m S ■ g ■ a ■ g g» w ` k . § @ § / IA § § § § § 2 § 2 o w $ 4 2 \ § # ~co 2 V) 2 .9 @q n ■ I 7 $ £ei f. oi cc § § - ` 22 2 t 7 $ $ t $ e k ■ $ e ; © a a . - a • od % 0 0 0 ° • � } co 0 . } 7 u C.) o S 0 0 , o u w u AL I.... 0 8 k 0 / � k CD U 8 m 8 m 8 8 8 8 8 ° 8 8 8 § ■ k .- / ƒ k k f co- f 1.- ' ° _ _ \ \ 6 \ s s k o a § § m m § § m CI a m a § 5 5 & & 5 5 5 § & 5 5 § A ARMSTRONG (iv,Am i,,LL( RECEIVE March 15th, 2011 A�aeke G"il&Gas Cons,Co �s1i0/1 Mr. Dan Seamount, Chairman 4fCt?Orag6 Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Well Completion Report Armstrong Cook Inlet, LLC North Fork Unit#14-25 PTD No. 210-111 Dear Mr. Seamount, Armstrong Cook Inlet, LLC hereby submits its Well Completion Report for the work performed in the testing of the North Fork Unit #14-25 well near Anchor Point on the Kenai Peninsula. Please find enclosed the following information for your files: 1) Form 10-407 Well Completion or Recompletion Report and Log 2) Final Well Schematic 3) Well Operation Summary 4) Testing Report If you have any questions or require additional information, please contact me at (303) 623-1821 or Alexey Sachivichik at 264-6112. Sincerely, ARMSTRONG SS • ET, LLC /10/1111111b, 41411111r - Edward Teng Vice President- Engineering enclosures 1424 Blake Street, Denver, Colorado 80202 Ph 303-623-1821 Fax 303-623-3019 • A ARMSTRONG C ouA'In/i,II( March 15th, 2011 RECEIVED Mr. Dan Seamount, Chairman MAR 1 7 2f 1) Alaska Oil and Gas Conservation Commission 333 West 7th, Ave., Suite 100 Alaska Oil&Gas Cons.Commission Anchorage, Alaska 99501 ,n t arage RE: Sundry Report Armstrong Cook Inlet NFU#14-25 (PTD 210-111) Sundry No. 310-450 Dear Mr. Seamount, Armstrong Cook Inlet, LLC hereby submits its Sundry Report for the work performed in its NFU#14-25 well. The work included perforation and testing of five intervals. The well is ready for production. Please find enclosed the following information for your files: 1) Form 10-404. 2) Final Well Schematic. 3) Well Operations Summary. ary• 4) Testing Report. If you have any questions or require additional information, please contact me at (303)623-1821 or Alexey Sachivichik at 264-6112. Sincerely, ARMSTRONG COOK INLET, Ed Teng Vice President- Engineering Cc: Alexey Sachivichik— SolstenXP 1424 Blake Street, Denver, Colorado 80202 Ph 303-623-1821 Fax 303-623-3019 STATE OF ALASKA .5 1 1 1/2_4 1 1 ALASKA AND GAS CONSERVATION COMMISSIC REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Repair Well Li Plug Perforations U Stimulate U Other U Performed: Alter Casing ❑ Pull Tubing❑ Perforate New Pool ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Perforate El Re-enter Suspended Well El 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Armstrong Cook Inlet,LLC. Development p Exploratory ❑ 210-111 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 1421 Blake Street,Denver,CO 80202 50- 31-20035-0000 7.Property Designation(Lease Number): 8.Well Name and Number: ADL-391 21 1/2095 ,NFU#14-25 9.Field/Pool(s): Uh�4�'1 Gee �� North Fork f7� 10.Present Well Condition Summary: 1 Total Depth measured 11,700' feet Plugs measured N/A feet true vertical 10,311' feet Junk measured N/A feet Effective Depth measured 11,566' feet Packer measured N/A feet true vertical 10,177' feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 178' 16" 178' 178' N/A N/A Surface 2,992' 10-3/4" 2,992' 2,786' 5,210 2,480 Intermediate 5,297' 8-5/8"/7-5/8" 5,297' 4,714' 5,714/6,890 2,530/4,790 Production 11,700 5-1/2" 11,700' 10,311' 10,640 7,480 Liner Perforation depth Measured depth 8,536-8,548', 8,620'-8,640', 8,760'-8,776', 9,536-9,552' feet True Vertical depth 7,8381-7,850', 7,922'-7,942', 8,062'-8,078', 8,838'-8,854' feet Tubing(size,grade,measured and true vertical depth) N/A Packers and SSSV(type,measured and true vertical depth) N/A RECEIVED 11.Stimulation or cement squeeze summary: MAR ��r Intervals treated(measured): N/A Alaska Gil&G83 CARS.Commission Treatment descriptions including volumes used and final pressure: 4Rc310ragc 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 N/A Subsequent to operation: 0 1293.17 0 1,850 psi N/A 13.Attachments: 14.Well Class after work: Copies of Logs and Surveys Run Exploratory ID Development III Service El Stratigraphic ❑ Daily Report of Well Operations yes 15.Well Status after work: Oil ❑ Gas El WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 16.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Alexey Sachivichik(907)264-6112 Printed Name Ed Teng , Title Vice President Engineering Sig :lure �� ._ Phone 303-623-1821 Date 3/15/2011 VK MAr b + MAR 21 2011 Form 10-404 Revised 10/2010 Submit Original Only Armstrong Cot,.__Aet,LLC North Fork Unit Kenai Borough,Alaska North Fork Well#14-25 Final Well Schematic March 10th,2011 TVD Est Est. Casing Formation Heaths Hole Size MW PoreP FracG � E 16"Conductor 84#,R3,N/80,PEB " r ® Driven 9.8 5.1/2"Chemical Injection Mandrel @ 355' 4.767 Drift ID,6.812"OD,P110 1/4"SS 0.049"wall chemical 13-1/2" injection line Beluga @ 1,392' S 10-3/4"Surface Casing 45.58,R3,L80,BTC,SMLS , 2,786'TVD(2,992'MD) 13.4 sa Intermediate casing swedge to 8-5/8"32#L80 Hydril 521 and Hydril 511 connection,Box OD machined to 8.889".Top 1500'is Hydril 521 and bottom 1000'is Hydril 511. The 8-5/8"casing set at 2,412'MD 9-7/8" TOC @ 4.470'TVD(5,000'MD) 7-5/8"Intermediate Casing 293#,R3,L80,BTC-M,SMLS J 4,714'TVD(5,297'MD) 16.4 I week 5.412' 6-3/4" Perforation Intervals: 8,536'-8,548' 8,620'-8,640' 8,760'•8,776' 9536'-9,552' RN NIP @ 10,868'TVD(11,566'MD)Left with ball&rod 5-1/2"Production Casing J ► FS @ 10,992'TVD(1 ,690' ) 178,R3,P110,Hydril 513,SMLS 15.7 TD 10,311'TVD(11,700'MD) A ARMSTRONG (0,A Iii!,',,it( North Fork Unit #14-25 Operations Summary January 27th, 2011 Swab well to 400'. Cups hanging on casing connections and chemical injection mandrel. Take cups to shop to shave to smaller OD. January 28th, 2011 Swabbed well to 1,400'. Swab cups failed—getting shredded by something downhole. Bring out new cups and junk basket. January 29th, 2011 Run junk basket, stopped at 50'. Swabbed to 1,604' —progress stopped. RDMO Pollard,call out BJ coil. January 30th, 2011 Received coil tubing unit and set up except for injector(need crane). PJSM with coil crew. February 1st, 2011 RU coil tubing unit and pressure test with BOPE. Load well with brine. February 2nd, 2011 RU injector head and lines for circulation. MU mill/motor below BOPE. Stab BOPE on tree. Pressure test lubricator. RIB with mill assembly, hanging up in wellhead. Break BOPE from tree, unstab. LD milling assembly. Stab BOPE back on tree and secure well. February 3`d, 2011 MU 4.74" milling assembly. Stab on to well with BOPE/lubricator/coil. RIB to 300'. POOH,L/D milling assembly. RIH with coil to 3,300'. Displace 115 bbls of 9.4 ppg brine with nitrogen. Continue RIH to 4,500'. Displace brine. Total returns from well 146 bbls.POOH. Stop coil at tree, bleed nitrogen from coil. Secure well. February 8th, 2011 Move in Expro E line and testers and rig up. Make 4.767 guage ring, run to 10,755'. Complete rig up of Expro testers. Test flow lines. Repair leaking cap flange on well head. Attempt to make gamma ray and CCL perforating gun run. POH re-head and replace flow tubes. February 9th, 2011 Perforate interval 9,536' —9,552'.RD, move out Expro E-line. Flow well,total of 106 bbls of fluid recovered. February 10th, 2011 Shut well in for pressure build up. Flow well at various choke settings to unload brine and clean up,total of 1.7 bbls of brine recovered. February 11th, 2011 Flow well, run Pollard dynamic fluid level tool. Continue to flow well. February 12th, 2011 Flow well.Move Pollard wire line tools and equipment from well. Prep for coil tubing operation. February 13th, 2011 Flow well, move coil in,RU and test BOPE. Flow well. February 14th, 2011 Flow well.RU and jet well with coil to 9,553'. 6-7 bbl returned to surface. Spot 13 bbl methanol pill. Shut well in. POH and secure coil. Wellhead pressure at 00:00— 1,856 psi. February 15th, 2011 Monitor well. Shut in 1,890 psi wellhead pressure. Flow well. Jet out wellbore from 9,374' to 11,000' — 38.5 bbls recovered. POH.Flow well at 10/64"choke WHP= 1,360 psi,WHT=37 deg, 1,072 mscf/d. February 16th, 2011 Flow well. Rig down BJ coil tubing unit. Run 4 point test. Flow well. February 17th, 201.1 Flow test well. Run tandem pressure gauges on wireline, set below perfs. Flow test well. February 18th, 2011 Flow test well. Shut in for 5-day build-up. Move Expro testing line to NFU 34-26. Monitor pressure. February 22nd, 2011 Pull gauges and send to Kenai for downloading and reservoir calculations. Leave well shut in. February 23`d, 2011 Well shut in waiting on arrival of isolation packer/tailpipe. February 28th, 2011 RU Expro E-line. Pressure test all lines. Set 5.5"WRBP at 9,450'. March 1st, 2011 Confirm bridge plug set. RIH and perforate interval 8,760' —8,776'. Open well to testing. Pressure dropped from 1,450 psi to 1,300 psi. Shut-in well for pressure build up. March 2nd, 2011 Conduct 4-point test. RIH with slickline to retrieve WRBP. Shut well in for pressure build up. March 3`d, 2011 Increase wellhead pressure with nitrogen to 2,000 psi. Work WRBP with slickline. March 4th, 2011 Re-dress and set WRBP at 8,740'. RIH with 3-3/8"gun. March 5th, 2011 Perforate 8,620'-8,640' interval.Flow well at 8/64"choke. Shut in well at 1,000 psi. Let pressure build up. March 6`h, 2011 Conduct 4-point test. Pressure up well to 1,900 psi with nitrogen. RIH with magnet. Lost,fished and recovered magnet. March 7th, 2011 Retrieve WRBP. Re-dress and set WRBP at 8,600'. Perforate 8,536' —8,548' interval. Flow well then shut in. March 8`h, 2011 Flow well at various choke settings. Shut well in. Pressure up casing with nitrogen. Retrieve WRBP with slickline.RD slickline.Leave well shut in. March 13t, 2011 Conduct 4-point test. Shut well in,turn to production facilities.RDMO Expro testing. FINAL REPORT IP •g 1n n co c09 O0) O O co F- 0 F- pF- n0 On, F- N. On On On On co V 0 d 01 01 M 0 0 00 N U) 00) O) O0) 001 co 0)) 0) 0) J U r J Y , t W p p p p p p p p p = j W .4 'O 8 8 8 N 8 8 100 O O O O 8 8 8 I- 3 Oi h ri (0 1{100� of co e! N /p 0 O O Z N L, 3 S 1n M of at N INO Q Oi N S. 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Y Y a Y co 0 0 0 0 0 0 O - O N O pfW U U 0 U 0 U U .' 0 �' V CO) C ~ Y Y 0 0 0 W U 0 0 _ mss v .0W 3 () W c 8 8 8 8 8 8 8 8 8 ,5 8 8 8 Z g E a a a 4 a Iei i to n I OS m of 2 W y ¢ a c3 g § c3 " " g g g cg N"+ c 1 c+f 5 elf 5 5 5 5 5 elf 5 5 5 of STATE OF ALASKA /J/ • • ALASKA OIL AND GAS CONSERVATION COMMISSIuN WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas 1 SPLUG❑ Other ❑ Abandoned ❑ Suspended N—lb.Well Class: 101/4.1 4+20AAC 25.105 20AAC 25.110 Development-a ' Exploratory U GINJ ❑ WINJ❑ WAG❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or / 12.Permit to Drill Number. / Amstrong Cook Inlet,LLC Abend.: 10/11/2010 210-111 3.Address: 6.Date Spudded: 13.API Number: 1421 Blake St.,Denver,Colorado 80202 8/29/2010 50-231-200350000 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number Surface: 649'FSL,1600'FEL,Sec 26 T4S R14W 9/26/2010 North Fork Unit#14-25 Top of Productive Horizon: 8.KB(ft above MSL): 21' 15.Field/Pool(s): 230'FSL,1025'FWL,Sec 25,T4S,R14W GL(ft above MSL): 715' North Fork Total Depth: 9.Plug Back Depth(MD+TVD): 230'FSL,1025'FWL,Sec 25,T4S,R14W N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MIDI , _IRS Ilk Property Designation: Surface: x- 199811.1 y- 2121193.414 Zone- 4 - 11,700'MD/,� 6`,'3(,(3 ADL-391211/2095 TPI: x- 202427 y- 2120711 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 202427 y- 2120711 Zone- 4 N/A N/A 18.Directional Survey: Yes El 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) N/A 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/lateral Top Window MD/TVD: Multipole Array Acousticlog,Borehole Profile Log,Neutron,Density,GR,CCL,CBL,Mud Log. N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BO M TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 84# N-80HC 0 178' 0 178' Driven Driven 0 10-3/4" 45.5# L80 0 2,-992' 0 2,786' 13-1/2" 397 bbl / 0 8-5/8" 32# L80 0 1,389' 0 1,388' 9-7/8" 183 bbl lead,27 bbl tail . 0 8-5/8" 32# L80 1,389' 2,412' 1,388' 2,394' 9-7/8" *** 0 7-5/8" 29.7# BTC-M 2,413' 5,297' 2,394' 4,714' 9-7/8" *** 0 5-1/2" 17# P110 0 11,700' 0 10,311' 6-3/4" 167 bbl 0 24.Open to production or injection? Yes❑ No 0 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) Will be perforated and tested after completion of the North Fork drilling program. 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. . x"P rf)Iw r DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED i 'i' 1' .!I •s, VE` MO 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Not tested Test Period Flow Tubing Casing Press: 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 AAC 25.071. RECEIVED NOV 0 3 2010 riE3LiVib NOV 03 2011, ___ Alaska(Id&Gas Coos.tT°wasion A Ie\.arage Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only i f 7 AIL ' 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes 1 No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Sterling 0' 0' and submit detailed test information per 20 AAC 25.071. Beluga 1,392' 1,389' Tyonek 5,412' 4,817' Hemlock 11,240' 10,529' West Foreland 11,272' 10,561' Mesozoic 11,446' 10,735' Formation at total depth:Mesozoic 31. List of Attachments: Baker HD Induction Log,X-Multipole Array AcoustiLog,Compensated Z-Densilog,Compensated Neutron Log,GR,CCL, Caliper Log,Baker Borehole Profile Log, Baker LWD Logs,Expro GR,CCL,CBL Log. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Alexey Sachivichik(907)264-6112 Printed Name: Edward Tenq Title: Vice President-Engineering Signatu . Phone: (303)623-1821 Date: 10/30/2010 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 1 b: 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 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: 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 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 to ` — EDGE OF R.O.W ` \\\\\1''' NORTH FO_ 1 __ _ �� OF A�':CkS2 nn' i� ' tr) 001 RL' r- N 2121143.9950 — '-',../ • �'/' -i7* , CP-1 ELEV=00 * 49 T H i� , N 2121137.2190 1 00 E 1339704.6100 EDGE OF R.O.W. __ • ELEV 656,$x._ --- . /,t-',..r).7411 c.R+`... 00 _._._ - - _ �- h4 SCOTT Mc LANE.: i ma :..-..-_ :-.;::'14=7- - se '�. 4928-S .• �r . i I-----"'':-. I- 6X--(/1 ® 65b //� CONEX I 'R I%V∎N\`, / RI G+ v 07\ t1/ Tract 18 •s. �,,�°� 0 v3 iii NORTH FORK — I 34-26 WELL ID Ir al 1601' 6'CHAINLINK :, FENCE " FEL co NFU 4-25 WELL x OF •1 x CON a UCTOR PIPE DRILLING PAD J I I W co N:2121948.576 E:133"836.494 LATITDE: 59°47'44.762"N ii I G� , LONGITUDE: 151°37'55.584" i / ,�' j NAD83 ASP ZONE 4 ELEV. � ,HE— ILI 657.8 FI\NAVD88 e II Tract 19 I . o North Fork Acres Subd. No" 2 0 co z , X x 8'CHAINLINK FENCE W I X X Q Z 7-. 11111111.111.1.1 �. Q c...„.................. ......_..........._.. -- �,. � � Ct bCP t � \ bTOP OF BERM 0 NN CO fill o W . N 2120261.15 I —I — E 1341421.67 — .,AK. Section 26,TO4S,R14W,S.M., S26 S25 S35 S36 NOTES N, —............ 1.BASIS OF HORIZONTAL COORDINATES ARE ALASKA STATE PLANE NAD 83 ZONE 4 EPOCH 2003 DETERMINED BY AN NGS OPUS SOLUTION FROM CORS NORTH BASE STATIONS ,"TSEA"AND"KODS"OBSERVED DEC.13,2007 ON , „ NF1 3 112"ALUM.CAP SET N:2121137.137 E:1339704.533 ELEV.656.69 li II' 2)BASIS OF ELEVATION IS NGS BENCHMARK N86 TT0195 ELEV.180.84 FT. �� NAVD88 DATUM. SCALE 3)SOUTHEAST CORNER SEC.26 COORDINATES DETERMINED FROM DIRECT 0 100 200 SURVEY TIE TO THE TO EXISTING BLM SECTION CORNER TIE PER HM91-57 FEET AND NOT THE PROTRACTED SECTION CORNER VALUES. PROJECT REVISION: ARMSTRONG COOK INLET, LLC NORTH FORK 14-25 WELL DATE: 8-21-10 700 17TH STREET#1400 DRAWN BY: MSM DENVER,CO 80202 AS-BUILT SURFACE LOCATION DIAGRAM NAD83 SCAB. 1,100' PROJECT NO. 103072 ENGINEERING P.O.BOX/488 SOLDOTNA I SURVEYING/TESTING BOOK NO. 10-25 Consulting Inc .O.BOX 488 SOLDOTNA AK.98889 LOCATION SHEET=a' VOICE(907)283-4218 FAX:(907)2933265 SW 1/4 SE 1/4 1 EMAIL:SAMCLANEOMCLANECG.COM S26 T4S R14W SEWARD MERIDIAN,ALASKA �°F Armstrong Cook Inlet,LLC North Fork Unit Kenai Borough,Alaska North Fork Well#1 Completion Well Schematic October 25th,2010 TVD Est Est. Est. Directional Casing Formation 1)e the Hole Size MW PoreP FracG Information 16"Conductor lie 849,R3,N/80,FEB ■ 153' Driven 9.8 /l 5-1/2"Chemical Injection Mandrel @+/-355' 4.767 Drift ID,6.812"OD,PI10 /1/4"SS 0.049"wan chemical \ 13-1/2" Beluga(a,1415' injection line l. 10-3/4"Surface Casing V. 45.59,R3,L80,BTC,SMLS 2,786'TVD(2,992'MD) 13.2 i "Intermediate casing swedge to 8-5/8"32#LS0 Hydril 521 and Hydril 511 connection,Box OD machined to 8.889".Top 1500'is Hydril 521 and bottom 1000'is Hydril 511. The 8-5/8"casing set at 2,412'MD \ 2 • 9-7/8" • TO('(a 4,470'TVD(5,000'MD) I i;iiiji i;iiiiiiiii:iii;iiiiiiij iiii;i 7-5/8"Intermediate Casing 29.7#,R3,L80,BTC-M,SMLS ; :?:& 4,714'TVD(5,297'MD) 15.7 Tyonek(a 4775' 6-3/4" • • • • 5-1/2"Production Casing :? 179,R3,P110,Hydril 513,SMLS A 10,311'TVD(11.700'MD) 15.7 TD 11,700'MD 10,311'TVD A ARMSTRONG C004 Met,LLC. North Fork Unit #14-25 Operation Summary August 25th, 2010 Move rig to new location and rig up with crane&trucks. August 26th, 2010 Rig up Glacier Rig#1. August 27th, 2010 Rig up Glacier Rig#1. August 28th, 2010 Finish rigging up Glacier Rig#1. Start mixing spud mud. Function test diverter system with,state man:' RU to PU 5"DP. Start PU 5"DP. August 29th, 2010 PU/SB 5"DP,HWDP,jars.RU floor, PU BHA,upload MWD, orient motor&tools,MU flex DC. RIH, tag @ 178' MD. Repair mud pump throttle controls. Drill f/ 178' to 754' MD. August 30th, 2010 Continue drilling 13-1/2"surface hole f/754' to 1,956'. Start kick-off at 1,005'. August 31St, 2010 Drill f/ 1,956' to 2,082'. Circ hole clean. Short trip out to 155'. Service rig, S &C drilling line. RIH—no fill. Drill f/2,082' to 2,714' MD. September 1st,2010 Drill f/2,714' to 2,992'. Circ hole clean. POOH to 817',20K-30K overpull in 3 spots, wip clean. RIH, wash last 25' to btm—no fill. Circ hole clean, condition mud. POOH. LD BHA, downlink MWD/LWD& LD.RD BHA tools,RU to run casing. September 2nd 2010 RU to run casing.PU&MU shoe track,BakerLok same. Pump thru& check floats. Run 10-3/4" surface casing. Wash down last 12', C & C mud and hole for cementing. Pump 40 bbls spacer,drop plug,mix& pump 397 bbls 12 ppg cement, drop plug, displace w/rig pump, recip pipe, did not see plug bump, casing stuck after cmt returned to surface,hold neutral 125K#wt, full returns throughout. CIP @ 2000 hrs. RD &clean up lines& stack, start ND diverter line. September 3rd,2010 WOC until 0400 hrs.ND diverter line while WOC. Release elevators. Rough cut 10-3/4".ND diverter. Prep starting head. Make final cut on 10-3/4"&NU Vetco Gray Multi-bowl wellhead,test to 2000 psi. NU BOPE. Set test plug. Start testing BOPE. September 4`h, 2010 Test BOPE—OK. PU BHA#2—clean out assy. RIH PU 56 jts DP,tag hard cement @ 2,815'. Drill cement to 2,877', circ hole clean. Test casing to 3000 psi—leaked. Verify no surface leaks, retest—held at 1,000 psi, leaks off at 1,500 psi. Discuss w/town. POOH. RU to PU BHA#3—section drilling assy. September 5`h, 2010 PU BHA#3, orient,uplink, load RA sources, shallow test tools,RIH 2,830'. Clean pits, inject old mud, rack&tally 805/8"& 7-5/8"casing, load puts w/water,mix new mud. September 6`h, 2010 Mix new 8.9 ppg mud, displace hole to same. Test 10-3/4"csg, staging up to 2,000 psi. Establish good test at 1,600 psi. Drill out cmt& shoe track, clean out rat hole, drill 20' of new hole to 3,012' MD. Circ hole clean,mud 8.9 ppg in& out. Perform formation leak-off test 0 650 psi w/8.9 pgg mud= 13.4 ppg EMW. Drill 9-7/8"directional hole,maintaining angle and direction from 3,012' to 4,006' MD at midnight. September 7th, 2010 Drill 9-7/8"hole f/4,006' to 4,275'. Circ hole clean.Precautionary short trip into 10-3/4" shoe. Service rig. RBIH, no fill. Drill 9-7/8"hole, maintain angle&direction, 4,275' to 5,238' at midnight. September 8th, 2010 Drill 9-7/8"hole f/5,238' to 5,306' MD, section TD. Short trip to 4,150' &back to btm, clean out light bridge at 5,003',wash last 80' to btm—no fill. C&C hole. POOH, LD BHA#3. Pull WB. Install 8-5/8" casing rams in UPR and test—leaked on low press. Clean& flip ram blocks,rinse stack.Test plug leaked. Install new o-ring on test plug. September 9`h, 2010 Test 8-5/8"UPR to 250 psi/5000 psi—OK after repairing leaks. RU&run 7-5/8"x 8-5/8"csg to 2,882', circ. Cont RIFT w/csg to 3,926' at XO to Hyd-521, elevators hanging up on box upsets, dress same. Circ &work pipe while dressing inserts. Continue RIH w/csg to 5,230' at midnight. September 10`h, 2010 Finish running csg, land on hgr, shoe @ 5,297'. Circ 2 csg vols. Cmt csg w/ 183 bbl lead, 27 bbl tail. LD landing jt, flush BOPs & lines, install csg packoff,test 5K psi—OK. Set WB. Install variable rams in UPR body. RIH&LD 5"DP, about 1,800' at a time. September 11`h, 2010 Finish LD DP. Test casing to 4,000 psi—OK. Change lwr pipe rams. Test BOPE. Spent much of day / attempting to get lwr pipe rams to test, finally successful. Finish BOP test. September 12`h,2010 Finish BOP test. MU clean-out assy,RIH PU 4"DP. Drill out cmt, shoe track and 20' of new hole. Conduct LOT to 16.4 ppg EMW. September 13`h, 2010 POOH w/clean-out assy. MU drilling assy,RIH PU DP. Drill f/5,326' to 5,412'. Lost communication w/ downhole tools. POOH, LD BHA. September 14"', 2010 Drill f/6,261' to 6,460'. September 15`h, 2010 Drill 6-3/4"hole f/6,261' to 7,135'. CBU,make short trip to 5,246' then back to bottom. Drill f/7,135' to 7,215'. September 161i, 2010 Drill 6-3/4"hole f/7,215' to 8,619'. September 17`h,2010 Drill f/ 8,619' to 8,830'.Repair top drive(Dennison engine). Drill f/8,830' to 8,836'.Repair top drive (breakout). Drill f/8,836' to 8,899'. Lost transmission on#1 carrier engine. Pull bit to casing shoe. Replace transmission. September 18`h, 2010 Finish transmission replacement on#1 main engine.RIH.Drill f/ 8,899' to 9,151'.#1 transmission failed again. Trouble shoot and POOH. September 19th,2010 POOH,handle BHA. Test BOPE while replace#1 engine transmission. --� September 20`h, 2010 Finish installation of transmission on#1 engine. RIH w/64 jts DP, circ out scale,POH.MU direction drilling BHA,test,RIH. Drill f/9,151' to 9,286'. September 21st, 2010 Drill f/9,286' to 10,219'. September 22°1, 2010 Drill f/ 10,219'to 10,598. Short trip to 9,026' and back to bottom-hole in good condition. Drill f/ 10,598' to 10,646'. September 23rd, 2010 Drill f/ 10,646' to 11,249'. September 24th, 2010 Drill f/ 11,249' to 11,299'.Pull one std trouble shoot mwd tools. Drill f/ 11,299' to 11,528'. POOH to 11,175' attempt to mad pass logging, (tools failed). RIH to 11,528'. Drill f/ 11,528 to 11,537'. September 25th, 2010 Drill 11,537' to 11,551'. CBU,POOH. LD MWD/LWD tools, motor and bit. MU new MWD/LWD tools, upload& back. Test BOPE,witness waived by AOGCC's John Crisp. wear bushing. P � Y p g September 26`h, 2010 MU BHA#8,RIH, clean out tight spots at 8,109' &9,028'. RIH to 11,169' MAD pass to 11,551'. Drill from 11,551' to 11,700' MD. CBU for short trip. September 27`h, 2010 CBU. POOH for short tip to 8,081'. RIH,tight spot at 11,373', 10' fill on bottom. Circ hole clean&WU to 9.8 ppg. POOH w/BHA#8. September 28th, 2010 Stand back MWD/LWD tools. LD motor&bit. RU E-line,run Quad-Combo,work down to 10,800' where stopped.Log out to csg shoe.POOH,RD E-line.MU clean out assy,RIH to shoe, service rig. Cont RIB to TD @ 11,700'. Hit bridges at 9,610' & 10,800'. Circ&weight up mud. September 29th,2010 Circ&weight up to 10.5 ppg. POOH,tight spots to 11,400',pull to 9,472'. RBIH, clean up bridges 11,214' & 11,408',ream last 22' to btm—4' fill,bottom 4' is sticky. C&C,pump slug. POOH,wipe tight spots 10,272', 5,840', 5,620', 5,470',no go at 5,464'.Very slow backream out 5,509' —5,377' then freed up. Wash up in to shoe. RBIH to 6,009',wipe out spot at 5,875'.POOH in to shoe OK. September 30th, 2010 POOH, LD BHA. RU E-line. R111 w/RSWC tools,tag&work thru 5,479' & 5,531',tools stuck at 5,785'.Work free&work up in to shoe.POOH,RD E-line. LD MWD/LWD tools f/derrick. MU clean- out BHA&RIH.No bridges or tight spots,wash last 85' to bottom, last 4' sticky. C&C,weight up to 10.8 ppg. October 1st,2010 C&C, WU to 10.8 ppg.POOH 10 stds, OK.Pump slug,POOH LD DP,HWDP, &BHA. Pull WB. Test UPR(VBR's)with 5-1/2"joint to 250/5000 psi. Make dummy run w/5-1/2"hanger& landing jt.RU to run 5-1/2"production casing. October 2❑d,2010 RU to run csg. Run shoe track,MU x-nipple 1 Jt above FC,test dart on seat&remove dart. Cont RIB w/ 5-1/2"casing to 5,261'. Circ csg volume. Drop dart,test casing to 8,500 psi for 30 min—OK.RU slickline,retrieve dart. Cont running csg to 6,030'. October 3rd, 2010 Cont rng 5-1/2"csg f/6,030' to 8,599', csg stopped. Circ one csg vol. MU top drive, circulate,work casing—stuck. Lower MW f/ 10.8 ppg to 9.6 ppg. Mix 62 bbl Black Magic pill. Spot 49 bbls pill in open hole X 5-1/2"annulus, 13 bbls left in csg. Continue working casing. Pumping 1/4 bbl every 15 min to allow spotting fluid to soak. October 4th,2010 Cont working stuck csg while soaking w/Black Magic pill.Pipe came free w/350K pull.Work pipe, break circulation, establish rotation. Wash&ream, circ out spotting pill(saved—60 bbls). Condition mud. Cont RIH w/5-1/2"casing to 10,165'. Displace 10.8 ppg mud from annulus w/9.6 ppg mud. October 5th,2010 Cont RIB w/5-1/2"csg,W&R thru tight spots 10,540'— 11,092'.RIB to 11,582' OK. LD6 jts,MU inj mandrel. RBIH,MU hgr& land csg. RILDS. Csg shoe at 11,690'. Circ 2,000 stks—OK.RU SL,make 2 runs to pull RHC body f/xn-nipple,no recovery. Circ csg volume—9.7 ppg mud in&out. Make 3rd run w/SL to pull RHC, could not jar free—no recovery. II 1 October 6th, 2010 @ POOH,RD SL. RU cmt head& lines. C&C for cmtg. PJSM. Cmt 5-1/2"casing. RD cmt&csg equip. RU equip for 2-7/8"DP. Set TWC, change rams,test BOPE. UPR failed twice.Replaced VBR's w/2- 7/8"pipe rams,retested OK—lower TD valve failed.AOGCC advised. October 7"', 2010 Fin testing BOPE,pull TWC.RU floor to run 2-7/8"DP. Rack&tally DP. Strap clean out BHA. MU 4- 3/4"bit&mud motor.RIH PU 2-7/8"DP to 6,208'. Slip&cut drilling wire. Rack&tally more DP. Continue RIB to 7,000'. October 8`h,2010 Cont RIB w/clean out assy PU 2-7/8"DP f/7,000' to 11,476'.Tag plugs&cmt. Drill same f/ 11,476' to 11,565'. POOH, LD motor and bit. MU mill and csg scraper,RIB on DP to 1,309'. October 9t',2010 Continue R111 w/csg scraper to XN-nipple. Displace mud from well w/9.4 ppg brine.POOH LD DP. October 10th, 2010 LD DP and scraper assy. Run CBL. Pressure test casing and annulus.ND BOPE and prep wellhead for installation of tree. October 11`h, 2010 10K master valve too tall to fit under rig. 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(907)561-2465 WELL North Fork Unit#14-25 LOG INTERVAL CASING DATA FIELD North Fork Unit DEPTHS: 178' TO 11700' REGION Kenai Peninsula 10 3/4" AT 2977' COORDINATES 648.47'FSL 1601.52'FEL DATES: 8/19/2010 TO 9/26/2010 8 5/8" AT 2414' Sec 26 T4S R14W SCALE: 2" = 100' 7 5/8" AT 5297' ELEVATION GL:657.80' 5 1/2" AT RT:679.52' MUD TYPES Spud Mud TO 2992' HOLE SIZE COUNTY,STATE Kenai Borough,Alaska API INDEX 50-231 -20035-00-00 13 1/2" TO 2992' TERRA-MAX System TO 11700' 9 7/8" TO 5306' SPUD DATE August 29,2010 TO CONTRACTOR Inlet Drilling 6 3/4" TO 11700' TO CO. REP. Brad Rasch Jim Rickel TO RIG/TYPE Glacier No.1/Land/Double ABBREVIATIONS LOGGING UNIT ML030 NB NEWBIT PV PLASTIC VISCOSITY LC LOST CIRCULATION RRB RERUN BIT Vp YIELD POINT CO CIRCULATE OUT GEOLOGISTS Craig Silva T.Winslow CB CORE BIT FL FLUID LOSS NR NO RETURNS Ralph Winkelman WOB WEIGHT ON BIT CL PPM CLORIDE ION TG TRIP GAS ADD.PERSONS D.Grunwald J.Dubowski RPM ROTARY REV/MIN Rm MUD RESISTIVITY SG SURVEY GAS pp PUMP PRESSURE Rmf FILTRATE RESISTIVITY WG WIPER GAS Z.Mester S.Franzen,G.Ham SPM STROKES/MIN PR POOR RETURNS CG CONNECTION GAS CO.GEOLOGIST Colby VanDenburg MW MUD WEIGHT LAT LOGGED AFTER TRIP V/S FUNNEL VISCOSITY LAS LOGGED AFTER SURVEY ALTERED ZONE l&� CHERT-GLASSY FELSIC SILIC DIKE T MARL-CALC _I SANDSTONE +t ANDESITE le CHERT-PORCEL © FOSSIL . METAMORPHICS 1 11 SANDSTONE-TUFFACEOUS ANHYDRITE CHERT-TIGER STRIPE lib.GABBRO MUDSTONE SERICITIZATION x x BASALT I d CHERT-UNDIFF �}.,GLASSY TUFF r %OBSIDIAN I I SERPENTINE �¢ BENTONITE CLAY . _._ GRANITE PALEOSOL SHALE BBB BIOTITIZATION r_—_CLAY-MUDSTONE GRANITE WASH • c PHOSPHATE 7 SHALE TUFFACEOUS Np i BRECCIA ='CLYST-TUFFACEOUS + GRANODIORITE p PORCELANITE Ic-± SHELL FRAGMENTS CALCARENITE CHLORITIZATION .GYPSUM eC PORCELANEOUS CLYST SIDERITE 7-4 CALCAREOUS TUFF =COAL .HALITE PYRITE I , SILICIFICATION CALCILUTITE ci CONGLOMERATE " HORNBL-QTZ-DIO PYROCLASTICS -- SILTSTONE : CARBONATES ';'..T.' CONGL.SAND . IGNEOUS(ACIDIC) ** QUARTZ DIORITE ;-..t-1 SILTST-TUFFACEOUS LSI CARBONACEOUS MAT CONGL.SANDSTONE . IGNEOUS(BASIC) 2 t QUARTZ LATITE E4 TUFF CARBONACEOUS SH Ls COQUINA :� INTRUSIVES Rib. QUARTZ MONZONITE VOLCANICLASTICS SEDS r CEMENT CONTAM. 1:.1: DACITE K K KAOLINITIC RECRYSTALLIZED CALCITE VOLCANICS CHALK poop_ DIATOMITE '' LIMESTONE `'`` RHYOLITE CRYSTALLINE TUFF »» DIORITE %LITHIC TUFF .SALT ztl CHERT-ARGILL W DOLOSTONE MARL-DOLO SAND 1••1- "wvpar LJuwwyy vn f\V I 0 SOa. """<10 Ethn C-2 10OK>I MCI IIaI na ft/hr units <10 Prop C-3 loot purvey Data,Mud Reports,Other Info. <50 Avg WOB 0> <0 Ctgs Gas 100><10 Butn C-4 100K> klbs units <10 PentC-5 100K> 1 II I '{ 11 I ALL GASES IN THE TOTAL GAS COLUMN ARE A , 1_1 i I �- i■ 4 I MAXIMUM VALUE IN UNITS,MINUS THE I I I 1 IMMEDIATE REPRESENTATIVE BACKGROUND ■ I 11, , GAS.AN EXCEPTION IS TRIP GAS,WHICH IS T 1 ' ' ALWAYS THE MAXIMUM PEAK OF TOTAL GAS t f- I I DURING TRIP RETURNS. i, GAS DETECTION IS BY FLAME IONIZATION METHOD.THE CALIBRATION STANDARD IS 100 1f"Conductor set at 157' 0 0 , I UNITS OF GAS EQUALS 2%METHANE IN AIR. CANRIG USES THE G.S.A.FIELD COLOR CHARTS AS A REFERENCE FOR LITHOLOGY COLOR DESCRIPTIONS. THE CHARTS PROVIDE THE ABILITY TO PRESENT A PRIMARY ROCK COLOR AND SECONDARY COLORATIONS IN A , MORE STANDARDIZED MANNER. BI # T3 1/2" in at 178'8' I BEGIN DRILLING 13:54 HOURS ON Fi-C G'"X C-1 3 x 16,1x14 AUGUST 29,2010 AT 178' rt i + t ± J SAND/SANDSTONE(180'-300')=MEDIUM __ ___ DARK GRAY TO DARK GRAY;UPPER TO LOWER r MEDIUM GRAINS WITH OCCASIONAL COARSE L AND FINE GRAINS;SUB ANGULAR TO ANGULAR C ROUNDING;SPHERICITY IS MODERATE; `— _ I MODERATE TO MODERATELY POORLY SORTED; N - r I GRAIN SUPPORTED SANDSTONE;SANDSTONE • �— MATRIX DIRTLY;SILICEDCOUS CEMENT; �— O = _ SU @ 04' MODERATELY HARD;TRANSLUCENT AND �� ___ IN• ,,,, AZ 56.33 MILKY WHITE QUARTZ;CARBONACEOUS -�_� • = -_-. = TV •'.97 LAMINAE IN FEW SANDSTONE FRAGMENTS; ---- - LITHICS WITH PALE !_ 1 YELLLOW YELLOWISH ORANGE TO VERY PALE ORANGE L-.' -'-' VOLCANICS AND BLACK CARBONACEOUS SHALE; _._._._._._. POROSITY AND PERMEABILITY ESTIMATED • -'-'-'-'-' s GOOD;NO OIL INDICATORS. 1- SILTSTONE(180'-300)=MEDIUM DARK GRAY TO DARK GRAY;BRITTLE TO DENSE -------- =._._._._.• • • • :. TENACITY;IRREGULAR FRACTURE;SUB _._._. NODULAR CUTTINGS HABIT;DULL TO EARTHY .. INC 1. �,@AZ2?,' LUSTER;SILTY TO GRITTY TEXTURE; .01 'MASSIVE OR LAMINAE STRUCTURE;SOME ___. TVD ■;• SILTSTONE FROM 210'TO 240'HAS MICRO __= CARBONACEOUS SHALE LAMINATIONS; -'- I SILTSTONE VARIES FROM SILTSTONE TO AT W =. ! TIMES A SANDY SILTSTONE;NO OIL. _ O = rm.- COAL/CARBONCEOUS SHALE(300'-350')= - - • • 0=III,_ BLACK TO BROWNISH BLACK;LIGNITE;GRADES nsa•- TO LOWER GRADE LIGNITE AND GARB SHALE; 1I l 'COMMON BROWN AND BLACK BANDS;MOSTLY PP" E AND MARGINALLY TOUGH; SU' � 1I 331' MAITTE TO OCCASIONALLY SMOOTH DENSE IN* � (., AZ 57.0 1 DULL LUSTRE;IRREGULAR PLANAR FRACTURE - = I TV" ' AND HABIT;MANY FRAGMENTS DISPLAY - - iii— ALTERNATING COAL GRADES;SOME LARGER ,, FRAGMENTS HAVE TIGHT FIBROUS TEXTURE -_---•------- > �:�� AND IMPERFECT EARLY CLEAT DEVELOPEMENT. .,-s-..,.----_�1s11 ' 1 it ' TUFFACEOUS CLAYSTONE/NON-DIFFERENTIATED . .•= €re CLAYSTONElTUFFACEOUS SILTSTONE(350- - s 400')=CLAYS AND SILTS MOSTLY DERIVED 13_v�rifili I FROM VOLCANIC ASH;ALL CONSTITUENT -='!.....7,4n14.:.-.- ' I TO LITHOLOGIES ARE CLOSELY GRADATIONAL r SU C�389•, EACH OTHER;LIGHT BROWNISH GRAY TO• IN• • • $4.25 • BROWNISH GRAY TO PALE BROWN;MOSTLY __ 1� SOFT TO SLIGHTLY BRITTLE,CONSISTENT O r,_=__ •• MINOR FRACTION OF FIRM AND BRITTLE; :. CLAYEY TO SILTY TO ASHY TO VARIOUS SOFT MATTE TEXTURES;EARTHY LUSTRES;SOME WITH GREATER GLASS MICROSHARDS HAVE MICROSPARKLY APPEARANCE. SAND/SANDSTONE(400'-510)=DIVERSE - •• SAND GROUPS;FROM VERY SILTY-CLAYEY TO --- _ "CLEAN-LOOKING";FROM CONSOLIDATED __ -- SU 451" •ND MODERATELY INDURATED TO ENTIRELY• • • • • IN 1 58.36 DISAGGREGATED AND/OR UNCONSOLIDATED; • • • • ' TV .8 ' LOOSE SAND PRESUMABLY WITH PATCHY,WEAK, r t---1 :SOLUBLE CLAY SUPPORT;DOES NOT APPEAR . . , INTERBEDDED,BUT THIN MASSIVE SECTIONS � I SEPARTED BY CLAY-SILT ZONES;SILTIER �1 SANDSTONE GRADES TO ASSOCIATED VERY - -t, SANDY SILTSTONE;DOMINANT TYPE IS LOOSE SAND:MEDIUM GRAY WITH STRONG OLIVE GRAY Meth C-1 100K SECONDARY HUES;RANGE FROM FINE UPPER <230 •P' 0> G <0 Ttl Gas 100><10 >TO COARSE LOWER,AND PROGRESSIVELY <50 Avg OB 0> O -- <0 Ctgs Gas 100> n C-2 100K>LARGE SIZE MODE TO VERY COARSE WITH g --- :0 g I7RVEY 57�77 SCATTERED GRAINULE IN BASAL ZONES. 1' rop' 3 100K? SL DE 515- 5 .8 SAND/SANDSTONE(51U-705')=MASSIVE <10 ��to SAND SECTIONS;95-100%LOOSE GRAINS; C 1 4 100 r"I EITHER UNCONSOLIDATED AND/OR .I n n__.ne .Hell/.. _____ T PT MEDIUM UPPER TO COARSE UPPER;VERY �y t 1INANT SUBANGULAR;SLIGHTLY IMPROVED .. SUR Y 5' I NDING AS GRAIN SIZE INCREASES;EQUANT 1 ` INC I• AL i•.0 4-SPHERICAL GRAIN SHAPE;BECOMING I- j______y_-__ .81`- H_-_ MORE ANGULAR AND SLIGHTLY MORE ELONGATED WITH IRREGULAR SHARP EDGES AS GRAIN SIZE _-_ 0 DECREASES;MINOR CONSOLIDATED PIECES Os • • • • O I COVER ENTIRE GRAIN SIZE RANGE;MOST CONSOLIDATED SANDSTONE IS SOFT,SOLUBLE O TUFFACEOUS CLAY MATRIX SUPPORTED;TRACE • , '0 TO SPOTTY SANDSTONE WITH COMPLEX MATRIX :..' 0 AND GRAIN SUPPORT;NOTE DISTINCTIVE II ::,=. . . . . . • !: ___:f::,1,.:;i:ii-• • : -. TRACE SANDSTONE WITH CALCAREOUS TUFF INTERGRAIN MATERIAL;NEARLY ALL SURVEY @ 630' COMPOSITIONAL GRAYWACKE(>30%LITHICS) INC 1 44 AZI 89.51 TO MARGINAL LITHIC ARENITE;OVERALL • • • • • • • • • • TVD 629.0' DISTINCTIVE APPEARANCE WITH MANY GREEN COLORED GRAINS CONTRASTED BY SPOTTY I I WELL DISTRIBUTED ORANGISH RED TO ORANGE VOLCANIC LITHICS AND BLACK CLASTIC COAL J AND ARGILLITE GRAINS;ESTIMATE 40-60% .. QUARTZ AND VOLCANIC GLASS GRAINS,TRACE •• _ FELDSPAR,5-10%CHALCEDONY,CHERT AND :• 'OTHER NON-DIFFERENTIATED CRYPTO-SILICA, • 40-60%LITHICS AND MAFIC MINERALS; - LITHICS DOMINATED BY GRAYISH GREEN-PALE • SU EA i�6.9' GREEN-VARIEGATED GREEN LOW GRADE META V - IN 5 AZ 107. 8 GREENSTONE ROCK FRAGMENTS AND DARK TV I6 8. . GRAY TO BLACK MEDIUM GRADE METAMORPHIC ..,...„......._..• • • • ....._• • •SLIDE 696'416 O _ ARGILLITE-PHYLLITE ROCK FRAGMENTS.__ _ ....._ - COAL/CARBONCEOUS SHALE(705'-750')= i BLACK TO BROWNISH BLACK;LIGNITE TO • SUB-BITUMINOUS,SOME GRADES TO GARB SH; 1 COMMON BROWN AND BLACK BANDS; BRITTLE AND MARGINALLY TOUGH TO FRAGILE;DENSE -=rye MATTE TO SMOOTH TEXTURE;DULL TO SUBVIT _=-= LUSTRE;DOM IRREGULAR PLANAR FRACTURE - SU \ 0 749' TO MINOR SUBCONCHOIDAL AND CONCHOIDAL IN 1. ' AZ 1 :.89 j FRACTURE;LARGE PIECES HAVE ALTERNATING THAT SIGNIFICANT •8/30/20'0� N4 7 75 IS PRESENT AS A OCLASTIC CONSTIUENT OF COAL THE COARSER SANDS. MW 8.9 VIS 69 PV 13 YP 34 GELS 22/33/34 33 4 3 j ' FL 14.8 FC 2 Oil/W 0/96 SOL 4.0 SD 0.33 __- - MBT 22.5 CI 500 Ca 100 pH 8.9 Alk 0.25 0p �'- TUFFACE •••••. TUFFACEOUS CLAYSTONE/TUFFACEOUS 1 O 4_ : - SILTSTONE(700'-830')=CLAYSTONE AND SILTSTONE DERIVED FROM REWORKED -€� SURVEY @ 81 VOLCANIC ASH;CONSTITUENT LITHOLOGIES JJ J�-�• — TVD 87`7,72' 14 ARE CLOSELY GRADATIONAL AND SHARE MANY CHARACTERISTICS;LIGHT BROWNISH GRAY TO = 1 7 726 BROWNISH GRAY TO PALE BROWN;SUBTLE ' SLIGHTLY YDBRRITTLE TO MODERATELY FIRM AND O BRITTLE;CLAYEY TO SILTY TO VARIOUS SOFT MATTE TEXTURES;EARTHY LUSTRES;SOME • -WITH ABUNDANT DISCERNIBLE VOLCANIC GLASS • 1 MICROSHARDS HAVE MICROSPARKLY LUSTRE; I NOTE THAT SOLUBLE TUFFACEOUS CLAYSTONE 1 IS THE APPARENT DOMINANT SUPPORTING SURVEY @ 77' MATRIX OF THE DISAGGREGATED SANDS. . . . . INC 1 84', 1 122.24• TVD 876.69' SAND/SANDSTONE(705'-1020')=GENERALLY DIVERSE"DIRTY"THINLY BEDDED SANDS • :O ASSOCIATED WITH THE TUFFACEOUS ROCKS; Om ;• • :O 1 SOME MASSIVE SANDS APPEAR LESS SILTED --- :.':O O AND HAVE THE SAME CHARACTERISTICS AS ,.i,.• ':O O 1I DESCRIBED IMMEDIATELY ABOVE;MEDIUM GRAY yna TO GRAYISH BROWN WITH FAINT TO STRONG :• OLIVE GRAY SECONDARY HUES;SIZE RANGE ---- FROM FINE LOWER TO SCATTERED GRANULES; •_"r' SHIFTING DOMINANT MEAN SIZE FROM MEDIUM :-rte;a'• (LOWER TO COARSE LOWER;NOTE SPOTTY • -'- __• ' . . SURVEY @ 939' FRACTION OF VERY FINE SAND GRADING TO --- -- INC 1.79, AZI 1 '.09 COARSE SILT;CONTINUED EQUANT, ----- - • TVD 938.66' SUBANGULAR GRAINS BECOMING SHARPER _ .. -=-z- --- ••.. EDGED AND ANGULAR AS SIZE DECREASES; CONSOLIDATED SANDSTONE IS SOFT,SOLUBLE TUFFACEOUS CLAY MATRIX SUPPORTED;TRACE ° TO SPOTTY SANDSTONE WITH COMPLEX MATRIX •==== AND GRAIN SUPPORT;NOTE DISTINCTIVE TRACE SANDSTONE WITH CALCAREOUS TUFF a=r� I INTERGRAIN MATERIAL;NEARLY ALL �r= - ' COMPOSITIONAL GRAYWACKE(>30%LITHICS) nom,---- 1 TO MARGINAL LITHIC ARENITE;CONTINUED <200 ROP 0> 0 .�.;.:i • • I Ttl Gas 100>i<10 Met.C-1 100K>DISTINCTIVE APPEARANCE WITH MANY GREEN DL 100591 iy• 0> p • • " _ • . <: Ctgs Gas 100><10 n C•2 100KsCOLORED GRAINS CONTRASTED BY SPOTTY �uRVEY @ e� �VOLCAN C DISTRIBUTED ITHICS AND BLACK CLASTIC COAL GE .. 1tttC 2.34, AZI"•:. 13 100K> • j1\60 1002.62But C-4 100KyTUFFACEOUS CLAYSTONE/CLAYSTONE '-- (1020'-1110')=DARK GRAY TO MEDIUM ROTATE <10 Pet C-5 100K>DARK GRAY WITH OLIVE GREEN SUB HUES; -;; SOFT;POORLY INDURATED;FLEXIBLE TO = ELASTIC TENACITY;IRREGULAR/EARTHY _ ; ) FRACTURE;MASSIVE CUTTINGS HABIT;WAXY -•'' TO DULL LUSTER;GRITTY TO SILTY.•.�.� ii.._ • . TYTO i= xd.- n CLAYEY TEXTURE;MASSIVE STRUCTURE, ;� c ._• SU . 1e: ' CLAYS INTERBEDDED WITH TUFFACEOUS "'°"-° - INC.)c...',79441..•5.19 SILTSTONE,SILTSTONE AND CARBONACEOUS SLIDE 1-075-1 I t m;Zs ▪ - TV e.6.5 1 SHALE;TACKY AND LUMPY CONSISTENCY; --------▪ - CLAY IS COHESIVE,ADHESIVE AND ---▪---- - -- PLASTICY;CARBONACOUS SILTSTONE; :;:z.1.1,47.;•71.3,-:;-• • NO OIL. ROTATE -- _ ' CARBONACEOUS SHALE/COAL(1110'- -------- -- O _ _ --- i i 1170)=BLACK TO GRAYISH BLACK WITH 0 � =� r_�s:- ,.'REDISH BROWN STREAKS;FIRM FRIABLE TO -- ssasi•.•s oan:n _ .1 -. i___ n.�, w.'i u., i STRUCTURE;w ,v,vv,,,, -:^;^^"" ___ 1 i___Tr/D -,.,,Q_ 3 14--_, -.. I THIN TO LAMINAR STRUCTURE;SUB-LIGNITE I cr..-- I II IGNITE COAL;CARBONACEOUS SHALE/ 4 - 1111----r ' _ NO'L IS INTERBEDDED WITH S SILTSTONE; -_-" , ll, OSTONE AND TUFFACEOUS SILTSTONE; __' I /. . - OIL. --- ROTAT - TUFFACEOUS CLAY/CLAY(1100'-1290') -:=.zrn..a.zz, 'MEDIUM DARK GRAY TO DARK GRAY WITH ssz;-,rz.;z�� GREENISH GRAY SUB HUES;SOFT;POORLY '===== ,='s:;= TO MODERATE INDURATION;COHESIVE, =. sss;.s.;.5.; z ADHESIVE,AND PLASTICY;CONSISTENCY IS -"" '""'-"— 1a SURVE .te ' STIFF,SLIMY AND LUMPY;TENACIY IS SLIDE 1195-12 - N -_- -___ -- = INC 7.21,AZI ,04.33 (STIFF TO ELASTIC;IRREGULAR FRACTURE; O ---- ---- TVD 1'92.94', CUTTINGS HABIT IS MASSIVE;GREASY TO -..srrrr�•r�•r�•r�s I I WAXY LUSTER;CLAYEY TO SILTY TO GRITTY TEXTURE;MASSIVE STRUCTURE;INTERBEDDED """" '"""'" ""' WITH CARBONACOUS SHALE I COAL TO 1170' Rl�Tf1T� ---------_=__-= : � AND SILSTSTONE;NO OIL INDICATORS. sz-r rr risasi -=7,,,,,,,,,,,,,,,,,,,,,,, SILTSTONE/TUFFACEOUS SILTSTONE(1110' """"'"'"".3.3.I [ '-1290')=DARK GRAY TO MEDIUM DARK ---------1111-. , II 1 • GRAY;FRIABLE TO FIRM FRIABLE; == MODERATELY INDURATED;TOUGH TO BRITTLE °n 338 1 a§ TENACITY;IRREGULAR FRACTURE;SUB ===== SUR,VEIY @ 1 6: , NODULAR CUTTINGS HABIT;EARTHY TO DULL —SLIDE 1;260-1285 INQ d.93,AZI 10•.3: LUSTER;SILTY TO GRITTY TEXTURE; ___"'j ° TVQI,12�06.31' MASSIVE STRUCTURE;SILTSTONE IS 1r3Y3 INTERBEDDED WITH CARBONACEOUS SHALE/ COAL UNTIL 1170'AND TUFFACEOUS CLAY/ ROTATE - - CLAY THROUGHOUT;NO OIL INDICATORS. .r.•r.•.-.•..-.�•.•.;.-. TUFFACECEOUS CLAY(1290'-1380')= . , MEDIUM GRAY TO MEDIUM DARK GRAY WITH o - --- 5 GREENISH SUB HUES;CLAY IS COHESIVE, 0 =.f.f=4T-T•f:t �� - ADHESIVE AND PLIABLE;CONSISTENCY IS ------------- 'STIFF AND LUMPY;TENACITY IS SIFF TO .zni SURE @ ' ELASTIC;FRACTURE IS IRREGULAR; SIIn 1322-134 INC 1047,AZI 105.55 CUTTINGS HABIT IS MASSIVE;LUSTER IS 118.40' WAXY TO DULL TO EARTHY;TEXTURE IS CLAYEY TO SILTY TO GRITTY;STRUCTURE IS z .-..z...�z..z MASSIVE; SAND ENTRAINED WITH IN CLAY ROTATE :- t r: INDICATIVE OF THINLY BEDDED SANDS; -- --..... - SAND IS LOWER FINE TO UPPER VERY FINE, ..7.-1,,17-17.-17.-17.;;;;•1•7-1-7 4:1_132, �! VERY WELL SORTED,ROUNDED WITH HIGH _ -_ _ _ SPHERICITY,SAND IS QUARTZ WITH SOME -----1717---- VOLCANICS;BLACK CARBONACEOUS MATERIAL --------- 1111 -z ALSO PRESENT OF FINE GRAINED SIZE;NO .;-1-7,-;-1-7r1;;;;;;;-1-7,1-1 OIL INDICATORS. SUi2VEY @ 13 TUFFACEOUS CLAY(1380'-1470')=DARK ".." S41DE 1 INC 11 91, AZ 03.85 GRAY TO MEDIUM DARK GRAY WITH GREENISH =='='=== NDI 13�1.18' (GRAY SUB TONES;SOFT;POORLY TO ..•.az- .z.z=�• MODERATELY POORLY INDURATED;COHESIVE, o �:.Q;z..z..z..�.�- 1 j ADHESIVE AND PLIABLE CLAY WITH STIFF 0 -==-=4:z====• • f__ ' 1 AND TACKY CONSISTENCY;STIFF TO ELASTIC ROTAT r.:.��z�z::r.z_ 1 I TENACITY;IRREGULAR FRACTURE;MASSIVE ----------_ ' CUTTINGS HABIT;DULL TO EARTHY LUSTER; - - CLAYEY TO SILTY TO GRITTY TEXTURE; _- _ � MASSIVE OBSERVED STRUCTURE,THOUGH -____ _ _ / ACCESSORIES INDICATE VARYING BED - THICKNESSES OF CLAY,CARBONACEOUS ---------- --- - SURVEY @ 1446' SHALE AND SAND; ALSO PRESENT IS SAND -1713-- ------ INC 13.05, AZI ;51''' _ SILTSTONE AND CARBONACEOUS SHALE; SLIDE 1450-147 -= 1111ND 1440.74' SAND IS UPPER FINE TO LOWER FINE --fffi3R2TZS �s GRAINED QUARTZ;CARBONACEOUS SHALE ------------------- - , === GRAINED _ ) LAMINATED BED NO OIL INDICATORS. _ ; ' I LA BEDS; ROTATE ."._.__.__-_ MW 9.0 VIS 58 PV 16 YP 28 GELS 12/25/26 N -_ jTily FL 12.8 FC 2 Oil/W 0/95.5 SOL 4.5 SD.33 <2,0 OP 0> <� Ttl Gas 100><10 -I Meth r_ MBT 22.5 CI 1100 Ca 40 pH 8.6 Alk 0.20 0 1 ____ 100K>TUFFACEOUS CLAY(1470'-1560')=DARK <50 Av WOB 0> 0 =-17.----.,.-.1.1.1.1--..;.-.4-1.1.......______ <, Ctgs Gas 100><10 Ethn -2 100K>GRAY TO MEDIUM DARK GRAY WITH GREENISH GRAY SUB HUES;SOFT;MODERATELY SLIDE 151 TO POORLY INDURATED;ADHESIVE,COHESIVE ...,...,...,.r '• J`[qt9RVEY @,,qq��$'U'C-3 100K'AND PLIABLE CLAY PROPERTIES;STIFF AND --_ 5213 1TS "rvD 1504.87**--,, - 100K'TENAC TENACITY;IRREGULR FRACTURE;MASSIVE ••• -- <10 Pe C-5 100K''CUTTINGS HABIT;EARTHY TO DULL LUSTER; X U IS LAY Y TO ILTY TO RITTY; ROTATE ___._................_."_._ MASSIVE STRUCTURE OBSERVED;SILTSTONE - -- - =- r' AND AMBER QUARTZ GRAINS AS WELL AS 111 III BERIN INTERPRETED AS FINELY BEDDOED WITHIN - ; ' -4 THE CLAY;PALE ORANGE VOLCANICS ALSO .1 PRESENT;NO OIL INDICATORS NOTED. -_ -- SURVEY @ 157 SLIDE 1575-1605 - ------------ INC 15.80, AZI•9.54 TUFFACEOUS CLAY(1560'-1620')=DARK -_------- -- TVD 1565.70' IGRAY TO MEDIUM DARK GRAY WITH GREENISH -4-41 __=.3..1.:-:- [BLACK SUB TONES;POOR TO MODERATELY ' POOR INDURATION;SOFT;COHESIVE, p� -z3 .Sr 25_- ADHESIVE AND PLIABLE CLAY PROPERTIES; 0 - -- -1x.21.1. I I CONSISTENCY IS STIFF AND TACKY;STIFF ROTATE 0 __ =T'1�_ , TO ELASTIC TENACITY;IRREGULAR ""- ll ' IFRACTUREMASSIVE CUTTINGS HABIT;EARTHY �T��T�.. EARTHY TO DULL LUSTER;CLAYEY TO SILTY TO GRITTY TEXTURE;MASSIVE STRUCTURE; ....""_"....".. SURVEY @ 1638 -- m =� CARBONACEOUS SHALE,CARBONACOUS SILT _=_=a ?} 'AND SILTSTONE;NO OIL INDICATORS. ;-.-...-,--.. ..-3..:s;;.1;;;;;,.-...ii.:. ' SURVE26.06`, SLIDE 11631-167 ; ,.;1.�5,.,.� '7` INC 17.45, AZI 99.'' TUFFACEOUS CLAYSTONE/TUFFACEOUS .. =.:1 z.;zla SILTSTONE(1620'-1890')=CUTTINGS ----- -4111-- RETURNS ARE WELL HYDRATED SOFT -4111 -- CLAYS AND SILTS;TUFFACEOUS LITHOLOGIES 1111 ----=1:f ARE DERIVED FROM REWORKED VOLCANIC ASH -- -----Szr ; AND SHARE MANY CHARACTERISTICS; ----- --- .-, i LIGHT BROWNISH GRAY TO BROWNISH GRAY V4'I,ZiPa'°':i.1.1" . 'ai TO PALE BROWN;MANY SUBTLE GRAY AND -__--- _---- BROWN SECONDARY HUES;DOMINANTLY VERY _-.-.--_: •_:__r .. SOFT TO SOFT WITH CONSISTENT MINOR � _ �� . n .___l 1 __ sv rY�.�1 �. 1[1111-ORGANIC CONTENT IS HIGH,IS NOT READILY ---- UBLE AFTER HYDRATING;GOOD TO .kt..�zs*•'▪▪ �'*""ii3 --+• -- O AD E ADHESIVENESS;NE ;CT VERY GOOD TO '-_ _- �D ADHESIVENESS;CUTTINGS COME ROTATE_._ __________ OVER THE SHAKERS AS LARGE STICKY ------------- I I �'SHEETLIKE"LUMPS;SAMPLES ARE DIFFICULT —_- !. TO CLEAN;CLAYEY TO SILTY TO ASHY TO rr. -=-..1.1q•-..a.-..3•111 VARIOUS SOFT MATTE AND MIXED(MOTTLED) —— I TEXTURES;EARTHY LUSTRES;SOME OF THE —__..•...._•..,• TV SURVEY @ 1744.83'1 64 CLA STONE HAS ABUNDANT FLOATING SAND S.IDE 1767-1 :: ' °---- IN 2131, 199 18 GRAINS,IS CLOSELY GRADATIONAL TO VERY —=='= -_rvsss r" i`I CLAYEY SANDSTONE AND OFTEN HAS A :-..7-1.-A-7.;,.......-.....iii- MICROGRITTY TEXTURE;WHEN VOLCANIC r MICROSHARDS ARE DISCERNIBLE AND _=-rrrr=r:•r.s.•_ '-__ "▪ "'-- LOCALLY ABUNDANT THE CLAYSTONE/SILTSTONE =s 1-Y OFTEN HAS A MICROSPARKLY LUSTRE; ..▪........-............rrr ------------ - CLAYSTONES ADJACENT TO COALS AND co p0 szn-.rr..zaz•�rr' �•�'� CARBONACEOUS SHALES OFTEN HAVE A DARKER •..7.1.....3.1:1-14•.......-_irra --------------- BROWN COLOR AND PROMINENT ORGANIC•z==�SiiTZ'j� MATERIAL;MIXED IN WITH THE PERVASIVE "`°==='"=°===•"i ' III III I Ill GRAY CLAYSTONE ARE"BLEBS"OF LIGHTER —=.f=-==== GRAY,LESS REWORKED-LESS DISTURBED SURVEY©1829'! VOLCANIC ASH-RICH TUFFACEOUS CLAYSTONE. SLIDE 1829-1-.:•[ -._-.�.y:.y.�z:..si INC 23.09, AZI 9:.30 --- -_- _ TVD 1805.01', TUFFACEOUS CLAYSTONENOLCANIC ASH/ ▪ - - I CALCAREOUS TUFF(1820'-1890')=NOTE ==▪ ====---z=• =-▪ - r THAT TUFFACEOUS CLAYSTONE BECOMES =.___...=.=s=:€: SLIGHLY"ASHIER"OVERALL AFTER 1820', - --'9:i ' AND SOME TRANSITIONS TO LESS REWORKED cA`' ,. .£= -- VOLCANIC ASH WITH SIGNIFICANT INCREASE ROTATE IN GLASS MICROSHARDS;TRACE TO SPOTTY .-.•...z rier BY SHARD-RICH MATERIAL;AL •33`+�� rr s• I NOTE TRACE TO SPOTTY HARD FRAGMENTS OF •Yy_ SURVEY 1851' I J CALCAREOUS TUFF WITH DISTINCTIVE DARK r` 2, A2I 9:.74 YELLOWISH ORANGE COLORATION;CALC TUFF SLIDE 1893 1928 TVD 1861.65 APPEARS ASSOCIATED WITH TRACE OF"CLEAN" CALCITE CEMENTED GRAY FINE TO MEDIUM 0 �..: SANDSTONE,SOME OF WHICH ENCLOSES IMPERFECT ALTERNATING MICROLAMINATIONS j j. OF COAL AND ASH. MW 9.25 VIS 53 PV 15 YP 25 GELS 10/25/29 ROTATE = FL 12.5 FC 2 Oil/W 0/94.5 SOL 5.5 SD.33 1 MBT 22.5 CI 1200 Ca 40 pH 8.4 AIk 0.10 COAL(1890'-2080')=BLACK TO BROWNISH _:::=. __ SURVEY @ 1954' BLACK;LOWER GRADE LIGNITE TO MEDIUM 8/31/2010 INC 26.66. AZI 98:40 GRADE SUBBITUMINOUS;MOSTLY MEDIUM TO SLIDE 195'-1993 ....'; TVD 1918 37' HIGHER GRADE LIGNITE;BRITTLE,FRAGILE TO TOUGH;VERY DENSE MATTE TO SMOOTH 7777 TEXTURE;DULL TO SUBVITREOUS TO MINOR VITREOUS AND RESINOUS LUSTRES;SOME OF O T THE LOWEST GRADE LIGNITE GRADING TO O TO SU BCON SHALE;IRREGULAR RARE BIRDEYE <200 P 0> G <0 TttI Gas 100><10 Meth C 100K FRACTURE;DISCERNIBLE LAMINAR BANDING ROTATE r! <50 Avg WOB 0> <0 Ct s as 100><10 Ethn C- 100K ND ZONING OF DIFFERENT COAL TYPES AND GRADES;RARE CLEATING ON SOME FACES. ` `I9IRVEY @P6c(l,C 100K,SAND/SANDSTONE/CONGLOMERATIC SANDSTONE SLID E2021-2056 J F ,28.42, I.A7C8 ..,,,,,,?1(1890'-2080')=MEDIUM DARK GRAY TO DARK 1 TVD 1975.17'1 GRAY WITH OCC FAINT OLIVE GRAY SECONDARY 7777 <10 Pen 100K'HUES;FINE LOWER TO GRANULE;MOSTLY 7 .' __ MODERATELY SORTED IN MEDIUM LOWER TO _-_ - • • • • • • I VERY COARSE LOWER RANGE;ANGULAR TO • ' ' ' • SUBANGULAR;MOSTLY EQUANT TO SLIGHTLY ELONGATED AND SUBDISCOIDAL SHAPE;COM ROTATE_ C• • • _ TUFF CLAY-ASH MATRIX SUPPORT;ABNT MIXED • ' • • ' GRAIN AND MATRX SUPPORT WITH WEAK SILIC- CALC CMTTN AND INTERGRAIN CLAY-SILT; COMPOSTIONAL GRAYWACKE;V ABNT(40-60%) NIIPEI�TRIP @ -:-= - PHYLLITE METALITHICS;TR MICROCGL CLASTS WIPER TRIP GAS 26 u --- ' • ' ' ' SURVEY©294.131' SILTSTONE/TUFFACEOUS SILTSTONE(2080' —.• • • ' • . ' ' INC 29.47', AZ 7.99 '-2190')=MEDIUM GRAY TO MEDIUM LIGHT N _- N O 2030.24' GRAY,BLUISH GRAY SUB TONES,BLACK O I CARBONACEOUS SHALE YIELDS SALT AND O -—— PEPPER APPEARANCE AT TIMES;HARDNESS — - - RANGES FROM SOFT TO EASILY FRIABLE TO --- FRIABLE;DENSE TO CRUMBLY TENACITY; III I 'IRREGULAR AND PLANAR FRACTURE;MASSIVE CUTTINGS HABIT;EARTH TO DULL TO LUSTER; iii-iii SILT TO GRITTY TEXTURE;LAMINAE STRUCTURE;INTERVAL ALSO CONTAINES SLIDE 2146-21 '1 ..r. SURVEY @ 2145' CARBONACEOUS SHALE WHICH IS INTERBEDDED " '- INC 29.97, AZI .07 WITH SILTSTONE IN MICROLAMINATIONS; _--___T`".r_o:3€ i TVD 2085.84' I I CARBONACEUES SHALE,BLACK TO GRAYISH '1€ BLACK WITH BROWNISH RED STREAKS,HARD TO zz ;� � MODERATELY HARD,BRITTLE TENACITY, ROTATE __- _ IRREGULAR FRACTURE;WAXY LUSTER,MATTE ==={s''r3 - TEXTURE,AND LAMINAE STRUCTURE;• 4r14r€ i MEDIUM GRAINED,TRANSLUCENT QUARTZ ;fj ` WITH ANGULAR ROUNDNESS AND SPHERICAL _ M SPERICITY ALSO PRESENT.NO OIL. N S rr ._ N = CARBONACEOUS SHALE/COAL(2190'- -S3i31 . _ O = SURVEnY @ 2206' 2280')=BLACK TO GRAYISH BLACK TO DARK O = .3+H. INC 31 13, AZI 98 GRAY;FRIABLE TO MODERATELY HARD;POOR SLIDE 2209-2240 -- TVO 2138.39' ITO WELL INDURATED;BRITTLE TO DENSE ——-.--114-144 TENACITY;CONCHOIDAL IN MATURE COAL, r34' PLANAR FRACTURE IN COAL AND CARBONACEOUS - a4 SHALE;CUTTINGS HABIT IS MASSIVE OR ti TABULAR;LUSTER IS DULL TO WAXY;MATTE ROTATE— _ • ITEXTURE;LAMINAE TO THIN STRUCTURE; - COAL AND CARBONACEOUS SHALE AT TIMES 0 ARE INTERBEDDED,CARBONACEOUS SHALE --- ALSO INTERBEDED WITH SILTSTONE,BEDDING _—= rrsrs C RANGES FROM LAMINATIONS TO THIN BEDS; ——_ ��€" I LIGHT GRAY TO GRAY SILSTONE GRADES TO -=3 • j SURVEY @ 2271'; CARBONACEOUS SILTSTONE;TRANSLUCENT t; F L 10.0 �,« FC 2 Oil/VV SOL 7.0 SD 0.33 T 22.5 CI 1700 Ca 40 pH 8.6 Alk 0.20 -- : -1 i' .BONACEOUS SHALE/COAL(2280'- o - -_- €; I 2420')=DARK GRAY TO GRAYISH BLACK TO - I BLACK;FIRM FRIABLE TO MODERATELY HARD; MODERATELY TO WELL INDURATED;BRITTLE SURVEY©2335 TO DENSE TENACITY;BLOCKY,PLANAR AND INC 33.23, AZI 98.64 CONCHOIDAL FRACTURE DEPENDING UPON rra:' TVD 2247.24' ,, t MATURITY OF CARBONACOUS MATERIAL AS IT ' :::" GRADES TO COAL;MASSIVE AND AT TIMES PLATEY CUTTINGS HABIT;WAXY TO DULL LUSTER;MATTE TEXTURE;STRUCTURE RANGES FROM LAMINAETED BEDS TO THIN BEDS,AT - - TIMES MICRO LAMINATIONS OF VARIOUS €�r€3 /// CARBONACEOUS MATERIAL INTERBEDS HIGHER ---- GRADE COAL,OTHER TIMES INTERBEDDED --- 1, , WITH CARBONACEOUS SILT;TRANSLUCENT --- — i SUR_VE Y@ 398' _ QUARTZ GRAINS,PALE YELLOWISH ORANGE INC 33. 5, ivI t8. 1 . 1VOLCANICS AND SILTSTONE ALSO PRESENT. A -- 111 TVD 2299.90' 00 --.. .. .... :. SAND/SANDSTONE(2420'-2720')=MEDIUM ! 'DARK GRAY TO DARK GRAY;OCCASIONAL FAINT — _ OLIVE GRAY TO OLIVE BLACK SECONDARY ;HUES;SPOTTY"DIRTY"GRAYISH SALT AND _-- 'PEPPER APPEARANCE WHEN COARSE AND I 111'1= ■ LARGER;RANGE FROM FINE UPPER TO RARE • • GRANULE(CONGLOMERATE);MOSTLY ' MODERATELY SORTED FROM MEDIUM LOWER TO (COARSE UPPER;NOTE THAT CONSOLIDATED SANDSTONE PIECES DISPLAY BETTER SORTING • ' THAN THE OVERALL LOOSE SAND GRAINS; _ SURVEY @ 2462') ANGULAR TO SUBANGULAR;MOSTLY EQUANT TO INC 33.37, AZI 99.10 SLIGHTLY ELONGATED AND SUBDISCOIDAL -- • • ' TVD 2353.35' \ SHAPE;NOTE CONSISTENT LARGER FRACTION L , _.„,::::::::: • __„„„,„ • • ...... . . __ __ OF CONSOLIDATED SANDSTONE CUTTINGS FRAGMENTS THAN DISAGGREGATED LOOSE L,� N j.• — GRAINS;SANDSTONE C IS BOTH GRAIN AND MATRIX SUPPORTED;COMMON TUFFACEOUS <200 ROP 0> <: Ttl Gas 100><10 Met -1 100K>CLAY-VOLCANIC ASH FRAGILE,SOLUBLE 3€€z- <� Ctgs Gas 100><10 Ef hn�h GRAIN SUPPORT;ABUNDANT A(DOMINANT) ) <50 Avg O 0> j €€J 0 E(hn 2 100K GRAIN SUPPORTED WITH SILICA(DOMINANT) _ AND CALCITE CEMENTATION;ALSO ABUNDANT 9 ZZ O 9 i 2 100K> SANDSTONE WITH COMPLEX MIX OF INTERGRAIN MATERIAL INCLUDING CLAY-SILT,SILICA- at 1 @ CALCITE CEMENTS SHARD-RICH VOLCANIC ASH, �'- • • ' J 33:52 •i. g 100K UNDIFFERENTIATED SILICA MICRO-PARTICLES €a • • • : j1VD 2405 09Pent C•5 100K ND AND REPLACEMENT MINERALIZATION OF NY OF THE ABOVE;NOTE THAT MANY CUTTING • • . . . FRAGMENTS AND(LARGE)INDIVIDUAL GRAINS -' ' • HAVE MICRO-AND MACRO-FRACTURES FILLED ' ' 'BY BOTH SILICA AND CALCITE. • • • 1 'SAND/SANDSTONE(2420'-2720')=NEAR 100% - IS COMPOSITIONAL GRAYWACKE(>30%LITHIC • , 'FRAGMENTS);ESTIMATE 30-50%QUARTZ AND VOLCANIC GLASS GRAINS,TRACE FELDSPAR, '' TR-15%CHALCEDONY,CHERT AND VARIOUS • ' ' ' ' ' . . SUR�i':Y @ 2587' UNDIFFERENTIATED CRYPTOSILICA,40-70% INC 302 AZI 99.:4 LITHICS AND MAFIC MINERALS;80-85%OF N . ' TVC 457.61' LITHICS FRACTION IS MEDIUM GRAY TO DARK 0 • • ... i GRAY SCHISTOSE PHYLLITE ROCK FRAGMENTS, : • 5-10%ARE DARK GRAY TO GRAYISH BLACK ASSOCIATED ARGILLITE FRAGMENTS,5-10% , • LOW GRADE META GREENSTONE ROCK FRAGMENT' AND REMAINING TR-5%ARE DIVERSE IGNEOUS, • • • •••'• META-IGNEOUS AND SEDIMENTARY LITHICS; • MINERALS ARE MOSTLY BLACK OR OTHER DARK .. COLORS AND,EXCEPT FOR AUGITE,BIOTITE 1 SAND GREENSTONE-GROUP MICAS,NOT EASILY • • • • " " "�y.. • • IDENTIFIABLE;NOTE THAT SOME LARGE VERY SUR\ Y @ 2650' I COARSE TO GRANULE CLASTS ARE LITHIC ROCK INC 33 54, AZI 99.4 FRAGMENTS OF HARDER SANDSTONE AND - ND 25555510.13' MICRO-CONGLOMERATE;NOTE LOCALLY COMMON CLASTIC COAL IN SANDSTONES ADJACENT TO • ......... .0 I I COAL ZONES;NOTE THAT BASAL ZONES OF MASSIVE SANDSTONES HAVE TRACE TO MINOR CONGLOMERATIC SAND AND CONGLOMERATE. ;ti A.. • N 'MW 9.5 VIS 49 PV 19 YP 18 GELS 5/18/22 V s _.• •• FL 7.2 FC 2 Oil/W 0/94 SOL 6.0 SD 0.33 00 ..../741-i-- • • • MBT 22.5 CI 1700 Ca 40 pH 9.0 AIk 0.35 '_.• SURVEY @ 2713' 9/01/2010 _• • • • • • INC 33.60, AZI 99.49 DIVERSE LITHOLOGIES(2630'-2880')=NOTE - '-- • • • •'• •• ___ MANY VARIATIONS IN CHARACTERISTICS FOR --_.. . 2 62 ALL LITHOLOGY TYPES;SIGNIFICANT CALCITE f:144: " • CEMENTATION AND REPLACEMENT;ESPECIALLY { i PROMINENT ARE:GRAY COLORED CALCAREOUS _. TUFFS,A NON-TUFFACEOUS BRITTLE TO HARD MEDIUM LIGHT GRAY SILTSTONE PLUS AN - • • ' ASSOCIATED COARSENING UPWARD VERY j SILTY VERY FINE HARD SANDSTONE,A SMOOTH O DENSE HARD NON-TUFFACEOUS CALCAREOUS LIGHT GRAY CLAYSTONE,COARSER SANDSTONES _---_- THAT ARE MATRIX SUPPORTED BY BOTH NON- - C- CRYSTALLINE AND CRYSTALLINE CALCITE(AND :.':0 SURVEY @ 2777' SILICA),SPOTTY MATRIX SUPPORTED INC 33.96, AZI 99.35 SANDSTONE THAT DISPLAYS BRITTLE TO HARD • TVD 2615.81' CALCITE SILICA REPLACED INTERGRAIN N • ..... ,VOLCANIC .'. 0 APPEARGRAIN SU PORTED BY PYR TI ED o I C • • • ' INTERGRAIN MATERIAL;MANY"FRESH CUT" • BEDDED COAL FRAGMENTS AND LITHIC CLASTIC COAL FRAGMENTS ARE PYRITIZED;INCREASING • :.':O AMOUNTS OF COAL HAVE A VITREOUS J APPEARANCE AND CONCHOIDAL FRACTURE;MOST • I OF THE SAND/SANDSTONE IS AS DECRIBED ' r ABOVE,BUT IS LESS WELL SORTED,AND MAY SU WE i1: 2840' ALSO BE BIMODAL IN PART. - -€i- • . . 0 IN 33.95,AZ 99.86-' TV �f 8.01' / ' CARBONACEOUS SHALE/COAL(2880'- I1 ' 1_ I __1 !I _ I IN MORE MATURE COALS;PLATY AND MASSIVE= I -,__ TINGS HABIT;WAXY TO DULL LUSTER; ) I___ I TE TEXTURE;LAMINAE TO THIN BEDS, I i � cBONACEOUS SHALE HAS LAMINATED BEDS • • I ' . OF VARYING DEGREES OF CARBONACEOUS 0 S •- 90 MATERIAL MIXED WITH SILT;COAL IS p v-}qs i :: IN_ 1 7 l ' 7 _ _ HOMOGENEOUS BUT STILL DISPLAYS SOME t x ' )wl ' LAMINAR DEVELOPEMENT. ---vv$°r :•• S I • 1 t 9 1, 'SAND/SANDSTONE(2880'-2990')= -°= va a7..,.-• M DIUM TO UPPER AFINE GRAINED;SPHERICAL II'- .vrvrvvb= • i i TO SUB DISCOIDAL;SUB ROUNDED TO r ' ROUNDED;WELL SORTED;UNCONSOLIDATED 6:.,,,c-E=4.71:17:=• :. ■ SAND,MODERATELY CONSOLIDATED SANDSTONE; GRAIN SUPPORTED;TEXTURALLY AND .II COMPOSITIONALLY IMMATURE;QUARTZ 80%, Bi # 2814' 44.7 .rs = $ ± I PALE YELLOW ORANGE AND MODERATE PINK –v VOLCANICSPRESENT;POROSITYAND Glade 2 21SS-A-E-1/16 • - D =_: lift g PERMEABILITY VISUALLY FAIR. Sect 10 3/4"Casing at 29 '_ i3€;€ Casing Point drdle rvto 2992' 'DRILL TO 2992'.SET 10 3/4"CASING AT I ' _ at 09:05 Hrs o 9f61/2010 2977'.CEMENT IN PLACE.NIPPLE DOWN 92/022/P0101p 9/06/ I I 0> �" C €a F./ T WG 34u DIVERTER AND NIPPLE UP BOP.TEST BOP. 000000 1 0 Ttl tSfie 6u 100><10 Meth C-1 100K>DRILL OUT TO TOP FLOAT WITH DUMB IRON. HCC HCD 0> O `r`z:€3 -, ' 'I 9 - P/U DIRECTIONAL BHA. SWAP OVER MUD -N t#3,9 i �B2e92' 0 =- as Ctgs Gas 100><10 Eth C-2 100K-- SYSTEM TO TERRA-MAX.PRESSURE TEST :._rr„ <ARVEY© C9 04 '=":::-.741.7,:,.-▪ vrvv 100K>CASING TO 1600PSI FOR 30 MINUTES.DRILL _ 1.�• OUT SHOE TRACT AND 20'NEW FORMATION. •=b ezt 100K> Jt�C PERFORM FIT=13.4 EQMW. TVD 2813.8'8 , ..-,--`r•r.... <10 Pen C-5 10GK},MW 8.9 VIS 45 PV 11 YP 13 GELS 4/8/ .4-sii.; FL 8.8 FC 1 OiI/W 0/96 SOL 4.0 SD Tr ------ =•r-ter:•,- ------ � • • :. MBT 3.0 CI 18000 Ca 440 pH 11.2 AIk 1.1 • . ==s -= :.:. J TUFFACEOUS CLAYSTONE/TUFFACEOUS SILT- __ _ _ = 322_ :... V___ ; ! STONE(3000'-3130')=LIGHT TO MEDIUM _ = 4_ _ • . 1 LIGHT GRAY WITH VERY LIGHT BROWNISH GRAY z ' • •'• ___ SECONDARY HUES;VERY SOFT TO SLIGHTLY - __= 4 FIRM;IRREGULAR TO SHAPELSS CUTTINGS; ▪1 ' i; SURVEY @ 3079' SILTY TO CLAYEY TEXTURE;DULL TO OCCAS- - NC 33.82,AZI 99.19 1 ZONALLY SPARKLY LUSTER;MODERATELY SOL- TVD TVD=2866.20' ' 1, UBLE;HYDROPHILIC;MODERATELY EXPANSIVE; nr,.. - , i1� POOR TO FAIR COHESIVENESS;FAIR TO GOOD �"� __ r� ADHESIVENESS;MODERATE TO VERY CALCAREOUS rpr.- I I I, TRACE VERY DARK BROWN TO BLACK MICROTHIN O ."9: • • • ••• � CARBONACEOUS LAMINATIONS AND PARTICLES; TRACE THIN COAL BEDS. . = z 1 � �l COAL/CARBONACEOUS SHALE(3100'-3200')= _ I _ ' 1 '1' BLACK WITH DARK BROWN AND DARK GRAY SEC- 'z▪"-' @ / ONDARY HUES;HARD TO BRITTLE AT TIMES; I -- --- a3 €3Z1�. -- ----. . — MASSIVE,IRREGULAR FRACTURE OVERALL WITH =▪ z:z:z SURVEY 3141' PLANAR FRACTURE COMMON ON MORE DEVELOPE INC 33:54,AZI 99.14 COALS,SHALE TENDS TO BE MORE IRREGULAR; I i �, _-- 'TVD= 917.79' ' SMOOTH TO SLIGHTLY GRITTY TEXTURE;DULL 4 i ==== na `- I I TO EARTHY LUSTER;COMMONLY PRESENT AS ' '47.- THIN BEDS IN DOMINANTLY SILTSTONE/CLAY- vi STONE FORMATION;NO VISIBLE OUTGASSING. -1 __ 3 Z` I TUFFACEOUS CLAYSTONE/TUFFACEOUS SILT- STONE(3180'-3260')=LIGHT TO MEDIUM LIGHT GRAY WITH LIGHT BROWN TO LIGHT I to =-r, 'BROWNISH GRAY SECONDARY HUES;SOFT TO s"-- CU O ---- • ° SUR Y 3205 TINGS;SILTY TO CLAYEY TEXTURE;DULL INC 40,AZ 99.•- LUSTER;MODERATE TO VERY SOLUBLE;MODER- - '' ▪ L € -'971.181– ATELY EXPANSIVE;HYDROPHILIC;POOR COHE- - - -r F.-.1z SIVENESS;POOR TO FAIR ADHESIVENESS;NON —Uziz TO SLIGHTLY CALCAREOUS;TRACE BLACK _ '_== 'Ll. �,K —t MBT 3A CI 22500 Ca 80 pH 10.5 Alk 1.0 I =F.FLI °tl 8 II-.- III__ L/CARBONACEOUS SHALE(3420'-3520')= Z.••. ° I IF III--II__I I SECONDARY HUES;FIRM TO MODERATELY HARD; –"– �a,z <0� Ttl 1 1+ II' r i III__ IO` BRITTLE AT TIMES;IRREGULAR SHAPED;OCC- ASIONAL PLANAR FRACTURE PRESENT;SMOOTH rr II TO SLIGHTLY GRITTY TEXTURE;DULL,EARTHY <200 OP a> — --- J II L:,•, ( TO MATTE LUSTER;NO TO TRACE VISIBLE OUT <50 A .WOB 0> + Ct s Gies 100 + 1 1� " GASSING BUBBLES PRESENT;PRESENT AS THIN O I "O BEDS IN DOMINANTLY CLAYSTONE/SILTSTONE __ n >FORMATION. — —-- :: �� + I� o SANDSTONE/SAND(3500'-3580')=MEDIUM•=__ _= i cGl: . 0• GRAY TO GREENISH GRAY AND DARK GRAY SEC- 3 r •' ;1'1'• ONDARY HUE;HARD TO BRITTLE;VERY FINE h-f•,,-:▪2S { t ��u� ' I 'LOWER TO FINE UPPER;ANGULAR TO CAREOU- OK _ [ULAR;VERY WELL SORTED;VERY CALCAREOUS CEMENT;INDIVIDUAL SAND GRAINS DOMINANT- -7.717:i{pm4- LY CLEAR TO TRANSLUCENT QUARTZ AND VOLC- j ====T4��T° . j__ �__ I ANIC GLASS;MEDIUM TO DARK GRAY,BLACK, I ___ f a 111 N fi11!l I III II cn-;z �'�MEDIUM TO DARK GREENISH GRAY;VERY FINE LOWER TO MEDIUM LOWER;WELL SORTED;ANG- =a- sii� ULAR TO SUBANGULAR;LOOSE GRAINS DOMIN- _ — ; I ANTLY SUSPENDED IN CLAY FORMATION;TRACE L_ ==- } SU` " , THIN COAL/CARBONACEOUS SHALE BEDS. _f.Tt5 ...ivies--• 14.01;•!:I' • I'• I 't I TO MEDIUM LIGHT (3570' RAY WITH A)MODERATE O �,.�:,z. • • I 1 —"'SALT AND PEPPER APPEARANCE,INDIVIDUAL O I GRAINS DOMINANTLY CLEAR TO TRANSLUCENT ;_:: , 1 QUARTZ AND VOLCANIC GLASS,MEDIUM TO — ____ - - ..... 'rv3 -14 DARK GRAY,BLACK,LIGHT TO MEDIUM GREEN- - L.,.r iia ' ISH PER,DO GRAY;VERY FINE UPPER TO MEDIUM UP- i i L PER,DO DOMINANTLY FINE LOWER TO UPPER;ANG ' ULAR TO SUBANGULAR;MODERATELY WELL �. ,�I SORTED;DOMINANTLY UNCONSOLIDATED WITH _-- - s=•=+zxxx r OCCASIONAL VERY CALCAREOUSLY CEMENTED _."•„z.,3ii3• - I SANDSTONE FRAGMENTS;VERY HARD;BRITTLE �,, z}zxi _ SUl2 @ 3 49' AT TIMES;TRACE THIN COALS;TRACE MEDIUM 33i3i INC : 0, A j1 98.:• GRAY ASHY TUFF;VERY CALCAREOUS. ! --- TVA ', 3.54' it I TUFFACEOUS CLAYSTONE/TUFFACEOUS SILT- ' STONE(3640'-3720')=LIGHT TO MEDIUM --.......,-77- -" . . LIGHT GRAY WITH LIGHT BROWNISH GRAY SEC- ------- ONDARY HUES;SHAPELESS,GLOBULAR CUTTING —_ -' SILTY TO CLAYEY TEXTURE;DULL TO GREASY w 'LUSTER;HYDROPHILIC;VERY SOLUBLE;EXP- ===== 7.ii,•- :..' SURVEY ANSIVE;POOR COHESIVENESS;FAIR TO GOOD O =;;`� � ADHESIVENESS;NON CALCAREOUS;TRACE DARK _--; �I I I BROWN TO BLACK MICROTHIN CARBONACEOUS V . . "�': ......_-.. • • EY @ 3712' LAMINATIONS AND INCLUSIONS. -:.: . INC 32.35, AZI 98.07 — --_ _ TVD 3396.69' SAND/SANDSTONE(3720'-4000')=MEDIUM —Paz.::. GRAY TO DARK GRAY;OCCASIONAL FAINT OLIVE GRAY AND/OR BROWNISH GRAY r , : SECONDARY HUES;VERY FINE LOWER TO • --- I COARSE LOWER RANGE;MOSTLY MODERATELY _=• -te , ` 'WITHIN FINE UPPER ITO MEDIUM LOWER;SHIFTING LARGEST FRACTION IS FINE UPPER;DOMINANT k ANGULAR TO SUBANGULAR;MOSTLY EQUANT TO SLIGHTLY ELONGATED AND SUBSPHERICAL 1` SU tiv- I SHAPE;CONSISTENT VERY MINOR FRACTION OF = IN T _ . _ . SURROUNDED TO ROUNDED GRAINS;NOTE THAT ,_ I MOST OF THE VERY FINE GRAINS APPEAR TO =:: . `_ ' BE LARGER GLASS SHARDS WINNOWED FROM J 1' REWORKED VOLCANIC ASH,AND HAVE VERY _ ANGULAR APPEARANCE;VERY ABUNDANT O - / i "CLAY-SILT-ASH MATRIX SUPPORTED SANDSTONE O i:,.;.r,.r,1._ GRADES TO VERY SANDY CLAYSTONE; VERY ABUNDANT DISAGGREGATED LOOSE SAND GRAINS RESULT OF SOLUBLE MATRIX CLAYS .... AND GENERALLY WEAK MATRIX STRENGTH OF SANDSTONES;VERY MINOR CONSOLIDATED GRAIN AND MATRIX SUPPORTED SANDSTONE t SU �L: @ •37' WITH WEAK CALCITE AND SILICA CEMENTATION IN1.,•v4+7 I98. AND/OR PACKED GLASS MICROSHARDS AND --- 4;+1 41'1 OTHER NON-DIFFERENTIATED MATERIAL;TRACE =""''''71-1[1:▪ 4'.' TO SPOTTY"CLEANER"GRAIN-SUPPORTED 1 SANDSTONE WITH DOMINANT CALCITE AND MINOR SILICA CEMENTATION.• _. .w . •'• . MW 9.2 VIS 50 PV 13 YP 21 GELS 7/12/14 "k;;= I ! FL 7.2 FC 1 OiUW 0/94.5 SOL 5.5 SD.33 i 'MBT 5.0 CI 21000 Ca 80 pH 9.7 Alk 0.9 �sr ------- .'. 1 O y INC 3 SURVEY IS COMPOSITIONAL(GRAYWAC E NEAR LITHIC --- IS COMPOSITIONAL GRAYWACKE(>30%LITHIC ©3902' FRAGMENTS);ESTIMATE 40-60%QUARTZ AND 0 z��_�_�s.-_ 31.91, AZI 98.20 VOLCANIC GLASS GRAINS,TRACE FELDSPAR, TVO 3557.54 TR-10%CHALCEDONY,CHERT AND VARIOUS --...:.-7.--..-_2 -g:-:- UNDIFFERENTIATED CRYPTOSILICA,40-50% ,..,.,. ■ I I�I• I 'LITHICS AND MAFIC MINERALS;60-80%OF "'�3i, _c • 'LITHICS FRACTION IS MEDIUM GRAY TO DARK _ GRAY SCHISTOSE PHYLLITE ROCK FRAGMENTS, _.:: 10-15%ARE DARK GRAY TO GRAYISH BLACK ASSOCIATED ARGILLITE FRAGMENTS,10-15% - � —• ; ,LOW GRADE META GREENSTONE ROCK FRAGMENT' ,z : • AND LAST TR-10%ARE DIVERSE IGNEOUS, V-r META-IGNEOUS LITHICS ■ SU :Y @ 65 MAFIC MINERALS ARE MOSTLY NON- IN. :1!73 198.'8 I DIFFERENTIATED BLACK,"BLACKISH"OR •• OP i+ 11A7 ilo OTHER DARK COLORS;AUGITE AND VARIOUS MICAS ARE DISCERNIBLE;NOTE LOCALLY 'y?_ COMMON CLASTIC COAL FRAGMENTS AND PARTICLES,ESPCIALLY WHEN ADJACENT TO 0> zz • + J Ttl Gas 100><10 Meth G1 10 MASSIVE COALS. <200 R P OK> 71i•7/40' e,g 0> y� _ � ; OC Ctgs Gas 100><10 Ethn C-2 100K>TUFFACEOUS CLAYSTONE/TUFFACEOUS U' :a:::a [, , SILTSTONE(3720'-4200')=VERY ABUNDANT --"-•" € I 1__.__ TJD '63'1 4I FLIGHT BROWNISH GRAY TO BROWNISH GRAY ......._ ��:rr;.r 'ALE BROWN;MANY VARIEGATED GRAY AND } II NN SECONDARY HUES;DOMINANTLY VERY -°=4.3.4.3444.17L-- q T TO SOFT WITH CONSISTENT MINOR ---- _ I __ '._____P __ _ FRACTION OF SLIGHTLY BRITTLE PIECES AND } ,' f i SPOTTY MODERATELY FIRM AND BRITTLE; _ ___'` _ CLAYSTONES ARE HYDROPHILIC,GENERALLY EXPANSIVE AND MOSTLY SOLUBLE;SOME CLAYSTONE,ESPECIALLY IF ORGANIC CONTENT IS HIGH,IS NOT READILY SOLUBLE WHEN S 40 ' (HYDRATED;GOOD TO POOR COHESIVENESS, SLIDE 4086 06 =='v--; INC•■• 4,'A21 j VERY GOOD TO GOOD ADHESIVENESS;CUTTINGS =ms' s TVD • 9.�T i OCCASIONALLY FORM LARGE STICKY "MATS" O .,..,;-=__=-rr- ON THE SHAKERS,AND MOST SAMPLES ARE 0 s• €�■ - I I DIFFICULT TO PREPARE.CLAYEY TO SILTY TO '-' f ASHY TO SOFT MATTE TO VARIOUS MIXED AND =s ss MOTTLED TEXTURES;EARTHY LUSTRES; --"- VERY COMMON CLAYSTONE WITH ABUNDANT �- '€ ! FLOATING SAND GRAINS AND MACRO-SHARDS =.=zz-=z „7,__...„.,.. DISPLAYS MICROGRITTY TEXTURE;"ASHIEST" i }___ TUFFACEOUS CLAYSTONE/SILTSTONE OFTEN ::_ €gs} I HAS DISCERNIBLE VERY ABUNDANT GLASS ��n}$€€;— @ LUSTRE;NOTE COMMON DISPLAYS DARKER ROSPARKLY ..:::::,====_._•=-=z• s : SURVEY 4156 LUSTRE;NOTE COMMON DARKER BROWN VI COLOR VARIATION WHEN ADJACENT AND _smi•ab INC 32.38, AZI 99.J10 , 'INTERBEDDED WITH CARBONACEOUS _— TVD 3773.04' : SHALES AND COALS; MANY CUTTINGS _ FRAGMENTS HAVE MICROLAMINATIONS AND PARTICLES OF COAL AND OTHER ORGANIC _ > 'MATERIAL;MIXED IN WITH THE PERVASIVE o GRAY CLAYSTONE ARE"BLEBS"OF LIGHTER saw ' GRAY,LESS REWORKED,LESS DISTURBED —1��... VOLCANIC ASH. ha O { O . —=•=rr:.•=.=.1 7:_;•:^1-- eT'{ COAL D/INTERBE=ALMOST BLACK ALL THINLY BROWNISH � INC 17, A200.11 = BEDDED/INTERBEDDED;BLACK TO BROWNISH -° SURD Y� 2116' BLACK;LOWER GRADE LIGNITE TO MEDIUM _ ' l GRADE SUBBITUMINOUS;MANY VARIATIONS IN 1,.;.'i_■�• <___* �'� GRADE DEVELOPEMENT;BRITTLE,FRAGILE TVD 3aa3 fit' -°` == = TO TOUGH;VERY DENSE MATTE TO SMOOTH _�__' - TEXTURE;DULL TO SUBVITREOUS TO MINOR - • "= ` VITREOUS AND RESINOUS LUSTRES;MOST — `1 I I' 'LOWER GRADE LIGNITE GRADES TO ====-. CARBONACEOUS SHALE;IRREGULAR SUBPLATY _°-f._ TO SUBCONHOIDAL FRACTURE;RARE BIRDEYE - ro _ FRACTURE;DISCERNIBLE LAMINAR BANDING - .i AND ZONING OF DIFFERENT COAL TYPES AND s;gi 46u ■ GRADES;RARE CLEATING ON SOME FACES. SLIDE•-_7_.5-4310' 3 ° —.__ __:3 ------- ss SURVEY @ 4282' SAND/SANDSTONE(4280'-4360')=MEDIUM INC 32.76,AZI 99.28 TO MEDIUM DARK GRAY OVERALL WITH A WEAK 2.277 TVD=3879.46' :SALT AND PEPPER APPEARANCE,INDIVIDUAL '.`!:!-'2•-n xx xx O _�_R•:z _ = Illiw .. ''BLACK,CLEAR TO TLRANSLLUCENTT QUARTZ AND JT .. 1J-.1f „-_ VOLCANIC GLASS,LIGHT GREEN TO GREENISH c T.T7Es=a;.1 ..... GRAY;VERY FINE UPPER TO TRACE COARSE O UPPER,DOMINANTLY FINE UPPER TO MEDIUM —_�= vavwT?'` LOWER;ANGULAR TO SUBANGULAR;POOR TO _— . _ FAIR SORTING;DOMINANTLY UNCONSOLIDATED `__ ` WITH TRACE LIGHT TO MEDIUM LIGHT GRAY SANDSTONE;VERY FINE GRAIN;FIRM TO BRITTLE;MODERATELY CALCAREOUS CEMENT; ---.-•-;,�jj SU YQ-0348' ( OCCASIONALLY GRADES TO SILTY SANDSTONE/ v v: IN AZ 00.14 SANDY SILTSTONE;ABUNDANT THIN COAL/ ° TVD= _33.07','._-(-,_. . . CARBONACEOUS SHALE BEDS;TRACE ASHY TUFF �s s I , LIGHT TO MEDIUM GRAY;FRAGILE;NON TO — � ,•o.... SLIGHTLY CALCAREOUS. _ v. ILT TUFFA E US CLAYSTONE/TUFFACEOUS S — € _� / STONE(4370'-4480')=LIGHT TO MEDIUM -z _ LIGHT BROWNISH GRAY SECONDARY HUES;SOFT TO SLIGHTLY FIRM;IRREGULAR TO SHAPELESS _ -""-"'3€€ GLOBULAR CUTTINGS;SILTY TO CLAYEY TO 1 TVD 3.1 84 0599.5 p ....... r ry v SLIGHTLY GRITTY TEXTURE;DULL,EARTHY _ r LUSTER;MODERATELY SOLUBLE AND EXPANSIVE HYDROPHILIC;POOR TO FAIR COHESIVENESS; FAIR TO GOOD ADHESIVENESS;SLIGHT TO MOD 1 -,-,;....i,-.14-7-7-- ERATELY CALCAREOUS;TRACE DARK BROWN TO _- - �, BLACK MICROTHIN CARBONACEOUS LAMINATIONS _' ' AND PARTICLES;LIGHT GRAY SILTSTONE COM �' --^ sue€€.€ 'MONLY GRADES TO SILTY SANDSTONE/SANDY -.4:44_4-14 SILTSTONE;FRAGILE;VERY CALCAREOUS;COM -=s=z ss 5 ON TO COAL(CARBONACEOUS SHALE _ re``- •" SURVEY @ 4470' COAL/CARBONACEOUS SHALE(4420'-4540')= INC 33.01,AZI 99.43 BLACK WITH DARK BROWN AND DARK GRAY SEC- _ `... TVD=4036.83' ONDARY HUES;FIRM TO FRAGILE,OCCASION- . _ _•=•= -- 4 ALLY HARD;BLOCKY AND PLATY TO SPLINTERY """"-'� °° 11 111 AND FLAKY;IRREGULAR FRACTURE WITH PLAN- AR FRACTURE COMMON AND TRACE CONCHOIDAL; <200 ROP 0> N €--- <0 I TtI Gas 100><10 Meth C-1 100K>SILTY TO SMOOTH TEXTURE;VITREOUS TO <50 Av WOB 0> O .--..Z.€€ <0 Ctgs Gas 100><10 Ethn C-2 100FCxEARTHY LUSTER;SUBBITUMINOUS;POORLY O �_ _- �==i€K€ 1 9 h DEVELOPED OVERALL WITH NO TO TRACE VISI- - r:',.=7.."-':-:.5i414 3F€ <10 Bufi C-4 F 100k>BLE OUTGASSING OBSERVED. -_,•v <10 Pro C-3 100FQ? TUFFACEOUS CLAYSTONE/TUFFACEOUS SILT- SUD 4fi2 ,__ 5 : i## ' _�' Atk 5 @ S 100{)JLIGH E GRAY -ITH LIGHT=LIGHT W TO MEDIUM �=rrr TVD /091.16 LIGHT GRAY WITH LIGHT BROWNISH AND YES- -- LOWISH GRAY SECONDARY HUES;VERY SOFT • :aza€€ AND STICKY;SHAPELESS,AMORPHOUS,GLOB- „ssss !' ULAR CUTTINGS;SILTY TO CLAYEY TEXTURE; -""'-° SLIMY TO GREASY LUSTER;VERY SOLUBLE; -. _ €€ , MODERATELY EXPANSIVE;HYDROPHILIC;NON — ,,is ,CALCAREOUS;TRACE DARK BROWN TO BLACK -7-43-3:▪3 „, MICROTHIN CARBONACEOUS LAMINATIONS AND PARTICLES IN FIRMER FRAGMENTS;TRACE 7Y3.. ` ;�v=7€€ \, (VERY LIGHT GRAY SILTSTONE GRADES TO r.-- , :7.:::::-.4:,:11.14- SILTY SANDSTONE/SANDY SILTSTONE;VERY ass FRAGILE;VERY CALCAREOUS CEMENT. j s = gib l I (II `�I ITUFFACEOUS CLAYSTONE/TUFFACEOUS SILT- - •. , i-- '® I •NE(4600'-4680')=LIGHT TO MEDIUM T GRAY WITH LIGHT TRACE LIGHT BROWN- �.z.. ) : __-=• 1 GRAY SECONDARY HUES;VERY SOFT; .._.. aaa .12214 I _ _ SLIMY TO PASTY;SHAPELESS,GLOBULAR CUT- ' ' ! TINGS;SILTY TO CLAYEY TEXTURE;DULL TO — bbb3. , I! ' GREASY LUSTER;VERY SOLUBLE;MODERATELY -`-' ��, EXPANSIVE;POOR COHESIVENESS;FAIR ADHES c *—' �,� °° CG 33u SU 4 IVENESS;NON CALCAREOUS;TRACE TO COMMON °` :61' DARK BROWN TO BLACK MICROTHIN CARBON- :;nz-.-�zzb .. IN 5 @AZ 99.8p II ACEOUS LAMINATIONS AND INCLUSIONS. - _ TV 195. f - SAND/SANDSTONE 4650'-4720' =MEDIUM =_ 1 TO MEDIUM LIGHT GRAY WITH A SALT AND PEP ��-:' ;i i '' I PER OVERALL APPERANCE;IRREGULAR,SHAT- z : ` 1 TERED CUTTINGS;FRAGILE AND FRIABLE; : r+r�a BRITTLE AT TIMES;FINE LOWER TO MEDIUM 0 LOWER;ANGULAR TO SUBANGULAR;MODERATELY O -____ °qa'=` • .•. ( WELL CONSOLIDATED WITH A WEAK CALCAREOUS T, CO 50u CEMENT;INDIVIDUAL GRAINS DOMINANTLY MED �S3bb°"_ IUM TO DARK GREENISH GRAY,CLEAR TO TRAN• -, .. Y @ 4724' SLUCENT QUARTZ AND VOLCANIC GLASS;VERY r- SURVE 1 99.57 FINE LOWER TO MEDIUM LOWER;MODERATELY Piii- TV 33:50,AZ ' as TVD=4248.27 WELL SORTED;ANGULAR TO SUBANGULAR. COAL/CARBONACEOUS SHALE(4700'-4800')= 5 °S VERY DARK BROWN TO BLACK;FIRM TO BRITTLE —== '� • .'. "IRREGULAR TO SPLINTERY AND FLAKY CUTTING TRACE PLANAR FRACTURE;SILTY TO SMOOTH _— rrrvrvr, TEXTURE;EARTHY TO RESINOUS LUSTER;SUB- BITUMINOUS;POORLY DEVELOPED;GRADES TO " . CARBONACEOUS SHALE;NO VISIBLE OUTGASSING ;:;. BUBBLES OBSERVED. —�i-�.= z • •• _ _ SURVEY @ 4787 TUFFACEOUS CLAYSTONE/TUFFACEOUS SILT- A. =mm.#n� INC 33:26, AZI 99.45 STONE(4770'-4850')=LIGHT TO MEDIUM co•[: " --- .. TVD 4300.88' i__ LIGHT GRAY WITH LIGHT BROWN AND LIGHT O -'°r• BROWNISH GRAY SECONDARY HUES;VERY SOFT; 33a _ • •• FRAGILE;FIRM IRREGULAR SHAPED CUTTINGS 1 TO SHAPELESS AND GLOBULAR;SILTY TO■#� CLAYEY TO SLIGHTLY GRITTY TEXTURE;DULL, ##� EARTHY LUSTER;MODERATE TO VERY SOLUBLE; • -•---- HYDROPHILIC;SLIGHT TO MODERATELY EXPAN- �, • • 1 'SIVE;OVERALL NON CALCAREOUS;TRACE DARK• '€a- BROWN TO BLACK MICROTHIN CARBONACEOUS r _ ---- .. LAMINATIONS AND INCLUSIONS;COMMON TO - ABUNDANT THIN COAL/CARBONACEOUS SHALE 4"""i•-4W: SURVEY @ 4851' •BEDS THROUGHOUT INTERVAL. S ---- 4 92 5•z :, SAND/SANDSTONE(4830'-4920')=MEDIUM TO MEDIUM LIGHT GRAY OVERALL WITH INDIV- IDUAL IIDUAL GRAINS DOMINANTLY CLEAR TO TRANSL- :: UCENT QUARTZ AND VOLCANIC GLASS,MEDIUM•-m 1,• TO DARK GRAY TO BLACK,LIGHT GREEN TO• ::..:.. GREENISH GRAY;VERY FINE LOWER TO MEDIUM aaabaar A -=^_ & LOWER,DOMINANTLY FINE LOWER TO UPPER; , , , ANGULAR TO SUBANGULAR;MODERATELY WELL p SORTED;CONSOLIDATED SANDSTONE PIECES 0 CG 27u 2 • SHOW SAME CHARACTERISTICS AS LOOSE GRAIN • . SURVEY @ 4914' NAND OCCASIONALLY HAVE AN OFF WHITE CALC- V rr-, INC 32.74, AZI 98.63 1 AREOUS CEMENT;VERY CALCAREOUS OVERALL. r TVD 4407.43' _' . . TUFFACEOUS CLAYSTONE/TUFFACEOUS SILT- r " STONE(4900' 4980') LIGHT TO MEDIUM — LIGHT GRAY WITH LIGHT BROWN SECONDARY• SLIDE 4940' =7•7=---7--_ i HUES;VERY SOTTO SLIGHTLY FIRM;IRREG- ULAR C, ^__ III ULAR T SHAPELESS CUTTINGS;SILTY TO CLAYEY TEXTURE;DULL TO GREASY LUSTER; ''E - :. SLIMY TO PASTY AT TIMES;MODERATELY SOL- UBLE AND EXPANSIVE;POOR TO FAIR COHESI- =:z;:I__ •• ___ VENESS;FAIR TO GOOD ADHESIVENESS;TRACE —__... c3 _° 62u DARK BROWN TO BLACK MICROTHIN CARBONAC- SURVEY @ 4977' EOUS LAMINATIONS AND PARTICLES;TRACE INC 33,75, AZI 98.55 THIN COAL/CARBONACEOUS SHALE BEDS;TRACE YY . TV"- •0.12' CALCAREOUS TUFF. <200 R 0} —— " Ji TtI Gas 100 1D I� 1 it 00K-COAL/CARBONACEOUS SHALE(4800'-5300')_•<50 Av WOB 0> 0 _ " Ctgs Gas 100 10 n C 2 ` 10K NOTE DIVERSE OCCURENCE OF COAL AND OTHER I� CARBONACEOUS SEDIMENTS; DOMINANT AMOUNT , OF COAL PRESENT AS WELL DISTRIBUTED, •p _ :.--. • .. _ p K LOCALLY INTERRUPTED,VERY THIN BEDS; 1D C 3 ��0 -- <10 OK SOME OF THE PROMINENT COAL-RICH ZONES 1 I •PPEAR TO BE STACKS OF THIN COALS, s " �'INSTEAD OF THICK MASSIVE-LOOKING COALS; _ as R @ 56 ,C}5 "- HERE IS A RELATIVE ABSENCE OF LARGE ,. INd 334, AEI 99.08 ,�i BLOCKY CONCHOIDAL FRAGMENTS IN CUTTINGS; TVD!,- 2.54'•' SANDSTONES SHOW SIGNIFICANT FRACTION 11:7:::• .` �_ I OF CITRIC CLASTIC COAL,AND TUFFACEOUS• CLAYSTONE/SILTSTONE HAS COMMON TO •BUNDANT COAL/CARB SHALE MICRO AND MACRO LAMINATIONS AND PARTICLES;NOTE MANY COMPLEX INDIVIDUAL CUTTINGS PIECES HAT DISPLAY ALTERNATING MICRO INTERBEDS •-- »a.: 1 OF COAL,CLAYSTONE,AND SANDSTONE;NOTE RACE PIECES THAT ARE MICRO-BRECCIAS OF y z�s i NEAR 100%CLASTIC LITHIC COAL FRAGMENTS ui s=,. -74.7,_i, •• CG 41u ITH VARIOUS INTERGRAIN SUPPORT. o = ,: _ ' 1 :� co -I e- dip O =A • cc! COAL/CARBONACEOUS SHALE(4800'-5300')_ i" `. I� OCCURENCE AS ABOVE;BLACK TO BROWNISH /:_ i=,.;:._;; • .'. b I ; BLACK;LOWER GRADE LIGNITE TO MEDIUM =" I GRADE SUBBITUMINOUS;MANY VARIATIONS IN _.— i.�.1z.-rte•:._;; • " GRADE DEVELOPEMENT;BRITTLE,FRAGILE __ =_---_ .. • II 0 TOUGH;VERY DENSE MATTE TO SMOOTH II TEXTURE;DULL TO SUBVITREOUS TO MINOR lib OD LIGNITE OFTEN GRADES TO CARBONACCEOUSADE ' Ii' SHALE;IRREGULAR TO PLATY FRACTURE;SOME �I�I SUBCONHOIDAL FRACTURE;NOTE ABUNDANT J — CG 58u LAMINAR BANDING AND ZONING OF DIFFERENT Z .m.-7,..--::,....-1:...:. SU © 6T 1 1 1 COAL TYPES AND GRADES;RARE CLEATING; __ N ttf ' 1I I Ir vu O ' 'r 1 'D/SANDSTONE(4920'-5300')=MEDIUM Y TO DARK GRAY;FAINT OLIVE GRAY• O n== _ I 1 '�1 .BROWNISH GRAY SECONDAY HUES; • ; 3„0 I VERY FINE UPPER TO COARSE UPPER;MOD '' CG 11u IN. c 194 •A 98.-3 111 SORTED AT FINE UPPER TO MED LOWER; - =s DOM SUBANG;EQUANT-SUBSPHER SHAPE; TVs 7 x71.47 ABNT SOLB CLAY MATRIX SUPPORTED SS;COM 9/_8/20'0 =-- • .'. i ' 'GR AND MTRX SPPRTED SS WITH MIXED CALC- 1 - SILIC CMTTN;TR TO LOCALLY COM PIECES OF MICRO-BRECCIA WITH ANG F-C GRS; __ SU'-1t @ 149' ` COMPOSITIONAL GYWKE;EST 40-60%QTZ AND 7 42' 11 VOLC GLASS,TR FSPR,TR-10%VARIOUS ..• • • • • • • TVs . 7 �l jtl CRYPTOSILIC;40-50%LITHICS/MAF MNRLS; IN• � 98. 99 . .F . . . . . . ABNT SS WITH CLASTIC LITHIC COAL FRGS; - I LITHICS DOM BY MED GRY PHYLLITE RK FRGS. -- -:r 2314' 4.20 Hrs - �i DRILL TO 5306'. RUN,SET,CMT 8 5/8"x B'it#3 _ . Grad(::1-taCT-G- -1-NO-TD ---▪ -..- I il � 7 5/8"TAPERED CASING STRING AT 5297'. -�,.,•r�z.._r.• CG 3u PRESSURE TEST CASING TO 4000psi FOR I 44 - - it 30 MINUTES.RIH 6 3/4""DUMB IRON"ASSY. 9/09/2 0101b 9/12/010 0 __ • ^ :- WG 88u 1 DRILL OUT WIPER PLUG AND NEARLY ALL OF a.�z _ HC• 4 6 3/4" in a C -sz-2S TVD ' ' SHOE WITH FRESH TO TERRA-MAX A-M X MUD;OLD R CONTAM S HCCSTX 3x20 20' 1.3,Hrs -=='= V @ 5• 4' : MUD WITH FRESH TERRA-MAX MUD;DRILL LAST Grade 1 1-WT-A-E-1-NO-B =;-, ▪ - INC 31 • 98. 5 12'OF SHOE TRACT AND 20'OF NEW HOLE TO 42.05' 5326'. PERFORM L.O.T.TO 16.4ppg EMW. 9/ 3/2010 ' • • . • TG 5u N.:#5 6 31." in @ 5326' 2..;.;;:: I I : MW 9.45 VIS 45 PV 12 YP 12 GELS 4/7/8 H i C DP51 X 5x11 -_- _ • - ' '' /W FL 8.2 FC<2 O 0/93.5 SOL 6.5 SD.25 � af$ ' ' MBT 6.0 CI 19000 Ca 100 pH 10.0 Alk.45 COAL/CARBONACEOUS SHALE(5330'-5410')_ tez.: BLACK WITH DARK BROWN SECONDARY HUES; �rt�_ ,.�., VERY FIRM TO MODERATELY HARD;BRITTLE; ' "▪'�7° ' EARTHY TO RESINOUS LUSTER;SMOOTH TO ▪,.,.1z , SILTY TO SLIGHTLY GRITTY TEXTURE;IRREG- ULAR 1 TO FLAKY AND SPLINTERY CUTTINGS; -?'=^'• • • INC 66,AZI 98.51 TRACE PLANAR FRACTURE;TRACE WEAK OUT- t ==:z1a; TVD=4796.06' GASSING BUBBLES;SUBBITUMINOUS;GRADING B' #5 8 0.86 Hrs -mss#;� iii TO CARBONACEOUS SHALE. G dr:O-0 O-A-X-1-NO-DTF • • • O n= .. DRILL TO 5412'.POOH FOR MWD TOOL S O -_ FAILURE/WASHOUT.CHANGE BHA.RIH. 9/4/2010 --- TG 22u B',5RR1 6 3• in at 5412 = MW 9.4 VIS 49 PV 14 YP 22 GELS 5/11/12 _ ^ FL 7.5 FC 1 Oil/W 0/93 SOL 7 SD.25 __^ a MBT 6.0 CI 21000 Ca 80 pH 10 Alk.45•is °'".i"▪g E' NCR SURVEY @ 54'0 TUFFACEOUS CLAYSTONE/TUFFACEOUS SILT- zzz =� .✓iii3a. 31.46,AZI 8.06 1 STONE(5410'-5520')=LIGHT TO MEDIUM TVD=4848.78' LIGHT GRAY WITH LIGHT BROWNISH GRAY SEC- `ONDARY HUES;SLIGHTLY FIRM TO SOFT AND PULVERULENT;IRREGULAR TO SHAPELESS, °` GLOBULAR CUTTINGS;SILTY TO CLAYEY TO I ',A7i;.��.,i Lj��_ SLIGHTLY GRITTY TEXTURE;DULL TO SLIGHTLY --- SPARKLY LUSTER;HYDROPHILIC;MODERATELY ▪ : SOLUBLE;SLIGHT TO MODERATELY EXPANSIVE; - SURVEY @ 5503' j POOR TO FAIR ADHESIVENESS AND COHESIVE- -= -- INC 30.85,AZI 98.69 i NESS;TRACE DARK BROWN TO BLACK MICRO- TV¢:4902.69' ( 'THIN CARBONACEOUS LAMINATIONS AND INCLU- <.r0 y.P 0> <0 Ttl Gas 100><10 j' Meth C- 100K>SIONS;OVERALL NON CALCAREOUS WITH TRACE < r :: 0> '�=°'� r Ctgs Gas 100><10I E C-2 100K>LIGHT GRAY SILTSTONE GRADING TO SILTY Pro C-3== ;1 ooK>SANDSTONE/SANDY SILTSTONE THAT IS VERY ==== CALCAREOUS;FRAGILE. :`7F, SAND/SANDSTONE(5500'-5590')=MEDIUM ut TO MEDIUM LIGHT GRAY OVERALL WITH INDIV- 10 Butn 4 100K> - _ -_„ 'I DUAL GRAINS DOMINANTLY CLEAR TO TRANSL- -�== =� UCENT QUARTZ AND VOLCANIC GLASS,LIGHT- a <10 Pent 5 100K> TO MEDIUM GRAY,DARK GRAY,LIGHT TO MED- -_ IUM GREENISH GRAY,BLACK AND TRACE RUST ------_==== AND TAN LITHS;VERY FINE LOWER TO MEDIUM UPPER,DOMINANTLY FINE LOWER TO UPPER; �; - - ) ANGULAR TO SUBANGULAR;MODERATELY WELL t SURVEY @ 55 t' SORTED;DOMINANTLY UNCONSOLIDATED WITH INC 30 13 AZ 9•.1 1SCATTERED GRAIN SUPPORTED SANDSTONE; "° TVD=4958,.70' MEDIUM TO LIGHT GRAY;VERY FINE TO FINE L C s▪ "'' GRAIN;FIRM TO MODERATELY HARD;OCCAS- 'afir IONALLY BRITTLE AND FRIABLE;MODERATE TO ' VERY CALCAREOUS CEMENTING. O -- ---?; • :•Ii MW9.2 VIS 46PV11YP13 GELS 4/8/9 O -_' •.-• FL 7.4 FC 1 OiI/W 0/94 SOL 6.0 SD 0.25 _._._... V �. : . ' MBT S.O CI 18000 Ca 80 pH 9.5 Alk 0.35 .: SAND/SANDSTONE/TUFFACEOUS SANDSTONE T_. 1 -�----._ RVE Y 5630'.1 5600'-5710' =LIGHT TO VERY LIGHT - - SU I INC 29.68 AZ J8. i GRAY WITH MEDIUM LIGHT GRAY SECONDARY 1 TVD=801245 HUES,INDIVIDUAL GRAINS DOMINANTLY CLEAR 111 'TO TRANSLUCENT QUARTZ AND VOLCANIC GLASS F Ail 1 ' TRACE LIGHT GRAY TO LIGHT GREENISH GRAY, 1 BLACK AND WHITE LITHS;VERY FINE UPPER ®� ' TO MEDIUM UPPER,DOMINANTLY FINE;ANGUL- - AR TO SUBANGULAR;DOMINANTLY UNCONSOLID- ATED WITH COMMON ASH SUPPORTED SANDSTONE 'VERY FRAGILE;MODERATE TO VERY CALCAR- �s_' ' , , EOUS;ABUNDANT LIGHT GRAY TO _,.r_n• -- T WHITE ASHY TUFF; RAGIILLE TO PULVERULENT; - �� 1 ANON TO VERY CALCAREOUS;ABUNDANT VISIBLE �/ • t 3s _- 1 SU)2WL @ 5f;9' GLASS SHARDS. INC 29.40 AZI 98.3' .,r V▪ `' - 1 I ' ' COAL(5700'-5730')=BLACK WITH TRACE �� 00 , ! TVA 5068.13 VERY DARK BROWN SECONDARY HUES;FIRM TO BRITTLE;SUBBLOCKY TO IRREGULAR TABULAR ,, 1 SHAPED CUTTINGS;PLANAR FRACTURE DOMIN- .... I'/ ANT WITH TRACE CONCHOIDAL AND BIRDEYE - U ! FRACTURE;SPLINTERY TO FLAKY AT TIMES; r5i ' EARTHY TO RESINOUS LUSTER;SMOOTH TO �7;z.€;i 11 SLIGHTLY SILTY TEXTURE;BITUMINOUS;MOD- . y_=^i ERATELY WELL DEVELOPED;COMMON TO ABUND- .. :::.:_ • I ANT OUTGASSING BUBBLES PRESENT. , . i I 1 ( ISHAPED CUTTINGS;SILTY TO CLAYEY TOE I • r!3! -, ,HTLY GRITTY TEXTURE;,DULL,EARTHY • - Z I T �•r=•= ayyyyfa SOLUBLE; LIGHTLY EXPANSIVE;POOR TO CO , FAIR ADHESIVENESS AND COHESIVENESS;NON 4__.• 1 / ! 0 SLIGHTLY CALCAREOUS;TRACE DARK BROWN 0 _ r� TO BLACK MICROTHIN CARBONACEOUS LAMINAT- SLIDE = _ =m= • '9@ 31 IONS AND INCLUSIONS. �;:z ° ' 20 _-_-__ �� 178. ".- SAND/SANDSTONE(5800'-5900')=MEDIUM -- 3 ' i LIGHT GRAY OVERALL WITH INDIVIDUAL GRAIN ''� .... DOMINANTLY CLEAR TO TRANSLUCENT QUARTZ AND VOLCANIC GLASS,LIGHT GRAY TO LIGHT ��-= I ,I GREENISH GRAY,MEDIUM GRAY,TRACE TAN rrr• ='= - '°. rls , li �� Ott i 1 IUM LOWER,DOMINANTLYIFINEOUPPERIOO LOW- __ yy. YV ' ER;ANGULAR TO SUBANGULAR;MODERATELY Mf ' WELL SORTED;DOMINANTLY UNCONSOLIDATED T' 1_ :�._ : ' WITH SCATTERED SANDSTONE PIECES OF 2 -s- ' TYPES;VERY LIGHT GRAY;VERY FINE GRAIN; SLIDE : . •: WELL SORTED;FIRM TO MODERATELY HARD; N @ 82' NON CALCAREOUS,GRAIN SUPPORTED;TYPE 2 • 9 .I 98 IS FINE TO MEDIUM GRAIN.MEDIUM GRAY -•b4 f- 3.77' WITH VARICOLORED GRAINS;POOR TO FAIR ®� •� � ��II SORTING;GRAYISH WHITE TO TAN CALCAREOUS 00 V III CEMENT PRESENT;VERY HARD. s ' '1 , COAL/CARBONACEOUS SHALE(5880'-5950')_ #3 : 1 BLACK WITH DARK BROWN SECONDARY HUES; «rib FIRM TO MODERATELY HARD;OCCASIONALLY .. :: !` '.1111 z I I I1 I 'B0 FLAKY;PLLANAAR FRACTURE DOMINANT WITH y� !I RACE CONCHOIDAL AND BIRDEYE;SMOOTH TO SLIDE' 3,'-5948' ; III .=. )6.EO. 2'�I B....J INOUS LUSTER;SUBBITUMINOUS AND GRAD GRADING i. • z ,.p 11 ', 44 0 CARBONACEOUS SHALE;TRACE OUTGASSING. .1, UFFACEOUS CLAYSTONE/TUFFACEOUS SILT- """'•sue • ••U TONE 5940'-6100' =LIGHT TO MEDIUM .asas S ( ) ��_�: •�•... ■ - � -' � � LIGHT GRAY AND LIGHT TO MEDIUM LIGHT •11 BROWN;IRREGULAR SHAPED CUTTINGS;SOFT '`_''_ • :.1111 O FIRM;SILTY TO CLAYEY TO SLIGHTLY .__1-. ...11II _ I T , 1 GRITTY TEXTURE;EARTHY TO SPARKLY LUSTER <200 Rs I�V 0> 0 4 . ;;;; �, Ctgs Gas 100 <10 Ethn 51 100K 100K POOR TO FAIR COHESIVENESS AND ADHESIVE- <200 I NESS;MODERATELY SOLUBLE AND EXPANSIVE; D 9 0 9 + 00 RACE DARK BROWN TO BLACK SLIGHTLY CANCAREOUS;LIGHT INCLUSIONS; RAY SILT ON = .r., z 1111 �: :- • • •I 1 RVEY @ g68 ,C . ' 100k STONE COMMONLY GRADES BETWEEN SANDY r=• • �q� A7 • ••.11 I 1 �'v0 534744`-9Ct� 100" COMMON LIGHT GRAY GRAY TO LIGHT OGRAYIISSH WHITE 1 <10 Pent C-5 100KaASITY TUFF;FRAGILE TO PULVERULENT;ABUN- .'..'.1I DANT VISIBLE SHARDS;NON TO SLIGHTLY 11 11111° ' CALCAREOUS. •'•,;; I I (590V-64001 S MEDIUM DARK GRAY TO DARK SANDSTONE �, GRAY WITH STRONG OLIVE GRAY TO OLIVE SLIDE 606.-6 :.-1:77--. "--:::-....-_- .„ I BLACK AND FAINT BROWNISH GRAY SECONDARY • '.t)'1, • '6 HUES;OCCASIONALLY DISPLAYS HIGHER s.,.rte.:. a y'.5.09'� LIGHTNESS VALUES TO MEDIUM GRAY AND ,, MEDIUM LIGHT GRAY AS PERCENTAGE FRACTION ■ OF INTERGRAIN VOLCANIC ASH INCREASES; NOTE CONSISTENT MINOR MODE VERY SILTY/ ASHY VERY FINE SANDSTONE THAT GRADES TO COARSE"SILTSTONE;VERY FINE SAND _ O "' �__ _ CONTENT IS LARGELY DEFINED BY PERCENTAGE _.... +� OF VERY FINE QUARTZ GRAINS,EVEN THOUGH ; �;�, � GLASS SHARDS/MICROSHARDS WINNOWED FROM �:�.,.,, � .' VOLCANIC ABUNDANT °"""" 1 SU 634' FRACTION;INTERGRAIN MATERIAL OF THE .. �E 327' ... SLIDE 6127-6140 _ "„ , IN• 192, AZI 9;07 NON-DCEORE TIATED MATRIX-SUPPORTED AND OTHER i. INON-DIFFERENTIATED MATRIX-SUPPORTED • SANDSTONES ALSO HAS VERY ABUNDANT GLASS SHARDS OF SAME GENERAL SIZE,BUT s--- ALSO INCLUDES MORE FINE POWDERY ASH �; :.;; WITH DISCERNIBLY LESS REWORKING. --_ .. MW 9.3 VIS 47 PV 14 YP 13 GELS 4/8/9 . FL 7.2 FC 1 Oil/W 0/94 SOL 6.0 SD 0.25 �-i, � • •.' ' MBT 5.0 CI 20000 Ca 80 pH 9.3 Alk 0.35 • II te: r: . . '..'. _ _ SURVEY @ 6195' SAND/SANDSTONE/TUFFACEOUS SANDSTONE :-M'-,3:7- 1 INC 20.60, AZI 99,: 5900'-6400' =VERY FINE LOWER TO SLIDE 619 6202 N 1 1 TVD 5520 11 COARSE UPPER;MODERATELY SORTED IN ...,f. • • . .......i,O FINE LOWER TO MEDIUM LOWER RANGE; O ;,,, I 0 ___ l_- MOST IS MODERATELY WELL SORTED CLOSE TO FINE UPPER-MEDIUM LOWER CUTOFF; :-- I 1 DOMINANT ANGULAR TO SUBANGULAR AND C---- = I. ( ' EQUANT-SUBSPHERICAL SHAPE;CONSISTENT SPOTTY TO VERY MINOR FRACTIONS DISPLAY EDISAGGREGATED NTIRE SCALE OF ROUND GRAINS;E COMMDNESS AND D SVERY HAPES; . 1 ' ABUNDANT TO VERY ABUNDANT LOOSE 1 ABUNDANT CONSOLIDATED SANDSTONE;LARGEST FRACTION OF CONSOLIDATED SANDSTONE SLIDE 62 54268--_ SURVEY @0$59' DISPLAYS BOTH MATRIX AND GRAIN SUPPORT•9/ °5/2010 INC h911, AZI 10 l' 'BY TUFFACEOUS CLAY AND/OR VOLCANIC ASH, a _? , ;_ ND 5530.21'. ., COMBINED WITH FRAGILE INTERGRAIN CALCITE rrr AND SILICA CEMENTATION;NEARLY EQUAL FRACTION OF GRAIN SUPPORTED FRIABLE : ( (SANDSTONE WITH WEAK TO MARGINALLY HARD ',,::;r:-.1:-:',,::;r:-.1:-: - I ' 'CALCITE AND SILICA CEMENT;MINOR • 0 .,z SANDSTONE HAS COMPLEX MIX OF INTERGRAIN � i , MATERIAL THAT INCLUDES ALL THE CLAY-SILT �� O 1 -ASH AND CALICITE-SILICA COMBINATIONS, ! INC 18. 5@ 32� AND VARIOUS MINERAL PRO,"SILICA FROM 0 AND VARIOUS MINERAL PRODUCTS FROM SLIDE 631 -6 SURVEY 6 DEVITRIFICATION OF THE VOLCANIC ASH. f=" :::::• ..•. •` 5 AZI 100.59 ,, z TVQ'i509.75'1 1 C` SAND/SANDSTONE/TUFFACEOUS SANDSTONE t fw" l IIIIpIF ERENTIATED FORMS OF SILICA 20 40/ rr:, r i } �__ - F g TICS AND MAFIC MINERALS;APPROXIMATE 1 I) OF QUARTZ IS COLORLESS TO VERY PALE ok, ..::—• ••• ' ' ,Y TO VERY PALE BROWN AND TRANSLUCENT, SLIDE 6380-6396 �Yii<: 1,1 I 1 + INC 17E33 @AZ 6385'0y VOL OF QUARTZ AND NEARLY ALL OF THE -g� VOLCANIC GLASS GRAINS ARE COLORLESS AND ff, 4 TRANSPARENT;LITHICS FRACTION SLIGHTLY TVD 5699.69' '- (DOMINATED BY MEDIUM GRAY MEDIUM GRADE 1 ,W Ili , METAMORPHIC PHYLLITE ROCK FRAGMENTS AND NEARLY EQUAL ABUNDANCE OF PALE GRAYISH O '. I 1 , GREEN TO PALE GREEN TO VARIEGATED GREEN ,> = .. 'LOW GRADE METAMORPHIC GREENSTONE ROCK •. I I \' FRAGMENTS;MINOR AMOUNTS OF DARK GRAY GRAYISH BLACK ARGILLITE ROCK FRAGMENTS, ��* �= � � BLACK TO GRAYISH BLACK TO BROWNISH BLACK 1 NON DIFFERENTIATED MINERALS AND TRACE I 1 SUR _ (Y 0&.47' _ I I TO SPOTTY GROUP OF OTHER DIVERSE LITHICS INC 1 99, AZI 181 SLIDE 644 -6460 _ .•.•I IT TVD( 59.08' �tl TUFFACEOUS CLAYSTONEITUFFACEOUS .'..*.11:1 II I SILTSTONENOLCANIC ASH 6100'-6600' _ • -1 .'I. ', ALL TUFFACEOUS LITHOLOGIES DERIVED FROM • • • • .....,,I I ,► I I ill. (REWORKED VOLCANIC ASH AND SHARE MANY ▪ "` • ...-,, CHARACTERISTICS;MEDIUM LIGHT GRAY TO s 11 i MEDIUM GRAY WITH STRONG LIGHT BROWNISH •'•••111 1 I 1 GRAY,BROWNISH GRAY AND PALE BROWN _ . I SECONDARY HUES;MANY FAINT VARIEGATED `°_ GRAY AND BROWN SECONDARY HUES;SOFT TO r-- \ SLIGHTLY BRITTLE TO BRITTLE;SOME WELL < D 65� 52C1= '0> O `r . '...•,:I <�J® Cigs Gas 100><10 Ethn 100. CALCATEO CLAYS S A VERY SOFT AND SOME 0> O <0 Ttl Gas 1.00><10 Meth C-1 _ 100K_> CALCAREOUS TUFFS AND SILTSTONES CAN BE O ' II BRITTLE AND TOUGH TO MARGINALLY HARD; : ': Sal9RVEY @ g6RR' 100K>AT LEAST TUFF PARTIALLY SOL ARE,HYDROPHILIC, AND CANIBE I 10 >AT LEAST PARTIALLY SOLUBLE,AND CAN BE 1 1tt1.0 14.63, AZI t� 10 K EXPANSIVE;IF LOCAL ORGANIC CONTENT '' I 7\Yp S HIGH,THE SOLUBILITY DIMINISHES;MOST 5820.81 HAS MODERATE TO POOR COHESIVENESS, ▪ ##• ,, \ MODERATE TO GOOD ADHESIVENESS;GENERALLY ' <10 Pent C-5 100K>WHEN DIVITRIFIED ASH CONTENT IS LOW, Lai ..:. = `: • q,a THE"STICKINESS"FACTOR IS LESS;CLAYEY • 11 TO SILTY TO ASHY TO VARIOUS SOFT MATTE AND MIXED(MOTTLED)TEXTURES;EARTHY 110P ■ 'OVERALL LUSTRE,BUT WHEN SHARD CONTENT SURVEY @ 6573' INCREASES THE ROCKS HAVE MICROSPARKLY SLIDE 656'6585 INC 13 27, AZI 99.94 APPEARANCE AND/OR OCCASIONALLY A yz. r-__1 TVD 5880.98' MICROGRITTY APPEARANCE;ALL TUFFACEOUS i 'LITHOLOGIES ARE CLOSELY GRADATIONAL TO . , -- • •• •. . EACH OTHER;MANY INDIVIDUAL CUTTINGS •- za Oa :_:.i 'PIECES DISPLAY DISCERNIBLE MI R TH N �.�-. + • • •'•11 l _ BEDDING AND INTERBEDDING;SOME OF THE O =:#,~ :..'.11 CLAYSTONES HAVE ABUNDANT FLOATING SAND O 7-: .'. GRAINS;ALL ROCKS CAN HAVE THIN COAL OR v°r'= 11 'CARBONACEOUS LAMINATIONS AND PARTICLES; = NOTE THAT SOME OF THE LEAST DISTURBED mac:' yam.::.. ASH HAS REMNANT FEATURES OF ITS ORIGINAL • •11 v� =ice' '.;t; AIRFALL VITRICLASTIC TEXTURES. SLID E 663+ I"= ' r:s SURVEY Q 6636 SAND/SANDSTONE/TUFFACEOUS SANDSTONE ..$- INC 11, 4,AZ'99.19 (6630'-6720')=LIGHT GRAY OVERALL A_ '--'.. • • 111 ' TVD= ,942.48' ._ WITH LIGHT PINKISH GRAY,LIGHT GREENISH s�• GRAY AND LIGHT BROWNISH GRAY SECONDARY HUES,INDIVIDUAL GRAINS DOMINANTLY CLEAR y s 11 I 'TO TRANSLUCENT QUARTZ AND VOLCANIC GLASS THE ASH COMPONENT RESULTS IN THE VARIOUS - _ :•11 HUES;VERY FINE LOWER TO FINE UPPER, • = DOMINANTLY TO SUBANG -=.z , ULAR,MODERATELY WELL SORTEDRVERY WEAK- ?... LY CONSOLIDATED WITH VERY ASHY MATRIX; NON TO VERY CALCAREOUS;FIRM TO SOFT AND•SLIDE 6693' V ;`- �- ___ SU Y(�6699' PULVERULENT;VERY FINE SANDSTONE COMMON- x-�z 1 O = � INC 11116,AZ 99.4 LY GRADES TO A SANDY SILTSTONE/SILTY O = • • I TVD=00433'. SANDSTONE;TRACE THIN COALS. 11 COAL/LACK WITH VERY 670 VERY DA K BROWN SECONDARY BROWN FIRM TO HARD;BRITTLE AT TIMES; ' •1 FLAKY TO SPLINTERY;BLOCKY TO PLATY; i n SMOOTH TO SILTY TEXTURE;EARTHY TO RES- .az INDUS LUSTER;SUBBITUMINOUS;COAL GRADES ✓ J 1 pp TO CARBONACEOUS SHALE;TRACE VISIBLE OUT �Z2221 1 ( �1 GASSING BUBBLES PRESENT. ,`.�'=....as-s s SIID� = ., SURVEY @ 6761 ) GASSING SOUS CLAYSTONE/TUFFACEOUS SILT- STONE(6740'-6830')=MEDIUM LIGHT TO .,,,,-_1_ ,z_ TVD 6065.47 LIGHT GRAY WITH LIGHT BROWNISH GRAY SEC- °` '' „' ONDARY HUES;SOFT TO FIRM AND OCCASION- :r� ` ; ALLY HARD IRREGULAR TO ROUNDED DISCOID ry^ SHAPED CUTTINGS;SILTY TO CLAYEY TO .r r , I- 11 SLIGHTLY GRITTY TEXTURE;DULL,EARTHY TO O ry' ' " OCCASIONALLY WAXY AND SPARKLY LUSTER; � ..: O _• :5 I POOR ADHESIVENESS;POOR TO FAIR COHESIV- ENESS;SLIGHT TO MODERATELY CALCAREOUS; TRACE DARK BROWN TO BLACK MICROTHIN CARL S ,1 ONACEOUS LAMINATIONS AND INCLUSIONS; SLID E6819'-6:•'a ='==°= - SURVEY @ 6824'` LIGHT GRAYISH BROWN SILTSTONE COMMONLY ----- '} INC 7.80,AZI 011 GRADES TO SILTY SANDSTONE/SANDY SILT- =,.,.�. r TVD=6127.79' STONE;FIRM;NON CALCAREOUS;COMMON TO ?----- ABUNDANT VERY LIGHT GRAY TO GRAYISH T----- rsr� ----- ' WHITE ASHY TUFF;VERY FRAGILE;ABUNDANT #$ ' VISIBLE GLASS SHARDS.• . �s="7-11 MW 9.4 VIS 47 PV 14 YP 18 GELS 4/8/9 , -aU- BI FL 7.2 FC 1 Oil/VV 0/93 SOL 7.0 SD 0.25 . i MBT 7.0 CI 22000 Ca 100 LpIHG9H.T4 AGIRkAOY.45WITH - : , SAND/SANDSTONE/TUFFACEOUS SANDSTONE "`7saT SUR =y E. T LIIGHT BROWNISH GRAY SECONDARY HUES, SLID=6882'-8904' ;,.;.spa,, • V� j INC 6.' ,AZI �'�.50 JI INDIVIDUAL GRAINS DOMINANTLY CLEAR TO _ sq TVD= 190. ' TRANSLUCENT QUARTZ AND VOLCANIC GLASS, co O y s _iii 11 'TIGHT TO MEDIUM GRAY,LIGHT GREENISH r' O �`:+=1353' •• , , GRAY,WHITE AND RUST LITHS;VERY FINE 11 I 1 n1......n�..n.w.,.,1-1 V1-1V11-14 11-1-0 SLIDE .� ._ - •••I I I I ___ t l__ TUFFACEOUS SANDSTONE IS VERY FRAGILE AND •III — SU V I � ')ERATELY CALCAREOUS;CALCITE CEMENTED •4. :969' I. GRAIN;HARD; TVD=8 !fI OSTONE IS FINE TO MEDIUM GRA N,ENT ' 402 AZI 04.71 II ISRAC TAN TO WHITE CALCAREOUS CEMENT;• ^^ ' _ CE LIGHT BROWNISH GRAY SANDSTONE; n FIRM TO FRAGILE;GRADES TO SANDY SILT- ___ NE/SILTY SANDSTONE;NON CALCAREOUS; • I I I I OP ' pp ,FIRM TO MODERATELY HARD;WELL SORTED. <200 •1� 0> s a <0 �Ttl Gas 100 1D Meth C 1. 1 nOK STONE 6940 CLAYSTONE/02 )=LIG TUFFACEOUS TO ERY SILT- --- t STONE(6940'-7020)=LIGHT TO VERY LIGHT GRAY WITH LIGHT YELLOWISH GRAY SEC V _ 1 ONDARY HUES;VERY SOFT TO FIRM;SILTY TO O CLAYEY TEXTURE;DULL TO SLIGHTLY SPARKLY r-z✓ns . , ' bDK <sD Avg WOB 0> co 9 i 1; @/Pa4� LUSTER;IRREGULAR DISCOIDAL TO SHAPELESS SLIDE •0�'-7031' ( <0 Ct s Gas 100 � Ethn C-2 100k CUTTINGS;POOR TO FAIR COHESIVENESS AND __r `�1#'r.•'� Q 4 1QOk ADHESIVENESS;NON TO MODERATELY CALCAR- 1D 316 Pent C- 100K CARBONACEOUS DARK BROWN TO BLACK INCLUSIONS; "" i + CARBONACEOUS LAMINATIONS AND INCLUSIONS; "" LIGHT TO MEDIUM BROWNISH GRAY SILTSTONE -...-..........t17••• =""" COMMONLY GRADES BETWEEN SANDY SILTSTONE 'v4,.r AND SILTY SANDSTONE;FIRM;NON CALCAREOUS • • COMMON TO ABUNDANT LIGHT GRAY TO GRAYISH ;,,:!K I, WHITE ASHY TUFF;VERY FRAGILE TO PULVER- _ ULENT•NON TO VERY CALCAREOUS;ABUNDANT (VISIBLE GLASS SHARDS. V�=.'. . - • ••1 I INC 7�r0 @Z7)93,:+, SAND/SANDSTONE/TUFFACEOUS VERY O I SANDSTONE SLIDE 707 '-7102' (7040'-7170')=LIGHT TO VERY LIGHT GRAY OVERALL LIGHT BROWNISH GRAY AND V:r •.::1 I , TVD�6a79.81' �i LIGHT GREENISH GRAY SECONDARY HUES,IND- IIVIDUAL GRAINS DOMINANTLY CLEAR TO IRAN- _ r SLUCENT QUARTZ AND VOLCANIC GLASS,LIGHT O TO MEDIUM GRAY,TRACE BLACK AND ROSE 0 ::::-4:37.--Y-71::::': LITHS;VERY FINE LOWER TO FINE UPPER, __Eif,_,. • ... '! DOMINANTLY FINE LOWER;ANGULAR TO SUBANG :�T =_._; • :.:. ULAR;MODERATELY WELL SORTED;LOOSELY --r 'CONSOLIDATED WITH VERY ASHY SUPPORTING ;;z ' ••• I_ ■ MATRIX;FRAGILE;OCCASIONALLY MODERATELY ="=== • •••••• HARD WITH STRONG CALCAREOUS CEMENT; °rs' WG 30u SURVEY @° 151'' ABUNDANT LIGHT GRAY TO GRAYISH WHITE IN . X1, AZ FRAGILE ASHY TUFF ASSOCIATED WITH THE :'' TUFFACEOUS SANDSTONE;NOTE ABUNDANT I CUTTINGS PIECES THAT DISPLAY MICROTHIN #b' . • •INTERBEDDEDING OF CALCITE CEMENTED 'SANDSTONE,TUFFACEOUS SANDSTONE AND r---c .-'=r, ... ;_._ ASSOCIATED TUFFACEOUS SILTSTONE;ALSO j EQUALLY ABUNDANT CUTTINGS PIECES OF " SANDSTONE WITH BLEBS AND/OR TINY LENSES 1 OF VARIOUS TUFFACEOUS LITHOLOGIES;SOME f_ r I _ OF THE BLEBS HAVE A DISTINCTIVE REPEATED AFLAME-LIKE SHAPE SUGGESTIVE OF MICRO T N i"RIP-UPS". SU IT �72p5 .- iMW 9.35 VIS 47 PV 14 YP 19 GELS 4/8/9 9/16/2010 IN• I ' 71.5 1 FL 7.0 FC 1 OiI/W 0/93.5 SOL 6.5 SD.25 .• . • ,4'17.79 IMBT 7.0 CI 22000 Ca 100 pH 9.3 Alk 0.40 -_.., , ; TUFFACEOUS CLAYSTONE/TUFFACEOUS 0► ( °� -• ISILTSTONENOLCANIC ASH/CALCAREOUS TUFF II 1(7020'-7400')=DIVERSE TUFFACEOUS LITHOLOGIES,ALL DERIVED FROM REWORKED y _ . �, III 'VOLCANIC ASH,ALL GRADATIONAL TO EACH • . • • '.' - . SH II OTHER,AND THUS HAVE MANY SHARED CHARACTERISTICS;MEDIUM LIGHT GRAY TO 'MEDIUM GRAY WITH STRONG LIGHT BROWN(• 72 Illi ' GRAY,BROWNISH GRAY AND PALE BROWN IN• ", ' SECONDARY HUES;MANY FAINT VARIEGATED _ • ' • • • • - I' '�8 73 ; I GRAY AND BROWN SECONDARY HUES;SOFT TO f SLIGHTLY BRITTLE TO BRITTLE;MANY = ' ' ' ' I._ I HYDRATED CLAYS ARE SOFT;SOME CALCAREOUS If / TUFFS AND SILTSTONES ARE BRITTLE TO MARGINALLY HARD;MOST ROCKS ARE FRAGILE; O `�,€} TUFF CLAYSTONES ARE HYDROPHILIC,AT O =rr. • • . : • I 'LEAST PARTIALLY SOLUBLE,AND LOCALLY EXPANSIVE;WHEN ORGANIC CONTENT IS HIGH, 'I, SOLUBILITY DIMINISHES;HYDRATED CLAYS NAVE MODERATE TO POOR COHESIVENESS, . . . SURVEY @ 7330' ,MODERATE TO GOOD ADHESIVENESS;WHEN • • . . ' ' 1 I 1 I INC 0.25, AZI 30.18 DIVITRIFIED ASH CONTENT IS LOW,THERE IS I. TVD 6632.78' AN INCREASED"STICKINESS"FACTOR;CLAYEY - 11 �' III II I TO SILTY TO ASHY TO VARIOUS SOFT MATTE ' ■ AND MIXED(MOTTLED)TEXTURES;EARTHY a :• 11 1 1111 I 1 I ► OVERALL LUSTRE;NOTE HIGH SHARD CONTENT I _ PRODUCES A MICROSPARKLY APPEARANCE 1 1 AND/OR OCCASIONALLY A MICROGRITTY rii. 1 1 ._.. ;- APPEARANCE;ABUNDANT INDIVIDUAL CUTTINGS PIECES HAVE DISCERNIBLE MICROTHIN I I I BEDDING AND INTERBEDDING;SOME CLAYSTONE s:`r / AND SILTSTONE HAS ABUNDANT FLOATING SAND 79 GRAINS;ABUNDANT ROCKS WITH THIN COAL OR V _ SURVEY©7393' �I1' CARBONACEOUS LAMINATIONS AND PARTICLES; A - - INC 0.1.4,AZI 295.69 ,.__ NOTE THAT SOME OF THE LEAST DISTURBED •O -- TVD=6695.78' VOLCANIC ASH HAS REMNANT TEXTURES OF THE O --- ORIGINAL VITRICLASTIC ROCK FABRIC. --- . S NE . ... SAND/SAND TO NE/TUFFACEOUS SANDSTONE -_ (7170'-7600')=MEDIUM GRAY TO MEDIUM ' DARK GRAY WITH VERY STRONG OLIVE GRAY TO F LIGHT OLIVE GRAY SECONDARY HUES;MOSTLY r F ! AN INTERMEDIATE COLOR BETWEEN THESE FOUR DOMINANT COLORS THAT FREQUENTLY } - LOCALLY HIGHER TLIIGHT NESS VALUE DTO MEDIUM -- '�- SU h.: 56' LIGHT GRAY AS INTERGRAIN VOLCANIC ASH IN• I. AZI Z.1 1 INCREASES;PERSISTENT MINOR MODE OF VERY ii_:"'" _ TV• ',;75o. FINE ASHY-SILTY SANDSTONE THAT GRADES TO - All "COARSE"SILTSTONE;RANGE VERY FINE LOWER TO COARSE UPPER;RARE LARGE CLASTS TO GRANULE;MOSTLY MODERATELY TO a.sg„— •. 1 MODERATELY WELL SORTED IN FINE LOWER TO . . . . . . I 1 - I 1Dt II Prop C' 1°°" iir6;ai,lid ,,,,,,,, TINGUISH SILTY SANDSTONE FROM SANDY r ------------ • ... . _Inf. • • • ii . Ktao.50,Azrts6.984, ,,,,,, STONE SINCE MICROSHARDS OFTEN - ' ..„. . . . . . =-:.a:-..7::• ,________ . . . _ < s'r-' 6820.K \ ., 4STITUTE THE INTERGRAIN MATERIAL ......01,11.■ • i'5u= nt C-5 . , lvOK >BETWEEN LARGER QUARTZ GRAINS;DOMINANT J,,•-- INIMM.' 1 EQUANT TO SLIGHTLY ELONGATED ANGULAR TO --. • " • • • - , :::nrEff,,T• • " :: III ' 1 ' ,1 ANGULAR GRAINS,BUT CONSTANT TRACE TO 4-fifitht, • • ; , I I 1 1 '1 MINOR MODES OF ENTIRE RANGE OF •...Rp.:_ I , I ROUNDEDNESS AND SHAPE;VERY ABUNDANT, , , F., • fi.i _ IP „1 ' PERVASIVE CONSOLIDATED SANDSTONE WITH -. iiT• • . • . • N.,. • • • ,. •-- ii .. 1 1 , smEAVTERRIXASLuvPAPROIARTTIO;MNSOSINT csAHANDESNTTOATNIEONISAND , ,_ , GRAIN SUPPORTED AND CALCITE CEMENTED, -1- : -- • • • :1 i SURVEY©7581' , 1 BUT NEARLY EQUAL FRACTION OF SANDSTONE, ='••• • " •" 1: BOTH GRAIN AND MATRIX SUPPORTED,WITH - .,., INC 0 54,AZ182,39.81,, 11 TVD=6883 7 COMPLEX MIX OF CALCITE-SILICA CEMENTS, 0 -;:4-iaz..z.•:: • :: TUFFACEOUS CLAY-SILT,VOLCANIC ASH, g ILI::. . . . :': 11111w : - INI , UNDADZSIIRTEEPDSHARDS,■ I DPERVOTDRU RE SHARDS, =.., , T.-. .-.--- --' • I. ' 'MATERIAL,CALCAREOUS TUFF AND ULTRA-FINE ;- --- -- - - " ' , OR CRYPTO-FINE PARTICLES;LITHIC ARENITE •T.7.1'''•- . 4 ( • • :: TO COMPOSITIONAL GRAYVVACKE;ESTIMATE ... —.7-3.iffi ; MO° . 60-80%QUARTZ(AND VOLCANIC GLASS),TR =.1.1.1...—...• ., FELDSPAR,5-10%CRYPTOSILICA(CHALCEDONY, '''="-..7.'"• " " 1 I . J I I CHERI)AND NON-DIFFERENTIATED SILICA, 1... § L''k'ii'Y @ '44' , 20-40%LITHICS AND MAFIC MINERALS; ._ '..-.i :-='':.:. INU•10L! AZI'' 6.31 II. LITHICS DOMINATED BY GREENSTONE AND -- -::7,_."--,::=• :.■::: pr I. r,•946. pr PHYLLITE-ARGILLITE META ROCK FRAGMENTS. -=::ifi- • ' • ' 1: _•,z,.-.=!•.,-.-- • ..., COAL/CARBONACEOUS SHALE(7600.-7740')= Tni..,_,..,,, ...... _._-,,_;;; . I BLACK WITH DARK BROWN AND DARK GRAY SEC- :', .:7-rf.fil•Jn" •.•;;:■ 1 ONDARY HUES;FIRM TO MODERATELY HARD, BRITTLE AT TIMES;SUBBLOCKY TO PLATY; . "";1 , , FLAKY TO SPLINTERY;PLANAR FRACTURE DOM- viSifig''.- , •:":•;I 6 , i ' i INANT WITH CONCHOIDAL AND BIRDEYE COMMON . •".•:■ "- SILTY TO SMOOTH TEXTURE;EARTHY TO VIT- '.';; A s4 . 4.341:4,,....118, 1 REOUS LUSTER;SUBBITUMINOUS TO SUBLIGN- - g eLf-24-:fit: —.....:: .9 I T I C,OCCASIONALLY GRADING TO CARBONAC- --- ::::'.g5-11b-:-"' ..".•., SURVEY @ 7707' EOUS SHALE;TRACE RESINITE ALONG BEDDING TVD I NC1.07160A9Z717225 01 ' PLANES;TRACE TO COMMON OUTGASSING BUB- -:',1•1•1•1414.i • ' ••••.. "v`.,xtr.f . • • • "" BLES PRESENT. . v/:...72..1.44.- • • .... ---,..,, ‘ .• ‘" ••;;: , r i ,SAND/SANDSTONE/S7A8N20D,ST OL LIGHT TT TU OF FVAECREYOLIGHT U S SANDSTONE ' GRAY OVERALL WITH LIGHT PINKISH GRAY, , , 1LIGHT GREENISH GRAY AND LIGHT YELLOWISH GRAY SECONDARY HUES FROM ABUNDANT ASH ----------- f _,..,_::=• • :.:.11 -z.- .i:i.;_.; - - • •••:•11 :::::::-: • • .I I 111 _ -;;,,,..7„.3-_4-i.i.- • • .'•I I • I _ _ ... / , CONTENT,INDIVIDUAL GRAINS DOMINANTLY ' CLEAR TO TRANSLUCENT QUARTZ AND VOLCANIC GLASS,TRACE LIGHT TO MEDIUM GRAY,LIGHT SURVEY @ 7769' GREENISH GRAY;VERY FINE LOWER TO FINE -----'--- ------------------- ;;:: - __ . „ I - --..-..-..f.l.gf::::-..:.'''.•:: ' I INC 1 11.AZI 219 65 ' TVD=7071.75' 1 UPPER;VERY WELL SORTED;DOMINANTLY UNCONSOLIDATED TO VERY LOOSELY ASHY GRAIN SUPPORTED;VERY FRAGILE;VERY CALC AREOUS AT TIMES;TRACE MEDIUM TO MEDIUM _< •-sle• ,11 ••• . _.i. , LIGHT GRAY TO GRAYISH BROWN SANDSTONE; ------- •••A '"-Y-.--3..:,'”:-:"- ••• 03 =1:.-P I-1:::,---■' •• II pil 1 !!"1 1 VERY FINE GRAIN;WELL SORTED;GRAIN SUP- 0 ,_17-.1 ..... • :.:I PORTED WITH NON CALCAREOUS CEMENT;FIRM 0 ----=;ii • •.I: ::::..;`*'. !..i4 f ::-. • ; TO MODERATELY HARD;OCCASIONALLY GRADES TO SANDY SILTSTONE/SILTY SANDSTONE, TUFFACEOUS CLAYSTONE/TUFFACEOUS SILT- -- -;',14.1-sii_.: .... 1.441„, ' STONE/VOLCANIC TUFFS(7800'-7920)= • SURVEY @ 7832' MEDIUM LIGHT GRAY TO LIGHT OLIVE GRAY _____ _,,,ffMMMM . 11.1 - ..,..iiii • • •••'., INC 1.27,AZI 213.03 TVD=7134 74' , ' WITH LIGHT TO MEDIUM BROWN TO LIGHT • BROWNISH GRAY SECONDARY HUES;IRREGULAR ••=•=ii.fiii;'; ' • --•:: TO WDGE SHAPED CUTTINGS;SOFT,FRAGILE H..... . . ....TO•,,7„._----,,,,,,, • .. ' TO MODERATELY FIRM;SILTY TO CLAYEY TO -';:lf-1--7777.4i-i•-i-M• '.'i i I ! GGERNITETRAY TLELXYTLUIGRHET;DULL,T MEEDAIRUTKAHGYRTAISTLOIGVHETRLYY _________ - . -.."....-..-.-.9.142L-7.1-,.. •• SPARKLY LUSTER;SLIGHT TO MODERATELY . . '' SOLUBLE;FAIR TO GOOD COHESIVENESS;POOR -v-.... .- .. ADHESIVENESS;TRACE DARK BROWN TO BLACK '":1141.:-'-- • • .. MICROTHIN CARBONACEOUS LAMINATIONS AND -71.41.M.• • " ..vt:::::•:.fifi•• • ••• •11 INCLUSIONS;SILTSTONE COMMONLY GRADES :',..`_-=-,frff f. . .• • .. TO SILTY SANDSTONE/SANDY SILTSTONE;NON .";:I vil su LLij 02 7;95' id/ 'TO MODERATELY CALCAREOUS,•ASHY TUFFS V tO Yvv.•'ill-'144-€t • ••"" "%_..i.7,4_ ;-i , , •.1!!! -.4 =- -_7.1.-., ,, iI• • • %.ii;■ -------- • • -...... _ _ . all■ IN ela AZI '13.6alk ti 197. I 1 LIGHT GRAYISH WHITE;VERY FRAGILE TO PULVERULENT;NON TO VERY CALCAREOUS; ABUNDANT VISIBLE GLASS SHARDS. MW 9 5 VIS 50 PV 16 VP 20 GELS 5/11/12 11 11 . ,FL 6.3 FC 1 Oil/W 0/93 SOL 7.0 SD.25 z.,,V-`=.==•=4::.:.: *.::.•:: •Vz:•:1'wi9,i' • '. .;.. 1 MBT 8.0 CI 20000 Ca 80 pH 9.4 Alk 0.40 1 8 • • • - i i 1111 62,O4 - . lk ; 1 I SAND/SANDSTONE/TUFFACEOUS SANDSTONE ':',,,X;Lf.• • • ...•.III I II , 1 1(7910'-8020')=VERY LIGHT TO LIGHT GRAY,INDIVIDUAL GRAINS DOMINANTLY CLEAR .=.-.7.- -"::,-:ifirrr • • 1.I 8 SURVEY @ 7958' TO TRANSLUCENT QUARTZ AND VOLCANIC GLASS ..%'''f=.7.444 • •••-..::■: ••%•-•/iils . ''''...' INC 1.60,AZI 212.60 I TRACE LIGHT TO MEDIUM GRAY,LIGHT GREEN- :•,..,:•&==.44.. '•": : TVD=7260 70' r ISH GRAY,PALE ROSE AND DARK GRAY;VERY i • :.•••.... 'FINE LOWER TO FINE UPPER,DOMINANTLY :, • • .'.:.111: III FINE LOWER;ANGULAR TO SUBANGULAR;MOD- 1 ERATELY WELL SORTED;DISAGGREGATED WITH ■ A .BUNDANT ASHY SUPPORTED SANDSTONE;VERY ' n ' FRAGILE;MULTICOLORED FROM VOLCANIC COM- <200 ---e'ROP 0> 0 Illuk, as 100 10 Meth C-1 Ilk, ti I PONET;TRACE VERY FIRM SANDSTONE;LIGHT <50 vg WOB 0> o • • • • '••'..1:1 1 opprirs Gas 100 10 Ethn C-2 r ,„ITO MEDIUM GRAY WITH A STRONG SALT AND "" PEPPER APPEARANCE;GRAIN SUPPORTED WITH t._-;,-,..t;q1,,. . • .... •V•*..I'v-va•--- --A 10 1,1' p A 00< 1121 I.. CALCAREOUS GRAYISH EvIZI;TtB,1/4.1SNHD,AV-uy/FERY , 1 A , ERY FRAGILE AND SLIGHT TO VERY CALCAR- ----)-'-- y•-.... :.::.,,: • .-.1111 .- _-'''-: • • : 11 -.............-• • : :: .•, AI.-V., @ . Prcilli..A [mu 1... ,AZ PO.3 ' Y°F NI EOUS;TRACE TO COMMON VISIBLE SHARDS. , " '322'Vent C'-5 OOK . CF I°R AML 1-1 CO AHRABZN;ABCLE0Ocry ST0HApLLEA(T7y9,8FOL.-A81K3y0;)- - ---) ,-.=...• • .-.11:1 ill , i BLACK WITH DARK BROWN SECONDARY HUES; - . • ...1.1!i P'"'" Iv EARTHY TO RESINOUS LUSTER;SMOOTH TO ,L-:4:1•..a=--=- • ' ••.. "-.▪.2------z---•...,,,, -,...,:s..sii P..'.' 1 ' SLIGHTLY SILTY TEXTURE;PLANAR FRACTURE : 11 I DOMINANT WITH COMMON CONCHOIDAL AND • BIRDEYE FRACTURE PRESENT;TRACE RESINITE ,1 IyV{,•NUJ.VY - I - ► I 1 ' I STONE(8060'-8180')=LIGHT GRAY WITH J p :. 1 ' I I 1 'IT BROWNISH GRAY AND YELLOWISH GRAY j O .,; ___ __ DNDARY HUES;SOFT TO OCCASIONALLY r.', I r A;IRREGULAR TO ROUNDED,DISCOIDAL v 1 �� L . __ , , __ , 1 SHAPED CUTTINGS;SILTY TO CLAYEY TEXTURE -- • • • ••11 C2,C1 MULL EARTHY TO SLIGHTLY SPARKLY LUSTER; SLIDE 8112'-8140' MODERATELY SOLUBLE;SLIGHTLY EXPNASIVE; 'HYDROPHILIC;POOR ADHESIVENESSL FAIR 1 COHESIVENESS;TRACE TO COMMON DARK BROWN r'- 11 .11 TO BLACK MICROTHIN CARBONACEOUS IAMINAT- 1' I�11 SURVEY . 8146' IONS AND INCLUSIONS;SLIGHT TO MODERATELY rv!.4 �_,_ _ •:.1111 illrll INC 0.90,AZI 221.63 ' JICALCAREOUS. TVD=7448.62'•''V'- = SAND/SANDSTONE/TUFFACEOUS SANDSTONE __ 1(8130'-8260')=LIGHT GRAY TO LIGHT -rr:- GRAYISH BROWN OVERALL WITH INDIVIDUAL y""" 11 GRAINS DOMINANTLY CLEAR TO TRANSLUCENT ti33,= .�s 11 t� QUARTZ AND VOLCANIC GLASS,LIGHT TO MED- :-I-- UM GRAY,LIGHT GREENISH GRAY AND TRACE CO ,",,,,,:7-- PALE ROSE LITHS;VERY FINE LOWER TO -yy a- __ TRACE COARSE LOWER,DOMINANTLY FINE LOW- O fir'- c- ER TO UPPER;ANGULAR TO SUBANGULAR;MOD- 0 = ' SURVEY @ 8209' 1 ERATELY WELL SORTED;SANDSTONE PIECES • i 9 1 1II.15 { ARE VERY LIGHT GRAY WITH VERY CALCAREOUS•rer�zar� . 11 - 11•1 217 1 I 11 ASHY SUPPORTING MATRIX;VERY FRAGILE TO �,.,.,z I N 1. FIRM;GRAYISH WHITE CEMENTING MATRIX; :°'_"'_'• LIGHT BROWNISH GRAY SANDSTONE WITH A . 'STRONG SALT AND PEPPER APPEARANCE IS ry`' ,-.• I I i VERY WELL SORTED;VERY FIRM TO HARD; 1111 GRAIN SUPPORTED AND NON CALCAREOUS; s TRACE VERY LIGHT BROWNISH GRAY SANDSTONE -=_'= FIRM TO FRAGILE;GRADES BETWEEN SANDY ==_:=' :•:• SILTSTONE/SILTY SANDSTONE;NON TO SLIG- - a T HTLY CALCAREOUS.- ____ 1 SURVEY @ 8272' G' ITUFFACEOUS CLAYSTONE/TUFFACEOUS SILT- S - • •:.:. INC 1.21,AZI 209.34 ` STONE(8240'-8350')=VERY LIGHT GRAY NO=7574.69' TO YELLOWISH LIGHT GRAY AND LIGHT BROWN; •' H3 ' VERY SOFT AND FRAGILE TO MODERATELY FIRM O z ;g* IRREGULAR,ROUNDED DISCOIDAL SHAPED CUT- TINGS;SILTY TO CLAYEY TEXTURE;EARTHY, p r 441 _ 1 DULL TO SLIGHTLY SPARKLY LUSTER;MODER- p EffInig• • • •••••• I ATELY SOLUBLE;NON TO SLIGHTLY EXPANSIVE i:..=r 11 POOR ADHESIVENESS;FAIR TO GOOD COHESIV- �;== ENESS;COMMON DARK BROWN TO BLACK MICRO- . THIN CARBONACEOUS LAMINATIONS AND INCL- _ ,1 i 1 USIONS;NON TO MODERATELY CALCAREOUS. SLID_8330'-: • 111 ■ SU Y E335'�� PP. INC . 5,Az1 19$.0.10. COAL/CARBONACEOUS SHALE(8250'-8360')_ ND 637169 ,� BLACK WITH DARK BROWN SECONDARY HUES; .- I HARD;BRITTLE AT TIMES;BLOCKY TO PLATY; _;: ,1 u' 4 PLANAR FRACTURE DOMINANT WITH ABUNDANT 11 CONCHOIDAL AND BIRDEYE FRACTURE PRESENT; ' SMOOTH TEXTURE;GLASSY TO RESINOUS LUST- ER;• 33s ••,, ER;TRACE RESINITE ALONG BEDDING PLANES; • • • 11 SUR Y @ 8398' 1I BITUMINOUS TO LIGNITIC;VERY WELL DEVEL- = - OPED BUT OCCASIONALLY GRADING TO CARBON- , ACEOUS SHALE;TRACE VISIBLE OUTGASSING BUBBLES PRESENT. vim.€.3._. :, INC 0.43, AZT 99. _ p 3334 .4 N0 7 0.59' SAND/SANDSTONE/TUFFACEOUS SANDSTONE O s SZ = 1 (8360'-8720')=NOTE TWO MAJOR COLOR O 11 MODES DEPENDENT ON CONTENT(OR ABSENCE) i..H.:-. • ' .1 OF INTERGRAIN SUPPORTING MATERIAL:1) v== ' • • .1 I i 1 LARGEST PERCENTAGE OF SANDSTONE IS SILTY,GENERALLY HAS LOWER LIGHTNESS VALUES AND DOMINANTLY IS MEDIUM DARK 1 GRAY TO DARK GRAY WITH STRONG OLIVE GRAY 14.- fix._ 1 AND FAINT BROWNISH GRAY SECONDARY HUES, P'' III 2) SANDSTONE SLIGHTLY LESSER AMOUNT OF SANDST THAT IS EITHER ASHY OR"CLEAN",WITH 11 I GENERALLY HIGHER LIGHTNESS VALUES AND SURVEY @ 8462' DOMINANTLY MEDIUM LIGHT GRAY WITH IN 0.37, AZ 137;3 'STRONG TO FAINT LIGHT OLIVE GRAY 11 N +764.59' SECONDARY HUES;SOME OF THE"CLEANER" '111 1 1 GRAIN SUPPORTED SANDSTONE HAS A DIRTY (-- ,,,,,,,:,...,:rt;:__._. . " . 1: 11 GRAYISH SALT AND PEPPER APPEARANCE; FULL RANGE OF GRAIN SIZE FROM VERY FINE 1 I LOWER TO COARSE LOWER(AND RARE GRAINS TO GRANULE);NO DISTINCT SIZE MODES,BUT <200 ROP 0> SC1/ _---- <0 �I Ttl Gas 100><10 Meth C-1( 100K>CONSISTENT 3 OR 4 SIZE GROUPS;COMMON <50 Avg B 0> p °,r <0 ' Ctgs Gas 100><10 Ethn C-2 100K>MODERATELY WELL SORTED VERY FINE "'' SANDSTONE GRADING TO SANDY SILTSTONE; ' ABUNDANT POORLY SORTED VERY FINE TO : <10 Pop C- 100K>COARSE SANDSTONE WITH DOMINANT SIZES AT SLIDE 8519-8553 yy i i '' Ili I�RVY @ MEDIUM LOWER TO COARSE UPPER;COMMON 11 INC 0.63, 100K>MODERATELY SORTED DISAGGREGATED SAND 1.! 4 J�[�7827.5 FROM FINE LOWER TO MEDIUM UPPER;VERY 1U Spent 100K> ;: ,,, 106 ABUNDANT DOMINANT MODERATELY WELL TO \ WELL SORTED SANDSTONE WITH MEDIAN SIZE 11 SLIDING FROM FINE UPPER TO MEDIUM UPPER; 'DOMINANT EQUANT TO SLIGHTLY ELONGATED ' ANGULAR TO SUBANGULAR,BUT NOTE TRACE TO ' MINOR FRACTIONS WITHIN ENTIRE RANGE OF it • ' ROUNDEDNESS AND SHAPE;ABUNDANT,NEARLY ; tf • • • I ; 'PERVASIVE,CONSOLIDATED SANDSTONE;BOTH ..."„ -1 ,1 SURVE GRAIN AND MATRIX SUPPORTED;ABUNDANT 1 E� 1-1•SANDSTONE WITH CALCITE(AND WEAK SILICA) , •I 1 INC 1.16,@PZ8588.6� CEMENTATION;ALSO ABUNDANT SS COMPLEX INTERGRAIN MATERIAL THAT INCLUDES TUFF co at ii#.i TVD 7889 58' • I CLAY AND VOLCANIC ASH;LITHIC ARENITE TO p ,T:_:._.• ••11 —COMPOSITIONAL GRAYWACKE;EST 60-80 0 - C-2,1 QUARTZ AND VOLCANIC GLASS,TR FELDSPAR, ' 1 i 5-10%CRYPTOSILICA(CHLCDNY,CHRT)AND 9/17/2010 • • ' ::. • NON-DIFFERENTIATED SILIC,20-40%LITHICS AND MAFIC MINERALS;GREENSTONES AND PHYLLITE-ARGILLITE METALITHIC ROCK FRAGMENTS ARE DOMINANT. - MW 9.5 VIS 50 PV 16 YP 20 GELS 5/9/11 __: • • • • ' ' I FL 6.1 FC 1 Oil/VV 0/93 SOL 7.0 SD.25 7 "°ffir I _ I"WEDGY"-IRREGULAR HABI;DOM PLANAR ` 11 } f I- __ OTURE;SMOOTH TOHDENSE MATTE TEXTURE; � rar »�.:_ L TO VITREOUS TO RESINOUS LUSTRE,TR V :v \ RESINITE AT SEPARATION PLANES;HI GRADE O SURVEY 8716• -LIGNITE TO LO BITUMINOUS;MINOR ASSOC E _ -- 0 .°° INC 1,S,�AZ 86.5 WITH CARB SH;TR VISIBLE OUTGASSING. - ---. TVD 18.5$' - , TUFFACEOUS CLAYSTONE/TUFFACEOUS SILT- STONE(8350'-8850')=MED LIGHT GRAY, C-2,' ' STRONG LIGHT BRNISH GRAY SEC HUES; NOTE MANY MINOR VARIEGATE GRAY AND I BROWN COLORS AND HUES WITH MEDIUM TO _ HIGH LIGHTNESS VALUE;SOFT TO SLI FRM TO SLID_:743-8770 -----' - I SLIGHTLY BRITTLE TO HARD;IRREG CUTTINGS _ a=• • ' ' 1 SHAPES;CLAYEY-SILTY-ASHY TO VARIOUS . SOFT MATTE AND MIXED TEXTURE;EARTHY _:• S. — -�.- i LUSTRE S;OCC MICROSPARKLY LUSTRE;SOLE _ '. _ IN PART;PERVASIVE HYDROPHILIC;MODERATE TO POOR COHESIVENESS AND ADHESIVENESS; } X'0 ----------------- SURVEY C-3,2,1 ABNT DARK BRN-BLK MICROLAMS/PARTICLES. / E @ 8778' ' SAND/SANDSTONE(8720'-8850')=MEDIUM k . ra 8, AZ!48.50 LIGHT GRAY TO MEDIUM GRAY;FNT TO STRNG ________. . . . . TV' 80$0.53' LIGHT OLIVE GRAY SEC HUES;MOD W SRTD IN O ##�' FINE UPPER TO MED UPPER RANGE;ANGULAR- 0 ='f; " :. 'SBANGULAR;SLI ELONG TO EQNT SHAPE; °°-'#r 1INCRSD SPHERICITY+RDDNESS OF LRGR GRS; T.+��'3c`_ E E r,- NEARLY ALL DISAGGREGATED;GEN"CLEANER" F ,-- 1 S+P APPEARANCE;SUBLITHIC ARENITE;80- --4fibbfil.- 185%QTZ,15-20%METALITHICS,MAF MNRLS. ,,14:,----4:::: SU Y @ 88 TUFFACEOUS SILTSTONE/TUFFACEOUS CLAY- 3 —_,_#€°r IN• 43, AZ j ,9: STONE(8830'-8900')=LIGHT YELLOWISH =�_'R€r 1 TV"8•44.49' 0 GRAY TO LIGHT OLIVE GRAY WITH LIGHT ='#€€ I BROWN AND LIGHT BROWNISH GRAY SECONDARY 1 HUES;SOFT TO SLIGHTLY FIRM,DOMINANTLY in , FRAGILE AND PULVERULENT;IRREGULAR TO' FINELY GROUND UP CUTTINGS;SILTY TO �_.iir- #r CLAYEY TEXTURE;DULL,EARTHY TO SLIGHTLY .. SPARKLY LUSTER;POOR TO FAIR COHESIVE- '-•'# q' . ' " [I NESS;POOR ADHESIVENESS;NON TO MODERAT- - € Y••„ :;,r ,##€#'PV: ... ELY CLACAREOUS;TRACE THIN COAL BEDS. = I 9/18/2010 _ WG 51u DRILL TO 8899'.CBU AND POOH TO CASING • c 00 -j • • • .. ' SURVEY @ 8904' ,SHOE AND REPLACE FAILED CARRIER MOTOR INC 2.00.AZI 58.07 #1 TRANSMISSION.SERVICE RIG.RIH. a • • • :•:•11 TVD=8206.45' MW 9.45 VIS 47 PV 16 YP 15 GELS 3/5/7 :.11 `' FL 6.1 FC 1 OiUW 0193 SOL 7.0 SD.25 — J MBT 10.0 CI 20000 Ca 80 pH 9.2 Alk 0.40 y :-`- :.1111 , ,:::;„4:, F ,. 1 1 1 1 I I SAND/SANDSTONE(8900'-8990' LIGHT TO VERY LIGHT G OVERALL WITH INDIVID- rr 1 1 UAL GRAINS DOMINANTLY CLEAR TO TRANSLUC- `"°'" ' ' " ENT QUARTZ AND VOLCANIC GLASS,TRACE =-="• • I I I LIGHT TO MEDIUM GRAY TO GREENISH GRAY, _- _'• . r '1 PALE ROSE AND TAN LITHS;VERY FINE LOWER 8991' ,A:V kb•ti 1 INC 1 99.A 1 486 TO TRACE MEDIUM UPPER,DOMINANTLY FINE r�, *--/ TVD . 9.AZI 4 36 'UPPER TO LOWER;ANGULAR TO TRACE SUBRO- SLID-8962'- �"�:` SURVEY 8966' UNDED,DOMINANTLY SUBANGULAR;MODERATELY �'- WELL TO VERY WELL SORTED;DOMINANTLY 0.=='°t# • �. DISAGGREGATED WITH TRACE VERY LIGHT GRAY ,—�,_ :$� <20 Avg WO 0> O ry^ �....3#€€ '.I <0 Ct s Gss 100><10 Met C-1 100 ST STONE;VERY FRAGILE;ASHY MODERATELY SAND- <200 R 0> < Ttl STONE;VERY FRAGILE;MODERATELY CALCAR- 9 0 _ 1' 9 p EOUS;COMMON TO ABUNDANT WHITE ASHY TUFF " PULVERULENT;MODERATE TO VERY CALCAREOUS• #bS'b �� / Y @ �'C 100 COAL(THIN COAL BEDS. COAL(8960'-9150')=BLACK WITH DARK f I >BROWN SECONDARY HUES;FIRM TO SLIGHTLY _ 4' 5 100f HARD;BRITTLE;IRREGULAR TO PLATY AND 1 331. � FLAKY CUTTINGS;PLANAR FRACTURE DOMINANT rYM �€ 1 � WITH TRACE CONCHOIDAL AND BIRDEYE FRACT- 11 C1 [' �q URE;SILTY TO SMOOTH TEXTURE;EARTHY TO ° RESINOUS LUSTER;SUBLIGNITIC TO SUBBITUM :, G 1 INOUS;OCCASIONALLY GRADING TO CARBONAC- : : �r -`3• EOUS SHALE;TRACE OUTGASSING BUBBLES. 7 y,-T I I TUFFACEOUS CLAYSTONE/TUFFACEOUS SILT- STONE(9060'-9150')=MEDIUML LIGHT TO LIGHT GRAY TO LIGHT GRAYISH BROWN WITH I} • I INC 2.3 ,AZI 0.94 ! LIGHT BROWN SECONDARY HUES;VERY SOFT TO t � . . " = z 1 SURD Y $1' [ OCCASIONALLY VERY FIRM TO HARD;IRREGUL- """ ' AR TO BIT ACTION SCOOPED APPEARANCE; O -.;• .c:.._•_ TVD 393.3 SILTY TO CLAYEY TEXTURE;DULL,EARTHY 0 w-="" • ' 11 : LUSTER;MODERATE TO VERY SOLUBLE;POOR SLID=9102'-9142' =,r , ,' ADHESIVENESS;FAIR COHESIVENESS;MODER- :.----- ATELY CALCAREOUS;TRACE DARK BROWN TO•::TT;, :... BLACK MICROTHIN CARBONACEOUS LAMINATIONS AND INCLUSIONS;TRACE TO COMMON LIGHT Bi #5RR1 3739' 48. I-rs = - GRAY TO GRAYISH WHITE ASHY TUFF;VERY Grade:1.1-NO-A-X-1-NO IG =- - FRAGILE;VERY CALCAREOUS;ABUNDANT SHARDS - 9/19010 to : : DRILL TO 9151',CBU,POOH.TEST BOPE. . .- TG 45u 1 I REPLACE CARRIER TRANSMISSION.PICKUP NB#SRI32 6 3/4" in. 9151' s=. : • • NU V Y @Z91376 2000'DRILL PIPE AND RACK BACK.CUT AND HCC DF505X 5x13 r� -. P .. SLIP DRILL LINE.MAKE UP BHA AND RIH. s: I TV =8459.30'. ' .. COAL(9150'-9220')=BLACK TO BROWNISH _ BLACK;BRITTLE,FRAGILE TO VERY TOUGH, l . MARGINALLY HARD;IRREGULAR TO SUBPLATY _`•. € , TO PLATY HABIT;DOMINANT PLANAR FRACTURE, 11 MINOR CONCHOIDAL AND BIRDEYE FRACTURE; CD _�€€ I SMOOTH TO DENSE MATTE TEXURE;DULL TO p ",v---==T "' VITREOUS TO RESINOUS LUSTRE;LOW GRADE 0 '"0.3 I. LIGNITE TO SUBBITUMINOUS;LO LIGNITE • 4 GRADING TO CARB SHALE;TR OUTGASSING; •"'ri SURVEY @ 9221' gyp, APPEARS THINLY INTERBEDDED WITH DIVERSE i- -- INC 0.40, AZI 32' , ,VOLCANIC ASH-DERIVED LITHOLOGIES. _-.-41- .. TVO 8523.30' -- - -.- . ' I I I1L1.,11. ..1.,:,.::, ..1� ..1 .,..1_....1..1..,.,111....1,VIII_ 1 it X9-HT GRAY WITH HVERY MEDIUM LIGHT OLIVE _ �I I I Y AND YELLOWISH GRAY SECONDARY HUES; 1 t '� Y FINE LOWER TO RARE VERY COARSE + 1 __. • • • „ S ;LN i_( t !.' LOWER;DISCERNIBLY FINING UPWARD THRU ■ "' " I • ' c.; INTERVAL;MODERATE TO MODERATELY WELL•w I;; ' I 'li till; 4' SORTED,WITH SHIFTING MEAN SIZE FROM 9/21/20'0 I II I I I II I,1 FINE LOWER TO MEDIUM LOWER;ANGULAR TO SUBANGULAR AND EQUANT TO SLI ELONGATED;• 0 • ( , 1 I CONSISTENT MINOR FRACTION OF SURROUNDED 0 ROUNDED,SUBSPHERICAL GRAINS;ABNT ' I I + DISAGGREGATED,BUT VERY DOMINANT MATRIX - "" :1 I;;I 1; ' ®'i I •ND GRAIN SUPPORTED SANDSTONE WITH■ I 1 OLCANIC ASH-TUFF CLAY INTERGRAIN MAT; ' p®s 1 I I plilDi i SUBLITHIC ARENITE TO MARGINAL LITHIC QUARTZ ARENITE IN(UPPERMOST ZONE,EST SU I i 180-90% UARTZ,TR FSPR,TR-5%CRYPTOSILICA Y 1 / II! Q vPrY_ . •:••."11 11 INL'C "1 IIII 110-15%METALITHICS AND MAFIC MNRLS.• n I TUFFACEOUS CLAYSTONE/TUFFACEOUS —__ • • • ......1:::• 11,1 ' I II � _' SILTSTONENOLCANIC ASH/CALCAREOUS TUFF ¢ _ 11 (9150'-9500')=DIVERSE TUFFACEOUS• ""• • 111 _ LITHOLOGIES DERIVED FROM REWORKED ; VOLCANIC ASH;GRADATIONAL TO EACH il , 1 OTHER;MANY SHARED CHARACTERISTICS; _ 1111 ii , MEDIUM LIGHT GRAY TO MEDIUM GRAY;STRONG ___• :. • "" /' III LIGHT BROWNISH GRAY,BROWNISH GRAY,PALE -- BROWN SECONDARY HUES;MANY VARIEGATED ,. N� FNT GRAY AND BROWN SECONDARY HUES;SOFT 0 .--_----- • • ' , 'TO SLIGHTLY BRITTLE TO BRITTLE;HYDRATED �1 1 0 • • I I I I SURVEY @ 9408' ) CLAY IS SOFT;CALCAREOUS TUFF ROCKS TVD .54, AZ 265. BRITTLE TO MARGINALLY HARD;OTHER ROCKS GENERALLY FRAGILE;TUFF CLAYSTONES ARE .1111 4 INC 4 HYDROPHILIC,SOLUBLE,OCC EXPANSIVE;NOTE 87 III � 4 1 II LOW SOLUBILITY IF HIGH ORGANIC CONTENT; ' ' ' I MODERATE TO POOR COHESIVENESS,MODERATE • •:.I I TO GOOD ADHESIVENESS;IF DEVITRIFIED ASH CONTENT IS LOW,"STICKINESS"IS INCREASED —— :1•1 11111• ■ , CLAYEY TO SILTY TO ASHY TO VARIOUS SOFT ,, - � 11 ► � MATTE AND MIXED TEXTURES;EARTHY LUSTRES; '1 •'� SURVEY s4 MICROSPARKLY APPEARANCE WHEN HIGH SHARD ' CONTENT,AND OCC MICROGRITTY APPEARANCE; • I1 - ••'• 71' ABUNDANT CUTTINGS PIECES WITH MICROTHIN :.III 1 INC 0.81, AZI 243.8 BEDDING AND INTERBEDDING;SOME CLAYSTONE TVD 8773.29' J AND SILTSTONE HAS ABUNDANT FLOATING SAND '•:.1111 _,_s GRAINS;ABUNDANT ROCKS WITH THIN COAL OR ' CARBONACEOUS LAMINATIONS AND PARTICLES; ...1 '' as 100> ,/'- NOTE THAT SOME OF THE LEAST DISTURBED <200 ROP 0> <10 Meth C- 100k;VOLCANIC ASH HAS REMNANT TEXTURES OF THE <50 Avg WOB 0> I 1 0�, . 10 Pro C 100K ORIGINAL VITRICLASTIC ROCK FABRIC9 0 9 Ct s Gas 100><10 Ethn 2 100k I 1 I I _ �R0.96 @ 3 100k SA3D/ 600' = IGHT G TUFFACEOUS DIUM TONE (9330•-9600')=LIGHT GRAY TO MEDIUM LIGHT GRAY;FNT YELLOWISH GRY AND LT OLV .. ,, GRY SEC HUES;VERY FINE UPPER TO MEDIUM �� S 2 UPPER;MOD WELL SORTED AT FINE UPPER TO ' 1�� ent C•5 ' MEDIUM LOWER;MASSIVE FINING UPWARD C-3, ,1 I f' SECTIONS;ANGULAR TO SUBANGULAR,EQUANT h TO SLI ELONGATED SHAPE;MNR FRACTION OF SBROUNDED TO ROUNDED;ABNT DISAGGREGATED SLIDE 9556-9591 . . . • • • '•- 1111, DOM MATRIX AND GR SPPRTD CONSOL SS WITH■ • MIX OF CALL-SILIC CMTTN AND ASH-CLY --- INTERGRAIN MAT;NOTE CALC-CMTD AND TUFF z.3 1'11'1 SS W/FAIR VIS POR AT 9535'-9555';DOM SUBLITHIC ARENITE;EST 80-85%QTZ AND ' GLASS,TR FSPR,TR-5°/CRYPTOSILIC,10-20°/ METALITHICS AND MAF MNRLS. ; ,„ 1111 . t0 •r SURVEY . R977'81� _ COAL/CARBONACEOUS SHALE(9500'-9660')= —_-.t.7. r. BLACK WIT DARK BROWN SECONDARY HUES; 0 Y— TVD=889 ' FIRM TO HARD;IRREGULAR TO FLAKY;PLANAR INC 1.. ' 'FRACTURE DOMINANT WITH TRACE CONCHOIDAL � ! 'EARTHY TO RESINOUS LUSTER;BITUMINOUS TO .��,. •_• .'.I; I LIGNITIC;COMMONLY GRADING TO A SILTY, DARK BROWN CARBONACEOUS SHALE;NO TO YTRACE VISIBLE OUTGASSING BUBBLES. -- -z I 1 I I TUFFACEOUS CLAYSTONE/TUFFACEOUS SILT- nEi ' I I I I �' STONE(9640'-9720')=MEDIUM TO MEDIUM :� 111 i !ill _ SURVEY @ LIGHT GRAY TO BROWNISH GRAY WITH LIGHT• == 1111 INC. 317. TO MEDIUM BROWN SECONDARY HUES;SOFT TO vV J INC 1.48, 2.2I OCCASIONALLY FIRM,DOMINANTLY FRAGILE TO 1 __ i® PULVERULENT;IRREGULAR SHAPED;SILTY TO `r _ :.1111 =n CLAYEY TEXTURE;DULL,EARTHY LUSTER; 11.1.1 �- -.s ' M O D E R A T E L Y SOLUBLE;POOR TO FAIR COHES- r= .I I I I IVENESS AND ADHESIVENESS;NON TO SLIGHT- LY CALCAREOUS;TRACE DARK BROWN TO BLACK CARBONACEOUS LAMINATIONS AND INCLUSIONS; C ,,,,,, C COMMONLY INTERBEDDED WITH VERY THIN COAL __ , pli C2,C1 - AND CARBONACEOUS SHALES. 1 I \ MW 9.5 VIS 48 PV 15 YP 16 GELS 4/6/10 '-- SURVEY 9723' 7 'FL 5.6 FC 1 011/W 0/92 SOL 6.0 SD 0.25 : ;! • • INC 1.40,AZI 305.07 MBT 13.0 CI 21000 Ca- pH 9.4 Alk 0.7 --- TVD=9025.23' ■ �: SAND/SANDSTONE/TUFFACEOUS SANDSTONE 4 _1111 I GRAY OVERALL WITH INDIVIDUAL GRAINS DOM- .r - 1111 ir' INANTLY CLEAR TO TRANSLUCENT QUARTZ AND _- VOLCANIC GLASS,TRACE LIGHT TO MEDIUM :: GRAY AND LIGHT GREENISH GRAY AND PALE r.•.Zi. .: ROSE LITHS;VERY FINE LOWER TO MEDIUM _•* :. • .•I I I I I I LOWER WITH TRACE VERY COARSE,SHATTERED _ ,,,,, LITHS,DOMINANTLY FINE GRAIN;ANGULAR TO s. 1111 SUBANGULAR;MODERATELY WELL SORTED;VERY --- ""' SU LOOSELY SUPPORTED WITH WHITE ASHY TUFF; IN.[ AEI 9.2 MODERATE TO VERY CAACAREOUS;FRAGILE; p :`Y= W' 088. ice. SCATTERED SANDSTONE;LIGHT GREENISH GRAY — FIRM TO BRITTLE; ON CALCAROEOUS;LIGHT TY 'YJ°fa tI;t FRAGILE;MODERATE TO VERY CALCAREOUS; ''NDANT GLASS SHARDS;COMMONLY ACTS AS . SUH :Y . 91...:' PORTING MATRIX FOR WEATHERED SANDS. �,_._ TVI?= 150. E 11 COAL/CARBONACEOUS SHALE(9820•-9900')= !BLACK WITH DARK BROWN SECONDARY HUES; 1ip FIRM TO FRAGILE TO OCCASIONALLY HARD AND .I BRITTLE;IRREGULAR TO PLATY AND FLAKY CUTTINGS;SILTY TO SMOOTH TEXTURE;DULL, EARTHY TO RESINOUS LUSTER;PLANAR FRACT- URE DOMINANT WITH TRACE CONCHOIDAL AND `"— ' "" BIRDEYE FRACTURE;TRACE VISIBLE OUTGAS- :V` O I t t 1 SING BUBBLES;BITUMINOUS TO SUBLIGNITIC; ••., SURW COAL COMMONLY GRADES TO A DARK BROWN C 11 1111 INC 1.29,A@Z900. — G _ � SU x,9214.1 +' - CARBONACEOUS SHALE. s 11 C1 TUFFACEOUS CLAYSTONE/TUFFACEOUS SILT- _Y' " I STONE BROWN TOME=LIGHT GRAY SO —- , LIGHT BROWN TO MEDIUM BROWNISH GRAY; _." � I !,SOFT TO SLIGHTLY FIRM;IRREGULAR SHAPED -� �_____ 'I CUTTINGS'SILTY TO CLAYEY TEXTURE DULL, L, EARTHY TO SLIGHTLY SPARKLY LUSTER;MOD- '°� _ ERATELY SOLUBLE;POOR ADHESIVENESS;POOR .v.� ' 0 TO FAIR COHESIVENESS;NON TO SLIGHTLY •:�==�-_ "" CALCAREOUS;ABUNDANT VERY LIGHT GRAY TO ' WHITE ASHY TUFF;VERY CLACAREOUS;FRAG- : 1111 i•?,4:,,.Y ILE;COMMON GLASS SHARDS. "" SURVEY @ 99 INC 1.13,AZI 291. 3 SAND/SANDSTONE/TUFFACEOUS SANDSTONE TVD=9276.16' (9940'-10060')=VERY LIGHT GRAY OVER- ALL WITH INDIVIDUAL GRAINS DOMINANTLY ``• " ' CLEAR TO TRANSLUCENT QUARTZ AND VOLCANIC <200 R0- 0> 0 •iMS. ' ' 11 <I Ttl Gas 100><10 Met C-1 100K>GLASS,LIGHT GRAY TO LIGHT GREENISH GRAY <50 'A?g W s: 0> 0 '�` . :' <0 Ctgs Gas 100><10 Ethr C-2 100k?TRACE RUST,PALE ROSE AND DARK GREEN TO GREENISH GRAY LITHS;VERY FINE LOWER TO I RARE VERY COARSE LOWER,DOMINANTLY FINE :.■:,• <10 Prop C-3 100I( UPPER TO LOWER;ANGULAR TO SUBANGULAR 'WITH TRACE SUBROUNDED;MODERATELY WELL �I�RVEY P 5 100K>SORTED;VERY LOOSELY SUPPORTED WITH r 0 LIGHT GRAYISH WHITE ASHY MATRIX;MODER- ATE TO VERY CALCAREOUS;TRACE VERY LIGHT ' "• ..0 INC 0.98 @AZI 281.10 BROWNISH GRAY SANDSTONE;FIRM TO MODER- TVD 9340.15' -- ...-.. ATELY HARD;VERY FINE GRAIN;NON CALC. KKKKKKKKKKKk KAOLINITIC SANDSTONE(10055'-10170')=V :. KK ALT GRY TO WHI;STRNG CONTRAST OF BLACK, - '•:KKKKK KKK uk` RED LITHICS VS.WHITE;VF Lo TO VC Up;P 14K i i ! F pTOM Up;DOM ANG;DOM MTRX SPTD DOM ' 1, INd 0.3Y AZjOj 0 71 S PRTDFSPR DISCERNIBLE E X LRG R SFT WHI GRS APR - .v � WHI INTERGRAIN FSPR;NOTE BS, PARTICLES R SOFT ____ WHI INTERGRAIN BLEBS,LITHC QTZ ARENITE. SLIDE 10094'- I--•: —i• y TV '94p2.14' COAL(9920'-10220')=BLACK TO BROWNISH•I �� / !BLACK;BRITTLE AND FRAGILE,TO BRITTLE G AND VERY TOUGH;MARGINALLY HARD; • _ IRREGULAR TO SUBPLATY TO PLATY HABIT; DOMINANTLY PLANAR FRACTURE,BUT S_=_ .I i CONSTANT MINOR FRACTION OF CONCHOIDAL C-2,1 AND BIRDEYE FRACTURE;SMOOTH TO DENSE °�"_-"'-' • I _ _ MATTE TEXTURE;DULL TO VITREOUS TO •— III ■ RESINOUS LUSTRE;LOW GRADE LIGNITE TO • -r_'_' ' C-2,1 ? POSSIBLE MID GRADE SUBBITUMINOUS; SOME SURVEY 10162 OF THE LOW GRADE LIGNITE GRADES TO I CARBONACEOUS SHALE;MOST COALS APPEAR I INC 0.32,@ 13 1 MASSIVE,BUT SOME APPEARS VERY THINLY ' TVD 9464.14' 'INTERBEDDED WITH THE DIVERSE VOLCANIC C-2,1 ASH DERIVED ROCKS;ABUNDANT PIECES HAVE :.I I 'DISCERNIBLE BANDS OF ALTERNATING COAL • • • 1 GRADES;TRACE OF VISIBLE OUTGASSING. 1 MW 9.4 VIS 47 PV 14 YP 15 GELS 4/7/10 ` FL 5.6 FC 1 0111W 0/90 SQL 7.0 SD - _ _MBT 13.0 CI 21000 Ca- pH 9.2 A1k 0.5 C ',.-:77-1 . H SAND/SANDSTONE/TUFFACEOUS SANDSTONE 9/22/2010 LIGHT GRAY T DOMINANTLY TO LIGHT GRAY;MANY FAINT • • 1 SURVEY @ 102. 5'' VARIEGATED GRAY SECONDARY HUES THAT • ';;'1 I1 1 . TVD 0.21, AZ 14'.27 INCLUDE LIGHT BROWNISH GRAY,YELLOWISH D 95.27.14' GRAY,LIGHT OLIVE GRAY;OFTEN LOCALIZED •.1 I I . �' HIGHER LIGHTNESS VALUES TO VERY LIGHT .. • 'I -GRAY AND"NEAR-WHITE"; TOTAL SIZE RANGE _ :.:.,,,1 I; FROM VERY FINE LOWER TO RARE GRANULE; ■ - EVIDENT MASSIVE FINING UPWARD SECTIONS; : MOSTLY MODERATE TO MODERATELY WELL ' SORTED IN SHIFTING SIZE MODE FROM FINE UPPER TO COARSE LOWER;FINER GRAIN :: ' , 1 SIZES LARGELY DERIVED FROM GLASS MICRO- , • • III 1 SHARD AND"MACRO-SHARDS"WINNOWED FROM ' • • - , VOLCANIC ASH;LARGER GRAINS TO VERY SLIDE 10282-10302 SURVEY @1t) :8' COARSE(AND GRANULE)ARE CONCENTRATED IN BASAL ZONES;DOMINANTLY ANGULAR TO INC 0.56, AZI 9..3� p 111.1 TVO9g90.14'. SUBANGULAR,EQUANT TO SLIGHTLY ELONGATED W I I ' •GRAIN DIMENSION,SUBSPHERICAL TO 0 • • • • • SUBDISCOIDAL SHAPE;CONSTANT MINOR 1111 'FRACTION OF BETTER ROUNDED,SUSPHERICAL ! TO SPHERICAL GRAINS;DOMINANTLY SMALL CUTTINGS FRAGMENTS OF CONSOLIDATED SANDSTONE AND TUFFACEOUS SANDSTONE, • • • ABUNDANT DISAGGREGATED GRAINS;OCC ' • ' Ill: ,INDIVIDUAL FRAGMENTS WITH GOOD VIS POR, • • • BUT MOST HAVE INTERGRAIN SPACE FILLED 1111 1 BY ASH-TUFF CLAY; ROUGH EQUAL FRACTIONS • • ' ' ' ' ' SURVEY @ 11 .1' OF GRAIN AND MATRIX SUPPORT;MINOR • • • 11:1 INC 0.96, AZ • .& "CLEAN"GR SUPPORTED CALCITE CMTD SS, •:.:•:•:.111 111 ND 9653.14' MOST IS COMPLEX SUPPORT FROM VARIOUS • • ASH DERIVED MATRIX MATERIAL AND SILIC- • . CALC CMTTTN;ASH-QUALIFIED SUBLITHIC • • • • I ARENITE TO LITHIC QUARTZ ARENITE(IN • • ,,,,,,„"' :: 'UPPERMOST ZONES OF MASSIVE SECTIONS); :I + EST 80-90%QTZ AND GLASS,TR-5%FSPR AND fr I �� INC 0.88,AZI 4.56 ��. �, .� 4 �.�8, y it j O 43Y J STONE(10400'-10480')=LIGHT OLIVE _ TVD=9717.1a' 4Y TO BROWNISH GRAY;SOFT TO SLIGHTLY • 1;IRREGULAR SHAPED CUTTINGS;SILTY • . II JLAYEY TO SLIGHTLY GRITTY TEXTURE; �..^ : 111 DULL,EARTHY TO SPARKLY LUSTER FROM HIGH y ^ r ASH CONTENT;MODERATELY SOLUBLE;POOR ADHESIVENESS;POOR TO FAIR COHESIVENESS; ""'q3 ( SLIGHT TO MODERATELY CALCAREOUS;TRACE I I,I DARK BROWN TO BLACK MICROTHIN CARBONAC- EOUS LAMINATIONS AND INCLUSIONS;ABUNDANT 1 LIGHT GRAY TO GRAYISH WHITE ASHY TUFF; 'FRAGILE TO PULVERULENT;COMMONLY ACTS AS - SURVEY©1041 III A SUPPORTING MATRIX FOR FINE GRAIN SAND; TVD 1.07,AZI 122-,- MODERATE TO VERY CALCAREOUS AT TIMES; ' ----- INC 1A7,AZI 9 5 � i V"rr =;rr 111' COMMON GLASS SHARDS VISIBLE. =br <200 ROP 0> C y " 0 Ttl Ga$ 100><10I __ _ Myth C-1 100K>MW 9.5 VIS 50 PV 21 YP 17 GELS 7/9/10 <50 Avg WOB 0> p r 0 Ctgs Gas 100><10I hn C-2 100K>FL 5.3 FC 1 Oil/W 0/89 SOL 7.0 SD 0.25 0 IrT^? S ..1 i ��-3 100K>MBT 12.5 CI 16000 Ca- pH 9.6 Alk 0.7 _..-..�.� ro ......_ COAL(10400'-105601=BLACK;MODERATELY HARD TO BRITTLE;PLATY TO BLOCKY;PLANAR O u ._.q <; I. p to > 100K>FRACTURE DOMINANT WITH TRACE CONCHOIDAL ... SURVEY 1 AND LA BIRDEYE RESINOUS SINOUS LUSTER;SMOOTH TEXTURE; IN 1i.0 AZI•...: �0 77 GLASSY TO RESINOUS LUSTER;LIGNITIC;NO ,.•. j 1 5 100K>OUTGASSING OBSERVED. • •. '.111111 SANDSTONE/TUFFACEOUS SANDSTONE(10520'- " TV $843.11' .. 10780')=LIGHT GRAY TO LIGHT BROWNISH • 'GRAY OVERALL WITH INDIVIDUAL GRAINS DOM- _: • • • .::. INANTLY CLEAR TO TRANSLUCENT QUARTZ AND • • :.:. VOLCANIC GLASS,RARE TRACE OTHER COLORED :.:. LITHS;VERY FINE LOWER TO COARSE LOWER; VERY FINE FRACTION MOSTLY GLASS SHARDS • I WINNOWED FROM VOLCANIC ASH;MODERATELY WELL SORTED IN VERY FINE UPPER TO FINE WG 59u 1 UPPER;ANGULAR TO SUBANGULAR;EQUANT o — c Oi .,604' SURVEY @ DIMENSIONS;MINOR DISAGGREGATED,VERY 0 • ■■■■■■■■■ INC 1.10, ' •'.91 DOMINANT VOLCANICASH-TUFFACEOUSCLAY TVD 6.16' MATRIX SUPPORT;GENERALLY WEAK AND FRAGILE BUT NOT FRIABLE SINCE HYDRATED I 'CLAYS ARE MUSHY AND GRAINS TEND TO STICK TOGETHER;NOTE THAT ASHY SANDSTONE IS 'OFTEN HIGHER LIGHTNESS VALUE AND VERY LIGHT GRAY TO WHITE;(ASHY)SUBLITHIC • ARENITE TO LITHIC QUARTZ ARENITE;EST 9/23/20'0 == , 75-90%QUARTZ AND VOLCANIC GLASS,TR FELDSPAR,TR-10%CRYPTOSILICA(CHALCEDONY) °cc :.'• AND NON-DIFFERENTIATED SILICA,10-20% rte:.:• SURVEY©10868' LITHICS AND MAFIC MINERALS;MAFIC MNRLS INC 1.1 6, AZI 190.06 MOSTLY NON-DIFFERENTIATED BLACK AND TVD 9970.08' "BLACKISH"VARIEGATED COLORED MINERALS, ••11 C-2,1 BUT BIOTITE AND AUGITE ARE PRESENT;NOTE VERY ABUNDANT MEDIUM GRAY TO DARK • :.11:1 ► - GRAY TO BLACK ARGILLITE-PHYLLITE ROCK • .- FRAGMENTS;GRAYISH GREEN TO MODERATE p ; • •'• :; _ .._.GREEN TO VARIEGATED GREEN LOW GRADE C I. =• METAMORPHIC ROCK FRAGMENTS ARE SPOTTY O . • BUT DISTINCTIVE;LOW GRADE RED TO • • ORANGISH RED JASPER,THOUGH PRESENT ONLY I AS WELL-DISTRIBUTED TRACE,CONTRASTS I STRONGLY AGAINST THE MOSTLY'WHITISH" •""""""" SURIO�Y @ 107 i' QUARTZ BACKGROUND;EST 80%OF QUARTZ IS - ' ' • INC 1.2�, AZI 11 .09 1 COLORLESS TO VERY PALE GRAY OR BROWN AND • ' ' • 1 111 - TVc 1Q032.0 ' -__ TRANSLUCENT,20%OF QUARTZ AND NEARLY .. 1 111100%OF VOLC GLASS IS COLORLESS AND • TRANSPARENT;NOTE THAT SOME OF THE WHITE • :. INTERGRAIN MATERIAL HAS SLIGHTLY MORE • •'•:• 11 CRYSTALLINE AND STRUCTURED APPEARANCE AND APPEARS TO BE POSSIBLE KAOLINITE. ' ,, 'MW 9.4 VIS 49 PV 18 YP 19 GELS 3/5/7 FL 5.0 FC 1 Oil/W 0/89 SOL 7.0 SD 0.25 • ; @ MBT 12.5 CI 23000 Ca- pH 9.5 Alk 0.7 SUR Y 107`•4'. • - I INC 1.26, AZI 104.x' COAL(10740'-10860')=BLACK WITH DARK 0 TVD 10096.08' BROWN SECONDARY HUES;FIRM TO BRITTLE; Co OW' FLAKY TO SPLINTERY TO SUBBLOCKY;PLANAR co •••• 'I li FRACTURE DOMINANT WITH ABUNDANT BIRDEYE 0 11 I AND CONCHOIDAL FRACTURE;SMOOTH TO SILTY • TEXTURE;EARTHY TO RESINOUS LUSTER;BIT- ,. ,, - • • 1 UMINOUS TO LIGNITIC;COAL OCCASIONALLY GRADES TO CARBONACEOUS SHALE;NO TO TRACE OUTGASSING BUBBLES. TUFFACEOUS SANDSTONE/SAND/SANDSTONE ► I I I (10830'-10950')=LIGHT GRAY TO LIGHT �; - . BROWNISH GRAY OVERALL WITH A WEAK SALT = SUR 1V E. @ 10866' AND PEPPER APPEARANCE,INDIVIDUAL GRAINS Y� ="'r' .:. INC 1.35,AZI 1(54.26 DOMINANTLY CLEAR TO TRANSLUCENT QUARTZ "2`' TVD=10158.04`, AND VOLCANIC GLASS,TRACE LIGHT GRAY TO GREENISH GRAY,PALE ROSE,DARK GRAY AND yY ""' BLACK;VERY FINE LOWER TO MEDIUM LOWER, :y DOMINANTLY FINE LOWER;ANGULAR TO SUBANG ,ti.= \. ULAR;MODERATELY WELL SORTED;TUFFACEOUS _ __ •• I SANDSTONE IS VERY FRAGILE;DIRTY GRAYISH O :.11 = WHITE;OTHER SANDSTONES ARE MODERATELY Y HARD;VERY CALCAREOUS CEMENT;MULTICOL- . ORED;FINE GRAIN;ABUNDANT ASHY TUFFS. t, 1 . '•III 1 SURVEY @ 109.0' 1 TUFFACEOUS CLAYSTONE/TUFFACEOUS SILT- __— `- • .•1 111 INC 1.�l$,Al Z )I1:.0• STONE(10900'-10990')=LIGHT GRAY TO 111111 TVD=;10222 2' 1 ' LIGHT YELLOWISH GRAY AND LIGHT BROWNISH .... GRAY;VERY SOFT;IRREGULAR TO PDC BIT — I ACTION"SCOOPED"APPEARANCE;MODERATE TO ..-1•-• . :: • I VERY SOLUBLE;SILTY TO CLAYEY TO SLIGHTLY f « _ ,,,, GRITTY;EARTHY TO SLIGHTLY SPARKLY LUSTER MODERATE TO VERY CALCAREOUS;COMMONLY ACTS AS A SUPPORTING MATRIX FOR SAND. i I I f 1 MW 9.4 VIS 54 PV 16 YP 18 GELS 5/9/12 <2b0 I ROP C. 0> = ',4.,;:7.-..-',, • ..' l<. Ttl Gas 100>k<10 Meth, -1 1b0 GRAYISH BROWN OVERALL WITH SCATTERED V9 O x:4,5� I I III 9 - T AND PEPPER APPEARANCE;VERY SOFT <50 A WOB 0> Y" • 111 1 Ct s Gas 100>'I<10 Ethn C• 10014 FRAGILE;IRREGULAR SHAPED CUTTINGS;•O ' <10 Pro C•3 1 Y ASHY;MODERATE TO VERY CALCAREOUS; 00K>A OB GLASS SHARDS;OAMS NMTALTYR ES rrr _;,:t.., ""'. <10 But 4 1QO 70TRANSLUCNT QUARTZ D AND VOLCANIC GLASS• 5ERY FINE TO TRACE VERY COARSE,DOMINAN- : = vaRY Y Q!"6•• - 7 LY FINE;ANGULAR TO SUBANGULAR;MODER- 'I y'=sa INC 1'. AZ1,101 91 'ATELY WELL SORTED;NO ODOR,STAINING, zn I I I TVD 1_45.97'45.97' ,, SHEEN,CUT OR CUT FLUORESCENCE. ==""sue"" ' 1 1 1 1 I TUFFACEOUS CLAYSTONE/TUFFACEOUS SILT- '. .;,.�T . r r STONE(11030'-11120')=LIGHT GRAY TO yyy= c T-- - •:. LIGHT GRAYISH BROWN WITH LIGHT BROWN a _.��or SECONDARY HUES;SOFT TO SLIGHTLY FIRM, . rr •• OCCASIONALLY VERY FIRM;IRREGULAR TO ate. - -------.-. .. __ - _.-._ - - ---- --- WEDGELIKE CUTTINGS;SILTY TO CLAYEY TEX- `` r V` r"""• : TURE;DULL TO SPARKLY LUSTER;SLIGHT TO MODERATELY SOLUBLE;POOR ADHESIVENESS; _ __- FAIR TO GOOD COHESIVENESS;NON TO SLIGH- "" 'TLY CALCAREOUS;ABUNDANT GRAYISH WHITE O y=vim° SURVEY @ 1111•" TO GRAYISH BROWN ASHY TUFF;VERY FRAGILE I .'14.-J-4,-'-E :. . I I I INC 1.69, AZI••.52 VERY CALCAREOUS;NO ODOR,FREE OIL,CUT, ° " TVD 10410 94' SHEEN,STAINING OR CUT FLUORESCENCE. ( SLIDE 11117' 11150' '�' SAND/SANDSTONE/TUFFACEOUS SANDSTONE ► (11120'-11195')=NOTE CHANGES IN SS: „ I OVERALL COLOR"SPECKLED"DARK GRAY AND - 111 'DIRTY PEPPER AND SALT"APPEARANCE;ROCK ` '-a 1 1 l. FABRIC ALSO HAS COM STREAKED APPEARANC; r=a :•1111 Z NOTE SHALES WITH SS;SOME SH PRESENT AS ` ' 1111 r __ 1 1 I I MICROLAMS WITHIN SS;3 VAR OF ASSOC SH: 1)ORGANIC BRNISH BLACK, 2)ARGILLACEOUS SURVEY @ 11171' VERY DUSKY RED TO DUSKY YELSH BRN TO INC 0.72, AZI 136.67 I"CHOCAATE"BRN,3)GRAYSH GRN TO GRNSH - TVD GRY TO PL BLUISH GRY;SS IS M W SRTD FN r r r r r 1 472 93' Lo TO FN Up;SUBANG BUT IMPROVED SPHER; .1..11 ° NOTE FAINT REDDISH FeO COLORATION ALONG CONTACT OF GRAY AND WH STREAKS;SOME o0 ,. INTERGRAIN CHALKY WH MAT IS PROB KAOL; N HU• • • • • • • 1 / CONTINUED V CALC;NOTE INCRSD XLN CALC. ❑oo0 1 I ii c ... G o00o SANDSTONE/SAND(11195'-11285')=MANY• 00 11 SIMILARITIES TO SS ABOVE,BUT SAND IS 11 "WHITER"AND ASSOCIATED SHALES ARE DOM a 11 DUSKY BRN(BOTH ARG AND ORG TYPES)AND SLIDE 11227-11257 -.113• • • ' ' • 11 SURVEY @ 11235' GENERALLY APPEAR AS A CASTIC,RATHER °° • ' ' ' ' ' 11 INC 0.47,AZI 12/3'14 (THAN BEDDED CONSTITUENT;V DUSKY RED AND • ®® 1111 • • • TVD=10536.93 IGRYISH GRN SHALES ALSO PRESENT BUT LESS 9/24/20'0 BP 1 — ABNT;NOTE BLACK VITREOUS CARBONACEOUS B° _ . , I,- - 4. 1 AS AND COAL DISTINCTIVELY PRESENT AS CASTS/LITHIC FRAGMENTS IN SS;MATRIX I ®1B°°° J SUPPORTED SS HAS PERVASIVE MIX OF VAR . / ....... l _ . _1111 C-5 WHI CLYS AND"BRIDGING"XLN CALC CMTTN; = 1111• ;MOD TO POORLY SRTD FROM F Lo TO CRSE Up; •v NOTE DISTINCTV SPTTY GRNSTS(CHLORITE) -e1• • . . . 11 AND RR CITRINE;TR OIL SHOW 11260-11266, r" SLO YELSH WHI SLO STRNG CUT FLUOR FROM 11 INDV SS PIECES(SINGLE PIECE W/OIL STN) 11. U 1/kYQ1' « r G I IN 0.3'9,AZI 2' .3' --SANDSTONE(11285'-11305')=SS CHANGE: - ...... .... O TV =1059892' ALL CONSOL;M W SRTD;COM GRNST LITHICS; CALC CMTD;DOM F Up-M Lo,W/SCTTRD LRG . - CLSTS TO VC;COLOR HAS DISTINCT GRY ' SEC HUE(UNLIKE ZN ABV);V ABN T CALC CM T. SAND/SANDSTONE/TUFFACEOUS SANDSTONE i. (11305'-11350')=SIM.TO 11120-11195; COLORED ELONGATED FRGS OF SH;CONTRASTY I STREAKED APP OF SS;POSS KAOL. SURVEY @ 113.0' COAL(11380'-11425')=BLACK WITH DARK INC 0.12,AZI$s.57' 'BROWN SECONDARY HUES;FIRM TO MODERATELY _ bbbs TVD=10661. 2' HARD;BRITTLE AT TIMES;SCALY TO FLAKY ITO PLATY AND BLOCKY;PLANAR FRACTURE DOM INANT WITH CONCHOIDAL AND TRACE BIRDEYE __ 411 'FRACTURE;SMOOTH TO MATTE TO SILTY TEXT- _- I I 1 IURE;EARTHY TO RESINOUS LUSTER;BITUMIN- OUS TO LIGNITIC;OCCASIONALLY GRADES TO CZI __'__ _A DARK BROWN CARBONACEOUS SHALE;TRACE A = TO ABUNDANT OUTGASSING BUBBLES PRESENT. O - 5� ■ C1 SHALE/SILTSTONE/CAYSTONE(11400'- -- C3.C32,C1 11500')=MANY ASSORTED LITHS THROUGH ® SURVEY @ 11422' ,-- (THESE INTERVALS;SHALE IS LIGHT BROWNISH -- INC 0.26,AZI 27.33 GRAY TO MEDIUM BROWN TO DARK BROWNISH TVD=10723.92' GRAY;VERY FIRM TO HARD;OCCASIONALLY BRITTLE;BLOCKY TO PLATY TO SPLINTERY; __= EARTHY TO WAXY LUSTER;SMOOTH TO SILTY • TEXTURE;NON TO SLIGHTLY CALCAREOUS; 13'=' . ' TRACE BLACK MICROTHIN PARTILCES;SILT- =r,'- =. :•11 STONE/CLAYSTONES ARE LIGHT GREENISH := GRAY TO LIGHT YELLOWISH GRAY AND LIGHT BROWNISH GRAY;IRREGULAR TO BIT ACTION .•• I SCOOPED APPEARANCE;VERY SOFT;FRAGILE; t-:',-.7_:::::•!-1-:- SURV Y 911•.'5' MUSHY TO CURDY;PULVERULENT;DULL TO IN b 3,AZI •50.69 A EARTHY R ; WAXY FAIR COHESIVENESS;CLAYEY TO SILTY; �- 11 TEXTURE;POOR TO FAIR COHESIVENESS;POOR <200 ROP .� N- r U �I Tts Gss 100><10 Mtn C-2 100K>NQTE PROMINENT CHANGE IN VERY LL BULK NOTE PROMINENT CHANGE IN OVERALL BULK <50 Avg WOB 0 9 SAMPLE COLOR AFTER 11425'FROM GRAYISH BROWN TO GREENISH GRAY. . . <10 F) :p C-3 100K>MW 9.4 VIS 45 PV 17 YP 16 GELS 3/4/4 1 4 100K>'FL 4.8 FC 1 011/W 0/89 SOL 7.0 SD - <t0 E3N MBT 15.0 CI 23000 Ca- pH 9.0 Alk 0.4 9/'5/010 __- % N Y @? •5 100 >DRILL TO 11551'.CBU.POOH FOR BIT/BHA BI'#5Rf�2 2400' 80,10 - V VVVV _ IN 3, AZ11 . 4 AND BOP TEST.RIH.RELOG MWD 11175'-TD. Grad 11-3,WT-M-X{1-CT-D TV 350.9 f IIi I ; I 1 - L. ,,,k7,-----..-.;;;7..: O" POORLY SORTED;GRAIN SUPPORTED;TYPE 2 BROWNISH GRAY WITH BLACK CARBONACEOUS USIONS;VERY FINE GRAIN;WELL SORTED ►i0 O l i TO HARD;CALCAREOUS CEMENT. v�r 01 - • ••l i DIVERSE LITHOLOGIES 11430'-11700' = SU 1111: � Mill' NOTE VERY SIGNIFICANT STEP INCREASES IN -------- ----°----- --- O -F-- ..: _.:•O KK IN• AZ'3b.'3 .-.. - -DIVERSITY OF ALL ROCKS PRESENT AT :'%., -=z= • • O a oi 13.9 11100'-11270',11270'-11430'AND 11430'- ':-.--=;,-. _ ' . O 11700'.NOTE THAT WITH THE MANY TYPE ` 0 VARIATIONS,ALTERATION CHANGES AND - '. 0 0 1'MINERAL REPLACEMENTS,THAT THERE ARE SU• Q .d2' AT LEAST 20 DIFFERENT LITHOLOGIES AFTER Kk IN• AZ '1.-6 11430';ESPECIALLY PROMINENT ARE HARD _.0 0 I' l:43.911 ROCKS OF MOSTLY GREENISH GRAY COLOR, vi vi ►i 011 .v.,^- a ` ORIGINALLY FORMED BY AIRFALL VOLCANIC ►.0 ASH,LATER DIVITRIFIED AND REPLACED BY v.,-,,,,,•-;;.-..„--,7: SILICA TO VARYING DENSITY AND OPACITY; 'Y : 2 KK .z o THE ABUNDANCE OF DIFFERENT SOFT AND HARD r 1i LITHOLOGIES SUGGESTS THAT INSTEAD OF ,?:-;= 0 J � 11 BEING BEDDED,THAT MOST(IF NOT ALL)OF Bii# 149' 6.92 "` ...ra...: ',1 i 11 THE CUTTINGS ARE BIT-INDUCED SAND-SIZED Grad -1•WI-A-X-1-• -TD _-.:.:.►i'. OKK_-_ FRAGMENTS OF LARGER CONGLOMERATES OR - O BRECCIAS;MANY OF THE SOFT ROCKS MAY BE ::=w=.,-___ ;LPARTIALLY BEDDED INTER-CLAST SUPPORT. T.D.=11780' V i 1 i 0 Prod n to'1700' REACH TOTAL DEPTH OF 11,700'M.D. INC 1. AZ 1,221.26 AT 23:28 HRS ON 9/26/2010 TVO t F101.86 RUN E-LOGS.RUN AND CEMENT 5 1/2" Il 1 PRODUCTION LINER. COMPLETE WELL. CRAIG SILVA RALPH WINKELMAN The log data,interpretations and recommendation provided by Epoch are inferences and assumptions based on measurements of drilling Fluids. Such inferences and assumptions are not infallible and reasonable professionals may differ. Epoch does not represent or warrant the accuracy,correctness or completeness of any log data,interpretations,recommendations or information provided by Epoch,its officers,agents or employees. Epoch does not and cannot guarantee the accuracy of any such interpretation of the log data,interpretations or recommendations and Company is fully responsible for all decisions and actions it takes based on such log data,interpretations and recommendations. A F ARMSTRONG C IV ^ C ooA Li/et,LLC NOV 0 3 2010 ACM t I&Gas Cons.cUm c 3siorr October 30,2010 Anchorage Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 Dear Mr. Seamount, RE: Well Completion Report Armstrong Cook Inlet, LLC North Fork Unit#14-25 PTD No. 210-111 Dear Commissioner Seamount, Armstrong Cook Inlet, LLC hereby submits it's Well Completion Report for the work performed in the drilling and completion of the North Fork Unit#14-25 well near Anchor Point on the Kenai Peninsula. Please fmd enclosed the following information for your files: 1) Form 10-407 Well Completion or Recompletion Report and Log 2) Well As-Built Survey 3) Wellbore Schematic 4) Well Operations Summary 5) Wellbore Directional Survey 6) Mud Log 7) LWD and Wireline Logs If you have any questions or require additional information,please contact me at(303) 623-1821 or Alexey Sachivichik at 264-6112. Sincerely, ARMSTRONG COOK INLET, LLC Edward Teng Vice President-Engineering enclosures 14.1 n)_)_..a...__. O/1•)119 nz /n/ £'17 7 O�7 r,.__ 27")� A .1 [i\iST 'o\ ; September 3, 2010 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations �l l Armstrong Cook Inlet,LLC: North Fork#14-25 (PTD#210-k1) Dear Mr. Seamount, This is a report of Armstrong Cook Inlet's well operations on the North Fork #14-25 for the period August 27 through September 2, 2010, inclusive. August 27, 2010 0' MW(N/A) Vis (N/A) Incl (N/A) Rigging up Glacier Rig#1. August 28, 2010 0' MW(N/A) Vis(N/A) Incl (N/A) Finish rigging up Glacier Rig #1. Function test diverter, witnessed by AOGCC's Jeff Jones. PU and SB 5"DP and BHA. August 29, 2010 754' MW 8.9 ppg Vis 72 sec Incl 1.44 deg Finish MU BHA. RIH, tag btm at 178'. Repair pump throttle motor control. Spud well, drill 13-1/2"hole from 178' to 754'. August 30, 2010 1,956' MW 9.3 ppg Vis 53 sec Incl 24.92 deg Drill 13-1/2" hole from 754' to 1,005'. Kick off well, directionally drill from 1,005' to 1,956'. August 31, 2010 2,714' MW 9.5 ppg Vis 49 sec Incl 33.54 deg Directionally drill 13-1/2" hole from 1,956' to 2,082'. CBU, short trip to 155', slip and cut drilling line. RIH, drill from 2,082' to 2,714'. September 1, 2010 2,992' MW 9.6 ppg Vis 43 sec Intl 34.24 deg Directionally drill 13-1/2" hole from 2,714' to 2,992'MD. CBU, short trip to 817' and back to btm — no fill. C&C hole and mud, POH, download and LD BHA. RU to run casing. September 2, 2010 2,992' MW 9.5 ppg Vis 42 sec Incl 34.24 deg Finish RU to run casing. Run 73 jts 10-3/4" csg to 2,982'. C&C hole for cementing. Pump 40 bbls spacer followed by 397 bbls 12.0 ppg Class G cement. Displace w/ mud using rig pumps. Good cement returns to surface and throughout job. Casing stuck as 1424 Blake Street,Denver,Colorado 80202 Ph 303-623-1821 Fax 303-623-3019 soon as cement came to surface. Did not bump plug. CIP at 2000 hrs. Begin ND diverter line. If you have any questions or require additional information, please contact me at 264- 6114. Sincerely, For ARMSTRONG COOK INLET, LLC eitt Peottede Bill Penrose Vice President/Drilling Manager SolstenXP,Inc. cc: Ed Teng- Armstrong 1424 Blake Street,Denver, Colorado 80202 Ph 303-623-1821 Fax 303-623-3019 1R N►sri o\ September 10, 2010 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations i t Armstrong Cook Inlet,LLC: North Fork#14-25 (PTD#210-H Dear Mr. Seamount, This is a report of Armstrong Cook Inlet's well operations on the North Fork #14-25 for the period September 3 through September 9, 2010, inclusive. September 3, 2010 2,992' MW(N/A) Vis (N/A) Incl 34.24 WOC until 0400 hrs. ND diverter line while WOC. Release elevators. Rough cut 10-3/4". ND diverter. Prep starting head. Make final cut on 10-3/4" & NU VetcoGray Multi-bowl wellhead, test to 2000 psi. NU BOPE. Set test plug. Start testing BOPE. BOPE test witness waived by AOGCC's Jim Regg. September 4, 2010 2,992' MW 9.4 Vis 42 Incl 34.24 Test BOPE - OK. PU BHA#2 -clean out assembly. RIH PU 56 jts DP,tag hard cement @ 2,815'. Drill cement to 2,877, circulate hole clean. Test casing to 3000 psi - leaked. Verify no surface leaks, retest - held at 1,000 psi, leaks off at 1,500 psi. Discuss with town. POOH. RU to PU BHA#3 - section drilling assembly. September 5, 2010 2,992' MW 9.0 ppg Vis 55 sec Incl 34.24 deg PU BHA#3, orient, load RA sources, shallow test tools -OK, RIH to 2,830'. Clean pits, inject old mud to NFU 34-26 well. Rack & tally 8-5/8" & 7-5/8" casing, load pits with water, mix new mud. September 6, 2010 4,006' MW 9.2 ppg Vis 50 sec Incl 32.92 deg Mix new 8.9 ppg mud, displace hole to same. Test 10-3/4" casing, staging up to 2,000 psi. Establish good test at 1,600 psi. Drill out cement & shoe track, clean out rat hole, drill 20'of new hole to 3,012'MD. Circulate hole clean, mud 8.9 ppg in& out. Perform formation leak-off test - 650 psi w/ 8.9 ppg mud = 13.4 ppg EMW. Drill 9-7/8" directional hole, maintaining angle and direction from 3,012'to 4,006'MD at midnight. September 7, 2010 5,238' MW 9.4 ppg Vis 50 sec Incl 33.57 deg Directionally drill 9-7/8" hole from 4,006' to 4,275'. Circulate hole clean. Precautionary short trip to 10-3/4" shoe. Service rig. RBIH, no fill. Drill 9-7/8" hole from 4,275' to 5,238', maintain angle and direction. 1424 Blake Street,Denver, Colorado 80202 Ph 303-623-1821 Fax 303-623-3019 September 8, 2010 5,306' MW 9.5 ppg Vis 48 sec Incl 32.83 deg Directionally drill 9-7/8" hole fr o m 5,238'to S 306'MD, section TD. S h ort trip to 4,1 50' and back to bottom, clean out light bridge at 5,003', wash last 80'to bottom-no fill. C&C hole. POOH, LD BHA #3. Pull wear bushing. Install 8-5/8" casing rams in upper rams and test - leaked on low pressure. Clean and flip ram blocks, rinse stack. Test plug leaked. Install new o-ring on test plug. September 9, 2010 5 306' MW 9.5 Vis 46 sec Incl 32.83 deg ppg g Repair leaks. Test 8-5/8" upper rams to 250 psi/5000 psi - OK. RU and run 7-5/8" X 8-5/8" casing to 2,882', circulate. Cont RIH with casing to 3,926' at XO to Hydril-521, elevators hanging up on box upsets, dress same. Circulate and work pipe while dressing inserts. Continue RIB with casing to 5,230' at midnight. If you have any questions or require additional information, please contact me at 264- 6112. Sincerely, For ARMSTRONG COOK INLET> LLC Alexey Sachivichik Senior Drilling Engineer SolstenXP,Inc. cc: Ed Teng- Armstrong 1424 Blake Street,Denver, Colorado 80202 Ph 303-623-1821 Fax 303-623-3019 A .1 „ ,,, I`RO\G September 17, 2010 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations i l 1 l'-‘6°- Armstrong Cook Inlet,LLC: North Fork#14-25 (PTD#21041) Dear Mr. Seamount, This is a report of Armstrong Cook Inlet's well operations on the North Fork #14-25 for the period September 10 through September 16, 2010, inclusive. September 10, 2010 5,306' MW 9.5 Vis 47 Incl 32.83 Finish running casing, land on hanger, shoe @ 5,297'. Circulate 2 casing volumes. Cement casing w/ 183 bbl lead, 27 bbl tail. Good cement to surface. LD landing joint, flush BOPs & lines, install casing pack-off, test 5K psi - OK. Set WB. Install variable rams in upper body. Rill and LD 5" DP,about 1,800' at a time. September 11, 2010 5,306' MW 9.45 Vis 46 Intl 32.83 Finish LD DP. Test casing to 4,000 psi - OK. Change lower pipe rams. Test BOPE. Spent much of day attempting to get lower pipe rams to test, finally successful. Finish BOP test. September 12, 2010 5,326' MW 9.45 ppg Vis 45 sec Inc132.83 deg Finish BOP test. BOPE test witness waived by AOGCC's Jim Regg. MU clean-out assembly, RIH PU 4" DP. Drill out cement, shoe track and 20' of new hole. Conduct LOT to 16.4 ppg EMW. September 13, 2010 5,412' MW 9.4 ppg Vis 49 sec Inc132.83 deg POOH w/ clean-out assy. MU drilling assembly, RIH PU DP. Drill from 5,326' to 5,412'. Lost communication with downhole tools. POOH,LD BHA. September 14, 2010 6,261' MW 9.3 ppg Vis 47 sec Incl 26.79 deg Finish LD BHA. Troubleshoot LWD. MU BHA #6 and RIH. Tag bottom at 5,412'. Directionally drill 6-3/4"hole from 5,412'to 6,261'. September 15, 2010 7,215' MW 9.4 ppg Vis 47 sec Incl 9.02 deg Directionally drill 6-3/4" hole from 6,261" to 7,135'. CBU, make short trip to 5,246'then back to bottom. Drill from 7,135'to 7,215'. 1424 Blake Street,Denver, Colorado 80202 Ph 303-623-1821 Fax 303-623-3019 September 16, 2010 8,619' MW 9.5 ppg Vis 50 sec Incl 1.82 deg Directionally drill 6-3/4" hole from 7,215'to 8,619'. If you have any questions or require additional information, please contact me at 264- 6112. Sincerely, For ARMSTRONG COOK INLET, LLC Alexey Sachivichik Senior Drilling Engineer SolstenXP,Inc. cc: Ed Teng- Armstrong 1424 Blake Street,Denver, Colorado 80202 Ph 303-623-1821 Fax 303-623-3019 A 11t\1S R0\(; September 24, 2010 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations 11, WO- Armstrong Cook Inlet,LLC: North Fork#14-25 (PTD#210-+) Dear Mr. Seamount, This is a report of Armstrong Cook Inlet's well operations on the North Fork #14-25 for the period September 17 through September 23, 2010, inclusive. September 17, 2010 8,899' MW 9.45 Vis 47 Incl 1.82 Drill from 8,619' to 8,830'. Repair top drive (Dennison engine). Drill from 8,830' to 8,836. Repair top drive (breakout). Drill from 8,836' to 8,899'. Lost transmission on #1 carrier engine. Pull bit to casing shoe. Replace transmission. September 18, 2010 9,151' MW 9.5 Vis 51 Incl 2.35 Finish transmission replacement on #1 main engine. R1H. Drill from 8,899' to 9,151'. #1 transmission failed again. Trouble shoot and POOH. September 19, 2010 9,151' MW 9.55 ppg Vis 57 sec Incl 2.35 deg POOH, handle BHA. Test BOPE while replacing #1 engine transmission. BOP test witnessed by AOGCC's Lou Grimaldi. September 20,2010 9,286' MW 9.5 ppg Vis 49 sec Intl 2.35 deg Finish installation of transmission on #1 engine. RIH with 64 joints DP, circulate out scale,POH. MU directional drilling BHA#7, test, RIH. Drill from 9,151" to 9,286'. September 21, 2010 10,219' MW 9.4 ppg Vis 47 sec Incl 1.40 deg Drill from 9,286' to 10,219'. September 22, 2010 10,646' MW 9.4 ppg Vis 49 sec Intl 0.58 deg Drill from 10,219' to 10,598'. Short trip to 9,026' and back to bottom - hole in good condition. Drill from 10,598'to 10,646'. September 23, 2010 11,249' MW 9.35 ppg Vis 51 sec Incl 1.48 deg Drill from 10,646' to 11,249'. 1424 Blake Street,Denver, Colorado 80202 Ph 303-623-1821 Fax 303-623-3019 114111I Uo\(; September 24, 2010 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations wok. Armstrong Cook Inlet, LLC: North Fork#14-25 (PTD#210- Dear Mr. Seamount, This is a report of Armstrong Cook Inlet's well operations on the North Fork #14-25 for the period September 24 through September 30, 2010, inclusive. September 24, 2010 11,537' MW 9.40 Vis 45 Incl 0.47 Drill from 11,249' to 11,537'. September 25, 2010 11,551' MW 9.40 Vis 48 Incl 0.15 Drill from 11,537' to 11,551'. CBU, POOH. LD MWD/LWD tools, motor and bit. MU new MWD/LWD tools, upload & stand back. Test BOPE, witness waived by AOGCC's John Crisp. Set wear bushing. September 26,2010 11,700' MW 9.40 ppg Vis 47 sec Incl 0.88 deg MU BHA#8, RIH, clean out tight spots at 8,109' and 9,028'. RITZ to 11,169', MAD pass to 11,551'. Drill from 11,551'to 11,700'MD. CBU for short trip. September 27, 2010 11,700' MW 9.80 ppg Vis 46 sec Incl 1.91 deg CBU. POOH for short trip to 8,081'. RIH, tight spot at 11,373', 10' fill on bottom. Circulate hole clean and WU mud to 9.8 ppg. POOH w/BHA#8. September 28, 2010 11,700' MW 10.45 ppg Vis 53 sec Incl 1.91 deg Stand back MWD/LWD tools. LD motor and bit. RU E-line, run Quad-Combo, work down to 10,800' where stopped. Log out to casing shoe. POOH, RD E-line. MU clean out assembly, RIH to shoe, service rig. Continue RIH to TD @ 11,700'. Hit bridges at 9,610' and 10,800'. Circulate and weight up mud. September 29, 2010 11,700' MW 10.5 ppg Vis 48 sec Incl 1.91 deg Circulate and weight up to 10.5 ppg. POOH,tight spots to 11,400' pull to 9,472'. RBIH, clean up bridges 11,214' and 11,408', ream last 22' to bottom -4' fill, bottom 4' is sticky. C&C, pump slug. POOH, wipe tight spots 10,272', 5,840', 5,620', 5,490', 5,470', no go at 5,464'. Very slow back ream out 5,509'- 5,377'then freed up. Wash up into shoe. RBIH to 6,009',wipe out spot at 5875'. POOH into shoe OK. 1424 Blake Street,Denver, Colorado 80202 Ph 303-623-1821 Fax 303-623-3019 September 30,2010 11,700' MW 10.80 ppg Vis 47 sec bid 1.91 deg POOH, LD BHA. RU E-Line. RIH with RSWC tools, tag and work through 5,479' and 5,531', tools stuck at 5,785'. Work free and work up into shoe. POOH, RD E-Line. LD MWD/LWD tools from derrick. MU clean-out BHA & RIH. No bridges or tight spots, wash last 85'to bottom, last 4' sticky. C&C, weight up to 10.8 ppg. If you have any questions or require additional information, please contact me at 264- 6112. Sincerely, For ARMSTRONG COOK INLET, LLC Alexey Sachivichik Senior Drilling Engineer SolstenXP,Inc. cc: Ed Teng- Armstrong 1424 Blake Street,Denver, Colorado 80202 Ph 303-623-1821 Fax 303-623-3019 A 1 R\ISTRO\G October 8, 2010 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations i t I idG041-- Armstrong Cook Inlet,LLC: North Fork#14-25 (PTD#210-14) Dear Mr. Seamount, This is a report of Armstrong Cook Inlet's well operations on the North Fork #14-25 for the period October 1 through October 7, 2010, inclusive. October 1, 2010 11,700' MW 10.80 Vis 49 Incl 1.91 C&C, WU to 10.8 ppg. POOH 10 stands, OK. Pump slug, POOH LD DP, HWDP and BHA. Pull WB. Test UPR(VBR's) with 5-1/2"joint to 250/5000 psi. Make dummy run w/ 5-1/2" hanger&landing jt. RU to run 5-1/2" production casing. October 2, 2010 11,700' MW 10.80 Vis 48 Incl 1.91 RU to run casing. Run shoe track, MU x-nipple 1 joint above FC, test dart on seat & remove dart. Cont RIH w/5-1/2" casing to 5,261'. Circulate casing volume. Drop dart, test casing to 8,500 psi for 30 min - OK. RU slickline, retrieve dart. Continue running casing to 6,030'. October 3, 2010 11,700' MW 9.60 ppg Vis 42 sec Incl 1.91 deg Cont RIH 5-1/2" casing from 6,030' to 8,599', casing stopped. Circulate one casing volume. MU top drive, circulate, work casing - stuck. Lower MW from 10.8 ppg to 9.6 ppg. Mix 62 Bbls Black Magic pill. Spot 49 bbls pill in open hole X 5-1/2" annulus, 13 bbls left in casing. Continue working casing. Pumping 1/4 bbl every 15 min to allow spotting fluid to soak. October 4, 2010 11,700' MW 9.60 ppg Vis 46 sec Incl 1.91 deg Cont working stuck casing while soaking with Black Magic pill. Pipe came free with 350K pull. Work pipe, break circulation, establish rotation. Wash & ream, circulate out spotting pill (saved —60 bbls). Condition mud. Continue RIB w/ 5-1/2" casing to 10,165'. Displace 10.8 ppg mud from annulus with 9.6 ppg mud. October 5, 2010 11,700' MW 9.70 ppg Vis 43 sec Incl 1.91 deg Cont RIH with 5-1/2" casing, W&R through tight spots 10,540' - 11,092'. RIH to 11,582' - OK. LD 6 joints, MU injection mandrel. RBIH, MU hanger and land casing. RILDS. Casing shoe at 11,690'. Circ 2,000 strokes-OK. RU SL, make 2 runs to pull RHC body 1424 Blake Street,Denver, Colorado 80202 Ph 303-623-1821 Fax 303-623-3019 from XN-nipple, no recovery. Circulate casing volume - 9.7 ppg mud in & out. Make 3rd run with SL to pull RHC, could not jar free-no recovery. October 6, 2010 11,700' MW 9.75 ppg Vis 43 sec Incl 1.91 deg POOH, RD SL. RU cement head & lines. C&C for cementing. PJSM. Cement 5-1/2" casing. RD cementing & casing running equipment. RU equipment for 2-7/8" DP. Set TWC, change rams,test BOPE. UPR failed twice. Replaced VBR's w/2-7/8" pipe rams, retested OK-lower TD valve failed. AOGCC advised. October 7, 2010 11,700' MW 9.75 ppg Vis 43 sec Incl 1.91 deg Finish testing BOPE, pull TWC. BOPE test witness waived by AOGCC`s Bob Noble. RU floor to run 2-7/8" DP. Rack & tally DP. Strap clean out BHA. MU 4-3/4" bit & mud motor. RIR PU 2-7/8" DP to 6,208'. Slip & cut drilling wire. Rack & tally more DP. Continue RIH to 7,000'. If you have any questions or require additional information, please contact me at 264- 6112. Sincerely, For ARMSTRONG COOK INLET,LLC Alexey Sachivichik Senior Drilling Engineer SolstenXP,Inc. cc: Ed Teng- Armstrong 1424 Blake Street,Denver, Colorado 80202 Ph 303-623-1821 Fax 303-623-3019 N\iSTNU\G October 15, 2010 Mr. Dan Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Weekly Report of Operations Armstrong Cook Inlet,LLC: North Fork#14-25 (PTD#210-111) Dear Mr. Seamount, This is a report of Armstrong Cook Inlet's well operations on the North Fork #14-25 for the period October 8 through October 11, 2010, inclusive. October 8, 2010 11,700' MW 9.70 ppg Vis 43 sec Incl 1.91 deg Continue RIH with clean out assembly. PU 2-7/8" DP from 7,000' to 11,476'. Tag plugs and cement. Drill same from 11,476' to 11,565'. POOH,LD motor and bit. MU mill and casing scraper,RIB on DP to 1,309'. October 9, 2010 11,700' MW 9.40 ppg Vis N/A Incl 1.91 deg Continue RIH with casing scraper to XN-nipple. Displace mud from well with 9.4 ppg brine. POOH LD DP. October 10, 2010 11,700' MW 9.40 ppg Vis N/A Incl 1.91 deg LD DP and scraper assembly. Run CBL. Pressure test casing to 8,500 psi for 30 min. and annulus to 5,000 psi for 30 min. —OK. ND BOPE and prep wellhead for installation of tree. October 11, 2010 11,700' MW 9.40 ppg Vis N/A Incl 1.91 deg 10K master valve too tall to fit under rig. Install spacer spool and rig down rig. Release the rig at 24:00 hours. FINAL REPORT 1424 Blake Street,Denver, Colorado 80202 Ph 303-623-1821 Fax 303-623-3019 If you have any questions or require additional information, please contact me at 264- 6112. Sincerely, For ARMSTRONG COOK INLET, LLC Alexey Sachivichik Senior Drilling Engineer SolstenXP,Inc. cc: Ed Teng- Armstrong 1424 Blake Street,Denver, Colorado 80202 Ph 303-623-1821 Fax 303-623-3019 Page 1 of 2 Aubert, Winton G (DOA) From: Aubert,Winton G (DOA) Sent Wednesday,September 08,2010 2:52 PM To: 'Bill Penrose' Subject RE:Request for Waiver-Armstrong Well#14-25(PTD#210-111) Bill, Pursuant to 20 AAC 25.030 (g)„AOGCC hereby approves a variance to the 10-3/4" casing pressure test requirement in well NFU 14-25 (PTD 210-111), as described below. You are authorized to continue with the approved drilling program. Please ensure that the subject test is documented in the well's daily drilling record. Winton Aubert AOGCC 793-1231 From: Bill Penrose[mailto:bill@solsterucp.com] Sent Wednesday, September 08, 2010 2:32 PM To:Aubert,Winton G(DOA) Cc:Alexey Sachivichik; Edward Teng Subject: Request for Waiver: Armstrong Well #14-25(PTD#210-111) Winton, This is to document a surface casing pressure test we conducted that fell short of meeting AOGCC regulation 20 MC 25.030(e)and to request authorization,per 20 MC 25.030(g),to proceed based on the reasoning given. 10-3/4"surface casing was run to 2,977'MD on Armstrong Cook Inlet,LLC's well NFU#14-25 on September 2 and cemented to surface. After waiting on cement,rigging down the diverter,rigging up and testing the BOP stack and displacing the spud mud out of the hole with polymer mud,an attempt was made to pressure test the casing to 3,000 psi on September 4. However,the highest pressure the casing would take and still pass a 30-minute test was 1,600 psi. At 2,000 psi,it fell just short of maintaining 90%integrity over 30 minutes. The required working pressure of the BOPE on this well is 5,000 psi and this 1,600 psi pressure test falls short of the 2,500 psi(50%of the BOPE working pressure) required. We plan to perform a formation leak-off test(LOT),immediately after drilling out the casing shoe. Based on a well drilled immediately adjacent to the current one,we expect to see leak-off at 600—700 psi casing pressure for a leak-off value of approximately 13.2 ppg EMW. If this is the case,then the strength of the formation at the casing shoe will become the critical pressure value in a well control situation and casing pressure integrity at a pressure significantly higher than that becomes a moot point. Our immediate plan forward,after drilling out and conducting the LOT,is to drill a 9-7/8"hole to 5,300' MD and set 7-5/8"x 8-5/8"casing there. We request a waiver to 20 MC 25.030(e),as authorized in 20 MC 25.030(g),in order to continue drilling operations past the 10-3/4"casing shoe. Thank you and regards, Page 2 of 2 Eilt PeyfroQe Vice President/Drilling Manager 310 K Street, Suite 700 Anchorage, Alaska 99501 Main 907-264-6100 Direct 907-264-6114 Cell 907-250-3113 9/13/2010 � ni [LnisEA SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 Edward Teng FAX (907)276-7542 Vice President - Engineering Armstrong Cook Inlet, LLC 1421 Blake Street Denver, CO 80202 Re: North Fork Field, North Fork Oil Pool, North Fork Unit #14-25 Armstrong Cook Inlet, LLC Permit No: 210-111 Surface Location: 649' FSL, 1600'FEL, SEC. 26, T4S, R14W Bottomhole Location: 230' FSL, 1025' FWL, SEC. 25, T4S, R14W Dear Mr. Teng: Enclosed is the approved application for permit to drill the above referenced exploration well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. Armstrong Cook Inlet, LLC assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. 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, Daniel T. Seamount, Jr. l 91°4"( Chair DATED this [ 0 day of August, 2010. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA RECEIVED „d - Al CA OIL AND GAS CONSERVATION COMI ION 8/G I4 PERMIT TO DRILL JUN 2 8 2010 QS/f/L/o 20 AAC 25.005 Al ka-0;1 h rag Carts.Commission - 1a.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone 1c.Spai ih b}s proposed for: Drill El Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone El coalbed Gas Al Gas Hydrates ❑ Re-entry ❑ Exploratory 0 Service- WAG ❑ Service-Disp ❑ (J(*" Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket g/ Single Well-- 11.Well Name and Number: Armstrong Cook Inlet,LLC Bond No. 559 North Fork Unit#14-25 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 1421 Blake St.,Denver,Colorado 80202 MD: 12,711' ND: 12,000' North Fork 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 649'FSL,1600'FEL,Sec 26 T4S R14W ADL-391211/ 09 j Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud D 230'FSL,1025'FWL,Sec 25,T4S,R14W N/A 54ug-10 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 230'FSL,1025'FWL,Sec 25,T4S,R14W 2520 sq.ft 649' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 16 feet 15.Distance to Nearest Well Open Surface:x- 199811.1 y- 2121193.414 Zone- 4 GL Elevation above MSL: 715 feet to Same Pool: 120'f/NFU 34-26 16.Deviated wells: Kickoff depth: 1,100 feet 17.Maximum Anticipated Pressured in psig(see 20 AAC 25.035) Y7 if L,r l,A- Maximum Hole Angle: 33.09 degrees Downhole: 6,365 psi 4 Surface: 4,044 psi 18.Casing Program: Specifications Top - Setting Depth - Bottom _ Cement Quantity,c.f.or sacks Hole _ Casing Weight Grade Coupling Length MD ND MD ND _ (including stage data) Driven 16" 84# N-80HC PEB 150' 16' 16' 150' 150' N/A 13-1/2" 10-3/4" 45.5# L80 BTC 2,984' 16' 16' 3,000' 2,794' 1,946.8 c.f. / 9-7/8" 8-5/8" 32# L80 Hydril 521 1,484' 16' 16' 1,500' 1,68E' iy9ff 9-7/8" 8-5/8" 32# L80 Hydril 511 984' 16' 16' .$i od,Je 190' .2J66111;1 c44- 9-7/8" 7-5/8" 29.7# L80 BTC-M 2,984' 16' 16' 5 .5,6#9' 4,889' 1 Ii 1,302.2 c.f. 6-3/4" 5-1/2" 17# P110 Hydril 513 12,695' 16' 16' 12,711' 12,000' 903.7 c.f. 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth ND(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 0 BOP Sketch El Drilling Program is Time v.Depth Plot 0 Shallow Hazard Analysis❑ Diverter Sketch El Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Alexey Sachivichik(907)264-6112 Printed N.u- 'ward Teng Title Vice President-Engineering . /0j i_ Signature -- ='' Phone (303)623-1821 Date ��C.42_ � 2 D/0 —� Commission Use Only Permit to Drill API Number: Permit A r9va See cover letter for other Number: 7J ), 50� ;/- J56'' Date: '6( 19; requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales:01 Other: T evi D o p E II, Too, e ice- • Samples req'd: Yes❑ No I Mud log req'd: Yes Rif No ❑ H2S measures: Yes❑ No le Directional svy req'd: Yes 1[J/No ❑ APPROVED BY THE COMMISSION V/(r61 DATE: AL ,COMMISSIONER l R Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate • \ >u, 444. `‘,A,‘ �Q� ' OF A�qs�,, 1� �i 0 i * 49 TH 1\ w / 0 c STAN A. McLANE ,o i ' `P., 4637—S �` ,§r-',S CFO �Oy \ T RSA C EEOFROW T 1 8 ,I PROFESS I ONP�LP NF1 1' 1,\V%N.NN ` \ N 2121382.00 NORTH FORK ROAD 100'RI�N NORTH FORK14-25 WELL E 199679.26 ELEV.656.69' EDGE°Pa°w NAD27 ASP ZONE 4 ® USE _ °�E a�'°�;� P."°s, � N:2121193.414 E:199811.131 TRACT 17-B-2 °r'q� µ LATITUDE: 59°47'46.964"N J LONGITUDE: 151°37'47.814"W ELEV. 657.5' NAVD88 '4- a ��_ ■■ S 1600' 2 __ `rte ---- FEL c. tJ6, w e' °"`— LOT 7 U Y o � O HM 1-485 \ g >j 2 64 SL J TRACT 20 UPLANDS OZ \�APPROx.e°U''''' L TRACT 19 W 0 0 re WETLANDS U 0 w N 2120505.98 WAGON ROAD 50'RNV(GRAVEL) E 201396.26 !SECTION LINE E1/16G, S26 S25 S351S36 c NOTES 1.BASIS OF HORIZONTAL COORDINATES ARE ALASKA STATE PLANE NAD 83 -__ ZONE 4 EPOCH 2003 DETERMINED BY AN NGS OPUS SOLUTION FROM CORS SCALE BASE STATIONS"KEN5","TSEA"AND"KOD5"OBSERVED DEC.13,2007 ON 0 SCALE 400 NF1 3 1/2"ALUM.CAP SET N:2121137.137 E:1339704.533 ELEV.656.69' NORTH 2)BASIS OF ELEVATION IS NGS BENCHMARK N86 TT0195 ELEV.180.84 FT. FEET NAVD88 DATUM. 91111111111111p I 3)SOUTHEAST CORNER SEC.26 COORDINATES DETERMINED FROM DIRECT SURVEY TIE TO THE TO EXISTING BLM SECTION CORNER TIE PER HM91-57 AND NOT THE PROTRACTED SECTION CORNER VALUES. `4)CORPSCON 6.0.1 UTILITY USED TO CONVERT FROM NAD83 TO NAD27. 1 PROJECT REVISION: _ ARMSTRONG COOK INLET, LLC NORTH FORK WELL 14-25 DATE: 06-10-10 700 17TH STREET#1400 SURFACE LOCATION DIAGRAM DRAWN BY: SAM DENVER,C080202 4R\($TRO\G NAD27 FOR INFORMATIONAL PURPOSES SCALE: 1,200' ONLY PROJECT NO. 073131 ENGINEERING/MAPPING/SURVEYING/TESTING BOOK NO. 07-29 Consaking Inc P.O.BOX 468 SOLDOTNA,AK.99669 LOCATION SHEET WeVOICE:(907)283-4218 FAX:(907)283-3265 S W 1/4 S E 1/4 EMAIL:SAMCLANE@MCLANECG.COM S26 T4S RI4W SEWARD MERIDIAN,ALASKA 1 OF 1 A ARMSTRONG COOK INLET, LLC ARMSTRONG CORAInlet.LLC North Fork Unit #14-25 General Prognosis Well Name: North Fork Unit#14-25 AFE Number: Permit To Drill No. Location Surface: 729' FSL, 1602' FEL, Sec 26, T4S R14W Bottom hole: 256' FSL, 1021' FWL, Sec 25, T4S R14W Planned TD 12,711' MD/ 12,000 TVD Directional Plan Directional, S-shape Well Summary A 16" conductor will be driven and installed, and a cellar will be constructed. Using water-based mud, approximately 3,000' MD of 13-1/2" hole will be drilled as per the directional program to the first casing point at 2,794' TVD where 10-3/4" surface casing will be run and cemented to surface. Then 2,500' of 9-7/8" hole will be drilled directionally to the intermediate casing point of 4,889' TVD, where 8-5/8" and 7-5/8" casing will be run and cemented. Finally, 7,211' of 6-3/4" hole will be drilled to a planned TD of 12,000' TVD and 5-1/2" production casing will be run and cemented in the Hemlock Formation. If open hole logs are sufficiently encouraging, the well will be stimulated and tested before being placed on production. Drilling Area Risks The lower portion of the surface hole and the entire intermediate hole will be drilled in the Beluga and Tyonek Formations which contain coal beds of varying thickness. Care must be exercised while drilling them as they tend to swell into the wellbore and may stick the drill pipe and possibly pack off, eliminating the ability to circulate. For this reason and others, the lower portion of the 13-1/2" hole, all of the 9-7/8" hole, and the upper portion of the 6-3/4"hole sections will be drilled using PDC bits. These bits exhibit a reverse drilling break upon encountering coals, allowing time to work them as they de- stress and swell. The nearest well to the North Fork Unit#14-25 (NFU #14-25) is the NFU#34-26, a shut- in gas producer located 60' away. The NFU #34-26 is a vertical well, and the directional plan for the NFU #14-25 calls for the build to head in the direction opposite of the NFU #34-26, so there will be no danger of intersecting the other wellbore. The mud weight needed to control pore pressures should rise gradually from 9.8 ppg near the surface and reach a maximum of approximately 10.2 ppg at the top of the Tyonek formation at±5,000' then remain fairly constant for the rest of the well. Based on offsetting well information, there are no shallow gas or H2S risks anticipated for this well. The maximum anticipated surface pressure in this well (assuming only gas in the wellbore) is 4,914 psi. This is calculated from the potential oil production zones (Hemlock and Hemlock repeat). The depth of the top of the Hemlock repeat interval is used for the calculation because this would be the deepest interval in which the well would take a kick. Prognosed Key Depths Depth Top of Beluga Fm. 1,402' TVD 10-3/4' Surface Casing Point 3,000' MD/2,794' TVD Top of Tyonek Fm. 4,690' TVD 7-5/8" Intermediate Casing Point 5,500' MD/4,889' TVD Top of Tyonek Red 5,782' TVD Top of Tyonek Blue 8,179' TVD Top of Tyonek Orange 9,689' TVDof�.K Top of Hemlock Fm. 10,360' TVD TD, 5-1/2"Production Casing Point 12,711' MD/ 12,000' TVD Pore Pressures/Mud Program The well will be spudded using water-base mud with a weight of 9.0 — 9.5 and P g � ppg adjusted as necessary while drilling into the top of the Tyonek Formation. The Tyonek Formation. is expected to require approximately 10.2 ppg mud the rest of the way to TD. Mud Logging Basic mud logging services will be provided from the surface to TD. Services will consist of cuttings description and construction of a lithology log to allow the Armstrong geologist to pick markers. The mud loggers will tie their well monitoring system into a PVT system to help monitor fluid levels and system gains/losses. Logging Program The following wireline logs will be run: 13-1/2" Surface Hole: GR, RES, DEN, NEUT, on LWD 9-7/8" Intermediate Hole: GR, RES, DEN,NEUT, on LWD 6-3/4" Production Hole: Quad-Pole Sonic ' BOP testing will be conducted at least every seven days. AOGCC Field Inspectors will be notified 24 hours in advance of spud and all diverter/BOP Tests. It will be noted on drilling report and on IADC sheet whether the test was witnessed by the AOGCC inspector or waived. Waste Disposal All solid waste, including drill cuttings, will be disposed of in a nearby permitted landfill. The drilling fluids will be disposed of down the permitted annulus of the NFU #34-26 well. Contacts Drilling Engineer Alexey Sachivichik Phone (907) 264-6112 Fax (907) 264-6190 Cell (907) 575-7315 Logistics Coordinator Brian Brigandi Phone (907) 264-6110 Fax (907) 264-6190 Cell (907) 748-7089 Operator's Rep Ed Teng Phone (303) 623-1821 (VP—Engineering) Fax (303) 623-3019 Cell (303) 981-9957 A ARMSTRONG (bnA brier.I/( North Fork Unit#14-25 Summary Drilling Program 1. Prior to moving in the drilling rig, drill/drive a 16" conductor to±150' below ground level then excavate around it and install a cellar. l 2. Move in, rig up Glacier Rig#1. Notify AOGCC of intention to spud. Rig up diverter on 16" conductor and function test. Rig up mud loggers. 3. M/U 13-1/2" drilling assembly with PDM and MWD tools and drill hole directionally to 3,000' MD (2,794' TVD)using 9.2 ppg spud mud. Angle will be built to 30 degrees. 4. Run 10-3/4", 45.5#, L80 BTC surface casing to TD and cement to surface per cementing j program. 5. Install wellhead, land casing,N/U 5K WP BOPE and test to 5,000 psi. 6. M/U 9-7/8"drilling assembly with PDM and MWD tools. 7. RIH with 9-7/8"drilling assembly, clean out to float collar and test 10-3/4" casing to 3,000 psi. Drill out float collar, cement, float shoe, and 20' of new hole. Conduct leak-off " test. 8. Drill 9-7/8"hole to 5,500' MD (4,889' TVD) as per directional program using 6..6,ppg mud. 9. Condition the hole, POH and run open-hole logs. 10. Run 7-5/8", 29.7#, L80 BTC-M x 8-5/8", 32#, L-80, Hydril 521/511 intermediate casing to TD. 7-5/8" casing will extend from TD to 2,500' MD and 8-5/8" casing will extend from 2,500' to surface. Cement as per cementing program. 11. M/U 6-3/4" drilling assembly with PDM and MWD tools. 12. RIH with 6-3/4"drill assembly, clean out to float collar and test 7-5/8" and 8-5/8" casing to 3,500 psi. Drill out float collar, cement, float shoe and 20' of new hole. Conduct leak- off test. 13. Drill 6-3/4"hole to TD of 12,711' MD (12,000 TVD) as per directional program. 14. Condition the hole, POH and run open-hole logs. 15. Perform a clean out run before running casing. 16. Run 5-1/2", 17#, P110, Hydril 513 production casing to TD and cement as per cementing program. 17. Pressure test 5-1/2" casing 3,500 psi. 18. N/D BOPE and N/U 10,000 psi WP tree and test tree. 19. Rig down and move out Glacier Rig#1. 20. After completion of the well, it will be perforated, fractured and tested. ANFU #14-25 ARMSTRONG Depth vs Days cook In/e/LLC (Set casing across Hemlock) 0 500 ' 1000 Dril 1 -1/2" ho e 1500 - 2000 2500 R n &cml 10-3/4"surface csc 3000 3500 Drill 9-7/8'hole 4000 4500 5000 Log, run &ant 7-5/8" i term ed iate c9g 5500 - w � L 6000 6500 7000 7500 Drill 6-3/4" hole 8000 1 8500 9000 Set&cmt 5-112" OH logg ng casing(3 days) 9500 (4 Jays) 10000 10500 11000 11500 12000 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 66 68 70 Days wjp 06/21/10 Armstrt. ,00k Inlet,LLC North Fork Unit Kenai Borough,Alaska North Fork Well#1 Proposed Well Schematic February 3rd,2010 1 N l) Est Est. Est. Directional Casing Formation Depths Ilole Size MW PoreP FracG Information 16"Drive Pipe 849,R3,N/80,PEB ,i i i/ 150' Uriscn 9.8 '` 13-1/2" 3 Beluga®1415' C3-test _ /11:1)'- IO.Z e j p pd 11°41 10-3/4"Surface Casing 45.5# R3 L80 BTC SMLS 2,794'TVD(3,000'MD) 13.2 1/4"SS 0.049"wall chemical Y injection line Intermediate casing swedg to 8-5/8"32#L80 Hydril 521 and Hydril 511 connection,Box OD 5-12"Chemical Irjectlor Sub @+/.2300' machined to 8.889".Top 1500'will be Hydril 4.767 Drift m,6.812"OD,P110 „i 521 and bottom 1000'will be Hydril 511.There ` will be one full length crossover joint from 521 to 511.Pin end will be 511.There will be a crossover sub from 8-5/8"32#L80 511 box to 7- Tyonek 4775' 5/8"29.7#L80 BTC-M pin. 9-78" • The 8-5/8"will be down to pass the injection nipple at around 2500'. / Weatherford xxxx BTC-M Hydraulic Stage Tool @ _ 3,000' TOC @ 4,470'TV (5,000' ) - t�% f( ? l\ _ / .L. 1Soo . llI-f vet ) J :.. ,2,6,AB 1:. w*a bdiri.6 s.wa.1,ar 7-5/8"Intermediate Casing 29.7#,R3,L80,BTC-M,SMLS 4,889'TVD(5,500'MD) 14.7 77/I G,Tt t 1 VANtr " ¶(( ) -(Si)`1(ilrjl �000) = Gytl(-'S 6-3/4" i;:::.:::1•••:1:..:•••••:.•i.,:f'i::.:.1.......:' 5-1/2"Production Casing 179,R3,P110,Hydril 513,SMLS 4 12,000''fVD(12,711'MI)) 16.8 TD 12,711'MD 12,000'TVD ANORTH FORK UNIT #14-25 ARMSTRONG Geo-Mechanical Plot Cook Inlet,LLC 0 16" Sterling 1000 - 2000 103/4" Frac.Grad. - 3000 7-5/8" Beluga 4000 • .-5000 - $ Tyonek 0)6000 cv X7000 Mud Weight Tyonek Red CU it8000 — Tyonek Blue 9000 5-/1/2" 10000 Tyonek Orange 11000 Hemlock 12000 - -- — - 13000 - -- 8 9 10 11 12 13 14 15 16 17 18 19 20 Mud Weight (ppg) A ARMSTRONG Cook Inlet,LLC MAXIMUM ANTICIPATED SURFACE PRESSURES (MASP) North Fork Unit#14-25 Note: Here MASP for each hole section is defined as the pore pressure at the next casing point less a gas column to surface. 13-1/2" Hole Section This hole section will be drilled with a diverter only, no BOPs. While MASP will equal the formation pore pressure at the surface casing shoe depth of 2,794' less a gas gradient to the surface, it cannot be shut in, only diverted. Calculation: MASP13_112 = (2,794 ft) ((9.2 ppg x 0.052)-0.1 psi/ft) = 1,057 psi 9-7/8" Hole Section The maximum anticipated surface pressure (MASP) for the 9-7/8"hole section in this directional hole will be the formation pore pressure at 4,889' section TD less a full gas column to the surface Offsetting well information indicates that the pore pressure in the base of the Beluga Fm above the 7-5/8" casing shoe at 4,862' will be 10.6 ppg EMW. The gas column in the well is assigned a density gradient of 0.11 psi/ft. Calculation: MASP9_7/8» = (4,721 ft) ((10.6 ppg x 0.052)-0.1 psi/ft) =2,130 psi 6-3/4" Hole Section The maximum anticipated surface pressure (MASP) for the 6-3/4"hole section in this directional hole will be the formation pore pressure at 12,000' TD less a full gas column from the base Tyonek formation to the surface and less oil column from TD to the base Tyonek. Offsetting well information indicates that the pore pressure in the lower Tyonek Formation at 12,000' will be 10.2 ppg EMW. The gas column in the well is assigned a density gradient of 0.1 psi/ft. The oil column in the well is assigned a density gradient of 0.33 psi/ft. Calculation: (JO.2_)i.0s0 16,10 MASP6_3i4-- = (12,000' x 0.5304 psi/ft)—(10,360' x 0.1 psi/ft)—((12,000'- 10,360') x 0.33 psi/ft) = 4,788 psi. 7 North Fork Unit #14-25 Casing Design Verification Planned Casing Program 10-3/4" 8-5/8" 8-5/8" 7-5/8" 5-1/2" Depth (MD) 3,000' 1,500' 2,500' 5,300' 12,711' Depth (TVD) 2,794' 1,494' 2,375' 4,721' 12,000' Hole Size 13-1/2" 9-7/8" 9-7/8" 9-7/8" 6-3/4" Weight(ppf) 45.5 32.0 32.0 29.7 17.0 Grade L80 L80 L80 L80 P110 Connection BTC Hydril 521 Hydril 511 BTC-M Hydril 513 Nominal ID (in) 9.95" 7.796" 7.796" 6.875" 4.892" API Casing Design Factors Design factors are essentially"safety factors"that allow the design of safe, reliable, casing strings. Each operator may have his own set of design factors based on his experience and the condition of the pipe. Here we use the following design factors. API Design Factors: Tensile Joint Strength: Nt= 1.8 Collapse (from external pressure): Nc= 1.125 Burst(from internal pressure): Ni= 1.1 The pore pressures and fracture gradients used here are those derived from studies of offsetting well data in the North Fork, Nikolaevsk, and Deep Creek Fields near Anchor Point,Alaska. Design Factor Calculations Burst Requirements Use maximum anticipated surface pressures(MASP)for each casing string. For each casing string, MASP is the formation pressure at the next casing point less a gas column to surface. 10-3/4',45.5#, L80, BTC Surface Casing: MASP at 9-7/8" hole section TD of 4,721: MASP =(4,721')((10.2 ppg x 0.052)-0.1 psi/ft) =2,032 psi DFb= burst strength/burst stress =5,210 psi/2,032 psi =2.6 8-5/8';32#, L80, Hydril 521 Intermediate Casing: Note: The depth used for this calculation is not the TD of the well, it is the Hemlock Repeat formation. This formation is a potential oil producer and would be where the well would receive an influx from a kick, even if the well was drilled to TD. MASP at 5-1/2" hole section TD of 11,689': MASP = (12,000'x 0.5304) -(10,360'x 0.1)-(1,640'x 0.33) =4,788 psi DFb= burst strength/burst stress =5,714 psi/4,788 psi =1.19 8-5/8",32#, L80, Hydril 511 Intermediate Casing: Note:The depth used for this calculation is not the TD of the well, it is the Hemlock Repeat formation. This formation is a potential oil producer and would be where the well would receive an influx from a kick,even if the well was drilled to TD. MASP at 5-1/2" hole section TD of 11,689': MASP = (12,000'x 0.5304)-(10,360'x 0.1) -(1,640'x 0.33) =4,788 psi DFb= burst strength/burst stress =5,714 psi/4,788 psi =1.19 7-5/8",29.7#, L80, BTC-M Intermediate Casing: Note:The depth used for this calculation is not the TD of the well, it is the Hemlock Repeat formation. This formation is a potential oil producer and would be where the well would receive an influx from a kick,even if the well was drilled to TD. MASP at 5-1/2" hole section TD of 11,689': MASP = (12,000' x 0.5304)- (10,360'x 0.1) -(1,640'x 0.33) =4,788 psi DFb= burst strength/ burst stress =6,890 psi/4,788 psi =1.44 5-1/2", 17#, P110, Hydril 513 Production Casing: Note:The depth used for this calculation is not the TD of the well, it is the Hemlock Repeat formation. This formation is a potential oil producer and would be where the well would receive an influx from a kick,even if the well was drilled to TD. MASP at 5-1/2" hole section TD of 11,689': MASP = (12,000'x 0.5304)- (10,360'x 0.1)-(1,640'x 0.33) =4,788 psi DFb= burst strength/burst stress =10,640 psi/4,788 psi =2.2 Collapse Requirements Use an external pressure consisting of formation pore pressure at the casing shoe and an internal pressure of a gas column to surface. 10-3/4",45.5#, L80, BTC Surface Casing: External pore pressure =9.2 ppg x 0.052 x 2,794' =1,337 psi Internal pressure w/gas only =0.1 x 2,794' =279 psi Collapse stress =1,337 psi—279 psi =1,058 psi DFc=collapse rating/collapse stress =2,480 psi/1,058 psi =2.34 8-5/8",32#, L80, Hydril 521 Intermediate Casing: External pore pressure =10.2 ppg x 0.052 x 1,494' =823 psi Internal pressure w/gas only =0.1 x 1,494' =149 psi Collapse stress =823 psi—149 psi =674 psi DFc=collapse rating/collapse stress =2,530 psi/674 psi =3.75 8-5/8",32#, L80, Hydril 511 Intermediate Casing: External pore pressure =10.2 ppg x 0.052 x 2,375' =1,309 psi Internal pressure w/gas only =0.1 x 2,375' =238 psi Collapse stress =1,309 psi—238 psi =1,071 psi DFc=collapse rating/collapse stress =2,530 psi/ 1,071 psi =2.4 7-5/8",29.7#,L80, BTC-M Intermediate Casing: External pore pressure =10.2 ppg x 0.052 x 4,721' =2,602 psi Internal pressure w/gas only =0.1 x 4,889' =489 psi Collapse stress =2,695 psi—489 psi =2,206 psi DFc=collapse rating/collapse stress =4,790 psi/2,206 psi =2.2 5-1/2", 17#, P110, Hydril 513 Production Casing: External pore pressure =10.2 ppg x 0.052 x 12,000' =6,365 psi Internal pressure w/gas only =0.1 x 12,000' =1,200 psi Collapse stress =6,365 psi—1,200 psi =5,165 psi DFc=collapse rating/collapse stress =7,460 psi/5,165 psi =1.4 Tension Check Use buoyed weight of casing in mud having expected density when running the pipe. 10-3/4",45.5#, L80, BTC Surface Casing: Weight in air =3,000'x 45.5 lb/ft =136,500 lbs Weight of displaced fluid =0.676 gal/ft x 3,000' x 9.2 ppg =18,658 lbs Pipe weight in fluid =136,500 lbs-18,658 lbs =117,842 lbs DFt= body tensile strength/ buoyed wt =1,040,00014J 117,842 lbs =8.8 i. k 8-5/8".32#, L80, Hydril 521 Intermediate Casing: Weight in air =1,500'x 32 lb/ft =48,000 lbs Weight of displaced fluid =0.475 gal/ft x 1,500'x 10.2 ppg =7,553 lbs Pipe weight in fluid =48,000 lbs-7,268 lbs =40,448 lbs DFt= body tensile strength/ buoyed wt =592,000 lbs/40,448 lbs =14.6 8-5/8".32#, L80, Hydril 511 Intermediate Casing: Weight in air =2,500'x 32 lb/ft =80,000 lbs Weight of displaced fluid = 0.475 gal/ft x 2,500'x 10.6 ppg =12,588 lbs Pipe weight in fluid =80,000 lbs-12,588 lbs =67,413 lbs DFt= body tensile strength/ buoyed wt =498,000 lbs/67,888 lbs =7.4 7-5/8',29.7#, L80, BTC-M Intermediate Casing: Weight in air =5,300'x 29.7 lb/ft =157,410 lbs Weight of displaced fluid =0.444 gal/ft x 5,300'x 10.2 ppg =24,944 lbs Pipe weight in fluid =163,350 lbs-24,944 lbs =132,466 lbs DFt= body tensile strength/buoyed wt =683,000 lbs/ 132,466 lbs =5.2 5-1/2", 17#, P110, Hydril 513 Production Casing: Weight in air =12,711'x 17 lb/ft =216,087 lbs Weight of displaced fluid =0.258 gal/ft x 12,711'x 10.2 ppg =33,450 lbs Pipe weight in fluid =216,087 lbs-33,450 lbs =182,637 lbs DFt= body tensile strength/ buoyed wt =390,000 lbs/183,637 lbs =2.1 Glacier 1 BOP Stack Flow Nipple Flow Line 13 5/8"5M Annular _ Preventer 13 5/8"5M Double Ram Preventer Pipe Ram 2 1/16"5M . Blind Ram . Check Valve 2 1/16"5M Manually 3 1/8"5M Manually Operated Valves Operated Valve X—•_1-X Choke II II[O]IIW ©III 13 5/8"5M Cross 3 1/8"5M Hydraulically Pipe Ram . 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Pat Tabet Coordinator—Technical Coordinates drilling fluids service and provides 303 573-2715 o Support technical support for engineering applications. 303 895-5855 c Denver,CO Robert Earl West Area Engineering Manages and provides engineering assistance to 307 389-1451 c Manager field operations and drilling fluids engineer's at Rock Springs,WY the well site. Don Schneider West Area Logistics Oversees warehousin g and product distribution 303 573-2707 o Manager for West area. 720 284-1667 c Denver,CO Aaron Bland Senior Account Rep Works with customers to sell products and 303 633-4522 o Denver,CO services and develop business. 720 810-5862 c Gerald Atol Alaska District Mgr Oversees operations and sales for Alaska for 907 561-4000 o Drilling Services Drilling Fluids,INTEQ and Hughes Christensen 907 240-8848 Jim Brown Mud Engineer Provides drilling fluids products and service at Consultant Engineer well site,including testing,maintenance, 907-398-8500 inventory and troubleshooting. DEN02211050176 Page 3 of 23 IMO Drilling Fluids Program Armstrong R� Drilling Fluids Cook Inlet, LLC SECTION 2 WELL#1 HEMLOCK The recommended fluid properties are meant only as a guide. Properties and Product concentrations should be adjusted onsite based on experience and the actual well bore conditions SPUD MUD MILGEL I MIL-LIME TERRA-MAX TERRA-MAX Interval(MD) Surface Intermediate Production 150'to+/-3,000' +/-3,000'to 5,500' 5,500'to 12,710' Hole Size 13 1/2" 9 7/8" 6 1/4" Casing Size 10 3/4" 7 5/8" 5 1/2" Fluid Weight 8.7—9.2 8.9—9.5 8.9—9.5 PPg Funnel Viscosity sec/qt (Funnel est. only 40-60 40-42 40-42 run system by YP) API Filtrate <9 <5 <5 ML/30 Minutes Plastic Viscosity ALAP ALAP ALAP cp Yield Point 15-20 10—15 10—15 #/100 ft2 Gel Strength g/10 4 l 8 4 1 8 10 Sec./10 Min pH +/-9.0 +/-9.5 +/-9.5 Drilled Solids% <6 <6 <6 DEN02211050176 Page 4 of 23 sits Drilling Fluids Program Armstrong RAKER Drilling Fluids Cook Inlet, LLC HUGHES SECTION 2.1 WELL SCHEMATIC 1-, , ,, 11 tl - .. Well trajectory SPUD MUD Horizontal displacement 30 60 MILGEL/MIL-LIME 0 5,000 10,01 O MW:8.7-9.2PP9 0 ' ' PV:ALAP YP:15-20 Ibs/100ft2 API:<9.0 5007 pH:+1-9.0 DS%:<6 1,000 1208 1,500- • • 3U00,O tt 10+14" 455 Ibsfft 206 2,0007 MW:8.9-9.5 ppg TERRA-MAX 2,500 PV:ALAP YP:12-18 Ibs1100ft2 3621 API:5 cc 3,000 pH:+/- 9 DS%:< 6 3,500- ,-. Al 4,000- L -4,500 5500.0 ft 7 5/8" 29.70 Ibs/ft [1 r 5,000 -=U10 ial B i�P�1 MW:8.9-9.5 ppg 5,500 TERRA-MAX 218 PV:ALAP YP:12-18 Ibs/100ft2 6,000 API:5 cc pH:+/-9.5 6,500 DS%:<6 8166 7,000 7,51111 - 9661 8,000 r 8,500 10812 9,000 115w N I [01 al 115 12710.9 ft E 1' 1E°r!IL:+N wr DEN02211050176 Page 5 of 23 Drilling Fluids Program Armstrong Drilling Fluids Cook Inlet, LLC SECTION 2.2 13 'h"HOLE- 10 3/4"CASING RECOMMENDED MUD PROPERTIES: Mud Viscosity Plastic Yield Point Gel API Filtrate pH Drilled Weight sec/qt Viscosity #/100ft2 Strengths nil Solids% ppg cps 10 sec/ 10 min 8.7-9.2 40-60 ALAP 15-20 8/10 <9 +/-9.0 <6 DEPTH: 150 TO 3,000' MD HOLE SIZE: 13 1/2" CASING SIZE: 10 3/4" MUD TYPE: SPUD MUD Make up the spud mud with 0.5 ppb of Soda Ash and 15 ppb of MILGEL.Adjust the pH with Caustic Soda as required to maintain a +/-9.0 pH. COMMON MUD MATERIALS Product Primary Function MILGEL Viscosity NEW-DRILL Sweeps BENEX Flocculent CAUSTIC SODA pH Control SAPP Bit Balling MIL-PLUG Bit Balling SODA ASH Hardness Control LCM(VARIOUS) Loss of Circulation MIL-BAR®410 Weight,Dry jobs LD-8 Defoamer SUPER SWEEP Sweep Agent During drilling of this first interval, cuttings removal may become problematic. This will be evidenced by tight hole and drag on connections. Should this occur, it will be necessary to circulate the hole and mechanically dislodge potential cutting beds. Our hydraulics model indicates that a 1 Yield Point is more beneficial than a 30 Yield Point in removing cuttings from the wellbore. This is primarily due to the fact that hole angle will be as high as 33° during the drilling of this surface hole. The model can be affected by actual drilling conditions, washouts, and the ability of the rig to provide the recommended pump output. Cuttings size also greatly influences the results obtained with the model. For our purpose, a cuttings size of 0.125"was used. Depending of hole conditions, periodic sweeps of NEW-DRILL and/or SUPER SWEEP are recommended. NEW-DRILL can be mixed directly down the drill pipe, using 2 to 3 viscosity cups at a time. SUPER SWEEP should be mixed in a 50 bbl pill and pumped as a viscous sweep. The benefit of SUPER SWEEP is its ability to clean the hole and not affect the overall circulating mud. The material along with the additional cuttings will be screened out upon return to surface, thereby leaving the mud properties unaffected. DEN02211050176 Page 6 of 23 Armstrong SAUCER Drilling Fluids Drilling Fluids Program Cook Inlet, LLC HUGHES During this interval, water dilutions will be required at a rate of 30 gallons per foot of hole drilled. This assumption is made using an 85% solids control efficiency and a target of 6% low gravity drilled solids. The use of all available solids control equipment, including a high speed centrifuge, is recommended at all times during the drilling of this interval. Treatments of BENEX at the flowline will help flocculate the circulating fluid and promote settling of drilled solids. Should loss of circulation or severe seepage occur, we recommend using inert materials in the fluid to address the proper particle size distribution. Our target particle size should be between 2 and 110 microns. MIL-CARB 5 and MIL-CARB 50 should adequately address the required particle size distribution in concentration of 5 ppb each. If bit balling is suspected, a pill containing SAPP and MIL-PLUG should be pumped to chemically and mechanically dislodge the ball. While drilling, the MBT of the mud should be kept below 20 ppb to prevent excessive viscosity and agglomeration of reactive solids. In this interval, between 200 and 400 feet, a "pea gravel" like formation may require a higher viscosity to clean and stabilize. A funnel viscosity up to 60 sec/qt may be required to maintain hole stability. Additional guidelines are listed below to ensure proper hole cleaning: Mud flow rate is the most important factor for hole cleaning in deviated wells.The maximum flow rate will be required throughout the hole section to effectively clean the hole. Maintain smooth flow rate delivery, stopping or starting the pumps can shock the hole. Use guidelines as per connections. Rotation of the drill string should be used whenever possible with a min of 90 rpm to 180 rpm. Change if vibration is detected. Movement of the drill pipe by both rotation or reciprocation will help mechanically disturb cuttings beds and greatly assist hole cleaning. Rotation is more effective since this distributes the cuttings from the low side into the higher flowing mud in the high side. Care should be exercised at connections, quickly bringing up the pumps and/or rotation can breakdown the formation. Expect an increase in ECD of 0.3 ppg while rotating above 70-80 rpm. Note that uncontrolled reaming down will give a larger ECD than the original drilling of the stand. Before connection Drill stand down then clear BHA of cuttings. Backream and ream down the full stand slowly(20 ft/min max) While backreaming/reaming, monitor trends(watch ECD while reaming if a PWD is available) Take torque and drag readings and compare on and off bottom with trends. If readings are off trend then backream stand again. Reduce flow rate to zero over 30 seconds. Stop rotating. Make connection. After connection Check returns, flow rate and pressure throughout the stages below. PU slowly and only 4 ft max when pulling out of the slips. Start rotating at 30 rpm, then slowly bring the pumps up to 250 gpm until returns are seen and stand pipe pressure breaks back(-30 sec). Monitor PWD readings if available and compare with trend readings. Slowly build flow rate and rotation to drilling rate. Check torque, drag and pressure with readings before connection. Monitor up, down & rotating weights each connection; compare trends. Examine for trends and sudden departures rather than absolute values. Monitor the amount, shape and size of cuttings over the shakers. Small rounded cuttings indicate that cuttings have been spending extended periods down hole being reground by the drill string. DEN02211050176 Page 7 of 23 IRfO Drilling Fluids Program Armstrong I EMER Drilling Fioids Cook Inlet, LLC Quantitatively measure the cuttings return rate at the shakers compared with the volume predicted from ROP. Watch for any sign of cavings over the shakers. Should cavings be observed, and if conditions permit, increase the mud weight by 0.2 ppg. Pills will only be pumped as hole conditions dictate. High weight pills(-3ppg over MW)may be used. The resulting increase in MW from these pills should be monitored with the projected weight up schedule. These pills will give—320'of annular length which equates to a total volume of—50 bbls. Only pump one pill at a time, after the hole has been conventionally cleaned with circulation and rotation, do not overload the annulus with cuttings, use the PWD for ECD control while pumping. Monitor the benefits of the pills on the PWD. Pills should be pumped at the beginning of a stand. Only allow one pill in the hole at any one time. Check shakers and numbers of bottoms up required to circulate pills out. Pump the pill all the way round the system without stopping to make connections. All pills at discretion of Drilling Supervisor. If pack off is detected or indicated, reduce the flow rate and reduce the rotation to 30 rpm before working the pipe back.A pack off can also cause a formation breakdown and loss of circulation if excessive flow rates are applied. The following discussion applies to lubricants for torque and drag management. This Recommended Practice covers the current best practices for torque and drag management through lubricant application in water-based fluid systems. Following these practices should result in major reductions in downhole torque and drag, and more effective weight transfer to the bit, which will result in easier directional control and higher ROP. Definitions: ROP Rate of Penetration BHA Bottom Hole Assembly ERD Extended Reach Drilling MWD Measurement While Drilling ppm parts per million ppg pounds per gallon v/v Volume/Volume Mud Engineer—Responsible for including lubricant recommendations for torque/drag management in approved Mud Program based on well design and area knowledge; responsible for ensuring that appropriate lubricants are available in sufficient quantity at the wellsite. Rig Supervisor—Responsible for coordinating needed requirements of the rig team in respect to wellbore torque/drag, directional drilling concerns, cost, and wellbore characteristics. Generally, surface intervals do not require lubricant support.The best means to achieve low torque and drag are operating practices that achieve good cuttings removal and low tortuosity. Liquid lubricants are often combined to enhance overall lubricant performance. The maximum total lubricant concentration should generally be limited to 3% v/v. The effectiveness of higher lubricant additions are small, and risks(discussed below)associated with "greasing"/saponification increase with DEN02211050176 Page 8 of 23 Bits Drilling Fluids Program Armstrong RAKER Drilling Fluids Cook Inlet, LLC HUGHES higher concentration. Our recommended luiquid lubricant is MIL-LUBE;we recommend a starting concentration of 1.5 to 2% v/v. A major contributor to drag in surface holes is clay "balling" of the BHA. Bit balling or BHA balling has been addressed earlier but to reiterate on the subject, maintaining a low MBT at or less than 20 ppb equivalent and sweeping the hole with SAPP/MIL-PLUG sweeps should be adequate measures to combat this issue. If however, torque and drag become an issue, and bit or BHA balling has been eliminated as the source of the problem, we recommend using 1.5% v/v of MIL-LUBE. Hole cleaning requirements and modeled flow rates: USW 111111111111111111 SPP ECD @ Casing Shoe ECD @ Bit Depth Max SPP 4000 9.28 3500 9.26 3000 9.24 N 9.22 p 2500 '.__._. -a a 920 Q 2000 9.18 1500 9.16 1000 - . - w ra.' 640 660 680 700 720 740 Flowrate(USgal/min) Our Advantage hydraulics model recommends a minimal flow rate of+/-700 gpm to effectively remove 0.125" cuttings from the wellbore. Please note that according to the model, due to the directional profile, a YP of 15 was found more effective than a YP of 30 lbs/100ft2. Pressure build up from inadequate hole cleaning thus excessive amounts of cuttings in the wellbore can lead to lost circulation. Do not over drill the ability to clean the hole. Fast drilling increases annular cutting concentrations and increases the potential to pack off. Monitor pressure build-ups at all times and circulate the hole clean if needed. DEN02211050176 Page 9 of 23 Armstrong sun MUER Drilling Fluids Drilling Fluids Program Cook Inlet, LLC HUME SECTION 2.3 9 7/8"HOLE -7 5/8"CASING RECOMMENDED MUD PROPERTIES: Mud Weight Viscosity Plastic Yield Point Gel Strengths API Filtrate pH KCL ppg sec/qt Viscosity #/100ft2 10 sec/ 10 nil Cps min 8.9-9.2 40-42 ALAP 12-15 4/8 <6 +/-9.5 5 DEPTH: 3,000 TO 5,500' MD HOLE SIZE: 9 7/8" CASING SIZE: 7 5/8" MUD TYPE: TERRA-MAX System If possible, drill-out the surface casing with water and divert cement-contaminated fluid. The pits should be thoroughly cleaned prior to building the TERRA-MAX mud. The proposed TERRA-MAX system is based on the inhibitive property of MAX-GUARD and its polyamine chemistry. The TERRA-MAX system is environmentally acceptable when used without salts. In this instance however, 5% KCI will be used in the formulation. COMMON MUD MATERIALS Product Primary Function BIOLOSETM Filtration Control MIL-PAC®R/LV Filtration Control and Encapsulation XAN-PLEX®D Viscosity Low and End Rheology MAX-GUARD Inhibition DESCO CF Deflocculent MILGEL® Filter Cake Quality LD-8® Defoamer CAUSTIC SODA pH Control MIL-LUBE Lubricant MIL-BAR 410® Weight XCIDE-102 Biocide SULFATROL Unconsolidated Formation Stabilizer KCI Inhibition from Potassium Ion PRODUCT 2077 Corrosion Inhibitor DEN02211050176 Page 11 of 23 101 Drilling Fluids Program Armstrong BAKER HES Drilling Fluids Cook Inlet, LLC HUG INITIAL DRILLING FLUID FORMULATION The recommended properties and product concentrations are only a guide that should be altered to maximize the drilling operation. It is the responsibility of the field personnel to assess hole conditions and come to a suitable agreement on the course of action needed to increase drilling efficiency. A trained Mud Engineer will be on site to provide additional recommendations based on current conditions. Product Recommended Treatment KCI 18 ppb XAN-PLEX®D 0.25 to 0.50 ppb for rheology control and low end rheology BIOLOSETM 2.0 ppb for filtration control MIL-PAC®R/LV 1 ppb for filtration control, encapsulation, high end rheology MILGEL® 5 ppb for wall cake quality only. DESCO CF Deflocculent MAX-GUARD 6 ppb for inhibition PRODUCT 2077 400 ppm Caustic Soda 0.15 ppb Mud-Up: Start the mud up process if at all possible while nippling up the BOPE. The products should be added in the order listed above. Add MILGEL (5 ppb) first and allow it to hydrate at least twenty minutes prior to adding other products. The hardness of the make-up water should be tested and brought down to less than 200 ppm if necessary with soda ash treatment. If starting from fresh water, as soon as practical, pre- hydrate 25 ppb of MILGEL in the pill pit to be added to the circulating system for an overall concentration of +/- 5 ppb of MILGEL. The purpose of adding MILGEL is strictly for filter cake quality and not for rheology control. If the current fluid has bentonite already in the system, estimate the quantity by an MBT test and dilute as to not exceed a 5 ppb concentration. Continue the mud-up process by adding 18 ppb of KCI to the system. This will provide additional inhibition from the potassium ion. Following the KCI, add MAX-GUARD to the system for a minimum initial concentration of +/- 6 ppb. Continue the mud-up process with 1 ppb of MIL-PAC R/ LV and 2 ppb of BIO-LOSE taking precautions as to not add these products at a rate faster than 30 minutes per sack to prevent fish eyes and product waste. Then finish mudding up by adding XAN-PLEX D as required to adjust the Yield Point and gel strength. The pH at this point should be maintained at +/- 9.5. If necessary, treat with small additions of Caustic Soda. The Yield Point and gels should be adjusted with XAN-PLEX D. We recommend a yield point of 12 to 15 and gels 4/8. The gel strength will be critical to support barite particles should hole conditions dictate an increase in mud weight. Adjust the gel strength as needed to prevent barite from settling. While drilling and maintaining or building volume, apply material balance calculations for water dilutions. MAX-GUARD concentrations should also be maintained at 6 ppb as per material balance calculations and Reinecke Salt test results. MAX-GUARD will only be effective as a clay hydration suppressant if it is maintain in excess in the system. Add 16 gallons of water per foot while drilling and dump the sand traps as needed or at least twice per DEN02211050176 Page 12 of 23 Drilling Fluids Program Armstrong Drilling Fluids Cook Inlet, LLC HUMES tour. Run all available solids control equipment including centrifuges if available in order to minimize low gravity solids build-up. The pipe corrosion should be monitored with rings at surface in the saver sub and on bottom of the string. For corrosion control, we recommend the use of PRODUCT 2077. Initial concentration should be brought up to 400 ppm, followed by 100 ppm daily treatment. The rings can be sent in for analysis every 80 to 120 hours or whenever a trip is made. Treat the mud with a ratio of two sacks of MIL-PAC R (60 min/sack) to four sacks of BIOLOSE (30 min/sack)in order to maintain the API at or below 6 cc. The mud weight should be adjusted according to hole conditions with additions of MIL-BAR 410 as required. According to preliminary data, the mud weight is not expected to exceed 9.5 ppg at TD of this interval or the next. Sweeps: HVS's should be pumped as dictated by hole conditions. If background torque is increasing, or drag on connections is elevated and persistent, then a HVS should be pumped. The HVS should be built according to the following formula. • Build 80 bbls of volume with water • Add MILGEL to obtain a 40'sec/qt slurry. Add approximately 20 ppb or 16 sacks. • Allow sufficient mixing time for MILGEL to completely yield. • Just prior to pumping, add 3 to 4 cups of NEW-DRILL to increase the viscosity to 100`sec/qt. Please note that adding MILGEL to the system will consume MAX-GUARD like reactive clays at a rate of 1 ppb per 4 ppb of reactive clays. Therefore, MILGEL additions should only be made when MBT readings are below 10 ppb equivalent. As an alternative,sweeps can be built with active mud from the circulating system,and additions of 1 ppb of XAN-PLEX D or 5 gallons of NEW-DRILL per 80 bbl pill. MIL-LUBE should be considered as a lubricant only if torque and drag become excessive. In "S curve"wells, the higher torque and drag is typically experienced after the tangent section while correcting the trajectory back to vertical. This is not programmed to happen until the next interval. Solids Control Equipment(SCE): Excellent solids control is essential to the system. By limiting the amount of undesirable solids, through the use of good separation equipment, the system becomes much more effective and economical. We recommend the use of a linear motion shaker utilizing the finest mesh shaker screens capable of handling the flow rate. Utilize the desander and desilter, and the centrifuge. Neglecting solids control when drilling can lead to differential sticking in sub-normally pressured, permeable zones because of the thick wall cake, which forms because of high differential pressure, and the relatively high solids content in the annulus. Precautions should be taken to prevent drilled solids from being re-circulated. The shale pit and the first settling pit should be dumped and cleaned frequently, all the available solids control equipment should be used, the pit dividers should remain closed and the risers should be elevated to provide a skimming effect on the first settling pit after the shaker and the pit directly prior to the suction. DEN02211050176 Page 13 of 23 �it1♦ Drilling Fluids Program Armstrong BAKER Drilling Fluids Cook Inlet, LLC HUGHES Hole cleaning requirements and modeled flow rates: 41104111 enninsi SPP ECD @ Casing Shoe ECD @ Bit Depth Max SPP 9.316 4000 9.314 9.312 3800 9.310 3600 9.308 a 3400 9 306 m 2 o �' 3200, 9.304 la 2 `a a 9.302 3000 9.300 2800 400 9.298 2600 ' 9.296 2400 •equired Flowrate 9.294 540 560 580 600 620 640 Flowrate (USgal/min) Our Advantage hydraulics model recommends a minimal flow rate of+/-580 gpm to effectively remove 0.125" cuttings from the wellbore. Please note that according to the model, due to the directional profile, a YP of 15 was found more effective than a YP of 30 Ibs/100ft2. Pressure build up from inadequate hole cleaning thus excessive amounts of cuttings in the wellbore can lead to lost circulation. Do not over drill the ability to clean the hole. Fast drilling increases annular cutting concentrations and increases the potential to pack off. Monitor pressure build-ups at all times and circulate the hole clean if needed. DEN02211050176 Page 14 of 23 Drilling Fluids Program Armstrong RAKER= Drilling Fluids Cook Inlet, LLC HUM SECTION 2.4 6 3/"HOLE—5 ''/2"CASING RECOMMENDED MUD PROPERTIES: Mud Weight Viscosity Plastic Yield Point Gel Strengths API Filtrate pH KCL ppg sec/qt Viscosity #/100ft2 10 sec/ 10 ml Cps min 8.9-9.2 40-42 ALAP 12-15 4/8 <6 +/-9.5 5 DEPTH: 5,500 TO 12,710' MD HOLE SIZE: 6 3/4" CASING SIZE: 5 1/2" MUD TYPE: TERRA-MAX System The mud system from the previous interval will be used. It is recommended to pre-treat with sodium bicarbonate in anticipation of drilling relatively fresh cement. The proposed TERRA-MAX system is based on the inhibitive property of MAX-GUARD and its polyamine chemistry. The TERRA-MAX system is environmentally acceptable when used without salts. In this instance however, 5% KCI will be used in formulation. COMMON MUD MATERIALS Product Primary Function BIOLOSETM Filtration Control MIL-PAC®R/LV Filtration Control and Encapsulation XAN-PLEX®D Viscosity Low and End Rheology MAX-GUARD Inhibition DESCO CF Deflocculent MILGEL® Filter Cake Quality LD-8® Defoamer CAUSTIC SODA pH Control MIL-LUBE Lubricant MIL-BAR 410® Weight XCIDE-102 Biocide SULFATROL Unconsolidated Formation Stabilizer KCI Inhibition from Potassium Ion PRODUCT 2077 Corrosion Inhibitor DEN02211050176 Page 16 of 23 Drilling Fluids Program Armstrong RAKER Drilling Fluids Cook Inlet, LLC HUGHES INITIAL DRILLING FLUID FORMULATION The recommended properties and product concentrations are only a guide that should be altered to maximize the drilling operation. It is the responsibility of the field personnel to assess hole conditions and come to a suitable agreement on the course of action needed to increase drilling efficiency. A trained Mud Engineer will be on site to provide additonal recommendations based on current conditions. Product Recommended Treatment KCI 18 ppb XAN-PLEX®D 0.25 to 0.50 ppb for rheology control and low end rheology BIOLOSETM 2.0 ppb for filtration control MIL-PAC®R/ LV 1 ppb for filtration control, encapsulation, high end rheology MILGEL® 5 ppb for wall cake quality only. DRILL-THIN Deflocculent MAX-GUARD 6 ppb for inhibition PRODUCT 2077 400 ppm Caustic Soda 0.15 ppb Adjust the filtrate to< 5 cc with BIO-LOSE and MIL-PAC R/LV. (2 to 1 ratio of BIOLOSE to MIL-PAC R) This is important to avoid tight hole issues in porous areas of the wellbore. The Yield Point and gels should be adjusted with XAN-PLEX D. We recommend a yield point of 12 and gels 4/8. The gel strength will be critical to support barite particles should hole conditions dictate an increase in mud weight. In this interval the dilution rate should be of +/- 7 gallons of water per foot of hole drilled. The concentration of products will need to be maintained as per dilution requirements. Continue additions of MAX-GUARD to maintain concentration around 4 ppb or as needed to maintain an excess in the mud filtrate. DEN02211050176 Page 17 of 23 Drilling Fluids Program Armstrong MAKER Drilling Fluids Cook Inlet, LLC HUSHES Daily Mud Maintenance: As drilling resumes, the mud system will need a daily treatment to maintain the desired properties. Tourly treatment suggestions will generally follow the guidelines offered below. • Maintain the Yield Point at+/- 12 - 15 Ibs/100ft2 with XAN-PLEX D as needed. The quantity used will depend upon water additions and dumping of volume. • Maintain +/- 4 ppb of MAX-GUARD in the system utilizing mass balance calculations to match makeup water additions, as well as the Reinecke Salt test results. • Maintain 5% of KCI (18 ppb)in the system with additions of KCL as required. • The mud weight should be adjusted with MIL-BAR 410 as dictated by hole conditions. The fluid's pH should be maintained around 9.5 with Caustic Soda additions. • As long as the fluid loss remains below 5 cc's, no additional chemicals will be necessary. Should the filtrate require to be lowered, 1 to 2 sacks of MIL-PAC R / LV per tour and 5 sacks of BIO-LOSE should be added. • Dump the sand trap/settling pit at least twice per tour. This helps keep the mud weight and drilled solids low. The sand trap should be dumped often but it is not necessary to dump the entire content of the pit. It is more effective to dump half the volume often to keep sediments from building up. This can be accomplished at any time, even during circulation. • Maintain the calcium levels below 200 mg/I with additions of Soda Ash as needed. A higher calcium content will lessen the effectiveness of the polymers in the system. • Should added hole stability be required, add 4 to 6 ppb of SULFATROL. This treatment will only be warranted if hole conditions deteriorate and the well bore becomes unstable. • Monitor bacteria growth with serial vial dilution tests and treat as needed with XCIDE-102. • Treat thickening or flocculation of the mud with DRILL-THIN as needed. • Treat the system with a minimum of 1.5% by volume of MIL-LUBE to decrease torque and drag. Solids Control Equipment(SCE): Excellent solids control is essential to the system. By limiting the amount of undesirable solids, through the use of good separation equipment, the system becomes much more effective and economical. We recommend the use of a linear motion shaker utilizing the finest mesh shaker screens capable of handling the flow rate. Utilize the desander and desilter, and the centrifuge. Neglecting solids control while drilling can lead to differential sticking in sub-normally pressured, permeable zones because of the thick wall cake, which forms because of high differential pressure, and the relatively high solids content in the annulus. Precautions should be taken to prevent drilled solids from being re-circulated. The shale pit and the first settling pit should be dumped and cleaned frequently, all the available solids control equipment should be used, the pit dividers should remain closed and the risers should be elevated to provide a skimming effect on the first settling pit after the shaker and the pit directly prior to the suction. DEN02211050176 Page 18 of 23 Drilling Fluids Program Armstrong BAKER HES Drilling Fluids Cook Inlet, LLC HUG Hole cleaning requirements and modeled flow rates: - 1_ - I SPP ECD @ Casing Shoe ECD @ Bit Depth Max SPP 4000 3500 ? 9.95 _3000 rn n C7 N O 9.90 N 2500 2 a 2000 9.85 1500 9 RO Required Pin 1000 160 170 180 190 200 210 220 230 240 250 Flowrate (USgal/min) Hole cleaning should not be an issue in this interval. The model predicts a minimum flow rate of 210 gpm to effectively remove the cuttings from the wellbore. DEN02211050176 Page 19 of 23 ■ LIPe!j Proposal No: 1001128368E Armstrong Cookinlet LLC NFU 14-25 (Hemlock Well) Glacier#1 Rig North Fork Field Alaska June 10, 2010 Well Proposal Prepared for: Prepared by: Ed Teng Kenneth Nix VP - Engineering District Technical Supervisor Armstrong Kenai, Alaska Bus Phone: (303) 623-1821 Mobile: (303) 981-9957 P0wERVIsI0N® POW E RPRO • PO W ERI'RAX • POW E RLIN K Service Point: Service Representatives: Kenai Rod Edwards Bus Phone: (907) 776-4084 Account Manager (907) 659-2329 Kenai, Alaska Fax: (907) 776-4087 Bus Phone: 907-349-6518 Mobile: 907-229-6536 Gr4105 Operator Name: Armstrong CookiV' ` LLC Well Name: NFU 14-25 (Her. K Well) Lid Job Description: 10 3/4" Surface Date: June 10, 2010 Proposal No: 1001128368E WELL DATA ANNULAR GEOMETRY ANNULAR I.D. I DEPTH(ft) (in) MEASURED I TRUE VERTICAL 15.000 CASING I 150 I 150 13.500 HOLE I 3,000 I 2,787 SUSPENDED PIPES DIAMETER (in) WEIGHT DEPTH(ft) O.D. I I.D. (lbs/ft) MEASURED TRUE VERTICAL 10.750 I I.D. I 45.5 I 3,000 I 2,787 Float Collar set @ 2,920 ft Mud Density 9.00 ppg Mud Type Water Based Est. Static Temp. 80 ° F Est. Circ. Temp. 80 ° F VOLUME CALCULATIONS 150 ft x 0.5969 cf/ft with 0% excess = 89.5 cf 2,850 ft x 0.3637 cf/ft with 75% excess = 1814.1 cf 80 ft x 0.5400 cf/ft with 0% excess = 43.2 cf(inside pipe) TOTAL SLURRY VOLUME = 1946.8 cf = 347 bbls Report Printed on June 10,2010 5 4 PM Page 1 5-4 STIMULATION . CEMENTING , COMPLETION SERVICES o SERVICE TOOLS o COILED TUBING PRODUCTION CHEMICALS 0 CASING AND TUBING RUNNING SERVICES o PIPELINE SERVICES a WELL CONTROL Operator Name: Armstrong Cooki '_LC Well Name: NFU 14-25 (Hem.--x Well) Job Description: 10 3/4"Surface Date: June 10, 2010 Proposal No: 1001128368E FLUID SPECIFICATIONS Spacer 40.0 bbls Mud Clean II VOLUME VOLUME FLUID CU-FT FACTOR AMOUNT AND TYPE OF CEMENT Slurry 1947 / 2.0 = 933 sacks Class G Cement+0.05% bwoc Static Free + 25% bwoc LW-6 +0.6% bwoc CD-32 + 1 gals/100 sack FP-6L +0.4% bwoc Sodium Metasilicate + 5% bwoc MPA-1 + 68.1% Fresh Water Displacement 280.8 bbls Displacement Fluid CEMENT PROPERTIES SLURRY NO. 1 Slurry Weight(ppg) 12.00 Slurry Yield (cf/sack) 2.09 Amount of Mix Water(gps) 7.68 Amount of Mix Fluid (gps) 7.69 Fluid design is for pricing purposes only. Actual design will change based on real well conditions. Report Printed on June 10,2010 5:41 PM Page 2 Gr4129 STIMULATION o CEMENTING o COMPLETION SERVICES o SERVICE TOOLS o COILED TUBING PRODUCTION CHEMICALS . CASING AND TUBING RUNNING SERVICES o PIPELINE SERVICES o WELL CONTROL Operator Name: Armstrong Cooki' LLC Well Name: NFU 14-25 (Hers K Well) Job Description: 10 3/4" Surface Date: June 10, 2010 Proposal No: 1001128368E WELL DATA ANNULAR GEOMETRY ANNULAR I.D. DEPTH(ft) (in) MEASURED I TRUE VERTICAL I 9.950 CASING I 3,000 I 2,787 9.500 HOLE I 5,500 I 4,862 SUSPENDED PIPES S DIAMETER (in) WEIGHT DEPTH(ft) O.D. I.D. (Ibs/ft) I MEASURED I TRUE VERTICAL 7.625 I 6.875 I 29.7 I 5,500 I 4,862 Float Collar set @ 5,420 ft Mud Density 9.00 ppg Est. Static Temp. 105 ° F Est. Circ. Temp. 90 ° F VOLUME CALCULATIONS 3,000 ft x 0.2229 cf/ft with 0% excess = 668.6 cf 2,500 ft x 0.1751 cf/ft with 40% excess = 613.0 cf 80 ft x 0.2578 cf/ft with 0% excess = 20.6 cf(inside pipe) TOTAL SLURRY VOLUME = 1302.2 cf 232 bbls Report Printed on June 10.2010 541 PM Page 5 Gr4115 STIMULATION c CEMENTING o COMPLETION SERVICES o SERVICE TOOLS o COILED TUBING PRODUCTION CHEMICALS o CASING AND TUBING RUNNING SERVICES o PIPELINE SERVICES o WELL CONTROL • Operator Name: Armstrong Cooki' '_LC Well Name: NFU 14-25 (Henm—K Well) Job Description: 7 5/8" Intermediate Date: June 10, 2010 Proposal No: 1001128368E FLUID SPECIFICATIONS Weighted Spacer 20.0 bbls BJ Seal Bond + 19 lbs/bbl Potassium Chloride + 124 lbs/bbl Barite-Sacked @ 11 ppg VOLUME VOLUME FLUID CU-FT FACTOR AMOUNT AND TYPE OF CEMENT Lead Slurry 669 / 2.4 = 272 sacks Class G Cement+0.2% bwoc CD-32 + 0.3% b w oc FL- 2 + bwoc Sodium Metasilicate +20% bwoc MPA-1 + 0.05% bwoc Static Free + 1 gals/100 sack FP-6L + 121.8% Fresh Water Tail Slurry 634 / 1.1 = 546 sacks Class G Cement+0.05% bwoc Static Free+ 1.2% bwoc BA-56 +0.5% bwoc EC-1 + 0.3% bwoc CD-32 + 1 gals/100 sack FP-6L +0.2% bwoc Sodium Metasilicate +43.6% Fresh Water Displacement 248.9 bbls Displacment Fluid CEMENT PROPERTIES SLURRY SLURRY NO. 1 NO.2 Slurry Weight(ppg) 12.50 15.80 Slurry Yield (cf/sack) 2.46 1.16 Amount of Mix Water(gps) 13.73 4.91 Amount of Mix Fluid (gps) 13.74 4.92 Fluid design is for pricing purposes only. Actual design will change based on real well conditions. Report Printed on June 10,2010 5:41 PM page 6 Gr4129 STIMULATION a CEMENTING o COMPLETION SERVICES o SERVICE TOOLS o COILED TUBING PRODUCTION CHEMICALS o CASING AND TUBING RUNNING SERVICES o PIPELINE SERVICES . WELL CONTROL Operator Name: Armstrong Cookir' ' LLC Well Name: NFU 14-25 (Hen. Well) Job Description: 7 5/8" Intermediate Date: June 10, 2010 Proposal No: 1001128368E WELL DATA ANNULAR GEOMETRY ANNULAR I.D. DEPTH(ft) I (in) MEASURED I TRUE VERTICAL 6.875 CASING I 5,500 I 4,862 6.750 HOLE I 12,743 I 12,000 SUSPENDED PIPES DIAMETER (in) WEIGHT DEPTH(ft) O.D. I I.D. (Ibs/ft) MEASURED I TRUE VERTICAL 5.500 I 4.892 I 17 I 12,743 I 12,000 Float Collar set @ 12,663 ft Mud Density 12.00 ppg Mud Type Water Based Est. Static Temp. 206 ° F Est. Circ. Temp. 154 ° F VOLUME CALCULATIONS 500 ft x 0.0928 cf/ft with 0% excess = 46.4 cf 7,243 ft x 0.0835 cf/ft with 40% excess = 846.9 cf 80 ft x 0.1305 cf/ft with 0% excess = 10.4 cf(inside pipe) TOTAL SLURRY VOLUME = 903.7 cf - 161 bbls Report Pooled on June 10,2010 5 41 PM Page 9 Gr4115 STIMULATION o CEMENTING . COMPLETION SERVICES a SERVICE TOOLS a COILED TUBING PRODUCTION CHEMICALS o CASING AND TUBING RUNNING SERVICES o PIPELINE SERVICES a WELL CONTROL Operator Name: Armstrong Cooki' _LC Well Name: NFU 14-25 (Hemi...,K Well) Job Description: 5.5" Long String Date: June 10, 2010 Proposal No: 1001128368E FLUID SPECIFICATIONS Weighted Spacer 40.0 bbls BJ Seal Bond + 19 Ibs/bbl Potassium Chloride + 124 lbs/bbl Barite-Sacked @ 11 ppg VOLUME VOLUME FLUID CU-FT FACTOR AMOUNT AND TYPE OF CEMENT Slurry 904 / 1.1 = 778 sacks Class G Cement+0.05% bwoc Static Free + 1.2% bwoc BA-56 +0.3% bwoc R-3 + 0.5% bwoc EC-1 + 0.3% bwoc CD-32 + 1 gals/100 sack FP-6L + 0.2% bwoc Sodium Metasilicate +43.5% Fresh Water Displacement 294.4 bbls Displacement Fluid CEMENT PROPERTIES SLURRY NO. 1 Slurry Weight(ppg) 15.80 Slurry Yield (cf/sack) 1.16 Amount of Mix Water(gps) 4.90 Amount of Mix Fluid (gps) 4.91 Fluid design is for pricing purposes only. Actual design will change based on real well conditions. Report Printed on.June 10,2010 5:41 PM Page 10 Gr4129 STIMULATION a CEMENTING o COMPLETION SERVICES o SERVICE TOOLS o COILED TUBING PRODUCTION CHEMICALS o CASING AND TUBING RUNNING SERVICES , PIPELINE SERVICES o WELL CONTROL ' Operator Name: Armstrong Cookinw. LLC Well Name: NFU 14-25 (Hen ;Well) • Date: June 10, 2010 Proposal No: 1001128368E CONDITIONS BJ Services' performance of services and sale of materials is expressly conditioned upon the applicability of the Terms and Conditions contained in the current BJ Services Price Book. The Terms and Conditions include, among other things, an indemnity in favor of BJ Services from Customer for damage to the well bore, reservoir damage, loss of the hole, blowouts and loss of control of the well, even if caused by the negligence or other fault of BJ Services. The Terms and Conditions also limit the warranties provided by the BJ Services and the remedies to which Customer may be entitled in the event of a breach of warranty by BJ Services. For these reasons, we strongly recommend that you carefully review a copy of the Terms and Conditions. If you do not have a copy of the BJ Services Price Book, you can view the Terms and Conditions on BJ Services Web Site,www.bjservices.com. By requesting that BJ Services perform the services described herein, Customer acknowledges that such Terms and Conditions are applicable to the services. Further, by requesting the services, Customer warrants that its representative on the well location or other service site will be fully authorized to acknowledge such Terms and Conditions by executing a Field Receipt or other document presented by BJ Services containing such Terms and Conditions. In the event that Customer and BJ Services have executed a Master Services Agreement covering the work to be performed, such Master Services Agreement shall govern in place of the Terms and Conditions. If you are interested in entering into Master Services Agreement with BJ Services, please contact us through the"Go BJ" button on the BJ Services Web Site. Report Printed on JUN-10.10 02:41 Gr4175 Page 11 Operator: Armstrong Cookinlet L Well Name: NFU 14-25 (Hemlock o.,il) Date: June 10, 2010 Proposal No: 1001128368E PRODUCT DESCRIPTIONS BA-56 A gas migration additive that controls fluid loss, limits free water and provides excellent solids support. It is functional at low to moderate temperatures ranges. Barite-Sacked A naturally occuring mineral (Barium Sulfate). It is widely used as a weighting material in cement spacers and occasionally in cement slurries. It can yield a slurry density in excess of 19 lbs/gal. CD-32 A patented, free-flowing, water soluble polymer that is an efficient and effective dispersant for primary and remedial cementing. Class G Cement Intended for use as a basic cement from surface to 8000 ft as manufactured, or can be used with accelerators and retarders to cover a wide range of well depths and temperatures. EC-1 A proprietary product that provides expansive properties and improves bonding at low to moderate temperatures. FL-52 A water soluble, high molecular weight fluid loss additive used in medium to low density slurries. It is functional from low to high temperature ranges. FP-6L A clear liquid that decreases foaming in slurries during mixing. LW-6 Natural graded hollow pozzolan microspheres, which when mixed with API cements, yield slurry densities from 8-12 lbs/gal. Besides having low densities and relatively high compressive strengths, these systems also offer good insulating properties for application such as steam floods. MPA-1 MPA-1 is a fine white pozzolanic type powder used to enhance various cement properties. These properties include: Enhanced Compressive Strength Development, Improved Sulfate Resistance, Increased Tensile and Flexural Strength, and Gas Control. MPA-1 is functional over a broad temperature range, and can be used in foamed lightweight, normal, and heavyweight cement designs. Concentrations range from 1 to 30% BWOC. Mud Clean II A water-base mud wash designed for use ahead of cement slurries to aid in mud and drilling debris removal and to prevent contamination of the cement slurry. It should be used only when water-base mud is used. Potassium Chloride A granular salt used to reduce clay swelling caused by water-base stimulation fluids. R-3 A low temperature retarder used in a wide range of slurry formulations to extend the slurry thickening time. Report Printed on June 10,2010 5:41 PM Gr4163 STIMULATION o CEMENTING o COMPLETION CERVICES o SERVICE TOOLS a COILED TUBING PRODUCTION CHEMICALS o CASING AND TUBING RUNNING SERVICES a PIPELINE SERVICES o WELL CONTROL . CHEMICAL SERVICES Operator: Armstrong Cookinlet L' Well Name: NFU 14-25 (Hemlock 1,...11) Date: June 10, 2010 Proposal No: 1001128368E PRODUCT DESCRIPTIONS (Continued) SealBond Spacer Forms a non invasive seal to prevent filtrate invasion into the producing formation. Sodium Metasilicate An accelerator used to decrease the thickening time of cement slurries. Sodium Metasilicate An extender used to produce an economical, low density cement slurry. Static Free An anti-static additive used to prevent air entrainment due to agglomerated particles. Can be used in Cementing and Fracturing operations to aid in the flow of dry materials. Report Printed on June 10,2010 5 4 PM Gr4163 n___ wn STIMULATION • CEMENTING • COMPLETION SERVICES , SERVICE TOOLS • COILED TUBING PRODUCTION CHEMICALS o CASING AND TUBING RUNNING SERVICES o PIPELINE SERVICES •WELL CONTROL . CHEMICAL SERVICES Operator Name: Armstrong Cookie. PLC Well Name: NFU 14-25 (Hemlock Well) Date: June 10, 2010 Proposal No: 1001128368E End of Report Report Printed on June 10,2010 5:41 P Gdast A RECEIVED ARMSTRONG ,x,A M„tei«< JUN 2 8 2010 Alaska Oil&Caa Cerra.Commission June 28, 2010 inehvrne Mr. Daniel Seamount, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill: North Fork Unit#14-25 Dear Mr. Seamount, Armstrong Cook Inlet, LLC hereby applies for a Permit to Drill an onshore oil exploration well near Anchor Point on the Kenai Peninsula. Armstrong plans to spud the North Fork Unit#14-25 approximately August 5th. Armstrong plans to use Marathon Glacier#1 Rig to drill this well and complete it for testing. If the well test results from the Hemlock formation are sufficiently encouraging, the well will be placed on long-term production. If not, the well will be plugged back to the Tyonek formation and be placed in long-term production as a gas producer. Please find attached information as required by 20 AAC 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 2) A plat showing the surface location of the well 3) General Prognosis with Drilling Area Risks and Waste Disposal 4) Summary Drilling Program 5) Drilling Time vs. Depth Plot 6) Proposed North Fork Unit#14-25 Wellbore Diagram 7) Geo-mechanical Plot 8) MASP Calculations 9) Casing Properties and Design Factors 10)Diagrams and Descriptions of the BOP Equipment to be used 11)Planned Wellpath Report 12)Drilling Fluid Program 13)Cementing Program The following are Armstrong's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Alexey Sachivichik (20 AAC 25.070) (907) 264-6112 2) Geologic Data and Logs Edward Teng, Vice President of Operations (20 AAC 25.071) (303) 623-1821 If you have any questions or require additional information, please contact me at (303) 623-1821 or Alexey Sachivichik at (907) 264-6112. Sincerely, ARMSTRONG COOK INLET, LLC Mt* — Edward Teng Vice President of Operations Enclosures Cc: Alexey Sachivichik—Fairweather E&P Services, Inc. Alaska Department of Natural "sources Land Administration System Page 1 of/ Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 2095 Printable Case File Summary See Township,Range, Section and Acreage? New Search Yes 0 No LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 2095 Search for Status Plat Updates As of 08/10/2010 Customer: 000048451 ARMSTRONG COOK INLET,LLC 1421 BLAKE STREET DENVER 80202 Case Type:785 O&G TRANS FEDERAL LEASE DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ACTIVE AUTHORIZATION Status Date: 02/01/1967 Total Acres: 1240.000 Date Initiated:02/01/1967 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 07/22/2008 Case Subtype: CI. COOK INLET Last Transaction: COMMENTS COMMENTS Meridian: S Township: 004S Range: 013W Section: 20 Section Acres: 600 Search Plats Meridian: S Township: 004S Range: 014W Section: 25 Section Acres: 640 Search Plats Legal Description 02-01-1967 ***TRANSFERRED LEGAL DESCRIPTION*** T4S, R14W, SM SECTION 25:ALL T4S, R13W, SM SECTION 8:ALL SECTION 17:ALL SECTION 20:N1/2, SW1/4 http://dnr.alaska.gov/projects/las/Case Summary.cfm?FileType=ADL&FileNumber=2095... 8/10/2010 Alaska Department of Natural r-sources Land Administration System Page 1 of/ ( `NIAlaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 391211 8 Printable Case File Summary See Township,Range, Section and Acreage? New Search 0 Yes O No LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 391211 ma� Search for Status Plat Updates As of 08/10/2010 Customer: 000048451 ARMSTRONG COOK INLET,LLC 1421 BLAKE STREET DENVER 80202 Case Type: 785 O&G TRANS FEDERAL LEASE DNR Unit: 780 OIL AND GAS File Location:DOG DIV OIL AND GAS Case Status: 35 ACTIVE AUTHORIZATION Status Date: 11/01/2006 Total Acres: 2520.000 Date Initiated: 11/01/2006 Office of Primaiy Responsibility:DOG DIV OIL AND GAS Last Transaction Date: 07/28/2008 Case Subtype: Cl COOK INLET Last Transaction: COMMENTS COMMENTS Meridian: S Township: 004S Range: 014W Section: 23 Section Acres: 640 Search Plats Meridian: S Township: 004S Range: 014W Section: 24 Section Acres: 640 Meridian: S Township: 004S Range: 014W Section: 26 Section Acres: 640 Meridian: S Township: 004S Range: 014W Section: 27 Section Acres: 600 Legal Description 11-01-2006 BLM transfer A-024366 to State of Alaska T.4S., R.14W., Seward Meridian, Alaska Section 23: Surveyed, all, 640.00 acres; Section 24: Surveyed, all, 640.00 acres; Section 26: Surveyed, all, 640.00 acres; Section 27: Surveyed, E2, E2W2, W2SW4, SW4NW4, 600.00 acres; Containing 2,520.00 acres, more or less. Lease committed in part to the North Fork Unit and Gas Pool #1 Participating Area NORTH FORK UNIT http://dnr.alaska.gov/prof ects/las/Case_Summary.cfm?FileType=ADL&FileNumber=3912... 8/10/2010 TRANSMITTAL LETTER CHECKLIST WELL NAME /YO'C77, .C,r 147 / :.ar PTD# Development Service ✓ Exploratory Stratigraphic Test Non-Conventional Well FIELD: AlaG,W iftAC POOL: ZiKES.e5z-4✓� Circle 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 perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception.j "., ' 0:5,ZQgt '1 '' 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: 1/11/2008 ❑❑ N aD o W N 0 n , 3 (j . . . „ . . . . . . . . . . . . . 12 cn a 0 O U o 111 d, . , , , , , , , , , O , , .e , , , v , , , , , , , CO J • u, c 0 e , 6 1101 Y al ur _a o ai a n s x co a} 03. fa' Q Q U1 Z CI) M M Z. Q, X w • . , .C) C , • .0 N Q CB' W W' N' W W W W W O, W, W. W. W O 0W. 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