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211-158
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, June 12, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Cook Inlet Natural Gas Storage Alaska, LLC S-5 CANNERY LOOP UNIT S-5 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/12/2024 S-5 50-133-20601-00-00 211-158-0 G SPT 4867 2111580 1500 1290 1291 1291 1291 0 0 0 0 4YRTST P Josh Hunt 4/25/2024 Good test. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:CANNERY LOOP UNIT S-5 Inspection Date: Tubing OA Packer Depth 116 1800 1796 1794IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240425182244 BBL Pumped:4.8 BBL Returned:4.5 Wednesday, June 12, 2024 Page 1 of 1 Clark Olsen ASRC Consulting & Environmental Services, LLC Well Site Leader (907) 252-2248 colsen@asrcenergy.com 1 March 25, 2024 Alaska Oil and Gas Conservation Commission Natural Resource Technician 333 W 7th Ave, Suite 100 Anchorage, Alaska 99501 RE: DATA TRANSMITTAL - WELL: CINGSA CLU S-5 PTD: 211-158 API: 50-133-20601-00-00 Initial Data Transmittal of x Sigma Analysis using RMT3D – 02/27/2024 x RMT3D Processed Log LAS file – 02/28/2024 Data Transfer Folder: CINGSA Well Logs Subfolders: 211-158 CLU Storage 5 Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: 211-158 T38672 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.26 13:16:37 -08'00' 1 Carlisle, Samantha J (OGC) From:Regg, James B (OGC) Sent:Friday, January 14, 2022 7:55 AM To:AOGCC Records (CED sponsored) Subject:FW: CINGSA Wells 1-5 SVS Test Report 1-13-2022 CLU S‐5; PTD 2111580 Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: Regg, James B (OGC) Sent: Friday, January 14, 2022 7:54 AM To: Stan Saner <Stan.Saner@cingsa.com> Subject: RE: CINGSA Wells 1‐5 SVS Test Report 1‐13‐2022 Thank you for the quick response. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: Stan Saner <Stan.Saner@cingsa.com> Sent: Friday, January 14, 2022 7:38 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Aaron Barlow <Aaron.Barlow@cingsa.com>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Matthew Federle <Matthew.Federle@cingsa.com> Subject: RE: CINGSA Wells 1‐5 SVS Test Report 1‐13‐2022 Jim, We are working on a plan to heat trace and insulating the tree valves in particular the SSV valve, including the Master, and Wing valve on Well #5. Stan Saner CINGSA Supervisor 1377 Beaver Loop Road Kenai, AK 99611 Desk Phone: 907‐714‐7582 Cell Phone: 907‐398‐0836 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Friday, January 14, 2022 7:32 AM To: Aaron Barlow <Aaron.Barlow@cingsa.com>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Matthew Federle <Matthew.Federle@cingsa.com>; Stan Saner <Stan.Saner@cingsa.com> Subject: RE: CINGSA Wells 1‐5 SVS Test Report 1‐13‐2022 CAUTION: This email originated outside of AltaGas. Do not click links or open attachments unless you recognize the sender and know the content is safe. If you are not sure, use the "Report Phish" button or contact itservicedesk@altagas.ca What is CINGSA doing to prevent recurrence of the frozen SSV? Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: Aaron Barlow <Aaron.Barlow@cingsa.com> Sent: Thursday, January 13, 2022 5:14 PM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Matthew Federle <Matthew.Federle@cingsa.com>; Stan Saner <Stan.Saner@cingsa.com> Subject: CINGSA Wells 1‐5 SVS Test Report 1‐13‐2022 Phoebe and Jim, Attached is the test report for our SVS testing wells 1‐5. Aaron Barlow CINGSA Operator 1377 Beaver Loop Road Kenai, AK 99611 Office: (907) 714‐7577 Cell: (907) 953‐5893 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. MEMORANDUM TO: Jim Regg P.I. Supervisor �Ce� FROM: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, November 2, 2021 SUBJECT: Mechanical Integrity Tests Cook Inlet Natural Gas Storage Alaska, LLC S-5 CANNERY LOOP UNIT S-5 Src: Inspector Reviewed B P.I. Supry Comm Well Name CANNERY LOOP UNIT S-5 API Well Number 50-133-20601-00-00 Inspector Name: Jeff Jones Well Permit Number: 211-158-0 Inspection Date: 10/1/2021 ✓ Insp Num: mitJJ211102081942 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-5 ' Type Inj N. TVD 4867 - Tubing 0 - 0 0 - 0 - PTD 2111580 ' Type Test SPT ITest psi 1650 IA 0 1660 1660- 1660 - BBL Pumped: 3.6 BBL Returned: 3-4 OA 0 0 - 0- 0 Interval OTS P/F P Notes: MITIA to 1650 psi per sundry 3� 21-296- OA is cemented. One well inspected, no exceptions noted. Tuesday, November 2, 2021 Page 1 of 1 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp W ell Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) 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. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Contact Email: Authorized Title:Contact Phone: Sr Pet Eng: Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 3. Address: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf MD measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: measuredPlugs Junk measured Length SizeCasing TVD Burst Collapse Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Samantha Carlisle at 4:37 pm, Nov 01, 2021 RBDMS HEW 11/3/2021 SFD 11/2/2021 DSR-11/1/21BJM 11/5/21 CINGSA CLU Storage 05 Current Velocity String Schematic October 01, 2021 7” 26# L80 VAMTOP Production Liner from 8,684’ MD / 4867’ TVD TOP To 11,099’ MD / 5127’ TVD TD 8-1/2” hole / Cemented 8.6 PPG KCl Brine Packer Fluid w/ Corrosion Inhibitor in 3.5” x 9-5/8” Annulus 7” RN Nipple @ 8707’ MD / 4878’ TVD 5.88” ID, 7.60” OD Top Btm Length Top Btm 9,060' 9,130' 70' 4,954' 4,966' Original Perfs 2/18/2012 ; Reperf'd (9060' - 9120') on 7/21/2012 9,210' 9,390' 180' 4,979' 5,010' Original Perfs 2/18/2012 ; Reperf'd (9230' - 9320' & 9330' - 9390') on 7/21/2012 9,420' 9,470' 50' 5,015' 5,023' Original Perfs 2/18/2012 9,770' 10,380' 610' 5,061' 5,100' Original Perfs 2/18/2012 ; Reperf'd (9780' - 9990' & 10000' - 10060' & 10070' - 10220') on 7/21/2012 10,580' 10,880' 300' 5,109' 5,119' Original Perfs 2/18/2012 ; Reperf'd (10630' - 10750') on 7/21/2012 1,210' MD Perforations TVD Perforations Comments Total Footage FMC Wellhead: 13-5/8” 5000# Multibowl FMC Tree: 7” 5000# complete with SSV 20” 133# X56 Driven to 117.5’ MD 13-3/8” 68# K55 BTC Surface Casing @ 2390’ MD / 2013’ TVD 9-5/8” DV Collar @ 3510’’ 16” hole / Cemented to Surface SSV Line to 3-1/2” SVLN 3-1/2” SVLN, RRQ, 2.813” ID @ 164’ MD w/ VAM TOP BxP, XO to 3-½” RTS-8 BxP, 9-5/8” 40# L80 BTC Intermediate Casing @ 8860’ MD / 4916’ TVD 12-1/4” hole / Cemented to Surface, Two Stages 3-½”, 9.3# L-80 RTS-8 Velocity String Tubing 7” x 9-5/8” Baker ZXP Liner Top Packer With 10’ seal bore @ 8,684’ MD / 4867’ TVD Eline Conveyed 7” x 3-½” Pkr w/ 10’ PBR @ 8702’ MD / 4877’ TVD. 3-½” XN Profile Nipple w/ WLEG w/ 3-½” EZGO HTGT Pin. WLEG @ 8731’ MD / 4885’ TVD 10’ Locator Seal Assy. w/ 3-½” EZGO HTGT Box x-over 7” VAM TOP X 3 ½” RTS-8 below tubing hanger and 7”VAMTOP pup jt. w/ 3 ½” BPV H-profile inside x-over CINGSA CLU S-5 2021 Operations Summary Report Revised By: Zan Walsh October 24, 2021 22 September 2021 Report 01 Rig released to demobilize to CINGSA at 06:00. Demobilize rig and move to CLU S-5. Note oversized load restrictions in place due to school high traffic hours. 23 September 2021 Report 02 Move in and rig up over well. Raise derrick, Hook up rig modules. 24 September 2021 Report 03 Continue hooking up rig. Mix 6% KCl brine with corrosion inhibitor, rig up on master valve to circulate out diesel freeze protect. Remove lower master valve. 25 September 2021 Report 04 Install blanking plug, nipple up and test BOPE.BOP test witnessed by AOGCC inspector Bob Noble. Had a Fail/Pass on leaking 4-way valve for lower VBR pipe rams on accumulator. Rebuilt valve and retested good. Make up overshot fishing assembly, RIH on 4-1/2” DP and tag top of 3-1/2” fish @ 151'. 26 September 2021 Report 05 Wash over and attempt to engage 3-1/2” fish, c/o overshot assy. and engage fish, P/U wt. indicates pipe is not cut and we have whole string, Mobilize e-line out and recut pipe above and below tubing anchor. POH and L/D fish above anchor. RIH w/ fishing BHA #2 (includes new 3-1/2” x 7” hydraulic tubing anchor) to top of tubing cut @ 233’, drop bar ball, pressure up to 4000 psi, set anchor in 7” tubing w/ overshot, and grapple latched to severed 3-1/2” tubing above old anchor, backoff safety joint. POOH. R/U and Pull 7" hanger to rig floor, circulate bottoms up, L/D hanger and POH laying down 7" casing. Pull second full joint below 7” SVLN and note only upper new tubing anchor in 7”, lower tubing anchor did not come out w/ 7” tubing. 27 September 2021 Report 06 L/D remaining 7" casing, install wear bushing, perform 1500 psi well integrity test. R/U and fish 3-1/2" EZGO tbg @ 226’, latch and POOH laying down 3-1/2" x 7” anchor and EZGO velocity string. 28 September 2021 Report 07 L/D remaining 3-1/2 completion string, P/U clean out BHA and RIH picking up DP to 3510’ MD (9-5/8 scraper would not pass DV collar). POH and L/D BHA, Test casing 1600 psi f/10 min. (Good test), P/U new cleanout BHA w/o scraper and RIH to 3493', Work through DV several times both with and without circulation w/ no problems. Continue RIH picking up DP to 6317'. 29 September 2021 Report 08 Continue RIH P/U DP to 8680',Circ sweeps and clean hole, POH standing back DP in derrick for second cleanout run if needed, L/D cleanout BHA. No need for secondary cleanout run, RIH to break apart each doubled joint of 4-1/2” DP to properly L/D and clean derrick floor of DP. Only running DP to 3100’ MD to stay above DV collar at 3510’ MD. 30 September 2021 Report 09 L/D the remaining DP out of the derrick, Retrieve wear bushing, Service rig, PJSM, Run 3-1/2" completion, M/U SVLN between jt 272 and 273. perform 1500 psi well integrity test. Run 3-1/2" completion, BOP test witnessed by AOGCC inspector Bob Noble. Test casing 1600 psi f/10 min. CINGSA CLU S-5 2021 Operations Summary Report Revised By: Zan Walsh October 24, 2021 01 October 2021 Report 10 RIH to top of BWD seal bore, insert seal assy into bore and PT to 2000 psi (Good), P/U, space out and M/U hanger and landing jt assy. Change over to clean filtered 6% KCl w/ corrosion inhibitor, Pump 10 bbl diesel freeze protection on backside, land hanger w/ seals in seal bore. R/U Pollard slick line, retrieve SVLN dummy, run 2.8" gauge to 8710', reset SVKN dummy sleeve, R/D Pollard, Perform charted MIT witnessed by AOGCC inspector Jeff Jones. Install BPV, Flush and rig down BOPE. 02 October 2021 Report 11 Clean and prep BOPE for storage, R/D Koomey lines to BOPE, N/D BOPE, Clean pits, Install bonnet and master valve on wellhead, PT cavity to 5000 PSI for 15 Minutes. Test Control Line 5000 PSI for 15 minutes, witnessed by CINGSA. Cont. R/D rig to be split and staged for moving when road restrictions are lifted Monday. 03 October 2021 Report 12 Rig down and stage rig modules on location for moving Monday. Install and test tree (Witnessed by PRA DSM and CINGSA Operator) Clean up and remove liner and felt. 04 October 2021 Report 13 Move remaining rig components. 05 October 2021 Report 14 Remove Hilcorp camp from location at 4:20 AM. insert seal assy into bore and PT to 2000 psi (Good) Perform charted MIT witnessed by AOGCC inspector Jeff Jones. STATE OF ALASKA Reviewed By: OIL AND GAS CONSERVATION COMMISSION P I Supry BOPE Test Report for: CANNERY LOOP UNIT S-5 ' Comm Contractor/Rig No.: Hilcorp 169 PTD#: 2111580- DATE: 9/25/2021 Inspector Bob Noble Insp Source Operator: Cook Inlet Natural Gas Storage Alaska, LL Operator Rep: Yessak Rig Rep: Van Evera Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopRCN210926125317 Rams -Annular. Valves: MASP: Type Test: INTT 321-296 1 250/2500 250/2500 - 250/2500 1400 • Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: Upper Kelly - I P/F Lower Kelly Visual Alarm Time/Pressure P/F Location Gen.: _P Trip Tank --P P ' System Pressure 3050 _ - FP Housekeeping: P - Pit Level Indicators P P Pressure After Closure 1350 P " PTD On Location P Flow Indicator P P 200 PSI Attained 31 - P Standing Order Posted P Meth Gas Detector P P Full Pressure Attained 121 P - Well Sign P - H2S Gas Detector P P Blind Switch Covers: All Stations - P - Drl. Rig P _ MS Mise NA NA Nitgn. Bottles (avg): 4 (a), 2450 _ P' - Hazard Sec. P _' P, Inside Reel Valves 0 NA___ ACC Misc 0 NA Misc NA Check Valve 0 none NA FLOOR SAFTY VALVES: BOP STACK: Quantity P/F Upper Kelly - I _-P Lower Kelly _ 1 P ' Ball Type 1 - _ P Inside BOP 1 P FSV Misc 0 NA BOP STACK: CHOKE MANIFOLD: Quantity Size P/F Quantity P/F Stripper 0 none NA No. Valves 15- P - Annular Preventer 1 13 5/8" - P Manual Chokes 1 P #1 Rams 1 -7"_ P__ Hydraulic Chokes --1 P_ #2 Rams 1 2 7/8" x 5" P CH Misc 0 NA #3 Rams 1 " Blinds P " #4 Rams 0 gone NA #5 Rams - - 0 none --NA- -- INSIDE REEL VALVES: #6 Rams 0 none NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 ' 3 1/18" P Quantity P/F HCR Valves 2 2 1/16", 1/8 - P, Inside Reel Valves 0 NA___ _ Kill Line Valves 2 "2 1/16" P Check Valve 0 none NA BOP Misc 0 none NA Number of Failures: 1 Test Results Test Time 7 Remarks: 4 -way valve on acc leaked and was rebuilt and passed retest. Tested 3 1/2", 4 1/2" and 7" test joints. Rig 169 Cingsa 13 5/8 5M stack 09/04/2021 Shaffer LWS 13 5/8 5M 13 5/8 5M Shaffer Shaffer SL 13 5/8 5M 2 7/8-5.5 Variables Blind 7'’ rams 3.74' 2.83' 2.00' Wellhead at 1.41' above grade 2.32' Ground level 1.41' From:Regg, James B (CED) To:AOGCC Records (CED sponsored) Subject:FW: CLU S-5 BOP Configuration Date:Monday, September 27, 2021 9:51:38 AM Attachments:Rig 169 CINGSA 13.625 BOP stack.pdf CLU S-5; PTD 2111580 Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Zan Walsh <zwalsh@petroak.com> Sent: Friday, September 24, 2021 10:45 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Steve Tyler <styler@petroak.com>; Matthew Federle <Matthew.Federle@cingsa.com>; Rodney Maniaci <rodneymaniaci@gci.net>; Bob Mize <bmize@petroak.com> Subject: CLU S-5 BOP Configuration Jim, Please find attached the updated BOP configuration for CINGSA’s CLU S-5 Well Workover as discussed on our phone call. Please let me know if you have any questions. Thank you, Zan Walsh Mechanical Engineer zwalsh@petroak.com 907-272-1232 (office) 907-677-5121 (direct) 907-317-8579 (cell) 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 Servic e 6. API Number: 7.If perforating:8.W ell Name and Number: W hat Regulation or Conservation Order governs well spacing in this pool? W ill planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft):Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): Casing Collapse Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 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.W ell Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission 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 COMMISSIONDate: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: Perforation Depth MD (ft):Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 3:36 pm, Jun 15, 2021 321-296 SFD 6/15/2021 DSR-6/15/21 10-404 BOP test to 2500 psi. , ADL 0391627 X X SFD 6/15/2021 Sterling C SFD 6/15/2021 BJM 6/21/21 dts 6/22/2021 6/22/21Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.06.22 13:26:57 -04'00' RBDMS HEW 6/23/2021 CLU S-05 Sundry Procedure 06-14-2021.docx June 11, 2021 Sundry Procedure . Note: All depths in this procedure are referencing the original well RKB. Note: 3-½” Tbg Anchor is one-way stuck at 240’ MD. Anchor will go down but will not go up. Note: 3-½” Tbg severed at ~232’ and ~242’ During Pre-Rig Wireline Operations. Rig Operations: . 1. M/I R/U Mob rig. Check well pressures. Bleed off any residual pressures. Top-off tubing, as necessary. 2. Blend/mix (~350 Bbls) of 8.6 ppg KCl Treated Brine. 3. RU to circulate down tbg while taking returns from 7” x 9-з” annulus. Pump/circulate till returns are clean. 4. Install back pressure valve. 5. N/D tree. Install Blanking Plug. N/U BOP. Pressure test BOP. Back out Lock Down Screws. 6. Remove Blanking Plug & Back Pressure Valve. RI set Wear Bushing. 7. PU/MU Overshot Dressed for 3-½” tbg. RIH on workstring. RI Latch 3-½” Tbg Stub above 7” SVLN. 8. PU and pull the following as one unit Note: (3-½” severed tbg stub, 6’ pup joint, SVLN Hanger Adapter, 2.63’ pup, 3-½” SVLN, 3.78’ pup, 6’ pup, 15’ pup, 33.31’ full joint and 1’ to 2’ of severed 3-½” pup joint ). 9. Break apart fish and laydown same. 10. PU the following, top down: Safety Joint, D&L Tbg Anchor, Profile nipple, Fishing Overshot dressed w/ 3-½” grapple. 11. RIH on 3-½” tbg. Latch 3-½” severed tbg at ~232’. Drop bar ball, pressure up to set tbg anchor. Release from Safety Joint. POOH. 12. RI pull Wear Bushing. PU 7” VAM Top landing joint. RI/MU to Tubing Hanger. 13. Close annular. P/U unseat tbg hngr. Continue to P/U to remove seals from sealbore of ZXP packer. Circulate Bottoms Up or until returns are clean w/ 6% treated KCl Brine. 14. Open annular. P/U to bring tubing hanger to rig floor. Break out tubing hanger and L/D same. 15. Continue POOH L/D completion string, while coiling control line at rig floor, to 7” SCSSV nipple. 16. BO 7” SVLN Nipple and LD same. PU to the 2nd full 7” tbg joint below SVLN. BO and LD. Note: The 2nd full 7” joint below 7” SVLN will have the 3 ½” anchor fish in it. Exercise caution when laying it down. 17. Continue POOH with 7” tbg. LD same. 18. PU/MU Fishing Assy with overshot dressed for 3-½” tbg. RIH to 3-½” tbg stub at ~246’. 19. Locate tbg stub. Slack-off, swallow/latch same. POOH laying down 3-1/2” tubing. Note any damaged or over torqued connection. 20. PU/MU 9-з” Cleanout Assembly w/ 3-½” stinger. RIH to top of liner @ 8684’. CBU. 21. Continue RI with 3-½” stinger while reverse circulating, inside 7” Liner to 8700’ (2’ above top of pkr). CBU. POOH. 22. PU/MU Tbg Locator Seal Assy w/ 10’ of seals, Pup joint on 3-½” RTS-8 tbg. RIH. 23. PU/MU 3-½” SVLN w/ Insert isolation sleeve. M/U control line, pressure test same. 24. RIH with new completion string, while maintaining pressure on control line, to where seal assembly is within ~1’ of BWD sealbore. 25. R/U to pump down tubing. Circulate down tubing +/-1 bbl/min while running in hole. When pressure increases, mark pipe. Continue to slack off until achieve set down weight on sealbore. Mark Pipe. Pressure up tubing to 2,000 psi surface pressure to test seal assembly. 26. P/U verify seal assembly length. Calculate space out. 27. P/U M/U tubing hanger and pups (as needed). Terminate control line to tubing hanger. Use caution laying down fish/obstruction from 5054' MD. Note - PX plug set in 3-1/2" x 7" packer Provide AOGCC with 24 hrs notice to witness BOP test. bjm Reservoir pressure @ 4877' TVD = 1955 psi when reservoir storage is full with 18 bcf gas. Hilcorp Rig 169 will be used for the RWO. CLU S-05 Sundry Procedure 06-14-2021.docx June 11, 2021 28. R/I to where seal assembly is above BWD sealbore. Close annular. Pump/circulate 5 bbls of diesel down tbg x csg annulus for freeze protection. Trap pressure on csg. 29. R/I stab seal assembly into BWD sealbore. Bleed pressure from csg. Land tubing hanger. R/I lockdown screws. 30. BO/LD Landing Joint. R/I set back pressure valve. 31. RD BOP. NU tree. RI pull BPV. Run set tree test plug. Pressure test tree. Remove tree test plug. 32. Perform AOGCC mandatory MIT test by pressure testing annulus to 1650 psi for 30 min. 33. DeMob rig off wellsite. Provide 24 hr notice for AOGCC to witness MITIA to 1650 psi. Perform AOGCC mandatory MIT test by pressure testing annulus to 1650 psi for 30 min. CLU S-05 Sundry Procedure 06-14-2021.docx June 11, 2021 CLU S-05 Sundry Procedure 06-14-2021.docx June 11, 2021 Current Tubing Tally . CLU S-05 Sundry Procedure 06-14-2021.docx June 11, 2021 CLU S-05 Sundry Procedure 06-14-2021.docx June 11, 2021 CLU S-05 Sundry Procedure 06-14-2021.docx June 11, 2021 CLU S-05 Sundry Procedure 06-14-2021.docx June 11, 2021 CLU S-05 Sundry Procedure 06-14-2021.docx June 11, 2021 CINGSA CLU Storage 05 Current Velocity String Schematic December 30, 2020 7” 26# L80 VAMTOP Production Liner from 8,684’ MD / 4867’ TVD TOP To 11,099’ MD / 5127’ TVD TD 8-1/2” hole / Cemented 8.6 PPG KCL Brine Packer Fluid in 3.5” tubing and 3 x 9-5/8 Annulus 7” RN Nipple @ 8707’ MD / 4878’ TVD 5.88” ID, 7.60” OD Top Btm Length Top Btm 9,060' 9,130' 70' 4,954' 4,966' Original Perfs 2/18/2012 ; Reperf'd (9060' - 9120') on 7/21/2012 9,210' 9,390' 180' 4,979' 5,010' Original Perfs 2/18/2012 ; Reperf'd (9230' - 9320' & 9330' - 9390') on 7/21/2012 9,420' 9,470' 50' 5,015' 5,023' Original Perfs 2/18/2012 9,770' 10,380' 610' 5,061' 5,100' Original Perfs 2/18/2012 ; Reperf'd (9780' - 9990' & 10000' - 10060' & 10070' - 10220') on 7/21/2012 10,580' 10,880' 300' 5,109' 5,119' Original Perfs 2/18/2012 ; Reperf'd (10630' - 10750') on 7/21/2012 1,210' MD Perforations TVD Perforations Comments Total Footage FMC Wellhead: 13-5/8” 5000# Multibowl FMC Tree: 7” 5000# complete with SSV 20” 133# X56 Driven to 117.5’ MD 13-3/8” 68# K55 BTC Surface Casing @ 2390’ MD / 2013’ TVD 9-5/8” DV Collar @ 3510’’ 16” hole / Cemented to Surface 7” 26# L80 VAMTOP Tubing Existing SCSSV Control Line 7” SVLN, RRQ, 5.963” ID, w/ 7” 26# VAM TOP HC @ 167’ MD 3-1/2” SVLN, RRQ, 2.813” ID w/ VAM TOP BxP, XO to 3-½” EZGO BxP, 9-5/8” 40# L80 BTC Intermediate Casing @ 8860’ MD / 4916’ TVD 12-1/4” hole / Cemented to Surface, Two Stages 7” SLVN x 3-1/2” SVLN Adapter XO locator w/ 3-½” EZGO HTGT Box x Pin 3-½”, 9.3# EZGO HTGT Velocity String Tubing 7” x 9-5/8” Baker ZXP Liner Top Packer With 10’ seal bore @ 8,684’ MD / 4867’ TVD Tbg Punch in existing 7” tbg 8670’-8671’ MD, Knockout RDX 4 spf. (10/04/20) Tbg Punch in existing 7” tbg 177’-178’ MD, Knockout RDX 4 spf. (10/04/20) 3-½” SSD w/ 3-½” EZGO HTGT Box x Pin Eline Conveyed 7” x 3-½” Pkr w/ 10’ PBR @ 8702’ MD / 4877’ TVD w/ PX plug installed. 3-½” XN Profile Nipple w/ WLEG w/ 3-½” EZGO HTGT Pin. WLEG @ 8731’ MD / 4885’ TVD 10’ Locator Seal Assy. w/ 3-½” EZGO HTGT Box Top of 7” x 3-1/2” Hydraulic Tbg Anchor @ 240’ MD. Note:tubing anchor moves in downward direction; unable to move anchor upward. Fish/Obstruction in 3.5” Tbg @ 5054’ MD Top of tubing fish @ 156’. 3.5” 9.3# L80 EZGO HTGT. (11/07/20) CINGSA CLU Storage 05 Proposed Velocity String Schematic June 11, 2020 7” 26# L80 VAMTOP Production Liner from 8,684’ MD / 4867’ TVD TOP To 11,099’ MD / 5127’ TVD TD 8-1/2” hole / Cemented 8.6 PPG KCL Brine Packer Fluid in 3.5” x 9-5/8” Annulus 7” RN Nipple @ 8707’ MD / 4878’ TVD 5.88” ID, 7.60” OD Top Btm Length Top Btm 9,060' 9,130' 70' 4,954' 4,966' Original Perfs 2/18/2012 ; Reperf'd (9060' - 9120') on 7/21/2012 9,210' 9,390' 180' 4,979' 5,010' Original Perfs 2/18/2012 ; Reperf'd (9230' - 9320' & 9330' - 9390') on 7/21/2012 9,420' 9,470' 50' 5,015' 5,023' Original Perfs 2/18/2012 9,770' 10,380' 610' 5,061' 5,100' Original Perfs 2/18/2012 ; Reperf'd (9780' - 9990' & 10000' - 10060' & 10070' - 10220') on 7/21/2012 10,580' 10,880' 300' 5,109' 5,119' Original Perfs 2/18/2012 ; Reperf'd (10630' - 10750') on 7/21/2012 1,210' MD Perforations TVD Perforations Comments Total Footage FMC Wellhead: 13-5/8” 5000# Multibowl FMC Tree: 7” 5000# complete with SSV x-over to 3 ½” RTS-8 under tubing hanger 20” 133# X56 Driven to 117.5’ MD 13-3/8” 68# K55 BTC Surface Casing @ 2390’ MD / 2013’ TVD 9-5/8” DV Collar @ 3510’’ 16” hole / Cemented to Surface SSV Line to 3-1/2” SVLN 3-1/2” SVLN, RRQ, 2.813” ID @ 171’ MD w/ VAM TOP BxP, XO to 3-½” RTS-8 BxP, 9-5/8” 40# L80 BTC Intermediate Casing @ 8860’ MD / 4916’ TVD 12-1/4” hole / Cemented to Surface, Two Stages 3-½”, 9.3# L-80 RTS-8 Velocity String Tubing 7” x 9-5/8” Baker ZXP Liner Top Packer With 10’ seal bore @ 8,684’ MD / 4867’ TVD Eline Conveyed 7” x 3-½” Pkr w/ 10’ PBR @ 8702’ MD / 4877’ TVD. 3-½” XN Profile Nipple w/ WLEG w/ 3-½” EZGO HTGT Pin. WLEG @ 8731’ MD / 4885’ TVD 10’ Locator Seal Assy. w/ 3-½” EZGO HTGT Box 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) 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. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas W DSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: 2. Operator Name: Senior Pet. Engineer: Senior Res. Engineer: CollapseBurstTVDLengthCasing Authorized Signature with date: Authorized Name: 5. Permit to Drill Number: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl measured true vertical Packer WINJ WAG Water-Bbl MD Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Cook Inlet Natural Gas Storage Alaska, LLC. P.O. Box 190989, Anchorage, AK 99519 211158 50-133-20601-0000 ADL 0230925 CLU S-5 Cannery Loop / Sterling Gas Storage Pool 11,101 5,127 8,702 5,054 11,059 5,125 8,684 / 8,702 4,867 / 4,877 Structural Conductor 118' 20" 118 118 N/A N/A Surface 2,390' 13-3/8" 2390 2013 3450 1950 Intermediate 8,860'9-5/8"8860 4916 5750 3090Production Liner 2,415' 7" 11099 5127 7240 5410 See Attached See Attached 3-1/2" 9.3# L80 8731' / 4885' 0 1200 0 120 1300 0001200 320-189Matthew Federle CINGSA Director Zan Walsh zwalsh@petroak.com 907-317-8579 Velocity String Install ZXPN Pkr - 8684' / 4867'SSSV - 167' / 167'BWD Pkr - 8702' / 4877' 320-461 4/19/21 By Samantha Carlisle at 12:42 pm, Apr 22, 2021 BJM 7/16/21 DSR-4/22/21 SFD 4/22/2021 Sterling C SFD 4/22/2021 , ADL 0391627 RBDMS HEW 4/23/2021 SFD 4/22/2021 CINGSA CLU Storage 05 Current Velocity String Schematic December 30, 2020 7” 26# L80 VAMTOP Production Liner from 8,684’ MD / 4867’ TVD TOP To 11,099’ MD / 5127’ TVD TD 8-1/2” hole / Cemented 8.6 PPG KCL Brine Packer Fluid in 3.5” tubing and 3 x 9-5/8 Annulus 7” RN Nipple @ 8707’ MD / 4878’ TVD 5.88” ID, 7.60” OD Top Btm Length Top Btm 9,060' 9,130' 70' 4,954' 4,966' Original Perfs 2/18/2012 ; Reperf'd (9060' - 9120') on 7/21/2012 9,210' 9,390' 180' 4,979' 5,010' Original Perfs 2/18/2012 ; Reperf'd (9230' - 9320' & 9330' - 9390') on 7/21/2012 9,420' 9,470' 50' 5,015' 5,023' Original Perfs 2/18/2012 9,770' 10,380' 610' 5,061' 5,100' Original Perfs 2/18/2012 ; Reperf'd (9780' - 9990' & 10000' - 10060' & 10070' - 10220') on 7/21/2012 10,580' 10,880' 300' 5,109' 5,119' Original Perfs 2/18/2012 ; Reperf'd (10630' - 10750') on 7/21/2012 1,210' MD Perforations TVD Perforations Comments Total Footage FMC Wellhead: 13-5/8” 5000# Multibowl FMC Tree: 7” 5000# complete with SSV 20” 133# X56 Driven to 117.5’ MD 13-3/8” 68# K55 BTC Surface Casing @ 2390’ MD / 2013’ TVD 9-5/8” DV Collar @ 3510’’ 16” hole / Cemented to Surface 7” 26# L80 VAMTOP Tubing Existing SCSSV Control Line 7” SVLN, RRQ, 5.963” ID, w/ 7” 26# VAM TOP HC @ 167’ MD 3-1/2” SVLN, RRQ, 2.813” ID w/ VAM TOP BxP, XO to 3-½” EZGO BxP, 9-5/8” 40# L80 BTC Intermediate Casing @ 8860’ MD / 4916’ TVD 12-1/4” hole / Cemented to Surface, Two Stages 7” SLVN x 3-1/2” SVLN Adapter XO locator w/ 3-½” EZGO HTGT Box x Pin 3-½”, 9.3# EZGO HTGT Velocity String Tubing 7” x 9-5/8” Baker ZXP Liner Top Packer With 10’ seal bore @ 8,684’ MD / 4867’ TVD Tbg Punch in existing 7” tbg 8670’-8671’ MD, Knockout RDX 4 spf.(10/04/20) Tbg Punch in existing 7” tbg 177’-178’ MD, Knockout RDX 4 spf. (10/04/20) 3-½” SSD w/ 3-½” EZGO HTGT Box x Pin Eline Conveyed 7” x 3-½” Pkr w/ 10’ PBR @ 8702’ MD / 4877’ TVD w/ PX plug installed. 3-½” XN Profile Nipple w/ WLEG w/ 3-½” EZGO HTGT Pin. WLEG @ 8731’ MD / 4885’ TVD 10’ Locator Seal Assy. w/ 3-½” EZGO HTGT Box Top of 7” x 3-1/2” Hydraulic Tbg Anchor @ 240’ MD. Note:tubing anchor moves in downward direction; unable to move anchor upward. Fish/Obstruction in 3.5” Tbg @ 5054’ MD Top of tubing fish @ 156’. 3.5” 9.3# L80 EZGO HTGT. (11/07/20) CINGSA CLU S-5 2020 Operations Summary Report Revised By: Zan Walsh November 8, 2020 28 September 2020 Report 01 Bring in tanks and mud mixing equipment to location, spotting them on containment. Hook up mixing equipment, fill mixing tank with water, and test mixing pump and hopper. 29 September 2020 Report 02 Mix and filter 385 Bbls 6% KCL brine to storage tank. Continue receiving tools, for completion, and equipment for wireline work. 30 September 2020 Report 03 Rig up Pollard slickline, test lubricator. Retrieve 7" SCSSV, run 5.9" GR to 8675'. Run bailer to 8800', No tag or recovery, Run 5.5" GR to 8800'. No tag, Run 5.9" GR to 8687'. POH, Rig down Pollard slickline. 1 October 2020 Report 04 PJSM, R/U & run Alaska Wireline, run to below RN nipple, and log up W/CCL. POH. P/u WellTech tractor on Alaska Wireline, and run 5.9" GR to 8697', POH. Pick up lower completion 7" BWD Pkr assy on tractor. Run in hole unable to pass 8707' tight spot. POH L/d tools. Inspect lower comp. tools, note ring on lower 5" end of entry guide indicating tight spot. CCL correlation indicates entry guide made it to RN nipple at 8707' MD (OD 5.88"). Secure well for the night. 2 October 2020 Report 05 Break off WL reentry guide and send to machine shop. Turn down OD of WL reentry guide 3/16" to 5.56" OD. Build 5.9" swedge type ring gauge. Discuss other lower completion modifications to mitigate issue; work w/ HES to reduce OD of the sealbore extension crossover from 5.77” OD to 5.50” OD. Clean out MI brine mixing tank and prepare for return. (8.6 PPG Brine on hand 385 Bbls.) 3 October 2020 Report 06 RU Alaska E-line w/CCL tool and 5.90” swedge gauge to 8707',tag top of RN nipple,POH. Run lower packer assembly completion, set middle of packer elements at 8702'. POH LD E-line. Lower tubing pressure F/1580 PSI to 1000 PSI. Conduct negative pressure test overnight. 4 October 2020 Report 07 Rig up Halliburton triplex pump unit, Displace gas in TBG w/ 334 bbls 8.6 PPG 6% KCl Brine. RU and run Alaska E-line tubing punch guns (Knockout RDX 4 SPF) to 8673’ MD, note tubing collar at 8672’ MD. Pressure up 7” tubing to 200 psi, 7 X 9-5/8” at 100 psi. Shoot tubing punches from 8673’ to 8674’ MD. Note No equalizing of pressure between inner 7” and 7” X 9-5/8” annulus. POOH, L/D tubing punch gun, all 4 shots fired, but no communication between IA and OA. Bleed off pressure in 7” tubing. R/U tubing punch gun again in same 4 spf configuration but w/ stiffer spring arm. RIH to 8670’, pressure up 7” tubing to 200 psi fire tubing punches from 8670’ to 8671’, note pressure equalizing between 7” and 7” X 9-5/8”. POOH, L/D tubing punch gun, note all shots fired. R/U tubing punch gun in same 4 spf configuration. RIH w/ gun and CCL tool to 177’. Note tubing collar at 176’. Fire tubing punches at 177’. Perform up-pass w/ CCL tool and note successful punches. R/D E-line and Test well 2000 PSI for 30 Minutes using HES triplex pump, good test. Bleed pressure off and secure well for evening. 5 October 2020 Report 08 Note zero pressure at wellhead. Remove production tree to top of master valve and prepare for rig operations. Mobilize tools for the upcoming job. Fire tubing punches at 177’ fire tubing punches from 8670’ to 8671’, but no communication between IA and OA. Test well 2000 PSI for 30 Minutes note pressure equalizing between 7” and 7” X 9-5/8” good test. Run lower packer assembly completion, set middle of packer elements at 8702'. Shoot tubing punches from 8673’ to 8674’ MD. CINGSA CLU S-5 2020 Operations Summary Report Revised By: Zan Walsh November 8, 2020 6 October 2020 Report 09 Rig up Rig 401 over well. Nipple up 7-1/16” 5K BOPE, Attempt to shell test BOP, unsuccessful. Leak traced to Master valve. Call out wellhead rep to troubleshoot tomorrow (10-7-20) AM. 7 October 2020 Report 10 Isolate master valve and confirm leak is coming from master valve. Replace master valve. Successfully shell test BOP. 8 October 2020 Report 11 State witnessed 7-1/16” 5K BOPE pressure test 250 psi low to 2500 psi high using 6% KCl brine, good test. Shell test master valve against tree test plug, good test. RIH w/ Dummy FXE Safety Valve on 3-1/2” tubing. Stop 1 jt above SVLN, rig up to pump 1 gal hydraulic fluid down SCSSV control line to ensure clear path through control line. Lower Dummy FXE Safety Valve onto SVLN, set down 5K and pressure up on control line to 5000 psi, holding pressure indicating Dummy is at SVLN. Pull 7'' dummy FXE SSV; L/D same. Level rig and prepare tools and equipment for completion run. 9 October 2020 Report 12 Pick up seal assembly, straight slot locator, SSD, on 3 1/2" EZGO HTGT tubing T/8590'.Drift all 3-1/2” EZGO HTGT tubing on rig floor. Ran at average 25 jts/hr. Secure well for night. 10 October 2020 Report 13 RIH to 8699', RU to pump down TBG. Pump 1 BPM slack off to locate seals entering seal bore, pressure up 100 PSI, bleed off, slack off 10' to set down on locator sub. PU 4'. (check pick slack off weights every 1/2 foot for 30' above 7" Pkr, Avg UP Wt=40k, DN WT=29). POH 6 joints for 181' of spaceout. LD 1 Jt tbg, PU Tbg Anchor, PU 1 Jt Tbg, PU 15' pup, 6' pup, Hanger Adaptor assy with 3.5" SVLN, run 5 Jts Tbg, RIH to 8699'. Pump 1 BPM slack off to locate seals entering seal bore, pressure up 100 PSI, shut down pump, bleed off, slack off 4' to land string. Test annulus and Tbg 1800 PSI to check seals. Press up SVLN control line to 5000 PSI. POH, 1 Jt, MU Scoop Guide, GS landing tool with crossover, and land string w/ scoop guide 3’ below tubing hanger. Set Tbg Anchor by pumping down the tubing 4000 PSI (Indication of shear at 3600 PSI) and hold press 5 minutes. Pull test anchor 3k over pull, good. Release GS tool from scoop guide, POOH, L/D. MIT witnessed test waved by AOGCC, Pressure up Tbg 1800 PSI, monitor annulus for 30 minutes on chart, good test. Bleed tbg pressure to 200 PSI. Switch to pump down 7 x 9-5/8 annulus. Pressure up annulus 1800 PSI and monitor Tbg pressure, for 30 minutes on chart, good test. Bleed off. Final test 5000 PSI on control line for 15 min, good test, bleed off. Close master and casing valves, nipple down BOP. 11 October 2020 Report 14 Demobilize rig, Nipple up and pressure test tree, trouble shoot tree test plug. 12 October 2020 Report 15 Attempt to pull FMC tree test plug 4 times. Nipple down tree to top of master valve, build a mechanical puller, pull tree test plug, nipple up tree, and test same 250/3500 PSI. 13 October 2020 Report 16 RU Pollard, Retrieve SVLN Blanking sleeve,POOH L/D blanking sleeve.P/U latch tool to open sliding sleeve, RIH unable to pass bridge at 5054’, multiple runs w/ LIB, note markings on LIB. Unable to pass bridge at 5054'. RD Pollard. 14 October 2020 Well Secure. Standby and discuss plan forward. Set Tbg Anchor by pumping down the tubing 4000 PSI sliding sleeve, RIH unable to pass bridge at 5054’, multiple runs w/ LIB, note markings on LIB. Unable t Pressure up annulus 1800 PSI and monitor Tbg pressure, for 30 minutes on chart, good test. Rig up Rig 401 over well. Final test 5000 PSI on control line for 15 min, good test, Test annulus and Tbg 1800 PSI to check seals. State witnessed 7-1/16” 5K BOPE pressure test 250 psi low to 2500 psi high MIT witnessed test waved by AOGCC, Pressure up Tbg 1800 PSI, monitor annulus for 30 minutes on chart, good test. CINGSA CLU S-5 2020 Operations Summary Report Revised By: Zan Walsh November 8, 2020 Report 17 15 October 2020 Report 18 Well Secure. Standby and discuss plan forward. 16 October 2020 Report 19 Well Secure. Standby. 17 October 2020 Report 20 Well Secure. Standby. 18 October 2020 Report 21 Well Secure. Standby. 19 October 2020 Report 22 RU WL and lubricator, pressure test same. RIH w/ 2.61” magnet to 5054’ MD, POOH L/D magnet. Note small metal shavings from pipe dope. PU 2.9” braided line brush to 5054’ MD, fall through (note: roller bogie catching on tight spot at 5054’MD, work through and continue RIH to 8709’ MD. POOH, hangup at 5072’ MD (appears to be top of roller bogies working through tight spot at 5054’MD). Work through, POOH, brush clean, no metal debris, L/D brush. RU 2.78” swedge, RIH to 5054’ MD, spang on tight spot, not gaining hole. POOH, L/D swedge note metal marks on largest OD of swedge. PU RIH w/ 2.73” fluted centralizing swedge to 5054’ MD, spang, no gains, POOH, L/D same (note: no significant marks on swedge). PU 2.72” swedge RIH to 5054’ MD, sticky, no gains. POOH L/D same. PU 2.71” swedge and RIH to 5054’ MD, sticky, no gains. POOH, R/D slickline, secure well for night. Prep for AM operations. 20 October 2020 Report 23 R/U WL and lubricator, pressure test same. RIH w/ 2.6” tapered broach (swedge) to 5054’ MD, bobble through tight spot to 5200’ MD, no tag POOH. RIH w/ 2.65” swedge to 5200’ MD, note small bobble at 5054’ MD, POOH. RIH w/ 2.71” swedge to 5054’ MD work through for 30 min, could not pass POOH. RIH w/ 2.67” Diamond broach, set down at 5054’ MD, work through tight spot until not visible, POOH. RIH w/ 2.78” swedge to 5054’ MD, make no gains, POOH, no significant marks on swedge. RIH w/ 2.72” swedge to 5200’ MD, nothing visible, POOH. RIH w/ 2.76” swedge to 5054’ MD, could not pass, POOH. RIH w/ 2.73” swedge to 5200’ MD, no tight spot visible, POOH. RIH w/ 2.75” swedge to 5200’ MD, POOH. RIH w/ 2.76” serrated swedge to 5054’ MD, could not pass, POOH. R/D slickline, secure well. Standby for plan forward. 02 November 2020 Report 24 Move in rig up equipment in prep to mix brine on location. 03 November 2020 Report 25 Mix 200 Bbls 6% KCL 8.6 PPG Brine. Stage in rig 401 to location. Remove tree to top of master valve. CINGSA CLU S-5 2020 Operations Summary Report Revised By: Zan Walsh November 8, 2020 04 November 2020 Report 26 Rig up 401 over well, nipple up BOPE. 05 November 2020 Report 27 Test BOPE, witnessed by AOGCC. Unseat Tbg anchor, pull scoop guide to floor, R/U and reverse circ. 150 Bbls brine, POH to 8655'. String became stuck. Free string on down stroke. Secure rig for the night. 06 November 2020 Report 28 Reverse circulate 8.6 ppg brine, Attempt to work tubing anchor free, No progress. 07 November 2020 Report 29 Freeze protect well (7 x 9-5/8 annulus and 7" tubing), cut tubing above safety valve XO Adapter Hanger w/ TOF at 156' and lay down same. Note: cutting tool stripped thread on running tool (5" of cutting tool left in hole, magnetic). Nipple down BOPE, and nipple up tree. Secure well. Test BOPE, witnessed by AOGCC. Unable to recover the stuck tubing and unable to complete the objectives of the Sundry. - bjm (5" of cutting tool left in hole, magnetic) cut tubing above safety valve XO Adapter Hanger w/ TOF at 156' and lay down same. String became stuck. F STATE OF ALASKA Reviewed By: S!3r— OIL AND GAS CONSERVATION COMMISSION P.I. Supry I I ?i'Zc: BOPE Test Report for: CANNERY LOOP UNIT S-5 Comm Contractor/Rig No.: Hilcorp 401 - PTD#: 2111580- DATE: 11/5/2020 Inspector Austin McLeod Insp Source Operator: Cook Inlet Natural Gas Storage Alaska, LL Operator Rep: RodneyManiaci Rig Rep: Chad Johnson Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopSAM201106122224 320 461 Rams: Annular. Valves: MASP: Type Test: INIT 250/3500 250/2500 ' 250/3500 1400 Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: P/F ACCUMULATOR SYSTEM: 0 __ NA ' P/F 0 - Visual Alarm Ball Type Time/Pressure P/F Location Gen.: P Trip Tank NA - NA System Pressure 3000 P ' Housekeeping: P Pit Level Indicators NA NA Pressure After Closure 2600 P PTD On Location P Flow Indicator NA - NA 200 PSI Attained 31 P " Standing Order Posted P Meth Gas Detector P P Full Pressure Attained 67 P ` Well Sign P 142S Gas Detector P P Blind Switch Covers: All stations, P " DO. Rig P - MS Misc NA NA Nitgn. Bottles (avg): 6(a),,2000 _P_ - -Hazard Hazard Sec. P NA ACC Misc 0 NA Misc NA FLOOR SAFTY VALVES: BOP STACK: Quantity P/F Upper Kelly__ 0 __ NA ' Lower Kelly 0 - NA Ball Type 2 . P - Inside BOP 1 P ' FSV Misc 0 NA BOP STACK: Quantity Size P/F Stripper 0 NA Annular Preventer 1 7-1/16" " P #1 Rams I-_ Blinds_ P - #2 Rams 1, 3-1/2" P #3 Rams 1 3-1/2" P " #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2-1/16" P HCR Valves 1 ' 2-1/16" P Kill Line Valves 3 '2-1/16" P Check Valve 0 NA BOP Misc 0 NA Number of Failures: 0 ✓ Test Results Remarks: 3-1/2" joint. CHOKE MANIFOLD: Quantity P/F No. Valves 8 P " Manual Chokes 2 P ' Hydraulic Chokes 0 -__ NA CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 0 NA Test Time 3 By Samantha Carlisle at 12:10 pm, Oct 27, 2020 320-461 gls 10/28/20 * 3500 psi BOPE test (2500 psi annular) * 2 YEAR MIT CYCLE REQUIRED 401 SFD 10/27/2020 X X Gas Storage well 1800 psi 10-404 (report 320-189 & 320-461) DSR-10/27/2020 10/29/2020 dts 10/28/2020 JLC 10/28/2020 RBDMS HEW 11/12/2020 Note: plug set in tubing tail.... wellbore is isolated from reservoir . gls BOPE pressure test to 3500 psi (GLS) SVS test within 5 days of wells return to operation. set tubing anchor. (MIT-IA before rig leaves. notify inspector to witness ...forward chart to AOGCC) MIT-IA MIT-IA to 1800 psi (send chart to AOGCC) Witnessed MIT-IA required after stabilized injection. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Reviewed By� �I : I t P.I. Suprr.l*1 BOPE Test Report for: CANNERY LOOP UNIT S-5 � Comm Contractor/Rig No.: Hilcorp 401 PTD#: 2111580 DATE: 10/8/2020 Inspector Brian Bixby Iosp Source Operator: Cook Inlet Natural Gas Storage Alaska, LL Operator Rep: Rodney Maniaci Rig Rep: Chad Johnson Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopBDB201010042918 320-189 ' Rams: Annular: Valves: MASP: Type Test: [NIT 250/2500 250/2500 - 250/2500- 1400 ' Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: P/F Upper Kelly P/F _NA_ Visual Alarm 0 Location Gen.: P Trip Tank NA - NA - Housekeeping: P Pit Level Indicators P P PTD On Location P Flow Indicator NA NA - Standing Order Posted P Meth Gas Detector P P " Well Sign P H2S Gas Detector P P Drl. Rig P MS Misc _ 0 NA Hazard Sec. P Misc NA FLOOR SAFTY VALVES: C181W XT" Quantity Size Quantity P/F Upper Kelly 0 _NA_ Lower Kelly 0 NA Ball Type 2 - P Inside BOP 1 P FSV Misc 0 NA C181W XT" Quantity Size Stripper 0 P Annular Preventer 1 '7 1/16" #1 Rams 1 'Blinds #2 Rams _1 3-1/2" #3 Rams 1 3 1/2" #4 Rams 0 P #5 Rams - 0 NA #6 Rams _0_ Choke Ln. Valves 1 -2 1/16" HCR Valves I -2 1/16" Kill Line Valves 2 _ 2 1/16" Check Valve 0 BOP Misc 0 ACCUMULATOR SYSTEM: Time/Pressure P/F System Pressure 3000 - P Pressure After Closure 2600 P _ 200 PSI Attained _ 29_ _ _'_ _ _ P Full Pressure Attained 64 - P Blind Switch Covers: YES P Nitgn. Bottles (avg): 6(x)1950_- P ACC Misc 0 NA P/F NA P P ' P P' NA NA NA P , P P NA NA CHOKE MANIFOLD: Quantity P/F No. Valves 8 - P " Manual Chokes 2 P Hydraulic Chokes 0 NA" CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 0 ' NA Number of Failures: 0 ✓ Test Results Test Time 3.5 Remarks: Tested with 3 1/2" test joint, tested all gas alarms and PVT's. All the bleed off and repressuring on the Low Tests were from the test equipment. Leaks on needle valves, hoses and fittings on the test pump. Good Test Gv:(S!(CL.Ori CA t; 1A®C WELLSHARP IARC Well Control Accreditation Program Certificate of Completion The individual below has successfully completed a well control course at an Institution accredited by the International Association of Drilling Contractors. Chad A Johnson— Trainee Name Drilling Operations, Supervisor Surface Course Name 27 February 2020 _ 27 February 2022 Completion Date Expiration Date Mlydno and Petroleum Training Service Unlvemi[y of Alaska 00125545. _ Training Provider ID Number 907-786-6413 Telephone Number David Spann Instructor Name Certificate Number: 19F9C1Da8887C8 ,okizr,, IADC WellShaTp Course Completion Card Trainee Name,AMMy_E_F.1a[I__ _. Course Name Drllllno Operations Su_p_ervfsor. Surface Supplement Name Drilling Operations, Workover Completions, Supervlso 09 May 2018 09 May 2021 Completion Date_ Expiration Date provider Petroleum College International Provider p 00077480 phone 711361-575.4882 Instructor Name Martin Walters tertmwte Nunaer. 64370WAEElES M Trainee Name Course Name IDrN ino OOerations Sucervisor Ski rf�r�,___ Supplement Name Drilling Operations Work ver ComMelion Supervisor Completion Date 28 March 2019 Expiration Date 28 March 2021 ✓ Provlder.NninaanjEaaaleum Treimmt Service UMvarsWyrof Alaska Provider p 00125545 _piwne 0907.786-G419____ _ _ Mstnictor Name Partial J GmnwaW_ _ cwtiamw Numhar. 8OE21ADC-774833 Trainee Na"Bodney I Course Naine-Daling Operations c -Car ,... Supplement Name Dnaino Operaagns. Wprtmwrr,.,..�_�. Completion Date 14 Febmary 2019 Expiration Dale /4 Faonmry2o2i027 RovltlerMmm antl Peaoleum Training_Sarvipa Uniwmlty yql� Provider 0 00125545_._Phone k7-7858413 Instructor Name_Daniel JGNrwVld-- CamocawNWA., FC1716E8.6W@81 From: Zan Walsh To: LaeQQ. Victoria TSFDI Cc: Chantal Walsh; Steve Tyler; "Matthew Subject: FW: CLU 5-5 RWO velocity string. Date: Tuesday, July 14, 2020 2:21:58 PM Attachments: CL -5 Velocity trim Affected Areas Final df Tomue Drao Analysis report - Petroak - CINGSA - Cl u 05 (June R 2020) Rey t odf Victoria, Attached for your review is our revised Tube Move Analysis for CINGSA's CLU S-05 gas storage well. Steve Tyler and myself have had ongoing discussions with Guy Schwartz and Mel Rixse regarding our well plan and design for a velocity string install. The attached PDFs are additional information to the Sundry Application. Please let me know if you require more information to approve the Sundry. We will have a detailed procedure for you by the end of the week. Please feel free to call my cell if you have any questions. Thank you, Zan Walsh Mechanical Engineer zwaish@petroak.com 907-272-1232 (office) 907-677-5121 (direct) 907-317-8579 (cell) Monk Pa�eGc:r.:tnt Ry«tiva AGti4r� From: Zan Walsh Sent: Tuesday, July 14, 20201:38 PM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: Davies, Stephen F (CED) <steve.davies@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Steve Tyler <STyler@petroak.com>; 'Matthew Federle' <M atthew. Federle@ci ngsa.com> Subject: RE: CLU S-5 RWO velocity string. Guy, Attached for your review is the revised Tube Move Analysis. Schlumberger ran the Torque & Drag Model for us, and using their numbers the Tube Move Calcs were rerun. I've included the scenario in which the SVS system is activated and the SSV fails but the SCSSV activates and closes successfully. In all scenarios the SVLN X -over Adapter does NOT unseat from the no-go landing. Steve and I are working to complete the Detailed Procedure by the end of the week and will send that over to you. In the meantime, please let me know if there is any other information you require in order to approve the Sundry. Regards, Zan Walsh Mechanical Engineer zwalshCa)netroak com 907-272-1232(office) 907-677-5121 (direct) 907-317-8579 (cell) "M pa,4 w,d Rte, A" From: Zan Walsh Sent: Friday, May 22, 2020 4:19 PM To: Schwartz, Guy L (CED) <guv.schwartz(@alaska gov> Cc: Davies, Stephen F (CED) <s ve.davi s( ala ka gov>; Rixse, Melvin G (CED) <melvin.rixse(@alaska gov>; Steve Tyler <STvlV[2oetroa1k.com>;'Matthew Federle' <Matthew.Federler@cingca com> Subject: RE: CLU S-5 RWO velocity string. Guy, I appreciate your comments. PRA will be supplying you with the detailed programs for the pre -rig and rig work. With this documentation we will have details on the installation and space out depths for the velocity string. We intend to have Schlumberger run a torque and drag model to qualify the tubing weight used in the Haliburton Tube Move calculator. With that information we will run Tube Move calculations on the scenario you describe in number 4 of your list of concerns. I anticipate this modeling will take a couple of weeks. At that time we will contact you with the results. You are correct, CINGSA does hold the IA pressures at 100-200 psi to confirm gauges are functioning. We are moving the placement of the, to be installed, 7", 26# packer up the well. The packer will locate under the existing ZXP Liner Top Packer (8684' MD) and above the 7" RN Nipple ( 8707' MD). This will be captured in the detailed procedure. Please let me know if you need more information. Thank you, Zan Walsh Mechanical Engineer zwalsh(@oetroak.com 907-272-1232 (office) 907-677-5121 (direct) 907-317-8579 (cell) P ;11 k4 ww4 AtF,4F From: Schwartz, Guy L (CED) <euy.schwartzPalaska eov> Sent: Wednesday, May 20,2020 4:06 PM To: Zan Walsh <zwalsh(@r) roak. om> Cc: Davies, Stephen F (CED) <steve.davies(a alaska.g_oy>; Rixse, Melvin G (CED) <melvin.rixse(@alaska.eov> Subject: CLU S-5 RWO velocity string. Zan, I have gone over the sundry in detail. I have a few follow-up questions and comments. This method is a bit unorthodox and has some inherent risk as we have discussed. The 1. Do you have a detailed program for the pre -rig and rig work? The executive summary lacks some detail on how this assembly will be actually installed. There are a lot of space out issues that are not addressed in your procedure. 2. The proposed schematic lacks estimated depths for many key details/ equipment. 3. Appears you are relying on HAL's tool to estimate hanging weight when the tubing is landed. If this is significantly off the safety margin for the system will be compromised. 4. One scenario not calculated is if the SVS system is activated (big leak on flowline etc) and the SSV fails but ScSSV closes successfully. You could have 0 psi above the ScSSV and 1600 psi plus IA pressure pushing up on SVLN and tubing. If the SVLN moves upward far enough the ScSSV hydraulics will dump and gas flow could move up IA to surface past the seals with no way to stop the flow. (this assumes the tubing seals also pull out of PBR at 8500 ft, ) Look at these calculations and please include this. 5. Also, I am not sure that CINGSA is leaving the IA pressures at 0 psi . I would assume they leave about 200 psi on the IA of these wells to monitor for leaks while they are operating them. I would check with them. This will affect your calculations a bit. BTW.. SSV is surface safety valve and ScSSV is the SVLN system. Regards, 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.aovl. 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: _Velocity String Install____ 2. Operator Name:4. Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 11,101'None Casing Collapse Structural Conductor N/A Surface 1,950 Intermediate 3,090 Production Liner 5,410 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 Commission Representative: GINJ Op Shutdown Abandoned Matt Federle Contact Name: Zan Walsh CINGSA Director Contact Email:zwalsh@petroak.com Contact Phone: 907-317-8579 Date: Conditions of approval: Notify Commission 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 COMMISSION Date: Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: July 20, 2020 11,0992,415 7", 26# 5,127 BHI 9 5/ 8" HR ZXPN Liner Top Packer Halliburton 7" WL FXE SSSV 2,390 Perforation Depth MD (ft): 8,860 See Attached Completion Schematic 7" 2,390 11820" 13 3/8" 118 9 5/8"8,860 5,750 N/A 3,450 118 2,013 4,916 Cannery Loop / Sterling Gas Storage Pool 5,127'11,059'5,125' TVD Burst 1400 psi None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 391627 CLU Storage 05 211158 P.O. Box 190989, Anchorage, AK 99519 50-133-20601-0000 Cook Inlet Natural Gas Storage Alaska, LLC Pkr- 8684'/4867' SSSV- 167'/ 167' Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size L-80 8,684' MD COMMISSION USE ONLY Authorized Name: 7,240 Tubing Grade:Tubing MD (ft): See Attached Completion Schematic Perforate Reppair Well Exploratory Stratigraphic Development Service BOP Test Mechanical IntegrityTest Location Clearance No No Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval.Submit Form and Attachments in Duplicate CINGSA Director 1 MAY 2020 By Jody Colombie at 3:21 pm, May 01, 2020 320-189 SFD 5/7/2020 ADL 0230925 SFD 5/7/2020 CLU S-5 X + 2500 psi BOPE pressure test SFD 5/7/2020 X DSR-5/1/2020 10-404 GSTOR _Velocity String Install ____ _ X X rig 401 1600 psi + 2 year MIT -IA test cycle required. gls 8/26/20 1800 psi 9/1/2020 dts 9/1/2020 JLC 9/1/2020 RBDMS HEW 9/3/2020 CINGSA CLU Storage 05 Procedure (08-19-20).docm CINGSA CLU Storage 05 Proposed Velocity Completion Updated on 08/19/20 Procedure . Pre-Rig Operations: . The following work is to be completed prior to rig arrival. Note: Maintain positive well pressure during Eline and slickline operations. Note: All depths in this procedure are referencing the original well RKB. 1. MIRU Slickline. NU PCE test same. RIH w/ Pulling Tool. Latch/Pull 7” Retrievable FXE SCSSV. RIH with GR. Tag RN nipple @ 8707’ MD. POOH. 2. RIH w/ Bailer to refusal depth below RN nipple @ 8707’. POOH. Note any recovery in bailer. RD Slickline. 3. MIRU Eline Unit. NU PCE. Test same. PU/MU Welltec Tractor with CCL tool. RIH below RN nipple, just above Refusal Depth. POOH logging through RN at 8707’ MD to surface. POOH BO/LD Tools 4. PU/MU completion BHA on bottom of tractor as follows: CCL, Setting tool, 7”, 26# Pkr w/ 10’ PBR and tail pipe consisting of Pup Joint, XN Profile Nipple (w/ PX Plug pre-installed) and WLEG. 5. RIH w/ completion. Tractor to depth. Correlate to CCL log. Set middle of BWD packing element @ 8702’ MD. POOH w/ tractor and Setting Tool. RD Eline. x NOTE: Middle of BWD Packing Element Setting Depth is in the middle of the top 4’ of existing Flexlock Hngr. x NOTE: Exercise extreme caution in not allowing BWD pkr to go below 7” RN Nipple. (BWD pkr gauge ring OD = 5.875”; the 7” RN Nipple ID = 5.88”) 6. Bleed 500 psi from tbg to negative test plug for 24 hours. 7. Check tbg pressure. MIRU Pump Truck. NU surface iron to tree. Pressure test same. Lube/Bleed tbg full of treated 6% KCl. Pressure test tbg. RD pump truck. 8. MIRU Eline. RIH with tbg punch guns. Punch holes in tbg above ZXP @ ~8670’ MD (4867’ TVD) and below 7” SCSSV Landing Nipple at ~180’ MD. RD Eline. x NOTE: modify tbg punch depths to ensure tbg punches are within 2’ of the closest 7” tbg collar. 9. Jug test wellbore to 1600 psi. Monitor for 30 min. Bleed pressure to zero. Rig Operations: . 10. MI spot rig. ND tree to bottom Master Valve. NU 7-1/16” Class III BOPE stack. Pressure test same. 11. PU/MU 7” Dummy FXE SSV onto Completion Tbg. RIH locate on 7” SVLN @ 167’ MD. Mark pipe. Note any depth discrepancies. 12. Close Annular. With 7” x 9-з” casing valve open, Pressure test 3-½” x 7” annulus to 500 psi. Monitor tbg, 7” x 9-з” annulus for flow. Bleed pressure to zero. Pressure test control line to 2000 psi. Bleed pressures to zero. 13. PU/MU Tbg Locator Seal Assy w/ 10’ of seals, Pup joint, 3-½” SSD on 3-½” Tbg. RIH till btm of seal assy is within ~30’ of top of BWD pkr. Establish PU and SO weights. Continue RI till within 3’ of BWD pkr. 14. RU to pump down tbg. Establish pump rate of 1 bpm. Slowly Slack-off until an increase of surface pressure. Stop pipe movement and pumping. Mark pipe. x Note: This confirms btm of seal assy starting to enter BWD pkr bore. 15. Continue slacking-off ~10’, set down 10 kips on pkr. Confirms the length of the seal assy entering pkr bore. Mark pipe. POOH ~6 joints of tbg. Calculate space-out of the 5.963” SVLN Adaptor Hanger x 3-½” SVLN. 16. PU/MU SVLN Adaptor Hanger Assy w/ Tbg Anchor. Add space-out pups as needed. 17. Continue to RIH till btm of locator seal assy is within 3’ of BWD pkr top. Locate pkr with tbg seal assy by pumping down 3-½” tbg and watching for pressure increase depicting seals starting to enter pkr. Bleed pressure to zero. 18. RU to pump down 7” x 9-з” annulus. Pump at 1 bpm while taking returns out 3-½” x 7” annulus out flowline. Monitor returns. 19. Continue slacking off till pressure increase is noted. Bleed pressure to zero. Update Fields (space out seal assembly 6 ft inside) Dummy run with FXE SSV Set packer/ seal bore (should slack off additional 6 ft and see the SVLN fully land) gls (Seal assembly just entering the seal bore) 2000 psi PNL log (verifies both sets of seals are holding) (10 foot seal bore) (test 9 5/8" post tubing punches) Tbg pressure test to 2000 psi min (record static hanging weight and hanging weight after pulling .5 ft) (chart test and forward to AOGCC) (4 holes per punch gun) verify eline wellcontrol Test BOPE to 2500 psi against MV . CINGSA CLU Storage 05 Procedure (08-19-20).docm 20. Continue slacking off till SVLN Adapter Hanger locates in 7” SVLN. Calculate space-out to spot 3-½” x 6” Scoop Guide just below Tbg Hngr by ~3’. 21. PU/MU pup joints as needed with Scoop Guide. With scoop guide at RT in slips, PU/MU Hydraulic GS Spear Running tool onto 3-½” landing joint. Latch spear into Scoop Guide @ RT. 22. RI 3-½” Velocity String on Hydraulic GS running tool. 23. Relocate Adapter Hanger Crossover Assy into 7” SVLN at 167’ MD. 24. Pressure test down 7” x 9-ǫ” annulus. Bleed pressure to zero. Pressure test down 7” tbg. Bleed pressure to zero. Pressure control line to 5,000 psi, monitor same for 5 minutes. Bleed pressure to zero. 25. With 7” x 9 з” annulus bled to zero, pressure 3-½” tbg in 500 psi increments to set 3 ½” x 7” tbg anchor. Note indication of anchor setting on pressure gauge. Bleed tbg pressure to zero. x NOTE: 3-½” and 7” x 3-½” will track the same pressure due to the GS Spear is NOT sealing. 26. PU and Pull Test Hydraulic Tbg Anchor. Slack-Off, drop ball. Pressure up on 3-½” Landing. With pressure on Landing Joint, PU to release spear from Scoop Guide. POOH LD same. 27. RD Rig and BOPE’s. NU tree and flowlines. 28. MIRU Slickline. RIH. Shift SSD open. Pump 10 bbls of diesel down tbg. Utilize injection gas to “push” fluid from velocity string while taking returns from 7” x 9-ǫ” annulus. x Note: May need N2 unit to supplement facility gas pressure to “push” fluid from the velocity string. 29. RI with slickline, Shift sleeve close. RI w/ retrieving tool. Pull prong and plug. RD slickline. 30. Turn well over to Production. Arrange to conduct a witnessed MIT with AOGCC. Highlights of Procedure Step #5 Surgically spotting and setting the BWD pkr in a 4’ area of the Baker Flex Lock Liner Hngr. Discussion: The 7” RN nipple ID is close to the OD of the BWD Pkr. Need to avoid getting stuck. We have incorporated a 4 bladed weld-on centralizer no-go just below pkr to mitigate risk. Need to set BWD Pkr Below ZXP Pkr. This mitigates exposure of 7” Tbg integrity loss causing wellbore integrity issues. Subsequent 24 hr negative test and pressure test after well is filled with fluid ensures reservoir isolation during Velocity String placement. Step #9 Jug testing wellbore reaffirms wellbore integrity, after tbg punches prior to rig arrival. Step #11 Tagging 7” SVLN reaffirms the depicted 7” tbg depth is consistent to 3-½” tbg. Step #12 Pressure tests ensure that we are indeed setting in the 7” SVLN @ 167’ MD. Step #13 through Step #15 Confirms space-out pups needed between SVLN Adapter/Hngr and tbg seal assy. Step #17 through Step #20 Reaffirms space-out between 7” SVLN Adapter Hngr Assembly and BWD assy is correct, using pressure indication. Also, Ascertain space-out pups needed to place Scoop Guide within ~3’ below 7” tbg hanger. Step #24 Pressure tests Velocity String integrity. Step #25 Setting the D&L Hydraulic Tubing Anchor. Step #26 Pull testing Tubing Anchor. Step #28 and Step #29 Add freeze protection and removing fluid from Velocity String. (displace approx 81 bbls tubing vol) (test IA to verify SSD is closed) set tubing anchor (SSSV open?) (Notify Inspector to witness MIT-IA to 1600 psi / 30 min) (also tests the IA ... SVLN fully seated) close BOPE rams on 3 1/2 tubing/landing jt (Witnessed SVS test and MIT-IA within 5 days of injection startup) ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------- (what pressure?) POST RIG open BOP Highlights of Procedure 1800 psi 90 day SVS test cycle CLU S-05 Detailed Procedure (7-29-20).docm Page 5 of 28 Executive Procedure . Pre-Rig Operations: . The following work is to be completed prior to rig arrival. Note: Maintain positive well pressure during Eline and slickline operations. Note: All depths in this procedure are referencing the original well RKB. 1. MIRU Slickline. NU PCE test same. RIH w/ Pulling Tool. Latch/Pull 7” Retrievable FXE SCSSV. RIH with GR. Tag RN nipple @ 8707’ MD. POOH. 2. RIH to refusal below RN nipple @ 8707’ MD. RIH w/ Bailer to refusal depth. POOH. Note any recovery in bailer. RD Slickline. 3. MIRU Eline Unit. NU PCE. Test same. PU/MU Welltec Tractor with CCL and Pulse Neutron Generator. RIH log through RN at 8707’ MD. POOH logging. 4. PU/MU completion BHA. RIH with 7”, 26# Pkr w/ 10’ PBR and tail pipe consisting of Pup Joint, XN Profile Nipple (w/ PX Plug pre-installed) and WLEG. Tractor to depth. Correlate to CCL log. Set middle of BWD packing element @ 8702’ MD. POOH w/ Setting Tool. RD Eline. x NOTE: Middle of BWD Packing Element Setting Depth is in the middle of the top 4’ of existing Flexlock Hngr. See Attachment #03) BWD Detail Drawings. x NOTE: Exercise extreme caution in not allowing BWD pkr to go below 7” RN Nipple. (BWD pkr gauge ring OD = 5.875”; the 7” RN Nipple ID = 5.88”) 5. Bleed 500 psi from tbg to negative test plug for 24 hours. 6. Check tbg pressure. MIRU Pump Truck. NU surface iron to tree. Pressure test same. Lube/Bleed tbg full of treated 6% KCl. Pressure test tbg. RD pump truck. 7. MIRU Eline. RIH with tbg punch guns. Punch holes in tbg above ZXP @ ~8670’ MD (4867’ TVD) and below 7” SCSSV Landing Nipple at ~180’ MD. RD Eline. 8. Jug test wellbore to 1600 psi. Monitor for 30 min. Bleed pressure to zero. Rig Operations: . 9. MI spot rig. ND tree to bottom Master Valve. NU 7-1/16” Class III BOPE stack. Pressure test same. 10. PU/MU Tbg Locator Seal Assy w/ 10’ of seals, Pup joint, 3-½” SSD on 3-½” Tbg. RIH till btm of seal assy is within ~30’ of top of BWD pkr. Establish PU and SO weights. Continue RI till within 3’ of BWD pkr. 11. RU to pump down tbg. Establish pump rate of 1 bpm. Slowly Slack-off until an increase of surface pressure. Stop pipe movement and pumping. Mark pipe. x Note: This confirms btm of seal assy starting to enter BWD pkr bore. 12. Continue slacking-off ~10’, set down 10 kips on pkr. Confirms the length of the seal assy entering pkr bore. Mark pipe. POOH ~6 joints of tbg. Calculate space-out of the 5.963” SVLN Adaptor Hanger x 3-½” SVLN. 13. PU/MU SVLN Adaptor Hanger Assy. Add space-out pups as needed. 14. Continue to RIH till btm of locator seal assy is within 3’ of BWD pkr top. Locate pkr with tbg seal assy by pumping down 3-½” tbg and watching for pressure increase depicting seals starting to enter pkr. 15. Continue to slack-off till SVLN Adapter Hanger locates in 7” SVLN. Calculate space-out to spot 3-½” x 6” Scoop Guide just below Tbg Hngr by ~3’. PU space-out MU Scoop Guide. RI 3-½” Velocity String on Hydraulic GS running tool. 16. Locate on 7” SVLN. Actuate Hydraulic GS running tool to release from velocity string. Pressure test down 7” x 9-ǫ” annulus and down 7” tbg to test velocity string system. 17. RD Rig and BOPE’s. NU tree and flowlines. 18. MIRU Slickline. RIH. Shift SSD open. Pump 10 bbls of diesel down tbg. Utilize injection gas to “push” fluid from velocity string while taking returns from 7” x 9-ǫ” annulus. x Note: May need N2 unit to supplement facility gas pressure to “push” fluid from the velocity string. 19. RI with slickline, Shift sleeve close. RI w/ retrieving tool. Pull prong and plug. RD slickline. 20. Turn well over to Production. Arrange to conduct a witnessed MIT with AOGCC. tbg punch 7" 2000 psi SUPERCEDED lower Packer/seal bore PNL log SUPERCEDED (See Procedure above for all steps) CINGSA CLU Storage 05 Current Schematic 08/15/2015 7” 26# L80 VAMTOP Production Liner from 8,684’ MD / 4867’ TVD TOP To 11,099’ MD / 5127’ TVD TD 8-1/2” hole / Cemented SSSV Control Line 8.6 PPG KCL Brine Packer Fluid 7” RN Nipple @ 8707’ MD / 4878’ TVD 5.88” ID, 7.60” OD Top Btm Length Top Btm 9,060' 9,130' 70' 4,954' 4,966' Original Perfs 2/18/2012 ; Reperf'd (9060' - 9120') on 7/21/2012 9,210' 9,390' 180' 4,979' 5,010' Original Perfs 2/18/2012 ; Reperf'd (9230' - 9320' & 9330' - 9390') on 7/21/2012 9,420' 9,470' 50' 5,015' 5,023' Original Perfs 2/18/2012 9,770' 10,380' 610' 5,061' 5,100' Original Perfs 2/18/2012 ; Reperf'd (9780' - 9990' & 10000' - 10060' & 10070' - 10220') on 7/21/2012 10,580' 10,880' 300' 5,109' 5,119' Original Perfs 2/18/2012 ; Reperf'd (10630' - 10750') on 7/21/2012 1,210' MD Perforations TVD Perforations Comments Total Footage FMC Wellhead: 13-5/8” 5000# Multibowl FMC Tree: 7” 5000# complete with SSV 20” 133# X56 Driven to 117.5’ MD SVLN, RRQ, 5.963” ID, 7” 26# VAMTOP 7” Halliburton Wireline Retrievable SSSV @ 167’ MD 13-3/8” 68# K55 BTC Surface Casing @ 2390’ MD / 2013’ TVD 9-5/8” DV Collar @ 3510’’ 16” hole / Cemented to Surface 7” 26# L80 VAMTOP Tubing 7” x 9-5/8” Baker ZXP Liner Top Packer With 10’ seal bore @ 8,684’ MD / 4867’ TVD 9-5/8” 40# L80 BTC Intermediate Casing @ 8860’ MD / 4916’ TVD 12-1/4” hole / Cemented to Surface, Two Stages CINGSA CLU Storage 05 Proposed Velocity String Schematic August 12, 2020 7” 26# L80 VAMTOP Production Liner from 8,684’ MD / 4867’ TVD TOP To 11,099’ MD / 5127’ TVD TD 8-1/2” hole / Cemented 8.6 PPG KCL Brine Packer Fluid in Annulus 7” RN Nipple @ 8707’ MD / 4878’ TVD 5.88” ID, 7.60” OD Top Btm Length Top Btm 9,060' 9,130' 70' 4,954' 4,966' Original Perfs 2/18/2012 ; Reperf'd (9060' - 9120') on 7/21/2012 9,210' 9,390' 180' 4,979' 5,010' Original Perfs 2/18/2012 ; Reperf'd (9230' - 9320' & 9330' - 9390') on 7/21/2012 9,420' 9,470' 50' 5,015' 5,023' Original Perfs 2/18/2012 9,770' 10,380' 610' 5,061' 5,100' Original Perfs 2/18/2012 ; Reperf'd (9780' - 9990' & 10000' - 10060' & 10070' - 10220') on 7/21/2012 10,580' 10,880' 300' 5,109' 5,119' Original Perfs 2/18/2012 ; Reperf'd (10630' - 10750') on 7/21/2012 1,210' MD Perforations TVD Perforations Comments Total Footage FMC Wellhead: 13-5/8” 5000# Multibowl FMC Tree: 7” 5000# complete with SSV 20” 133# X56 Driven to 117.5’ MD 13-3/8” 68# K55 BTC Surface Casing @ 2390’ MD / 2013’ TVD 9-5/8” DV Collar @ 3510’’ 16” hole / Cemented to Surface 7” 26# L80 VAMTOP Tubing Existing SCSSV Control Line 7” SVLN, RRQ, 5.963” ID, w/ 7” 26# VAM TOP HC @ 167’ MD Proposed 3-1/2” SVLN, RRQ, 2.813” ID w/ VAM TOP BxP, XO to 3-½” EZGO BxP , Proposed Scoop Guide, 6” OD x 3-½” w/ 7” GS Profile 9-5/8” 40# L80 BTC Intermediate Casing @ 8860’ MD / 4916’ TVD 12-1/4” hole / Cemented to Surface, Two Stages Proposed 7” SLVN x 3-1/2” SVLN Adapter XO locator w/ 3-½” EZGO HTGT Box x Pin Proposed 3-½”, 9.3# EZGO HTGT Velocity String Tubing 7” x 9-5/8” Baker ZXP Liner Top Packer With 10’ seal bore @ 8,684’ MD / 4867’ TVD Proposed Tbg Punch in existing 7” tbg Proposed Tbg Punch in existing 7” tbg Proposed 3-½” SSD w/ 3-½” EZGO HTGT Box x Pin Proposed Eline Conveyed 7” x 3-½” Pkr w/ 10’ PBR @ 8702’ MD / 4877’ TVD Proposed 3-½” XN Profile Nipple w/ WLEG w/ 3-½” EZGO HTGT Pin. WLEG @ 8731’ MD / 4885’ TVD Proposed 10’ Locator Seal Assy. w/ 3-½” EZGO HTGT Box Proposed 7” x 3-1/2” Hydraulic Tbg Anchor (depth of scoop guide TBD) Torque & Drag Analysis Report Wellbore Cleanout Specialized Tools Client Name: Petroak Field Name: CINGASA Country: USA Well Name: CLU S 05 Engineer: Zan Walsh Prepared by: Omar Alabdullah Reviewed by: James Harwell Revision: 1 Date: June 23 2020 Contents Aims, Planned Survey, Plot report & Graphic report…………………………………………. Wellbore & Workstring information …………………………………………………………… Torque and Drag Analysis ………………………………………………………………………. Comments: Top ConnectionCum length (ft) Young's lod (m·psi): 29.00 Torsion Limit (lb·ft): 9,900.0 Equipment : 3.500 in, Tubing 3.500 2.992 279.0 8,730.00 N/A291 Model : Mfg. : 8,730.009.30 1 Tension limit (klbs): 207.00 TJOD: 4.250 TJID: 2.942 Grade: L-80 String Assembly OD (in)Weight (lb): Length (ft)ID/EqID (in)Unit weight (lb/ft): Joint count Seq # String Assembly Report Mech EngineerPetroak Walsh, Zan zwalsh@petroak.com Title: Email:Phone:Name:Company: Contacts: PETROAK On ShoreWell Location: Well/Lease Name: Company/Operator: CLU S 05Well Number: CINGSA Prepared By: Country: UNITED STATES Assembly Type/Number: Completion/1 Date Prepared: 6/23/2020 Omar Alabdullah Page 1 of 16/23/2020 7:41:16 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Wellpath Directional Report Prepared By: Omar Alabdullah Petroak Walsh, Zan zwalsh@petroak.comMech Engineer Email:Phone:Namer:Company: Title: PETROAK UNITED STATESCountry:On ShoreWell Location: Well/Lease Name: Company/Operator: Completion/1Assembly Type/Number:CLU S 05Well Number: CINGSA Date Prepared: 6/23/2020 Contacts: Comments: Page 1 of 46/23/2020 7:41:39 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Planned survey MD (ft) Incl (°) Azim (°) TVD (ft)North (ft)East (ft) H. Disp (ft) DLS (°/100ft) 0.0 0.00 0.00 0.0 0.0 0.0 0.0 0.00 202.0 0.74 65.74 202.0 0.5 1.2 1.3 0.37 295.0 0.44 218.15 295.0 0.5 1.5 1.6 1.23 384.0 2.67 241.74 384.0 -0.7 -0.5 0.9 2.55 473.0 5.12 239.09 472.7 -3.8 -5.8 6.9 2.76 563.0 7.61 236.55 562.2 -9.1 -14.2 16.9 2.78 653.0 9.92 237.29 651.1 -16.6 -25.7 30.6 2.57 742.0 13.97 234.85 738.2 -26.9 -40.9 49.0 4.58 832.0 18.16 233.16 824.6 -41.6 -61.0 73.9 4.68 927.0 22.52 231.12 913.7 -61.9 -87.1 106.8 4.65 1,023.0 25.66 232.52 1,001.3 -86.1 -117.9 146.0 3.32 1,119.0 27.56 234.15 1,087.2 -111.8 -152.4 189.0 2.12 1,214.0 29.32 233.45 1,170.7 -138.5 -188.9 234.2 1.89 1,310.0 31.24 233.25 1,253.6 -167.4 -227.7 282.6 2.00 1,406.0 34.14 231.75 1,334.4 -199.0 -268.8 334.4 3.14 1,501.0 36.47 232.84 1,411.9 -232.5 -312.3 389.3 2.54 1,597.0 37.49 233.87 1,488.6 -267.0 -358.6 447.1 1.24 1,693.0 39.30 233.55 1,563.8 -302.3 -406.6 506.7 1.90 1,789.0 41.97 233.40 1,636.7 -339.5 -456.9 569.2 2.78 1,885.0 44.98 234.73 1,706.3 -378.2 -510.4 635.2 3.28 1,981.0 48.55 233.99 1,772.1 -419.0 -567.2 705.1 3.76 2,077.0 51.49 233.75 1,833.8 -462.3 -626.6 778.7 3.07 2,173.0 53.92 233.75 1,891.9 -507.5 -688.2 855.1 2.53 2,268.0 55.94 232.65 1,946.5 -554.1 -750.4 932.8 2.33 2,347.0 57.52 232.66 1,989.8 -594.1 -802.9 998.9 2.00 2,558.0 60.01 234.75 2,099.3 -700.9 -948.3 1,179.2 1.45 2,654.0 60.55 234.76 2,146.8 -749.0 -1,016.4 1,262.6 0.56 2,751.0 61.10 234.26 2,194.1 -798.2 -1,085.4 1,347.3 0.72 2,846.0 61.68 233.49 2,239.6 -847.3 -1,152.8 1,430.7 0.94 2,942.0 62.17 233.48 2,284.8 -897.7 -1,220.8 1,515.4 0.51 3,039.0 62.93 233.15 2,329.5 -949.2 -1,289.9 1,601.5 0.84 3,134.0 62.86 232.82 2,372.8 -1,000.1 -1,357.4 1,686.0 0.32 3,231.0 62.87 232.62 2,417.0 -1,052.4 -1,426.1 1,772.3 0.18 3,327.0 62.88 232.59 2,460.8 -1,104.3 -1,494.0 1,857.8 0.03 3,423.0 62.88 233.10 2,504.6 -1,155.9 -1,562.1 1,943.2 0.47 3,518.0 62.87 232.97 2,547.9 -1,206.7 -1,629.6 2,027.7 0.12 3,614.0 62.92 233.07 2,591.6 -1,258.1 -1,697.9 2,113.2 0.11 3,710.0 63.10 233.26 2,635.2 -1,309.4 -1,766.3 2,198.7 0.26 3,806.0 63.00 233.61 2,678.7 -1,360.4 -1,835.1 2,284.3 0.34 3,901.0 63.05 233.91 2,721.8 -1,410.4 -1,903.4 2,369.0 0.29 3,997.0 63.04 233.86 2,765.3 -1,460.9 -1,972.5 2,454.5 0.05 4,093.0 63.05 234.25 2,808.8 -1,511.1 -2,041.8 2,540.1 0.36 4,188.0 63.10 234.40 2,851.8 -1,560.5 -2,110.6 2,624.8 0.15 4,284.0 63.04 234.08 2,895.3 -1,610.5 -2,180.0 2,710.4 0.30 4,380.0 63.01 234.53 2,938.9 -1,660.4 -2,249.5 2,795.9 0.42 4,476.0 63.09 234.37 2,982.4 -1,710.2 -2,319.1 2,881.5 0.17 4,571.0 63.04 234.51 3,025.4 -1,759.4 -2,388.0 2,966.2 0.14 4,667.0 63.09 234.69 3,068.9 -1,809.0 -2,457.8 3,051.8 0.18 Page 2 of 46/23/2020 7:41:39 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Planned survey MD (ft) Incl (°) Azim (°) TVD (ft)North (ft)East (ft) H. Disp (ft) DLS (°/100ft) 4,762.0 63.10 234.89 3,111.9 -1,857.9 -2,527.0 3,136.5 0.19 4,859.0 63.17 234.90 3,155.7 -1,907.6 -2,597.8 3,223.0 0.07 4,956.0 63.06 234.74 3,199.6 -1,957.5 -2,668.5 3,309.5 0.19 5,052.0 63.08 234.53 3,243.1 -2,007.0 -2,738.3 3,395.1 0.20 5,148.0 63.00 234.15 3,286.6 -2,056.9 -2,807.8 3,480.6 0.36 5,243.0 63.04 234.09 3,329.7 -2,106.5 -2,876.4 3,565.3 0.07 5,339.0 63.04 233.90 3,373.2 -2,156.8 -2,945.7 3,650.8 0.18 5,435.0 63.10 233.53 3,416.7 -2,207.5 -3,014.6 3,736.4 0.35 5,531.0 63.04 233.77 3,460.2 -2,258.2 -3,083.6 3,822.0 0.23 5,625.0 63.10 233.73 3,502.7 -2,307.7 -3,151.2 3,905.8 0.07 5,721.0 63.05 233.58 3,546.2 -2,358.5 -3,220.1 3,991.4 0.15 5,817.0 63.07 233.36 3,589.7 -2,409.4 -3,288.9 4,077.0 0.21 5,912.0 63.07 233.63 3,632.7 -2,459.8 -3,357.0 4,161.7 0.25 6,008.0 63.04 233.63 3,676.2 -2,510.5 -3,425.9 4,247.3 0.03 6,104.0 63.04 233.37 3,719.8 -2,561.4 -3,494.6 4,332.8 0.24 6,200.0 63.06 233.70 3,763.3 -2,612.3 -3,563.5 4,418.4 0.31 6,295.0 63.07 233.60 3,806.3 -2,662.5 -3,631.7 4,503.1 0.09 6,391.0 63.10 233.45 3,849.7 -2,713.4 -3,700.5 4,588.7 0.14 6,487.0 62.98 233.68 3,893.3 -2,764.2 -3,769.4 4,674.3 0.25 6,584.0 63.04 233.23 3,937.3 -2,815.7 -3,838.8 4,760.7 0.42 6,680.0 63.06 233.15 3,980.8 -2,867.0 -3,907.3 4,846.3 0.08 6,775.0 63.06 233.35 4,023.8 -2,917.6 -3,975.2 4,931.0 0.19 6,871.0 63.02 233.35 4,067.4 -2,968.7 -4,043.8 5,016.5 0.04 6,967.0 63.11 233.36 4,110.9 -3,019.8 -4,112.5 5,102.1 0.09 7,063.0 62.97 233.21 4,154.4 -3,070.9 -4,181.1 5,187.7 0.20 7,158.0 62.76 233.01 4,197.7 -3,121.7 -4,248.7 5,272.2 0.29 7,254.0 62.72 233.44 4,241.7 -3,172.8 -4,317.1 5,357.6 0.40 7,350.0 62.67 233.84 4,285.7 -3,223.3 -4,385.7 5,442.9 0.37 7,445.0 62.71 233.88 4,329.3 -3,273.1 -4,453.9 5,527.3 0.06 7,540.0 62.65 234.11 4,372.9 -3,322.7 -4,522.2 5,611.7 0.22 7,636.0 62.72 234.16 4,417.0 -3,372.7 -4,591.3 5,697.0 0.09 7,732.0 62.68 234.31 4,461.0 -3,422.6 -4,660.5 5,782.3 0.14 7,827.0 62.73 234.28 4,504.5 -3,471.9 -4,729.1 5,866.7 0.06 7,923.0 62.75 234.12 4,548.5 -3,521.8 -4,798.3 5,952.0 0.15 8,018.0 62.75 234.21 4,592.0 -3,571.2 -4,866.8 6,036.5 0.08 8,114.0 62.63 233.94 4,636.1 -3,621.3 -4,935.9 6,121.8 0.28 8,210.0 62.76 233.85 4,680.1 -3,671.5 -5,004.8 6,207.1 0.16 8,305.0 62.70 234.12 4,723.6 -3,721.2 -5,073.1 6,291.5 0.26 8,401.0 64.03 234.09 4,766.7 -3,771.5 -5,142.6 6,377.3 1.39 8,497.0 66.48 234.38 4,806.8 -3,822.4 -5,213.3 6,464.5 2.57 8,593.0 69.80 234.32 4,842.6 -3,874.4 -5,285.7 6,553.6 3.46 8,688.0 72.88 234.07 4,873.0 -3,927.0 -5,358.7 6,643.6 3.25 8,783.0 75.69 233.07 4,898.7 -3,981.3 -5,432.3 6,735.0 3.13 8,831.0 77.39 232.28 4,909.9 -4,009.6 -5,469.4 6,781.7 3.89 8,937.0 79.55 231.42 4,931.1 -4,073.8 -5,551.1 6,885.5 2.19 9,033.0 79.28 228.87 4,948.7 -4,134.2 -5,623.5 6,979.7 2.63 9,129.0 80.33 229.27 4,965.7 -4,196.1 -5,694.9 7,073.8 1.17 9,225.0 80.36 228.87 4,981.8 -4,258.1 -5,766.4 7,168.2 0.41 9,320.8 79.66 228.52 4,998.4 -4,320.4 -5,837.2 7,262.2 0.81 Page 3 of 46/23/2020 7:41:39 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Planned survey MD (ft) Incl (°) Azim (°) TVD (ft)North (ft)East (ft) H. Disp (ft) DLS (°/100ft) 9,416.0 80.96 229.31 5,014.4 -4,382.1 -5,908.0 7,355.7 1.59 9,512.0 80.96 229.88 5,029.5 -4,443.5 -5,980.2 7,450.3 0.59 9,608.0 82.51 229.11 5,043.3 -4,505.2 -6,052.4 7,545.1 1.80 9,702.0 83.78 228.43 5,054.5 -4,566.8 -6,122.6 7,638.2 1.53 9,799.0 85.20 227.81 5,063.9 -4,631.2 -6,194.5 7,734.3 1.60 9,895.0 85.66 227.39 5,071.5 -4,695.7 -6,265.1 7,829.6 0.65 9,990.0 85.78 226.75 5,078.6 -4,760.3 -6,334.5 7,923.8 0.68 10,085.0 86.93 226.22 5,084.6 -4,825.5 -6,403.3 8,018.0 1.33 10,180.0 86.62 226.36 5,090.0 -4,891.1 -6,471.8 8,112.2 0.36 10,277.0 87.39 226.34 5,095.0 -4,957.9 -6,541.9 8,208.4 0.79 10,371.0 87.11 225.98 5,099.6 -5,023.0 -6,609.6 8,301.7 0.48 10,467.0 86.99 226.09 5,104.5 -5,089.5 -6,678.6 8,396.9 0.17 10,564.0 88.46 225.76 5,108.3 -5,157.0 -6,748.3 8,493.1 1.55 10,660.0 88.22 225.78 5,111.1 -5,223.9 -6,817.0 8,588.4 0.25 10,756.0 87.85 225.10 5,114.4 -5,291.2 -6,885.4 8,683.6 0.81 10,852.0 87.79 225.76 5,118.1 -5,358.5 -6,953.7 8,778.9 0.69 10,947.0 88.00 225.77 5,121.6 -5,424.8 -7,021.8 8,873.2 0.22 11,043.0 88.13 225.10 5,124.8 -5,492.1 -7,090.1 8,968.4 0.71 11,101.0 88.13 225.10 5,126.7 -5,533.0 -7,131.2 9,025.9 0.00 Page 4 of 46/23/2020 7:41:39 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Wellbore Geometry Report Wellbore Casing/Hole Data 6.276 Equipment : 7.000 in, Casing 7.000 26.00 6.151 Conn OD (in): 7.000 0.0 8,860.0 1 L80 Air gap (ft): 0.0 Water depth (ft): 0.0 Mud line (ft): 0.0 Bottom MD (ft) Top MD (ft)Drift ID (in)Nom./Hole ID (in) Seq #Unit Weight (lb/ft) Casing OD (in) Grade Comments: Prepared By: Omar Alabdullah Petroak Walsh, Zan zwalsh@petroak.comMech Engineer UNITED STATESCountry:On ShoreWell Location: Well/Lease Name: Company/Operator: Assembly Type/Number:CLU S 05Well Number: CINGSA Date Prepared: 6/23/2020 PETROAK Completion/1 Email:Phone:Name:Company: Title: Contacts: Page 1 of 16/23/2020 7:41:45 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Detail Report Job Casing/Hole Data 7.000 in, Casing 7.000 26.00 6.276 6.151 7.000 0.0 8,860.0 Equipment Top MD (ft)Bottom MD (ft) Casing OD (in) Nom./Hole ID (in) Drift ID (in)Conn OD (in)Unit Weight (lb/ft) Notes: String Assembly Equipment OD (in)Weight (lb): Length (ft) 3.500 in, Tubing 3.500 2.992 279.0 8,730.00 TJOD:4.250; TJID: 2.9421291 ID/EqID (in)Top ConnectionSeq # Notes: Joint count Mech EngineerPetroak Walsh, Zan zwalsh@petroak.com Contacts: Title: Email:Phone:Name:Company: On ShoreWell Location: Well/Lease Name: Company/Operator: CLU S 05Well Number: CINGSA PETROAK Prepared By: Omar Alabdullah Country: UNITED STATES Assembly Type/Number: Completion/1 Date Prepared: 6/23/2020 Planned survey Current Input Parameters Bit/Shoe depth (ft): 8,860.0 Mud weight (ppg): 8.60 Planned survey String assembly: Open Open hole fric. coef (): 0.360 In casing fric. coef (): 0.350 Apply end load weight? No WOB (klbs): Apply end load torque? No String assemb. rotate? No Calculation model: Hybrid Full 0.0TOB (lb·ft): Tripping direction: In Tool of intrest(TOI)? No Desired wt. at TOI (lb): 0.0 Desired torq at TOI (lb·ft): 0.0 Set tool? No TOI Name: Rotate thru TOI? Yes Surf. slack off wt (klbs): N/A 0.00 Job Notes: To analyze the Drag forces experienced by the Tubing as being RIH with 8.6 ppg KCL Sim Notes: Block weight (klbs): 0.00 (est.) Rotate above TOI? No Mud type: Water/clear fluid No N/ACalculate pipe wraps: Pipe wrap rounds: In casing pipe wrap F.C. (): 0.380 Open hole pipe wrap F.C. (): 0.380 0.00Gel 10 min (lb/100ft²): 0.00Gel 10 sec (lb/100ft²): Water/clear fluidMud type: Mud Data MW [In-Out] (ppg): 8.60-8.60 Annulus friction model: Bore friction model: PV [In-Out] (mPas): 0.00-0.00 YP [In-Out] (lb/100ft²): 0.00-0.00 Bottom temp. (°F): 150.0 Notes: 8.6 ppg 6% KCL Output Results Surface tension (klbs): 20.19 0.0Surface torque (lb·ft): Neutral point depth (ft): 8,371.9 Surface hook load (klbs): 20.19 0 0Est. Pipe Wrap to Activate TOI(total) Est. Pipe Wrap to reach set tool (total) Page 1 of 26/23/2020 7:41:50 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Notes: Page 2 of 26/23/2020 7:41:50 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Graphic ReportPetroak Walsh, Zan zwalsh@petroak.comMech EngineerOn ShoreWell Location:Well/Lease Name:Company/Operator:CLU S 05Well Number:CINGSAPETROAKTitle: Email:Phone:Name:Company:Contacts:Prepared By: Omar AlabdullahCountry: UNITED STATESAssembly Type/Number: Completion/1Date Prepared: 6/23/2020N/ASurf. slack off wt (klbs): YesRotate thru TOI? NoSet tool? 0.0Desired torq at TOI (lb·ft): 0.0Desired wt. at TOI (lb): TOI NameNoTool of intrest(TOI)? 0.0TOB (lb·ft): FalseApply end load torque? 0.00WOB (klbs): NoApply end load weight? Not RotateRotate:OpenString assembly: InTripping direction: 0.360Open hole fric. coef (): 0.350In casing fric. coef (): 8.60Mud weight (ppg): 8,860.0Bit/Shoe depth (ft): Planned surveyHybrid FullCalculation model: Current Input ParametersBlock weight (klbs): 0.00 (est.)Rotate above TOI? NoMud type: Water/clear fluidN/APipe Wrap Rounds: Job: To analyze the Drag forces experienced by the Tubing as being RIH with 8.6 ppg KCLSimulation: Comments:Page 1 of 26/23/2020 7:41:55 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Apply WOB/TOB: Block Wt.: (klbs)Model:Drill String:Trip Direction:Rotate:Planned surveyNoInOpenHybrid Full0.00 (t)No / NoPage 2 of 26/23/2020 7:41:55 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Plot ReportPetroak Walsh, Zan zwalsh@petroak.comMech EngineerOn ShoreWell Location:Well/Lease Name:Company/Operator:CLU S 05Well Number:CINGSAPETROAKTitle: Email:Phone:Name:Company:Contacts:Prepared By: Omar AlabdullahCountry: UNITED STATESAssembly Type/Number: Completion/1Date Prepared: 6/23/2020N/ASurf. slack off wt (klbs): YesRotate thru TOI? NoSet tool? 0.0Desired torq at TOI (lb·ft): 0.0Desired wt. at TOI (lb): TOI NameNoTool of intrest(TOI)? 0.0TOB (lb·ft): FalseApply end load torque? 0.00WOB (klbs): NoApply end load weight? Not RotateRotate:OpenString assembly: InTripping direction: 0.360Open hole fric. coef (): 0.350In casing fric. coef (): 8.60Mud weight (ppg): 8,860.0Bit/Shoe depth (ft): Planned surveyHybrid FullCalculation model: Current Input ParametersBlock weight (klbs): 0.00 (est.)Rotate above TOI? NoMud type: Water/clear fluidN/APipe Wrap Rounds: Pipe wrap:()0.380Pipe wrap:()0.380Job: To analyze the Drag forces experienced by the Tubing as being RIH with 8.6 ppg KCLSimulation: Comments:Page 1 of 16/23/2020 7:41:59 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Detail Report Job Casing/Hole Data 7.000 in, Casing 7.000 26.00 6.276 6.151 7.000 0.0 8,860.0 Equipment Top MD (ft)Bottom MD (ft) Casing OD (in) Nom./Hole ID (in) Drift ID (in)Conn OD (in)Unit Weight (lb/ft) Notes: String Assembly Equipment OD (in)Weight (lb): Length (ft) 3.500 in, Tubing 3.500 2.992 279.0 8,730.00 TJOD:4.250; TJID: 2.9421291 ID/EqID (in)Top ConnectionSeq # Notes: Joint count Mech EngineerPetroak Walsh, Zan zwalsh@petroak.com Contacts: Title: Email:Phone:Name:Company: On ShoreWell Location: Well/Lease Name: Company/Operator: CLU S 05Well Number: CINGSA PETROAK Prepared By: Omar Alabdullah Country: UNITED STATES Assembly Type/Number: Completion/1 Date Prepared: 6/23/2020 Planned survey Current Input Parameters Bit/Shoe depth (ft): 8,860.0 Mud weight (ppg): 8.60 Planned survey String assembly: Open Open hole fric. coef (): 0.360 In casing fric. coef (): 0.350 Apply end load weight? No WOB (klbs): Apply end load torque? No String assemb. rotate? Yes Calculation model: Hybrid Full 0.0TOB (lb·ft): Tripping direction: In Tool of intrest(TOI)? No Desired wt. at TOI (lb): 0.0 Desired torq at TOI (lb·ft): 0.0 Set tool? No TOI Name: Rotate thru TOI? Yes Surf. slack off wt (klbs): N/A 0.00 Job Notes: To analyze the Drag forces experienced by the Tubing as being RIH with 8.6 ppg KCL Sim Notes: Block weight (klbs): 0.00 (est.) Rotate above TOI? No Mud type: Water/clear fluid No N/ACalculate pipe wraps: Pipe wrap rounds: In casing pipe wrap F.C. (): 0.380 Open hole pipe wrap F.C. (): 0.380 0.00Gel 10 min (lb/100ft²): 0.00Gel 10 sec (lb/100ft²): Water/clear fluidMud type: Mud Data MW [In-Out] (ppg): 8.60-8.60 Annulus friction model: Bore friction model: PV [In-Out] (mPas): 0.00-0.00 YP [In-Out] (lb/100ft²): 0.00-0.00 Bottom temp. (°F): 150.0 Notes: 8.6 ppg 6% KCL Output Results Surface tension (klbs): 39.66 4,301.5Surface torque (lb·ft): Neutral point depth (ft): N/A Surface hook load (klbs): 39.66 0 0Est. Pipe Wrap to Activate TOI(total) Est. Pipe Wrap to reach set tool (total) Page 1 of 26/23/2020 7:43:32 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Notes: Page 2 of 26/23/2020 7:43:32 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Graphic ReportPetroak Walsh, Zan zwalsh@petroak.comMech EngineerOn ShoreWell Location:Well/Lease Name:Company/Operator:CLU S 05Well Number:CINGSAPETROAKTitle: Email:Phone:Name:Company:Contacts:Prepared By: Omar AlabdullahCountry: UNITED STATESAssembly Type/Number: Completion/1Date Prepared: 6/23/2020N/ASurf. slack off wt (klbs): YesRotate thru TOI? NoSet tool? 0.0Desired torq at TOI (lb·ft): 0.0Desired wt. at TOI (lb): TOI NameNoTool of intrest(TOI)? 0.0TOB (lb·ft): FalseApply end load torque? 0.00WOB (klbs): NoApply end load weight? RotateRotate:OpenString assembly: InTripping direction: 0.360Open hole fric. coef (): 0.350In casing fric. coef (): 8.60Mud weight (ppg): 8,860.0Bit/Shoe depth (ft): Planned surveyHybrid FullCalculation model: Current Input ParametersBlock weight (klbs): 0.00 (est.)Rotate above TOI? NoMud type: Water/clear fluidN/APipe Wrap Rounds: Job: To analyze the Drag forces experienced by the Tubing as being RIH with 8.6 ppg KCLSimulation: Comments:Page 1 of 26/23/2020 7:43:39 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Apply WOB/TOB: Block Wt.: (klbs)Model:Drill String:Trip Direction:Rotate:Planned surveyYesInOpenHybrid Full0.00 (t)No / NoPage 2 of 26/23/2020 7:43:39 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Plot ReportPetroak Walsh, Zan zwalsh@petroak.comMech EngineerOn ShoreWell Location:Well/Lease Name:Company/Operator:CLU S 05Well Number:CINGSAPETROAKTitle: Email:Phone:Name:Company:Contacts:Prepared By: Omar AlabdullahCountry: UNITED STATESAssembly Type/Number: Completion/1Date Prepared: 6/23/2020N/ASurf. slack off wt (klbs): YesRotate thru TOI? NoSet tool? 0.0Desired torq at TOI (lb·ft): 0.0Desired wt. at TOI (lb): TOI NameNoTool of intrest(TOI)? 0.0TOB (lb·ft): FalseApply end load torque? 0.00WOB (klbs): NoApply end load weight? RotateRotate:OpenString assembly: InTripping direction: 0.360Open hole fric. coef (): 0.350In casing fric. coef (): 8.60Mud weight (ppg): 8,860.0Bit/Shoe depth (ft): Planned surveyHybrid FullCalculation model: Current Input ParametersBlock weight (klbs): 0.00 (est.)Rotate above TOI? NoMud type: Water/clear fluidN/APipe Wrap Rounds: Pipe wrap:()0.380Pipe wrap:()0.380Job: To analyze the Drag forces experienced by the Tubing as being RIH with 8.6 ppg KCLSimulation: Comments:Page 1 of 16/23/2020 7:43:43 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Plot ReportPetroak Walsh, Zan zwalsh@petroak.comMech EngineerOn ShoreWell Location:Well/Lease Name:Company/Operator:CLU S 05Well Number:CINGSAPETROAKTitle: Email:Phone:Name:Company:Contacts:Prepared By: Omar AlabdullahCountry: UNITED STATESAssembly Type/Number: Completion/1Date Prepared: 6/23/2020N/ASurf. slack off wt (klbs): YesRotate thru TOI? NoSet tool? 0.0Desired torq at TOI (lb·ft): 0.0Desired wt. at TOI (lb): TOI NameNoTool of intrest(TOI)? 0.0TOB (lb·ft): FalseApply end load torque? 0.00WOB (klbs): NoApply end load weight? RotateRotate:OpenString assembly: InTripping direction: 0.360Open hole fric. coef (): 0.350In casing fric. coef (): 8.60Mud weight (ppg): 8,860.0Bit/Shoe depth (ft): Planned surveyHybrid FullCalculation model: Current Input ParametersBlock weight (klbs): 0.00 (est.)Rotate above TOI? NoMud type: Water/clear fluidN/APipe Wrap Rounds: Pipe wrap:()0.380Pipe wrap:()0.380Job: To analyze the Drag forces experienced by the Tubing as being RIH with 8.6 ppg KCLSimulation: Comments:Page 1 of 16/23/2020 7:43:46 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Detail Report Job Casing/Hole Data 7.000 in, Casing 7.000 26.00 6.276 6.151 7.000 0.0 8,860.0 Equipment Top MD (ft)Bottom MD (ft) Casing OD (in) Nom./Hole ID (in) Drift ID (in)Conn OD (in)Unit Weight (lb/ft) Notes: String Assembly Equipment OD (in)Weight (lb): Length (ft) 3.500 in, Tubing 3.500 2.992 279.0 8,730.00 TJOD:4.250; TJID: 2.9421291 ID/EqID (in)Top ConnectionSeq # Notes: Joint count Mech EngineerPetroak Walsh, Zan zwalsh@petroak.com Contacts: Title: Email:Phone:Name:Company: On ShoreWell Location: Well/Lease Name: Company/Operator: CLU S 05Well Number: CINGSA PETROAK Prepared By: Omar Alabdullah Country: UNITED STATES Assembly Type/Number: Completion/1 Date Prepared: 6/23/2020 Planned survey Current Input Parameters Bit/Shoe depth (ft): 8,860.0 Mud weight (ppg): 8.60 Planned survey String assembly: Open Open hole fric. coef (): 0.360 In casing fric. coef (): 0.350 Apply end load weight? No WOB (klbs): Apply end load torque? No String assemb. rotate? No Calculation model: Hybrid Full 0.0TOB (lb·ft): Tripping direction: Out Tool of intrest(TOI)? No Desired wt. at TOI (lb): 0.0 Desired torq at TOI (lb·ft): 0.0 Set tool? No TOI Name: Rotate thru TOI? Yes Surf. slack off wt (klbs): N/A 0.00 Job Notes: To analyze the Drag forces experienced by the Tubing as being RIH with 8.6 ppg KCL Sim Notes: Block weight (klbs): 0.00 (est.) Rotate above TOI? No Mud type: Water/clear fluid No N/ACalculate pipe wraps: Pipe wrap rounds: In casing pipe wrap F.C. (): 0.380 Open hole pipe wrap F.C. (): 0.380 0.00Gel 10 min (lb/100ft²): 0.00Gel 10 sec (lb/100ft²): Water/clear fluidMud type: Mud Data MW [In-Out] (ppg): 8.60-8.60 Annulus friction model: Bore friction model: PV [In-Out] (mPas): 0.00-0.00 YP [In-Out] (lb/100ft²): 0.00-0.00 Bottom temp. (°F): 150.0 Notes: 8.6 ppg 6% KCL Output Results Surface tension (klbs): 72.41 0.0Surface torque (lb·ft): Neutral point depth (ft): N/A Surface hook load (klbs): 72.41 0 0Est. Pipe Wrap to Activate TOI(total) Est. Pipe Wrap to reach set tool (total) Page 1 of 26/23/2020 7:44:30 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Notes: Page 2 of 26/23/2020 7:44:30 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Graphic ReportPetroak Walsh, Zan zwalsh@petroak.comMech EngineerOn ShoreWell Location:Well/Lease Name:Company/Operator:CLU S 05Well Number:CINGSAPETROAKTitle: Email:Phone:Name:Company:Contacts:Prepared By: Omar AlabdullahCountry: UNITED STATESAssembly Type/Number: Completion/1Date Prepared: 6/23/2020N/ASurf. slack off wt (klbs): YesRotate thru TOI? NoSet tool? 0.0Desired torq at TOI (lb·ft): 0.0Desired wt. at TOI (lb): TOI NameNoTool of intrest(TOI)? 0.0TOB (lb·ft): FalseApply end load torque? 0.00WOB (klbs): NoApply end load weight? Not RotateRotate:OpenString assembly: OutTripping direction: 0.360Open hole fric. coef (): 0.350In casing fric. coef (): 8.60Mud weight (ppg): 8,860.0Bit/Shoe depth (ft): Planned surveyHybrid FullCalculation model: Current Input ParametersBlock weight (klbs): 0.00 (est.)Rotate above TOI? NoMud type: Water/clear fluidN/APipe Wrap Rounds: Job: To analyze the Drag forces experienced by the Tubing as being RIH with 8.6 ppg KCLSimulation: Comments:Page 1 of 26/23/2020 7:44:37 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Apply WOB/TOB: Block Wt.: (klbs)Model:Drill String:Trip Direction:Rotate:Planned surveyNoOutOpenHybrid Full0.00 (t)No / NoPage 2 of 26/23/2020 7:44:37 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Plot ReportPetroak Walsh, Zan zwalsh@petroak.comMech EngineerOn ShoreWell Location:Well/Lease Name:Company/Operator:CLU S 05Well Number:CINGSAPETROAKTitle: Email:Phone:Name:Company:Contacts:Prepared By: Omar AlabdullahCountry: UNITED STATESAssembly Type/Number: Completion/1Date Prepared: 6/23/2020N/ASurf. slack off wt (klbs): YesRotate thru TOI? NoSet tool? 0.0Desired torq at TOI (lb·ft): 0.0Desired wt. at TOI (lb): TOI NameNoTool of intrest(TOI)? 0.0TOB (lb·ft): FalseApply end load torque? 0.00WOB (klbs): NoApply end load weight? Not RotateRotate:OpenString assembly: OutTripping direction: 0.360Open hole fric. coef (): 0.350In casing fric. coef (): 8.60Mud weight (ppg): 8,860.0Bit/Shoe depth (ft): Planned surveyHybrid FullCalculation model: Current Input ParametersBlock weight (klbs): 0.00 (est.)Rotate above TOI? NoMud type: Water/clear fluidN/APipe Wrap Rounds: Pipe wrap:()0.380Pipe wrap:()0.380Job: To analyze the Drag forces experienced by the Tubing as being RIH with 8.6 ppg KCLSimulation: Comments:Page 1 of 16/23/2020 7:44:41 PM Running Tubing 3 1/2 / RIH with 3 1/2" Tubing Page | 1 Tube Move Calculations July 13, 2020 CLU S-05 Velocity String Project General Tube Move Calculations Depicting Weight of Tubing During State Mandated MIT July 13, 2020 Page | 2 Tube Move Calculations July 13, 2020 Executive Summary: The following calculations and diagrams show the forces CLU S-5 will experience during the velocity string installation workover and during the life of the well as an injection and production gas storage well. PRA initially reached out to Halliburton to run Tube Move Calculations during the four initial scenarios shown in the below report. Halliburton ran the scenarios in CyberString. After performing the calculations PRA and Halliburton compared results and presented them to the AOGCC. With this discussion with the AOGCC, PRA reached out for a second opinion on the tubing weight. Schlumberger came into the project and ran a Torque and Drag model to analyze the tubing weight for the CLU S-5 well. The value was then used to rerun the Tube Move Calculations. Along with this, an additional scenario was evaluated. The case was to assess the event of the SSV failing to close but a successful closing of the Surface Controlled SSV. With the new Torque and Drag model tubing weight and the additional scenario, the SVLN X-over Adapter does NOT come unseated from the no-go landing nipple and all cases have a significant amount of force acting in a downward direction at the SVLN no-go. The weight at the safety valve landing nipple (SVLN) X-over Adapter was ~20,190 lbs downward in all the scenarios. In the case of the failed SSV but successful closing of the SCSSV more than 40,000 lbs of upward force is needed to overcome the weight of the pipe and the frictional forces. All other cases required even more upward force to be applied to unseat the safety valve landing nipple X-over Adapter. The results for the cases are listed in this report as well as a summary of assumptions made. Page | 3 Tube Move Calculations July 13, 2020 Well Scenarios: Scenario #1: Initial Conditions x Annulus filled with fluid (7” X 9-5/8”). x Tubing filled with fluid (3-1/2”). x Tubing plugged @ 3-1/2” Tubing Packer (4877’ TVD). Scenario #2: Dry 3-1/2” Tubing with Plug Removed x Annulus filled with fluid (7” X 9-5/8”). x Tubing dry of fluid (3-1/2”). No buoyancy forces. x Reservoir is now in connection to wellhead through 3-1/2” tubing. Well Static. Scenario #3: Injecting into Reservoir x Annulus filled with fluid (7” X 9-5/8”). x Tubing dry of fluid (3-1/2”). No buoyancy forces. x Reservoir is now in connection and injecting into reservoir. Scenario #4: Producing from Reservoir x Annulus filled with fluid (7” X 9-5/8”). x Tubing dry of fluid (3-1/2”). No buoyancy forces. x Reservoir is now in connection and producing from reservoir. Scenario #5: SSV Fails, SCSSV Closes (IA @ 1650 psi) x SVS is activated, SSV fails but SCSSV closes. 0 psi above SCSSV. x Annulus filled with fluid (7” X 9-5/8”). x Tubing dry of fluid (3-1/2”). No buoyancy forces. x Reservoir is now in connection and producing from reservoir. Page | 4 Tube Move Calculations July 13, 2020 Assumptions: Cross Sectional Areas Affected x Top and Bottom of seal bore at 167’ TVD with cross sectional area of 17.99 in 2. x Top of 3-1/2” tubing packer at 4,877’ TVD with cross sectional area of 2.94 in 2. x Bottom of 3-1/2” tubing packer at 4,877’ TVD with cross sectional area of 5.53 in 2. Forces x Positive values are forces acting to keep the tubing in the well (noted in green). x Negative values represent forces acting to push the tubing up/out the well (noted in red). Assumptions x Fluid is 8.6 ppg 6% KCL Brine o Fluid Gradient is 0.447 psi/ft x Gas gradient is 0.04 psi/ft x 200 psi held in 7” x 9-5/8” annulus x Shut-in well pressure is 1500 psi x Injection well pressure is 1650 psi x Production well pressure is 1550 psi x MIT test annular pressure used is 1600 psi w/ the exception of an 1800 psi MIT in Scenario #1 and 2300 psi in Scenario #2. x Assume both top and bottom of 7” SVLN x 3-1/2” SVLN Adapter XO Locator are at same depth 167’ TVD. x Assume both top and bottom of 3-1/2” Packer are at same depth 4877’ TVD. x Tubing weight is 20.19 klbs when tubing and annuli are fluid packed with 8.6 ppg 6% KCl brine. x Frictional force to overcome when tripping the tubing out of the well is 52.22 klbs. gls (seal bore - tubing ID) (Seal bore - tubing OD) Page | 5 Tube Move Calculations July 13, 2020 Calculations: Weight of Pipe in Air Weight of Pipe with Buoyancy Annular Area Hydrostatic Pressure Page | 6 Tube Move Calculations July 13, 2020 CINGSA CLU Storage 05 Proposed Velocity String Schematic June 3, 2020 7” 26# L80 VAMTOP Production Liner from 8,684’ MD / 4867’ TVD TOP To 11,099’ MD / 5127’ TVD TD 8-1/2” hole / Cemented 8.6 PPG KCL Brine Packer Fluid in Annulus 7” RN Nipple @ 8707’ MD / 4878’ TVD 5.88” ID, 7.60” OD Top Btm Length Top Btm 9,060' 9,130' 70' 4,954' 4,966' Original Perfs 2/18/2012 ; Reperf'd (9060' - 9120') on 7/21/2012 9,210' 9,390' 180' 4,979' 5,010' Original Perfs 2/18/2012 ; Reperf'd (9230' - 9320' & 9330' - 9390') on 7/21/2012 9,420' 9,470' 50' 5,015' 5,023' Original Perfs 2/18/2012 9,770' 10,380' 610' 5,061' 5,100' Original Perfs 2/18/2012 ; Reperf'd (9780' - 9990' & 10000' - 10060' & 10070' - 10220') on 7/21/2012 10,580' 10,880' 300' 5,109' 5,119' Original Perfs 2/18/2012 ; Reperf'd (10630' - 10750') on 7/21/2012 1,210' MD Perforations TVD Perforations Comments Total Footage FMC Wellhead: 13-5/8” 5000# Multibowl FMC Tree: 7” 5000# complete with SSV 20” 133# X56 Driven to 117.5’ MD 13-3/8” 68# K55 BTC Surface Casing @ 2390’ MD / 2013’ TVD 9-5/8” DV Collar @ 3510’’ 16” hole / Cemented to Surface 7” 26# L80 VAMTOP Tubing Existing SCSSV Control Line 7” SVLN, RRQ, 5.963” ID, w/ 7” 26# VAM TOP HC @ 167’ MD Proposed 3-1/2” SVLN, RRQ, 2.813” ID w/ VAM TOP BxP, XO to 3-½” EZGO BxP , Proposed Scoop Guide, 6” OD x 3-½” w/ 7” GS Profile 9-5/8” 40# L80 BTC Intermediate Casing @ 8860’ MD / 4916’ TVD 12-1/4” hole / Cemented to Surface, Two Stages Proposed 7” SLVN x 3-1/2” SVLN Adapter XO locator w/ 3-½” EZGO HTGT Box x Pin Proposed 3-½”, 9.3# EZGO HTGT Velocity String Tubing 7” x 9-5/8” Baker ZXP Liner Top Packer With 10’ seal bore @ 8,684’ MD / 4867’ TVD Proposed Tbg Punch in existing 7” tbg Proposed Tbg Punch in existing 7” tbg Proposed 3-½” SSD w/ 3-½” EZGO HTGT Box x Pin Proposed Eline Conveyed 7” x 3-½” Pkr w/ 10’ PBR @ 8702’ MD / 4877’ TVD Proposed 3-½” XN Profile Nipple w/ WLEG w/ 3-½” EZGO HTGT Pin. WLEG @ 8731’ MD / 4885’ TVD Proposed 10’ Locator Seal Assy. w/ 3-½” EZGO HTGT Box tubing anchor Page | 7 Tube Move Calculations July 13, 2020 Scenario #1: Initial Conditions x Annulus filled with fluid (7” X 9-5/8”). x Tubing filled with fluid (3-1/2”). x Tubing plugged @ 3-1/2” Tubing Packer (4877’ TVD). Hydrostatic Force = 1,343 lbs Pipe Weight = 20,190 lbs Hydrostatic Force = 4,941 lbs Hydrostatic Force = 6,417 lbs Hydrostatic Force = 7,006 lbs Sum of Forces = 69,401 lbs (Down) Friction Force = 52,220 lbs ( IA = includes 3 1/2"x 7 x 9 5/8" ) Page | 8 Tube Move Calculations July 13, 2020 Scenario #1 with MIT: Hydrostatic Force = 1,343 lbs Hydrostatic Force = 33,725 lbs Pipe Weight = 20,190 lbs Hydrostatic Force = 11,716 lbs Hydrostatic Force = 6,417 Sum of Forces = 45,327 lbs (Down) Friction Force = 52,220 lbs Page | 9 Tube Move Calculations July 13, 2020 Scenario #2: Dry 3-1/2” Tubing with Plug Removed x Annulus filled with fluid (7” X 9-5/8”). x Tubing dry of fluid (3-1/2”). No buoyancy forces. x Reservoir is now in connection to wellhead through 3-1/2” tubing. Well Static. Hydrostatic Force = 28,328 lbs Sum of Forces = 93,425 lbs (Down) Pipe Weight = 20,190 lbs Hydrostatic Force = 4,941 lbs Hydrostatic Force = 7,006 lbs Reservoir Force + Hydrostatic = 9,378 lbs Friction Force = 52,220 lbs Page | 10 Tube Move Calculations July 13, 2020 Scenario #2 with MIT: Reservoir Force + Hydrostatic = 9,378 lbs Sum of Forces = 61,811 lbs (Down) Hydrostatic Force = 13,171 lbs Hydrostatic Force = 42,720 lbs Hydrostatic Force = 28,328 lbs Pipe Weight = 20,190 lbs Friction Force = 52,220 lbs Page | 11 Tube Move Calculations July 13, 2020 Scenario #3: Injecting into Reservoir x Annulus filled with fluid (7” X 9-5/8”). x Tubing dry of fluid (3-1/2”). No buoyancy forces. x Reservoir is now in connection and injecting into reservoir. Gas Injection Force = 10,213 lbs Sum of Forces = 95,288 lbs (Down) Hydrostatic Force = 4,941 lbs Hydrostatic Force = 31,026 lbs Pipe Weight = 20,190 lbs Hydrostatic Force = 7,006 lbs Pipe Weight = 52,220 lbs Page | 12 Tube Move Calculations July 13, 2020 Scenario #3 with MIT: Gas Injection Force = 10,213 lbs Sum of Forces = 71,200 lbs (Down) Hydrostatic Force = 11,701 lbs Hydrostatic Force = 33,725 lbs Hydrostatic Force = 31,026 lbs Pipe Weight = 20,190 lbs Friction Force = 52,220 lbs Page | 13 Tube Move Calculations July 13, 2020 Scenario #4: Producing from Reservoir x Annulus filled with fluid (7” X 9-5/8”). x Tubing dry of fluid (3-1/2”). No buoyancy forces. x Reservoir is now in connection and producing from reservoir. Gas Injection Force = 9,588 lbs Sum of Forces = 94,115 lbs (Down) Hydrostatic Force = 4,941 lbs Hydrostatic Force = 29,227 lbs Pipe Weight = 20,190 lbs Hydrostatic Force = 7,006 lbs Friction Force = 52,220 lbs Page | 14 Tube Move Calculations July 13, 2020 Scenario #4 with MIT: x Annulus filled with fluid (7” X 9-5/8”). x Tubing dry of fluid (3-1/2”). No buoyancy forces. x Reservoir is now in connection and producing from reservoir. Gas Injection Force = 9,588 lbs Sum of Forces = 70,041 lbs (Down) Hydrostatic Force = 33,725 lbs Hydrostatic Force = 29,227 lbs Pipe Weight = 20,190 lbs Hydrostatic Force = 11,716 lbs Friction Force = 52,220 lbs Page | 15 Tube Move Calculations July 13, 2020 Scenario #5: SSV Fails, SCSSV Closes (IA @ 1650psi) x Annulus filled with fluid (7” X 9-5/8”). x Tubing dry of fluid (3-1/2”). No buoyancy forces. x Reservoir is now in connection and producing from reservoir. Gas Injection Force = 10,213 lbs Sum of Forces = 65,605 lbs (Down) Hydrostatic Force = 4,941 lbs Hydrostatic Force = 1,343 lbs Pipe Weight = 20,190 lbs Hydrostatic Force = 7,006 lbs Friction Force = 52,220 lbs tubing SI @1650 psi IA press= 200 psi 2.94in2 x 1650= 4851lbs gls SSSV forces IA = 200 psi SSSV 0lbs assume 0 psi gas above SSSV 11650 + 4941= 16,591 lbs upward * line break downstream of SSV Page | 16 Tube Move Calculations July 13, 2020 Scenario #5 with MIT: x Annulus filled with fluid (7” X 9-5/8”). x Tubing dry of fluid (3-1/2”). No buoyancy forces. x Reservoir is now in connection and producing from reservoir. Gas Injection Force = 10,213 lbs Sum of Forces = 41,531 lbs (Down) Hydrostatic Force = 33,725 lbs Hydrostatic Force = 1,343 lbs Pipe Weight = 20,190 lbs Hydrostatic Force = 11,716 lbs Friction Force = 52,220 lbs 400HP 229,500 lbs 11,900 ft / 3626 m No No Dragon 104' Powerpro 229,500 lbs Model 150 1" 150 kv as per contract 6 station, 16 bottles as per contract as per contract SJ Petroleum Machinery 200 BBL JC 400-S 1 Tank (3 compart.) Detroit Series 60 Double Life 4X5 450 HP Spraying 47,250 lbs / 221 kN 3M BTU 125 Tons 3 24" Gardner Denver PAH 200 450 HP Skidding Capable Crane Required Mast Telescopic Double RIG INVENTORY RIG 401 XJ400 Workover Rig Rig HP Rating Max Hook Load Nom. Depth Rating Make Hight static Hook Load Drilling Line size Well Control BOPE Accumulator Draworks Mechanical Travelling Block Load Rating Crosby McKissic 83-A WT Make Model Input Power Horsepower Rating Cooling Type Model Input Power Make Tubulars Drill Pipe Tubing Power Generation Make Mud System Active Volume Number of Tanks Shaker No. of Sheaves Sheave size Mud Pump Max pull Fast Line Travelling Assembly Kilowatt Rating Additional Equipment Pipe handler Dragon Heater !""#$%#&’()*!’"+),-*!.(!$/.’*(#/0& )*1(2!()&’//0"’*# $.#’,,)& "23#,(0++)+#($.#4#%"5# (&3#!,’4#’ $.#6#7879:;<<<#&=.3#.*7>;:<6<;:<<<7?77(* $.#’,,)& "23#* $.#6#7879:;<<<#&=.3#.*73#,(0++)+# $(($#($.3#=!(@#A?B#C#7879:;D#&=.3#,(0++)+#$0(")(6<:<6<;:<<<C>7C77CC??EE;;9966FF’’ --++0/"),,#$(@)*=!,)#,.)-!%!)++=5#,!G)+/’&) +’()+=/-@D’D,H!/’2F8F8C<7>F8F8C<7>+),-*!.(!$/&’()*!’"I###,))# $&*)H($")*’/-)%*’-(!$/ 7879J4J44J444 J<? J<7; J<<;’/5"),4!4J4! ?<K 7;K%!/!,@#############*&,C;<(@!,#+$-0&)/(#’/+#’""#(@)#!/%$*&’(!$/#-$/(’!/)+#@)*)!/#!,#(@)#,$")#’/+#)4-"0,!H)#.*$.)*(2#$%#!/()5*’()+#)10!.&)/(#’/+#,@’""#/$(# )#0,)+3#+!,-"$,)+3#$*#-$.!)+#=!(@$0(#(@)#)4.*),,#=*!(()/#.)*&!,,!$/#$%#!/()5*’()+#)10!.&)/(J#(@!,#+$-0&)/(#!,#"$’/)+.0*,0’/(#($#’5*))&)/(#($#(@)#%$*)5$!/5#’/+#,@’""# )#*)(0*/)+#($#!/()5*’()+#)10!.&)/(J#0.$/#+)&’/+3#!/()5*’()+#)10!.&)/(#*),)*H),#(@)#*!5@(#($#-@’/5)#+),!5/,3#&’()*!’",3#’/+#,.)-!%!-’(!$/,#=!(@$0(#/$(!-)J*)H:#:,@))(7#87# !"#$%&"#’)10!.&)/()-//$J,(’-D# $.3#6#7879L:#;D####J<?<#&!/!&0&#J<7;#&’4!&0&-$/-)/(*!-!(2-$*/)*#*’+!! *)’D#,@’*.#)+5),#J<7<#!/#7<LJ.’*’"")"!,&#J<7<#!/#7<LJ#J<7<#(J!J*J,10’*)/),,+$#/$(#,-’")#(@!,#+*’=!/5J’""#+!&)/,!$/,#!/#!/-@),J’""#%"’/5)#+*!""!/5#&0,(#,(*’++")#-$&&$/#-)/()*"!/)J*%,#)4-).(#=@)/###&###&$+!%!)+J+*’=!/5#!,#’#(@!*+’/5")#.*$M)-(!$/J 2)-/#+),-*!.(!$/+’().’*(#/$J?7:<<77E6A9;J?BA?<J>BAC>JFB77C7 30.90"Annular Blind Rams 29.80"VBR Pipe Rams 3-1/2" Pipe Rams Mud cross 29"7-1/16" 5k Lower Master Valve 28" 7-1/16" BOPE A P B P Hilcorp Rig 401 Choke Manifold 04/22/2020 Blooey Line To Gas Buster All Valves 2 1/16 5M WKM Safety Seal type D&L OIL TOOLS Product Catalog Made in the U.S.A.Rev. 2/1647 We Know Downhole.(800) 441-3504 www.dloiltools.com HYDRAULIC TUBING ANCHOR The Hydraulic Tubing Anchor is a hydraulically-activated retrievable anchor designed to hold the tubing string in tension or compression. The Hydraulic Tubing Anchor catcher prevents movement of the tubing during pumping strokes and holds it stationary if it should part. The use of a tubing anchor increase pump efficiency, reduces rod and tubing wear, and keeps tubing and rods from falling into the well in case of a part. The Hydraulic Tubing Anchor is operated by applying pressure to the tubing. This pressure shears screws that hold the anchor unset. A setting piston drives the slips set while locking the setting force in place. The Hydraulic Tubing Anchor utilizes specially designed slips - heat-treated steel alloy double-acting slips for maximum holding power in tension or compression. Slips are fully enclosed for extra breakage resistance and will be retained if slips break. The Hydraulic Tubing Anchor is retrieved by shearing screws with tension. Shear pins are added in 5,000 lb increments to achieve the desired shear value necessary to release.Hydraulic Set PackersProduct Specifications Casing Recommended Hole Size (inches) Tool OD (inches) Tool ID (inches) Thread Connections Box Up / Pin Down Part NumberSize (inches) Weight (lbs/ft) 4-1/2 9.5 - 13.5 3.920 - 4.090 3.750 1.94 2-3/8 EUE 32445 5 11.5 - 15.0 4.408 - 4.560 4.125 1.94 2-3/8 EUE 32452 18.0 - 21.0 4.154 - 4.276 4.000 1.94 2-3/8 EUE 32450 5-1/2 13.0 - 23.0 4.670 - 5.044 4.500 2.44 2-7/8 EUE 32455 7 17.0 - 32.0 6.094 - 6.538 5.750 3.00 3-1/2 EUE 32473 3.88 4-1/2 EUE 32474 #324 7” SVLN Locator Mandrel Crossover adapter to 3-1/2”3-1/2” Box3-1/2” Pin6.030” OD5.968” OD5.968” OD5.0” ODControl Line from 3-1/2” SVLN3-1/2” SVLN 1 Carlisle, Samantha J (CED) From:Zan Walsh <zwalsh@petroak.com> Sent:Monday, August 24, 2020 12:18 PM To:Schwartz, Guy L (CED) Cc:Steve Tyler; Rixse, Melvin G (CED); Chantal Walsh; Matthew Federle; Rick Gentges; Tom Walsh Subject:RE: CLU S-5 Procedure w/ Space Out Details (PTD 211-158) Guy, Thatsoundsgreat!Thanksforworkingwithusonthis.Doyouhaveanestimateforwhenwewillreceiveasigned Sundry10Ͳ403? LetmeknowifyouhaveanyissuesinsertingthenewTubeMoveslideintothePDFdoc. Thankyou, ZanWalsh MechanicalEngineer zwalsh@petroak.com 907Ͳ272Ͳ1232(office) 907Ͳ677Ͳ5121(direct) 907Ͳ317Ͳ8579(cell) From:Schwartz,GuyL(CED)<guy.schwartz@alaska.gov> Sent:Monday,August24,20209:19AM To:ZanWalsh<zwalsh@petroak.com> Cc:SteveTyler<styler@petroak.com>;Rixse,MelvinG(CED)<melvin.rixse@alaska.gov>;ChantalWalsh <cwalsh@petroak.com>;MatthewFederle<Matthew.Federle@cingsa.com>;RickGentges <Richard.Gentges@cingsa.com>;TomWalsh<twalsh@petroak.com> Subject:RE:CLUSͲ5Procedurew/SpaceOutDetails(PTD211Ͳ158) Zan, Thanksfortheadditionalinfo…IalreadyhandwroteintheMITͲIAafterstep26onthe8Ͳ19Ͳ20versionAlso,a witnessedMITͲIAandSVStestisrequiredafterthewellstartsoninjection.IwrotethatintothestepsafterNo.30.(two witnessedMITͲIAsarerequiredforthiswell.) Itlookslikethe“Executiveprocedure”hasmostofthestepsbutnotall.Isuggesteliminatingitfromthedocumentand justusethefirstshownproceduretoreduceconfusion.Icandothatmanuallyonmycopy. Iwillinsertthenewtubingmoveforslide44(SSVfails/ScSSVcloses)intothedocumentalso. 2 GuySchwartz Sr.PetroleumEngineer AOGCC 907Ͳ301Ͳ4533cell 907Ͳ793Ͳ1226office 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:ZanWalsh<zwalsh@petroak.com> Sent:Friday,August21,20201:46PM To:Schwartz,GuyL(CED)<guy.schwartz@alaska.gov> Cc:SteveTyler<styler@petroak.com>;Rixse,MelvinG(CED)<melvin.rixse@alaska.gov>;ChantalWalsh <cwalsh@petroak.com>;MatthewFederle<Matthew.Federle@cingsa.com>;RickGentges <Richard.Gentges@cingsa.com>;TomWalsh<twalsh@petroak.com> Subject:RE:CLUSͲ5Procedurew/SpaceOutDetails(PTD211Ͳ158) Guy, Goodcatchontheforcethesafetyvalvewouldsee;Iranthenumbersthereanditcomesoutto11,600lbsofextra upwardforceatthesafetyvalveat167’.Asyoumentionthisisnotahighriskscenarioandwiththeaddedupwardforce wearestilloverbalancedattheSVLN. Also,whatImeantbytheInnerAnnulusat1650psiwasactuallytheinsideofthe3Ͳ1/2”tubingnotthe3Ͳ1/2”x9Ͳ5/8” annulus;that,asyoustate,isat200psi.I’vechangedthewordinginthetubemovedocument. I’veattachedtheproceduremovingourwitnessedMITtesttodirectlyafterstep#26beforetherigdemobs. Thereasonforthescoopguideiseaseofentryintothe3Ͳ1/2”tubingandgettingthetubingasclosetosurfaceas possibleinordertomaintainvelocityofproduction. Regards, ZanWalsh MechanicalEngineer zwalsh@petroak.com 907Ͳ272Ͳ1232(office) 907Ͳ677Ͳ5121(direct) 907Ͳ317Ͳ8579(cell) 3 From:Schwartz,GuyL(CED)<guy.schwartz@alaska.gov> Sent:Friday,August21,202010:00AM To:ZanWalsh<zwalsh@petroak.com> Cc:SteveTyler<styler@petroak.com>;Rixse,MelvinG(CED)<melvin.rixse@alaska.gov>;ChantalWalsh <cwalsh@petroak.com>;MatthewFederle<Matthew.Federle@cingsa.com>;RickGentges <Richard.Gentges@cingsa.com>;TomWalsh<twalsh@petroak.com>;Rixse,MelvinG(CED)<melvin.rixse@alaska.gov> Subject:RE:CLUSͲ5Procedurew/SpaceOutDetails(PTD211Ͳ158) Onemorequestion…Whatisthereasoningforthescoopheadlocatedupholenearwellhead?Whataboutimpactsto fishing/pullingthevelocitystringlateron? GuySchwartz Sr.PetroleumEngineer AOGCC 907Ͳ301Ͳ4533cell 907Ͳ793Ͳ1226office 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,GuyL(CED) Sent:Thursday,August20,202010:08AM To:ZanWalsh<zwalsh@petroak.com> Cc:SteveTyler<styler@petroak.com>;Rixse,MelvinG(CED)<melvin.rixse@alaska.gov>;ChantalWalsh <cwalsh@petroak.com>;MatthewFederle<Matthew.Federle@cingsa.com>;RickGentges <Richard.Gentges@cingsa.com>;TomWalsh<twalsh@petroak.com>;MelvinGRixse(DOA)(melvin.rixse@alaska.gov) <melvin.rixse@alaska.gov> Subject:RE:CLUSͲ5Procedurew/SpaceOutDetails(PTD211Ͳ158) Zan, Regardingquestion5belowlookat20AAC25.412(c)and(e).OperatorisrequiredtoperformawitnessedMITͲIA beforeinjection. YoucouldwaittillrigleavestodothewitnessedMITͲIAtestbutmostoperatorsdotheMITwhentherigisinplacein casethereareissues.YoucoulddoMITͲIAto1600psibeforeorafterthetubinganchorisset(step24or26).Doing theMITͲIAbeforeanchorissetisthehighestriskforunseatingthenippleprofilethoughwith0psiinthetubingand fluidpacked(scenario#1). ThereisalsoarequirementtodoafollowͲupwitnessedMITͲIAafterinjectionisstabilized. Alsocouldyoulookatscenario#5withSSVfailureandScSSVclosing.Shouldn’ttherealsobeaforce(SIWHPof1600 psi)actingupwardagainsttheflappervalveintheIDofthetubing2.94in2?YoualsostatetheIAisat1650psi?isthis correct?Normallyitwouldbeatabout200Ͳ300psi…otherwisetheforceactingupwardwouldbemuchhigherthan shownonthenippleprofile.ImissedthisthefirsttimeIlookedatit.Thisscenariodoesn’tlooklikeitwillbeahighrisk though. GuySchwartz Sr.PetroleumEngineer 4 AOGCC 907Ͳ301Ͳ4533cell 907Ͳ793Ͳ1226office 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:ZanWalsh<zwalsh@petroak.com> Sent:Wednesday,August19,20204:09PM To:Schwartz,GuyL(CED)<guy.schwartz@alaska.gov> Cc:SteveTyler<styler@petroak.com>;Rixse,MelvinG(CED)<melvin.rixse@alaska.gov>;ChantalWalsh <cwalsh@petroak.com>;MatthewFederle<Matthew.Federle@cingsa.com>;RickGentges <Richard.Gentges@cingsa.com>;TomWalsh<twalsh@petroak.com> Subject:RE:CLUSͲ5Procedurew/SpaceOutDetails Guy, Thankyouforthequestions.Attachedistheprocedurewithdetailsincluded,pleaseletmeknowifthisiswhatyouare lookingfor. 1. WhatisthepurposeofthePNLlog? CINGSAhasdecidedtoremovethisfromtheworkoverandrunthePNLseparatefromtheCLUSͲ5Velocity Completion.AKEͲlinedoesn’tcarrythePNLtoolatthistimeandCINGSAwillworkwiththemtorunitinthe future. 2. Whatistheultimatedepthforthetubingsealassembly?Assumeyouarelocating8ftorsointothesealbore. (2ftfrombottom) WhenwecalculateourspaceͲoutfortheStraightSlotSealAssemblyLocatorwewillhave6’ofsealsstabbed intoBWDPackerw/SealboreExtension. 3. Instep20wouldn’tyoualreadyhavethespaceoutfiguredoutfromthefirstdummyrunwiththeFXE(step11) Webuiltthisportionoftheproceduretobeconservative.Wanttoinsureeveryoneonsiteisclickedinonthe importanceofthespaceͲout. 4. Instep23areyougoingtoPTthecontrollinestomakesurebothupperandlowersealsareholding? Yeswecanpressuretestthecontrollineupto5000psiandbleeditoffbeforewesetthetubinganchor(noted instep#24). 5. YouwillneedtoincludeawitnessedMITͲIAto1600psibeforetherigleavesandyoudisplacethewellboreto gas.Coulddothatrightafteryousetthetubinganchorandlaydownspear. NeedfurtherdiscussiontoclarifytheseissueswithAOGCC. 6. HaveyouforwardedthelatestproceduretoHilcorpyet? Hilcorphasnotyetseentheprocedure.We’llbepushingthatouttotheminthenextdayortwo. 7. Ilikedyour“HighlightsofProcedure“section.Goodideatoincludeit. Regards, ZanWalsh MechanicalEngineer zwalsh@petroak.com 907Ͳ272Ͳ1232(office) 907Ͳ677Ͳ5121(direct) 907Ͳ317Ͳ8579(cell) 5 From:Schwartz,GuyL(CED)<guy.schwartz@alaska.gov> Sent:Wednesday,August19,202010:49AM To:ZanWalsh<zwalsh@petroak.com> Cc:SteveTyler<styler@petroak.com>;Rixse,MelvinG(CED)<melvin.rixse@alaska.gov>;ChantalWalsh <cwalsh@petroak.com>;MatthewFederle<Matthew.Federle@cingsa.com>;RickGentges <Richard.Gentges@cingsa.com>;TomWalsh<twalsh@petroak.com> Subject:RE:CLUSͲ5Procedurew/SpaceOutDetails Zan, Ireviewedtheprocedureagainandhavesomecomments.Nothingmajor.Couldyourecombinethelasttwo procedurestoreflectallthechangesintoonePDFdocument.Alsoincludethetubingmovementcalcs.Ican’teasily combinealltheversionsIhave.Youdon’tneedtoincludethe10Ͳ403page. Questions: 1. WhatisthepurposeofthePNLlog? 2. Whatistheultimatedepthforthetubingsealassembly?Assumeyouarelocating8ftorsointothesealbore. (2ftfrombottom) 3. Instep20wouldn’tyoualreadyhavethespaceoutfiguredoutfromthefirstdummyrunwiththeFXE(step11) 4. Instep23areyougoingtoPTthecontrollinestomakesurebothupperandlowersealsareholding? 5. YouwillneedtoincludeawitnessedMITͲIAto1600psibeforetherigleavesandyoudisplacethewellboreto gas.Coulddothatrightafteryousetthetubinganchorandlaydownspear. 6. HaveyouforwardedthelatestproceduretoHilcorpyet? 7. Ilikedyour“HighlightsofProcedure“section.Goodideatoincludeit. GuySchwartz Sr.PetroleumEngineer AOGCC 907Ͳ301Ͳ4533cell 907Ͳ793Ͳ1226office 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:ZanWalsh<zwalsh@petroak.com> Sent:Friday,August14,202010:54AM To:Schwartz,GuyL(CED)<guy.schwartz@alaska.gov> Cc:SteveTyler<styler@petroak.com>;ChantalWalsh<cwalsh@petroak.com>;MatthewFederle <Matthew.Federle@cingsa.com>;RickGentges<Richard.Gentges@cingsa.com>;TomWalsh<twalsh@petroak.com> Subject:CLUSͲ5Procedurew/SpaceOutDetails 6 Guy, AttachedforyourreviewandapprovalistheprocedureforCINGSA’sCLUSͲ5velocitystringinstall.Thisprocedure detailsthespaceoutofthecompletionandI’veincludedthespecsforthehydraulictubinganchor. Don’thesitatetogivemeacall. Regards, ZanWalsh MechanicalEngineer zwalsh@petroak.com 907Ͳ272Ͳ1232(office) 907Ͳ677Ͳ5121(direct) 907Ͳ317Ͳ8579(cell) 1 Carlisle, Samantha J (CED) From:Richard Gentges <Richard.Gentges@cingsa.com> Sent:Tuesday, March 5, 2019 2:22 PM To:Schwartz, Guy L (DOA) Cc:Richard Gentges; John Lau; Matthew Federle Subject:Wellhead Schematic for CLUS-5 Velocity String Attachments:DM100106450_SH2 WH Schematic 3 4 19 K Hite.pdf Follow Up Flag:Follow up Flag Status:Flagged Guy, Perourphoneconversationtoday,CINGSAisplanningtoruna31/2inchvelocitystringintheCLUSͲ5storage welllaterthisyeartoaddressanongoingwaterloadingissueduringstoragewithdrawals.The31/2inchwill besetonapackerabovethecompletioninterval.We'llbemodifyingtheexistingwellheadtoaccommodate thesmallerdiameterstringinsideoftheexisting7inchtubingstring.Weplantoruna31/2inchwireline retrievablesubsurfacesafetyvalveandtheexistingsurfacesafetyvalvewillremaininthewellheadabovethe newtubingstring.AttheappropriatetimewewillofcourseincludemorespecificsinaSundryNotice.Inthe interim,attached,isaschematicoftherevisedwellheadplan.Wewouldappreciateitifyouwouldlookthis overandadviseastowhetherthisconfigurationwouldbeacceptablefromtheAOGCC'sperspective. Pleasegivemeacalloremailmewithanyquestions.Cellphoneis989Ͳ464Ͳ3849. Thanksmuch. RickGentges 1 Carlisle, Samantha J (CED) From:Zan Walsh <zwalsh@petroak.com> Sent:Sunday, August 30, 2020 7:48 PM To:Schwartz, Guy L (CED) Cc:Steve Tyler; Matthew Federle; Chantal Walsh Subject:RE: Review to Install CLU S-5 Velocity String w/ New Tubing Hanger and Tubing Head Adapter Follow Up Flag:Follow up Flag Status:Flagged Guy, IspokewiththepreviousengineerwhoworkedtheoptionofinstallinganewtubinghangeronCLUSͲ5.Theywerenot comfortableaskingthestateforavariancetotakethesurfacesafetyvalveoffofitscurrentverticalpositiononthetree andmoveittothehorizontalproductionlineduetosafetyconcerns.TheydiddiscussitwithCINGSAandCINGSA managementdecidedtheydidnotwanttocompromisetheirsafetystandardsanddidnotwanttofurtherpursue movingthesurfacesafetyvalve. Regards, ZanWalsh MechanicalEngineer zwalsh@petroak.com 907Ͳ272Ͳ1232(office) 907Ͳ677Ͳ5121(direct) 907Ͳ317Ͳ8579(cell) From:Schwartz,GuyL(CED)<guy.schwartz@alaska.gov> Sent:Friday,August28,202011:55AM To:ZanWalsh<zwalsh@petroak.com> Cc:SteveTyler<styler@petroak.com>;MatthewFederle<Matthew.Federle@cingsa.com>;ChantalWalsh <cwalsh@petroak.com> Subject:RE:ReviewtoInstallCLUSͲ5VelocityStringw/NewTubingHangerandTubingHeadAdapter Zan, Thanksfortheinformationbelow…Icanseewhatyoumean.ButCINGSAshouldalsobeawarethattheycanaddthe 3.5”tubingspoolabovethecurrent7”hangerandbymovingtheSurfaceSafetyValve(SSV)tothewingsidethe wellhead/flowlinewouldonlybeabout3”higherthanitisnow(wasthisconsideredinthe2017analysis?).Thiswould 2 requiresomemodificationtotheSͲRiserbutitisagood(preferred)option.(AOGCCwouldgrantavariancetomoveSSV tohorizontalrun…thedownsideishavingonemanualmastervalvebelowtheflowcross). Ithinkyourcurrentplanistechnicallyfeasiblebutitdoeshavesometrickyspaceoutissuesandputsholesinperfectly goodpipe(whichcouldcompromisethe95/8”productioncasing).TheAOGCC’smissionistoensurethegreatest possiblewellintegrityandsafetyofthewellboresystem.Byaddingavelocitystringthiswellisautomaticallyvery differentfromtheother4wells….whetherornotyouchangeanythingonthesurfaceportionofthewellhead.Andof coursethesewellsaresomeofthehighestprofileinthestateduetotheirlocation. Regards, GuySchwartz Sr.PetroleumEngineer AOGCC 907Ͳ301Ͳ4533cell 907Ͳ793Ͳ1226office 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:ZanWalsh<zwalsh@petroak.com> Sent:Thursday,August27,202012:50PM To:Schwartz,GuyL(CED)<guy.schwartz@alaska.gov> Cc:SteveTyler<styler@petroak.com>;MatthewFederle<Matthew.Federle@cingsa.com>;ChantalWalsh <cwalsh@petroak.com> Subject:ReviewtoInstallCLUSͲ5VelocityStringw/NewTubingHangerandTubingHeadAdapter Guy, In2017,onbehalfofCINGSA,PRAreviewedtheequipment,logisticsandcostofinstallinga3½”velocitystringtoCLUSͲ 5.Belowisasummaryofthereview. WorkovertoInstalla3½”VelocityStringinCLUSͲ5 Scope: AfterdiscussionswithFMC,BakerandSchlumbergerthereisanoptionforinstallingthe3½”velocitystring.Giventhe requirementforasubsurfacesafetyvalve(SSSV)hangingoff,avelocitystringintheexistingtubingisnotanoption. 1. Leavethe7”tubinginplace,installanothertubingheadtoallowfortherunningofthe3½”tubingvelocity string.ThiswouldrequireanFMCcustompackofftosealaroundthetopoftheexisting7”tubinghangerthat wouldfitintothebottomofthenewtubinghead,runningthe3½”tubing,installationofanewtubinghanger andtubingheadadapter.Theexisting7”treewouldbereinstalled. 2. Pullthe7”tubingandrun3½”tubing,reinstalltheexisting7”hanger(XOto3½”),adapterand7”tree. Note:Leavingthe7”inplacewouldincreasethewellheadheightapproximately3.5feetrequiringmodificationtothe surfacelines. 3 Note:EstimatednumberofdaysusingRigforworkoveris10. EstimatednumberofdaysusingPullingUnitis6. Thecurrent2020plantohangthetubingfromtheSVLNAdapterXOat167’MDisestimatedtotake3dayswith theRig. Note:Allfive(5)ofCINGSA’sgasstoragewellshaveidenticalsurfaceequipment.Thisenablesallprocessesforsurface workonthewellstobeconsistent.Achangeofsurfacelinestoaccommodateanelevationchangeinawellheadwill meanuniquecheckoffsfortheCLUSͲ5Well.TheconsistencyofthewellsatCINGSA’sstoragepadisasafer environmentfortheoperationalcrewsandoverallfacility. Regards, ZanWalsh MechanicalEngineer zwalsh@petroak.com 907Ͳ272Ͳ1232(office) 907Ͳ677Ͳ5121(direct) 907Ͳ317Ͳ8579(cell) MEMORANDUM To: Jim Regg � ,Jr/71 17 P.[. Supervisor / W' lf'qf l FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, April 24, 2020 SUBJECT: Mechanical Integrity Tests Cook INet Natural Gas Storage Alaska, LLC S-5 CANNERY LOOP UNIT S-5 Src: Inspector Reviewed B P.I. Supry J Comm Well Name CANNERY LOOP UM'F 5-5 API Well Number 50-133-20601-00-00 Inspector Name: Brian Bixby Permit Number: 211-15M Inspection Date: 4/21/2020 IBSp Num: mitBDB200423112749 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Wells -5 Type Inj G TVD 4867 Tubing 1134 1134 1135' 1135 ' PTD 2111580 Type Test SPT Test psi 1500 IA 92 2096 2037 2084 " BBL Pumped: 25 BBL Returned: 2.5 OA o o o o ' Interval 4YRTST P/F P Vr Notes: Friday, April 24, 2020 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,April 13,2016 Jim Regg � P.I.Supervisor ' ` 1 4(zo /(, SUBJECT: Mechanical Integrity Tests COOK INLET NATURAL GAS STORAGE A S-5 FROM: Brian Bixby CANNERY LOOP UNIT S-5 Petroleum Inspector Src: Inspector Reviewed B P.I.Supry J NON-CONFIDENTIAL Comm Well Name CANNERY LOOP UNIT S-5 API Well Number 50-133-20601-00-00 Inspector Name: Brian Bixby Permit Number: 211-158-0 Inspection Date: 4/5/2016 Insp Num: mitBDB160406111724 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well s s Type Injj G'TVD 4867 PTDTubing Isco 1541 • Isal Isal , - -- 2111580 — Type Test SPT Test psi; 1500 IA 100 2100 2100- 2100 - Interval 4YRTST Pte, P ✓ OA o 0 0 _ o Notes: SCANNED SEF 2 7 2016 Wednesday,April 13,2016 Page 1 of 1 . • � OF TFJ . �w\����yj,_6 THE STATE Alaska Oil and Gas '! Ti—s ofA AS� Conservation Commission - i.t ___, __ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279 1433 Off"ALASY'� Fax: 907.276 7542 www.aogcc.alaska.gov SCANNED lei U12 I 9 it)1 Jared Green President ca I 1 — I Cook Inlet Natural Gas Storage Alaska, LLC P.O. Box 190989 Anchorage, AK 99519 Re: Cannery Loop Field, Sterling C Pool, CLU Storage 5 Sundry Number: 315-437 Dear Mr. Green: 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, Csi.. .7 Cathy P. Foerster Chair DATED this 2 i day of July, 2015 Encl. RECEIVED ' STATE OF ALASKA JUL 2 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION 07s rj'FIs APPLICATION FOR SUNDRY APPROVALS AOGCC 2QAAC 25.280 1 Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ ) Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate [ Alter Casing ❑ Change Approved Program ❑ Plug for Redrdl❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ CT-FCO 0 • 2.Operator Name: 4 Current Well Class: 5.Permit to Drill Number Cook Inlet Natural Gas Storage Alaska,LLC Exploratory ❑ Development ❑ 211-158 ' 3 Address: Stratigraphic 6.API Number: ❑ Service 0 P.O.Box 190989,Anchorage,AK 99519 50-133-20601-0000 • 7 If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CLU Will planned perforations require a spacing exception? Yes ❑ No 0 Storage 5 ' 9 Property Designation(Lease Number)• 10. Field/Pool(s). ADL 391627 Cannery Loop/Sterling C 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). 11,101' . 5,127' • 11,059' - 5,125' • none none Casing Length Size MD TVD Burst Collapse Structural Conductor 117.5 20" 117.5 117.5 n/a n/a Surface 2,390 13 3/8" 2,390 2,013 3,450 1,950 Intermediate 8,860 9 5/8" 8,860 4,916 5,750 3,090 Production Liner 2,415 7" 11,099 5,127 7,240 5,410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size. Tubing Grade. Tubing MD(ft): see attached comp.sche. see attached comp sche 7"26# L80 8,684 Packers and SSSV Type: BHI 9 5/8"HR ZXPN Liner Top Packer Packers and SSSV MD(ft)and ND(ft)• Pkr-8684'/4867' SSSV-167'/167' Halliburton 7"WL FXE SSSV 12 Attachments: Description Summary of Proposal El 13.Well Class after proposed work. Detailed Operations Program 0 BOP Sketch 0 'Exploratory ❑ Stratigraphic❑ Development❑ Service 0 14.Estimated Date for . 7/15/2015'15.Well Status after proposed work. Commencing Operations. OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John Lau Email John.lau(a�enstarnaturalgas.com Printed Name Jared Green Title President Signature Phone 907-334-7736 Date ,k. -7// 7/45 COMMISSION USE ONLY Conditions of app oval. Notify Commission so that a representative may witness Sundry Number. C / 315 - '137 Plug Integrity ❑ BOP Test (1d Mechanical Integrity Test ❑ Location Clearance ❑ Other. k LIS L, fJ s,- ik I re-S (-- '" (/ t/-3 P = / D0 r3— 1 Spacing Exception Required? Yes ❑ No Ll Subsequent Form Required: 10 -1---/C., 1 APPROVED BY Approved by: ai4(. - ,4„....2 COMMISSIONER THE COMMISSION Date:7-1 _/5 it_ 7 23-I' RBDMS AUG - 2 2015 /� t Giik Sub it Form and Form 10-403 Revised 5/2015 Approved applicatio rs f r f e date of approval. Attachments in Duplicate Cook Inlef NaluralGas Inlet Natural Gas Storage Alaska,LLC • PO Box 190989 STO RAQAnchorage,AK 99519-0989 ;; Main:907-334-7980 � 4M ,� Fax:907-334-7671 www.cingsa.corn July 17, 2012 RECEIVED JUL 2 0 2015 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 AOGCC Re: CLU S-5 Application for Sundry Approvals Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) is requesting Sundry Approval to clean out solids/fill material from CLU S-5. CINGSA proposes to rig up a 1 3/4-inch coil tubing unit and well test equipment on location in mid-June. The proposed operations are described in the attached outline of well procedures but will generally consist of running coil in hole to bottom and then washing down with foam and nitrogen. The well will be flowed ' back via a choke manifold to a separator. Fluids will be recovered in a frac tank and gas will be either flared or vented through a flare stack. The well flow is not expected to last more than 1 houLafter the foa solution is off the perforations. '26 44,-„, 356/)C_Y) If you have any questions or require additional information,please contact John Lau at 907 334-7736 or email to john.lau@enstarnaturalgas.com I/3./s- Sincerely, s.../Zy% red Green President Enclosure as stated Cc: J. Lau M. Smith R. Gentges CLU Storage 5 Outline Well Clean Procedures GENERAL SAFETY GUIDELINES A pre job safety meeting will be held with all affected personnel before every phase and for any change of program. Topics should include the following points: • H2S risks, spill prevention, and well control issues • Personnel assignments • Contingencies It should be stressed that while testing the BOP,only essential personnel should be around/near the tree. Normally"essential personnel" will consist of the coil crew and a roustabout for crane signals. All other personnel will stay clear of the tree area. Wellhead shut-in pressure on the CLU S-5 at the time of treating is expected to be approximately 1350-1400 psig. Coiled tubing treating pressure is not expected to exceed approximately 1800 psig. - RIG UP AND PRESSURE TEST 1. Notify AOGCC of upcoming rig up and BOP test 48 hours prior. Confirm SSSV protection sleeve is in place. 2. Mobilize and rig up 13/4"coil tubing and well testing equipment to CINGSA Drill Pad. 3. Position Blind/Shear Rams in upper Combi BOP body and- 311•_pipe rams in lower body. Pre-test BOP, all lines and valves to 250 psi/4500 psi. Install fusible cap on SSV. 4. Call for AOGCC Inspector. Pressure test BOP, all lines and valves to 250 psi/4500 psi. Ensure form 10-424 is sent in to AOGCC within 24 hours of Pressure Test. WELL CLEAN UP 5. Pick up circulating wash nozzle and injector head with crane. Lower injector head and make up lubricator connection. 6. Run in hole to 11,059'MD/5125'TVD or fill TD. When wash nozzle stacks weight begin washing down with 3% KCI/foam system until reaching TD. Displace wash fluid and any solids/fill with nitrogen and take returns through choke manifold to separator. The choke manifold, separator skid, and flare equipment set up will be similar to the Weatherford schematic below. 7. Monitor returns for methane. Strap tanks for return volume. Continue pumping N2 until well is clean of foam and flowing gas on its own. Shut off N2. 8. Flow well clean for up to one hour or until fluid is off perforations while POH with coil. Record pressures and rates. 9. Once coil is clear of tree, close upper and lower master and. Bleed pressure off through choke manifold until no flow. Close swab valve. 10. Nipple down coil. Nipple down test equipment. Send fluids to Emerald Anchorage for disposal. 11. Release coil unit. • •'• COIL TiBINr G Coiled Tubing Services ctrr. c Ileg3A • ..1' SERVICES Pre::_ureCategory 1 BOPCorfigurstion 1f°l CIU-5SI:4 Mels° 1Uto .,CIJpsi) Dar .1.-re E.,3715 A Sc`I o'nts•g?'C^.r-r a`, - Drarr�D, BrerOtr.UxteD illirilliP-. • aI`. e� I ca_m l Orator Head r.ICE"Ca p?nrotl 1 _. — i +! -A I 401•'it/.uen.ent.lona Bt'1pon- I . z ma f qe ♦ I rrK'Raw 5 rj S 131t iC- a:62141..5"7JN Mango I o...o...,..I a`i' /1:731{ - I 108.in Galan aqP I ..1 h.. a +I2,a De( MC Auld Ratan!to Surf a*Handling$7 tam as ■. n..w .u.... : 1 l.`-r....: I.: ,r ."w..I 401'9N Renard Mr...Tie 'w,,,•1 Oar i.21/'151C lama fat Coe Ply VINO mimic.20,11unisl Siallarvai kir Mae Ply liblue, 0 ( Male b.2oa Mimi 6Keean l IJ ave Phi lace) 4_ L., _ Mae e.-2S t9<U L PUt IICO PIM ANC i -V • I 40d'10r:.vetmladsasprrRanor I sem; '9.` • I wtnrad I Revision° Not Drawn To Scale--- For Reference Oats. Well Clean Rig Up ,-en .... • I '•..' !ansi I LW *MO TOW 0,1101“••••••• ..*..... . 41...9 •aeww.an a i iI�IR � __�_.. . ..�... ...tS ' g; jr lem l * or'vim moor.or •mat aralal.aaP�+ e:T y �",;- _t AMY FMB MI ew w.nP.an•wa 1�.n the'rj,-)r'�� t .c•w...o. 1140111/041 TAMS , 3C as.r -- vM. w____MST MON 'u..'°'a•4O .� 1 .r.x..-s.�gl_.:= n...... ....a...�... Y•.^ } Ilaalrleaee MIMI..i .,/[i'11r�uw n0� i S etlArrrt. E ��...—. — Iwr '� ' +i •p•.i ..,..—! t .w.r� —..arww ie.�r."" �..•+� N.T.S - aw-.n -.w 1117.4111‘ 'l0 CINGSA CLU Storage 5 Re-completion Schematic FMC Wellhead- 13 5/8" 5000#Multibowl 7/21/2012 FMC Tree-7" 5000#complete with SSV I F4 "' `� 20" 133# X56 driven to 117.5'TVD/117.5' MD <' 7" Halliburton Wireline Retrievable SSSV 0:/1 167'TVD/I67'MD so � 1f ! 3 3i8"68#155 BTC Surface Casing(a;2.013''IND/2.390'MD '' 16"hole/Cemented to Surface r $ DV Collar @ 3,510' q }" ' 7"x 9 5/8" Baker ZXP Liner Top Packer ) with 10'seal bore(a 4,867'TVD, 8,684'MD 9 5/8"40#L80 BTC Intermediate Casing @ 4,916'TVD/8,860'MD xt 12 1/4" hole/Cemented to Surface w Original Perforations 2-18-2012 1 7" 260 L80 t,"" MD Perforation TVD Perforation Vam Top Tubing (,,"" From To Footage From To Footage 10,880 10,580 300 5,119 5,109 10 10,380 9,770 610 5,100 5,061 39 > 9,470 9,420 50 5,023 5,015 8 4'°, 9,390 9,210 180 5,010 4,979 31 1 9,130 9,060 70 4,966 4,954 12 M Total Footage 1210 Total Footage 100 7" RN Nipple, - 8,707' 1~ r New Perforations 7/21/12 5.88" ID, 7.60"OD ', cl.t. 1 MD Perforation TVD Perforation r-t From To Footage From To Footage ,..= 10,750 10,630 120 5,114 5,110 4 1 10,220 10,070 150 5,092 5,084 8 10,060 10,000 60 5,083 5,080 3 ` 9,990 9,780 210 5,079 5,062 17 9,390 9,330 60 5,010 5,000 10 t •= 9,320 9,230 90 4,998 4,983 15 a" 9120 9060 60 4,964 4,954 10 lw ! 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R y d = a w a O en M c C o G O O N n U � 4 J < M H N 1— Z N 5 = O G a0 N Ca 0 J ce N I Cn z f0 Q z 0 LL U 0 1 I— N c a 0 E U R Z d _• N .4''' Lo I ago COT r d N d a' 6 O V ✓ C_ R E Ti. ` a 0 E 2 o Vaal BAKER PRINT DISTRIBUTION LIST HUGHES COMPANY CINGSA INTERMEDIATE FINAL Yes (mandatory) WELL NAME CLU Storage#3 RUN NUMBER LWD (mandatory) FIELD Cannery Loop Unit BH SALESMAN Woods,Jim (mandatory) (mandatory) COUNTY Kenai Peninsula BH DISTRICT Alaska ff (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: 9/16/2011 TODAYS DATE: 11/18/2&1i (mandatory) dl� DISTRIBUTION LIST AUTHORIZED BY: CINGSA (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? Yes COMPANY FIELD FINAL CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) FILM PERSON ATTENTION #OF PRINTS #01- I'1-<IN I s #OF COPIES #OF COPIES v v v n 1 I PRA 4 4 Attn: Tom Walsh, Rick Gentges,Rig 3601 C Street,Ste 822 Anchorage,AK 99503 2 AOGCC I 1 1 Attn: Christian Mahnken 333 West 7th Ave. Anchorage,AK 3 DNR I 1 1 Attn:William C. Barron -Director Dept. of Natural Resources-Div. of Oil and Gas 550 West 7th Ave. Anchorage,AK 4 1 I 1 TOTALS FOR THIS PAGE: 0 6 6 0 0 0 TOTALS FOR ALL PAGES: 0 6 6 0 0 0 Cook Inlet Natural: Gas 30uu Spenard Road STU�� - PBox 1e 4. ;�..::., Anchorage, AK AK 99519-0989 July 30, 2012 RECEIVED Alaska Oil &Gas Conservation Commission JUL 3 0 2012 333 W 7th Avenue, Suite 100 A®�^^ Anchorage,AK 99501 CC Re: Cook Inlet Natural Gas Storage Alaska, LLC(CINGSA) Report of Sundry Well Operations—Form 10-404 CLU Storage 5 (Permit No. 211158) Attached,please find Report of Sundry Well Operations Form 10-404 for CINGSA's CLU Storage 5, and associated Daily Report of Well Operations,well schematic,and perforation log. This well has been returned to injection service. If you have any questions concerning the foregoing, please contact Rick Gentges at 907-310- 7322. Sincerely, ./K. (L' • eta M. Colleen Starring Vice President Enclosure as stated • STATE OF ALASKA ALA._ ,OIL AND GAS CONSERVATION COMM. ION REPORT OF SUNDRY WELL OPERATIONS GTS 1.Operations Abandon U Repair Well ❑ Plug Perforations U Perforate Other U Clean out fill Performed: Alter Casing 11 Pull Tubing❑ Stimulate-Frac El Waiver ❑ Time Extension 0 Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well El 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number:211158 Name: Cook Inlet Natural Gas Storage Alaska,LLC Development ❑ Exploratory ❑ 3.Address: Stratigraphic❑ Service Q 6.API Number: P.O.Box 190989,Anchorage,AK 99519 50-133-20601-0000 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 391627 CLU Storage 5 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Perforation Record Cannery Loop/Sterling Gas Storage Pool 11.Present Well Condition Summary: Total Depth measured 11,101 feet Plugs measured none feet true vertical 5,127 feet Junk measured none feet Effective Depth measured 11,059 feet Packer measured 8,648 feet true vertical 5,125 feet true vertical 4,867 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 117.5' 20" 117.5' 117.5' n/a n/a Surface 2,390' 13 3/8" 2,390' 2,013' 3,450 1,950 Intermediate 8,860' 9 5/8" 8,860' 4,916' 5,750 3,090 Production Liner 2,415' 7" 11,099' 5,127' 7,240 5,410 Perforation depth Measured depth see attach. feet True Vertical depth see attach. feet Tubing(size,grade,measured and true vertical depth) 7"26# L80 8,684' 4,867' Packers and SSSV(type,measured and true vertical depth) BHI 9 5/8"ZXPN Halliburton 7"FXE SSSV Pkr-8,684'/4,867' SSSV-167'/167' 12.Stimulation or cement squeeze summary: Cleaned out fill material using 6%KCL,Clay Guard,and 70 quality foam treatment. Intervals treated(measured): 9,230'-10,750'MD Treatment descriptions including volumes used and final pressure: Ran in hole with mill/motor and wash to 10,750'with 70 quality foam. Total treatment vol.was 187.4 Bbls. Recovered 187 Bbls. Final circulating pressure was 2660 psi. Re-perforated per attached schematic. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 10,200 600 725 Subsequent to operation: 15,600 550 800 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Perforation Record Exploratory0 Development❑ Service ❑✓ Stratigraphic ❑ Daily Report of Well Operations 16.Well Status after work: Oil ❑ Gas E WDSPL 0 6/16/2012 -6/18/2012 and 7/13/2012 -7/23/2012 GSTOR ❑✓ WINJ ❑ WAG 0 GINJ El SUSP❑ SPLUG E 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: p 312/94 and 312241 Contact *X C .-c fs a\G r 1 Printed Name M , WNWI V l(� Title \) 1 C 5\�'!�t' ..,u. e• Signature Phone 2)3L\,1 VS-ID Date ) ' RSDMS AUG 012012] /y-ft 1L Form 10-404 Revised 11/20110y / Submit Original Only Date Daily Operations Summary CLU Storage 5 6/15/2012 RU Pollard and pull SSSV and set sleeve. 6/16/2012 j Rig up BJ Services coil and perform BOP test. Test witnessed by Matt Herrera. 6/17/2012 ✓ RIH and clean out fines to TD of 11056 with 70Q foam.Total fluid used 187 Bbls; recovered 187 Bbls. 6/18/2012 RU Pollard and RIH with SSSV; purge control line and set valve. Test valve for hydraulic leaks; ok. RD Pollard. 7/13/2012 RU Schlumberger E Line. RIH with 30', 2 7/8"gun,4 spf on tractor. Tractor to 10,800'. Pull up and re-perforate 10,750'-10,720'. POOH and SD for day. 7/14/2012 RIH with Guns#2,#3, and#4 on tractor, and re-perforate with 30' , 2 7/8"guns,4 spf, from 10,720'-10,690', 10.690'-10,660', and 10,660'-10,630'. POOH SD for day. 7/15/2012 RIH with Guns#5,#6, and#7 on tractor and re-perforate from 10,220'-10,190', 10,190'- 10,160', and 10,160'-10,130'. POOH and SD for day. 7/16/2012 RIH with Guns#8,#9, and#10 on tractor and re-perforate from 10,130'-10,100', 10,100'-10,070', and 10,060'-10,030'. POOH and SD for day. 7/17/2012 RIH with Guns#11,#12, and#13 on tractor and re-perforate from 10,030'-10,000', 9,990'-9,960',and 9,960'-9,930'. POOH and SD for day. 7/18/2012 RIH with Guns#14,#15,#16, and #17 on tractor and re-perforate from 9,930'-9,900', 9,900'-9,870',9,870'-9,840', and 9,840-9,810'. POOH and SD for day. 7/19/2012 RIH with Guns#18,#19, and #20 on tractor and re-perforate from 9,810'-9,780',9,390'- 9,360', and 9,360'-9,330'. Gun#20 had faulty detonator and failed to fire; POOH with live guns and SD for day. 7/20/2012 RIH with Guns#20,#21, and #22 on tractor and re-perforate from 9,360'-9,330',9,320'- 9,290', and 9,290'-9,260'. POOH and SD for day. 7/21/2012 ✓ RIH with Gun#23 on tractor to re-perforate from 9,260'-9,230'; gun failed to fire. POOH with live gun and replace firing head. RIH with Guns#23,#24, and #25 on tractor and re-perforate from 9,260'-9,230', 9,120'-9,090', and 9,090'-9,060'. POOH and RD Schlumberger. 7/22/2012 SD for day. 7/23/2012 RU Weatherford and flow back well to remove perf debris. Flowed well on 32/64 choke for 70 minutes. Incr. choke to 44/64 and then 52/64 for additional 80 minutes. SI well for build up. Total flow during clean up was 909 Mcf. 7/24/2012 RU Pollard and pull protective sleeve. COOH. RIH with SSSV and purge control line. Set SSSV and pressure up valve. Monitor for leakage. Pressure holding good. RD Pollard and move off location. 1 CINGSA CLU Storage 5 Re-completion Schematic FMC Wellhead- 13 5/8" 500011 Multibowl 7/21/2012 FMC Tree-7" 5000#complete with SSV c e. 1 20" 13311 X56 driven to 117.5'TVD'117.5'MD ,, f•, ,,, 7"llalliburton Wireline Retrievable SSSV(i{? 167'TVD/167'MD to 4 ! 13 3/8"68#155 BTC Surface Casing(d),2.013'TVD/2.390'MD ,: 16"hole/Cemented to Surface t DV Collar div, 3,510' k• 7"x 9 5/8"Baker ZXP Liner Top Packer 4 with 10'seal bore 4 4,867'TVD/8,684'MD x 14, z h 1 9 5/8"40#L80 BTC Intermediate Casing @ 4,916'TVD/8,860'MD ` 12 1/4"hole I Cemented to Surface r"1 Original Perforations 2-18-2012 7"2611 L80 : i? MD Perforation TVO Perforation Vam Top Tubing From To Footage From To Footage y M e. 10,880 10,580 300 5,119 5,109 10 I" 10,380 9,770 610 5,100 • 5,061 39 t 9,470 9,420 50 5,023 5,015 8 ,ti a^'S4 9,390 9,210 180 5,010 4,979 31 1 1 9,130 9,060 70 4,966 4,954 12 1 5A Total Footage 1210 Total Footage 100 7" RN Nipple, - 8,707' j New Perforations 7121131 5.8$" ID, 7.60"UD " ah 416 MD Perforation TVD Perforation From To Footage From To Footage . 70,750 10,630 120 5,114 5,110 4 10,220 10,070 150 5,092 5,084 8 t 10,060 10,000 60 5,083 5,080 3 9,990 9,780 210 5,079 5,062 17 9,390 9,330 60 5,010 5,000 10 9,320 9,230 90 4,998 4,983 15 9120 9060 60 4,964 4,954 10 • Total Footage 750 Total Footage 67 7"26.#1.80 Vam Top Production Liner from 4.867'TVD/8,684'MD TOP to 5.127'TVD/11,099'MD TD 8 1/2"hole/Cemented Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, July 18, 2012 8:59 AM To: 'Richard Gentges' Subject: RE: Perf Interval for CLU Storage 5 (PTD 211-158) Rick, You can add the perfs .. I will amend the approved procedure. ( Please remember put the PTD on the subject line of the email. ) Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Richard Gentges [mailto:Richard.Gentges@cingsa.com] Sent: Wednesday, July 18, 2012 8:31 AM To: Schwartz, Guy L (DOA) Cc: Richard Gentges Subject: Perf Interval for CLU Storage 5 Guy, CINGSA would like to expand the re-perforation interval on CLU Storage 5 to include an additional 60' extending from 9060'-9120' MD. This interval was part of the original perforated interval so we are not shooting any zone that has not already been perforated. Geologist took a second look at the data and decided it should be included. Attached is original completion schematic. Please advise whether we may proceed or if we need to file an amended 10-403. Thanks Rick Gentges 7/18/2012 SIITE 0 [F ALMEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMI►IISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 M. Colleen Starring Vice President Cook Inlet Natural Gas Storage Alaska, LLC P.O. Box 190989 QL Anchorage, AK 99519 Re: Cannery Loop Field, Sterling C Gas Storage Pool, CLU Storage 5 Sundry Number: 312-241 Dear Ms. Starring: 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, Cathy P Foerster Chair, ommissioner Y�- DATED this day of July, 2012. Encl. , # 1"Set y STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION /Si ," APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool 0 Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations❑ 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: Cook Inlet Natural Gas Storage Alaska,LLC Development ❑ Exploratory ❑ 211-158 . 3.Address: Stratigraphic ❑ Service ❑✓ ' 6.API Number: P.O.Box 190989,Anchorage,AK 99519 50-133-20601-0000 ' 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes 0 No 0 CLU Storage 5 9.Property Designation(Lease Number): 10.Field/Pool(s): 6in-<1 .ai. ADL 391627 • Cannery Loop/Sterling C pool 11. PRESENT WELL CONDITION SUMMARY A. 11• - Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,101' • 5,127' - 11,059' 5,125' none none Casing Length Size MD TVD Burst Collapse Structural Conductor 117.5 20" 117.5 117.5 n/a n/a Surface 2,390 13 3/8" 2,390 2,013 3,450 1,950 Intermediate 8,860 9 5/8" 8,860 4,916 5,750 3,090 Production Liner 2,415 7" 11,099 5,127 7,240 5,410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: nEeei iQD(ft): see attached comp.sche. see attached comp.sche. 7"26# L80 V !8® Packers and SSSV Type: BHI 9 5/8"HR ZXPN Liner Top Packer Packers and SSSV MD(ft)and TVD(ft): JUN 2 n 201 2 Halliburton 7"WL FXE SSSV Pkr-8,684'/4,867' SSSV-167'/167' i7 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: /q O Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development CI 5e� Q 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 7/9/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: 7_s L WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: C-i GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is rue and correct to the best of my knowledge. Contact ' 1111 V\ l 3 jL.A—4---q-L,'3 Printed Name tQk, `er_S(\ -A NW 3 Ik Title vi "errSlcO, x\-1— Signature / P one Date '�Y .P/Se / . r,5oir3i Y5' , 12a 11-z / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 I . 9%(_\ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: / O —L f ,9- APPROVED BY 7 Approved by: -7 COMMISSIONER THE COMMISSION Date: / —�— /Z ABa/ANB JUL 06 2012 Q���Ln- /C �� �1 ate �/ Form 10-403 Revised 1/2010 C� / '6"/� Submi in uplicate � Cook Inlet Natural-Gas3000 Spenard Road S T"Z 'RA crci . S. POBox 1e }.. , Anchorage,, AK AK 99519-0989 June 29,2912 RECEIVE® Alaska Oil and Gas Conservation Commission JUN 2 9 2012 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 AOGCC Re: CLU Storage 5 Application for Sundry Approvals Cook Inlet Natural Gas Storage Alaska, LLC(CINGSA) is requesting Sundry Approval to re- perforate CLU Storage 5. Limited injections into the well have confirmed evidence of near- wellbore damage to the existing perforations,thus the need to re-perforate. Only a portion of ✓ the previously perforated intervals will be re-perforated; no new sections of the reservoir will be perforated. CINGSA proposes to complete the re-perforating work via an electric line unit,tractor tool,and lubricator on or about July 9, 2012. The operations as described in the attached outline well procedure will take place in two phases. A tractor tool, perforating gun and a GR/CCL correlation log will be run to TD to ensure proper depths. Perforating will take place in a balanced state and through a lubricator. The current BHP is approximately 700-750 psi. The second phase will involve flowing the well back through a separator and flare system to clean up the perforations. The well flow is not expected to last more than 1 hour after all perforation work is completed. The return gas will be measured via ultrasonic meter for relative volumes. If you have any questions or require additional information,please contact Tom Arminski at 907 334-7743 or email to tom.arminski@enstarnaturalgas.com. Sincerely, hietA„,o1/-4,ciaer M. Colleen Starring Vice President Enclosure as stated June 29,2012 Page 2 CLU Storage 5 Outline Perforating and Well Clean Procedures GENERAL SAFETY GUIDELINES A pre job safety meeting will be held with all affected personnel before every phase and for any change of program. Topics should include the following points: • Well site safety and placement of warning signs • H2S risks,spill prevention,and well control issues • Personnel assignments • Communications with crane operator • Contingencies CINGSA will establish a restricted area for arming the guns and Post Danger Explosives signs. All non-essential personnel must remain clear of the restricted area until after the gun assembly has been armed and run in the well to a depth of 200'or greater. It should be stressed that while picking up and running the perforating guns,only essential personnel should be in the vicinity of the well. Normally"essential personnel" will consist of the perforating crew, crane operator,and well site supervisor. All other personnel will stay a minimum of 200 feet from the well until the perforating string is at least 200' below ground level. Similarly,while retrieving fired guns, non-essential personnel must remain a minimum of 200 feet from the well until it has been confirmed that all shots have been fired and the spent guns laid down. Radio silence is not required with the firing systems described in this recommended practice. Flow-back from the well will not commence until all perforating operations have been completed and fired guns laid down. RIG UP AND PRESSURE TEST 1. Confirm SSSV protection sleeve is in place. 2. Mobilize electric line,tractor tool, lubricator, and perforating guns to CINGSA Drill Pad. 3. Install fusible cap on SSV. June 29,2012 Page 3 PERFORATING RUN 4. Install Wireline Valves(WLV) on Well Head with crane. 5. Hang upper Sheave on crane. Install E-line in upper sheave. Run E-line through lubricator. 6. Pressure test lubricator. 7. Op check tractor 8. Make depth correlations for re-perforating. 9. Review Well-site procedures for explosive services. SECURE detonators will be used. 10. Arm guns(Follow the safety placard for SECURE detonators) 11. Lift lubricator with crane. Lift tractor,GR/CCL,and gun into lubricator with the E-line. Position the lubricator and gun over well-head with crane and install lubricator on BOP's. 12. Test the Quick Test Sub 13. Open well-head and RIH. At 200 ft,switch from Safe to Operating mode. 14. Tag Float Collar at 11,059'MD/5,1251VD. Note: Depth of packer/tubing tail/well restrictions/well deviation. 15. Correlate CCL/GUN to Reference Log(previous GR/CCL log). Go deeper than the perforated interval and pull gun up to the perforating interval. 16. Check Grease Injector for adequate pressure to maintain seal. Fire gun. 17. Check for Well Pressure loss/gain. POOH using caution at locations with restrictions. 18. At 200'STOP, check all that all safety switches are in the OFF position before proceeding to the surface with the tool-string. 19. Note: Always assume the gun(s) is live. 20. Pull gun into well-head/WLV/Lubricator. Close master gate and swab valves. Blow down lubricator. Bleed off any pressure in the lubricator. Verify the lubricator is not fluid packed. Break the lubricator off of the WLV's. Lay down gun. Confirm all shots have fired. Lay down the lubricator. Remove the WLV's. Install the tree cap. Rig down E-line. 21. The following intervals will be re-perforated: 10,750'to 10,630' MD(120',4 runs with 30'guns) 10,220'to 10,070' MD(150', 5 runs with 30'guns) 10,060'to 10,000' MD(60', 2 runs with 30'guns) 9,990'to 9,780' MD(210',7 runs with 30'guns) 9,390'to 9,330' MD(60',2 runs with 30'guns) 9,320'to 9,230' MD(90',3 runs with 30'guns) June 29,2012 Page 4 22. Repeat steps 10-20 for subsequent perf intervals. Perforations 2 7/8" PowerJet 2906 HMX 4 SPF MD Perforation TVD Perforation From I To Footage From To Footage 10,750 10,630 120 5,114 5,110 4 10,220 10,070 150 5,092 5,084 8 10,060 10,000 60 5,083 5,080 3 9,990 9,780 210 5,079 5,062 17 ✓ 9,390 9,330 60 5,010 5,000 10 9,320 9,230 90 4,998 4,983 15 Total Footage 690 Total Footage 57 WELL FLOW/CLEAN UP 23. Flow well clean for one hour through gathering system,well pad separator, and vent • silencer. Record pressures and rates. 24. Release e-line unit and return well to injection operations. June 29, 2012 Page 5 CINGSA CLU Storage 5 FMC Wellhead- 13 5/8"SOOU#Multibowl Proposed Completion Schematic FMC Tree-7" 5000#complete with SSV Re-Pert Jul'2012 C N ` 20" 133#X56 driven to 117.5'TVD/1 17.5'MD Ii�a 7"Halliburton Wireline Retrievable SSSV(a, 167 TVD/167'MD 00 5 loP `t 13 3/8"68#J55 BTC Surface Casing @ 2,013'TVD/2,390'MD on 16"hole/Cemented to Surface 4 eq 4 DV Collar @ 3,510' 3 7"x 9 5/8"Baker ZXP Liner Top Packer "10 q with 10'seal bore @ 4,867'TVD/8,684'MD it II is 9 5/8"40#L80 BTC Intermediate Casing (a@ 4,916'TVD/8,860'MD 12 1/4"hole/Cemented to Surface New Perfs-2 7/8" PwerJet 4 spf 7"26#L80 , MD Perforation TVD Perforation Vam Top Tubing From To Footage From To Footage , , 5,114 5,110 4 1010,220750 1010,070630 150120 5,092 5,084 8 10,060 10,000 60 5,083 5,080 3 9,990 9,780 210 5,079 5,062 17 1i 9,390 9,330 60 5,010 5,000 10 cr 9,320 9,230 90 4,998 4,983 15 IlaiJ 7"RN Nipple, -8,707' �j 1 5.88" ID, 7.60"OD Total Footage 690 Total Footage 57 '• 4 Original Perfs MD Perforation TVD Perforation rR: From To Footage From To Footage 7*' '' . 9,C60 9,130 70 4,954 4,966 12 L 9210 9,390 180 4,979 5,010 31 9.420 9,470 50 5,015 5,023 8 • 9,770 10,380 610 5,061 5,100 39 10,580 10,880 300 5,109 5,119 10 ok. e' Total Footage 1210 Total Footage 100 7"26#L80 Vam Top Production Liner from 4,867 TVD/8,684'MD TOP to 5.127'TVD/11,099'MD TD 8 1/2"hole/Cemented June 29,2012 Page 6 CINGSA CLU Storage 5 FMC Wellhead- 13 5/8"5000#Multibowl Completion Schematic FMC Tree-7"5000#complete with SSV 02/18/2012 I0 ,,, x 20" 133#X56 driven to 117.5'TVD/117.5'MD M 1 7"Halliburton Wireline Retrievable SSSV @ 167'TVD/167'MD t-) J ,„ 13 3/8"68#J55 BTC Surface Casing L),2,013'TVD/2,390'MD +j 4 16"hole/Cemented to Surfacc a1 r. art 1 DV Collar @ 3,510' 7"26#L80 ',Co ,E 7"x 9 5/8"Baker ZXP Liner Top Packer + with 10 seal bore @ 4,867'TVD/8,684'MD Vam Top Tubing w +16 • 9 5/8"40#L80 BTC Intermediate Casing :' g 4,916'TVD 1 8,860'MD 7"RN Nipple, -8,707' 12 1/4"hole/Cemented to Surface 5.88" [D, 7.60"OD ." / I4 MD Perforation TVD Perforation 711 ., From To Footage From To Footage �` 9,060 9,130 70 4,954 4,966 12 �" 9,210 9,390 180 4,979 5,010 31 ti J1 9,423 9,470 50 5,015 5,023 8 • • 9,770 10,380 610 5,061 5,100 39 • 0 10,580 10,880 300 5,109 5,119 10 • • Total Footage 1210 Total Footage 100 1 7"26#L80 Vam Top Production Liner from 4,867'TVD/8,684'MD TOP to 5,127'TVD/11,099'MD TD 8 1/2"hole/Cemented Page 1of1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, July 05, 2012 12:12 PM To: 'Richard Gentges' Cc: John Nicholson (john419halibut@gmail.com) Subject: RE: Sundry Notices for CLU S-2 and CLU S-5 ( PTD 211-135 &211-158) Rick, You have verbal approval to re-perforate CLU S-2 and CLU S-5 as outlined in your sundry applications. We should have them signed in a day or so. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Richard Gentges [mailto:Richard.Gentges@cingsa.com] Sent: Thursday, July 05, 2012 8:43 AM To: Schwartz, Guy L (DOA); Regg, James B (DOA) Cc: John Nicholson (john419halibut@gmail.com) Subject: Sundry Notices for CLU S-2 and CLU S-5 Jim and Guy, Any possibility that CINGSA can get a verbal approval on re-perforating these two wells? We finished up the re-perforating work on CLU S-3 and S-4 a little ahead of plan and I've got the service companies on stand-by? I can be reached on my cell phone if you have any questions (907-310-7322). Thanks Rick Gentges 7/5/2012 (7- r ALASEA 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 M. Colleen Starring Vice President Cook Inlet Natural Gas Storage Alaska, LLC P.O. Box 190989 P`V Anchorage, AK 99519 Re: Cannery Loop Field, Sterling C Gas Storage Pool, CLU Storage 5 Sundry Number: 312-194 Dear Ms. Starring: 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. S'. . -rely 1 ,1 Jo . Norman Sday 'ss': er DATED this J day of June, 2012. Encl. RECEIVED • STATE OF ALASKA MAY 2 4 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS A 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool 9 Repair Well 9 Change Approved Program 9 Suspend 9 Plug Perforations 9 Perforate❑ Pull Tubing❑ Time Extension 9 Operations Shutdown❑ Re-enter Susp.Well 9 Stimulate❑' Alter Casing❑ Other: C r—FG 0 Mr 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Cook Inlet Natural Gas Alaska,LLC Development 9 Exploratory 9 211-158 • 3.Address: Stratigraphic 9 service Q 6.API Number: P.O.Box 190989,Anchorage,AK 99519 50-133-20601-0000 - 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: • Spacing Exception Required? Yes ❑ No E CLU Storage 5 9.Property Designation(Lease Number): 10.Field/Pool(s): <.45" °YYil ,' ?E' / ADL 391627 Cannery Loop/Sterling C.jaeOr. s.3c),n- 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): 11,101' 5,127' 11,059' 5,125' none none Casing Length Size MD TVD Burst Collapse Structural Conductor 117.5 20" 117.5 117.5 n/a n/a Surface 2,390 13 3/8" 2,390 2,013 3,450 1,950 Intermediate 8,860 9 5/8" 8,860 4,916 5,750 3,090 Production Liner 2,415 7" 11,099 5,127 7,240 5,410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): see attached comp.sche. see attached comp.sche. 7"26# L80 8,684 Packers and SSSV Type: BHI 9 5/8"HR ZXPN Liner Top Packer Packers and SSSV MD(ft)and TVD(ft): Halliburton 7"WL FXE SSSV Pkr-8,684'/4,867' SSSV-167'/167' 12.Attachments: Description Summary of Proposal 2 13.Well Class after proposed work: Detailed Operations Program 9 BOP Sketch 9 Exploratory ❑ Development 9 Service 2 14.Estimated Date for 15.Well Status after proposed work: 11-Jun-12 Commencing Operations: Oil 9 Gas 9 WDSPL 9 Suspended 9 16.Verbal Approval: Date: WINJ 9 GINJ 9 WAG 9 Abandoned 9 Commission Representative: GSTOR 9 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. i� Contacta' 1 G i/h Ci-� ;f C,/S 1(0-�-37: . Printed Name 4 C t1,c() C,JlJ� I✓ Title V(�. i'v' c I V`nVj-} Y�LJ�(.I�L[t I? °` Signature Iii � "' — 4 , PI.tone Date ,...f:f COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ?' 2_,[q(4 Plug Integrity 9 BOP Test X Mechanical Integrity TestJ9 Location Clearance 9 Other: 45'00 I-on S;y 13 0 P 175+ No t�i Fy i i spe- • Kgs. ,�-,cl r cal,-d Subsequent Form Required: l/5 , /7 / /(J V / APPROVED BY Approved by: / CO ER THE COMMISSION Date: I'''Sir;*/ DMSjuNo820* ii��� � iNe .w orm 10 403 Revised 1/2010 0 R 1 6 1 N A ��/� ���in 1. fit) • Cook Inlet Nutural:GusCook Inlet Natural Gas Storage Alaska,LLC 3000 Spenard Road PO Box 190989 STORAQJ Mainor07- 4-99519-0989 Main:907-334-7980 Qj,Qp Fax:907-334-7671 www.cingsa.com May 24, 2012 RECEIVED Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 MAY 2 4 2012 Anchorage,AK 99501 AOGCC Re: CLU S-5 Application for Sundry Approvals Cook Inlet Natural Gas Storage Alaska,LLC(CINGSA) is requesting Sundry Approval to clean out solids/fill material from CLU S-5. CINGSA proposes to rig up a 1 3/4-inch coil tubing unit and well test equipment on location in mid-June. The proposed operations are described in the attached outline of well procedures but will generally consist of running coil in hole to bottom and then washing down with foam and nitrogen.The well will be flowed back via a choke manifold to a separator. Fluids will be recovered in a frac tank and gas will be either flared or vented through a flare stack. The well flow is not expected to last more than 1 hour after the foam solution is off the perforations. If you have any questions or require additional information,please contact Rick Gentges at 907-310-7322 or email to Richard.gentges@cingsa.com. Sincerely, )71. 4-41,Lc.et M. Colleen Starring Vice President Enclosure as stated CLU Storage 5 Outline Well Clean Procedures GENERAL SAFETY GUIDELINES A pre job safety meeting will be held with all affected personnel before every phase and for any change of program. Topics should include the following points: • H2S risks,spill prevention,and well control issues • Personnel assignments • Contingencies It should be stressed that while testing the BOP, only essential personnel should be around/near the tree. Normally"essential personnel" will consist of the coil crew and a roustabout for crane signals. All other personnel will stay clear of the tree area. PRESSURE UP AND TEST 1. Notify AOGCC of upcoming rig up and BOP test 48 hours prior. Confirm SSSV protection sleeve is in place. 2. Mobilize and rig up 1%"coil tubing and well testing equipment to CINGSA Drill Pad. 3. Position Blind/Shear Rams in upper Combi BOP body and 1%"pipe rams in lower body. Pre-test BOP, all lines and valves to 250 psi/4500 psi. Install fusible cap on SSV. 4. Call for AOGCC Inspector. Pressure test BOP, all lines and valves to 250 psi/4500 psi. Ensure form 10-424 is sent in to AOGCC within 24 hours of Pressure Test. WELL CLEAN UP 5. Pick up circulating wash nozzle and injector head with crane. Lower injector head and make up lubricator connection. 6. Run in hole to 11,059'MD/51251VD or fill TD. When wash nozzle stacks weight begin washing down with 3% KCI/foam system until reaching TD. Displace wash fluid and any solids/fill with nitrogen and take returns through choke manifold to separator. 7. Monitor returns for methane. Strap tanks for return volume. Continue pumping N2 until well is clean of foam and flowing gas on its own. Shut off N2. 8. Flow well clean for up to one hour or until fluid is off perforations while POH with coil. Record pressures and rates. 9. Once coil is clear of tree, close upper and lower master and. Bleed pressure off through choke manifold until no flow. Close swab valve. 10. Nipple down coil. Nipple down test equipment. Send fluids to Emerald Anchorage for disposal. 11. Release coil unit. • • • • • ."` CINGSA PROJECT Ver COILED TUBING STACK UP • Kenai, AK WI. Fl.'.7...14,1 a Injector lk-ad 4 CM .n-aendnnal Shipper i 10-15 ft of I.00"lubricator 1 1 t I"' ••. 7.06'Cmbt SOP .i.:__, o • .._---- 1375-CT String • LOW SK Flow cans odoutkt •4+,W 7.06'5K Well Tree ..... __,.....„me Well Clean Rig Up ..11111 Ft • _r. %- - >�•®. e.,U.' -SON 'i:M_- ........,.....u.. il ..gym— wb w `' r rri n 1' - ! t r i. r min immir min Me 'Fr 11 -= r — -9--_= ntrzWI- woT_w IW PLASM n.o..s,.e�r �► .so .LL owns.� ^- PeF- - STACK nwtr=T • " ^+. =.-. _o�— wwwrt�ty u�--,-- Weatherford -www — t. -+w�w�srrwor .......... K •„ .o.. ... _ ^• wiMMIK1Y `uri ar..�,.AMY If.WV r.r... ..L.".�•' �� .. t. t ...—..—.w...ww.r. ...` N.T.S — i uss-•rr-wc-.»I 1 st 1 0 • • • CINGSA CLU Storage 5 FMC Wellhead- 13 5/8"5000#Multibowl Completion Schematic FMC Tree-7"5000#complete with SSV 02/18/2012 r i, 20" 1330 X56 driven to 117.5'TVD/I 17.5'MD 7"Halliburton Wireline Retrievable SSSV @ 167'TVD/167'MD M- iI k ti• 4, -\ ,4 13 318"68#J55 BTC.Surface Casing(a 2,013'TVD/2,390'MD w 16"hole/Cemented to Surface i ars ���DV Collar(cu 3,510' 1 y' s 7" x 9 5/8"Baker ZXP Liner Top Packer 7"260 L80 with 10'seal bore L 4,867'TVD/8,684'MD Vam Top Tubing 9 5/8"400 L80 BTC Intermediate Casing a%4,916'TVD/8,860'MD 7"RN Nipple, - 8,707' 12 1/4" hole/Cemented to Surface 5.88" [D, 7.60"OD MD Perforation TVD Perforation From To Footage From To Footage - 9,060 9,130 70 4,954 4,966 12 [ 1 9210 9,390 180 4,979 5,010 31 , 9,420 9,470 50 5,015 5,023 8 o • us 9,770 10,380 610 5,061 5,100 39 ■ • 4 10,580 10,880 300 5,109 5,119 10 Ili f • Total Footage 1210 Total Footage 100 1 1 7"26#L80 Vam Top Production Liner from 4,867'TVD/8,684'MD TOP to 5,127'TVD/11,099'MD TI) 8 1/2"hole/Cemented Ferguson, Victoria L (DOA) From: Richard Gentges [Richard.Gentges@cingsa.com] Sent: Monday, June 04, 2012 12:55 PM To: Ferguson, Victoria L(DOA) Cc: Schwartz, Guy L (DOA); Richard Gentges Subject: RE: CLU Storage 2, 3, 4 &5 Sundry Applications Victoria, Maximum allowable surface pressure will be 3000 psi. This would be on the coil tubing reel rotating joint itself. Let me know if you have any other questions. Rick Gentges From: Ferguson, Victoria L (DOA) f mailto:victoria.ferguson©alaska.govj Sent: Monday, June 04, 2012 12:18 PM To: Richard Gentges Cc: Schwartz, Guy L(DOA) Subject: CLU Storage 2, 3, 4 & 5 Sundry Applications Rick, Could you please provide a maximum allowable surface pressure(MASP)for the four wells CLU Storage 2,3,4&5 in reference to your Sundry Applications for stimulation and fill clean out. Thank you in advance, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferquson(a alaska.gov 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday,April 24,2012 TO: Jim Regg `� P.I.Supervisor Isle?" if I Z ` /Z/ SUBJECT:Mechanical Integrity Tests COOK INLET NATURAL GAS STORAGE A S-5 FROM: Lou Grimaldi CANNERY LOOP UNIT S-5 Petroleum Inspector Src: Inspector Reviewed B P.I.Supry-i NON-CONFIDENTIAL Comm Well Name CANNERY LOOP UNIT S-5API Well Number 50-133-20601-00-00 Inspector Name: Lou Grimaldi Permit Number: 211-158-0 Inspection Date: 4/20/2012 Insp Num: mitLG120422075839 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min S-5 G> 4867 ' i 0 1510 1510 1510 Well Type Inj TVD � IA PTD 2111580 Type Test SPT Test psi 1500 '; OA o o 0 0 Interval ,INITAL - P/F P '1Tubing 690 690 690 690 Notes: Solid test Tuesday,April 24,2012 Page 1 of 1 • DIF ALAszu /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 April 4, 2012 M. Colleen Starring Cook Inlet Natural Gas Storage Alaska, LLC Vice President P.O. Box 190989 Anchorage, AK 99519-0989 Re: Cannery Loop Gas Storage Project Start-up Storage Injection Order 9 CLU S-01 (PTD 2111490) CLU S-02 (PTD 2111350) CLU S-03 (PTD 2110880) CL -I ' 0 CLU S-05 (PTD 2111580) Dear Ms. Starring: The Alaska Oil and Gas Conservation Commission (AOGCC), by letter dated March 22, 2012, reminded Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) that injection associated with the Cannery Loop Gas Storage Project shall not commence until all outstanding obligations identified in that letter were resolved, namely review of pre-injection mechanical integrity tests of the five storage injection wells; review of the design, operation and testing of the well safety valve systems; remediation of existing pool wells with penetrations through the gas storage reservoir; and confirmation of plans for the installation of gas monitoring equipment. This letter provides official notice that CINGSA has satisfied AOGCC's requirements and is therefore authorized to commence injection into the Cannery Loop gas storage wells. This notice follows verbal approval to commence injection provided by the AOGCC on March 31, 2012. All requested information has been provided by CINGSA and reviewed by AOGCC. Affected wells — including the five new gas storage wells and the existing Cannery Loop Unit wells that penetrate the reservoir — have been confirmed to have mechanical integrity which will prevent the migration of injected gas from the storage reservoir. Technical discussions and reviews of the safety valve system information were supplemented by a walkthrough inspection of the well pad facilities by an AOGCC Inspector on March 31, 2012. The Inspector also witnessed a successful function test of the well safety valve system. CINGSA has committed to install gas monitoring equipment in 2 buildings owned by Inlet Fish Producers, Inc. that are within 50 feet of abandoned Kenai Unit well 13-08. Agreement by both r M. Colleen Starring April 4,2012 Page 2 of 2 parties — CINGSA and Inlet Fish Producers, Inc. — with equipment installation occurring as outlined in the agreement will satisfy Rule 3 of Storage Injection Order 9. Additional, post-injection obligations for operating the gas storage injection project are outlined in Storage Injection Order 9 and AOGCC regulations at 20 AAC 25. AOGCC appreciates CINGSA's effort to date to provide require requested information in a timely manner, make available technical staff to answer questions and resolve concerns, and in notifying AOGCC for opportunities to witness tests that are key to the success of the storage injection project operations. Sincerely, P30,,54. Iry Cathy . Foerster Daniel T. Seamount, Jr. Chair, Commissioner Commissioner cc: R. Gentges, CINGSA C t--G( S-5 • Regg, James B (DOA) From: Brooks, Phoebe L (DOA) y Sent: Friday, March 23, 2012 3:21 PM ZPrcl 31 ' l To: Richard Gentges Cc: Regg, James B (DOA) Subject: RE: CINGSA Initial MIT Results Attachments: MIT CLU S-3 09-21-11.xls; MIT CLU S-4 10-23-11.xls; MIT CLU S-5 01-16-12.xls; MIT CLU S-1 12-15-11.xls; MIT CLU S-2 11-19-11.xls Rick, Attached are revised reports as follows: • File naming convention was changed (ex. MIT CLU S-1 12-15-11) • "0" in OA data fields were removed and "0" was added to the tubing or casing fields • Verbiage pertaining to 10-23-11 testing was removed from the Notes(located near the bottom of the data portion of the form) Please let me know if you disagree. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 From: Richard Gentges [mailto:Richard.Gentges@cingsa.com] Sent: Friday, March 23, 2012 10:25 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Richard Gentges; cperry@)att.net; Matthew Federle Subject: CINGSA Initial MIT Results Jim Attached, per your instructions yesterday are the initial results of mechanical integrity tests that were performed on all five of CINGSA's storage wells while the drilling rig was still on each well. You had a number of questions in your email yesterday(copied below),which I have provided responses to. Thank you for the MIT reports; couple items: 1) Do wells have casing-casing annulus (OA)?Or was the pressure zero? The Outer Annulus (9 x 13) is cemented to- surface on each of the five wells,thus pressure was not recorded. 2) Please verify Tubing pressure in CLU S-1; pressure fall off never stabilized. I've confirmed the correct pressures are listed for CLU S-1. 3) CLU S-3 IA pressure fell below the required 1500psi; I will accept this as a passing test; refer to Industry Guidance Bulletin 10-002, paragraph labeled "Test Pressure" regarding future tests 4) Was CLU S-4 tested 30 minutes?; report only shows 15 min data. I went back and checked the drilling records and CLU S-4 was tested for only 18 minutes; no indication noted as to why. 1 5) We need separate reports for each well since done on different dates; include the test date in the "Date"field. Done 6) PTD#should be formatted without dash and adding trailing zero (ex. 2111490 instead of 211-149). Done 7) Interval should be I (initial) instead of 0 (other); I probably gave you bad advice on this previously. Done Please give me a call if you have any questions on these submittals. I can be reached at 310-7322. Thanks very much. Rick Gentges 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(Ualaska.gov doa.aoocc.prudhoe.bay(alaska.gov• phoebe.brooks(Walaska.gov OPERATOR: Cook Inlet Natural Gas Storage Alaska,LLC ` 6.(Z--- FIELD/UNIT/PAD: Cannery Loop Gas Storage-Sterling C DATE: 01/16/12 OPERATOR REP: Matt Federle AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CLU S5 Type Inj. G' TVD ' 4,867' Tubing 0 3,070' 3,060 3,060' Interval P.T.D. 2111580 Type test P Test psi -3000 Casing 0 0 0 0 P/F P Notes: Test performed on 1/16/12 while drilling rig was on OA location,immdiately after runnin tubing. Casing pressure(9 5/8" registered zero and the Outer Annulus(9 x 13)is cemented to surface. Well CLU S5 Type Inj. G / TVD '4867' Tubing 0 0 0 0 Interval P.T.D. 2111580 Type test P Test psi / 1500 Casing 0 1,500 ' 1,500 1,500 " P/F P Notes:Test performed on 1/16/12 while drilling rig was on OA location,immdiately after runnin tubing. Tubing pressure(7")re istered zero and the Outer Annulus(9 x 13)is cemented to surface. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 02/2012) MIT CLU S-5 01-16-12 STATE OF ALASKA ALASr'A OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 1b.Well Class: 20AAC 25.105 2oMc 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ❑ WAG ❑ WDSPL❑ GSTOR[ No.of Completions: 1 Service 0 Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: Cook Inlet Natural Gas Alaska,LLC Aband.:02/18/2012 211-158 / 31 z--C 53 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 190989,Anchorage,AK 99519 12/22/2011 50-133-20601-0000 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 720'FNL 1760 FEL SEC.9 T5N R11W 1/7/2012 CLU Storage 5 Top of Productive Horizon: 8,836'MD/4912'TVD 8.KB(ft above MSL): 50.5' 15.Field/Pool(s): 559'FSL 1959'FEL SEC.8 T5N R11W GL(ft above MSL): 33' Cannery Loop/Sterling C Pool Total Depth: 11,101'MD/5,127'TVD 9.Plug Back Depth(MD+TVD): 967'FNL 1657 FWL SEC.17 T5N R11W 11,059'/5,125' 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 281845.44 y- 2392832.83 Zone- 4 11,101' /5,127' ADL 391627 TPI: x- 276299.39 y- 2388922.06 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 274613.794 y- 2387432.61 Zone- 4 167'/167' ADL 230925 18.Directional Survey: Yes 0 No H 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 andprinted informationper 20AAC25.071): 22.Re-drill/Lateral TopWindow MD/TVD: ) GRAM,CALM,RPC-SHM-SLM-CLM; BDCM,NPCKSM,DPEM,MagTrak-8 1/2"only N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 133 X56 23 117.5 23 117.5 Driven N/A 13 3/8" 68 J-55 22 2,390 22 2,013 16" 516sx 12.2 lead/295 sx 15.4 tail 9 5/8" 40 L-80 20.5 8,860 20.5 4,916 12 1/4" Stage 1-695 12 ppg lead,209 sx 14 ppg tail Stage 2 493 sx 12.0 ppgDV @3,510'MD 7" 26 L-80 8,684 11,099 4,867 5,127 8 1/2" 301 sx 14.0 ppg 24.Open to production or injection? Yes Q No El 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) MD Perforation TVD Perforation 7" 8,684 8,684/4867 From To Footage From To Footage 9,060 9,130 70 4,954 4,966 12 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 9,210 9,390 180 4,979 5,010 31 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 9,420 9,470 50 5,015 5,023 8 9,770 10,380 610 5,061 5,100 39 10,580 10,880 300 5,109 5,119 10 27 Total Footage 1210 Total Footage 100Rnnt1CTION 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: Test Period Flow Tubing Casing Press: Calculated 4Oil-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 •,- . . , .- or w-er (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photograph s and laboratory analytical results r 20 AAC 25.171. RECEIVED R I MAR 1 2012 i I 1 RBDMS MAR 15 2012; Alaska Gi; &Gas Cons. Commission Anchorage _..1 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 3 /6• /z ubmit original only /4q 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 2 No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base B5 Coal 8790 4900 Sterling Cl 8836 4911 Sterling C2 9757 5060 Formation at total depth: Sterling C2 31. List of Attachments: Daily Reports,Completion Schematic,Perforating Reports,Well Cleanup Pressure Chart. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tom Arminski 907 334-7743 Printed Name: M. Colleen Starring Title: Vice President Signature: 1, 9�/ y� /10/“...1,13- Phone:907 277-5551 Date: _g-13-#20-4.Z 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 lb: 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 Cook Inlef Natura :Gas Cook Inlet l Gas Storage Alaska,LLC 3000 Spenard Road PO Box 190989 Anchorage,Main: r99519-0989 ;;tk907-334-7980 Fax:907-334-7671 Q$ °,,r www.cingsa.corn March 13, 2012 RECEIVED 1Alaska t2Alaska Oil & Gas Conservation Commission Oil& Gas Cons. Commission 333 W. 7th Avenue, Suite 100 Anchorage Anchorage, Alaska 99501 Re: Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Well Completion Form 10-407 CLU Storage 5 Gas Storage Well Please find attached Well Completion form 10-407 for CINGSA's CLU Storage 5 Gas Storage Well and associated daily reports/well schematic. The well work has been completed and the well is available for storage operations. The following is a summary of operations conducted since the previous report. Date Operations 2/14/12 Rig Up SLB Coil 2/15/12 Reverse out perf pill. Run Correllation log. Blow down well 2/16/12 Perforate lower zone underballanced. 10,580'to 10,880' Kill Well. Recover guns. 2/17/12 perforate runs 2 and 3 9,770'to 10,380' 9,420'to 9,470' 9,210'to 9,390' 9,060'to 9,130' 2/18/12 Blow down well. - Recover 311 bbls w/76 bbls losses. 2/19/12 Pressured up on well with N2 - started leaking off at 1508 psi, injected at 3000 SCFM with 1459 psi until N2 ran out. 2/20/12 Opened well to flare -bled down to 0 psi. 2/21/12 Set SSSV - Released well to Production AOGCC March 13, 2012 Page 2 Thank you and if you have any questions,please do not hesitate to contact Tom Arminski at 907 334-7743 or tom.arminski@enstarnaturalgas.coin. Sincerely, 214/-ah,L4.er M. Colleen Starring Vice President Enclosure as stated CINGSA CLU Storage 5 FMC Wellhead- 13 5/8" 5000# Multibowl Completion Schematic FMC Tree- 7" 5000#complete with SSV 02/18/2012 0 20" 133# X56 driven to 117.5'TVD/117.5' MD F :: 7" Halliburton Wireline Retrievable SSSV @ 167' TVD/167'MD } '''' 0 13 3/8" 68#J55 BTC Surface Casing @ 2,013' TVD/2,390' MD ,k, t16" hole/Cemented to Surface i �DV Collar @ 3,510' 7" 26#L80 7" x 9 5/8" Baker ZXP Liner Top Packer with 10' seal bore @ 4,867' TVD/8,684' MD Vam Top Tubing SMI 9 5/8" 40#L80 BTC Intermediate Casing R @ 4,916' TVD/8,860' MD 7" RN Nipple, - 8,707' 12 1/4" hole/Cemented to Surface 5.88" ID, 7.60" OD MD Perforation ND Perforation ,42; Ioz From To Footage From To Footage 6 MOM ea 9,060 9,130 70 4,954 4,966 12 1,6 t" 9,210 9,390 180 4,979 5,010 31 Y _ 9,420 9,470 50 5,015 5,023 8 9,770 10,380 610 5,061 5,100 39 10,580 10,880 300 5,109 5,119 10 Total Footage 1210 •' Total Footage 100 7" 26# L80 Vam Top Production Liner from 4,867' TVD/8,684'MD TOP to 5,127' TVD/11,099' MD TD 8 1/2" hole/Cemented 7,INGSA - DAILY DRILLING REPORT 2/15/2012 Well Name CLU Storage 5 BHA#: DSM Days: John Nicholson AK 11101 Target 11100' Location: Kenai, ' Cell Phone: (907) 299-4306 Depth: 0 Fleld/Pool: Cannery Loop/Sterling C :eof SLB Coil DSM Mike Grubb Nights. ' 34/ICT Present Cut coil r-it'''''1A,-• (907)398-3156 Cell Phone: (509)431-7988 ;•„,,,,,,,,,,,,,,,' operation: : ''' DRILLING DATA „, , ,- , ...,,,,,,,, FEET BIT GRADE TOTAL HOUrf417—,k:v: •,,S;',"..' SIZE MFO TYPE --1';';t:7”t - 4ET.A.,,1,-,,;,qr,0- IN OUT CASING I SIZE I WEIGHT I GRADE I THREAD[ DEPTH I CEMENT COMPANY I DATE I Conductor 20 133# X-56 Welded 97N/A July - Surface. 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40# L-80 BTC 8860' Slumberger 2-Jan Liner 7 26# L-80 VAM-Top 11100-8684' Slumberger 14-Jan Tubing 7” 26# L-80 VAM-Top 8684' Tie back 17-Jan space out 2.5'above no gc PUMP#1 IPUMP#2 ,:,,,''''',77,„7,,,-‘,,x,A,,,,-.;;;;;„41, RTIES: 'MUD ADDITIVES:' I Daily 'Cumulative PUMP MANE PUMP MANE WEIGHT GEL(50 lb bag) 630 PUMP TYPE PUMP TYPE FUNNEL VIS S ASH(50 lb bag) 42 LINER SIZE -LINER SIZE R600/R300 KLA-GUARD 172 STOKE LNGTH STOKE LNGTH R200/R100 LOTORQ/776ISTEEL LUBE 4400 SPM RPM R6/R3 ASPHASOL SUPREME 233 GPS GPS PV CONCOR 404 8 1 GPM GPM YP POTASSIUM CHLORIEW3 415 PSI PSI GELS FLOV)W1/4N -',.ti: ' " 183 BTMS UP MIN BTMS UP MIN API FLUID LOSS PeIe ,'`.,',40,4144Ie-- - " 4. 139 TOT CIR MIN TOT CIR MIN CAKE APH/HT CF-Dpv -,7::, .,,„_ ), 96 f;) AVDP. AVDP SOLIDS MY ''''::g'- -1:1,1k7iVh,r,','!"", 7 ,41-0 AVDC: AVDC: OIL/WATER 0151-4(,i,/7",'/',4 —", - 7 C: - AVDC SAND cfritifit/ 476::4, :-FE CARB/mix II 767 ::::7;TR1NG&HYDRAULICS r/1JOti,7' !PH RESINEX 24 STRING WT. WO8 Pf/1/11 CAUSTIC SODA 40 PICK UP RPM CHLORIDES SODIUM BICARBONATE/mrtabisulf 104 milh, S TEA CA BARITE/NUT PLUG/G SEAL 752 HSP VOL PIT-(BBL) LIQUIDS /screen clean 320 EC PRESS DROP HOLE-(BBL) SOU ,4(BBLS hauled by AIMM) 8813.7 0; JET VEL ,, '7 '"- e,k ';',',, ,klijtix:1$4,0 Cum, 0 17152.7 ' - l ' I ACTIVITY SUMMARY I TIME SUMMAR4i.,,A w4oh,., „ .,., Start I Finish I Hours 1 .,,,,„4,„„„. . ,.„Description I Detail I tot51billitti -I e 18:00 PJSM, RID and move coil unit from GS-3. Move CT unit on RU/RD 12.00 274.50 to CLUS-5 move work platform.Remove BOP stack and set Drilling 137.00 on CLU-5. Move pumps and power pack. Install hydrauilic Service/Repair Rig 27.50 control lines.Set burms, run flow lines and R/U choke, R/U Surveys 0.00 2:30 8.50 reverse iron. Tripping 224.00 2:30 PJSM,fluid pack coil.Pressure test BOP and related equip- Change BI-IA 0.00 4:30 2.00 ment 250/4000 psi. Casing Crew 54.50 4:30 6:00 1.50 Remove injector head.Cut 100'coil Cementing Crew 16.50 Logging 10.50 NU/ND Test 62.00 DST/Core 0.00 Well Control 0.00 WOC 1.00 Safety Meetings 0.00 Drilling Cement 3.50 Circ/Other .. 63.00 1240A TOTAL `-'' ., 12.00 906.00 --..--------- ----- BOTTOM HOLE ASSEMBLY.-. ', -, :/,-;:ttI-k,,,, , , " I CONN DOWN I CONN UP I VENDOR I O.D.77, 1:11 I - 'M,Tr,k" i NECK I LENGTH [TOTAL LENGTH BHA TOTAL LENGTH 0.00 , 'REMARKS&COIMPENTS DIESEL PJSM prior to work scope change Well head pressure #1 1500 psi Diesel on Location day before 3,869 AOGCC(Lou Grimaldi)waived witness 2-14-12 @ 06:00 on BOP test 2-200 psi Diesel Used Last 24 257 3-1600 psi Diesel Received, 4-200 psi TOTAL DIESEL 3,612 519,- t,-"-'45PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL SLB Rig Crew 10 6 60 PRA DSM 2 6 12 PRA Safety/PM 1 1 1 Weaver Loader 2 6 12 Peak Crane 2 6 12 Weathor ford Testing 2 6 12 Aimm RoustNac 5 7 35 TOTAL COUNT 24 TOTAL MAN HOURS 144 OINGSA - DAILY DRILLING REPOR Date 2/16/2012 Wet Name CLU Storage 5 BHA#: DSM Days: John Nicholson Current Depth: 11100' Location: Kenai,AK Target 11101' Celt Phone. (907) 299-4306 Depth: Ftg/24hrs. 0 Field/Pool: Cannery Loop/Sterling C Contractor:Rig SLB Coil N4 u: Mike Grubb Days SincePresent 35/2CT R/U to run guns Rig Phone: (907)398-3156 Cell Rhone: (509)431-7988 Spud[ Operation: DUN, iii SSS /: t , SER; ��SIT# %,,, „„- yam,MI~ „z„,!, Ot1T' 4 " s�% I;111;SFiAFE TgTAL H+;71JRS 4>•,S1NG I SiZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor: 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40# L-80 BTC 8860' Slumberger 2-Jan Liner 7" 26# L-80 VAM-Top 11100'-8684' Slumberger 14-Jan rng 7" 26# L-80 VAM-Top 8684' Tie back 17-Jan space out 2.5'above no gc MP#1 [PUMP#Z ,',, 'Mut)PR« .:$ t ,S: )MUD ADDITIVES: 1 Daily IGumuiative PUMP MANF PUMP MANE'' WEIGHT '' GEL(5o lb bag) 630 PUMP TYPE PUMP TYPE.'1 FUNNEL VIS S.ASH(50 lb bag) 42 t LINER SIZE LINER SIZEli R600/R300 KLA-GUARD 172 OKE LNGTH STOKE LNGTH R200/R100 LOTORQ/776/STEEL LUBE 4400 SPM R6/R3 ASPHASOL SUPREME 233 GPS GPS PV CONDOR 404 8 GPM GPM YR POTASSIUM CHLORIDE 415 PSI PSI GELS FLOWZAN 183 �i BTMS UP MIN BTMS UP MIN API FLUI `O PAC ,Y 139 TOT CIR MIN TOT CIR MIN CAKE APH/HT CF-DESCCt; ) 96 AVDP SOLIDS MYACIDE �«� 7 AVDC: OIL/WATER GEL-X �,����/-^" 7 A AVDC: SAND CITRIC ACID/SAFE CARB/mix II 767 -- DRILL STRING&HYDRAULICS PH RESINEX 24 STRING WT. WOB Pf/MI CAUSTIC SODA 40 PICK UP RPM CHLORIDES SODIUM BICARBONATE/mrtabisulf 104 SLACK OFF TEA CA BARITE 1 NUT PLUG/G SEAL + 752 PULL HSP VOL.PIT-{BBL} LIQUIDS /screen clean 320 PRESS DROP HOLE-(BBL) SOLIDS (BB '-®by AIMM) 8813.7 k D , JET VEL API SCREEN w, .Iiy id Cum. 0 17152.7 LI ACTIVITY SUMMARY I TIME SUMMARY Start I Finish I Hours I Description I Detail 40. I I iyc,, , Cumulative 6:00 8:00 2.00 PJSM, Reheading coil RU/RD 0.50 275.00 8:00 RIH with coil to 8500'Begin reversing out perfpill at top of 'Drilling 137.00 liner 8684'2.25bbls min 958psi on annulus 50 psi in coil Service/Repair Rig 27.50 down to 11045'CTM tag landing collar,Continue circ until Surveys 0.00 12:00 4.00 220bbls pumped and returning fluid cleaned up Tripping 3.00 227.00 12:00 15:00 3.00 POH W/coil F/10998'. Pull injector head and set down Change BHA 0.00 15:00 16:00 1.00 Drop ball and drift coil at surface due to reverse circulating Casing Crew 54.50 16:00 17:00 1.00 Make up memory logging tools to coil. Cementin• Crew 16.50 17:00 20:30 3.50 Rih with memory tools,perform memory correlation log .oggin;, a`;:: 4.50 14.50 20:30 POH to 7500',displace 302 bbls brine with nitrogen at 2 bpm 'NU/ND Test 62.00 5:00 8.50 for 1.5 hours.Start POH at 25 fpm pumping 1000 scfm DST/Core 0.00 Used 4772 gals nitrogen Guns 0.50 0.50 5:00 5:30 0.50 Remove injector head. WOC 1.00 5:30 6:00 0.50 PJSM,prep guns to run Nitrogen 9.00 9.00 Drilling Cement 3.50 CirclOther 7.00 70.00 TOTAL 24.50 930.00 ",- rf wo i ""'",'"'Ti., ;`" BOTTOM HOLEASSEMBLY 4,;::,:":',,,:"'"'"'-' ITEM IIIrItO DDtKfN'„ =NN UP VENDOR I O.D. I LD. I GAUGE . I NECK 1 LENGTH [TOTAL LEND ' BHA TOTAL LENGTH 0.00 REMARKS&COMMENTS %, iDIESEL PJSM prior to work scope change Well head pressure #1 1500 psi Diesel on Location',day before 3,612 AOGCC(Lou Grimaldi)waived witness 2-14-12 @ 06:00 on BOP test 2-150 psi Diesel Used Last 24 879 3-1550 psi DieselReceived: 4-200 psi TOTAL DIESEL 2,733 ;,.,, ;,PERsDNN L N LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL - SLB Rig Crew 10 12 120 Pollard wireline 5 8 40 PRA DSM 2 12 24 SLB Guns 3 2 6 PRA Safety/PM 2 6.5 13 - Weaver Loader 2 12 12 Peak Crane 2 12 12 Weathor ford Testing 2 12 12 Aimm RoustNac 5 13 35 - TOTAL COUNT 33 TOTAL MAN HOURS 274 :,INGSA - DAILY DRILLING REPOR- Date 2/17/2012 Well Name CLU Storage 5 BHA# DSM Days: John Nicholson Current Depth: 11100' Location: Kenai,AK Target 11101' Cell Phone: (907) 299-4306 Depth: Ftg/24hrs. 0 Field/Pool: Cannery Loop/Sterling C Conttrra tor:ig SLB Coil Nghts: Mike Grubb Days Since 36/3CT Present RIH W/Gun Run#2 Ri -/, Spud Operation: 9 Phone: (907)398-3156 Cell Phone: (509)431-7988 RILLING DATA /' .. . °� BIT# rr 1 , „;;' 1 MFG i E., , i,, , � F MEET$ IN OUT 111, : �� '., i ASING I SIZE I WEIGHT I GRADE j THREAD I DEPTH I CEMENT COMPANY I DATE I .=' "' Conductor 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec 9 5/8 40# L-80 BTC 8860' Slumberger 2-Jan 7" 26# L-80 VAM-Top 11100'-8684' Slumberger 14-Jan 7" 26# L-80 VAM-Top 8684' Tie back 17-Jan space out 2.5'above no g. PUMP#1 IPUMP#2 ,. ]MUD PR+` n• ]MUD ADDITIVES: ] Daily 'Cumulative P` PUMP MANE WEIGHT GEL(50 ib bag) 630 P PUMP TYPE FUNNEL VIS S.ASH(50 lb bag) 42 LINER SIZE LINER SIZE R600/R300 KLA-GUARD 172 -OKE LNGTH STOKE LNGTH R200/R100 LOTOROR76JSTEEL LUBE 4400 `° SPM R6/R3 ASPHASOL SUPREME 233 GPS GPS PV CONDOR 404 8 GPM GPM YP POTASSIUM0,dI LORIDE 415 PSI PSI GELS FLOV3IZAN ' 183 BTMS UP MIN BTMS UP MIN API FLUID LOSS 139 �T CR MIN TOT CIR MIN CAKE APHtHT 96 AVDP. SOLIDS MYACIDE GA25 7 .. Y AVDC: OIL/WATER GEL-X 7 '.C: AVDC. SAND CITRIC ACIE$AFE CARB/rnix II 767 DRILL STRING&HYDRAULICS „4,4.7 PH RESINEX 24 ING WT, WOB Pf/MI CAUSTIC SODA 40 K UP RPM CHLORIDES SODIUM BICARBONATE/mrtabisulf 104 .�"CK OFF TFA CA BARITE;NUT PLUG I G SEAL 752 ,1-, PULL HSP VOL PIT-(BBL) LIQUIDS /screen clean 320 FED PRESS DROP HOLE-(BBL) SOLIDS (BBLS hauled by AIMM) 8813.7 DGOD: JET VEL API SCREEN p1,�,Y'ApiIy Mud.Gunn,,;; 0 17152.7 ACTIVITY SUMMARY i F,: TIME SUMMARY Start I Finish I Hours f Description JDetail I Daily I Cumulative 6:00 Blow down N2 remaing in well, Remove injector head Hold RU/RD 2 50 275.00 6:30 0.50 PJSM:for handling guns. Drilling 137.00 6:30 P/U 342'of 4.72 4spf 450PJ guns to shoot perfs F/10880- Service/Re.air Ri. 1.00 27.50 8:00 1.50 10580'and rih. Make up gun bha to coil. Surveys 0.00 8:00 RIH and tag up at 11056'stack out 10k P/U to 10880.6 and Tripping, 5.00 227.00 park guns.Pump 8bbl to fill coil.Coil reel valve packing failed Chartgik , 4.00 4.00 repair,drop ball and let fall F/30min then start pumping at Casing Crew 54.50 15:00 7.00 1.6bbls min at 44bbls and 465psi the guns fired. Cementing Crew 16.50 15:00 15:30 0.50 Monitor well for build up No pressure after 30min Logging 14.50 15:30 16:30 1.00 Repair power pack on coil NU/ND Test 62.00 16:30 21:30 5.00 POH,filling backside,hole took 17 extra bbls to fill,flow check DST/Core 0.00 21:30 22:00 0.50 Remove injector head Guns 11.00 11.00 22:00 0:30 2.50 Lay down guns.All guns fired WOC 1.00 0:30 2:00 1.50 Reconfigure iron and shell test. Fill hole and check flow Nitrogen 0.50 9.00 2:00 4:30 2.50 PJSM:for handling guns.P/U interval 2 run#2,658'guns Drilling Cement 3.50 4:30 6:00 1.50 PT head/coil. RIH Circ/Other____ 70.00 a y ,`,.,; . ;; rmA, 4..00 SEE GUN INTERVAL LIST BELOW TOTAL; , , 24.00 930.00 NISIMMIlllarrhaN',;',, ,, 04:,,,, BOTTOM Hal. , ' " -r . . . ,,r /, . i , +e, '` CONN UP VENDOR O.D. I.D. ., ""1<.' LE,..,r f '?a All 4.72" 4spf 450Pj Interval RUN# Depth 1 1 10580'-1( 2 2 9770'-10 3 3 9420'-94 5 3 9210'-9390' 6 3 9060'-91: BHA TOTAL LENGTH 0.00 DIESEL PJSM prior to work scope change Well head pressure #1 1500 psi Diesel on Location day before 2,733 2-150 psi Diesel Used Last 24 880 3-1550 psi Diesel Received' 0 4-200 psi TOTAL DIESEL' 1,853 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL SLB Rig Crew 10 12 120 Pollard PRA DSM 2 12 24 SLB Guns 3 12 6 PRA Safety/PM 2 6.5 13 _ Weaver Loader 2 12 12 Peak Crane 2 12 12 _ Weathor ford Testing 4 12 48 Aimm RoustNac 5 13 35 - TOTAL COUNT 30 TOTAL MAN HOURS 270 ;INGSA - DAILY DRILLING REPOR- ,,,.Date 2/18/2012 Well Name CLU Storage 5 BHA#: DSM Days: John Nicholson 11100' Location: Kenai,AK Target 11101' Cell Phone:Depth: (907) 299-4306 0 Field/Pool: Cannery Loop/Sterling C Contractor''' SLB Coil k DSM Mike Mike Grubb 36/3CT Present Laydown Guns Rig Phone ' Operation: 9 (907)398-3156 Cell Phone. (509)431-7988 � „„, y, «, MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS BASINGI;', :SIZE I WEIGHT[ GRADE I THREAD I DEPTH I ,,ENT COMPANY 71 DATE I Conte% 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Interco 9 5/8 40# L-80 BTC 8860' Slumberger 2-Jan Liner :? 7" 26# L-80 VAM-Top 11100'-8684' Slumberger 14-Jan Tubing 7" 26# L-80 VAM-Top 8684' Tie back 17-Jan space out 2.5'above no gc PUMP#1 ',Vii;:'':" ; ,/Oi,: t`UMP#2 IMUD PROPERTIES: IMUD ADDITIVES: I Daily ]cumulative PUMP MANF , MP MANE WEIGHT GEL(501b bag) 630 PUMP TYPE PUMP TYPE FUNNEL VIS S.ASH(50 Ib bag) 42 LINER SIZE LINER.SIZE R600/R300 KLA-GUARD 172 STOKE LNGTH STOKE LNGTH 8200/RI00 LOTOR41776/STEEL LUBE 4400 SPI"F', ' O R6/R3 ASPHASOL SUPREME 233 GPS GPS PV CONQOR 404 8 GPM GPM VP POTASSIUM CHLORIDE 415 FI PSI GELS FLOWZAN 183 MS UP MIN BTMS UP MIN API FLUID LOSS PAC 139 TOT CIR MIN TOT CIR MIN CAKE APH/HT CF-DESCO II/SAPP 96 AVDP % rf.: SOLIDS MYACIDE GA25 7 AVDC: ;s;% OIL/WATER GEL-X i,/l/// 7 AVDC: . i!!!,o: SAND CITRIC ACID/SAFE CARS/mix Ii 767 DRILL STRING&HYDRAULICS PH RESINEX 24 STRING WT. WOB PK/Mf CAUSTIC SODA 40 PICK UP RPM CHLORIDES SODIUM BICARBONATE/nlrtabist 104 SLACK OFF TFA CA BARITE/NUT PLUG/G SEAL 752 MAX PULL HSP VOL.PIT-(BBL) LIQUIDS /screen clean 320 ECO PRESS DROP HOLE-(BBL) SOLIDS (BBLS hauled by AIMM) 8813.7 DCOD JET VEL API SCREEN Daily Mud Cum i4a. 0 17152.7 L ACTIVITY SUMMARY I TIME SUMMARY Start I Finish I Hours I Description !Detail I Daily I Cumulative 6:00 Continue RIH W/gun run#2 to 11045,tag bottom make RU/RD 2.50 275.00 correction in stretch and place guns to shoot at 10380- Drilling ,, 137.00 9770'. Drop ball and pump at 2.5bbl min to 35bbls drop rate Service/Repair Rig 27.50 to 1.0 bbl min 450psi at 43bbls pumped ball seated pressure Surveys 0.00 increased to 2100,guns fired. Pull up to 9700'fill hole.Had Tripping 6.00 233.00 7bbl loss to perfs, POH at 100'per min with spent guns to Change BHA 6.00 10.00 12:00 6.00 300'monitor well 10min. Casing Crew 54.50 12:00 13:00 1.00 R/D injector head,and set on ground Cementing Crew 16.50 13:00 17:00 4.00 Lay down guns(30)jts .��" 14.50 17:00 M/U gun run#3 20jts 4.72 4spf 4505PJ guns.To pert f-9470' NU/ND Test 62.00 20:00 3.00 9060'PT coil p/u injector head make up to coil DST/Core 0.00 20:00 RIH W/per guns to 9650'make correction to depth, rih to Guns 9.50 9.50 11056'tag bottom mak correction pull up to shooting depth WOC 1.00 9650'drop ball pump 44bbls ball on seat pressure up to 2400 Nitrogen 9.00 1:00 5.00 guns fired. POH Drilling Cement 3.50 1:00 5.00 POH Lay guns down Circ/Other 70.00 24.00 -SEE GUN INTERVAL LIST BELOW 'TOTAL '' 24.00 930.00 ' '- BOTTOM HOLE ASSEMBLY QTY I ITEM I CONN DOWN I CONN UP I VENDOR I O.0. I I.D. I GAUGE I NECK I LENGTH ITOTAL LENGTH All 4.72" 4spf 450Pj Interval RUN# Depth 1 I 1058a-1( 2 2 9770'-10: 3 3 9420'-94- 5 3 9210'-9390' 6 3 9060'-91C BHA TOTAL LENGTH 0.00 RRKS It COMMENTS DIESEL PJSM prior to work scope change Well head pressure #1 1500 psi Diesel on Location day before 2,733 Fuli #2 150 psi Diesel Used Last 24 825 bop drill with safety joint #3 1550 psi Diesel Received 2.500 4-200 psi TOTAL DIESEL 3,388 �� � PERSONNEL ON LOCATION . ,,, 4 ////�///�ys ,-5,,, s 'S£/, �.,.r �`.If/ f //////,yip ./!... COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL SLB Rig Crew 10 12 120 Pollard PRA DSM 2 12 24 SLB Guns 3 12 6 PRA Safety/PM 2 6.5 13 Weaver Loader 2 12 12 Peak Crane 2 12 12 Weathor ford Testing 4 12 48 Aimm Roust/Vac 5 13 35 - ' TOTAL COUNT 30 TOTAL MAN HOURS 270 CINGSA - DAILY DRILLING REPOR Dale 2/19/2012 Well Name CLU Storage 5 BHA#: DSM Days:', John Nicholson Target Current Depth: 11100' Location: Kenai,AK 11101' Cell Phone (907) 299-4306 Depth: =1f Ftg/24hrs. 0 Field/Pool: Cannery Loop/Sterling C Contractor. SLB Coil Ngh€Ms Days Since 36/3CT Present Move Coil Rt Spud Operation: 9 Phone* (907)398-3156 Cell Phone: DRILLING DATA ',I, BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTALHOURS CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPA ,//,.14'' I DATE I ++ 20 133# X-56 Welded 97' N/A July:::1,0,0* 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec 9 5/8 40# L-80 BTC 8860' Slumberger 2-Jan pAs a t,6 7" 26# L-80 VAM-Top 11100'-8684' Slumberger 14-Jan 5' 7" 26# L-80 VAM-Top 8684' Tie back 17-Jan space out 2.5'above no g. Mfr / „e:rl, s,'-, 13f1111k{ '!f- k., •';';:i, MUD PROPERTIES: MUDA ill , , 4y -f WEIGHT GEL a0, I - 630 FUNNEL VIS S.ASH(''' '','',c!.',.!), 42 rn% LINER SIZE R80Q/R300172 :� STOKE LNGT i;20O/R1G0 (,OTOR« r � 4400 ;'1 " SPM Rf3 t3 ASPHASOL SUPREME 233 GPS PV. CONDOR 404 8 I5PM GPM VP POTASSIUM CHLORIDE 415 I'SIj;;',; PSI GELS FLOWZAN 183 ;TMS IJ, N BTMS UP MIN API FLUID LOSS' PAC 139 TOT CIR!I ' TOT CIR MIN CAKE APH/HT CF-DESCO II/SAPP 96 AVDP.: AVDP SOLIDS MYACIDE GA25 7 AVDC: " AVDC: OIL/WATER GEL-X 7 AVDC AVDC: SAND CITRIC ACID/SAFE CARE/mix II 767 DRILL STRING&HYDRAULICS PH RESINEX 24 STRING WT. WOB Pf/Mf CAUSTIC SODA 40 PICK UP RPM CHLORIDES SODIUM BICARBONATEimrtabisulf 104 SLACK OFF TFA CA BARITE/NUT PLUG/G SEAL 752 MAX PULL HSP VOL.PIT-(BBL) LIQUIDS/screen clean 320 EGO PRESS DROP HOLE-(BBL) SOLIDS (EELS hauled by AIMM) 8813.7 DCOD JET VEL API SCREEN Daily Mud Cum. 0 17152.7 ACTIVITY S / I TIME:SUMMARY ( Finish I Hours I aescription (Detail ,; �,,,,,,,, ;� ®Y ,'+ , Cumulative 6:00 8:00 2.00 Lay down pert guns.All shots fired. R/D gun handling tools RI i/RCI' #i 2.50 275.00 8:00 9:00 1.00 Blow down all fluids in coil 51 bbls Drilling.', 1 n 137.00 9:00 RIH to 2000'start N2 displacement of well bore @ 1100scf Service " 27.50 fluid started to return to surface at 5000'2.5bbl min.Found Surveys 0.00 that setting on N2 pump as at 2200 scf adjust pump back to Tripping 6.00 233.00 1100scf. Blow down well to 10883.Total of 311 bbls Change BHA 6.00 10.00 14:30 5.50 losses to well 76bbls.Ran out of N2 total of 8000 gal N2 Casing Crew 54.50 14:30 18:00 3.50 POH with coil R/D MHA Set injector head on carrier Cementing Crew 16.50 Release rig to CLU-3 at 1800hrs 2-18-12 Logging 14.50 NU/ND Test 62.00 DST/Core 0.00 Guns 9.50 9.50 WOC , 1.00 Nitrogen 9.00 Drilling Cement P 3.50 Circ/Other 70.00 , 12.00 TOTAL 24.00 930.00 -'- ,-,,-s `BOTTOM HOLE ASSEMBLY r-, . ,. . .,,N,,,,.:. QTY I ITEM [CONN DOWN( CONN UP I VENDOR I 0.D. ( I.D. ( GAUGE I NECK J LENGTH (TOTAL LENGTH BHA TOTAL LENGTH o.00 REMARKS&COMMENTS DIESEL Diesel on Location day before 3,388 Diesel Used Last 24 425 Diesel Received 0 TOTAL DIESEL, 2,963 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL SLB Rig Crew _ 10 12 120 Pollard PRA DSM 2 12 24 _ PRA Safety/PM 2 6.5 13 Weaver Loader 2 12 12 Peak Crane 2 12 12 Weathor ford Testing 4 12 48 ` Aimm RoustNac 5 13 35 - TOTAL COUNT 27 TOTAL MAN HOURS264 Schlumberger Tubing Cc ✓eyed Perforating Client Well Riq Field Date Guns CINGSA CLUS 5 SLB 1 KENAI 1/12/2012 4.72"4spf 4505PJ Count of Entries==> 19 Description Gun # Length Top Bottom Gun S/N MHA, Swivel, Checks,Disconnect 3 5.71 10,537.98 10,543.69 Safety Jnt. 2-3/8" EUE 2 16.25 10,543.69 10,559.94 CBF firing head 1 4.50 10,559.94 10,564.44 /puncher) 4 15 15.5t 10,564.44 10,580.00 ; Mer"teza un(Partial) ` , rtet mm"p a¢ 21 Gun 14 21.08 10,585.52 10,606.60 450 - 4 - 881 80 Gun 13 21.08 10,606.60 10,627.68 450 - 4 - 891 80 Gun 12 21.08 10,627.68 10,648.76 450 - 4 - 882 80 Gun 11 21.08 10,648.76 10,669.84 450 - 4 - 883 80 Gun 10 21.08 10,669.84 10,690.92 450 - 4 - 892 80 Gun 9 21.08 10,690.92 10,712.00 450 - 4 - 884 80 Gun 8 21.08 10,712.00 10,733.08 450 - 4 - 893 80 Gun 7 21.08 10,733.08 10,754.16 450 - 4 - 885 80 Gun 6 21.08 10,754.16 10,775.24 450 - 4 - 878 80 Gun 5 21.08 10,775.24 10,796.32 450 - 4 - 896 80 Gun 4 21.08 10,796.32 10,817.40 450 - 4 - 899 80 Gun 3 21.08 10,817.40 10,838.48 450 - 4 - 875 80 Gun 2 21.08 10,838.48 10,859.56 450 - 4 - 900 80 Gun 1 20.44 10,859.56 10,880.00 450 - 4 - 901 80 'Bottom nose 0.86 10,880.00 10,880.86 342.88 <--BHA length Count of Guns (Charges) --> (1142) Depths are referenced by shot location. See additional handout for physical lengths. Partially Loaded Gun - 1 Intervals Top MD Bottom MD Net Blank Net Loaded spf Fully Loaded Gun - 13 Blank (Top) 10,564.44 10,580.00 15.56 Bottom Gun - 1 1 Loaded 10,580.00 10,880.00 • 300.00 4 R LI N I. Total Total Blank 10 500.000 Total Gun Length 10,875.50 CLU. Total Schlumberger BHA Lengtl 342.88 Ft. Prepared By: Reviewed By: Client Representative: WCP/TCP/SDP-054 Scot Shier Nikolai Soshnin John Nicholson Revision: AKA1.4- 15-Dec-07 1 of 1 Schlumberger Tubing Coereyed Perforating Client Well Rig Field Date Guns CINGSA CLUS 5 SLB 1 KENAI 1/12/2012 4.72"4spf 4505PJ Count of Entries==> 34 Description Gun # Length Top Bottom Gun S/N MHA, Swivel, Checks,Disconnect 3 5.71 9,722.08 9,727.79 Safety Jnt. 2-3/8" EUE 2 16.25 9,727.79 9,744.04 CBF Firing Head, 5/8" BALL 1 4.20 9,744.04 9,748.24 Blank(Safety Spacer w/puncher) 30 21.08 9,748.24 9,769.32 _I puncher 450 - 4 - 336 2 9,769.32 9,770.00 9,770.00 9,790.40 20.0 ft FULL GU 80 Gun 28 21.08 9,790.40 9,811.48 450 - 4 - 246 80 Gun 27 21.08 9,811.48 9,832.56 450 - 4 - 325 80 Gun 26 21.08 9,832.56 9,853.64 450 - 4 - 321 80 Gun 25 21.08 9,853.64 9,874.72 450 - 4 - 320 80 Gun 24 21.08 9,874.72 9,895.80 450 - 4 - 319 80 Gun 23 21.08 9,895.80 9,916.88 450 - 4 - 318 80 Gun 22 21.08 9,916.88 9,937.96 450 - 4 - 315 80 Gun 21 21.08 9,937.96 9,959.04 450 - 4 - 314 80 Gun 20 21.08 9,959.04 9,980.12 450 - 4 - 334 80 Gun 19 21.08 9,980.12 10,001.20 450 - 4 - 333 80 Gun 18 21.08 10,001.20 10,022.28 450 - 4 - 316 80 Gun 17 21.08 10,022.28 10,043.36 450 - 4 - 317 80 Gun 16 21.08 10,043.36 10,064.44 450 - 4 - 537 80 Gun 15 21.08 10,064.44 10,085.52 450 - 4 - 538 80 Gun 14 21.08 10,085.52 10,106.60 450 - 4 - 339 80 Gun 13 21.08 10,106.60 10,127.68 450 - 4 - 342 80 Gun 12 21.08 10,127.68 10,148.76 450 - 4 - 313 80 Gun 11 21.08 10,148.76 10,169.84 450 - 4 - 335 80 Gun 10 21.08 10,169.84 10,190.92 450 - 4 - 327 80 Gun 9 21.08 10,190.92 10,212.00 450 - 4 - 328 80 Gun 8 21.08 10,212.00 10,233.08 450 - 4 - 332 80 Gun 7 21.08 10,233.08 10,254.16 450 - 4 - 330 80 Gun 6 21.08 10,254.16 10,275.24 450 - 4 - 331 80 Gun 5 21.08 10,275.24 10,296.32 450 - 4 - 329 80 Gun 4 21.08 10,296.32 10,317.40 450 - 4 - 326 80 Gun 3 21.08 10,317.40 10,338.48 450 - 4 - 341 80 Gun 2 21.08 10,338.48 10,359.56 450 - 4 - 303 80 Gun 1 20.44 10,359.56 10,380.00 450 - 4 - 340 80 Bottom nose 0.86 10,380.00 10,380.86 658.78 <--BHA length 2ount of Guns (Charges) --> 3C (2322) Depths are referenced by shot location. See additional handout for physical lengths. Blank (Gun Puncher) - 1 Partially Loaded Gun - 1 Intervals Top MD Bottom MD ]Net Blank Net Loaded spf Fully Loaded Gun -27 Blank (Top) 9,748.24 9,770.00 ' 21.76 Bottom Gun - 1 1 Loaded 9,770.00 10,380.00 II 610.00 4 RUN 2 Total Loaded 610.00 I otal blank 21.76 I otal Gun Length 631.76 J5i5 Total Schlumberger BHA Lengtl 658.78 Ft. Prepared By Reviewed By: Client Representative: WCP/TCP/SDP-054 Scot Shier Nikolai Soshnin John Nicholson Revision: AKA1.4- 15-Dec-07 1of1 Schlumberger Tubing CcOveyed Perforating Client Wellg Field Date Guns CINGSA CLUS 5 SLB 1 KENAI 1/12/2012 4.72"4spf 4505PJ Count of Entries ==> 28 Description Gun # Length Top Bottom Gun S/N MHA, Swivel, Checks,Disconnect 3 5.71 9,022.58 9,028.29 Safety Jnt. 2-3/8" EUE 2 16.25 9,028.29 9,044.54 CBF Firing Head, 5/8" BALL 1 4.50 9,044.54 9,049.04 lank(Partial w/puncher) 20 10.96 9,049.04 9,060.00 ; puncher 1 Cx � tial) „ ...20 _. .. ,0 9,060.00 9,070.12 39 Gun 19 21.08 9,070.12 9,091.20 450 - 4 - 305 80 Gun 18 21.08 9,091.20 9,112.28 450 - 4 - 306 80 artial) 9,112.28 9,130.00 .. 69 9,130.00 9,133.36 I ,-,,,,t.---, 1 Blank(Gun Puncher) 16 21.08 9,133.36 9,154.44 ; 1 puncher 450 - 4 - 312 2 Blank(Gun Puncher) 15 21.08 9,154.44 9,175.52 I J puncher 450 - 4 - 311 2 Blank(Gun Puncher) 14 21.08 9,175.52 9,196.60 �_I puncher 450 - 4 - 310 2 at wlptm er) 13 _ 13.40 9,196.60 9,210.00 ; 1 =i0 . . 9,210.00 9,217.68 29 Gun 12 21.08 9,217.68 9,238.76 450 - 4 - 307 80 Gun 11 21.08 9,238.76 9,259.84 450 - 4 - 308 80 Gun 10 21.08 9,259.84 9,280.92 450 - 4 - 309 80 Gun 9 21.08 9,280.92 9,302.00 450 - 4 - 304 80 Gun 8 21.08 9,302.00 9,323.08 450 - 4 - 287 80 Gun 7 21.08 9,323.08 9,344.16 450 - 4 - 288 80 Gun 6 21.08 9,344.16 9,365.24 450 - 4 - 302 80 Gun 5 21.08 9,365.24 9,386.32 450 - 4 - 286 80 artial) 9,386.32 9,390.00 13 lank(Partial w/puncher) . ! 9,390.00 9,407.40 1 nk(Partial w/puncher) 9,407.40 9,420.00 (Partial) 9,420.00 9,428.48 31 • Gun 2 21.08 9,428.48 9,449.56 450 - 4 - 244 80 Gun 1 20.44 9,449.56 9,470.00 450 - 4 - 245 80 (Bottom nose 0.86 9,470.00 9,470.86 . 448.28 <--BHA length Count of Guns (Charges) --> (1152) Depths are referenced by shot location. See additional handout for physical lengths. Intervals Top MD Bottom MD Nnk N8FEINIGIRI spf Blank (Gun Puncher) -3 Blank (Top) 9,049.04 9,060.00 10.96 Partially Loaded Gun -5 1 Loaded 9,060.00 9,130.00 111 70.00 4 Fully Loaded Gun - 11 Blank 9,130.00 9,210.00 80.00 Bottom Gun - 1 2 Loaded 9,210.00 9,390.00 II 180.00 4 Blank 9,390.00 9,420.00 30.00 3 Loaded 9,420.00 9,470.00 IW, 50.00 4 RuN Total Loaded300.00 Total Blank 120.96 Total Gun Length 420.96 CLUSI15 Total Schlumberger BHA Lengtl 448.28 Ft. Prepared By: Reviewed By: Client Representative: WCP/TCP/SDP-054 Scot Shier Nikolai Soshnin John Nicholson Revision: AKA1.4- 15-Dec-07 1 of 1 CINGSA Well: CLUS#5 Field: Cannery Loop Unit 02-20-2012 lib IllNM IIIL L _ _ _... _co O In MIL MEM MINK — -- 4- MIER a 11.11111111111111M VIM III1M11 MI 4-0 III Q O 5500 • ■ 6000 , — — 1 i 6500 7000 ■ - ■ — 7500 ■ 8000 ina ma 8500 9000 S- 9500 i I i I I 20 30 40 50 60 70 80 90 100 110 120 Temperature (Deg. F) —Pressure — Perfs 7" —Temperature Report Date 2-7-2012 Y,A1xis C) C} CS C3 n 0o c ' ca ca to 0 0 0 to n o o p S7 Cy IN- (Co Intr] r ; '; 9. I r r r r r r Cis ILI lJ 7 al C mss' O NEIL C71 CI 0 CD J rir UUc CI i - Cy z r 6 , ii.1 i ;r / c"., „ . 4-.I . CI1 0. C I d 4PJ _ 0.a = d 0,1 tuE i:--- \ o5 : 0 w = SP \_ 3 0 ?5 cy 0 v cz.:,0 4 iL 8 01 c Q o n o C7 o n C n n n n rl v co ty T 10 isd - einsseid Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, February 16, 2012 9:20 AM To: 'cperry@att.net Cc: 'Richard Gentges'; 'Well Pad' Subject: RE: CLU Storage 5 (PTD 211-158) Conrad, You have approval to perforate CLU Storage 5 underbalanced as per your request. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Conrad Perry [mailto:cperry@att.net] Sent: Thursday, February 16, 2012 8:18 AM To: Schwartz, Guy L(DOA) Cc: 'Richard Gentges'; 'Well Pad' Subject: CLU Storage 5 Guy, We have a minor change to the sundry request on CLU Storage 5 perforating. We would like to perforate the first run about 100 psi underbalance rather than over balance as was done previously. We have drawn the fluid level down to 7500' MD/4355'TVD or approximately 3000' MD/700'TVD of 8.6 ppg KCL Brine head. Conrad 907-727-7404 2/16/2012 � firpri � /L ' 1 �\9 i' 1 li SEAN PARNELL,GOVERNOR J L Li L . L �__ L _ i ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMAIISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 M. Colleen Starring Vice President _55 Cook Inlet Natural Gas Alaska, LLC P.O. Box 190989 ` Anchorage, AK 99519 Re: Cannery Loop Field, Sterling C Pool, CLU Storage 5 Sundry Number: 312-053 Dear Ms. Starring: 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. This sundry approval includes perforating and a limited flowback for cleanup but does not authorize injection of gas for the initiation of the storage project. 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, $1' Daniel Seamount, Jr. Chair DATED this' day of February, 2012. Encl. 944A- - 0 ?A �'�O�vl-- RECEIVED • STATE OF ALASKA a.'1 d 94? ALASKA UIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS FEB 0 6 2012 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Alaska 91 66131M114?( 91 1 s�'ion Suspend❑ Plug Perforations❑ Perforate Q - Pull Tubing❑ Anch'lf erasion❑ Operations Shutdown❑ Re-enter Susp.Well Stimulate❑ Alter Casing❑ = . me 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Cook Inlet Natural Gas Alaska,LLC Development ❑ Exploratory ❑ 211-158 3.Address: Stratigraphic ❑ Service Q_ 6.API Number. P.O.Box 190989,Anchorage,AK 99519 50-133-20601-0000 ' 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number property line where ownership or landownership changes: Spacing Exception Required? Yes 2No IDCLU Storage 5 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 391627• Cannery Loop/Sterling C Pool " 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 11,101' , 5,127' • 11,059' - 5,125'- none none Casing Length Size MD ND Burst Collapse Structural Conductor 118 20" 117.5 117.5 na na Surface 2,390 13 318" 2,390 2,013 3,450 1,950 Intermediate 8,860 95/8" 8,860 .i 4,916 5,750 3,090 Production Liner 2,415 7" 11,099 5,127 7,240 5,410 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): see attached see attached 7"26# L80 Vam Top 8,684 Packers and SSSV Type: BHI 9 5/8"HR ZXPN Liner Top Packer Packers and SSSV MD(ft)and TVD(ft): Halliburton 7"WL FXE SSSV Pkr-8,684'/4,867' SSSV-167'1167' 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑, BOP Sketch 0 Exploratory ❑ Development ❑ Service ❑✓ 14.Estimated Date for February 10th,2012 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR l' SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tom Arminski 907 334-7743 Printed Name M. Colleen Starring Title Vice President SignaturePhone 907 277- 551 Date � A•dV-efi.w <4 �t:44r COMMISSION a � /� `� USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 re....,--053 Plug Integrity ❑ BOP Test IXMechanical Integrity Test ❑ Location Clearance El Other 4... /1000 p 5. i o P s7' 4. a(fiok,k cpp�• -L � - A..._c_,,,42_ k.../ S 10 it'll Subsequent Form Required: /D — Li O 7 0 .APPROVED BY q r Approved by: ippT COMMISSIONER THE COMMISSION Date: L 1 /0 l 1 '01 X Flews FEB 13 202•g i ; � ORIGINAL CLU Storage 5 Outline Perforating and Well Clean Procedures GENERAL SAFETY GUIDELINES A pre job safety meeting will be held with all affected personnel before every phase and for any change of program. Topics should include the following points: • H2S risks,spill prevention, and well control issues • Personnel assignments • Maximum safe pumping pressure prior to firing guns • Contingencies It should be stressed that while picking up and running the perforating string, only essential personnel should be on the work platform. Normally"essential personnel" will consist of the perforating crew and a roustabout for crane signals. All other personnel will stay off the platform and out of the cellar until the perforating string is at least 300' below ground level. Radio silence is not required with the Schlumberger systems described in this recommended practice. Fired guns will not be recovered unless the well is dead and stable. Should the well flow during recovery with the guns across the BOPs,the deployment bar with circulation ports on the lower end and a tested TIW valve on the upper will be stabbed into the gun BHA and immediately lowered below the BOPS. The pipe rams will then be activated on the deployment bar shutting the well in. RIG UP AND PRESSURE TEST 1. Notify AOGCC of upcoming rig up and BOP test 48 hours prior. Confirm SSSV protection sleeve is in place. 2. Mobilize and rig up 2 3/8"Coil tubing and Well testing equipment to CINGSA Drill Pad. 3. Position Blind/Shear Rams in upper Combi BOP body and 2 3/8" pipe rams in lower body. Pre-test BOP, all lines and valves to 250 psi/4000 psi. Install fusible cap on SSV. 4. Call for AOGCC Inspector. Pressure test BOP, all lines and valves to 250 psi/4000 psi. Ensure form 10-424 is sent in to AOGCC within 24 hours of Pressure Test. CORRELATION RUN 5. Pick up memory GR/CCL. Pick up and tag stuffing box for a zero. RIH at 60-80 fpm. Take diesel freeze protection initial returns to slop tank. Break circulation every 1000'. 6. Tag Landing Collar at 11,059' MD/5,125'TVD. Flag coil and POH while slowly circulating to back fill tubing displacement volume. 7. Make depth correlations for perforating. TCP PERFORATING 8. Pick up safety joint,TIW valve and any necessary crossovers to top of CT Jacking Frame. 9. Pick up and space out gun assembly to perforate the following intervals (3 runs required) Run Sheets are attached. Run j# - 10,880'to 10580'-300'guns Total BHA Length- 344' Run#2- 10,380'to 9,770' -610' Guns Total BHA Length- 653' Run#3- 9,470'to 9,420'-50'Guns 9,390'to 9,210'-180'Guns 9,130'to 9,060'-70'Guns Total Guns-300' Total Blank-121' Total BHA Length-442' Perforations 4.5" PowerJet 4505 HMX 4 SPF MD Perforation TVD Perforation From To Footage From To Footage tt-$ 9,060 9,130 70 4,954 4,966 12 9,210 9,390 180 4,979 5,010 31 9,420 9,470 50 5,015 5,023 8 2- 9,770 10,380 610 5,061 5,100 39 At. 1 10,580 10,880 300 5,109 5,119 10 Total Footage 1210 Total Footage 100 10. Make up Coil Tubing Running tools. 11. Pickup BHA and injector head with crane. Remove slip bowl. 12. Lower injector and make up lubricator connection. 13. Pick up and tag stuffing box. Set zero. RIH tagging float collar for depth conformation. Set guns to perforating depth. 14. Activate E-Fire head according to TCP specialist procedures. Verify firing. Check well for pressure. 15. Pick up to second interval depth. Pump ball to seat and perforate second interval. Verify firing. Check well for pressure. 16. Pull out of hole until connector tags stuffing box. 17. Check well for pressure. Open well and confirm well dead. Observe for 15 minutes. 18. Break lubricator connection and raise injector head. Disconnect coil. Set injector head off to the side. 19. Lay down spent perforating guns. Note: perform TIW stab-in drill at least once per shift. Record on daily report. 20. Repeat steps 8 through 19 for subsequent runs. WELL CLEAN UP 21. Pick up circulating wash nozzle and injector head with crane. Lower injector head and make up lubricator connection. 22. Run in hole to 11,059' MD/5,125'TVD while pumping N2 at a rate of 750-1250 scfm. Take returns through choke manifold to Ptank. Note Liner portion of well was displaced with FloPro perf fluid at 8.6 ppg. 23. Monitor returns for methane. Strap tanks for return volume. Continue pumping N2 until well is clean of brine and flowing gas. Shut off N2. 24. Flow well clean for one hour or until fluid is off perforations while POH with coil . Record pressures and rates. 25. Once coil is clear of tree, close upper and lower master and. Bleed pressure ott through choke manifold until no flow. Close swab valve. 26. Nipple down coil. Nipple down test equipment. Send fluids to Emerald Anchorage for disposal. 27. Release coil unit. CI GSA CLU Storage 5 PMC Wellhead- 13 5/8"5000#Multibowl Proposed FMC Tree-7"5000#complete with SSV Completion Schematic 02/2/2012 4 20" 133#X56 driven to 117.5'TVD/117.5'MD 7"Halliburton Wireline Retrievable SSSV @ 167'TVD/167'MD 4' .4: ) s eg 13 3/8"68#J55 BTC Surface Casing @ 2,013'TVD 12,390'MD 16' hole/Cemented to Surface , 0 zp P 16 it 1r v 4...---_,,,..-DV Collar @ 3,510' * 7"x 9 5/8"Baker ZXP Liner Top Packer 7 26#L80 with 10'seal bore @ 4,867'TVD/8,684'MD Vam Top Tubing „ 9 5/8"40#L80 BTC Intermediate Casing @ 4,916'TVD/8,860'MD 12 1/4"hole/Cemented to Surface 5k � 0 '; ' MD Perforation ND Perforation o' �17`-' t� From To Footage From To Footage S _ " . 9,060 9,130 70 4,954 4,966 12 i�4 - '' - , 9,210 9,390 180 4,979 5,010 31 " 9,420 9,470 50 5,015 5,023 8 w 9,770 10,380 610 5,061 5,100 39 10,580 10,880 300 5,109 5,119 10 714/4 Z A-11' asr ,, f Total Footage 1210 Total Footage 100 7"26#L80 Vam Top Production Liner from 4,867'TVD/8,684'MD TOP to 5,127'TVD/11,099'MD TD 8 1/2"hole/Cemented CINGSA PROJECT f % ``~°,a,_ COILED TUBING STACK UP iirf Kenai,AK } e . (T ifi '\\N\ i °i1}Pt4 i tie,..i fitiv a>. s 4.161 Conventional Snippet 10-25 ft Ct 7.&Y°hex icata s, t I Citi"Cs+rrrl�i IiQP '.o , 2.315"C'T$dr u*,-,Ktin*anw aeA*e1 t x r IOW SK W4?we Well Clean Rig Up 150 MAWP P-Tank >oo • SSV2" 2„ frBP Gas LoTorc ChokeMeasurement Tree T'5k ® relief Rain for Rent 100' • Tank . f 9 Rain for Rent 2"1502 as out\\ .. ® se > Tank . drain + 1 " ._...._.. 4'-206 _. _..._....,..___'� 150' ..__.___ ..�� ._.._.._._._.._.. 2'-1502 w1ngx \ 1001 4"-206 Thread ` ._._.._., + data 1502 4"-206.. . i 1 2 aheader header iliI i I y W .. . . .... _ ,.., _ ,, Gas to chorit tower Perforating Run Sheets Sclihntherpr Tubing Conveyed Perforating a Per: ABIIlag ES2ki Date C I NGSA CLUS 5 SLB 1 KENAI 1;12,2012 4.7.*4spi 4505PJ Cart of Enines=>18 Description Gun 0 Length Top Bottom Gan SM ISafety.kit.2-18`EJE I 2j 1625 15,537.01 10,553.26 ITC*eFre head I 11 11.18 10.553.26 10,564.44 10,584.44 10,580.00 puncher 10,580.00 10,585.52 5.0 ft bottom up 21 Gun 14 21.08 10,585.52 10,606.60 20 !Gun I 131 21.08 10,606.60 10,627.68 80 !Gun I 121 21.08 10,627.68 10,648.76 80 IGun I 111 21.08 10,648.76 10,669.84 80 !Gun I 101 21.08 10,669.84 10,690.92 20 !Gun 1 91 21.08 10,690.92 10,712.00 80 !Gun 1 81 21.08 10,712.00 10,733.08 80 IGun 71 21.08 10,733.08 10.754.16 80 IGun61 21.08 10,754.16 10,775.24 80 IGun 51 21.08 10,775.24 10,796.32 80 !Gun 4� 21.08 10,796.32 10,817.40 80 Gun 3 21.08 10,817.40 10,838.48 80 IGun 2� 21.08 10,838.48 10,859.56 80 Gun 1 I 20.44 10,859.56 10,880.00 80 IBM=mage I 0,8+3 10,8.0.03 '0.885 85 • �-BHA wigs. (C1W sl --� ('142) Depths are referenced by shot Iccaton. See ad adoidchal handout for physical lengths. Partially Loaded Gun-1 blonds Tap MD Bottom MI Net Blank Net Loaded spf Fully Loaded Gun-13 Blarcic ITga;i 10,584.44 /0.58.0 co Li 15 56 Bohern Gun-1 1 Loaded 10,580.00 10,880.00 300.00 4 Total Loaded 300.00 RUNTotal Bank 10,558.82 �/ Totai vrr Length10,888.82 To4a1 Sc hlurnberger BHA Lengtl 343.85 Ft. Prepared By Renewed By: Client Repnesentatve WC PiTCP..I .004 Soot Shier Nikolai Soshnr Conrad Perry Revision:AKA1.4-15 0eao07 rtfr S8rgr Tubing Conveyed Perforating Cern Dar s C1NGSA CLUS 5 SLB 1 KENA •. `2312 4.72"4s0 4505PJ Count of Entries=>33 Description Gun# Length Top Bottom Gun SIN jSafety Art.2-30 EJE j 21 1625 9,727.40 9.742 74 ICBF Firing Bead,518"BALL 1 11 4.50 9,743.74 2.74824 !Blank(Safety Spacer wdqu cher) 30! 2".08 9,748.24 .3.765.32 9,788.32 2.770 G0 I 9,770.00 9,790.40 20.0ft FULL GUN 80 Gun 28. 21.08 9,790.40 9,811.48 80 !Gun 1 271 21.08 9,811.48 9,832.56 80 !Gun 1 261 21.08 9,83256 9,853.64 80 !Gun 1 251 21.08 9,853.64 9,874.72 80 !Gun 1 241 21.08 9,874.72 9,895.80 80 ;Gun i 23i 21.08 9,895.80 9,916.138 80 IGun 221 21.08 9,916.88 9,937.96 80 I Gun 21 j 21.08 9,937.96 9,959.04 80 jGun 20j 21.08 9,959.04 9,980.12 80 jGun 1 191 21.08 9,980.12 10,001.20 80 jGun j 18j 21.08 10,001.20 10,022.28 80 jGun j 171 21.08 10,02228 10,043.36 80 IGun j 161 21.08 10,043.36 10,064.44 80 jGun I 151 21.08 10,064.44 10.085.52 80 jGun j 14j 21.08 10,085.52 10,106.60 80 jGun j 131 21.08 10,106.60 10,127.68 80 jGun j 121 21.08 10,127.68 10,148.76 80 jGun I 111 21.08 10,148.76 10,169.84 80 IGun j 101 21.08 10,169.84 10,190.92 80 IGun I 91 21.08 10,190.92 10,212.00 80 !Gun I 81 21.08 10,212.00 10,233.08 80 IGun I 71 21.08 10,233.08 10,254.16 80 jGun I 61 21.08 10,254.16 10,27524 80 !Gun 1 51 21.08 10,275.24 10,296.32 80 !Gun 1 4! 21.08 10,296.32 10,317.40 80 !Gun I 31 21.08 10,317.40 10,338.48 80 !Gun 1 2! 21.08 10,338.48 10,359.56 80 !Gun 1 11 20.44 10,359.56 10,380.00 80 ['Sodom nose 1 1 0.85 10,387.00 10.380.85 653.37 8W,1 Mylor, Count of Gans pales)-b 3 (2322) Depths are referenced by shot location. See additional handout for physical lengths_ Blank IGun Puncher)-1 Partially Loaded Gun-1 Intervals Top MD Baboon MIFF&Blank Net Loaded spf Fully Loaded Gun-27 Blank(Top) 9,748.24 9.77D CO Li 21.7: Schur Gun-1 1 Loaded 9,770.00 10,380.00 1 610.00 4 ' Total Loaded 610.00 iikile* Total&a,nk 21.70 Tota+Gun Length 63`.75 Tata Schlumberger BHA Lengtl 653.37 Ft. Primed By Rearecwd By Client Rep esenta Wi:.7TCP? .0 i4 _tot Sills, 1Jikola:Soshnin ...kiln Nish son?,fike aubb Revision:AKA1.4-1 7 toff Scillonthmipr Tubing Conveyed Perforating aient Well 112 fled Date G,.r+s CINGSA CLUS 5 SLS ' KENAI 1/12,2312 4.72'4sp'4505PJ Cart of Entries=>27 Description Gun4 Length Top Bottom Gun S/N (Safety Jrk.2-318'EUE I 21 18.25 9,028.59 9,044.84 ICBF Firing Bead,5/BALL I 11 4.29 9,044.84 9.049 04 8,049.04 9.080.0+ iris r±;+t': 9.060.00 9,070.12 39 .Gun 19. 21.08 9,070.12 9,091.20 81 !Gun 1 18! 21.08 9,091.20 9,112.28 81 ' _ _ 9,11228 9,130.00 FG Blank(Portal**puncher) 17 • - 9,130.00 9.133.38 'Blank(Gun Puncher) 1 t; 1 21.08 9.,133.38 9,154.44 •Blank(Gun Puncher) 151 21.08 9,154.44 9.175.52 . (Gun Puncher) 14' 21.08 9,175.52 9.198.60 ..; ,:, , ,i IL:.:24---- 9,198.80 9.210.00 .,k-te:,rGun(Partial) 7 9,210.00 9,217.68 29 (Gun 1 121 21.08 9,217.68 9,238.76 80 !Gun j 111 21.08 9,238.76 9,259.84 89 (Gun 1 101 21.08 9,259.84 9,280.92 80 (Gun 1 91 21.08 9,280.92 9,302.00 80 !Gun I 81 21.08 9,302.00 9,323.08 80 IGun I 71 21.08 9,323.08 9,344.16 89 IGun I 61 21.08 9,344.16 9,365.24 80 IGun I 51 21.08 9,365.24 9,386.32 80 Kon(Partial) 4 9,386.32 9,390.00 13 Blank Pana.riltuncher) 4 17. 9,390.00 9.407.40 grinch t Blank,Pa-34 wt;uncer) 3 12.,'. 9,407.40 9,420.00 "1' '.r Gtun(Penia) 3 8 9,420.00 9,428.48 31 Gun 2 21.08 9,428.48 9,449.56 80 IGun 1. 20.44 9,449.56 9,470.00 80 [Bottom nose � 0.850 9,470.00 9.470 Sri <-sib tangonr or GIRLS(Craves; --- ('1541, Depths are referenced by shot location. See addtional handout for physical lengths. Inters Top MD Bottum MDI INet Blank Net Loaded spf Blank lGun Pundrer)-3 Blank(Top) 9,049.04 9.060.0{1 U 13.98 Partially Loaded Gun-5 1 Loaded 9,060.00 9,130.00 7.3.37 4 Fully Loaded Gun-11 Blank 9,130.00 9,210.00 Li 83.X BaMom Gun-1 2 Loaded 9,210.00 9,390.00 18C.X 4 Blank 9,390.00 9,420.0933 3G 3 Loaded 9,420.00 9,470.00. 5,.1.1. 4 1 Total Loaded 300.00 GuTotal Length 42:1.96 Total Scheurnberger B1-1A Lengtl 44227 Ft. Prepared By Reuien d ByClient Representatve: WCPITC P/SIJP-{5+4 Scot Shite N4olas Soshn=- .k hn t otsort't4ke C-tubb Revision:AKA1.4-155-Lees-07 toft Cook Inlet Natural:Gas Cook Inlet Natural Gas Storage Alaska,LLC 3000 Spenard Road PO Box 190989 STORAQ1$ Q Fax:907-334-7671 www.cingsa.com February 6,2012 Alaska Oil and Gas Conservation Commission RECEIVED 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 FEB 0 6 2012 Re: CLU Storage 5 Alaska Oil&Gas Cons.Commission Application for Sundry Approvals Anchorage Cook Inlet Natural Gas Storage Alaska,LLC (CINGSA) is requesting Sundry Approval to perforate and clean up CLU Storage 5. The well was suspended on January 23, 2011 pending Coil Tubing perforating. There are currently no open perforations in the well and 8.6 KCL brine was left in the 7-inch tubing string. The tubing was tested to 3,000 psi. CINGSA proposes to rig up a 2 3/8-inch coil tubing unit and well test equipment on location February 9, 2012. The operations as described in the attached outline well procedures will take place in three phases. First, a correlation run will be made with coil and a Gr/CCL memory log to ensure proper depths. Second, a series of coil conveyed perforating runs will be made. Perforating will take place overbalanced.The current expected BHP is 380 psi,however,virgin pressure pockets may be expected up to the datum pressure of 2,206 psi. A viscous polymer pill was left in the liner to inhibit losses. The final phase will be well clean. Coil will be run in hole to bottom while displacing the brine with nitrogen. The well will be flowed back via a choke manifold to a P tank. Fluids will be recovered in a frac tank and gas will be either flared or vented through a flare stack. The well flow is not expected to last more than 4 hours after the brine is off the perforations. The return gas will be measured via a turbine meter for relative volumes. CINGSA does not consider this well clean up procedure a well test. If you have any questions or require additional information,please contact Tom Arminski at 907 334-7743 or email to tom.anninski(jenstarnaturalgas.com. Sincerely, AiPth,„, d771-wor M. Colleen Starring Vice President Enclosure as stated Page 1 of 1 Schwartz, Guy L (DOA) From: Conrad Perry [cperry@att.net] Sent: Tuesday, February 07, 2012 8:52 AM rT "D VI' I S To: Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA) Cc: 'Richard Gentges'; 'Well Pad' Subject: RE: CINGSA Update Saturday morning we should be back on CLU Storage 4 for 2 1/2 days, then 4 days on CLU Storage 3, before getting to CLU Storage 5. conrad From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, February 07, 2012 8:40 AM To: cperry@att.net; Saltmarsh, Arthur C (DOA) Cc: Richard Gentges; Well Pad Subject: RE: CINGSA Update Conrad, We have the CLU St 5 sundry request and 407 report. Do you have an estimate as to when you will get the coil back up and running? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Conrad Perry [mailto:cperry@att.net] Sent: Tuesday, February 07, 2012 7:15 AM To: Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA) Cc: Richard Gentges; Well Pad Subject: CINGSA Update Guy/Art, We ran into a couple of speed bumps. CLU Storage 3 had some cement on bottom so we moved over to CLU Storage 4 while waiting on a motor and mill. After two perforating runs on CLU Storage 4 the coil sprung a pinhole leak. We are currently waiting on a new coil reel from the slope to finish CLU Storage 4 (one more perf run). Plan after CLU Storage 4 is to return to CLU Storage 3. Coil is expected in Kenai on Friday afternoon. I believe we have submitted the 407 suspension report for CLU Storage 5 and the 403 perforating sundry. I am working on getting the 426 MIT form filled out. At the conclusion of the well perforating I will submit final 407s. We really appreciate the agency working through the paperwork with us. • Best Regards, conrad 2/7/2012 Page 1 of 1 Schwartz, Guy L (DOA) From: Conrad Perry [cperry@att.net] n-;-7) 21(—Q II Sent: Tuesday, February 07, 2012 8:52 AM To: Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA) Cc: 'Richard Gentges'; 'Well Pad' Subject: RE: CINGSA Update Saturday morning we should be back on CLU Storage 4 for 2 1/2 days,then 4 days on CLU Storage 3, before getting to CLU Storage 5. conrad From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, February 07, 2012 8:40 AM To: cperry@att.net; Saltmarsh, Arthur C (DOA) Cc: Richard Gentges; Well Pad Subject: RE: CINGSA Update Conrad, We have the CLU St 5 sundry request and 407 report. Do you have an estimate as to when you will get the coil back up and running? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Conrad Perry [mailto:cperry@att.net] Sent: Tuesday, February 07, 2012 7:15 AM To: Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA) Cc: Richard Gentges; Well Pad Subject: CINGSA Update Guy/Art, We ran into a couple of speed bumps. CLU Storage 3 had some cement on bottom so we moved over to CLU Storage 4 while waiting on a motor and mill. After two perforating runs on CLU Storage 4 the coil sprung a pinhole leak. We are currently waiting on a new coil reel from the slope to finish CLU Storage 4 (one more perf run). Plan after CLU Storage 4 is to return to CLU Storage 3. Coil is expected in Kenai on Friday afternoon. I believe we have submitted the 407 suspension report for CLU Storage 5 and the 403 perforating sundry. I am working on getting the 426 MIT form filled out. At the conclusion of the well perforating I will submit final 407s. We really appreciate the agency working through the paperwork with us. Best Regards, conrad 2/7/2012 Page 1 of 1 r " L . Schwartz, Guy L (DOA) From: Conrad Perry [cperry©att.net] ,�l_ 1 ZZ Sent: Tuesday, February 07, 2012 8:52 AM PT To: Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA) Cc: 'Richard Gentges'; 'Well Pad' Subject: RE: CINGSA Update Saturday morning we should be back on CLU Storage 4 for 2 1/2 days,then 4 days on CLU Storage 3, before getting to CLU Storage 5. conrad From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, February 07, 2012 8:40 AM To: cperry@att.net; Saltmarsh, Arthur C (DOA) Cc: Richard Gentges; Well Pad Subject: RE: CINGSA Update Conrad, We have the CLU St 5 sundry request and 407 report. Do you have an estimate as to when you will get the coil back up and running? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Conrad Perry [mailto:cperry@att.net] Sent: Tuesday, February 07, 2012 7:15 AM To: Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA) Cc: Richard Gentges; Well Pad Subject: CINGSA Update Guy/Art, We ran into a couple of speed bumps. CLU Storage 3 had some cement on bottom so we moved over to CLU Storage 4 while waiting on a motor and mill. After two perforating runs on CLU Storage 4 the coil sprung a pinhole leak. We are currently waiting on a new coil reel from the slope to finish CLU Storage 4 (one more perf run). Plan after CLU Storage 4 is to return to CLU Storage 3. Coil is expected in Kenai on Friday afternoon. I believe we have submitted the 407 suspension report for CLU Storage 5 and the 403 perforating sundry. I am working on getting the 426 MIT form filled out. At the conclusion of the well perforating I will submit final 407s. We really appreciate the agency working through the paperwork with us. Best Regards, conrad 2/7/2012 STATE OF ALASKA ALASKA-.L AND GAS CONSERVATION COMMIS6 ,1V WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: Service Q Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: Cook Inlet Natural Gas Alaska,LLC Aband.:01/23/2012 211-158 3.Address: 6.Date Spudded: .13.API Number: P.O.Box 190989,Anchorage,AK 99519 12/22/2011 50-133-20601-0000 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 720'FNL 1760 FEL SEC.9 T5N R11W 1/7/2012 CLU Storage 5 Top of Productive Horizon: 8,836'MD/4912'TVD 8.KB(ft above MSL): 15.Field/Pool(s): 559'FSL 1959'FEL SEC.8 T5N R11W GL(ft above MSL): 33 Cannery Loop/Sterling C Pool Total Depth: 11,101'MD/5,127'TVD 9.Plug Back Depth(MD+TVD): 967'FNL 1657 FWL SEC.17 T5N R11W 11,059'/5,125' 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x- 281845.44 y- 2392832.83 Zone- 4 11,101' /5,127' ADL 391627 TPI: x- 276299.39 y- 2388922.06 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x- 274613.794 y- 2387432.61 Zone- 4 167'/167' ADL 230925 18.Directional Survey: Yes Q No U 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: GRAM,CALM,RPC-SHM-SLM-CLM; BDCM,NPCKSM,DPEM,MagTrak-8 1/2"only N/A 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT FT. TOP BOTTOM TOP BOTTOM PULLED 20" 133 X56 23 117.5 23 117.5 Driven N/A 13 3/8" 68 J-55 22 2,390 22 2,013 16" 516sx 12.2 lead/295 sx 15.4 tail ----1/9A/ 9 5/8" 40 L-80 20.5 8,860 20.5 4,916 12 1/4" Stage 1-695 12 ppg lead,209 sx 14 ppg tail aT Stage 2 493 sx 12.0 ppgDV @3,510'MD 5. 7" 26 L-80 8,684 11,099 4,867 5,127 8 1/2" 301 sx 14.0 ppg 24.Open to production or injection? Yes❑ No If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 7" 8,684 8,684/4867 RECEIVED 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. i • :Ja., L= a DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED �-` FEB 0 0 2012 , 'r -rte`^Y Alaska Oil&Gas Cons. Commission 27. Anchorage PRODUCT ON TEST Date First Production: - Methed-of Opefetion(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period -0. 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 MC 25.071. RBDMS FEB 0 7 2012 A Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Z jEPLSUbIorigin?! 0j11y 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? ❑ Yes ❑ No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base B5 Coal 8790 4900 Sterling Cl 8836 4911 Sterling C2 9757 5060 Formation at total depth: Sterling C2 31. List of Attachments: Directional,Cement and Mud Summaries,Daily Drilling Reports,Current Well Schematic, Well Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tom Arminski 907 334-7743 Printed Name: M. Colleen Starring Title: Vice President Signature: / Phone: 907 277-5551 Date: AZ-4 'V's2 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 lb: 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 ND 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 Cook Inlet Natural:Gas Cook►nlet Naturl Gas Storage Alaska,LLC 3000 Spenard Roaad PO Box 190989 STORAAnchorage, 99519-0989 t' ;�-i Main:907-334-7980 ¢ Fax:907-334-7671 www.cingsa.com RECEIVED February 6, 2012 FEB 0 6 2012 Alaska 011& Cas Cons, Commission L Anchorage Alaska Oil & Gas Conservation Commission - 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Records and Reports Information Acquired from Operations Well: CLU Storage 5 In accordance with 20 AAC 25.070(3), CINGSA hereby submits the records and reports related to drilling of its well, CLU Storage 5. Thank you and if you have any questions, please do not hesitate to contact Tom Arminski at 907 334-7743 or tom.arminski(&,,enstarnaturalgas.com. Sincerely, Atte/fee-0u d4Cer/XAr M. Colleen Starring Vice President Enclosure as stated CLU Storage 5 - Well Suspension Report Transmittal Hard Copies 1. CINGSA CLU Storage 5 Well Document Transmittal Notice 2. AOGCC Well Completion or Recompletion Report and Log Form 10-407 3. Daily Drilling Reports 4. Mud Recap 5. Directional Report including surveys, plot and section views,and Bit Record 6. Cementing Recap 7. Well Schematic 8. CINGSA Well D (CLU Storage 5)AS BUILT Electronic Copies (thumb drive or CD) 1. CLU Storage 5- Daily Drilling Report-checked.pdf 2. CLU Storage 5-9-22-2011 Completion Schematic.pdf 3. CLU Storage 5 Directional End of Well Report.pdf 4. CINGSA CLU Storage 5 Cementing Recap_redacted.pdf 5. CLU Storage 5-Mud ReCap_Redacted.pdf 6. CLU Storage 5 NAD27 Directional Data File.xlsx 7. CLU Storage 5 Certified Location As Built.pdf 8. 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TRACT F / I` s''.391-;.\ KN 2005-122 i `� `', z STATE OF ALASKA // ' • 1 `` .",'\ • i 03 oN Z CINGSA 1 , 1 N o'o r` DRILL PAD 11 ` �0 I— / i 1 ,•\ l - wp / 1 nz / \ • \ \ ' \\ CINGSA V ELL' " 1,\ \ I , SURFACE LOCATION 1 ` \ , NAD27ASPZONE4 ,, GRID N:2392832.93 ` GRID E:281845.44 ', , :l) LATITUDE:60°32'39.0076" ` . 1 LONGITUDE:-151°12'42.1745" 1 ELEV:32.98 , , ' 1760' ', FEL • ,' 1 z �' z z r E, a 6 F O O ,,\ W W > < , , 1 ----'---`2_, 1 ` 11 ` 1 , \ .._, 1 1 1 , 1 I I II , 1 . SURVEY CONTROL 1) BASIS OF GEODETIC CONTROL AND NAD83 POSITION / `1. (EPOCH 2003)IS STATE OF ALASKA DEPARTMENT OF TRANSPORTATION&PUBLIC FACILITIES SURVEY CONTROL AKSAS PROJECT NO.58703 BENCHMARK 601 ALASKA STATE PLANE COORDINATES(ASP)ZONE 4 ARE: NORTH N=2393464.742 ��.►� E=1422055.815 --.16, 2)BASIS OF VERTICAL CONTROL IS ADOT BM 601 LOCATED SCALE AT BRIDGE ACCESS RD. BEAVER LOOP RD. INTERSECTION 0 150 300 ELEV. :42.20 FT. NAVD88. FEET REVISION: - Cook Inlet Natural Gas CINGSA WELL"E" DATE 8/10/11 (� P.O. BOX 190288 PROJECT STORA .:','• '�' ANCHORAGE, AK 99519 AS BUILT WELL SURFACE DRAWN BY BOB LOCATION DIAGRAM NAD 27 SCALE 1'=100' PROJECT NO. 103049 j ENGINEERING/MAPPING/SURVEYING/TESTING LOCATION BOOK NO. - Corralling l,< P.O.BOX 468 SOLDOTNa A(99069 SEC. 9 T5N R11W SHEET MCI-Att. VOCE:(907)283-4219 FAX(907)2833265 � EMAIL: SAMCLANEQMCIANECGCOM SEWARD MERIDIAN, ALASKA 6 °F 6 IW W J Z Q • V Z I CO O O P I- O I- � 1 Oz 3 fi1� z� .I- 33 N-.B) z1z O I o TOP STERLING C 1- F- UJi�Ui NAD 27 ASP ZONE 4 cO z I GRID N:2388922.060 o I GRID E:276299.390 0 U LATITUDE:60°31'59.482" CI � 1 LONGITUDE:-151°14'31.566" j 1959' / • FEL I in(/' u_ • 7g148 SECTION 8 TSN R11W — SECTION LINE 18T17 SECTION 17 T5N R11W— —N NOT TO SCALE — — — — — 8 9 - ,�T,6 I ALL I I 1657'---------1TD 1 313 FWL NAD 27 ASP ZONE 4 '&. GRID N:2387432.610 Il'27 I � F • GRID E:274613.794 E m I` LATITUDE:60°31'44.501" F_F z•O LONGITUDE:-151°15'04.684" I.II 0z z 0 I U O O w w 17 CO'In UJ Lu w I u) w SURVEY CONTROL 1)BASIS OF GEODETIC CONTROL AND NAD83 POSITION (EPOCH 2003)IS STATE OF ALASKA DEPARTMENT OF TRANSPORTATION&PUBLIC FACILITIES SURVEY NORTH CONTROL AKSAS PROJECT NO.58703 BENCHMARK 601 ALASKA STATE PLANE COORDINATES(ASP)ZONE 4 ARE: N=2393464.742 E=1422055.815 SCALE 2)BASIS OF VERTICAL CONTROL IS ADOT BM 601 LOCATED 0600 1200 I AT BRIDGE ACCESS RD.BEAVER LOOP RD.INTERSECTION 1II FEET ELEV.:42.20 FT.NAVD88. ((''��''�� 1 �"+ . REVISION: - Cook Inlet Nafural,Gas DATE: 2/1/12 STORAQ„ ANCHORAGE, AK 99519 P.O. OX 190288 '� PROJECT CINGSA CLU STORAGE SURFACE LOCATION DIAGRAM NAD 27 DRAWN BY: BOB ter` SCALE: 1' 00' PROJECT NO. 103049 BOOK NO. - ConsultingENGINEERING/MAPPING/SURVEYING/TESTING LOCATION SEC. 17 &8 T5N R11 W SHEET Consulting Inc P.O.BOX 468 PINGSOLDOTNA,AK.99669 VOICE:(907)283-4218 FAX:(907)283-3265 EMAIL:SAMCLANE@MCLANECG.COM SEWARD MERIDIAN,ALASKA 1 OF 1 q Cook Inlet Naturaj:Gas . ... . , ,, ---, ., -3 • I- .,‘,..,-;.. '-'7,- -- . �.-3.•,..._-- —�-,mss, `' yy d ,,,. , �f,,0.. STORAQa ..,....-r-, -, , ! ., - -,... -.:.--17----r- ^..n�k .xy�«y, wsy.�.4 r Tz. ry �^5 tr.�.ai..r.:zL `1. .._ "�`t-'� %,:',„..4.i,,,,-,-,t4� ,.'r���`�k tea{ ice; �' , ,.. y ........,,-„,-,..1-,;,,,,,, CINGSA 7t :eke. �� {� . - _ �.-,. . ,::".„ CLUStorage5 is. f i. CanneryLoopUnit .--..,,,,,,,,...„ ..,.,...,,,=-:.:,).3::'r; - f,- .1...i,.. ,0-'..;.-.-„,,,.„ . ? 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Cook Inlet Natural Gas Storage Alaska Cannery Loop #5 Kenai, Alaskaa Prepared by. Pete Nelson Reviewed by. Ray Figueroa Presented to: Conrad Perry Date: January 20, 2012 Mi SWAG Cook Inlet Natural;GQs CINGCa STORA Well. Cannery Loop #5 QS A Schlumberger Company Kenai, Alaska Table of Contents 1 , EXECUTIVE SUMMARY 2. SUMMARY OF FLUID RELATED COST 3. PROJECT SUMMARY 4. WELL SUMMARY 5. PROJECT COST SUMMARY 6. INTERVAL DISCUSSION 7. PRODUCT SUMMARY 8. DRILLING FLUIDS SUMMARY 9. HYDRAULICS SUMMARY 10. DAILY DISCUSSION 11 . FLUID VOLUME SUMMARY 12. HIGHLIGHTS / RECOMMENDATIONS 13. APPENDIX A. PRODUCT CONCENTRATIONS B. HOUSTO\ LAB RESULTS Mi SWAG CINGSA Cook Inlet Natural;CQs STORAWeIL Cannery Loop #5 J �,J as a A Schlumberger Company Kenai, Alaska EXECUTIVE SUMMARY No incidents or spills attributable to M-I SWACO personnel occurred .41, itteduring the drilling and completing of this well. Safety Meetings attended - 28 meetings 4 RONNIE6P C�7 Man-hours worked - 672 hours The drilling phase was shorter than expected due to high ROP, IFEoperational efficiency, and no major problems. Liner running did encounter issues with thick mud and was pulled and re-run. MiSWA� Minor formation losses occurred in all intervals of CLU #5. Losses were more significant in the injection interval. MiSWAB LoTorq and Lube 776 were successfully used in combination as lubricants on this well with very good performance for reducing torque and drag and minimizing bit stick / slip. M� SWACO - CINGSA Cook Inlet Natural Gas STORAG p A Schlumberger Company Well: Cannery Loop #5 as`Q Ni* Kenai, Alaska Project Sum m a ry IFE Project Services Summary MISWACO Well Name: Cannery Loop #5 Casing Program Conductor 118"" Bit Interval Planned Actual Size Depth Days Days 16 2,376 6 4 ?µ`7 12.25 8,860 7 8 8.5" 11,101 10+1 13+1 24 26 Comments: DF = Drilling Fluids with engineering CF = Completion Fluids with field engineering services Mi SWAC Cook Inlet Katural;Gas CINGSA STORAQ 1 p • A Schlumberger Company Well. Cannery Loop #5 \ as a Kenai, Alaska Wel I Summary M i SW_I. 0000/- A Schlumberger Company RECAP - WELL SUMMARY Operator: CINGSA Well Name: CLU Storage#5 Well Location: Kenai,Alaska Spud Date:12/22/2011 Contractor:Nabors Drilling Toatl Depth(TD/TVD)11101 ft/5107 ft TD Date:1/8/2012 Project Engineer f-Iaag/Nelson Max Temp/Max Angle120°F/87°inclin. Field/Area Cannery Loop/Kenai Fluids Engineer Brown/Rooney Max Mud Weight 9.4 lb/gal Description Sec.9/T5N/R11W,sm Fluids Engineer Faulkner/Smith Warehouse:Nikiski,Alaska Total Days to TD 18 M-I Well No.137676 Air Gap/Water Depth 0/0 ft End of Well Final well for Enstar/CINGSA Comments: Csg Depth Depth Hole Max.Mud Max Max. Int. Inteval Dates Int. Casing Frac. Principal TD/TVD Drilled Size Weight Angle Temp. No. Days Size/Type Gradient Fluid Type Begin End (ft) (ft) (in) (lb/gal) (degrees) (°F) 13.375 in l 22-Dec-Il I 25-Dec-11 4 2376/2000 2,400 16 9.2 62.00 90 Spud Mud Casing 9.625 in 2 26-Dec-11 2-Jan-I2 8 8860/4918 6,472 121/4 9.4 70.00 110 Kla-Shield Casing 7 in 3 3-Jan-12 15-Jan-12 13 11101/5107 2,229 81/2 9.4 87.00 100 Kla-Shield Liner 7 in Potassium 4 16-Jan-12 16-Jan-12I Completion 11101/5107 8 1/2 8.6 87.00 120 Chloride rluidv 5 Mi SWAC Cook Inlet Natural Gas CINGSA STORAGE A Schlumberger Company Weil; Cannery Looe #5 as a ;3 8p Kenai, Alaska SUMMARY OF FLUID RELATED COSTS Mi SWACa A Scldhaoe'ter - WELL COSTS SUMMARY v Operato£INGSA Contractddabors Drilling Descriptidec.9/T5N/R11 W,sm TD/TVD1101 ft/5107 ft Well Narfidil Storage 05 Field/Anfaannery Loop/Kenai LocatioiCenai,Alaska Max.Well Tet:/13:°F Start Dat 2rDec-11 End Datk6-Jan-12 Total Days to ID: Max.Well Arte: Entire Interval 0 Interval 0 2 Interval 0 3 Interval 0 4 Interval 0 5 Interval 0 6 Interval 0 7 Interval 0$Interval 0 9 Interval 0 10 Well/Project Fluid Type Spud Mud Kla-Shield Kta-Shield Potassium Chlnridr Starting Depth(MU) ' 0 2,376 8,860 11,101 Final Depth(MD) ft 2,376 8,860 11,101 11,101 11,101 Depth Drilled ft 2,400 6,472 2,229 ii Hole Size in 16 12 9 9 Casing Size in 13 10 7 7 Casing Type Casing Casing Liner Completion Fluids Start Day 22-Dec-11 26-Dec-Il 03-Jan-12 16-Jan-I2 22-Dec-11 End Day 25-Dec-11 02-Jan-12 15-Jan-12 16-Jan-12 16-Ian-12 Total days 4 8 13 1 Mi CINGSA Cook Ielet NaturQl,FGcts STORAGE Well: Cannery Loop #5 J 1 ° A Schlumberger Company • 115 Kenai, Alaska Drilling Interval Sum mary Surface Interval 0— 2,376' MD, 2,000' TVD 16" Open Hole /13-3/8" Casing 8,8 - 9.2 ppg Gei Spud Mud The surface interval was drilled, casing run, and cemented in 4 days. M-I Swaco mud engineers were called out 12/20 to mix new spud mud for drilling. The well was spudded on 12/22/11 at 12:20 P.M. on the 13.375"casing on 12/25/11 at 04:00 A.M. Cement was in place A 16" bit (HCC VM1) and mud motor was picked up and ran in. The conductor had been previously cleaned out to 118' by a truck mounted rig. The shakers were fitted with 165 mesh screens (API 100). Drilling ahead began with penetration rates of 100 - 300 fph. The first 500' was predominantly clay/sand with a gravel layer between 200 - 250'. Pump rates for the first 400' were kept at 425 gpm to avoid excessive washout. A 40 bbl high viscosity sweep was built in the pill pit to be used at the driller's discretion. Several more sweeps were pumped in the first 2000' to clean-out the unconsolidated sand a n d gravel. For most of the surface hole, the funnel viscosity was in the 55 - 65 sec/qt range and the YP @18 - 25. Water was run at 10 - 25 bph to maintain volume. M-I Gel and Gelex were added to maintain viscosity while adding water. By-900',the pump rate was up to 600 gpm. Hole cleaning for the surface hole was good and connections were problem free to TD. High viscosity sweeps were pumped at 400 - 500' intervals. There were no problems with fill on connections and no short trips were made while drilling the surface hole. The rig's Derrick centrifuge was running most of the time while drilling. Sand content never exceeded 1.0 % but it was in the 0.25 - .5% range for most of the surface hole. The final mud weight was 9.2 ppg. The funnel viscosity was 55 with a YP of 19. PolyPac Supreme was added at 1 ppb beginning at 1,850' to reduce the fluid loss to <10 cc. After rigging up, the 13-3/8"casing was run to 2,376' without incident. There was about 30 bbls of losses while running the casing, mostly in the first 1,200'. An inner string was run using the 5" drill pipe that stung into the"EZ Cementer". A full casing volume was circulated without losses. The cement job went well and the 12.0 ppg cement made it to surface. There were no losses while cementing. The cement job began with 40 bbls of 10.2 ppg mud push followed by 210 bbls of 12.0 ppg lead cement, followed by 64 bbls of 15.4 ppg tail cement. The cement was then displaced from the inner string with 39 barrels of 9.1 ppg spud mud. Cement was in place at 04:00 12/25. MI SWAG Cook Inlet Natural;Gas CINGSA SToRA Well: Cannery Looe #5 J 1' o A Schlumberger Company as°y Kenai, Alaska Mi SWAc9 DRILLING FLUIDS & VOLUME SUMMARY A Schlumberger Company INTF R V A T. 1 Operator: CINGSA Description: Sec.9/T5N/R11W,sm 1 V 1 f��l Start Depth/TVD: 0ft/0 ft Well Name: CLU Storage#5 Location: Kenai,Alaska End Depth/TVD: 2376 ft/2000 ft Contractor: Nabors Drilling Field/Area: Cannery Loop/Kenai Total Depth Drilled(ft): 2,400 Start Date: 22-Dec-11 Mud Type: Spud Mud Maximum Interval Angle e): 62 End Date: 25-Dec-1l Hole Size(in): 16 Maximum Interval Temperature(°F): 90 Interval Days: 4 Casing Size(in): 13 3/8 Fracture Gradient(lb/gal): Water Depth(ft): Top of Liner(ft): Maximum Interval Mud Weight(lb/gal): 9.2 PRODUCT&MUD ENGINEERING USAGE ON THIS INTERVAL Product Concentration Total Rig Time Distribution Product Name Unit Cost($) Total Cost($) %Total Cost (Ib/bbl) Units Min Max Average Name Days CAUSTIC SODA 2 0.26% 0.030 0.064 0.053 Rig Up/Service 0.08 CF DESCO II 14 2.18% 0.141 0.187 0.164 Drilling 1.21 ENGINEERING SERVICE 15 53.57% Tripping 0.92 GELEX BENT EXTENDER 0.000 0.002 0.001 BOP NU 0.35 M-1 GEL EXPORT 630 29.07% 8.857 18.856 14.227 Cementing 0.13 M-I WATE(BARITE) 136 6.13% 2.955 3.597 3.276 Condition Mud 0.44 POLYPAC SUPREME UL 8 4.16% 0.120 0.255 0.210 Direction Work 0.04 PORTABLE ARTIC MUD LAB RENTAL 8 3.99% Reaming 0.02 PRE-JOB SAFETY MEETING 12 Rig Repair 0.17 SODA ASH 1 0.08% 0.015 0.032 0.026 Running Casing 0.46 SODIUM BICARBONATE 8 0.56% 0.242 0.242 0.242 Wait on Cement 0.04 Well Head Work 0.15 100% Total Days 4.01 Volume Description Volume(bbl) Losses Detail(bbl) 1.Volume on board @ start Shakers 692 2.Received Haul off 587 3.Back Loaded/Transferred Formation 75 4.Remaining 850 Dumped 11 5.Volume Built 2,204 Left Behind Csg 6.Surface Volume Lost 1,290 Centrifuge 7.Subsurface Volume Lost 75 Left in Hole Interval Comments: De-Silter Fluid Processed Total Mud Losses(bbl) 1,365 Cook Inlet Natural Gas MI SWAB CINGSA STOP A Well: Cannery Loop #5 J 1 I11'1 '� A Schlumberger Company ff'"u - Kenai, Alaska Drilling Interval Summary Inter mediate I nterval 2,376' MD (2,000' TVD) — 8,860' MD (4,918') TVD 12-1/4" Open Hole/ 9-5/8" Casing 8.8 - 9,4 ppg Kla-Shield Drilling Fluid The intermediate interval took 8 days with actual drilling completed in 4 days. The 9 5/8" casing was successfully run and cemented. Approximately 600 barrels of new KLA-SHIELD mud were built in pits 1 through 6 while the BOPE was nippled up and tested. The mud weight was 8.9 ppg with a 45 funnel viscosity and a 22 yield point. The shakers were screened to 200 mesh screens (API 120). A 12.25" bit (HCC QD 505XX), AutoTrak, MWD, and LWD were picked up and run in the hole. The cement, shoe, and 20' of new formation were drilled out to 2,420'. The spud mud was displaced out of the hole with the new KLA-SHIELD at 8 to 9 barrels per minute. A FIT was performed to 15.5 ppg EMW. After the displacement, pit 6 was cleaned and an additional 100 barrels of new KLA-SHIELD mud was built. This was repeated several times to bring the active pit volume up to 650 barrels. Drilling ahead proceeded with rates of penetration in the 200 to 250 feet per hour with an inclination of 62 degrees. This angle was held for most of the intermediate hole. Hole cleaning appeared good based on the amount of cuttings coming over the shakers. At 2,900', a 40 barrel high viscosity sweep (FV=170) was pumped around and resulted a 25% to 50% increase in cuttings. Sweeps continued to be pumped at-500' intervals all the Way to TD with about the same results. Chemical additions were added as per the mud program. Water was run at 20 to 30 barrels per hour while drilling ahead. Flowzan was added to maintain a yield point of —20. LoTorq was added beginning at 3,000' and maintained at a 3% concentration. PolyPac Supreme was added at 2 pounds per barrel to lower water loss to 5 to 6 cc range. KCL was added to maintain a 6% concentration. SafeCarb 40 was strung-in to the active system as bridging material to control seepage losses. The centrifuge was run continuously while drilling to remove drill solids. At 4,900', a wiper trip back to the shoe was made. The trip out started on elevators. However, by 4,000' it was necessary to pump and back ream the rest of the way to the shoe. The trip back in on elevators found the same tight spot which was associated with a clay/claystone interval. This was washed and reamed through. Washing and reaming continued until back on bottom. Drilling ahead continued to 6,529' where another wiper trip was made while back reaming and pumping up to 4,709'. There was tight hole from 5,571' to 5,475' that was worked through. The trip back to bottom was done on elevators with no problems. M� '.SWAG CINGSA Cook Inlet Natural:Gas STOD A (�' E ASchiumbergerCompany Well; Cannery Loop #5 J Il!'11 0.$ ,1 Kenai, Alaska frrlff ttt At 7,000', CINGSA requested that the lubricant concentration be increased to 4%. Both Lo I orq and Lube 776wereused to iincrease the concentration and maintain it until TD. At approximately 8,000', Asphasol Supreme and Resinexeconcentrations were increased in preparation for drilling the coals near the top of the Sterling Formation, The coals were drilled without problem and the top of the Sterling was drilled without losses. By 8,500', the torque was increasing with each stand. The lubricant concentration was still at 4%. From 8,600' to TD at 8,872' the torque was in the 20K to 23K ft-lbs range. Although high, it was manageable for the top drive to make it to TD. Upon reaching TD at 8,872', a 10 stand wiper trip was made and a lubricant pill spotted on bottom. A bottoms up was circulated and a sweep was pumped around. This was followed by back reaming out 10 stands and then running back to bottom on elevators. Another sweep was pumped around and circulation continued until the shakers cleaned-up. A 100 barrel, 10.1 ppg, 12% lubricant, 40 ppb LCM (Safecarb) pill was spotted on bottom covering 500' of open hole. This was to stabilize the B-5 coal and to "slick up"the hole for running casing. To get above the pill, 10 stands were pulled on elevators. The 10 stands pulled out of the hole without problems. The remainder of the trip was made by back reaming and pumping all the way to the shoe. There was tight hole from 7,391 to 6,241' which required double wiping on some stands. At the shoe, a bottoms up was circulated to clean-out the casing. A 100% increase in cuttings was observed while circulating at the shoe. A dry job was pumped and the trip out continued. The drilling BHA was laid down. At TD, the mud weight was 9.4 ppg with a 20 yield point and the funnel viscosity was 56.0The lubricant concentration was at 4%. Black product concentration was at 6 ppb. Fluid loss was at 5.8 cc. Weatherford was rigged up and the 9 5/8" casing was successfully run and landed at 8,861'. When at the 13 3/8" shoe, the mud was circulated and conditioned with Desco and sodium bicarbonate. While running through the open hole, a bottoms up was circulated at 4,000', 5,500', and 7,000'. During each circulation, Desco and sodium bicarbonate were mixed. The last joint and the landing joint were washed down and the casing was landed without problems. After the casing was landed, a full casing volume was circulated (670 barrels) at a rate of 6 barrels per minute. Water was run at 20 barrels per hour to thin the mud. While circulating with the casing on bottom there were no losses. Preparations were made for cementing. The 9 5/8" casing two stage cement job was successful, although there was a significant amount of excess cement to surface for both stages. The first stage began with the rig pumping 37 barrels of 10.2 ppg mud push, followed by Schlumberger pumping 266 barrels of 12 ppg lead, followed by 48 barrels of 14.0 ppg tail cement. The rig then displaced the cement with 665 barrels of mud at 6 to 7 barrels per minute to bump the plug. There were no losses while pumping the 1g stage. Cement made it to surface while displacing. About 150 barrels of mud push, cement contaminated mud, and cement were diverted to the cellar. The DV collar was then opened. A bottoms up was circulated with the rig pumps. It was d The to dump approximately 190 barrels of excess cement and cement contaminated mud. The 2n stage began with 38 barrels of 10.2 ppg mud push, followed by 212 barrels of 12 ppg cement. 1 he cement was then displaced with 266 barrels of mud. About 155 barrels of mud push, cement, and cement contaminated mud was dumped at the surface. A final cement sample from the cellar weighed 11.9 ppg. This completed the 9 5/8"casing cement job. Mi SW ..,- N. AG Cook Inlet NaturQl;GQs CINGSA STORAQE ASchlumbergerCompany Well: Cannery Loop #5 as a Kenai, Alaska Mi SWA__CC9._ - DRILLING FLUIDS & VOLUME SUMMARY A Schlumberger Company - INTF R V A i. 2 Operator: CINGSA Description: Sec.9/T5N/21 I W,sm Start Depth/TVD: 2376 ft/2000 ft Well Name: CLU Storage#5 Location: Kenai,Alaska End Depth/TVD: 8860 ft/4918 ft Contractor: Nabors Drilling Field/Area: Cannery Loop/Kenai Total Depth Drilled(ft): 6,472 Start Date: 26-Dec-11 Mud Type: Kla-Shield Maximum Interval Angle(°): 70 End Date: 2-Jan-12 Hole Size(in): 12 1/4 Maximum Interval Temperature(°F): 110 Interval Days: 8 Casing Size(in):9 5/8 Fracture Gradient(1b/gall: Water Depth(ft): Top of Liner(ft): Maximum Interval Mud Weight(1b/gall: 9.4 PRODUCT&MUD ENGINEERING USAGE ON THIS INTERVAL Product Concentration Product Name Total Rig Time Distribution %Total Cost (lb/bbl) Units Min Max Average Name Days ASPHASOL SUPREME 183 6.68% 0.144 3.418 2.533 Rig Up/Service 0.04 CAUSTIC SODA 20 0.36% 0.017 0.309 0.214 Drilling 2.88 CF DESCO II 40 0.87% 0.013 0.530 0.130 Tripping 1.06 CITRIC ACID 25 1.35% 0.021 0.969 0.168 BOP NU 0.23 CONQOR 404 6 3.70% 0.166 0.978 0.573 BOP Testing 0.46 ENGINEERING SERVICE 14 6.96% Cementing 0.4 FLOWZAN 156 10.92% 0.471 0.931 0.765 Condition Mud 0.92 GELEX BENT EXTENDER 3 0.02% 0.001 0.006 0.002 Reaming 0.81 KLA-GARD 12 3.86% 0.339 2.714 1.163 Running Casing 0.94 LOTORQ 3424 24.13% 0.956 8.562 6.394 WOO 0.02 LUBE 776 8 5.04% 0.778 1.152 1.057 FIT 0.04 M-I WATE(BARITE) 459 2.88% 0.380 7.222 2.487 Well Head Work 0.06 MIX II COARSE 15 0.17% 0.192 0.192 0.192 PU BHA 0.15 MYACIDE GA25 6 0.41% 0.007 0.092 0.027 POLYPAC SUPREME UL 124 8.98% 1.014 1.416 1.162 PORTABLE ARTIC MUD LAB RENTAL 7 0.49% POTASSIUM CHLORIDE(KCL) 1070 13.72% 6.073 12.556 10.742 PRE-JOB SAFETY MEETING 14 RESINEX 69 3.09% 0.433 1.140 0.978 SAFE-CARB 20 100 1.15% 2.483 2.644 2.585 SAFE-CARB 250 50 0.61% 0.886 0.950 0.929 SAFE-CARB 40 271 3.32% 1.171 3.865 2.699 SAPP 20 0.56% 0.021 0.408 0.097 SODA ASH 10 0.11% 0.054 0.175 0.086 SODIUM BICARBONATE 40 0.39% 0.017 1.052 0.239 SODIUM METABISULFITE 10 0.23% 0.039 0.337 0.098 WEEKLY SAFETY MEETING 2 100% Total Days 8.01 Volume Description Volume(bbl) Losses Detail(bbl) 1.Volume @ start 850 Shakers 2,613 2.Received Dumped 536 3.Back Loaded/Transferred Haul off 459 _ 4.Remaining 1,399 Formation 102 5.Volume Built 4,327 Centrifuge 59 6.Surface Volume Lost 3,667 Left Behind Csg 7.Subsurface Volume Lost 102 Left in Hole Interval Comments: De-Sitter _ Fluid Processed Total Mud Losses(bbl) 3,769 Mi SWAG CINGSA Cook Inlet Natural Gas GE STORA Well. Cannery Loop #5 a5 a ? A Schlumberger Company Kenai, Alaska Drilling Interval Sum mary Injection Interval 8,860' MD (4,918' TVD) - 11 ,101 ' MD (5,107' TVD) 8-1/2" Open Hole / 7" Casing 9.0 - 9.4 ppg FLO-PRO Drilling Fluid The production interval required 13 days to complete with drilling taking 4 1/2 days. The Kla-Shield from the intermediate interval was re-used to drill the production interval. One 500 barrel tank was moved close to the rig to be used for displacements. A 100 barrel 40 pounds per barrel LCM pill consisting of Safe Carb 40, G-seal, Mix II Med, and Safe Carb 250 was built in pit 6 prior to drilling out of the shoe. An 8 1/2" bit (HCC HCR503ZX), mud motor, MWD, and LWD were picked up and run in the hole. The DV collar was drilled out at 3,512'. The cement, shoe, and 20' of new formation were drilled out to 8,890'. The mud was treated with Sodium Bicarbonate and Desco while drilling cement. The mud weight was at 9.3 ppg with an 18 yield point. A FIT was performed to a 15.0 ppg EMW. The 8 1/2" hole was control drilled at 70 to 80 feet per hour. Pump rates were between 390 and 415 gallons per minute, The inclination of the hole was 80 degrees and increased to 86 degrees at TD. Steel Lube EP was added at Y2 to 1% while drilling for metal-to-metal lubrication inside the 9 5/8" casing. LoTorq was at 2.5 to 3%. The lubricants did a good job of keeping the torque in a manageable range of 10 to 12K ft-lbs. The fluid loss was kept in the 5 to 7 cc range. Drill down to 10,049' where a planned wiper trip was made. While pumping out and reaming the hole at 9,150', the BHA became packed off and 40-50 bbls of losses were noted.fAn LCM pill was spotted then the BHA was pulled into the casing shoe while rig service was done. Run in the hole to bottom while experiencing losses so the remainder of the LCM pill was pumped; when drilling resumed losses were about 20 bbls per hour. Drilling ahead continued as losses slowed to 11-15 bbls/hr, and the mud weight was reduce to 9.1 ppg. LCM was added to the active system as drilling progressed and losses were reduced. Drilling ahead continued to 11,101' TD/ 5127 TVD. The mud weight was at 9.2 ppg with a 20 yield point. Water loss was at 6.4 cc. The lubricant concentration was at 4%. The rig then back reamed and pumped to 10,040'. RIH to bottom on elevators and circulate the hole clean. A 50 bbl lubricant pill was spotted on bottom using Lube 776. POH on elevators to 10,140'; when trying to establish circulation, the MI SWAC Cook Inlet Natural-Gas CINGSA TORAC Well: Cannery Loop #5 SJ A Schlumberger Company as ar.. Kenai, Alaska mud pumps would not stay primed; the pumps were taken apart and some coal was found in the amount of 5 gals under both pump valve seats. Aftertcleaning both pumps, new mud was made up in the pill pit and circulation was resumed. At this time, the shaker screens became blinded with the lubricants in the mud where the pump rate was limited to 60 spm and mud running over the shakers. The mud was reclaimed and pumped back over the shakers during connections. After getting into the shoe, a dry job was mixed and pumped down hole without problem and the drill string was pulled out of the hole. Samples of the thick fluid were sent to Houston for analysis and the results are attached. The 7" liner was run to 9,018' where tight hole and packing off prevented the liner from going down. Pull out of the hole and lay the liner down. When the liner was pulled out, it was noted that they had left a rigid stabilizer in the hole. Make a wiper trip to bottom. Before going into open hole, circulate and condition the mud with soda ash and ScreenKleen. Ream to bottom pushing a lost centralizer down and work through coal formations just under the shoe. Asphasol and PolyPac UL was added to help heal the coals and reduce the fluid loss. After reaming to bottom, two bottoms up were circulated before back reaming out of the hole to 9108'. Work the pipe up and down twice from 9,108' to 9,208' while circulating before continuing out of the hole. POH to the 8,950' pumping 1.8 bpm; increase the pump to 88 spm and pump into the shoe from 8,850'. Pump up to 8,000' at 128 spm from the shoe where a full bottoms up was pumped before POH. Ri g u p and RIH with the 7" liner to 8,800' where a string volume was circulated at 66 spm. Run into open hole pumping 22-24 spm to 9,030' where rotation was needed to help work the pipe through the coals at 9,000-9,150'. Rotate and pump down to 9,280' when the rotary was shut down and the liner was pumped to bottom without further problems. The cement job went well with no losses. It began with a 40 barrel 11.5 ppg mud push spacer, followed 69 barrels of 14.0 94 ° by ppg cement, followed by barrels of solids free perforating fluid (viscosified 6�0 KCL brine), and followed by active system mud. The plug was successfully bumped. The liner packer was then set and the liner setting tool was released from the packer. A nerf was dropped in the drill pipe and a bottoms up was pumped to circulate out any excess cement from the liner top. There was a very small amount of cement detected at the surface. This completed the production interval. Mi SWAG Cook Inlet Natural;Gas CINGSA J lI SToRAQ . p ASchiumbergerCompany Weil; Cannery Loop #5 as ar Io Kenai, Alaska Mi SWA�� DRILLING FLUIDS & VOLUME SUMMARY A Schlumberger Company I1 N TTFR\TA i. Operator: CINGSA Description: Sec.9/i5N/R11 W,sm Start Depth/TVD: 8860 ft/4918 ft Well Name: CLU Storage#5 Location: Kenai,Alaska End Depth/TVD: 11101 ft/5107 ft Contractor: Nabors Drilling Field/Area: Cannery Loop/Kenai Total Depth Drilled(ft): 2,229 Start Date: 3-Jan-12 Mud Type: Kla-Shield Maximum Interval Angle(°): 87 End Date: 15-Jan-12 Hole Size(in):8 1/2 Maximum Interval Temperature(°F): 100 Interval Days: 13 Liner Size(in): 7 Fracture Gradient(lb/gal): Water Depth(ft): Top of Liner(ft): 8,707 Maximum Interval Mud Weight(1b/gal): 9.4 PRODUCT&MUD ENGINEERING USAGE ON THIS INTERVAL Product Concentration Total Rig Time Distribution Product Name %Total Cost (lb/bbl) Units Min Max Average Name Days ASPHASOL SUPREME 50 2.79% 1.478 3.231 2.421 Rig Up/Service 0.54 CAUSTIC SODA 18 0.49% 0.217 0.727 0.452 Drilling 2.46 CF DESCO II 27 0.89% 0.368 0.666 0.518 Tripping 5.7 CITRIC ACID 15 1.23% 0.401 1.104 0.652 BOP Testing 0.54 CONQOR 404 2 1.88% 0.410 1.138 0.648 Cementing 0.19 ENGINEERING SERVICE 24 18.21% Condition Hole 0.68 FLOWZAN 53 5.67% 0.061 1.130 0.635 Reaming 0.31 G-SEAL 50 3.34% 0.613 1.395 0.917 Running Casing 1.98 GELEX BENT EXTENDER 2 0.02% 0.001 0.003 0.002 Handle BHA 0.15 KLA-GARD 4 1.96% 0.518 1.815 1.059 LOTORQ 330 3.55% 3.131 8.376 5.477 LUBE 776 22 21.15% 1.078 4.979 3.507 M-I WATE(BARITE) 393 3.76% 3.142 16.784 7.848 MIX II MEDIUM 45 0.89% 0.278 0.633 0.407 MYACIDE GA25 7 0.74% 0.007 0.138 0.056 PECAN NUT PLUG MEDIUM 16 0.34% 0.194 0.442 0.298 POLYPAC SUPREME UL 21 2.32% 0.545 1.050 0.806 PORTABLE ARTIC MUD LAB RENTAL 12 1.27% POTASSIUM CHLORIDE(KCL) 845 16.54% 7.676 22.404 12.957 PRE-JOB SAFETY MEETING 2 RESINEX 24 1.64% 0.631 1.417 0.972 SAFE-CARB 20 1.408 2.790 2.115 SAFE-CARB 250 75 1.40% 0.889 2.326 1.686 SAFE-CARB 40 145 2.71% 2.641 5.781 3.922 SCREENKLEEN 320 3.63% 1.254 1.914 1.512 SODA ASH 10 0.18% 0.054 0.746 0.401 SODIUM BICARBONATE 19 0.28% 0.182 1.095 0.891 SODIUM METABISULFITE 15 0.52% 0.039 0.309 0.173 STEEL LUBE EP 4 2.59% 0.348 1.016 0.561 l00% Total Days 12.55 Volume Description Volume(bbl) Losses Detail(bbl) 1.Volume 0 start 1,399 Haul off 2,387 2.Received Dumped 208 3.Back Loaded/Transferred Formation 200 4.Remaining 810 Shakers 11 5.Volume Built 774 Left Behind Csg 6.Surface Volume Lost 2,606 Centrifuge 7.Subsurface Volume Lost 200 Left in Hole Interval Comments: De-Silter Fluid Processed Total Mud Losses(bbl) 2,806 Mi SWAC CINGSA Cook Inlet NaturallGQs STORA ' Well: Cannery Loop #5 A Schlumberger Company as a y Kenai, Alaska Completion Interval Summary Completion 7" T Tubing A polish mill was picked up and run in the hole to clean out the polish bore receptacle at 8,684'. After cleaning out the PBR and circulating the hole clean using one pit and circulating through the trough, work continued cleaning the pits and mixing the 8.6 ppg KCI brine. The well was displaced to 8.6 KCL brine before pulling out of the hole laying down drill pipe. Four drums of Congor 303A, 10 gallons of Myacide and 5 barrels of diesel were spotted in the annulus after spacing out before landing the tubing hanger. After manifesting all mud products and backhauling same along with the M-1 mud lab and the mud engineer was released. DRILLING FLUIDS&VOLUME SUMMARY Mi SWAC�fy� _Asshtoeb.roarCompany ur INTERVAL 4 Operator: CINGSA Description:Sec.9/P5N/RI l W,sm Start Depth/TVD: 11101 ft/5107 ft Well Name: CLU Storage 05 Location: Kenai,Alaska End Depth/TVD: 11101 ft/5107 ft Contractor: Nabors Drilling Field/Area: Cannery Loop/Kenai Total Depth Drilled(ft): Start Date: 16-Jan-12 Mud Type: Potassium Chloride Maximum Interval Angle(°): 87 End Date: 16-Jan-12 Hole Size(in):81/2 Maximum Interval Temperature(°F): 120 Interval Days: 1 Compl.Equip.Size(in): 7 Fracture Gradient(lb/gal): Water Depth(ft): Top of Liner(ft): 8,707 Maximum Interval Mud Weight(lb/gal): 8.6 PRODUCT&MUD ENGINEERING USAGE ON THIS INTERVAL Total Product Concentration Rig Time Distribution Product Name Unit Cost(5) Total Cost(5) I's Total Cost (Ib/bbl) Units Min Max Average Name Days CONQOR A303 4 41.26% 2.287 2.287 2.287 Rig Up/Service ENGINEERING SERVICE 2 44.33% Drilling PORTABLE ART1C MUD LAB RENTAL I 3.09% Tripping 1 SAPP 9 11.31% 0.563 0.563 0.563 100% Total Days Volume Description Volume(bbl) Losses Detail(bbl) I.Volume c:start 810 Haul off 43 2.Received Shakers 3.Back Loaded/Transferred Left Behind Csg 4.Remaining 799 Centrifuge 5.Volume Built Formation 6.Surface Volume Lost 43 Left in Hole 7.Subsurface Volume Lost De-Silter Interval Comments: Dumped Fluid Processed Total Mud Losses(bbl) 43 Packer fluid placed behind tubing Mi SWAC Cook Inlet Natural;Gas CINGSA SORA N A Schlumberger Company Well: Cannery Loop #5 1 as a r .Ia Kenai, Alaska WELL PRODUCT SUMMARY MI SWAC TOTAL PRODUCT &ENGINEERING CONSUMPTION FOR THE WELL A scmvmoeryer Company Operator: CINGSA Contractor: Nabors Drilling Description:Sec.9/r5N/RIIW,sm TO/TVD: 11101 ft/5107 ft Well Name: CLU Storage 05 Field/Area: Cannery Loop/Kenai Location: Kenn,Alaska Max.Well Temp.: 120°F Start Date: 22-Dec-11 End Date: 16-Jan-12 Total Days to TD: 18 Max.Well Angle: 87° PRODUCT&ENGINEERING USAGE FOR THE WELL Product Name Unit Size Start Amount Received Returned Total Used %Total Cost ASPHASOL SUPREME 50.LB BG 230 233 4.68% CAUSTIC SODA 50.LB BG 40 29 29 40 0.40% CF DESCO II 25.LB BG 102 21 81 0.97% CITRIC ACID _ 50.LB BG 90 50 40 1.19% CONQOR 404 55.GA DM 10 4 6 8 2.72% CONQOR A303 _ 55.GA DM 2 4 0.51% ENGINEERING SERVICE 1. EA 80 55 15.05% FLOWZAN 25.LB BG 143 160 94 209 8.06% G-SEAL 50.LB BG 81 50 50 1.21% GELEX BENT EXTENDER 2.LB BG _ 5 10 8 5 0.02% KLA-CARD _ 55.GA DM 16 _ 8 8 16 2.83% LOTORQ 1.GA 784 2970 3754 14.56% ' LUBE 776 55.GA DM 8 24 2 30 10.40% M-I GEL EXPORT ' 50.LB BG 420 350 140 630 2.23% M-I SEAL MEDIUM _ 40.LB BG 95 95 M-I WATE(BARITE) 50.LB BG 988 550 550 988 3.41% MAGMA FIBER REG 30.LB BG 20 20 MIX II COARSE 25.LB BG 120 105 15 0.10% MIX II FINE 25.LB BG _ MIX II MEDIUM 25.LB BG 115 _ 70 45 032% MYACIDE GA25 5.GA CN 59 46 13 0.49% ' PECAN NUT PLUG FINE 50.LB BG 35 _ 35 PECAN NUT PLUG MEDIUM 50.LB BG81 - 65 16 0.12% _ POLYPAC SUPREME UL 50.LB BG 9 165 45 153 6.10% PORTABLE ARTIC MUD LAB RENTAL 1. EA 30 _ 28 1.07% POTASSIUM CHLORIDE(KCL) 50.LB BG 166 _ 1984 160 1915 13.51% RESINEX ' 50.LB BG ' 143 108 24 93 2.29% SAFE-CARB 20 50.LB BG 226 115 100 0.63% SAFE-CARB 250 50.LB BG 129 90 125 0.84% SAFE-CARB 40 50.LB BG 320 130 416 2.81% SAPP 50.LB BG 40 20 29 0.45% SCREENKLEEN - 1.GA 320 320 1.31% SODA ASH 50.LB BG 42 21 0.13% SODIUM BICARBONATE 50.LB BG 127 _ 60 67 0.36% SODIUM METABISULFITE 50.LB BG _ 118 98 25 0.31% STEEL LUBE EP 55.GA DM 8 4 8 4 0.93% 10090 DRILLING FLUIDS SUMMARY Mi SWAC Cook Inlet Natural Gas CINGSA STORA A Schlumberger Company Well; Cannery Looe #5 as a Kenai, Alaska Mi SWAC_9.f� A Schlumberger Company � --' Drilling Fluid Summary Operator: CINGSA Field/Area: Cannery Loop/Kenai Well Name: CLU Storage#5 Description: Sec.9/T5N/R11W,sm Contractor: Nabors Drilling Location: Kenai, Alaska Date 12/22/2011 12/23/2011 12/24/2011 12/25/2011 12/26/2011 12/27/2011 Depth ft 886 ' 2400 ' 2400 ' 2400 r 2400 ' 4038 TVD ftr 886 ' 2018 ' 2017 r 2017 r 2017 ' 2784 Activity Drilling Surface Short Trip Run 13-3/8"csg Mix New Mud Clean Out Cement Drlg 1225"OH Mud Type Gel Spud Gel Spud Gel Spud Gel Spud Kla-Shield Kla-Shield Hole Size in 16.000 16.000 16.000 16.000 13250 12250 arc Volume bbl 822 464 768 850 1024 1272 Flow Rate gal/min 533 622 457 596 arc Pressure psi 1400 1950 700 1300 Average ROP 16o Sample From PIT PfT PIT PIT PIT Time Taken 22:30 23:00 2100 23:00 22:45 22:00 Flow Line Temp 'F ' 76 P 90 N/A NA NA H 84 Mud Weight ' lb/gal p 8.8 p 9.1 p 9.1 p 8.4 P 8.9 P 9.0 Mud Temp F r 75 r 80 r 76 P 55 r 80 r 84 Funnel Viscosity r s/qt P 58 p 56 I, 49 V' 52 P 45 Rheology Temp `F P 120 r 40 I, 120 r 130 r 120 R600 r 46 I, 58 I, 44 r 46 p 38 R300 r 32 P 42 ' 32 p 35 I, 27 R200 r 27 r 33 P 25 P 28 1, 20 R100 P 19 P 26 I, Tr I, 21 r 15 R6 p 9 I, 4 "I 7 P 8 p 6 R3 ' 8 P 11 p 6 P 7 P 5 FV cP r 14 p 16 ' 4 p 11 P 11 YP Ib/IjOft' l' 18 P 26 P 20 r 24 ' 16 10 s Gel Ib/40ft' r 1) P 22 P 10 p 8 r 5 10 m Gel lb/100W p 15 P 29 P 14 p 11 p 7 30 m Gel Ib/130ft' P V r 31 P 16 P 4 8 API FL cc/30min P 42 P 8.6 I, 8.5 P 6.4 P 6.4 HTI-P FL cc/30min HTHP FL Temp ' Cake API r 2 ' 2 r 2 V' 1 P 1 Cake HT Solids %Vol p 4 r 5 p 5 I, 0 I, 3 p 4 Oil %Vol P 0 P 0 P 0 I, 0 P 0 ' 1 Water %Vol r 96 p 95 p 95 p 100 P 97 P 95 Sand %vol p 0.25 p 0.7 P 0.5 ir 0 P 0 'F 0.75 MBT lb/bbl p 22 ' 23 I, 22 P 0 P 0 P 1 pH P 8.8 p 8.6 P 8.5 p 7.4 P 8.5 p 9.1 pH Temp 'F ' 80 P 78 P 70 P 55 P 70 I, 60 Alkal Mud(Pm) P 0.1 p 0.25 P 0.15 Pf TR P 0.02 P 0.02 P 0.04 p 0.05 Mf r 0.4 1, 0.3 I, 0.3 ' 0.35 r 0.35 Chloride mg/L P 2000 P 1130 P 1000 p 28500 P 28000 Hardness,Ca r 40 p 40 P 40 1, 40 p 280 DissolvedOxygen ppm <2 Congor 404 ppmP 4000 p 3800 Potassium mg/I p 31000 ' 27500 API Screen size P 130 Remarks Engr arrive 4-20;mix mud on 4-21;spud on 2-22.Drill to 102T by midnight. Alternate slide/rotary drilling from 1027-2400';Circ hole clean,make wiper trip to monels. POOH from 1927-790';RIH back to 2400;2'of fill.CB U+;POH.RU 8 run 13 3/8 csg.RIH w/5"DP. Cement in place at 04:00.Circ casing clean.POH w/DP.RD diverter.Haul mud off;clean pits. NU BOP E;test BOP E;mix new Kla-Shield mud volume On out FC,shoe and 20'of new hole.Perform FIT to 15.5 ppg EM W;dr!to 4230'at midnight. Mi SWAG Cook Inlet Natural-Gas Gas CINGSA STORA 1 Well, Cannery Loop #5 QS Q 1 �".'Qo A Schlumberger Company _. .- Kenai, Alaska Mi SWAG, A Schlumberger Company - Drill Drilling Fluid Summary Operator: CINGSA Field/Area: Cannery Loop/Kenai Well Name: CLU Storage#5 Description: Sec.9/T5N/R11W,sm Contractor: Nabors Drilling Location: Kenai, Alaska Date 12/28/2011 12/29/2011 12/30/2011 12/31/2011 1/1/2012 1/2/2012 Depth ft • 5382 ' 7185 ' 8872 • 8872 ' 6672 ' 8872 • TVD ft ' 3393 ' 4209 1' 4918 ' 4918 ' 4918 ' 4918 Activity Drlg 12.25"OH Drilling Ahead Short Trip L/D BHA Run Casing W.O.C. Mud Type Kla-Shield Kla-Shield Kla-Shield Kla-Shield Kla-Shield Kla-Shield Hole Size in 12.250 12250 12.250 12.250 12.250 12.250 • Circ Volume bbl 1444 1779 1939 1823 1802 1)29 • Flow Rate gal/min 596 609 612 612 Circ Pressure psi 1550 1650 1950 1950 Average ROP 180 156.7 200 200 Sample From PIT Prr _ PIT PIT PFT Prr Time Taken 22:00 2215 22:00 22:00 22:30 23:00 Flow Line Temp 7 ' 88 ' 100 • 110 ' 99 NA ' 70 Mud Weight ' lb/gal ' 9.0 p 9.05 • 9.3 ' 9.3 ' 9.4 9.4 Mud Temp 7 r 88 p 98 ' 11D ' 100 ' 90 ' 70 Funnel Viscosity ' s/qt ' 50 ' 50 • 52 ' 60 ' 58 ' 59 Rheology Temp `F ' 120 ' 20 1, 120 ' 120 ' 20 IP20 R600 ' 44 ' 47 ' 51 ' 55 ' 52 ' 50 R300 ' 32 ' 36 ' 37 ' 39 ' 36 ' 35 R200 ' 27 ' 30 • 31 ' 33 ' 31 ' 28 R100 ' 20 ' 23 ' 24 ' 38 ' 25 ' 23 R6 ' 10 ' 9 • 11 ' 13 ' 11 ' 10 R3 8 8 10 11 D 9 Pd cP 12 11 14 16 16 15 YP lb/180ft' 20 25 23 23 20 20 10 s Gel lb/Doff= 10 9 13 15 15 9 10 m Gel lb/100ft. - A A 20 23 22 16 30 m Gel lb/Dort' 2 15 29 35 35 22 API FL cc/30min 5.8 5.6 5.8 5.6 5.6 5.8 HTHP FL cc/30min HTHP FL Temp 'F Cake API 1 1 1 1 1 1 Cake HT Solids %Vol 4 4 6 6 6 6 Oil %Vol 3 3.5 4 4 4 4 Water %Vol 93 92.5 90 90 90 90 Sand %Vol 0.5 0.5 05 0.5 0.5 0.5 • MT lb/bbl 2.5 3 5 5.5 6 5 pH 9.5 8.8 8.8 8.8 8.8 8.8 pH Temp 7 80 80 A0 80 80 70 Alkal Mud(Pm) 0.2 0.15 0.15 02 02 02 Pt 0.04 0.03 _ 0.02 0.02 0.03 0.03 MI 0.4 025 0.25 02 0.25 025 Chloride mg/L 27800 28000 29000 28000 27000 27000 Hardness,Ca 280 280 280 280 300 40 DssolvedOxygen ppm • Conqor 404 ppm 3100 Potassium mg/I 27000 27000 27000 26000 26000 26000 • API Screen size 100 100 100 100 100 100 Remarks Wash/ream to bottom;drilled ahead to @5571 @midnight Drilled @5571-6529';circulate/condition-pump viscous;drilled to 7295'@report time Drilled @9295-7677';viscous sweeps pumped every 500';circulate and condition;drilled @7677-8347 Back ream to 7964',RIH;spot Lube pill,POH on elevators to 7900';pump out of hole to shoe;POH. POOH from 539';set back HWDP;L/D BHA;change rams;test BOP E;rig down from test;rig up-run casing to 2386' RIH w/9.625"casing;Cement and displace.RD Schlumberger,clean up rig. Mi SWAC Cook Ielet Natural.Gas CINGSA STORA jj�LJJ Well: Cannery Looe #5 ; A Schlumberger Company as °:,' Kenai, Alaska Mi SWA -- -- Drilling Fluid Summary A Schlumberger Company Operator: CINGSA Field/Area: Cannery Loop/Kenai Well Name: CLU Storage#5 Description: Sec.9/T5N/R11W,sm Contractor: Nabors Drilling Location: Kenai, Alaska Date 1/3/2012 1/4/2012 1/5/2012 1/6/2012 1/7/2012 1/8/2012 Depth ftI. 8872 r 8872 ' 9857 p. 10404 ' 11101 r 11101 TVD ft I. 4918 ' 5050 r 5103 p 5127 r 5127 Activity BOPE Testing DrIg8.5"OH Drilling Ahead Drilling Ahead Tripping Lay down BHA Mud Type Kla-Shield Kla-Shield Kla-Shield Kla-Shield Kla-Shield Kla-Shield Hole Size in 8.500 8.500 8.500 8.500 8.500 8500 arc Volume bbl 1362 1175 1313 1203 1306 217 Flow Rate gal/min 355 400 355 368 Circ Pressure psi 071 071 096 1396 Average ROP 75 75 Sample From PFT PIT PIT PIT PIT Time Taken 22:00 23:45 00:00 23:45 23:00 2200 Flow Line Temp 'F NA ' 72 r 93 I 89 I 88 r 60 Mud Weight r' lb/gal r 9.4 I 9.2 1 9.2 I 9.2 P 9.2 r 9.1 Mud Temp 'F r 70 r 72 p 88 r 89 I 82 r 60 Funnel Viscosity " s/qt ' 70 p 62 64 I 54 IP 54 r 53 Rheology Ten 'F r 120 I 220 p 120 r 120 r 120 I' 120 R600 r 54 p 49 r 58 I 50 I 49 ' 42 R300 ~ 38 p 33 P 44 P 36 P 36 P 30 R200 IP 33 r 27 p 36 ' 30 p 30 p 21 R100 ' 25 p 22 P 31 p 22 IP 20 r 17 R6 IP 11 I. 9 P 0 r 9 p 8 p 6 R3 r 1) 7 r 11 p 7 p 6 r 4 PV cP p 18 p 5 r 14 r 14 p 13 p 12 YP Ib/DOft' ► 22 p 17 p 30 p 22 1 23 P 0 10 s Gel Ib/10ft' p 14 p 8 p 13 1 D p 13 p 7 10 m Gel Ib/100ft' Ir 18 r 12 p 17 p 22 p 13 p 12 30 m Gel Ib/130ft' p 20 p 16 P 21 1 D p 19 p 16 AR FL cc/30min r 6.2 r 7.1 p 5.6 p 6.2 p 6.1 HTHP FL cc/30min HTHP FL Ten 'F Cake AR r 1 p 2 ► 2 p 2 P 2 ► 2 Cake HT Solids %vol p 6 7.0 P 6 P 7 p 7 r 6 Oil %Vol p 3 P 2.5 p 3 p 25 1 3.5 r 3 Water %Vol p 91 p 90.5 ' 91 p 90.5 I 89.5 r 91 Sand %vol p 025 p 0.25 P 0.3 p 0.3 p 0.33 r 0.2 MBT Ib/bbl p 5 r 7 P 7.5 r 8 I 9 IP 9 pH p 8.3 p 9.1 P 8.6 r 8.4 p 92 r 9.2 pH Ten 'F p 70 p 72 r 82 p 75 IP 88 r 60 Alkal Mud(Rn) r 0 r 02 ' 0.2 p 0.1 p 0.2 p 0.2 Ff r 0 p 0.5 r .1 r 0.05 p 0.1 p 0.1 Mf IP 0.2 r 12 p to ' 0.9 ' 0.7 P 0.8 Chloride mg/L 1 25000 r 26000 ' 25000 r 26000 p 20000 p 16000 Hardness,Ca r 400 p 240 r 80 P 320 p 240 p 320 DissolvedOxygen ppm p 2 Conqor 404 ppm p 3500 r 3000 p 3000 p 3000 p 3000 Potassium mg/I P 23000 p 27500 r 27573 P 28676 ' 22058 r 17648 API Screen size ► 120 p 120 IP 120 p 120 r 220 r 130 Remarks Rigged down Weatherford casing equipment;rig up-test BOPE;service/repair top drive;test BOPE;pick up BHA Make up BHA;RIH and drill out DV plug/cmt to 3539'.Tested casing to 2500 PSI.DrI FC,shoe and 20'of new hole Continued drilling and sliding ahead to 9.861 M D(5,087'TVD). Continued drilling and sliding to 13,048'.Sh trip to shoe;lost returns below coals at 950'.RIH to bottom;Ddg ahead Drill to 11,131M D/527'TVD.Circ hole clean and pump out to the shoe. RIH to bottom;spot Lube pill;POH to 0,00 on elevators.Pump out of hole to shoe while circ hole clean.Pump dryjob MI Cook Inlet NaturaL,Gas SWAG Wei,: Loop #5 S 1 ORAQaEi ( ell: C ,r No, A Schlumberger Company Kenai, Alaska MI SWAGS-- Drilling Fluid Summary A Schlumberger Company "'�-y� Operator: CINGSA Field/Area: Cannery Loop/Kenai Well Name: CLU Storage#5 Description: Sec.9/T5N/R11W,sm Contractor: Nabors Drilling Location: Kenai, Alaska Date 1/9/2012 1/10/2012 1/11/2012 1/12/2012 1/13/2012 1/14/2012 Depth ft r 11101 r 11101 r 11101 P 11101 r 11101 r 11101 TVD ft r 5127 r 5127 5127 P 5127 r 5127 r 5127 Activity RIH wLiner POH with Liner Reaming RIH w7"Liner Cementing Displacing to Brine Mud Type Kla-Shield Kla-Shield Kla-Shield Kla-Shield Kia-Shield Kla-Shield Hole Size in 8.500 8.500 8.375 8.500 8.500 8.500 Circ Volume bbl 1161 1214 1253 1353 484 732 Flow Rate gal/min 295 3 425 Circ Pressure psi 625 Average ROP Sample From PR PR FLOWLINE PR PIT PIT Time Taken 2300 23:00 23:45 22:45 2t00 23:45 Flow Line Temp F na na p 82 na ir 83 na Mud Weight " lb/gal r 9.1 p 9.1 p 9.2 p 920 p 925 r 8.7 Mud Temp F r 60 r 82 p 82 p 82 p 80 r 76 Funnel Viscosity r s/qt r 54 p 47 p 45 p 45 1- 46 r 17 Rheology Temp F • 100 • 40 • 1D0 • 'DO " 130 • 130 __ R600 r 38 P 34 p 35 ' 43 p 46 r 4 R300 40, 22 1 25 p 24 p 31 p 30 r 3 R200 V 8 • 22 v 13 • 23 • 24 • 2 - R1 00 r 15 p 13 p 4 P 17 p 17 r 1 R6 6 p 7 p 5 p 7 p 6 r 1 R3 p 4 p 5 p 3 p 5 p 4 p 1 PJ cP r '6 P 9 • 11 P 4 p 8 r 1 YP lb/1D0ft' • 6 p 16 p 13 p 19 p 14 p 2 10 s Gel Ib/ro0ft' p 6 p 6 p 6 p 7 p 7 p 1 10 m Gel Ib/130ft' r 11 p 10 p 4 p 4 p 4 p 1 30 m Gel Ib/100ft' p 14 r 11 r 15 r 17 r 15 P 2 API FL cc/30min p 6.0 p 6.1 p 6.2 p 6.0 p 6.1 na HTHP FL cc/30min HTHP FL Temp F Cake API P 15 <2 <2 <2 <2 na Cake HT Solids %Vol p 6 p 7 P 6.0 p 6.5 p 6.0 p 0 Oil %Vol p 3 p 2.5 r 3 r 2 p 2 Water %Vol p 91 p 90.5 P 91 r 915 p 92 p 100 Sand %Vol p 02 p 25 p .5 p .35 MBT Ib/bbl p 9 p 8 p 8 p 8 p 8 pH r 9.1 p 8.6 r 9.0 p 8.7 p 8.5 r 8.3 pH Temp F p 60 p 82 r 82 p 76 p 78 r 76 Alkal Mud(Pm) p 0.2 p .1 r 0.2 p .15 p 0.1 r 0.0 Pf p 0.1 p .05 V 0.1 p .01 1, .01 Mf p 0.8 ' .8 ' 0.8 ' .8 p .7 Chloride mg/L p 17000 p 21500 p 20500 p 21000 p 20500 • 33200 Hardness,Ca p 320 p 240 r 180 p 220 p 280 DissolvedOxygen ppm Congor 404 ppm p 3000 I 3000 p 2500 Potassium mg/I I 8751 p 23714 p 22611 • 22066 p 37000 API Screen size p 60 p 64 p 60 p 60 Remarks Continued POOH,laying down BHA..Run CBL;RU liner handling equipment and began running in with 7"liner. RIH w/Iiner to 908';would not go down;POH and LD liner. Tripped out of hole,laying down 7"liner.RIH w/mill and HWDP,one collar,2 stabs.Circ at shoe;ream to 10259' Ream to bottom.CBU X 2;Pump and rotate out to shoe.Circ hole clean,POH. RIH to 8800'w/the liner;Circ liner volume;RIH to bottom-work thru coals 9030 to 9150'.Cmt and displace.No losses. CIP at 02:30.Set packer,release from liner.Circ hole clean.POH w/DP.Dump mud and start cleaning pits. Mi SWAC Cook Inlet Natural,Gas CINGSA STORAC p., ASchlumbergerCompany Well, Cannery Looe #5 1 e0 - as a Kenai, Alaska MiSWAG� - A Schlumberger Company Drilling Fluid Summary Operator: CINGSA Field/Area: Cannery Loop/Kenai Well Name: CLU Storage#5 Description: Sec.9/T5N/R11W,sm Contractor: Nabors Drilling Location: Kenai, Alaska Date 1/15/2012 1/16/2012 Depth ft P 11101 ND ft P 5127 Activity RIH w/7"Tubing NU Tree;Test Mud Type Kla-Shield Kla-Shield Hole Size in 8.500 8.500 Circ Volume bbl 811 800 Row Rate gal/min arc Pressure psi Average ROP Sample From PIT PIT Time Taken 23:45 12:00 Row Line Temp 'F na Mid Weight F lb/gal I. 8.7 r 8.6 , MAI Temp 7 ' 76 Funnel Viscosity ' s/qt ' 27 Rheology Tenp `F I' 130 R600 r 4 R300 r 3 R200 r 2 R100 r 1 R6 r 1 R3 1, 1 PV cP r 1 YP lb/130W ' 2 10 s Gel lb/130ft' ' 1 10 m Gel lb/100ft' ' 1 30 m Gel Ib/100ft' 11. 2 API FL cc/30min na HTHPFL cc/30min HTHP FL Temp Cake API na Cake HT Solids %Vol r 0 Oil %Vol Water %Vol r AO Sand %Vol NBT lb/bbl pH r 8.3 pH Temp 7 r 76 Alkal Mud(Pm) r 0.0 Pf Nf Chloride mg/L ' 33200 Hardness,Ca DissolvedOxygen ppm KCL Brine Connor 404 ppm Potassium mg/I 37000 AR Screen size r 60 Remarks Displaced KLA-GA RD fluid with 6%KCI brine.P U&M U tubing and seal assembly,RIH RIH w/7'tbg;Backhaul mud pro ducts;Pump Packer fluid;ND Stack,NUTree:Test. Mi Cook Inlet Natural Cas SWAC CINGSA A Schlumberger Company Weil; Cannery Looe #5 STORA as a x y . Kenai, Alaska HYDRAULICS SUMMARY Mi SWAB A Schlumberger Company HYDRAULICS SUMMARY Operator: CINGSA Field/Area: Cannery Loop/Kenai Well Name: CLU Storage#5 Description: Sec.9/T5N/R11W,sm Contractor: Nabors Drilling Location: Kenai, Alaska Da=e 12/22/2011 12/23/2011 12/24/2011 12/25/2011 12/26/2011 12/27/2011 12/28/2011 12/29/2011 Depth +,' 886 ' 2400 ' 2400 ' 2400 ' 2400 ' 4038 ' 5382 ' 7185 Day.Sir,«Sp„d *RHEOLOGICAL PROPERTIES Mud Weight ' 8.8 ' 9.1 ' 9.1 ' 8.4 ' 8.9 r 9.0 ' 9.0 ' 9.05 P' 14 ' 16 ' 12 ' 11 ' 11 ' 12 • 11 „/100,2 18 26 20 24 16 20 25 3-=pm Read..,9 Fa.,.,de.' 8 ' 11 ' 6 ' 7 ' 5 ' 8 ' 8 np V..- ' 0.6412 ' 0.5846 ' O. ' 0. ' 0.4637 ' 0.5636 ' 0.5472 ' 0.4637 Ka V.,- ,e.*a/100,,2' 0.4585 ' 0.8351 ' 0. ' 0. ' 1.609 ' 0.6844 ' 0.8571 ' 1.609 .,a V..- ' 7. ' 10. ' O. r 0. ' 6. ' 4. ' 6. ' 7. Ka Value ^.,/100,12 *FLOW DATA F o Ra=e gal/Inc,r 533 ' 622 ' 0 0 F 457 ti 596 ' 596 ' 609 P m p P e s e 1400 1950 1100 1300 1550 1650 P,.r.,p hh„' 435 ' 708 * ' 293 ' 452 ' 539 ' 586 *PRESSURE LOSSES Dr...5==mgr 229 ' 435 * ' 248 ' 382 ' 767 ' 870 B,= p.ff' 260 ' 366 * * ' 219 ' 378 ' 378 ' 397 p ' 5 ' 15 * * ' 22 ' 28 ' 51 ' 69 To=a.Sys=temas.' 494 ' 817 * " ' 490 ' 788 ' 1196 ' 1337 -*BIT HYDRAULICS No ,e s 1/32" 3.18 3,18 3.18 8.12 8.12 8.12 8.12 Nozzles 1/32" 16 16 16 %' 19 ' 19 ' 20 ' 29 ' 24 ' 24 B.r hhp' 81 ' 133 * ' 59 ' 131 ' 131 ' 141 B. HIS (,.,de.)' 0.4 ' 0.66 ' 0.5 ' 1.11 ' 1.11 ' 1.2 Ve,o =y r=/s' 182 ' 212 * ' 166 ' 216 ' 216 ' 221 I,p act F.„e a.,' 441 ' 621 ' 349 ' 601 ' 601 ' 632 *DRILL COLLAR ANNULUS Ve�o�=v ' 60 ti 70 * ' 90 ' 217 ' 217 ' 222 C a Ve oe= r,/,,,,„r 411 ' 505 ' 511 ' 500 ' 566 ' 643 Rey o dz N mde ' 94 ' 96 ' 181 ' 776 ' 609 ' 544 ' ?.,i ;a - ' 2698 ' 2720 ' 2835 V Y ,/,„;,,' 51 ' 59 ' 90 ' 110 ' 110 ' 113 ran,ir+' 382 ' 467 * * ' 511 ' 375 ' 439 ' 500 Reynolds Number ' 74 ' 77 * ' 181 ' 394 ' 274 ' 267 Cr.,Re(Lam T-) ' 2592 ' 2869 " ' 2835 ' 2898 ' 2720 ' 2835 *HOLE CLEANING S p Veo =y ' 40 ' 30 25 34 ' 31 ' 24 R...aaWe, rc/.nen' 11 ' 30 * * ' 65 ' 76 ' 79 ' 88 %' 22 ' 50 * * ' 73 ' 69 ' 72 ' 78 C == 9 Co e %' 0.0 F 0.0 * * ' 0.0 ' 4.45 ' 4.28 ' 3.35 180 180 156.7 *CASING SHOE PRESSURES ECD ' 8.91 r 9.24 * ' 9.13 ' 9.18 ' 9.25 r 9.34 ECD+C.=,.,,, ' 8.91 ' 9.24 ' 9.13 ' 9.6 ' 9.65 ' 9.68 *TOTAL DEPTH PRESSURES ECD ,a/g..,' 8.92 ' 9.27 * . ' 9.13 ' 9.23 ' 9.33 ' 9.43 ECD+G.==,.,,. ,*/*..,' 8.92 ' 9.27 * " r 9.13 ' 9.64 ' 9.72 ' 9.77 Cook Ielet Katura l;G aa. s Mi SWAC STORAF - Well: Cannery Looe #5 ' as �; Its A Schlumberger Company Kenai, Alaska Mi SWAPHYDRAULICS SUMMARY A Schlumberger Company - Operator: CINGSA Field/Area: Cannery Loop/Kenai Well Name: CLU Storage#5 Description: Sec.9/T5N/R11W,sm Contractor: Nabors Drilling Location: Kenai, Alaska Dare 12/30/2011 12/31/2011 1/1/2012 1/2/2012 1/3/2012 1/4/2012 1/5/2012 1/6/2012 Dep,, ,r' 8872 ' 8872 ' 6672 ' 8872 ' 8872 ' 8872 ' 9857 ' 10404 Day s S,„oe Sp,,,, *RHEOLOGICAL PROPERTIES Mod We enc ,d/g, ' 9.3 ' 9.3 ' 9.4 ' 9.4 ' 9.4 ti 9.2 ' 9,2 ' 9.2 Pas �Vs� JP' 14 r 16 ' 16 ' 15 ' 16 ' 16 ' 14 ' 14 Y,e,d Point 1r/100..2 23 23 20 20 22 17 30 22 3--pre Reed„„y Fa,,,, de,' 10 ' 11 ' 10 ' 9 F 10 r 7 ' 11 ' 7 np Value ' 0.5846 ' 0.6163 ' 0. ' 0. ' 0. ' 0.6517 ' 0.4851 ' 0.5373 Kp Vere ie s^n/1001,2' 0.7307 F 0.6425 F 0. ' O. F O. ' 0.4809 ' 1.6986 ' 1.0864 .,e V.,- ' 9. ' 9. ' 0. ' 0. ' 0. ' 5. ' 9. ' 5. Ka Value m.^./100.,2 *FLOW DATA F ow Rare /,m .-,' 612 ' 612 ' 0 ' 0 ' 0 ' 355 ' 400 ' 355 Pomp Pressors psi 1950 1950 1371 1371 1396 P.,mp ppp' 696 ' 696 " * r 284 ' 320 ' 289 *PRESSURE LOSSES D„::S,.�.,, p=,' 1188 ' 595 * * ' 583 ' 632 ' 520 B. psi 413 413 151 193 152 A psi 86 34 - 181 334 259 Tp Sysrem 1688 1042 916 1158 931 *BIT HYDRAULICS Ne<<e 1/32" 8.12 8.12 3.13 3.13 3.13 3.13 No., 1/32" 1114 1114 3,14 3.14 Br Pres,o�e % 21 21 11 14 11 B r ,,,,p 148 147 * 31 45 31 B,HIS (:-e.) 1.25 1.25 ' 0.55 0.79 0.55 Veo�,r.y rr/. 222 222 * * 136 153 136 Impact.Fr,��e Thr 656 656 • - 229 291 230 *DRILL COLLAR ANNULUS rrm , 223 235 184 * * Critical Velocity rt./min 607 390 ' * * 502 * * Roy olds N mbe 572 * ' * * 560 * * C,-,r Re(Lam-Tam) 2669 2626 ' * * 2577 2805 2734 *DRILL PIPE ANNULUS Veo�ry /m , 3 • o 184 207 184 *,/m,* 464 477 502 784 685 Reynolds Number 263 * 560 873 907 Cr..Re(Lam-Tram) 2669 2626 * * 2577 2805 2734 *HOLE CLEANING Slip Velocity 31 33 37 23 27 Rising Velocity ft/min 82 84 * * 147 185 157 L f, 9 Ca,ate, y % 72 72 * 80 89 85 C��rp,Co % 4.61 9,37 * * 0.0 0.0 1 22 Pe er�ar� Ra« *rip 200 200 75 *CASING SHOE PRESSURES ECD 9.63 9.69 * ' * 9.93 10.35 10.05 ECD+CC,, *,, 10.05 10.11 " C 9.93 10.35 10.18 *TOTAL DEPTH PRESSURES ECD ,piy.: 9.72 9.5 * * * 9.93 10.51 10.23 ECD+CCrr:n,, ,,,/,e: 1014 9.67 * * 9.93 10.51 10.35 Mi SWAG Cook Inlet Natural:Gas CINGSA STORAXs A Schlumberger Company Weir Cannery Loop #5 aa �' Kenai, Alaska Mi SWAC„�,...- A SchlumbergerC om Company Y HYDRAULICS SUMMARY Operator: CINGSA Field/Area: Cannery Loop/Kenai Well Name: CLU Storage#5 Description: Sec.9/T5N/R11W,sm Contractor: Nabors Drilling Location: Kenai, Alaska D a�0 1/7/2012 1/8/2012 1/9/2012 1/10/2012 1/11/2012 1/12/2012 1/13/2012 1/14/2012 Dau�h ,_' 11101 ' 11101 ' 11101 ' 11101 ' 11101 r 11101 ' 11101 r 11101 *RHEOLOGICAL PROPERTIES /g,i' 9.2 ' 9.1 ' 9.1 ' 9.1 F 9.2 ' 9.20 r 9.25 ' 8.7 Pa, V,: sP' 13 ' 12 ' 16 ' 9 ' 11 F 12 ' 16 ' 1 Y,e,d Po,00 ,e/100.2 23 18 6 16 13 19 14 2 3-rpm Raanr.,g F,,,,, aeg' 6 ' 4 ' 4 ' 5 ' 3 ' 5 74 ' 1 „p Vague ' 0.4916 ' 0. ' 0 ' 0. ' 0.5636 ' 0. ' 0.6517 ' 0.5846 Kr, V.,,.e ,o s^r,/100,2r 1.492 ' 0. ' 0, F O. ' 0.6844 ' 0. F 0.4809 ' 0.0522 .,a Value ' 4. ' 0. ' 0 ' 0. ' 1. ' 0. ' 2. ' 1. K.,Vag,. ,„ ^.,/100..2 *FLOW DATA F �w Rao g,,/..,,,,F 368 ' 0 ' 0 ' 0 ' 295 ' 0 ' 3 ' 425 P,.,,,P Pre, ,,,. pg1 1396 625 P,,,,„ ,,,,r 300 * ' 155 *PRESSURE LOSSES psi' 563 * * * F 322 * F 11 ' 180 B, p, 163 * * * 22 8 A,,,,,,,, p , 283 * * 91 * 1 34 1009 * 435 * 11 222 *BIT HYDRAULICS 1,32 3.13 3.13 3.13 13.3 6.20 No�zas 1/32" 3.14 3.14 3.14 3.14 B r P asp e % 12 * * * ' 1 B, hhp 35 * • 4 2 B, HIS (,„*o.) 0.62 * * 0.07 * 0. 0.03 P�Va,o*,ov +r/. 141 51 * 32 247 72 * 61 *DRILL COLLAR ANNULUS V,> * « 275 ' 1 196 CTS*�aV, �:ry .,L,,.,, 371 * 247 276 106 * r « * * C,-, R0(Lam-T,,m) 2797 ' 2698 * 2577 2669 *DRILL PIPE ANNULUS ^ 191 * * 160 * 1 196 ,/,,, 695 * ' 388 276 106 955 * 729 - Cr,, R„(L:,,,,-T,:,,») 2797 2698 2577 2669 *HOLE CLEANING .-/.,,,., 24 33 37 69 Rising Velocity frim in 167 127 ' -35 127 L,nnog Capacity °0 87 - 79 * * 65 C 9Co � % 1.15 00 * * 0.0 .,V 75 *CASING SHOE PRESSURES ECD 10.06 9 52 * 9.29 8.86 ECD+C,,,,,,,. ',. 10.19 9.52 9.29 8-86 *TOTAL DEPTH PRESSURES ECD 10.3 9.58 * 9.29 8.86 ECD+G,..,,,„ 4 10.43 ` * 9.58 * 9.29 8.86 MI SWAG Cook Inlet Natural Gas CINGSA STORA J l� _..._ .. Well. Cannery Loop #5 a5 Q x A Schlumberger Company _ Kenai, Alaska Mi SWAG A Schlumberger Company _ HYDRAULICS SUMMARY Operator: CINGSA Field/Area: Cannery Loop/Kenai Well Name: CLU Storage#5 Description: Sec.9/T5N/R11W,sm Contractor: Nabors Drilling Location: Kenai,Alaska Daae 1/15/2012 1/16/2012 Deere 6 r 11101 Days S,„e SP d `RHEOLOGICAL PROPERTIES M We,gh, ]3n r 8 7 r 8.0 P'as V's <P r 1 Y'ea PO e/100 2 3 ppm Read; g Fe 1 np Ve ee 0. r C Kp Va,.e s^„/100r 0 ' C Va'„e ' 0 ' C K \i,,, R.,.. Pimp Press��e PU P , *PRLSSUP B' A Ps' T ta'Sysr.em F No<re" N es 1/32 B't Press % * B', B',HIS ('„Pr.) Jen Ve'oc'zy �,s mpa�tFo ,e *DRILL COLLAR ANNULUS Rey e n N�,ree, • Re�(Lnm-Tram) .RRC ;'1,1- .jzi r l: Ve'o.. y CrtrjcaI Ve'o y /m „ Ray ewes Numner Cr,Re(Lam-Tram) "HOLE CLEANING SVeie*,ry Rs"gVe'o�;iy 6/, * L'fi„9 CaP a�'cy % * _ C 9 Cope /, * Pee a „Rai- *CASING SHOE PRESSURES ECD ECD–C„��'aps Y *TOTAL DEPTH PRESSURES ECD /,. ECDC �z'ngs – — Q NII SWAG CINGSA S LCook Inlet Natural:Gas ORA J 1 P•+p Well, Cannery Loop #5 as a A Schlumberger Company Kenai, Alaska DAILY DISCUSSION RECAP 12/22/2011 TD=1010 Report Na.=1 Built spud mud--gel and Gelex as needed for viscosity 12/23/2011 O TD=2400 Report No.=2 Alternate slide/rotary drilling from 1027-1844; service and inspect top drive; replace top drive comm. cable, slide/rotary drilline to TD @2400; circulate viscous sweep around surface-to-surface until hole cleaned up; short trip 12/24/2011 TD=2400 Report No.=3 POOH from 1927-790; RIH back to 2322'; reamed/washed down to 2400--tagged 2 fill; circulated a high viscosity sweep around; monitor well; POOH; L/D BHA; rigged up, ran casing; RIH with 5 inner string; tagged float collar and prepared to circulate 12/25/2011 TD=2400 Report No.=4 Cement in place at 04:00. Circ casing clean. POH w/DP. RD diverter. 12/26/2011 TD=2400 Report No.=5 N/U BOPE; test BOPE; mix new Kla-Shield mud system 12/27/2011 TD=4038 Report No.=6 Wait on orders--reboot CANRIG computers; tag TOC (soft) @2336; drilled out shoe track, float collar @2346 through shoe @2390-2400'; drilled new hole @2420'; circ./cond. displace to new mud system; FIT to @15.5 PPG EMW; drilled ahead pumping sweeps as needed to 4230 @midnight 12/28/2011 TD=5572 Report No.-7 Drilled @4230-4900'; tiro./oond. high viscosity sweep; short trip @4900-3846'; wash/ream up to casing shoe; service top drive; RIH on elevators to 4165'; wash/ream to bottom; drilled ahead to @5571'@midnight 12/29/2011 TD=7185 Report No.=8 Drilled @5571-6529'; circulate/condition pump viscous sweep around; backream 6529-4709'; tight spot @5571-5475'; RIH on elevators @4709-6528 washed last stand to bottom; drilled @6912-7103'; circulated viscous 30 bbl sweep surface to surface while rotating and reciprocating pipe at 130 rpm; drilled to 7295 @report time 12/30/2011 TD=8872 Report No.=9 Cook Inlet Natural Cas Mi SWAC CINGSA STORA ASchlumberger Company Well: Cannery Loop #5 as "�dp Kenai, Alaska Drilled @9295-7677; viscous sweeps pumpedOevery 500'; circulate and condition; drilled @7677-8347; circulate and condition viscous sweep--worked pipe @8347-8251 ; drilled on to TD @8872; circulate and condition with high viscosity sweep surface to surface; started back reaming 12/31/2011 TD=8872 Report No.-10 Back reamed @8634-7964; ran back to bottom--circulated and spotted lube pill treated with LCM on bottom; pulled 10 stands on elevators; back reamed 7964-6241' (tight 7391-6241'--double wiped until clean); circulate condition bottoms up; back reamed 6241-2409; circulate/condition until shakers cleared up; POOH on elevators 1/1/2012 TD=8872 Report No.-11 POOH from 539'; set back HWDP; L/D BHA; change rams; test BOPE; rig down from test; rig up--run casing to 2386'; circulate/condition--bottoms up; run casing to 4015'; circulate/condition--bottoms up; run casing to 5474' @report time 1/2/2012 TD=8872 Report No.-12 Circulate/condition CBU @5515'; run casing to 7031'; circulate/condition CBU @7031'; run casing to 8791'; washed down to 8832'; P/U, M/U landing joint and hanger; wash down and land casing @8860.95; rig up/circulate and condition--pumped cement first and second stage; bumped plug; dumped excess cement, mud push, contaminated mud; CIP @19:36 hrs; rig down cementers, lines; prepare cellar and wellhead to install, test 9-5/8" packoffs 1/3/2012 TD=8872 Report No.-13 Rigged down Weatherford casing equipment; change out to short bales; change rams--clean out cement and repair blind rams; rig up--test BOPE; service/repair top drive, test BOPE; pick up BHA 1/4/2012 TD=8872 Report No.-14 Make up BHA; RIH and drill out DV plug/c mt to 3539'. Tested casing to 2500 PSI. Continued tripping in hole, drilled float collar and shoe track. 1/5/2012 TD=9861 Report No.-15 Continued drilling and sliding ahead to 9.861' MD (5,087'TVD). 1/6/2012 p TD=10406 Report Ne.=16 Continued drilling and sliding to 10,048' MD. Circulated BU and began pulling to shoe. Packed off with 50 bbls loss at 9,150'. Pumped 40 bbl LCM pill @ 33 lb/bbl. Established returns. Continued short trip, service top drive and blocks. TIH to 9.953', wash to 10,048' and pumped 60 bbls LCM pill. Continued drill and slide to 10,336'. Stopped to repair top drive COM cable. Continued drilling and sliding to 10,406' MD. 1/7/2012 TD=11101 Report No.-17 L NII �'�/At: CINGSA Cook Inlet Nafural;Cas STORAQ A Schlumberger Company Well; Cannery Loop #5 a$ a :,;47. as Kenai, Alaska Drill to 11,101'MD/5127'TVD. Circ hole clean and pump out to the shoe. RIH to bottom, pumped bottoms up. Pumped 50 bbls LUBE 776 pill, spotted in OH, Prepare to trip out. 1/8/2012 TD=11101 Report No.-18 RIHto bottom; spot Lube pill; POH to 10,130 on elevators. Pumps were unable to get charge fluid; check all valve seats and suctions, mix new mud in the pill pit; have to circ at reduce flow due to lubes greasing out on screens. Pump out of hole to shoe while circ hole clean. Pump dry job and POH. Laying down BHA. 1/9/2012 TD=11101 Report No.-19 Continued POOH, laying down BHA.. Run CBL; RU liner handling equipment and began running in with 7" liner. 1/10/2012 TD=11101 Report No.=20 RIH w/liner to 9018'; would not go down; POH and LD liner. 1/11/2012 TD=11101 Report Ne.=21 Tripped out of hole, laying down 7" liner. PU drill pipe, cut and slipped line. PU BHA with mill. TIH with BHA to 8,824. Circ and cond mud; Ream and wash centralizer and clamps from 8,224 to 10,259' MD. 1/12/2012 TD=111101 Report No.-22 p Pump and rotate at 350 gpm and 60 rpm to bottom; ICU X 2; pump and rotate at the same rates up hole to 9110'. Circ at 1.8 bpm past coals to 8950 and increase pump rate to 300 gpm into the shoe. POH to 8060 and circulate the hole clean. Pump dry job and POH. LDA assembly and prepare to RIH w 7" liner. 1/13/2012 TD=11101 Report No.-23 RIH to 8800' w/the liner; Circ liner volume. Start RIH pumping 22-24 spm. RIH to 9030'; have to work and rotate down until pipe went down without rotation at 9280. Liner went down to bottom without further problems. Circulated and conditioned. Held PJSM and performed cementing job. Dropped dart, and bumped plug. 1/14/2012 TD=11101 Report No.=24 CIPat 01:10. Set packer, release from liner. Circ hole clean. POH w/DP. Dump mud and start cleaning pits. Trip out of hole, pumped dry job. Blow down top drive. Lay down pipe and liner running tool. Service rig. TIH with Baker mill tool. Tagged top of BPR @ 8,684'. Tag and dress 3 times. Tested casing to 2500 psi. Prepare to displace to brine. 1/15/2012 TD=11101 Report No.-25 Displaced KLA-GARD fluid with 6% KCI brine. TOOH, laying down pipe. PU & MU completion tubing running tools and seal assembly, prepare to RIH with 95 joints of 7 Tie-back tubing. 1/16/2012 TD=11101 Report No.-26 RIH /7 tbg; space out, pump packer fluid, land tubing. ND Stack; NU tree, test. Mi SWAG Cook Inlet Natural-Gas CINGSA STORA( i Well: Cannery Loop #5 Q$`Q ..r� A Schlumberger Company Kenai, Alaska Fluid Volume Summary Mi SWA '_ � Volume Account Report A Schlumberger Company - Operator CINGSA Spud Date: December 22,2011 Well Name: CLU Storage 15 Mud Volume(bbl) Mud Bit(bbl) Volume lost(bbl) e .d w v a e _ o 7 u a O v Date r6t� Depth Mod Type MW 2 d `� `0 6 i r & e g e e arm I a 1 e G E S. a Qd r, y a L. 8 12722/2011 13.375 866 Gel Spud I 8.8 257 565 822 1000 12 1012 1012 I 189 .� - Y_- ---i---- l- - 12/2312011 13.375 2400 Bel Spud 9.1 629 435 1084 720 24 744 1756 503 I 1212412011 13.375 2400 Gel Spud l 9.1 333 435 769 2 2 1758 75 11 I 212 1212512011 13.375 2400 Gel Spud 8.4 382 489 850 443 3 446 2204 I 374 1212812011 9.625 2400 01a-Shield 8.9 333 691 1024 600- 47 647 2851 15 I 445 12/2112011 9.625 4038 KlaShield I 9 570 702 1272 1450 24 1474 43251239 12128/2011 9.625 5382 019-Shield I 9 795 649 1444 500 41 541 4887 314 13 I 12/2912011 9.625 7185 Kle-Shield 9.05 1031 748 1779 900 58 862 5528 280 59 I 12/30/2011 9.625 8872 KlaShield I 9.3 1278 661 1939 785 77 882 6391 522 154 1 13 12131/2011 9.825 8872 014-Shield I 9.3 1321 503 1823 13 23 36 6428 155 V112012 9.625 8672 01e-Shield 9.4 1350 452 1802 2 2 8428 49 -52 13 172/2012 9.625 8872 KlaShieldI 9.49.4 674 355 370 1399 93 10 103 6531 21 495 11312012 7 _ 8872 Ole-Shield i 94 873889 1362 6531 11 131 1141201I 7 8672 01a-Shield ( 9.2 596 579 112 1287 12 12 6543 I 100 115/2012 7 9857 Kla-Shield 9.2 858 680 112 1430 222 40 262 6805 12 L 95 1/612012 7 10404 Kle-Shield I 9.2 692 511 77 1279 238 25 263 7068 200 I 225 1/772012 7 11101 Kia Shield ! 9.2 738 571 10 1318 217 20 237 7305 24 I 184 119/2012 7 11101 KlaShield 9.1 827 380 10 1228 7305 102 I 1/8/2012 7 11101 KlaShield 9.1 790 371 , 22 1183 7305 14 I 83 510/2012 7 11101 KlaShield I 9.1 829 385 108 1322 175 8 183 7488 I 57 11152012 7 11101 Ole-Shield 92 752 501 -1 1253 5 5 - 7193 1/ /7 1/1272012 7 11101 019-Shield I 9.2 823 530 -1 1352 160 31 191 7684 I 108 513/2012 7 11101 KlaShield I 915 891 593 14 1298 143 11 154 7838 15 i 177 61412012 7 11101 KlaShield I 8.7 691 41 14 746 15 4 19 7856 i 588 1/1572012 7 11101 KlaShield 8.7 706 105 -1 810 814 27 841 8897 15 I 747 918/2012 7 Ole-Shield I 8.6 665 135 -1 799 11 7 19 8715 I 43 Cook Inlet Natural;Gas Mi sWAC Welnl;: Cannery Loop #5 dSTORACA7 1. A Schlumberger Company Was a Kenai, Alaska Highlights • An casing strings were run and cemented without problems. • The liner had to be pulled a cleanout run was performed before successfully landing the liner. • All the required mud products were available and delivered to the well site in a timely manner. • There were no HSE incidents attributable to M-I SWACO personnel during the drilling of the Cannery Loop #5 well. • This is the last of the 5 wells for the Enstar drilling campaign. Lessons Learned and Recom mendations Written instructions should be handed to the pit watchers along with verbal instructions for additions of product. It should be noted how much and how fast a product is to be added to the system. Any questions on this should be brought up. • If there is suspicion that the fluid has issues, nothing should be added to it unless it is to come to a solution. • Do not add Barite while adding Lubricants. This causes greasing issues and will blind off screens. • Inspect shaker screens on every connection. Replace when there are any signs of holes. Do not allow shakers to be used if there are holes in the screens. Mi SWAC Cook Inlet Natural;has CINGSA T SORAQ A Schlumberger Company Well: Cannery Loop #5 1 p '� —as.at Kenai, Alaska APPENDIX Mi SWAG Cook Inlet Natural:Gas CINGSA STORA A Schlumberger Company Well: Cannery Looe #5 ns ar ; ',' Kenai, Alaska A, PRODUCT CONCENTRATIONS Mi SWAG Product Concentration A Schlumberger Company - Operator: CINGSA Contractor: Nabors Drilling Well Name: CLU Storage#5 M-1 Engineer: Brown/Rooney Location: Kenai, Alaska Rig Name: Nabors 105E Field/Area: Cannery Loop/Kenai Stock Point: Product Products Concentrations(lb/bbl) Name 22-Dec-11 23-Dec-11 24-Dec-11 25-Dec-11 26-Dec-11 27-Dec-11 28-Dec-11 29-Dec-11 ASFI-IASOL SUPREME 50 LB BG 0.144 1683 CAUSTIC SODA 50 LB BG 0.064 0.064 0.030 0.017 0.061 0.22 0.309 FLO-VIS PLUS 25LBBG POLYPAC SUPREME UL 50 LB BG 0.255 0.255 0.20 14'8 1014 126 1307 POTASSIUM CHLORIDE(KCL) 50 LB BG 2.099 6.073 8.817 11829 CONQOR 404 55 GA DM 0.617 0.235 0.166 0.978 M-I WATE(BARRE) 50 LB BG 2.955 3.597 2.059 0.783 0.553 0.380 SODIUM METABISULFITE 50 LB BG 0.337 0.128 0.090 0.062 SAFE-CARB 10 50 LB BG SAFE-GARB 40 50 LB BG, 2.693 1171 1966 195 SAFE-CA RB 250 50 LB BG SODA ASH 50 LB BG 0.032 0.032 0.08 0.076 0.175 0.24 0.085 KLA-GA RD 55 GA DM 2.714 1032 0.729 0.501 M-I GEL EXPORT 50 LB BG 2.380 8.856 18.88 8.857 5.070 1928 1362 0.935 GELEX BENT EXTENDER 2 LB BG 0.002 0.001 0.001 0.006 0.002 0.002 0.001 CITRIC ACID 50 LB BG 0.88 0.064 0.045 0.031 CF DESCO II 25 LB BG 0.141 0.87 0.27 0.041 0.029 0.020 SODIUM BICARBONATE 50 LB BG 0.242 0.138 0.053 0.037 0.026 CONQOR A303 55 GA DM DEFOAM X 5GACN MDC II FINE 25LBBG MDC II MEDIUM 25LBBG M-I SEAL FINE 40 LB BG M-I SEAL MEDIUM 40 LB BG PECAN NUT PLUG MEDIUM 50 LB BG PECAN NUT PLUG CSE 50 LB BG SA PP 50 LB BG 0.58 0.064 0.045 0.031 G-SEAL 50 LB BG BIOZAN 50 LB BG RESINEX 50 LB BG 0.433 MDC II COARSE 25LBBG SAFE- ARB 20 50 LB BG MAGMA FIBER REG 30 LB BG MAGMA FIBER FINE 25 LB BG LOTORQ 1GA 0.956 5.026 6.376 DUO-VIS 25 LBB G MYACIDE GA25 5GACN 0.056 0.021 0.08 0.02 SCREENKLEEN 1GA FLOWZAN 25 LB BG 0.471 0.600 0.841 0.931 Sita LUBE EP 55 GA DM PECAN NUT PLUG FINE 50 LB BG LUBE 776 55 GA DM 0.778 Mi SWAC Gook Inlet Natural:Gas CINGSA STORA c, Well: Cannery Loop #5 J '''47 'N A Schlumberger Company �k a., .." Kenai, Alaska Mi SWI:!, Product Concentration A Schlumberger Company Operator: Faulkner/Smith Contractor: Nabors Drilling Well Name: CLU Storage#5 M-1 Engineer: Brown/Rooney Location: Kenai, Alaska Rig Name: Nabors 105E Field/Area: Cannery Loop/Kenai Stock Point: Product Products Concentrations(Ib/bbl) Name 30-Dec-11 31-Dec-11 1-Jan-12 2-Jan-12 3-Jan-12 4-Jan-12 5-Jan-12 6-Jan-12 ASFHASOL SUPREME 50 LB BG 3.413 3.372 3.393 3.187 3231 3.198 2.602 2.207 CAUSTIC SODA 50 LB BG 0.285 0281 0283 0.266 0269 0267 0.217 0.286 FLO-VIS PLUS 25 LB BG POLY PAC SUPREME UL 50 LB BG 1111 1096 1133 1036 1050 1040 0.846 0.718 POTASSIUM CHLORIDE(KCL) 50 LB BG 12.556 4.387 4.465 11708 11868 11747 11293 9.459 CONQOR 404 55 GA DM 0.661 0.652 0.656 0.618 0.625 0.618 1138 0.922 M-I WATE(BARITE) 50 LB BG 7.222 1168 126 6.517 5.705 5.646 4.595 3.897 SODIUM METABISULFITE 50 LB BG 0.042 0.041 0.042 0.039 0.040 0.039 0205 0.309 SAFE-CARE 10 50 LB BG SAFE-CARE 40 50 LB BG 2.511 3.841 3.865 3.631 3.680 3.643 4.177 4.970 SAFE-CARS 250 50 LB BG 0.950 0.937 0.943 0.886 0.898 0.889 1763 2207 SODA ASH 50 LB BG 0.057 0.057 0.057, 0.054 0.054 0.054 0286 0.490 KLA-GA RD 55 GA DM 0.338 1353 1361 1278 1296 1283 1044 0.885 M-I Ga.EXPORT 50 LB BG 0.632 0.624 0.628 0.590 0.598 0.592, 0.481 0.408 GELEX BENT EXTENDER 2 LB BG 0.001 0.001 0.001 0.001 0.001 0.001 0.003 0.003 CITRIC ACID 50 LB BG 0.021 0.021 0.021 0.969 0.725 0.717 1104 0.900 CF DESCO II 25 LB BG 0.013 0.013 0289 0.530 0.538 0.532 0.554 0.579 SODIUM BICARBONATE 50 LB BG 0.017 0.017 0.569 1052 1066 1055 0.859 0.728 CONQOR A303 55 GA DM DEFOAM X 5 GA CN MIX II FINE 25 LB BG MX II MEDIUM 25 LB BG 0.398 0.633 M-I SEAL FINE 40 LB BG M-I SEAL MEDIUM 40 LB BG PECAN NUT PLUG MEDIUM 50 LB BG 0.416 0.442 PECAN NUT PLUG CSE 50 LB BG SAPP 50 LB BG 0.021 0.021 0.021 0.408 0.413 0.409 0.333 0282 G-SEAL 50 LB BG 1074, 1395 BIOZAN 50 LB BG RESINEX 50 LB BG 1140 125 1132 1063 1078 1067 1214 1417 MX II COARSE 25 LB BG 0.22 SAFE-CARS 20 50 LB BG 2.627 2.644 2.483 2.517 2.492 2.790 2.472 MAGMA FIBER REG 30 LB BG MAGMA FIBER FINE 25 LB BG LOTORQ 1GA 7.287 8.509 8.562, 8.042 8.152 8.069 8.376 6.980 DUO-V IS 25 LB BG MYAODE GA25 5 GA CN 0.092 0.007 0.007 0.007 0.007 0.007 0.063 0.050 SORB NKLB N 1 GA FLOWZAN 25 LB BG 0.82 0.833 0.839 0.788 0.798 0.790 0.730 0.613 STEEL LUBE EP 55 GA DM 102 0.792 PECAN NUT PLUG FINE 50 LB BG LUBE 776 55 GA DM 1152 1137 1144 1074 1089 1078 2.591 4.572 Cook Inlet Natural;-Gas Mi SWAC �_J/i► CINGSA STOD J� A Schlumberger Company J " "l Well. Cannery Looe #5 STORA Q� Q :II' �, Kenai, Alaska Mi 'SSWAC_,i.,� Product Concentration A Schlumberger Company Operator: Contractor: Nabors Drilling Well Name: CLU Storage#5 M-1 Engineer: Brown/Rooney Location: Kenai, Alaska Rig Name: Nabors 105E Field/Area: Cannery Loop/Kenai Stock Point: Product Products Concentrations(Ib/bbl) Name 7-Jan-12 8-Jan-12 9-Jan-12 10-Jan-12 11-Jan-12 12-Jan-12 13-Jan-12 14-Jan-12 ASFI-ASOL SUPREME 50 LB BG 1779 1796 1605 1478 3.161 2.839 2.601 2.541 CAUSTIC SODA 50 LB BG 0.720 0.727 0.600 0.552 0.521 0.448 0.411 0.401 FLO-VIS FLUS 25 LB BG POLYPAC SUPREME UL 50 LB BG 0.709 0.716 0.592 0.545 0.591 1018 0.932 0.911 POTASSIUM CHLORIDE(KCL) 50 LB BG 11362 7.676 12.314 9.492 2.891 16.527, 8.901 8.507 CONQOR 404 55 GA DM 0.735 0.742 0.613 0.564 0.532 0.458 0.420 0.412 M-I WATE(BARITE) 50 LB BG 3.142 3.172 6.309 8.552 7.949 12.035 16.784 8.393 SODIUM METABISULFITE 50 LB BG 0.244 0.247 0204 0.187 0.177 0.152 0.139 0.136 SAFE-CARB 10 50 LB BG SAFE-CARB 40 50 LB BG, 5.727 5.781 3.828 3.525 3.430 2.952 2.704 2.641 SAFE-CARB 250 50 LB BG 2.304 2.326 1995 1837 1759 1514 1387 1355 SODA ASH 50 LB BG 0.388 0.392 0.323 0.297 0.433 0.746 0.683 0.667 KLA-GA RD 55 GA DM 0.714 0.720 0.596 0.549 0.58 185 1663 1624 M-I GEL EXPORT 50 LB BG 0.329 0.332 0275, 0.253 0.239 0.206 0.88 0.84 GELEX BENT EXTENDER 2 LB BG 0.002 0.002 0.002 0.002 0.002 0.001 0.001 0.001 CITRIC ACID 50 LB BG 0.719 0.726 0.600 0.552 0.521 0.449 0.411 0.401 CF DESCO II 25 LB BG 0.660 0.666 0.550 0.506 0.478 0.411 0.377 0.368 SODIUM BICARBONATE 50 LB BG 0.980 0.989 1095 1008 0.946 0.950 0.870 0.850 CONQOR A303 55 GAD M DEFOAM X 5 GA CN MIX II FINE 25 LBB G MIX II MEDIUM 25 LB BG 0.500 0.505 0.417 0.383 0.362 0.311 0.285 0.278 M-I SEAL FINE 40 LB BG M-I SEAL MEDIUM 40 LB BG PECAN NUT PLUG MEDIUM 50 LB BG 0.349 0.352 0.290 0.267 0252 0.217 0.199 0.194 FECAN NUT PLUG CSE 50 LB BG SAPP 50 LB BG 0.228 0230 0.190 0.175 0.55 0.142 0.130 0.27 G-SEAL 50 LB BG 1102 1112 0.917 0.845 0.796 0.685 0.628 0.613 BIOZAN 50 LB BG RESINEX 50 LB BG 1131 1142 0.943 0.869 0.820 0.705 0.646 0.631 MIX II COARSE 25 LB BG SAFE-CA RB 20 50 LB BG 2.420 2.443 2.080 195 1828 1573 1441 1408 MAGMA FIBER REG 30 LB BG MAGMA FIBER FINE 25 LB BG LOTORQ 1GA 5.605 5.658 4.678 4.307 4.065 3.499 3.206 3.131 DUO-VIS 25 LB BG MYACIDE GA25 5 GA CN 0.039 0.040 0.033 0.030 0.028 0.138 0.126 0.23 SCREENKLEEN 1GA 1369 1254 1914 FLOWZAN 25 LB BG 0.493 0.498 0.550 0.507 0.571 0.746 0.772 1130 S I tt L LUBE EP 55 GA DM 0.626 0.632 0.521 0.480 0.452 0.389 0.357 0.348 PECAN NUT PLUG FINE 50 LB BG LUBE 776 55 GA DM 4.864 3.658 4.979 4.584 4288 3.691 3.381 3.303 MI SWAG Cook Inlet Nafural;"Cas CINGSA F.. Well. Cannery Loop #5 STORAC QS Q A Schlumberger Company Kenai, Alaska Mi SWAG Product Concentration A Schlumberger Company Operator: Contractor: Nabors Drilling Well Name: CLU Storage#5 M-1 Engineer: Brown/Rooney Location: Kenai, Alaska Rig Name: Nabors 105E Field/Area: Cannery Loop/Kenai Stock Point: Product Products Concentrations(Ib/bbl) Name 15-Jan-12 16-Jan-12 ASFHASOL SUPREME 50 LB BG CAUSTIC SODA 50 LB BG FLO-VIS PLUS 25 LB BG POLY PAC SUPREME UL 50 LB BG POTASSIUM CHLORIDE(KCL) 50 LB BG 22.404 21913 CONDOR 404 55 GA DM M-I WATE(BARITE) 50 LB BG SODIUM METABISULFITE 50 LB BG SAFE-GARB 10 50 LB BG SAFE GARB 40 50 LB BG SAFE-CARB 250 50 LB BG SODA ASH 50 LB BG KLA-GA RD 55 GA DM M-I GEL EXPORT 50 LB BG GELIX BENT EXTENDER 2 LB BG CITRIC ACID 50 LB BG CF DESCO II 25 LB BG SODIUM BICARBONATE 50 LB BG 0.182 0.178 CONDOR A303 55 GA DM 2287 DEFOAM X 5 GA CN MIX II FINE 25 LB BG MIX II MEDIUM 25 LB BG M-I SEAL FINE 40 LB BG M-I SEAL MEDIUM 40 LB BG PECAN NUT PLUG MEDIUM 50 LB BG PECAN NUT PLUG CSE 50 LB BG SAFP 50 LB BG 0.563 G-SEAL 50 LBB G BIOZAN 50 LB BG RESINIX 50 LB BG MX II COARSE 25 LB BG SAFE-CA RB 20 50 LB BG MAGMA FIBER REG 30 LB BG MAGMA FIBER FINE 25 LB BG LOTORQ 1GA DUO-VIS 25 LB BG MYAODE GA25 5 GA CN 0.050 0.049 SCREENKLEEN 1GA FLOWZAN 25 LB BG 0.061 0.059 STEEL LUBE EP 55 GA DM PECAN NUT PLUG FINE 50 LB BG LUBE 776 55 GA DM Mi SWAG Cook Inlet Natural,Gas CINGSA TORAQ J _ Well, Cannery Looe #5 SaS a A Schlumberger Company Kenai, Alaska B . HOUSTON LAB REPORT Mi SWAG A Schlumberger Company ANALYTICAL SERVICES LABORATORY 5950 NORTH COURSE DRIVE,HOUSTON,TX 77072 281 561-1383 FAX 281 561-7240 Project Number AS074-0112-2012 Analyst : Sue Wong Date : 1-12-2012 Sample Identification: WBM &filtrate from CINGSA CLU Storage#5 Kenai, Alaska USA Lab Master# :20120112 Request : PSD &Calcium Testing Procedure : Coulter, Atomic Absorption Spectroscopy Test Data: Particle size Distribution----See 0112-074 pdf. Sample IDI Calcium 20120112 100 mg/1 Copies to: Eric Davis Signed: Sue Wong Marc Churan Page 1 of 1 Notice:This report is limited to the described sample tested. Any person using or relying on this report agrees that M-1 L.L.c. and its affiliates shall not be liable for any loss or damage,whether due to act or omission, resulting from such report or its use. MI SWACO ASchlumberger Company ANALYTICAL SERVICES LABORATORY 5950 NORTH COURSE DRIVE, HOUSTON,TX 77072 281 561-1383 FAX 281 561-7240 Project Number : AS072-0111-2012 Analyst : Marc Churan Date : 1-12-2012 Sample Identification: KLA-SHIELD WBM from CINGSA, well CLU Storage 5 Alaska Lab Master Number: Request : Extractable organics, water wet solids, analysis of solids Testing Procedure : Extraction with dichloromethane, Gas Chromatography/mass spectrometry(GC/MS) Separation of solids, X-ray diffraction (XRD) Test Data: The sample as received exhibits only a small amount of oil wet solids. Total extractable organics was about 1.8 v/v% of the sample. GC/MS scan of the extractable organics shows peaks typical of LOTORQ and LUBE 776 as seen in Figure 1. KLA-SHIELD WBM 1-9-2012 Water wet/oil wet solids Mostly water wet with only a small amount of oil wet solids seen Sample dispersed in water with no greasing seen Sample only slightly dispersed in organic solvent Extractable organics 14,100 mg/L (Approximately 1.8 v/v%) GC/MS of extracted organics Sample shows peaks for Lotorq and Lube 776 See Figure 1 Insoluble solids 16.3 wt% of whole sample Mineralogy of solids Copies to: Pete Nelson Signed: Marc Churan Jim Cucullu Ray Figueroa Robert Haag Page 1 of 2 Notice: This report is limited to the described sample tested. Any person using or relying on this report agrees that M-I L.L.0 shall not be liable for any loss or damage,whether due to act or omission, resulting from such report or its use. Figure 1. GC/MS fingerprint scan of extractable organics from WBM: 4.0E+07 - 3.5E+07 - 3.0E*07 - 2.5E+07 - o .`1 u J J OOOG 2 s 2.0E+07 - Q J O 0 1.5E+07 - 1 0E+07 - 0 O J O J 5.0E+06 - o °a J O L O JI ' 2 5 8 11 14 17 20 23 26 29 32 35 38 41 44 47 50 53 56 59 62 65 68 71 74 Time,Minutes Copies to: Pete Nelson Signed: Marc Churan Jim Cucullu Ray Figueroa Robert Haag Page 2 or 2 Notice:This report is limited to the described sample tested. Any person using or relying on this report agrees that M-I L.L.0 shall not be liable for any loss or damage,whether due to act or omission, resulting from such report or its use. Mi SWA ,�� Beck' n Coulter LS Particle Size Analyze A Schlumberger Company 12 Jan 2012 13:44 M-I SWACO Analytical Services Laboratory File name: C:\LS13320\samples\Samples 2011\20120112_13_01.$Is 20120112_13_01.$Is File ID: 20120112 Sample ID: GINGSA 9.29 PPG KLASHIELD WBM Operator: Sue Wong Run number: 13 Comment 1: CLU Storage#5 Kenai,Alaska USA Comment 2: AS074-0112-2012 Optical model: Fraunhofer.rf780d PIDS included Residual: 0.60% LS 13 320 Universal Liquid Module Start time: 13:40 12 Jan 2012 Run length: 62 seconds Pump speed: 55% Obscuration: 5% PIDS Obscur: 44% Fluid: water Software: 5.01 Firmware: 2.02 GINGSA 9.29 PPG KLASHIELD WBM 3- 20120112 13_01.$1s Diff.Volume -100 20120112 13 01.$Is Cum.<Volume 2.5- - - -80 2- _ -70 0 E -60 E z - o > 1.5- - / - - -50 v To _ a) c - - -40 •� o - - -30 U - -20 0.5- - - -10 0 1 r r 1 I I I 1 1 l 1 r 1 rii i , r r l I 0 0.04 0.1 0.2 0.4 1 2 4 6 10 20 40 60 100 200 400 1000 2000 Particle Diameter(pm) Volume Statistics(Arithmetic) 20120112_13_01.$Is Calculations from 0.040 pm to 2000 pm Volume: 100% Mean: 10.40 pm S.D.: 14.55 pm Median: 4.746 pm Variance: 211.6 pm2 Mean/Median ratio: 2.192 Skewness: 2.448 Right skewed Mode: 6.453 pm Kurtosis: 6.154 Leptokurtic <10% <25% <50% <75% <90% 0.843 pm 1.842 pm 4.746 pm 11.49 pm 29.17 pm 20120112_13_01.$1s Particle Volume Particle Volume Diameter % < Diameter % < Pm um 1 12.6 75 99.5 1.5 20.4 84 99.9 2 27.0 90 99.96 3 37.3 96 99.99 4 45.1 128 100 6 56.9 192 100 8 65.5 256 100 10 71.7 384 100 12 76.0 512 100 16 81.4 768 100 24 87.7 1024 100 25 88.3 1536 100 32 91.0 2000 100 48 95.6 50 96.1 64 98.5 72 99.3 Mi SWACD A Schlumberger Company ANALYTICAL SERVICES LABORATORY 5950 NORTH COURSE DRIVE,HOUSTON,TX 77072 281 561-1383 FAX 281 561-7240 Project Number : AS072-0111-2012 Analyst : Marc Churan Date : 1-12-2012 Sample Identification: KLA-SHIELD WBM from CINGSA, well CLU Storage 5 Nabors 105 rig Alaska Lab Master Number: 20120112 Request : Extractable organics, water wet solids, analysis of solids Testing Procedure : Extraction with dichloromethane, Gas Chromatography/mass spectrometry(GC/MS) Separation of solids, X-ray diffraction (XRD) Test Data: The sample as received exhibits only a small amount of oil wet solids. Total extractable organics was about 1.8 v/v% of the sample. GC/MS scan of the extractable organics shows peaks typical of LOTORQ and LUBE 776 as seen in Figure 1. The solids in this sample are primarily formation solids and clays as shown in table below. KLA-SHIELD WBM 1-9-2012 Water wet/oil wet solids Mostly water wet with only a small amount of oil wet solids seen Sample dispersed in water with no greasing seen Sample only slightly dispersed in organic solvent Extractable organics 14,100 mg/L (Approximately 1.8 v/v%) GC/MS of extracted organics Sample shows peaks for Lotorq and Lube 776 See Figure 1 Insoluble solids 16.3 wt% of whole sample Mineralogy of solids Quartz 44% Feldspar 15% Calcite 3% Siderite 2% Barite 2% Hematite 1% Kaolinite 6% Illite 4% Smectite and 23% mixed layer clays CEC = 18 meq/100 grams Copies to: Pete Nelson Signed: Marc Churan Jim Cucullu Ray Figueroa Robert Haag Page 1 ,,f 2 Notice:This report is limited to the described sample tested. Any person using or relying on this report agrees that M-I L.L.0 shall not be liable for any loss or damage,whether due to act or omission, resulting from such report or its use. Figure 1. GC/MS fingerprint scan of extractable organics from the KLA-SHIELD WBM: 4.0E+07 - 0 0 3.5E+07 3.0E+07 - 2.5E+07 - o � O C J J (O A C C 2 2.0E+07 - Q J A rc 1.5E+07 - J 1.0E+07 - 2 O J 22 J 5.0E+06 - o O o JI 1.0E+00 t r� - `-- . 2 5 8 11 14 17 20 23 26 29 32 35 38 41 44 47 50 53 56 59 62 65 68 71 74 Time,Minutes Copies to: Pete Nelson Signed: Marc Churan Jim Cucullu Ray Figueroa Robert Haag Page 2 of 2 Notice:This report is limited to the described sample tested. Any person using or relying on this report agrees that M-I L.L.0 shall not be liable for any loss or damage,whether due to act or omission, resulting from such report or its use. Schlumberger CLU-STORAGE#5: Cementing Recap Executive Summary: Surface Casing 2390' MD: The Surface Casing Cement job was accomplished during the early hours of Christmas morning 12-25-2011, with the primary objective to observe cement returns to surface, and provide sufficient shoe strength and isolation to drill ahead. Planning called for 75% Open-hole excess, based on the volume to surface on previous wells. The hole was circulated with casing on bottom for 1 1/2 hour (about 1.25 times hole vol). 40 bbls of spacer was pumped ahead of the cement. With approximately 225 bbls of Lead slurry pumped, cement was seen at surface. Lead was continued for 19 bbls, and then shut down with 244 bbls total of 12.0 ppg lead slurry pumped. 1 ,Z �6 � 4 The volume indicates a virtually gauge 16" hole.= `'� .• iL 64 bbls of 15.4 ppg Tail slurry were pumped. eel Approxoimately 115 bbls of lead was returned to surface. .,L-- There There were no losses during the job. The cement job utilized an inner-string with a stab-in collar; all of the float equipment functioned as expected. Drill out was accomplished without incident and the expected isolation was confirmed r with a 15.5 ppg EMW FIT test. Costs were in-line with preliminary estimates. Intermediate Casing 8860' MD: The Intermediate Cement job was accomplished on 01-02-2012. The primary objective was to ensure zonal isolation from the shoe to 8660' with F1exSTONE slurry, to ensure a competent seal above the storage zone. The secondary objective was lead cement for the length of the casing, for isolation of minor gas-sands in the well, as well as protection of the casing for the life of the well. The cement job was done in two stages, with a DV tool at approximately 3510' MD. Pre job planning called for 10% open-hole excess. During the casing run the rig circulated bottoms up at the surface shoe, and at 1500' intervals to 7800', where the interval was cut in half, and 2 more bottoms up were circualated between 7800' and TD. Full returns were established after landing out, and 2 more circulations were done prior to commencing the cement job. 40 bbls of MUDPUSH II spacer, pumped with the rig pumps. 299 hhls of 12..0 ppg I. .ad slurry were pumped 4R hhls of 14 0 ppg FIexSTONE Tail slurry was pu raped. The plug was bumped as anticipated, and the stage collar opened successfully. An anullar volume from the stage collar to surface was pumped. There was approximately 90 bbls of contaminated mud/spacer/cement returned to surface. Schlumberger The daily report indicates that pre job circulation at TD; pumped at 4 BPM had surface pressure of 510 psi. Modeling indicates that a hole possibly as tight as 10.5 inches for at least 1500' would create that pressure at that rate. Other factors can also influence the pressure, but a smaller than anticipated "mobile" anullar volume would sufficiently impact pressure, as well as the volume of hole displaced by the cement, as indicated by the volume of cement and spacer returns for this section. The second stage was pumped using 40 bbls of MUDPUSH II spacer. and 212 bhls of 12.0 ppg Lead slurry. The closing plug was dropped and the stage collar successfully closed. Mud contaminated with spacer and cement was reported at surface —80 bbls. Drill out was accomplished without incident, and a Leak-Off-Test performed indicating a 15.0 ppg EMW at leak-off. A bond-log was run after the next hole interval had been drilled. Results were acceptable. Costs were in-line with preliminary estimates. Production Liner 8684' — 11,099' MD: The Liner was unable to be run to bottom on the first try. It was laid down, and a wiper trip made, prior to running again. The second time it was run the liner went to bottom, with some tight hole through the coal sections. The liner was circulated and reciprocated at TD, with full returns. After circulating for 2 hrs. the pipe was parked in the slips, and the cement head was rigged up. After rigging up the cement head, full returns were established, but the liner could no longer be moved. The Production Liner Cement job was accomplished on 01-14-2012. The primary objective was zonal isolation for the depleted gas-storage zone. Planned excess was 10%, plus 200' of slurry above the liner top. 40 bbls of MUDPUSH II spacer 69 bbls of F1exSTONE slurry at 14.0 ppg were pumped. The DP wiper dart was dropped, displacement was as expected, the wiper dart sheared, and the plug was bumped. The liner hanger and packer were set. Circulated the long way on top of the liner, traces of cement and spacer were seen on bottoms up. Liner and casing were pressure tested to 2500 psi. Costs were in-line with preliminary estimates. Cementing Job R"ort CemCATv1.4 Schlumberger Well CLU 5 Client Cingsa Field Kenai SIR No. BC8Z-00076 Engineer Peter Cahill Job Type Surface Casing Country United States Job Date 12-24-2011 I Time Treatment Press Rate DH Density WHP Messages 12/25/2011 00:15:3. 01:35:07 PJSM 01:50:00 rP)SM done Rig circulated 1 bottoms up continue to circulate till slb ready 02:05:00 f 1 Rear Head rate tested Reset Total,Vol=4.35 bbl Front head tested Reset Total,Vol=3.43 bbl LiuD down l p Reset Total,Voldril=0.39 ipe SRL moving 5 bbls h20 bbl 02:20:00 j / Reset Total,Vol=0.01 bbl ' 4 ' *� 2x2 open 1 I moving fluid Down on pump 5 bbls away Close valve on floor Clear ground for Low PT Low PT 1,000 psi 02:35:00 High PT 3,000 psi PT Pass 3,000 psi Line rig up to pump MP2 t Reset Total,Vol=4.21 bbl Batch time 12:35 AM lined up to pump lead open 2 inch 02:50:00 MB read 11.9 ppg Full returns Mix h20 50 bbls matching 48 bbls mix h20 on 70 bbls mix h20 away 03:05:00 swap silo 03:20:00 03:35:00 MP2 to surface suck tub swap to tail Cement to surface done with lead 244 bbls away Start batching Tail @ 15.4 ppg Reset Total,Vol=244.50 bbl • .,—.32 in open 03:50:00 39 bbls mix h20 away I Reset Total,Vol=64.18 bbl ' 64 bbls tail away lining up for h20 04:05:00 Pump 5 bbls h20 away Lining rig to displace 33.66 bbls o 04:20:00 C 04:30:26 I - rig displaced 33.66 bbls Cement in place 4:15 AM Cmt wash up hh:mm:ss 0.00 1000 2000 3000 0000 5000 0.00 2.0 4.0 6.0 8.0 10.0 5.0 8.0 11.0 10.0 17.0 20.0 0.00 1000 2000 3000 4000 5000 12/25/2011 51.24.2: PSI B/M LB/G — -PSI 12/25/2011 04:41:32 Schlumberger Laboratory Cement Test Report Nabors 105 CLU Storage 5 Surface Lead Field Blend Signatures Fluid No : PAK 11sfc4035 Client :CINGSA Location/Rig : Nabors 105 Date : Dec-23-2011 Well Name :CLU Storage 5 Field :Cannery Loop M. Schinnell Job Type 13 3/8"Surface Depth 2307.0 ft TVD 1957.0 ft BHST 85 degF BHCT 80 degF BHP 946 psi Starting Temp. 80 degF Time to Temp. 00:10 hr:mn Heating Rate 0.00 degF/min Starting Pressure 500 psi Time to Pressure 00:10 hr:mn Schedule () Composition Slurry Density 12.00 lb/gal Yield 2.45 ft3/sk / Mix Fluid 14.523 gal/sk Solid Vol.Fraction 20.743% Porosity 79.257% Slurry type Extended Code Concentration Sack Reference Component Blend Density Lot Number D929 94.00 lb of CEMENT Blend 197.27 Ib/ft3 Fresh water 14.373 gal/sk Base Fluid D046 0.200%BWOC Antifoam TU1A0243A0 D020 3.000%BWOC Extender 08251121 D079 2.000%BWOC Extender 44210303A D110 0.150 gal/sk Retarder TU1H0357A2 Rheology Temperature 80 de•F 80 de•F (rpm) Up Down Average Up Down Average (deg) (deg) (deg) (deg) (deg) (deg) 300 38.0 38.0 38.0 61.0 61.0 61.0 200 36.0 34.0 35.0 57.0 57.0 57.0 100 33.0 30.0 31.5 53.0 51.0 _ 52.0 60 33.0 28.0 30.5 48.0 49.0 48.5 C) s 30 34.0 27.0 30.5 45.0 47.0 46.0 = 6 29.0 25.0 27.0 32.0 30.0 31.0 3 3 27.0 24.0 25.5 29.0 24.0 26.5 a- m 10 sec Gel 19.0 deg-20.28 Ibf/100ft2 25.0 deg-26.68 Ibf/100ft2 10 min Gel 44.0 deg-46.96 Ibf/100ft2 34.0 deg -36.29 Ibf/100ft2 -s Rheo.computed I Viscosity:9.097 cP Yield Point:28.93 Ibf/100ft2 I Viscosity: 15.987 cP Yield Point:45.78lbf/100ft2 Thickenin' Time Consistency Time p POD: 02:50 hr:mn 30 Bc 00:28 hr:mn 70 Bc 05:28 hr:mn 100 Bc 06:00 hr:mn Free Fluid 0 mL/250mL in 2 hrs At 80 degF and 45 deg incl Sedimentation: None Water Analysis CINGSA Well Water Dec-20-2011 Chloride Calcium Magnesium 586 mg/L 22 mg/L 2 mg/L , Page 1 w` ti; N O H 2 2 2 '_ in CA °' !O tD mcr, O Q ^ M n 0) oIrnif N U N a O- CV cf. clW /^ J O O - M 6c; 0 a 0 .= ,n O_ O O r I V G U + + I U O O N y N N O C 1 •- N N N = N L E V U a z a o_ m _ d o �_ N y • LL y V Q F- H a. _- - -,----t---- - - - --..-I- O N t - I • t t •• • • O • _ _1 L _...__.__. _0 .• tll) t - M o 2 N a N O n M - C) N E L a O1 p i— ` M I M Q Q Q H H a a to L r i Z Z Z N CO CD C. 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'y 0) 'I I— I— Z H m Eo (UI/OesoJ01w)awll)ISUBJ,1 O o = = CCi >_ = a rn C cn U J U N G N O] m -) O: Schlumberger Laboratory Cement Test Report Nabors 105 CLU Storage 5 Surface Tail Field Blend Signatures Fluid No : PAK 11sfc4036 Client :CINGSA Location/Rig : Nabors 105 Date : Dec-23-2011 Well Name :CLU Storage 5 Field :Cannery Loop _ M. Schinnell Job Type 13 3/8"Surface Depth 2307.0 ft TVD 1957.0 ft BHST 85 degF BHCT 80 degF BHP 946 psi Starting Temp. 80 degF Time to Temp. 00:10 hr:mn Heating Rate 0.00 degF/min Starting Pressure 500 psi Time to Pressure 00:10 hr:mn Schedule () Composition Slurry Density 15.40 lb/gal Yield 1.22 ft3/sk ✓ Mix Fluid 5.509 gal/sk Solid Vol.Fraction 39.706% Porosity 60.294% Slurry type Conventional Code Concentration Sack Reference Component Blend Density Lot Number D929 94.00 lb of CEMENT Blend 197.27 lbfft3 Fresh water 5.439 gal/sk Base Fluid D046 0.200%BWOC Antifoam TU1A0243A0 D065 0.400%BWOC Dispersant Y12212SCL D167 0.200%BWOC Fluid loss GBG0018466 D145A 0.050 gal/sk Dispersant 320124 D110 0.020 gal/sk Retarder TU1H0357A2 Rheology Temperature 80 de.F 80 de.F (rpm) Up Down Average Up Down Average (deg) (deg) (deg) (deg) (deg) (deg) 300 67.0 67.0 67.0 87.0 87.0 87.0 200 49.0 48.0 48.5 75.0 76.0 75.5 100 22.0 26.0 24.0 58.0 61.0 59.5 n 60 16.0 20.0 18.0 41.0 43.0 42.0 E 30 10.0 14.0 12.0 32.0 35.0 33.5 3 6 6.3 10.0 8.2 24.9 30.2 27.5 Cr 3 4.6 10.0 7.3 22.5 28.9 25.7 0 10 sec Gel 18.2 deg-19.43 Ibf/100ft2 29.6 deg-31.59 Ibf/100ft2 10 min Gel 121.8 deg-130.00 Ibf/100ft2 61.7 deg -65.85 Ibf/100ft2 11 Rheo.computed I Viscosity:61.590 cP Yield Point:5.89 Ibf/100ft2 I Viscosity:61.437 cP Yield Point:31.20 Ibf/100ft2 Thickenin Time sv 30 Bc 03:28 hr:mn 70 Bc 03:58 hr:mn 100 Bc 04:05 hr:mn Free Fluid Trace mL/250mL in 2 hrs At 80 degF and 45 deg incl Sedimentation: None Fluid Loss API Fluid Loss 316 mL 50 mL in 3 min at 80 degF and 1000 psi Water Analysis CINGSA Well Water Dec-20-2011 Chloride Calcium Magnesium 586 mg/L 22 mg/L 2 mg/L Page 1 WC01 CIO 01 O CD J O O • . 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E n •, o m ti N 1- 1:Z Cl) J CU V) O N OO O] -, CD Schlumberger Laboratory Cement Test Report Nabors 105 CLU Storage 5 Intermediate Stage 1 Lead Field Blend Signatures Fluid No : PAK 11int4031 Client :CINGSA Location/Rig : Nabors 105 Date : Dec-30-2011 Well Name : CLU Storage 5 Field : Cannery Loop Daniel Himel Job Type 9 5/8"Intermediate Depth 8630.0 ft TVD 4938.0 ft BHST 104 degF BHCT 84 degF BHP 2388 psi Starting Temp. 80 degF Time to Temp. 01:45 hr:mn Heating Rate 0.04 degF/min Starting Pressure 500 psi Time to Pressure 01:45 hr:mn Schedule () Composition Slurry Density 12.00 lb/gal Yield 2.45 ft3/sk Mix Fluid 14.523 gal/sk Solid Vol.Fraction 20.7% Porosity 79.3% Slurry type Conventional Code Concentration Sack Reference Component Blend Density Lot Number D929 94 lb of CEMENT Blend 197.27 Ib/ft3 Fresh water 14.373 gal/sk Base Fluid D046 0.200%BWOC Antifoam TU1A0243A0 D020 3.000%BWOC Extender 08231121 D079 2.000%BWOC Extender 44210303A D110 0.150 gal/sk Retarder TU1H0357A2 Rheology Temperature 80 degF 84 degF (rpm) Up Down Average Up Down Average (deg) (deg) (deg) (deg) (deg) (deg) 300 43.0 43.0 43.0 87.0 87.0 87.0 200 40.0 42.0 41.0 86.0 84.0 85.0 to 100 36.0 41.0 38.5 83.0 78.0 80.5 o 60 36.0 40.0 38.0 83.0 76.0 79.5 C 30 34.0 40.0 37.0 82.0 74.0 78.0 3 6 32.6 33.6 33.1 43.0 42.2 42.6 7 3 23.0 24.4 23.7 20.4 28.4 24.4 cn 10 sec Gel 21 deg-21.88 Ibf/100ft2 23 deg-24.55 Ibf/100ft2 10 min Gel 34 deg-35.86 Ibf/100ft2 26 deg -27.32 Ibf/100ft2 - Rheo.computed Viscosity:6.318 cP Yield Point:36.74 lbf/100ft2 I Viscosity:8.658 cP Yield Point:78.65 Ibf/100ft2 <' m Thickenin' Time 0 Consistency Time POD: 03:00 hr:mn 30 Bc 03:00 hr:mn 70 Bc 04:31 hr:mn 100 Bc 04:54 hr:mn Free Fluid Trace mL/250mL in 2 hrs At 80 degF and 45 deg incl Sedimentation: None Water Analysis Chloride Calcium Magnesium 586.00 mg/I 22.00 mg/I 2.00 mg/I Page 1 II &., a...Is) c" w 2 2 2 aJ COrnm co 01 Q c.,— F.-U L r2 02 M V V XI CO Q, Q, C r- N N NO — U } t O O ` C \N G, = N N .-- COc _ Y M \ � m nE - a / csi N 'O 6, V N U N d d G Ci) Ty u_ E 0 d m co t o d m - Z c9 cn N d in o _ N L 1 173 N F- d - I.• 4 r 7 � - O I M ---- I's: .y O = O M t0 E lig _ N F- L d cn M O cun`, O M Q Q N 0. NM a tiL a Z Z M M ,j O MN NN V c N N I - N V7 d d c, O L L E. > lO O -c. N .- N O N i U y C 0- 0 y E o 0 U U CO c I1 I- 4 4- _Lc) - m o, O a a5 c m + -o y O O O O O O O J O O (O 0 V M N 3- 0.1 y CO } Q (Pd)y;6Ua1;g anissa�dwoO o LT C 0 0 D o N d C3 , I I I ", = O a; E m o m I , , , L I i i Q l i , l CO Q , , , i 0 , , . I O 0 'v m 'El Z J M c r r O Q U O D fn N 3 (d)amiwadwal = z E N E o 3 o m a + 11 o `m J d 0 0 O N c c � .y I 1l „ I „ 1 , I , , , , I „ „ Il , „ IL „ LI , L , LII , ll � lll , C0 p � Ovc`S c CU d c N co c0 CV O W CO 'Cr N 0 c a`, w on E E _ m o nn o 'E ..a- 0E- F- I—- z H Ec (U/oesonIw)awl;ISUBl o = m o O = >_ = a' C 0 U J U CO 0 (n m CO , CC Schlumberger Laboratory Cement Test Report Nabors 105 CLU Storage 5 Intermediate Stage 1 Tail Field Blend Signatures Fluid No :PAK 11int4032 Client :CINGSA Location/Rig :Nabors 105 Date : Dec-25-2011 Well Name :CLU Storage 5 Field :Cannery Loop M.Schinnell Job Type 9 5/8"Intermediate Depth 8630.0 ft TVD 4938.0 ft BHST 104 degF BHCT 84 degF BHP 2388 psi Starting Temp. 90 degF Time to Temp. 01:10 hr:mn Heating Rate -0.09 degF/min Starting Pressure 500 psi Time to Pressure 01:10 hr:mn Schedule () Composition Slurry Density 14.00 lb/gal Yield 1.29 ft3/sk Mix Fluid 4.099 gal/sk Solid Vol.Fraction 57.589% Porosity 42.411 % Slurry type FIexSTONE Code Concentration Sack Reference Component Blend Density Lot Number FIexSTONE 100.00 lb of BLEND Blend 136.78 lb/ft3 CLU Flex Fresh water 4.089 gal/sk Base Fluid D046 0.200%BWOB Antifoam TU1H0300A0 D202 0.500%BWOB Dispersant 116529 D400 0.500%BWOB Gas Migratio 091911-82 D177 0.010 gal/sk Retarder Kenai Sample Rheology(R1-B5) Tem•erature 80 de•F 84 de•F (rpm) Up Down Average Up Down Average (deg) (deg) (deg) (deg) (deg) (deg) 300 116.0 116.0 116.0 124.0 124.0 124.0 200 95.0 95.0 95.0 95.0 95.0 95.0 100 65.0 61.0 63.0 64.0 60.0 62.0 0 60 42.0 35.0 38.5 50.0 34.0 42.0 r) S 30 31.0 24.0 27.5 27.0 23.0 25.0 E 6 17.6 13.0 15.3 12.9 11.7 12.3 3 3 14.0 11.5 12.8 9.3 10.5 9.9 rs to 10 sec Gel 12.7 deg-15.08 Ibf/100ft2 11.5 deg-13.66 Ibf/100ft2 10 min Gel 26.0 deg-30.88 Ibf/100ft2 20.4 deg -24.23 Ibf/100ft2 St Rheo.computed I Viscosity:229.930 cP Yield Point:21.29 lbf/100ft2 I Viscosity:250.407 cP Yield Point: 18.04 Ibf/100ft2 Thickenin• Time Free Fluid sv Consistency Time 0.0 mU250mL in 2 hrs p 30 Bc 02:57 hr:mn At 80 degF and 45 deg incl 70 Bc 05:47 hr:mn Sedimentation: None 100 Bc 06:21 hr:mn Fluid Loss Remark:Thickening time includes batch time API Fluid Loss 8 mL Batch Mix Time: 01:00 hr:mn at 90 degF 4 mL in 30 min at 84 degF and 1000 psi UCA Com ressive Stren th Water Analysis CINGSA Well Water Dec-20-2011 07:31 hr:mn 50 psi Chloride Calcium Magnesium 12:00 hr:mn 489 psi 568 mg/L 22 mg/L 2 mg/L 12:08 hr:mn 500 psi 24:00 hr:mn 1024 psi Page 1 La-n N Y L L G d CD Si _ _ - - —0 N d d LL >T 2 0 of 1 i n- y .— C) N cc L O R] Ln I U gCC I� a CD CD - N CD - r-- r-. 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Cr LU N 0 in (N O N- LO N C 0 H ca C m m N N N o •• f E n G o 'y 23 h- F- H z w (i,)a�n;eiadwal O u m a c y v N a C N J U CO Cl CO m m -, 2 Schlumberger Laboratory Cement Test Report Nabors 105 CLU Storage 5 Intermediate Stage 2 Field Blend _ ____ Signatures Fluid No :PAK 11int4034 Client :CINGSA Location/Rig :Nabors 105 Date :Dec-31-2011 Well Name :CLU Storage 5 Field :Cannery Loop Daniel Himel Job Type 9 5/8"Intermediate Depth 3500.0 ft TVD 2550.0 ft BHST 73 degF BHCT 76 degF BHP 1233 psi Starting Temp. 80 degF Time to Temp. 00:30 hr:mn Heating Rate -0.13 degF/min Starting Pressure 500 psi Time to Pressure 00:30 hr:mn Schedule () Composition Slurry Density 12.00 lb/gal Yield 2.45 ft3/sk Mix Fluid 14.523 gal/sk Solid Vol.Fraction 20.7% Porosity 79.3% Slurry type Conventional Code Concentration Sack Reference Component Blend Density Lot Number D929 94 lb of CEMENT Blend 197.27 Ib/ft3 Fresh water 14.373 gal/sk Base Fluid D046 0.200%BWOC Antifoam TU1A0243A0 D020 3.000%BWOC Extender 12097CMI Gel D079 2.000%BWOC Extender 44210303A D110 0.150 gal/sk Retarder TU1H0357A2 Rheology Temperature 80 de•F 76 degF (rpm) Up Down Average Up Down Average (deg) (deg) (deg) (deg) (deg) (deg) 300 52.0 52.0 52.0 87.0 87.0 87.0 200 43.0 47.0 45.0 84.0 83.0 83.5 cn 100 42.0 43.0 42.5 83.0 79.0 81.0 o 60 42.0 43.0 42.5 81.0 76.0 78.5 30 41.0 43.0 42.0 77.0 74.0 75.5 3 6 25.5 34.8 30.1 51.1 50.8 51.0 rs- CD 3 18.4 23.1 20.8 19.3 28.1 23.7 , 10 sec Gel 22 deg-23.27 Ibf/100ft2 25 deg-26.58 Ibf/100ft2 CD 10 min Gel 50 deg-53.79 Ibf/100ft2 27 deg -28.39 Ibf/100ft2 Rheo.computed Viscosity: 11.905 cP Yield Point:39.44 Ibf/100ft2 I Viscosity:9.749 cP Yield Point:77.34 Ibf/100ft2 <' ai Thickenin• Time m Consistency Time 30 Bc 05:16 hr:mn 70 Bc 06:29 hr:mn 100 Bc 07:08 hr:mn Free Fluid Trace mL/250mL in 2 hrs At 80 degF and 45 deg incl Sedimentation: None Water Analysis Chloride Calcium Magnesium 586.00 mg/I 22.00 mg/I 2.00 mg/I Page 1 a"� c7 2 2 2 dina O Y a LLa COCm T - � --O acn y/ 2 CA CA , CO — ^ m N. t0 Lw, 01 CO CO V M y Lo W —I co O O e^{ N 1,4 1� ▪ NE .2 O O M N C O N N CU 0 CD I N O N C — � O CO O L -7 0 CO N I O d UT(' OI I1 0_ 4‘.13 • Ln~ - CO a a z (. 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H co Eo (upasa0iw)awlsue�l0 > > mH o >x x c m E N U J U N G fn CO co -7 CL Cementing Job sport CemCATv1.4 Schlumberger Well CLU 5 Client CINGSA Field Kenai SIR No. BC8Z-0078 Engineer Peter Cahill Job Type Cement Liner Country United States Job Date 01-13-2012 Time -- Treatment Press Rate DH Density WHP I Messages in/13/3412 le:5,18 i 21:42:15 Blow Air down hard line I 22:02:00 Cement plug found in 2X2 down fixed continue prime up Air blown back to pump 5 h20,40 mpg,67 cmt, 22:22:00 5 Reset Total,Vol=29.71 bbl i Front head rate test 3 bpm Reset Total,Vol=1.73 bbl front pass Rear head 3 bpm 22:42:00 Reset Total,Vol,..= 4.86 bbl Rear head pass Reset Total,Vol=3.34 bbl 23:02:00 Lining cementers down drill pipe - ? lined uo down drill oioe — Down on pump close for PT r • All clearon ground 23:22:00 , / 7 Low PT 1,000 psi All clear HPT 4,800 psi PT Pass • f Rig lining to pump MP2 23:42:00 SLB Start Batching CEMENT 6:33 Batched at 11:40 PM Reset Total,Vol=7.92 bbl Reset Total,Vol=0.23 bbl 17 bbls mix h20 used 00:02:00 r I 27 bbls mix h20 away right on wil /J E T Down on pump 69 bbls away Reset Total,Vol=72.21 bbl Reset Total,Vol=2.15 bbl behind5 bbls 00:22:00 Y Rig lined uto pits TT tripped Rig Displacing at 5 bpm to displace 245.14 bbls Rig to blow back hard line 00:42:00 [ •L 01:02:00 l 01:22:00 01:42:00 ! f 02:02:00 02:22:00 Y - rig displaced 3075 strokes • plug bumped at 1:05 AM plug bumped @ 2200 psi 02:39:32 Liner released by slb to 4200 psi job end hh:mm:ss 0.00 1000 2000 3000 4000 5000 0.00 2.0 4.0 6.0 8.0 10.0 5.0 8.0 11.0 14.0 27.0 20.0 0.00 1000 2000 3000 0000 5000 01/14/221:22:39 32 PSI B/M LB/G PSI 01/14/2012 02:42:08 Schlumberger Laboratory Cement Test Report Nabors 105 CLU Storage 5 7in Liner Field Blend Signatures Fluid No : PAK 12Inr1002 Client :CINGSA Location/Rig :Nabors 105 Date :Jan-06-2012 Well Name :CLU Storage 5 Field :Cannery Loop Daniel Himel Job Type 7"Production Depth 10796.0 ft TVD 5180.0 ft BHST 107 degF BHCT 98 degF BHP 2505 psi Starting Temp. 90 degF Time to Temp. 01:45 hr:mn Heating Rate 0.05 degF/min Starting Pressure 500 psi Time to Pressure 01:45 hr:mn Schedule () Composition Slurry Density 14.00 lb/gal Yield 1.29 ft3/sk Mix Fluid 4.101 gal/sk Solid Vol.Fraction 57.6% Porosity 42.4% Slurry type FIexSTONE Code Concentration Sack Reference Component Blend Density Lot Number CLU Flex 100 lb of BLEND Blend 136.78 lb/ft3 Fresh water 4.081 gal/sk Base Fluid D046 0.200%BWOB Antifoam TU1H0300A0 D202 0.500%BWOB Dispersant 116529 D400 0.500%BWOB Gas Migratio 091911-82 D177 0.020 gal/sk Retarder Kenai Sample Rheology Temperature 80 de•F 98 de•F (rpm) Up Down Average Up Down Average (deg) (deg) (deg) (deg) (deg) (deg) 300 121.0 121.0 121.0 123.0 123.0 123.0 200 91.0 95.0 93.0 89.0 90.0 89.5 cn 100 72.0 64.0 68.0 71.0 69.0 70.0 m 60 59.0 50.0 54.5 58.0 56.0 57.0 30 49.0 28.0 38.5 48.0 33.0 40.5 E. 3 6 20.7 16.2 18.5 21.2 18.4 19.8 0 3 17.5 12.8 15.1 17.0 14.9 15.9 10 sec Gel 13 deg-15.32 lbf/100ft2 14 deg-16.75 Ibf/100ft2 a) 10 min Gel 26 deg-31.00 Ibf/100ft2 23 deg -27.44 Ibf/100ft2 - Rheo.computed I Viscosity: 196.963 cP Yield Point:35.58 Ibf/100ft2 I Viscosity: 193.412 cP Yield Point:37.57 Ibf/100ft2 _ c' a) Thickenin. Time Free Fluid m Consistency Time 0.0 mU250mL in 2 hrs Remark:Thickening time includes batch time At 80 degF and 45 deg incl 30 Bc 03:14 hr:mn Sedimentation: None 70 Bc 06:33 hr:mn 100 Bc 07:06 hr:mn Fluid Loss Batch Mix Time: 01:00 at 90 degF API Fluid Loss 16 mL hr:mn 8 mL in 30 min at 98 degF and 1000 psi Water Analysis Chloride Calcium Magnesium 568.00 mg/I 22.00 mg/I 2.00 mg/I Page 1 L' �LnN N 22 2 G.) 0 CD CO m - - - - -_ —O N o Q Q O (T O md LO Cn ILr V tD M M Ln O O iqj c; A d' JO O i N 0 0 0, - 0 N N N 0 U t t NLN N4, d O\ n C - C f E. 1N O - = N O. 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Stephen Ratcliff Days Since Spud 0 Present R/D for Move to CLU 5 Rig Phone: (907)398-3156 Cell Phone: (281)914-6250 Operation: DRILLING DATA BIT it SIZE MFG TYPE SER k JETS IN OUT FEET BT GRADE TOTAL HOURS Pe. #DIV/01 CASING ! SIZE WEIGHT GRADE I THREAD DEPTH I CEMENT COMPANY DATE I - Conductor 20 1338 X-56 Welded 97' N/A July - Surface: Intermediate Liner Tubing PUMP#1 PUMP#2 -- IMUD PROPERTIES: 'MUD ADDITIVES: J Daily Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT - GEL(50 lb bag) 0 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS - S.ASH(50 lb bag) 0 LINER SIZE 6 LINER SIZE 6 R600/R300 - KLA-GUARD 0 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 - LOTORQ/776/STEEL LUBE 0 SPM - SPM - R6/R3 - ASPHASOL SUPREME 0 GPS - GPO - PV - CONDOR 404 0 GPM - GPM - YP - POTASSIUM CHLORIDE 0 PSI - PSI - GELS - FLOWZAN 0 BTMS UP MIN - BTMS UP MIN - API FLUID LOSS - PAC 0 TOT CIR MIN - TOT CIR MIN - CAKE APH/HT - CF-DESCO II 0 AVDP: AVDP: - SOLIDS - MYACIDE GA25 0 AVDC: AVDC: - OIUWATER - GEL-X 0 AVDC: AVDC: SAND - CITRIC ACID/SAFE CARB 0 DRILL STRING&HYDRAULICS PH - RESINEX 0 STRING WT. - WOB - Pf/Mf - CAUSTIC SODA 0 PICK UP - RPM - CHLORIDES - SODIUM BICARBONATE/mrtabisul6 0 SLACK OFF - TFA - CA - BARITE/NUT PLUG/G SEAL 0 MAX PULL - HOP - VOL.PIT-(BBL) - LIQUIDS(BBLS hauled) 0 ECD - PRESS DROP - HOLE-(BBL) - SOLIDS (BBLS hauled by AIMM) 0 DCOD - JET VEL - API SCREEN - Daily Mud Cum. 0 0 ACTIVITY SUMMARY I TIME SUMMARY Start I Finish I Hours I Description IDetail I Daily I Cumulative 18:00 6:00 12.00 Clear pipe shed and rig floor. Prep pipe shed and move RU/RD 12.00 12.00 pipe shed away from rig. Prep pits for move,disconnect Drilling 0.00 lines,L/D kelly hose,move SLB hoppers and equipment, Service/Repair Rig 0.00 move service company shacks,R/D wind walls. Remove Surveys 0.00 matting boards at pipe shed area. Remove cuttings tanks Tripping 0.00 and rig fuel tank. Remove sills from perimeter of rig. Change BHA 0.00 Off load kelly hose from rig floor. L/D Top Drive service Casing Crew 0.00 loop. R/D Stabbing board. Prep derrick to scope down. Cementing Crew 0.00 Install shipping pins on top drive skid and disconnect blocks Logging 0.00 from top drive. Remove choke house. Continue tong down NU/ND Test 0.00 pits and mud lines. DST/Core 0.00 Well Control 0.00 WOC 0.00 Safety Meetings 0.00 Drilling Cement 0.00 Circ/Other 0.00 12.00 See Remarks&Coments Below TOTAL 12.00 12.00 BOTTOM HOLE ASSEMBLY QTY I ITEM 1 CONN DOWN I CONN UP 1 VENDOR I O.D. I I.D. I GAUGE I NECK I LENGTH (TOTAL LENGTH BHA TOTAL LENGTH o.00 REMARKS&COMMENTS DIESEL No accidents or spills. Diesel on Location day before 2,868 PJSM's for all jobs. Diesel Used Last 24 0 Diesel Received 0 TOTAL DIESEL 2,868 PERSONNEL ON LOCATION _ COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 0 PRA DSM 2 24 48 0 PRA Safety/PM 1 12 12 0 Peak Rig Move 10 12 120 0 0 0 0 0 0 - TOTAL COUNT 37 TOTAL MAN HOURS 480 FROM TO LENGTH JOINT DESCRIPTION Gil 97' 97' Welded 20"133#X-56 Welded Conductor Pipe .3INGSA-DAILY DRILLING REPORT Date: 12/18/2011 Well Name CLU Storage 5 BHA ft: - ,.SM Days: Steve Ratcliff • Current Depth: 97 Location: Kenai,AK Target 2<386'MD Cell Phone: (907)230-9902 Depth: Rig Ftg/24hrs. 0 Field/Pool: Cannery Loop/Sterling C Contractor: Nabors Alaska-Rig 105 E NdDSM Stephen Ratcliff Days Since Spud 0 Present R/U rig at CLU Storage 5 Rig Phone: (907)398-3156 Cell Phone: (281)914-6250 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER it JETS IN OUT FEET BIT GRADE TOTAL HOURS FTr/R #DIV/0! CASING I SIZE [WEIGHT I GRADE THREAD I DEPTH I CEMENT COMPANY I DATE I. - Conductor: 20 1335 X-56 Welded 97' N/A July - Surface: Intermediate Liner Tubing PUMP#1 PUMP#2 _ (MUD PROPERTIES: tMUD ADDITIVES: I Daily (Cumulative PUMP MANE Gardner Denver PUMP MANE Gardner Denver WEIGHT - GEL(50 lb bag) 0 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS - S.ASH(50 lb bag) 0 LINER SIZE 6 LINER SIZE 6 R600/R300 - KLA-GUARD 0 STOKELNGTH 9 STOKELNGTH 9 R200/R100 - LOTORO/776/STEELLUBE 0 SPM - SPM - R6/R3 - ASPHASOL SUPREME 0 GPS - GPS - PV - CONQOR 404 0 GPM - GPM - YP - POTASSIUM CHLORIDE 0 PSI - PSI - GELS - FLOWZAN 0 BTMS UP MIN - BTMS UP MIN - API FLUID LOSS - PAC 0 TOT CIR MIN - TOT CIR MIN - CAKE APH/HT - CF-DESCO II 0 AVDP: AVDP: - SOLIDS - MYACIDE GA25 0 AVDC: AVDC: - OIL/WATER - GEL-X 0 AVDC: AVDC: SAND - CITRIC ACID/SAFE CARB 0 DRILL STRING&HYDRAULICS PH - RESINEX 0 STRING WT. - WOB - Pf/MI - CAUSTIC SODA 0 PICK UP - RPM - CHLORIDES - SODIUM BICARBONATE/mrtabisul6 0 SLACK OFF - TFA - CA - BARITE/NUT PLUG/G SEAL 0 MAX PULL - HSP - VOL.PIT-(BBL) - LIQUIDS(BBLS hauled) 0 ECD - PRESS DROP - HOLE-(BBL) - SOLIDS (BBLS hauled by AIMM) 0 DCOD - JET VEL - API SCREEN - Daily Mud Cum. 0 0 ACTIVITY SUMMARYTIME SUMMARY Start I Finish I Flours I Description Detail j j j j j,J Daily I Cumulative 6:00 6:00 24.00 Scope down and remove derrick sections. Rig down pits. RU/RD 24.00 36.00 Remove BOPE trolley and rails. Remove section of Drilling 0.00 derrick below crown. Remove back wind wall. Spool drilling Service/Repair Rig 0.00 line off drawworks drum on to drilling line spool. Cut off Surveys 0.00 50'drilling line. Set crown section on drilling line module Tripping 0.00 and pin. Remove A-Leg section. Remove off side driller Change BHA 0.00 and driller side dog houses. Pull meeting room and water Casing Crew 0.00 tank. Remove final pit modules. Move away Canrig shack. Cementing Crew 0.00 Remove boiler units from rig. Remove matting boards from Logging j 0.00 around sub-base. Rig up with crane to load sub base on NU/ND Test 0.00 truck to move.Move away pump rooms from rig. Move DST/Core 0.00 sub base away from CLU-1. Roll out herculite for CLU-5. Well Control 0.00 Set matting boards around CLU-5 well. WOC 0.00 Safety Meetings 0.00 Drilling Cement 0.00 Circ/Other 0.00 24.00 See Remarks&Coments Below TOTAL 24.00 36.00 BOTTOM HOLE ASSEMBLY QTY I ITEM I CONN DOWN I CONN UP I VENDOR I O.D. I I.D. I GAUGE I NECK I LENGTH (TOTAL LENGTH BHA TOTAL LENGTH 0.00 REMARKS&COMMENTS DIESEL No accidents or spills. Diesel on Location day before 2,868 PJSM's for all jobs. Diesel Used Last 24 372 Diesel Received 0 TOTAL DIESEL 2.496 PERSONNEL ON LOCATION _ COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 0 PRA DSM 2 24 48 0 PRA Safety/PM 1 1 1 0 Peak Rig Move 10 12 120 0 Weaver Bros Rig Move 2 8 16 0 0 0 0 - TOTAL COUNT 39 TOTAL MAN HOURS 485 FROM TO LENGTH JOINT DESCRIPTION G/L 97' 97' Welded 20"133#X-56 Welded Conductor Pipe ;INGSA-DAILY DRILLING REPORT Date: 12/19/2011 Well Name CLU Storage 5 BHA#: - ,.,SM Days: Steve Ratcliff Current Depth: 97 Location: Kenai,AK Target 2,386'MD Cell Phone: (907)230-9902 _ Depth: , Ftg/24hrs. 0 Field/Pool: Cannery Loop/Sterling C contractor Nabors Alaska-Rig 105E NiRig ghts: Stephen Ratcliff Days Since Spud 0 Present R/U rig at CLU Storage 5 Rig Phone: (907)398-3156 Cell Phone: (281)914-6250 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS FTM. #DIV/01 CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH I, CEMENT COMPANY I DATE - Conductor. 20 1334 X-56 Welded 97' N/A July - Surface. Intermediate Liner Tubing PUMP#1 (PUMP#2 MUD PROPERTIES: IMUD ADDITIVES: 1 Daily ICumulative _ PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT - GEL(50 lb bag) 0 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS - S.ASH(50 lb bag) 0 LINER SIZE 6 LINER SIZE 6 R600/R300 - KLA-GUARD 0 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 - LOTORQ/776/STEEL LUBE 0 SPM - SPM - R6/R3 - ASPHASOL SUPREME 0 GPS - GPS - PV - CONQOR 404 0 GPM - GPM - YP - POTASSIUM CHLORIDE O PSI - PSI - GELS - FLOWZAN 0 BTMS UP MIN - BTMS UP MIN - API FLUID LOSS - PAC 0 TOT CIR MIN - TOT CIR MIN - CAKE APH/HT - CF-DESCO II 0 AVDP: AVDP: - SOLIDS - MYACIDE GA25 0 AVDC: AVDC: - OIL/WATER - GEL-X 0 AVDC: AVDC: SAND - CITRIC ACID/SAFE CARB 0 DRILL STRING&HYDRAULICS PH - RESINEX 0 STRING WT. - WOB - PI/Mf - CAUSTIC SODA 0 PICK UP - RPM - CHLORIDES - SODIUM BICARBONATE/mrtabisulfr 0 SLACK OFF - TFA - CA - BARITE/NUT PLUG/G SEAL 0 MAX PULL - HSP - VOL.PIT-(BBL) - LIQUIDS(BBLS hauled) 0 ECD - PRESS DROP - HOLE-(BBL) - SOLIDS (BBLS hauled by AIMM) 0 DCOD - JET VEl - API SCREEN - Daily Mud Cum. 0 0 ACTIVITY SUMMARY ITIME SUMMARY Start rFinish I Hours I Description 'Detail I Daily 1—Cumulative 6:00 6:00 24.00 Set sub,crown,water tanks,manifold house,volume tank. RU/RD 24.00 60.00 Spot hopper room,pit module. Set driller side and off Drilling 0.00 driller side dog houses with crane. Rig up and spot meeting Service/Repair Rig 0.00 room and water tank double stack. Spot pump modules with Surveys 0.00 crane. Make up mud lines. Spot pit modiles,breeze way, Tripping 0.00 and motor complex mats. Rig up and spot motor complexes. Change BHA 0.00 Pull wire and install mud lines. Pull wire from motors and Casing Crew 0.00 install mud lines. Rig up and spot VFD Module. Work on Cementing Crew 0.00 / interconnects through out inside of rig. Rig up and spot Logging 0.00 first section of mast and A-Legs with crane. Spot Canrig NU/ND Test 0.00 mud logger shack. Spot Baker LWD shack and MI Swaco DST/Core 0.00 Mud Engineering shack. Power up rig. Work on berming Well Control 0.00 around rig perimeter. WOC 0.00 Safety Meetings 0.00 Drilling Cement 0.00 Circ/Other 0.00 24.00 See Remarks&Coments Below TOTAL 24.00 60.00 BOTTOM HOLE ASSEMBLY QTY I ITEM I CONN DOWN I CONN UP I VENDOR I O.D. I I.D. I GAUGE I NECK I LENGTH 'TOTAL LENGTH • • • BHA TOTAL LENGTH 0.00 REMARKS&COMMENTS DIESEL No accidents or spills. Diesel on Location day before 2,496 PJSM's for all jobs. Diesel Used Last 24 375 TENTATIVE SPUD DATE OF DECEMBER 22,2012. Diesel Received 0 TOTAL DIESEL 2,121 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 0 PRA DSM 2 24 48 0 PRA Safety/PM 2 1 2 0 Peak Rig Move 10 12 120 0 0 0 0 0 0 - TOTAL COUNT 38 TOTAL MAN HOURS 470 FROM TO LENGTH JOINT DESCRIPTION G/L 97' 97' Welded 20"133#X-56 Welded Conductor Pipe CINGSA-DAILY DRILLING REPORT Date: 12/20/2011 Well Name CLU Storage 5 BHA 0: - DSM Days: Steve Ratcliff Current Depth: 97 Location: Kenai,AK Target 2,386'MD Cell Phone: (907)230-9902 Depth: Ftg/24hrs. 0 Field/Pool: Cannery Loop/Sterling C ConRi tor: Nabors Alaska-Rig 105 E Nights_ Stephen Ratcliff Days Since Spud 0 Present R/U rig at CLU Storage 5 Rig Phone (907)398-3156 Cell Phone: (281)914-6250 Operation: DRILLING DATA BIT It SIZE r' MFG TYPE SER# JETS IN OUT FEET SIT GRADE TOTAL HOURS FT/HR #DIV/0l CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor: 20 133# X-56 Welded 97' N/A Juiy - Surface: Intermediate Liner Tubing PUMP#1 IPUMP#2 IMUD PROPERTIES: (MUD ADDITIVES: I Daily 'Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT - GEL(50 lb bag) 0 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS - S.ASH(50 lb bag) 0 LINER SIZE 6 LINER SIZE 6 R600/R300 - KLA-GUARD 0 STOKELNGTH 9 STOKELNGTH 9 R200/R100 - LOTORQ/776/STEELLUBE 0 SPM - SPM - R6/R3 - ASPHASOL SUPREME 0 GPS - GPS - PV - CONQOR 404 0 GPM - GPM - YP - POTASSIUM CHLORIDE 0 PSI - PSI - GELS - FLOWZAN 0 BTMS UP MIN - BTMS UP MIN - API FLUID LOSS - PAC 0 TOT CIR MIN - TOT CIR MIN - CAKE APH/HT - CF-DESCO II 0 AVDP: AVDP: - SOLIDS - MYACIDE GA25 0 AVDC - AVDC. - OIL/WATER - GEL-X 0 AVDC: AVDC. SAND - CITRIC ACID/SAFE CARB 0 DRILL STRING&HYDRAULICS PH - RESINEX 0 STRING WT. - WOB - Pf/Mf - CAUSTIC SODA 0 PICK UP - RPM - CHLORIDES - SODIUM BICARBONATE/mrtabistlllii 0 SLACK OFF - TFA - CA - BARITE/NUT PLUG/G SEAL 0 MAX PULL - HSP - VOL.PIT-(BBL) - LIQUIDS(BBLS hauled) 0 ECD - PRESS DROP - HOLE-(BBL) - SOLIDS (BBLS hauled by AIMM) 0 DCOD - JET VEL - API SCREEN - Daily Mud Cum. 0 0 ACTIVITY SUMMARY _ _ TIME SUMMARY Start I Finish I Hours I Description Detail I Daily I Cumulative 6:00 6:00 24.00 Set A-Legs,crown,and intermediate derrick sections. RU/RD 24.00 84.00 Continue to rig up pits.steam,air,and water. Rig up and Drilling 0.00 scope first portion of derrick,50k. Scope second section, Service/Repair Rig 0.00 75k,third section,120k. Install top drive and stabbing Surveys 0.00 board. Rig up kelly hose on rig floor. Install pipe shed Tripping 0.00 side wind wall. Set rear side wind wall. Set choke house. Change BHA 0.00 Install derrick service loop and erect rear wind wall. Erred Casing Crew 0.00 driller side dog house wind walls. Hang kelly hose and work Cementing Crew 0.00 on interconnects through out rig. Set matting boards for Logging 0.00 pipe shed. Rig up and move first section of pipe shed in NU/ND Test 0.00 place. Rig up and move remaining sections of pipe shed DST/Core 0.00 in place. Work on berming around ng and patch trip Well Control 0.00 hazards with plywood. Fire up boilers and get heat on ng. WOC 0.00 Safety Meetings 0.00 Drilling Cement 0.00 Circ/Other 0.00 24.00 See Remarks&Coments Below TOTAL 24.00 84.00 BOTTOM HOLE ASSEMBLY QTY I ITEM I CONN DOWN I CONN UP I VENDOR_j 0.D. I I.D. _ GAUGE I NECK LENGTH (TOTAL LENGTH BHA TOTAL LENGTH 0.00 REMARKS&COMMENTS DIESEL Had an incident before midnight where Nabors employee chipped a tooth and was brought to the Diesel on Location day before 2,420 hospital to be checked out. Awaiting report from Nabors Drilling. Diesel Used Last 24 492 Service companies scheduled to be on location Wednesday,12/21/11. Diesel Received 0 TENTATIVE SPUD DATE OF DECEMBER 22,2012. TOTAL DIESEL 1,928 n. PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 0 PRA DSM 2 24 48 0 PRA Safety/PM 2 1 2 0 Peak Rig Move 10 12 120 0 0 0 0 0 0 - TOTAL COUNT 38 TOTAL MAN HOURS 470 FROM TO LENGTH JOINT DESCRIPTION G/L 97' 97' Welded 20"133#X-56 Welded Conductor Pipe 3INGSA-DAILY DRILLING REPORT Date: 12/21/2011 Well Name CLU Storage 5 BHA it: - DSM Days: Steve Ratcliff Current Depth: 97 Location: Kenai,AK Target 2,386'MD Cell Phone: (907)230-9902 Depth: Ftg/24hrs. 0 Field/Pool: Cannery Loop/Sterling C Rig Contractor Nabors Alaska-Rig 105 E Nights: Stephen Ratcliff Days Since Spud 0 Present R/U rig at CLU Storage 5 Rig Phone: (907)398-3156 Cell Phone: (281)914-6250 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS FEHR #DIV/0! CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor: 20 133# X-56 Welded 97' N/A July - Surface Intermediate Liner Tubing PUMP#1 (PUMP#2 IMUD PROPERTIES: 1MUD ADDITIVES: 1 Daily (Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT - GEL(50 lb bag) 0 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS - S.ASH(50 lb bag) 0 LINER SIZE 6 LINER SIZE 6 R600/R300 - KLA-GUARD 0 STOKE LNGTH 9 STOKE LNGTH_ 9 R200/R100 - LOTORQ/776/STEEL LUBE 0 SPM - SPM - R6/R3 - ASPHASOL SUPREME 0 GPS - GPS - PV - CONOOR 404 0 GPM - GPM - `IP - POTASSIUM CHLORIDE 0 PSI - PSI - GELS - FLOWZAN 0 BTMS UP MIN - BTMS UP MIN - API FLUID LOSS - PAC 0 TOT CIR MIN - TOT CIR MIN - CAKE APH/HT - CF-DESCO II _ 0 AVDP: AVDP: - SOLIDS - MYACIDE GA25 0 AVDC: AVDC: - OIL/WATER - GEL-X _ 0 AVDC: AVDC. SAND - CITRIC ACID/SAFE GARB 0 DRILL STRING&HYDRAULICS PH - RESINEX _ 0 STRING err. - WOB - Pf/Mf - CAUSTIC SODA 0 PICK UP - RPM - CHLORIDES - SODIUM BICARBONATE/mrtabisulfi 0 SLACK OFF - TFA - CA - BARITE/NUT PLUG/G SEAL 0 MAX PULL - HSP - VOL.PIT-(BBL) - LIQUIDS(BBLS hauled) 0 ECD - PRESS DROP - HOLE-(BBL) - SOLIDS (BBLS hauled by AIMM) 0 DCOD - JET VEL - API SCREEN - Daily Mud Cum. 0 0 ACTIVITY SUMMARY 1 TIME SUMMARY r Start I Finish I Hours I Description (Detail I Daily I Cumulative 6:00 3:00 21.00 Rig up and terminate service loop to top drive. Trouble RU/RD 24.00 108.00 shoot comm fault. Set and berm tioga heater. Rig up Drilling 0.00 pipe shed. Replace ram on link tilt. Inspect top drive and Service/Repair Rig 0.00 check for leaks. Rig up cont.descent device from derrick. Surveys 0.00 Rig up and trouble shoot top drive. Engauge all hydraulic Tripping 0.00 functions and check for leaks. Inspect top drive prior to Change BHA 0.00 hoisting into derrick. Install stand pipe jumper hose Casing Crew 0.00 assembly. Run cement lines to floor and install mud Cementing Crew 0.00 manifold on rig floor. Install flex flanges on charge pump Logging 0.00 suction. Run lines from super choke. Install pop off line on NU/ND Test 0.00 #2. Rig up kelly hose to top drive. Install cement hose. DST/Core 0.00 ✓ Install kill line and and blank. Install cameras on rig floor. Well Control 0.00 Rig up bails on top drive and install elevators. Hang rig WOC 0.00 tongs. Inspect top drive saver sub. Load pipe shed w/DP. Safety Meetings 0.00 3:00 6:00 3.00 Accept rig from moving/MOB to operating @ 03:00 Drilling Cement 0.00 Nipple up diverter and get ready for AOGCC. , ' Circ/Other 0.00 24.00 See Remarks&Coments Below TOTAL 24.00 108.00 BOTTOM HOLE ASSEMBLY QTY I ITEM I CONN DOWN I CONN UP I VENDOR I O.D. I.D. I GAUGE I NECK I LENGTH (TOTAL LENGTH • BHA TOTAL LENGTH 0.00 REMARKS 8 COMMENTS DIESEL No accidents or spills. Diesel on Location day before 1,928 Held PJSM's for all jobs. Diesel Used Last 24 1,448 Called AOGCC at 13:15 to give 24 hour notice for Diverter test. Diesel Received 9,411 TENTATIVE SPUD DATE OF DECEMBER 22,2012. TOTAL DIESEL 9,891 - • .. PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 0 PRA DSM 2 24 48 0 PRA Safety/PM 2 1 2 0 - Peak Rig Move 10 12 120 _ 0 - 0 _ 0 _ 0 0 0 - TOTAL COUNT 38 TOTAL MAN HOURS 470 FROM TO LENGTH JOINT DESCRIPTION G/L 97' 97' Welded 20"133#X-56 Welded Conductor Pipe .;INGSA-DAILY DRILLING REPORT Date: 12/22/2011 Well Name CLU Storage 5 BHA#: - DSM Days: Steve Ratcliff Current Depth: 97 Location: Kenai,AK Target 2,386'MD Cell Phone: (907)230-9902 Depth: Ftg/24hrs. 0 Field/Pool: Cannery Loop/Sterling C COnRig tor Nabors Alaska-Rig 105 E N9hM: Stephen Ratcliff Days Since Spud 0 Present P/U HWDP&Prep for Spud Rig Phone: (907)398-3156 Cell Phone: (281)914-6250 Operation: DRILLING DATA • BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS FLun #DIV/01 CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor: 20 1334 X-56 Welded 97' N/A July - Surface: Intermediate Liner Tubing PUMP#1 IPUMP#2 IMUD PROPERTIES: IMUD ADDITIVES: I Daily (Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT - GEL(50 lb bag) 0 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS - S.ASH(50 lb bag) 0 LINER SIZE 6 LINER SIZE 6 R600/R300 - KLA-GUARD 0 STOKELNGTH 9 STOKE LNGTH 9 R200/R100 - LOTORO/776/STEELLUBE 0 SPM - SPM - R6/R3 - ASPHASOL SUPREME 0 GPS - GPS - PV - CONQOR 404 0 GPM - GPM - VP - POTASSIUM CHLORIDE 0 PSI - PSI - GELS - FLOWZAN 0 BTMS UP MIN - BTMS UP MIN - API FLUID LOSS - PAC 0 TOT CIR MIN - TOT CIR MIN - CAKE APH/HT - CF-DESCO II 0 AVDP: AVDP: - SOLIDS - MYACIDE GA25 0 AVDC: AVDC: - OIL/WATER - GEL-X 0 AVDC: AVDC: SAND - CITRIC ACID/SAFE CARB 0 DRILL STRING&HYDRAULICS PH - RESINEX 0 STRING WT. - WOB - Pt/Mf - CAUSTIC SODA 0 PICK UP _ - RPM - CHLORIDES - SODIUM BICARBONATE/mrtabisulh 0 SLACK OFF - TFA - CA - BARITE I NUT PLUG/G SEAL 0 MAX PULL - HSP - VOL.PIT-(BBL) - LIQUIDS(BBLS hauled) 0 ECD - PRESS DROP - HOLE-(BBL) - SOLIDS (BBLS hauled by AIMM) 0 DCOD - JET VEL - API SCREEN - Daily Mud Cum. 0 0 ACTIVITY SUMMARY I TIME SUMMARY Start I Finish I Hours I Description iDetail 1 Daily I Cumulative 6:00 14:00 8.00 Nipple up starting head,diverter tee,annular,flow visor, RU/RD 1.00 109.00 knife valve,and diverter line. Install flow risor and plumb Drilling 0.00 knife valve. Install final section of diverter and clean cellar Service/Repair Rig 0.00 area. Surveys 0.00 14:00 17:00 3.00 Pick up 63 joints of drill pipe and stand back in derrick, Tripping 14.00 14.00 strap in pipe shed,rabbit on skate to 2.867". Change BHA 0.00 17:00 18:00 1.00 Test diverter and perform diverter test. Test accumulator. ,-Casing Crew 0.00 AOGCC Waived Witness at 08:50 AM by Jim Regg. ,/ Cementing Crew 0.00 18:00 0:00 6.00 Pick up drill pipe joints 64-201. Talley and rabbit each joint. Logging 0.00 0:00 1:00 1.00 Rig up mouse hole on rig floor. NU/ND Test 9.00 9.00 1:00 6:00 5.00 Pick up drill pipe,rabbit and tally each joint. P/U HWDP DST/Core 0.00 Well Control 0.00 WOC 0.00 Safety Meetings 0.00 Drilling Cement 0.00 Circ/Other 0.00 24.00 See Remarks&Coments Below TOTAL 24.00 132.00 BOTTOM HOLE ASSEMBLY • P QTY I _ ITEM CONN DOWN I CONN UP I VENDOR I O.D. I I.D. I GAUGE I NECK I LENGTH ITOTAL LENGTH BHA TOTAL LENGTH 0.00 REMARKS&COMMENTS DIESEL No accidents or spills. Diesel on Location day before 9,891 Held PJSM's for all jobs. Diesel Used Last 24 1,427 Diesel Received 0 AOGCC Waived Witness by Jim Regg at 08:50 am. TOTAL DIESEL 8,464 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 0 PRA DSM 2 24 48 0 PRA Safety/PM 2 1 2 0 Canrig Mud Loggers 2 12 24 0 MI Swaco Mud Engineer 1 2 2 0 Baker Directional 2 1 2 0 Baker LWD 2 12 24 - TOTAL COUNT 33 TOTAL MAN HOURS 402 FROM TO LENGTH JOINT DESCRIPTION G/L 97' 97' Welded 20"1338 X-56 Welded Conductor Pipe CINGSA-DAILY DRILLING REPORT Date: 12/23/2011 Well Name CLU Storage 5 BHA#: 1 DSM Days: Steve Ratcliff Current Depth: 118' Location: Kenai,AK Target 2,386'MD Cell Phone: (907)230-9902 Depth: - Ftg/24hrs. 1438' Field/Pool: Cannery Loop/Sterling C Rig Nabors Alaska-Rig 105 E DSM Mike Grubb Contractor: Nights: , Days Since Spud 1 Present Drilling Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS FT/HR1 16 HCC MXL-1 5194403 3-18 1-16 118 1438' 9.3 155.00 CASING SIZE WEIGHT GRADE t THREAD DEPTH CEMENT COMPANY DATE - Conduclor 20 1336 X-56 Welded 97' N/A July - Surface Intermediate Liner Tubing PUMP#1 IIPUMP#2 IMUD PROPERTIES: MUD ADDITIVES: Daily (Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT 8.8 GEL(50 lb bag) 210 210 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 58 S.ASH(501h bag) 0 LINER SIZE 6 LINER SIZE 6 R600/R300 46/32 KLA-GUARD 0 STOKELNGTH 9 STOKELNGTH 9 R200/R100 27/19 LOTORQ/776/STEELLUBE 0 SPM 84 SPM 84 R6/R3 9/8 ASPHASOL SUPREME 0 GPS 3.17 GPS 3.17 PV 14 CONDOR 404 0 GPM 266 GPM 266 VP 18 POTASSIUM CHLORIDE 0 PSI 1450 PSI 1450 GELS 10/15/19 FLOWZAN 0 BTMS UP MIN 19.5 BTMS UP MIN 19.5 API FLUID LOSS 12.2 PAC 0 TOT CIR MIN 65 TOT CIR MIN 65 CAKE APH/HT 2/ CF-DESCO II 0 AVDP: 324.00 AVDP: 324 SOLIDS 4 MYACIDE GA25 0 AVDC: 341.00 AVDC: 341 OIL/WATER /94 GEL-X 1 1 AVDC: - AVDC: SAND 0.25 CITRIC ACID/SAFE GARB 0 DRILL STRING&HYDRAULICS PH 8.8 RESINEX 0 STRING WT. - WOB 15 Pf/Mf TR/.40 CAUSTIC SODA 0 PICK UP - RPM 60 CHLORIDES 2000 SODIUM BICARBONATE/mrtabisulR 0 SLACK OFF - TFA 0.942 CA 40 BARITE/NUT PLUG/G SEAL 0 MAX PULL - HSP 124/0.6 VOL.PIT-(BBL) 565 LIQUIDS(BELS hauled) 0 ECD 9.41 PRESS DROP 397/28.4 HOLE-(BBL) 257 SOLIDS (BBLS hauled by AIMM) 187 187 DCOD - JET VEL , 182 API SCREEN 4-165 4-165 Daily Mud Cum. 398 398 ACTIVITY SUMMARY I TIME SUMMARY Start I Finish I Hours I Description Detail -I Daily I Cumulative 6:00 7:00 1.00 Service and lube ng. RU/RD 109.00 7:00 9:00 2.00 Circulate,check for leaks,test surface lines 500/2500 psi. Drilling 18.00 18.00 9:00 12:00 3.00 P/U BHA#1 RIH T/118' Service/Repair Rig 1.00 1.00 12:00 Drill 16"surface hole F/118.-510'up wt45 Dn 45 rot 45 Surveys 0.00 Spudded Well at 1200 hrs December 22,2011 Tripping 3.00 17.00 18:00 6.00 375 gpm,WOB 10/18k,750psi,tq 2-3k,ART-1.3,AST-1.3 Change BHA 0.00 18:00 Drill 16"surface hole F/510'-1027'up wt65 Dn 60 rot 60 Casing Crew 0.00 Pumped 40 bbl high vis sweep @ 980',100%excess cutting Cementing Crew 0.00 0:00 6.00 475/525gpm,WOB 10/18k,1400 psi tq 2-4k,ART-1.1,AST2.3 Logging 0.00 0:00 Drill 16"surface hole F/1027'-1556'up75 do 65,rot 68 NU/ND Test 9.00 6:00 6.00 525/600gpm,16SOpsi 60rpm,tq 3-4,ART-1.7,AST1.6 DST/Core 0.00 Well Control 0.00 WOC 0.00 Safety Meetings 0.00 Drilling Cement 0.00 Circ/Other 2.00 2.00 24.00 See Remarks&Coments Below TOTAL 24.00 156.00 BOTTOM HOLE ASSEMBLY QTY l ITEM I CONN DOWN I CONN UP I VENDOR I O.D. I I.D. I GAUGE I NECK I LENGTH (TOTAL LENGTH MX1 Bit RR 6-5/8 reg Baker 16 1.30 1.30 Steerable Mud Motor 1.3 deg 6-5/8 reg 6-518 H-90 Baker 8 15-7/8 1.80 28.62 29.92 NM pony collar 6-5/8 H-90 6-5/8 H-90 Baker 8 1/16 213/16 1.78 9.57 39.49 NM Stabilizer 6-5/8 H-90 6-5/8 H-90 Baker 8 1/8 2 131 16 15 7/8 1.95 5.27 44.76 MWD/Gamma 6-5/8 H-90 6-5/8 H-90 Baker 8 2 13/16 33.45 78.21 CSNMDP 6-5/8 H-90 6-5/8 H-90 Baker 6 3/4 2 7/8 7 3/4 1.86 29.97 108.18 CSNMDP 6-5/8 H-90 6-5/8 H-90 Baker 6 3/4 2 7/8 7 1/4 3.00 29.24 137.42 CSNMDP 6-5/8 H-90 6-5/8 H-90 Baker 6 3/4 2 7/8 7 1/2 3.22 29.59 167.01 X-OVER 6-5/8 H-90 4 1/21F Baker 7 3/4 3 1/2 1.58 168.59 4-HWDP 4-1/2 IF 4-1/2 IF Nabors 5 3 6 1/2 119.45 288.04 JARS 4-1/2 IF 4-1/2 IF W/Ford 6 3/16 2 1/4 1.70 32.09 320.13 19-HWDP 4-1/2 IF 4-1/2 IF Nabors 5 3 6 1/2 566.40 886.53 BHA TOTAL LENGTH 886.53 REMARKS&COMMENTS DIESEL No accidents or spills. Diesel on Location day before 8,464 Held PJSM's for all jobs. Diesel Used Last 24 1,506 Note RKB to GL 20.8' Diesel Received 0 TOTAL DIESEL 6,958 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS- TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck 2 24 48 PRA DSM 2 12 24 Aimm Roust, 2 18 36 PRA Safety/PM 2 1 2 0 Canrig Mud Loggers 2 12 24 0 MI Swaco Mud Engineer 2 12 24 0 Baker Directional 2 12 24 0 Baker LWD 2 12 24 - TOTAL COUNT 40 TOTAL MAN HOURS 506 FROM TO LENGTH JOINT DESCRIPTION Gil_ 97' 97' Welded 20"1336 X-56 Welded Conductor Pipe :,INGSA-DAILY DRILLING REPORT Date: 12/24/2011 Well Name CLU Storage 5 BHA#: 1 JSM Days: Steve Ratcliff Current Depth: 118' Location: Kenai,AK Target 2400'MD Cell Phone: (907)230-9902 Depth: Ftg/24hrs. 844' Field/Pool: Cannery Loop/Sterling C Rigfor Nabors Alaska-Rig 105 E Nights: Mike Grubb ContracDays Since Spud 2 Present Drilling Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER It JETS IN OUT FEET BIT GRADE TOTAL HOURS 10100 1 16 HCC MXL-1 5194403 3-18 1-16 118 2282 14.9 153.00 CASING I SIZE I WEIGHT I GRADE 1 THREAD I DEPTH I CEMENT COMPANY DATE 1 Conductor. 20 133# X-56 Welded 97' N/A July - Surface: Intermediate Liner Tubing PUMP#1 LPUMP#2 IMUD PROPERTIES: -_- MUD ADDITIVES: I Daily !Cumulative PUMP MANE Gardner Denver PUMP MANF Gardner Denver WEIGHT 9.1 GEL(50 lb bag) 420 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 56 S.ASH(50 lb bag) 1 1 LINER SIZE 6 LINER SIZE 6 R600/R300 58/42 KLA-GUARD 0 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 33/26 LOTORQ/776/STEEL LUBE 0 SPM 95 SPM 95 R6/R3 12/11 ASPHASOL SUPREME 0 GPS 3.17 GPO 3.17 PV 16 CONQOR 404 0 GPM 300 GPM 300 YP 26 POTASSIUM CHLORIDE 0 PSI 1750 PSI 1750 GELS 22/29/31 FLOWZAN 0 BTMS UP MIN 41 BTMS UP MIN 41 API FLUID LOSS 8.6 PAC 8 8 TOT CIR MIN 72 TOT CIR MIN 72 CAKE APH/HT 2/ CF-DESCO II 0 AVDP: AVDP: 467 SOLIDS 5 MYACIDE GA25 0 AVDC. AVDC: 505 OIL/WATER /95 GEL-X 1 AVDC: AVDC: SAND .7 CITRIC ACID/SAFE CARE 0 DRILL STRING&HYDRAULICS PH 8.6 RESINEX 0 STRING WT. 75 WOB 15 Pf/Mf .02/.3 CAUSTIC SODA 2 2 PICK UP 89 RPM 60 CHLORIDES 1100 SODIUM BICARBONATE/mrtabisulft 0 SLACK OFF 65 TFA 0.942 CA 40 BARITE/NUT PLUG/G SEAL 0 MAX PULL _ 95 HSP 133/0.7 VOL.PIT-(BBL) 435 LIQUIDS(BELS hauled) 0 ECD 9.41 PRESS DROP 366/18.8 HOLE-(BBL) 629 SOLIDS (BBLS hauled by AIMM) 503 690 DCOD - JET VEL 212 API SCREEN 4-165 4-165 Daily Mud Cum. 934 1332 ACTIVITY SUMMARY I TIME SUMMARY Start I Finish I Hours I Description !Detail J Daily Cumulative 6:00 Drill 16"surface hole F/1556-1844',up 80,dn 66,rot 70 RU/RD 109.00 10:00 4.00 rpm 60,600gpm@1800psi,TQ-2-5,AST-1.1,ART-.9 Drilling 10.50 28.50 10:00 10:30 0.50 Service Top Drive and inspect Service/Repair Rig 5.00 6.00 10:30 15:00 4.50 Repair top drive(broken corn cable) Surveys 0.00 15:00 Drill 16"surface hole F/1844'-2400',up 89,dn 66,rot 75 •, Tripping 5.50 22.50 21:30 6.50 rpm 60,600gpm@1800psi,TQ-2-5,AST-1.4,ART-1.2 Change BHA 0.00 21:30 23:00 1.50 Pump 30bbl high vis sweep,condition mud for wiper trip Casing Crew 0.00 23:00 Monitor well,POOH SLM(wiper trip)on elevators F/2400'- Cementing Crew 0.00 1:00 2.00 790'smooth trip no overpulls,No corrections SLM Logging 0.00 1:00 2:30 1.50 RIH(wiper trip)F/790'-2322'wash to 2400',2'fill NU/ND Test 9.00 2:30 4:00 1.50 Pump 30bbl high vis sweep,condition mud for casing run, DST/Core 0.00 4:00 6:00 2.00 Monitor well,pump dry job,POH F/2400'-320',monitor well Well Control 0.00 for swabbing,blow down top drive WOC 0.00 Safety Meetings 0.00 Drilling Cement 0.00 Circ/Other 3.00 5.00 24.00 See Remarks&Coments Below TOTAL 24.00 180.00 BOTTOM HOLE ASSEMBLY QTY I ITEM I CONN DOWN I CONN UP I VENDOR I O.D. I I.D. 1 GAUGE I NECK I LENGTH (TOTAL LENGTH MX1 Bit RR 6-5/8 reg Baker 16 1.30 1.30 Steerable Mud Motor 1 3 deg 6-5/8 reg 6-5/8 H-90 Baker 8 15-7/8 1.80 28.62 29.92 NM pony collar 6-5/8 H-90 6-5/8 H-90 Baker 8 1/16 2 13/16 1.78 9.57 39.49 NM Stabilizer 6-5/8 H-90 6-5/8 H-90 Baker 8 1/8 2 13/16 15 7/8 1.95 5.27 44.76 MWD/Gamma 6-5/8 H-90 6-5/8 H-90 Baker 8 2 13/16 33.45 78.21 CSNMDP 6-5/8 H-90 6-5/8 H-90 Baker 6 3/4 2 7/8 7 3/4 1.86 29.97 108.18 CSNMDP 6-5/8 H-90 6-5/8 H-90 Baker 6 3/4 2 7/8 7 1/4 3.00 29.24 137 42 CSNMDP 6-5/8 H-90 6-5/8 H-90 Baker 6 3/4 2 7/8 7 1/2 3.22 29.59 167.01 X-OVER 6-5/8 H-90 41/2 IF Baker 7 3/4 3 1/2 1.58 168.59 4-HWDP 4-1/2 IF 4-1/2 IF Nabors 5 3 6 1/2 119.45 288.04 JARS 4-1/2 IF 4-1/2 IF W/Ford 6 3/16 2 1/4 1.70 32.09 320.13 19-HWDP 4-1/2 IF 4-1/2IF Nabors 5 3 6 1/2 566.40 886.53 BHA TOTAL LENGTH 886.53 REMARKS 8 COMMENTS DIESEL No accidents or spills. Diesel on Location day before 6,958 Held PJSM's for all jobs. Diesel Used Last 24 2,094 Note RKB to GL 20.5' Diesel Received 9,397 Emerald p/u 200 gal mud sample TOTAL DIESEL 14,261 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 23 12.5 287.5 Aimm Vac truck 2 24 48 PRA DSM 2 12 24 Aimm Roust. 2 18 36 PRA Safety/PM 2 5 10 0 Canrig Mud Loggers 2 12 24 0 MI Swaco Mud Engineer 2 12 24 0 Baker Directional 2 12 24 0 Baker LWD 2 12 24 - TOTAL COUNT 40 TOTAL MAN HOURS 501.5 • FROM TO LENGTH JOINT DESCRIPTION G/L 97' 97' Welded 20"133#X-56 Welded Conductor Pipe CINGSA-DAILY DRILLING REPORT Date: 12/25/2011 Well Name CLU Storage 5 BHA 0: USM Days: Steve Ratcliff Current Depth: 2400' Location: Kenai,AK Target Depth: 2400'MD Cell Phone: (907)230-9902 Ftg/24hrs. 0 Field/Pool: Cannery Loop/Sterling C CoNabors Alaska-Rig 105E Nights Mike Grubb Days Since Spud 3 Present Drilling Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER 0 JETS IN OUT FEET BIT GRADE TOTAL HOURS FT/HR 1 16 HCC MXL-1 5194403 3-18 1-16 118 2400 2282 153.00 CASING I SIZE I_WEIGHT GRADE J THREAD I DEPTH CEMENT COMPANY I DATE I - Conductor: 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Intermediate Liner Tubing PUMP#1 PMP#2 LMUD PROPERTIES: IMUD ADDITIVES: Daily (Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT 9.1 GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 49 S.ASH(50 lb bag) 1 LINER SIZE 6 LINER SIZE 6 R600/R300 44/32 KLA-GUARD 0 STOKELNGTH 9 STOKELNGTH 9 R200/R100 25/17 LOTORQ/776ISTEELLUBE 0 SPM SPM R6/R3 7/6 ASPHASOL SUPREME 0 GPS 3.17 GPS 3.17 PV 12 CONDOR404 0 GPM GPM YP 20 POTASSIUM CHLORIDE 0 PSI PSI 0 GELS 10/14/16 FLOWZAN 0 BTMS UP MIN BTMS UP MIN 0 API FLUID LOSS 8.5 PAC 8 TOT CIR MIN TOT CIR MIN 0 CAKE APH/HT 2/ CF-DESCO II 6 6 AVDP: AVDP: 0 SOLIDS 5 MYACIDE GA25 0 AVDC: AVDC: 0 OIL/WATER /95 GEL-X 1 AVDC AVDC: SAND 0.5 CITRIC ACID/SAFE CARE 0 DRILL STRING&HYDRAULICS PH 8.5 RESINEX 0 STRING WT. WOB Pf/Mf .02/.3 CAUSTIC SODA 2 PICK UP RPM CHLORIDES 1000 SODIUM BICARBONATE/mrtabisulfi 0 SLACK OFF TFA CA 40 BARITE/NUT PLUG/G SEAL 63 63 MAX PULL HSP VOL.PIT-(BBL) 435 LIQUIDS(BBLS hauled) 0 ECD PRESS DROP HOLE-(BBL) 344 SOLIDS (BBLS hauled by AIMM) 164 854 DCOD - JET VEL API SCREEN 4-165 4-165 Daily Mud Cum. 233 1565 ACTIVITY SUMMARY TIME SUMMARY Start I Finish I Hours I Description Detail I Daily I Cumulative 6:00 9:00 3.00 Lay down BHA#1,clean and clear floor,grade bit RU/RD 109.00 9:00 10:30 1.50_ R/U to run 13 3/8 casing,(j-55 68#BTC mod) Drilling 28.50 10:30 19:30 9.00 PJSM,Run casing,check floats,FC @2346',shoe @2390' Service/Repair Rig 6.00 19:30 20:00 0.50 R/D casing tools,R/U false rotary table and base plate Surveys 0.00 20:00 0:00 4.00 M/U pup and stab in tool and centilizer on 5"dp,RIH tag FC Tripping 7.00 29.50 0:00 01:30 V 1.50 M/U cementing head and circulate Change BHA 0.00 1:30 r-\t 7 PJSM,test lines T/3k,pump 40 bbls mudpush 10.2ppg,pump Casing Crew 10.50 10.50 F244 bbls 12ppg lead&64bbls 15.4ppg tail,chase w/5bbls Cementing Crew 3.50 3.50 .1 �' water and 34bbls mud,floats held 100%returns w/115bbls Logging 0.00 4:30 3.00 to surface(3bbls left in DP to spot on top of FC)CIP 04:16 NU/ND Test 9.00 4:30 Unsting From FC 30',circ.Casing volume,drop wiper dart DST/Core 0.00 6:00 1.50 circ.1.5 DP volume.R/D flow nipple,R/U false rotary Well Control 0.00 WOC 0.00 Safety Meetings 0.00 Drilling Cement 0.00 Circ/Other 3.00 8.00 24.00 See Remarks&Coments Below TOTAL 24.00 204.00 ___ _ BOTTOM HOLE ASSEMBLY QTY I ITEM I CONN DOWN I CONN UP I VENDOR I O.D. I I.D. I GAUGE I NECK I LENGTH ITOTAL LENGTH MX1 Bit RR 6-5/e reg Baker16 1 30 1.30 Steerable Mud Motor 1.3 deg 6-5/8 reg 6-5/8 H-90 Baker 8 15-7/8 1.80 28.62 29.92 NM pony collar 6-5/8 H-90 6-5/8 H-90 Baker 8 1/16 2 13/16 1.78 9.57 39.49 NM Stabilizer 6-5/8 H-90 6-5/8 H-90 Baker 8 1/8 2 13/16 15 7/8 1.95 5.27 44.76 MWD/Gamma 6-5/8 H-90 6-5/8 H-90 Baker 8 2 13/16 33.45 78.21 CSNMDP 6-5/8 H-90 6-5/8 H-90 Baker 6 3/4 2 7/8 7 3/4 1.86 29.97 108.18 CSNMDP 6-5/8 H-90 6-5/8 H-90 Baker 6 3/4 2 7/8 7 1/4 3.00 29.24 137.42 CSNMDP 6-5/8 H-90 6-5/8 H-90 Baker 6 3/4 2 7/8 7 1/2 3.22 29.59 167.01 X-OVER 6-5/8H-90 41/2 IF Baker 7 3/4 3 1/2 1.58 168.59 4-HWDP 4-1/21F 4-1/21F Nabors 5 3 6 1/2 119.45 288.04 JARS 4-1/21F 4-1/2 IF W/Ford 6 3/16 2 1/4 1.70 32.09 320.13 19-HWDP 4-1/2 IF 4-1/2 IF Nabors 5 3 6 1/2 566.40 886.53 BHA TOTAL LENGTH 886.53 REMARKS&COMMENTS DIESEL No accidents or spills. CLU-1 tree tested 4600psi for 10 mm.(good test) Diesel on Location day before 14,261 Held PJSM's for all jobs. Diesel Used Last 24 1,910 Diesel Received TOTAL DIESEL 12,351 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck drivers 4 7 28 PRA DSM 2 12 24 Aimm Roust. 2 6 12 PRA Safety/PM 0 FMC 1 1 12 12 Canrig Mud Loggers 2 12 24 Pollard 1 1 6 6 MI Swaco Mud Engineer 2 12 24 SLB cementers 5 6 30 Baker Directional 2 12 24 0 Baker LWD 2 12 24 - TOTAL COUNT 40 TOTAL MAN HOURS 504 FROM TO LENGTH JOINT DESCRIPTION G/L 97' 97' Welded 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 BTC-MOD 13 3/8 68#J-55(FC @ 2346,Shoe @2390') CINGSA-DAILY DRILLING REPORT Date: 12/26/2011 Well Name CLU Storage 5 BHA#: DSM Days: Steve Ratcliff Current Depth: 2400' Location: Kenai,AK Target 8956' Cell Phone: (907)230-9902 Depth: Ftg/24hrs. 0 Field/Pool: Cannery Loop/Sterling C Conv aor Nabors Alaska-Rig 105 E N 9hM: Mike Grubb Days Since Spud 4 Present N/U BOPE Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS Ursa CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor: 20 1338 X-56 Welded 97' N/A July - Surface. 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate Liner Tubing PUMP#1 PUMP#2 IMUD PROPERTIES: IMUD ADDITIVES: I Daily (Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT 9.1 GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 47 S.ASH(50 lb bag) 1 LINER SIZE 6 LINER SIZE 6 R600/R300 38/28 KLA-GUARD 0 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 22/17 LOTORQ/776/STEEL LUBE 0 SPM SPM R6/R3 5/4 ASPHASOL SUPREME 0 GPS 3.17 GPS 3.17 PV 10 CONQOR 404 0 GPM GPM YP 18 POTASSIUM CHLORIDE 0 PSI PSI 0 GELS 5/9/9 FLOWZAN 0 BTMS UP MIN BTMS UP MIN 0 API FLUID LOSS 8.5 PAC 8 TOT CIR MIN TOT CIR MIN 0 CAKE APH/HT 2/ CF-DESCO II 8 14 AVDP: AVDP: 0 SOLIDS 5 MYACIDE GA25 0 AVDC: AVDC: 0 OIL/WATER /95 GEL-X 1 AVDC: AVDC: SAND .33 CITRIC ACID/SAFE CARB 0 DRILL STRING&HYDRAULICS PH 9 RESINEX 0 STRING WT. WOB Pf/Mf .10/.35 CAUSTIC SODA 2 PICK UP RPM CHLORIDES 1000 SODIUM BICARBONATE/mrtabisulfi 8 8 SLACK OFF TFA CA 40 BARITE/NUT PLUG/G SEAL 73 136 MAX PULL HSP VOL.PIT-(BBL) 478 LIQUIDS(BBLS hauled) 0 ECD PRESS DROP HOLE-(BBL) 359 SOLIDS (BBLS hauled by AIMM) 839 1693 DCOD - JET VEL API SCREEN 4-165 4-165 Daily Mud Cum. 928 2493 ACTIVITY SUMMARY _ __I TIME SUMMARY Start i Finish I Hours 1 Description (Detail I Daily I Cumulative 6:00 8:30 2.50 Continue circulate wiper plug,clean and clear drill pipe. RU/RD 12.00 121.00 8:30 11:00 2.50 POH inner string and false rotary F/2346',LJD stab in tool, Drilling 28.50 clean and clear floor Service/Repair Rig 6.00 11:00 12:00 1.00 While waiting on cement,prep for N/D Surveys 0.00 12:00 Continue cleaning pits,N/D diverter,P/U stack,rough cut, Tripping 2.50 32.00 move out 20"annular and 16"spool,cut conductor 37"BGL Change BHA 0.00 20:30 8.50 cut 13 3/8 20"BGL&dress.(hard cement above cutoff) Casing Crew 10.50 20:30 Install FMC 13 3/8 x 5k c-22 SL wellhead,testT/1560psi for Cementing Crew 3.50 21:30 1.00 15 min good test,tq slips t/250psi Logging 0.00 21:30 N/U bops,set double gate on wellhead,spot annular in cellar NU/ND Test 6.00 15.00 23:00 1.50 Notice double gate not setting level DST/Core 0.00 23:00 Pull well head with double gate to inspect&redress 13 3/8 Well Control 0.00 1:30 2.50 Good retest @1560psi for 15 min.,tq slips t/250psi WOC 1.00 1.00 1:30 N/U BOPS,set annular,R/U kill and choke lines,torque Safety Meetings 0.00 6:00 4.50 studs,Continue building Flo Pro mud Drilling Cement 0.00 Circ/Other 2.50 10.50 24.00 See Remarks&Coments Below TOTAL 24.00 228.00 BOTTOM HOLE ASSEMBLY QTY ITEM CONN DOWN CONN UP I VENDOR I O.D. I I.D. I GAUGE I NECK I LENGTH TOTAL LENGTH • BHA TOTAL LENGTH 0.00 REMARKS&COMMENTS DIESEL No accidents or spills. 60 bbls spud mud in pits to drill out with,418 bbls building flo pro mud Diesel on Location day before 12,351 Held PJSM's for all jobs. Diesel Used Last 24 1,594 Bob Noble called @ 5:45 12.24-11 waived witness Diesel Received Cut length 13 3/8"casing=23.88' TOTAL DIESEL 10,757 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors _ Rig Crew 24 12.5 300 Aimm Vac truck drivers 6 12 72 PRA DSM 2 12 24 Aimm Roust. 2 12 24 PRA - Safety/PM 0 FMC 1 1 12 12 Canrig _ Mud Loggers 2 12 24 Pollard test truck 1 1 1 MI Swaco Mud Engineer 2 12 24 0 Baker Directional 2 12 24 0 Baker LWD 2 12 24 - TOTAL COUNT 44 TOTAL MAN HOURS 529 • FROM TO LENGTH JOINT DESCRIPTION • G/L 97' 97' Welded 20"1339 X-56 Welded Conductor Pipe RKB 2390' 2390 BTC-MOD 13 3/8 68#J-55(FC @ 2346,Shoe @2390') CINGSA-DAILY DRILLING REPORT Date: 12/27/2011 Well Name CLU Storage 5 BHA#: 2 JSM Days: John Nicholson Current Depth: 2572' Location: Kenai,AK Target 8956' Cell Phone: (907)299-4306 Depth: Ftg/24hrs. 172' Field/Pool: Cannery Loop/Sterling C �nR aor Nabors Alaska-Rig 105 E NightsMike Grubb Days Sane Spud 5 Present DRILL FROM 2572' Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS rune • 2 121/4 HCC QD505XX 7131957 8-12's 2400' 172' 1.2 143.00 ' CASING I SIZE WEIGHT I GRADE THREAD E DEPTH - CEMENT COMPANY I DATE / Conductor: 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate Liner C i Tubing PUMP#1 PUMP#2 MUD PROPERTIES: MUD ADDITIVES: Daily Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT 8.9 GEL(50 lb bag) 630 I PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 52 5.ASH(50/b bag) 2 3 LINER SIZE 6 LINER SIZE 6 R800/R300 46/35 KLA-GUARD 0 STOKELNGTH 9 STOKELNGTH 9 R200/R100 28/21 LOTORO/776/STEELLUBE 0 SPM 85 SPM 85 R6/R3 8/7 ASPHASOL SUPREME 0 GPS 3.17 GPO 3.17 PV 11 CONDOR 404 2 2 GPM 270 GPM 270 VP 24 POTASSIUM CHLORIDE 300 300 PSI 1100 PSI 1100 GELS 8/11/12 FLOWZAN 28 28 BTMS UP MIN 28 BTMS UP MIN 28 API FLUID LOSS 6.4 PAC 20 28 TOT CIR MIN 95 TOT CIR MIN 95 CAKE APH/HT 1/ CF-DESCO II 14 AVDP: AVDP: 86..7 SOLIDS 3 MYACIDE GA25 2 2 AVDC: AVDC: 103.2 OIL/WATER /95 GEL-X 4 5 AVDC: AVDC: SAND 0 CITRIC ACID/SAFE CARB 85 85 DRILL STRING&HYDRAULICS PH 8.5 RESINEX 0 STRING WT. 75 WOB 10 Pf/Mf .04/.35 CAUSTIC SODA 2 PICKUP 93 RPM 60 CHLORIDES 28500 SODIUM BICARBONATE/mrtabisulfr 15 23 SLACK OFF 60 TFA 0.8836 CA 40 BARITE/NUT PLUG/G SEAL 136 MAX PULL 75 HSP 59/.5 VOL.PIT-(BBL) 366 LIQUIDS(BELS hauled) 0 ECD 9.13 PRESS DROP 219/20 HOLE-(BBL) 333 SOLIDS (BBLS hauled by AIMM) 0 1693 DCOD 11.2 JET VEL 166 API SCREEN 4-165 4-165 Daily Mud Cum. 458 2951 ACTIVITY SUMMARY I __ TIME SUMMARY Start I Finish I Hours Description (Detail I Daily I Cumulative 6:00 9:00 3.00 Continue N/U BOPE RU/RD 121.00 9:00 14:30 5.50 Test BOPE,250psi/2500psi,test alarms,koomy,flow,pvt Drilling 4.00 32.50 14:30 15:30 1.00 L/D test equip,Install long wear bushing Service/Repair Riq 1.00 7.00 ')�7 br 15:30 16:30 1.00 Service and Lube Top Drive Surveys 0.00 F' 16:30 21:00 4.50 P/U Directional BHA#2,RIH T/878',download,test MWD Tripping 6.00 38.00 1G' 21:00 22:00 1.00 RIH with DP F/878'-2213' Change BHA 0.00 22:00 R/U and test 13 3/8 casing @ 2000psi for 30 min.(good test) Casing Crew 10.50 r�. 23:30 1.50 R/D test equipment,Blow down mud lines Cementing Crew 3.50 23:30 0:00 0.50 Wash F/2213.-2336'(tag soft cement) Logging 0.00 0:00 0:30 0.50 Reboot Canrig computer(problem W/data collection) NU/ND Test 11.50 26.50 0:30 2:00 1.50 Drill out cement and shoe track F/2336'-2400' DST/Core 0.00 4°` 2:00 2:30 0.50 Drill 12 1/4"hole F/2400'-2420'(pump 40 bbl hi vis sweep) Well Control 0.00 2:30 3:30 1.00 Displace hole with Flo Pro mud 8.9mw WOC 1.00 3:30 4:00 0.50 Preform FIT test W/8.9mw 698psi @2017tvd=15.5 EMW Safety Meetings 0.00 4:00 6:00 2.00 Drill 12 1/4"hole F/2420'-2572'60 rpm,450 gpm Drilling Cement 0.00 up 93,do 60,rt 75,bit wt 10,tq 3-5k ART- Circ/Other 1.50 12.00 24.00 See Remarks&Coments Below TOTAL 24.00 252.00 _ BOTTOM HOLE ASSEMBLY any I ITEM I CONN DOWN I CONN UP I VENDOR I O.D. I I.D. I GAUGE I NECK I LENGTH (TOTAL LENGTH 121/400505x0 PDC BIT 65/8 Ie5 HCC 121/2" J" 1.34 1.34 steering head,6ex,NM X-O 65./8 reg T2 BHI 91/2" 121/4" 8.67 3725 62.06 Ontrak,Sab,BCPM,Stop T2 65./8 reg BHI 8 1/4" 12.125" 1.70 37.25 62.06 NM Filter Sub 6 5/8 reg 6 5/8 reg BHI 8 1/8" 2 7/8" 5.44 67.50 NM X-O Float Sub 6 5/8 reg 6 5/B H90 BHI 7 13/16" _ 2 7/8" 2.76 70.26 CSNMDP 6 5/8 H90 6 5/8 H90 BHI 6 3/4" 2 7/8" 7 1/2" 3.22 29.59 99.85 CSNMDP 6 5/8 H90 6 5/8 H90 BHI 6 3/4" 2 7/8" 7 1/4" 3.00 29.24 129.09 CSNMDP 6 5/8 H90 6 5/8 H90 BHI 6 3/4" 2 7/8" 7 3/4" 1.86 29.97 159.06 X-O 6 5/8 H90 4 1/2 IF BHI 7 3/4" 3 1/2" 1.58 160.64 4 HWDP 41/2 IF 4 1/2IF GP 5" 3 6 1/2" 119.45 280.09 Jars 41/21F 4 1/2IF WFD 63/16" 21/4" 1.70 32.09 312.18 19 HWOP 41/2 IF 41/21F GP 5" 3" 61/2" 566.40 878.68 BHA TOTAL LENGTH 878.58 REMARKS&COMMENTS DIESEL No Accidents No Spills Diesel on Location day before 10,757 Held PJSM's for all jobs. Diesel Used Last 24 1,952 Bob Noble called @ 5:45 12-24-11 waived witness Diesel Received TOTAL DIESEL 8,805 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck drivers 2 2 4 PRA DSM 2 _ 12 24 Aimm Roust. 2 2 4 PRA Safety/PM _ 0 FMC 1 1 12 12 Canrig Mud Loggers 2 12 24 Nabors FMC help 2 4 8 MI Swaco Mud Engineer 2 12 24 0 Baker Directional 2 12 24 0 Baker LWD 2 12 24 - TOTAL COUNT 41 TOTAL MAN HOURS 448 FROM TO LENGTH JOINT DESCRIPTION G/L 97' 97' Welded 20"133#X-56 Welded Conductor Pipe RKB - 2390' 2390 BTC-MOD 13 3/8 68#J-55(FC @ 2346,Shoe @2390') CINGSA-DAILY DRILLING REPORT Date: 12/28/2011 Well Name CLU Storage 5 BHA#: 2 OSM Days: John Nicholson Current Depth: 4900 Location: Kenai,AK Target 8956' Cell Phone: (907)299-4306 Depth, Ftg/24hrs. 2328 Field/Pool: Cannery Loop/Sterling C contractor Rig Nabors Alaska-Rig 105 E Nights Mike Grubb Days Since Spud 6 Present circ for wiper trip Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT S SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS FT/HR 2 121/4 HCC OD505XX 7131957 8-12's 2400' 2500' 50.4 162.00 CASING SIZE WEIGHT GRADE THREAD DEPTH CEMENT COMPANY DATE - Conductor: 20 1336 X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Siumberger 25-Dec Intermediate Liner Tubing PUMP#1 PUMP#2 [MUD PROPERTIES: MUD ADDITIVES: I Daily (Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT 9.045 GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 45 S.ASH(50 lb bag) 8 11 LINER SIZE 6 LINER SIZE 6 R600/R300 38/27 KLA-GUARD 0 STOKE LNGTH 9 STOKELNGTH 9 R200/R100 20/16 LOTORQ/776/STEELLUBE 330 330 SPM 94 SPM 94 R6/R3 6/5 ASPHASOL SUPREME 0 GPS 3.17 GPS 3.17 PV 11 CONDOR404 2 GPM 300 GPM 300 YP 16 POTASSIUM CHLORIDE 122 422 PSI 1100 PSI 1100 GELS 5/7/8 FLOWZAN 46 46 BTMS UP MIN 36 BTMS UP MIN 36 API FLUID LOSS 6.4 PAC 40 68 TOT CIR MIN 89 TOT CIR MIN 89 CAKE APH/HT 1/ CF-DESCO II 14 AVDP: AVDP: 110.2 SOLIDS 4 MYACIDE GA25 2 AVDC: AVDC: 130.4 OIL/WATER 1/95 GEL-X 5 AVDC: AVDC: SAND .75 CITRIC ACID/SAFE GARB 8 93 DRILL STRING&HYDRAULICS PH 9.1 RESINEX 0 STRING WT. i 85 WOB 10 Pf/Mf .05/.35 CAUSTIC SODA 3 5 PICK UP 125 RPM 120 CHLORIDES 28000 SODIUM BICARBONATE/mrtabisulfi 23 SLACK OFF i 55 TFA 0.8836 CA 280 BARITE/NUT PLUG/G SEAL 136 MAX PULL 128 HSP 131/1.1 VOL.PIT-(BBL) 686 LIQUIDS(BBLS hauled) 0 • ECD i 9.22 PRESS DROP 378/29 HOLE-(BBL) 573 SOLIDS (BBLS hauled by AIMM) 1240 2932 DCOD 11.2 JET VEL 216 API SCREEN 4-200 3-200.1-165 Daily Mud Cum. 1797 4719 ACTIVITY SUMMARY TIME SUMMARY Start I Finish I Hours I Description Detail I Daily I Cumulative 6:00am Drilling F/2572'-3080'RPM 120,540gpm,1200psi,tq 3-4 RU/RD 121.00 12:00 6.00 UP 110,DN 50,RT 80,bit wt 10 ART-3.3 hrs Drilling 24.00 56.50 12:00 Drilling F/3080'-3654'RPM 120,550gpm,t 250psi,tq 7-9k Service/Repair Rig 7.00 18:00 6.00 UP 115,DN 55,RT 85,bit wt 10 ART-3.5 hrs Surveys 0.00 18:00 Drilling F/3080'-4230'RPM 120,600gpm,1300psi,tq 8-10 Tripping 38.00 0:00 6.00 UP 123,DN 55,RT 86,bit wt 10 ART-3.2 hrs Change BHA 0.00 " 0:00 Drilling F/4230'-4900'RPM 120,600 gpm,1425 psi,tg8-11 Casing Crew 10.50 6:00 6.00 UP 125,DN 70,RT 90,bit wt 10-14,ART 4.2 Cementing Crew 3.50 Logging 0.00 NU/ND Test 26.50 DST/Core 0.00 Well Control 0.00 WOC 1.00 Safety Meetings 0.00 Drilling Cement 0.00 Circ/Other 12.00 24.00 See Remarks&Coments Below TOTAL 24.00 276.00 BOTTOM HOLE ASSEMBLY • QTY I ITEM I CONN DOWN I CONN UP I VENDOR I O.D. I I.D. I GAUGE I NECK I LENGTH 1TOTAL LENGTH 12 1/4 OD505xx PDC BIT 6 5/8 reg HCC 12 1/2" 3" 1.34 1.34 steering heatl flex,NM X-O 6 5./8 reg 72 BHI 9 1/2" 12 1/4" 8.67 37.25 i 62.06 Ontrak,Sab,BCPM,SIop 72 65./8 reg BHI 8 1/4" 12.125" 1.70 37.25 62.06 NM Filter Sub 6 5/8 reg 6 5/8 reg BHI 8 1/8" 2 7/8" 5.44 67.50 NM 8-0 Float Sub 6 5/8 reg 6 5/8 H90 818 7 13/16" 2 7/8" 2.76 70.26 CSNMDP 6 5/8 H90 6 5/8 H90 BHI 6 3/4" 2 7/8" 7 1/2" 3.22 29.59 99.85 CSNMDP 6 5/8 H90 6 5/8 H90 BHI 6 3/4" 2 7/8" 7 1/4" 3.00 29.24 129.09 CSNMDP 6 5/8 H90 6 5/8 H90 BHI 6 3/4" 2 7/8" 7 3/4" 1.86 29.97 159.06 X-O 65/8 H90 4 1/2 IF BHI 7 3/4" 3 1/2" 1.58 160.64 4 HWDP 41/2 IF 4 1/2IF GP 5" 3 6 1/2" 119.45 280.09 Jars 41/2 IF 41/2 IF WFD 63/16" 2 1/4" 1.70 32.09 312.18 19 HWDP 41/2 IF 41/2 IF GP 5" 3" 61/2" 566.43 878.68 BHA TOTAL LENGTH 878.58 REMARKS&COMMENTS DIESEL No Accidents No Spills Diesel on Location day before 8,805 Held PJSM's for all jobs. Diesel Used Last 24, 2,034 Flow check every connection Diesel Received Increase lube from 1%to 2 1/2%before short trip TOTAL DIESEL 6,771 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck drivers 4 12 48 PRA DSM 2 12 24 Aimm Roust. 2 12 24 PRA - Safety/PM 0 Canrig Mud Loggers 2 12 24 MI Swaco Mud Engineer 2 12 24 0 Baker Directional 2 12 24 0 Baker LWD 2 12 24 - TOTAL COUNT 41 TOTAL MAN HOURS 492 • FROM TO LENGTH JOINT DESCRIPTION G/L 97' 97' Welded 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 BTC-MOD 13 3/8 68#J-55(FC @ 2346,Shoe @2390') CINGSA-DAILY DRILLING REPORT Date: 12/29/2011 Well Name CLU Storage 5 BHA#. 2 M Days: John Nicholson Current Depth: 6337 Location: Kenai,AK Target Depth 8956' Cell Phone: (907)299-4306 Ftg/24hrs. 1437 Field/Pool, Cannery Loop/Sterling C Contractor, Nabors Alaska-Rig 105 E Nights: Mike Grubb Days Since Spud 7 Present Drill Ahead©6337 Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS rnHe 2 121/4 HCC QD505XX 7131957 8-12's 2400' 2500' 50.4 162.00 CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor, 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate Liner Tubing PUMP#1 IPUMP#2 IMUD PROPERTIES: ',MUD ADDITIVES: I Daily (Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT 9.0 GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 50 S.ASH(50 lb bag) 11 LINER SIZE 6 LINER SIZE 6 R600/R300 44/32 KLA-GUARD 0 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 27/20 LOTORQ/776/STEEL LUBE 990 1320 SPM 94 SPM 94 R6/R3 10/8 ASPHASOL SUPREME 0 GPS 3.17 GPS 3.17 PV 12 CONQOR 404 2 GPM 300 GPM 300 YP 20 POTASSIUM CHLORIDE 163 585 PSI 1650 PSI 1650 GELS 10/12/12 FLOWZAN 30 76 BTMS UP MIN 36 BTMS UP MIN 36 API FLUID LOSS 5.8 PAC 18 86 TOT CIR MIN 89 TOT CIR MIN 89 CAKE APH/HT 1/ CF-DESCO II 14 AVDP: 110.20 AVDP: 110.2 SOLIDS 4 MYACIDE GA25 2 AVDC: 130.40 AVDC: 130.4 OIL/WATER 3/93 GEL-X 5 AVDC: AVDC: SAND 0.5 CITRIC ACID/SAFE CARB 41 134 DRILL STRING&HYDRAULICS PH 9.5 RESINEX 0 STRING WT. 97 WOB 12 Pf/Mf .04/.40 CAUSTIC SODA 6 11 PICKUP 145 RPM 120-130 CHLORIDES 27000 SODIUM BICARBONATE/mrtabisulfr 23 SLACK OFF 70 TFA 0.8836 CA 280 BARITE/NUT PLUG/G SEAL 136 MAX PULL 150 HSP 131/1.1 VOL.PIT-(BBL) 662 LIQUIDS(BBLS hauled) 0 ECD 9.25 PRESS DROP 378/29 HOLE-(BBL) 795 SOLIDS (BELS hauled by AIMM) 344 3276 DCOD 11.2 JET VEL 216 API SCREEN 4-200 2-200.2-165 Daily Mud Cum. 1592 6311 ACTIVITY SUMMARY TIME SUMMARY Start I Finish I Hours I Description Detail I Daily I Cumulative 6:00am 7;00 1.00 C&C hole for wiper trip.Pump 40bbl hi vis sweep,Recip& RU/RD 121.00 rotate pipe 120rpm 600gpm 1400psi.Hvy returns on bttms Drilling 13.00 69.50 up.continue circ until shakers clean up, Service/Repair Rig 1 00 8.00 7:00 11:30 4.50 POH wiper trip F/4900'.3846'3740'work tight hole.Hole Surveys 0.00 beginning to swab,pump out F/3846'-2314'no gain loss Tripping 9.00 47.00 11:30 12:30 1.00 Service rig BOP Drill,Crew change. Change BHA 0.00 12:30 16:30 4.00 RIH F/2314'to 4165'wash and ream due to tight hole to Casing Crew 10.50 4805'.Wash down to 4900'tag 7'of fill on bottom.Heavy Cementing Crew 3.50 returns on bottoms up. Logging 0.00 16:30 17:00 0.50 Open ribs on ontrac tool take survey. NU/ND Test 26.50 17:00 0:00 7.00 Drill 12 1/4 hole section F/4900"-5571',125rpm,600gpm, DST/Core 0.00 TQ 9-10,UP 130,DN 75,RT 95,bit wt 10-14,1600 Psi,ART3.8 Well Control 0.00 0:00 6:00 Drill 12 1/4 hole section F/5571-6337',125rpm,600gpm, WOC 1.00 6.00 TQ11-14,UP 145,DN 7ORT 97,bit wt 10-14,1650 Psi,ART4.3 Safety Meetings 0.00 Drilling Cement 0.00 Circ/Other 1.00 13.00 24.00 See Remarks&Coments Below TOTAL 24.00 300.00 BOTTOM HOLE ASSEMBLY QTY ITEM CONN DOWN CONN UP VENDOR O.D. I.D. GAUGE NECK LENGTH TOTAL LENGTH 12 1/4 QD505xx PDC BIT 65/8 reg HCC 121/2" 3" 1.34 1.34 steering head flex,NM 0-0 6 5./8 reg T2 BHI 9 1/2" 12 1/4" 8.67 37.25 62.06 Ontrak,Sab,BCPM,SIop T2 65/8 reg BHI 81/4" 12.125" 1.70 37.25 62.06 NM Fitter Sub 6 5/8 reg 6 5/8 reg BHI 8 1/8" 2 7/8" 5.44 67.50 NM X-0 Float Sub 6 5/8 reg 6 5/8 H90 BHI 7 13/16" 2 7/8" 2.76 70.26 CSNMDP 6 5/8 H90 6 5/8 H90 BHI 6 3/4" 2 7/8" 7 1/2" 3.22 29.59 99.85 CSNMDP 6 5/8 H90 6 5/8 H90 BHI 6 3/4" 2 7/8" 7 1/4" 3.00 29.24 129.09 CSNMDP 6 5/8 H90 6 5/8 H90 BHI 6 3/4" 2 7/8" 7 3/4" 1.86 29.97 159.06 X-O 65/8 H90 41/2 IF BHI 73/4" 31/2" 1.58 160.64 4 HWDP 41/21F 41/2 IF GP 5" 3 61/2" 119.45 280.09 Jars 41/2 IF 41/2 IF WFD 63/16" 21/4" 1.70 32.09 312.18 19 HWDP 41/2 IF 41/21F GP 5" 3" 61/2" 566.40 878.68 BHA TOTAL LENGTH 878.58 REMARKS&COMMENTS DIESEL No Accidents No Spills max gas 90units @5542' Diesel on Location day before 6,771 Held PJSM's for all jobs. Pump sweeps as needed Diesel Used Last 24 2,457 Flow check every connection Diesel Received 9,494 BOP drill 43 Sec.all hands on stations TOTAL DIESEL 13,808 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck drivers 4 12 48 PRA DSM 2 12 24 Aimm Roust. 4 12 48 PRA Safety/PM 2 1 2 Canrig Mud Loggers 2 12 24 MI Swaco Mud Engineer 2 12 24 0 Baker Directional 2 12 24 0 Baker LWD 2 12 24 - TOTAL COUNT 44 TOTAL MAN HOURS 506 FROM I TO I LENGTH I JOINT I DESCRIPTION G/L 97' 97' WP.'"d 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 Bl ) 13 3/8 68#J-55(FC @ 2346,Shoe(2390') CINGSA-DAILY DRILLING REPORT Date: 12/30/2011 Well Name CLU Storage 5 BHA#: 2 USM Days: John Nicholson Current Depth: 7790' Location: Kenai,AK Target 8956' Cell Phone: (907)299-4306 Depth: Ftg/24hrs. 1453' Field/Pool: Cannery Loop I Sterling C Conhactor: Nabors Alaska-Rig 105 E NIghM: Mike Grubb Days Since Spud 8 Present Drilling Ahead @ 7790' Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation'. DRILLING DATA BIT# SIZE MFG TYPE SER S JETS IN OUT FEET BR GRADE TOTAL HOURS rEHR 2 121/4 HCC OD505XX 7131957 8-12's 2400' 5390' 33.3 162' CASING I SIZE I WEIGHT I GRADE I THREAD 4 DEPTH CEMENT COMPANY I DATE I - Conductor: 20 1334 X-56 Welded 97' N:A� July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate Liner Tubing PUMP#1 PUMP#2 MUD PROPERTIES: MUD ADDITIVES: Daily Cumulative PUMP MANE Gardner Denver PUMP MANE Gardner Denver WEIGHT 9.1 GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 50 S.ASH(501b bag) 11 LINER SIZE 6 LINER SIZE 6 R600/R300 47/36 KLA-GUARD 0 STOKELNGTH 9 STOKELNGTH 9 R200/R100 30/23 LOTORQ/776/STEELLUBE 1004 2324 SPM 94 SPM 94 R6/R3 9/8 ASPHASOL SUPREME 60 60 GPS 3.17 GPS 3.17 PV 11 CONDOR 404 4 6 GPM 300 GPM 300 YP 25 POTASSIUM CHLORIDE 245 730 PSI 1650 PSI 1650 GELS 9/13/15 FLOWZAN 30 106 BTMS UP MIN 36 BTMS UP MIN 36 API FLUID LOSS 5.6 PAC 20 106 TOT CIR MIN 89 TOT CIR MIN 89 CAKE APH/HT 1/ CF-DESCO II 14 AVDP: AVDP: 110.2 SOLIDS 4 MYACIDE GA25 2 AVDC: AVDC: 130.4 OIUWATER 4/93 GEL-X 5 AVDC: AVDC. SAND 0.5 CITRIC ACID/SAFE CARB 24 158 DRILL STRING 8 HYDRAULICS PH 8.8 RESINEX 0 STRING WT. 115 WOB 12 Pf/Mf .03/25 CAUSTIC SODA 7 18 PICKUP 165 RPM 120-130 CHLORIDES 28000 SODIUM BICARBONATE/mrtabisul6 23 SLACK OFF 70 TFA 0.8836 CA 280 BARITE/NUT PLUG/G SEAL 136 MAX PULL 170 HSP 141/1.2 VOL.PIT-(BBL) 735 LIQUIDS(BBLS hauled) 0 ECD 9.43 PRESS DROP 378/24.1 HOLE-(BBL) 1031 SOLIDS (BBLS hauled by AIMM) 339 3615 DCOD 11.2 JET VEL 216 API SCREEN 4-200 2-200.2-165 Daily Mud Cum. 1733 7944 ACTIVITY SUMMARY I TIME SUMMARY Start I Finish I. Hours 1 Description )Detail I Daily I Cumulative 6:00am 7:30 1.50 Drill 12 1/4 hole section F/6337-6529",l3Orpm,600gpm, RU/RD 121.00 TQ11-14,UP 145,DN 7ORT 104,bitwt 10-14,1650p art 1hr Drilling 16.50 86.00 7:30 8:30 1.00 Circ and pump sweep @ 6529'600gpm 1675psi 130rpm Service/Repair Rig 8.00 Sweep returned at calculated strokes with hvy returns. Surveys 0.00 8:30 Monitor well POH(wiper trip)F 6529'to 4809'pump and Tripping 6.00 53.00 back ream 500gpm 100rpm saw tight hole at 5520 work& Change BHA 0.00 12:30 4.00 clean up.No gain/loss Casing Crew 10.50 12:30 13:00 0.50 Blow down mud lines Service rig,top drive blocks Cementing Crew 3.50 13:00 14:00 1.00 RIFI F/4905-6434'Wash down F/6434'-6529'tag bottom Logging 0.00 no fill.Hole slick no problems with TIH. NU/ND Test 26.50 14:00 Drill 12 1/4 hole section F/6529'-7103',13Orpm,600gpm, DST/Core 0.00 20:00 6.00 T012-15,UP 150,DN85,RT 108,bit wt 10-14,1750p art 4 hr Well Control 0.00 20:00 Circ and pump sweep @ 7103'600gpm 1675psi 130rpm WOC 1.00 21:00 1.00 15%excess returns thruout circ.,30%@ sweep return Safety Meetings 0.00 21:00 Drill 12 1/4 hole section F/7103'-7677',13Orpm,600gpm,CBU Drilling Cement 0.00 6:00 9.00 TO18-21,UP 165,DN70,RT 115,bit wt 10-14,1750p art 4.8hr Circ/Other 1.50 14.50 24.00 See Remarks&Coments Below TOTAL 24.00 324.00 BOTTOM HOLE ASSEMBLY QTY I ITEM CONN DOWN I ;DNN UP I VENDOR 1 O.D. I I.D. I GAUGE I NECK I LENGTH 1TOTAL LENGTH 121/4 OD505xx PDC BIT 65/8 reg HCC 121/2" 3" 1.34 1.34 steering head,Bex,NM X-0 6 538 reg T2 BHI 9 1/2" 12 1/4" 8.67 37.25 62.06 Ontrak,Sab,BCPM,Stop T2 6 5./8 reg BHI 8 1/4" 12.125" 1.70 37.25 82.06 NM Filler Sub 65/8 reg 6 5/8 reg BHI 8 1/8" 2 7/8" 5.44 67.50 NM X-0 Float Sub 65/8 rag 65/8 H90 BHI 713/16" 2 7/8" 2.76 70.26 CSNMDP 6 5/8 H90 6 5/8 H90 BHI 6 3/4" 2 7/8" 7 1/2" 3.22 29.59 99.85 CSNMDP 6 5/8 H90 65/8 H90 BHI 6 3/4" 2 7/8" 7 1/4" 3.00 29.24 129.09 CSNMDP 6 5/8 H90 6 5/81490 BHI 6 3/4" 2 7/8" 73/4" 1.86 29.97 159.06 X-0 6 5/8 H90 4 1/2 IF BHI 7 3/4" 3 1/2" 1.58 160.64 4 HWDP 41/2 IF 41/2 IF GP 5' 3 6 1/2" 119.45 280.09 Jam 4 1/2 IF 4 1/2 IF WFD 6 3/16" 2 1/4" 1.70 32.09 312.18 19 HWDP 4 1/2IF 4 1/2IF GP 5" 3" 6 1/2" 566.40 878.68 BHA TOTAL LENGTH 878.58 REMARKS 8 COMMENTS DIESEL No Accidents No Spills Max gas 579 units @7075'-Back ground gas 94 units Diesel on Location day before 13,808 Held PJSM's for all jobs. Pump sweeps as needed Diesel Used Last 24 3,166 Flow check every connection Diesel Received 0 BOP Drill TOTAL DIESEL 10,642 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck drivers 4 13 52 PRA DSM 2 12 24 Aimm Roust. 3 12 36 PRA _ Safety/PM 2 1 2 Canrig Mud Loggers 2 12 24 MI Swaco " Mud Engineer 2 12 24 0 Baker Directional 2 12 24 0 Baker LWD 2 12 24 TOTAL COUNT 44 TOTAL MAN HOURS 510 FROM TO LENGTH JOINT DESCRIPTION G/L 97' 97' Welded 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 BTC-MOD 133/8 68#J-55(FC @ 2346,Shoe @2390') 7,ING5A-DAILY DRILLING REPORT Date: 12/31/2011 Well Name CLU Storage 5 BHA#: 2 JsM Days: John Nicholson Current Depth: 8872' Location: Kenai,AK Target 8956' Cell Phone: (907)299-4306 Depth: , Rig Ftg/24hrs. 1082' Field/Pool: Cannery Loop/Sterling C Contractor Nabors Alaska-Rig 105 E NIghM. Mike Grubb Days Since Spud 9 PresentPull out of hole to run 9 5/8 casing Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA • BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS FT/HR 2 121/4 HCC QD505XX 7131957 8-12's 2400' 6472 42.4 152.60 CASING I SIZE WEIGHT I GRADE I THREAD I DEPTH 1 CEMENT COMPANY I DATE ( - Conductor: 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate Liner Tubing PUMP#1 PUMP#2 IMUD PROPERTIES: MUD ADDITIVES: 1 Daily ICumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT 9.3 GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 52 S.ASH(50 lb bag) 11 LINER SIZE 6 LINER SIZE 6 R600/R300 51/37 KLA-GUARD 0 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 31/24 LOTORQ/776/STEEL LUBE 990 3482 SPM 94 SPM 94 R6/R3 11/10 ASPHASOL SUPREME 120 180 GPS 3.17 GPS 3.17 PV 14 CONQOR 404 6 GPM 300 GPM 300 YP 23 POTASSIUM CHLORIDE 240 970 PSI 1650 PSI 1650 GELS 13/20/29 FLOWZAN 20 126 BTMS UP MIN 36 BTMS UP MIN 36 API FLUID LOSS 5.8 PAC 12 118 TOT CIR MIN 89 TOT CIR MIN 89 CAKE APH/HT 1/ CF-DESCO II 14 AVDP: AVDP: 113.2 SOLIDS 6 MYACIDE GA25 2 AVDC: AVDC: 222.8 OIL/WATER 4/90 GEL-X 5 AVDC: AVDC: SAND 0.5 CITRIC ACID/SAFE GARB 114 272 DRILL STRING&HYDRAULICS PH 8.8 RESINEX 60 60 STRING WT. 125 WOB 12 Pt/Mt .02/.25 CAUSTIC SODA 4 22 PICKUP 175 RPM 120-130 CHLORIDES 29000 SODIUM BICARBONATE/mrtabisul8 23 SLACK OFF 85 TFA 0.8836 CA 280 BARITE/NUT PLUG/G SEAL 136 MAX PULL 185 HSP 141/1.2 VOL.PIT-(BBL) 664 LIQUIDS(BELS hauled) 0 ECD 9.43 PRESS DROP 413/21.2 HOLE-(BBL) 1278 SOLIDS (BBLS hauled by AIMM) 522.5 4136.8 DCOD 11.2 JET VEL 222 API SCREEN 4-200 2-200.2-165 Daily Mud Cum. 2082.5 10193.8 ACTIVITY SUMMARY I TIME SUMMARY C Start I Finish Tours I Description Detail I Daily [Cumulative 6:00am 11:30 5.50 Drill 12 1/4 hole section F/7790-8347",13Orpm,600gpm, RU/RD 121.00 TQ 17-19,UP 165,DN 85RT 120,bit wt 10-14,1800p art 3.6 Drilling 5.50 91.50 11:30 13:00 1.50 Pump sweep Circulate B/U @ 8347'600gpm 13Orpm1840psi Service/Repair Rig 8.00 Hvy returns over shakers all during circulating B/U Surveys 0.00 13:00 21:30 8.50 Drill 12 1/4 hole section F/8347-887213Orpm,600gpm, Tripping 13.00 66.00 TQ 19-24,UP 175,DN 85RT 125,bit wt 10-14,1850p art 5.5 Change BHA 0.00 21:30 TD as per geologist @8872',Circ.around 32bbl hi vis sweep Casing Crew 10.50 23:30 2.00 612gpm,130 rpm,1950psi Cementing Crew 3.50 23:30 1:30 2.00 Back ream out of hole F/8872'-7964',500gpm,10Orpm Logging 0.00 1:30 2:30 1.00 Blow down lines,RIH on elevators F/7964.-8835'wash to NU/ND Test 26.50 8872'smooth trip no fill DST/Core 0.00 2:30 5:00 2.50 Circ.bottoms up,spot 100bbl hi vis 12%lube LCM pill Well Control 0.00 5:00 6:00 1.00 POH F/8872.-8160'on elevators WOC 1.00 Safety Meetings 0.00 I NOTE:Last 100'of hole torque 23-24 k fp/lbs. Drilling Cement 0.00 Circ/Other 5.50 20.00•_ 24.00 See Remarks&Coments Below TOTAL 24.00 348.00 BOTTOM HOLE ASSEMBLY QTY I ITEM I CONN DOWN I CONN UP T VENDOR I O.D. I I.D. I GAUGE I NECK I LENGTH [TOTAL LENGTH 121/4 OD505xx PDC BIT 65/8 reg HCC 12 1/2" 3" 1.34 1.34 steering head flex,NM X-O 6 518 reg T2 BHI 9 1/2" 12 1/4" 8.67 37.25 62.06 Ontrak,Sab,BCPM,Stop 72 6518 reg BHI 81/4" 12.125" 1.70 37.25 62.06 NM Filter Sub 6 5/8 reg 6 5/8 reg BHI 8 1/8" 2 7/8" 5.44 67.50 NM X-O Float Sub 6 5/8 reg 6 5/8 H90 BHI 7 13/16" 2 7/8" 2.76 70.26 CSNMDP 6 5/8 H90 6 5/8 H90 8HI 6 3/4" 2 7/8" 7 1/2" 3.22 29.59 99.85 _ CSNMDP 6 5/8 H90 6 5/8 H90 BHI 6 3/4" 2 7/8" 7 1/4" 3.00 29.24 129.09 CSNMDP 6 5/8 H90 6 5/8 H90 861 _ 6 3/4" 2 7/8" 7 3/4" 1.86 26.97 150.06 X-O 65/8 H90 41/21F BHI 73/4" 31/2" 1.58 160.64 4 HWDP 41/21F 41/21F GP 5" 3 61/2" 119.45 280.09 Jars 41/21F 41/21F WFD 63/16" 2114" 1.70 32.09 312.18 19 HWDP 4 1/2IF 41/2 IF GP 5" 3" 61/2" 566.40 878.68 BHA TOTAL LENGTH 878.58 REMARKS 8 COMMENTS DIESEL No Accidents No Spills Max gas 702 units @8570'-Back ground gas 142 units Diesel on Location day before 10,642 Held PJSM's for all jobs. Pump sweeps as needed Diesel Used Last 24 _ 2.947 __ Flow check every connection Diesel Received 0 BOP Drill, TOTAL DIESEL 7,695 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck drivers 4 13 52 PRA DSM 2 12 24 Aimm Roust. 2 12 24 PRA Safety/PM 2 1 2 Canrig Mud Loggers 2 12 24 Ml Swaco Mud Engineer 2 12 24 0 Baker Directional 2 12 24 0 Baker LWD 2 12 24 - TOTAL COUNT 42 TOTAL MAN HOURS 498 FROM TO LENGTH JOINT DESCRIPTION G/L 97' 97' Welded 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 BTC-MOD 13 3/8 68#J-55(FC @ 2346,Shoe @2390') CINGSA-DAILY DRILLING REPORT Date: 1/1/2012 Well Name CLU Storage 5 BHA it: USM Days: John Nicholson Current Depth: 8872' Location: Kenai,AK Target 8872' Cell Phone: (907)299-4306 Depth: Ftg/24hrs. 0 Field/Pool: Cannery Loop/Sterling C Rig Contractor Nabors Alaska-Rig 105 E NghM: Mike Grubb Days since Spud 10 Present Test 9 5/8"rams Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS FT/Hn 2 121/4 HCC OD505XX 7131957 8-12's 2400' 8872' 6472 11w,a-,,ore 42.4 152.60 CASING I SIZE LWEIGHT I GRADE THREAD DEPTH I CEMENT COMPANY I DATE I - Conductor: 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate Liner Tubing PUMP#1 IPUMP#2 IMUD PROPERTIES: MUD ADDITIVES: I Daily ICumulative PUMP MANE Gardner Denver PUMP MANE Gardner Denver WEIGHT 9.3 GEL(50 lb bag) 630 PUMP TYPE PZ-9 j PUMP TYPE PZ-9 FUNNEL VIS 60 S.ASH(50 lb bag) 11 LINER SIZE 6 LINER SIZE 6 R600/R300 55/39 KLA-GUARD 168 168 STOKELNGTH 9 STOKELNGTH 9 R200/R100 33/38 LOTORO/776/STEEL LUBE 330 3812 SPM 94 SPM 94 R6/R3 13/11 ASPHASOL SUPREME 180 GPS 3.17 GPS 3.17 PV 16 CONDOR 404 6 GPM 300 GPM 300 YP 23 POTASSIUM CHLORIDE 970 PSI 1850 PSI 1850 GELS 15/23/35 FLOWZAN 2 128 BTMS UP MIN 36 BTMS UP MIN 36 API FLUID LOSS 5.6 PAC 118 TOT CIR MIN 89 TOT CIR MIN 89 CAKE APH/HT 1/ CF-DESCO II 14 AVDP: AVDP: 113.2 SOLIDS 6 MYACIDE GA25 2 AVDC: AVDC: 222.8 OIL/WATER 4/90 GEL-X 5 AVDC: AVDC: SAND 0.5 CITRIC ACID/SAFE CARB 158 430 DRILL STRING&HYDRAULICS PH 8.8 RESINEX 0 STRING WT. 125 WOB 12 PEM( .02/.20 CAUSTIC SODA 22 PICK UP 175 RPM 120-130 CHLORIDES 28000 SODIUM BICARBONATE/mrtabisulfr 23 SLACK OFF 85 TFA 0.8836 CA 280 BARITE/NUT PLUG/G SEAL 37 173 MAX PULL 185 HSP 141/1.2 VOL.PIT-(BBL) 490 LIQUIDS(BELS hauled) 0 ECD 9.43 PRESS DROP 413/21.2 HOLE-(BBL) 1321 SOLIDS (BBLS hauled by AIMM) 203 4339.8 DCOD 11.2 JET VEL 222 API SCREEN 4-200 2-200.2-165 Daily Mud Cum. 898 11031.8 L ACTIVITY SUMMARY -- TIME SUMMARY _ _ Start I Finish 1 Hours I Description Detail I Daily TCumulative 6:00 11:30 5.50 POH Fi7964'Back ream 100rpm,pump 512gpm work tight RU/RD 121.00 hole F/7964'-6241'double back ream and clean up Drilling 91.50 11:30 12:30 1.00 circulate B/U at 6241,large amount of clay coal and sand Service/Repair Rig 8.00 returing over shakers. Surveys 0.00 12:30 21:30 9.00 Continue POH Back ream F/6241'-2409'10Orpm,512gpm Tripping 20.00 88.00 Work thru all over pulls Change BHA 0.00 21:30 22:30 1.00 Circ.B/U+at 2409',large amount of clay&coal and sand Casing Crew 10.50 Check flow,pump dry job,blow down surface lines Cementing Crew 3.50 22:30 23:30 1.00 POH F/2409'-870' Logging 0.00 23:30 3:30 4.00 Stand back HWDP and Jars,L/D BHA#2,(plug into Ontrak& NU/ND Test 1.50 28.00 download) DST/Core 0.00 3:30 4:00 0.50 Clear and clean floor Well Control 0.00 4:00 4:30 0.50 Change out rams to 9 5/8" WOC 1.00 4:30 5:00 0.50 Pull wear ring Safety Meetings 0.00 5:00 6:00 1.00 R/U to test rams Drilling Cement 0.00 Circ/Other 2.50 22.50 24.00 See Remarks&Coments Below TOTAL 24.00 374.00 BOTTOM HOLE ASSEMBLY QTY I ITEM I CONN DOWN 1 CONN UP I VENDOR I O.D. I I.D. I GAUGE I NECK I LENGTH (TOTAL LENGTH 12 1/4 OD505xx PDC BIT 6 5/8 reg HCC 12 112" 3" 1.34 1.34 steering head,flex,NM X-O 6 5./8 reg T2 BHI 9 1/2" 12 1/4" 8.67 37.25 62.06 Ontrak,Sab,BCPM,Stop T2 65./8 reg BHI 8 1/4" 12.125" 1.70 37.25 62.06 NM Filter Sub 6 5/8 reg 6 5/8 reg BHI 8 1/8" 2 7/8" 5.44 67.50 NM X-0 Float Sub 6 5/8 reg 6 5/8 H90 BHI 7 13/16" 2 7/8" 2.76 70.26 CSNMDP 6 5/8 H90 6 5/8 H90 BHI 6 3/4" 2 7/8" 7 1/2" 3.22 29.59 99.85 CSNMDP 6 5/8 H90 6 5/8 H90 BHI 6 3/4" 2 7/8" 7 1/4" 3.00 29.24 129.09 CSNMDP 6 5/8 H90 6 5/8 H90 BHI 6 3/4" 2 7/8" 7 3/4" 1.86 29.97 159.06 X-O 6 5/8 H90 4 1/2 IF BHI 7 3/4" 3 1/2" 1.58 160.64 4 HWDP 41/2 IF 4 1/2IF GP 5" 3 6 1/2' 11945 280.09 Jars 41/2 IF 41/2/F WFD 63/16" 21/4" 1.70 32.09 312.18 19 HWDP 41/2/F 41/2 IF GP 5" 3" 61/2" 566.40 878.68 BHA TOTAL LENGTH 878.58 REMARKS&COMMENTS DIESEL No Accidents No Spills pull test plug from CLU-1,Test CLU-4 to 5k f/15 min.(pull plug) Diesel on Location day before 7,695 Held PJSM's for all jobs. Pump sweeps as needed Diesel Used Last 24 2,958 Flow check every connection Called Jeff Jones @ AOGCC 12-31-11 @ 13:30 Diesel Received 9,530 BOP Drill, TOTAL DIESEL 14,267 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck drivers 4 13 52 PRA DSM 2 12 24 Aimm Roust. 1 13 13 PRA Safety/PM 2 1 2 FMC Hanger 2 12 24 Canrig Mud Loggers 2 12 24 Davis Lynch Cs9 Acc. - 1 12 12 MI Swaco Mud Engineer 2 12 24 Weatherford Csg Crew 4 2.5 10 Baker Directional 2 12 24 0 Baker LWD 2 12 24 - TOTAL COUNT 48 TOTAL MAN HOURS 533 FROM TO LENGTH JOINT DESCRIPTION G/L 97' 97' Welded 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 BTC-MOD 13 3/8 68#J-55(FC @ 2346,Shoe @2390') CINGSA-DAILY DRILLING REPORT Date: 1/2/2012 Well Name CLU Storage 5 BHA#: DSM Days: John Nicholson Current Depth: 8872' Location: Kenai,AK Target 11161' Cell Phone: (907)299-4306 Depth, Ftgi24hrs. 0 Field/Poor Cannery Loop/Sterling C contras tor: Nabors Alaska-Rig 105E Nights: Mike Grubb Days Since Spud 11 Present Run 9 5/8"casing @ 7820' Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER# JETS IN OUT - FEET BIT GRADE TOTAL HOURS FTWIR CASING I SIZE WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor: 20 1338 X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate Liner Tubing PUMP#1 PUMP#2 MUD PROPERTIES: MUD ADDITIVES: Daily Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT 9.4 GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 58 S.ASH(50 lb bag) 11 LINER SIZE 6 LINER SIZE 6 R600/R300 52/36 KLA-GUARD 168 STOKE LNGTH 9 STOKE LNGTH 9 R200/RI05 31/25 LOTORQ/776/STEEL LUBE 3812 SPM 80 SPM R6/R3 11/10 ASPHASOL SUPREME 180 GPS 3.17 GPS 3.17 PV 16 CONDOR 404 6 GPM 252 GPM 252 YP 20 POTASSIUM CHLORIDE 970 PSI PSI GELS 15/22/35 FLOWZAN 128 BTMS UP MIN BTMS UP MIN 0 API FLUID LOSS 5.6 PAC 118 TOT CIR MIN TOT CIR MIN 0 CAKE APH/HT 1/ CF-DESCO II 20 34 AVDP: AVDP: 0 SOLIDS 6 MYACIDE GA25 2 AVDC: AVDC: 0 OIL/WATER 4/90 GEL-X 5 AVDC AVDC: SAND 0.5 CITRIC ACID/SAFE GARB 430 DRILL STRING&HYDRAULICS PH 8.8 RESINEX 0 STRING WT. WOB Pf/Mf .03/.25 CAUSTIC SODA 22 PICK UP RPM CHLORIDES 27000 SODIUM BICARBONATEImrtabisulf 20 43 SLACK OFF TFA CA 300 BARITE/NUT PLUG I G SEAL 173 MAX PULL HSP VOL.PIT-(BBL) 500 LIQUIDS(BBLS hauled) 0 ECD PRESS DROP HOLE-(BBL) 1314 SOLIDS (BBLS hauled by AIMM) 49 4388.8 DCOD JET VEL API SCREEN 4-200 2-200.2-165 Daily Mud Cum. 89 11120.8 ACTIVITY SUMMARY L, TIME SUMMARY Start I Finish fI Hours I Description (Detail I Daily I Cumulative 6:00 7:00 1.00 Test 9 5/8"Rams 250/2500psi RU/RD 3.00 124.00 7:00 8:00 1.00 Make gage run W/9 5/8 hanger Drilling 91.50 8:00 Rig up spider,elevators and casing tongs 0/0 baiils install Service/Repair Rig 8.00 11:00 3.00 fill up tool.Rig up stabbing board&rails. Surveys 0.00 11:00 Make up(baker loc(shoe track Fill and CK floats,OK Tripping 88.00 Run 9 5/8 40#L-80 casing to 2390'&circulate B/U.Cont. Change BHA 0.00 20:00 9.00 running casing to 4010' Casing Crew 17.00 25.50 20:00 21:00 1.00 Circulate B/U @252 gpm @530 psi Cementing Crew 3.50 21:00 0:00 3.00 Continue RIH with 9 5/8"Casing F/4010'-5520' Logging 0.00 0:00 1:00 1.00 Circulate B/U @252 gpm @ 580 psi NU/ND Test 1.00 29.00 1:00 4:00 3.00 Continue RIH with 9 5/8"Casing F/5520'-7060' DST/Core 0.00 4:00 5:00 1.00 Circulate B/U @ 252 gpm @ 675 psi Well Control 0.00 5:00 6:00 1.00 Continue RIH with 9 5/8"Casing F/7060'-7820' WOC 1.00 Safety Meetings 0.00 Drilling Cement 0.00 Circ/Other 3.00 25.50 24.00 See Remarks&Coments Below TOTAL 24.00 396.00 _ _ BOTTOM HOLE ASSEMBLY QTY I ITEM I CONN DOWN I CONN UP I VENDOR I O.D. I I.D. I GAUGE I NECK I LENGTH 'TOTAL LENGTH BHA TOTAL LENGTH 878.5e I REMARKS&COMMENTS DIESEL No accidents near misses or spills.Temp-25 Diesel on Location day before 14,267 Hole slick to 7000'good returns over shakers small coals sand and silt on circulations Diesel Used Last 24 2,073 Called Jeff Jones @ AOGCC 12-31-11 @ 13:30 Diesel Received BOP Drill, TOTAL DIESEL 12,194 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck drivers 0 0 0 PRA DSM 2 12 24 Aimm Roust. 0 PRA Safety/PM 2 1 2 FMC Hanger 2 12 24 Canrig Mud Loggers 2 12 24 Davis Lynch Csq Acc. 1 12 12 MI Swaco Mud Engineer 2 12 24 Weatherford Csg Crew 4 2.5 10 Baker Directional 2 12 24 0 Baker LWD 2 12 24 - TOTAL COUNT 43 TOTAL MAN HOURS 468 FROM TO LENGTH JOINT DESCRIPTION G/L 97' 97' Welded 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 BTC-MOD 13 3/8 68#J-55(FC @ 2346,Shoe @2390') CINGSA-DAILY DRILLING REPORT Date: 1/3/2012 Well Name CLU Storage 5 BHA#: M Days: John Nicholson Current Depth: 8872' Location: Kenai,AK Target Depth: 11161' Cell Phone: (907)299-4306 Ftg/24hrs. 0 Field/Pool: Cannery Loop I Sterling C Contractor. Nabors Alaska-Rig 105 E N DSM Mike Grubb Days Since Spud 12 Present Prep to Testing BOPE Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS FT/HR CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Gondoaor 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40 L-80 BTC 8860' Slumberger 2-Jan Liner Tubing PUMP#1 PUMP#2 'MUD PROPERTIES: MUD ADDITIVES: I Daily 'Cumulative PUMP MANE Gardner Denver PUMP MANF Gardner Denver WEIGHT 9.4 GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 59 S.ASH(50 lb bag) 11 LINER SIZE 6 LINER SIZE 6 R600/R300 50/35 KLA-GUARD 168 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 28/23 LOTORQ/776/STEEL LUBE 3812 SPM SPM R6/R3 10/9 ASPHASOL SUPREME 180 GPS 3.17 GPS 3.17 PV 15 CONQOR 404 6 GPM GPM 0 YP 20 POTASSIUM CHLORIDE 970 PSI PSI GELS 9/16/22 FLOWZAN 128 BTMS UP MIN BTMS UP MIN 0 API FLUID LOSS 5.8 PAC 118 TOT CIR MIN TOT CIR MIN 0 CAKE APH/HT 1/ CF-DESCO II/SAPP 35 69 AVDP. AVDP: 0 SOLIDS 6 MYACIDE GA25 2 AVDC: AVDC: 0 OIL/WATER 4/90 GEL-X 5 AVDC: AVDC: SAND 0.5 CITRIC ACID/SAFE CARB 20 450 DRILL STRING&HYDRAULICS PH 8.8 RESINEX 0 STRING WT. WOB Pf/Mf .03/.25 CAUSTIC SODA 22 PICK UP RPM CHLORIDES 27000 SODIUM BICARBONATE/mnabisulrr 20 63 SLACK OFF TFA CA 40 BARITE/NUT PLUG/G SEAL 150 323 MAX PULL HSP VOL.PIT-(BBL) 342 LIQUIDS(BBLS hauled) 0 ECD PRESS DROP HOLE-(BBL) 674 SOLIDS (BBLS hauled by AIMM) 746.9 5135.7 DCOD JET VEL API SCREEN 4-200 2-200.2-165 Daily Mud Cum. 971.9 12092.7 ACTIVITY SUMMARY I TIME SUMMARY Start f Finish I Hours I Description !Detail I Daily [Cumulative 6:00 Continue RIH with 9 5/8"Casing F!7820'-8240'Circulate RU/RD 8.00 132.00 and wash down to 8280'continue running 9 5/8 casing to Drilling 86.00 8800'Wash last 60'to land out in well head.No problems Service/Repair Rig 8.00 8:00 2.00 hole slick Surveys 0.00 8:00 Circulate 5bbl per min 760psi,Rig down casing tools.And Tripping 2.00 90.00 10:30 2.50 fill up tool.Install cement head and lines Change BHA 0.00 10:30 12:30 2.00 Circulate B/U at 4bbis per min 510 psi Casing Crew 27.50 12:30 PJSM,pump 5bbi water test line 1000-4400psi,pump 40bbls Cementing Crew 9.50 13.00 10.2 mudpush Il,pump 290bb1 12ppg lead cmt(10%excess), Logging 0.00 45bbls 14ppg FIexSTONE tail,drop plug,chase W/5bbl water NU/ND Test 2.50 37.00 displace W/660.15 bbls mud,bump plug,check floats,open DST/Core 0.00 DV @2400psi(Est 90bbl cement return to surface)2nd stage Well Control 0.00 5bbl water,40bbl 10.2 mudpush 212bb1 Cmt(10%excess)5b WOC 1.00 water,displace 266b,bump plug Check for flow none,80b cmt Safety Meetings 0.00 19:30 7.00 estimate back to surface.Cement in place 19:30 Drilling Cement 0.00 19:30 0:30 5.00 Flush lines,R/D csg&cement equip.,install pack off&test Circ/Other 2.00 25.50 00:30 06:00 5.50 C/O elevators&bails,clear floor C/O rams V4.5"x7", TOTAL 24.00 420.00 BOTTOM HOLE ASSEMBLY ITEM QTY I -. 'CONN DOWN CONN UP I VENDOR .. O.D. I LD. I GAUGE t_NECK I LENGTH__.TOTAL LENGTH 1 1 BHA TOTAL LENGTH REMARKS&COMMENTS DIESEL No accidents near misses or spills. Test pack off T/3000psi for 15 min. Diesel on Location day before 12,194 Hole slick to 8860'good returns over shakers small coals sand and silt on circulations Diesel Used Last 24 2.269 Called Jeff Jones @ AOGCC 12-31-11 @ 13:30 Diesel Received Spill Drill, 1st stage cement 97 strokes over to bump plug(7.1 bbls over shoe track) TOTAL DIESEL 9,925 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck dnvers 4 13 52 PRA DSM 2 12 24 Aimm Roust. 2 12 24 PRA Safety/PM 2 1 2 FMC Hanger 1 12 12 Canrig Mud Loggers 2 12 24 Davis Lynch Csq Acc. 1 12 12 MI Swaco Mud Engineer 2 12 24 Weatherford Csg Crew 4 2.5 10 Baker Directional 2 12 24 Slumberger cement crew 4 12 48 Baker LWD 2 12 24 - TOTAL COUNT 52 TOTAL MAN HOURS 580 FROM I TO I LENGTH I JOINT I DESCRIPTION G/L 97' 97' Welded 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 Bi ) 13 3/8 68#J-55(FC @ 2346,Shoe @2390') Intermediate FROM TO LENGTH Rh., DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-by 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder CINGSA-DAILY DRILLING REPORT Date: 1/4/2012 Well Name CLU Storage 5 BHA#: 3 M Days: John Nicholson Current Depth: 8872' Location: Kenai,AK Target 11161' Cell Phone: (907) 299-4306 Depth: Ftg/24hrs. 0 Field/Pool: Cannery Loop/Sterling C onRi for Nabors Alaska-Rig 105 E Nights Mike Grubb Days Since Spud 13 Present Check for blockage Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS ruuu 3 8 1/2 HCC HCR 503ZX 7114328 3-13 3-14 8872 CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor: 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40 L-80 BTC 8860' Slumberger 2-Jan Liner Tubing PUMP#1 PUMP#2 IMUD PROPERTIES: IMUD ADDITIVES: 1 Daily iCumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT 9.4 GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 70 S.ASH(50 lb bag) 11 LINER SIZE 6 LINER SIZE 6 R800/R300 54/38 KLA-GUARD 168 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 33/25 LOTORO/776/STEELLUBE 3812 SPM SPM R6/R3 11/10 ASPHASOL SUPREME 180 GPS 3.17 GPS 3.17 PV 16 CONDOR 404 6 GPM GPM 0 YP 22 POTASSIUM CHLORIDE 970 PSI PSI GELS 14/18/20 FLOWZAN 128 BTMS UP MIN BTMS UP MIN 0 API FLUID LOSS 6.2 PAC 118 TOT CIR MIN TOT CIR MIN 0 CAKE APHMT 1/ CF-DESCO II/SAPP 69 AVDP: AVDP: 0 SOLIDS 6 MYACIDE GA25 2 AVDC: AVDC: 0 OIL/WATER 3/91 GEL-X 5 AVDC: AVDC: SAND .25 CITRIC ACID/SAFE GARB 450 DRILL STRING&HYDRAULICS PH 8.3 RESINEX 0 STRING WT. WOB Pf/Mf .00/.20 CAUSTIC SODA 22 PICK UP RPM CHLORIDES 25000 SODIUM BICARBONATE/mrtabisulfr 63 SLACK OFF TFA CA 400 BARITE/NUT PLUG I G SEAL 323 MAX PULL HSP VOL.PIT-(BBL) 702 LIQUIDS(BBLS hauled) 0 ECD PRESS DROP HOLE-(BBL) 673 SOLIDS (BBLS hauled by AIMM) 50 5185 DCOD JET VEL API SCREEN 4-200 2-200.2-165 Daily Mud Cum. 50 12142 ACTIVITY SUMMARY TIME SUMMARY Start I Finish I Hours I Description Detail I Daily I Cumulative 6:00 Test BOP and all related components 250/2500psi 5min RU/RD 132.00 .,A. Test 4 1/2 X 7"var rams using 7"casing test joint.Test gas Drilling 86.00 % and PVT/Flow alarms.Perform accumulator drawdown test. Service/Repair Rig 5.50 13.50 replace bind ram rubbers/packing element.RE test upper Surveys 0.00 14:00 8.00 IBOP/Failed. Tripping 6.50 96.50 14:00 Replace IBOP and flush out mud in air lines and air volume Change BHA 0.00 Tanks.Down time repair rig.Change out saver sub and Casing Crew 27.50 19:30 5.50 grabber dies Cementing Crew 13.00 19:30 20:30 1.00 Test upper and lower IBOP 250/2500psi 5 min,R/D Equip Logging 0.00 20:30 0:00 3.50 P/U make up BHA#3,scribe tools,Plug into MWD NU/ND Test 10.00 47.00 0:00 3:00 3.00 RIH with BHA#3,Load sources DST/Core 0.00 3:00 4:00 1.00 RIH with HWDP and jars F/234'-952' Well Control 0.00 4:00 4:30 0.50 Attempt to Surface test MWD,pressured up mud lines,check WOC 1.00 and blow thru surface lines. Safety Meetings 0.00 4:30 6:00 1.50 Checking as POH W/HWDP and JARS,attempt to pump thru Drilling Cement 0.00 BHA @ NMCDSP(could not pump),Pull up and check filter Circ/Other 2.00 27.50 24.00 sub TOTAL 24.00 444.00 BOTTOM HOLE ASSEMBLY QTY ITEM CONN DOWN CONN UP VENDOR O.D. I.D. GAUGE NECK LENGTH TOTAL LENGTH 1 Motor-Steerable I.sdeg 4 1/2 reg 4 1/2 h-90 BHI 6 3/4 8.38 1.60 23.58 24.65 1 N M Flex Pony Collar 4 1/2 h-90 4 1/2 h-90 BHI 6 3/4 2 13/16 2.23 9.20 33.85 1 N M String Stabilizer 4 1/2 h-90 4 1/2 h-90 BHI 6 3/16 2 13/16 8 3/8 2.32 5.05 38.90 1 NM X-over 4 1/2 h-90 4 1/2 If BHI 6 3/4 2 3/4 2.84 41.74 1 Stop/Ontrac/Stab/Bcpm 4 1/2 if T2B BHI 7 8 3/8 1.45 33.15 74.89 1 Ord/Ccn T2B T2B BHI 6 3/4 2 1/2 8 3/8 2.50 16.28 91.17 1 Mag Trac/Stop Sub T2B 4 1/2 ills BHI 7 1.23/43 8 3/8 31.99 123.16 1 N M Fiher Sub 4 1/2 if 4 1/2 ifb BHI 6 7./8 2 13/16 5.27 128.43 1 N M X-Over 4 1/2 if 4 1/2 h-90 BHI 6 3/4 2 13/16 2.03 130.46 1 NMCSDP 4 1/2 h-90 4 1/2 h-90 BHI 5 2 7/8 6 5/16 1.97 29.26 159.72 1 NMCSDP 4 1/2 h-90 4 1/2 h-90 BHI 5 2 13/16 6 3/8 2.20 30.15 189.87 1 NMCSDP 41/2 h-90 41/2 h-90 BHI 5 2 7/8 6 1/8 2.71 30.00 219.87 1 X-over 41/2 h-90 4 1/2if BHI 6 3/8 2 7/8 1.70 221.57 1 Well Commander 41/2if 4 112if MI swaco 6 7/8 3 1/2 2.46 13.20 234.77 4 4x HWDP 4 1/2if 4 112if NAD 5 3 119.45 354.22 1 Jars 4 1/2if 4 1/2if WFD 6 3/16 2 1/4 6 1/2 32.09 386.31 19 5"HWDP 4 1/2if 41/21 NAD 5 3 BHA TOTAL LENGTH 952.71 REMARKS&COMMENTS DIESEL No accidents near misses or spills. Diesel on Location day before 9.925 Next BOP Test 1-17-12 Diesel Used Last 24 1,931 Called Jeff Jones @ AOGCC 12-31-11 @ 13:30,Witness waived no call back Diesel Received BOP Drill, TOTAL DIESEL 7,994 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck drivers 2 13 26 PRA DSM 2 12 24 Aimm Roust. 1 12 12 PRA Safety/PM 2 1 2 Canriq Mud Loggers 2 12 24 MI Swaco Mud Engineer 2 12 24 Baker Directional 2 12 24 Baker LWD 3 12 36 - TOTAL COUNT 40 TOTAL MAN HOURS 472 FROM I TO I LENGTH I JOINT I DESCRIPTION G/L 97' 97' WO' -' 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 BT 13 3/8 68#J-55(FC @ 2346,Shoe(&2390') Intermediate FROM TO LENGTH JOINTS DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 _ 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-hy 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder CINGSA-DAILY DRILLING REPORT Date: 1/5/2012 Well Name CLU Storage 5 BHA#: 3 M Days: John Nicholson Current Depth: 8996' Location: Kenai,AK Target 11161' Cell Phone: (907) 299-4306 Depth Ftg/24hrs. 124' Field/Pool: Cannery Loop/Sterling C Contractor:ig Nabors Alaska-Rig 105 E DSM Mike Grubb Days Since Spud 14 Present Drilling 8 1/2"hole @8996' Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER it JETS IN OUT FEET BIT GRADE TOTAL HOURS FT/9P 3 8 1/2 HCC HCR 503ZX 7114328 3-13 3-14 8872 124 1.9 65' CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor 20 133# X-56 Welded 97' N/A July - Surfaoe: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40 L-80 BTC 8860' Slumberger 2-Jan Line Tubing PUMP#1 !PUMP#2 IMUD PROPERTIES: IMUD ADDITIVES: I Daily Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT 9.2 GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 62 S.ASH(50 lb bag) 11 LINER SIZE 6 LINER SIZE 6 R600/R300 49/33 KLA-GUARD 168 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 27/22 LOTORQ/776/STEEL LUBE 3812 SPM 63 SPM 63 R6/R3 9/7 ASPHASOL SUPREME 180 GPS 3.17 GPS 3.17 PV 16 CONDOR404 6 GPM 355 GPM 355 YP 17 POTASSIUM CHLORIDE 970 PSI 1500 PSI 1500 GELS 8/12/16 FLOWZAN 128 BTMS UP MIN 53 BTMS UP MIN 53 API FLUID LOSS 6.6 PAC 118 TOT CIR MIN 138 TOT CIR MIN 138 CAKE APH/HT 2/ CF-DESCO II/SAPP 69 AVDP: 136.00 AVDP: 136 SOLIDS 7 MYACIDE GA25 2 AVDC: '64.00 AVDC: 164 OIL/WATER 3/91 GEL-X 5 AVDC: AVDC: SAND .25 CITRIC ACID/SAFE CARB 450 DRILL STRING&HYDRAULICS PH 9.1 RESINEX 0 STRING WT. v WOB 10 Pf/Mf .15/1.2 CAUSTIC SODA 22 PICK UP RPM 40 CHLORIDES 26000 SODIUM BICARBONATEfmnabisulfi 63 SLACK OFF TFA 0.8399 CA 240 BARITE/NUT PLUG/G SEAL 323 MAX PULL HSP 151/11 VOL.PIT-(BBL) 596 LIQUIDS(BBLS hauled) 0 ECD 9.43 PRESS DROP 5 HOLE-(BBL) 567 SOLIDS (BBLS hauled by AIMM) 118.5 5304.2 DCOD JET VEL 31/0.6 API SCREEN 4-200 2-200.2-165 Daily Mud Cum. 118.5 12261.2 ACTIVITY SUMMARY TIME SUMMARY Start I Finish I-HOD rs I Description Detail I Daily I Cumulative 6:00 Check filter sub,un load sources,Stand back MWD and RU/RD 132.00 mag tools.POH with motor,Break out bit found large rag Drilling 3.00 89.00 in the bit.Clean out CK jets.Make up bit rih.Scribe motor Service/Repair Rig 0.50 14.00 10:00 4.00 &MWD.Load sources.RIH Pulse test MWD.and mag frac Surveys 0.00 10:00 11:30 1.50 P/U Drift(3.132)drillpipe from pipe shed 22jts RIH.T/1590' Tripping 13.50 110.00 11:30 12:00 0.50 Service and lube rig Change BHA 0.00 12:00 13:30 1.50 P/U Drift(3.132)drillpipe from pipe shed 41jts RIH T/3020' Casing Crew 27.50 13:30 14:30 1.00 Cont.RIH with stands F/3020'-3340'wash T/3510'tag DV Cementing Crew 13.00 14:30 16:00 1.50 Drill out DV collar @3510' - _ Logging 0.00 16:00 17:00 1.00 Circulate and cleanup shakers NU/ND Test 1.50 48.50 17:00 18:00 1.00 R/U and test 9 5/8"casing T/2500psi for 3omin.,R/D equip. DST/Core 0.00 18:00 _ 19:00 1.00 Wash down F/3510'-3720'checking for stringers,blow down Well Control 0.00 19:00 23:00 4.00 Cont.RIH F/3720'-8613'wash to 8772',tag Float collar WOC 1.00 23:00 1:00 2.00 Drill Shoe track F/8772'-8860',Cleanout cement to 8872' Safety Meetings 0.00 1:00 2:30 1.50 Drill 8 1/2"hole F8872'-8892',Circulate botto --- Drilli 1�q Cement 3 50 3.50 2:30 3:00 0.50 Preform FIT mud wt 9.2 x 4918TVD x14 psi=l5ppg EMW Circ/Ot(ter 2.0C 29.50 03:00 06:00 3.00 Drill F/8892'-8996'ART-1.5,AST-.4,60 rpm,400gpm,1500p TOT 24.00 468.00 BOTTOM HOLE ASSEMBLY--- QTY I ITEM I CONN DOWN[ CONN UP ] _ VENDOR O.D. I I.D. L GAUGE d _NECK I LENGTH TOTAL LENGTH 1 Motor-Steerable 1 Odeg 41/2 reg 4 1/2 h-90 BHI 6 3/4 8.38 1.60 23.58 24.65 1 N M Flex Pony Collar 4 1/2 h-90 4 1/2 h-90 BHI 6 3/4 2 13/16 2.23 9.20 33.85 1 N M String Stabilizer 4 1/2 h-90 4 1/2 h-90 BHI 6 3/16 2 13/16 8 3/8 2.32 5.05 38.90 I NM X-over 4 1/2 h-90 4 1/2 if BHI 6 3/4 2 3/4 2.84 41.74 _ 1 Stop/Ontrac/Stab/Bcpm 41/21 T2B BHI 7 8 3/8 145 33.15 74.89 1 Ord/Ccn T2B T2B BHI 6 3/4 2 1/2 8 3/8 2.50 16.28 91.17 1 Mag Too/Stop Sub T2B 4 1/2 ifb BHI 7 1.23/43 8 3/8 31.99 123.16 1 N M Fitter Sub 4 1/2 if 4 1/2 ifb BHI 6 7./8 2 13/16 527 128.43 1 N M X-Over 4 1/2 if 4 1/2 h-90 BHI 6 3/4 2 13/16 2.03 130.46 1 NMCSDP 4 1/2 h-90 4 1/2 h-90 BHI 5 2 7/8 6 5/16 1.97 29.26 159.72 1 NMCSDP 4 1/2 h-90 4 1/2 h-90 BHI 5 2 13/16 6 3/8 220 30.15 189.87 1 NMCSDP 41/2 5-90 4 1/2 5-90 BHI 5 2 7/8 6 1/8 2.71 30.00 219.87 1 X-over 4 1/2 h-90 4 1/24 BHI 6 3/8 2 7/8 1.70 221.57 1 Well Commander 4 1/2if 41/210 MI swaco 6 7/8 3 1/2 2.46 13.20 234.77 4 4x HWDP 4 1/2if 4 1/2if NAD 5 3 119.45 354.22 1 Jars 41/24 4 1/2if WFD 6 3/16 2 1/4 6 1/2 32.09 386.31 19 5"HWDP 4 1/2if 4 1/24 NAD 5 3 BHA TOTAL LENGTH 952.71 REMARKS&COMMENTS DIESEL No accidents near misses or spills. Firm Cement in shoe,soft cement below shoe Diesel on Location day before 7,994 Next BOP Test 1-17-12 Diesel Used Last 24 2,100 FIT Test=EMW 15PPG Diesel Received 9,452 BOP Drill, TOTAL DIESEL 15,346 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck drivers 2 13 26 PRA DSM 2 12 24 Aimm Roust. 1 12 12 PRA Safety/PM 2 1 2 PRA Geologist 1 12 12 Canrig Mud Loggers 2 12 24 MI Swaco Mud Engineer 2 12 24 Baker Directional 2 12 24 Baker LWD 3 12 36 - TOTAL COUNT 41 TOTAL MAN HOURS 484 FROM I TO I LENGTH I JOINT I DESCRIPTION G/L 97' 97' W,'' ' 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 Bl i 13 3/8 68#J-55(FC @ 2346,Shoe @2390') Intermediate FROM TO LENGTH JOINTS DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-by 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder CINGSA-DAILY DRILLING REPORT Date: 1/6/2012 Well Name CLU Storage 5 BHA#: 3 v Days: John Nicholson Current Depth. 10048' Location: Kenai,AK Target 11161' Cell Phone: (907) 299-4306 Depth: , Ftg/24hrs. 1052' Field/Pool: Cannery Loop/Sterling C Rigcontractor Nabors Alaska-Rig 105 E NghM: Mike Grubb Days since spud 15 Present Back reaming to shoe Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SERB JETS IN OUT FEET BIT GRADE TOTAL HOURS FT/. 3 8 1/2 HCC HCR 503ZX 7114328 3-13 3-14 8872 1176' 17.5 67' CASINGSIZE I WEIGHT I GRADE I THREAD J DEPTH I CEMENT COMPANY I DATE I - Conductor: 20 1338 X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40 L-80 BTC 8860' Slumberger 2-Jan Liner Tubing PUMP#1 PUMP#2 MUD PROPERTIES: IMUD ADDITIVES: I Daily Cumulative PUMP MANE Gardner Denver PUMP MANF Gardner Denver WEIGHT 9.2 GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 64 S.ASH(50 lb bag) 7 18 LINER SIZE 6 LINER SIZE 6 R600/R300 58/44 KLA-GUARD 168 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 36/31 LOTORO/776/STEEL LUBE 3812 SPM 63 SPM 63 R6/R3 13/11 ASPHASOL SUPREME 180 GPS 3.17 GPS 3.17 PV 14 CONDOR 404 2 8 GPM 355 GPM 355 YP 30 POTASSIUM CHLORIDE 50 1020 PSI 1600 PSI 1600 GELS 13/17/21 FLOWZAN 128 BTMS UP MIN 52 BTMS UP MIN 52 API FLUID LOSS 7.1 PAC 118 TOT CIR MIN 140 TOT CIR MIN 140 CAKE APH/HT 2/ CF-DESCO II/SAPP 7 76 AVDP: AVDP: 136 SOLIDS 6 MYACIDE GA25 2 AVDC: AVDC: 207.5153 OIL/WATER 3/91 GEL-X 2 7 AVDC: AVDC: SAND .3 CITRIC ACID/SAFE CARB/mix It 120 570 DRILL STRING 8 HYDRAULICS PH 8.6 RESINEX 10 10 STRING WT. 115 WOB 14 Pf/Mf .10/1.0 CAUSTIC SODA 22 PICKUP 140 RPM 65 CHLORIDES 25000 SODIUM BICARBONATE/mrtabIsoIti 5 68 SLACK OFF 85 TFA 0.8399 CA 80 BARITE/NUT PLUG/G SEAL 43 366 MAX PULL 145 HSP 193/14.1 VOL.PIT-(BBL) 658 LIQUIDS(BBLS hauled) 0 ECD 10.35 PRESS DROP 9 HOLE-(BBL) 672 SOLIDS (BBLS hauled by AIMM) 163.9 5399.1 DCOD JET VEL 45/0.8 API SCREEN 4-200 2-200.2-165 Daily Mud Cum. 409.9 12602.1 ACTIVITY SUMMARY TIME SUMMARY • Start I Finish r Hours I Description Detail Daily I Cumulative 6:00 12:00 6.00 Drill 8 1/2hole section F/-8996-9284 60 rpm,400gpm, RU/RD 132.00 TQ 8-9,UP 145,DN 85RT-115,61)wt 5-7,1800p Art=3.2 Drilling 21.50 110.50 AST=1.3 Controll drill 80feet per hr.Added steel lube Service/Repair Rig 14.00 torque decreased F 17500 down to 9000 fp/lbs max gas385 Surveys 0.00 12:00 18:00 6.00 Drill 8 1/2hole section F/-9284'9595'-60 rpm,400gpm, Tripping 1.50 111.50 TQ 8-9,UP 145,DN 87R-115,bit wt 12,1800p Art=3.7 Ast=.6 Change BHA 0.00 18:00 0:00 6.00 Drill 8 1/2hole section F/-9595-'9857-65 rpm,400gpm, Casing Crew 27.50 TQ 9-12,UP 140,DN 85,R-110,bit wt 12,1800pArt=2.9Ast=1 Cementing Crew 13.00 0:00 03:30 3.50 Drill 8 1/2hole section F/-9857-'10048'-65 rpm,400gpm, Logging 0.00 TQ 9-13,UP 140,DN 85,R-110,bit wt 12,1800pArt=2.2Ast=.7 NU/ND Test 48.50 3:30 4:30 1.00 Circulate bottoms up,Check flow,400gpm,65rpm,1750psi DST/Core 0.00 4:30 6:00 1.50 POH(wiper trip)Backream F/10048.-9200'40rpm 300gpm Well Control 0.00 WOC 1.00 Safety Meetings 0.00 Drilling Cement 3.50 Circ/Other 1.00 30.50 24.00 TOTAL 24.00 492.00 BOTTOM HOLE ASSEMBLY QTY , ITEM 'CONN DOWN CONN UP VENDOR O.D. I.D. GAUGE NECK LENGTH TOTAL LENGTH 1 Motor-Steerable 1.Sdeg 4 1/2 reg 41/2 h-90 BHI 6 3/4 8.38 1.60 23.58 24.65 1 N M Flex Pony Collar 41/2 h-90 41/2 h-90 BHI 6 3/4 2 13/16 2.23 9.20 33.85 1 N M String Stabilizer 41/2 h-90 41/2 h-90 BHI 6 3/16 2 13/16 8 3/8 2.32 5.05 38.90 / NM Xover 4 1/2 h-90 4 1/2 if BHI 6 3/4 23/4 2.84 41.74 / Stop/Ontrac/Stab/Bcpm 4 1/2 if T2B BHI 7 8 3/8 1.45 33.15 74.89 1 Ord/Con 726 728 BHI 6 3/4 2 1/2 8 3/8 2.50 16.28 91.17 1 Mag Trac/Stop Sub T2B 4 1/2 ifb BHI 7 1.23/43 8 3/8 31.99 123.16 1 N M Finer Sub 4 1/2 if 4 1/2 ilb BHI 6 7/8 2 13/16 5.27 128.43 1 N M X-Over 4 1/2 if 4 1/2 h-90 BHI 6 3/4 2 13116 2.03 130.46 1 NMCSDP _ 4 1/2 h-90 4 1/2 h-90 BHI 5 2 7/8 6 5/16 1.97 29.26 159.72 1 NMCSDP 4 1/2 h-90 4 1/2 h-90 BHI 5 2 13/16 6 3/8 2.20 30.15 189.87 1 NMCSDP 4 1/2 h-90 4 112 h-90 SRI 5 2 7/8 6 1/8 2.71 30.00 219.87 1 Xover 4 1/2 h-90 4 1/2if BHI 6 3/8 2 7/8 1.70 221.57 1 Well Commander _ 41/2if 41/2i( Ml swaco 6 7/8 3 1/2 2.46 13.20 234.77 4 4x HWDP 41/211 4 1/2if NAD 5 3 119.45 354.22 1 Jars 41/24 41/211 WFD 6 3/16 2 1/4 6 1/2 32.09 386.31 19 5"HWDP 4 1/2if 4//2if NAD 5 3 BHA TOTAL LENGTH 952.71 REMARKS&COMMENTS DIESEL No accidents near misses or spills. Controlled drilling @ 80FPH for logging data Diesel on Location day before 15,346 Next BOP Test 1-17-12 mud products used were adjusted to inventory Diesel Used Last 24 2,890 Flow check each connection Diesel Received BOP Drill, TOTAL DIESEL 12,456 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew , 24 12.5 300 Aimm Vac truck drivers 2 13 26 PRA DSM 2 12 24 Aimm Roust. 2 13 26 PRA Safety/PM 2 1 2 PRA Geologist 1 12 12 Canrig Mud Loggers 2 12 24 MI Swaco Mud Engineer 2 12 24 Baker Directional 2 12 24 Baker LWD 3 12 36 - TOTAL COUNT 42 TOTAL MAN HOURS 498 FROM I TO I LENGTH I JOINT I DESCRIPTION G/L 97' 97' Wv' ' 20"133#X-56 Welded Conductor Pipe _ RKB 2390' 2390 BT 13 3/8 68#J-55(FC @ 2346,Shoe @2390') Intermediate FROM TO LENGTH JOINTS DESCRIPTION ___ 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 _ 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-hy 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder CINGSA-DAILY DRILLING REPORT Date: 1/7/2012 Well Name CLU Storage 5 BHA#: 3 M Days: John Nicholson Current Depth: 10718' Location: Kenai,AK Target Depth: 11161' Cell Phone: (907) 299-4306 Ftg/24hrs. 670' Field/Pool: Cannery Loop/Sterling C ContractorRNabors Alaska-Rig 105 E Ni Mike Grubb Days Since Spud 16 Present Drilling from 10718' Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT 9 SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS 71e 3 8 1/2 HCC HCR 503ZX, 7114328 3-13 3-14 8872 1846 28.2 65.50 CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor: 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40 L-80 BTC 8860' Slumberger 2-Jan Liner Tubing PUMP#1 IPUMP#2 IMUD PROPERTIES: IMUD ADDITIVES: _ Daily Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT 9.2 GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 54 S.ASH(50 lb bag) 9 27 LINER SIZE 6 LINER SIZE 6 R600/R300 50/36 KLA-GUARD 168 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 30/22 LOTORQ/776/STEEL LUBE 168 3980 SPM 55 SPM 55 R6/R3 9/7 ASPHASOL SUPREME 180 GPS 3.17 GPS 3.17 PV 14 CONQOR404 8 GPM 355 GPM 355 YP 22 POTASSIUM CHLORIDE 1020 PSI 1400 PSI 1400 GELS 10/12/19 FLOWZAN 128 BTMS UP MIN 62 BTMS UP MIN 62 API FLUID LOSS 5.6 PAC 118 TOT CIR MIN 140 TOT CIR MIN 140 CAKE APH/HT 2/ CF-DESCO II/SAPP 8 84 AVDP: 136.0 AVDP: 136 SOLIDS 7 MYACIDE GA25 2 AVDC: 207.5• AVDC: 207.5153 OIL/WATER 3/91 GEL-X 7 AVDC: AVDC: SAND .3 CITRIC ACID/SAFE CARE/mix II 197 767 DRILL STRING&HYDRAULICS PH 8 RESINEX 14 24 STRING WT. 107 WOB 14 Pf/Mf .05/.9 CAUSTIC SODA 3 25 PICK UP 137 RPM 60 CHLORIDES 26000 SODIUM BICARBONATE/mrtabisulrr 10 78 SLACK OFF 87 TFA 0.8399 CA 320 BARITE/NUT PLUG/G SEAL 19 419 MAX PULL 140 HSP 152/10.9 VOL.PIT-(BBL) 499 LIQUIDS 0 ECD 10.23 PRESS DROP 5 HOLE-(BBL) 692 SOLIDS (BBLS hauled by AIMM) 259 5658 DCOD JET VEL 136 API SCREEN 4-200 2-200.2-165 Dally Mud Cum. 687 13323 ACTIVITY SUMMARYTIME SUMMARY Start I Finish I Hours I Description Detail I Daily I Cumulative 6:00 POH(wiper trip)Backream F/9200'-8860'40rpm,300gpm RU/RD 132.00 Hole started packing off at 9150'Started loosing fluid Drilling 17.00 127.50 Reduce pump rate F/330gpm to 200gpm.Pull to 9050' Service/Repair Rig 1.50 15.50 spot 40bbl 45ppb Icm pill in pipe then RIH to 9150 spot pill Surveys 0.00 8:00 2.00 Continue POH 8814'50rpm 200gpm,losses stoped. Tripping 5.00 116.50 8:00 9:00 1.00 Service ng/let pill soak Change BHA 0.00 9:00 RIH F/8804'-9953',wash F/9953'-10048',Pump 60bbl 40# Casing Crew 27.50 11:30 2.50 LCM pill Cementing Crew 13.00 11:30 17:00 5.50 Drill 8 1/2"hole section F/10048'-10230'60rpm,336 gpm Logging 0.00 tq-9,up140,dn88,rt115, NU/ND Test 48.50 17:00 18:00 1.00 Repair Top Drive,replace com.cable DST/Core 0.00 18:00 18:30 0.50 R/D Circulating head and blow down lines Well Control 0.00 18:30 Drill 8 1/2"hole section F/10230'-10406'60rpm,336 gpm WOC 1.00 0:00 5.50 tq-8-9,up-138,do-86,rt-110,ART-2.2,AST-1.1 Safety Meetings 0.00 0:00 Drill 8 1/2"hole section F/10406.-10718'60rpm,350 gpm Drilling Cement 3.50 6:00 6.00 tq-8-9,up-137,do-87,rt107,ART-3.9,AST-0.5 Circ/Other 0.50 31.00 24.00 TOTAL 24.00 516.00 BOTTOM HOLE ASSEMBLY OTY ITEM CONN DOWN CONN UP VENDOR O.D. I.D. GAUGE NECK LENGTH TOTAL LENGTH 1 Motor-Steerable 1.0deg 4 1/2 reg 4 1/2 h-90 BHI 6 3/4 8.38 1.60 23.58 24.65 1 N M Flex Pony Collar 4 1/2 h-90 4 1/2 h-90 BHI 6 3/4 2 13/16 223 9.20 33.85 1 N M String Stabilizer 4 1/2 h-90 4 1/2 h-90 BHI 6 3/16 2 13/16 8 3/8 2.32 5.05 38.90 1 NM Xover 4 1/2 h-90 4 1/2 if BHI 6 3/4 2 3/4 2.84 41.74 1 Stop/Ontrac/Stab/Bcpm 4 1/2 if T2B BHI 7 8 3/8 1.45 33.15 74.89 1 Ord/Ccn T2B T2B BHI 6 3/4 2 1/2 8 3/8 250 1628 91.17 1 Mag Trac/Stop Sub T2B 4 1/2 ifb BHI 7 1.23/43 8 3/8 31.99 123.16 1 N M Filter Sub 4 1/2 if 4 1/2 ifb BHI 6 7./8 2 13/16 5.27 128.43 1 N M X-Over 4 1/2 if 4 1/2 h-90 BHI 6 3/4 2 13/16 2.03 130.46 1 NMCSDP 4 1/2 h-90 4 1/2 h-90 BHI 5 2 7/8 6 5/16 1.97 29.26 159.72 1 NMCSDP 4 1/2 h-90 4 1/2 h-90 BHI 5 2 13/16 6 3/8 2.20 30.15 189.87 1 NMCSDP 4 1/2 h-90 4 1/2 h-90 BHI 5 2 7/8 6 1/8 2.71 30.00 219.87 1 X-over 4 1/2 h-90 4 1/2it SRI 6 3/8 2 7/8 1.70 221.57 1 Well Commander 4 1/2if 4 1/2it MI swaco 6 7/8 3 1/2 2.46 13.20 234.77 4 4x HWDP 41/211 4 1/2it NAD 5 3 11945 354.22 1 Jars 4 1/2if 41/21( WFD 6 3/16 2 1/4 6 1/2 32.09 386.31 19 5"HWDP 4 1/2if 4 1/2it NAD 5 3 BHA TOTAL LENGTH 952.71 REMARKS&COMMENTS DIESEL No accidents near misses or spills. Controlled drilling @ 80FPH for logging data Diesel on Location day before 12,456 Next BOP Test 1-17-12 Losses to hole approx.200 bbls Diesel Used Last 24 2,282 Flow check each connection max gas 121 units©10128' Diesel Received BOP Drill, Slow pump rate 5030'TVD/10240'MD=#1MP-400psi @ 2bpm TOTAL DIESEL 10,174 PERSONNEL ON LOCATION - COMPANY NOTE I COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck drivers 2 13 26 PRA DSM 2 12 24 Aimm Roust. 1 13 13 PRA Safety/PM 2 1 2 PRA Geologist 1 12 12 Canriq Mud Loggers 2 12 24 MI Swaco Mud Engineer 2 12 24 Baker Directional 2 12 24 Baker LWD 3 12 36 - TOTAL COUNT 41 TOTAL MAN HOURS 485 FROM I TO I LENGTH I JOINT I DESCRIPTION G/L 97' 97' Wr'' '_20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 BT 13 3/8 68#J-55(FC X2346,Shoe @2390') Intermediate FROM TO LENGTH JOINTS DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-hy 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder CINGSA-DAILY DRILLING REPORT Date: 11812012 Well Name CLU Storage 5 BHA if: 3 >M Days: John Nicholson Current Depth. 11101 TD Location: Kenai,AK Target Depth: 11161' Cell Phone: (907) 299-4306 Rig Ftg/zahrs. 383 Fiero/Poor Cannery Loop 1 Sterling C contractor. Nabors Alaska-Rig 105 E NightstsM : Mike Grubb Days Since spud 17 Present Prep to back ream out of hole Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS 710 3 8 1/2 HCC HCR 503ZX 7114328 3-13 3-14 8872 11101 2229 33.8 66.00 CASING I SIZE ILWEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor: 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40 L-80 BTC 8860' Slumberger 2-Jan Liner Tubing PUMP#1 IpUMP#2 IMUD PROPERTIES: IMUD ADDITIVES: I Daily Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT 9.2 GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 54 S.ASH(50 lb bag) 27 LINER SIZE 6 LINER SIZE 6 R600/R300 49/36 KLA-GUARD 168 STOKE LNGTH 9 STOKE LNGTH 9 R200IR100 30/20 LOTORQ/7761STEEL LUBE 168 4148 SPM 53 SPM 53 R6/R3 8/6 ASPHASOL SUPREME 180 GPS 3.17 GPS 3.17 PV 13 CONQOR404 8 GPM 336 GPM 336 YP 23 POTASSIUM CHLORIDE 1020 PSI 1350 PSI 1350 GELS 10/12/19 FLOWZAN 128 BTMS UP MIN 62 BTMS UP MIN 62 API FLUID LOSS 6.2 PAC 4 122 TOT CIR MIN 140 TOT CIR MIN 140 CAKE APH/HT 2/ CF-DESCO II/SAPP 12 96 AVDP: AVDP: 136 SOLIDS 7 MYACIDE GA25 2 AVDC: AVDC: 207.5153 OIL/WATER 4/90 GEL-X 7 AVDC: AVDC: SAND .33 CITRIC ACID/SAFE CARB/miz II 767 DRILL STRING&HYDRAULICS PH 9 RESINEX 24 STRING WT. 107 WOB 14 Pf/Mf .10/.7 CAUSTIC SODA 15 40 PICK UP 137 RPM 60 CHLORIDES 20000 SODIUM BICARBONATE/mrtabisulfr 12 90 SLACK OFF 87 TFA 0.8399 CA 240 BARITE/NUT PLUG/G SEAL 419 MAX PULL 140 HSP 152/10.9 VOL.PIT-(BBL) 583 LIQUIDS 0 ECD 10.23 PRESS DROP 5 HOLE-(BBL) 736 SOLIDS (BBLS hauled by AIMM) 213 5871 DCOD JET VEL 136 API SCREEN 4-200 2-200.2-165 Daily Mud Cum. 424 13747 ACTIVITY SUMMARY TIME SUMMARY Start I Finish ( Hours I Description Detail I Daily I Cumulative 6:00 Drill 8 1/2"hole section F/10718'-10930'60rpm,350 gpm RU/RD 132.00 12:00 6.00 tq-8-9,up-140,do-82,1110 ART-,3.1 Controll drill Drilling 9.50 137.00 80fph.Having trouble with signal from mag trac and MWD Service/Repair Rig 3.50 19.00 12:00 Drill 8 1/2"hole section F/10930-11101 60rpm,350 gpm Surveys 0.00 tq-8-9,up-140,dn-85,1107 ART-2.3 Control drill Tripping 6.50 123.00 15:30 3.50 Achieved TD on well as per geologist.1500hrs 1-7-12 Change BHA 0.00 15:30 17:30 2.00 C&C mud 335gpm 1550psi 100rpm @ 11101' Casing Crew 27.50 17:30 Monitor well.POH(wiper Trip)F/11101-10048'Back ream Cementing Crew 13.00 21:00 3.50 &pump 335gpm 1400psi.(re-ream 6 tight spots) Logging 0.00 21:00 21:30 0.50 Blow down surface lines,Prep to RIH NU/ND Test 48.50 21:30 23:00 1.50 RIH F/10048'-11006'Wash to 11101'(no fill) DST/Core 0.00 - 23:00 1:00 2.00 C&C mud 335gpm 1550psi 100rpm @ 11101',spot 50bb1 Well Control 0.00 hi vis 8%lube LCM pill WOC 1.00 1:00 2:30 1.50 POH on elevaters F/11101'-10048'(slick hole) Safety Meetings 0.00 2:30 6:00 3.50 Stroke Drill pipe while working on pump issues Drilling Cement 3.50 Circ/Other 4.50 35.50 24.00 TOTAL 24.00 540.00 BOTTOM HOLE ASSEMBLY QTY ITEM CONN DOWN CONN UP VENDOR O.D. I.D. GAUGE NECK LENGTH TOTAL LENGTH 1 Motor-Steerable 1.0deg 4 1/2 reg 4 1/2 h-90 BHI 6 3/4 8.38 1.60 23.58 24.65 1 N M Flex Pony Collar 4 1/2 h-90 4 1/2 h-90 BHI 6 3/4 2 13/16 2.23 9.20 33.85 1 N M String Stabilizer 41/2 h-90 4 1/2 h-90 BHI 6 3/16 2 13/16 8 3/8 2.32 5.05 38.90 1 NM X-over 4 1/2 h-90 4 1/2 if BHI 6 3/4 2 3/4 2.84 41.74 1 Stop/Ontrac/Stab/Bcpm 4 1/2 if T2B BHI 7 8 3/8 1.45 33.15 74.89 1 Ord/Ccn T2B T28 BHI 6 3/4 2 112 8 3/8 2.50 16.28 91.17 1 Mag Trac/Stop Sub T2B 4 1/2 Aro BHI 7 1.23/43 8 3/8 31.99 123.16 1 N M Filter Sub 4 1/2 if 4 1/2 lib BHI 6 7./8 2 13/16 5.27 128.43 1 N M X-Over 4 1/2 if 4 1/2 h-90 SRI 6 3/4 2 13/16 2.03 130.46 1 NMCSDP 4 1/2 h-90 4 1/2 5-80 BHI 5 2 7/8 6 5/16 1.97 29.26 159.72 1 NMCSDP 4 1/2 h-90 4 1/2 5-90 BHI 5 2 13/16 6 3/8 2.20 30.15 189.87 1 NMCSDP 4 1/2 5-90 4 1/2 h-90 BHI 5 2 7/8 6 118 2.71 30.00 219.87 1 X-over 4 1/2 5-90 4 1/24 BHI 6 3/8 2 7/8 1.70 221.57 1 Well Commander 4 1/2if 4 1/2if MI swaw 6 7/8 3 1/2 2.46 13.20 234.77 4 40 HWDP 41/24 41/2if NAD 5 3 119.45 354.22 1 Jars 4 1/2if 41/2if WED 6 3/16 2 1/4 6 1/2 32.09 386.31 19 5"HWDP 4 I/2if 4 v2if NAD 5 3 BHA TOTAL LENGTH 952.71 REMARKS&COMMENTS DIESEL No accidents near misses or spits. Controlled drilling @ 80FPH for logging data Diesel on Location day before 10,174 Next BOP Test 1-17-12 Diesel Used Last 24 2,370 Flow check each connection max gas 51 units @ 10757' Diesel Received 3.997 BOP Drill, TOTAL DIESEL 11,801 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck drivers 2 13 26 PRA DSM 2 12 24 Aimm Roust. 2 13 26 _ PRA Safety/PM 2 1 2 PRA Geologist 1 12 12 Canrig Mud Loggers 2 12 24 MI Swaco Mud Engineer 2 12 24 Baker Directional 2 12 24 Baker LWD 3 12 36 - TOTAL COUNT 42 TOTAL MAN HOURS 498 FROM I TO I LENGTH I JOINT I DESCRIPTION G/L 97' 97' Wef+4d 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 137 1 13 3/8 68#J-55(FC @ 2346,Shoe @2390') Intermediate FROM TO LENGTH JOIN'S DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-hy 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder CINGSA-DAILY DRILLING REPORT Date: 1/9/2012 Well Name CLU Storage 5 BHA ft: 3 M Days: John Nicholson Current Depth: 11101 TD Location: Kenai,AK Target Depth: 11161' Cell Phone: (907) 299-4306 - • Ftg/24hro. 0 Field/Poor Cannery Loop I Sterling C conn Rig Nabors Alaska-Rig 105 E Nights: Mike Grubb Days Since Spud 18 Present Run Cement Bond Log Rig Phone: (907)398-3156 Cell Phone; (509)431-7988 Operation: DRILLING DATA BITS SIZE MFG TYPE SER lit JETS IN OUT FEET BIT GRADE TOTAL HOURS MS 3 8 1/2 HCC HCR 503ZX 7114328 3-13 3-14 8872 11101 2229 '-i,-----i 33.8 66.00 CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40 L-80 BTC 8860' Slumberger 2-Jan Liner Tubing PUMP#1 PUMP#2 [MUD PROPERTIES: [MUD ADDITIVES: I Daily (Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT 9.1 GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 53 S.ASH(50 lb bag) 27 LINER SIZE 6 LINER SIZE 6 R600/R300 42/30 KLA-GUARD 168 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 21/17 LOTORQ/776/STEEL LUBE 252 4400 SPM 53 SPM 53 R6/R3 6/4 ASPHASOL SUPREME 3 183 GPS 3.17 GPS 3.17 PV 12 CONQOR 404 8 GPM 336 GPM 336 VP 18 POTASSIUM CHLORIDE 100 1120 PSI 1350 PSI 1350 GELS 7/12/16 FLOWZAN 7 135 BTMS UP MIN 62 BTMS UP MIN 62 API FLUID LOSS 6.1 PAC 122 TOT CIR MIN 140 TOT CIR MIN 140 CAKE APH/HT 2/ CF-DESCO II/SAPP 96 AVDP: 164.00 AVDP: 164 SOLIDS 6 MYACIDE GA25 2 AVDC: '64.00 AVDC: 164 OIL/WATER 3/91 GEL-X 7 AVDC: AVDC: SAND 0.2 CITRIC ACID/SAFE CARB/mix II 767 DRILL STRING&HYDRAULICS PH 9 RESINEX 24 STRING WT. 107 WOB Pf/Mf .10/.80 CAUSTIC SODA 40 PICKUP 137 RPM 60 CHLORIDES 16000 SODIUMBICARBONATE/mrtabisulrr 7 97 SLACK OFF 87 TFA 0.8399 CA 320 BARITE I NUT PLUG/G SEAL 93 512 MAX PULL 140 HSP 151/1 VOL.PIT-(BBL) 376 LIQUIDS 0 ECD 9.93 PRESS DROP 5 HOLE-(BBL) 827 SOLIDS (BELS hauled by AIMM) 262 6133 DCOD JET VEL 136 API SCREEN 4-200 2-200.2-165 Daily Mud Cum. 724 14471 ACTIVITY SUMMARY TIME SUMMARY Start I Finish I Hours I Description Detail I Daily I Cumulative 6:00 Continue to clean out low pressure mud and suction lines RU/RD 132.00 plugged with coal and sand,replace all valves and seats Drilling 137.00 in#1 mud pump.Coal was getting under suction valves. Service/Repair Rig 3.50 22.50 Clean out pill pit to use as circulating pit Work pipe @ 10144 Surveys 0.00 Found all pits with coal.Circulate pit#4 over shakers and Tripping 19.50 142.50 9:30 3.50 clean up Change BHA 0.00 9:30 POH F-10144,250 gpm,60rpm Work tight hole F/9260 to Casing Crew 27.50 9240'Hole attempting to pack off(lost 40bb1) with 15bbls Cementing Crew 13.00 returned after pumps were S/0.Continue POH to 8860' Logging 1.00 1.00 22:00 12.50 9 5/8 shoe.Pump dry job.Drop rabbit,POH F/8860'-852' NU/ND Test 48.50 22:00 23:30 1.50 Lay down HWDP and Jars F/852'-354' DST/Core 0.00 23:30 L/D BHA#3 F/354',unload sources,plug in and download Well Control 0.00 5:00 5.50 from on trak and mag trak, WOC 1.00 5:00 6:00 1.00 R/U to run Baker Atlas cement bond log Safety Meetings 0.00 Drilling Cement 3.50 Circ/Other 35.50 24.00 TOTAL 24.00 564.00 BOTTOM HOLE ASSEMBLY • QTYITEM CONN DOWN CONN UP VENDOR O.D. I.D. GAUGE NECK LENGTH TOTAL LENGTH 1 Motor-Steerable 1.0deg 4 1/2 reg 4 1/2 h-90 BHI 6 3/4 _ H.38 1.60 23.58 24.65 1 N M Flex Pony Collar 4 1/2 h-90 4 1/2 h-90 BHI 6 3/4 2 13/16 2.23 920 33.85 1 N M String Stabilizer 4 1/2 h-90 4 1/2 h-90 BHI 6 3/16 2 13/16 8 3/8 2.32 5.05 38.90 1 NM X-over 4 1/2 h-90 4 1/2 if BHI 6 3/4 2 3/4 2.84 41.74 _ 1 Slop/Ontrac/Stab/Bcpm 4 1/2 if T2B BHI 7 8 3/8 1.45 33.15 74.89 1 Ord/Ccn T2B T20 BHI 6 3/4 2 1/2 8 3/e 2.50 16.28 91 17 1 Mag Trac/Stop Sub T28 4 1/2 ifb BHI 7 1.23/43 8 3/8 31.99 123.16 1 N M Filter Sub 4 1/2 if 4 1/2 1fb BHI 6 7/8 2 13/16 5.27 12843 1 N M X-Over 4 1/2 If 41/2 h-90 BHI 6 3/4 2 13116 2.03 130.46 _ 1 i NMCSDP 4 1/2 h-90 4 1/2 h-90 BHI 5 2 7/8 6 5/16 i 1.97 29.26 159.72 _ 1 NMCSDP 4 1/2 h-90 41/2 h-90 BHI 5 __ 213/16 6 3/8 2.20 30.15 189.87 1 NMCSDP 4 1/2 h-90 4 1/2 h-90 BHI 5 2 7/8 6 1/8 2.71 30.00 219.87 1 X-over 41/2 h-90 41/2i( BHI 6 3/8 2 7/8 1.70 221.57 1 Well Commander 41/26 4 1/2if MI swaco 6 7/8 3 1/2 2.46 1320 234-77 4 4x HWDP 41/2if 41/2i( NAD 5 3 119.45 354.22 1 Jars 4 1/2if 4l/2i( WFD 6 3/16 2 1/4 B 1/2 32.09 386.31 19 5'HWDP 4 /24 4 112if NAD 5 3 BHA TOTAL LENGTH 952.71 REMARKS&COMMENTS DIESEL No accidents near misses or spills. Diesel on Location day before 11,801 Next BOP Test 1-17-12 Diesel Used Last 24 1,662 Cleaning mud system Diesel Received BOP Drill, TOTAL DIESEL 10.139 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck drivers 3 13 39 PRA DSM 2 12 24 Aimm Roust. 2 13 26 PRA Safety/PM 2 1 2 PRA Geologist 1 12 12 Canrig Mud Loggers 2 12 24 Baker wireline 4 4 12 MI Swaco Mud Engineer 2 12 24 Baker Directional 2 12 24 Baker LWD 3 12 36 - TOTAL COUNT 47 TOTAL MAN HOURS 523 FROM I TO 1 LENGTH I JOINT 1 DESCRIPTION G/L 97' 97' Wele—I_20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 BP 13 3/8 68#J-55(FC @ 2346,Shoe @2390') Intermediate _ FROM TO LENGTH JOINIS DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-hy 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder CINGSA- DAILY DRILLING REPORT Date: 1/10/2012 Well Name CLU Storage 5 BHA#: 3 M Days: John Nicholson Current Depth: 11101 TD Location: Kenai,AK Target 11161' Cell Phone: (907) 299-4306 Depth: Ftgt24hrs. 0 Field/Poor. Cannery Loop/Sterling C ConRi to Nabors Alaska-Rig 105 E DSNighM: Mike Grubb Days Since Spud 19 Present Run 7"liner in hole on drill pipe Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS naU 3 8 1/2 HCC HCR 503ZX 7114328 3-13 3-14 8872 11101 2229 66.00 CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I_DATE I - Conductor: 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40 L-80 BTC 8860' Slumberger 2-Jan Liner Tubing PUMP#1 PUMP#2 IMUD PROPERTIES: (MUD ADDITIVES: I Daily (Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT 9.1 GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 54 S.ASH(50 lb bag) 27 LINER SIZE 6 LINER SIZE 6 R600/R300 38/22 KLA-GUARD 168 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 18/15 LOTORQ/776/STEEL LUBE 4400 SPM SPM R6/R3 6/4 ASPHASOL SUPREME 183 GPS 3.17 GPS 3.17 PV 16 CONQOR404 8 GPM GPM YP 6 POTASSIUM CHLORIDE 1120 PSI PSI GELS 6/11/14 FLOWZAN 135 BTMS UP MIN BTMS UP MIN 0 API FLUID LOSS 6 PAC 122 TOT CIR MIN TOT CIR MIN 0 CAKE API-1/1-1T 2/ CF-DESCO II/SAPP 96 AVDP: AVDP: 0 SOLIDS 6 MYACIDE GA25 2 AVDC: AVDC: 0 OIL/WATER 3/91 GEL-X 7 AVDC: AVDC: SAND 0.2 CITRIC ACID/SAFE GARB/mix II 767 DRILL STRING&HYDRAULICS PH 9 RESINEX 24 STRING WT. WOB Pf/Mf .10/.80 CAUSTIC SODA 40 PICKUP RPM CHLORIDES 17000 SODIUM BICARBONATE/mrtabisulfr 97 SLACK OFF TFA CA 320 BARITE/NUT PLUG/G SEAL 512 MAX PULL HSP VOL.PIT-(BBL) 385 LIQUIDS 0 ECD PRESS DROP HOLE-(BBL) 790 SOLIDS (BBLS hauled by AIMM) 83 6216 DCOD JET VEL API SCREEN 4x84 4x84 Daily Mud Cum. 83 14554 ACTIVITY SUMMARY TIME SUMMARY Start I Finish I Hours I Description Detail _ I Daily I Cumulative 6:00 1 Rill Baker Atlas(1.5 hr.thawing out wire line unit.)for RU/RD 132.00 9:00 3.00 running CBL. Drilling 137.00 9:00 RIH with CBL on wire line Run bond log F 8876up to 5000' Service/Repair Rig 1.00 23.50 15:30 6.50 P rig down tools Move out of pipe shed Surveys 0.00 15:30 16:00 0.50 CK and blown down cement lines and top drive Service rig Tripping 142.50 / 16:00 16:30 0.50 Hold PJSM(Running liner)Rig up casing tools Change BHA 0.00 16:30 21:00 4.50 Run 7"yam top liner.M/U shoe track CK floats RIH T/2386' Casing Crew 12.00 39.50 21:00 22:00 1.00 P/U and M/U FlexLock liner hanger and ZXPN liner top Cementing Crew 13.00 packer&running tool,R/U to run drill pipe Logging 9.50 10.50 22:00 23:00 1.00 Attempt to circ.liner volume,trouble shooting pumps NU/ND Test 48.50 23:00 1:45 2.75 RIH with 7"liner on drill pipe(filling every 10 stands)T/4291' DST/Core 0.00 1:45 2:45 1.00 Circulate annular volume,255gpm @ 175 psi Well Control 0.00 2:45 6:00 3.25 Cont.RIH F/4291'-6290'with 7"liner on drill pipe,filling WOC 1.00 every 10 stands Safety Meetings 0.00 Drilling Cement 3.50 Circ/Other 1.50 37.00 24.00 TOTAL 24.00 588.00 BOTTOM HOLE ASSEMBLY_ _ QTY I ITEM I CONN DOWN CONN UP I VENDOR I O.D. I I.D. GAUGE I NECK J LENGTH (TOTAL LENGTH BHA TOTAL LENGTH 0.00 REMARKS&COMMENTS DIESEL No accidents near misses or Spills. Heating pits with steam Diesel on Location day before 10,139 Next BOP Test 1-17-12 Diesel Used Last 24 1,360 shaker screens blinding off,found small pieces coal under mud pump valves Diesel Received BOP Drill, TOTAL DIESEL 8,779 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck drivers 3 13 39 PRA DSM 2 12 24 Aimm Roust. 3 12 36 PRA Safety/PM 2 1 2 Canriq Mud Loggers 2 12 24 Baker wireline 4 9 12 MI Swaco Mud Engineer 2 12 24 Baker tool 1 12 12 Baker Directional 2 12 24 Baker LWD 3 12 36 - TOTAL COUNT 48 TOTAL MAN HOURS 533 FROM I TO I LENGTH I JOINT I DESCRIPTION G/L 97' 97' Wel^a1_20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 BT 13 3/8 68#J-55(FC @ 2346,Shoe @2390') Intermediate • FROM TO LENGTH JOIN1S DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-hy 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder CINGSA-DAILY DRILLING REPORT Date: 1/11/2012 Well Name CLU Storage 5 BHA#: IM Days: John Nicholson Current Depth: 11101 TD Location: Kenai,AK et Dept 11161' Cell Phone: (907) 299-4306 Rig Ftg/24hrs. 0 Field/Pool: Cannery Loop/Sterling C Contractor. Nabors Alaska-Rig 105E Nights: Mike Grubb Days since spud 20 Present Stand back HWDP and jars Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS ne 3 8 1/2 HCC HCR 503ZX 7114328 3-13 3-14 8872 11101 2229 1-1,-e-"", 33.8 66.00 CASING I SIZE J WEIGHT 1 GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor: 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40 L-80 BTC 8860' Slumberger 2-Jan Liner Tubing PUMP#1 PUMP#2 IMUD PROPERTIES: IIMUD ADDITIVES: I Daily (Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT 9.1 GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 47 S.ASH(50 lb bag) 27 LINER SIZE 6 LINER SIZE 6 R600/R300 34/25 KLA-GUARD 168 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 22/18 LOTORQ/776/STEEL LUBE 4400 SPM SPM R6/R3 7/5 ASPHASOL SUPREME 183 GPS 3.17 GPS 3.17 PV 9 CONDOR404 8 GPM GPM VP 16 POTASSIUM CHLORIDE 70 1190 PSI PSI GELS 6/10/11 FLOWZAN 5 140 BTMS UP MIN BTMS UP MIN API FLUID LOSS 6.1 PAC 2 124 TOT CIR MIN TOT CIR MIN CAKE APH/HT <2/ CF-DESCO II/SAPP 96 AVOP: AVDP: SOLIDS 7 MYACIDE GA25 2 AVDC: AVDC: OIL/WATER 3/91 GEL-X 7 AVDC: AVDC: SAND 0.25 CITRIC ACID/SAFE CARB/mix II 767 DRILL STRING&HYDRAULICS PH 8 RESINEX 24 STRING WT. WOB PHMf .05/.80 CAUSTIC SODA 40 PICK UP RPM CHLORIDES 21500 SODIUM BICARBONATE/mrtabisulfr 97 SLACK OFF TFA CA 240 BARITE/NUT PLUG/G SEAL 70 582 MAX PULL HSP VOL.PIT-(BBL) 371 LIQUIDS 0 • ECD PRESS DROP HOLE-(BBL) 829 SOLIDS (BBLS hauled by AIMM) 117 4553 DCOD JET VEL API SCREEN 4x84 4x84 Daily Mud Cum. 264 13038 ACTIVITY SUMMARY TIME SUMMARY Start I Finish I Hours I Description Detail _ I Daily I Cumulative 6:00 7:30 1.50 Continue running 7"liner to 8800' RU/RD 132.00 7:30 9:30 2.00 Circ.B/U 5300 stks 7bbl per min 400psi @ 8800' Drilling 137.00 9:30 Run 7"liner F/8800'-9018'attempt to work and clean up Service/Repair Rig 2.00 25.50 W/O success.Stand back 1 stand.Circulate 2.5bbls min Surveys 0.00 increase to 3.5bbls min wash down F 8923'to 8950'hole Tripping 11.00 153.50 packing off.P/U and clean up.Pump and rotate liner 15rpm Change BHA 0.00 3540 tq.3.5bbls min 395psi.Work down and attempt to Casing Crew 6.50 46.00 clean up.Hole started packing off with Tq increasing to Cementing Crew 13.00 8000 fp.With a max of 15000 fp.P/U and release Tq. Logging 10.50 12:00 2.50 Start to loose hole.Stop rotation pump out back 8800' NU/ND Test 48.50 12:00 Circulate B/U at 285gpm Fine sand and silt over shakers DST/Core 0.00 14:00 2.00 Blown down top drive and mud lines Well Control 0.00 14:00 19:00 5.00 POH with 7"liner on drillpipe F-8800'-2386'top of ZXP WOC 1.00 19:00 1:30 6.50 R/U casing tongs&elevators,LID ZXP,hanger&7"liner Safety Meetings 0.00 1:30 3:30 2.00 Prep BHA and RIH HWDP&JARS Drilling Cement 3.50 3:30 5:30 2.00 Cut and slip drilling line Circ/Other 4 50 41.50 05:30 06:00 0.50 POH with HWDP and jars,stand back TOTAL 24.00 ' 612.00 BOTTOM HOLE ASSEMBLY _ QTY ITEM I CONN DOWN CONN UP I VENDOR I O.D. I I.D. I GAUGE I NECK 1,, LENGTH TOTAL LENGTH - BHA TOTAL LENGTH o.00 REMARKS&COMMENTS DIESEL No accidents near misses or spills. Heating pits with steam Diesel on Location day before 8,779 Next BOP Test 1-17-12 Diesel Used Last 24 2,233 POH with liner,lost 1 centrilizer and 2 stop rings Diesel Received BOP Drill, TOTAL DIESEL 6,546 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck drivers 2 12 24 PRA DSM 2 12 24 Aimm Roust. 3 8 24 PRA Safety/PM 2 1 2 Baker tool _ 1 12 12 _ Canrig Mud Loggers 2 12 24 _ _ ___ MI Swaco Mud Engineer 2 12 24 Baker Directional 2 12 24 Baker LWD 3 12 36 - TOTAL COUNT 43 TOTAL MAN HOURS 494 FROM I TO I LENGTH I JOINT I DESCRIPTION G/L 97' 97' Wei'+ad 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 BT 1 13 3/8 68#J-55(FC @ 2346,Shoe @2390') Intermediate _ FROM TO LENGTH 1011..5 DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-hy 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder CINGSA-DAILY DRILLING REPORT Date: 1/12/2012 Well Name CLU Storage 5 BHA#: 4 iM Days: John Nicholson Current Depth: 11101 TD Location: Kenai,AK depth 11161' Cell Phone: (907) 299-4306 Ftg/24hrs. 0 Field/Pool Cannery Loop/Sterling C Contractor Nabors Alaska-Rig 105 E ig N�hM. Mike Grubb Days Since Spud 21 Present Circulate and condition Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT S SIZE MFG TYPE SER 8 JETS IN OUT FEET BIT GRADE TOTAL HOURS 7r8. CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY J DATE I - Conductor. 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40 L-80 BTC 8860' Slumberger 2-Jan Liner Tubing PUMP#1 IPUMP#2 IMUD PROPERTIES: IMUD ADDITIVES: I Daily Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT 9.1 GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 47 S.ASH(50 lb bag) 4 31 LINER SIZE 6 LINER SIZE 6 R600/R300 34/25 KLA-GUARD 168 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 22/18 LOTORQ/776/STEEL LUBE 4400 SPM 46 SPM 46 R6/R3 7/5 ASPHASOL SUPREME 47 230 GPS 3.17 GPS 3.17 PV 9 CONDOR404 8 GPM 300 GPM 300 YP 16 POTASSIUM CHLORIDE 35 1225 PSI 665 PSI 665 GELS 6/10/11 FLOWZAN 140 BTMS UP MIN 74 BTMS UP MIN 74 API FLUID LOSS 6.1 PAC 124 TOT CIR MIN 173 TOT CIR MIN 173 CAKE APH/HT <2/ CF-DESCO II/SAPP 96 AVDP: 160.00 AVDP: 160 SOLIDS 7 MYACIDE GA25 2 AVDC: '75.00 AVDC: 275 OIL/WATER 3/91 GEL-X 7 AVDC: AVDC: SAND 0.25 CITRIC ACID/SAFE CARB/mix II 767 DRILL STRING 8,HYDRAULICS PH 8 RESINEX 24 STRING WT. 114 WOB 0 PM/ .05/.80 CAUSTIC SODA 40 PICKUP 154 RPM 60 CHLORIDES 21500 SODIUMBICARBONATE/mrrabisulh 97 SLACK OFF 85 TFA 1.84 CA 240 BARITE/NUT PLUG/G SEAL 582 MAX PULL 157 HOP 1-Apr VOL.PIT-(BBL) 371 LIQUIDS 0 ECD 9.52 PRESS DROP 22/1 HOLE-(BBL) 829 SOLIDS (BBLS hauled by AIMM) 47 6380 DCOD JET VEL 51 API SCREEN 4x84 4x84 Daily Mud Cum. 133 14951 ACTIVITY SUMMARY--- TIME SUMMARY Start I Finish _ I Hours I Deitrigllaa, Detail I Daily I Cumulative 6:00 7:00 1.00 M/U 8 3/8"mill and BHA RIHRU/RD 132.00 7:00 14:00 7.00 P/U drift(3.132)12 jts 5"DP RIH..to-8860' Drilling 137.00 14:00 Break Circ @ 8840�ircu4t0nd condition mud Initial rate Service/Repair Rig 25.50 -1-75grartrdutrfingsses over shakers.Add screen clean at Surveys 0.00 4500stks increase flow rate to 250gpm @ 8600stks continue Tripping 23.50 153.50 16:00 4.00 increasing pump rate at 12000 stokes 2X B/U pump 400gpm Change BHA 0.00 16:00 Enter open hole at 8860'Rotate 50rpm 300gpm wash and Casing Crew 46.00 work mill down to 8954'10k clean up.Wash down to 9026' Cementing Crew 13.00 set 20-30k down Tq 9000fp clean up continue to wash and Logging 10.50 ream 300gpm 60rpm,takel5k F10880'-10920,reream(OK) NU/ND Test 48.50 cont.ream to 11101'no fill,tag bottom with 20K no rot. DST/Core 0.00 3:30 11.50 stroke up rot back down TQ increase 4-5k Well Control 0.00 3:30 6:00 2.50 C&C mud,increase flow to 400gpm,915 psi,120 rpm WOC 1.00 Safety Meetings 0.00 Drilling Cement 3.50 Circ/Other 2.50 41.50 'TOTAL 26.00 612.00 BOTTOM HOLE ASSEMBLY QTY ITEM CONN DOWN CONN UP VENDOR O.D. I.D. GAUGE NECK LENGTH TOTAL LENGTH 1 Concave Mill 4 1/2 reg SOT 8 3/e 2.93 2.93 1 Near Bit Stab.W Float 4112reg 41/2 H-90 BHI 6 5/8 2 1/4 8 1/2 1.30 4.44 4.44 1 NMCSDP 41/2 H-90 4 1/2 H-90 BHI 5 2 7/8 6 1/8 2.71 30.00 30.00 1 String Stab. 4 1/2 H-90 4 1/2 H-90 BHI 6 3/16 2 4/5 8 3/8 2.34 5.05 5.05 1 X-Over Steel Sub. 4 1/2 H-90 4 1/21F8 BHI 6 3/8 2 7/8 1.70 1.70 3 HWDP 4 112 if 4 1/2 if NAD 5 3 89.68 89.68 1 Jars 41/2 if 4 1/2 if WFD 6 3/16 2 1/4 1.70 32.09 32.09 11 HWDP 41/2 if 4 1/2 if NAD 5 3 327.69 327.69 BHA TOTAL LENGTH 493.58 REMARKS 8 COMMENTS DIESEL No accidents near misses or spills. Heating pits with steam Diesel on Location day before 6,546 Next BOP Test 1-17-12 B/U gas 1571 units from coal seams under shoe Diesel Used Last 24 1,471 POH with liner,lost 1 centrilizer and 2 stop rings Diesel Received 9,500 BOP Drill, TOTAL DIESEL 14,575 _ PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck drivers 2 12 24 PRA DSM 2 12 24 Aimm Roust. 5 12 60 PRA Safety/PM 2 1 2 Baker tool 1 12 12 Canriq Mud Loggers 2 12 24 MI Swaco Mud Engineer 2 12 24 Baker Directional 1 12 12 - TOTAL COUNT 41 TOTAL MAN HOURS 482 FROM I TO I LENGTH I JOINT I DESCRIPTION G/L 97' 97' Weidod 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 Bi ) 13 3/8 68#J-55(FC 2346,Shoe @2390') Intermediate FROM TO LENGTH JOu..S DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-hy 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder CINGSA-DAILY DRILLING REPORT Date: 1/13/2012 Well Name CLU Storage 5 BHA#: an Days: John Nicholson Current Depth: 11101 TD Location: Kenai,AK Target 11161' Cell Phone: (907) 299-4306 Depth: ig Ftg/24hrs. 0 Field/Pool.. Cannery Loop I Sterling C ContractorNabors Alaska-Rig 105 E Nights Mike Grubb Days Since Spud 22 Present Run 7 liner on drill pipe Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS lie CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40 L-80 BTC 8860' Slumberger 2-Jan Liner Tubing PUMP#1 !PUMP#2 ILMUD PROPERTIES: MUD ADDITIVES: I Daily (Cumulative PUMP MANE Gardner Denver PUMP MANE Gardner Denver WEIGHT 9.2 JOEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 45 S.ASH(50 lb bag) 11 42 LINER SIZE 6 LINER SIZE 6 R600/R300 43/31 KLA-GUARD 4 172 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 23/17 LOTORO/778/STEEL LUBE 4400 SPM 46 SPM 46 R6/R3 7/5 ASPHASOL SUPREME 3 233 GPS 3.17 GPS 3.17 PV 12 CONQOR 404 8 GPM 300 GPM 300 YP 19 POTASSIUM CHLORIDE 160 1385 PSI 665 PSI 665 GELS 7/12/17 FLOWZAN 15 155 BTMS UP MIN 74 BTMS UP MIN 74 API FLUID LOSS 6 PAC 15 139 TOT CIR MIN 173 TOT CIR MIN 173 CAKE APH/HT <2/ CF-DESCO II/SAPP 96 AVDP: AVDP: 160 SOLIDS 6.5 MYACIDE GA25 4 6 AVDC: AVDC: 275 OIL/WATER 2/92 GEL-X 7 AVDC: AVDC: SAND .5 CITRIC ACID/SAFE CARB/mix II 767 DRILL STRING&HYDRAULICS PH 8.7 RESINEX 24 STRING WT. WOB Pt/Mf .01/.80 CAUSTIC SODA 40 PICKUP RPM CHLORIDES 21000 SODIUM BICARBONATE/mrtabisulf'r 4 101 SLACK OFF TFA CA 220 BARITE/NUT PLUG 1 G SEAL 153 582 MAX PULL HSP VOL.PIT-(BBL) 515 LIQUIDS/screen clean 220 220 ECD PRESS DROP HOLE-(BBL) 823 SOLIDS (BBLS hauled by AIMM) 102 6482 DCOD JET VEL API SCREEN 4x84 4x84 Daily Mud Cum. 691 15489 L ACTIVITY SUMMARY TIME SUMMARY Start I Finish I Hours I Description Detail I Daily I Cumulative 6:00 Back ream out of hole F/11101'- 9111' 60rpm 360gpm SRU/RD 132.00 Pump out F 9111'-8950'21 spm no rotation,pull through Drilling 137.00 coals W/O problems Increase pump rate to 300gpm F 8950' Service/Repair Rig 25.50 to 8824'.Increase pump rate to 400gpm and pump out to Surveys 0.00 14:00 8.00 8000'. Tripping 23.00 176.50 14:00 Circ B/U @ 8000'SOOgpm large amount of sand,coal and Change BHA 0.00 silt returning over shakers pump 3000stk over B/U to clean Casing Crew 46.00 15:00 1.00 up shakers Cementing Crew 13.00 15:00 21:00 6.00 Monitor well,POH F 8000',lay down HWDP,jars&BHA Logging 10.50 21:00 PJSM,R/U and run 7"liner,pump mud through shoe track. NU/ND Test 48.50 3:30 6.50 check floats(good),RIH,M/U hanger and packer DST/Core 0.00 3:30 6:00 2.50 RIH with liner on drill pipe F/2422'-4330'filling drill pipe every Well Control 0.00 10 stands WOC 1.00 ,..----- Safety Meetings 0.00 Drilling Cement 3.50 Circ/Other 1.00 42.50 24.00 TOTAL 24.00 636.00 BOTTOM HOLE ASSEMBLY CITY ITEM CONN DOWN CONN UP VENDOR O.D. I.D. GAUGE NECK LENGTH TOTAL LENGTH 1 Concave Mill 41/2 reg BOT 8 3/8 2.93 2.93 1 Near Bit Stab.W Float 4 1/2reg 4 1/2 H-90 BHI 6 5/8 2 1/4 8 1/2 1.30 444 4.44 1 NMCSDP 4 1/2 H-90 4 1/2 H-90 OHI 5 2 7/8 6 1/8 2.71 30.00 30.00 1 String Stab. 4 1/2 H-90 4 112 H-90 BHI 6 3/16 2 4/5 8 3/8 2.34 5.05 5.05 1 X-Over Steel Sub. 4 1/2 H-90 4 1/21 FB BHI 6 3/8 2 7/8 1.70 1.70 3 HWDP 41/2 if 41/2 if NAD 5 3 89.68 89.68 1 Jars 41/2 if 41/2 if WFD 6 3/16 2 1/4 1.70 32.09 32.09 11 HWDP 41/2 rf 4 1/2 if NAD 5 3 327.69 327.69 BHA TOTAL LENGTH 493.58 REMARKS&COMMENTS DIESEL No accidents near misses or spills. Heating pits with steam Diesel on Location day before 14,575 Next BOP Test 1-17-12 Diesel Used Last 24 2,129 Diesel Received 0 BOP Drill, TOTAL DIESEL 12,446 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck drivers 4 12 48 PRA DSM 2 12 24 Aimm Roust. 4 12 48 PRA Safety/PM 2 1 2 Baker tool 1 12 12 Canriq Mud Loggers 2 12 24 MI Swaco Mud Engineer 2 12 24 Baker Directional 1 12 12 - TOTAL COUNT 42 TOTAL MAN HOURS 494 FROM I TO I LENGTH I JOINT I DESCRIPTION .........._. . . .. . ........_ G/L 97' 97' Weld..d 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 B1 ) 13 3/8 68#J-55(FC @ 2346,Shoe @2390') Intermediate FROM TO LENGTH JOu.1S DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-hy 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder CINGSA-DAILY DRILLING REPORT Date: 1/14/2012 Well Name CLU Storage 5 BHA#: iM Days: John Nicholson Current Depth: 11101 TD Location. Kenai,AK Target 11161' Cell Phone: (907) 299-4306 Depth: Ftg/24hrs. 0 Field/Pool.. Cannery Loop I Sterling C Con actor. Nabors Alaska-Rig 105 E NghM, Mike Grubb RigDays Since Spud 23 Present POH with liner running tool Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE ' SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS n r CASING I SIZE J WEIGHT( GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40# L-80 BTC 8860' Slumberger 2-Jan Liner 7" 26# L-80 VAM 11099-8684' Slumberger 14-Jan Tubing PUMP#1 IPUMP#2 IMUD PROPERTIES: IMUD ADDITIVES: I Daily ICumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT 9.3 GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 46 S.ASH(50 lb bag) 42 LINER SIZE 6 LINER SIZE 6 R600/R300 46/30 KLA-GUARD 172 STOKE LNGTH 9 STOKE LNGTH 9 R200IR100 24/17 LOTORQ/776/STEEL LUBE 4400 SPM 65 SPM 65 R6/R3 6/4 ASPHASOL SUPREME 233 GPS 3.17 GPS 3.17 PV 16 CONQOR404 8 GPM 412 GPM 412 YP 14 POTASSIUM CHLORIDE 60 45 PSI PSI GELS 7/12/15 FLOWZAN 6 161 BTMS UP MIN BTMS UP MIN API FLUID LOSS 6.1 PAC 139 TOT CIR MIN TOT CIR MIN CAKE APHIHT <2/ CF-DESCO II/SAPP _ 96 AVDP: AVDP: SOLIDS 6 MYACIDE GA25 6 AVDC: AVDC: OIL/WATER 2/92 GEL-X 7 • AVDC: AVDC: SAND 0.35 CITRIC ACID/SAFE GARB/mix!' 767 DRILL STRING&HYDRAULICS PH 8.5 RESINEX 24 STRING WT. WOB Pf/Mf .01/.70 CAUSTIC SODA 40 PICKUP RPM CHLORIDES 20500 SODIUM BICARBONATE/mrtabisulrr 101 SLACK OFF TFA CA 280 BARITE/NUT PLUG/G SEAL 170 752 MAX PULL HSP VOL.PIT-(BBL) 608 LIQUIDS/screen clean 220 ECD PRESS DROP HOLE-(BBL) 691 SOLIDS (BBLS hauled by AIMM) 122 6604 DCOD JET VEL API SCREEN 4x84 4x84 Daily Mud Cum. 358 14447 L ACTIVITY SUMMARY TIME SUMMARY Start I Finish I Hours I Description Detail I Daily I Cumulative 6:00 11:00 5.00 RIH with liner on drill pipe F/4330'-8805'filling drill pipe every RU/RD 132.00 every 10 stands Drilling 137.00 11:00 12:00 1.00 Circulate @ 190 gpm-300psi,P/U 125,S/O 93,Rot 107 Service/Repair Rig 25.50 12:00 19:30 7.50 RIH with liner on drill pipe F/8805'-11101',wash and ream F,' Surveys 0.00 9284'-11101',lost 120 bbls working thru coals Tripping 13.50 190.00 19:30 23:00 3.50 Circ.and recip EU*,R/U cement head(pipe set 16 min) Change BHA 0.00 7 4 unable to move @11099' Casing Crew 46.00 p 23:00 Pump 5bbl water,press test lines,pump 40bbl 11.5 spacer, Cementing Crew 3.50 16.50 ! r _ pump 69bb1 14ppg FIexSTONE cement chase d with95b Logging 10.50 / -_j[� vis brine,and 150bbls 9.3 mud and bump plug-100%retums".{JU/ND Test 48.50 t''�+-z�'�- CIP @ 01:10,Checked Floats,(held) DST/Core 0.00 Press T/2200psi set hanger,set ZXP W/4200psi and confirm Well Control 0.00 2:30 3.50 at 8684',unsting, WOC 1.00 2:30 5:00 2.50 Unsting circ BU x 2,seen trace interface&mud push Safety Meetings 0.00 5:00 6:00 1.00 Pump dry job,POH F/8684'-8150 Drilling Cement 3.50 Circ/Other 7.00 49.50 24.00 TOTAL 24.00 660.00 BOTTOM HOLE ASSEMBLY r QTY I ITEM I CONN DOWN CONN UP VENDOR I O.D. I I.D. I GAUGE I NECK L LENGTH I TOTAL LENGTH BHA TOTAL LENGTH o.oa REMARKS&COMMENTS DIESEL No accidents near misses or spills. Diesel on Location day before 12,446 Next BOP Test 1-17-12 Diesel Used Last 24 2,077 CIP 01:10 Diesel Received 0 BOP Drill. TOTAL DIESEL 10,369 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck dnvers 4 12 48 PRA DSM 2 12 24 Aimm Roust. 4 12 48 PRA Safety/PM 2 1 2 Baker tool 1 12 12 Canrig Mud Loggers 2 12 24 Slumber-J cement 3 12 36 MI Swaco Mud Engineer 2 12 24 Baker Directional 1 12 12 - TOTAL COUNT 45 TOTAL MAN HOURS 530 I FROM I TO I LENGTH I JOINT I DESCRIPTION G/L 97' 97' IM.IH.d 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 BT )13 3/8 68#J-55(FC @ 2346,Shoe @)2390') Intermediate _ FROM TO LENGTH JO....S DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-by 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder Liner FROM TO LENGTH JOINTS DESCRIPTION 11101.00 11099.00 2.00 - Rat hole 11099.00 11099.00 0.55 - 7"BHI H266674701-Float Shoe 11099.00 11059.00 40.42 7"26#L-80 Vam Top NC with BHI-H266624704-Internal Float Collar 11059.00 11059.00 0.00 7"26#L-80 Vam Top HC with BHI-H266564702-Landing Collar internal 11059.00 8713.00 2386.00 58 7"26#L-80 Vam Top HC 8713.00 8709.00 4.86 - 7"Handling Pup-26#L-80 Vam Top HC,6.192"ID 8709.00 8707.00 1.73 - 7"Vam Top HC-RN Casing Nipple,5.88"No-Go ID 8707.00 8700.00 7.20 - 7"X 9.625"FlexLock Hanger,6.19"ID,BHI-29410WW16 8700.00 8684.00 15.45 - HR ZXPN Liner Top Packer,w/10.81"Polished Seal Bore Assembly,6.188"ID,BHI-H2964260W10 C_INGSA-DAILY DRILLING REPORT Date: 1/15/2012 Well Name CLU Storage 5 BHA#: M Days: John Nicholson Current Depth: 11101' Location: Kenai,AK Target 11101 Cell Phone: (907) 299-4306 Depth: Ftg/24hrs. 0 Field/Pool: Cannery Loop/Sterling C Cono-S0r. Nabors Alaska-Rig 105 E NDghM. Mike Grubb Days Since Spud 24 Present Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS r+6 CASING SIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40# L-80 BTC 8860' Slumberger 2-Jan Liner 7" 26# L-80 VAM 11099-8684' Slumberger 14-Jan Tubing PUMP#1 IPUMP#2 IMUD.PROPERTIES: IMUD ADDITIVES: 1 Daily Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT 8.7 GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 17 S.ASH(50 lb bag) 42 LINER SIZE 6 LINER SIZE 6 R600/R300 4/3 KLA-GUARD 172 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 2/1 LOTORQ/776/STEELLUBE 4400 SPM 65 SPM 65 R6/R3 1/1 ASPHASOL SUPREME 233 GPS 3.17 GPS 3.17 PV 1 CONQOR404 8 GPM 412 GPM 412 YP 2 POTASSIUM CHLORIDE 45 PSI 387 PSI 387 GELS 1/1/2 FLOWZAN 20 181 BTMS UP MIN 44 BTMS UP MIN 44 API FLUID LOSS na PAC 139 TOT CIR MIN 62 TOT CIR MIN 62 CAKE APH/HT CF-DESCO II/SAPP 96 AVDP: AVDP: SOLIDS MYACIDE GA25 6 AVDC: AVDC: OIL/WATER /100 GEL-X 7 AVDC: AVDC: SAND CITRIC ACID/SAFE CARB/mix II 767 DRILL STRING&HYDRAULICS PH 8.3 RESINEX 24 STRING WT. WOB Pf/Mf .00/.00 CAUSTIC SODA 40 PICK UP RPM 50 CHLORIDES 33200 SODIUM BICARBONATE/mrtabisulfr 101 SLACK OFF TFA CA BARITE I NUT PLUG/G SEAL 752 MAX PULL HSP 8/1.3 VOL.PIT-(BBL) 26 LIQUIDS/screen clean 100 320 ECD 8.86 PRESS DROP 8/1.3 HOLE-(BBL) 691 SOLIDS (BBLS hauled by AIMM) 677 7281 DCOD JET VEL 32 API SCREEN 4x60 4x60 Daily Mud Cum. 797 15244 ACTIVITY SUMMARY TIME SUMMARY Start I Finish I Hours I Description Detail I Daily I Cumulative 6:00 10:00 4.00 Continue POH F/8150'-1910' RU/RD 132.00 10:00 13:30 3.50 POH F 1910'and L/D drill pipe 57jts.&liner running tool Drilling 137.00 13:30 14:30 1.00 Service rig Service/Repair Rig 1.00 26.50 14:30 20:00 5.50 Make up PBR mill RIH to 8600'wash down to top of ZXP Surveys 0.00 packer and tag at 8684' Tripping 14.50 204.50 20:00 20:30 0.50 Tag wash and polish PBR x 3, Change BHA 0.00 20:30 21:30 1.00 Circulate Casing Crew 46.00 21:30 23:00 1.50 R/U and test 7"and 9 5/8"casing and liner top T/2500 psi Cementing Crew 16.50 for 30 min.good test Logging 10.50 23:00 23:30 0.50 Stroke back thru PBR,clear and smooth NU/ND Test 1.50 50.00 23:30 1:00 1.50 Building brine,blow down surface lines DST/Core 0.00 1:00 1:30 0.50 Displace dp w/8.7ppg brine and spacer Well Control 0.00 1:30 3:00 1.50 Building brine WOC 1.00 3:00 4:30 1.50 C/O fluid to packer fluid 8.6 ppg brine,Blow down top drive Safety Meetings 0.00 4:30 6:00 1.50 PJSM,POH LJD 5"drill pipe with polish mill F/8684'-8100' Drilling Cement 3.50 Note:Cleaning pits while POH F 0600hrs to 23:30 Circ/Other 7.00 56.50 24.00 TOTAL 24.00 684.00 BOTTOM HOLE ASSEMBLY QTY ITEM CONN DOWN CONN UP VENDOR O.D. I.D. GAUGE NECK LENGTH TOTAL LENGTH BHA TOTAL LENGTH 0.00 REMARKS&COMMENTS DIESEL No accidents near misses or spills. Diesel on Location day before 10.369 Next BOP Test 1-17-12 Diesel Used Last 24 2,650 Diesel Received 0 BOP Drill. TOTAL DIESEL 7,719 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck drivers 6 12 72 PRA DSM 2 12 24 Aimm Roust. 3 12 36 PRA Safety/PM 2 1 2 Baker tool 1 12 12 Canrig Mud Loggers 2 12 24 MI Swaco Mud Engineer 2 12 24 - TOTAL COUNT 42 TOTAL MAN HOURS 494 FROM I TO I LENGTH I JOINT 1 DESCRIPTION G/L 97' 97' Welded 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 BT ') 13 3/8 68#J-55(FC @ 2346,Shoe 42390') Interm i to ---..FROM TO LENGTH 11,,,".s DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-hy 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder Liner FROM TO LENGTH JOINTS DESCRIPTION 11101.00 11099.00 2.00 - Rat hole 11099.00 11099.00 0.55 - 7"BHI H266674701-Float Shoe 11099.00 11059.00 40.42 7"26#L-80 Vam Top HC with BHI-H266624704-Internal Float Collar 11059.00 11059.00 0.00 7"26#L-80 Vam Top NC with BHI-H266564702-Landing Collar internal 11059.00 8713.00 2386.00 58 7"26#L-80 Vam Top HC 8713.00 8709.00 4.86 - 7"Handling Pup-26#L-80 Vam Top HC,6.192"ID 8709.00 8707.00 1.73 - 7"Vam Top HC-RN Casing Nipple,5.88"No-Go ID 8707.00 8700.00 7.20 - 7"X 9.625"FlexLock Hanger,6.19"ID,BHI-29410WW16 8700.00 8684.00 15.45 - HR ZXPN Liner Top Packer,w/10.81"Polished Seal Bore Assembly,6.188"ID,BHI-H2964260W10 CINGSA-DAILY DRILLING REPORT 7 1/16/2012 Well Name CLU Storage 5 BHA#: 7"Tie back IM Days: John Nicholson - Current Depth: 11101' Location: Kenai,AK Target Depth: 11101' Cell Phone: (907) 299-4306 DSM Ftg/24hrs. 0 Field/Pool: Cannery Loop/Sterling C G�nR'for Nabors Alaska-Rig 105 E Nights: Mike Grubb - Days Since Spud 25 Present Run in hole with 7"tie back tubing Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER# JETS IN OUT FEET SIT GRADE TOTAL HOURS NV CASING ISIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor. 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40# L-80 BTC 8860' Slumberger 2-Jan Liner 7" 26# L-80 VAM-Top 11099-8684' Slumberger 14-Jan Tubing PUMP#1 PUMP#2 MUD PROPERTIES: ,MUD ADDITIVES: I Daily ICumulatiye PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT 8.7 GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS 27 S.ASH(50 lb bag) 42 LINER SIZE 6 LINER SIZE 6 R600/R300 4/3 KLA-GUARD 172 STOKELNGTH 9 STOKELNGTH 9 R200/R100 2/1 LOTORQ/776/STEELLUBE 4400 SPM SPM R6/R3 1/1 ASPHASOL SUPREME 233 GPS 3.17 GPS 3.17 PV 1 CONQOR404 8 GPM GPM YP 2 POTASSIUM CHLORIDE 370 415 PSI PSI GELS 1/1/2 FLOWZAN 2 183 BTMS UP MIN BTMS UP MIN API FLUID LOSS na PAC 139 TOT CIR MIN TOT CIR MIN CAKE APH/HT CF-DESCO II/SAPP 96 AVDP: AVDP: SOLIDS MYACIDE GA25 1 7 AVDC: AVDC: OIL/WATER /100 GEL-X 7 AVDC: AVDC: SAND CITRIC ACID/SAFE CARB/mix II 767 DRILL STRING&HYDRAULICS PH 8.3 RESINEX 24 STRING WT. WOB Pf/Mf .00/.00 CAUSTIC SODA 40 PICK UP RPM CHLORIDES 33200 SODIUM BICARBONATE/mrtabisulfr 3 104 SLACK OFF TFA CA BARITE/NUT PLUG/G SEAL 752 MAX PULL HSP VOL.PIT-(BBL) 120 LIQUIDS/screen dean 320 ECD PRESS DROP HOLE-(BBL) 706 SOLIDS (BBLS hauled by AIMM) 979 8260 DCOD JET VEL API SCREEN 4x60 4x60 Daily Mud Cum. 1355 16599 L ACTIVITY SUMMARY TIME SUMMARY Start I Finish fHours I Description Detail _ I Daily I Cumulative 6:00 12:00 6.00 Continue POH with DP and polish tool F/8100'-3440 RU/RD 3.00 135.00 12:00 13:00 1.00 Service Rig Adjust skate Crew Change Drilling 137.00 13:00 _ _ 16:00 3.00 POH LID Drill Pipe F/3440'to PBR mill.B/0&LID Service/Repair Rig 1.00 27.50 16:00 19:00 3.00 C/O bails,Rig up WFD casing tongs and elevators, Surveys 0.00 19:00 19:30 0.50 Pull wear ring Tripping 19.50 224.00 19:30 6:00 10.50 PJSM,M/U Locator seal and RIH with 7 tie back tubing to Change BHA 0.00 8050' Casing Crew 46.00 Cementing Crew 16.50 Logging 10.50 NU/ND Test 50.00 DST/Core 0.00 Well Control 0.00 WOC 1.00 Safety Meetings 0.00 Drilling Cement 3.50 Note:clean pits and haul off mud Circ/Other 0.50 57.00 24.00 TOTAL 24.00 708.00 BOTTOM HOLE ASSEMBLY QTY ITEM I CONN DOWN CONN UP J VENDOR I O.D. t I.D. GAUGE I NECK LENGTH iITOTAL LENGTH BHA TOTAL LENGTH 0.00 REMARKS&COMMENTS DIESEL No accidents near misses or spills. Load out MI mud products Diesel on Location day before 7,719 Next BOP Test 1-17-12 Diesel Used Last 24 2,141 Move all drill pipe off location Diesel Received BOP Drill, TOTAL DIESEL 5,578 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Aimm Vac truck drivers 6 10 60 PRA DSM 2 12 24 Weathorford Casing crew 4 10 40 PRA Safety/PM 2 1 2 Baker tool 1 12 12 Canrig Mud Loggers 2 12 24 FMC hanger 1 12 12 MI Swaco Mud Engineer 2 12 24 TOTAL COUNT 44 TOTAL MAN HOURS 498 FROM I TO I LENGTH I JOINT I DESCRIPTION G/L _ 97' 97' WeIdad 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 BT 1 13 3/8 68#J-55(FC @ 2346,Shoe @2390') Intermediate - FROM TO LENGTH JOu...x DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-hy 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder Liner FROM TO LENGTH JOINTS DESCRIPTION 11101.00 11099.00 2.00 - Rat hole 11099.00 11099.00 0.55 - 7"BHI H266674701-Float Shoe 11099.00 11059.00 40.42 7"26#L-80 Vam Top HC with BHI-H266624704-Internal Float Collar 11059.00 11059.00 0.00 7"26#L-80 Vam Top HC with BHI-H266564702-Landing Collar internal 11059.00 8713.00 2386.00 58 7"26#L-80 Vam Top HC 8713.00 8709.00 4.86 - 7"Handling Pup-26#L-80 Vam Top HC,6.192"ID 8709.00 8707.00 1.73 - 7"Vam Top HC-RN Casing Nipple,5.88"No-Go ID 8707.00 8700.00 7.20 - 7"X 9.625"FlexLock Hanger,6.19"ID,BHI-29410WW16 8700.00 8684.00 15.45 - HR ZXPN Liner Top Packer,w/10.81"Polished Seal Bore Assembly,6.188"ID,BHI-H2964260W10 CINGSA-DAILY DRILLING REPORT 7 1/17/2012 Well Name CLU Storage 5 BHA#: MIDays: John Nicholson Current Depth: 11101' Location: Kenai,AK Target` 11101' Cell Phone: (907) 299-4306 Rig Ftg/24hrs. 0 Field/Pool: Cannery Loop/Sterling C Contractor Nabors Alaska-Rig 105E NghM . Mike Grubb Present N/D BOP Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Days Since Spud 26 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER It JETS IN OUT FEET BIT GRADE TOTAL HOURS n+e• CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40# L-80 BTC 8860' Slumberger 2-Jan Liner 7" 26# L-80 VAM-Top 11099-8684' Slumberger 14-Jan Tubing 7" 26# L-80 VAM-Top 8684' Tie back 17-Jan PUMP#1 PUMP#2 IMUD PROPERTIES: MUD ADDITIVES: I Daily Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS S.ASH(50 lb bag) 42 LINER SIZE 6 LINER SIZE 6 R600/R300 KLA-GUARD 172 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 LOTORQ/776/STEEL LUBE 4400 SPM SPM R6/R3 ASPHASOL SUPREME 233 GPS 3.17 GPS 3.17 PV CONQOR 404 8 GPM GPM YP POTASSIUM CHLORIDE 415 PSI PSI GELS FLOWZAN 183 BTMS UP MIN BTMS UP MIN API FLUID LOSS PAC 139 TOT CIR MIN TOT CIR MIN CAKE APH/HT CF-DESCO II/SAPP 96 AVDP: AVDP: SOLIDS MYACIDE GA25 7 AVDC: AVDC. OIL/WATER GEL-X 7 AVDC: AVDC: SAND CITRIC ACID/SAFE CARB/mix II 767 DRILL STRING&HYDRAULICS PH RESINEX 24 STRING WT. WOB Pf/Mf CAUSTIC SODA 40 PICK UP RPM CHLORIDES SODIUM BICARBONATE/mrtabisolrr 104 SLACK OFF TFA CA BARITE/NUT PLUG/G SEAL 752 MAX PULL HSP VOL.PIT-(BBL) LIQUIDS/screen clean 320 ECD PRESS DROP HOLE-(BBL) SOLIDS (BBLS hauled by AIMM) 284 8544 DCOD JET VEL API SCREEN Daily Mud Cum. 284 16883 ACTIVITY SUMMARYTIME SUMMARY I Start I Finish I Hours I Description Detail I Daily I Cumulative 6:00 Continue RIH W/locator seal and 7"tie back tubing F/8050' RU/RD 8.50 143.50 To top of ZXP @ 8684'Pump into ZXP W/250 Pressure Inc. Drilling 137.00 to 435psi confirm erteungJhe_ BR.Set 20k down.P/U and Service/Repair Rig 27.50 space our 67'to SSSV,run controiltnes-�nd make Surveys 0.00 14:30 8.50 up to?tiffs on the tubing hanger.Test control lines te,5000psi Tripping 224.00 14:30 R/k(and reverse circulate 4bbls diesel followed by 244bb1s Change BHA 0.00 15:30 1.00 6✓KCL with conquer 303 inhibitor in 7X 9 5/8 annulus. Caing Crew __ 8.50 54.50 15:30 16:00 0.50 R/U and test 7"X 9 5/8 annulus 1500psi F/30min test good Ce7tentinq Crew 16.50 16:00 16:30 0.50 R/U and test 7"Tubing to 3000psi F/30min,test good Logging 10.50 16:30 17:00 0.50 Install Back pressure Valve JNU/ND Test 1.00 51.00 17:00 21:00 4.00 F'/bsh all surface line,clean out rig floor drip pans and pipe - DST/Core 0.00 blo own all lines,flush lines in pits Well Control 0.00 21:00 23:00 2.00 Open B oors and rinse stack,remove V nd prep to WOC 1.00 ship,Remove b I s Safety Meetings 0.00 23:00 6:00 7.00 N/D BOP stack,pull riser,R/D choke and kill line&double gate Drilling Cement 3.50 cleaning pits, Circ/Other 6.00 63.00 . 24.00 TOTAL 24.00 732.00 ' r BOTTOM HOLE ASSEMBLY QTY ITEM CONN DOWN CONN UP VENDOR O.D. I.D. GAUGE NECK LENGTH TOTAL LENGTH BHA TOTAL LENGTH 0.00 REMARKS&COMMENTS DIESEL No accidents near misses or spills. Load out MI mud products Diesel on Location day before 5,578 Diesel Used Last 24 2,045 haul off brine and rinse water Diesel Received Used 3ea 7"pups 14.74' placed under the last full joint of 7"tubing for space out TOTAL DIESEL 3,533 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 - 12.5 300 Aimm Vac truck drivers 3 12 36 PRA DSM 2 12 24 PRA Safety/PM 1 1 2 Baker tool 1 12 12 Canriq Riq down 1 12 12 FMC hanger 1 12 12 MI Swaco Mud Engineer 1 10.5 10.5 Canrig Rig Down 1 12 12 - TOTAL COUNT 35 TOTAL MAN HOURS 420.5 FROM I TO I LENGTH I JOINT I DESCRIPTION G/L 97' 97' Wel,+Ad 20"133#X-56 Welded Conductor Pipe _ RKB 2390' 2390 BT 1 13 3/8 68#J-55(FC @ 2346,Shoe @2390') Intermediate _ FROM TO LENGTH JO...,S DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC _ 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-hy 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder Liner FROM TO LENGTH JOINTS DESCRIPTION 11101.00 11099.00 2.00 - Rat hole 11099.00 11099.00 0.55 - 7"BHI H266674701-Float Shoe 11099.00 11059.00 40.42 7"26#L-80 Vam Top HC with BHI-H266624704-Internal Float Collar 11059.00 11059.00 0.00 7"26#L-80 Vam Top HC with BHI-H266564702-Landing Collar internal 11059.00 8713.00 2386.00 58 7"26#L-80 Vam Top HC 8713.00 8709.00 4.86 - 7"Handling Pup-26#L-80 Vam Top HC,6.192"ID 8709.00 8707.00 1.73 - 7"Vam Top HC-RN Casing Nipple,5.88"No-Go ID 8707.00 8700.00 7.20 - 7"X 9.625"FlexLock Hanger,6.19"ID,BHI-29410WW16 8700.00 , 8684.00 15.45 - HR ZXPN Liner Top Packer,w/10.81"Polished Seal Bore Assembly,6.188"ID,BHI-H2964260W10 Tubin FROM TO LENGTH JOINTS DESCRIPTION 8683.00 1.40 - 7 3/8"Bullet Locator Seal Assembly-BHI-H297551040-6.184"ID 8683.00 8672.00 9.93 - 7"26#L-80 Vam Top HC-Casing Pup 8672.00 175.82 8498.25 207 7"26#L-80 Vam Top HC 175.82 170.93 4.89 - 7"26#L-80 Vam Top HC-Casing Pup 170.93 167.48 3.45 - 7"Vam Top-S.S.S.V.Nipple-102026798,5.963"ID-W/1/4"S.S.Control Line-X-Profile 167.48 162.60 4.88 - 7"26#L-80 Vam Top HC-Casing Pup 162.60 80.92 81.68 2 7"26#L-80 Vam Top HC 80.92 76.03 4.89 - 7"26#L-80 Vam Top HC-Casing Pup 76.03 71.13 4.90 - 7"26#L-80 Vam Top HC-Casing Pup 71.13 66.18 4.95 7"26#L-80 Vam Top HC-Casing Pup 66.18 26.03 40.15 1 7"26#L-80 Vam Top HC 26.03 23.85 2.18 - 7"26#L-80 Vam Top HC Pup Joint 23.85 23.00 0.85 - 7"26#L-80 Vam Top HC-FMC Tubing Hanger W/SBMS Metal Seal 20.50 0.00 20.50 - RT to hanger CIN GSA-DAILY DRILLING REPORT 7 1/18/2012 Well Name CLU Storage 5 BHA#: IM Days: John Nicholson Current Depth: 11101' Location: Kenai,AK Target 11101' Cell Phone: (907) 299-4306 Depth, Ftgr24hrs. 0 Field/Pool: Cannery Loop/Sterling C Contra or, Nabors Alaska-Rig 105 E Nights Mike Grubb Days Since Spud 27 Present Demob NAD 105 Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS cr0 CASING I SIZE I WEIGHT I GRADE I,THREAD( DEPTH I CEMENT COMPANY I DATE I - Gond uctor: 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40# L-80 BTC 8860' Slumberger 2-Jan Liner 7" 26# L-80 VAM-Top 11099-8684' Slumberger 14-Jan Tubing 7" 269 L-80 VAM-Top 8684' Tie back 17-Jan space out 2.5'above no go PUMP#1 PUMP#2 'MUD PROPERTIES: IMOD ADDITIVES: __ Daily Cumulative DPUMP MANE Gardner Denver PUMP MANF Gardner Denver WEIGHT GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS S.ASH(50 lb bag) 42 LINER SIZE 6 LINER SIZE 6 R600/R300 KLA-GUARD 172 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 LOTORQ/776/STEEL LUBE 4400 SPM SPM R6/R3 ASPHASOL SUPREME 233 GPS GPS PV CONDOR 404 8 GPM GPM YP POTASSIUM CHLORIDE 415 PSI PSI GELS FLOWZAN 183 BTMS UP MIN BTMS UP MIN API FLUID LOSS PAC 139 TOT CIR MIN TOT CIR MIN CAKE APH/HT CF-DESCO II/SAPP 96 AVDP: AVDP: SOLIDS MYACIDE GA25 7 AVDC: AVDC: OIL/WATER GEL-X 7 AVDC: AVOQ SAND CITRIC ACID/SAFE CARB/Mx II 767 DRILL STRING&HYDRAULICS PH RESINEX 24 STRING WT. WOB Pt/Mt CAUSTIC SODA 40 PICKUP RPM CHLORIDES SODIUM BICARBONATE/rnrtabisu#t 104 SLACK OFF TFA CA BARITE/NUT PLUG/G SEAL 752 MAX PULL HSP VOL.PIT-(BBL) LIQUIDS/screen clean 320 ECD PRESS DROP HOLE-(BBL) SOLIDS (BBLS hauled by AIMM) 142.7 8686.7 DCOD JET VEL API SCREEN Daily Mud Cum. 142.7 17025.7 L ACTIVITY SUMMARY TIME SUMMARY Start I Finish I Hours I Description Detail I Daily I Cumulative 6:00 9:00 3.00 N/D BOP stack,break down all components&move out RU/RD 13.00 156.50 9:00 20:00 11.00 N/D up FMC bonnet and master valve Test to 5000psi OK Drilling 137.00 continue FUD of inner connects and rig while N/U&test well Service/Repair Rig 27.50 head,test fail,trouble shoot and pull plug,install back up Surveys 0.00 and test 300/5000psi good test(cont.with RID and clean up Tripping 224.00 during test attempts)finish cleaning pits Change BHA 0.00 REALEASED RIG AT 20:00 Casing Crew 54.50 _ 20:00 6:00 10.00 Clean,dress,and pickle mud pumps,start disconnecting Cementing Crew 16.50 dressor sleeves,general clean up and scrubbing,organize Logging 10.50 yard,remove kelly hose,power wash windwalls on rig floor NU/ND Test 11.00 62.00 DST/Core 0.00 Well Control 0.00 . WOC 1.00 Safety Meetings 0.00 Drilling Cement 3.50 Circ/Other 63.00 24.00 TOTAL 24.00 756.00 BOTTOM HOLE ASSEMBLY _ QTY I ITEM _ I CONN DOWN CONN UP Y VENDOR I O.D. I- I.D. W __GAUGE I NECK I LENGTH TOTAL LENGTH BHA TOTAL LENGTH 6.00 REMARKS&COMMENTS DIESEL No accidents near misses or spills. Diesel on Location day before 3,533 load out mud shack and Canrig unit Diesel Used Last 24 1,599 realeased mud loggers and mud men Diesel Received 1,500 shipped variable rams and spare rubbers @ 16:00 TOTAL DIESEL 3,434 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 FMC hanger 1 12 12 PRA DSM 2 12 24 Aimm vac 3 12 36 PRA Safety/PM 1 1 2 - TOTAL COUNT 31 TOTAL MAN HOURS 374 FROM I TO I LENGTH I JOINT I DESCRIPTION G/L 97' 97' WeIrc.,r1 20"133#X-56 Welded Conductor Pipe _ RKB 2390' 2390 BT ) 13 3/8 68#J-55(FC @ 2346,Shoe @2390') Intermediate FROM TO LENGTH JOn.1S DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-hy , 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder Liner FROM TO LENGTH JOINTS DESCRIPTION 11101.00 11099.00 2.00 - Rat hole 11099.00 11099.00 0.55 - 7"BHI H266674701-Float Shoe 11099.00 11059.00 40.42 7"26#L-80 Vam Top HC with BHI-H266624704-Internal Float Collar 11059.00 11059.00 0.00 7"26#L-80 Vam Top HC with BHI-H266564702-Landing Collar internal 11059.00 8713.00 2386.00 58 7"26#L-80 Vam Top HC 8713.00 8709.00 4.86 - 7"Handling Pup-26#L-80 Vam Top HC,6.192"ID 8709.00 8707.00 1.73 - 7"Vam Top HC-RN Casing Nipple,5.88"No-Go ID 8707.00 8700.00 7.20 - 7"X 9.625"FlexLock Hanger,6.19"ID,BHI-29410WW16 8700.00 . 8684.00 15.45 - HR ZXPN Liner Top Packer,w/10.81"Polished Seal Bore Assembly,6.188"ID,BHI-H2964260W10 Tubing FROM TO LENGTH JOINTS DESCRIPTION 8683.00 1.40 - 7 3/8"Bullet Locator Seal Assembly-BHI-H297551040-6.184"ID 8683.00 8672.00 9.93 - 7"26#L-80 Vam Top HC-Casing Pup 8672.00 175.82 7150.27 207 7"26#L-80 Vam Top HC 175.82 170.93 4.89 - 7"26#L-80 Vam Top HC-Casing Pup 170.93 167.48 3.45 - 7"Vam Top-S.S.S.V.Nipple-102026798,5.963"ID-W/1/4"S.S.Control Line-X-Profile 167.48 162.60 4.88 - 7"26#L-80 Vam Top HC-Casing Pup 162.60 80.92 121.83 2 7"26#L-80 Vam Top HC 80.92 76.03 4.89 - 7"26#L-80 Vam Top HC-Casing Pup 76.03 71.13 4.90 - 7"26#L-80 Vam Top HC-Casing Pup 71.13 66.18 4.95 7"26#L-80 Vam Top HC-Casing Pup 66.18 26.03 40.15 1 7"26#L-80 Vam Top HC 26.03 23.85 2.18 - 7"26#L-80 Vam Top HC Pup Joint 23.85 23.00 0.85 - 7"26#L-80 Vam Top HC-FMC Tubing Hanger W/SBMS Metal Seal 20.50 0.00 20.50 - RT to hanger CINGSA-DAILY DRILLING REPORT 7 1/19/2012 Well Name CLU Storage 5 BHA#: M Days. John Nicholson Current Depth: 11101' Location: Kenai,AK Target 11101' Cell Phone: (907) 299-4306 Depth: Ftg/24hrs. 0 Field/Pool: Cannery Loop I Sterling C Contractor.dor Nabors Alaska-Rig 105E NghM: Mike Grubb Days Since Spud 28 OPresent ti m RID NAD 105E Prep for shipping Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 pera DRILLING DATA BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS rte CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor 20 1339 X-56 Welded 97' N/A July Surface: 13 3/8 689 J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40# L-80 BTC 8860' Slumberger 2-Jan Liner 7" 26# L-80 VAM-Top 11099-8684' Slumberger 14-Jan Tubing 7" 269 L-80 VAM-Top 8684' Tie back 17-Jan space out 2.5'above no go PUMP#1 IPUMP#2 IMUD PROPERTIES: 'MUD ADDITIVES: I Daily 'Cumulative PUMP MANE Gardner Denver PUMP MANE Gardner Denver WEIGHT GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS S.ASH(50 lb bag) 42 LINER SIZE 6 LINER SIZE 6 R600/R300 KLA-GUARD 172 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 LOTORO/776/STEEL LUBE 4400 SPM SPM R6/R3 ASPHASOL SUPREME 233 GPS GPS PV CONDOR 404 8 GPM GPM YP POTASSIUM CHLORIDE 415 PSI PSI GELS FLOWZAN 183 BTMS UP MIN BTMS UP MIN API FLUID LOSS PAC 139 TOT CIR MIN TOT CIR MIN CAKE APH/HT CF-DESCO II/SAPP 96 AVDP: AVDP: SOLIDS MYACIDE GA25 7 AVDC: AVDC: OIL/WATER GEL-X 7 AVDC: AVDC: SAND CITRIC ACID/SAFE CARB/mix II 767 DRILL STRING&HYDRAULICS PH RESINEX 24 STRING WT. WOB Pf/Mf CAUSTIC SODA 40 PICK UP RPM CHLORIDES SODIUM BICARBONATE/mrtabisNR 104 SLACK OFF TFA CA BARITE/NUT PLUG/G SEAL 752 MAX PULL HSP VOL.PIT-(BBL) LIQUIDS/screen clean 320 ECD PRESS DROP HOLE-(BBL) SOLIDS (BBLS hauled by AIMM) 92 8778.7 DCOD JET VEL API SCREEN Daily Mud Cum. 92 17117.7 ACTIVITY SUMMARY TIME SUMMARY Start I Finish I Hours I Description Detail I Daily I Cumulative 6:00 9:00 3.00 Continue Demob of NAD 105.Complete pressure washing RU/RD 24.00 180.50 of rig floor wind walls. Drilling 137.00 9:00 Pressure wash and clean mezzanine sub Remove exterior Service/Repair Rig 27.50 lighting.Break apart dresser sleeves on lower pit sections. Surveys 0.00 12:00 3.00 R/D low pressure mud lines Tripping 224.00 12:00 Pressure lower sub,walkways and stairs.Continue to R/D Change BHA 0.00 lighting.Remove pipe shed door brackets from roof of pipe Casing Crew 54.50 shed.Clean out/chip mud from centrifuge dump area. Cementing Crew 16.50 and cuttings tank walls under shaker discharge.Load out Logging 10.50 cuttings tank and centrifuge dump buckets and ship to Aimm NU/ND Test 62.00 ,,) 18:00 6.00 for cleaning. DST/Core 0.00 $� /y 18:00 Prep derrick for move,set top drive on shipping pins and dis- Well Control 0.00 I II connect blocks,R/D kelly hose and service loop,remove WOG 1.00 / T 0:00 6.00 exterior lights,empty aux water tank,R/D charge pumps Safety Meetings 0.00 0:00 R/D degasser,pump pop offs&bleeder lines,flow line,pits Drilling Cement 3.50 �'stv� 6:00 6.00 exaust fans,rig tongs,stand pipe,prep stabbing board to pull, Circ/Other 63.00 24.00 TOTAL 24.00 780.00 BOTTOM HOLE ASSEMBLY QTY ITEM CONN DOWN CONN UP VENDOR O.D. I.D. GAUGE NECK LENGTH TOTAL LENGTH BHA TOTAL LENGTH 0.00 REMARKS 8 COMMENTS DIESEL No accidents near misses or spills. Diesel on Location day before 3,434 shipped variable rams and spare rubbers @ 16:00 1-17-12 Diesel Used Last 24 744 outside temp as low as-28 degrees Diesel Received 1,500 TOTAL DIESEL 4,190 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 PRA DSM 2 12 24 Aimm vac 3 12 36 PRA Safety/PM 1 1 2 - TOTAL COUNT 30 TOTAL MAN HOURS 362 FROM I TO I LENGTH I JOINT I DESCRIPTION G/L 97' 97' WPi'=wI 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 BT 1 13 3/8 68#J-55(FC @ 2346,Shoe(a2390') Intermediate FROM TO LENGTH JOii.,S- DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 _ 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-hy 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder Liner FROM TO LENGTH JOINTS DESCRIPTION 11101.00 11099.00 2.00 - Rat hole 11099.00 11099.00 0.55 - 7"BHI H266674701-Float Shoe 11099.00 11059.00 40.42 7"26#L-80 Vam Top HC with BHI-H266624704-Internal Float Collar 11059.00 11059.00 0.00 7"26#L-80 Vam Top HC with BHI-H266564702-Landing Collar internal 11059.00 8713.00 2386.00 58 7"26#L-80 Vam Top HC 8713.00 8709.00 4.86 - 7"Handling Pup-26#L-80 Vam Top HC,6.192"ID 8709.00 8707.00 1.73 - 7"Vam Top HC-RN Casing Nipple,5.88"No-Go ID 8707.00 8700.00 7.20 - 7"X 9.625"FlexLock Hanger,6.19"ID,BHI-29410WW16 8700.00 8684.00 15.45 - HR ZXPN Liner Top Packer,w/10.81"Polished Seal Bore Assembly,6.188"ID,BHI-H2964260W10 Tubing FROM TO LENGTH JOINTS DESCRIPTION 8683.00 1.40 - 7 3/8"Bullet Locator Seal Assembly-BHI-H297551040-6.184"ID 8683.00 8672.00 9.93 - 7"26#L-80 Vam Top HC-Casing Pup 8672.00 175.82 7150.27 207 7"26#L-80 Vam Top HC 175.82 170.93 4.89 - 7"26#L-80 Vam Top HC-Casing Pup _ -,___ 170.93 167.48 3.45 - 7"Vam Top-S.S.S.V.Nipple-102026798,5.963"ID-W/1/4"S.S.Control Line-X-Profile 167.48 162.60 4.88 - 7"26#L-80 Vam Top HC-Casing Pup 162.60 80.92 121.83 2 7"26#L-80 Vam Top HC 80.92 76.03 4.89 - 7"26#L-80 Vam Top HC-Casing Pup 76.03 71.13 4.90 - 7"26#L-80 Vam Top HC-Casing Pup 71.13 66.18 4.95 7"26#L-80 Vam Top HC-Casing Pup 66.18 26.03 40.15 1 7"26#L-80 Vam Top HC 26.03 23.85 2.18 - 7"26#L-80 Vam Top HC Pup Joint 23.85 23.00 0.85 - 7"26#L-80 Vam Top HC-FMC Tubing Hanger W/SBMS Metal Seal 20.50 0.00 20.50 - RT to hanger CINGSA-DAILY DRILLING REPORT 7 1/20/2012 Well Name CLU Storage 5 BHA#: ,M Days: John Nicholson Current Depth: 11101 Location: Kenai,AK Target 11101' Cell Phone: (907) 299-4306 Depth: Ftg/24hrs. 0 Field/Pool: Cannery Loop I Sterling C Convactor:ig Nabors Alaska-Rig 105 E DSM Mike Grubb Days Since Spud 29 Present RID NAD 105E Prep for shipping Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT it SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS 71B CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH 1 CEMENT COMPANY I DATE I - conductoc 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' _ Slumberger 25-Dec Intermediate 9 5/8 40# L-80 BTC 8860' _ Slumberger 2-Jan Liner 7" 26# L-80 VAM-Top 11099-8684' Slumberger 14-Jan Tubing 7" 26# L-80 VAM-Top 8684' Tie back 17-Jan space out 2.5'above no go PUMP#1 LPUMP#2 IMUD PROPERTIES: (MUD ADDITIVES: Daily (Cumulative PUMP MANE Gardner Denver PUMP MANF Gardner Denver WEIGHT GEL(50 Ib bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS S.ASH(50 lb bag) 42 LINER SIZE 6 LINER SIZE 6 R600/R300 KLA-GUARD 172 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 LOTORO/776/STEEL LUBE 4400 SPM SPM R6/R3 ASPHASOL SUPREME 233 GPS GPS PV CONQOR 404 8 GPM GPM YP POTASSIUM CHLORIDE 415 PSI PSI GELS FLOWZAN 183 BTMS UP MIN BTMS UP MIN API FLUID LOSS PAC 139 TOT CIR MIN TOT CIR MIN CAKE APH/HT CF-DESCO II/SAPP 96 AVDP: AVDP: SOLIDS MYACIDE GA25 7 AVDC: AVDC: OIL WATER GEL-X 7 AVDC: AVDC: SAND CITRIC ACID/SAFE CARB/mix II 767 DRILL STRING&HYDRAULICS PH RESINEX 24 STRING WT. WOB Pf/Mf CAUSTIC SODA 40 PICK UP RPM CHLORIDES SODIUM BICARBONATE/mrtabisulfii 104 SLACK OFF TFA CA BARITE/NUT PLUG/G SEAL 752 MAX PULL HSP VOL.PIT-(BBL) LIQUIDS/screen dean 320 ECD PRESS DROP HOLE-(BBL) SOLIDS (BBLS hauled by AIMM) 8778.7 DCOD JET VEL API SCREEN Daily Mud Cum. 0 17117.7 ACTIVITY SUMMARY TIME SUMMARY :-Marr•.,- -_ Finish I Hours I Description DetailDaily I Cumulative 6:00 Demobe NAD 105 E,Palletize and box up hoses parts and RU/RD 24.00 204.50 pieces,prep top side of service loop,disconnect electrical Drilling 137.00 for derrick,R/D turnbuckles on rig floor windwalls,RID pipe Service/Repair Rig 27.50 shed,R/D;mud manifold,water line,gen exausts,pickle power Surveys 0.00 18:00 12.00 washers and test pump,pull wires in motor complex Tripping 224.00 18:00 R/D lay down machine,finish rig down pipe shed and load out, Change BHA 0.00 RID cattle chute&flap,Bag and prep mud lines,Inspect Casing Crew 54.50 derrick,finish rig down of poor boy and choke house,lay down Cementing Crew 16.50 6:00 and load out,fold down back windwalls Logging 10.50 NU/ND Test 62.00 DST/Core 0.00 Well Control 0.00 WOC 1.00 Safety Meetings 0.00 Note:6 loads moved off location by Carlile Drilling Cement 3.50 Circ/Other 63.00 12.00 TOTAL 24.00 804.00 BOTTOM HOLE ASSEMBLY QTY ITEM CONN DOWN CONN UP VENDOR O.D. I.D. GAUGE NECK LENGTH TOTAL LENGTH BHA TOTAL LENGTH 0.00 REMARKS&COMMENTS DIESEL No accidents near misses or spills. Diesel on Location day before 4,190 shipped variable rams and spare rubbers @ 16:00 1-17-12 Diesel Used Last 24 2,689 outside temp as low as-26 Diesel Received 1,500 TOTAL DIESEL 1,501 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Peak rig move 5 12 60 PRA DSM 2 12 24 Carlile trucking 5 9 45 PRA Safety/PM 2 3 6 - TOTAL COUNT 38 TOTAL MAN HOURS 435 FROM I TO I LENGTH I JOINT I DESCRIPTION G/L 97' 97' Welded 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 BT 1 13 3/8 68#J-55(FC @ 2346,Shoe @2390') Intermediate - FROM TO LENGTH JOE...s DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 _ 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-hy 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder Liner FROM TO LENGTH JOINTS DESCRIPTION 11101.00 11099.00 2.00 - Rat hole 11099.00 11099.00 0.55 - 7"BHI H266674701-Float Shoe 11099.00 11059.00 40.42 7"26#L-80 Vam Top HC with BHI-H266624704-Internal Float Collar 11059.00 11059.00 0.00 7"26#L-80 Vam Top HC with BHI-H266564702-Landing Collar internal 11059.00 8713.00 2386.00 58 7"26#L-80 Vam Top HC 8713.00 8709.00 4.86 - 7"Handling Pup-26#L-80 Vam Top HC,6.192"ID 8709.00 8707.00 1.73 - 7"Vam Top HC-RN Casing Nipple,5.88"No-Go ID 8707.00 8700.00 7.20 - 7"X 9.625"FlexLock Hanger,6.19"ID,BHI-29410WW16 8700.00 8684.00 15.45 - HR ZXPN Liner Top Packer,w/10.81"Polished Seal Bore Assembly,6.188"ID,BHI-H2964260W10 Tubing FROM TO LENGTH JOINTS ' DESCRIPTION 8683.00 1.40 - 7 3/8"Bullet Locator Seal Assembly-BHI-H297551040-6.184"ID 8683.00 8672.00 9.93 - 7"26#L-80 Vam Top HC-Casing Pup .-_-_ 8672.00 175.82 7150.27 207 7"26#L-80 Vam Top HC 175.82 170.93 4.89 - 7"26#L-80 Vam Top HC-Casing Pup ___ 170.93 167.48 3.45 - 7"Vam Top-S.S.S.V.Nipple-102026798,5.963"ID-W/1/4"S.S.Control Line-X-Profile 167.48 162.60 4.88 - 7"26#L-80 Vam Top HC-Casing Pup 162.60 80.92 121.83 2 7"26#L-80 Vam Top HC 80.92 76.03 4.89 - 7"26#L-80 Vam Top HC-Casing Pup 76.03 71.13 4.90 - 7"26#L-80 Vam Top HC-Casing Pup 71.13 66.18 4.95 7"26#L-80 Vam Top HC-Casing Pup 66.18 26.03 40.15 1 7"26#L-80 Vam Top HC 26.03 23.85 2.18 - 7"26#L-80 Vam Top HC Pup Joint 23.85 23.00 0.85 - 7"26#L-80 Vam Top HC-FMC Tubing Hanger W/SBMS Metal Seal 20.50 0.00 20.50 - RT to hanger CINGSA-DAILY DRILLING REPORT Date 1/21/2012 Well Name CLU Storage 5 BHA it: IM Days: John Nicholson Current Depth: 11101' Location: Kenai,AK Target 11101' Cell Phone: (907) 299-4306 Depth: Ftgl24hrs. 0 Field/Pool: Cannery Loop/Sterling C ConRig for Nabors Alaska-Rig 105 E N QhG' Mike Grubb Days Since Spud 30 Present Demobe NAD 105E Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS rrs CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor 20 133# X-56 Welded 97' N/A July - surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40# L-80 BTC 8860' Slumberger 2-Jan Liner 7" 26# L-80 VAM-Top 11100'-8684' Slumberger 14-Jan Tubing 7" 266 L-80 VAM-Top 8684' Tie back 17-Jan space out 2.5'above no go PUMP#1 IPUMP#2 IMUD PROPERTIES: IMUD ADDITIVES: I Daily [Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS S.ASH(50 lb bag) 42 LINER SIZE 6 LINER SIZE 6 R600/R300 KLA-GUARD 172 STOKE LNGTH 9 STOKE LNGTH 9 R200IR100 LOTORQ/776/STEEL LUBE 4400 SPM SPM RE/R3 ASPHASOL SUPREME 233 GPS GPS PV CONDOR 404 8 GPM GPM YP POTASSIUM CHLORIDE 415 PSI PSI GELS FLOWZAN 183 BTMS UP MIN BTMS UP MIN API FLUID LOSS PAC 139 TOT CIR MIN TOT CIR MIN CAKE APH/HT CF-DESCO II/SAPP 96 AVDP: AVDP: SOLIDS MYACIDE GA25 7 AVDC: AVDC: OIL/WATER GEL-X 7 AVDC: AVDC: SAND CITRIC ACID/SAFE CARE/mix II 767 DRILL STRING&HYDRAULICS PH RESINEX 24 STRING WT. WOB Pf/Mf CAUSTIC SODA 40 PICK UP RPM CHLORIDES SODIUM BICARBONATE/mrtabisuin 104 SLACK OFF TFA CA BARITE/NUT PLUG/G SEAL 752 MAX PULL HSP VOL.PIT-(BBL) LIQUIDS/screen clean 320 ECD PRESS DROP HOLE-(BBL) SOLIDS (BBLS hauled by AIMM) 8778,7 DCOD JET VEL API SCREEN Daily Mud Cum. 0 17117.7 t ACTIVITY SUMMARY I TIME SUMMARY Start I Finish T Hours I Description Detail I Daily I Cumulative 6:00 Demob NAD 105 E,lay down drillers side and front sub RU/RD 24.00 228.50 wind walls remove pins and dissemble for load out.Crane Drilling 137.00 13:00 7.00 down service loops,&Top Drive,load out Service/Repair Rig 27.50 13:00 Prep mast for scope down,string up yoke and bridal up. Surveys 0.00 Scope down lower section of mast.Crane down board. Tripping 224.00 and break down for shipping.Remove lower mast section Change BHA 0.00 18:00 5.00 and load out. Casing Crew 54.50 18:00 Remove middle section of mast,set crown on A leg,R/D Cementing Crew 16.50 tuggers and manriders, hang blocks,spool line off drum onto Logging 10.50 0:00 6.00 spool,remove dog knot,load out trailers,unplug moduals NU/ND Test 62.00 0:00 Lower crown section and unstring blocks,lay down and lay DST/Core 0.00 over crown&load out,Remove A leg section from rig floor Well Control 0.00 6:00 6.00 prep for shipping Remove iron rough neck and load out WOC 1.00 Safety Meetings 0.00 Drilling Cement 3.50 Total loads shipped off location 14,4 more trailer full&ready Circ/Other 63.00 24.00 Continue building loads with matting boards and windwalls. TOTAL 24.00 828.00 BOTTOM HOLE ASSEMBLY QTY ITEM I CONN DOWN I CONN UP 1 VENDOR I O.D. I.D. I GAUGE NECK I LENGTH (TOTAL LENGTH BHA TOTAL LENGTH 0.00 REMARKS&COMMENTS DIESEL No accidents near misses or spills. Diesel on Location day before 1,501 Hold PJSM on all critical picks with crane Diesel Used Last 24 1,149 Diesel Received 1,496 TOTAL DIESEL 1,848 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Peak rig move 6 12 72 PRA DSM 2 12 24 Carlile trucking 5 12 60 PRA Safety/PM 2 1 2 Foster Const. flagging 2 12 24 - TOTAL COUNT 41 TOTAL MAN HOURS 482 FROM I TO I LENGTH I JOINT I DESCRIPTION G/L 97' 97' Wel,'-,1 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 BT 7 13 3/8 68#J-55(FC @ 2346,Shoe @23901 Intermediate - FROM TO LENGTH IOI...S DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-hy 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder Liner FROM TO LENGTH JOINTS DESCRIPTION 11101.00 11099.00 2.00 - Rat hole 11099.00 11099.00 0.55 - 7"BHI H266674701-Float Shoe 11099.00 11059.00 40.42 7"26#L-80 Vam Top HC with BHI-H266624704-Internal Float Collar 11059.00 11059.00 0.00 7"26#L-80 Vam Top HC with BHI-H266564702-Landing Collar internal 11059.00 8713.00 2386.00 58 7"26#L-80 Vam Top HC 8713.00 8709.00 4.86 - 7"Handling Pup-26#L-80 Vam Top HC,6.192"ID 8709.00 8707.00 1.73 - 7"Vam Top HC-RN Casing Nipple,5.88"No-Go ID 8707.00 8700.00 7.20 - 7"X 9.625"FlexLock Hanger,6.19"ID,BHI-29410WW16 8700.00 8684.00 15.45 - HR ZXPN Liner Top Packer,w/10.81"Polished Seal Bore Assembly,6.188"ID,BHI-H2964260W10 Tubin FROM TO LENGTH JOINTS DESCRIPTION 8683.00 1.40 - 7 3/8"Bullet Locator Seal Assembly-BHI-H297551040-6.184"ID 8683.00 8672.00 9.93 - 7"26#L-80 Vam Top HC-Casing Pup 8672.00 175.82 7150.27 207 7"26#L-80 Vam Top HC 175.82 170.93 4.89 - 7"26#L-80 Vam Top HC-Casing Pup 170.93 167.48 3.45 - 7"Vam Top-S.S.S.V.Nipple-102026798,5.963"ID-W/1/4"S.S.Control Line-X-Profile 167.48 162.60 4.88 - 7"26#L-80 Vam Top HC-Casing Pup 162.60 80.92 121.83 2 7"26#L-80 Vam Top HC 80.92 76.03 4.89 - 7"26#L-80 Vam Top HC-Casing Pup 76.03 71.13 4.90 - 7"26#L-80 Vam Top HC-Casing Pup 71.13 66.18 4.95 7"26#L-80 Vam Top HC-Casing Pup 66.18 26.03 40.15 1 7"26#L-80 Vam Top HC 26.03 23.85 2.18 - 7"26#L-80 Vam Top HC Pup Joint 23.85 23.00 0.85 - 7"26#L-80 Vam Top HC-FMC Tubing Hanger W/SBMS Metal Seal 20.50 0.00 20.50 - RT to hanger CINGSA-DAILY DRILLING REPORT 7 1/22/2012 Well Name CLU Storage 5 BHA St: ;IA Days: John Nicholson Current Depth: 11101' Location: Kenai,AK Target Depth: 11101' Cell Phone: (907) 299-4306 - Rig Ftg/24hrs. 0 Field/Pool: Cannery Loop/Sterling C Contractor Nabors Alaska-Rig 105 E Nights: Mike Grubb DaysPresent Demobe NAD 105E Rig Sinces Spud 31 Operation Phone: (907)398-3156 Cell Phone: (509)431-7988 DRILLING DATA - BITS SIZE MFG TYPE SERB JETS IN OUT FEET BIT GRADE TOTAL HOURS CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor: 20 133# X-56 Welded 97' N/A July - Surace: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40# L-80 BTC 8860' Slumberger 2-Jan Liner 7" 26# L-80 VAM-Top 11100'-8684' Slumberger 14-Jan Tubing 7" 26# L-80 VAM-Top 8684' Tie back 17-Jan space out 2.5'above no go PUMP#1 PUMP#2 LMUD PROPERTIES: IMUD ADDITIVES: I Daily !Cumulative PUMP MANF Gardner Denver PUMP MANF Gardner Denver WEIGHT GEL(50 lb bag) 630 PUMP TYPE PZ-9 PUMP TYPE PZ-9 FUNNEL VIS S.ASH(501b bag) 42 LINER SIZE 6 LINER SIZE 6 R600/R300 KLA-GUARD 172 STOKE LNGTH 9 STOKE LNGTH 9 R200/R100 LOTORQ/776/STEEL LUBE 4400 SPM SPM R6/R3 ASPHASOL SUPREME 233 GPS GPS PV CONDOR 404 8 GPM GPM YP POTASSIUM CHLORIDE 415 PSI PSI GELS FLOWZAN 183 BTMS UP MIN BTMS UP MIN API FLUID LOSS PAC 139 TOT CIR MIN TOT CIR MIN CAKE APH/HT CF-DESCO II/SAPP 96 AVDP: AVDP: SOLIDS MYACIDE GA25 7 AVDC: AVDC: OILIWATER GEL-X 7 AVDC: AVDC: SAND CITRIC ACID/SAFE CARB/mirr II 767 DRILL STRING&HYDRAULICS PH RESINEX 24 STRING WT. WOB Pf/M1 CAUSTIC SODA 40 PICK UP RPM CHLORIDES SODIUM BICARBONATE/mrtabisutfr 104 SLACK OFF TFA CA BARITE/NUT PLUG I G SEAL 752 • MAX PULL HSP VOL.PIT-(BBL) LIQUIDS/screen clean 320 ECD PRESS DROP HOLE-(BBL) SOLIDS (BBLS hauled by AIMM) 72 8778.7 DCOD JET VEL API SCREEN Daily Mud Cum. 72 17117.7 ACTIVITY SUMMARY TIME SUMMARY Start I Finish THours I Description Detail I Daily I Cumulative 6:00 Load out A legs and ship out.Crane down shaker bubble, RU/RD 24.00 252.50 offside doghouse and shaker module,Remove vacuum de- Drilling 137.00 12:30 6.50 gasser from shaker pit Crane down Centrifuge and LJO Service/Repair Rig 27.50 12:30 Blow down boilers and all steam lines.Load out lower pit Surveys 0.00 18:00 5.50 modules and Ship out.Move crane to drillers side. Tripping 224.00 18:00 R/D line spool modual and load out,load water tank.Remove Change BHA 0.00 0:00 6.00 drillers side dog house windwalls,prep sub for move. Casing Crew 54.50 0:00 Load out compressor module,change room,beat out pins in Cementing Crew 16.50 6:00 6.00 sub,load out rig floor&draw works section. Logging 10.50 NU/ND Test 62.00 DST/Core 0.00 Well Control 0.00 WOC 1.00 Safety Meetings _ 0.00 Drilling Cement 3.50 Total loads shipped off location 29,8 more trailers ready to go Circ/Other 63.00 24.00 TOTAL 24.00 852.00 BOTTOM HOLE ASSEMBLY QTY I ITEM I CONN DOWN CONN UP I VENDOR I O.D. I.D. J GAUGE J NECK I LENGTH (TOTAL LENGTH BHA TOTAL LENGTH coo REMARKS 8 COMMENTS DIESEL No accidents near misses or spills. Diesel on Location day before 1,848 Hold PJSM on all critical picks with crane Diesel Used Last 24 980 large crawler crane break down with elec.issues @21:00 continue rig down with 1 crane,repaired 01:00 Diesel Received S&R pump septic TOTAL DIESEL 868 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Peak rig move 10 12 120 PRA DSM 2 12 24 Carlile trucking 10 12 120 PRA Safety/PM 1 1 1 Foster Const. flagging 2 12 24 Aimm vac truck 1 4 4 TOTAL COUNT 50 TOTAL MAN HOURS 593 1 FROM TO LENGTH I JOINT I DESCRIPTION G/L 97' 97' Welded 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 BT ) 13 3/8 68#J-55(FC @ 2346,Shoe @2390') Intermediate FROM TO LENGTH JOt...d^ DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' _ 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-hy 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 .RKB To load shoulder Liner FROM TO LENGTH JOINTS DESCRIPTION 11101.00 11099.00 2.00 - Rat hole 11099.00 11099.00 0.55 - 7"BHI H266674701-Float Shoe 11099.00 11059.00 40.42 7"26#L-80 Vam Top HC with BHI-H266624704-Internal Float Collar 11059.00 11059.00 0.00 7"26#L-80 Vam Top HC with BHI-H266564702-Landing Collar internal 11059.00 8713.00 2386.00 58 7"26#L-80 Vam Top HC 8713.00 8709.00 4.86 - 7"Handling Pup-26#L-80 Vam Top HC,6.192"ID 8709.00 8707.00 1.73 - 7"Vam Top HC-RN Casing Nipple,5.88"No-Go ID 8707.00 8700.00 7.20 - 7"X 9.625"FlexLock Hanger,6.19"ID,BHI-29410WW16 8700.00 8684.00 15.45 - HR ZXPN Liner Top Packer,w/10.81"Polished Seal Bore Assembly,6.188"ID,BHI-H2964260W10 T 1tig FROM TO LENGTH JOINTS DESCRIPTION 8683.00 1.40 - 7 3/8"Bullet Locator Seal Assembly-BHI-H297551040-6.184"ID 8683.00 8672.00 9.93 - 7"26#L-80 Vam Top HC-Casing Pup 8672.00 175.82 7150.27 207 7"26#L-80 Vam Top HC 175.82 170.93 4.89 - 7"26#L-80 Vam Top HC-Casing Pup 170.93 167.48 3.45 - 7"Vam Top-S.S.S.V.Nipple-102026798,5.963"ID-W/1/4"S.S.Control Line-X-Profile 167.48 162.60 4.88 - 7"26#L-80 Vam Top HC-Casing Pup 162.60 80.92 121.83 2 7"26#L-80 Vam Top HC ,__ 80.92 76.03 4.89 - 7"26#L-80 Vam Top HC-Casing Pup 76.03 71.13 4.90 - 7"26#L-80 Vam Top HC-Casing Pup 71.13 66.18 4.95 7"26#L-80 Vam Top HC-Casing Pup 66.18 26.03 40.15 1 7"26#L-80 Vam Top HC 26.03 23.85 2.18 - 7"26#L-80 Vam Top HC Pup Joint 23.85 23.00 0.85 - 7"26#L-80 Vam Top HC-FMC Tubing Hanger W/SBMS Metal Seal 20.50 0.00 20.50 - RT to hanger CINGSA-DAILY DRILLING REPORT Date 1/23/2012 Well Name CLU Storage 5 BHA#: 'M Days: John Nicholson Current Depth: 11101' Location: Kenai,AK Target 11101' Cell Phone: (907) 299-4306 Depth: DSM Ftg/24hrs. 0 Field/Pool: Cannery Loop/Sterling C ConR aor Nabors Alaska-Rig 105 E Nights: Mike Grubb Days Since Spud 32 Present Clean up pad and move out NAD 105E Rig 9 Phone: (907)398-3156 Cell Phone: (509)431-7988 DRILLING DATA BIT# SIZE ( MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH I CEMENT COMPANY I DATE I - Conductor: 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40# L-80 BTC 8860' Slumberger 2-Jan Liner 7" 26# L-80 VAM-Top 11100'-8684' Slumberger 14-Jan Tubing 7" 26# L-80 VAM-Top 8684' Tie back 17-Jan space out 2.5'above no go PUMP#1 IPUMP#2 MUD PROPERTIES: _ !MUD ADDITIVES: I Daily Cumulative PUMP MANF PUMP MANF WEIGHT GEL(50 lb bag) 630 PUMP TYPE PUMP TYPE FUNNEL VIS S.ASH(50 lb bag) 42 LINER SIZE LINER SIZE R600/R300 KLA-GUARD 172 STOKE LNGTH STOKE LNGTH R200/R100 LOTORQ/776/STEEL LUBE 4400 SPM SPM R6/R3 ASPHASOL SUPREME 233 GPS GPS PV CONDOR 404 8 GPM GPM YP POTASSIUM CHLORIDE 415 PSI PSI GELS FLOWZAN 183 BTMS UP MIN BTMS UP MIN API FLUID LOSS PAC 139 TOT CIR MIN TOT CIR MIN CAKE APH/HT CF-DESCO II/SAPP 96 AVDP: AVDP. SOLIDS MYACIDE GA25 7 AVDC: AVDC: OIUWATER GEL-X 7 AVDC: AVDC: SAND CITRIC ACID/SAFE CARB/mix II 767 DRILL STRING&HYDRAULICS PH RESINEX 24 STRING WT. WOB Pf/Mf CAUSTIC SODA 40 PICK UP RPM CHLORIDES SODIUM BICARBONATE/mrtabisulfr 104 SLACK OFF TFA CA BARITE I NUT PLUG/G SEAL 752 MAX PULL HSP VOL.PIT-(BBL) LIQUIDS/screen clean 320 ECD PRESS DROP HOLE-(BBL) SOLIDS (BBLS hauled by AIMM) 8778.7 OCOD JET VEL API SCREEN Daily Mud Cum. 0 17117.7 L ACTIVITY SUMMARY J TIME SUMMARY Detail Start j Finish f Hours I Description Daily I Cumulative 6:00 Set frog and support beams in lower sub.Crane sub off RU/RD 24.00 252.50 center of well and load out.Load out#2 fuel tank,mud pump Drilling 137.00 manifold module,#1 mud pumps,mud pump causeway Service/Repair Rig 27.50 12:00 6.00 and#1 fuel tank. Surveys 0.00 12:00 Remove mufflers from generators.Crane/load out 1,2,3&4 Tripping 224.00 generators/boiler modules and haul off.Crane/load out VFD Change BHA 0.00 and motor control modules and haul off.All major rig Casing Crew 54.50 18:00 6.00 components loaded and shipped off location. Cementing Crew 16.50 18:00 R/D rig shop and prep for shipping.Start cleaning up location. Logging 10.50 0:00 6.00 Load out rig mats,building loads,pull up liner and dispose. NU/ND Test 62.00 0:00 Remove shop roof and doors.Pallitize and band misc.&load DST/Core 0.00 6:00 6.00 on trailers.Start cleanup around yard. Well Control 0.00 WOC 1.00 Safety Meetings 0.00 Drilling Cement 3.50 Total loads shipped off location.51 Circ/Other 63.00 24.00 TOTAL 24.00 876.00 BOTTOM HOLE ASSEMBLY CITY ITEM CONN DOWN CONN UP VENDOR O.D. I.D. GAUGE NECK LENGTH TOTAL LENGTH BHA TOTAL LENGTH o.00 REMARKS&COMMENTS DIESEL No accidents near misses or spills. Diesel on Location day before 868 Hold PJSM on all critical picks with crane Diesel Used Last 24 800 Crews roll over to days Diesel Received TOTAL DIESEL 68 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 24 12.5 300 Peak rig move/crane 8 12 96 PRA DSM 2 12 24 Carlile trucking 6 12 72 PRA Safety/PM 1 1 1 Foster Const. flagging 2 12 24 AIMM Roust. 4 7 28 - TOTAL COUNT 47 TOTAL MAN HOURS 545 FROM I TO I LENGTH I JOINT I DESCRIPTION G/L 97' 97' Weir=s 20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 BT ) 13 3/8 68#J-55(FC @ 2346,Shoe @2390') Intermediate - FROM TO LENGTH JO1...6 DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-hy 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder Liner FROM TO LENGTH JOINTS DESCRIPTION 11101.00 11099.00 2.00 - Rat hole 11099.00 11099.00 0.55 - 7"BHI H266674701-Float Shoe 11099.00 11059.00 40.42 7"26#L-80 Vam Top HC with BHI-H266624704-Internal Float Collar 11059.00 11059.00 0.00 7"26#L-80 Vam Top HC with BHI-H266564702-Landing Collar internal 11059.00 8713.00 2386.00 58 7"26#L-80 Vam Top HC 8713.00 8709.00 4.86 - 7"Handling Pup-26#L-80 Vam Top HC,6.192"ID 8709.00 8707.00 1.73 - 7"Vam Top HC-RN Casing Nipple,5.88"No-Go ID 8707.00 8700.00 7.20 - 7"X 9.625"FlexLock Hanger,6.19"ID,BHI-29410WW16 8700.00 8684.00 15.45 - HR ZXPN Liner Top Packer,w/10.81"Polished Seal Bore Assembly,6.188"ID,BHI-H2964260W10 Tuning FROM TO LENGTH JOINTS DESCRIPTION 8683.00 1.40 - 7 3/8"Bullet Locator Seal Assembly-BHI-H297551040-6.184"ID 8683.00 8672.00 9.93 - 7"26#L-80 Vam Top HC-Casing Pup 8672.00 _ 175.82 7150.27 207 7"26#L-80 Vam Top HC 175.82 170.93 4.89 - 7"26#L-80 Vam Top HC-Casing Pup 170.93 167.48 3.45 - 7"Vam Top-S.S.S.V.Nipple-102026798,5.963"ID-W/1/4"S.S.Control Line-X-Profile 167.48 162.60 4.88 - 7"26#L-80 Vam Top HC-Casing Pup 162.60 80.92 121.83 2 7"26#L-80 Vam Top HC 80.92 76.03 4.89 - 7"26#L-80 Vam Top HC-Casing Pup 76.03 - 71.13 4.90 - 7"26#L-80 Vam Top HC-Casing Pup 71.13 66.18 4.95 7"26#L-80 Vam Top HC-Casing Pup 66.18 26.03 40.15 1 7"26#L-80 Vam Top HC 26.03 23.85 2.18 - 7"26#L-80 Vam Top HC Pup Joint 23.85 23.00 0.85 - 7"26#L-80 Vam Top HC-FMC Tubing Hanger W/SBMS Metal Seal 20.50 0.00 20.50 - RT to hanger CINGSA-DAILY DRILLING REPORT Date 1/24/2012 Well Name CLU Storage 5 BHA#. M Days: John Nicholson Current Depth: 11101' Location: Kenai,AK Target 11101' Cell Phone: (907) 299-4306 Depth: •Ftg/24hrs. 0 Field/Pool: Cannery Loop/Sterling C Conn GOr: Nabors Alaska-Rig 105 E Nights: Mike Grubb Days Since Spud 33 Present Rig released 1800hrs 1-23-2012 Rig Phone: (907)398-3156 Cell Phone: (509)431-7988 Operation: DRILLING DATA BIT# SIZE MFG TYPE SER# JETS IN OUT FEET BIT GRADE TOTAL HOURS CASING I SIZE I WEIGHT I GRADE I THREAD I DEPTH 1, CEMENT COMPANY I DATE I - Conductor: 20 133# X-56 Welded 97' N/A July - Surface: 13 3/8 68# J-55 BTC-mod 2390' Slumberger 25-Dec Intermediate 9 5/8 40# L-80 BTC 8860' Slumberger 2-Jan Liner 7" 26# L-80 VAM-Top 11100'-8684' Slumberger 14-Jan Tubing 7" 26# L-80 VAM-Top 8684' Tie back 17-Jan space out 2.5'above no go PUMP#1 IPUMP#2 MUD PROPERTIES: 'MUD ADDITIVES: I Daily Cumulative PUMP MANF PUMP MANF WEIGHT GEL(50 lb bag) 630 PUMP TYPE PUMP TYPE FUNNEL VIS S.ASH(50 lb bag) 42 LINER SIZE LINER SIZE R600/R300 KLA-GUARD 172 STOKE LNGTH STOKE LNGTH R200/R100 LOTORQ/776/STEEL LUBE 4400 SPM SPM R6/R3 ASPHASOL SUPREME 233 GPS GPS PV CONQOR 404 8 GPM GPM YP POTASSIUM CHLORIDE 415 PSI PSI GELS FLOWZAN 183 BTMS UP MIN BTMS UP MIN API FLUID LOSS PAC 139 TOT CIR MIN TOT CIR MIN CAKE APH/HT CF-DESCO II/SAPP 96 AVDP: AVDP: SOLIDS MYACIDE GA25 7 AVDC: AVDC: OILNVATER GEL-X 7 AVDC: AVDC: SAND CITRIC ACID/SAFE CARB/mix II 767 DRILL STRING&HYDRAULICS PH RESINEX 24 STRING WT. WOB Pf/Mf CAUSTIC SODA 40 PICK UP RPM CHLORIDES SODIUM BICARBONATEJmrtabisulfr 104 SLACK OFF TFA CA BARITE/NUT PLUG/G SEAL 752 MAX PULL HOP VOL.PIT-(BBL) LIQUIDS/screen clean 320 ECD PRESS DROP HOLE-(BBL) SOLIDS (BBLS hauled by AIMM) 35 8813.7 DCOD JET VEL API SCREEN Daily Mud Cum. 35 17152.7 ACTIVITY SUMMARY TIME SUMMARY Start I Finish I Hours I Description Detail I Daily I Cumulative 6:00 Clean yard,palitize and band misc.equipment and parts. ,RU/RD 12.00 264.50 Load out matting boards.Load out NAD shop and haul off Drilling 137.00 Continue load out of matting boards mud boxes and tools Service/Repair Rig 27.50 18:00 12.00 Install tree on CLU-5.Clean up location. Surveys 0.00 Tripping 224.00 Change BHA 0.00 Casing Crew 54.50 Cementing Crew 16.50 Logging 10.50 NU/ND Test 62.00 Rig released from cingsa location @ 1800hrs.1/23/2012 DST/Core 0.00 1800 hrs January 23,2012 Well Control 0.00 WOC 1.00 Safety Meetings 0.00 Drilling Cement 3.50 Total loads shipped off location.61 Circ/Other 63.00 12.00 TOTAL 12.00 894.00 BOTTOM HOLE ASSEMBLY QTY ITEM I CONN DOWN CONN UP I VENDOR I O.D. I I.D. J GAUGE NECK LENGTH 'TOTAL LENGTH • BHA TOTAL LENGTH o.00 REMARKS 8 COMMENTS DIESEL No accidents near misses or spills. Diesel on Location day before 68 35 bbls haul off from AIMM-tank cleaning Diesel Used Last 24 Diesel Received Called AOGCC(Jim Regg)gave notice of pending Coil BOP test 11:00am 1-23-12 TOTAL DIESEL 68 PERSONNEL ON LOCATION COMPANY NOTE COUNT HOURS TOTAL COMPANY NOTE COUNT HOURS TOTAL Nabors Rig Crew 9 12.5 112.5 Peak rig move/crane 4 12 96 PRA DSM 2 12 24 Carlile trucking 6 12 72 PRA Safety/PM 1 1 1 AIMM Roust. 4 7 28 - TOTAL COUNT 26 TOTAL MAN HOURS 333.5 FROM I TO I LENGTH I JOINT I DESCRIPTION G/L 97' 97' WF'' _20"133#X-56 Welded Conductor Pipe RKB 2390' 2390 Bl 13 3/8 68#J-55(FC @ 2346,Shoe @2390') Intermediate FROM TO LENGTH JOINTS DESCRIPTION 8860' 8872' 12.00 Rat hole 8860' 8858' 2.00 Float shoe-Davis Lynch 501 Down jet Float shoe 8858' 8774.92 83.04 2 9 5/8"40#L-80 BTC 8774.92 8772.82 2.10 9 5/8"BTC-Davis Lynch SB Float Collar 8772.82 3512.56 5260.26 129 9 5/8"40#L-80 BTC 3512.56 3510.26 2.30 9 5/8"Davis Lynch Stage Collar-Type 777-hy 3510.26 27.33 3482.93 85 9 5/8"40#L-80 BTC 27.33 24.83 2.50 9 5/8"40#L-80 BTC PUP 24.83 24.28 0.55 HANGER 22.80 22.80 RKB To load shoulder Liner FROM TO LENGTH JOINTS DESCRIPTION 11101.00 11099.00 2.00 - Rat hole 11099.00 11099.00 0.55 - 7"BHI H266674701-Float Shoe 11099.00 11059.00 40.42 7"26#L-80 Vam Top HC with BHI-H266624704-Internal Float Collar 11059.00 11059.00 0.00 7"26#L-80 Vam Top HC with BHI-H266564702-Landing Collar internal 11059.00 8713.00 2386.00 58 7"26#L-80 Vam Top HC 8713.00 8709.00 4.86 - 7"Handling Pup-26#L-80 Vam Top HC,6.192"ID 8709.00 8707.00 1.73 - 7"Vam Top HC-RN Casing Nipple,5.88"No-Go ID 8707.00 8700.00 7.20 - 7"X 9.625"FlexLock Hanger,6.19"ID,BHI-29410WW16 8700.00 8684.00 15.45 - HR ZXPN Liner Top Packer,w/10.81"Polished Seal Bore Assembly,6.188"ID,BHI-H2964260W10 Tubing FROM TO LENGTH JOINTS DESCRIPTION 8683.00 1.40 - 7 3/8"Bullet Locator Seal Assembly-BHI H297551040-6.184"ID 8683.00 8672.00 9.93 - 7"26#L-80 Vam Top HC-Casing Pup 8672.00 175.82 7150.27 207 7"26#L-80 Vam Top HC 175.82 170.93 4.89 - 7"26#L-80 Vam Top HC-Casing Pup 170.93 167.48 3.45 - 7"Vam Top-S.S.S.V.Nipple-102026798,5.963"ID-W/1/4"S.S.Control Line-X-Profile 167.48 162.60 4.88 - 7"26#L-80 Vam Top HC-Casing Pup 162.60 80.92 121.83 2 7"26#L-80 Vam Top HC 80.92 76.03 4.89 - 7"26#L-80 Vam Top NC-Casing Pup 76.03 71.13 4.90 - 7"26#L-80 Vam Top HC-Casing Pup 71.13 66.18 4.95 7"26#L-80 Vam Top HC-Casing Pup 66.18 26.03 40.15 1 7"26#L-80 Vam Top HC 26.03 23.85 2.18 - 7"26#L-80 Vam Top HC Pup Joint 23.85 23.00 0.85 - 7"26#L-80 Vam Top HC-FMC Tubing Hanger W/SBMS Metal Seal 20.50 0.00 20.50 - RT to hanger 1[ TJ 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 M. Colleen Starring Vice President Cook Inlet Natural Gas Alaska, LLC P.O. Box 190989 Anchorage, AK 99519 Re: Cannery Loop Field, Sterling C Pool, CLU Storage 5 Cook Inlet Natural Gas Alaska, LLC Permit No: 211-158 Surface Location: 720' FNL, 1760' FEL, SEC. 9, T5N, R11W Bottomhole Location: 546' FNL, 1799' FWL, SEC. 17, T5N, R 11 W Dear Ms. Starring: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Chair ct(-- DATED this ?day of December, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) „''- IVED STATE OF ALASKA ALAS. OIL AND GAS CONSERVATION COMMIS,._14 DEL 1 2 201 Ago-// PERMIT TO DRILL 20 AAC 25.005 8;.s,,.;a *,, ,:; ‘I.Dli COM.Conlin==IOf la.Type of Work: 1 b.Proposed Well Class: Development-Oil U Service- Winj ❑ Single Zone ❑ 1c.Specify kitiieftileosed for: Drill ❑Q - Redrill ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑., • Multiple Zone 0 , Coalbed Gas Gas Hydrates ❑ Re-entry ❑ Exploratory D Service- WAG ❑ Service-Disp ❑ Service-Gstor 0 ' Shale Gas ❑ 2.Operator Name: i5. Bond: Blanket Q Sin le Well ❑ 11.Well Name and Number: Cook Inlet Natural Gas Alaska,LLC Bond No. IQ SC-. 9N / ;z i-3'11 CLU Storage 5 • 3.Address: -6.Proposed Depth: 12.Field/Pool(s): P.O.Box 190989,Anchorage,AK 99519 MD: 10,797'• TVD: 5,180' . Cannery Loop/Sterling C pool • 4a. Location of Well(Governmental Section):NAD 27 t 7.Property Designation(Lease Number): Surface: 720'FNL 1760 FEL SEC.9 T5N R11 W . ADL 391627 Top of Productive Horizon:8,605'MD/4,936'TVD 8.Land Use Permit: 13.Approximate Spud Date: 645'FSL 1648 FEL SEC.8 T5N R11W ADL 230925 12/22/2011 Total Depth:10,797'MD/5,180'TVD 9.Acres in Property: 14.Distance to Nearest Property: 546'FNL 1799 FWL SEC.17 T5N R11 W 1272 207' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.RT Elevation above MSL: 53.5 feet 15.Distance to Nearest Well Open Surface: x-281845.44' y-2392832.83 / Zone- 4 GL Elevation above MSL: 33 feet v to Same Pool: 720 feet(CLU-10) 16.Deviated wells:Yes Kickoff depth: 300' feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 84 degrees Downhole: 2,220 - Surface: 1,772 • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length _ MD TVD MD TVD (including stage data) Driven 20” 133 X56 PE 98' 0 0 118.5' 118.5' N/A 16" 13 3/8" 68 J-55 BTC 2,307' • 0 0 2,307' 1,958' 593sxs lead/276 sxs tail 12 1/4" 9 5/8" 40 L-80 BTC 8,630' 0 0 , ,TKO' 4,939' 633 sxs lead/196 sxs tail/484 2nd stg 8 1/2" • 7" 26 L-80 VamTop 2,367' 8,430' 4,909' 1,, 9 5,180' 296 sxs i z -"" 9 5/8"stage collar @-3,500'MD 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑., BOP Sketch Drilling Program Q Time v.Depth Plot ❑., Shallow Hazard Analysis Diverter Sketch Seabed Report ❑ Drilling Fluid Program ❑., 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Printed Name M.Colleen Starring Title Vice Presidenty� Signature //�1.4011eC,C, / Phone 907-334-7659 Date AZ/ Z /Z/1/ Commission Use Only Permit to DrillAPI Number: �,� Permit Appr va 1 See cover letter for other Number: 2____I� l S0-r ��� ` ate: I' 1'l 11 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methan ,gas hydrates,or gas contained in sh s:d Other: Samples req'd: Yes❑ No[ Mud log req'd: Yes LIo El S VC..:,Sk ��( \ H25 measures: Yes❑ No II Directional svy req'd: Yes Q No ❑ 4 / APPROVED BY THE COMMISSION 1 2 1 Zc [-/ ) DATE: ,COMMISSIONER ORIGINALA ' 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 Cook Inlet Natura Gas 3000 Inlet Natural Gas Storage Alaska,LLC 3000 Spenard Road PO Box 190989 STORAQ! Anchorage,AK 99519-0989 Main:907-334-7980 ;� Q Fax:907-334-7671 www.cingsa.corn December 12, 2011 DEC 1 2 Z011 uf&Gas Cons.Conmissi00 Ms. Jodie Colombie, Special Assistant to the Commission f'itticeta:e Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Drilling Permit Application for Gas Storage Injection Well, CLU Storage 5 Cannery Loop Gas Storage Project Kenai, Alaska Dear Ms. Colombie: Cook Inlet Natural Gas Alaska, LLC (CINGSA) submits the enclosed Permit to Drill Application for its CLU Storage 5 gas storage injection well. If you have any questions or comments regarding the enclosed application, please feel free to contact Mr. Richard Gentges, Senior Project Manager at 907 335-1488 (office) or 907 3107322 (cell). Sincerely, 7)1 dvW—C4X-911 a,474-€365/ M. Colleen Starring Vice President Enclosure as stated Cc: T. Arminski, ENSTAR,w/o enclosure J. Lau, ENSTAR,w/o enclosure C.Perry,PRA,w/o enclosure N. Thompson, CINGSA,w/o enclosure T. Walsh,PRA,w/o enclosure Cook Inlet Nuturc4Gas STORAQ ,-c, „›--8,Q „,"%s CINGSA DRILLING PROGRAM CLU STORAGE 5 Originator Date Conrad Perry Approved by Date Ri and Gentges Approved by _ Date 1 2/12/1/ John Lau 1jPage DEPTH TIME CURVE 4 AREA MAP 5 GENERAL RESERVOIR OVERVIEW 5 CINGSA CURRENT WELL PLANS 6 CINGSA FACILITIES MAP 7 SURVEYED LOCATION PLOT 8 WELL PAD LAYOUT 9 GENERAL WELL DATA 9 GEOLOGIC PROGRAM SUMMARY 10 SUMMARY OF POTENTIAL DRILLING HAZARDS 11 FORMATION EVALUATION SUMMARY 11 DRILLING PROGRAM SUMMARY 12 CASING PROGRAM 13 CASING DESIGN 13 MAXIMUM ANTICIPATED SURFACE PRESSURE 13 WELL CONTROL AND CASING DESIGN CALCULATIONS 14 BOPE PROGRAM 17 BOPE DIAGRAMS 18 CHOKE MANIFOLD 18 BOP STACK 20 WELLHEAD EQUIPMENT SUMMARY 21 21 Page DIRECTIONAL PROGRAM SUMMARY 22 DIRECTIONAL SURVEYING SUMMARY 22 DETAILED DIRECTIONAL PLANNING 23 WELL CLEARANCE REPORT 28 PLANNED WELL SUMMARY SHEET 29 DRILLING FLUID PROGRAM SUMMARY 30 DRILLING FLUID SPECIFICATIONS 30 SOLIDS CONTROL EQUIPMENT 31 CEMENT PROGRAM SUMMARY 31 REGULATORY WAIVERS AND SPECIAL PROCEDURES 32 BIT SUMMARY 32 HYDRAULICS SUMMARY 33 FORMATION INTEGRITY TEST PROCEDURE 34 PROPOSED COMPLETION SCHEMATIC 35 SURFACE USE PLAN FOR CLU STORAGE 5 36 3IPage DEPTH TIME CURVE - S yozi ase- ad ad In ll°D• a M .40 — — 'Iti ase alaa/ON I. I haldwoo d una -------------- 0J lII_ ,. E V I 0 o E — �, 4_0 i: __ — „$fs6;uawaapue una J - re, — — --— D ri SdO9 7sa1 PUe f1N- 765 agit£T 1urj l$Inn c U' 00 cea ---— 0 (g Udall Paunaaayr 41 Page AREA MAP G 'ir .0, r, . i „...... rAirl 111 Anchorage i "I-,onek - • •J ‘ • •• 1 __J , d , 1 • " c._2_,Y Kenai Field, i Cannery Loop Unit, 1 .../ • Sterling Undef Nil:Isla -, L_I _ __--- Gas Pool Kenai , _ Cooper Landing k -1 .... i- — I 1 14 / Seward GENERAL RESERVOIR OVERVIEW ,y '...: 7"r7 --- - 3 ,, ,... a --- • .. ,..,!A. a., - - I ...c,Li' - • i, I 4, ON G SA-c . jr ,..-.! .. k.i..;'101.411•r•'.. . ..1 ---- . Fp'•t , ....40 • 4 , . , ' . --: r 1 ;,--A.7 •z. ' -----— — L ,-rim:ro.0• ....5b,44c 0..-4 1 /.... r- - I 6. ' .-1. ' ir'"; , 1-.- f '.-- i •. 1 I ) -:.'e,7, Wage CINGSA CURRENT WELL PLANS CLU-3 1111111Wp •• l'I'lligligile . U-11 ,LUS-1 _:LU-7 r. ACLU zr.V-7 . ... 0°V rj C LU- ! -11= Y f Uy !Ai • ._,f -r} -.0 LU- iiiIIa 61Page CINGSA FACILITIES MAP ,\ s.�,/- PROJECT OVERVIEW .. \` / #; \ , EXISTING CONTOURS x \ NY.N-N / ¢ 1 / \ \/' 4""eow gufu�a •! :,r, a !. • \ ••,,\t.',.. ..' / PROPOSE ¢ �, \ FACILITY 0- \ . \\ r -\.\ PAD v i- • J »w ` ti 1 '� �t� "• E g D' to -�\ slA \ ; \. i / /..." 11111.1r,t �`\� L� -'''.-7:-1141-Nel- � r PAD i, \\\\ �'\ ��� � c�.rr.� % \1,1t- _ �;i^ ��- ''••"'" ED. 71 Page SURVEYED LOCATION PLOT • • '',\ ,,-... , \t \ I ..,..------so. , t TI9N41 11YY 8ECTION UNE • a' •} ' a, !COON 2 MOR111k' NOT TO 9C. E /' a --- _._ IIA , g .E.3 - - TRACTE 1 / t; v� KN 2005 ,,\444,,,\ i a' 1' i 'a CIT'OF KENN j a , a 5 .— —. .. _ _ _ _ _.._._ _ _ ._.t .:_ _._.. , ra �`� r a 1 ar I 1 1 TRACT c 1 1 - ' at•'..+� +1 KN:CCS-1:: % y• ~' 1 -ATE OF ALA3K•1 / I ,• -y,. 1 C o—1 CINGSA i t$ f �ti DRILL PAD i ' --- ' / t . b r'p t \ I\ 1. \ wr rrri i i \\\ / � a 1 1� 1 1 / 1 MGM NELLE' i 11 SURFACE LOCATION NAD 2'ASP ZONE 4 1 1 Ir ORDN:2392'-ES32E3 t a GRID E1Bi5A4 i1 i LATTTUDE:SD•32Q'r+E a 39A . 1 LANGRUDE:-151' u 12421^ / / Ii ELEY.3Z� 'IA V 1 t 17811': % FEL .1 1 1 1 , 1• ' fi 1 1 ' \:J:'1L ..> i,I\ 1 1 1 1 1 1 I 1 I . 1 1 t - 1\ 1 • I rI. 11 - 1 a ; I 1 I ' I t l 1 % t I t SURVEY CONTROL 1}BASIS GEOSETIA C LA AND EPAR PENTON (EPOCH H2003)IS STATE OF OF ALASKA DEPARTiVENi OF TRANSPORTATION 8 PUBLIC FACILITIES SURVEY / ``1 CONTROL AKSAS PROJECT NO.56703 BENCHMARK 601 ALASKA STATE PLANE COORDINATES,:ASP:ZONE 4 ARE 1 NO,RTH N=2383494.742E.14229585-51v 2I BASIS OF VERTICAL CONTROL IS ADOT BM 001 LOCATED SCALE AT BRIDGE ACCESS RD.BEAVER LOOP RD.INTERSECTION 0 1513 3x ELEV.:4220 FT NAVD55 I 1 Pyr 1I Cook kid Natural GasCINGSA WELL''E'' MT .'er1+ « STORAGE P.O. BOX 190288 AS BUILT WELL SURFACE K.�.13. .W ANCHORAGE,AK 99519 LOCATION DIAGRAM NAD 27 ' WAX '•"x • nraMEna lab,I POrre,dallitr11O:lrs'u: COX 4GIuuiiIIU 1I •0 KA MI winoa...,a .13x.-�„ SEC.9 T5N R11 W 1 -..rrr SKYE aim2eo4ra Pu 11ue7.203.21e PPM/ 1411::101tellA AIIOna KO/ SEWARD MERIDIAN,ALASKA 6 -1 6 81Pagt WELL PAD LAYOUT t I ` 1 / � 145' ,r W �__ \ !— -,`1 ----\\r w l r aunt; r,rea Ltv w I 10' r Z I r ; J LL jShk s y 1V �skigalt 1 t Mud Loggers * r . 1 T? IN . 1110110 _._. Mud Eng. ` r r !WYE 't -A Beat Latina Exeltiolgeante I Inn ic1�lF- - g tt r , x , a , SL8 Cementing 14 CLU Stotage S Dewatetity Plant NCc'tanment ,t I y7--T ( r !labors Truckshop J IIH / \ 1 Drum Containment 1 1 1 1 ,\ l __„ , 420' 1 1 l 1 4' , t GENERAL WELL DATA General Well Data Well Name CLU Storage 5 Lease/License ADL 391627 Surface Location 720' FNL 1760 FEL SEC. 9 T5N R11W Est. Spud Date 12/22/2011 Slot/Pad CINGSA Field Cannery Loop API No. RT Elev. above 53.5' Borough Kenai Well Class Storage Ground level 33' State / Alaska Rig Contractor Nabors Alaska Comments: none 91 _ S GEOLOGIC PROGRAM SUMMARY The proposed gas storage reservoir interval is the Cannery Loop—Sterling C Gas Pool. The Sterling C Gas Pool is vertically defined as the underground formations comprising the Cl and C2 sands, bounded by the coal at the base of the B5 sand formation (top) and the top of the Upper Beluga formation (base). The Sterling C Pool is vertically defined in the "Pool Type Log" Cannery Loop Unit (CLU)-8 well (API #50-133-20534-00)as the interval between the depths of 6690 feet measured depth (MD) (4871 feet true vertical depth subsea [TVDSS]) and 6945 feet MD (5101 feet TVDSS). The gross reservoir interval thickness averages —200 feet across the pool area, and average net sand thickness is —95 feet. The original gas accumulation is comprised of fluvial channel sandstones with interbedded silty sands and shales folded in a structural 4-way dip closure and charged by biogenic methane gas. MD- RT TVD-RT Pore Pore Formation (ft) (ft) Pressure Pressure Lithology Possible Fluid (psi) (PIN) Sterling A 6,768 4,173 1,808 8.33 silty sand gas/water Sterling B 7,135 4,355 1,886 8.33 silty sand gas/water Sterling C-1, 8,605 4,934 2,203 8.59 sand gas Sterling C-2. 10,106 5,103 2,220 8.36 sand gas Comments: Sterling A& B are transient sands above the Sterling C. They have never been tested in the Cannery Loop Field and are included only as a potential source of gas. The depths are estimated and not projections. Sterling A& B sand pore pressures are estimated at fresh water gradient. The Sterling C sands do not appear to have a water drive. Pore pressures are extrapolated from original reservoir pressure datum plus or minus a .1 psi/ft gas gradient. Surface Location Coordinates From Lease/Block Lines 720' FNL 1760 FEL SEC. 9 T5N R11W Latitude 60°32' 39.0076" N Longitude 151° 12' 42.1745" W ASP Zone 4 NAD 27 Grid N 2392832.83 ASP Zone 4 NAD 27 Grid E 281845.44 !TARGETS mine ]lD TVD ?Gtr Ems Geld East GeM Marti Lad. LayWde SlawI&1 l�I I tM I Pl ' NS S9 Ns IJ I)Pla Pieter]ed lip Heel REVISED 24- 860.1-82 circle Oet-11 2)Pla Preferred IR.To RIVISED 24- 100601 cycle Oct-11 TARGETS are in NAD 87. Comments: none 10IPage SUMMARY OF POTENTIAL DRILLING HAZARDS Potential Hazards Statement To comply with state regulations the Potential Hazards section and the well shut-in procedures must be posted in the driller's dog house. The man on the brake (driller or relief driller) has the authority and is responsible for shutting the well in as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC inspector. This well's primary objective is the Sterling C sand packages and no oil sands have been encountered or are expected to be encountered. No H2S has been encountered or is anticipated.- Gas sands may be encountered from approximately 5,800' MD (4,125' TVD} to total depth of the well. These sands will run from highly depleted to possibly normal gradient pressure. Lost circulation and differential sticking are potential hazards in some of the Sterling sands. The Flo-Pro mud system that will be used to drill the well will help reduce these risks and lost circulation materials will be on location. Weighting material will available on location for proper well control. No abnormal gradients are expected. The Sterling C sand is expected to be depleted to 380 psia or r approximately 1.5 ppg EMW. There is potential for isolated sand packages within the Sterling C to be at original pressure. Original reservoir pressure was measured at 2206 psi at a datum depth of 7853' MD (4966' TVD) in CLU-6. This equates to 2203 psi at the top of the Sterling C sand at 7,619'MD (4,934'TVD). As such, the interval will be drilled with a suitable mud weight to control any normal pressures. FORMATION EVALUATION SUMMARY Basic with Gas ' Surface Chromatography 0' to 2,307' MD GR None Analysis(GCA), PVT, sample collection (30' samples). Intermediate Basic with GCA, PVT, 2,30T to 8,630' MD GR/Res ' 9 5/8" CBL/GR/CCL sample collection , (30' samples). Triple Combo ti Basic with GCA, PVT, Production GR/Res/Neutron/ 7" CBL/GR/CCL sample collection 8,630' to 10,797' MD Magtrak (10' samples). Coring Requirements: None Comments: None 11IPage DRILLING PROGRAM SUMMARY CONDUCTOR: 1. Drive 20" conductor to +/-100 ft. RKB_ Install FMC 20" 2000# landing ring 2. Move in and rig up rotary drilling rig. 3. Nipple up 21 1/4", 3M diverter with x/o, 16" diverter valve, and 16" diverter line. 4. Function test diverter and diverter valve. SURFACE: 1. Directionally Drill a 16" hole to 2,307' MD (1,958' TVD) per the directional plan. 2. RIH with 13 3/8"casing, centralized according to program and hang off in the spiders. Rig up false table and make up stab-in sub and centralizer on 5" drill pipe. RIH with inner string and latch into stab-in float collar. 3. Cement 13 3/8" casing. Sting out, shear out drill pipe wiper plug, and circulate drill pipe clean. POH with inner string. 4. Monitor well until cement sets. Lift riser and cut off 13 3/8" casing. ND diverter. Dress 20" conductor. 5. Install and test 13 3/8" slip lock connection X 13 5/8" 5M flanged FMC Multi-bowl wellhead. 6. NU 13 5/8" 5M BOP'S. Test BOP'S and choke manifold to 250psi/2500 psi 7. Set wear bushing. 8. Make up 12 1/4" directional BHA and RIH to shoe. Test surface casing to 2,000 psi. INTERMEDIATE: 1. Drill out float equipment and make 20' of new hole. CBU. 2. Test shoe to leak off. Estimated leak off is 15.0 ppg EMW. 3. Directional drilll2 1/4" hole to 8,630'MD (4,939'TVD) as per directional program. Exact depth will be determined by Geologist call on the bottom of the B5 coal plus rat hole. 4. At TD circulate hole clean. Make wiper trip. CBU and POH. 5. Set test plug and change from Variable Rams to 9-5/8" casing rams. Test casing rams to 250/2500. Run and cement 9 5/8" casing in two stages. Land hanger in FMC multi-bowl wellhead. 6. Back out landing joint. Set Test Plug and change out 9-5/8" casing rams to 4 1/2" x 7" variable pipe rams and test pipe rams to 250/2,500 psi. 7. Set wear bushing. PRODUCTION: 1. Pick up 8 1/2" QD505X PDC bit and directional BHA. Drill out DV, Test casing to 2,500 psi. Continue RIH and drill out float equipment and 20' of new formation. CBU. 2. Perform FIT to leak-off expected at 13.0 ppg EMW. 3. Directionally drill 8 1/2" hole to 10,797' MD (5,180'TVD) per the directional program. Note: exact TD will be determined while drilling by the top of Sterling C2 pick in order to stay minimum of 15'vertically above the Beluga Sand formation. 4. At TD circulate hole clean. Make wiper trip as required. CBU. POH. 5. Rig up and Run CBL. 6. Set Test Plug and test 4 1/2"x 7" variable rams if not done previously with 7" pipe. 7. Pick up 7" liner assembly(200' Liner Lap) and RIH on 5"drillpipe. Circulate and condition hole. Cement liner according to program. Set hanger and liner packer. Circulate casing and drill pipe clean 8. Pick up polish mill and RIH. Test liner, liner lap, and 9 5/8" casing to 2,500 psi for 30 minutes. Polish seal bore extension. 9. POH laying down drill pipe. 10. Pull wear bushing. Pick up 7" seal assembly and RIH on 7" tubing. Stab into Liner hanger polished bore receptacle. Pressure up back side to 1000 psi confirming stab in. 11. Pick up 7" and space out 7" mandrel tubing hanger. Circulate well to 8.7 ppg KCL brine. Reverse in 8.7 ppg packer fluid. Observe well dead. Stab into polished bore receptacle. Land and test hanger seals. Test Annulus to 1,500 psi. Test tubing to 3,000 psi. Back out landing jt. Set BPV. 12. ND BOPs. 13. NU ADAPTER ASSY, A-4, 13 5/8-5K STDD BTM X 7 1/16-5K STDD TOP and 7" 5M tree. Test to 5,000 psi. 14. Rig down and move out drilling rig. Comment: • Drill all hole sections with 5"drill pipe • Perforating will be done after rig release with coil. 12IPage CASING PROGRAM MD(ft) ! Connection API Ratings Casing 1 E -- ------ Weight - - Hole Size Size , I Grade F (Ib/ft) O.D. Makeup (inches) Burst Collapse Tension (in) Top Bottom I ; Type I Torque € (inches) 1 (ft lbs) j (psi) (psi) (kips) 13 3/8" Surface 2,307' 68 J-55 BTC 14.375 , N/A • 16 3,450 1,950 1,069 9 5/8" Surface 8,630' 40 L-80 BTC 10.625 N/A • 12 1/4 5,750 3,090 916 7"L 8,430' 10,797' 26 L-80 VAM Top 7.565 11,950 8 1/2 7,240 5,410 604 Comments: *The make-up of the buttress connection will be to the proper mark. Vam Top will be torque turned. Make up and Bakerlok all float equipment to joints prior to running in the hole CASING DESIGN Casing Shoe Safety Factors Casing Setting Mud Wt Maximum Size Weight Grade Depth When Surface (In) (Ib/ft) (TVD ft) Set Pressure (lb/gal) (psi) Frc. Formation Grad. Pressure Burst Collapse Tension (lb/Gal) (lb/gal) 13 3/8" 68 J-55 1,958 9.4 15 8.5 1710 2.5 2.04 6.81 9 5/8" 40 L-80 4,939 9.8 13 1.5 -8.5 1772 3.25 2.46 2.65 7"L 26 L-80 5,180 9.8 13 1.5 -8.5 1182 6.13 3.14 9.81 I Comments: Production zone is expected to be depleted with potential virgin pressure cells. MAXIMUM ANTICIPATED SURFACE PRESSURE Casing Size Setting Depth MAWP* MASP** (in) (TVD) (psi) (psi) 13 3/8 1,958 2,651 1,382 9 5/8 4,939 2,468 1,772 7 5,180 3,556 1,182 *MAWP = Maximum Allowable Working pressure (80% Burst)**MASP = Maximum Anticipated Surface Pressure 13 I i WELL CONTROL AND CASING DESIGN CALCULATIONS Surface Casing=13 3/8' (2,307' MD / 1,958' TVD) Collapse 9.4 ppg mud wt at setting depth- evacuated = 9.4 ppg x .052 x 1,958' = 957 psi Safety Factor = 1,950 psi / 957 psi = 2.04 Burst Ca? Surface a) Frac Pressure @ Csg Shoe = (15.0 ppg + 0.5 ppg) X .052 X 1,958' -(.1 psi/ft x 1,958') = 1,578 psi - 196 psi = 1,382 psi b) Surface Pressure = Max Pore Pressure - Gas Gradient x next Casing Depth = (2,203* psi) - (0.1 psi/ft X 4934) = 2,203 psi -493 psi = 1,710 psi * Assumes 9 5/8" TDs in non-depleted formation. Use lesser of a or b = 1,382 psi Safety Factor = 3,450 / 1,382 = 2.5 Tension no buoyancy, hung in air = 2,307' x 68 =156,876# Safety Factor = 1,069,000/156,876 = 6.81 Maximum Allowable Surface Casing Pressure MASCP = (0.8 x Casing Burst) - (Mud Wt. - Backup Fluid Wt.) x .052 x TVD MASCP = (.8 x 3,450 psi)- ((9.4 -8.33)x .052 x 1,958')) MASCP = 2,651 psi 14IPage Intermediate casing: 9 5/8" (8,o30'MD/4,939' TVD) Collapse 9.8 ppg outside, 1/2 filled inside = .5 x 9.8 ppg x .052 x 4,939' = 1,258 psi Safety Factor = 3,090 psi / 1,258 psi = 2.46 Burst Surface a) Frac Pressure @ Csg Shoe = (13.0 ppg + 0.5 ppg)X .052 X 4,939' - (.1 psi/ft x 4,939') = 3,467 psi - 494 psi = 2973 psi b) Surface Pressure = Max Pore Pressure - Gas Gradient x next Casing Depth = (8.5 ppg X .052 X 5,180') - (0.1 psi/ft X 5,180') = (2,290 psi) - (518 psi) = 1,772 psi Assumption under b) is made to demonstrate worst case surface pressure if the reservoir had not been depleted. Current projected depletion pressure of 380 psi at TD results in a negligible surface pressure for burst calculations. Use lesser of a or b = 1,772 psi Safety Factor = 5,750 / 1,772 = 3.25 Tension Hung in air = 8,630' x 40# =345,200# Safety Factor = 916,000/345,200 = 2.65 Maximum Allowable Surface Casing Pressure This assumes the 9 5/8" penetrates the Sterling C in a depleted area and only affects the very bottom portion of the casing. MASCP = (0.8 x Casing Burst) - (Mud Wt. - Backup Fluid Wt.) x .052 x TVD MASCP = (.8 x 5,750 psi- (9.8 - 1.5) x .052 x 4,939') MASCP = 2,468 psi 15 II E; : Production Liner: 7" (10,797'MD/5180' TVD) Collapse 1/2 x 9.8 ppg x .052 x 5,180' = 1,320 psi or Formation Pressure - gas gradient = (8.5 ppg X .052 X 5,180') - (0.1 psi/ft X 5,180') = 2,290 psi - 518 psi = 1,772 psi Choose worst case = 1,722 psi Safety Factor = 5,410 psi /1,722 psi = 3.14 Burst @ Surface a) Frac Pressure @ Csg Shoe = (13.0 ppg + 0.5 ppg) X .052 X 5,180' - (.1 psi/ft x 5,180') = 3,636 psi - 518 psi = 3,118 psi b) Surface Pressure = Max Pore Pressure - Gas Gradient x next Casing Depth = (380 psi) - (0.1 psi/ft X 5,180') = 380psi - 518 psi = Surface pressure is negligible in this calculation due to reservoir depletion. c) Injection to Maximum allowable reservoir pressure = Max Pore Pressure - Gas Gradient x next Casing Depth = (1700 psi) - ( 0.1 psi.ft x 5180) = 1700 psi - 518psi = 1182 psi Use C as more realistic condition, rather than lesser of a) or b) or c) = 1,182 psi Safety Factor = 7,240 / 1,182 = 6.13 Tension Hung in air = 2,367' x 26# = 61,642# Safety Factor = 604,000/61,642 = 9.81 Maximum Allowable Surface Casing Pressure MASCP = (0.8 x Casing Burst) - (Mud Wt. - Backup Fluid Wt.) x .052 x TVD MASCP = (.8 x 7,240 psi- (9.8 - 1.5) x .052 x 5,180') MASCP = 3,556 psi Comments 16 I I ,, {- e BOPE PROGRAM Casing Test Casing Size MASCP MASP Test Pressure Casing (in) (Psi) (Psi) Test Pressure Fluid Density BOPS Size&Rating Low/High (psi) (lb/gal) (psi) (1)13-5/8"5M annular 250/2,500 Surface 13 3/8 2651 1382 2,000 9 (1)13-5/8"5M pipe ram (1)13 5/8"5M blind ram (1)13-5/8"5M drilling spool with 4 1/16"5M outlets (1)13-5/8"5M annular 250/2,500 Intermediate 9 5/8 2468 1772 2,500 9.5 (1)135/8"5M pipe ram (1)135/8"5M blind ram (1)13-5/8"5M drilling spool with 4 1/16"5M outlets (1)13-5/8"5M annular 250/2.500 Production Liner 7 3556 1182 3,000 9.4 (1)13-5/8"5M pipram (1)135/8"5M blind ram (1)13-5/8"5M drilling spool with 4-1/16"5M outlets MASCP - Maximum Allowable Surface Pressure (80% Burst) MASP- Maximum Anticipated Surface Pressure 17IPage BOPE DIAGRAMS Diverter System I / I I __,, I . -047 --, I , . , I, , . r- 1 _ I , II —^. I i _.....--V----, I I ___...A.„ I 1 I I I 21 1/4"" DIVERTER SPOOL I i I FABRI-VALVE 16" KNIFE VALVE I ANSI 300 FLANGES CHOKE MANIFOLD TO ELEVATION FLARE LINE VIEW "B" PRESSURE ----4 8, 1 GUAGE ®c::mom CD © ;----0 3 '`+ '�T) 4 0 17i� �e e . 0 uo ®. v r,.-1 0 35` • " * . I 0 . 4.47#.'- ' i 3,04;4 t5,2 4 ELEVATION CaVIEW II I FROM `ov ap MATERIAL LIST WELLHEAD ELEVATION VA VIEW "A" -----(1-6) I ITEM I I.D.NO. ' DESCRIPTION -. 1 ASO611161 3-1/16'10,000*CNV'FC G, 2 Ni166 3-1116'x3-1/16"x3-1/16'x3-1. -- V 0 - 1 2.1'16'10,000*x 23'OAL STU -__ 15 14 11` 3 F3092AC 3116 10,000# BLIND FLAN 4 27430 3-1.16 x 10,000# VALVEWOI �- "VW-FC"GATE VALVE _ 31!16 II 10,000# VALVEWOI II• III I♦��♦ '' 11 ...-6 1 N1188 3 1.'16C 10. * STUDDED ND FLAN_.. TO GASBUSTER iI� r., 21 20 N II-10000 as aa, ELEVATION VIEW "A" 19 ' Page BOP STACK Shaffer 13 5/8" 5M Annular / } J L Shaffer 13 5/8" 5M Double Ram BOP ,: `LI_� J 3 ---_ LE L j�O�j L u _--- Pipe Rams n r- __nn� r-nn u_L L L �1 L U p LI 1 Blind Rams II I -1-Wl-,:- 7 P--------mii Kill Line - I AIA 3 1/16" 3 1/16" 3 1/16" 4 1/16" 10M 10M Check 10M 4 1/16" HCR 3 1/16" 10M 10M HCR wirmow UPPER UNIHEAD ASSY, UHM-ET,j = 1 ° 13 5/8-3K STDD BTM -' • X 13 5/8-5K FLG TOP111=1111. i 16-5K M120 PLUS GV (P150532) - Ell— (l�,• , 1.---ei - 133/8" ODCSG CASING HEAD ASSY, C22-EG �g 5/8" OD CSG 13 3/8 SLIPLOCK X 13 5/8-3K P183999 7" OD CSG Cook Inlet Natural Gas Storage Alaska 13 3/8 x 9 5/8 X 7 20 IPage Blowout Preventers The blowout preventer stack is a 13-5/8" x 5000 psi annular preventer, a 13-5/8" x 5000 psi double gate ram type preventer with blind rams in the bottom and pipe rams in the top and a 13-5/8" x 5000 psi drilling spool (mud cross) with 3-1/8" x 5000 psi outlets. The choke manifold is rated 3-1/8" x 10,000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also induded are a poor-boy gas buster and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mud pits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. Casing Test Pressures Casing test pressures are based on the most severe conditions expected either while drilling or during the production life of the well. Minimum casing test pressure is 50%of the 5M BOP rating which is 2,500 psi for all casings in this well per AOGCC 20 AAC 25.030(e)however,a 3,000#stack is all that is required to drill this well. A variance is requested to accept a minimum casing test pressure of 50%of 3,000#or 1,500 psi although as indicated in this application actual test pressures will be 2,000 psi or higher. WELLHEAD EQUIPMENT SUMMARY Component Description Hanger Type CASING HEAD ASSY, C-22-EG, 13 3/8 SLIP-LOCK BTM CASING MANDREL HANGER, UH-A, Casing Head PREP X 13 5/8-3K FLG TOP W/TWO 2 LPO, PREP F/ FLUTED, BODY, F/ 13.505 BOWL, 9.625 API UPPER UNIHEAD ASSY, UHM-ET, 13 5/8-3K STDD BTM TUBING HANGER ASSY, TC-1A-ENS, 13 5/8 X 13 5/8-5K FLG TOP, W/TWO 2 1/16-5K STDD OUT, FLG, 7 VAM TOP (29 LB/FT)BTM &TOP, Tubing Head 13.505 THRU-BORE, A 320 GR L7, NON-EXP BLTG, EE- ISA BPVT, 8.985 EN, W/2 CONT SCSSV 0,5, P-U, PSL 2, MONOGRAMMED, W/ LOWER AND PORT, COMP PACKOFF BTM, DD-NL, P-U, UPPER LDS, PSL 2 ADAPTER ASSY, A-4, 13 5/8-5K STDD BTM X 7 1/16-5K Adapter Flange STDD TOP, L7, F/8.985 EN, EE, K-U, PSL 2, MONOGRAMMED Comments: Hanger is prepped for two control line penetrations. 21IPage DIRECTIONAL PROGRAM SUMMARY Well Profile Data Design Comment MD(ft) Inc(°) Az(0) TVD(ft) Local N(ft) Local E(ft) DLS(°/100ft) VS(ft) Est. RKB 53.55' 0.00 0.000 232.445 0.00 0.00 0.00 0.00 0.00 KOP 300.00 0.000 232.445 300.00 0.00 0.00 0.00 0.00 End of Build/13 3/8"Csg Pt 2307.49 60.225 232.445 1957.72 -586.01 -762.18 3.00 961.14 Begin Final Build&Turn 7812.32 60.225 232.445 4691.43 -3498.38 -4550.07 0.00 5737.84 Tgt Entry/EOC 8604.82 83.596 237.077 4935.92 -3928.23 -5162.08 3.00 6485.58 9 5/8"Casing Pt 8629.82 83.596 237.077 4938.71 -3941.73 -5182.93 0.00 6510.38 TD/7"Liner 10796.91 83.596 237.077 5180.43 -5112.22 -6990.64 0.00 8660.47 Comments: Verticalsection calculated from a reference azimuth of 233.82° taken from surface location to bottom hole location. Potential Well Interference: ellipse of Clearance @MD uncertainty Well Distance (ft) (ft) separation (ft) CLU#6 2149 7132 1779 CLU#9 533 9605 136 CLU#10 720 10,797 347 CLU Storage 4 49.7 0 37 CLU Storage 3 99.77 0 87 Comments: No serious interference exists. See attached directional plan and anti-collision analysis for more details. DIRECTIONAL SURVEYING SUMMARY MWD Magnetic Gyro Interval Comments Survey Multi-shot Multi-shot 0 -2,307' X 2,307' - 8,630' X 8,630' - 10,797' X Comments: 22IPage a.) tio fp a m N • W Northing(tt) kV z SI we Mum o2 or o �� •e ti P 1 a • n fi ni y, (U lri r/i � 3 g viUU altiiii O a ''Y^^ t v/ U) (U o 0 '' r ii Y4 L G h Z ‘7; R i l L 7$ tC d(n C° u+ C �f5 r sa C z - Y Y? O - . _ o o Yc., 1 U .Qa �" aeta m r .. s cU'v Z Zc�ic7 0 a x ZU a z 4� U J �a a z I- AVW AA jfl X .. ; ui J 7,ce tird W (.3tl) CI l v to az MErtir ilb d 1 i Is 0i J J s► ► ► m ► ► . ► , ► N or, s %i A n A t 4 -V r 4 -4 J Ai r il— 5 —I 8 g Z., i 4_ ., . .l aig — ! fill al-)- 11. 4- Ill : ' -0c(1, ll' 1111 ! % i. 1 ' 4- t-i - \ -0I 4- 111 l —1 4- j 11 11 - —1 I— ' Hai. i 14 Alli : ! 111111 iR , . 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H - 2 2 r y J t/! 4h .r M M 1'- ,W " VI rk -* -L qb Y j7- V Z Z 5 ih �4 1- 3 O SESZS XX2X iiX222P _2[222 PLANNED WELL SUMMARY SHEET Cook Inlet Natural Gas Mill STORAQ ,- CINGSA(Cook Inlet Natural Gas Storage Alaska) hoc r n Coat loot,Panto Aro Pertmuia; SOt Sot P6 Flea Carvery Loco Unit sh.1Ce3 WV- CU,Strive 5 %MIS Plot reference vre oat^is CLL Storage 5 Version 47 True vertica depths re re`erenced to Nabors 105E(RTE) Grid System:NAD83!TM Alaska SP.Zone 4(50041.US feet Meas rec depths are referenced to Nabors 105E(RTE) North Reference:True north Nabors 105E(RTE)to Mean Sea Level:53.55 feet Scale:True distance _ Mean Sea Level to Mud fine;At Slot:Slot 45):0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by pnethoh on 19-Nov-It Location Information Facility Name :3ndd East(US ft) Grid North(US ft) Latitude Lorgituoe Gas Storage Pad '412992.830 2388198.600 60'31'52.018'N 151°15'45.884'W Sic- Local N(ft) Local E(it) Grid East(US ft) �d North(US ft) Latitude Longitude Slot#5 4568.00 8787.18 1421865.620 2392594.970 5C'32'36.952'N 1 E 1°12'50.198'Jb' Nabors 105E(RTE)to Mud line(AX Slot Slot#5) ._ 5_-r Mean Sea Level to Mud line(At Slot Slot ifs) Nabors 'DFE IRTE)to Mean Sea Level f 5.5:ft Survey Program Start MDOtl ='d MD(ft) Tool Model _ogName.Cor'ment Weltore 53.55 2307.49 NaviTrak NavTrak(MagCorr) CLU Storage 5 2307.49 5529.82 AutoTtak G3 .4JtoTrak G3 (Standard) CLU Storage 5 8629.82 1:796_91 OnTrak DnTrak (Standard) CLU Storage 5 Well Profile Data Design Comment MD(ft) Inc(°) Az(`) ND(ft) Loca ',. Local E ifti DLS(°1100ft) VS(ft; Est RKB 53.55' 0 DD 0 DDD 232.445 0.00 _ 0.00 0.0.E 0.00 0.00 KOP 300 00 0 DDD 232.445 300.00 0.00 0.00 0.00 0.00 End of Build 1 13 3t8"Csg Pt 2307.49 52.225 232.445 1957.72 -586.01 -752.18 3.00 981.14 Begin Final Bull 8 Tam 7Er 2.32 80.225 232.445 469143 -3498.38 -4550.07 0.00 5737_64 Tgt Entry!EOC 5634.82 83.595 237.077 4935.92 -3928.23 -5162.08 3.00 6485.58 9 51-Casing Pt 5e29.52 83.596 237.077 4938.71 -3941.73 -5182.93 0.00 6510.38 TD 7-Luer 10795 91 93.596 237.077 5180.43 -511222 -6990.64 0.00 8680.47 Hole and Casing Sections ',3'le NO i ti M D(I)) Interval in: rvo(11) TVD(R) Loc N(t) Loc E Rt) Loc N(Iq ..nMart Man Ens al Er.: wel ore 213'0ond rcor E.03 118.00 11E10 0.00 11800 am DOC CO3 DX CLU mirage 5 13 3 8"Castg Grtaoe C.O0 2307.49 2307.49 0.D3 1957.72 0.00 ODD -5850- -762.18 CW Storage 5 9 5R"Caerg Iiiennedlaea C.00 5629.M 8625. 2 C.00 4938.71 000 00C -3911.7: -518293 OW Stirage 5 7 Liner 5429.82 10795.90 2367.08 490E59 5180.43 -3833.15 -5017.80 -51122 1 -693E13 CW 0b439e 5 Targets Name Mo(II) 1VD(R) Local N(ft) Local E 11.1 980 East(1.Z111 Grid Oath(00111 LAlkrde Longitude ='13 -e.•red TT Nee REVISED 24-05-11 161.82 4935.92 -382823 -515209 141663220 2386762.82 EC-3158256N 151'1433.3711A' =1: =•-.7,i•-el Tgt Toe REV 24-OQ-11 1079591 51E18.43 -611222 -6990.64 1414782.20 238761282 60'3116,557W 151'18139.90M Bottom Hole Location ND(8) no r) Azr) TVD fr.) Local 1:^. _a:al E.ht: Grid East fun 1t 1 lard Notal(US 1n arum Longitude 10796.91 53.596 237. 77 5180.43 -51122 :.:?:7 54 141478220 2387512.42 60'31'46.587N 151'15129.9041V 29IPage DRILLING FLUID PROGRAM SUMMARY Casing Hole Depth TVD Mud Mud Weight Additives Size Size (MD) (TVD) System (ppg) (in) (in) (ft) (ft) Gel, Gelex, Soda Ash,Caustic, Barite, Polypac Supreme UL 13.375" 16" 2,307 1,958 GEL SPUD 8.8-9.4 Flo-Vis,PolyPac UL,KCI, SafeCarb(F/M) ,Barite,LOTORQ Caustic,Conqor 404, 9.625" 12.25" 8,630 4,939 6%KCL FLOPRO NT Sodium Meta Bisulfate 9.2—9.8 Flo-Vis,PolyPac UL,KCI, SafeCarb(F/M) Barite,LOTORQ, Caustic,Conqor 404, 7" 8.5" 10,797' 5,180' 6%KCL FLOPRO NT Sodium Meta Bisulfate 9.4—9.8 Liner Comments: See mud prognosis for details. The mud system from the intermediate section may be utilized in the production hole section Instead of building a new mud for that section. Sized CaCO3 (SafeCarb) will be used to control seepage losses and aid in wellbore strengthening. DRILLING FLUID SPECIFICATIONS Plastic Yield API Funnel Depth TVD Mud Wt. Viscosity Point Fluid Loss Viscosity LGS (ft) (ppg) (cp) (Ib/100ft2) (mI/30min) (sec/qt.) pH 0' - 1,958' 8.8 - 9.4 15 - 24 >30 <18 70 - 150 8.0 - 9.0 < 6 1,958' - 4,939' 9.2 -9.8 10 - 16 12 - 18 5 - 7 30 - 50 9 - 9.5 < 6 4,939' - 5,180' 9.4- 9.8 10 - 16 12 - 18 4 - 6 40 - 50 9 - 9.5 < 6 Comments: None 30 1 SOLIDS CONTROL EQUIPMENT Item Equipment Specifications (quantity, design type, model, flow capacity, etc) Shakers 2 x King Cobra , Brandt Linear Motion Desander na Desilter na Mud Cleaner na SWACO model 518, 75-140 gpm at Centrifuge 2,500 to 3,300 rpm, 180-250 gpm at 1,900 rpm. Comments: Additional equipment on site will be a Swaco Model 518 centrifuge and tank package to de-water discarded drilling fluids. The water will be re-used to limit disposal volumes and the solids processed, tested and disposed of in the Kenai Borough Landfill. CEMENT PROGRAM SUMMARY Casing Depth Gauge Top of cement Ann Vol WOC Open Size Hole To TOC Time Hole (in) Size (bbls) (hrs) Excess MD TVD (in) MD TVD (%) (ft) (ft) (ft) (ft) 13 3/8 2307' 1958' 16 0 0 196 5 75 9 5/8 8630' 4939' 12 1/4 0 0 497 24 10 7" L 10797' 5180' 8 1/2 8,430 4,909 68 8 Note 1 Note 1: No excess in Production liner OH,excess volume accounted for in 200' of slurry on top of the liner. Compressive Casing TOC Mix Water Strength Cement Density Qty Yield Slurry WL FW Size Slurry MD ° ) (psi) (. ) Description (lb/gal) (sxs) (cu.ft/sx) (bbls) (ft) Qty (cc) (/o m Type 8 hr 24hr (gal/sx) 13 3/8 lead Type I/II 12.0 593 2.45 259 0 14.52 Fresh NA <1 120 350 tail Type I/II 15.4 276 1.22 60 1941 5.5 Fresh 245 0 420 2,449 lead Type I/II 12.0 633 2.45 276 3,500 14.52 Fresh NA <1 120 350 9 5/8 tail FIexSTONE 14.0 196 1.29 45 7,995 4.1 Fresh 10 0 520 1327 2nd Type I/II 12.0 484 2.45 211 0 14.52 Fresh NA <1 120 350 stage 7 F1exSTONE 14.0 296 1.29 68 8,229 4.1 Fresh 8 0 520 1327 9 5/8"cementing will be performed in two stages using a hydraulically actuated stage collar at approximately 3,500' MD. Comments: See cement prognosis for details and spacer specifications. 31IPage REGULATORY WAIVERS AND SPECIAL PROCEDURES 1) AOGCC Regulation 20 ACC 25.035 (e) (1) (A) for an operation with a maximum potential surface pressure of 3,000 psi or less, BOPE must have at least three preventers, including The Nabors 105ac rig has a 5,000 psi BOP stack and 10,000 psi choke manifold as standard equipment. The maximum potential surface pressure is less than 3,000 psi and CINGSA requests that the AOGCC accept CINGSA's determination under this regulation that only three preventers are required. 2) AOGCC 20 AAC 25.412 (b) The packer must be placed within 200 feet measured depth above the top of the perforations, unless the commission approves a different placement depth as the commission considers appropriate given the thickness and depth of the confining zone. CINGSA requests to increase the packer measured depth distance to 400'for this well. The intermediate casing string will be cemented into the top of the Sterling C, however, the expected top perforations for this well may be up to a hundred feet below the 9 5/8" shoe. The exact location will not be known until the logs are processed. The liner lap is designed to be 200'to provide optimal liner lap isolation with cement. The packer is a BakerHughes ZXP liner top packer. CINGSA believes the primary isolation of the reservoir is the 500'+ of high compressive strength premium cement used for the tail slurry of the 9 5/8"cement job. Secondary protection is the cemented 7" liner with calculated top of cement above the liner top. Tertiary protection is then provided by the liner top packer. 3) 20 AAC 25.035. (10)the BOPE must be tested as follows: (A)when installed, repaired, or changed on a development or service well and at time intervals not to exceed each 14 days thereafter, BOPE, including kelly valves, emergency valves, and choke manifolds, must be function pressure-tested to the required working pressure specified in the approved Permit to Drill, using a non-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure; however, the commission will require that the BOPE be function pressure-tested weekly, if the commission determines that a weekly BOPE pressure test interval is indicated by a particular drilling rig's BOPE performance; CINGSA requests to perform BOPE tests at intervals not to exceed 14 days in accordance with 20 AAC 25.035: BIT SUMMARY Interval MD Size Type Manufacturer Model No. IADC Recommended Estimated WOB - RPM ROP -Ft/Hr 0 -2307' 16" ST HCC VM-1 115 55 klbs-250 120 2307'-8630' 12 1/4" PDC HCC QD505X M223 38 klbs- 175 100 8630'- 10,797' 8 1/2" PDC HCC QD505X M223 25 klbs - 175 75 Comments: See bit prognosis for additional Information. 32 I Page HYDRAULICS SUMMARY Rig mud pumps available are shown below. Max Displacement Qty Make Model Liner Stroke Press@ at 100% Max Rate Hole Sections (in) (in) 90% WP efficiency (spm/gpm Used (psi) (gal/strk) 6 9 3232 3.3 130/430 Surface Gardner 2 PZ9 1000 5.5 9 3847 2.78 130/361 Intermediate Denver 5.5 9 3847 2.78 130/362 Production Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. Depth MD Hole Pump Standpipe Min. ECD Nozzle Size Rate Pressure AV Size Remarks (ft) (PPM(In) (gpm) (psi) (fpm) (32nds) 0 -2307' 16-18-18- 16 650 2,000 70 +0.2 18-0 2307'-8630' 12.25 650 2,000 130 +0.3 5 x 13 8630'- 10,797' 8.5 450 2,500 233 +0.6 5 x 15 Comments: See separate hydraulics calculations. Annular velocities in the 16",12 1/4", and 8 1/2" holes were calculated using 5" drill pipe. 5" drill pipe will be used to drill all hole sections to maximize hole cleaning, while minimizing stand pipe pressure. 33IPage FORMATION INTEGRITY TEST PROCEDURE Surface and Intermediate casing shoes will be tested to Leak-off. Prior to drilling out of casing strings, test BOPs, and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak-off tests (LOT) are to be conducted as described below: 1. Drill 20' to 25' of new formation below the casing shoe and condition the mud to the same properties in and out. 2. Pull drill bit into the casing shoe and close pipe ram preventer. Line up to the choke manifold with a closed choke. 3. Begin slowly pumping fluid down the drill string at 1/2 bpm while recording casing and drill pipe pressures at 1/2 bbl intervals. 4. A running plot of pressure versus volume should be kept by the Drill Site Manager while the test is in progress. 5. Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports. 6. Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. 341Page PROPOSED COMPLETION SCHEMATIC CINGSA CLU Storage 5 Proposed Completion Schematic FM( TJl'elheai- 3 5 5'5000=Muln rar: FIC Tr - 5i '=complete wah SSS' 133*155 driven to 1155 TVD 1155 MD Halhbartca'R'aeLme RFvabe SSSS'rig 150'TVD,15O'MD 1 r a ]3 31' 68=155 BTC S.mface CaM3e r 1.95S'TVC 2.3007'NC R n Id'hole Caromed to Sine Fy SFr yet' Vex Tap Tubing 7' s 9 5 8"Bake 1731Lurer Tap Packer with]C✓yea bare 4 4.R9' TVD;&437'MD 9 Ira"4 LSO BTC Immediate Cosine 4 4,9391 TVD L630'MD • 1 1:4"hole Cemenaed.to Surface • +, 5+X"014-6 SPF perforation • 7' 6=LSO V n Tap Pro&uciaa Lim from 4.909'TVD SAM MD TOP to 5.18(7 TVD..10,797"MD TD S 1,'2"hole;Cemented 351Page SURFACE USE PLAN FOR CLU STORAGE 5 Surface location: 1) Existing Roads Existing roads which will be used for access to CLU Storage 5 are shown on the attached map. Kenai, Alaska is the nearest town to the site and is also shown on the map. 2) Access Roads to be Constructed or Reconstructed No new roads will be required to access CLU Storage 5 3) Location of existing wells Well CLU Storage 5 will be drilled on the CINGSA Drill Pad. A pad drawing is enclosed that shows the proposed well surface locations 4) Location of existing and/or proposed facilities The attached plot plans show the proposed facilities that will be installed on the Drill Pad and Main Facilities pad for the gas storage operations. 5) Location of Water Supply Water supply will be taken from a permitted water well on the Well Pad. 6) Construction Materials Installation of production equipment, flowlines and headers are expected during the drilling of this well. All operations in addition to well drilling will be addressed as Simultaneous Operations (SIMOPS) and will be addressed to mitigate potential hazards with proper pre-job safety meetings, coordination protocols, and emergency response procedures. 7) Methods of handling waste disposal; a) Mud and Cuttings Annular Injection will not be used for disposal of drilling waste(mud and cuttings). Waste(formation cuttings and drilling fluid)generating during the drilling of CINGSA's 5 gas storage wells will be disposed of in the Kenai Borough Solid Waste disposal site just outside of Soldotna, Alaska. Wet solid wastes coming off of the shale shakers and centrifuges will be gathered in a small tub at the base of the shale chute. AIMM Technologies is contracted to continuously pick up the cuttings in a 70 bbl vac truck and deliver to their processing facility in Kenai. AIMM will process the cuttings by adding dry solid material until it meets the filter test standards of the landfill then store the cuttings in 100 cubic yard piles in an approved lined pit until the results from multiple samples show the waste to be suitable for disposal at the Kenai Borough landfill. Once cleared for disposal, AIMM will load the cuttings onto transport trucks and take them to the land fill. Transport of Cuttings will be manifested from the time they leave the Drilling Pad to entry into the landfill. 36IPage b) Garbage All household and approved industrial garbage will be hauled to the Kenai Peninsula Borough Soldotna Landfill. c) Completion Fluids Clear fluids will be disposed of at a commercial facility. d) Chemicals Unused chemicals will be returned to the vendors that provided them. Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage will be picked up and disposed of through the municipal sewer system by a licensed local service company. 8) Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption. Potable water will be delivered to the camp and gray and black water picked up and properly disposed of by a commercial pumper. 9) Plans for reclamation of the surface Reclamation of the pad will occur after the abandonment of CLU Storage and the other roposed wells on the pad. Approval of the plan of reclamation will be obtained from the U.S. Fish and Wildlife Service prior to any reclamation work beginning. 10) Surface ownership The surface owner of the land on the CINGSA Drill Pad is the State of Alaska. The pad is leased from the State of Alaska. 11) Operator's Representative and Certification I hereby certify that I, or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions that currently exist; that the statements made in this plan are, to the best of my knowledge, true and correct; and that the work associated with operations proposed herein will be performed by Cook Inlet Natural Gas Storage Alaska, LLC and its contractors and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 18 U.S.C. 1001 for the filing of a false statement. Date: Name and Title: 37IPage OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME Ca G1 dAt l l J PTD# 2// / cy Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: //62 fuL L POOL: � --'(//)15 Cl S Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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No special effort has been made to chronologically organize this category of information. CLU Storage 5 Kenai Borough, Alaska December 22, 2011 to January 17, 2012 Provided by: Approved by: Ari Berland Compiled by: Ralph Winkelman John Lundy Distribution: January 23, 2012 T.D. Date January 7, 2012 CLU STORAGE 5 2 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT AND CREW...........................................................................................3 1.1 Equipment Summary ......................................................................................................................3 1.2 Crew................................................................................................................................................3 2 GENERAL WELL DETAILS...................................................................................................................4 2.1 Well Objectives...............................................................................................................................4 2.2 Well Resume ..................................................................................................................................5 2.3 Hole Data........................................................................................................................................5 3 GEOLOGICAL DATA.............................................................................................................................6 3.1 Lithology Review.............................................................................................................................6 3.2 Sampling Program........................................................................................................................19 4 DRILLING DATA..................................................................................................................................20 4.1 Daily Activity Summary.................................................................................................................20 4.2 Surveys.........................................................................................................................................26 4.3 Bit Record.....................................................................................................................................29 4.4 Mud Record ..................................................................................................................................30 4.5 Drilling Progress Chart..................................................................................................................31 5 DAILY DRILLING REPORTS...............................................................................................................32 Enclosures: 2”/ 100’ Formation Log (MD and TVD) 2”/ 100’ LWD Combo Log (MD and TVD) 2”/ 100’ Drilling Dynamics Log (MD) Final Data on CD ROM CLU STORAGE 5 3 1 MUDLOGGING EQUIPMENT AND CREW 1.1 Equipment Summary Parameter Equipment Type /Position Total Downtime Comments Computer – Driller’s Monitor Azonics 0 Computer -- Pit Monitor Azonics 0 Computer -- Company Man RigWatch Remote (HP Compaq) 0 Computer – Directional Driller RigWatch Remote (HP Compaq) 0 Computer – Tool Pusher RigWatch Remote (HP Compaq) 0 Computer – Mud Engineer RigWatch Remote (HP Compaq) 0 Computers – Mudloggers (4) RigWatch Master, DML, RigWatch Remote, WITS Feed (all HP Compaq) 0 Ditch gas QGM gas trap; Flame ionization total gas & chromatography. 2 Multiple cleaning and adjustment Hook Load/ Weight on bit Fed from Academy PLC 0 Mud Flow In Derived from Strokes/Minute and Pump Output 0 Mud Flow Out Vega Sonic Flow-line Sensor 0 Pit Volumes, Pit Gain/Loss Vega Sonic Volume Sensors (8) 0 Pump Pressure Fed from Academy PLC 0 Pump Stroke Counters (2) Hard-wired Proximity Sensors 0 Rate of Penetration Crown Sheave Encoder 0 RPM Fed from Academy PLC 0 Torque Fed from Academy PLC 0 WITS—To / From Baker Hughes Inteq RigWatch Remote (HP Compaq) 10 Rigwatch issues 1.2 Crew Mud Logging Unit Type: Arctic Mud Logging Unit Number: ML057 Mud Loggers Years Days Sample Catchers Years Days Technician Days Ralph Winkelman 21 19 Larry Resch 9 13 Howard Lamp 2 John Lundy 20 25 Justin Rosenblume 1/2 12/24 *1 Years experience as Mudlogger *2 Days at wellsite between rig up and rig down of logging unit. CLU STORAGE 5 4 2 GENERAL WELL DETAILS 2.1 Well Objectives The objective of CLU Storage 5 is to drill and log a single zone gas storage well in the (Kenai Group, Sterling Formation) Cannery Loop/ Sterling C Gas Pool with a minimum of hole problems or other concerns. Based on the characteristics of electric log data, the stratigraphic top of the Sterling C is a contact with marker coals at the base of the massive Sterling B5 Sand Unit, and its base is a conformable contact with the top with the Upper Beluga (Formation). The Sterling C is composed of channelized fluvial sandstones with interbedded silty sands and shales that are minimally folded within a low gradient 4-directional dip closure. The Sterling C Gas Pool consists of the Sterling C1 and C2 Sand Units, at depths from 4871’ TVDSS to 5101’ TVDSS. The gross reservoir interval thickness averages approximately 200 feet across the closure, and the average net sand thickness is approximately 95 feet. Wireline logs and production data from Marathon Oil Company’s CLU-8 Well were used to delineate the localized Gas Pool interval and provide the critical post-production reference data for depletion gradients. CINGSA plans to use this depleted reservoir of the Sterling C Gas Pool for gas injection and storage. CLU STORAGE 5 5 2.2 Well Resume Operator: CINGSA Well Name: CLU Storage 5 Field: Cannery Loop / Sterling C County: Kenai Borough State: Alaska Company Representatives: John Nicholson, Mike Grubb, Steve Ratcliff Location: Surface Coordinates 720’ FNL 1760’ FEL, Sec. 9 T5N R11W SM Pad Elevation 33.0’ AMSL Rotary Table Elevation 53.5’ AMSL Classification: Gas Storage API #: 50-133-20601-00-00 Permit #: 211158 Rig Name /Type: NAD 105-E / Arctic/ Triple Spud Date December 22, 2011 Total Depth Date: January 07, 2012 Total Depth 11,101’ Primary Targets Sterling C Sands Primary Target Depths 9211’ MD, 4979’ TVD Total Depth Formation: Sterling Completion Status: Run 7” Liner, (Run 7” Tie-Back to surface) LWD-MWD Services. Baker Hughes Inteq Directional Drilling Baker Hughes Inteq Wireline Logging Services Baker Atlas Drilling Fluids Service MISwaco CANRIG Logging Geologists: Ralph Winkelman, John Lundy CANRIG Logger Trainees: Justin Rosenblume, Larry Resch 2.3 Hole Data Maximum Depth Shoe Depth LOT (ppg) Hole Section MD (ft) SSTVD (ft) TD Formation Mud Weight (ppg) Dev. (oinc) Casing Diam. MD (ft) SSTVD (ft) Conductor 118.5’ 64.99’ Recent -- 0.00 20” 118.5’ 64.99’ NA 16” 2400’ 1964.02’ Sterling 9.1 59.50 13 3/8” 2390’ 1959.43’ 15.5 12-1/4” 8872’ 4864.97’ Sterling 9.3 78.42 9 5/8” 8860’ 4862.71’ 15.0 8-1/2” 11101’ 5073.19’ Sterling 9.2 88.13 7” 11099’ 5073.13’ N/A CLU STORAGE 5 6 3 GEOLOGICAL DATA 3.1 Lithology Review Sand/Conglomeratic Sand (2400’-2540’) = medium to medium light gray with a slight greenish secondary hue; unconsolidated/disaggregated loose sand; moderately well sorted; medium lower to fine upper grain; trace medium upper; scattered coarse lower grains; about evenly divided between translucent white to smokey quartz and medium gray common orange volcanics/jasper; trace to common dark gray to black mafic mineral/lithics; trace varicolored mineral grains and fine mica flakes; trace partially de-composed wood fragments; trace to locally abundant medium gray claystone; occasional thin tuffaceous siltstone interbeds; trace very fine grain silty sandstone and soft white fluffy ash; slightly calcareous overall. Sand/Conglomeratic Sand (2540’-2640’) = medium to medium light gray with a slight greenish secondary hue; unconsolidated/disaggregated loose sand; moderately well sorted; medium lower to fine upper grain; trace medium upper; scattered coarse lower grains; scattered granule size quartzite grains; scattered coarse lower grains; translucent white to smokey and clear colorless quartz predominate; 40 to 50% medium to medium light greenish gray; common to very abundant orange jasper/ volcanics; common mica flakes; trace bluish greenish gray, brown, rose and other varicolored minerals; occasional thin coal and siltstone interbeds; trace to common very fine grain silty calcareous silty sandstone; very slightly to moderately calcareous. Sand/Conglomeratic Sand (2640’-2730’) = medium to medium light gray with a slight greenish secondary hue; unconsolidated/disaggregated loose sand; well sorted; fine upper to medium lower; trace medium upper; angular to subangular; individual grains dominantly clear to translucent quartz and volcanic glass with abundant multicolored lithics; medium to dark gray, light to medium green to greenish gray, orange, rust, pale rose, black and trace light yellowish green; non calcareous. Sand (2740’-2800’) = medium to medium light gray overall with abundant multi- colored lithics throughout, dominantly clear to translucent quartz and volcanic glass, light to medium green to greenish gray, light to dark gray, black, rust, orange, pale rose and light yellowish green; very fine upper to medium upper, dominantly fine upper to lower; angular to subangular; moderately well sorted; unconsolidated. Sand (2800’-2880’) = medium to medium light gray overall with a strong salt and pepper appearance from the abundant multicolored lithics, dominantly clear to translucent quartz and volcanic glass with varicolored lithics as previously described; very fine upper to coarse lower, dominantly fine lower to medium lower; angular to subangular; poor to fair sorting; unconsolidated; non calcareous; rare trace tuffaceous claystone; light to very light gray; soft; shapeless cuttings; silty to clayey texture; dull to greasy luster; very soluble; poor cohesiveness and adhesiveness; moderately expansive; non calcareous. Sand/Conglomeratic Sand (2880’-2970’) = medium to medium light gray with abundant multicolored lithics, dominantly clear to translucent quartz and volcanic glass light to medium greenish gray to bluish green, medium to dark gray, black, rust, orange, pale rose and light yellowish green; very fine lower to trace very coarse lower, dominantly fine lower to medium lower; poorly sorted; angular to subangular; dominantly unconsolidated; trace carbonaceous material with medium varicolored sand grains interbedded along bedding planes; non calcareous; trace tuffaceous claystone/ siltstone; non calcareous. CLU STORAGE 5 7 Sand/Conglomeratic Sand (2970’-3060’) = medium to medium light gray overall; salt and pepper in part; abundant multicolored lithics; dominantly clear to translucent quartz and volcanic glass with lesser light to medium gray, light to medium greenish gray, black, orange, rust, pale rose and light yellowish green grains; very fine upper to trace very coarse upper, dominantly medium upper to lower; angular to sub-angular; poorly sorted; dominantly unconsolidated; trace varicolored, non-calcareous, hard, grain supported, moderately well sorted, medium sandstone; trace soft soluble light gray tuffaceous claystone-siltstone; shapeless; silty to clayey texture; dull luster; poor adhesiveness and cohesiveness; non calcareous. Sand/Conglomeratic Sand (3070’-3110’) = medium to medium light gray with abundant multicolored lithics, dominantly clear to translucent quartz and volcanic glass light to medium greenish gray to bluish green, medium to dark gray, black, rust, orange, pale rose and light yellowish green; very fine lower to very coarse upper, dominantly medium upper to lower; angular to subangular; poorly sorted; disaggregated. Tuffaceous Claystone/Tuffaceous Siltstone (3110’-3190’) = light gray with very light brownish gray and yellowish gray secondary hues; very soft and fragile to slightly firm and brittle; irregular, shapeless cuttings; silty to clayey texture; dull, earthy luster; hydrophilic; soluble; poor adhesiveness; poor to fair cohesiveness; non calcareous; trace dark brown to black micro thin carbonaceous laminations and inclusions. Sand (3190’-3270’) = medium to medium light gray overall with abundant multi- colored lithics throughout, dominantly clear to translucent quartz and volcanic glass, light to medium green to greenish gray, light to dark gray, black, rust, orange, pale rose and light yellowish green; very fine upper to coarse lower dominantly fine upper to medium lower; angular to subangular; poor to fair sorting; dominantly unconsolidated; non calcareous; trace tuffaceous claystone/ tuffaceous siltstone; light gray; soft; fragile; silty to clayey texture; earthy luster; poor adhesiveness and cohesiveness; non calcareous. Sand/Conglomeratic Sand (3270’-3340’) = medium to medium light gray overall with a strong salt and pepper appearance from abundant multicolored lithics, dominantly clear to translucent quartz and volcanic glass with lesser amounts of light to medium gray, light to medium greenish gray, black, orange, rust, pale rose and light yellowish green; very fine upper to trace very coarse upper, dominantly medium upper to lower; angular to sub-angular; poorly sorted; dominantly unconsolidated; non calcareous. Sand (3340’-3400’) = medium to medium light gray overall with a strong salt and pepper appearance from the abundant multicolored lithics, dominantly clear to translucent quartz and volcanic glass with varicolored lithics as previously described; very fine lower to coarse upper, dominantly fine lower to medium lower; angular to subangular; poor to fair sorting; unconsolidated; non calcareous. Tuffaceous Claystone/Tuffaceous Siltstone (3400’-3470’) = light gray with very light brownish gray and yellowish gray secondary hues; very soft and fragile to slightly firm and brittle; irregular, shapeless cuttings; silty to clayey texture; dull, earthy luster; hydrophilic; soluble; poor adhesiveness; poor to fair cohesiveness; non calcareous; trace dark brown to black micro thin carbonaceous laminations and inclusions; light yellowish gray siltstone commonly grades to silty sandstone and sandy siltstone; fragile; non calcareous. Sand (3480’-3560’) = medium to medium light gray overall with abundant multi- colored lithics throughout, dominantly clear to translucent quartz and volcanic glass, light to medium green to greenish gray, light to dark gray, black, rust, orange, pale rose and light yellowish green; very fine upper to coarse lower, dominant fine upper to medium lower; angular to subangular; poor to fair sorting; dominantly unconsolidated; non calcareous; trace tuffaceous claystone. CLU STORAGE 5 8 Sand (3550’-3640’) = medium to medium light gray overall with abundant multi- colored lithics throughout, dominantly clear to translucent quartz and volcanic glass, light to medium green to greenish gray, light to dark gray, black, rust, orange, pale rose and light yellowish green; very fine lower to coarse upper dominantly fine upper to medium lower; angular to subangular; poor to fair sorting; dominantly unconsolidated; non calcareous; trace tuffaceous claystone/ tuffaceous siltstone; light gray; soft; fragile; silty to clayey texture; earthy luster; poor adhesiveness and cohesiveness; non calcareous; trace dark brown to black micro thin carbonaceous laminations and inclusions. Sand (3640’-3750’) = medium to medium light gray overall with abundant multi- colored lithics throughout, dominantly clear to translucent quartz and volcanic glass, light to medium green to greenish gray, light to dark gray, black, rust, orange, pale rose and light yellowish green; very fine lower to coarse lower dominantly fine upper to medium lower; angular to subangular; poor to fair sorting; dominantly unconsolidated; non calcareous; trace tuffaceous claystone-siltstone; light gray; soft; fragile; silty to clayey texture; earthy luster; non calcareous; trace black micro carbonaceous inclusions; trace light yellowish gray siltstone commonly grades between silty sandstone and sandy siltstone; fragile; irregular shaped cut tings; non calcareous. Tuffaceous Claystone/Tuffaceous Siltstone (3750’-3840’) = present in trace amounts in dominantly sand formation; very light gray with light brownish gray secondary hues; very soft and fragile to slightly firm and brittle; irregular, shapeless cuttings; silty to clayey texture; dull, earthy luster; hydrophilic; very soluble; poor adhesiveness; poor to fair cohesiveness; non calcareous; trace dark brown to black micro thin carbonaceous laminations and inclusions; trace light yellowish gray siltstone commonly grades between silty sandstone and sandy siltstone; fragile; irregular shaped cut tings; non calcareous. Sand/Sandstone/Conglomeratic Sandstone (3840’-3960’) = medium to medium dark gray; brownish to greenish secondary hues; moderately well to well sorted; friable; unconsolidated/disaggregated loose sand; medium lower to fine upper predominate; locally variable to both coarser and finer grain; angular to sub- angular and sub-discoidal; dominantly translucent gray-white to white and clear quartz; 30 to 40 % medium to light and dark gray; abundant to 5% orange jasper/volcanics; common to abundant green, blue-gray and brown mineral/lithics; common mica; scattered pyrite; locally abundant medium to coarse grain size fragments of very fine grain tuffaceous silty sandstone; occasional thin tuffaceous siltstone, tuffaceous conglomeratic sandstone ash, some with marked carbonaceous and iron staining; occasional trace amounts of coal may be clastics or thin interbeds, occasional ash matrix supported sandstone and conglomeratic sandstone fragments; no visible crystal overgrowth residues; trace calcareous primarily from point sources. Sand/Sandstone/Conglomeratic Sandstone (3960’-4100’) = medium to medium dark gray; brownish to greenish secondary hues; moderately well to well sorted; friable; unconsolidated/disaggregated loose sand; medium lower to fine upper predominate; locally medium upper to medium lower and fine upper; locally fine upper to medium lower and very fine with scattered larger grains; angular to sub-angular and sub-discoidal; dominantly translucent gray-white to white and clear quartz; 30 to 40 % medium to light and dark gray ; abundant to 5% orange jasper/volcanics; common to abundant green, blue-gray and brown mineral/ lithics ; common mica; locally abundant very fine grain silty tuffaceous sand- stone grades to associated tuffaceous siltstone; trace tuffaceous conglomeratic sandstone, thin coals and ash/tuff inter beds, some with marked red brown staining no visible cement overgrowth residues; trace calcareous. Tuffaceous Siltstone/Claystone (4100’-4200’) = medium to medium light gray; very slight greenish secondary hue; soft to firm; irregular angular to tabular fragments; coarsely fissile in part silty to smooth clayey and sandy texture dull earthy to silky and gritty luster; slightly adhesive; slightly cohesive; hydrophilic; expansive when re-wet; interbedded with fine to very fine grain silty and very silty sandstone, occasion al thin ash/tuffs and rare thin coal stringers; trace fragments display slight to moderate carbonaceous micro-lamina; trace clean grain supported medium to fine grain carbonaceous sandstone; trace to very slightly calcareous. CLU STORAGE 5 9 Sand/Sandstone/Conglomeratic Sandstone (4200’-4300’) = medium to medium dark gray; brownish to greenish secondary hues; moderately well to well sorted; friable; unconsolidated/disaggregated loose sand; fine upper grading to medium upper and coarse with increasing depth; basal material contains scattered coarse upper grains and small pebble fragments; sub-angular to angular and sub-discoidal; trace slightly rounded; mineral distribution as previously noted; occurs as moderately thick beds in apparent erosional contact with adjacent tuffaceous siltstone/tuffaceous claystones; trace clean grain supported conglomeratic sandstone fragments display slight visible porosity; trace to very slightly calcareous. Tuffaceous Siltstone/Claystone (4300’-4360’) = medium to medium light gray; very slight greenish secondary hue; soft to firm; irregular angular to tabular fragments; coarsely fissile in part silty to smooth clayey and sandy texture dull earthy to silky and gritty luster; slightly adhesive; slightly cohesive; slightly hydrophilic; interbedded with sandstone complex as described above; trace thin ash interbeds; occasional coal fragments; trace to non calcareous. Sand/Conglomeratic Sand (4360’-4500’) = medium to medium light gray; slight brownish to greenish secondary hue; disaggregated/unconsolidated loose sand with trace intact sandstone fragments; fine upper to medium lower predominate; trace to abundant medium upper and coarse lower grain becoming dominant with increasing depth; angular to sub- angular; light to medium gray, white and clear quartz predominate; 40% +/- medium to light gray lithic/mineral grains; trace dark gray to black mafic mineral; common to abundant orange jasper; common to trace blue-gray, green and brown; appears primarily grain supported; trace well indurated matrix supported fragments; occasional thin very poorly developed lignitic coal interbeds; occasion-al thin to moderate tuffaceous siltstone and claystone interbeds; trace to very slightly calcareous. Sand/Sandstone (4500’-4590’) = medium to medium light gray; prominent brownish secondary hue; disaggregated/unconsolidated; soft, friable; fine upper to medium lower and fine lower; locally grades to medium lower, fine upper and medium upper; moderate sorting; angular to sub-angular; translucent light gray to milky white and clear quartz with 40%+/- medium to light gray mineral grains; 15-5% orange jasper/volcanics; trace to common dark gray to black mafic mineral/lithics/ and coal fines; common blue-gray green and brown grains; trace to common mica; occasional tin tuffaceous siltstone interbeds; trace very fine grain tuffaceous silty sandstone and coal stringers; non to trace calcareous. Tuffaceous Siltstone/Claystone (4600’-4630’) = medium light to light gray with a very slight bluish secondary hue; soft to firm; irregular angular to flakey fragments; silty/sandy texture; earthy to micro sparkly luster; non adhesive/ cohesive; hydrophilic; very ashy; non calcareous. Sand/Conglomeratic Sand (4630’-4720’) = medium to medium light gray; slight brownish to greenish secondary hue; disaggregated/unconsolidated sand medium lower to medium upper and fine lower predominate; trace coarse lower; angular to sub-angular; dominant light to medium gray, white and clear quartz; 40%+ medium to light and dark gray lithics/mineral grains, common blue-gray, green and brown, common to abundant orange jasper/volcanics and trace dark gray to black mafics/lithics; trace moderately indurated matrix supported fragments appear primarily grain supported; tuffaceous siltstone/claystone becoming more abundant with depth; at 4710’ very poor grade lignitic coal; trace to non calcareous. Coal (4690’-4720’) = very dark to medium brown; firm to soft and very firm; hackly in part; lignitic; abundant carbonized wood; minor sandy/silty carbonaceous material; interbedded with silky off-white clay/ash. Sand/Conglomeratic Sand (4720’-4900’) = medium to medium light gray; slight brownish to greenish secondary hue; disaggregated/unconsolidated; medium lower to fine upper predominant; becoming finer and siltier with depth; angular to sub-angular; light to medium gray, white and colorless clear quartz predominant; 40%+ medium to light and dark gray lithic/mineral grains; common to very abundant orange jasper/volcanics; trace dark gray to black mafic mineral; common blue-gray, green and brown; abundance of partly hydrated ash suggests primarily matrix supported; common to trace off white to white ash with variable amounts of very fine grain angular volcanics; occasional thin coals and tuffaceous siltstone interbeds; trace calcareous. CLU STORAGE 5 10 Sand/Conglomeratic Sand (4900’-4980’) = medium light to light gray overall; weak salt and pepper appearance; unconsolidated; dominantly clear to translucent quartz and volcanic glass grains with lesser light to medium gray, medium greenish gray, pale rose, orange, rust, dark gray to black and bluish gray; very fine lower to dominant fine upper to lower to trace very coarse lower; angular to subangular; moderately sorted when fine, poorly sorting when medium to coarse; non calcareous. Tuffaceous Claystone/Tuffaceous Siltstone (4980’-5030’) = light gray to light brownish gray; soft and mushy to very firm and brittle; shapeless to wedgelike; dull, earthy to waxy; silty to gritty texture; moderately soluble; poor adhesiveness; fair to good cohesiveness; trace dark brown to black micro thin carbonaceous laminations and inclusions; non calcareous; trace light yellowish siltstone that commonly grades between silty sandstone and sandy siltstone; trace dark brown to black carbonaceous material/ thin coals. Sand/Conglomeratic Sand/ Conglomerate (5030’-5120’) = medium light to light gray overall; moderate salt and pepper; loose grains dominantly clear to translucent quartz and volcanic glass; abundant multicolored lithics; very fine lower to dominant lower-upper medium to very coarse upper with pebbles-pebble fragments, angular to dominant subangular, trace subrounded pebbles, poorly sorted; unconsolidated; non calcareous. Tuffaceous Claystone/Tuffaceous Siltstone (5120’-5190’) = present in trace amounts in dominantly a sand formation; very light gray to light brownish gray with light yellowish gray secondary hues soft to slightly firm; shapeless to irregular shaped cuttings; silty to clayey to slightly gritty texture; dull, earthy to waxy luster; moderately soluble; poor adhesiveness; fair cohesiveness; non calcareous; trace dark brown to black micro thin carbonaceous laminations and inclusions; trace thin coals. Coal (5190’-5280’) = black to medium brown; firm to soft and very firm; hackly in part; lignitic; remnant woody characteristics; part sandy/silty carbonaceous material; grades to harder sub-fissile carbonaceous shale; interbedded with silky off white clay/ash. Sand/Conglomeratic Sand (5220’-5340’) = medium to medium light gray and light brownish gray; unconsolidated or disaggregated; soft to firm to moderately hard rare intact fragments; moderately to poorly sorted; medium lower to fine upper and medium upper and coarse lower with scattered pebbles-pebble fragments; sub-angular to angular and sub-rounded; translucent white to clear colorless quartz predominant; 20- 30% medium to light gray mineral/ trace to common orange jasper/volcanics; trace blue-gray; scattered green and brown; trace fine to very fine grain medium gray grain supported sandstone; common to abundant off white to light brownish white ash grades to light brownish white tuffaceous conglomeritic sandstone and siltstone; interbedded with tuffaceous siltstone and claystone and occasional coals; non to trace calcareous. Tuffaceous Claystone/Siltstone (5340’-5400’) = medium light brownish gray to medium gray; soft to firm; waxy micro- sparkly to earthy luster; waxy to silty and sandy texture; irregular lumpy to angular fragments; moderately to slightly cohesive; non adhesive; hydrophilic; abundantly ashy; contains variable amounts of sharp angular glass fragments; grades to tuffaceous sandstone and ash; non calcareous. Tuffaceous Siltstone/Claystone (5400’-5500’) = medium gray to medium light gray; soft to firm; dull earthy to micro sparkly luster; silty to slightly sandy texture; irregular lumpy to angular fragments; slightly cohesive; non to slightly adhesive; somewhat hydrophilic; micro shards and mica inclusions yield micro-sparkly appearance; trace to abundant carbonaceous micro-lamina; interbedded with sand/sandstone as above described; and occasional thin coals; non calcareous. Sand/Tuffaceous Sand (5470’-5600’) = medium to medium light gray, light brownish gray; soft- unconsolidated or disaggregated; moderately sorted; fine upper to medium lower with scattered larger grains; sub-angular to angular; abundant silt/ash matrix; translucent to clear colorless quartz predominant; 40%+/- medium to light and dark gray; common orange jasper/volcanics; trace to common dark mafic minerals/lithics and blue-gray, green and brown minerals; matrix supported with some grain support in basal section; interbedded with similar tuffaceous silt/claystone and occasional thin coals; non to very slightly calcareous. CLU STORAGE 5 11 Coal (5600’-5650’) =very dark brownish black to black; firm to vey firm; hackly irregular angular fragments; somewhat tabular in part; shaley/silty in part; common remnant woody characteristics; no conchoidal fracture noted; interbedded with similar appearing carbonaceous shale. Tuffaceous Siltstone/Claystone (5630’-5690’) = medium gray to medium light gray; soft to firm; dull earthy to micro sparkly luster; silty to slightly sandy texture; irregular lumpy to angular fragments; slightly cohesive; non to slightly adhesive; somewhat hydrophilic; micro shards and mica inclusions yield micro-sparkly appearance; trace carbonaceous micro-lamina; common sand/sandstone interbeds as above described; and occasional thin coals; non to trace calcareous. Sand/Tuffaceous Sand (5690’-5800’) = medium to medium light gray and light brownish gray; soft- unconsolidated or disaggregated; moderately well to well sorted; medium lower to fine upper above 5730’; becoming fine upper to medium lower in the base; angular to sub-angular; abundant silty/ashy residue; translucent white to clear colorless quartz predominate; 40%+/- medium to light and dark gray; common to abundant orange jasper/volcanics; trace to common dark mafic minerals/lithics and blue-gray, green and brown minerals; trace mica; occasional tuffaceous sandstone fragments; in upper section may be grain supported between interbedded tuffaceous silt-claystone and thin coals; very slightly to slightly calcareous. Sand/Tuffaceous Sand (5820’-5910’) = medium to medium light gray and light brownish gray; soft/unconsolidated or disaggregated; moderately well to well sorted; fine upper to medium lower angular to sub-angular and subrounded; locally abundant silty/ashy residue; translucent white to clear colorless quartz predominate; 40 +/- % medium to light and dark gray; common to abundant orange jasper/volcanics; trace to common dark mafic mineral/lithics/; common blue-gray, green and brown mineral/lithic grains; trace phlogophite mica; occasional intact tuffaceous sandstone fragment; trace grain sup ported sandstone fragments; thinly interbedded with similar tuffaceous silt/claystone; very slightly to slightly calcareous. Sand/Tuffaceous Sand (5910’-6000’) = medium to medium light gray and light brownish gray; soft/unconsolidated or disaggregated; moderately well to well sorted; fine upper to medium lower becoming medium lower to medium upper and fine upper with scattered larger grains as depth increases; angular to sub-angular and subrounded; locally abundant silty/ashy residue; predominantly translucent white to clear colorless quartz predominate; 40 +/- % medium to light and dark gray; common to abundant orange jasper/volcanics; trace to common dark mafic mineral/lithics; common blue-gray, green and brown mineral/lithic grains; trace phlogophite mica; occasional intact tuffaceous sandstone fragment; trace grain sup ported sandstone fragments; occasional thin carbonaceous micro laminated tuffaceous silt/claystone; very slightly to slightly calcareous. Sand/Tuffaceous Sand/Conglomeratic Sand (6000’-6150’) = medium to medium light gray with a slight brownish secondary hue; soft-unconsolidated/ disaggregated; friable in part; moderately well to poorly sorted; medium lower to medium upper and fine upper grading to medium upper, coarse lower and medium lower with increasing depth; scattered granule and pebble fragments above 6060’ interval returns to fine upper and medium grain below 6060’; angular to sub-angular to sub-rounded; abundant silty/ashy residue; predominantly translucent white to clear colorless quartz predominate; 40 +/- % medium to light and dark gray; common to abundant orange jasper/volcanics; trace to common dark mafic mineral/lithics/ ; common blue-gray, green and brown mineral/lithic grains; trace phlogophite mica; occasional intact tuffaceous sandstone fragment; trace grain supported sandstone fragments; occasional thin carbonaceous micro laminated tuffaceous silt/claystone; common coal fragments may be clastic or very thin inter-beds; slightly to very slightly calcareous. Coal (6150’-6180’) =very dark brownish black to black; firm to vey firm; hackly irregular angular fragments; trace remnant woody characteristics; no conchoidal fracture; common carbonaceous shale; adjacent to very light bluish gray silt (underclay) over conglomerate/conglomeratic sand. CLU STORAGE 5 12 Sand/Tuffaceous Sand (6170’-6230’) = medium to medium light gray to brownish gray; unconsolidated to soft, friable in part; moderately well sorted; fine upper to medium lower to locally medium upper; angular to sub-angular; abundant silty-ashy matrix; dominant translucent white to colorless clear quartz/volcanics; 40%+ light to dark gray lithic/mineral grains; common to abundant orange jasper/volcanics; trace dark gray mafic minerals/lithics; common to locally abundant blue-gray, green and brown minerals/lithics; trace possible phlogophite mica; occasional sandstone fragments; trace tuffaceous sandstone interbedded with carbonaceous micro-laminated tuffaceous siltstone/claystone; very slightly to slightly calcareous Coal (6150’-6180’) =black to very dark brownish black; firm to vey firm; hackly irregular very angular fragments; brittle; no conchoidal fracture; bedded on conglomeratic sand. Tuffaceous Siltstone/Claystone (6360’-6440’) = medium light to medium gray with a slight brownish to locally bluish secondary hue; soft to firm; irregular flaky to rounded fragments; dull earthy to micro-sparkly luster; silty to sandy texture; somewhat hydrophilic; slightly to moderately cohesive; non adhesive; commonly with moderate amounts of carbonaceous micro-lamina; trace thin ash/tuff interbeds; occasional thin coal stringers; non calcareous. Sand/Tuffaceous Sandstone (6440’-6530’) = medium light to medium gray; soft to unconsolidated; well to moderately well sorted; friable in part; fine upper to medium lower and fine lower grain; trace larger grains; generally slightly silty; grades to sandy siltstone/ silty sandstone; irregular shaped pieces; firm; friable in part; grain supported with occasional ashy supporting matrix; non calcareous. Sand/Conglomeratic Sand (6520’-6610’) = light to very light gray overall, weak salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray, light to medium green to greenish gray to bluish green, black, pale rose and orange; very fine upper to very coarse lower, dominantly fine upper to medium upper; angular to trace subrounded, dominantly subangular; poorly sorted; disaggregated; non calcareous; trace light yellowish gray very fine sandstone, firm to moderately hard; grain supported; non calcareous; common grading between silty sandstone and sandy siltstone. Coal (6570’-6670’) = black with dark brownish black and dark grayish black secondary hues; flexible to stiff and brittle; moderately firm to hard; irregular to blocky, planar fracture dominant; trace conchoidal and birdeye fracture; platy to flaky, occasionally massive; earthy to resinous luster; smooth to slightly gritty texture; poorly developed; sub-bituminous; no outgassing detected. Tuffaceous Claystone/Tuffaceous Siltstone (6660’-6720’) = present in trace amounts in dominantly a sand formation; very light gray to light brownish gray with light yellowish gray secondary hues soft to very firm; shapeless to irregular shaped cuttings; silty to clayey to slightly gritty texture; dull, earthy to waxy luster; moderate to very soluble; poor adhesiveness; fair to good cohesiveness; non calcareous. Sand/Conglomeratic Sand (6730’-6810’) = light to very light gray overall with a weak salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray, light to medium green to greenish gray to bluish green, black, pale rose, rust and orange; very fine upper to very coarse lower, dominantly fine upper to medium upper; angular to trace subrounded, dominantly subangular; poorly sorted; disaggregated; non calcareous; trace sandstone; medium to fine grain; multicolored; grain supported; hard; non calcareous. Tuffaceous Claystone/Tuffaceous Siltstone (6810’-6900’) = present as minor fraction in dominantly sand formation; light to very light gray with light brownish gray and light yellowish gray secondary hues; very soft to moderately firm and occasionally hard; shapeless to irregular to very ground up from bit action; silty to clayey to slightly gritty texture; dull, earthy luster; soluble in part; poor adhesiveness; poor to fair cohesiveness; non calcareous; trace dark brown to black micro thin carbonaceous laminations and inclusions. CLU STORAGE 5 13 Sand/ Conglomeratic Sand (6880’-6970’) = light to very light gray overall with a weak salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, light to medium gray, light to medium green to greenish gray to bluish green, black, pale rose, rust and orange; very fine upper to very coarse upper, dominantly fine upper to medium upper; angular to trace subrounded, dominantly subangular; poorly sorted; disaggregated; non calcareous. Coal (6950’-7000’) = black with dark brown and dark gray secondary hues; firm to moderately hard and brittle at times; blocky to platy; planar fracture dominant with trace conchoidal and bird-eye fracture; earthy to resinous luster; smooth to slightly gritty texture; sub- bituminous; no outgassing observed. Sand/Sandstone (7000’-7060’) = light to medium light gray; soft/disaggregated/ unconsolidated loose sand with common small very fine grain silty sandstone fragments; moderately well sorted; angular to sub-angular; predominantly translucent white to clear colorless quartz/volcanics; 20 to 30% light to medium gray lithic/mineral grains; trace to common dark gray, black, green-gray, blue-gray, pale rose and orange; abundant thin tuffaceous siltstone and carbonaceous shale interbeds; trace calcareous. Coal/Carbonaceous Shale (7060’-7120’) = sub-bituminous to lignitic; black to very dark gray and brownish gray; firm to moderately hard; brittle/ hackly in part; angular irregular to tabular fragments; smooth to gritty/texture; resinous to earthy luster; silty/sandy carbonaceous material in part; interbedded with moderate beds of sub-fissile hard carbonaceous shale; initial vigorous outgassing slows after 15 minutes. Sand/Conglomeratic Sand (7120’-7290’) =light to medium light gray with a slight brownish secondary hue; soft/un- consolidated; moderately well to moderately sorted; fine upper to medium lower and fine lower in the upper portion; grades to medium lower, medium upper and fine upper with depth; angular to sub- angular and very slightly rounded; translucent white to slightly smokey and clear quartz/volcanics predominate;20 to 30% light to medium gray/ mineral grains; common to trace orange and gray-green; trace blue-gray, brown and pale rose; rare intact fragments show both matrix and grain support interbedded with thin tuffaceous silt/ claystone with slight carbonaceous micro lamination, coal and carbonaceous shale; non calcareous. Coal/Carbonaceous Shale (7290’-7350’) =very dark gray to black, brownish gray and brown; firm to slightly firm and moderately hard; brittle/ hackly; angular irregular to splintery and tabular fragments; smooth to gritty/ texture; resinous to earthy luster; interbedded with moderate beds of sub-fissile hard carbonaceous shale and brown silty lignite; lignitic to sub- bituminous overall; some initial outgassing does not persist. Sand (7350’-7410’) = light to very light gray with a very slight brownish secondary hue; soft-unconsolidated or disaggregated; moderately well sorted; fine upper to medium lower; scattered larger grains; trace fine lower; fining upward from medium upper; angular to sub-angular; trans lucent white to slightly smokey and clear quartz/volcanics predominate; 20 to 30% light to medium gray/ mineral grains; common to trace orange and gray-green; trace blue-gray, brown and pale rose; interbedded with thin tuffaceous, slightly carbonaceous laminated tuffaceous siltstone/claystone and thin flaky carbonaceous shale; non calcareous. Coal/Carbonaceous Shale (7400’-7520’) =very dark gray to black, brownish gray and brown; firm to slightly firm and moderately hard; brittle/ hackly; angular irregular to splintery and tabular fragments; smooth to gritty/ texture; resinous to earthy luster; interbedded with moderate beds of sub-fissile hard carbonaceous shale, sandstone/conglomeratic sand and tuffaceous siltstone/tuffaceous claystone as previously seen; lignitic to sub-bituminous overall; initial fair outgassing when fresh cut does not persist. CLU STORAGE 5 14 Sand/Conglomeratic Sand (7520’-7610’) = light to very light gray with a slight brownish secondary hue; moderately well sorted in the upper portion gradual coarsening with depth to poorly sorted; fine upper to medium lower with scattered larger grains grading to medium upper, medium lower and coarse lower with common granule and coarse upper and scattered pebble to 6mm at the 7550’ and 7610 samples; angular to sub-angular dominates; granule and pebble/pebble fragments tended to be moderately rounded; material appears to be primarily grain supported with some samples showing fragments with an ash/clay supporting matrix; translucent white to smokey and clear colorless quartz/volcanics predominate; 20 +/- % light to medium gray /mineral grains; common to abundant orange jasper/volcanics; trace to common pale rose, gray-blue and green grains; scattered mica flakes; interbedded with thin tuffaceous silt/ claystone, carbonaceous shale and very thin ash; non to very slightly calcareous. Sand/Conglomeratic Sand (7610’-7770’) = light to very light gray with a slight brownish secondary hue; moderately well sorted in the upper portion gradual coarsening with depth to poorly sorted; fine upper to medium lower with scattered larger grains grading to medium upper, medium lower and coarse lower with scattered coarse upper, granule and small pebble/pebble fragments; angular to sub-angular predominates; larger fragments tend to be somewhat rounded; material appears to be primarily grain supported with some samples showing fragments with an ash/clay sup- porting matrix; translucent white to smokey and clear colorless quartz/volcanics predominate; 20 +/- % light to medium gray mineral grains; common to abundant orange jasper/volcanics; trace to common pale rose, gray-blue and green grains; scattered mica flakes; interbedded with thin tuffaceous silt/ claystone, carbonaceous shale and very thin ash; non to very slightly calcareous. Sand/Conglomeratic Sand (7700’-7890’) = light to very light gray with a slight brownish secondary hue; moderately to poorly sorted; friable in part; soft/disaggregated or unconsolidated; moderately poorly sorted; intact fragments are fine upper to medium lower with scattered larger grains; coarser fraction is recovered as loose sand medium upper to medium lower, coarse lower and scattered granule and small pebble/pebble fragments; angular to sub-angular predominates; larger size grains tend to be somewhat rounded; primarily matrix supported in the finer grain; may be partial grain support in the where larger grain predominates; primarily translucent white to smokey and clear colorless quartz; 20% +/- light to medium gray; abundant orange and pale rose; trace to common blue-gray, green and brown; trace to scattered mica flakes; non to trace calcareous. Sand/Conglomeratic Sand (7890’-7960’) = light gray overall with a weak salt and pepper appearance from numerous dark lithics, dominantly clear to translucent quartz and volcanic glass with lesser amounts of light to medium gray, light to medium greenish gray, bluish gray, rust, orange, pale rose and black; very fine upper to very coarse upper and pebble and pebble fragments, dominantly medium lower to upper; angular to trace subrounded, dominantly subangular; poorly sorted; unconsolidated; non calcareous. Sand/Conglomeratic Sand (7960’-8050’) = light to medium light gray overall with abundant multicolored lithics throughout, dominantly clear to translucent quartz and volcanic glass, light to medium gray black, light to medium green to greenish gray, rust, orange, pale rose and light yellowish green; very fine upper to very coarse upper with pebble and pebble fragments, dominantly medium upper to lower; angular to trace subrounded, dominantly subangular; poorly sorted; disaggregated with trace sandstone; fine to medium grain; multicolored individual grains; fragile and friable; light grayish white ashy supporting matrix; non calcareous. Sand/Tuffaceous Sandstone/Conglomeratic Sand (8050’-8150’) = medium light to light gray overall with a moderate salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, abundant multicolored lithics as previously described; very fine lower to very coarse upper, dominantly fine upper to medium upper; angular to trace subrounded very coarse lithics, dominantly subangular; poorly sorted; dominantly disaggregated with tuffaceous sandstone; very fragile; fine to medium grain; bluish white to grayish white ashy supporting matrix; slight to moderately calcareous; non calcareous sandstone is pulverulent; calcareous is hard and well cemented. CLU STORAGE 5 15 Sand/Conglomeratic Sand/Tuffaceous Sandstone (8150’-8240’) = light gray to medium light gray with multicolored lithics, dominantly clear to translucent quartz and volcanic glass with lesser amounts of light to medium gray, light to medium greenish gray, bluish gray, rust, orange, pale rose and black; very fine upper to very coarse upper and pebble and pebble fragments, dominantly medium lower to upper; angular to trace subrounded, dominantly subangular; poorly sorted; unconsolidated; non calcareous scattered tuffaceous sandstone; multi-hue from abundant multicolored grains; fine to medium grain; bluish white ash supporting matrix; non to slightly calcareous; fragile to friable. Sand/Tuffaceous Sandstone/Conglomeratic Sand (8250’-8330’) = medium light to light gray overall with a moderate salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, abundant multicolored lithics as previously described; very fine lower to very coarse upper, dominantly fine upper to medium upper; angular to trace subrounded very coarse lithics, dominantly subangular; poorly sorted; dominantly disaggregated with tuffaceous sandstone; very fragile; fine to medium grain; bluish white to grayish white ashy supporting matrix; slight to moderately calcareous; trace visible glass shards; trace light yellowish brown sandstone; very fine lower; well sorted; firm to moderately hard; non calcareous; commonly grades between silty sandstone and sandy siltstone. Sand/Conglomeratic Sand (8340’-8440’) = light to medium light gray overall with abundant multicolored lithics throughout, dominantly clear to translucent quartz and volcanic glass, light to medium gray black, light to medium green to greenish gray, rust, orange, pale rose and light yellowish green; very fine lower to very coarse upper with pebble and pebble fragments, dominantly medium upper to lower; angular to trace subrounded, dominantly subangular; poorly sorted; disaggregated with trace sandstone; fine to medium grain; multicolored individual grains; fragile and friable; light grayish white ashy supporting matrix; non calcareous; trace medium light gray tuffaceous clay-stone; soft to slightly firm; silty to clayey texture; dull luster; abundant dark brown to black micro thin inclusions and laminations; non calcareous. Sand/Tuffaceous Sandstone/Conglomeratic Sand (8450’-8540’) = medium light to light gray overall with a moderate salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass, abundant multicolored lithics as previously described; very fine lower to very coarse upper, dominantly fine upper to medium upper; angular to trace subrounded very coarse lithics, dominantly subangular; poorly sorted; dominantly disaggregated with tuffaceous sandstone; very fragile; fine to medium grain; bluish white to grayish white ashy supporting matrix; slight to non calcareous. Sand/ Conglomerate/Conglomeratic Sand/Tuffaceous Sandstone (8540’-8630’) = light to medium light gray with abundant multicolored lithics, dominantly clear to translucent quartz and volcanic glass, light to medium green to greenish gray and greenish blue, light to dark gray, rust, orange, pale rose and light yellow to yellowish green; very fine upper to very coarse upper with pebble and pebble fragments common, dominantly medium lower to upper; angular to trace subrounded pebbles, dominantly subangular; poorly sorted; disaggregated; scattered tuffaceous sandstone; very light yellowish brown ashy tuff supporting matrix; multicolored individual grains; fragile to friable; non calcareous. Sand/Conglomeratic Sand/Tuffaceous Sandstone (8630’-8720’) = medium light to light gray with light brownish gray secondary hues from tuffaceous sandstone content, individual grains dominantly clear to translucent quartz and volcanic glass with abundant varicolored lithics as previously described; very fine upper to very coarse upper with pebble and pebble fragments, dominantly fine upper to medium upper; angular to trace subrounded, dominantly subangular; poorly sorted; dominantly disaggregated with abundant ashy supported sandstone; light to medium light brown ashy supporting matrix; friable; non calcareous. Sand/Conglomeratic Sand/ Tuffaceous Sandstone (8720’-8780’) = light to medium light gray; soft to disaggregated; moderately to poorly sorted; angular to subangular to slightly rounded; medium lower to medium upper, coarse lower and scattered granule/pebble; predominantly translucent white quartz/volcanics; common clear and smokey quartz/volcanics; common to trace orange, pale rose, blue-gray and green lithic/mineral; generally clean grain supported; ash matrix supported in part; trace calcareous. CLU STORAGE 5 16 Coal (8780’-8840’) =black to very dark brownish black; moderately hard to firm/brittle; hackly in part; blocky to irregular/angular fragments; common conchoidal fracture of larger fragments; resinous to gritty/earthy luster; initial moderate outgassing persists to very slight after one hour; interbedded with thin carbonaceous shales and sand; trace very light gray clay; overlays conglomeratic sand with occasional thin coal interbeds. Sand/Conglomeratic Sand/Tuffaceous Sand (8872’-9000’) = light to medium light gray; all intact fragments surface stained medium reddish brown/rust color by unknown agent; moderately to moderately well sorted; medium lower to medium upper and coarse lower predominate; scattered coarse upper and pebble/ pebble fragments; locally fine upper to medium; sub-angular to angular and sub-rounded; translucent white to clear quartz/volcanics with variable amounts of light to medium gray lithics; trace to common clastic coal grains; interbedded with soft light gray tuffaceous silt common calcareous tuff. Coal (8960’-9000’) = very dark gray to black and very dark brownish black; very firm to firm; brittle; hackly; irregular angular to tabular fragments; lignitic; silty to slightly shaley; common thin hard tabular sub- bituminous coal fragments; trace poorly developed conchoidal fracture; commonly silty; note very carbonaceous shaley/silty section below 9020’; slight non-persistent outgassing. Sand/Conglomeratic Sand (9040’-9120’) = medium light to light gray overall with individual grains dominantly clear to translucent quartz and volcanic glass, light gray, light greenish gray, dark gray, black and trace rust and pale rose very fine upper to trace very coarse lower, dominantly medium upper to fine upper; angular to sub-angular; poorly sorted; unconsolidated; abundant sloughing coal. Tuffaceous Claystone/Tuffaceous Siltstone (9100’- 9190’) = light gray with light brownish gray secondary hues; soft to fragile and pulverulent; irregular shaped cuttings; silty to clayey texture dull, earthy to slightly sparkly luster; very soluble; poor adhesiveness; poor to fair cohesiveness; non-calcareous; trace dark brown to black micro-thin carbonaceous laminations and inclusions; trace dark brown carbonaceous material/siltstone; silty to gritty texture; fragile; earthy luster; irregular to blocky. Sand (9190’-9280’) = light to very light gray overall, minor salt and pepper appearance, individual grains dominantly clear to translucent quartz and volcanic glass with trace amounts of medium to dark gray, black, greenish gray, rust orange and pale rose; very fine lower to trace very coarse lower, dominantly fine upper to medium lower; angular to sub-angular; poor to fair sorting; dominantly unconsolidated with trace bluish white tuffaceous sandstone; very fragile; very fine grain; ashy supporting matrix; non-calcareous. Sand/Tuffaceous Sandstone (9280’-9360’)= light to very light gray with a weak salt and pepper appearance overall with individual grains dominantly clear to translucent quartz and volcanic glass with minor amounts of light to medium gray, dark gray and black, light to medium greenish gray, rust, orange and pale rose; very fine lower to medium upper, dominantly fine upper to medium lower; angular to sub-angular; moderately well sorted; disaggregated with scattered tuffaceous sandstone; bluish white with various multicolored hues; very fragile to pulverulent; very fine to fine grain; continued multicolored individual grains; very ashy supporting matrix; trace to common glass shards; non-calcareous. Tuffaceous Claystone/Tuffaceous Siltstone (9360’-9460’) = light to very light gray with very light brown to light brownish gray secondary hues; soft and fragile; pulverulent; irregular shaped cuttings with rare pdc bit metamorphism; silty to clayey texture; dull, earthy luster; moderately soluble and expansive; hydrophilic; poor adhesiveness; poor to fair cohesiveness; non-calcareous; abundant tuffaceous sandstone; multi-hued, bluish white dominant; very fragile; fine grain; silty to gritty texture; sparkly luster; non to slightly calcareous. Sand (9440’-9520’) = light to very light gray overall with weak salt and pepper appearance; dominant clear to translucent quartz and volcanic glass, with trace medium to dark gray, black, greenish gray, rust, orange and pale rose grains; very fine lower to trace coarse lower, dominantly fine upper to medium lower; angular to sub-angular; poor to fair sorting; dominantly unconsolidated with trace bluish and yellowish gray tuffaceous sandstone; fragile to pulverulent; fine to medium grain; ashy supporting matrix; non to slightly calcareous. CLU STORAGE 5 17 Tuffaceous Claystone/Tuffaceous Siltstone (9520’-9600’) = light gray with very light brown to light brownish gray secondary hues; soft to slightly firm; irregular to sub-tabular shaped cuttings; silty to clayey texture, dull, earthy luster; hydrophilic; moderately soluble, slightly expansive; poor adhesiveness; fair cohesiveness; trace dark brown to black micro-thin carbonaceous laminations and inclusions; non calcareous. Sand/Tuffaceous Sandstone (9600’-9660’)= light to very light gray with a weak salt and pepper appearance overall with individual grains dominantly clear to translucent quartz and volcanic glass with minor amounts of light to medium gray, dark gray and black, light to medium greenish gray, rust, orange and pale rose; very fine lower to coarse upper, dominantly fine upper to medium lower; angular to sub-angular; poor to fair sorting; disaggregated with abundant tuffaceous sandstone; bluish white with various multicolored hues; very fragile to pulverulent; non to slightly calcareous. Tuffaceous Claystone/Tuffaceous Siltstone (9660’-9760’) = light to very light gray with very light brown to light brownish gray secondary hues; locally common medium gray brown carbonaceous sandy tuffaceous siltstone with abundant carbonaceous micro-lamina and occasional well preserved brown and black carbonized grass blade impressions; soft to slightly firm; irregular angular to sub-tabular fragments; silty to clayey and sandy texture; somewhat hydrophilic; non to slightly cohesive; non-adhesive; occurs as interbeds in the associated sand complex; non to very slightly calcareous. Sand/Tuffaceous Sandstone (9760’-9900’) = light to very light gray; dominant medium lower to fine upper; locally grades to medium upper with scattered coarse; dominant disaggregated; trace to common very fine to fine to medium tuffaceous sandstone; mixed grain and matrix supported when finer; coarser often grain supported; moderately to well sorted; dominant angular to sub-angular; scattered slightly rounded and spheroidal; translucent white to clear quartz/volcanics; trace light to medium gray and scattered darker grains, salt and pepper in part; common to trace very silty tuffaceous sandstone; non to trace calcareous. Sand/Tuffaceous Sandstone/Conglomeratic Sandstone (9900’-10000’) = light to very light gray; unconsolidated/disaggregated; moderately to locally well sorted; angular to sub-angular predominate; scattered slightly rounded and spheroidal grains; dominant medium lower to fine upper; locally grades to medium upper with abundant coarse; grains include translucent white to clear color less quartz/volcanics, trace light to medium gray, scattered to trace orange mottled jasper/volcanics and bluish gray, green, scattered dark gray and black lithics/minerals; interbedded with thin tuffaceous siltstone/claystone and occasional very thin ash; scattered hard fragments of silica cemented conglomeratic sandstone and fine medium to medium dark gray silica-cemented fine sandstone; non to trace calcareous. Sand/Conglomeratic Sand (10050’-10130’)= medium light to light gray overall; individual grains dominantly clear to translucent quartz and volcanic glass; minor grains are light gray, light greenish gray, dark gray, black and trace rust and pale rose; very fine upper to very coarse lower, dominantly medium upper to lower; angular to sub-angular; poorly sorted; disaggregated. Sand (10130’-10180’) = light to very light gray overall; slight salt and pepper; individual grains dominantly clear to translucent quartz and volcanic glass with scattered multi-colored lithics; very fine lower to coarse lower, dominantly fine upper to medium lower; angular to sub-angular; poor to fair sorting; disaggregated. Sand (10180’-10250’) = light overall; dominant clear to translucent quartz/volcanic glass; trace light to medium gray, light to medium greenish gray, black, orange, rust and pale rose grains; very fine lower to coarse upper, dominant fine upper to medium lower; poor sorting; angular to sub-angular; disaggregated. Sand (10250’-10340’) = light to very light gray; disaggregated; friable grain-supported sandstone; moderately well sorted; sub-angular to angular; primary medium lower to medium upper, grading to fine upper; scattered coarse; scattered very fine, trace hard, silica cemented sandstone; grains dominantly translucent white to clear quartz/volcanics, common greenish gray and trace to common light to medium gray lithics/minerals; trace mottled orange jasper/volcanics, pale rose and rust brown grains. CLU STORAGE 5 18 Sand/Conglomeratic Sand (10340’-10460’) = light to medium light gray; disaggregated; very fine to conglomeratic; dominant fine to medium; moderate to moderately poor sorting; sub-angular to angular; dominant translucent white to clear quartz; abundant very light gray minerals; common light to medium gray lithics/minerals; trace to common greenish gray; trace orange/clear mottled jasper/volcanics, pale rose, brown and blue-gray mineral/lithic grains; trace clastic coal/carbonaceous shale; locally moderately feldspathic; scattered red-brown mineral grains; occasional thin tuffaceous siltstone/ claystone interbeds. Sand/Tuffaceous Sand (10460’-10600’)= light to medium light gray with a distinct brownish secondary hue; disaggregated sand as seen above becoming tuffaceous sandstone with increasing depth; moderately to poorly sorted in the loose sand; moderately well sorted in the finer grain tuffaceous sandstone; sub-angular to angular and sub-rounded grading to sub-rounded to sub-angular as grain size becomes finer; primarily translucent white to clear quartz/volcanics; common to abundant medium to light gray lithics; trace to common pale rose jasper; trace orange jasper; common bluish gray and green mineral; trace brown; trace light pinkish brown feldspar usually as coarse sand to small pebble grains; dominantly matrix supported at 10600’; trace to common medium gray tuffaceous sandy siltstone/very fine grain silty tuffaceous sandstone. Sand/Tuffaceous Sand (10600’-10700’)= light to medium light gray with a slight brownish secondary hue; disaggregated sand and common intact tuffaceous sandstone fragments; moderately well to moderately sorted; fine upper to medium lower, fine lower and very fine grain; scattered medium upper; sub-angular to angular and sub-rounded; translucent white to clear colorless quartz/volcanic glass predominate; 20 to 30% medium to light gray lithic/mineral grains; common darker gray grains; trace to common bluish gray, green and pale rose grains; interbedded with very firm flaky bluish gray slightly to very sandy tuffaceous siltstone. Sand (10700’-10800’) = light to very light gray; samples collected as loose disaggregated or unconsolidated sand; friable; moderately to moderately well sorted; sub-angular to angular and sub-rounded; medium lower to fine lower, medium upper and scattered coarse; translucent white to clear colorless quartz/volcanics predominate; common medium to light and dark gray lithi c/mineral grain common to trace light bluish gray, trace green, pale rose, orange, and brown; trace dark gray to black mafic mineral/lithics; poor salt and pepper appearance in part; locally abundant fine to very fine grain tuffaceous sandstone. Sand/Sandstone (10780’-10870’) = light to very light gray; dominantly clear to translucent quartz and volcanic glass; lesser light to medium gray, light to medium greenish gray, rust orange, pale rose, light bluish green and black grains; very fine lower to trace very coarse upper; dominantly fine upper to medium upper; angular to sub-angular; poor to fair sorting; dominantly disaggregated, trace fine to medium, hard to brittle sandstone with salt and pepper appearance from abundant varicolored grains; slight to moderate calcareous cement. Tuffaceous Claystone/Tuffaceous Siltstone (10860’-10930’) = medium light to light gray with light brownish gray and light olive gray secondary hues; soft to moderately firm; fine irregular cuttings; silty to clayey texture; earthy luster; soluble; poor adhesiveness; fair to good cohesiveness; trace to common light brown to light brownish gray and yellowish gray siltstone grades to silty sandstone-sandy siltstone; non calcareous. Sand/Sandstone/Conglomeratic Sand (10930’-11010’) = light gray overall; individual grains dominantly clear to translucent quartz and volcanic glass with various multi-colored lithics; very fine lower to trace very coarse upper and pebble fragments, dominantly fine upper to medium upper; poorly sorted; angular to sub- angular; dominantly disaggregated, with trace fine to medium sandstone; partial salt and pepper appearance from multicolored lithics; moderate calcite cementation. Sand/Sandstone/Conglomeratic Sand (11010’-11101’) = overall light brown to light brownish gray, loose sand light gray and slight salt and pepper; dominantly medium; very fine lower to very coarse upper with common (angular to subrounded) pebbles/pebble fragments; moderately to poorly sorted; dominantly sub- angular; disaggregated to firm-friable grain supported; dominant clear to translucent quartz and volcanic glass; abundant multicolored lithics; non-calcareous. CLU STORAGE 5 19 3.2 Sampling Program BOXED WASHED AND DRIED SAMPLES 1 Set Total: 1 Package of 7 Boxes Each Operator: CINGSA Well Name: CLU Storage 5 Field: Cannery Loop/ Sterling C Pool County: Kenai Borough State: Alaska Company Representatives: John Nicholson, Mike Grubb, Steve Ratcliff, Location: Kenai Peninsula, Alaska Classification: Gas Storage API #: 50-133-20601-00-00 Permit #: 211158 Rig Name /Type: Nabors 105-E/ Land/ Triple Total Depth 11101’ Total Depth Formation: Sterling C Total Depth Date: January 7, 2012 Logging Geologists: Ralph Winkelman, John Lundy Logger Trainees/ Sample Catchers: Justin Rosenblume, Larry Resch Set Type and Purpose Interval Frequency Distribution 1 Washed and Dried Reference Samples 2400’ to 8872’ 8872’ to 11101’ 30’ Interval 20’ Interval PRA/ CINGSA NOTE: All samples released to Ari Berland, Geologist, PRA/CINGSA CLU STORAGE 5 20 4 DRILLING DATA 4.1 Daily Activity Summary 21 Dec 2011: Mobilization of NAB 105; Complete rig berming. Miscellaneous insulating on rig. Install safety clamps and cables on mud lines. Rig up BOT BPA. Ready eye wash stations. Circulate pit system and inspect lines. Dress shakers. Service skate. Rig up roughneck and function test Nipple up/down diverter system. Rig accepted. Nipple up starting head, diverter tee, annular, flow riser, knife valve and diverter valve. Nipple up BOPs. Install flow riser and plumb in the knife valve. Install final section of diverter. Clean cellar area. Pick up drill pipe (63 joints) and rack back in derrick. Strap pipe in shed. Rabbit on skate to 2,867’. Test diverter/perform diverter test. Performance test accumulator. Pick up drill pipe joints 64 to 201. Talley and rabbit to 2,867’. Canrig Mudlogging Unit 57 rigged up and ready to log 22 Dec 2011: Pick up 5” drill pipe building stands from 202. Directional work (Baker) block height calibration. Pick up and build stands to 86 in derrick. Pick up heavy weight drill pipe and jars – 8 stands. Service rig. Circulation and condition mud, pressure test lines; 500/2500 psi – fill stack/riser and check for leaks; blow down lines. Pick up BHA #1. Slide drilling spud. Slide approximately 75’ of each stand drilled. Rotate remainder at 154 strokes per minute and 500 gallons per minute at 1400 psi OBP. 2K torque at 60 rpm. 65K up – 60 down, 65K rotating 0 to 15K WOB. 160’/hr ROP. Drill to 1027’ at midnight. 23 Dec 2011: Slide drilling and rotary drilling from 1027’ to 1844’; 189 spm/600 gpm@1800 psi, TQ off 2, TQ on 5; PUW 80/SOW 66, ROT weight 70 @ 60 RPM. Service and inspect top drive. Downtime, topdrive – broken com cable., replace broken communications cable. Slide and rotary drilling from 1844’ to 2400’ TD. 189 spm, 600 gpm @ 2100 psi DBP. TQ off 4.5, TQ on 6, PUW 86/SOW 66, ROT weight 74, 60 rpm. Circulate and condition, circulate sweep to surface until clear. 24 Dec 2011: Trip out of the hole from 1927’ to 790’; trip in hole from 790’ to 2322’; reaming/washing from 2322’, tag 2’fill, monitor the well for losses, about 2 BPH loss; circulate and condition, pump 30 BBLS high viscosity, sweep- rotate, 70 RPM reciprocate, PUW 90/SOW 65; RT. WT. 75 – 10000, Total Strokes 609 GPM @ 80 PSI; circulate and condition, monitor well blow down lines; trip out of hole, from 2400’ to 885’; lay down BHA, number 1 clear clean floor; rig up and down to run casing, rig up Weatherford casing equipment to run in 13.375” casing; run casing; pre-job safety meeting; pick up show track Baker LOK, fill casing and check floats; run casing for surface, 57 joints total as per running order; 17K up, 80K down; rig up/down to run casing, clear rig floor of unneeded tools and equipment; trip in hole, make up 5’ PUP w/ seal assembly and run in hole on 5” drill pipe; service rig audible pop from derrick, inspect derrick and top drive, determine pop came from compensator on top drive sticking in down position and moving into up position while ascending with top drive into derrick for stand; trip in hole, continue to run in hole with 5’ PUP, 24 stands, 20’ PUP and single; tag float collar and rig up to circulate, 65K up, 50K down. CLU STORAGE 5 21 25 Dec 2011: Circulate and condition, rig up lines, stab into float collar at 2346’; circulate and condition, CBU, stage up to 5 BPM at 415 PSI; primary cementing PJSM, cement 13.375” casing as per CINGSA/Schlumberger procedure, pressure test lines 1000/3000 psi, pump 245 BBLS 12.0 PPG Lead 64 BBLS, Tail cement in place at 4:15; circulate and condition, rig up flow nipple and flow line hose, clear DP, pump wiper 5 BPM at 350 PSI, circulate surface to surface, rig down BD lines, monitor well (dead); trip out of hole with inner string, clean and clear floor; waiting on cement, prep for nipple down diverter stack; nipple down BOPs, remove knife valve and Koomey hoses, break stack below diverter T; run casing, pick stack and cut casing and lower down cut joint; nipple down BOPs, pull riser, remove annular, diverter T and lock ring flange and remove from cellar, clean out drip pan; nipple down BOPs, make cut on conductor pipe and 13 3/8” casing for well head; install wellheads with FMC Rep.; nipple up BOPs, set double gate on wellhead and place annular in cellar to warm; install wellheads, pull wellhead with double gate to inspect cut, re-cut casing. 26 December 2011: Install wellheads, re-dress 13.375” casing, stump and reset FMC slip lock wellhead 13.375”; overall cut off length 24.54’; build Flo-Pro mud in pits, FMC PT CLU #4; nipple up BOPs, nipple up BOPE surface stack; pick up test tools; test BOPs, 250/2500 psi, PT 5”x7” VBR w/5” T. joint; test BOPs, test BOP 250 low, 2500 high, perform accumulator test; lower down test tool, break out test assembly; blow down mud lines and choke manifold; pull test plug; install/remove wear bushing, install wear bushing and RILDS; lower down running tool and joint; clear shed of unneeded tools and equipment; service top drive; pick up BHA, pick up 12-1/4 BHA, down load; trip in hole, run in hole with heavy weight drill pipe and shallow pulse; test downlink MWD; trip in hole, trip in hole to 2213’; pressure test casing/shoe, rig up and test casing 2000 psi; rig down test assembly; blow down mud lines; trip in hole, run in hole to 2314’ 87K up and 63K down. 27 December 2011: Waiting on orders. Re-boot Canrig computer system. Rotary drilling - tag top of cement, soft at 2336’. Drill out shoe track, float collar at 2346’. Through shoe at 2390 to 2400’. Start new hole at 0150 hrs. Drill to 2420’Circulate and condition, displace hole with 8.9ppg Flo-Pro mud. Formation integrity test (FIT) perform LOT to 15.5ppg MWE. Rotary drilling from 2420’ to 4230’. 28 December 2011: Rotary/rotary steerable drilling from 4230 to4900’. Circulate and condition mud. Pump high viscosity sweep. Short trip from 4900 to 3846’, tight from 4037. Wipe tight spots (X2). Pump out of the hole from 3846’ to 2314’. Service top drive. Grease WP packing – Blocks. Inspect quill. Trip into the hole from 2314’ to 4165’ on elevators. Wash and ream to bottom from 4165 to 4900’. Tag fill at 4894’. Rotary drill/rotary steerable drill from 4900 to 5571’. 29 December 2011: Rotary Drilling, rotate steerable directional drill from 5571’ to 6529’; circulate and condition, pump 40 bbls high viscosity sweep, rotate and reciprocate; back reaming, back ream out of hole from 6529’ to 4900’, worked a tight spot from 5571’ to 5475’; back reaming to 4709’; trip in hole on elevators from 4709’ to 6528’, wash last stand to bottom; rotary drilling, drill to 6912’ at 130 RPM; drill to 7103’ at 130 RPM; circulate 30 bbls, sweep to surface then pump; rotate and reciprocate pipe from 7103’ to 7008’ at 130 RPM; drill to 7295’ at 130 RPM. 30 December 2011: Rotary Drilling, rotate steerable directional drill from 7295’ to 7677’, high viscosity sweeps each 500’ as needed; circulate and condition, circulate high viscosity sweep, rotate and reciprocate; rotary drilling, rotate steerable directional drill from 7677’ to 8347’, high viscosity sweeps each 500’ as needed; circulate and condition, circulate high viscosity sweep, rotate and reciprocate; pump high viscosity sweep, rotate, working pipe from 8347’ to 8251’; circulate and condition, connection survey; rotary drilling to 8872’TD @ 21:30 HRS, pumping high viscosity sweep as needed, MWD downlink and survey; circulate and condition, high viscosity sweep, work pipe and rotate; back reaming from 8872’ to 8641’. CLU STORAGE 5 22 31 December 2011: Back reaming, back ream from 8634’ to 7964’; trip in hole back to bottom 8872’, lay down top joint of stand 83 to work full stand; circulate and condition, CBU; circulate and condition, spot lube and LCM pill 10.1 ppg 100 bbls; trip out of the hole 10 stands (pick up single on top of stand 83) on the elevators, no significant over-pull; back reaming from 7964’ to 6241’, tight 7391’ to 6241’, double wipe until clean; circulate and condition 6241’; circulate and condition, continued CBU at 6241’; work pipe and rotate 130 rpm and 10K torque; back reaming from 6241’ to 2409’, work tight spots as needed slm each row; circulate and condition, circulate bottoms up until clean, work and rotate pipe from 6241’ to 2409’; pump 14 bbls dry job, blow down top drive, monitor well; trip out of the hole on elevators from 2409’ to 878’ slm each row; POOH with heavy weight drill pipe 4 stands. 1 January 2012: POOH from 539’. Set back HWDP. Lay down BHA#2. Change rams. Pull wear bushing. Set test plug. Pick up test tools. Test BOPs (9 5/8” pipe rams) to 250/2500 psi. Lay down test tool. Rig down lines. Blow down stack. Run casing/dummy run 9.625” casing hanger as per FMC. Rig up Weatherford to run 9 5/8” casing. Pick up/make up shoe track. Check floats and run casing as per CINGSA run order TO #7 in (290’). Continue RIH with 9 5/8” casing as per run order from 290’ to 2386’. Fill each joint with fill up tool. CBU at shoe. Continue running 9 5/8” casing as per run order to 4015’. Circulate bottoms up. Continue running into hole with 9 5/8” casing from 4015’ to 5474’. Make up DV collar between joints 131 and 132. 134 joints in at midnight. 2 January 2012: Circulate and condition mud/circulate bottoms up at 5515’. Continue running 9 5/8” casing to 7031’. CBU at 7031’. Continue RIH with 9 5/8” casing from 7031’ to 8791’. Circulate and wash down from 8791’ to 8832’. P/U, M/U landing joint and hanger. Wash down and land 9 5/8” casing at 8861’. Total of 216 joints run. Rig down LaFleur tool, spiders and power tongs. Rig up cement head and lines. CBU 8800 strokes. Lay down Weatherford tools. Continue circulation. Mix batch job and test lines to 1000/4000psi with Schlumberger per plan. Pump 37 bbls of 10.1 ppg mud push. Circulate and cement with Schlumberger first stage 298 bbl 12 lb lead cement and 48 bbls 14 lb/gal Flexstone tail cement. Drop Davis Lynch plug. Chase with 8842 strokes, pressure to 1600psi. bleed off and check floats. Load plug #2 and pressure to 2710 psi. to shear DV collar. Pump 165 bbls mud and 40 bbls 10.1 ppg mud push to clear O/A 4/6 BPM at 225/360 psi., Schlumberger batch cement. Batch time 17.3 hours. Schlumberger pump second stage with 212 bbls 12.0 ppg cement. Drop #2 plug and chase with mud. Bump plug and pressure to 2200 psi, 3484 strokes. Hold 5 minutes. Bleed off and check plug. Cement in place at 19:36 hrs. Rig down cement lines, cement head and landing joint. Flush stack, cement line and all ports. Blow down choke and kill lines. Clear pipe shed. Prepare cellar and wellhead. Pick up running tools. Install 9 5/8” packoff. RILDS and test to 3000 psi for 15 minutes. Lay down running tools. Rig down elevators and casing equipment 3 January 2012: Lay down Weatherford casing equipment. Change out to short bales. Set test plug. Open ram doors. Clean out cement. Blind ram seal damaged; replaced with blind/shear rams. Install 5”x7” variable blind ram. Pick up/make up test joint and test tools. Fill stack and manifold, air out lines. Start BOP test 250/2500 psi test joint. Break off and lay down 5” test joint. Pick up and make up 7” test joint. Test blind/shear rams. Attempt to test upper IBOP valve. Rig down test equipment. Install test joint and perform Koomey test. Lay down test tool. Pull test plug. Drain stack and blow down manifold. Install 9 1/8” wear ring 2 L.D.S. Lay down test joint and run tool. Service top drive. Change out IBOP valves. Service ram and change out gripper heads and install tailing pad eyes for casing equipment. Install electric cord for derrick heater. Test gas alarms. Rig up test equipment and test upper and lower IBOP valves. Rig down test equipment. Blow down top drive. Pick up BHA #3 CLU STORAGE 5 23 4 January 2012: Pick up BHA #3; 8.5” bit. Pick up HWDP from derrick. Attempt to circulate and test MWD. Tools plugged with 2000psi pressure. POOH; set back HWDP and MWD tools. Investigate plugging issues. Attempt to circulate 2000psi. Bit plugged with a rag. Clear bit. Pick up BHA #3 and #1 HWDP. Circulate and test MWD. Blow down top drive. Continue picking up HWDP. Pick up drill pipe to 1590’. Service rig. Pick up drill pipe from 1590’ to 2962’. RIH from derrick to 3346’. Make up stand 26and wash down. Make up 27, rotate and wash to 3510’. Drill plug and DV collar. Rig up and pressure test casing/shoe to 2500 psi for 30 minutes; 76 strokes to achieve pressure. R/D test equipment. Wash and ream cement stringer at 3600’. Blow down top drive. RIH on elevators from 3728’ to 8772’. Drilling cement/float 5 January 2012: Drill shoe track from 8777’ through shoe at 8860’ to 8872’ TD for 12.25” hole section. Back ream 3x through shoe. Drill new 8 ½” hole from 8872’ to 8892’. CBU/clean hole. Perform FIT to 15 ppg-EMW. Rotary drill/slide (controlled to 80 ft/hr for logging) from 8992’ to 9284’. Note: adding G-seal lube to mud system decreased torque and drag significantly. Rotary drill/slide (controlled to 80 ft/hr for logging) from 9284’ to 9857’. 6 January 2012: Rotary drilling/sliding from 9857’ to 10048’. CBU for wiper trip. Back ream out of the hole from 10048’ to 8804’n shoe at 8860’. Packed off with 50 bbl loss at 9150’. Pumped 40 bbls LCM and establish full returns. Service rig and top drive, blocks, crown and tugger sheaves. RIH from 8804’ to 9953’. Wash down from 9953’ to 10048’. Pump 80 bbls LCM. Rotary drilling/sliding from 10048’ to 10064 with decreasing losses to 21 bbl/hr; 150 bbl loss for tour. Rotary drill and slide from 10064’ to 10336’ pumping LCM and lube as needed. Downtime for top drive pipe handler. Comm cable broken. Blow down top drive. Rig up to circulate down drill pipe. Change out comm. Cable. Rig down circulating head. Blow down cement line. Kelly up to stand #98. Work pipe and circulate. Rotary drilling/sliding from 10336’ to 10406’ pumping lube and LCM as needed. 7 January 2011: Rotary and slide drilling from 10406’ to 10936’ adding LCM and lube as necessary. Circulate for MWD, poor signal on MWD tool. Clean suction screens and check MWD tools. Rotary (control to 80 ft/hr) drill from 10936’ to 11101’ TD. Circulate bottoms up/ rotate and work pipe. Back ream from 11101’ to 10040’; work through tight spots. Blow down top drive. Trip into the hole with drill pipe on hook. Kelly up stand #106 and wash down to 11101’, no fill. Circulate and condition, B/U work pipe and rotate while circulating. 8 January 2012: Circulate and condition med. Spot 50 bbl 12% lube/high vis pill on bottom at 11101’. Work pipe from 11101 to 11070’. Trip out of the hole on elevators from 11101’ to 10144’; no tight hole. Attempt to circulate. No pump pressure. Troubleshoot pump/mud system. Change valves and seats on #1 mud pump. Flush coal from CH pumps and lines. Clean pits and mix volume. Work pipe from 10144’ to 10124’; no tight hole problems. Back ream from 10144’ to 9570’. No hole problems. Back ream from 9570’ to 8860’. Work through tight spot at 9245’. Slow pump to 66 G/min to work through tight spot at 9150’ to minimize loss. Filter fluid for trucks, change out shaker screens to 165s. Pump 11.2 ppg dry job. Blow down top drive. Drop drill pipe drift. Trip out of hole from 8860’ to 952’ on hook. Filter fluid from trucks. Change out back screen on shaker #1. Lay down Heavy weight drill pipe and jars. Lay down BHA #3 to non magnetic drill collar. CLU STORAGE 5 24 9 January 2011: Inspect and lay down BHA #3. JSA on unloading nuclear sources. Lay down third party tools and unload nuclear sources. Downlink smart tools and lay down Baker comm. Cable from Tee on stand pipe. Continue to lay down BHA. Clean pit #3. PJSM on rigging up to Run Wireline logs and clean pit #5. Run into hole with Wireline Cement Bond Logs. Clean pit #6. Change valves and seats on mud pump #2. Wash tools and rig down wire line. Remove tools from shed and load out. Service top drive and blocks. Clear rig floor. Rig up to run 7” liner. PJSM with all hands. Make up shoe track with Baker-Lock. Fill pipe and check float. Run 7” – 26# VAM top liner with Weatherford, 58 joints total. Change out elevators. Make up 7” packer and wiper plug. Mix and pour Pal Mix and let stand 30 minutes. Flush pumps with charge pump and attempt to pump liner volume. Change/replace pump expendables/ troubleshoot and flush pumps. Lay down top single off of stand #1. RIH with drill pipe, 5 minutes per stand maximum run time. 10 January 2012 Run 7” liner into hole on drill pipe from 3060’ to 4287’; 1.5 min/stand, filling every 10 stands. Circulate bottoms up. Continue running 7” liner into hole on drill pipe from 4287’ to 8800’ filling every 10 stands, Circulate bottoms up, 163u gas. RIH from 8800’ to 9018’, tight hole, - circulate. Rack back 1 stand. Circulate. Pump out to shoe at 8860’. Circulate bottoms up at shoe. Build dry job 6190 strokes. Pump 20bbl dry job. Blow down top drive. Monitor well. Install stripping rubber. Trip out of the hole with drill pipe and 7” liner on hook 1.5 minute/stand maximum run time from 8860’ to 2422’. Pick up single on last stand. Pull, clean and inspect liner hanger. Cover elements, remove wiper plug and lay down. Lay down and inspect 7” liner, 54 joints out at midnight. 11 January 20112: Lay down liner from 144’ to 81’. Change out elevators. Pick up 15’ drill pipe PUP. Stand shoe track back in derrick. Rig down Weatherford. Pick up drill pipe. Clean up drill floor. Stage BHA and HWDP in pipe shed. Pick up HWDP and jars to 417’. Slip and cut 153’ of drilling line. Trip out of the hole and stand back HWDP from 417’. Pick up BHA/make up milling BHA to 44’. Trip into hole with HWDP and jars from 44’ to 493’. Pick up 12 joints of 5” drill pipe. Trip into hole to 6237’. Blow down top drive. Trip into hole from 6237’ to 8824’. Circulate and condition mud from shoe to surface at 8824’. Stage up, adding screen clean. Reaming and washing from 8824’ to 10259’ 12 January 2012: Continue reaming into hole from 10259’ to 10929’. Back ream from 10929’ to 10874’. Continue reaming down from 10874 to 11101’. Circulate and condition mud/ circulate bottoms up at 11101’ while reciprocating. Back- ream from 11101’ to 9111’. Trip out of the hole from 9111’ to 8824’. Trip out of the hole, pumping out from 8824’ to 8057’ Circulate and condition at 8057’. Trip out of the hole from 8057’ to 493’. Lay down BHA #4, mill, jars and HWDP. Rig up casing equipment. Steam float assembly. Install centralizer and 2 stop rings with baker lok 15’ up from shoe. PJSM with all applicable personnel. Pump through shoe track/float assembly. Break out pup joint and crossover. Blow down top drive. Change elevators to 7”. Check floats. Run 7” – 26# top liner. Install centralizer and fill every joint. 13 January 2012: Run 7” completion liner from 492’ to 2396’. Change elevators. Pick up liner hangar. BOT install 7” plug wiper. Run into hole with 1 single of 5” drill pipe out of derrick. Wait for BOT gell to set while breaking circulation. Run liner into hole with 5” drill pipe stands from derrick as per running order from 2386’ to 8805’; filling every 10 stands. Lay down top single of stand #26. Work on mix pump #1. Clean pit #6 and pill pit. Circulate and condition at 8805’. Prep for cement job. Trip into hole with liner on drill pipe from shoe, 8860’ to 11101’. Wash down and ream to 9284’ Wash from 9284’ to 11101’. Tag bottom and set down 15K on bottom. Circulate and condition, reciprocate pipe no rotary,Rig up cement head. Continue Circulating with no rotary. Pump 5 bbls from Schlumberger cementers and pressure test 1000psi low to 4800 psi high. Batch up and pump 40 bbl mud push. Line up and pump cement 3.75 bbl/minute @ 500 psi. CLU STORAGE 5 25 14 January 2012: Pump 14.0 PPG Cement at 5 BPM, 69 BBLS total. Drop dart and chase cement with viscosified brine. Then swap to mud and bump the plug. Pressure up to 2200 PSI and then bleed off to check the float. Pressure up to 2600 PSI and slack off 50K on hanger to verify that not on bottom. Hanger set at 8700’ and liner top at 8684’. Set packer and pressure up to 500 PSI unsting. Clean out cement hanger and rig down cement hoses and manifold. Lower down cement head and single of 5” drill pipe. Trip out of the hole and pump dry job. Install pipe wiping rubber. Blow down top drive. Trip out of the hole from 8684’ to 1659’. Off load the mud from pits and clean pits. Lay down drill pipe and come out sideways while continuing to clean the pits. Lay down drill pipe and liner running tool. Service the top drive, crown, iron rough neck and pipe skate. Clear the rig floor of unneeded tools and equipment. Mud up and run in hole with Baker packer mill on 4.5 IF drill pipe. Milling tag top of BPR at 8684’, no go at 8693’. Increase pump pressure to 500 PSI. Tag and dress 3 times. Wash and circulate BPR. Set back one stand and blow down top drive. Pressure test casing and shoe to 2500 PSI for 30 minutes. Bleed off and blow down mud lines. Trip in hole and tag no go on BPR at 8684’. Mix KCL in pits. 15 January 2012: Build Volume by adding 8.7 PPG 6% KCL in pits and lay down single. Make up TIW floor valve into string m/u TD. Displace to completion fluid by pumping 35 bbls spacer pill and chase with 6% KCL, drill pipe volume 154 bbls of brine at 5.5 bbls/min. Weight 8.7 PPG 6% KCL and blow down top drive. Pump 457 bbls 6% KCL, displace annulus at 10 bbls/min 650 PSI adjusting rate as needed, rotating at 50 RPM 2-3 torque. Shut down blow down of top drive, install pipe wiper and build batch of 6% KCL for coming out of the hole. Clean trip tank. Pre-job safety meeting on laying down drill pipe with all hands involved. Trip out of hole and lay down drill pipe from 8682’ to off load drilling fluid. Batching up brine for trip out and cleaning pits 1, 2 and 6. Service top drive by greasing blocks and inspecting pipe skate. Lay down drill pipe from joint 120 to 273 and PBR dress off mill. Rig up trip tubing/drill pipe to run tie back string. Change bails, hang power tongs and string hoses. Remove wear bushing and pull wear ring. Make up seal assembly and run in hole with 95 joints of 7” tie back string. 16 January 2012: Continue to run in hole with 7” tubing from 3868’ to 8684’. Stage in corrosion inhibitor and diesel in pits to prepare for freeze protection. Rig up for reverse circulating. Sting into packer bore. Pull out of packer and lay down 2 joints of tubing. Hold PJSM before rigging up Pollard and running control line. Spool out control line and make up to Sub-Surface Safety Valve. Pick up three 5’ pups to space out. Pick up tubing hanger and make up to landing joint. Run control line using 10 steel bands to hold in place. Rig down Weatherford and Pollard. Hold PJSM before pumping diesel and inhibitor. Pump and spot diesel and inhibitor for freeze protection. Pump 5 bbls of diesel and 242 bbls of inhibited KCl fluid. Land tubing hanger. Run in lockdowns. Lay down landing joint and rig down circulating assembly. Pressure test 9 5/8”x7” annulus to 1500psi for 30 minutes. Pressure test 7” tubing to 3000psi for 30 minutes. Install BPV. Flush all surface mud. Suck out stack. Clean out drip pan. Blow down all open lines. Continue all preparations to nipple down. Nipple down stack. 17 January 2012: Finish nippling down stack. Make up “half” tree. Finish cleaning out all pits. Continue all other general rig down operations for Nabors 105-E and remaining CINGSA testing and completion procedures. CLU STORAGE 5 26 4.2 Surveys Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 0 0.00 0.00 0.00 0.00 0.00 0.00 202 0.74 65.74 201.99 0.54 1.19 -1.26 0.37 295 0.44 218.15 294.99 0.50 1.52 -1.50 1.23 384 2.67 241.74 383.95 -0.75 -0.52 0.87 2.55 473 5.12 239.09 472.74 -3.77 -5.75 6.85 2.76 563 7.61 236.55 562.18 -9.12 -14.17 16.77 2.78 653 9.92 237.29 651.12 -16.59 -25.67 30.42 2.57 742 13.97 234.85 738.18 -26.93 -40.91 48.79 4.58 832 18.16 233.16 824.65 -41.60 -61.03 73.66 4.68 927 22.52 231.12 913.70 -61.90 -87.05 106.67 4.65 1023 25.66 232.52 1001.33 -86.10 -117.87 145.85 3.32 1119 27.56 234.15 1087.16 -111.75 -152.36 188.82 2.12 1214 29.32 233.45 1170.69 -138.48 -188.87 234.03 1.89 1310 31.24 233.25 1253.59 -167.37 -227.70 282.41 2.00 1406 34.14 231.75 1334.38 -198.95 -268.81 334.24 3.14 1501 36.47 232.84 1411.90 -232.52 -312.25 389.14 2.54 1597 37.49 233.87 1488.59 -266.98 -358.59 446.85 1.24 1693 39.30 233.55 1563.83 -302.27 -406.64 506.43 1.90 1789 41.97 233.40 1636.67 -339.48 -456.88 568.91 2.78 1885 44.98 234.73 1706.33 -378.22 -510.36 634.89 3.28 1981 48.55 233.99 1772.08 -418.97 -567.18 704.74 3.76 2077 51.49 233.75 1833.75 -462.34 -626.59 778.23 3.07 2173 53.92 233.75 1891.92 -507.50 -688.17 854.54 2.53 2268 55.94 232.65 1946.50 -554.08 -750.42 932.26 2.33 2347 57.52 232.66 1989.84 -594.15 -802.93 998.30 2.00 2558 60.01 234.75 2099.25 -700.89 -948.34 1178.56 1.45 2654 60.55 234.76 2146.84 -749.00 -1016.43 1261.80 0.56 2751 61.10 234.26 2194.13 -798.17 -1085.39 1346.39 0.72 2846 61.68 233.49 2239.62 -847.34 -1152.76 1429.72 0.94 2942 62.17 233.48 2284.80 -897.74 -1220.83 1514.38 0.51 3039 62.93 233.15 2329.51 -949.17 -1289.86 1600.42 0.84 3134 62.86 232.82 2372.80 -1000.08 -1357.38 1684.96 0.32 3231 62.87 232.62 2417.04 -1052.36 -1426.07 1771.27 0.18 3327 62.88 232.59 2460.81 -1104.25 -1493.95 1856.69 0.03 3423 62.88 233.10 2504.57 -1155.86 -1562.05 1942.12 0.47 3518 62.87 232.97 2547.89 -1206.70 -1629.61 2026.64 0.12 3614 62.92 233.07 2591.63 -1258.11 -1697.87 2112.07 0.11 3710 63.10 233.26 2635.19 -1309.39 -1766.34 2197.58 0.26 CLU STORAGE 5 27 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 3806 63.00 233.61 2678.70 -1360.37 -1835.07 2283.11 0.34 3901 63.05 233.91 2721.79 -1410.42 -1903.36 2367.72 0.29 3997 63.04 233.86 2765.31 -1460.86 -1972.49 2453.22 0.05 4093 63.05 234.25 2808.83 -1511.09 -2041.76 2538.71 0.36 4188 63.10 234.40 2851.84 -1560.49 -2110.57 2623.32 0.15 4284 63.04 234.08 2895.32 -1610.50 -2180.02 2708.81 0.30 4380 63.01 234.53 2938.87 -1660.42 -2249.50 2794.27 0.42 4476 63.09 234.37 2982.38 -1710.18 -2319.13 2879.74 0.17 4571 63.04 234.51 3025.41 -1759.43 -2388.03 2964.33 0.14 4667 63.09 234.69 3068.90 -1809.01 -2457.79 3049.80 0.18 4762 63.10 234.89 3111.88 -1857.86 -2527.01 3134.38 0.19 4859 63.17 234.90 3155.72 -1907.62 -2597.80 3220.77 0.07 4956 63.06 234.74 3199.58 -1957.46 -2668.51 3307.15 0.19 5052 63.08 234.53 3243.06 -2007.00 -2738.31 3392.62 0.20 5148 63.00 234.15 3286.58 -2056.88 -2807.83 3478.09 0.36 5243 63.04 234.09 3329.68 -2106.50 -2876.43 3562.66 0.07 5339 63.04 233.90 3373.21 -2156.80 -2945.65 3648.16 0.18 5435 63.10 233.53 3416.69 -2207.46 -3014.64 3733.69 0.35 5531 63.04 233.77 3460.16 -2258.19 -3083.58 3819.22 0.23 5625 63.10 233.73 3502.74 -2307.74 -3151.16 3902.97 0.07 5721 63.05 233.58 3546.21 -2358.47 -3220.10 3988.51 0.15 5817 63.07 233.36 3589.70 -2409.41 -3288.87 4074.04 0.21 5912 63.07 233.63 3632.73 -2459.80 -3356.95 4158.69 0.25 6008 63.04 233.63 3676.23 -2510.55 -3425.86 4244.22 0.03 6104 63.04 233.37 3719.75 -2561.44 -3494.65 4329.74 0.24 6200 63.06 233.70 3763.26 -2612.30 -3563.47 4415.26 0.31 6295 63.07 233.60 3806.29 -2662.50 -3631.68 4499.90 0.09 6391 63.10 233.45 3849.75 -2713.39 -3700.51 4585.45 0.14 6487 62.98 233.68 3893.27 -2764.21 -3769.35 4670.97 0.25 6584 63.04 233.23 3937.29 -2815.68 -3838.80 4757.36 0.42 6680 63.06 233.15 3980.80 -2866.95 -3907.31 4842.90 0.08 6775 63.06 233.35 4023.84 -2917.62 -3975.17 4927.56 0.19 6871 63.02 233.35 4067.37 -2968.70 -4043.82 5013.08 0.04 6967 63.11 233.36 4110.85 -3019.78 -4112.49 5098.63 0.09 7063 62.97 233.21 4154.38 -3070.94 -4181.08 5184.16 0.20 7158 62.76 233.01 4197.70 -3121.69 -4248.70 5268.67 0.29 7254 62.72 233.44 4241.68 -3172.78 -4317.05 5353.97 0.40 7350 62.67 233.84 4285.71 -3223.35 -4385.75 5439.22 0.37 7445 62.71 233.88 4329.30 -3273.13 -4453.92 5523.57 0.06 7540 62.65 234.11 4372.90 -3322.75 -4522.19 5607.90 0.22 CLU STORAGE 5 28 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 7636 62.72 234.16 4416.95 -3372.72 -4591.32 5693.11 0.09 7732 62.68 234.31 4460.98 -3422.58 -4660.54 5778.32 0.14 7827 62.73 234.28 4504.55 -3471.85 -4729.09 5862.65 0.06 7923 62.75 234.12 4548.52 -3521.77 -4798.31 5947.90 0.15 8018 62.75 234.21 4592.02 -3571.21 -4866.78 6032.27 0.08 8114 62.63 233.94 4636.06 -3621.26 -4935.85 6117.49 0.28 8210 62.76 233.85 4680.10 -3671.53 -5004.77 6202.73 0.16 8305 62.70 234.12 4723.63 -3721.18 -5073.07 6287.09 0.26 8401 64.03 234.09 4766.66 -3771.49 -5142.59 6372.82 1.39 8497 66.48 234.38 4806.84 -3822.44 -5213.33 6459.91 2.57 8593 69.80 234.32 4842.58 -3874.36 -5285.72 6548.89 3.46 8688 72.88 234.07 4872.98 -3927.01 -5358.70 6638.79 3.25 8783 75.69 233.07 4898.71 -3981.32 -5432.27 6730.18 3.13 8831 77.39 232.28 4909.88 -4009.62 -5469.39 6776.85 3.89 8937 79.55 231.42 4931.06 -4073.78 -5551.06 6880.70 2.19 9033 79.28 228.87 4948.70 -4134.25 -5623.49 6975.03 2.63 9129 80.33 229.27 4965.69 -4196.14 -5694.87 7069.42 1.17 9225 80.36 228.87 4981.79 -4258.15 -5766.38 7163.97 0.41 9321 79.66 228.52 4998.45 -4320.55 -5837.40 7258.39 0.81 9416 80.96 229.31 5014.44 -4382.09 -5907.98 7351.93 1.60 9512 80.96 229.88 5029.52 -4443.54 -5980.17 7446.68 0.59 9608 82.51 229.11 5043.32 -4505.25 -6052.41 7541.62 1.80 9702 83.78 228.43 5054.54 -4566.76 -6122.59 7634.83 1.53 9799 85.20 227.81 5063.85 -4631.21 -6194.48 7731.20 1.60 9895 85.66 227.39 5071.50 -4695.74 -6265.14 7826.66 0.65 9990 85.78 226.75 5078.59 -4760.26 -6334.51 7921.10 0.68 10085 86.93 226.22 5084.63 -4825.54 -6403.26 8015.53 1.33 10180 86.62 226.36 5089.98 -4891.08 -6471.82 8109.98 0.36 10277 87.39 226.34 5095.05 -4957.94 -6541.91 8206.44 0.79 10371 87.11 225.98 5099.56 -5022.98 -6609.63 8299.91 0.48 10467 86.99 226.09 5104.50 -5089.53 -6678.64 8395.33 0.17 10564 88.46 225.76 5108.35 -5156.95 -6748.27 9491.78 1.55 10660 88.22 225.78 5111.13 -5223.89 -6817.03 8587.24 0.25 10756 87.85 225.10 5114.42 -5291.21 -6885.39 8682.63 0.81 10852 87.79 225.76 5118.07 -5358.53 -6953.73 8778.01 0.69 10947 88.00 225.77 5121.56 -5424.76 -7021.75 8872.45 0.22 11043 88.13 225.10 5124.80 -5492.08 -7090.11 8967.85 0.71 *11101 88.13 225.10 5126.69 -5533.00 -7131.17 9025.44 0.00 *Projection CL U S T O R A G E 5 29 4. 3 B i t R e c o r d BI T NO . SI Z E TY P E S / N JE T S / TF A IN O U T F T H R S AV E RO P Ft / H R CONDITION RR 1 1 6 ” H C C M X 1 5 1 9 4 4 0 3 3x 1 8 , 1 6 c j / 0. 9 2 4 11 8 ’ 2 4 0 0 ’ 2 2 8 2 ’ 1 4 . 9 3 1 5 2 . 8 5 1 - 2 - W T - A - E - I - N O - T D 2 1 2 - 1 / 4 ” H C C Q D 5 0 5 X X 7 1 3 1 9 5 7 8 x 1 2 ’ s 2 4 0 0 ’ 8 8 7 2 ’ 64 7 2 ’ 4 2 . 4 7 1 5 2 . 3 9 1 - 1 - W T - A - X - I - N O - T D 3 8 - 1 / 2 ” H C C H C R 5 0 3 Z X 7 1 1 4 3 2 8 3 x 1 3 , 3 x 1 4 8 8 7 2 ’ 1 1 1 0 1 ’ 2 2 2 9 ’ 3 3 . 8 2 6 5 . 8 9 1 - 1 - C T - N - X - I - N O - T D 4 8 - 1 / 2 ” B O T C o n c a v e M i l l 4 4 6 6 6 x 2 0 1 1 1 0 1 1 1 1 0 1 ’ 0 n / a n / a N / A M i l l R u n O n l y CL U S T O R A G E 5 30 4. 4 M u d R e c o r d Co n t r a c t o r : M I S w a c o Mu d T y p e : S u r f a c e : G e l / G e l e x S p u d M u d 1 1 8 ’ 2 4 2 0 ’ ; In t e r m e d i a t e / P r o d u c t i o n : K l a - S h i e l d 2 4 2 0 ’ – 1 1 1 0 1 ’ Da t e D e p t h MW (p p g ) VI S (s / q t ) PV Y P G e l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) MB T p H Cl (ml/l) Ca (ml/l) 12 / 2 2 / 2 0 1 1 8 8 6 8 . 8 5 8 1 4 1 8 1 0 / 1 5 / 1 9 1 2 . 2 2 / 4 / 9 6 0 . 2 5 2 2 8 . 8 2 0 0 0 4 0 12 / 2 3 / 2 0 1 1 2 4 0 0 9 . 1 5 6 1 6 2 6 2 2 / 2 9 / 3 1 8 . 6 2 / 5 / 9 5 0 . 7 2 3 8 . 6 1 1 0 0 4 0 12 / 2 4 / 2 0 1 1 2 4 0 0 9 . 1 4 9 1 2 2 0 1 0 / 1 4 / 1 6 8 . 5 2 / 5 / 9 5 0 . 5 2 2 8 . 5 1 0 0 0 4 0 12 / 2 5 / 2 0 1 1 2 4 0 0 9 . 1 4 7 1 0 1 8 5 / 9 / 9 8 . 5 2 / 5 / 1 0 0 0 . 3 3 2 2 . 5 9 . 0 1 0 0 0 4 0 12 / 2 6 / 2 0 1 1 2 4 0 0 8 . 9 5 2 1 1 2 4 8 / 1 1 / 1 2 6 . 4 1 / 3 / 9 7 8 . 5 2 8 5 0 0 4 0 12 / 2 7 / 2 0 1 1 4 0 3 8 9 . 0 4 5 1 1 1 6 5 / 7 / 8 6 . 4 1 / 4 1 / 9 5 0 . 7 5 1 9 . 1 2 8 0 0 0 2 8 0 12 / 2 8 / 2 0 1 1 5 3 8 2 9 . 0 5 0 1 2 2 0 1 0 / 1 2 / 1 2 5 . 8 1 / 4 3 / 9 3 0 . 5 2 . 5 9 . 5 2 7 8 0 0 2 8 0 12 / 2 9 / 2 0 1 1 7 1 8 5 9 . 1 5 0 1 1 5 9 / 1 3 / 1 5 5 . 6 1 / 4 4 / 9 3 0 . 5 3 8.8 28000 280 12 / 3 0 / 2 0 1 1 8 8 7 2 9 . 3 5 2 1 4 2 3 1 3 / 2 0 / 2 9 5 . 8 1 / 6 4 / 9 0 0 . 5 5 8 . 8 2 9 0 0 0 2 8 0 12 / 3 1 / 2 0 1 1 8 8 7 2 9 . 3 6 0 1 6 2 3 1 5 / 2 3 / 3 5 5 . 6 1 / 6 4 / 9 0 0 . 5 5 . 5 8 . 8 2 8 0 0 0 2 8 0 1/ 1 / 2 0 1 2 8 8 7 2 9 . 4 5 8 1 6 2 0 1 5 / 2 2 / 3 5 5 . 6 1 / 6 4 / 9 0 0 . 5 6 8 . 8 2 7 0 0 0 3 0 0 1/ 2 / 2 0 1 2 8 8 7 2 9 . 4 5 9 1 5 2 0 9 / 1 6 / 2 2 5 . 8 1 / 6 4 / 9 0 0 . 5 5 8 . 8 2 7 0 0 0 4 0 1/ 3 / 2 0 1 2 8 8 7 2 9 . 4 7 0 1 6 2 2 1 4 / 1 8 / 2 0 6 . 2 1 / 6 3 / 9 1 0 . 2 5 5 8 . 3 2 5 0 0 0 4 0 0 1/ 4 / 2 0 1 2 8 8 7 2 9 . 2 6 2 1 6 1 7 8 / 1 2 / 1 6 6 . 6 2 / 7 3 / 9 1 0 . 2 5 7 9 . 1 2 6 0 0 0 2 4 0 1/ 5 / 2 0 1 2 9 8 5 7 9 . 2 6 4 1 4 3 0 1 3 / 1 7 / 2 1 7 . 1 2 / 6 3 / 9 1 0 . 3 7 . 5 8 . 6 2 5 0 0 0 8 0 1/ 6 / 2 0 1 2 1 0 4 0 4 9 . 2 5 4 1 4 2 2 1 0 / 1 2 / 1 9 5 . 6 2 / 7 3 / 9 1 0 . 3 8 8 . 4 2 6 0 0 0 3 2 0 1/ 7 / 2 0 1 2 1 1 1 0 1 9 . 2 5 4 1 3 2 3 1 0 / 1 3 / 1 9 6 . 2 2 7 4 / 9 0 0 . 3 3 9 9 . 2 2 0 0 0 0 2 4 0 1/ 8 / 2 0 1 2 1 1 1 0 1 9 . 1 5 3 1 2 1 8 7 / 1 2 / 1 6 6 . 1 2 6 3 / 9 1 0 . 2 9 9 . 2 1 6 0 0 0 3 2 0 Ab b r e v i a t i o n s : MW = M u d W e i g h t V I S = F u n n e l V i s c o s i t y PV = P l a s t i c V i s c o s i t y Y P = Y i e l d P o i n t G e l s = G e l S t r e n g t h F L = W a t e r o r F i l t r a t e Lo s s F C = F i l t e r C a k e O / W = O i l t o W a t e r r a t i o S o l s = S o l i d s S d = S a n d c o n t e n t M B T = M e t h y l e n e B l u e A l k = A l k a l i n i t y , M u d pH = % H y d r o g e n i o n C l = C h l o r i d e s C a = H a r d n e s s C a l c i u m n r = N o t R e c o r d e d CL U S T O R A G E 5 31 4. 5 D r i l l i n g P r o g r e s s C h a r t CLU STORAGE 5 32 5 DAILY DRILLING REPORTS
