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Home My WebLink About208-098Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250220 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 18RD 50133205840100 222033 1/27/2025 AK E-LINE Patch BRU 223-24 50283201830000 221072 1/26/2025 AK E-LINE Perf CLU 10RD 50133205530100 222113 11/2/2024 YELLOWJACKET PLUG GP 03-87 50733204370000 166052 12/16/2024 AK E-LINE Plug/Cement IRU 44-36 50283200890000 193022 1/22/2025 AK E-LINE Perf KU WD-01 50133203450000 181107 10/15/2024 YELLOWJACKET PERF MPI 1-29 50029216690000 186181 1/29/2025 AK E-LINE Perf MPU C-39 50029228490000 197248 1/27/2025 AK E-LINE TubingCut MPU E-20A 50029225610100 204054 2/1/2025 READ CaliperSurvey MPU K-33 50029227290000 196202 2/8/2025 AK E-LINE TubeCut MPU S-08 50029231680000 203123 2/6/2025 AK E-LINE CmtRtr/Punch MRU A-13 50733200770000 168002 2/6/2025 AK E-LINE TubingPunch MRU M-02 50733203890000 187061 1/22/2025 AK E-LINE Perf MRU M-32RD2 50733204620200 217091 2/10/2025 AK E-LINE TubingPunch NCIU A-09 50883200290100 222024 1/31/2025 AK E-LINE Perf NCIU A-16 50883201270000 208098 1/30/2025 AK E-LINE Perf NCIU A-21 50883201990000 224086 1/15/2025 AK E-LINE Plug, Perf NK-41A 50029227780100 197158 1/6/2025 HALLIBURTON Coilflag PAVE 3-1 50029238060000 224140 1/4/2025 YELLOWJACKET CBL PBU P1-13 50029223720000 193074 12/3/2024 HALLIBURTON PPROF PTM P1-07A 50029219960100 204037 12/31/2024 YELLOWJACKET PPROF Please include current contact information if different from above. T40127 T40128 T40129 T40130 T40131 T40132 T40133 T40134 T40135 T40136 T40137 T40138 T40139 T40140 T40141 T40142 T40143 T40144 T40145 T40146 T40147 NCIU A-16 50883201270000 208098 1/30/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.20 14:09:18 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,314 N/A Casing Collapse Structural Conductor Surface 3,090psi Intermediate Production 5,410psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Rupert Contact Email:Ryan.Rupert@hilcorp.com Contact Phone:(907) 777-8503 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng North Cook Inlet Tertiary System Gas Same 7,631 6,957 5,282 1,843psi See schematic Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 / ADL0037831 208-098 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-883-20127-00-00 Hilcorp Alaska, LLC N Cook Inlet Unit A-16 Length Size Proposed Pools: L-80 TVD Burst 391 & 5,113 7,240psi MD 5,750psi 400' 3,457' 400' 4,536' 7,618'7" 30" 9-5/8" 400' 4,536' Perforation Depth MD (ft): 5,993 - 6,940 9,301' 3-1/2" 4,383 - 5,265 Other: CTCO & N2 Operations CO 68A 9/18/2024 7,029'1,924' 4-1/2" & 3-1/2" 5,353' See schematic See schematic 9,301' No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:28 pm, Sep 09, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.09.09 12:16:53 - 08'00' Dan Marlowe (1267) Yes, for plug set only 9/18/24 Bryan McLellan 10-404 BJM 9/18/24 A.Dewhurst 11SEP24 DSR-9/11/24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.19 10:34:29 -08'00'09/19/24 RBDMS JSB 092324 CT Cleanout Well: NCIU (Tyonek) A-16 Well Name:NCIU (Tyonek) A-16 API Number:50-883-20127-00-00 Current Status:Online gas well Leg:Leg #2 (SW corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:208-098 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:2,370 psi @ 5,265’ TVD 0.45psi/ft to deepest perf Max. Potential Surface Pressure: 1843 psi Using 0.1 psi/ft Brief Well Summary Gas producer A-16 was recompleted to the Upper Beluga portion of the Tertiary System Gas Pool in 2020. Several sands were perf/repeforated and the well got up to 3000+ MCFD. The well took an abrupt step change down from 1500 MCFD to <900MCFD in October-2023 and hasn’t recovered since. The rate is now <650MCFD. This intervention aims to restore production to September-2023 rates and add some infill perfs sands. If possible, we will aim to shutoff any water sources. Perfs / Repefs and a fill cleanout may also be necessary. All planned perforations below are within the Tertiary System Gas Pool as defined by CO 68A. The goal of this project is to cleanout the well, add infill perfs, and shutoff water to improve rate CT Cleanout Well: NCIU (Tyonek) A-16 Pertinent wellbore information: - WL-SSSV installed and functional - Max inclination above PBTD: 54 degree sail angle from 2300 – 5700’ MD - Historical activity o May-2020: RWO to isolate Lower Beluga, and recomplete in Upper Beluga o 7/1/20: perf’d G+F sands down to 6940’ MD (PBTD = 6957’ MD): No sustained flow o 7/11/20: SL found FL at 6443’ (above all perfs) and tagged bottom at 6947’ MD o 8/7/20: Perf Beluga-E. Appears to sustain flows >1800mcfd and 20+bwpd o 8/14/20: Well was flowing 1900mcfd when EL showed up. Perf'd D, C, B sands. Sustainable flow at 2600mcfd+ and 10+bwpd o 2/4/21: Dummy gun drift makes it down to 6925’ MD o 2/8/21: Added A+B sand parfs. Was 2400MCFD prior, and 3000+MCFD afterwards. Water constant or increased at 10-20bwpd o 2/9/21: Spinner temp pressure production Log Well was making 3000mcfd and 22bwpd Major cooling:6250' (BEL-B) 235psi FBHP Some cooling: 6810' (BEL-F), 6760' (BEL-E), 6430' (BEL-B) Minor cooling: 6470' (BEL-C), 6370' (BEL-B) o 11/16/21: 18’ dummy patch makes it down to 6905’ MD o 11/20/21: perf'd additional D and E sands with strip guns. No change in production o 12/3/21: Perf'd additional D-sand (no change in rate). Perf'd CI 11 and CI 9 sands (no changes) o 12/4/21: SL finds FL at 6750’ MD (above BEL-E) and tags at 6896’ MD o 10/19/23: Production rapidly drops from 1500MCFD to <900MCFD after a shut in. No additional water production after this, either o 3/22/24: SL FL at 6720' MD (above BEL-E). Tag of bottom at 6831' MD. BEL-G and partial BEL-F covered now. Run flowing PT survey: x All gas above 6418 (Base BEL-B), All water below 6568' MD (mid BEL-D) x Major cooling at 6463' (BEL-C),6274' (BEL-B) 187psi FBHP, 6177' (BEL-A) CT Cleanout Well: NCIU (Tyonek) A-16 Coiled Tubing Procedure 1. MIRU Fox Energy offshore Coiled Tubing and pressure control equipment 2. PT lubricator to 250psi low / 2000psi high a. Multiple wells planned for CT intervention on this leg (#2) b. Hilcorp requests a weekly CT BOP test requirement while on this leg, instead of each well 3. MU cleanout BHA 4. RIH and clean / mill out to PBTD or as deep as practical a. Working fluid will be freshwater (8.33ppg) or heavier b. If necessary, add foam and nitrogen for the cleanout 5. Once hole is clean, lift well to production with nitrogen 6. RDMO CT E-Line Perf procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2000psi high 3. RIH and perforate / Reperforate from ±5,993’ - ±6,957’ MD (±4,383’ - ±5,265’ TVD) per RE/Geo a. All proposed perfs within Tertiary System Gas Pool b. Bottom pool is below PBTD c. Top pool is at top Sterling sands (Far above top proposed perfs) 4. RDMO EL CONTINGENCY plug/patch: (if any zone makes unwanted solids or water) 1. RU nitrogen to tubing and PT lines to 2000psi (or higher if needed) 2. Pressure up on tubing and displace water back into formation 3. MIRU E-line and pressure control equipment 4. PT lubricator to 250psi low / 2000psi high 5. Set 3-1/2” isolation plug or patch per OE 6. RDMO Nitrogen and EL Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. CT BOP Drawing (Fox energy) 4. Nitrogen procedure Verbal approval granted to set a CIBP in this well at 6800' MD per the below contingency procedure since water entry _____________________________________________________________________________________ Updated By: JLL 09/06/24 SCHEMATIC Tyonek Platform Well: A-16 Last Completed: 05/17/20 PTD: 208-098 API: 50-883-20127-00-00 PBTD:6,957’ TD: 9,314’ 20” RKB– 42.6’, RKB to MSL – 119.2’, RKB to Mudline 239.2’ 7” 2 17 12 9-5/8” 1 19 23 22 10 11 16 20 14 15 21 24 25 26 13 3-1/2” liner cemented in place 3 5 4 7 6 8 Beluga F & G Beluga H Beluga D&E 9TOC 6,957’ Beluga A -C Sterling CI9&11 23 18 17 R 22333222223233333333 X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” Conductor Welded 19.100” 45’ 400’ 9-5/8” 40 L-80 BTCM 8.835” 48.6’ 4,536’ 3-1/2” 9.3 L-80 8rd 2.992 5,105’ 7,029’ 7” 26 L-80 BTCM 6.276” 44.8’ 9,301’ TUBING DETAIL 4-1/2” 12.60 L-80 IBTM 3.958” Surface 391’ 3-1/2” 9.2 L-80 IBT 2.992” 391’ 4,762’ 3-1/2” 9.2 L-80 8RD 2.992” 4,762’ 5,113’ GRAVEL PACK 4” 11.00 P-110 SLHT 3.430” 7,426’ 8,805’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 348’ 348’ 3.813 5.40 Nipple, Camco BP-6i Landing - Camco 3.813” WRDP, DB Lock 2 391’ 391’ 3.000 5.210 4-1/2” x 3-1/2” Crossover 3 4,711’ 3,563’ 2.867” 5.313” Chemical Injection Mandrel 4 4,763’ 3,594’ 3.000” 6.000” Packer - Hydraulic Retrievable 5 4,809’ 3,621’ 2.813” 3.750” X-Nipple 6 5,103’ 3,796’ 2.992” 3.500” Dummy Seal Bore Assembly 7 5,105’ 3,797’ 4.176” 5.924” ZXP Liner Top Packer with 10’ extension and Liner Hanger 8 5,113’ 3,801’ 3.020” 5.000” Landing Collar and Float Assembly 9 7,030’ 5,354’ CIBP –TOC 6,957 (5/14/20) Isolated Jewelry Details on page 2 GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 1,839’ 1,761’ 2.867”SPM – 1 IPOC-1 16 DOME 800 5/18/2020 2 3,797’ 3,008’ 2.867”SPM – 1 IPOC-1 16 DOME 770 5/18/2020 3 4,662’ 3,534’ 2.867”SPM – 1 IPOC-1 20 ORIFICE 5/18/2020 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf Date Comments Sterling CI 9 5,993’ 6,001’ 4,383’ 4,390’ 8’ 5 12/3/21 Open Sterling CI 11 6,067 6,083’ 4,445’ 4,458’ 16’ 5 12/3/21 Open Beluga A 6,141’ 6,157’ 4,508’ 4,522’ 16’ 5 02/08/21 Open Beluga B 6,242’ 6,258’ 4,599’ 4,613’ 16’ 5 02/08/21 Open Beluga B 6,315’ 6,320’ 4,666’ 4,670’ 5’ 5 02/08/21 Open Beluga B 6,361’ 6,366’ 4,709’ 4,713’ 5’ 05/15/20 Isolated Beluga B 6,367’ 6,381’ 4,714’ 4,732’ 14 5 08/14/20 Open Beluga B 6,427’ 6,434’ 4,770’ 4, 777’ 7' 5 08/14/20 Open Beluga C 6,467’ 6,475’ 4,808’ 4, 816’ 8’ 5 08/14/20 Open Beluga D 6,642’ 6,655’ 4,976’ 4,988’ 13’ 5 08/14/20 Open Beluga D 6,537’ 6,542’ 4,875’ 4,880’ 5’ 4 12/3/21 Open Beluga D 6,663’ 6,671’ 4,996’ 5,004’ 4’ 4 11/20/21 Open Beluga D 6,582’ 6,586’ 4,918’ 4,922’ 8’ 4 11/20/21 Open Beluga E 6,663’ 6,671’ 4,996’ 5,004’ 8’ 05/15/20 Isolated Beluga E 6,755’ 6,769’ 5,085’ 5,098’ 14 5 08/07/20 Open Beluga F 6,805’ 6,813’ 5,135’ 5,142’ 9’ 5 07/01/20 Open Beluga F 6,846’ 6,876’ 5,173’ 5,202’ 30’ 5 07/01/20 Open Beluga G 6,912’ 6,940’ 5,238’ 5,265’ 28’ 5 07/01/20 Open Updated by: JLL 09/06/24 SCHEMATIC Tyonek Platform Well: A-16 Last Completed: 05/17/20 PTD: 208-98 API: 50-883-200127-00 ISOLATED PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf Date Comments Beluga H 7,038’ 7,066’ 5,362’ 5,389’ 28’ 6 5/14/20 Isolated Beluga H 7,046’ 7,066’ 5,370’ 5,389’ 20’ 6 5/14/20 Isolated Beluga H 7,125’ 7,133’ 5,448’ 5,456’ 8’ 6 5/14/20 Isolated Beluga J 7,289’ 7,337’ 5,651’ 5,659’ 48’ 6 5/14/20 Isolated Beluga J 7,329’ 7,337’ 5,651’ 5,659’ 8’ 6 5/14/20 Isolated Beluga K 7,364’ 7,382’ 5,686’ 5,704’ 18’ 6 5/14/20 Isolated Beluga M 7,500’ 7,524’ 5,821’ 5,845’ 24’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga O 7,677’ 7,694’ 5,998’ 6,015’ 17’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga P 7,797’ 7,810’ 6,117’ 6,130’ 13’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,880’ 7,885’ 6,200’ 6,205’ 5’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,912’ 7,922’ 6,232’ 6,242’ 10’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,946’ 7,978’ 6,266’ 6,298’ 32’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,958’ 7,978’ 6,278’ 6,298’ 20’ 6 5/14/20 1/31/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga S 8,278’ 8,284’ 6,597’ 6,603’ 6’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,291’ 8,300’ 6,610’ 6,619’ 9’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,291’ 8,300’ 6,610’ 6,619’ 9’ 6 5/14/20 1/31/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga T 8,414’ 8,424’ 6,733’ 6,743’ 10’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,464’ 8,490’ 6,783’ 6,809’ 26’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,517’ 8,523’ 6,836’ 6,841’ 6’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,564’ 8,576’ 6,882’ 6,894’ 12’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,565’ 8,571’ 6,883’ 6,889’ 6’ 6 5/14/20 1/29/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga U 8,587’ 8,593’ 6,905’ 6,911’ 6’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,709’ 8,724’ 7,027’ 7,042’ 15’ 6 5/14/20 1/26/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga U 8,709’ 8,724’ 7,027’ 7,042’ 15’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,734’ 8,741’ 7,052’ 7,059’ 7’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,746’ 8,756’ 7,064’ 7,074’ 10’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,767’ 8,771’ 7,085’ 7,089’ 4’ 14 5/14/20 1/26/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG OPEN HOLE / CEMENT DETAIL 9-5/8”12.25” Hole: Pumped 524 bbls of 12.0 ppg Cement. Observed 70 bbls cement returns.ToC at surface. 7”8.75” Hole: Pumped 222 bbls (385 sxs) of Class G cement. 9314' MD.CBL ran on 5/14/20 showed TOC at 4530' MD. 3-1/2” Scab Liner 7” casing: Cemented with 53bbls 15.8ppg cement. Spacer and trace cement returns circulated off top liner. 5/16/20 CBL shows ToC at 5270’ MD. ISOLATED JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item 10 7,399’ 5,721’ 3.450 4.000 Packer, Sump, Baker SC-2 11 7,424 5,745’ 3.250 4.530 Nipple, R - PR Plug set in R profile with 4’ Catcher on top 12 7,425’ 5,746’ 3.260 5.000 Snap Latch 13 7,426’ 5,747’ 3.260 3.980 Seal Unit 14 7,426’ 5,747’ 4.000 6.000 Packer, Baker SC-2 70B-40 7,430’ 5,752’ 3.260 Mule Shoe 15 7,434’ 5,755’ 4.000 5.560 Seal Bore 16 7,458’ 5,779’ 3.430 5.650 KOIV Isolation Sleeve 7,464’ 5,785’ 3.430 Sub, Shear Out Safety 17 7,481’ 5,802’ 0.000 Plug, Baker IBP 7,487’ 5,808’ 3.430 5.800 Screen, Bakerweld 10 ga. 18 7,715’ 6,037’ 3.250 5.000 Seal Bore receptacle 7,719’ 6,040’ 3.430 5.800 Screen, Bakerweld 10 ga. 19 8,007’ 6,327’ 3.250 5.000 Seal Bore receptacle 8,010’ 6,330’ 3.430 5.800 Screen, Bakerweld 10 ga. 20 8,318’ 6,637’ 3.250 5.000 Seal Bore receptacle 8,320’ 6,639’ 3.430 5.800 Screen, Bakerweld 10 ga. 21 8,540’ 6,858’ 3.250 4.490 Seal Bore receptacle 8,543’ 6,861’ 3.430 5.800 Screen, Bakerweld 10 ga. 22 8,613’ 6,932’ 3.250 4.490 Seal Bore receptacle 8,616’ 6,934’ 3.430 5.800 Screen, Bakerweld 10 ga. 23 8,796’ 7,114’ 3.260 5.000 Snap Latch 82-40 S-22B 24 8,797’ 7,115’ 4.000 5.850 Packer, Sump, FS 25 8,801’ 7,119’ 4.890 5.510 Mule Shoe, 5-1/2”, 23#, L-80 26 8,991’ 7,308’ 0.000 Plug, Baker CIBP Note: 8/21/11 Gravel Pack (M thru U) 27304 lbs. 20/40 sand, 65.9 lbs/ft perfs @ 10.1 BPM, 33% returns _____________________________________________________________________________________ Updated By: JLL 09/09/24 PROPOSED Tyonek Platform Well: A-16 Last Completed: 05/17/20 PTD: 208-098 API: 50-883-20127-00-00 PBTD:6,957’ TD: 9,314’ 20” RKB– 42.6’, RKB to MSL – 119.2’, RKB to Mudline 239.2’ 7” 2 17 12 9-5/8” 1 19 23 22 10 11 16 20 14 15 21 24 25 26 13 3-1/2” liner cemented in place 3 5 4 7 6 8 Beluga F & G Beluga H Beluga D&E 9TOC 6,957’ Beluga A -C Sterling CI9&11 23 18 17 R 22333222223233333333 X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” Conductor Welded 19.100” 45’ 400’ 9-5/8” 40 L-80 BTCM 8.835” 48.6’ 4,536’ 3-1/2” 9.3 L-80 8rd 2.992 5,105’ 7,029’ 7” 26 L-80 BTCM 6.276” 44.8’ 9,301’ TUBING DETAIL 4-1/2” 12.60 L-80 IBTM 3.958” Surface 391’ 3-1/2” 9.2 L-80 IBT 2.992” 391’ 4,762’ 3-1/2” 9.2 L-80 8RD 2.992” 4,762’ 5,113’ GRAVEL PACK 4” 11.00 P-110 SLHT 3.430” 7,426’ 8,805’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 348’ 348’ 3.813 5.40 Nipple, Camco BP-6i Landing - Camco 3.813” WRDP, DB Lock 2 391’ 391’ 3.000 5.210 4-1/2” x 3-1/2” Crossover 3 4,711’ 3,563’ 2.867” 5.313” Chemical Injection Mandrel 4 4,763’ 3,594’ 3.000” 6.000” Packer - Hydraulic Retrievable 5 4,809’ 3,621’ 2.813” 3.750” X-Nipple 6 5,103’ 3,796’ 2.992” 3.500” Dummy Seal Bore Assembly 7 5,105’ 3,797’ 4.176” 5.924” ZXP Liner Top Packer with 10’ extension and Liner Hanger 8 5,113’ 3,801’ 3.020” 5.000” Landing Collar and Float Assembly 9 7,030’ 5,354’ CIBP –TOC 6,957 (5/14/20) Isolated Jewelry Details on page 2 GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 1,839’ 1,761’ 2.867”SPM – 1 IPOC-1 16 DOME 800 5/18/2020 2 3,797’ 3,008’ 2.867”SPM – 1 IPOC-1 16 DOME 770 5/18/2020 3 4,662’ 3,534’ 2.867”SPM – 1 IPOC-1 20 ORIFICE 5/18/2020 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf Date Comments Sterling / Bel ±5,993' ±6,957' ±4,383' ±5,265' ±964' Future Proposed Perf/Reperf Sterling CI 9 5,993’ 6,001’ 4,383’ 4,390’ 8’ 5 12/3/21 Open Sterling CI 11 6,067 6,083’ 4,445’ 4,458’ 16’ 5 12/3/21 Open Beluga A 6,141’ 6,157’ 4,508’ 4,522’ 16’ 5 02/08/21 Open Beluga B 6,242’ 6,258’ 4,599’ 4,613’ 16’ 5 02/08/21 Open Beluga B 6,315’ 6,320’ 4,666’ 4,670’ 5’ 5 02/08/21 Open Beluga B 6,361’ 6,366’ 4,709’ 4,713’ 5’ 05/15/20 Isolated Beluga B 6,367’ 6,381’ 4,714’ 4,732’ 14 5 08/14/20 Open Beluga B 6,427’ 6,434’ 4,770’ 4, 777’ 7' 5 08/14/20 Open Beluga C 6,467’ 6,475’ 4,808’ 4, 816’ 8’ 5 08/14/20 Open Beluga D 6,642’ 6,655’ 4,976’ 4,988’ 13’ 5 08/14/20 Open Beluga D 6,537’ 6,542’ 4,875’ 4,880’ 5’ 4 12/3/21 Open Beluga D 6,663’ 6,671’ 4,996’ 5,004’ 4’ 4 11/20/21 Open Beluga D 6,582’ 6,586’ 4,918’ 4,922’ 8’ 4 11/20/21 Open Beluga E 6,663’ 6,671’ 4,996’ 5,004’ 8’ 05/15/20 Isolated Beluga E 6,755’ 6,769’ 5,085’ 5,098’ 14 5 08/07/20 Open Beluga F 6,805’ 6,813’ 5,135’ 5,142’ 9’ 5 07/01/20 Open Beluga F 6,846’ 6,876’ 5,173’ 5,202’ 30’ 5 07/01/20 Open Beluga G 6,912’ 6,940’ 5,238’ 5,265’ 28’ 5 07/01/20 Open Updated by: JLL 09/09/24 PROPOSED Tyonek Platform Well: A-16 Last Completed: 05/17/20 PTD: 208-98 API: 50-883-200127-00 ISOLATED PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf Date Comments Beluga H 7,038’ 7,066’ 5,362’ 5,389’ 28’ 6 5/14/20 Isolated Beluga H 7,046’ 7,066’ 5,370’ 5,389’ 20’ 6 5/14/20 Isolated Beluga H 7,125’ 7,133’ 5,448’ 5,456’ 8’ 6 5/14/20 Isolated Beluga J 7,289’ 7,337’ 5,651’ 5,659’ 48’ 6 5/14/20 Isolated Beluga J 7,329’ 7,337’ 5,651’ 5,659’ 8’ 6 5/14/20 Isolated Beluga K 7,364’ 7,382’ 5,686’ 5,704’ 18’ 6 5/14/20 Isolated Beluga M 7,500’ 7,524’ 5,821’ 5,845’ 24’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga O 7,677’ 7,694’ 5,998’ 6,015’ 17’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga P 7,797’ 7,810’ 6,117’ 6,130’ 13’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,880’ 7,885’ 6,200’ 6,205’ 5’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,912’ 7,922’ 6,232’ 6,242’ 10’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,946’ 7,978’ 6,266’ 6,298’ 32’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,958’ 7,978’ 6,278’ 6,298’ 20’ 6 5/14/20 1/31/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga S 8,278’ 8,284’ 6,597’ 6,603’ 6’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,291’ 8,300’ 6,610’ 6,619’ 9’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,291’ 8,300’ 6,610’ 6,619’ 9’ 6 5/14/20 1/31/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga T 8,414’ 8,424’ 6,733’ 6,743’ 10’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,464’ 8,490’ 6,783’ 6,809’ 26’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,517’ 8,523’ 6,836’ 6,841’ 6’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,564’ 8,576’ 6,882’ 6,894’ 12’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,565’ 8,571’ 6,883’ 6,889’ 6’ 6 5/14/20 1/29/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga U 8,587’ 8,593’ 6,905’ 6,911’ 6’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,709’ 8,724’ 7,027’ 7,042’ 15’ 6 5/14/20 1/26/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga U 8,709’ 8,724’ 7,027’ 7,042’ 15’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,734’ 8,741’ 7,052’ 7,059’ 7’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,746’ 8,756’ 7,064’ 7,074’ 10’ 14 5/14/20 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,767’ 8,771’ 7,085’ 7,089’ 4’ 14 5/14/20 1/26/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG OPEN HOLE / CEMENT DETAIL 9-5/8”12.25” Hole: Pumped 524 bbls of 12.0 ppg Cement. Observed 70 bbls cement returns.ToC at surface. 7”8.75” Hole: Pumped 222 bbls (385 sxs) of Class G cement. 9314' MD.CBL ran on 5/14/20 showed TOC at 4530' MD. 3-1/2” Scab Liner 7” casing: Cemented with 53bbls 15.8ppg cement. Spacer and trace cement returns circulated off top liner. 5/16/20 CBL shows ToC at 5270’ MD. ISOLATED JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item 10 7,399’ 5,721’ 3.450 4.000 Packer, Sump, Baker SC-2 11 7,424 5,745’ 3.250 4.530 Nipple, R - PR Plug set in R profile with 4’ Catcher on top 12 7,425’ 5,746’ 3.260 5.000 Snap Latch 13 7,426’ 5,747’ 3.260 3.980 Seal Unit 14 7,426’ 5,747’ 4.000 6.000 Packer, Baker SC-2 70B-40 7,430’ 5,752’ 3.260 Mule Shoe 15 7,434’ 5,755’ 4.000 5.560 Seal Bore 16 7,458’ 5,779’ 3.430 5.650 KOIV Isolation Sleeve 7,464’ 5,785’ 3.430 Sub, Shear Out Safety 17 7,481’ 5,802’ 0.000 Plug, Baker IBP 7,487’ 5,808’ 3.430 5.800 Screen, Bakerweld 10 ga. 18 7,715’ 6,037’ 3.250 5.000 Seal Bore receptacle 7,719’ 6,040’ 3.430 5.800 Screen, Bakerweld 10 ga. 19 8,007’ 6,327’ 3.250 5.000 Seal Bore receptacle 8,010’ 6,330’ 3.430 5.800 Screen, Bakerweld 10 ga. 20 8,318’ 6,637’ 3.250 5.000 Seal Bore receptacle 8,320’ 6,639’ 3.430 5.800 Screen, Bakerweld 10 ga. 21 8,540’ 6,858’ 3.250 4.490 Seal Bore receptacle 8,543’ 6,861’ 3.430 5.800 Screen, Bakerweld 10 ga. 22 8,613’ 6,932’ 3.250 4.490 Seal Bore receptacle 8,616’ 6,934’ 3.430 5.800 Screen, Bakerweld 10 ga. 23 8,796’ 7,114’ 3.260 5.000 Snap Latch 82-40 S-22B 24 8,797’ 7,115’ 4.000 5.850 Packer, Sump, FS 25 8,801’ 7,119’ 4.890 5.510 Mule Shoe, 5-1/2”, 23#, L-80 26 8,991’ 7,308’ 0.000 Plug, Baker CIBP Note: 8/21/11 Gravel Pack (M thru U) 27304 lbs. 20/40 sand, 65.9 lbs/ft perfs @ 10.1 BPM, 33% returns KLU A-1 Well Head Rig Up 1 1 1 1 4 1/16" 15K Lubricator - 10 ft 100" Gooseneck HR680 Injector Head 4 1/16" 10K Flow Cross, 2" 1502 10k Flanged Valves 4 1/16" 15K Lubricator - 10 ft API Flange Adapter 10K to 5K for riser/wellhead Hydraulic Stripper 4 1/6" 15K API Bowen CB56 15K 4 1/16" 10K Combi BOPs Blind/Shear Ram Pipe/Slip Ram 4 1/16" 10K bottom flange 4 1/16" 5K flanged Riser - 10 ft if necessary STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. 1 McLellan, Bryan J (OGC) From:McLellan, Bryan J (OGC) Sent:Wednesday, September 18, 2024 4:27 PM To:Ryan Rupert Subject:RE: 10-403 N Cook Inlet Unit A-16 PTD 208-098 - Application for Sundry Approval Ryan, Hilcorp has approval to set the CIBP at 6800’ MD, as included in the sundry application contingency section steps 1-6. The remainder of the sundry steps will be approved through the normal process, expected to be complete by this Friday. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Monday, September 16, 2024 6:13 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Trevor Willms - (C) <Trevor.Willms@hilcorp.com> Subject: FW: 10-403 N Cook Inlet Unit A-16 PTD 208-098 - Application for Sundry Approval Bryan- Apologies for the request, but I'm going to have some opportunistic EL time available tomorrow on Tyonek platform. Hilcorp would like to request verbal approval to set a CIBP at plus or minus 6800' MD in well A-16 (part of the submitted sundry attached). I can give you a call in the morning to discuss as well, if you'd like. Thank you Ryan Rupert 907-301-1736 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 -------- Original message -------- From: Juanita Lovett <jlovett@hilcorp.com> Date: 9/9/24 12:26 PM (GMT-09:00) To: "AOGCC Permitting (CED sponsored)" <aogcc.permitting@alaska.gov> Cc: Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: 10-403 N Cook Inlet Unit A-16 PTD 208-098 - Application for Sundry Approval For processing. Thank you, Juanita L Lovett Sr. Operations/Regulatory Tech Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 | Anchorage | AK | 99503 (907) 777-8332 | jlovett@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 12/28/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NCI A-16 (PTD 208-098) Perf 12/03/2021 Please include current contact information if different from above. 37' (6HW Received By: 12/29/2021 By Abby Bell at 8:57 am, Dec 29, 2021 2SHUDWLRQV $EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 3XOO7XELQJ 2SHUDWLRQVVKXWGRZQ 3HUIRUPHG 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH $OWHU&DVLQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HSDLU:HOO 5HHQWHU6XVS:HOO 'HYHORSPHQW ([SORUDWRU\ 6WUDWLJUDSKLF 6HUYLFH $3,1XPEHU 3URSHUW\'HVLJQDWLRQ/HDVH1XPEHU :HOO1DPHDQG1XPEHU /RJV/LVWORJVDQGVXEPLWHOHFWURQLFGDWDSHU$$&)LHOG3RROV 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ϲ͕ϴϱϴ͛ ϯ͘ϮϱϬ ϰ͘ϰϵϬ ^ĞĂůŽƌĞƌĞĐĞƉƚĂĐůĞ ϴ͕ϱϰϯ͛ ϲ͕ϴϲϭ͛ ϯ͘ϰϯϬ ϱ͘ϴϬϬ ^ĐƌĞĞŶ͕ĂŬĞƌǁĞůĚϭϬŐĂ͘ Ϯϯ ϴ͕ϲϭϯ͛ ϲ͕ϵϯϮ͛ ϯ͘ϮϱϬ ϰ͘ϰϵϬ ^ĞĂůŽƌĞƌĞĐĞƉƚĂĐůĞ ϴ͕ϲϭϲ͛ ϲ͕ϵϯϰ͛ ϯ͘ϰϯϬ ϱ͘ϴϬϬ ^ĐƌĞĞŶ͕ĂŬĞƌǁĞůĚϭϬŐĂ͘ Ϯϰ ϴ͕ϳϵϲ͛ ϳ͕ϭϭϰ͛ ϯ͘ϮϲϬ ϱ͘ϬϬϬ ^ŶĂƉ>ĂƚĐŚϴϮͲϰϬ^ͲϮϮ Ϯϱ ϴ͕ϳϵϳ͛ ϳ͕ϭϭϱ͛ ϰ͘ϬϬϬ ϱ͘ϴϱϬ WĂĐŬĞƌ͕^ƵŵƉ͕&^ Ϯϲ ϴ͕ϴϬϭ͛ ϳ͕ϭϭϵ͛ ϰ͘ϴϵϬ ϱ͘ϱϭϬ DƵůĞ^ŚŽĞ͕ϱͲϭͬϮ͕͟Ϯϯη͕>ͲϴϬ Ϯϳ ϴ͕ϵϵϭ͛ ϳ͕ϯϬϴ͛ Ϭ͘ϬϬϬ WůƵŐ͕ĂŬĞƌ/W EŽƚĞ͗ϴͬϮϭͬϭϭ'ƌĂǀĞůWĂĐŬ;DƚŚƌƵhͿϮϳϯϬϰůďƐ͘ϮϬͬϰϬƐĂŶĚ͕ϲϱ͘ϵůďƐͬĨƚƉĞƌĨƐΛϭϬ͘ϭWD͕ϯϯйƌĞƚƵƌŶƐ hƉĚĂƚĞĚďǇ͗:>>ϭϮͬϮϱͬϮϭ ^,Dd/ dǇŽŶĞŬWůĂƚĨŽƌŵ tĞůů͗Ͳϭϲ >ĂƐƚŽŵƉůĞƚĞĚ͗ϬϱͬϭϳͬϮϬ Wd͗ϮϬϴͲϵϴ W/͗ ϱϬͲϴϴϯͲϮϬϬϭϮϳͲϬϬ WZ&KZd/KEd/> ŽŶĞ dŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ ŵƚ ƐƉĨ ĂƚĞ ŽŵŵĞŶƚƐ ^ƚĞƌůŝŶŐ/ϵ ϱ͕ϵϵϯ͛ ϲ͕ϬϬϭ͛ ϰ͕ϯϴϯ͛ ϰ͕ϯϵϬ͛ ϴ͛ ϱ ϭϮͬϯͬϮϭ KƉĞŶ ^ƚĞƌůŝŶŐ/ϭϭ ϲ͕Ϭϲϳ ϲ͕Ϭϴϯ͛ ϰ͕ϰϰϱ͛ ϰ͕ϰϱϴ͛ ϭϲ͛ ϱ ϭϮͬϯͬϮϭ KƉĞŶ ĞůƵŐĂ ϲ͕ϭϰϭ͛ ϲ͕ϭϱϳ͛ ϰ͕ϱϬϴ͛ ϰ͕ϱϮϮ͛ ϭϲ͛ ϱ ϬϮͬϬϴͬϮϭ KƉĞŶ ĞůƵŐĂ ϲ͕ϮϰϮ͛ ϲ͕Ϯϱϴ͛ ϰ͕ϱϵϵ͛ ϰ͕ϲϭϯ͛ ϭϲ͛ ϱ ϬϮͬϬϴͬϮϭ KƉĞŶ ĞůƵŐĂ ϲ͕ϯϭϱ͛ ϲ͕ϯϮϬ͛ ϰ͕ϲϲϲ͛ ϰ͕ϲϳϬ͛ ϱ͛ ϱ ϬϮͬϬϴͬϮϭ KƉĞŶ ĞůƵŐĂ ϲ͕ϯϲϭ͛ ϲ͕ϯϲϲ͛ ϰ͕ϳϬϵ͛ ϰ͕ϳϭϯ͛ ϱ͛ ϬϱͬϭϱͬϮϬ /ƐŽůĂƚĞĚ ĞůƵŐĂ ϲ͕ϯϲϳ͛ ϲ͕ϯϴϭ͛ ϰ͕ϳϭϰ͛ ϰ͕ϳϯϮ͛ ϭϰ ϱ ϬϴͬϭϰͬϮϬ KƉĞŶ ĞůƵŐĂ ϲ͕ϰϮϳ͛ ϲ͕ϰϯϰ͛ ϰ͕ϳϳϬ͛ ϰ͕ ϳϳϳ͛ ϳΖ ϱ ϬϴͬϭϰͬϮϬ KƉĞŶ ĞůƵŐĂ ϲ͕ϰϲϳ͛ ϲ͕ϰϳϱ͛ ϰ͕ϴϬϴ͛ ϰ͕ϴϭϲ͛ ϴ͛ ϱ ϬϴͬϭϰͬϮϬ KƉĞŶ ĞůƵŐĂ ϲ͕ϲϰϮ͛ ϲ͕ϲϱϱ͛ ϰ͕ϵϳϲ͛ ϰ͕ϵϴϴ͛ ϭϯ͛ ϱ ϬϴͬϭϰͬϮϬ KƉĞŶ ĞůƵŐĂ ϲ͕ϱϯϳ͛ ϲ͕ϱϰϮ͛ ϰ͕ϴϳϱ͛ ϰ͕ϴϴϬ͛ ϱ͛ ϰ ϭϮͬϯͬϮϭ KƉĞŶ ĞůƵŐĂ ϲ͕ϲϲϯ͛ ϲ͕ϲϳϭ͛ ϰ͕ϵϵϲ͛ ϱ͕ϬϬϰ͛ ϰ͛ ϰ ϭϭͬϮϬͬϮϭ KƉĞŶ ĞůƵŐĂ ϲ͕ϱϴϮ͛ ϲ͕ϱϴϲ͛ ϰ͕ϵϭϴ͛ ϰ͕ϵϮϮ͛ ϴ͛ ϰ ϭϭͬϮϬͬϮϭ KƉĞŶ ĞůƵŐĂ ϲ͕ϲϲϯ͛ ϲ͕ϲϳϭ͛ ϰ͕ϵϵϲ͛ ϱ͕ϬϬϰ͛ ϴ͛ ϬϱͬϭϱͬϮϬ /ƐŽůĂƚĞĚ ĞůƵŐĂ ϲ͕ϳϱϱ͛ ϲ͕ϳϲϵ͛ ϱ͕Ϭϴϱ͛ ϱ͕Ϭϵϴ͛ ϭϰ ϱ ϬϴͬϬϳͬϮϬ KƉĞŶ ĞůƵŐĂ& ϲ͕ϴϬϱ͛ ϲ͕ϴϭϯ͛ ϱ͕ϭϯϱ͛ ϱ͕ϭϰϮ͛ ϵ͛ ϱ ϬϳͬϬϭͬϮϬ KƉĞŶ ĞůƵŐĂ& ϲ͕ϴϰϲ͛ ϲ͕ϴϳϲ͛ ϱ͕ϭϳϯ͛ ϱ͕ϮϬϮ͛ ϯϬ͛ ϱ ϬϳͬϬϭͬϮϬ KƉĞŶ ĞůƵŐĂ' ϲ͕ϵϭϮ͛ ϲ͕ϵϰϬ͛ ϱ͕Ϯϯϴ͛ ϱ͕Ϯϲϱ͛ Ϯϴ͛ ϱ ϬϳͬϬϭͬϮϬ KƉĞŶ ĞůƵŐĂ, ϳ͕Ϭϯϴ͛ ϳ͕Ϭϲϲ͛ ϱ͕ϯϲϮ͛ ϱ͕ϯϴϵ͛ Ϯϴ͛ ϲ /ƐŽůĂƚĞ ĞůƵŐĂ, ϳ͕Ϭϰϲ͛ ϳ͕Ϭϲϲ͛ ϱ͕ϯϳϬ͛ ϱ͕ϯϴϵ͛ ϮϬ͛ ϲ /ƐŽůĂƚĞ ĞůƵŐĂ, ϳ͕ϭϮϱ͛ ϳ͕ϭϯϯ͛ ϱ͕ϰϰϴ͛ ϱ͕ϰϱϲ͛ ϴ͛ ϲ /ƐŽůĂƚĞ ĞůƵŐĂ: ϳ͕Ϯϴϵ͛ ϳ͕ϯϯϳ͛ ϱ͕ϲϱϭ͛ ϱ͕ϲϱϵ͛ ϰϴ͛ ϲ /ƐŽůĂƚĞ ĞůƵŐĂ: ϳ͕ϯϮϵ͛ ϳ͕ϯϯϳ͛ ϱ͕ϲϱϭ͛ ϱ͕ϲϱϵ͛ ϴ͛ ϲ /ƐŽůĂƚĞ ĞůƵŐĂ< ϳ͕ϯϲϰ͛ ϳ͕ϯϴϮ͛ ϱ͕ϲϴϲ͛ ϱ͕ϳϬϰ͛ ϭϴ͛ ϲ /ƐŽůĂƚĞ ĞůƵŐĂD ϳ͕ϱϬϬ͛ ϳ͕ϱϮϰ͛ ϱ͕ϴϮϭ͛ ϱ͕ϴϰϱ͛ Ϯϰ͛ ϭϰ ϮͬϭϬͬϬϵ,^ϰͲϱͬϴ͟^,>KtW>h' ĞůƵŐĂK ϳ͕ϲϳϳ͛ ϳ͕ϲϵϰ͛ ϱ͕ϵϵϴ͛ ϲ͕Ϭϭϱ͛ ϭϳ͛ ϭϰ ϮͬϭϬͬϬϵ,^ϰͲϱͬϴ͟^,>KtW>h' ĞůƵŐĂW ϳ͕ϳϵϳ͛ ϳ͕ϴϭϬ͛ ϲ͕ϭϭϳ͛ ϲ͕ϭϯϬ͛ ϭϯ͛ ϭϰ ϮͬϭϬͬϬϵ,^ϰͲϱͬϴ͟^,>KtW>h' ĞůƵŐĂY ϳ͕ϴϴϬ͛ ϳ͕ϴϴϱ͛ ϲ͕ϮϬϬ͛ ϲ͕ϮϬϱ͛ ϱ͛ ϭϰ ϮͬϭϬͬϬϵ,^ϰͲϱͬϴ͟^,>KtW>h' ĞůƵŐĂY ϳ͕ϵϭϮ͛ ϳ͕ϵϮϮ͛ ϲ͕ϮϯϮ͛ ϲ͕ϮϰϮ͛ ϭϬ͛ ϭϰ ϮͬϭϬͬϬϵ,^ϰͲϱͬϴ͟^,>KtW>h' ĞůƵŐĂY ϳ͕ϵϰϲ͛ ϳ͕ϵϳϴ͛ ϲ͕Ϯϲϲ͛ ϲ͕Ϯϵϴ͛ ϯϮ͛ ϭϰ ϮͬϭϬͬϬϵ,^ϰͲϱͬϴ͟^,>KtW>h' ĞůƵŐĂY ϳ͕ϵϱϴ͛ ϳ͕ϵϳϴ͛ ϲ͕Ϯϳϴ͛ ϲ͕Ϯϵϴ͛ ϮϬ͛ ϲ ϭͬϯϭͬϬϵ ϯͲϭͬϴ͟,ŝsŽů WŽǁĞƌ&ƌĂĐϯϭϬϲͲϮϬϭŐ͘ĐŚƌŐ>KtW>h' ĞůƵŐĂ^ ϴ͕Ϯϳϴ͛ ϴ͕Ϯϴϰ͛ ϲ͕ϱϵϳ͛ ϲ͕ϲϬϯ͛ ϲ͛ ϭϰ ϮͬϭϬͬϬϵ,^ϰͲϱͬϴ͟^,>KtW>h' ĞůƵŐĂd ϴ͕Ϯϵϭ͛ ϴ͕ϯϬϬ͛ ϲ͕ϲϭϬ͛ ϲ͕ϲϭϵ͛ ϵ͛ ϭϰ ϮͬϭϬͬϬϵ,^ϰͲϱͬϴ͟^,>KtW>h' ĞůƵŐĂd ϴ͕Ϯϵϭ͛ ϴ͕ϯϬϬ͛ ϲ͕ϲϭϬ͛ ϲ͕ϲϭϵ͛ ϵ͛ ϲ ϭͬϯϭͬϬϵϯͲϭͬϴ͟ ,ŝsŽůWŽǁĞƌ&ƌĂĐϯϭϬϲͲϮϬϭŐ͘ĐŚƌŐ >KtW>h' ĞůƵŐĂd ϴ͕ϰϭϰ͛ ϴ͕ϰϮϰ͛ ϲ͕ϳϯϯ͛ ϲ͕ϳϰϯ͛ ϭϬ͛ ϭϰ ϮͬϭϬͬϬϵ,^ϰͲϱͬϴ͟^,>KtW>h' ĞůƵŐĂd ϴ͕ϰϲϰ͛ ϴ͕ϰϵϬ͛ ϲ͕ϳϴϯ͛ ϲ͕ϴϬϵ͛ Ϯϲ͛ ϭϰ ϮͬϭϬͬϬϵ,^ϰͲϱͬϴ͟^,>KtW>h' ĞůƵŐĂh ϴ͕ϱϭϳ͛ ϴ͕ϱϮϯ͛ ϲ͕ϴϯϲ͛ ϲ͕ϴϰϭ͛ ϲ͛ ϭϰ ϮͬϭϬͬϬϵ,^ϰͲϱͬϴ͟^,>KtW>h' ĞůƵŐĂh ϴ͕ϱϲϰ͛ ϴ͕ϱϳϲ͛ ϲ͕ϴϴϮ͛ ϲ͕ϴϵϰ͛ ϭϮ͛ ϭϰ ϮͬϭϬͬϬϵ,^ϰͲϱͬϴ͟^,>KtW>h' ĞůƵŐĂh ϴ͕ϱϲϱ͛ ϴ͕ϱϳϭ͛ ϲ͕ϴϴϯ͛ ϲ͕ϴϴϵ͛ ϲ͛ ϲ ϭͬϮϵͬϬϵϯͲϭͬϴ͟,ŝsŽůWŽǁĞƌ&ƌĂĐϯϭϬϲͲϮϬϭŐ͘ĐŚƌŐ>KtW>h' ĞůƵŐĂh ϴ͕ϱϴϳ͛ ϴ͕ϱϵϯ͛ ϲ͕ϵϬϱ͛ ϲ͕ϵϭϭ͛ ϲ͛ ϭϰ ϮͬϭϬͬϬϵ,^ϰͲϱͬϴ͟^,>KtW>h' ĞůƵŐĂh ϴ͕ϳϬϵ͛ ϴ͕ϳϮϰ͛ ϳ͕ϬϮϳ͛ ϳ͕ϬϰϮ͛ ϭϱ͛ ϲ ϭͬϮϲͬϬϵϯͲϭͬϴ͟,ŝsŽůWŽǁĞƌ&ƌĂĐϯϭϬϲͲϮϬϭŐ͘ĐŚƌŐ>KtW>h' ĞůƵŐĂh ϴ͕ϳϬϵ͛ ϴ͕ϳϮϰ͛ ϳ͕ϬϮϳ͛ ϳ͕ϬϰϮ͛ ϭϱ͛ ϭϰ ϮͬϭϬͬϬϵ,^ϰͲϱͬϴ͟^,>KtW>h' ĞůƵŐĂh ϴ͕ϳϯϰ͛ ϴ͕ϳϰϭ͛ ϳ͕ϬϱϮ͛ ϳ͕Ϭϱϵ͛ ϳ͛ ϭϰ ϮͬϭϬͬϬϵ,^ϰͲϱͬϴ͟^, >Kt W>h' ĞůƵŐĂh ϴ͕ϳϰϲ͛ ϴ͕ϳϱϲ͛ ϳ͕Ϭϲϰ͛ ϳ͕Ϭϳϰ͛ ϭϬ͛ ϭϰ ϮͬϭϬͬϬϵ,^ϰͲϱͬϴ͟^,>KtW>h' ĞůƵŐĂϲ͕ϲϲϯ͛ϲ͕ϲϳϭ͛ϰ͕ϵϵϲ͛ϱ͕ϬϬϰ͛ϰ͛ϰ ϭϭͬϮϬͬϮϭ KƉĞŶ ĞůƵŐĂ ϲ͕ϱϯϳ͛ ϲ͕ϱϰϮ͛ ϰ͕ϴϳϱ͛ ϰ͕ϴϴϬ͛ ϱ͛ ϰ ϭϮͬϯͬϮϭ KƉĞŶ ^ƚĞƌůŝŶŐ/ϵ ϱ͕ϵϵϯ͛ ϲ͕ϬϬϭ͛ ϰ͕ϯϴϯ͛ ϰ͕ϯϵϬ͛ ϴ͛ ϱ ϭϮͬϯͬϮϭ KƉĞŶ ^ƚĞƌůŝŶŐ/ϭϭ ϲ͕Ϭϲϳ ϲ͕Ϭϴϯ͛ ϰ͕ϰϰϱ͛ ϰ͕ϰϱϴ͛ ϭϲ͛ ϱ ϭϮͬϯͬϮϭ KƉĞŶ ĞůƵŐĂϲ͕ϱϴϮ͛ϲ͕ϱϴϲ͛ϰ͕ϵϭϴ͛ϰ͕ϵϮϮ͛ϴ͛ϰ ϭϭͬϮϬͬϮϭ KƉĞŶ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ůŝŶĞ ϭϭͬϮϬͬϮϭ ϭϮͬϯͬϮϭ <>ĐƌĞǁĂƐƐĞŵďůĞƐĂŶĚĂƚƚĞŶĚƐŵŽƌŶŝŶŐƉƌŽĚƵĐƚŝŽŶŵĞĞƚŝŶŐ͕ŽďƚĂŝŶƐƉĞƌŵŝƚƐ͘ƐƐŝƐƚůŽĂĚŝŶŐĂŶĚƵŶůŽĂĚŝŶŐŽĨĞͲůŝŶĞƵŶŝƚ͕ ŐƵŶƐĂŶĚƚŚŝƌĚƉĂƌƚǇĞƋƵŝƉŵĞŶƚƚŽĂŶĚĨƌŽŵďŽĂƚ͘ZŝŐƵƉĞͲůŝŶĞĞƋƵŝƉŵĞŶƚ͘WƌĞƐƐƵƌĞƚĞƐƚůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁĂŶĚϮϱϬϬ ƉƐŝŚŝŐŚ͘ƌŵĂŶĚZ/,ǁŝƚŚϴΖϮ͘ϱΗ^ŚŽŐƵŶƐƉŝƌĂůƐƚƌŝƉŐƵŶ͘ŽƌƌĞůĂƚĞƚŽŽƉĞŶŚŽůĞůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌĐŽƌƌĞĐƚŝŽŶ͘KŶ ĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞĞůƵŐĂĨƌŽŵϲϲϲϯͲϲϲϳϭΖ͘^/dWƐƚĂďůĞĂƚϮϴϱƉƐŝ͘WKK,͘dŽŽůƐƚƌŝŶŐďƵŵƉĞĚƵƉĞĂƌůǇ͘ƚƚĞŵƉƚƚŽĐůŽƐĞ ƐǁĂďĂŶĚŽŶůǇŐĞƚϭϴŽĨϮϯ͘ϱƚƵƌŶƐ͘ůŽƐĞůŽǁĞƌŵĂƐƚĞƌĂŶĚďůĞĞĚĚŽǁŶƉƌĞƐƐƵƌĞ͘ƌĞĂŬŽĨĨĨƌŽŵƌŝƐĞƌĂŶĚůĂǇĚŽǁŶŐƵŶ͕Ăůů ƐŚŽƚƐĨŝƌĞĚ͘ĂďůĞǁĂƐƐƚƵĐŬŝŶĨůŽǁƚƵďĞƐĚƵĞƚŽĐĂďůĞĚĂŵĂŐĞϮϬΖĂďŽǀĞĐĂďůĞŚĞĂĚ͘ZĞͲŚĞĂĚ͘ƌŵĂŶĚZ/,ǁŝƚŚϰΖϮ͘ϱΗ ^ŚŽŐƵŶƐƉŝƌĂůƐƚƌŝƉŐƵŶ͘ŽƌƌĞůĂƚĞƚŽŽƉĞŶŚŽůĞůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌĐŽƌƌĞĐƚŝŽŶ͘ŽƌƌĞĐƚĚĞƉƚŚ;нϭΖͿĂŶĚƉĞƌĨŽƌĂƚĞ ĞůƵŐĂDŝĚĨƌŽŵϲϱϴϮͲϲϱϴϲΖ͘WƵůůƵƉĂŶĚĂĨƚĞƌϭϬΖƚŽŽůƐďĞĐĂŵĞŚƵŶŐƵƉ͕ƉƵůůŝŶŐϴϬϬηŽǀĞƌ͘DĂĚĞǁĞĂŬƉŽŝŶƚĐĂůĐƵůĂƚŝŽŶƐ ĂŶĚǁŽƌŬĞĚůŝŶĞƵƉƚŽϴϬйŽĨůŽǁĞƌůŝŵŝƚĂŶĚĐĂŵĞĨƌĞĞ͘dŽŽůƐĂĐƚĞĚƐƚŝĐŬǇĨŽƌĂďŽƵƚϭϬΖĂŶĚƚŚĞŶƐŵŽŽƚŚĞĚŽƵƚ͘WKK,ĂŶĚ ƵŶƐƚĂďĨƌŽŵƌŝƐĞƌ͘>ĂǇĚŽǁŶĂŶĚŝŶƐƉĞĐƚƚŽŽůƐ͕ĂůůƐŚŽƚƐĨŝƌĞĚ͘ZŝŐĚŽǁŶĞͲůŝŶĞĂŶĚƐĞĐƵƌĞǁĞůůƚŽƉƵƚďĂĐŬŽŶůŝŶĞ͘^ĞĐƵƌĞ ƌĞŵĂŝŶŝŶŐŐƵŶƐƚŽƌĞƚƵƌŶƚŽƐŚŽƌĞ͘ƌĞǁůĞĂǀĞƐĨĂĐŝůŝƚǇ͘ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ E/Ͳϭϲ ϱϬͲϴϴϯͲϮϬϭϮϳͲϬϬ ϮϬϴͲϬϵϴ ϭϭͬϮϬͬϮϭͲ^ĂƚƵƌĚĂǇ WĞƌĨŽƌĂƚĞĞůƵŐĂĨƌŽŵϲϲϲϯͲϲϲϳϭΖ ƉĞƌĨŽƌĂƚĞ ĞůƵŐĂDŝĚĨƌŽŵϲϱϴϮͲϲϱϴϲΖ͘W ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ůŝŶĞ ϭϭͬϮϬͬϮϭ ϭϮͬϯͬϮϭ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ E/Ͳϭϲ ϱϬͲϴϴϯͲϮϬϭϮϳͲϬϬ ϮϬϴͲϬϵϴ ϭϮͬϬϯͬϮϬϮϭͲ&ƌŝĚĂǇ W:^DĂŶĚWdt͘ZͬhŽŶͲϭϲ͘WƌĞƐƐƵƌĞƚĞƐƚůƵďƌŝĐĂƚŽƌǁŝƚŚDĞK,ǁĂƚĞƌďůĞŶĚƚŽϮϱϬƉƐŝͬϮ͕ϱϬϬƉƐŝͲdĞƐƚŐŽŽĚ ^ŚƵƚŝŶƉƌŽĚƵĐƚŝŽŶ;ǁĞůůǁĂƐĨůŽǁŝŶŐΕϮ͘ϲDD&Ϳ͘Z/,ǁͬ>͕'ĂŵŵĂ͕'ƵŶηϭͲϱĨƚŽĨϮ͘ϱΗƐŚŽŐƵŶƐƉŝƌĂůƐƚƌŝƉŐƵŶƐ;ϰƐƉĨͿ͘ >ƚŽƚŽƉƐŚŽƚϴ͘ϲΖ͘ WƵůůůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌĐŽƌƌĞůĂƚŝŽŶ͘KŶĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞĞůƵŐĂƐĂŶĚƐĨƌŽŵ;ϲ͕ϱϯϳΖͲϲ͕ϱϰϮΖͿǁŝƚŚǁĞůůƐŚƵƚŝŶ͘WKK,͘ >ŐƵŶƐͲůůƐŚŽƚƐĨŝƌĞĚ͘Dͬh'ƵŶηϮ͘ ϬŵŝŶͲϯϬϱƉƐŝ͘ ϱŵŝŶͲϯϬϲƉƐŝ͘ ϭϬŵŝŶͲϯϬϯƉƐŝ͘ ϭϱŵŝŶͲϯϬϮƉƐŝ͘ƌŵĂŶĚZ/,ǁͬ>͕'ĂŵŵĂ͕'ƵŶηϮͲϭϲĨƚϮͲϯͬϴΗϱƐƉĨƌĂǌŽƌŐƵŶƐϭϭ͘ϴ'͘>ƚŽƚŽƉƐŚŽƚϭϮ͘ϬΖ͘ ƌŝĞĨůǇĚĞƚĂŝŶĞĚŝŶƚŚĞǁĞůůŚĞĂĚ͘ƵŵƉĞĚϱŐĂůDĞK,ŝŶƚŚĞƌŝƐĞƌĂŶĚǁĂƐĂďůĞƚŽŐĞƚƚŚƌŽƵŐŚǁĞůůŚĞĂĚ͘ WƵůůůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌĐŽƌƌĞůĂƚŝŽŶ͘KŶĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞ^ƚĞƌůŝŶŐ/ϭϭƐĂŶĚƐĨƌŽŵ;ϲ͕ϬϲϳΖͲϲ͕ϬϴϯΖͿǁŝƚŚǁĞůůƐŚƵƚŝŶ͘ WKK,͘>ŐƵŶƐͲůůƐŚŽƚƐĨŝƌĞĚ͘Dͬh'ƵŶηϯ͘ ϬŵŝŶͲϯϬϵƉƐŝ͘ ϱŵŝŶͲϯϬϴƉƐŝ͘ ϭϬŵŝŶͲϯϬϴƉƐŝ͘ ϭϱŵŝŶͲϯϬϴƉƐŝ͘&ůŽǁͲϭϲĨŽƌϭŚƌƚŽĐŚĞĐŬĨŽƌǁĂƚĞƌƉƌŽĚƵĐƚŝŽŶ͘Ϭ͘ϱ>ǁĂƚĞƌƉƌŽĚƵĐĞĚ͘ŚŽŬĞǁĞůůďĂĐŬƚŽĨůŽǁŝŶŐ ΕϲϱϬD&͘WƌŽĐĞĞĚǁŝƚŚ'ƵŶƌƵŶηϯ͘ƌŵĂŶĚZ/,ǁͬ>͕'ĂŵŵĂ͕'ƵŶηϯͲϴĨƚϮͲϯͬϴΗϱƐƉĨƌĂǌŽƌŐƵŶƐϭϭ͘ϴ'͘>ƚŽƚŽƉ ƐŚŽƚϭϬ͘ϬΖ͘ WƵůůůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌĐŽƌƌĞůĂƚŝŽŶ͘KŶĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞ^ƚĞƌůŝŶŐ/ϵƐĂŶĚƐĨƌŽŵ;ϱ͕ϵϵϯΖͲϲ͕ϬϬϭΖͿǁŝƚŚǁĞůůĨůŽǁŝŶŐ ϲϱϬD&͘WKK,͘>ŐƵŶƐͲůůƐŚŽƚƐĨŝƌĞĚ͘ ϬŵŝŶͲϮϱϴƉƐŝͲϬ͘ϲϮϴDD&͘ ϱŵŝŶͲϮϲϮƉƐŝͲϬ͘ϲϱϱDD&͘ ϭϬŵŝŶͲϮϲϰƉƐŝͲϬ͘ϲϰϱDD&͘ ϭϱŵŝŶͲϮϲϱƉƐŝͲϬ͘ϲϴϲDD&͘ZŝŐĚŽǁŶͲůŝŶĞ͕ƐĞĐƵƌĞǁĞůůĂŶĚƚƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ WĞƌĨŽƌĂƚĞĞůƵŐĂƐĂŶĚƐĨƌŽŵ;ϲ͕ϱϯϳΖͲϲ͕ϱϰϮΖͿǁ WĞƌĨŽƌĂƚĞ^ƚĞƌůŝŶŐ/ϭϭƐĂŶĚƐĨƌŽŵ;ϲ͕ϬϲϳΖͲϲ͕ϬϴϯΖͿǁ WĞƌĨŽƌĂƚĞ^ƚĞƌůŝŶŐ/ϵƐĂŶĚƐĨƌŽŵ;ϱ͕ϵϵϯΖͲϲ͕ϬϬϭΖͿ From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] RE: Tyonek A-16 SCSSV (PTD# 208-098) Date:Tuesday, November 30, 2021 3:17:51 PM Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (OGC) Sent: Tuesday, November 30, 2021 3:17 PM To: Chad Helgeson <chelgeson@hilcorp.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: Tyonek A-16 SCSSV (PTD# 208-098) Thank you for the updated information this morning regarding NCIU A-16 in support of Hilcorp’s request for an extension of time to continue flowing with the SSSV removed. You indicated the perforating equipment is onboard the Tyonek Platform and expect the perforating crew to arrive by this weekend. AOGCC grants Hilcorp’s request for an extension through 12/6. Please note that no further time extensions will be granted for installing and performance testing the SSSV in A-16 unless the request is accompanied with a written contingency plan for killing the well, and confirmation that the equipment is rigged up and ready for use. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Monday, November 29, 2021 4:37 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL] RE: Tyonek A-16 SCSSV (PTD# 208-098) Jim, Our wellwork perforating schedule didn’t get better where we finished the work for A-16 before the 14-day window closes tomorrow to operate the well without a SSSV. The crew that can execute the perforating is currently work on perforating our new drill well in Beluga and they are trying to urgently get that done before we can’t barge equipment in/out of the west side for the winter (coil, N2 and cement equipment). The perforating on A-16 is currently planned for Friday this week. Can we get an extension to flow Tyonek A-16 until next Monday (12/6) without a SSSV, instead of installing one and then removing it, or shutting the well in during this cold snap? Thanks Chad From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Wednesday, November 24, 2021 4:45 PM To: Chad Helgeson <chelgeson@hilcorp.com> Subject: [EXTERNAL] RE: Tyonek A-16 SCSSV (PTD# 208-098) Contact me on Monday about the request for extension. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Wednesday, November 24, 2021 11:52 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Sandy Reynolds <sreynolds@hilcorp.com>; Brad Blossom <bblossom@hilcorp.com>; Scott Bumbaugh <sbumbaugh@hilcorp.com>; Ben Quesnel <bquesnel@hilcorp.com> Subject: Tyonek A-16 SCSSV (PTD# 208-098) Jim, We pulled the SSSV on Tyonek A-16 well on November 16th for the perf add work we have planned. We started perforating 2 of the 5 zones we wanted to shoot on 11/20 and we ran into some gun troubles and decided to get different guns built and sent to the platform. There is a chance these will not get to the platform for perforating the rest of the zones before next Tuesday (the 30th) 14- days after pulling the SSSV. I am asking if we can have an extension to flow this well without a SCSSSV more than the 14days, until the perforating is complete on the well, which we expect to be done sometime between December 5th-7th if everything goes on schedule with equipment, weather etc. Chad Helgeson ASC Operations Engineer Hilcorp Alaska L 907-777-8405 (O) 907-229-4824 (C) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 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): North Cook Inlet Field / Tertiary System Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 9,314'N/A Casing Collapse Structural Conductor Surface 3,090 psi Intermediate Production 5,410 psi Liner 10,540 psi 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 Contact Name: Contact Email:chelgeson @hilcorp.com Contact Phone: (907) 777-8405 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: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7,631' 6,957' 5,282' 584 psi 1,924' 3-1/2" 7,619'7" 7,029' 5,353' 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. 11/22/2021 4-1/2" & 3-1/2" Daniel E. Marlowe See schematic 6,141 - 6,940 4,536' 9,301' Perforation Depth MD (ft): 9,301' See schematic Tubing Grade:Tubing MD (ft): 4,508 - 5,265 Perforation Depth TVD (ft): 400' 4,536' 30" 9-5/8" 400'400' N Cook Inlet Unit A-16 12.6 / L-80 & 9.2 / L-80 TVD Burst 5,113' 7,240 psi 10,160 psi Tubing Size: MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 / ADL0037831 208-098 50-883-20127-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC CO 68A COMMISSION USE ONLY Authorized Name: 5,750 psi3,457' Other: Patch Perfs Authorized Signature: Operations Manager Chad Helgeson PRESENT WELL CONDITION SUMMARY Length Size 7,030, 7,424; 7,481; 8,991 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 8:35 am, Nov 12, 2021 321-583 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.11.12 08:11:31 -09'00' Dan Marlowe (1267) X 10-404 DLB 11/12/2021 BJM 11/15/21 DSR-11/12/21 SSSV to be replaced and tested within 5 days or return to production. dts 11/15/2021 11/15/21 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.11.15 13:52:33 -09'00' RBDMS HEW 11/17/2021 Well Work Prognosis Well Name:NCIU A-16 API Number: 50-883-20127-00-00 Current Status:Gas Well Leg:2 (SW Corner) Estimated Start Date:11/22/2021 Rig:E-Line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Donna Ambruz Permit to Drill Number:208-098 First Call Engineer:Chad Helgeson Office: 907-777-8405 Cell: 907-229-4824 Second Call Engineer:Katherine O’Connor Office: 907-777-8376 Cell: 214-684-7400 Current Bottom Hole Pressure:675 psi @ 5265’ TVD Maximum Expected BHP:1085 psi @ 5004’ TVD (New Perfs being added) Maximum Potential Surface Pressure:584 psi Based on 0.1 psi/ft gas gradient Max Inclination 54.55° @ 3,340’ MD Brief Well Summary: The A-16 well is producing from the Beluga lower B thru G sands. This well has had solid production performance since the RWO in July 2020, with majority of perf adds occurring in Mid-August 2020. Additional perfs were added in the Beluga A and B in February of 2021. Notes Regarding Wellbore Condition x Current Conditions: 2.5 mmscfd @ 57 psi & 6 bwpd (IA -2 psi, OA – 15 psi) Objective: The objective of this program is to add perforations that were derisked (water influx) from previous perf adds in Beluga D & E sands and Perforate some Sterling C9 and 11 sands. The Sterling Sand will be perforated in lengths that can easily be patched if they are wet. Any undesired water, or potential gas contribution will be determined with a pressure/temp/spinner log to be run soon after adding the proposed perforations for data gathering. Pre-Rig Procedure: 1. Slickline MIRU, PT lubricator (250L/1500H) 2. RIH and pull SSSV from nipple at 348ft. 3. RIH w 2.80 gauge ring. 4. Drift well with 3.5” patch drift (minimum of 2.75” bailer) 5. RDMO slickline E-line Procedure: 1. MIRU E-line, PT lubricator (250L/1500H). 2. Perforate the following Beluga and Sterling sands with the well flowing. Well Work Prognosis Gross Proposed Perforated Intervals Pool Sands Top (MD) Btm (MD) Total Top (TVD) Bottom (TVD) Tertiary Gas System Sterling CI 9 ±5,993’ ±6,001’±8’ ±4,383’ ±4,390’ Tertiary Gas System Sterling CI 11 ±6,067’ ±6,083’±16’ ±4,445’ ±4,458’ Tertiary Gas System Beluga D ±6,537’ ±6,542’5’ ±4,875’ ±4,880’ Tertiary Gas System Beluga D ±6,582’ ±6,586’4’ ±4,918’ ±4,922’ Tertiary Gas System Beluga E ±6,663’ ±6,671’8’ ±4,996’ ±5,004’ a. Send the correlation pass to the Reservoir Engineer (Chris Kanyer), and Geologist (Daniel Yancy) for confirmation. b. Verify PTs are open to SCADA before perforating. Record tubing pressures and well flow rate at 0, 5, 10 and 15 minutes after each perforating run. 3. RDMO E-line. 4. Turn over to operations. 5. Monitor production for up to 2 weeks to evaluate any significant water production. Contingency (If water production from new perfs in sterling sands impacts gas rate): 6. MIRU E-line, PT lubricator (250L/1500H). 7. MU & Run spinner survey to find zone making water. 8. SI Production. 9. PU permanent Owen Patch, RIH and set patch across zone making water. 10. RD E-Line 11. Turn well over to Production Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic SSSV to be replaced and tested within 5 days or return to production. bjm SSSV to be replaced and tested within 5 days or return to production. bjm _____________________________________________________________________________________ Updated By: JLL 02/24/21 SCHEMATIC Tyonek Platform Well: A-16 Last Completed: 05/17/20 PTD: 208-098 API: 50-883-20127-00 PBTD: 6,957’ TD: 9,314’ 20” RKB– 42.6’, RKB to MSL – 119.2’, RKB to Mudline 239.2’ 7” Beluga B 2 18 13 9-5/8” 1 20 24 23 3 11 12 17 21 15 19 16 22 25 26 27 14 3-1/2” liner cemented in place 4 6 5 8 7 9 Beluga F Beluga G Beluga H Beluga C Beluga E 10TOC 6,957’ Beluga A Beluga B R X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” Conductor Welded 19.100” 45’ 400’ 9-5/8” 40 L-80 BTCM 8.835” 48.6’ 4,536’ 3-1/2” 9.3 L-80 8rd 2.992 5,105’ 7,029’ 7” 26 L-80 BTCM 6.276” 44.8’ 9,301’ TUBING DETAIL 4-1/2” 12.60 L-80 IBTM 3.958” Surface 391’ 3-1/2” 9.2 L-80 IBT 2.992” 391’ 4,762’ 3-1/2” 9.2 L-80 8RD 2.992” 4,762’ 5,113’ GRAVEL PACK 4” 11.00 P-110 SLHT 3.430” 7,426’ 8,805’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 348’ 348’ 3.813 5.40 Nipple, Camco BP-6i Landing - Camco 3.813” WRDP, DB Lock 2 391’ 391’ 3.000 5.210 4-1/2” x 3-1/2” Crossover 3 1,839’ 1,761’ 2.867” 5.313” GLM#1 - SPM – 1 IPOC-1 16/64” 3,797’ 3,008’ 2.867” 5.313” GLM#2 - SPM – 1 IPOC-1 16/64” 4,662’ 3,534’ 2.867” 5.313” GLM#3 - SPM – 1 Orifice 20/64” 4 4,711’ 3,563’ 2.867” 5.313” Chemical Injection Mandrel 5 4,763’ 3,594’ 3.000” 6.000” Packer - Hydraulic Retrievable 6 4,809’ 3,621’ 2.813” 3.750” X-Nipple 7 5,103’ 3,796’ 2.992” 3.500” Dummy Seal Bore Assembly 8 5,105’ 3,797’ 4.176” 5.924” ZXP Liner Top Packer with 10’ extension and Liner Hanger 9 5,113’ 3,801’ 3.020” 5.000” Landing Collar and Float Assembly 10 7,030’ 5,354’ CIBP – TOC 6,957 11 7,399’ 5,721’ 3.450 4.000 Packer, Sump, Baker SC-2 12 7,424 5,745’ 3.250 4.530 Nipple, R - PR Plug set in R profile with 4’ Catcher on top 13 7,425’ 5,746’ 3.260 5.000 Snap Latch 14 7,426’ 5,747’ 3.260 3.980 Seal Unit 15 7,426’ 5,747’ 4.000 6.000 Packer, Baker SC-2 70B-40 7,430’ 5,752’ 3.260 Mule Shoe 16 7,434’ 5,755’ 4.000 5.560 Seal Bore 17 7,458’ 5,779’ 3.430 5.650 KOIV Isolation Sleeve 7,464’ 5,785’ 3.430 Sub, Shear Out Safety 18 7,481’ 5,802’ 0.000 Plug, Baker IBP 7,487’ 5,808’ 3.430 5.800 Screen, Bakerweld 10 ga. 19 7,715’ 6,037’ 3.250 5.000 Seal Bore receptacle 7,719’ 6,040’ 3.430 5.800 Screen, Bakerweld 10 ga. 20 8,007’ 6,327’ 3.250 5.000 Seal Bore receptacle 8,010’ 6,330’ 3.430 5.800 Screen, Bakerweld 10 ga. 21 8,318’ 6,637’ 3.250 5.000 Seal Bore receptacle 8,320’ 6,639’ 3.430 5.800 Screen, Bakerweld 10 ga. 22 8,540’ 6,858’ 3.250 4.490 Seal Bore receptacle 8,543’ 6,861’ 3.430 5.800 Screen, Bakerweld 10 ga. 23 8,613’ 6,932’ 3.250 4.490 Seal Bore receptacle 8,616’ 6,934’ 3.430 5.800 Screen, Bakerweld 10 ga. 24 8,796’ 7,114’ 3.260 5.000 Snap Latch 82-40 S-22B 25 8,797’ 7,115’ 4.000 5.850 Packer, Sump, FS 26 8,801’ 7,119’ 4.890 5.510 Mule Shoe, 5-1/2”, 23#, L-80 27 8,991’ 7,308’ 0.000 Plug, Baker CIBP Note: 8/21/11 Gravel Pack (M thru U) 27304 lbs. 20/40 sand, 65.9 lbs/ft perfs @ 10.1 BPM, 33% returns -00 DLB Updated by: JLL 02/24/21 SCHEMATIC Tyonek Platform Well: A-16 Last Completed: 05/17/20 PTD: 208-98 API: 50-883-200127-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf Date Comments Beluga A 6,141’ 6,157’ 4,508’ 4,522’ 16’ 5 02/08/21 Open Beluga B 6,242’ 6,258’ 4,599’ 4,613’ 16’ 5 02/08/21 Open Beluga B 6,315’ 6,320’ 4,666’ 4,670’ 5’ 5 02/08/21 Open Beluga B 6,361’ 6,366’ 4,709’ 4,713’ 5’ 05/15/20 Isolated Beluga B 6,367’ 6,381’ 4,714’ 4,732’ 14 5 08/14/20 Open Beluga B 6,427’ 6,434’ 4,770’ 4, 777’ 7' 5 08/14/20 Open Beluga C 6,467’ 6,475’ 4,808’ 4, 816’ 8’ 5 08/14/20 Open Beluga D 6,642’ 6,655’ 4,976’ 4,988’ 13’ 5 08/14/20 Open Beluga E 6,663’ 6,671’ 4,996’ 5,004’ 8’ 05/15/20 Isolated Beluga E 6,755’ 6,769’ 5,085’ 5,098’ 14 5 08/07/20 Open Beluga F 6,805’ 6,813’ 5,135’ 5,142’ 9’ 5 07/01/20 Open Beluga F 6,846’ 6,876’ 5,173’ 5,202’ 30’ 5 07/01/20 Open Beluga G 6,912’ 6,940’ 5,238’ 5,265’ 28’ 5 07/01/20 Open Beluga H 7,038’ 7,066’ 5,362’ 5,389’ 28’ 6 Isolate Beluga H 7,046’ 7,066’ 5,370’ 5,389’ 20’ 6 Isolate Beluga H 7,125’ 7,133’ 5,448’ 5,456’ 8’ 6 Isolate Beluga J 7,289’ 7,337’ 5,651’ 5,659’ 48’ 6 Isolate Beluga J 7,329’ 7,337’ 5,651’ 5,659’ 8’ 6 Isolate Beluga K 7,364’ 7,382’ 5,686’ 5,704’ 18’ 6 Isolate Beluga M 7,500’ 7,524’ 5,821’ 5,845’ 24’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga O 7,677’ 7,694’ 5,998’ 6,015’ 17’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga P 7,797’ 7,810’ 6,117’ 6,130’ 13’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,880’ 7,885’ 6,200’ 6,205’ 5’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,912’ 7,922’ 6,232’ 6,242’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,946’ 7,978’ 6,266’ 6,298’ 32’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,958’ 7,978’ 6,278’ 6,298’ 20’ 6 1/31/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga S 8,278’ 8,284’ 6,597’ 6,603’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,291’ 8,300’ 6,610’ 6,619’ 9’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,291’ 8,300’ 6,610’ 6,619’ 9’ 6 1/31/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga T 8,414’ 8,424’ 6,733’ 6,743’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,464’ 8,490’ 6,783’ 6,809’ 26’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,517’ 8,523’ 6,836’ 6,841’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,564’ 8,576’ 6,882’ 6,894’ 12’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,565’ 8,571’ 6,883’ 6,889’ 6’ 6 1/29/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga U 8,587’ 8,593’ 6,905’ 6,911’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,709’ 8,724’ 7,027’ 7,042’ 15’ 6 1/26/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga U 8,709’ 8,724’ 7,027’ 7,042’ 15’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,734’ 8,741’ 7,052’ 7,059’ 7’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,746’ 8,756’ 7,064’ 7,074’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,767’ 8,771’ 7,085’ 7,089’ 4’ 14 1/26/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG -00 DLB _____________________________________________________________________________________ Updated By: CAH 11/10/21 PROPOSED Tyonek Platform Well: A-16 Last Completed: 05/17/20 PTD: 208-098 API: 50-883-20127-00 PBTD: 6,957’ TD: 9,314’ 20” RKB– 42.6’, RKB to MSL – 119.2’, RKB to Mudline 239.2’ 7” 2 18 13 9-5/8” 1 20 24 23 3 11 12 17 21 15 19 16 22 25 26 27 14 3-1/2” liner cemented in place 4 6 5 8 7 9 Beluga F & G Beluga H Beluga D&E 10TOC 6,957’ Beluga A -C Sterling C9&11 R X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” Conductor Welded 19.100” 45’ 400’ 9-5/8” 40 L-80 BTCM 8.835” 48.6’ 4,536’ 3-1/2” 9.3 L-80 8rd 2.992 5,105’ 7,029’ 7” 26 L-80 BTCM 6.276” 44.8’ 9,301’ TUBING DETAIL 4-1/2” 12.60 L-80 IBTM 3.958” Surface 391’ 3-1/2” 9.2 L-80 IBT 2.992” 391’ 4,762’ 3-1/2” 9.2 L-80 8RD 2.992” 4,762’ 5,113’ GRAVEL PACK 4” 11.00 P-110 SLHT 3.430” 7,426’ 8,805’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 348’ 348’ 3.813 5.40 Nipple, Camco BP-6i Landing - Camco 3.813” WRDP, DB Lock 2 391’ 391’ 3.000 5.210 4-1/2” x 3-1/2” Crossover 3 1,839’ 1,761’ 2.867” 5.313” GLM#1 - SPM – 1 IPOC-1 16/64” 3,797’ 3,008’ 2.867” 5.313” GLM#2 - SPM – 1 IPOC-1 16/64” 4,662’ 3,534’ 2.867” 5.313” GLM#3 - SPM – 1 Orifice 20/64” 4 4,711’ 3,563’ 2.867” 5.313” Chemical Injection Mandrel 5 4,763’ 3,594’ 3.000” 6.000” Packer - Hydraulic Retrievable 6 4,809’ 3,621’ 2.813” 3.750” X-Nipple 7 5,103’ 3,796’ 2.992” 3.500” Dummy Seal Bore Assembly 8 5,105’ 3,797’ 4.176” 5.924” ZXP Liner Top Packer with 10’ extension and Liner Hanger 9 5,113’ 3,801’ 3.020” 5.000” Landing Collar and Float Assembly 10 7,030’ 5,354’ CIBP – TOC 6,957 11 7,399’ 5,721’ 3.450 4.000 Packer, Sump, Baker SC-2 12 7,424 5,745’ 3.250 4.530 Nipple, R - PR Plug set in R profile with 4’ Catcher on top 13 7,425’ 5,746’ 3.260 5.000 Snap Latch 14 7,426’ 5,747’ 3.260 3.980 Seal Unit 15 7,426’ 5,747’ 4.000 6.000 Packer, Baker SC-2 70B-40 7,430’ 5,752’ 3.260 Mule Shoe 16 7,434’ 5,755’ 4.000 5.560 Seal Bore 17 7,458’ 5,779’ 3.430 5.650 KOIV Isolation Sleeve 7,464’ 5,785’ 3.430 Sub, Shear Out Safety 18 7,481’ 5,802’ 0.000 Plug, Baker IBP 7,487’ 5,808’ 3.430 5.800 Screen, Bakerweld 10 ga. 19 7,715’ 6,037’ 3.250 5.000 Seal Bore receptacle 7,719’ 6,040’ 3.430 5.800 Screen, Bakerweld 10 ga. 20 8,007’ 6,327’ 3.250 5.000 Seal Bore receptacle 8,010’ 6,330’ 3.430 5.800 Screen, Bakerweld 10 ga. 21 8,318’ 6,637’ 3.250 5.000 Seal Bore receptacle 8,320’ 6,639’ 3.430 5.800 Screen, Bakerweld 10 ga. 22 8,540’ 6,858’ 3.250 4.490 Seal Bore receptacle 8,543’ 6,861’ 3.430 5.800 Screen, Bakerweld 10 ga. 23 8,613’ 6,932’ 3.250 4.490 Seal Bore receptacle 8,616’ 6,934’ 3.430 5.800 Screen, Bakerweld 10 ga. 24 8,796’ 7,114’ 3.260 5.000 Snap Latch 82-40 S-22B 25 8,797’ 7,115’ 4.000 5.850 Packer, Sump, FS 26 8,801’ 7,119’ 4.890 5.510 Mule Shoe, 5-1/2”, 23#, L-80 27 8,991’ 7,308’ 0.000 Plug, Baker CIBP Note: 8/21/11 Gravel Pack (M thru U) 27304 lbs. 20/40 sand, 65.9 lbs/ft perfs @ 10.1 BPM, 33% returns -00 DLB Updated by: CAH 11/10/21 PROPOSED Tyonek Platform Well: A-16 Last Completed: 05/17/20 PTD: 208-98 API: 50-883-200127-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf Date Comments Sterling CI 9 ±5,993’ ±6,001’ ±4,383’ ±4,390’ ±8’ 4 Proposed Sterling CI 11 ±6,067 ±6,083’ ±4,445’ ±4,458’ ±16’ 4 Proposed Beluga A 6,141’ 6,157’ 4,508’ 4,522’ 16’ 5 02/08/21 Open Beluga B 6,242’ 6,258’ 4,599’ 4,613’ 16’ 5 02/08/21 Open Beluga B 6,315’ 6,320’ 4,666’ 4,670’ 5’ 5 02/08/21 Open Beluga B 6,361’ 6,366’ 4,709’ 4,713’ 5’ 05/15/20 Isolated Beluga B 6,367’ 6,381’ 4,714’ 4,732’ 14 5 08/14/20 Open Beluga B 6,427’ 6,434’ 4,770’ 4, 777’ 7' 5 08/14/20 Open Beluga C 6,467’ 6,475’ 4,808’ 4, 816’ 8’ 5 08/14/20 Open Beluga D 6,642’ 6,655’ 4,976’ 4,988’ 13’ 5 08/14/20 Open Beluga D ±6,537’ ±6,542’ ±4,875’ ±4,880’ ±5’ 4-6 Proposed Beluga D ±6,663’ ±6,671’ ±4,996’ ±5,004’ ±4’ 4-6 Proposed Beluga D ±6,582’ ±6,586’ ±4,918’ ±4,922’ ±8’ 4-6 Proposed Beluga E 6,663’ 6,671’ 4,996’ 5,004’ 8’ 05/15/20 Isolated Beluga E 6,755’ 6,769’ 5,085’ 5,098’ 14 5 08/07/20 Open Beluga F 6,805’ 6,813’ 5,135’ 5,142’ 9’ 5 07/01/20 Open Beluga F 6,846’ 6,876’ 5,173’ 5,202’ 30’ 5 07/01/20 Open Beluga G 6,912’ 6,940’ 5,238’ 5,265’ 28’ 5 07/01/20 Open Beluga H 7,038’ 7,066’ 5,362’ 5,389’ 28’ 6 Isolate Beluga H 7,046’ 7,066’ 5,370’ 5,389’ 20’ 6 Isolate Beluga H 7,125’ 7,133’ 5,448’ 5,456’ 8’ 6 Isolate Beluga J 7,289’ 7,337’ 5,651’ 5,659’ 48’ 6 Isolate Beluga J 7,329’ 7,337’ 5,651’ 5,659’ 8’ 6 Isolate Beluga K 7,364’ 7,382’ 5,686’ 5,704’ 18’ 6 Isolate Beluga M 7,500’ 7,524’ 5,821’ 5,845’ 24’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga O 7,677’ 7,694’ 5,998’ 6,015’ 17’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga P 7,797’ 7,810’ 6,117’ 6,130’ 13’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,880’ 7,885’ 6,200’ 6,205’ 5’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,912’ 7,922’ 6,232’ 6,242’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,946’ 7,978’ 6,266’ 6,298’ 32’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,958’ 7,978’ 6,278’ 6,298’ 20’ 6 1/31/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga S 8,278’ 8,284’ 6,597’ 6,603’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,291’ 8,300’ 6,610’ 6,619’ 9’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,291’ 8,300’ 6,610’ 6,619’ 9’ 6 1/31/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga T 8,414’ 8,424’ 6,733’ 6,743’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,464’ 8,490’ 6,783’ 6,809’ 26’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,517’ 8,523’ 6,836’ 6,841’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,564’ 8,576’ 6,882’ 6,894’ 12’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,565’ 8,571’ 6,883’ 6,889’ 6’ 6 1/29/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga U 8,587’ 8,593’ 6,905’ 6,911’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,709’ 8,724’ 7,027’ 7,042’ 15’ 6 1/26/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga U 8,709’ 8,724’ 7,027’ 7,042’ 15’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,734’ 8,741’ 7,052’ 7,059’ 7’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,746’ 8,756’ 7,064’ 7,074’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG -00 DLB Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 04/07/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NCI A-16 (208-098) PERF & HOIST 02/08/2021 Please include current contact information if different from above. PTD: 2080980 E-Set: 34922 Received by the AOGCC 04/08/2021 04/08/2021 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 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 9,314 feet 7,030; 7,424; 7,481; 8,991 feet true vertical 7,631 feet N/A feet Effective Depth measured 6,957 feet See schematic feet true vertical 5,282 feet See schematic feet Perforation depth Measured depth 6,141 - 6,940 feet True Vertical depth 4,508 - 5,265 feet Tubing (size, grade, measured and true vertical depth)4-1/2" & 3-1/2" 12.60 & 9.2 / L-80 5,113 MD 3,802 TVD Packers and SSSV (type, measured and true vertical depth)See schematic 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: Authorized Title: Contact Email: Contact Phone: TVD measured true vertical Packer Other: measured Collapse 7" 3-1/2" 9,301 MD 400 4,536 7,029 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 5523 Casing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 208-098 50-883-20127-00-00 Plugs ADL0017589 / ADL0037831 N Cook Inlet Unit A-16 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-051 58 Authorized Signature with date: Authorized Name: 49 WINJ WAG 0 Gas-Mcf 137 N/A Oil-Bbl 2,373 Water-Bbl Intermediate N/A Junk 5. Permit to Drill Number: 2,862 North Cook Inlet Field / Tertiary System Gas PoolN/A measured 9,301 Size 69 Production Casing Structural Liner 1,924 Length 400 4,536 Conductor Surface 10,540psi 5,410psi 30" 9-5/8" 907 777-8376 7,240psi 400 3,457 7,619 5,353 Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure 3,090psi5,750psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 10,160psi Daniel E. Marlowe Operations Manager Burst Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:45 am, Feb 25, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.02.25 08:49:34 -09'00' Dan Marlowe (1267) SFD 2/26/2021DSR-2/25/21 RBDMS HEW 2/25/2021 BJM 4/6/2021 _____________________________________________________________________________________ Updated By: JLL 02/24/21 SCHEMATIC Tyonek Platform Well: A-16 Last Completed: 05/17/20 PTD: 208-098 API: 50-883-20127-00 PBTD: 6,957’ TD: 9,314’ 20” RKB– 42.6’, RKB to MSL – 119.2’, RKB to Mudline 239.2’ 7” Beluga B 2 18 13 9-5/8” 1 20 24 23 3 11 12 17 21 15 19 16 22 25 26 27 14 3-1/2” liner cemented in place 4 6 5 8 7 9 Beluga F Beluga G Beluga H Beluga C Beluga E 10TOC 6,957’ Beluga A Beluga B R X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” Conductor Welded 19.100” 45’ 400’ 9-5/8” 40 L-80 BTCM 8.835” 48.6’ 4,536’ 3-1/2” 9.3 L-80 8rd 2.992 5,105’ 7,029’ 7” 26 L-80 BTCM 6.276” 44.8’ 9,301’ TUBING DETAIL 4-1/2” 12.60 L-80 IBTM 3.958” Surface 391’ 3-1/2” 9.2 L-80 IBT 2.992” 391’ 4,762’ 3-1/2” 9.2 L-80 8RD 2.992” 4,762’ 5,113’ GRAVEL PACK 4” 11.00 P-110 SLHT 3.430” 7,426’ 8,805’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 348’ 348’ 3.813 5.40 Nipple, Camco BP-6i Landing - Camco 3.813” WRDP, DB Lock 2 391’ 391’ 3.000 5.210 4-1/2” x 3-1/2” Crossover 3 1,839’ 1,761’ 2.867” 5.313” GLM#1 - SPM – 1 IPOC-1 16/64” 3,797’ 3,008’ 2.867” 5.313” GLM#2 - SPM – 1 IPOC-1 16/64” 4,662’ 3,534’ 2.867” 5.313” GLM#3 - SPM – 1 Orifice 20/64” 4 4,711’ 3,563’ 2.867” 5.313” Chemical Injection Mandrel 5 4,763’ 3,594’ 3.000” 6.000” Packer - Hydraulic Retrievable 6 4,809’ 3,621’ 2.813” 3.750” X-Nipple 7 5,103’ 3,796’ 2.992” 3.500” Dummy Seal Bore Assembly 8 5,105’ 3,797’ 4.176” 5.924” ZXP Liner Top Packer with 10’ extension and Liner Hanger 9 5,113’ 3,801’ 3.020” 5.000” Landing Collar and Float Assembly 10 7,030’ 5,354’ CIBP – TOC 6,957 11 7,399’ 5,721’ 3.450 4.000 Packer, Sump, Baker SC-2 12 7,424 5,745’ 3.250 4.530 Nipple, R - PR Plug set in R profile with 4’ Catcher on top 13 7,425’ 5,746’ 3.260 5.000 Snap Latch 14 7,426’ 5,747’ 3.260 3.980 Seal Unit 15 7,426’ 5,747’ 4.000 6.000 Packer, Baker SC-2 70B-40 7,430’ 5,752’ 3.260 Mule Shoe 16 7,434’ 5,755’ 4.000 5.560 Seal Bore 17 7,458’ 5,779’ 3.430 5.650 KOIV Isolation Sleeve 7,464’ 5,785’ 3.430 Sub, Shear Out Safety 18 7,481’ 5,802’ 0.000 Plug, Baker IBP 7,487’ 5,808’ 3.430 5.800 Screen, Bakerweld 10 ga. 19 7,715’ 6,037’ 3.250 5.000 Seal Bore receptacle 7,719’ 6,040’ 3.430 5.800 Screen, Bakerweld 10 ga. 20 8,007’ 6,327’ 3.250 5.000 Seal Bore receptacle 8,010’ 6,330’ 3.430 5.800 Screen, Bakerweld 10 ga. 21 8,318’ 6,637’ 3.250 5.000 Seal Bore receptacle 8,320’ 6,639’ 3.430 5.800 Screen, Bakerweld 10 ga. 22 8,540’ 6,858’ 3.250 4.490 Seal Bore receptacle 8,543’ 6,861’ 3.430 5.800 Screen, Bakerweld 10 ga. 23 8,613’ 6,932’ 3.250 4.490 Seal Bore receptacle 8,616’ 6,934’ 3.430 5.800 Screen, Bakerweld 10 ga. 24 8,796’ 7,114’ 3.260 5.000 Snap Latch 82-40 S-22B 25 8,797’ 7,115’ 4.000 5.850 Packer, Sump, FS 26 8,801’ 7,119’ 4.890 5.510 Mule Shoe, 5-1/2”, 23#, L-80 27 8,991’ 7,308’ 0.000 Plug, Baker CIBP Note: 8/21/11 Gravel Pack (M thru U) 27304 lbs. 20/40 sand, 65.9 lbs/ft perfs @ 10.1 BPM, 33% returns Updated by: JLL 02/24/21 SCHEMATIC Tyonek Platform Well: A-16 Last Completed: 05/17/20 PTD: 208-98 API: 50-883-200127-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf Date Comments Beluga A 6,141’ 6,157’ 4,508’ 4,522’ 16’ 5 02/08/21 Open Beluga B 6,242’ 6,258’ 4,599’ 4,613’ 16’ 5 02/08/21 Open Beluga B 6,315’ 6,320’ 4,666’ 4,670’ 5’ 5 02/08/21 Open Beluga B 6,361’ 6,366’ 4,709’ 4,713’ 5’ 05/15/20 Isolated Beluga B 6,367’ 6,381’ 4,714’ 4,732’ 14 5 08/14/20 Open Beluga B 6,427’ 6,434’ 4,770’ 4, 777’ 7' 5 08/14/20 Open Beluga C 6,467’ 6,475’ 4,808’ 4, 816’ 8’ 5 08/14/20 Open Beluga D 6,642’ 6,655’ 4,976’ 4,988’ 13’ 5 08/14/20 Open Beluga E 6,663’ 6,671’ 4,996’ 5,004’ 8’ 05/15/20 Isolated Beluga E 6,755’ 6,769’ 5,085’ 5,098’ 14 5 08/07/20 Open Beluga F 6,805’ 6,813’ 5,135’ 5,142’ 9’ 5 07/01/20 Open Beluga F 6,846’ 6,876’ 5,173’ 5,202’ 30’ 5 07/01/20 Open Beluga G 6,912’ 6,940’ 5,238’ 5,265’ 28’ 5 07/01/20 Open Beluga H 7,038’ 7,066’ 5,362’ 5,389’ 28’ 6 Isolate Beluga H 7,046’ 7,066’ 5,370’ 5,389’ 20’ 6 Isolate Beluga H 7,125’ 7,133’ 5,448’ 5,456’ 8’ 6 Isolate Beluga J 7,289’ 7,337’ 5,651’ 5,659’ 48’ 6 Isolate Beluga J 7,329’ 7,337’ 5,651’ 5,659’ 8’ 6 Isolate Beluga K 7,364’ 7,382’ 5,686’ 5,704’ 18’ 6 Isolate Beluga M 7,500’ 7,524’ 5,821’ 5,845’ 24’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga O 7,677’ 7,694’ 5,998’ 6,015’ 17’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga P 7,797’ 7,810’ 6,117’ 6,130’ 13’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,880’ 7,885’ 6,200’ 6,205’ 5’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,912’ 7,922’ 6,232’ 6,242’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,946’ 7,978’ 6,266’ 6,298’ 32’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,958’ 7,978’ 6,278’ 6,298’ 20’ 6 1/31/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga S 8,278’ 8,284’ 6,597’ 6,603’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,291’ 8,300’ 6,610’ 6,619’ 9’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,291’ 8,300’ 6,610’ 6,619’ 9’ 6 1/31/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga T 8,414’ 8,424’ 6,733’ 6,743’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,464’ 8,490’ 6,783’ 6,809’ 26’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,517’ 8,523’ 6,836’ 6,841’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,564’ 8,576’ 6,882’ 6,894’ 12’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,565’ 8,571’ 6,883’ 6,889’ 6’ 6 1/29/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga U 8,587’ 8,593’ 6,905’ 6,911’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,709’ 8,724’ 7,027’ 7,042’ 15’ 6 1/26/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga U 8,709’ 8,724’ 7,027’ 7,042’ 15’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,734’ 8,741’ 7,052’ 7,059’ 7’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,746’ 8,756’ 7,064’ 7,074’ 10’ 14 2/10/09 HES 4-5/8” SH BELOWPLUG Beluga U 8,767’ 8,771’ 7,085’ 7,089’ 4’ 14 1/26/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG ()()()() p Beluga A 6,141’ 6,157’ 4,508’ 4,522’ 16’ 5 02/08/21 Open Beluga B 6,242’ 6,258’ 4,599’ 4,613’ 16’ 5 02/08/21 Open Beluga B 6,315’ 6,320’ 4,666’ 4,670’ 5’ 5 02/08/21 Open ()()()() p Rig Start Date End Date Eline 2/8/21 2/9/21 02/09/21 - Tuesday Morning meeting with ops, Get PTW signed PJSM. Make up logging tools and test them. Don't have communicaiton with inline spinner. Troubleshoot tools. The inline spinner had a short. Replace it with new one. All good. Stab on well, PT low/high 250/1500. Open well, swab 23. WHP 60, Flow rate 3.2mm. RIH, at 5050' start our logging pass. Log at 30 fpm down to 6900' (Tag),@ 6900' Start logging up @ 30fpm to 5050',@ 5050' Log down at 60 fpm, 3.1mm rate 60psi whp,@ 6900', log up at 60 fpm, 3.1mm, 60 psi whp.@ 5050' log down at 90 fpm, 3.2mm, 60 psi whp @ 6900' log up 90 fpm rates still the same. @ 5050' log down at 120 fpm, 3.2mm, 60 psi whp. @ 6900' do 12 min stop count. Log up @ 120 fpm, rates still the same. @ 5050' do 12 min stop count. POOH,Tagged up, swab shut, bleed down, pop off well. All tools intact and look good. Download Data and send off to town. RDMO. 02/08/21 - Monday Arrive on Tyonek. Get signed in, do orientation for new hand to the platform. Get PTW signed, PJSM. Go over job scope with all hands on Deck. MIRU. Gas alarm went off, meet up at muster area. All personnel accounted for. All clear to head back to work. Make up Gun #1, 5', 2.375", 5 spf low swell, 60* phase 11 gram razor gun. Head to well, stabbed on well. Line up to pt wlv and lubricator. low/high 250/1500. All good. Bleed down. Open well, swab 20, whp 50. flow rate 2.3mm. Start pinching well in as we run in hole. whp 50, flow rate 1mm. RIH, at 6500' pull log at 40 fpm up to 6100'. Down load and send off to town engineers for approval. Got approval to shoot 6315'-6320' (Geologist). Rih to 6500', PU getting on CCL depth 6300.4', CCL T/top shot 14.6', CCL T/bottom shot 19.6'. Shoot Beluga B Mid 6315'-6320'. FP 1mm, ITP 210, FTP 216. Log up 200'. POOH,Tagged up, swab shut, bleed down, pop off well. All shots fired. Dry gun. Make up Gun #2 16', 2.375", 5 spf low swell, 60* phase 11 gram razor gun. Stab on well, Open swab. RIH, at 6500', log up at 40 fpm to 6100', Download and send log to town Engineers to correlate logging pass. Got confirmation to shoot Beluga B upper 6242'-6258' zone. (Geologist). RIH to 6500'. PU getting on CCL depth @ 6230'. CCL T/top shot 12', CCL T/bottom shot 28'. Shoot Beluga B upper 6242'-6258'. IFP 216, FTP 226. Log up 200'. POOH. Tagged up, swab shut, bleed down, pop off well. All shots fired. Dry gun. Make up Gun #3, 16', 2.375", 5 spf low swell, 60* phase 11 gram razor gun. RIH, @ 6500' log up at 40 fpm to 6000'. Send log to town Engineers for correlation if needed. Approval to shoot Beluga A 6141'-6157' (Geologist). RIH to 6500', PU getting on CCL depth @ 6129'. CCL T/top shot 12', CCL T/bottom shot 28'. Shoot Beluga A 6141'-6157' sands. ITP 226, FTP 225. Log up 200'. POOH,Tagged up, swab shut, bleed down, pop off well. All shots fired. Dry gun. Rig down turn well over to production for the night. Job in progress. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-16 50-883-20127-00 208-098 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 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 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): North Cook Inlet Field / Tertiary System Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 9,314'N/A Casing Collapse Structural Conductor Surface 3,090 psi Intermediate Production 5,410 psi Liner 10,540 psi 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 Contact Name: Contact Email:Katherine.Oconnor@hilcorp.com Contact Phone: (907) 777-8376 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: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7,631' 6,957' 5,282' 976 psi 1,924' 3-1/2" 7,619'7" 7,029' 5,353' 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. 2/14/2021 4-1/2" & 3-1/2" Daniel E. Marlowe See schematic 6,367 - 6,940 4,536' 9,301' Perforation Depth MD (ft): 9,301' See schematic Tubing Grade: Tubing MD (ft): 4,714 - 5,265 Perforation Depth TVD (ft): 400' 4,536' 30" 9-5/8" 400' 400' N Cook Inlet Unit A-16 12.6 / L-80 & 9.2 / L-80 TVD Burst 5,113' 7,240 psi 10,160 psi Tubing Size: MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 / ADL0037831 208-098 50-883-20127-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC CO 68A COMMISSION USE ONLY Authorized Name: 5,750 psi3,457' Other: Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size 7,030, 7,424; 7,481; 8,991 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 11:50 am, Jan 26, 2021 321-051 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.01.26 08:37:34 -09'00' Dan Marlowe (1267) erforate X DSR-1/27/21DLB 01/26/2021 B GAS 10-404 GLS 2/1/21Comm on Required? Yes 2/1/21 dts 2/1/2021 JLC 2/1/2021 RBDMS HEW 2/2/2021 Well Work Prognosis Well Name:NCIU A-16 API Number: 50-883-20127-00-00 Current Status:Gas Well Leg:2 (SW Corner) Estimated Start Date:02/14/2021 Rig:E-Line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:208-098 First Call Engineer:Katherine O’Connor Office: 907-777-8376 Cell: 214-684-7400 Second Call Engineer:Karson Kozub Cell: 907-570-1801 Current Bottom Hole Pressure:675 psi @ 4987’ TVD Maximum Expected BHP:1085 psi @ 4720’ TVD Maximum Potential Surface Pressure:976 psi Based on 0.1 psi/ft gas gradient Brief Well Summary: The A-16 well is producing from the Beluga lower B thru G sands. This well has had solid production performance since the RWO in July 2020, with majority of perf adds occurring in Mid-August 2020. The objective of this program is to add perforations into the Beluga A and B sands. There will be a contingent 20ft patch to allow for isolation if the perfs are not ideal. Any undesired water, or potential gas contribution will be determined with a pressure/temp log to be run soon after adding the proposed perforations for data gathering. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. Perforate with well flowing per program. x Contingent: patch perfs to isolate 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic o add perforations into the Beluga A and B sands. (perf Beluga A & B per schematic attached) _____________________________________________________________________________________ Updated By: JLL 09/04/20 SCHEMATIC Tyonek Platform Well: A-16 Last Completed: 05/17/20 PTD: 208-098 API: 50-883-20127-00 PBTD: 6,957’ TD: 9,314’ 20” RKB– 42.6’, RKB to MSL – 119.2’, RKB to Mudline 239.2’ 7” Beluga B 2 18 13 9-5/8” 1 20 24 23 3 11 12 17 21 15 19 16 22 25 26 27 14 3-1/2” liner cemented in place 4 6 5 8 7 9 Beluga F Beluga G Beluga H Beluga C Beluga E 10TOC 6,957’ R X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” Conductor Welded 19.100” 45’ 400’ 9-5/8” 40 L-80 BTCM 8.835” 48.6’ 4,536’ 3-1/2” 9.3 L-80 8rd 2.992 5,105’ 7,029’ 7” 26 L-80 BTCM 6.276” 44.8’ 9,301’ TUBING DETAIL 4-1/2” 12.60 L-80 IBTM 3.958” Surface 391’ 3-1/2” 9.2 L-80 IBT 2.992” 391’ 4,762’ 3-1/2” 9.2 L-80 8RD 2.992” 4,762’ 5,113’ GRAVEL PACK 4” 11.00 P-110 SLHT 3.430” 7,426’ 8,805’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 348’ 348’ 3.813 5.40 Nipple, Camco BP-6i Landing - Camco 3.813” WRDP, DB Lock 2 391’ 391’ 3.000 5.210 4-1/2” x 3-1/2” Crossover 3 1,839’ 1,761’ 2.867” 5.313” GLM#1 - SPM – 1 IPOC-1 16/64” 3,797’ 3,008’ 2.867” 5.313” GLM#2 - SPM – 1 IPOC-1 16/64” 4,662’ 3,534’ 2.867” 5.313” GLM#3 - SPM – 1 Orifice 20/64” 4 4,711’ 3,563’ 2.867” 5.313” Chemical Injection Mandrel 5 4,763’ 3,594’ 3.000” 6.000” Packer - Hydraulic Retrievable 6 4,809’ 3,621’ 2.813” 3.750” X-Nipple 7 5,103’ 3,796’ 2.992” 3.500” Dummy Seal Bore Assembly 8 5,105’ 3,797’ 4.176” 5.924” ZXP Liner Top Packer with 10’ extension and Liner Hanger 9 5,113’ 3,801’ 3.020” 5.000” Landing Collar and Float Assembly 10 7,030’ 5,354’ CIBP – TOC 6,957 11 7,399’ 5,721’ 3.450 4.000 Packer, Sump, Baker SC-2 12 7,424 5,745’ 3.250 4.530 Nipple, R - PR Plug set in R profile with 4’ Catcher on top 13 7,425’ 5,746’ 3.260 5.000 Snap Latch 14 7,426’ 5,747’ 3.260 3.980 Seal Unit 15 7,426’ 5,747’ 4.000 6.000 Packer, Baker SC-2 70B-40 7,430’ 5,752’ 3.260 Mule Shoe 16 7,434’ 5,755’ 4.000 5.560 Seal Bore 17 7,458’ 5,779’ 3.430 5.650 KOIV Isolation Sleeve 7,464’ 5,785’ 3.430 Sub, Shear Out Safety 18 7,481’ 5,802’ 0.000 Plug, Baker IBP 7,487’ 5,808’ 3.430 5.800 Screen, Bakerweld 10 ga. 19 7,715’ 6,037’ 3.250 5.000 Seal Bore receptacle 7,719’ 6,040’ 3.430 5.800 Screen, Bakerweld 10 ga. 20 8,007’ 6,327’ 3.250 5.000 Seal Bore receptacle 8,010’ 6,330’ 3.430 5.800 Screen, Bakerweld 10 ga. 21 8,318’ 6,637’ 3.250 5.000 Seal Bore receptacle 8,320’ 6,639’ 3.430 5.800 Screen, Bakerweld 10 ga. 22 8,540’ 6,858’ 3.250 4.490 Seal Bore receptacle 8,543’ 6,861’ 3.430 5.800 Screen, Bakerweld 10 ga. 23 8,613’ 6,932’ 3.250 4.490 Seal Bore receptacle 8,616’ 6,934’ 3.430 5.800 Screen, Bakerweld 10 ga. 24 8,796’ 7,114’ 3.260 5.000 Snap Latch 82-40 S-22B 25 8,797’ 7,115’ 4.000 5.850 Packer, Sump, FS 26 8,801’ 7,119’ 4.890 5.510 Mule Shoe, 5-1/2”, 23#, L-80 27 8,991’ 7,308’ 0.000 Plug, Baker CIBP Note: 8/21/11 Gravel Pack (M thru U) 27304 lbs. 20/40 sand, 65.9 lbs/ft perfs @ 10.1 BPM, 33% returns Updated by: JLL 09/04/20 SCHEMATIC Tyonek Platform Well: A-16 Last Completed: 05/17/20 PTD: 208-98 API: 50-883-200127-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf Date Comments Beluga B 6,361’ 6,366’ 4,709’ 4,713’ 5’ 05/15/20 Isolated Beluga B 6,367’ 6,381’ 4,714’ 4,732’ 14 5 08/14/20 Open Beluga B 6,427’ 6,434’ 4,770’ 4, 777’ 7' 5 08/14/20 Open Beluga C 6,467’ 6,475’ 4,808’ 4, 816’ 8’ 5 08/14/20 Open Beluga D 6,642’ 6,655’ 4,976’ 4,988’ 13’ 5 08/14/20 Open Beluga E 6,663’ 6,671’ 4,996’ 5,004’ 8’ 05/15/20 Isolated Beluga E 6,755’ 6,769’ 5,085’ 5,098’ 14 5 08/07/20 Open Beluga F 6,805’ 6,813’ 5,135’ 5,142’ 9’ 5 07/01/20 Open Beluga F 6,846’ 6,876’ 5,173’ 5,202’ 30’ 5 07/01/20 Open Beluga G 6,912’ 6,940’ 5,238’ 5,265’ 28’ 5 07/01/20 Open Beluga H 7,038’ 7,066’ 5,362’ 5,389’ 28’ 6 Isolate Beluga H 7,046’ 7,066’ 5,370’ 5,389’ 20’ 6 Isolate Beluga H 7,125’ 7,133’ 5,448’ 5,456’ 8’ 6 Isolate Beluga J 7,289’ 7,337’ 5,651’ 5,659’ 48’ 6 Isolate Beluga J 7,329’ 7,337’ 5,651’ 5,659’ 8’ 6 Isolate Beluga K 7,364’ 7,382’ 5,686’ 5,704’ 18’ 6 Isolate Beluga M 7,500’ 7,524’ 5,821’ 5,845’ 24’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga O 7,677’ 7,694’ 5,998’ 6,015’ 17’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga P 7,797’ 7,810’ 6,117’ 6,130’ 13’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,880’ 7,885’ 6,200’ 6,205’ 5’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,912’ 7,922’ 6,232’ 6,242’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,946’ 7,978’ 6,266’ 6,298’ 32’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,958’ 7,978’ 6,278’ 6,298’ 20’ 6 1/31/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga S 8,278’ 8,284’ 6,597’ 6,603’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,291’ 8,300’ 6,610’ 6,619’ 9’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,291’ 8,300’ 6,610’ 6,619’ 9’ 6 1/31/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga T 8,414’ 8,424’ 6,733’ 6,743’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,464’ 8,490’ 6,783’ 6,809’ 26’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,517’ 8,523’ 6,836’ 6,841’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,564’ 8,576’ 6,882’ 6,894’ 12’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,565’ 8,571’ 6,883’ 6,889’ 6’ 6 1/29/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga U 8,587’ 8,593’ 6,905’ 6,911’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,709’ 8,724’ 7,027’ 7,042’ 15’ 6 1/26/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga U 8,709’ 8,724’ 7,027’ 7,042’ 15’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,734’ 8,741’ 7,052’ 7,059’ 7’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,746’ 8,756’ 7,064’ 7,074’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,767’ 8,771’ 7,085’ 7,089’ 4’ 14 1/26/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG _____________________________________________________________________________________ Updated By: JLL 01/21/2021 PROPOSED Tyonek Platform Well: A-16 Last Completed: 05/17/20 PTD: 208-098 API: 50-883-20127-00 PBTD: 6,957’ TD: 9,314’ 20” RKB– 42.6’, RKB to MSL – 119.2’, RKB to Mudline 239.2’ 7” Beluga B 2 18 13 9-5/8” 1 20 24 23 3 11 12 17 21 15 19 16 22 25 26 27 14 3-1/2” liner cemented in place 4 6 5 8 7 9 Beluga F Beluga G Beluga H Beluga C Beluga E 10TOC 6,957’ Beluga A Beluga B R X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” Conductor Welded 19.100” 45’ 400’ 9-5/8” 40 L-80 BTCM 8.835” 48.6’ 4,536’ 3-1/2” 9.3 L-80 8rd 2.992 5,105’ 7,029’ 7” 26 L-80 BTCM 6.276” 44.8’ 9,301’ TUBING DETAIL 4-1/2” 12.60 L-80 IBTM 3.958” Surface 391’ 3-1/2” 9.2 L-80 IBT 2.992” 391’ 4,762’ 3-1/2” 9.2 L-80 8RD 2.992” 4,762’ 5,113’ GRAVEL PACK 4” 11.00 P-110 SLHT 3.430” 7,426’ 8,805’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 348’ 348’ 3.813 5.40 Nipple, Camco BP-6i Landing - Camco 3.813” WRDP, DB Lock 2 391’ 391’ 3.000 5.210 4-1/2” x 3-1/2” Crossover 3 1,839’ 1,761’ 2.867” 5.313” GLM#1 - SPM – 1 IPOC-1 16/64” 3,797’ 3,008’ 2.867” 5.313” GLM#2 - SPM – 1 IPOC-1 16/64” 4,662’ 3,534’ 2.867” 5.313” GLM#3 - SPM – 1 Orifice 20/64” 4 4,711’ 3,563’ 2.867” 5.313” Chemical Injection Mandrel 5 4,763’ 3,594’ 3.000” 6.000” Packer - Hydraulic Retrievable 6 4,809’ 3,621’ 2.813” 3.750” X-Nipple 7 5,103’ 3,796’ 2.992” 3.500” Dummy Seal Bore Assembly 8 5,105’ 3,797’ 4.176” 5.924” ZXP Liner Top Packer with 10’ extension and Liner Hanger 9 5,113’ 3,801’ 3.020” 5.000” Landing Collar and Float Assembly 10 7,030’ 5,354’ CIBP – TOC 6,957 11 7,399’ 5,721’ 3.450 4.000 Packer, Sump, Baker SC-2 12 7,424 5,745’ 3.250 4.530 Nipple, R - PR Plug set in R profile with 4’ Catcher on top 13 7,425’ 5,746’ 3.260 5.000 Snap Latch 14 7,426’ 5,747’ 3.260 3.980 Seal Unit 15 7,426’ 5,747’ 4.000 6.000 Packer, Baker SC-2 70B-40 7,430’ 5,752’ 3.260 Mule Shoe 16 7,434’ 5,755’ 4.000 5.560 Seal Bore 17 7,458’ 5,779’ 3.430 5.650 KOIV Isolation Sleeve 7,464’ 5,785’ 3.430 Sub, Shear Out Safety 18 7,481’ 5,802’ 0.000 Plug, Baker IBP 7,487’ 5,808’ 3.430 5.800 Screen, Bakerweld 10 ga. 19 7,715’ 6,037’ 3.250 5.000 Seal Bore receptacle 7,719’ 6,040’ 3.430 5.800 Screen, Bakerweld 10 ga. 20 8,007’ 6,327’ 3.250 5.000 Seal Bore receptacle 8,010’ 6,330’ 3.430 5.800 Screen, Bakerweld 10 ga. 21 8,318’ 6,637’ 3.250 5.000 Seal Bore receptacle 8,320’ 6,639’ 3.430 5.800 Screen, Bakerweld 10 ga. 22 8,540’ 6,858’ 3.250 4.490 Seal Bore receptacle 8,543’ 6,861’ 3.430 5.800 Screen, Bakerweld 10 ga. 23 8,613’ 6,932’ 3.250 4.490 Seal Bore receptacle 8,616’ 6,934’ 3.430 5.800 Screen, Bakerweld 10 ga. 24 8,796’ 7,114’ 3.260 5.000 Snap Latch 82-40 S-22B 25 8,797’ 7,115’ 4.000 5.850 Packer, Sump, FS 26 8,801’ 7,119’ 4.890 5.510 Mule Shoe, 5-1/2”, 23#, L-80 27 8,991’ 7,308’ 0.000 Plug, Baker CIBP Note: 8/21/11 Gravel Pack (M thru U) 27304 lbs. 20/40 sand, 65.9 lbs/ft perfs @ 10.1 BPM, 33% returns OV Updated by: JLL 01/21/2021 PROPOSED Tyonek Platform Well: A-16 Last Completed: 05/17/20 PTD: 208-98 API: 50-883-200127-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf Date Comments Beluga A ±6,141’ ±6,157’ ±4,508’ ±4,522’ ±16’ Future Proposed Beluga B ±6,242’ ±6,258’ ±4,599’ ±4,613’ ±16’ Future Proposed Beluga B ±6,315’ ±6,320’ ±4,666’ ±4,670’ ±5’ Future Proposed Beluga B 6,361’ 6,366’ 4,709’ 4,713’ 5’ 05/15/20 Isolated Beluga B 6,367’ 6,381’ 4,714’ 4,732’ 14 5 08/14/20 Open Beluga B 6,427’ 6,434’ 4,770’ 4, 777’ 7' 5 08/14/20 Open Beluga C 6,467’ 6,475’ 4,808’ 4, 816’ 8’ 5 08/14/20 Open Beluga D 6,642’ 6,655’ 4,976’ 4,988’ 13’ 5 08/14/20 Open Beluga E 6,663’ 6,671’ 4,996’ 5,004’ 8’ 05/15/20 Isolated Beluga E 6,755’ 6,769’ 5,085’ 5,098’ 14 5 08/07/20 Open Beluga F 6,805’ 6,813’ 5,135’ 5,142’ 9’ 5 07/01/20 Open Beluga F 6,846’ 6,876’ 5,173’ 5,202’ 30’ 5 07/01/20 Open Beluga G 6,912’ 6,940’ 5,238’ 5,265’ 28’ 5 07/01/20 Open Beluga H 7,038’ 7,066’ 5,362’ 5,389’ 28’ 6 Isolate Beluga H 7,046’ 7,066’ 5,370’ 5,389’ 20’ 6 Isolate Beluga H 7,125’ 7,133’ 5,448’ 5,456’ 8’ 6 Isolate Beluga J 7,289’ 7,337’ 5,651’ 5,659’ 48’ 6 Isolate Beluga J 7,329’ 7,337’ 5,651’ 5,659’ 8’ 6 Isolate Beluga K 7,364’ 7,382’ 5,686’ 5,704’ 18’ 6 Isolate Beluga M 7,500’ 7,524’ 5,821’ 5,845’ 24’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga O 7,677’ 7,694’ 5,998’ 6,015’ 17’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga P 7,797’ 7,810’ 6,117’ 6,130’ 13’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,880’ 7,885’ 6,200’ 6,205’ 5’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,912’ 7,922’ 6,232’ 6,242’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,946’ 7,978’ 6,266’ 6,298’ 32’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,958’ 7,978’ 6,278’ 6,298’ 20’ 6 1/31/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga S 8,278’ 8,284’ 6,597’ 6,603’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,291’ 8,300’ 6,610’ 6,619’ 9’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,291’ 8,300’ 6,610’ 6,619’ 9’ 6 1/31/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga T 8,414’ 8,424’ 6,733’ 6,743’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,464’ 8,490’ 6,783’ 6,809’ 26’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,517’ 8,523’ 6,836’ 6,841’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,564’ 8,576’ 6,882’ 6,894’ 12’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,565’ 8,571’ 6,883’ 6,889’ 6’ 6 1/29/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga U 8,587’ 8,593’ 6,905’ 6,911’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,709’ 8,724’ 7,027’ 7,042’ 15’ 6 1/26/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga U 8,709’ 8,724’ 7,027’ 7,042’ 15’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,734’ 8,741’ 7,052’ 7,059’ 7’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,746’ 8,756’ 7,064’ 7,074’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,767’ 8,771’ 7,085’ 7,089’ 4’ 14 1/26/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga A ±6,141’±6,157’±4,508’±4,522’±16’Future Proposed Beluga B ±6,242’±6,258’±4,599’±4,613’±16’Future Proposed Beluga B ±6,315’±6,320’±4,666’±4,670’±5’Future Proposed 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 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 9,314 feet 7,030; 7,424; 7,481; 8,991 feet true vertical 7,631 feet N/A feet Effective Depth measured 6,957 feet See schematic feet true vertical 5,282 feet See schematic feet Perforation depth Measured depth 6,367 - 6,940 feet True Vertical depth 4,714 - 5,265 feet Tubing (size, grade, measured and true vertical depth)4-1/2" & 3-1/2" 12.60 & 9.2 / L-80 5,113 MD 3,802 TVD Packers and SSSV (type, measured and true vertical depth)See schematic 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: Authorized Title: Contact Email: Contact Phone: Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 10,160psi Daniel E. Marlowe Operations Manager Burst kkozub@hilcorp.com Tubing Pressure 3,090psi5,750psi 907 777-8376 7,240psi 400 3,457 7,619 5,353 Karson Kozub 400 4,536 Conductor Surface 10,540psi 5,410psi 30" 9-5/8" 9,301 Size 161 Production Casing Structural Liner 5,105 Length Intermediate N/A Junk 5. Permit to Drill Number: 2,618 North Cook Inlet Field / Tertiary System Gas PoolN/A measured 0 Gas-Mcf 0 N/A Oil-Bbl 0 Water-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-153 & 320-214 58 Authorized Signature with date: Authorized Name: 11 WINJ WAG STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 208-098 50-883-20127-00-00 Plugs ADL0017589 / ADL0037831 N Cook Inlet Unit A-16 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 200 Casing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 7" 3-1/2" 9,301 MD 400 4,536 7,029 TVD measured true vertical Packer Other: G/L Completion/ N2 Operations measured Collapse Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:29 am, Sep 14, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.09.13 09:07:42 -08'00' Dan Marlowe (1267) gls 9/22/20 RBDMS HEW 9/14/2020 DSR-9/15/2020 _____________________________________________________________________________________ Updated By: JLL 09/04/20 SCHEMATIC Tyonek Platform Well: A-16 Last Completed: 05/17/20 PTD: 208-098 API: 50-883-20127-00 PBTD: 6,957’ TD: 9,314’ 20” RKB– 42.6’, RKB to MSL – 119.2’, RKB to Mudline 239.2’ 7” Beluga B 2 18 13 9-5/8” 1 20 24 23 3 11 12 17 21 15 19 16 22 25 26 27 14 3-1/2” liner cemented in place 4 6 5 8 7 9 Beluga F Beluga G Beluga H Beluga C Beluga E 10TOC 6,957’ R X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” Conductor Welded 19.100” 45’ 400’ 9-5/8” 40 L-80 BTCM 8.835” 48.6’ 4,536’ 3-1/2” 9.3 L-80 8rd 2.992 5,105’ 7,029’ 7” 26 L-80 BTCM 6.276” 44.8’ 9,301’ TUBING DETAIL 4-1/2” 12.60 L-80 IBTM 3.958” Surface 391’ 3-1/2” 9.2 L-80 IBT 2.992” 391’ 4,762’ 3-1/2” 9.2 L-80 8RD 2.992” 4,762’ 5,113’ GRAVEL PACK 4” 11.00 P-110 SLHT 3.430” 7,426’ 8,805’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 348’ 348’ 3.813 5.40 Nipple, Camco BP-6i Landing - Camco 3.813” WRDP, DB Lock 2 391’ 391’ 3.000 5.210 4-1/2” x 3-1/2” Crossover 3 1,839’ 1,761’ 2.867” 5.313” GLM#1 - SPM – 1 IPOC-1 16/64” 3,797’ 3,008’ 2.867” 5.313” GLM#2 - SPM – 1 IPOC-1 16/64” 4,662’ 3,534’ 2.867” 5.313” GLM#3 - SPM – 1 Orifice 20/64” 4 4,711’ 3,563’ 2.867” 5.313” Chemical Injection Mandrel 5 4,763’ 3,594’ 3.000” 6.000” Packer - Hydraulic Retrievable 6 4,809’ 3,621’ 2.813” 3.750” X-Nipple 7 5,103’ 3,796’ 2.992” 3.500” Dummy Seal Bore Assembly 8 5,105’ 3,797’ 4.176” 5.924” ZXP Liner Top Packer with 10’ extension and Liner Hanger 9 5,113’ 3,801’ 3.020” 5.000” Landing Collar and Float Assembly 10 7,030’ 5,354’ CIBP – TOC 6,957 11 7,399’ 5,721’ 3.450 4.000 Packer, Sump, Baker SC-2 12 7,424 5,745’ 3.250 4.530 Nipple, R - PR Plug set in R profile with 4’ Catcher on top 13 7,425’ 5,746’ 3.260 5.000 Snap Latch 14 7,426’ 5,747’ 3.260 3.980 Seal Unit 15 7,426’ 5,747’ 4.000 6.000 Packer, Baker SC-2 70B-40 7,430’ 5,752’ 3.260 Mule Shoe 16 7,434’ 5,755’ 4.000 5.560 Seal Bore 17 7,458’ 5,779’ 3.430 5.650 KOIV Isolation Sleeve 7,464’ 5,785’ 3.430 Sub, Shear Out Safety 18 7,481’ 5,802’ 0.000 Plug, Baker IBP 7,487’ 5,808’ 3.430 5.800 Screen, Bakerweld 10 ga. 19 7,715’ 6,037’ 3.250 5.000 Seal Bore receptacle 7,719’ 6,040’ 3.430 5.800 Screen, Bakerweld 10 ga. 20 8,007’ 6,327’ 3.250 5.000 Seal Bore receptacle 8,010’ 6,330’ 3.430 5.800 Screen, Bakerweld 10 ga. 21 8,318’ 6,637’ 3.250 5.000 Seal Bore receptacle 8,320’ 6,639’ 3.430 5.800 Screen, Bakerweld 10 ga. 22 8,540’ 6,858’ 3.250 4.490 Seal Bore receptacle 8,543’ 6,861’ 3.430 5.800 Screen, Bakerweld 10 ga. 23 8,613’ 6,932’ 3.250 4.490 Seal Bore receptacle 8,616’ 6,934’ 3.430 5.800 Screen, Bakerweld 10 ga. 24 8,796’ 7,114’ 3.260 5.000 Snap Latch 82-40 S-22B 25 8,797’ 7,115’ 4.000 5.850 Packer, Sump, FS 26 8,801’ 7,119’ 4.890 5.510 Mule Shoe, 5-1/2”, 23#, L-80 27 8,991’ 7,308’ 0.000 Plug, Baker CIBP Note: 8/21/11 Gravel Pack (M thru U) 27304 lbs. 20/40 sand, 65.9 lbs/ft perfs @ 10.1 BPM, 33% returns 3-1/2” liner cemented in place sssv CIBP @7030ft Updated by: JLL 09/04/20 SCHEMATIC Tyonek Platform Well: A-16 Last Completed: 05/17/20 PTD: 208-98 API: 50-883-200127-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf Date Comments Beluga B 6,361’ 6,366’ 4,709’ 4,713’ 5’ 05/15/20 Isolated Beluga B 6,367’ 6,381’ 4,714’ 4,732’ 14 5 08/14/20 Open Beluga B 6,427’ 6,434’ 4,770’ 4, 777’ 7' 5 08/14/20 Open Beluga C 6,467’ 6,475’ 4,808’ 4, 816’ 8’ 5 08/14/20 Open Beluga D 6,642’ 6,655’ 4,976’ 4,988’ 13’ 5 08/14/20 Open Beluga E 6,663’ 6,671’ 4,996’ 5,004’ 8’ 05/15/20 Isolated Beluga E 6,755’ 6,769’ 5,085’ 5,098’ 14 5 08/07/20 Open Beluga F 6,805’ 6,813’ 5,135’ 5,142’ 9’ 5 07/01/20 Open Beluga F 6,846’ 6,876’ 5,173’ 5,202’ 30’ 5 07/01/20 Open Beluga G 6,912’ 6,940’ 5,238’ 5,265’ 28’ 5 07/01/20 Open Beluga H 7,038’ 7,066’ 5,362’ 5,389’ 28’ 6 Isolate Beluga H 7,046’ 7,066’ 5,370’ 5,389’ 20’ 6 Isolate Beluga H 7,125’ 7,133’ 5,448’ 5,456’ 8’ 6 Isolate Beluga J 7,289’ 7,337’ 5,651’ 5,659’ 48’ 6 Isolate Beluga J 7,329’ 7,337’ 5,651’ 5,659’ 8’ 6 Isolate Beluga K 7,364’ 7,382’ 5,686’ 5,704’ 18’ 6 Isolate Beluga M 7,500’ 7,524’ 5,821’ 5,845’ 24’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga O 7,677’ 7,694’ 5,998’ 6,015’ 17’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga P 7,797’ 7,810’ 6,117’ 6,130’ 13’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,880’ 7,885’ 6,200’ 6,205’ 5’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,912’ 7,922’ 6,232’ 6,242’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,946’ 7,978’ 6,266’ 6,298’ 32’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,958’ 7,978’ 6,278’ 6,298’ 20’ 6 1/31/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga S 8,278’ 8,284’ 6,597’ 6,603’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,291’ 8,300’ 6,610’ 6,619’ 9’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,291’ 8,300’ 6,610’ 6,619’ 9’ 6 1/31/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga T 8,414’ 8,424’ 6,733’ 6,743’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,464’ 8,490’ 6,783’ 6,809’ 26’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,517’ 8,523’ 6,836’ 6,841’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,564’ 8,576’ 6,882’ 6,894’ 12’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,565’ 8,571’ 6,883’ 6,889’ 6’ 6 1/29/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga U 8,587’ 8,593’ 6,905’ 6,911’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,709’ 8,724’ 7,027’ 7,042’ 15’ 6 1/26/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga U 8,709’ 8,724’ 7,027’ 7,042’ 15’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,734’ 8,741’ 7,052’ 7,059’ 7’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,746’ 8,756’ 7,064’ 7,074’ 10’ 14 2/10/09 HES 4-5/8” SH BELOWPLUG Beluga U 8,767’ 8,771’ 7,085’ 7,089’ 4’ 14 1/26/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga B 6,367’ 6,381’ 4,714’ 4,732’ 14 5 08/14/20 Open Beluga B 6,427’ 6,434’ 4,770’ 4, 777’ 7' 5 08/14/20 Open Beluga C 6,467’ 6,475’ 4,808’ 4, 816’ 8’ 5 08/14/20 Open Beluga D 6,642’ 6,655’ 4,976’ 4,988’ 13’ 5 08/14/20 Open B l B 6 367’ 6 381’ 4 714’ 4 732’ 14 5 08/14/20 O g,,,, //p Beluga E 6,755’ 6,769’ 5,085’ 5,098’ 14 5 08/07/20 Open Beluga F 6,805’ 6,813’ 5,135’ 5,142’ 9’ 5 07/01/20 Open Beluga F 6,846’ 6,876’ 5,173’ 5,202’ 30’ 5 07/01/20 Open Beluga G 6,912’ 6,940’ 5,238’ 5,265’ 28’ 5 07/01/20 Open B l E 6 755’ 6 769’ 5 085’ 5 098’ 14 5 08/07/20 O Beluga G 6,912 6,940 5,238 5,265 28 5 07/01/20 Open Rig Start Date End Date HAK 404 CTU / EL / SL 4/27/20 8/14/20 Set in mud pump. Set accumulator. Pin mast to carrier. String out guy lines. Organize decks. Rebuild mud pump. Installed new valves and seats. Plumb in auxiallary air to carrier manifold. Continue organizing decks. Assist welder with stair modifications. Installed stairs to doghouse. Hook up Koomey lines to doghouse. Run electrical lines for Koomey house. Finish changing out valves and seats on mud pump. Continue installing stairs/landings. Organize drill deck in preparation for boat. Test run mud pump. Offload work boat: mix pit, BOP's, mud product and miscellaneous rig equipment. Assist crane crew with offloading work boat. Spot equipment as directed. Rig up mix pit and stage mud product. Prepare to fill pits with DW. String out choke and kill hoses. Begin filling pits with DW. String out accumulator hoses. Mobilized AAO crews to platform & orientated same. Offload boat & spotted 404 tool conex’s, pits, base beams, & misc. eq baskets. Organize & inventory tool conex's, make order list for supplies. Verify, continue with housekeeping and organization. Continue with housekeeping and organization. Offload work boat. Set pipe rack on skid beam and secure. Set carrier in place on skid beams. Install A-leg and chain off. Install catwalk around carrier. Install turnbuckles to skid beams under carrier. Set draw works and bolt down same. 04/28/2020 - Tuesday 04/27/2020 - Monday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-16 50-883-20127-00 208-098 04/29/2020 - Wednesday Function test mix pump good, r/u agitator & run good. Mix/fill rig pit w/3% KCL brine. Mix 27 bbl Calcium Carbonate Pill. Prep BOPE for N/U. Finish R/U lines t/circulate well. PJSM with rig crew & production for circulating well. PT surface lines t/1000 psi good, annulus on vac & 25 psi on tubing. Pump 25 bbls CC pill & chase w/65 bbls 3% KCL. Blow down surface lines while monitoring well, 39 PSI on Annulus, dropped t/9 psi, tubing on vac. R/D circulating lines, set BPV. N/D tree, assist production r/d & i solate lines. Prepare and inspect tubing hanger threads (4.909 MCA). Install blanking sub. Install DSA and rise r. N/U mud cross with manual valves and HCR's. N/U double gate and install rams. N/U annular preventer and hawes head. R/U accumulator hoses and begin torqueing all bolts. Set choke house in place. Rig Start Date End Date HAK 404 CTU / EL / SL 4/27/20 8/14/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-16 50-883-20127-00 208-098 Install 3 1/2" tj, test replacement Annular 250/2500 good. R/D test eq. B/D test joints, M/U landing joint, test 4 1/2" IBT safety valve 250/2500 good for e-line work, Pull BPV, Fluid had dropped approx. 2/3 down stack. Install landing joint. R/U Pollard e-line. Pick up lubricator and test at 500 psi. RIH with 3.625 chemical cutter to 3750' (unable to pass). R/U to circulate down tubing and taking returns through choke manifold. Pump down tubing to assist wireline at 2 BPM/180 psi. Correlate cutter on depth at 6257' and make cut. POOH with e-line. R/D circulating lines, e-line and back out lock down screws. Pull hanger off seat at 95K. Work string up to 50 K over string weight (140 K total) with 44" stretch several times. Circulate at 2 BPM to assist with no success. R/U Pollard e-line. RIH with 2.5 RCT and correlate on depth at 6255'. Make cut at 0300 hours with good indication. POOH and rig down e-line. R/U circulating lines. Work string up to 50 K over string weight (140 K total) with 44" stretch several times. No joy. Circulate at 2 BPM to assist with no success. Park string at 130 K. Circulate at 2 BPM/150 psi. Mobilize additional cutters. 04/30/2020 - Thursday Cont. Tq. BOPE flange bolts & install choke line. Prep mast for raising. R/u tugger lines string out guy lines, stand mast, install drill line to DW, move Driller house into position. Cont. arrange decks. Quadco working on install of PVT system. M/U kill line. Install accumulator lines, cont. prep derrick to raise, scope up derrick, raise floor into position, move driller & pin. Install stairs to same. R/u drill er controls, total safety working on install of gas system. Hook up Koomey lines to BOP's. Center rig over well. Se cure BOP stack. R/U handling equipment: tubing tongs, elevators, HPU for tongs and set beaver slide. Make up 4 1/2" test joint. Function test BOPE. Prepare for shell test. R/U choke control panel. R/U revers lines, sensors, etc. Land 4 1/2" test joint. R/U FIW lines. R/U test pump and chart recorder. Fluid pack BOP and test system. Shell test at 250 L/2500 H (annular, dart valve, kill valve and CMV's 1 and 2. Good test. Install wind walls on rig floor. Build 30 bbl pill. Clean and organize. 05/01/2020 - Friday Continue with general housekeeping. Remove door from Koomey house. Perform walkabout with platform electrician and mechanic and discussed issues with manrider, drawworks and brake systems that need attention. Test BOPE on 4 1/2" at 250 L/2500 H. All tests good. AOGCC inspector (Austin McLeod) witnessed test. Repair hydraulic leaks on tubing tongs. Change out test joint to 3 1/2". Attempt to test annular on 3 1/2" to no avail. Pulled accumulator hoses and pumped through system to purge any possible trapped air. Reattempt to test and running annular pressure up to 2200 psi. No joy. PJSM. Lay down test joint. Nipple down Hawes head and annular preventer. Perform housekeeping and rig maintenance while mobil izing back up annular preventer. Clean mix pit. Annulus is static. Boat arrived. Offload same. Nipple up annular preventer and Hawes head. Hook up accumulator hoses and lower rig floor. Torque all bolts. Pick up 3 1/2" te st joint, fill stack and function test. 05/02/2020 - Saturday Test BOPE on 4 1/2" at 250 L/2500 H. All tests good. AOGCC inspector (Austin McLeod) w . RIH with 3.625 chemical cutter to 3750' (unable to pass). R/U to circulate down tubing and taking returns through choke manifold. Pump down tubing to assist wireline at 2 BPM/180 psi. Correlate cutter on depth at 6257' and make cut. Rig Start Date End Date HAK 404 CTU / EL / SL 4/27/20 8/14/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-16 50-883-20127-00 208-098 05/05/2020 - Tuesday POOH with e-line. Latch onto landing joint and pull hanger to rig floor (hanger off seat @ 54k). Finish rigging down e-line. Rig up power tongs, break down and lay down hanger and landing joint. POOH laying down 4.5", 12.6#,L-80, IBTM completion string. L/D 1 ea. 3',6' ad 10' pup, 14 jt. 4.5" tbg., SSSV, 24 jt. 4.5" tbg (total of 38 jt. tbg. L/D). Recovered 19 band clamps. PUW at start 54k, ending PUW 40k. Continue POOH laying down 4.5" completion string. L/D 16 jt. 4/5" tbg., GLM #1 w/ pups, 48 jt. 4.5" tbg., GLM #2 with pups, 37 jt. 4.5 tbg, #3 GLM. (total of 139 jt. tbg. L/D). Crane in use to rig up e-line on A-08. Had muster drill f or fire alarm and shut well in. Finish laying down 4 1/2" tubing. Stub was belled out to 5". Photos in o-drive well file. Clear rig floor. Work boat. Prepare to pick up BHA #1. C/O handling equipment. Make up BHA #1 (rotary shoe). Stage and strap PH-6 work string. Attempt to make up work string with Hawkjaw. Hawkjaw not functioning prope rly (would not spin pipe even after adjustment, lift cylinder not working, etc.). R/D Hawkjaw and R/U Gill tongs. RIH with BHA #1 picking up 3 1/2" PH- 6 work string to +-1800'. 05/03/2020 - Sunday Continue circulating at 2 BPM/150 psi. Work pipe form 90 K to 140 K periodically with no effect. Wait on tubing cutter from beach. Service rig. R/D circulating equipment. R/U e-line. RIH with 2.5 RCT. Correlate on depth and make cut at 6255.5'. POOH with e-line. R/U circulating lines. Attempt to pull tubing free. Stage up to 63 K over pull. Pump at 4 BPM/300 psi while working string without success. R/D circulating lines. R/U e-line. RIH with 2.5 RCT. Correlate on depth and make cut at 6244'. POOH with e-line. R/D same. R/U circulating lines. Attempt to pull tubing free. Stage up to 63 K over pull. Pump at 3 BPM/200 psi while working string without success. Consult with engineer. Mobilize slick line crew. Perform hazard hunt and continue with housekeeping. R/D circulating line s. R/U slick line. RIH with 1" dummy valve and set in GLM at 6137'. POOH and R/D slick line. R/U to circulate. Circulate bottoms up at 4 BPM/475 psi through choke manifold. Saw no change (solids) at bottoms up. Work string +-8 times with 50K over pull with no success. Circulate at 2 BPM/200 psi while working pipe with the same result. Consult with engineer. Mobilize free point tools. Pump tracer sweep to determine circulating depth. 05/04/2020 - Monday Pump tracer sweep around at 4 BPM/400 psi. Sweep came back on time. Housekeeping and rig maintenance while waiting on free point tools and personnel. R/U slick line. RIH with kick-over tool and LIB to 5266' GLM. POOH (impression shows valve in place). Change tools to MOP. RIH wi th MOP while circulating at 3.8 BPM/300 psi. Reciprocate MOP from 4350' to 6200'. No anomalies observed. POO H with slick line. R/D slick line, R/U e-line. IH with free point tool. Search for free point from 5290' to 4926'. Power failure to e-line unit. POOH and recalibrate free point tools. RIH with free point tool to 4400'. Free point anchors failed to engage. POOH and troubleshoot. Change out anchors. RIH with tools and perform free point at various depths. Determined to be 100% stuck at 5266' and 100% free at 4430'. POOH for tubing cutter. Pick up 3.5" jet cutter and RIH with same. Correlate on depth. Make cut at 5258'. POOH. 5266' and 100% free at 4430'. Cut tubing 3 times and will not pull OOH> and make cut at 6244'. Make cut at 5258'. k line, R/U e-line. IH with free point tool. Search f cut 5258 ft. Stub was belled out to 5". Rig Start Date End Date HAK 404 CTU / EL / SL 4/27/20 8/14/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-16 50-883-20127-00 208-098 RIH with BHA #2 to 5240'. P/U Power Swivel and 10' pup jt. R/U static lines for power swivel. Rotate over fish f/ 5241' to 5244'. Verify overshot grapple engaged. (PUW 58k, SOW 34K, ROT 44K) Jar up on fish with 120k (60k over) working up to 160k (100k over) where fish came free. Picked up 14k string wt. R/D power swivel and L/D pup. POOH W/ BHA #2 and fish to top of BHA. Change out handling equi pment. Stand back BHA. POOH laying down fish. Recovered 1001.31' including 2 GLMs, 28 jts 4 1/2" tbg and pack er. New TOF at +-6773'. Break and lay down over shot. Pick up BHA #3 spear assembly. Service rig. RIH with BHA #3. Began having set-downs at 3290' (stop ring hanging up on casing collars). Continue RIH slowly and working through issue as necessary. 5205' at report time. 05/08/2020 - Friday RIH picking up 3.5" PH-6 singles, tag TOF @ 6725'. Set down 15k on fish. P/U and observe ~9-10k over string wt.,POOH F/6725'. Change out handling equipment and stand back BHA. No Fish. Service Rig. Inspect derrick, install new anchor wedge in manrider winch. Rig up Pollard slick line unit. RIH with 5.0 LIB. Tagged at 6713' and results were inconclusive. R/D slick line. Make up 3 1/2" test joint. Set test plug. R/U test equipment. Fill stack and fluid pack BOPE. Shell test at 2500 psi. Test BOPE at 250 L/2500 H on 3 1/2". AOGCC (Jim Regg waived witness on 5- 7-20 at 1430 hrs). Change out test joints for 4 1/2". Test variable rams on 4 1/2" and perform accumulator draw down test. Pull test plug (28 K to unseat). Pick up swivel and test valve. Break and lay down 4 1/2" test joint and testing equipment. 05/06/2020 - Wednesday RIH with BHA #1 picking up 3.5" PH-6 work string. Tag top of fi sh at top of jt. #164 (5241' SLM) w/ Yellow Jacket rep. on rig floor to verify. Lay down jt. # 165. PUW= 56k, SOW= 30k, calc. displacement= 24 bbl. actual displacement = 24 bbl. Remove power tongs from rig floor, stage stripper head busing and prep static lines for power swivel while waiting on boat to arrive with unit. Continue prepping for powe r swivel operations while waiting to off load swivel from boat. Spot power swivel unit on ODS of rigs front s preader beam. Fire up power unit. P/U and set swivel on floor with crane. P/U swivel with blocks. String out control lines and control box to rig floor and secure same. R/U Gill power tongs. M/U Kelly cock and X/O on bottom of swivel. Dress TOF at 5241'. Circulate at 1 BPM/20 psi. 80 RPM. Rotate over TOF with minimal weight Work over 2 f eet until clean. Break out and set power swivel back. POOH with BHA #1. Change out handling equipment. Change out BHA. P/U BHA #2 (overshot assembly). RIH with BHA #2 to +-5100'. 05/07/2020- Thursday 6 singles, tag TOF @ 6725'. Recovered 1001.31' including 2 GLMs, 28 jts 4 1/2" tbg a top of stub at 6725ft recover 1000ft fish Rig Start Date End Date HAK 404 CTU / EL / SL 4/27/20 8/14/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-16 50-883-20127-00 208-098 05/10/2020 - Sunday Finish P/U BHA #5 clean out assembly and RIH to 6448'. PUW=80k, SOW=34k. C/O tong dies and POOH laying down 4 jt to 6326'. Service Rig : grease drawworks and blocks. Conti nue RIH with BHA #5 to 6631' PUW=76k, SOW=34k. Calc disp= 29.8 bbl, Act. disp=28.4 bbl. P/U last stand in derrick. Install Halstrip head and tighten lock down screws. RIH to 6688'. P/U Power swivel. Attempt to start HPU motor. Trouble shoot starter issue and determine starter is bad. Perform housekeeping and maintenance tasks while waiting on starter from town. Replace starter on HPU motor. Make connection and wash down to 6725'. Having issues keeping HPU running. Change fuel filters. No change. Production mechanic troubleshoot problem with no result. Mobilize mechanic. Wash down to 6750'. Circulate at 4 BPM/300 psi while waiting on mechanic. HPU began working after mechanic "wiggled' wiring in panel. Make connection. Mud pump began hammering. Troubleshoot and removed piece of rubber from #3 discharge valve. Attempt to wash and ream after connection. HPU issues still not solved. Continue circulating at 4 BPM/400 psi and attempt to wash down without success (6756'). P/U 82 K, S/O 40 K. Continue troubleshooting HPU issues. 05/09/2020 - Saturday Rig down test equipment and blow down lines. Clear rig floor, change out handling equipment and put tools and equipment at bottom of beaver slide in baskets. Stage BHA #4 components on rig floor. Make up BHA #4 per Yellow Jacket tool hand. Change out handling equipment and change out dies in power tongs. RIH with BHA #4 to 3256' PUW= 38k SOW= 24k. Lubricate rig (drawworks, blocks and power tongs). Continue RIH with BHA #4 (lay down top joint on stand #59 due to slip marks on tube) to 6729'. P/U 80 K, S/O 34 K Calculated 16.7 bbls/ Actual 15.5 bbls. Tag fish at 6729'. P/U 20 K over pull. R/U power sw ivel. Replace relief valve on swivel. Attempt to pump. Packed off at 500 psi. Bleed off. P/U 50 K over and fish came f ree as jars bled down. P/U and observe 6 K drag. Slack off to neutral. Establish circulation at 3 BPM/330 psi. Wash down and taking weight at 6729'. Observe pressure increase and attempt to wash fill. Unable to progress further. P/U to 6720'. P/U to 86 K while pumping. CBU at various rates and adjust to what the shaker can handle. Had substantial amount of gas at bottoms up. R/D power swivel. Observe well for 10 minutes. (static). POOH with BHA #4. Calculated: 27.2 bbls/Actual: 31.1 bbls,Work BHA. Stand back collars. Full recovery of fish (31.69'). Make up BHA #5 clean out assembly. Rig Start Date End Date HAK 404 CTU / EL / SL 4/27/20 8/14/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-16 50-883-20127-00 208-098 Wash & ream f/ 6845' t/6875', Pump @ 3.5bpmw/ 290 psi, rot @ 60 rpm, tq..= 5200 ft/lb. Line up and reverse circulate 2500 stk. @ 4 bpm w/ 470 psi. Wash and ream f/ 6875' to 6935' Pump @ 3.6 bpm w/ 310 psi, rot @ 60 rpm, tq..= 2500-2800 ft/lb. PUW=88k, SOW= 40k, ROT Wt.= 56k. Hard spot @ 6910' took 10k WOB to get through. Once through picked up above and didn't see anything going back down through it. Line up and reverse circulate 4500 stks @ 4 bpm w/ 395 psi. Wash and ream f/ 6935' to 6998' Pump @ 3.6 bpm w/ 310 psi, rot @ 60 rpm, tq..= 2500- 2800 ft/lb. PUW=88k, SOW= 40k, ROT Wt.= 56. Coming out of sli ps on connection @ 6965' power swivel stalled. Had to pull 140k to free pipe and re-establish free rotation. Line up and reverse circulate 4700 stks @ 4.1 bpm w/ 416 psi. Wash and ream f/ 6998' to 7003' where we encountered hard spot. Wash and ream f/ 7003' to 7030' pump 3.8 bpm / 379 psi, rot @ 60 rpm, tq. = 2500 ft./lb. PUW=80k, SOW= 40k, ROT Wt.= 62k. Break off power swivel and hang off. Pull bushing from Halstrip head. POOH standing back 3 1/2" PH-6 work string. Work BHA, stand back collars, clean magnet & boot baskets, captured some SS bands, & several pieces of junk metal, face of mill balding. Discussed findings with town, decide to run another mill, re-assemble BHA & work on rig projects while waiting on new Mill. M/U BHA #6-6" Reverse junk mill, 2- boot basket, Double pin, scraper, bit sub, string magnet, 1-4 3/4 DC, Hyd, drilling jar, 3-4 3/4 DC, XO = 184.04,TIH w/c/o assy t/3080'. 05/11/2020 - Monday Work pipe f/ 6756' to 6749' every 10 min. while circulating 1.5 BPM/30 psi. PUW 84k, SOW 40k. Clean and organize rig w/ continuing to address HPU issues. Prepping back up HPU in Farm Yard for shipping. Locate and order ECM unit for current HPU at Caterpiller in Seattle. To arrive tonight in Anchorage for programming prior to sending to rig. Reciprocate pipe f/ 6756' to 6749' every 10 min. while circulating 1.5 BPM/30 psi. PUW 84k, SOW 40k. Clean and organize rig w/ continuing to address HPU issues. Set slips with pipe @ 6750’ and L/D top single. Continue circulating @ 1.5 bpm w/ 20 psi. Reciprocating pipe periodically f/ 6750’ to 6735’ PUW=88k, SOW=40k. Waiting on arrival of boat with backup power unit. Continue circulating @ 1.5 bpm w/ 20 psi. Reciprocating pipe periodically f/ 6750’ to 6735’ PUW=88k, SOW=40k. Waiting on arrival of boat with backup power unit. L/D w/l & r/d current HPU. Spot & R/U spare swivel HPU, make up xo's, to rig up hoses & install same, r/u control panel, hook up Tq line. Start HPU, engage swivel no rotation, troubleshoot & gain rotation, unable to read tq. or adjust from remote. Install gauge in line at HPU. Test HPU set Tq. t/7k & verify good. P/U single & M/U connection, tighten static lines. Wash & ream f/ 6750' t/6810', pump @ 4bpm, 360 psi, rot 60 rpm, tq 5200. Attempt to reverse circulate clean, unable to function 4" on standpipe manifold, CBU x2 clean long way. Pull stand pipe reverse valve apart, found cmt in it clean out & re-assemble. Wash & ream f/ 6814' t/6845', pump @ 4bpm, 360 psi, rot 60 rpm, tq 5200. 05/12/2020 - Tuesday Rig Start Date End Date HAK 404 CTU / EL / SL 4/27/20 8/14/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-16 50-883-20127-00 208-098 05/13/2020 - Wednesday RIH w/ BHA #6 F3080' to 7003' (Clean Out Assembly=Reverse jun k mill, 2- boot basket, Double pin, scraper, bit sub, string magnet, 1-4 3/4 DC, Hyd, drilling jar, 3-4 3/4 DC, XO = 184.04) L/D top single of last stand. PUW 84k, SOW 38k. Trouble shoot hydraulic tugger issue. (Air li ne off on carrier). PJSM Install Halstrip packing element in head and run in LDS. Remove elevators and pick up power swivel. P/U single and make it up to the Power Swivel. Wash and rotate single down to 7035'. Wash and Reaam f/ 7035'. At 7038' pipe torqued up, picked up and released torque and had a 21 bbl loss in mud volume. Continue cleaning out to 7056'. Experiencing low penetration rates, torque issues and continued fluid loss. Call ed and discussed situation with town. Decission made to spot a Calcium Carbonate pill on bottom and POOH. Total fluid losses=136 bbl. Rig up and pump 7 bbl Calcium Carbonate pill and displace with 1300 stks. Break off s wivel & l/d same, (safety valve broke from swivel had to break from single), pull Halstrip bushing, dress tongs for POOH. Pull 5 stands, up wt 100k ,dn wt 37k, fill hole 40 bbls, pulled 5 more stands took 10 bbls, (loss rate @ 25 BPH). TIH f/6478' t/7050', Spotted 15 bbls calcium carbonite pill, monitored hole 20 min loss rate @ 12 BPH. POOH t/6786', up wt 100k, dn wt 37k. Spot 22 bbls calcium carbonite pill, monitored hole 20 min loss rate @ 9 BPH. R/D circ. lines, POOH f/6786' t/2662', up wt 37k. Daily losses: 232 BBLS. Total losses: 272 BBLS Calcium Carbonite Pill: 44 BBLS. 05/14/2020- Thursday Continue POOH w/ BHA #6 f/2662' to top of BHA. Calc. hole fill for TOOH= 33 bbl. Actual hole fill=84 bbl. Work BHA, clean off string magnet (minimal filings) Break off mill (1-1/2" divot worn into middle of face of mill. Break off mill and junk baskets (minimal sand and filings recovered). Waiting on fishing tools from beach. Clear and clean rig floor, service equipment and transfer calcium carbonate pill from mix pit to cuttings totes. Decision made to call 7055' as final depth. Call out e-line crews to run CBL and set CIBP. L/D BHA while waiting on their arrival. Monitor well. Static losses to hole avg. = 8 bbl/hr. Lubricate rig, grease crown, blocks, drawworks, brake linkage, wash pipe and power swivel. Continue monitoring well. Rig up Pollard E-Li ne. RIH with CBL, GR, CCL tools log up F/7018', send logs to town & correlate same. P/U 7" CIBP on e-line, RIH w/ same, correlate & set @ 7030'. Tag to verify w/ e-line after set, good. POOH r/d e-line. Change out handling Eq. unload boat & tally 3.5" liner. M/u shoe track w/Baker lock, cont. in hole t/60', r/u & break circulation, @ 4 BPM 165 psi. Cont. RIH w/ 3 1/2" L-80 9.3#, liner as per Proposed plan filling every 20 joints. t/628'. Daily losses: 182 BBLS. Total losses: 454 BBLS. Calcium Carbonite Pill: 44 BBLS. RIH with CBL, GR, CCL tools log up F/7018', send logs to town & correlate same. P/U 7" CIBP on e-line, RIH w/ same, correlate & set @ 7030'. CIBP at 7030 ft Call out e-line crews to run CBL and set CIBP. Rig Start Date End Date HAK 404 CTU / EL / SL 4/27/20 8/14/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-16 50-883-20127-00 208-098 05/15/2020 - Friday Cont. RIH w/ 3 1/2" L-80 9.3#, liner as per Proposed plan filling every 20 joints. t/1885' . Calc. Disp. = 6 bbl, Act. Disp. = 6 bbl. P/U Baker ZXP Liner Hanger assembly as per Baker Rep. Change out McCoy power tongs for Gill power tongs and RIH 1st stand of 3 1/2" work string. Circ. through l iner hanger assembly. RIH w/ 3 1/2" L-80 9.3#, liner on 3 1/2" work string f/ 1966' to 2862'. Fill pipe every 15 stands. Calc. Disp. = 5.88 bbl, Act. Disp. = 6 bbl. Cont. RIH w/ 3 1/2" L-80 9.3#, liner on 3 1/2" work string f/ 2862' and tag to p of CIBP @ 7030' SLM. Fill pipe every 15 stands. 48 hour notice given to AOGCC on 5/14/2020 @ 12:58 pm. Jim Regg w/ AOGCC gave verbal waiver of AOGCC witness on 5/15/2020 @ 2:29 pm. POOH to 6956', pick up 9' pup to space out . RIH to 7025'. PUW= 80k , SOW=29k. Pick up cement head and R/U to circulate. RIH tag CIBP & p/u t/7029',Ci rculate @2.9 BPM, 430 psi while R/U cementers. PJSM w/all involved in cmt job, flood line to cmt head, pump 5 bbls water, PT lines 590/4800 good. Pump 5 bbls spacer followed by 53bbls 15.8ppg cmt, @ 3bpm, 54psi. Clear cmt line, drop dart & chase w/54bbls 8.4 brine @5 bpm, 600psi bump plug pressure up t/1800psi set liner hanger, slack off & verify set, good. Cont. pressure up t/4200psi setting packer & releasing from HRDE. P/U 3' verify released, good, up wt 52k, check float good. L/T @ 5105' shoe @ 7029'. Blow down cmt line, line up t/rig pump, pre ssure up t/820psi, p/u & observe pressure drop @ 10.6' pump. Cont. p/u 28' total while pumping 3.7 bpm 325 psi, CBU x1.5 observe spacer returns & trace of cmt at rig pits. Monitor well static. R/d circulating lines & l/d cmt head, 2 singles & 9' pup, break down same. POOH standing back 3 1/2" wk string t/3781'. Drop wiper ball circulate tubing volume 3.6 bpm, 230 psi. Cont. POOH t/1733' standing back 3 1/2" wk string. POOH l/d 3 1/2" wk string. L/D 21 joints. Daily losses: 0 BBLS. Total losses: 454 BBLS. Calcium Carbonite Pill: 44 BBLS. 05/16/2020 - Saturday POOH l/d 3 1/2" wk string. Trip out of hole calc. hole fill = 23.5 bbl. Actual fill =26 bbl. L/D Baker liner running tool assembly as per Baker Rep. Clear and clean rig floor. R/U and test casing w/ 1500 psi for 30 minutes - Charted. Good Test. R/D test equipment. R/U Pollard Wireline and RIH w/ 2.85 gage ring tag up at 6940'. P/U and set down several times with no change. POOH and R/D wireline. Rig up to test BOPE. M/U 3 1/2" test joint, install test plug and flood BOPE with water. Rig up test pump, test lines and chart recorde r. Weekly BOPE test as per AOGCC and Hilcorp policies. Test all components w/ 250 psi low, 2500 psi high for 5 min. each. No Failures. AOGCC witness of test waived by Jim Regg. R/D test equipment. R/U E-Line. P/u CBL, GR, CCl tools. RIH w/ e-line for CBL log Tag at 6882', log up across liner top @ 5105', EST toc @5300~. R/D e-line, (cont. Unload & tally completion from boat while logging). RIH w/3 1/2" wk string out of derrick t/2972' up wt 26k, dn wt 24k. POOH L/D 3 1/2" wk string, l/d 25 jts. Rig Start Date End Date HAK 404 CTU / EL / SL 4/27/20 8/14/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-16 50-883-20127-00 208-098 RIH with last 36 std. 3 1/2" work string out of derrick. PUW= 30k, SOW = 24k. POOH L/D 3 1/2" work string (L/D 132 jts). Calculated hole fill 24 bbl. Actual hole fill 26 bbl. Se rvice rig. Clean and clear rig floor. R/U Pollard Wireline. RIH with 3.81" gage ring and tag up @ 5105' WLM. (TOL @ 5105. Minimum ID of liner hanger assembly is 4.19" until Cross Over Busing @ 5141' which is 3.00" ID) POOH w/ wireline. M/U and RIH w/ 2.86" gage ring, tagged at 6867' (saw TOL @ ~5105' and bushing @ ~5141'). Worked several times with no progress. POOH. Discuss results of gage runs with engineer in town. RIH with 2.5" bailer while town di scuses next step. Bailed f/ 6867' to 6880'. POOH, recovered ~1" of sticky contaminated cement back in bail. RIH and bail f/ 6880' to 6885' POOH, same recovery as 1st run. R/D wireline. Clear floor and R/U to run completion string. RIH w/ 3 1/2" IBT L-80, 9.2# gas lift completion =WLEG dummy seal assy 9.17', 9 jts 3 1/2" 9.3# L-80 EUE 8RD jts , pup, x nipple, 1 jt 3 1/2" 9.3# L-80 EUE 8RD, pup jt, 7" DLH Packer pinned 46k release, pup jt, 1 tj 3 1/2" 9.2# L-80 IBT, pup, Chemical injection mandrel, pup jt, 1 tj 3 1/2" 9.2# L-80 IBT, GLM w/pup top & btm, 26 jts 3 1/2" 9.2# L-80 IBT, GLM w/pups top & btm, tubing to 1732'. Cont RIH w Completion t/ 4034'- 60 jts 3 1/2" 9.2# L-80 IBT, GLM w/pups to p &btm, 44 jts 3 1/2" 9.2# L-80 IBT, GLM w/pups top & btm, xo, 1 jt 4 1/2" 12.6# L-80 IBTM tubing, Nipple, Camco BP-6I Landing WRDP, DB lock with pups top & btm, 10 jts 4 1/2" 12.6# L-80 IBTM tubing. Installing CC every other joint from Chem. inj. mandrel. 05/18/2020 - Monday Cont. RIH w/ 3 1/2" Completion t/ 4717'. Change out handling equipment f/ 3 1/2" to 4 1/2",P/U 3 1/2" IBT X 4 1/2" X/O, 1 jt. 4 1/2" 12.6# L-80 IBTM tubing and CampcoBP-61 Landing WRDP, DB lock- connect and test control line w/5000 psi -Good test. Cont. RIH w/ 4 1/2" Completion. Space ou t. M/U hanger to landing jt. Land string. Run in lock down screws. Tubing tail @ 5113.(Tieback Locating Assy 7.75' inside Liner top @ 5105.35'), Drop setting bar. Set packer at 4000 psi. Bleed pressure down to 2800 psi for tubing test. Pressure bled off 300 psi in 15 minutes. Tie into annulus and pump +- 2 bbl taking returns out tubing. Shut in tubing and attempt to test annulus at 1500 psi. Had fitting leak at rig floor. Bled off annulus to 0 psi/tubing held 1100 psi. Bleed off and replace fitting. Test annulus at 1700 psi on chart for 30 minutes. Good test. Retest tubing at 2850 psi. on chart for 30 minutes. Good test. Rig down testing equipment. R/U W/L, RIH retrieve ball &rod, retrieve plug. R/D w/l, clear rig floor, cont. organize deck for rig move, set BPV @ 23:00. R/D wind walls, el evators & bails, remove turnbuckles from BOPE stack, r/d choke & kill lines, prep mast for scoping. Cont. pre pping mast to scope. 05/17/2020 - Sunday Rig Start Date End Date HAK 404 CTU / EL / SL 4/27/20 8/14/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-16 50-883-20127-00 208-098 05/27/2020 - Wednesday Finish N/U tree and test to 5000 psi - Test good. Pull BPV. 06/29/2020 - Monday Finish spotting up CTU package on drill deck. Run hydraulic lines from power pack to Ops cab, reel & injector. Run pumping iron from fluid pump to reel. Spot flowback tank & choke manifold, run flowback iron to both. Fly 240 bbl supply tank to pipe deck. Test BOPE as per Hilcorp & AOGCC requirements, witnessed waived 6/27/2020 by AOGCC Inspections Supervisor Jim Regg, 250/4000. BOPE test complete, tab pipe, make up Coil connector. SDFN 06/30/2020 - Tuesday PJSM & Permit. RU CTU. PU injector & MU lubricator. Pull Test C TC = 30,000#. Press Test CTC = 3500 psi. MU Quadco BHA1: CTC(2" X 0.23'), DFCV(2.13" X 1.70'), BI-DI JAR(2.13"" X 5.18'), TJ DISCO(2.13" X 1.58'), CIRC SUB(2.13" X 1.17'), PDM(2.13" x 11.60'), JUNK MILL(2.80" X 0.96') OAL = 22.42' Move to well. PT Lub & WHA = 4000. T = 20, KB Corr = 21.1'. Open swab (24T), RIH. Tag Top of Cement @ 6917' CT RKB. Milling ahead pumping FW & 5 bbl Flo Vis gel sweep @ 1.25 BPM, PP = 3000 psi. Mill to 6975' RKB stall. PUW = 19K. 4 stalls @ 6975' w/ 4 - 5K overpulls on PU. 5th stall, PU to 33K & detained. RBIH to cock jar. PU to 35K & pull free w/o jar lick. Circulate 5 bbl gel sweep to end of coil. POOH @ 80% chasing gel sweep OOH. RD & stand back CTU. Total Volume Pumped = 260 bbl FW, 10 bbl FloVis gel. MIRU ELU. ELU RIGGED UP, OPEN WELL, SWAB 20 TURNS, RIH WITH GAMMA/CCL/5' WT BAR. TAG AT 6957' KB. 17' DEEPER THAN OUR BOTTOM SHOT 6940' KB. Well ready for Coil blow down of tubing. 05/19/2020 - Tuesday Remove beaver slide and ODS stairs from rig. Inspect derrick for scoping in. Unplug lights and remove same. Bleed down accumulator and remove from stack. Part of crew working on A-07 nipple down. Move driller doghouse for scoping down. Prepare and scope down derrick. Secure lines and hoses on derrick and prepare to lay over. Lay mast over. Organize and secure guy wires. Remove hydraulic cyli nders. Housekeeping and organizing around rig. N/D BOPE from A-16. Pull hatch cover from A-16, n/u adaptor, master valve, test void 500/5000 good. Remove derrick from carrier, install bolsters, put on work boat. Move to A-07 AFE/report for remainder of rig move. Rig Start Date End Date HAK 404 CTU / EL / SL 4/27/20 8/14/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-16 50-883-20127-00 208-098 PJSM & permit. RU CTU. MU BHA: CTC(2" X 0.23'), DFCV(2.13" X 1.70'), XO(2.12" X 0.58'), MBT(2.12" X 4'), DJN(2.20" X 0.63') OAL = 7.14'. Move to well. PT Lubricator & WHA = 250/4000. T/IA/OA = 500/550/0 Open swab & RIH to 2500'. Platform production turbine offline. Standby for production to bring turbine BOL. Waiting for production to BOL turbine. Turbine online. Cool dow n N2 pump. Start N2 @ 500 SCFM. Continue RIH @ 60 FPM. CTP lines out @ 1400 psi. Inc. N2 rate = 850 SCFM. RIH jetting well bore fluids to surface taking returns to production facility. 3100' N2 = 850 SCFM, CTP = 1700, WHP = 130 RIH @ 70 FPM 4100' N2 = 850 SCFM, CTP = 1535, WHP = 50 Inc. RIH to 90 FPM 5000' N2 = 850 SCFM, CTP = 1450, WHP = 52 RIH @ 90 FPM 6500' N2 = 850 SCFM, CTP = 1500, WHP = 35,6956' RKB tag bot tom. N2 = 850 scfm, CTP = 1500, WHP = 35. Hold on bottom for 10 minutes lifting fluids @ 850 SCFM. POOH pumping 850 SCFM chasing fluids to surface, N2 = 850 SCFM, CTP = 1400, WHP = 52. SD N2 @ 1450' & Pull to surface. Cl ose Swab. 50.5 bbl fluid volume recovered from well bore.( 30bbls from coil, 20.5 bbls from well) T/IA/OA = 0/50/0 Total N2 pumped = 130,200 SCF. Bleed off all pressures to FB tank. LD BHA, RD injector & lubricator. RD BOP & riser. Install 7" bowen companion flange on tree. Turn over well to ELU for perforating runs. MIRU ELU. Make up l ubricator, test wire, make up Gun #1, 20' 2 3/8" 5spf 60* 10.8 gram razor gun. Stab on well. PT WLV & lubricator low 250, high 1500 WHP 280, IA 275. Tag at 6928' ccl depth+ 28.8' bottom of gun= 6957'. Log up to 6557', send log ov er to Daniel for approval to shoot first interval. WHP 280, IA 275. RIH to 6928' ccl depth. pu to 6911.8' ccl depth. CCL-TS 8'.3", CCL-BS 28'1" Shoot Beluga G sands, Top shot @ 6920'- BS 6940'. WHP 280, IA 275. No change in WHP afte r first shot. Log up 200'. POOH, OOH, all shots fired. Gun a little wet. More than likely from the sump. Make up Gun #2, 10' 2 3/8" 5spf 60* 10.8 gram razor gun, stab on well, open up rih, WHP 280, IA 275. Tag @ 6937'CCL depth. Log u p to 6600' CCL depth. Send Logs to Daniel. Got confirmation to shoot second gun 6912'-6922'. RIH to 6937' CCL . PU to 6903.8' CCL Depth. CCL-TS 8'2", CCL- BS 18'. Shoot Beluga G from 6912'-6922'. WHP 280, IA 275. No change in pressures. POOH, OOH, All shots fired. Gun a little wet. Nothing Excessive. Make up Gun #3, 20' 2 3/8" 5 spf, 60* p hase, 10.8 gram razer gun. Stab on well, open up, WHP 280, IA 275. RIH. Tag at 6928'ccl depth. Log up to 6600' ccl. Download and send log to Daniel for approval. Got approval to shoot Beluga F interval 6856'-6876'. CCL-TS=8'2", CCL- BS 28' Park at 6847' CCL. Top shot 6856'-6876'. WHP 280, IA 275. POOH,OOH, All shots fired. Gun a tiny bit wet. Couple cups of fluid in bullnose. Make up Gun #4, 10' 2 3/8" 5 spf, 60* phase, 10.8 gram razer gu n. Stab on well, Open well, WHP 280, IA 275 RIH. Tag 6937' CCL depth. Log up to 6550' CCL. Send log to Daniel for approval to shoot Beluga F 6846'-6856'. Got approval to shoot. RIH to 6937', puh to 6837.8' CCL depth. CCL-Top shot 8'2", CCL-Bottom shot 18'. WHP 280, IA 275 Shoot 6846'- 6856'. No change in WHP. POOH, OOH, all shots fired, gun a little wet, nothing excessive. Make up Gun #5, 9' 2 3/8" 5 spf, 60* phase, 10.8 gram razer gun. Stab on well, Open well , WHP 280, IA 271. RIH. Tag 6937' CCL depth. Log up to 6550'. Download and send log to Daniel for approval to shoot Be luga F 6805’-6814’. Got approval to shoot. RIH to 6937'ccl. PU to 6796.1' ccl. CCL-To-Top shot 8'9", CCL-To-Botto m shot 18'1". Shoot Beluga F 6805'-6814'. WHP 280, IA 271. No change in pressure. POOH 07/01/2020 - Wednesday Rig Start Date End Date HAK 404 CTU / EL / SL 4/27/20 8/14/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-16 50-883-20127-00 208-098 PJSM & permit. RU SLU. MU 1-3/4" TS w/ 4" PRS. PT = 250/2500. T/IA = 160/134. RIH w/ 4" PRS & latch SSSV @ 362' KB. Hand spang to release SSSV & POOH. OOH w/ SSSV. RBIH w/ 2.70" Blind Box. See Fluid Top @ 5960' & tag bottom @ 6936' KB (Beluga G bottom perf = 6940'). POOH. RD SLU. Move SLU to Well# A-03 & Standby waiting on A- 16 ELU runs. PJSM & permit. RU ELU w/ GR/CCL & 2.70" X 20' Dummy Tubing Patch. Surface test CCL. PT 250/2500. RIH w/ DMY Patch to 6780' KB. POOH. LD DMY Patch. Surface test CCL & fire check Firing Dead. MU Perf GUN# 6: 2- 3/8" X 14', 5spf, 60* phase, 11 gm HMX Razor charge, Geodynamics HS carrier. CCL-to Top Shot = 8.3' CCL-to Bottom Shot = 22.3' T/IA = 160/134. RIH w/ Perf Gun# 6 t o 6850' CCL. Log up to 6547' CCL for correlation. Correction = + 2.50'. Send correlation pass for verification. RBIH to 6850' CCL. Log up to 6746.7' CCL to place shots on depth (6746.7 + 8.3 = 6755' Top Shot). Fire Perf Gun# 6 perforating Zone Beluga E Lower @ 6755' - 6769'. T/IA = 160/134. Log up 200' & POOH. OOH w/ all shots fired. RDMO ELU. Turn over well to Production to bring on line. RDMO ELU. Fly crew to beach. Turn over well to Production to bring online. 07/02/2020- Thursday Continue from 7-2-20, OOH with ELU. Confirm all shots fired. RDMO ELU. Turnover well to Prod Operator to BOL. Turnover drill deck to CTU. RDMO CTU. Suspend RD to allow crane to work boat. Working MV Titan. Offload Hammer BLU, grease skid, lubricator, toolbox, WLV, 1 loaded SLB N2 tank & overpack of misc. fittings(production). Backload Tank# 4618, 1 empty SLB N2 tank. Return to RDMO of CTU. Unstab CT from injector. Break pump iron from reel and hoses from power pack to ops cab & injector. CTU & Eli ne operations for perforation of Beluga G& F sands complete. 08/07/20 - Friday Rig Start Date End Date HAK 404 CTU / EL / SL 4/27/20 8/14/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI A-16 50-883-20127-00 208-098 08/14/20 - Friday Eline crew arrives @ OSK heliport. Fly to platform. PJSM & permit. RU ELU. MU GR/CCL & Firing Head Tool Suite. Surface test GR/CCL & fire check FH. MU Perf Gun# 7: 2-3/8" X 13', 5 spf, 60* phase, 10.8 gm HMX razor charge, Geodynamics HS carrier. Move to well & PT WLV & Lub = 250/2500. CCL-to-Top Shot = 9' CCL-to-Bottom Shot = 22' Well is flowing @ 1.9 MMSCFD. Well flowed to Test Separator & flow line choke is pinched in for Flow Rate = 1.0 MMSCFD for each gun run. T/IA = 240/118. RIH w/ Perf Gun# 7 to 6750' CCL. Log up to 6286' CCL for correlation pass. Correct +9'. Send correlation pass for verification and approval. RBIH to 6750' CCL. Log up to 6633' CCL to put shots on depth (6633' + 9' = 6642' TS). Fire Perf Gun# 7 perforating Zone Beluga D Lower 6642' - 6655'. Log up 200' & POOH. OOH w/ all shots fired. OOH w/ trace amount of water in bull pl ug. T = 250. Surface test GR/CCL & fire check FH. MU Perf Gun# 8: 2-3/8" X 8', 5 spf, 60* phase, 10.8 gm HMX razor charge, Geodynamics HS carrier. CCL-to-Top shot = 10', CCL-to-Bottom Shot = 18'. RIH w/ Perf Gun# 8 to 6606' CCL. Log up to 6272' CCL. Correct +6.3'. Send log for verification & approval. RBIH to 6605' CCL. Log up to 6457' CCL to put shots on depth (6457' + 10' = 6467' TS). Fire Perf Gun# 8 perforating Zone Beluga C Lower 6467' - 6475'. Log up 200' & POOH. OOH w/ all shots fired. OOH w/ trace amount of water in bull plug. T = 250. Surface test GR/CCL & FH. MU Perf Gun# 9: 2-3/8" X 7', 5 spf, 60* phase, 10.8 gm HMX razor charge, Geodynamics HS carrier. CCL-to-Top shot = 11', CCL-to-Bottom Shot = 18'. RIH w/ Perf Gun# 9 to 6611' CCL. Log up to 6274' CCL. Correction = +0.3'. Send log for verification & approval. RBIH to 6610' CCL. Log up to 6416' to put shots on depth (6416' = 11' = 6427' TS). Fire Perf Gun# 9 to perforate Zone Beluga C Upper 6427' - 6434'. Log up 200' & POOH. OOH w/ all shots fired & trace amount of water in bull plug. T = 257 psi, Flow = 0.560 MMSCFD. Prod. open choke = 0.96 MMSCF D w/ WHP = 195. Surface test GR/CCL & FH. MU Perf Gun# 10: 2-3/8" X 14', 5 spf, 60* phase, 10.8 gm HMX razor charge, Geodynamics HS carrier. CCL-to-Top shot = 8.2', CCL-to-Bottom Shot = 22.2'. RIH to 6520' CCL. Log up to 6268' CCL. Send log for verification & approval. RBIH to 6523' CCL. Log up to 6358.8' CCL to put shots on depth (6358.8' + 8.2' = 6367' TS). Fire Perf Gun# 10 to perforate Zone Beluga B Lower 6367' - 6381'. Log up 200' & POOH. OOH w/ all shots fired & trace of water in bull plug. Flow = 1.5 MMSCFD, WHP = 230. MU GR/Press/Temp tool suite. CCL-to-Bottom o f Tool = 7'. Flow Rate = 1.2 MMSCFD, WHP = 190. RIH to 5123' CCL & log down @ 80 FPM to tag @ 6928' KB (6921' CCL + 7'). Log up @ 80 FPm to 5990' CCL. Fluid Top @ 6812' CCL. POOH. RDMO ELU. Fly crew to beach. Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 09/24/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NCIU A-16 (208-098) GASSAT3D ANALYSIS with TMD3D 02/29/2020 ANALYSIS FIELD DATA Please include current contact information if different from above. Received by the AOGCC 08/24/2020 PTD: 2080980 E-Set: 33987 Abby Bell 09/24/2020 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 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 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): North Cook Inlet Field / Tertiary System Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 9,314'N/A Casing Collapse Structural Conductor Surface 3,090 psi Intermediate Production 5,410 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:mmckinley@hilcorp.com Contact Phone: (907) 777-8387 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: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7,631' 7,424' 5,745' 1,893 psi 7,619'7" 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. 6/10/2020 4-1/2" Daniel E. Marlowe See schematic 6,361 - 7,382 4,536' 9,301' Perforation Depth MD (ft): 9,301' See schematic Tubing Grade:Tubing MD (ft): 4,709 - 5,704 Perforation Depth TVD (ft): 400' 4,536' 30" 9-5/8" 400' 400' N Cook Inlet Unit A-16 12.6 / L-80 TVD Burst 6,292' 7,240 psi Tubing Size: MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 / ADL0037831 208-098 50-883-20127-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC CO 68 COMMISSION USE ONLY Authorized Name: 5,750 psi3,457' Other: N2 Operations Authorized Signature: Operations Manager Mark McKinley PRESENT WELL CONDITION SUMMARY Length Size 7,424; 7,481; 8,991 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 3:33 pm, May 26, 2020 320-214 Daniel Marlowe I am approving this document 2020.05.26 14:55:43 -08'00' Daniel Marlowe CT N2 Operations * 4000 psi BOPE test (Coil tubing) DSR-5/26/2020 X gls 5/28/20 Change Approved Program X DLB 05/26/2020 10-404 (report both 320-214 and 320-153) Comm. equired? Yes 5/29/2020 dts 5/28/2020 RBDMS HEW 6/4/2020 Well Work Prognosis CHANGE APPROVED PROGRAM Well Name:NCIU A-16 API Number: 50-883-20127-00 Current Status:Producer Leg:Leg #2 SW Corner Estimated Start Date:06/10/20 Rig:HAK 404 Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:208-098 First Call Engineer:Mark McKinley (907) 777-8387 (O) (907) 953-2685 (M) Second Call Engineer:Dan Marlowe (907) 283-1329 (O) (907) 398-9904 (M) Current Bottom Hole Pressure: 2,462 psi @ 5,686’TVD 0.433 psi/ft gradient to surface Maximum Expected BHP:2,462 psi @ 5,686’ TVD 0.433 psi/ft gradient to surface Maximum Potential Surface Pressure: 1,893 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary The NCIU A-16 well was drilled and completed in 2009 as a Beluga sands producer. In 2010, fill came in to 7,158’and a coil tubing cleanout was performed down to 7,508’. The well continued to produce sand and bringing in fill. The well is currently shut-in. It is proposed to run a 3-1/2” liner over the Beluga sands to isolate the individual zones. Then perforate the Beluga sands from the bottom up, isolating each sand as it becomes depleted. Production will be through a single string completion. Waiver Request: Hilcorp requests waiver to 20AAC25.265(c)(1). We request locating the SSV on the tree wing allowing the SSV to remain in the production stream while providing concurrent well bore access. Additionally, a SSSV will be installed. Wellbore Notes: x Last fill tagged at 6,793’MD on 2/5/2020. x Slickline will remove SSSV x PR plug set in R Nipple at 7,424’MD Procedure: 1. MIRU HAK 404 2. Test BOP’s to 250psi low/2,500psi high / 2,500 psi annular. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 3. Workover fluid will be brine. BOP’s will be closed as needed to circulate the well. 4. Rig up E-line. PT lubricator to 2,500 psig 5. RIH with tubing cutter. Cut packer to release at 6,251’. RD E-line. 6. Pull upper completion, fishing tubing and cleaning out as needed to ±7,399’. Lay down 4-1/2” tubing completion. 7. P/U and rack back work string 8. RIH with casing scraper to sump packer ±7,399’. Circulate clean. POOH. 9. RU E-line CBL Logging tool. RIH with tool. Log ±7,399’ to TOC. POOH – Send log to AOGCC 10. RIH with 7” x 3-1/2” liner hanger assembly and 3-1/2” Liner from ±6,205’ to ±7,379’ per program. 1. RIH with Shoe, 1 st liner joint, float collar, 2nd liner joint, and landing collar. This may vary at time of running. *Keep joints as short as practical to minimize spacing. 2. RIH with liner and confirm number of joints. *Fill liner as necessary to prevent collapse. 3. PU Liner Hanger Assembly: Liner Hanger, Liner Top Packer, and 10’ Extension 4. PU running/setting tools 5. RIH with Drill Pipe. Confirm drill pipe tally. 11. At proper liner depth, circulate minimum of one bottoms up to condition the wellbore. 12. RU cementing equipment. Pressure test cementing equipment to 5,000 psig. 13. Position liner in tension. Shoe at ±7,379’. Well Work Prognosis CHANGE APPROVED PROGRAM 14. Cement liner from±6,205’ to ±7,379’ per program, 1. Pump ~40 bbl of 8.34 ppg spacer fluid at 3-4 GPM. 2. Pump ~38 bbl (includes 20%) of 15.8 ppg Cement at 3-4 GPM. 3. Engage Liner Wiper Plug 4. Pump ~64 bbl of 8.34 ppg Displacement fluid at 3-4 BPM. 5. As the liner wiper plug nears the landing collar, make note of volume. Bump Plug. 15. Pressure up to 2,200 psig to set liner hanger. Slack off to ensure line hanger is set. *Pressure may vary due to model actually run. 16. Pressure up to 3,000 psig to set liner top packer. *Pressure may vary due to model actually run. 17. Pressure up to 4,500 psig to release from Hanger Assembly. *Pressure may vary due to model actually run. 18. Ensure Liner Hanger assembly was released. Slack off to verify weight change. 19. PU until running tool assembly is just above TOL and circulate out excess cement. POOH. 20. RIH with 4-1/2” tubing to SSSV Nipple, 4-1/2” x 3-1/2” crossover, 3-1/2” tubing, 3-1/2” Gas Lift completion (live valves), chemical injection mandrel, and packer assembly. See proposed schematic for details and set depths. 21. Set Packer / Pressure test completion: 1. Pressure up and set packer 2. Test tubing against plug in X nipple to >2,500psig and chart for 30 minutes. 3. Test IA to 1,500 psi and chart for 30 minutes (This will pressure up tubing also). 4. Pull prong and plug in X-Nipple. 22. Set BPV. NU tree, test same. 23. RD HAK 404 Hilcorp requests the following Change to Approved Sundry: *** Tagged cement high inside liner – 24. R/U Coil tubing unit 25. Perform BOPE pressure test 250psi/4,500psi (Note: Notify AOGCC 48hrs in advance to allow them to witness) 26. RIH and clean out to ±7,000’ 27. Blow well dry with Nitrogen to production header or non-enclosed open top tank. POOH, R/D Coil tubing. 28. Continue per Sundry (320-153) 29. RU E-line and perforate per program. Note: Deepest zone will be perforated as first. This zone will be tested. 1.Contingency: If zone is unproductive, a CIBP w/cement will be placed above the open zone. E-line will perforate the next shallowest zone. This will be repeated until a productive zone is achieved. 30. Turn over to production. 31. Schedule SVS testing with AOGCC as per regulations Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Proposed 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form 7. Coil Tubing BOP Drawing 8. Standard Well Procedure – Nitrogen Operations 9. Coil Flow Diagrams 214320- Coil tubing FCO w/ N2 Coiled Tubing BOP 05/21/2020 SWAB VALVE MASTER VALVE Hilcorp Monopod Rig 56 Flow Diagram Fluids Pumped Fluids Returned Valve Open Valve Closed Gate Valve Ball Valve Butterfly Valve Lo Torq Valve Automatic Choke Manual Choke Pressure Gauge Knife Valve Choke Line P PIT SYSTEM SucƟon SHAKER SHAKER CHOKE MANIFOLD GAS BUSTER Panic Line C12 C13 C15 C14 C16 A B C4 C5 C6 C7 C2 C10 C9 C11 C8 C3 P C1 C STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. STATE OF ALASKA -> OIL AND GAS CONSERVATION COMMISSION Reviewed By: JU� P.I. Supry BOPE Test Report for: N COOK INLET UNIT A-16 ,/ Comm Contractor/Rig No.: Hilcorp 404 PTD#: 2080980 - DATE: 5/12020 ' Inspector Austin McLeod , Insp Source Operator: Hilcorp Alaska, LLC Operator Rep: Soule/Brumley Rig Rep: Steiner/Hannevold Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopSAM200503100603 320-153 Rams: Annular: Valves: NIASP: Type Test: INIT 250/2500 2502500 ' 250/2500 1893 - Related Insp No: MISC. INSPECTIONS: FLOOR SAFTY VALVES: P/F Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P Well Sign P OrE Rig P Hazard Sec. P Misc NA FLOOR SAFTY VALVES: MUD SYSTEM: Quantity P/F Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA TEST DATA MUD SYSTEM: 3025 Visual Alarm Trip Tank NA NA Pit Level Indicators P - P Flow Indicator NA - NA Meth Gas Detector P - P H2S Gas Detector P - P - MS Mise NA NA ACCUMULATOR SYSTEM: Time/Pressure P/F System Pressure 3025 P Pressure After Closure 2000 P 200 PSI Attained 40 P Full Pressure Attained 180 P Blind Switch Covers: All stations - P _ Nitgn. Bottles (avg): 6@1950 ' P ' ACC Mise 0 NA BOP STACK: CHOKE MANIFOLD: Quantity Size P/F Quantity P/F Stripper 0 NA No. Valves 10 - P Annular Preventer 1 13-5/8" - F Manual Chokes I P #1 Rams 1 "2-7/8"x5-1/21" P Hydraulic Chokes 1 P - #2 Rams 1 , Blinds P CH Mise 0 NA #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 2-1/16" - P - Quantity P/F HCR Valves 2 ' 2-1/16" P Inside Reel Valves 0 NA Kill Line Valves 2 2-1/16" P ' Check Valve 0 NA BOP Misc 0 NA Number of Failures: I ✓ Test Results Test Time 8 Remarks: 3-1/2" & 4-1/2" joints. Annular would not test on 3-1/2". Was replaced for a pass. Not witnessed. Chart of restest sent to Jim Regg. Time/date reflects when 1 was on f e rig. Alco,p R, 904- Aj G,,i -37 ke- A--•) (Pzb W60aro) 2e4e,4- &F- AAA d el Pr y 0-/`4 n7 44kd"J--4v kC-CC -TtS-P 0p3* bob, SAPti7oDsog10obo3 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 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address: 3800 Centerpoint Drive, Suite 1400 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): North Cook Inlet Field / Tertiary Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,314'N/A Casing Collapse Structural Conductor Surface 3,090 psi Intermediate Production 5,410 psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:jkaiser@hilcorp.com Contact Phone: (907) 777-8393 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: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7,631' 7,424' 5,745' 1,893 psi 7,619'7" 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. 4/21/2020 4-1/2" Daniel E. Marlowe See schematic 6,361 - 7,382 9,301' See schematic Tubing Grade: Tubing MD (ft): 4,709 - 5,704 Perforation Depth TVD (ft): 4,536' 9,301' Perforation Depth MD (ft): 400' 4,536' 30" 9-5/8" 400' N Cook Inlet Unit A-16 12.6 / L-80 TVD Burst 6,292' 7,240 psi Tubing Size: MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 / ADL0037831 208-098 50-883-20127-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC CO 68 COMMISSION USE ONLY Authorized Name: 5,750 psi 400' 3,457' Other: G/L Completion Authorized Signature: Operations Manager Joe Kaiser PRESENT WELL CONDITION SUMMARY Length Size 7,424; 7,481; 8,991 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Daniel Marlowe I am approving this document 2020.04.06 15:28:45 -08'00' Daniel Marlowe By Samantha Carlisle at 3:58 pm, Apr 06, 2020 320-153 GLS 4/7/20 ^ X System 10-404 SFD 4/6/2020 * Alternate SSV placement approved per 20 AAC 25.265 (o)(1) DSR-4/6/2020 * 2500 psi BOPE test GWV quired? Yes No Com m.S 4/8/2020 JLC 4/8/2020 Well Work Prognosis Well Name:NCIU A-16 API Number: 50-883-20127-00 Current Status:Producer Leg:Leg #2 SW Corner Estimated Start Date:April 21st, 2020 Rig:HAK 404 Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:208-098 First Call Engineer:Joe Kaiser (907) 777-8393 (O) (907) 952-8897 (M) Second Call Engineer:Dan Marlowe (907) 283-1329 (O) (907) 398-9904 (M) Current Bottom Hole Pressure: 2,462 psi @ 5,686’TVD 0.433 psi/ft gradient to surface Maximum Expected BHP:2,462 psi @ 5,686’ TVD 0.433 psi/ft gradient to surface Maximum Potential Surface Pressure: 1,893 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary The NCIU A-16 well was drilled and completed in 2009 as a Beluga sands producer. In 2010, fill came in to 7,158’and a coil tubing cleanout was performed down to 7,508’. The well continued to produce sand and bringing in fill. The well is currently shut-in. It is proposed to run a 3-1/2” liner over the Beluga sands to isolate the individual zones. Then perforate the Beluga sands from the bottom up, isolating each sand as it becomes depleted. Production will be through a single string completion. Waiver Request: Hilcorp requests waiver to 20AAC25.265(c)(1). We request locating the SSV on the tree wing allowing the SSV to remain in the production stream while providing concurrent well bore access. Additionally, a SSSV will be installed. Wellbore Notes: x Last fill tagged at 6,793’MD on 2/5/2020. x Slickline will remove SSSV x PR plug set in R Nipple at 7,424’MD Procedure: 1. MIRU HAK 404 2. Test BOP’s to 250psi low/2,500psi high / 2,500 psi annular. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 3. Workover fluid will be brine. BOP’s will be closed as needed to circulate the well. 4. Rig up E-line. PT lubricator to 2,500 psig 5. RIH with tubing cutter. Cut packer to release at 6,251’. RD E-line. 6. Pull upper completion, fishing tubing and cleaning out as needed to ±7,399’. Lay down 4-1/2” tubing completion. 7. P/U and rack back work string 8. RIH with casing scraper to sump packer ±7,399’. Circulate clean. POOH. 9. RU E-line CBL Logging tool. RIH with tool. Log ±7,399’ to TOC. POOH – Send log to AOGCC 10. RIH with 7” x 3-1/2” liner hanger assembly and 3-1/2” Liner from ±6,205’ to ±7,379’ per program. 1. RIH with Shoe, 1 st liner joint, float collar, 2nd liner joint, and landing collar. This may vary at time of running. *Keep joints as short as practical to minimize spacing. 2. RIH with liner and confirm number of joints. *Fill liner as necessary to prevent collapse. 3. PU Liner Hanger Assembly: Liner Hanger, Liner Top Packer, and 10’ Extension 4. PU running/setting tools 5. RIH with Drill Pipe. Confirm drill pipe tally. 11. At proper liner depth, circulate minimum of one bottoms up to condition the wellbore. 12. RU cementing equipment. Pressure test cementing equipment to 5,000 psig. 13. Position liner in tension. Shoe at ±7,379’. scab liner --- circ wellbore with brine thru open GLM at 6160 ft gls APPROVED Well Work Prognosis 14. Cement liner from±6,205’ to ±7,379’ per program, 1. Pump ~40 bbl of 8.34 ppg spacer fluid at 3-4 GPM. 2. Pump ~38 bbl (includes 20%) of 15.8 ppg Cement at 3-4 GPM. 3. Engage Liner Wiper Plug 4. Pump ~64 bbl of 8.34 ppg Displacement fluid at 3-4 BPM. 5. As the liner wiper plug nears the landing collar, make note of volume. Bump Plug. 15. Pressure up to 2,200 psig to set liner hanger. Slack off to ensure line hanger is set. *Pressure may vary due to model actually run. 16. Pressure up to 3,000 psig to set liner top packer. *Pressure may vary due to model actually run. 17. Pressure up to 4,500 psig to release from Hanger Assembly. *Pressure may vary due to model actually run. 18. Ensure Liner Hanger assembly was released. Slack off to verify weight change. 19. PU until running tool assembly is just above TOL and circulate out excess cement. POOH. 20. RIH with 4-1/2” tubing to SSSV Nipple, 4-1/2” x 3-1/2” crossover, 3-1/2” tubing, 3-1/2” Gas Lift completion (live valves), chemical injection mandrel, and packer assembly. See proposed schematic for details and set depths. 21. Set Packer / Pressure test completion: 1. Pressure up and set packer 2. Test tubing against plug in X nipple to >2,500psig and chart for 30 minutes. 3. Test IA to 1,500 psi and chart for 30 minutes (This will pressure up tubing also). 4. Pull prong and plug in X-Nipple. 22. Set BPV. NU tree, test same. 23. RU E-line and perforate per program. Note: Deepest zone will be perforated as first. This zone will be tested. 1.Contingency: If zone is unproductive, a CIBP w/cement will be placed above the open zone. E-line will perforate the next shallowest zone. This will be repeated until a productive zone is achieved. 24. RD HAK 404 25. Turn over to production. 26. Schedule SVS testing with AOGCC as per regulations Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Proposed 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form MIT - T MIT- CASINGTest IA to 1,500 psi and chart for 30 minutes ( _____________________________________________________________________________________ Updated By: JLL 2017-10-27 SCHEMATIC Tyonek Platform Well: A-16 Last Completed: 5/19/2009 PTD: 208-098 API: 50-883-20127-00 PBTD: 8,991’ TD:9,314’ 20” RKB to TBG Head – 42.6’ 7” 2 7 18 4 6 13 9-5/8” 1 9 20 8 10 24 23 3 11 12 17 21 15 19 16 5 22 25 26 27 14 D B X R CASING DETAIL Size Wt Grade Conn ID Top Btm 30” Conductor Welded 19.100” 45’ 400’ 9-5/8” 40 L-80 BTCM 8.835” 48.6’ 4,536’ 7” 26 L-80 BTCM 6.276” 44.8’ 9,301’ TUBING DETAIL 4-1/2” 12.60 L-80 IBTM 3.958” 42.6’ 6,292’ GRAVEL PACK 4” 11.00 P-110 SLHT 3.430” 7,426’ 8,805’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1503’503’ 3.813 5.570 Nipple, Camco BP-6i Landing - Camco 3.813” WRDP, DB Lock 2 1,747’ 1689’ 3.813 5.000 GLM#1 Camco KBG-2-1R DV 3 3,259’ 2692’ 3.813 5.000 GLM#2 Camco KBG-2-1R DV 4 4,432’ 3,393’ 3.813 5.000 GLM#3 Camco KBG-2-1R DV 5 5,266’ 3,894’ 3.938 5.000 GLM#4 Camco KBG-2-1R DV 6 6,160’ 4,525’ 3.813 5.980 GLM#5 Camco KBG-2-1R OPEN 7 6,208’ 4,568’ 3.813 5.000 Nipple, X 8 6,251’ 4,607’ 3.890 5.980 Packer, Baker Premier 9 6,279’ 4,632’ 3.750 5.560 Nipple, DB Landing 10 6,290’ 4,643’ 3.930 5.000 Wireline Entry Guide 11 7,399’ 5,721’ 3.450 4.000 Packer, Sump, Baker SC-2 12 7,424 5,745’ 3.250 4.530 Nipple, R - PR Plug set in R profile with 4’ Catcher on top 13 7,425’ 5,746’ 3.260 5.000 Snap Latch 14 7,426’ 5,747’ 3.260 3.980 Seal Unit 15 7,426’ 5,747’ 4.000 6.000 Packer, Baker SC-2 70B-40 7,430’ 5,752’ 3.260 Mule Shoe 16 7,434’ 5,755’ 4.000 5.560 Seal Bore 17 7,458’ 5,779’ 3.430 5.650 KOIV Isolation Sleeve 7,464’ 5,785’ 3.430 Sub, Shear Out Safety 18 7,481’ 5,802’ 0.000 Plug, Baker IBP 7,487’ 5,808’ 3.430 5.800 Screen, Bakerweld 10 ga. 19 7,715’ 6,037’ 3.250 5.000 Seal Bore receptacle 7,719’ 6,040’ 3.430 5.800 Screen, Bakerweld 10 ga. 20 8,007’ 6,327’ 3.250 5.000 Seal Bore receptacle 8,010’ 6,330’ 3.430 5.800 Screen, Bakerweld 10 ga. 21 8,318’ 6,637’ 3.250 5.000 Seal Bore receptacle 8,320’ 6,639’ 3.430 5.800 Screen, Bakerweld 10 ga. 22 8,540’ 6,858’ 3.250 4.490 Seal Bore receptacle 8,543’ 6,861’ 3.430 5.800 Screen, Bakerweld 10 ga. 23 8,613’ 6,932’ 3.250 4.490 Seal Bore receptacle 8,616’ 6,934’ 3.430 5.800 Screen, Bakerweld 10 ga. 24 8,796’ 7,114’ 3.260 5.000 Snap Latch 82-40 S-22B 25 8,797’ 7,115’ 4.000 5.850 Packer, Sump, FS 26 8,801’ 7,119’ 4.890 5.510 Mule Shoe, 5-1/2”, 23#, L-80 27 8,991’ 7,308’ 0.000 Plug, Baker CIBP Note: 8/21/11 Gravel Pack (M thru U) 27304 lbs. 20/40 sand, 65.9 lbs/ft perfs @ 10.1 BPM, 33% returns Updated by: JLL 2017-10-27 SCHEMATIC Tyonek Platform Well: A-16 Last Completed: 5/19/2009 PTD: 208-98 API: 50-883-200127-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf Comments Beluga B 6,361’ 6,366’ 4,709’ 4,713’ 5’ 6 6/22/09 2-7/8” HSD PJ Omega Max, 60 phase OPEN Beluga B 6,366’ 6,386’ 4,713’ 4,732’ 20’ 6 6/22/09 2-7/8” HSD PJ Omega Max, 60 phase OPEN Beluga B 6,427’ 6,434’ 4,770’ 4,777’ 7' 6 6/22/09 2-7/8” HSD PJ Omega Max, 60 phase OPEN Beluga C 6,467’ 6,475’ 4,808’ 4,816’ 8’ 6 6/22/09 2-7/8” HSD PJ Omega Max, 60 phase OPEN Beluga E 6,642’ 6,655’ 4,976’ 4,988’ 13’ 6 6/21/09 2-7/8” HSD PJ Omega 6 OPEN Beluga E 6,663’ 6,671’ 4,996’ 5,004’ 8’ 6 6/21/09 2-7/8” HSD PJ Omega 6 OPEN Beluga E 6,755’ 6,776’ 5,085’ 5,105’ 21’ 6 6/21/09 2-7/8” HSD PJ Omega 6 OPEN Beluga F 6,806’ 6,814’ 5,135’ 5,142’ 8’ 6 6/21/09 2-7/8” HSD PJ Omega 6 OPEN Beluga F 6,846’ 6,856’ 5,173’ 5,183’ 10’ 6 6/21/09 2-7/8” HSD PJ Omega 6 OPEN Beluga F 6,846’ 6,876’ 5,173’ 5,202’ 30’ 6 6/20/09 2-7/8” HSD PJ Omega 6 OPEN Beluga G 6,911’ 6,941’ 5,237’ 5,266’ 30’ 6 6/20/09 2-7/8” HSD PJ Omega 6 OPEN Beluga H 7,038’ 7,066’ 5,362’ 5,389’ 28’ 6 6/9/09 2-7/8” HSD PJ Omega 6 OPEN Beluga H 7,046’ 7,066’ 5,370’ 5,389’ 20’ 6 6/9/09 2-7/8” HSD PJ Omega 6 OPEN Beluga H 7,125’ 7,133’ 5,448’ 5,456’ 8’ 6 10/06/17 –2-3/4” GG & 8’ 2-7/8” 6 SPF Beluga J 7,289’ 7,337’ 5,651’ 5,659’ 48’ 6 6/9/09 2-7/8” HSD PJ Omega 6 OPEN Beluga J 7,329’ 7,337’ 5,651’ 5,659’ 8’ 6 6/9/09 2-7/8” HSD PJ Omega 6 OPEN Beluga K 7,364’ 7,382’ 5,686’ 5,704’ 18’ 6 6/8/09 2-7/8” HSD PJ Omega 6 OPEN Beluga M 7,500’ 7,524’ 5,821’ 5,845’ 24’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga O 7,677’ 7,694’ 5,998’ 6,015’ 17’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga P 7,797’ 7,810’ 6,117’ 6,130’ 13’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,880’ 7,885’ 6,200’ 6,205’ 5’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,912’ 7,922’ 6,232’ 6,242’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,946’ 7,978’ 6,266’ 6,298’ 32’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,958’ 7,978’ 6,278’ 6,298’ 20’ 6 1/31/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga S 8,278’ 8,284’ 6,597’ 6,603’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,291’ 8,300’ 6,610’ 6,619’ 9’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,291’ 8,300’ 6,610’ 6,619’ 9’ 6 1/31/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga T 8,414’ 8,424’ 6,733’ 6,743’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,464’ 8,490’ 6,783’ 6,809’ 26’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,517’ 8,523’ 6,836’ 6,841’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,564’ 8,576’ 6,882’ 6,894’ 12’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,565’ 8,571’ 6,883’ 6,889’ 6’ 6 1/29/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga U 8,587’ 8,593’ 6,905’ 6,911’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,709’ 8,724’ 7,027’ 7,042’ 15’ 6 1/26/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga U 8,709’ 8,724’ 7,027’ 7,042’ 15’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,734’ 8,741’ 7,052’ 7,059’ 7’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,746’ 8,756’ 7,064’ 7,074’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,767’ 8,771’ 7,085’ 7,089’ 4’ 14 1/26/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG _____________________________________________________________________________________ Updated By: KK 2020-04-03 PROPOSED SCHEMATIC Tyonek Platform Well: A-16 Last Completed: Future PTD: 208-098 API: 50-883-20127-00 PBTD: 8,991’ TD: 9,314’ 20” RKB– 42.6’, RKB to MSL – 119.2’, RKB to Mudline 239.2’ 7” Beluga B 2 18 13 9-5/8” 1 20 24 23 3 11 12 17 21 15 19 16 22 25 26 27 14 3-1/2” liner cemented in place 4 6 5 8 7 9 Beluga F Beluga G Beluga H Beluga K Beluga C Beluga E Beluga J R X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” Conductor Welded 19.100” 45’ 400’ 9-5/8” 40 L-80 BTCM 8.835” 48.6’ 4,536’ 7” 26 L-80 BTCM 6.276” 44.8’ 9,301’ TUBING DETAIL 4-1/2” 12.60 L-80 IBTM 3.958” Surface ±350’ 3-1/2” 9.2 L-80 IBT 2.992”±350’±6,205’ 3-1/2” 9.2 L-80 8RD 2.992”±6,205’±7,379’ GRAVEL PACK 4” 11.00 P-110 SLHT 3.430” 7,426’ 8,805’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 ±350’±350’ 3.813 5.570 Nipple, Camco BP-6i Landing - Camco 3.813” WRDP, DB Lock 2 ±360’±360’ 4-1/2” x 3-1/2” Crossover 3 ±1,825’±1,750’ 2.867” 5.313” GLM#1 - SPM – 1 IPOC-1 20/64” ±3,785’±3,000’ 2.867” 5.313” GLM#2 - SPM – 1 IPOC-1 20/64” ±5,277’±3,900’ 2.867” 5.313” GLM#3 - SPM – 1 IPOC-1 20/64” ±6,073’±4,450’ 2.867” 5.313” GLM#4 - SPM – 1 Orifice 20/64” 4 ±6,104’±4,476’ 2.867” 5.313” Chemical Injection Mandrel 5 ±6,175’±4,538’ 3.000” 6.000” Packer - Hydraulic Retrievable 6 ±6,185’±4,547’ 2.813” 3.750” X-Nipple 7 ±6,205’±4,565’ 2.992” 3.500” Dummy Seal Bore Assembly 8 ±6,205’±4,565’ 4.176” 5.924”ZXP Liner Top Packer with 10’ extension and Liner Hanger 9 ±7,379’±5,701’ Landing Collar and Float Assembly 11 7,399’ 5,721’ 3.450 4.000 Packer, Sump, Baker SC-2 12 7,424 5,745’ 3.250 4.530 Nipple, R - PR Plug set in R profile with 4’ Catcher on top 13 7,425’ 5,746’ 3.260 5.000 Snap Latch 14 7,426’ 5,747’ 3.260 3.980 Seal Unit 15 7,426’ 5,747’ 4.000 6.000 Packer, Baker SC-2 70B-40 7,430’ 5,752’ 3.260 Mule Shoe 16 7,434’ 5,755’ 4.000 5.560 Seal Bore 17 7,458’ 5,779’ 3.430 5.650 KOIV Isolation Sleeve 7,464’ 5,785’ 3.430 Sub, Shear Out Safety 18 7,481’ 5,802’ 0.000 Plug, Baker IBP 7,487’ 5,808’ 3.430 5.800 Screen, Bakerweld 10 ga. 19 7,715’ 6,037’ 3.250 5.000 Seal Bore receptacle 7,719’ 6,040’ 3.430 5.800 Screen, Bakerweld 10 ga. 20 8,007’ 6,327’ 3.250 5.000 Seal Bore receptacle 8,010’ 6,330’ 3.430 5.800 Screen, Bakerweld 10 ga. 21 8,318’ 6,637’ 3.250 5.000 Seal Bore receptacle 8,320’ 6,639’ 3.430 5.800 Screen, Bakerweld 10 ga. 22 8,540’ 6,858’ 3.250 4.490 Seal Bore receptacle 8,543’ 6,861’ 3.430 5.800 Screen, Bakerweld 10 ga. 23 8,613’ 6,932’ 3.250 4.490 Seal Bore receptacle 8,616’ 6,934’ 3.430 5.800 Screen, Bakerweld 10 ga. 24 8,796’ 7,114’ 3.260 5.000 Snap Latch 82-40 S-22B 25 8,797’ 7,115’ 4.000 5.850 Packer, Sump, FS 26 8,801’ 7,119’ 4.890 5.510 Mule Shoe, 5-1/2”, 23#, L-80 27 8,991’ 7,308’ 0.000 Plug, Baker CIBP Note: 8/21/11 Gravel Pack (M thru U) 27304 lbs. 20/40 sand, 65.9 lbs/ft perfs @ 10.1 BPM, 33% returns CMiT to 1500 psi Updated by: KK 2020-04-03 SCHEMATIC Tyonek Platform Well: A-16 Last Completed: Future PTD: 208-98 API: 50-883-200127-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt spf Comments Beluga B ±6,361’ ±6,366’ ±4,709’ ±4,713’ 5’ Isolate / Re-Perf Beluga B ±6,366’ ±6,386’ ±4,713’ ±4,732’ 20’ Isolate / Re-Perf Beluga B ±6,427’ ±6,434’ ±4,770’ ±4, 777’ 7' Isolate / Re-Perf Beluga C ±6,467’ ±6,475’ ±4,808’ ±4, 816’ 8’ Isolate / Re-Perf Beluga E ±6,642’ ±6,655’ ±4,976’ ±4,988’ 13’ Isolate / Re-Perf Beluga E ±6,663’ ±6,671’ ±4,996’ ±5,004’ 8’ Isolate / Re-Perf Beluga E ±6,755’ ±6,776’ ±5,085’ ±5,105’ 21’ Isolate / Re-Perf Beluga F ±6,806’ ±6,814’ ±5,135’ ±5,142’ 8’ Isolate / Re-Perf Beluga F ±6,846’ ±6,856’ ±5,173’ ±5,183’ 10’ Isolate / Re-Perf Beluga F ±6,846’ ±6,876’ ±5,173’ ±5,202’ 30’ Isolate / Re-Perf Beluga G ±6,911’ ±6,941’ ±5,237’ ±5,266’ 30’ Isolate / Re-Perf Beluga H ±7,038’ ±7,046’ ±5,362’ ±5,370’ 8’ Isolate / Re-Perf Beluga H ±7,046’ ±7,066’ ±5,370’ ±5,389’ 20’ Isolate / Re-Perf Beluga H ±7,125’ ±7,133’ ±5,448’ ±5,456’ 8’ Isolate / Re-Perf Beluga J ±7,289’ ±7,301’ ±5,651’ ±5,623’ 12’ Isolate / Re-Perf Beluga J ±7,329’ ±7,337’ ±5,651’ ±5,659’ 8’ Isolate / Re-Perf Beluga K ±7,364’ ±7,382’ ±5,686’ ±5,704’ 18’ Isolate / Re-Perf Beluga M 7,500’ 7,524’ 5,821’ 5,845’ 24’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga O 7,677’ 7,694’ 5,998’ 6,015’ 17’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga P 7,797’ 7,810’ 6,117’ 6,130’ 13’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,880’ 7,885’ 6,200’ 6,205’ 5’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,912’ 7,922’ 6,232’ 6,242’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,946’ 7,978’ 6,266’ 6,298’ 32’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga Q 7,958’ 7,978’ 6,278’ 6,298’ 20’ 6 1/31/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga S 8,278’ 8,284’ 6,597’ 6,603’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,291’ 8,300’ 6,610’ 6,619’ 9’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,291’ 8,300’ 6,610’ 6,619’ 9’ 6 1/31/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga T 8,414’ 8,424’ 6,733’ 6,743’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga T 8,464’ 8,490’ 6,783’ 6,809’ 26’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,517’ 8,523’ 6,836’ 6,841’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,564’ 8,576’ 6,882’ 6,894’ 12’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,565’ 8,571’ 6,883’ 6,889’ 6’ 6 1/29/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga U 8,587’ 8,593’ 6,905’ 6,911’ 6’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,709’ 8,724’ 7,027’ 7,042’ 15’ 6 1/26/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Beluga U 8,709’ 8,724’ 7,027’ 7,042’ 15’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,734’ 8,741’ 7,052’ 7,059’ 7’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,746’ 8,756’ 7,064’ 7,074’ 10’ 14 2/10/09 HES 4-5/8” SH BELOW PLUG Beluga U 8,767’ 8,771’ 7,085’ 7,089’ 4’ 14 1/26/09 3-1/8” Hi Vol PowerFrac 3106-20 1g. chrg BELOW PLUG Tyonek Platform A-16 Current 03/13/2020 Valve, Master, WKM-M, 4 1/16 5M FE, HWO, DD trim Valve, Swab, WKM-M 4 1/16 5M FE, HWO, DD trim BHTA, Otis, 4 1/16 5M FE x 9 1/2 Otis quick union top Valve, Wing, SSV, WKM-M, 4 1/16 5M FE, HWO, w/ 15'͛operator, DD trim Valve, Wing, WKM-M, 4 1/16 5M FE, HWO, DD trim Vetco Gray, MB-230 system, 11'͛5M top 28'͛ 9 5/8'͛ 7'͛ 4 ½͛͛ Tyonek Platform A-16 28 x 9 5/8 x 7 x 4 ½ Tubing hanger, Vetco-230, 11 x 4 ½ IBT susp x 4.909 MCA lift threads, 4'͛type H BPV profile, 2- CCL ports, flex neck Valve, Master, SSV, WKM- M, -4 1/16 5M FE, w/ 15'͛ oper, DD trim Tyonek Platform A-16 Proposed 03/13/2020 Valve, Master, WKM-M, 4 1/16 5M FE, HWO, DD trim Valve, Swab, WKM-M 4 1/16 5M FE, HWO, DD trim BHTA, Otis, 4 1/16 5M FE x 9 1/2 Otis quick union top Valve, Wing, SSV, WKM-M, 4 1/16 5M FE, HWO, w/ 15'͛operator, DD trim Valve, Wing, WKM-M, 4 1/16 5M FE, HWO, DD trim Vetco Gray, MB-230 system, 11'͛5M top 28'͛ 9 5/8'͛ 7'͛ 4 ½͛͛ Tyonek Platform A-16 28 x 9 5/8 x 7 x 4 ½ Tubing hanger, Vetco-230, 11 x 4 ½ IBT susp x 4.909 MCA lift threads, 4'͛type H BPV profile, 2- CCL ports, flex neck Valve, Master, WKM-M, 4 1/16 5M FE, HWO, DD trim Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: N Cook Inlet Unit A-16 (PTD 208-098)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date STATE OF ALASKA RECEIVED ALL OIL AND GAS CONSERVATION COMWION REPORT OF SUNDRY WELL OPERATIONS OCT 3 0 2017 1.Operations Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 6 e i r.on 0 Performed: Suspend ❑ Perforate CI Other Stimulate ❑ Alter Casing❑ Change Approved `ro. am ❑ Plug for Redrill 0 Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: 0 1 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 208-098 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service El 6.API Number: Anchorage,AK 99503 50-883-20127-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0017589/ADL0037831 N Cook Inlet Unit A-16 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A North Cook Inlet Field/Tertiary Gas Pool 11.Present Well Condition Summary: Total Depth measured 9,314 feet Plugs measured 7,424/7,481/ feet 8.991 true vertical 7,631 feet Junk measured N/A feet Effective Depth measured 7,424 feet Packer measured See Schematic feet true vertical 5,745 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural Conductor 400' 30' 400' 100' Surface 4,536' 9-5/8" 4,536' 3,457' 5,750 psi 3,090 psi Intermediate Production 9,301' 7" 9,301' 7,619' 7,240 psi 5,410 psi Liner Perforation depth Measured depth 6,361 -8,771 feet True Vertical depth 4,709-7,089 feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 6,292(MD) 4,644(TVD) Packers and SSSV(type,measured and true vertical depth) See Schematic 12.Stimulation or cement squeeze summary: Intervals treated(measured): _ Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 692 15 232 53 Subsequent to operation: 0 894 1 693 234 14.Attachments(required per 20 AAc 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Cl Exploratory 0 DevelopmentE Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas 0 WDSPL❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-450 Authorized Name: Stan W.Golis Contact Name: Joe Kaiser Authorized Title: Operations`Manager Contact Email: jkaiSer@hilcorp.com Authorized Signature: LLw Date: % (SO/ t 1 Contact Phone: (907)777-8393 Form 10-404 Revised 4/2017 /11. 1' DMS w Nov - 2 2017 Submit Original Only • • Tyonek Platform Well:A-16 SCHEMATIC Completed:5/19/2009 PTD: 208-098t 1 ileorp Alaska,LLC API: 50-883-20127-00 RKB to TBG Head-42.6' CASING DETAIL I Size Wt Grade Conn ID Top Btm 1 30" Conductor Welded 19.100" 45' 400' 20` 9 5/8" 40 L-80 BTCM 8 835" 48.6' 4,536' 7" 26 L-80 BTCM 6.276" 44.8' 9,301' 2 , TUBING DETAIL 3 4-1/2" 12.60 L-80 IBTM 3.958" 42.6' 6,292' GRAVEL PACK 4 lii 4" 11.00 P-110 SLHT 3.430" 7,426' 8,805' J 9-5/8" I a 5 JEWELRY DETAIL 6 5No Depth Depth ID OD Item (MD) (TVD) X 503' 3.813 5.570 Nipple,Camco BP-6i Landing-Camco 3.813" 1 503' WRDP,DB Lock 8 2 Z 2 1,747' 1689' 3.813 5.000 GLM#1 Camco KBG-2-1R DV 0 3 3,259' 2692' 3.813 5.000 GLM#2 Camco KBG-2-1R DV 9 g 4 4,432' 3,393' 3.813 5.000 GLM#3 Camco KBG-2-1R DV 5 5,266' 3,894' 3.938 5.000 GLM#4 Camco KBG-2-1R DV 10 H 6 6,160' 4,525' 3.813 5.980 GLM#5 Camco KBG-2-1R OPEN 7 6,208' 4,568' 3.813 5.000 Nipple,X - -7-'-' 8 6,251' 4,607' 3.890 5.980 Packer,Baker Premier 9 6,279' 4,632' 3.750 5.560 Nipple,DB Landing 10 6,290' 4,643' 3.930 5.000 Wireline Entry Guide 11 7,399' 5,721' 3.450 4.000 Packer,Sump,Baker SC-2 11 12 7,424 5,745' 3.250 4.530 Nipple,R PR Plug set in R profile with 4'Catcher on top 1 ®R 12 ' 13 7,425' 5,746' 3.260 5.000 Snap Latch 13 14 14 7,426' 5,747' 3.260 3.980 Seal Unit 15 rr _- _..mow`.` 15 7,426' 5,747' 4.000 6.000 Packer,Baker SC-2 70B-40 `l`--116 7,430' 5,752' 3.260 Mule Shoe 17 Doo 16 7,434' 5,755' 4.000 5.560 Seal Bore 18 •,;•st= 17 7,458' 5,779' 3.430 5.650 KOIV Isolation Sleeve ' MI { 7,464' 5,785' 3.430 Sub,Shear Out Safety 18 7,481' 5,802' 0.000 Plug,Baker IBP 7,487 5,808' 3.430 5.800 Screen,Bakerweld 10 ga. 19 19 7,715' 6,037' 3.250 5.000 Seal Bore receptacle 7,719' 6,040' 3.430 5.800 Screen,Bakerweld 10 ga. 20 8,007' 6,327' 3.250 5.000 Seal Bore receptacle 20 8,010' 6,330' 3.430 5.800 Screen,Bakerweld 10 ga. : 21 8,318' 6,637' 3.250 5.000 Seal Bore receptacle 8,320' 6,639' 3.430 5.800 Screen,Bakerweld 10 ga. 21 22 8,540' 6,858' 3.250 4.490 Seal Bore receptacle v 8,543' 6,861' 3.430 5.800 Screen,Bakerweld 10 ga. 23 8,613' 6,932' 3.250 4.490 Seal Bore receptacle -; 22 8,616' 6,934' 3.430 5.800 Screen,Bakerweld 10 ga. 24 8,796' 7,114' 3.260 5.000 Snap Latch 82-40 S-22B _:=7. 25 8,797' 7,115' 4.000 5.850 Packer,Sump,FS L ° 26 8,801' 7,119' 4.890 5.510 Mule Shoe,5-1/2",23#,L-80 27 8,991' 7,308' 0.000 Plug,Baker CIBP Note:8/21/11 Gravel Pack(M thru U)27304 lbs.20/40 sand,65.9 lbs/ft perfs @ 10.1 BPM,33%returns Ilmi 24 25 ;L' 'Y 26 27 .`., 7" , ; >,i_.."'' ;% P BTD:8,991' TD:9,314' Updated By:JLL 2017-10-27 H . • Tyonek Platform Well:A-16 SCHEMATIC Last Completed:5/19/2009 PTD:208-98 Hilcorp Alaska,LLC API: 50-883-200127-00 PERFORATION DETAIL Top Btm Top Btm Zone (MD) (MD) (ND) (ND) Amt spf Comments Beluga B 6,361' 6,366' 4,709' 4,713' 5' 6 6/22/09 2-7/8"HSD PJ Omega Max,60 phase OPEN Beluga B 6,366' 6,386' 4,713' 4,732' 20' 6 6/22/09 2-7/8"HSD PJ Omega Max,60 phase OPEN Beluga B 6,427' 6,434' 4,770' 4,777' 7' 6 6/22/09 2-7/8"HSD PJ Omega Max,60 phase OPEN Beluga C 6,467' 6,475' 4,808' 4,816' 8' 6 6/22/09 2-7/8"HSD PJ Omega Max,60 phase OPEN Beluga E 6,642' 6,655' 4,976' 4,988' 13' 6 6/21/09 2-7/8"HSD PJ Omega 6 OPEN Beluga E 6,663' 6,671' 4,996' 5,004' 8' 6 6/21/09 2-7/8"HSD PJ Omega 6 OPEN Beluga E 6,755' 6,776' 5,085' 5,105' 21' 6 6/21/09 2-7/8"HSD PJ Omega 6 OPEN Beluga F 6,806' 6,814' 5,135' 5,142' 8' 6 6/21/09 2-7/8"HSD PJ Omega 6 OPEN Beluga F 6,846' 6,856' 5,173' 5,183' 10' 6 6/21/09 2-7/8"HSD P1 Omega 6 OPEN Beluga F 6,846' 6,876' 5,173' 5,202' 30' 6 6/20/09 2-7/8"HSD PJ Omega 6 OPEN Beluga G 6,911' 6,941' 5,237' 5,266' 30' 6 6/20/09 2-7/8"HSD PJ Omega 6 OPEN Beluga H 7,038' 7,066' 5,362' 5,389' 28' 6 6/9/09 2-7/8"HSD PJ Omega 6 OPEN Beluga H 7,046' 7,066' 5,370' 5,389' 20' 6 6/9/09 2-7/8"HSD PJ Omega 6 OPEN Beluga H 7,125' 7,133' 5,448' 5,456' 8' 6 10/06/17-2-3/4"GG&8'2-7/8"6 SPF Beluga J 7,289' 7,337' 5,651' 5,659' 48' 6 6/9/09 2-7/8"HSD PJ Omega 6 OPEN Beluga J 7,329' 7,337' 5,651' 5,659' 8' 6 6/9/09 2-7/8"HSD PJ Omega 6 OPEN Beluga K 7,364' 7,382' 5,686' 5,704' 18' 6 6/8/09 2-7/8"HSD PJ Omega 6 OPEN Beluga M 7,500' 7,524' 5,821' 5,845' 24' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga 0 7,677' 7,694' 5,998' 6,015' 17' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga P 7,797' 7,810' 6,117' 6,130' 13' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga Q 7,880' 7,885' 6,200' 6,205' 5' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga Q 7,912' 7,922' 6,232' 6,242' 10' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga Q 7,946' 7,978' 6,266' 6,298' 32' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga Q 7,958' 7,978' 6,278' 6,298' 20' 6 1/31/09 3-1/8"Hi Vol PowerFrac 3106-20 1g.chrg BELOW PLUG Beluga S 8,278' 8,284' 6,597' 6,603' 6' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga T 8,291' 8,300' 6,610' 6,619' 9' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga T 8,291' 8,300' 6,610' 6,619' 9' 6 1/31/09 3-1/8"Hi Vol PowerFrac 3106-20 1g.chrg BELOW PLUG Beluga T 8,414' 8,424' 6,733' 6,743' 10' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga T 8,464' 8,490' 6,783' 6,809' 26' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga U 8,517' 8,523' 6,836' 6,841' 6' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga U 8,564' 8,576' 6,882' 6,894' 12' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga U 8,565' 8,571' 6,883' 6,889' 6' 6 1/29/09 3-1/8"Hi Vol PowerFrac 3106-20 1g.chrg BELOW PLUG Beluga U 8,587' 8,593' 6,905' 6,911' 6' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga U 8,709' 8,724' 7,027' 7,042' 15' 6 1/26/09 3-1/8"Hi Vol PowerFrac 3106-20 1g.chrg BELOW PLUG Beluga U 8,709' 8,724' 7,027' 7,042' 15' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga U 8,734' 8,741' 7,052' 7,059' 7' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga U 8,746' 8,756' 7,064' 7,074' 10' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga U 8,767' 8,771' 7,085' 7,089' 4' 14 1/26/09 3-1/8"Hi Vol PowerFrac 3106-20 1g.chrg BELOW PLUG Updated by: JLL 2017-10-27 • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NCI A-16 W/L& E/L 50-883-20127-00 208-098 10/2/17 10/9/17 Daily Operations: 10/02/2017- Monday JSA/TGSM. RIG UP. STAND BY FOR WIND. RE-BUILD W/L VALVES. (P/T 2500PSI GOOD) ISOLATE C-LINE. RIH W/4" GS TO 500KB W/T LATCH AND PULL A-STOP. POOH. RIH W/4"PRS W/PRONG TO 502KB LATCH, BLEED C-LINE OFF, PULL SSSV, POOH. RIH W/3.71" 7' DUMMY GUN TO (SEE FL @4780KB) 6883KB W/T FALL 7090KB W/T 7103KB. LOST SPANG ACTION BUT NOT VERY STICKY. POOH, SEE CLAY IN SPANGS. OOH C/O STEM FOR 1 3/4. RIH W/1 3/4 DD BAILER TO 6852'KB, W/T FALL THROUGH TO 71231KB W/T 7155KB POOH. OOH W/BAILER FULL OF CLAY/MUD. RIH W/3" 6' DD BAILER ON 3.23 SWEG TO 71211KB W/T 7145KB POOH. FULL SAND. OOH, LAY DOWN FOR NIGHT. 10/03/2017-Tuesday JSA/TGSM. CHECK TOOL STRING, RE HEAD. STAND BY FOR CRANE. RIG UP RIH W/3" 6' DD BAILER ON 3.23 CEN TO (SEE FL @4700KB) 6866KB W/T FALL TO 7108KB, W/T 7130KB POOH. RIH W/3" 6' DD BAILER ON 3.23 CEN TO 7133KB W/T FALLS IN LAST TAG 7120KB POOH. 1/2 FULL SAND AND SOME COAL. RIH W/3" 6' DD BAILER ON 3.23 CEN TO 7120' W/T FALL THROUGH TO 7150' KB, W/T 7155'KB. POOH, FULL BAILER SAND. RIH W/3" 6' DD BAILER 3.23 TO 7157KB W/T 7158KB POOH, FULL SAND. OOH,ADD K-JAR BETWEEN STEM, PUT KJ ABOVE BAILER, REMOVE CENT. RIH W/3" 6' DD BAILER TO 7148'KB, W/T 7160'KB POOH FULL SAND. RIH W/3" DD BAILER TO 7157KB W/T 7166KB POOH FULL SAND. RIH W/3" DD BAILER TO 7163KB W/T 7165KB POOH FULL SAND. RIH W/3" DD BAILER TO 7157 W/T 7168KB POOH, FULL SAND. RIH W/3" DD BAILER TO 7170KB W/T LOST HOLE 7167KB POOH FULL SAND. RIH W/3.56 G-RING 7167KB W/T TO SCRAPE WALLS POOH. RIH W/3.71 7' DUMMY GUN TO (SEE FL @3750KB) 7169KB TAG FILL POOH. OOH, RIG DOWN. RIG UP E-LINE TO PERF. 10/04/2017-Wednesday JSA/TGSM. CHECK TOOL STRING RE-HEAD. RIH W/3" DD BAILER TO 7106KB W/T 7112KB, POOH, OOH WI FULL SAND. RIH W/3" DD BAILER TO 7101KB, W/T 7120'KB POOH, OOH W/ FULL SAND. RIH W/3" DD BAILER TO 7117KB W/T 7121KB POOH FULL SAND. RIH W/3" DD BAILER TO 7123KB W/T 7130KB POOH W/EMPTY. FIX BOTTOM, RIH W/3" DD BAILER TO 7127KB W/T 7131KB POOH OOH FULL MUD. RIH W 3" DD BAILER TO 7127KB W/T 7134KB POOH FULL MUD. RIH W/3" DD BAILER TO 7138KB W/T FALLS IN. PULL FREE TAG 7132KB POOH FULL SAND. RIH W/3" DD BAILER TO 7121'KB W/T FALL TO 7137'KB W/T LAST TAG 7138KB, POOH FULL SAND. RIH W/3" DD BAILER TO 7139KB W/T LOSE HOLE 7137KB, POOH FULL MUD.TAKE OFF KJ, RIH W/3" DD BAILER TO 7144KB W/T. CAN WORK DOWN TO 7160, POOH SET BACK DOWN 7144'KB, POOH FULL MUD. PUT KJ BACK ON BOTTOM OF SJ. RIH W/3" DD BAILER TO 7143KB W/T 7145KB POOH EMPTY. 1 CHUNK OF COAL JAMMED BALL BOTTOM. CHANGE BACK TO FLAPPER. RIH W/3" DD BAILER TO 7149KB W/T 7155KB POOH, OOH FULL SAND. RIH W/3" DD BAILER TO 7159'KB W/T 7166'KB POOH. RIH W/3.9" BRAIDED LINE BRUSH TO 7159KB W/T 7162KB. RIH W/3" DD BAILER TO 7163' KB W/T POOH, OOH W/ FULL SAND. RIH W/3" DD BAILER TO 7164KB W/T 7170KB POOH, OOH W/ FULL SAND. RIH W/6' BY 3.71 DD DUMMY GUN TO 7164KB TAG PULL'1500LB TO 7030KB ABOUT 20 FPM. RE TAG 7159KB POOH (SEE FL @4430KB). OOH RIG DOWN. RIG Up E-LINE. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NCI A-16 W/L& E/L 50-883-20127-00 208-098 10/2/17 10/9/17 Daily Operations: 10/05/2017-Thursday RIG UP E-LINE PRESSURE UP TUBING TO 200PSI W/GAS. RIH with 3 1/8" GG & 12' of 3 3/8" 6spf(loaded in 20' carrier).Tag sand at 7093' worked it and could not make any hole. POOH - 2100#when pulling off bottom. JSA/TGSM. TALK W/TOWN DECIDE TO RUN SMALLER GUNS. SEND FOR TOOLS. OSK ON WEATHER HOLD. RE HEAD, CHECK TOOL STRING, RE DRESS SSSV. OFF WEATHER HOLD.TOOLS ARRIVE, RIG UP E-LINE W/10' OF 2-7/8" GUNS. Rig Up E-LINE. RIH with 2 3/4" GG & 8' of 2 7/8" 6spf(loaded in 10' carrier).Tag sand at 7099' worked it down to 7105' and could not make any more hole. POOH. RIG DOWN E-LINE. RIG UP W/LINE. RIH W/3" BY 7' DD BAILER TO 3730KB, FALLING SLOW, POOH, PULLING HEAVY. OOH TOOLS, COVERED IN E-LINE GREASE DROP 15 GAL OF DIESEL. RIH W/3" DD BAILER TO 7124KB W/T, POOH, OOH FULL SAND. RIH W/3" DD BAILER TO 7125'KB W/T 7134'KB, POOH, SET BACK DOWN @ 7126'KB. POOH, OOH W/FULL BAILER. RIH/W 3" DD BAILER TO 7127KB W/T 7129'KB POOH, OOH W/ FULL SAND. RIH W/3" DD BAILER TO 7130'KB, W/T 7133'KB, POOH. OOH W/FULL SAND. 10/06/2017 Friday Rig up. RIH with 2 3/4" GG &8' of 2 7/8" 6spf(loaded in 10' carrier). Perf Depth 7125' to 7133' (8' from CCL to top shot). CCL Depth 7117', Send log to town for engineer review. Pressured up tubing to 760psig. Approval from town. Perf- POOH - pulled 2600#to get gun moving- pulled heavy for 70' then pulled freely. POOH.All shots fired. Rig down E-line. 10/07/2017-Saturday No operations to report. 10/08/2017-Sunday No operations to report. 10/09/2017- Monday ARRIVE ON PLATFORM JSA/TGSM. RIG UP, SHUT IN WELL. P/T 2200PSI GOOD. RIH W/4" BRAIDED LINE BRUSH TO 501KB. BRSH SSSV PROFILE, BRUSH PROFILE 30X, POOH. RIH W/SSSV ON 4" PRS TO W/T 39KB CAN'T PASS POOH. ADD KJ BELOW Si. RIH W/SSSV ON 4" PRS TO 39KB W/T CAN'T PASS, POOH, SAND PACKING. RIH W/SSSV ON 4" PRS TO 39KB W/T CAN'T PASS, POOH, SAND PACKING. RIH W/SSSV ON 4" PRS TO 39KB W/T CAN'T PASS, POOH, ROLLED PACKING, REBUILD. RIH W/SSSV ON 4" PRS TO 39KB W/T CAN'T PASS, POOH SAND PACKING. RIH W/SSSV ON 4" PRS TO 39KN W/T FALL 301KB W/T FALL 475KB. PURGE C-LINE W/STOP, LEAK 501KB, SET SSSV SLOWLY. WALK C-LINE UP TO 800PS1 W/T AS WE STEP UP PSI. RIH W/Z-6 W/PINNED TATTLETALE TP 501KB W/T CLOSE LOCK. POOH, PIN NOT SHEARED. RIH W/Z-6 W/PINNED TATTLETALE TP 501KB W/T CLOSE LOCK. POOH, PIN SHEARED. RIH W/A-STOP ON 4" GS TO 500KB W/T SET STOP, POOH. OOH LAY DOWN FOR NIGHT LET PACKING SWELL BEFORE TESTING.TEST GOOD. • v. OF 7.4F S w\�\ 1yy, cp THE • STATE Alaska Oil and Gas F�►'ti� �, ofLASKA Conservation Commission 2_. _- 333 West Seventh Avenue ' '' h, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 pFA ,S�Q• Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager �� Noy 0 20 7, Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: North Cook Inlet Field, Tertiary Gas Pool,NCIU A-16 Permit to Drill Number: 208-098 Sundry Number: 317-450 Dear Mr. Golis: 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, tX20 Hollis S. French Chair DATED this 23 day of September, 2017. RBDMS OCT - 3 2017 • • RECEIVED STATE OF ALASKA SEP 2 2 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 0 ` Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 2 ' 208-098 ' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-883-20127-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 68 • Will planned perforations require a spacing exception? Yes ❑ No 0 / N Cook Inlet Unit A-16 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017589/ADL0037831 North Cook Inlet Field/Tertiary Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9,314 , 7,631 . 7,424 . 5,745 1,050 psi 7,424;7,481 &8,991 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 400' 30" 400' 400' Surface 4,536' 9-5/8" 4,536' 3,457' 5,750 psi 3,090 psi Intermediate Production 9,301' 7" 9,301' 7,619' 7,240 psi 5,410 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6,361 -8,771 • 4,709-7,089 4-1/2" )12.6#/L-80 6,292 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Packers(x4)See Schematic&Camco BP-6i Landing Nipple I Packers(x4)See Schematic&Camco BP-6i Landing Nipple 503(MD)503(TVD) 12.Attachments: Proposal Summary 0 Wellbore schematic 2 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 2 ' Service ❑ 14.Estimated Date for • 15.Well Status after proposed work: Commencing Operations: 10/6/2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 , WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W.Golis Contact Name: Joe Kaiser Authorized Title: Operations Manager Contact Email:jkaiser(Dhilcorp.com Authorized Signature: "NItet4 Date: 1.1.3.01 1 Contact Phone: (907)777-8393 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3t-'-4{50 Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDIVIS �_L OCTs — 97 Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /O-- 1 09 l APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 9 (Z,i ICR- PM ��C) 1'4' IpNaA L. aIidvl'V-1chSubmit Form and Form 10 ao a ed 201 for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: Tyonek A-16 Hilcorp Alaska,LLQ Date:9/22/2017 Well Name: Tyonek A-16 API Number: 50-883-20127-00 Current Status: Active Gas Well Leg: N/A Estimated Start Date: October 6th, 2017 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 208-098 First Call Engineer: Joe Kaiser (907)777-8393 (0) (907) 952-8897 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907)-398-9904 (M) AFE Number: Current Bottom Hole Pressure: 1,621 psi @ 5,702' TVD (Static Build up 9/13/2017) Max. Potential Surface Pressure: 1,050 psi (Based on 0.1 psi/ft gas gradient) Brief Well Summary NCIU A-16 was drilled in late 2008 and completed in 2009 to target the Beluga B—U Sands.The well was drilled to a depth of 9,314'. Hydraulic fracs were completed in the Beluga Q—U sands early 2009 with gravel packs. This well produced from 2009—2010 when it was shut-in. In September 2017, a static build-up pressure was completed and GLVs installed to unload well. The purpose of this work/sundry is to add perforations in Beluga H Sand. / Notes Regarding Wellbore Condition • Tagged at 6,163' WLM on 9-13-2017. Procedure: 1. MIRU wireline, PT lubricator to 2,000 psi Hi 250 Low. 2. RIH pull SSSV. POOH. LD SSSV 3. RIH with 3.5" GR to bottom. POOH. Note: confirm water level. 4. RU 3-3/8" 6 spf wireline guns. 5. RIH and perforate the following intervals: Zone Sands (MD) Btm (MD) FT SPF Beluga H ±7,120' ±7,140' 20' 6 a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using Correlation Log. d. Use Gamma/CCL to correlate. Utilize Press/Temp tool if available. e. Record tubing pressures before and after each perforating run. 6. RIH w/SSSV and set in profile. 7. RD wireline. 8. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic • • • Well:A-16 Tyonek PlatformII i SCHEMATIC Last Completed:5/19/2009 PTD: 208-098 Hikora Alaska,LLC API: 50-883-20127-00 RKB to TBG Head-42.6' CASING DETAIL r ,•' Size Wt 40 Grade Conn ID Top Btm 30" 9-5 8" Conductor Welded L-8 19.100" 45' 400' 20 / 0 BTCM 8.835" 48.6' 4,536' ;. - ` • 7" 26 L-80 BTCM 6.276" 44.8' 9,301' Sxl" • 2 TUBING DETAIL '7' .1-.0:3 "n 4-1/ 2" 12.60 L-80 IBTM 3.958" 42.6' 6,292' 4 $. ' GRAVEL PACK . + 4 k !b *�.,-, 4" 11.00 P-110 SLHT 3.430" 7,426' 8,805' 9-5/8" 4,*. I .� s s p JEWELRY DETAIL s . , No Depth Depth ID OD Item (MD) (TVD) X.! 503' 3.813 5.570 Nipple,Camco BP-6i Landing-Camco 3.813" 1 503' WRDP,DB Lock 8 x 2 1,747 1689' 3.813 5.000 GLM#1 Camco KBG-2-1R DV "-- 3 3,259' 2692' 3.813 5.000 GLM#2 Camco KBG-2-1R DV "' 9 16 4 4,432' 3,393' 3.813 5.000 GLM#3 Camco KBG-2-1R DV 5 5,266' 3,894' 3.938 5.000 GLM#4 Camco KBG-2-1R DV 0 6 6,160' 4,525' 3.813 5.980 GLM#5 Camco KBG-2-1R OPEN �� 7 6,208' 4,568' 3.813 5.000 Nipple,X .--,- 8 6,251' 4,607' 3.890 5.980 Packer,Baker Premier 9 6,279' 4,632' 3.750 5.560 Nipple,DB Landing 10 6,290' 4,643' 3.930 5.000 Wireline Entry Guide --r 11 7,399' 5,721' 3.450 4.000 Packer,Sump,Baker SC-2 11 '* - 12 7,424 5,745' 3.250 4.530 Nipple,R-PR Plug set in R profile with 4'Catcher ' on top 1314®R 12 • 13 7,425' 5,746' 3.260 5.000 Snap Latch 14 14 7,426' 5,747' 3.260 3.980 Seal Unit 15 j a' 15 7,426' 5,747' 4.000 6.000 Packer,Baker SC-2 70B-40 I MI6 7,430' 5,752' 3.260 Mule Shoe _- 17 M 16 7,434' 5,755' 4.000 5.560 Seal Bore _� 18 17 7,458' 5,779' 3.430 5.650 KOIV Isolation Sleeve ," 7,464' 5,785' 3.430 Sub,Shear Out Safety ;;; . r 18 7,481' 5,802' 0.000 Plug,Baker IBP •• _ 7,487' 5,808' 3.430 5.800 Screen,Bakerweld 10 ga. 1s 19 7,715' 6,037' 3.250 5.000 Seal Bore receptacle _ :::: 7,719' 6,040' 3.430 5.800 Screen,Bakerweld 10 ga. .••• 20 8,007' 6,327' 3.250 5.000 Seal Bore receptacle a.,'20 8,010' 6,330' 3.430 5.800 Screen,Bakerweld 10 ga. `,*' 21 8,318' 6,637' 3.250 5.000 Seal Bore receptacle 8,320' 6,639' 3.430 5.800 Screen,Bakerweld 10 ga. 21 22 8,540' 6,858' 3.250 4.490 Seal Bore receptacle t-•---• 8,543' 6,861' 3.430 5.800 Screen,Bakerweld 10 ga. 23 8,613' 6,932' 3.250 4.490 Seal Bore receptacle .. 8,616' 6,934' 3.430 5.800 Screen,Bakerweld 10 ga. w• 24 8,796' 7,114' 3.260 5.000 Snap Latch 82-40 5-22B 25 8,797' 7,115' 4.000 5.850 Packer,Sump,FS .-^.` 23 26 8,801' 7,119' 4.890 5.510 Mule Shoe,5-1/2",23#,L-80 27 8,991' 7,308' 0.000 Plug,Baker CIBP Note:8/21/11 Gravel Pack(M thru U)27304 lbs.20/40 sand,65.9 lbs/ft peas @ 10.1 BPM,33%returns 24 25 . '; 26 y< y •-iii •s. PBTD:8,991' TD:9,314' Updated By:JLL 2017-09-21 •II • Tyonek Platform Well:A-16 SCHEMATIC Last Completed:5/19/2009 PTD:208-98 Hilcorp Alaska,LLC API: 50-883-200127-00 PERFORATION DETAIL Top Btm Top Btm Zone (MD) (MD) (ND) (ND) Amt spf Comments Beluga B 6,361' 6,366' 4,709' 4,713' 5' 6 6/22/09 2-7/8"HSD PJ Omega Max,60 phase OPEN Beluga B 6,366' 6,386' 4,713' 4,732' 20' 6 6/22/09 2-7/8"HSD PJ Omega Max,60 phase OPEN Beluga B 6,427' 6,434' 4,770' 4,777' 7' 6 6/22/09 2-7/8"HSD PJ Omega Max,60 phase OPEN Beluga C 6,467' 6,475' 4,808' 4,816' 8' 6 6/22/09 2-7/8"HSD PJ Omega Max,60 phase OPEN Beluga E 6,642' 6,655' 4,976' 4,988' 13' 6 6/21/09 2-7/8"HSD PJ Omega 6 OPEN Beluga E 6,663' 6,671' 4,996' 5,004' 8' 6 6/21/09 2-7/8"HSD P1 Omega 6 OPEN Beluga E 6,755' 6,776' 5,085' 5,105' 21' 6 6/21/09 2-7/8"HSD PJ Omega 6 OPEN Beluga F 6,806' 6,814' 5,135' 5,142' 8' 6 6/21/09 2-7/8"HSD PJ Omega 6 OPEN Beluga F 6,846' 6,856' 5,173' 5,183' 10' 6 6/21/09 2-7/8"HSD PJ Omega 6 OPEN Beluga F 6,846' 6,876' 5,173' 5,202' 30' 6 6/20/09 2-7/8"HSD PJ Omega 6 OPEN Beluga G 6,911' 6,941' 5,237' 5,266' 30' 6 6/20/09 2-7/8"HSD P1 Omega 6 OPEN Beluga H 7,038' 7,066' 5,362' 5,389' 28' 6 6/9/09 2-7/8"HSD Pi Omega 6 OPEN Beluga H 7,046' 7,066' 5,370' 5,389' 20' 6 6/9/09 2-7/8"HSD Pi Omega 6 OPEN Beluga J 7,289' 7,337' 5,651' 5,659' 48' 6 6/9/09 2-7/8"HSD PJ Omega 6 OPEN Beluga J 7,329' 7,337' 5,651' 5,659' 8' 6 6/9/09 2-7/8"HSD P1 Omega 6 OPEN Beluga K 7,364' 7,382' 5,686' 5,704' 18' 6 6/8/09 2-7/8"HSD PJ Omega 6 OPEN Beluga M 7,500' 7,524' 5,821' 5,845' 24' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga 0 7,677' 7,694' 5,998' 6,015' 17' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga P 7,797' 7,810' 6,117' 6,130' 13' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga Q 7,880' 7,885' 6,200' 6,205' 5' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga Q 7,912' 7,922' 6,232' 6,242' 10' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga Q 7,946' 7,978' 6,266' 6,298' 32' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga Q 7,958' 7,978' 6,278' 6,298' 20' 6 1/31/09 3-1/8"Hi Vol PowerFrac 3106-20 1g.chrg BELOW PLUG Beluga S 8,278' 8,284' 6,597' 6,603' 6' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga T 8,291' 8,300' 6,610' 6,619' 9' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga T 8,291' 8,300' 6,610' 6,619' 9' 6 1/31/09 3-1/8"Hi Vol PowerFrac 3106-20 1g.chrg BELOW PLUG Beluga T 8,414' 8,424' 6,733' 6,743' 10' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga T 8,464' 8,490' 6,783' 6,809' 26' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga U 8,517' 8,523' 6,836' 6,841' 6' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga U 8,564' 8,576' 6,882' 6,894' 12' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga U 8,565' 8,571' 6,883' 6,889' 6' 6 1/29/09 3-1/8"Hi Vol PowerFrac 3106-20 1g.chrg BELOW PLUG Beluga U 8,587' 8,593' 6,905' 6,911' 6' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga U 8,709' 8,724' 7,027' 7,042' 15' 6 1/26/09 3-1/8"Hi Vol PowerFrac 3106-20 1g.chrg BELOW PLUG Beluga U 8,709' 8,724' 7,027' 7,042' 15' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga U 8,734' 8,741' 7,052' 7,059' 7' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga U 8,746' 8,756' 7,064' 7,074' 10' 14 2/10/09 HES4-5/8"SH BELOW PLUG Beluga U 8,767' 8,771' 7,085' 7,089' 4' 14 1/26/09 3-1/8"Hi Vol PowerFrac 3106-20 1g.chrg BELOW PLUG Updated by: JLL 2017-09-21 ' • • W Tyonek Platform 11 Well:A-16 PROPOSED Last Completed:5/19/2009 PTD: 208-098 Hikurp Alaska,LLC API: 50-883-20127-00 RKB to TBG Head-42.6' CASING DETAIL Size Wt Grade Conn ID Top Btm i ' 1 1 1 30" Conductor Welded 19.100" 45' 400' 20 9-5/8" 40 L-80 BTCM 8.835" 48.6' 4,536' 7" 26 L-80 BTCM 6.276" 44.8' 9,301' 2 TUBING DETAIL s '' 4-1/2" 12.60 L-80 IBTM 3.958" 42.6' 6,292' GRAVEL PACK 4 4" 11.00 P-110 SLHT 3.430" 7,426' 8,805' 9-5/$" ►, k , 5 JEWELRY DETAIL 6 ii Depth No (MD) (Depth) ID OD Item 503' 3.813 5.570 Nipple,Camco BP-6i Landing-Camco 3.813" ' 1 503' WRDP,DB Lock 8 2 1,747' 1689' 3.813 5.000 GLM#1 Camco KBG-2-1R DV 3 3,259' 2692' 3.813 5.000 GLM#2 Camco KBG-2-1R DV 9 - 4 4,432' 3,393' 3.813 5.000 GLM#3 Camco KBG-2-1R DV T' 5 5,266' 3,894' 3.938 5.000 GLM#4 Camco KBG-2-1R DV 10 6 6,160' 4,525' 3.813 5.980 GLM#5 Camco KBG-2-1R OPEN 7 6,208' 4,568' 3.813 5.000 Nipple,X 8 6,251' 4,607' 3.890 5.980 Packer,Baker Premier 9 6,279' 4,632' 3.750 5.560 Nipple,DB Landing 10 6,290' 4,643' 3.930 5.000 Wireline Entry Guide 11 7,399' 5,721' 3.450 4.000 Packer,Sump,Baker SC-2 12 7,424 5,745' 3.250 4.530 Nipple,R-PR Plug set in R profile with 4'Catcher 11 on top I i IN 13 7,425' 5,746' 3.260 5.000 Snap Latch 14 7,426' 5,747' 3.260 3.980 Seal Unit 15 li 15 7,426' 5,747' 4.000 6.000 Packer,Baker SC-2 70B-40 1.i.11 7,430' 5,752' 3.260 Mule Shoe 16 7,434' 5,755' 4.000 5.560 Seal Bore 17 7,458' 5,779' 3.430 5.650 KOIV Isolation Sleeve all '. 7,464' 5,785' 3.430 Sub,Shear Out Safety 18 7,481' 5,802' 0.000 Plug,Baker IBP 7,487' 5,808' 3.430 5.800 Screen,Bakerweld 10 ga. • 19 19 7,715' 6,037' 3.250 5.000 Seal Bore receptacle I 0 7,719' 6,040' 3.430 5.800 Screen,Bakerweld 10 ga. 20 8,007' 6,327' 3.250 5.000 Seal Bore receptacle *`•120 8,010' 6,330' 3.430 5.800 Screen,Bakerweld 10 ga. ' 21 8,318' 6,637' 3.250 5.000 Seal Bore receptacle 8,320' 6,639' 3.430 5.800 Screen,Bakerweld 10 ga. Illr 1111121 22 8,540' 6,858' 3.250 4.490 Seal Bore receptacle 8,543' 6,861' 3.430 5.800 Screen,Bakerweld 10 ga. 23 8,613' 6,932' 3.250 4.490 Seal Bore receptacle j �! 8,616' 6,934' 3.430 5.800 Screen,Bakerweld 10 ga. 24 8,796' 7,114' 3.260 5.000 Snap Latch 82-40 S-22B 25 8,797' 7,115' 4.000 5.850 Packer,Sump,FS 26 8,801' 7,119' 4.890 5.510 Mule Shoe,5-1/2",23#,L-80 27 8,991' 7,308' 0.000 Plug,Baker CIBP Note:8/21/11 Gravel Pack(M thru U)27304 lbs.20/40 sand,65.9 lbs/ft perfs @ 10.1 BPM,33%returns I MI in Li 25 271. ►„ PBTD:8,991' TD:9,314' Updated By:ILL 2017-09-21 Tyonek Platform f • Well:A-16 PROPOSED Last Completed: 5/19/2009 PTD: 208-98 Hilcorp Alaska,LLC API: 50-883-200127-00 PERFORATION DETAIL Top Btm Top Btm Zone (MD) (MD) (ND) (ND) Amt spf Comments Beluga B 6,361' 6,366' 4,709' 4,713' 5' 6 6/22/09 2-7/8"HSD PJ Omega Max,60 phase OPEN Beluga B 6,366' 6,386' 4,713' 4,732' 20' 6 6/22/09 2-7/8"HSD PJ Omega Max,60 phase OPEN Beluga B 6,427' 6,434' 4,770' 4,777' 7' 6 6/22/09 2-7/8"HSD PJ Omega Max,60 phase OPEN Beluga C 6,467' 6,475' 4,808' 4,816' 8' 6 6/22/09 2-7/8"HSD PJ Omega Max,60 phase OPEN Beluga E 6,642' 6,655' 4,976' 4,988' 13' 6 6/21/09 2-7/8"HSD PJ Omega 6 OPEN Beluga E 6,663' 6,671' 4,996' 5,004' 8' 6 6/21/09 2-7/8"HSD PJ Omega 6 OPEN Beluga E 6,755' 6,776' 5,085' 5,105' 21' 6 6/21/09 2-7/8"HSD PJ Omega 6 OPEN Beluga F 6,806' 6,814' 5,135' 5,142' 8' 6 6/21/09 2-7/8"HSD PJ Omega 6 OPEN Beluga F 6,846' 6,856' 5,173' 5,183' 10' 6 6/21/09 2-7/8"HSD PJ Omega 6 OPEN Beluga F 6,846' 6,876' 5,173' 5,202' 30' 6 6/20/09 2-7/8"HSD PJ Omega 6 OPEN Beluga G 6,911' 6,941' 5,237' 5,266' 30' 6 6/20/09 2-7/8"HSD PJ Omega 6 OPEN Beluga H 7,038' 7,066' 5,362' 5,389' 28' 6 6/9/09 2-7/8"HSD P1 Omega 6 OPEN Beluga H 7,046' 7,066' 5,370' 5,389' 20' 6 6/9/09 2-7/8"HSD PJ Omega 6 OPEN 5 Beluga H ±7,120' ±7,140' ±5,443' ±5,463' ±20' 6 Future Beluga J 7,289' 7,337' 5,651' 5,659' 48' 6 6/9/09 2-7/8"HSD P1 Omega 6 OPEN Beluga J 7,329' 7,337' 5,651' 5,659' 8' 6 6/9/09 2-7/8"HSD P1 Omega 6 OPEN Beluga K 7,364' 7,382' 5,686' 5,704' 18' 6 6/8/09 2-7/8"HSD P1 Omega 6 OPEN Beluga M 7,500' 7,524' 5,821' 5,845' 24' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga 0 7,677' 7,694' 5,998' 6,015' 17' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga P 7,797' 7,810' 6,117' 6,130' 13' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga Q 7,880' 7,885' 6,200' 6,205' 5' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga Q 7,912' 7,922' 6,232' 6,242' 10' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga Q 7,946' 7,978' 6,266' 6,298' 32' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga Q 7,958' 7,978' 6,278' 6,298' 20' 6 1/31/09 3-1/8"Hi Vol PowerFrac 3106-20 1g.chrg BELOW PLUG Beluga S 8,278' 8,284' 6,597' 6,603' 6' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga T 8,291' 8,300' 6,610' 6,619' 9' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga T 8,291' 8,300' 6,610' 6,619' 9' 6 1/31/09 3-1/8"Hi Vol PowerFrac 3106-20 1g.chrg BELOW PLUG Beluga T 8,414' 8,424' 6,733' 6,743' 10' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga T 8,464' 8,490' 6,783' 6,809' 26' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga U 8,517' 8,523' 6,836' 6,841' 6' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga U 8,564' 8,576' 6,882' 6,894' 12' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga U 8,565' 8,571' 6,883' 6,889' 6' 6 1/29/09 3-1/8"Hi Vol PowerFrac 3106-20 1g.chrg BELOW PLUG Beluga U 8,587' 8,593' 6,905' 6,911' 6' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga U 8,709' 8,724' 7,027' 7,042' 15' 6 1/26/09 3-1/8"Hi Vol PowerFrac 3106-20 1g.chrg BELOW PLUG Beluga U 8,709' 8,724' 7,027' 7,042' 15' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga U 8,734' 8,741' 7,052' 7,059' 7' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga U 8,746' 8,756' 7,064' 7,074' 10' 14 2/10/09 HES 4-5/8"SH BELOW PLUG Beluga U 8,767' 8,771' 7,085' 7,089' 4' 14 1/26/09 3-1/8"Hi Vol PowerFrac 3106-20 1g.chrg BELOW PLUG Updated by: JLL 2017-09-21 • . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. v_q.Q 2 - 0q2 Well History File Identifier 1 Organizing (done) /Two-sided 1111111111111111111 ❑ Rescan Needed III UIIIIIII1 111111 R ES AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Dis tes, No. ❑ Maps: ❑ Greyscale Items: Other, No/Type: a tip. 3.. ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Date: IF IP /s/ Al _ . Project Proofing III I vvi i p BY: Maria Date: q_fry Is, i 1 II Scanning Preparation 10 x 30 = 300 + = TOTAL PAGES 306 BY: Date: (Count does not include cover sheet) j/0 Q' // /s/ ' Production Scanning III 1111111111 Stage 1 Page Count from Scanned File: 30(3' (Count does include cover sheet) Page Count Matches Number in Scanning Pre aration: I,V NO BY: AM Date: L ac ii /s/ vki r Stage 1 If NO in stage 1, page(s) discrepancies were ound: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 1111111111 IIII ReScanned 11111E111 Mil BY: Maria Date: /s/ Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc RECEIVED • • 3 Conoco Phillips ttlain 8 riaf. CcVns. Cwitirtiission TRANSMITTAL I SKq�i�r��(sf. i f CONFIDENTIAL DATA FROM: Sandra D. Lemke, ATO1808 TO: Christine Shartzen ConocoPhillips Alaska, Inc. State of Alaska -AOGCC P.O. Box 100360 333 W. 7 Ave., Suite 100 Anchorage AK 99510 -0360 Anchorage, Alaska 99501 -3539 RE: NCI A -14, 15, 16 DATE: 5/10/2011 Transmitted: 1 North Cook Inlet Unit CDROM NCI A -14 Df 'U 3 ig(#3 } pdsview deliverables to replace large scale log prints; FE /Sonic Scanner /Microresist/MDT NCI A-15 9005 'ocY4. f ,3 pds view as above; USIT/CBE Eval/MDT 4400Mai MAY 2 3 201 INC! A -16 pdsview as above; MDT d X105 -Y3 '- 4/(03q Sign, scan and return in .pdf format if applicable to Sandra.D.Lemke& ConocoPhillips com CC: NCI A -14, 15, 16 w'Il file Receipt: Date: 6/ 5/ // )% GIS Technical Data Management 1 ConocoPhillips 1 Anchorage, Alaska 1 Ph: 907265.6947 III DATA SUBMITTAL COMPLIANCE REPORT 4/18/2011 Permit to Drill 2080980 Well Name /No. N COOK INLET UNIT A -16 Operator CONOCOPHILLIPS COMPANY API No. 50- 883 - 20127 -00 -00 MD 9314 TVD 7631 Completion Date 2/24/2009 Completion Status 1 -GAS Current Status 1 -GAS UIC N REQUIRED INFORMATION 1 Mud Log No Samples No Directional Survey Yes C.----- DATA INFORMATION Types Electric or Other Logs Run: GR /RES, USIT, Dens /Neu /MDT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr III Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments D C Asc Directional Survey 0 4498 Open 8/8/2008 'pt Directional Survey 0 4498 Open 8/8/2008 D C Asc Directional Survey 0 1120 Open 8/8/2008 PB 1 Rpt Directional Survey 0 1120 Open 8/8/2008 PB 1 ED C Asc Directional Survey 0 1168 Open 8/8/2008 PB 2 Rpt Directional Survey 0 1168 Open 8/8/2008 PB 2 D C Asc Directional Survey 0 9314 Open 10/29/2008 pt Directional Survey 0 9314 Open 10/29/2008 • C Lis 17223 Sonic 4481 9179 Case 11/28/2008 Analysis behind casing Sonic Scanner • Sonic 5 Blu 4479 9147 Open 11/28/2008 Analysis behind Casing Sonic Scanner, GR 1 •g Sonic 2 Blu 4479 9147 Open 11/28/2008 Analysis behind Casing • 1 Sonic Scanner, GR og Sonic 5 Col 4479 9147 Open 11/28/2008 Analysis behind Casing Sonic Scanner, GR Ps Cement Evaluation 5 Col 4479 9147 Case 11/28/2008 CEL, SSL, CBL, GR og Cement Evaluation 5 Col 4479 9147 Case 11/28/2008 CEL, USIT, GR Formation Tester 5 Col 4894 8722 Open 11/28/2008 Modular Formation Dynamics Tester pt LIS Verification 1420 9314 Open 12/12/2008 LIS Veri, RPD, RPM, FET, RPS, RPX, GR, ROP, FCNT, NPHI, PEF, NCNT, RHOB, DRHO DATA SUBMITTAL COMPLIANCE REPORT 4/18/2011 Permit to Drill 2080980 Well Name /No. N COOK INLET UNIT A -16 Operator CONOCOPHILLIPS COMPANY API No. 50- 883 - 20127 -00 -00 MD 9314 TVD 7631 Completion Date 2/24/2009 Completion Status 1 -GAS Current Status 1 -GAS UIC N E6 C Lis 17309V I duction /Resistivity 1420 9314 Open 12/12/2008 LIS Veri, RPD, RPM, FET, RPS, RPX, GR, ROP, FCNT, NPHI, PEF, NCNT, RHOB, DRHO Rpt LIS Verification 396 1168 Open 12/12/2008 PB1 LIS Veri, RPD, RPS, RPX, FET, GR, ROP fED C Lis 17310`"induction /Resistivity 396 1168 Open 12/12/2008 PB2 LIS Veri, RPD, RPS, RPX, FET, GR, ROP D C Pdf 17311" Induction /Resistivity 0 0 Open 12/12/2008 MD and TVD EWR logs in • EMF, CGM and PDF Graphics D C Pdf 17312' /Resistivity 0 0 Open 12/12/2008 P2 MD and TVD EWR logs in EMF, CGM and PDF Graphics og Induction /Resistivity 25 Col 420 9314 Open 12/12/2008 MD ROP, DGR, EWR, ALD, CTN 17- Oct -2008 i og Induction /Resistivity 25 Col 420 7630 Open 12/12/2008 TVD DGR, EWR, ALD, CTN 17- Oct -2008 og Induction /Resistivity 25 Col 400 1168 Open 12/12/2008 PB2 MD ROP, DGR, EWR 22 -Jul -2008 og Induction /Resistivity 25 Col 400 1166 Open 12/12/2008 PB2 TVD DGR, EWR 22- Jul -2008 'pt Report: Final Well R 0 0 Open 12/31/2008 Final Well Report, Table of Cont, Equip & Crew, Well Data, Geo Data, Pres /Form Strength Data, III Drilling Data, Daily Reports ED C 17319 i eport: Final Well R 0 0 Open 12/31/2008 Final Well Report, Table of Cont, Equip & Crew, Well Data, Geo Data, Pres /Form Strength Data, Drilling Data, Daily Reports in Word, w /PDF and PDS digital Mudlogs /og Mud Log 2 Col 4483 9314 Open 12/31/2008 MD Formation Log og Mud Log 2 Col 4483 9314 Open 12/31/2008 TVD Formation Log `*L Mud Log 2 Col 4483 9314 Open 12/31/2008 MD LWD Combo Log Log Mud Log 2 Col 4483 9314 Open 12/31/2008 TVD LWD Combo Log Log Mud Log 2 Col 4483 9314 Open 12/31/2008 MD Gas Ratio Log Mud Log 2 Col 4483 9314 Open 12/31/2008 TVD Gas Ratio DATA SUBMITTAL COMPLIANCE REPORT 4/18/2011 Permit to Drill 2080980 Well Name /No. N COOK INLET UNIT A -16 Operator CONOCOPHILLIPS COMPANY API No. 50- 883 - 20127 -00 -00 MD 9314 TVD 7631 Completion Date 2/24/2009 Completion Status 1 -GAS Current Status 1 -GAS UIC N tog Mud Log 2 Col 4483 9314 Open 12/31/2008 MD Drilling Dynamics Log Mud Log 2 Col 4483 9314 Open 12/31/2008 TVD Drilling Dynamics .Log Plug 5 Blu 8800 9300 Case 2/23/2009 Plug Rec 26- Dec -2009 og Perforation 5 Blu 7958 8724 Case 2/23/2009 Perf Rec 3.125 Powerfrac, 6SPF, 60 Deg, GR, CCL 25- Jan -2009 1 og See Notes 5 Blu 6800 7317 Case 2/23/2009 TCP Correlation, Halliburton 4 -5/8' 14SPF SH, GR, CCL 10- Feb -2009 • og Perforation 5 Blu 7038 7382 Case 7/20/2009 Perf Rec, GR, CCL 9 -Jun- 2009 C Pds 18319 `'erforation 7038 7382 Case 7/20/2009 Perf Rec, GR, CCL 9 -Jun- 2009 Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORM Well Cored? Y KO Daily History Received? ' 0 N Chips Received ? -Y Formation Tops g N Analysis s777 R • eceived? Comments: Compliance Reviewed By: __ Date: IL-, / �� SMITE AELASEA 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 Brett Packer Wells Engineer ConocoPhillips Alaska, Inc. c6 ,098 P.O. Box 100360 0 Anchorage, AK 99510 Re: North Cook Inlet Field, Tertiary System Gas Pool, NCI A -16 Sundry Number: 310 -271 Dear Mr. Packer: 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, ‘6 Daniel T. Seamount, Jr. 51 4- Chair DATED this 3 ( day of August, 2010. Encl. 14Gk— • • obit jtoia itkok_ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool 0 Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate IS ' Pull Tubing ei Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Ct✓0.Ve 1 Pot. 11*" 101 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: • ConocoPhillips Alaska, Inc. Development is " Exploratory ❑ 208 -098 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 883 - 20127 -00 ' 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 IS NCI A -16 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 17589, 37831 " North Cook Inlet / Tertiary System Gas Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9314' • 7631' 8991' 7308' 7481', 8991' Casing Length Size MD TVD Burst Collapse Conductor 400' 30" 400' 400' Surface 4536' 9 -5/8" 4536' 3457' Production 9302' 7" 9302' 7619' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6361' -8771' 4708' -7089' 4-1/2" L -80 6291' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Premier pkr, SC -2 pkr, SC -2 pkr, Sump pkr @ 6251', 7391', 7426', 8797' BP -6i landing nipple @ 503' 12. Attachments: Description Summary of Proposal is 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: /15/2b10 Commencing Operations: Oil ❑ Gas 0 • WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Brett Packer @ 265 -6845 Printed Name Brett Packer Title Wells Engineer Signature --7� �. Phone 265 -6845 Date 8/27/2010 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 0 1 1 Plug Integrity ❑ BOP Test i Mechanical Integrity Test ❑ Location Clearance ❑ RFETIVFD Other: -re Tope Z5Oo t o EA' Subsequent Form Required: 1 ' — ti Q 9- _ . APPROVED BY +/ Approved by: COMMISSIONER THE COMMISSION Date: ` 31 / ) 0 RBDMS SEP 01 - % 31- /-' o R 1 G 1 NA L Form 10 -403 Revised 1/2010 Submit in Duplicate • . • NCIU A -16 Expense Rig Workover (PTD #: 208 -098) Current Status: The well is currently shut in awaiting a workover. Scope of Work: Pull the existing 4 'h" tubing and Premier packer, cleanout the well, re- perforate all existing perfs in the Upper . Beluga w/ TCP guns, run the gravel pack, and re- complete the well with 4' 'A" tubing. General Well info: Well Type: Producer Maximum SI WHP: 1045 psi Wellhead type /pressure rating: Vetco MB 230, 11" 5K btm x 11" 5K top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams Estimated Start Date: September 15, 2010 Drilisite Engineer: John Braden Workover Engineer: Brett Packer (265 -6845 / j.brett.packer @conocophillips.com) Pre - Rig Work Request: 1. RU Slickline: Pull SSSV, tag fill. 2. RU CCT: Clean out down to IBP at 7481' RKB. 3. RU Slickline: Set 3.25" plug in R- nipple at 7416' RKB, set catcher sub on top, pull GLV's & replace w/ DV's except for bottom mandrel. 4. RU Eline: Cut the 3.89" OD Premier packer at 7251' RKB, run caliper through to verify cut. 5. Set BPV. General Procedure: 1. Skid Cudd 136 from A -15 to A -16. 2. Displace well w/ filtered 6% KCL seawater (8.6 ppg). Set BPV. ND tree. NU 11" 5K BOP. Function test Koomey unit. Pressure test BOPE to 250/3500 psi and annular to 250/2500 psi. 3. Pull blanking plug and BPV. MU landing joint, pull hanger — straight pull to release Premier packer. RU to circulate. Continue to circulate until fluid is 20 NTU's or less. 4. POOH standing back 41/2" tubing. 5. RIH w/ cleanout assy and cleanout to the SC -2 packer at 7392' RKB. Circulate well clean. 6. Re -perf all existing perfs w/ TCP guns in preparation for gravel pack. Pickle workstring. 7. Install Baker `CK' gravel pack system and pump HRWP. 8. RIH w/ 41/2" tubing to top of gravel pack packer, load IA w/ corrosion inhibited 6% KCL seawater, sting into PBR, space out and land hanger. 9. PT tub ', g 8, �, set BPV, NDBOP. 10. NU . Pdll BPV, install test plug and PT tree & packoffs to 5000 psi. 11. Pull test plug, install BPV. RDMO. Post - Rig Work: 1. RU Slickline: Install GLD. 2. Flowback Upper Beluga for cleanup. 3. RU Slickline: Pull `PR' prong & plug from 7416' MD. Bail fill to IBP. Equalize & retrieve IBP. Install SCSSV. • ConacoPhilaps Alaska P.O. BOX 100360 RP j^y ANCHORAGE, ALASKA 99510 - 0360 (,,! f" z x , y August 30, 2010 p aftn ISSi017 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Approval: NCIU A -16 Permit to Drill: 208 -098 API Number: 50- 883 - 20127 -00 Field / Pool: North Cook Inlet / Tertiary System Gas Pool Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the NCIU A -16 wellbore (PTD 208 -098), located in the North Cook Inlet / Tertiary System Gas Pool drilled on the - Tyonek Platform. NCIU A -16 was originally completed in February 2009 in the Lower Beluga (M -U) sands to help evaluate the reserve potential in those sands. The resulting production was well below predicted, therefore, the well was re- completed in May 2009 to the Upper Beluga (B -K) sands to target improved production rates; the Lower Beluga sands were isolated with an IBP. Due to regulatory time constraints, A -16 was never • gravel packed in the Upper Beluga and was completed post -rig with wireline perforations. The well produced for 6 months before sanding up, and following a concentric coiled tubing cleanout, it appears to have sanded up again. The purpose of this workover is to install a gravel pack across the Upper Beluga sands to prevent the well from sanding up in the future. We will pull the existing 4 1 /" tubing and Premier packer, cleanout the well, re- perforate all existing perfs in the Upper Beluga w/ TCP guns, run the gravel pack, and re- complete the well with 4 %2" tubing. If you have any questions or require any further information, please contact me at 265 -6845 or Ty Senden at 265 -1544. Sincerely, J. Brett Packer Wells Engineer CPAI Drilling and Wells i ' STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMIIIN REC6..I RECEIVED REPORT OF SUNDRY WELL OPERATIONS rrg 2 6 2010 1. Operations Performed: Abandon r Repair w ell r Rug Ft'rforations E Stimulate j7,7 Other E Alter Casing r Pull Tubing Perforate New Pool r Waiver f Time at Change Approved R - ogram r Operat. Shutdow n r Perforate r Re -enter kispended Well r Anc 2. Operator Name: 4. Current Well Status: . Permit to Drill Number: ConocoPhillips Alaska, Inc. Development R. Exploratory r 208 - 098 3. Address: X. API Number: Stratigraphic r Service E P. O. Box 100360, Anchorage, Alaska 99510 50 883 - 20127 - 00 7. operty Design�aton: 8. Well Name and NN No ADL 17589, 37831 NCI A -16 \9. Field /Pool(s): ' North Cook Inlet / Tertiary System Gas Pool 10. Present Well Condition Summary: Total Depth measured 9314 feet Plugs (measured) 7481', 8991' true vertical 7631 feet Junk (measured) None Effective Depth measured 8991 feet Packer (measured) 6251, 7391, 7426, 8797 true vertical 7308 feet (true vertucal) 4607, 5712, 5748, 7115 Casing Length Size MD TVD Burst Collapse CONDUCTOR 400 30 400 400' SURFACE 4536 9.625 4536 3457 PRODUCTION 9301 7 9301 7619 Perforation depth: Measured depth: 6361'- 6386', 6427'- 6434', 6467'- 6475', 7500' -8771' True Vertical Depth: 4709'- 4732', 4770'- 4777', 4808'- 4816', 5821' -7089' Tubing (size, grade, MD, and TVD) 4.5 ", L -80, 6292' MD, 4644 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 6251 MD and 4607 TVD PACKER - BAKER SC -2 PKR 70B-40 NITRLE @ 7391 MD and 5712 TVD PACKER - PACKER SC -2 70B -40 NITRILE @ 7426 MD and 5748 TVD PACKER - PACKER - FS @ 8797 MD and 7115 TVD NIPPLE - CAMCO BP -6i LANDING NIPPLE @ 503 MD and 503 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 -- 0 Subsequent to operation 0 1346 3 -- 215 13. Attachments 'hQ. Well Class after proposed work: Copies of Logs and Surveys run Exploratory Development Service 5. Well Status after work: Oil r Gas ✓ WDSPL Daily Report of Well Operations XXX GSTOR r WAG r GASINJ r WIND r SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact R . nis 265 -1544 Printed Name 1 � 14 : 4r n•: Title Wells Engineer Signature .47 Phone: 265 - 1544 Date 2 t 0 Form 10 -40 .ed 7/2009 S FEB 26 Submit Original Only Z. -24 . to ,DATE . SUMMARY i 7/6/09 WORK BEING DONE: Survey WIRELINE AT: Tubing Hanger, MIN TAIL ID: N /A, TOTAL WIRELINE MILES: 0, MAX DEPTH(KB): N /A, WELL KB: N /A, MAX TOOL OD: N /A, PRESENT OPERATIONS: Shut Down 7/9/09 WORK BEING DONE: 4 Point Test - Survey ZERO WIRELINE AT: Tubing Hanger, MIN TUBING ID: 3.813 ", TOTAL WIRELINE MILES: 1, MAX DEPTH(KB): 5,750', WELL KB: 43', MAX TOOL OD: 43', (( IN PROGRESS )) 7/10/09 Finish survey -set SSSV 7/26/09 PULLED 4.5" WRDP @ 503' SLMD, FOUND SAND @ 7330' SLMD,BAILED DOWN TO 7396' SLMD, TOP OF IBP @ 7437', RESUME BAILING IN THE AM, IN PROGRESS 7/27/09 CONTINUED BAILING SAND FROM PRODUCTION LINER, TOTAL DEPTH ACHIVED' SLMD, (( IN PROGRESS 7/28/09 Bail sand from 7,360' KB to 7,402' KB 7/29/09 BAILED SAND FROM LINER DOWN TO 7410' SLMD, (( IN PROGRESS )) 7/30/09 MADE SIX BAILER RUNS, TOTAL DEPTH ACHIVED WAS 7407' SLMD, SET 4.5" WRDP @ 503' MD, TURN WELL OVER TO PRODUCTION, ( COMPLETE ) 10/27/09 WORK STRING DETAIL: 1 3/4" TS -RS, KJ, Stem, Stem, KJ, SJ 6" 8" 5' 5' 8" 7'DEBRIS LEFT IN HOLE: NONE SUMMARY OF WORK: Pull SSSV -flow well -set new SSSV 12/16/09 Mobilze equipment from OSK Dock to Tyonek Platform. Utilize Pollard slickline to pull WRDP @ 400' RKB 12/20/09 MIRU BJ CCT AND BEGIN SAND VAC OPERATIONS. START SAND VAC 6400' CTMD USING 2 "x1" CCT WITH 6% SLICK KCL WITH 1 FT /MIN PENETRATION RATE AND .5 BPM PUMP /RETURN RATE. (( IN PROGRESS)) 12/21/09 CONTINUE SAND VAC CLEAN OUT FROM 12/20/09. TOTAL DEPTH ACHIEVED AT TIME OF REPORT END WAS 6860' CTMD, CONSISTENT RETURNS WITH TRACE AMOUNTS OF FORMATION SAND /FINES. 12/22/09 UNABLE TO WORK PAST 6860' CTMD IN FORWARD JET, POOH AND PREP UNIT FOR STANDBY 12/23/09 ALL CREWS RETURNED FROM A DAY AT THE BEACH WAITING ON COMPANY MAN. BJ, MI SWACO, PTS CONTINUE BJ CCT FCO FROM PREVIOUS DAY. CIRCULATE OUT METHANOL FROM SURFACE EQUIPMENT, MAKE UP SAND VAC BHA, SHELL TEST TO 3,000 PSI. RIH WITH SAND VAC TOOL AND DRY TAG @ 6,814' CTM, PULL TEST 26,500 #, CCT FCO IN PROGRESS. 12/24/09 CONTINUED FROM PREVIOUS DAY, UNABLE TO DOWN JET OR SAND VAC THROUGH COAUSAND BRIDGE @ 6,814'CTM AFTER SEVERAL ATTEMPTS. POOH WITH SAND VAC BHA. RIH W/ 2.125" MOTOR AND 3 BLADED JUNK MILL TO SAND BRIDGE (c 6.814'CTM, WORKED THROUGH BRIDGE WITH LITTLE MOTOR WORK TC3, 6,830'CTM, POOH. START BACK IN HOLE WITH 2.125" SAND VAC TOOL TO 6,814'CTM. BJ CCT FCO IN PROGRESS. 12/25/09 CONTINUE SAND VAC OPERATIONS FROM PREVIOUS DAY. SAND VAC FROM 6,836' TO 6,965'CTM, STARTED GETTING BETTER SAND RETURNS 1/2 TO 1 CUP PER 15 MINUTE BUCKET TEST BELOW 6,900'CTM, HAVING TO PULL UP HOLE EVERY 2 -3 HOURS TO FLUSH INTAKE SCREENS FOR BETTER RETURN RESULTS, BJ CCT FCO IN PROGRESS. 12/26/09 CONTINUE SAND VAC OPERATIONS FROM PREVIOUS DAY. SAND VAC FROM 6,944' TO 7,060'CTM. RECOVERED APPROXIMATELY 20 BBLS TOTAL FORMATION SAND THUS FAR. BJ CCT FCO IN PROGRESS. 12/27/09 CONTINUE SAND VAC OPERATIONS FROM PREVIOUS DAY. SAND VAC FROM 7,090' TO 7392'MD, APPROXIMATELY 26' BELOW LOWER MOST ACCESSIBLE PERF'S, STILL GETTING CLOSE TO 1:1 RETURNS WITH GOOD SAND RETURNS. BJ CCT FCO IN PROGRESS. 12/28/09 12/28/09 WORK STRING DETAIL: 2 1/8" TS -RS, KJ, Stem, Stem, KJ, SJ 6" 8" 5' 5' 8" 7'DEBRIS LEFT IN HOLE: NONE SUMMARY OF WORK: Try to set SSSV 12/29/09 WORK STRING DETAIL: 2 1/8" TS -RS, KJ, Stem, Stem, KJ, SJ 6" 8" 5' 5' 8" 7'DEBRIS LEFT IN HOLE: NONE SUMMARY OF WORK: Try to set SSSV 1/3/10 WORK STRING DETAIL: N/A DEBRIS LEFT IN HOLE: NONE SUMMARY OF WORK: Standby at OSK for weather 1/4/10 WORK STRING DETAIL: 2 1/8' RS, KJ, Stem, Stem, KJ, SJ IN" 5' 5' 8" 7'DEBRIS LEFT IN HOLE: NW E SUMMARY OF WORK: Set SSSV 1/10/10 WORK STRING DETAIL: 1.5" TS -RS, KJ, Stem, Stem, KJ, OJ, SJ 6" 8" 5' 5' 8" 3' 7'DEBRIS LEFT IN HOLE: NONE SUMMARY OF WORK: Tag fill at 7,260' KB e • 0 • .. SAK NCI A-16 C onoco 'till1 35 ( Well ttnbute M ax M & MD . - TD �f @ S (t.3. k lv.' . ,. h 508832012700 (COOK INLET SHUT IN 9 �_ . Wel lbore AP W WI I Reid Name Well Status � Inc] (1 MD (ftKB) At Bb. ( ,-".","--"'",.:17'; _ ,314.0 Comment H2S (ppm) Date Annotation End Data KB19rd (ft) R Release age ate 1 I c J �� 2d _ SSSV: NIPPLE _ Last WO: 5/18/2009 _ .._ _ _ 70272008 �5'"" > - Annotation (Depth (ftKB En Drte Annotation Last Mod By End Date w.nnso_' _ Last Tag: Rev Reason: CASING ADJUSTMENT Imosbor 7/14/2009 - - ' + CasinqStnngs = Casing Description Strng 0._ String ID _ Top (MB) Set Depth (L. Set Depth (TVD) String WL String _ String Top Thrd CONDUCTOR 30 28.000 45.0 400.0 400.0 ,fin Casing Descri ption Sing 0._ String ID _ Top (ftK L B) Set Depth (L. Set Depth (TVD) _. String W String - String Top Thrd ° SURFACE 95/8 8.835 48.6 4,535.8 3,4572 40.00 L - 80 BTCM _ Casing Des npt Siring O String ID Top (ftKB) Set Depth (L. Set Depth (TVD) String WL String String Top Thrd r..KC.n - PRODUCTION 7 6.276 44.8 9,301,0 7,617.1 26 00 L-80 BTCM I a°, Tubing Stnngs ' Tubing Description !String 0... 'String ID ...11 (nKB) Set Depth (L Set Depth (TVD) _. IStnng WL. lstrir ' string Top Thee TUBING 4 12 3.958 42.6 6,291.5 4,644.1 1260 L-8 IBTM 11/0111 Completion D)eta 171 T Dep ,wrn...o, (T Top Intl -- TeD (1t103 l_ (. B) C) ItenDn opton ID )ln) 42.6 42.6 -0.12 HANGER TUBING HANGER 3.958 . 9 , 503.0 5029 4.40 NIPPLE CAMCO BP-6i LANDING NIPPLE 3.813 e".......y.- 6,208.3 4,568.0 2522 NIPPLE 'X' NIPPLE 3.813 6,251.5 4,607.3 24.00 PACKER Baker Premier Packer 3.890 .. 6,278.9 4,632.4 2122 NIPPLE "DB" Landing Nipple 3.750 aim __ _ e - 6,290.3 4,642.8 22.90 WLEG Wireline Entry Guide 1930 m Tubing Description String 0... Sting ID._ Top (ftKB) Set Depth (L Set D pth (TVD) _. String WL. Siring _ String Top Thrd Or SUMP PACKER 2 I 4 I 3.450 7,390 8 1 7,430.1 5 751 5 I. 11 00 � SLHT a ten, CotnPfetion Details _ o ll Top Depth (1VD) Top Intl w eakeemear. -- = Top (ftKB) (NKB) (*) Item Desaription comment ID )in) ee1 7,390.8 5,712.4 4.75 PACKER Baker SC-2 Pkr 70840 Nitrle 4.000 P EW, OW . ` - _ 7,395.0 5,716.6 4.74 MILL OUT EXT M81 Out extension - ��_ -- 4.650 7,416.1 5,737.5 4.69 NIPPLE R- Nipple 3.250 rLL ft. .. i"`--,..__ , 1 7,417.1 5,738.5 4.69 Snap Latch Snap Latch 82-40 5-228 3.260 s --- x,m "" - SiE\ i 7,423.1 5,744.5 4.68 SEAL Seal Unit 3260 ' ;.,. p` '405'! 7,426.2 5,747.6 4.67 Spacer 3260 PJ 7,430.1 5,751.5 4.67 SHOE Mule Shoe 2.410 .. '3 "' w ...,:=1.7a Tubing Description String 0- String ID ._Top (ftKB) Set Depth (f_. Set Depth (TVD) _. String WL. String - String Top Thrd GRAVEL PACK I 4_59 - 3.430 7,426.4 8,805.1 7,122.9 I 11.00 P-110 SLHT x .: x,... ° • y Completion Details ...TUna'm Top Depth .. . i �.� (ND) Top Inc! I Top MB)._ (ftKB) C) Kart. Despt1oo _ C _ m en t ID (in) `""` =`xu a 7,426.4 5,747.8 4.67 PACKER Packer SC-2 70B-40 Nitrile 4.000 .es,x, ,n x,.n 7,433.7 5,755.1 4.61 SBE Seal Bore 80-40 CK -250 4.000 n =-. 7,457.9 5,779.2 4.54 SLEEVE KOIV C -2 isolation sleeve 3.340 ."=''''''' l 1 7,460.5 5,781.8 4.53 KOIV KOIV C -2 3.310 V• r . ,,, 7,463.5 5,784.8 452 SOS Shear out Safety joint GPR -24 3.430 •� - . 7,715.9 6,036.5 4.28 SBR SBRs @ 7716', 8007', 8318', 8540', 8613' 3250 ':.� 8, 796.0 7,113.8 3. 83 SNAP Latch Snap Latch 82-40 S228 3.260 ....... �x r.ir P. _ Tubing Description Sin g 0... String ID ._ T op (ftKB) Set Depth (f_. Sot Depth (TVD) _. String W! _ String _ String Top Thrd o i� , - SUMP PACKER 1 LS 51 I 4 8901 8,797.0 8,8210 7,137.7 �'"°"" "" C Det .. _ _ = - _ , . - `.ov.xpuav e_. Top p Depth (TVD) Top Intl TKUNO. ter - �r'. '''' i i s i , , _ , es _ Top MICE) (ftKB) (1 Item Description Comment ID (in) ne,.n ``: _. 8,797.0 7,114.8 3.83 PACKER Packer -FS 4.000 Wes* T.33x0. Sawn. _ - Other In Hole reli ie retrievable plugs valves pumps, fish, etc =) Top Depth ' U. b T -N (TV ID) Top l 1 r..,'"Z le4: . - --1:: T�ftKfi (ftKB) C) Description Comment_ Run Date ID (in) a or•. -sw " L - ) 7,481 5.802.3 4.47 PLUG BAKER IBP DSSS 5/10/2009 1.000 c 8,991 7,308A 183 PLUG BAKER CIBP (OAL 2.54' 0 12/27/2008 4.670 Perforations & ' Slots , . - - t Shot 11.1.1,2,43.14,12.1 @> Top(TVD) Btm (TVD) Dens ,a'""iueaaena s .a.� - Top (ftKBL Bbn (MB) (h105) (ftKB) Zone Date (eh... Type Comment 1°vi "er°0 - P -: 6,361 6,366 4,708.5 4,7112 Beluga B, NCI 6/22/2009 6.0 IPERF 2.875" HSD PJ OMEGA MAX, 60 deg A-16 Phase ,,,manna+ l� ;,,... :-.., PSG _ 6,366 6,386 4,7132 4,732.0 Beluga B, NCI 6122/2009 6.0 IPERF 2.875" HSD PJ OMEGA MAX, 60 deg or n .u - -- _ - A - phase c... '.. ' � ` - , 6,427 6,434 4,770.4 4,777.1 Be)uga B, NCI 6/22/2009 6.0 IPERE 2.875" HSD PJ OMEGA MAX, 60 deg • s.n. e - 1• A -16 phase Mandrel Details _ _ _ _ _, - Port $°".. „anu. 1 Top Depth Top - (TVD) Inei - OD Valve Latch Sire 1RO Run Lam' - S TopUtKe) (9103) (.) Make Model tin) Sere Type Type (in) (psi) Run Date Com_. x u+- '�- 1 1,747.4 1,688.9 37.96 CAMCO KBG 1 GAS LIFT GLV BK 0.158 970.0 5/17/2009 .Seam n.6n - '-- -'-- -- _ --- rx„r.i z _LL_. 2 3,258.9 2,691.6 53.03 CAMCO KBG-2-1R 1 GAS LIFT GLV BK 0.188 960.0 5/172009 i o rom..m»a. n . - we.r .ra�_ - 3 4,431.6 3,3926 51.65 CAMCO KBG-2-1R 1 GAS LIFT GLV BK 0.185 941 .0 5/172009 '''''"j'''' . -= 11v 4 5,266.4 3,893.5 53.36 CAMCO KBG-2 -1R 1 UFT GLV BK 0.188 890.0 5/172009 KW. 3,7.1.1.75i ' - -- 5 6 , 1 6 0 . 2 KBG2 -1R 1 GAS UFT OV BK 0.375 0.0 5/772009 W� • w !W newrbe..m, a,couRen ss. 19 iuomssa+. • • • ; � SAK NCI A -16 ConcoPhiilips A4asic31tc. P - - - e�acal•veos�+ KB-Grd (ft) Rig Release Date ••• 10/27/2008 wmt ss.p., == oo i, A:]. §.,Xi..4/26g.2144.9.V4ta.._- ._ __.- 1_.- SsitTemtIc M,W OVIGOVO Perfo[atlons $:?$lots shat Top (ND) Biro (ND) Den 1 ■ - Top (MB) Btm (ftXB) (MB) ( ) Zone Date NI, • - Tie - Cortanent ca.nmlo4....mJ 6 6,475 4,808.4 4,816.0 Beluga C, NCI 6/22/2009 6.0 I 2.875" HSD PJ OMEGA MAX, 60 deg Mar- A -16 phase WO... a _ 7,500 7,524 5,821.2 5,845.1 Beluga M, NCI 2/10/2009 14.0 TCP HES 45/8" SH guns A -16 11 era1 7,677 7,694 5,997.7 6,014.7 Beluga 0, NCI 2/10/2009 14.0 TCP HES 45/8" SH guns o.surr,uv A -16 7,797 7,810 6,117A 6,130.4 Beluga P, NCI 2/10/2009 14.0 TCP HES 4 5/8" SH guns .51....n0 A- 7,880 7,885 6,200.2 6,2052 Beluga Q, NCI 2/10/2009 14.0 IPERF HES 4 5/8" SH guns A-16 ... 7,912 7,922 6,232.1 6,242.1 Beluga Q, NCI 2/10/2009 14.0 IPERF - o.n.o..... .+ HES 4 5/8" SH guns ..., �A 16 w,v . 7,946 7,978 6,266.0 6,297,9 Beluga Q, NCI 2/10/2009 14.0 IPERF HES 4 5/8" SH guns A -16 omit,a1m 7,958 7,978 6,278.0 6,297,9 Beluga Q, NCI 1/31/2009 6.0 RPERF 3 1/8" Hi Vol PowerFrac 3106 -20.19 A -16 Chrg WOE. O. �e _ ` 8,278 8,284 6,597.1 6,603.1 Beluga S, NCI 2/10/2009 14.0 IPERF HES 4 5/8" SH guns rwa.t.x A -16 ....X. 140,--, 8,291 8,300 6,610.0 6,619.0 Beluga T, NCI 2/10/2009 14.0 IPERF HES 45/8" ....X. SH guns ...s.. A -16 rew.M..om rer......am- 8,291 8,300 6,610.0 6,619.0 Beluga T, NCI 1/31/2009 6.0 RPERF 3 1/8" Hi Voi PowerFrac 3106 -20.19 n,.... - - A -16 Chrg r.w,..m.,,.n -_ _ 8,414 8,424 6,732.7 6,742.7 Beluga T, NCI 2/10/2009 14.0 IPERF HES 45/8" SH guns A -16 ...1 i art l- P. . r exr. r 8,464 8,490 6,782.6 6,808.5 Beluga T, NCI 2/10/2009 14.0 IPERF HES 4 5/8" SH guns r ,X 1.4 A-16 A 16 M � _1 8,517 8,523 6,835.5 6,841.5 Beluga U, NCI 2/10/2009 14.0 IPERF HES 4 5/8 SH guns A -16 VI nr0. m.m ' 8,564 8,576 6,882.3 6,894.3 Beluga U, NCI 2/10/2009 14.0 IPERF HES 4 5/8" SH guns ca A -16 eW '""� 8,565 8,571 6,883.3 6,889.3 Beluga U, NCI 1/29/2009 S0 RPERF 3 1/8" Hi Vol PowerFrac 3106 -20.1g °°'r" ' ,. Imo" A -16 Chrg AS, i , " . 0 a, rte 8,587 8,593 6,905,3 6,911.3 Beluga U, NCI 2/10/2009 14.0 IPERF HES 4 5/8" SH guns A-16 '03 8,709 8,724 7,027.0 7041.9 Beluga U, NCI 1/26/2009 6A RPERF 3 1/8" Hi Vol PowerFrac 3106 -20 -1g ash A -16 Chrg 7.4. 7,1., 1- 8,709 8,724 7,027,0 7,041.9 Beluga U, NCI 2/10/2009 14.0 IPERF HES 4 5/8" SH guns z...,c.."w i - " 4 A - 16 ,aea � j "` c:= 8,734 8,741 7,051.9 7,058.9 Beluga U, NCI 2/10/2009 14.0 IPERF HES 45/8" SH guns .......¢ .¢ .: A-16 770 SEr. °'' r � sue- 8,746 8,756 7,063.9 7,073.9 Beluga U, NCI 2/10/2009 14.0 IPERF HES 4 5/8" SH guns MAO,'JO m l_.- r hea; ; _ 8,767 8 7,084.8 7 088 8 Beluga Ubase, 2/10/2009 14,0 IPERF HES 4 5/8 SH guns �,iue ° iaii M NCI A-16 VOW,.m. s �.�r.�- � a, Noy =General: Safety =- __ _ - _ - - , __ _ :. _ ra• rrw - . - "° t' � 1 -. End Doto __ .. A nofafi u _ r .a. r.+ L. End 2/28/2009 NOTE VIEW SCHEMATIC w /Alaska Schematic9 ..".uewuml _ ,� az rew,.a,..um -4 I:- /..."....”4.34. ! AZ 311471141 017 147114,4114 4,41 1 441, P . µ.,4m a. . m J h .am um 5 ran w '. M .! : um.un ( tt ( x.ua. 1 'I uu� r row, satrarn rt O.,. IIIIL "5sww..,r""_m fir►�'� s...aen..� Fes`=... w.ma.n s� rotw.,n ran STATE OF ALASKA RECEIVED ALAS IL AND GAS CONSERVATION COMMI A N GAS WELL OPEN FLOW POTENTIAL TEST REPORTG 0 7 2009 1a. Test: U Initial 11 Annual U Special 1b. Type Test: U Stabilized t on,S.ta iliAed 1 1Multipoint ❑ Constant Time ❑ Isochronal Other a !�, , t' '1? 2. Operator Name: 5. Date Completed: 11. Permit to Drib Number' ConocoPhillips Alaska, Inc 5/20/2009 208 -098 3. Address: 6. Date TD Reached: 12. API Number: PO Box 100360 Anchorage, AK 99510 10/16/2008 50- 880 - 20127 -00 4a. Location of Well (Governmental Section): 7. KB Elevation (ft): 13. Well Name and Number: Surface: 1305 FNL 1016' FWL Sec. 6 T 11N R 9W, SM 116 NCIU A -16 Top of Productive Horizon: 8. Plug Back Depth(MD +TVD): 14. Field /Pool(s): 951' FSL 1922' FEL Sec. 36 T12N, R1OW, SM 8991/7371 North Cook Inlet Unit Total Depth: 9. Total Depth (MD + TVD): Tertiary Gas Pool 1141' FSL 2209' FWL Sec. 36 T12N R1OW, SM 9314/7631 4b. Location of Well (State Base Plane Coordinates): 10. Land Use Permit: 15. Property Designation: Surface: x- 332034 y- 2586675 Zone- 4 ALK 2916 ADL 17589 /ADL 37831 TPI: x- 329130 y- 2588973 Zone- 4 16. Type of Completion (Describe): Total Depth: x- 328846 y- 2589167 Zone- 4 Cased & Perforated 17. Casing Size Weight per foot, Ib. I.D. in inches Set at ft. 19. Perforations: From To 7 26 6.276 9301 6361 -6386, 6427 -6434, 6467 -6475 18. Tubing Size Weight per foot, Ib. I.D. in inches Set at ft. 4-1/2 12.6 3.958 6292 20. Packer set at ft: 21. GOR cf /bbl: 22. API Liquid Hydrocardbons: 23. Specific Gravity Flowing Fluid (G): 6251 n/a n/a 24a. Producing through: 24b. Reservoir Temp: 24c. Reservoir Pressure: 24d. Barometric Pressure (Pa): 0 Tubing ❑ Casing 91 F° 494 psia @ Datum -4100 TVDSS psia 25. Length of Flow Channel (L): Vertical Depth (H): Gg: % CO % N2: % H2S: Prover: Meter Run: Taps: 0.565 0.25 0.25 0 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice psig Hw F psig F psig F° Hr. Size (in.) Size (in.) 1. X 351 91 351 4.1 2. X 371 91 371 4.0 3. X 401 91 401 4.0 4. X 438 91 438 4.0 5. X Basic Coefficient Flow Temp. Super Comp. Pressure Gravity Factor Rate of Flow No. (24 -Hour) by wPm Pm Factor F Factor Q Mcfd Fb or Fp Ft g Fpv 1. 5620 2. 4100 3. 2834 4. 1680 5. Temperature for Separator for Flowing No. Pr T Tr z Gas Fluid Gg G 1. 0.52 91 1.59 2. 0.55 91 1.59 3. 0.60 91 1.59 Critical Pressure 673 4. 0.65 91 1.59 Critical Temperature 345 5. Form 10 -421 Revised 1/2004 : L , , C `:..I IDE Submit in Duplicate Pc P a PO 494 pf 244036 No. Pt Pt Pc -Pt Pw Pw Pc Ps Ps Pf -Ps 1. 351 123201 120835 2. 371 137641 106395 3. 401 160801 83235 4. 438 191844 52192 5. 25. AOF (Mcfd) 14219 n 1.42 Remarks: I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /A .1a6 . Title I�� f , Date 0 - OT DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfd/ 4 hwPm Fp Basic critical flow prover or positive choke factor Mcfd /psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= - I - 17Z — dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air = 1.000), dimensionless Gg Specific gravity of separator gas (air= 1.00), dimensionless GOR Gas -oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet (TVD) L Length of flow channel, feet (MD) n Exponent (slope) of back - pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut -in wellhead pressure, psia Pf Shut -in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back- Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10 -421 Revised 1/2004 Side 2 NCIU A -16 Multi -point 7110109 1 , 000, 000 _ ,..,, n= 1.418, AOF =3 -- — < C • Test Data ( • 1) f i as 1 1 I N — .... 100,000 - 1 N ........i _ 1 ID- I CD 10 1 I 1,000 10,000 Q, Mscf /D 07/06/09 c {um r r NO.5302 Schlumberger -DCS 2 525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: North Cook Inlet Well Job # Log Description Date BL Color CD NOV A -16 BOOQ -00011 PERFORATION RECORD 06/08/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561 -8317. Thank you. STATE OF ALASKA • JUL 1. 5 2009 Oil & Gas Cons. Commission ALASKA OIL AND GAS CONSERVATION COMMISSION Ant htti88 REPORT OF SUNDRY WELL OPERATIONS 07 /i6,400 1. Operations Performed: Abandon ❑ Repair Well ❑ Plug Perforations Stimulate ❑ Other ❑ Alter Casing ❑ Pull Tubing 0 Perforate New Pool®•' • Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown❑ Perforate wir Re -enter Suspended Well ❑ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 • Exploratory ❑ 208 -098 / • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 - 883 - 20127 - • 7. KB Elevation (ft): 9. Well Name and Number: RKB 120.6' - NCIU A - • 8. Property Designation: 10. Field /Pool(s): ADL 17589, 37831 North Cook Inlet / Tertiary System Gas Pool • 11. Present Well Condition Summary: Total Depth measured 9314' • feet true vertical 7631' • feet Plugs (measured) 7481', 8991' Effective Depth measured 8991' feet Junk (measured) true vertical 7308' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 400' 30" 400' 400' SURFACE 4536' 9 -5/8" 4536' 3457' PRODUCTION 9302' 7" 9302' 7619' Perforation depth: Measured depth: 6361'- 6386', 6427'- 6434', 6467- 6475', 7500' -8771' true vertical depth: 4709'- 4732', 4770'- 4777', 4806- 4816', 5821' -7089' Tubing (size, grade, and measured depth) 4.5" , L -80 , 6292' Packers & SSSV (type & measured depth) Baker Premier pkr @ 6252', Baker SC -2 pkr @ 7391', Baker SC -2 pkr © 7426', 'FS' pkr @ 8797' Camco landing nipple @ 503' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation SI -- Subsequent to operation 5933 ' 5 -- 280 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ❑ Development 0 Service ❑ Daily Report of Well Operations _X 16. Well Status after work: OHO Gas El WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ 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: 309 -151 Contact Dave Reimer @ 263 -4347 Printed Name David Reimer Title Drilling Engineer Signature I / r / ,," Phone: 263 -4347 Date '/ 1 j /L 9 Prepared by Sharon Allsup -Drake 263 -4612 7 • (5 `7 Form 10 -404 Revised 04/2006 Submit Original Only RBOMS BFL JUL 1 6 2009 0. 7/",' Cono co Phillips Time Log & Summary WelNiew Web Reporting Report Well Name: NCI A -16 Rig Name: KUUKPIK 5 Job Type: OTHER Rig Accept: 5/21/2009 12:00:00 AM Rig Release: 6/3/2009 12:00:00 AM ti : T o Dur . $: Deoth E . D e o h \ P h a s e ` . . : code S u b o o d e „ "f' Coma ? , . . 05/21/2009 24 hr Summa Skid Tank Farm - Lay Over and Spot Tanks - Spot Mud Lab - Clean Mud Pits - Unstring Blocks - Unload /Load Boat - Disconnect and Stow Miscellaneous Electrical /Hydraulic Lines - Prep Mud Pumps for Storage - Remove Front Wind Walls 00:00 06:00 6.00 0 0 DEMOB MOVE DMOB P Skidded Tank Skid - Layed Over Tanks - Cleaned Pits 1 -3 - Removed Top Drive & Controls from Rig Floor 06:00 12:00 6.00 0 0 DEMOB MOVE DMOB P Unstrung Blocks - Cleaned Remainder of Pits - Remove Possum Bellies - Unload /Load Boat 12:00 18:00 6.00 0 0 DEMOB MOVE DMOB P Complete Loading of Boat - Spot Derrick Ram Skid - R/D Draw Works Hydraulic Hoses - Remove Front Wind Walls 18:00 00:00 6.00 0 0 DEMOB MOVE DMOB P Pull Electrical Lines - Remove Rig Steam & Water Lines - Prep Mud Pumps for Stack Out - R/D & Plug Derrick Hyd Lines - Remove Choke & Mud Lines f/ Cellar 05/22/2009 Start Remvoing Draw Works Bolts - Remove Rear Wind Walls - Remove Inside Sub Supports - Hook Up Portable HPU and Raised Cylinders - Lubricated Mud Pumps - Pulled Rig Floor Plates - Skidded Rig Into Position - Layed Down Front Wind Walls - Squatted Sub - Secured Floor and Connected Cylinders to the Derrick - Positioned Mud and Top Drive Stand Pipes - Took Down Wind Sock & Flag Poles from the Crown - Reposition Hydraulic Lines in the Cellar - Pulled Electric Cables - Lay Over the Derrick - Unspool Tuggers and Disconnect Tugger / Draw Works Hydraulic Lines - Remove Draw Works & Mast Racking Board - Off Load / Load Boat 00:00 12:00 12.00 0 0 DEMOB MOVE DMOB P Satart Remvoing Draw Works Bolts - Remove Rear Wind Walls - Remove Inside Sub Supports - Hook Up Portable HPU and Raised Cylinders - Lubricated Mud Pumps - Pulled Rig Floor Plates - Skidded Rig Into Position - Layed Down Front Wind Walls - Squatted Sub - Secured Floor and Connected Cylinders to the Derrick 12:00 00:00 12.00 0 0 DEMOB MOVE DMOB P Positioned Mud and Top Drive Stand Pipes - Took Down Wind Sock & Flag Poles from the Crown - Reposition Hydraulic Lines in the Cellar - Pulled Electric Cables - Lay Over the Derrick - Unspool Tuggers and Disconnect Tugger / Draw Works Hydraulic Lines - Remove Draw Works & Mast Racking Board - Off Load / Load Boat Page 1 of 1 • _ A ° • • 1 *�.:•� ��..: �� ;. ‘„ate ` .�\ mil° �: �. ,� 1,;)', , � ;+�'.�,,�� ®d e � . 1. Dur ' . S. Diudb.. ..E D&4h _Phase Cod ' ubc e.. T .Comment , .. 05/23/2009 g4 hr Summary Disconnect Clamps Securing Upper /Lower Derrick Halves and Separate - Pull Rotary Table, Monkey Board, Rooh Caps, Do House, Change Room, Rig Water Tank, Rig Floor and Stairs - Load All and Return to OSK 00:00 12:00 12.00 0 ' 0 DEMOB MOVE DMOB P Disconnect Derrick Clamps - Load Lower / Upper Halves of the Derrick, Wind Walls & Draw Works on Boat - Pulled Dog House, Change Room, Rig Water Tank, and Roof Caps 12:00 00:00 12.00 0 0 DEMOB MOVE DMOB P Pulled Tool House, Rotary Table and Rig Floor, Loaded Boat w/ Rotary Table, Rig Floor, Dog House, Water Tank, Change Room, Roof Caps, "Monkey Board" and 2 Pallets 05/24/2009 Rig Down Shaker, Pull "Frogs" from Sub Base, Pull Bubble from Shaker House, Build Loads on Flats, Dig Dry Mud from Under White Iron, Clean White Iron & Deck, Load Boat, Remove Grating from Sub, Roll and Palletize Hoses, Prep Other Modules for Storage, Begin Loading Boat 00:00 12:00 12.00 0 0 DEMOB MOVE DMOB P Rig Down Shaker, Pull "Frogs" from Sub Base, Pull Bubble from Shaker House, Build Loads on Flats, Dig Dry Mud from Under White Iron, Clean _ White Iron & Deck, Load Boat 12:00 00:00 12.00 0 0 DEMOB MOVE DMOB P Continue to Clean White Iron, Remove Grating from Sub, Roll and Palletize Hoses, Prep Other Modules for Storage, Begin Loading Boat 05/25/2009 Load Out Boat w/ Choke House, Accumulator Bldg., Shaker Mud Pit, Degasser, Shaker House, Shaker Bubble w/ Wlak Way, Raising Rams w/ Service Piping, Joy Flat w/ Floor Legs, Misc BOP Stands, Wind Walls & Hand Rails - Teardown of Kuukpik Sub (White Iron) - Wash of CPAI Sub (Grey Iron) - Load Boat w/ Sub Skids (White Iron), Frog Beam, 2 Skid Jacks, 3 Pallets of Hoses & 1 Cuttings Box w/ Misc Hoses - Begin Teardown of Grey Iron 00:00 12:00 12.00 0 0 DEMOB MOVE DMOB P Load Out Boat w/ Choke House, Accumulator Bldg., Shaker Mud Pit, Degasser, Shaker House, Shaker Bubble w/ Wiak Way, Raising Rams w/ Service Piping, Joy Flat w/ Floor Legs, Misc BOP Stands, Wind Walls & Hand Rails - Begin Teardown of Kuukpik Sub (White Iron) - Begin Wash of CPAI Sub (Grey Iron) 12:00 00:00 12.00 0 0 DEMOB MOVE DMOB P Complete Teardown of White Iron - Complete Wash of CPAI Grey Iron - Load Boat w/ Sub Skids (White Iron), Frog Beam, 2 Skid Jacks, 3 Pallets of Hoses & 1 Cuttings Box w/ Misc Hoses - Begin Teardown of Grey Iron 05/26/2009 Continue to Teardown CPAI Sub Skid (Grey Iron) - Loaded Boat w/ Grey Iron - R/U and Skid Support Skid Into Position - Actuator Claw Broke - Rig Down Walkways and Stairs to Top Modules while Working Support Skid Claw 00:00 12:00 12.00 0 0 DEMOB MOVE DMOB P Continue to Teardown CPAI Sub Skid (Grey Iron) - Begin Loading Boat w/ Grey Iron . gage 2 of • • \ . From To Dur. S, I E. Depth. use Cci A cc rcfe T gent @ s ..... 12:00 00:00 12.00 0 0 DEMOB MOVE DMOB P Complete Loading Boat w/ Grey Iron - R/U and Skid Support Skid Into Position - Actuator Claw Broke - Rig Down Walkways and Stairs to Top Modules while Working Support Skid Claw 05/27/2009 PJSM on Critical Lifting due to High Winds - Skid Support Module to Crane - P/U Company Rep Office, and Meeting Room and Load to Boat - Load Misc Walkways and Stairs to Boat - Boat Departed to Meet Marathon Oil Co. Call Out - Remove Tool Pusher and Medic Offices, 3 -Parts Houses, Grey Convex Box, Tesco MCC and Pulled Pins on the Support Structure - Load Kuukpik Top Drive MCC, Parts Houses, Medic Office, Tesco Hydraulic Unit, Pason, Totes, and Associated Walkways and Stairs to Boat - Continue to Break Down Support Skid 00:00 12:00 12.00 0 0 DEMOB MOVE DMOB P PJSM on Critical Lifting due to High Winds - Skid Support Module to Crane - P/U Company Rep Office, and Meeting Room and Load to Boat - Load Misc Walkways and Stairs to Boat - Boat Departed to Meet Marathon Oil Co. Call Out - Remove Tool Pusher and Medic Offices, 3 -Parts Houses, Grey Connex Box, Tesco MCC and Pulled Pins on the Support Structure 12:00 00:00 12.00 0 0 DEMOB MOVE DMOB P Load Kuukpik Top Drive MCC, Parts Houses, Medic Office, Tesco Hydraulic Unit, Pason, Totes, and Associated Walkways and Stairs to Boat - Continue to Break Down Support Skid 05/28/2009 Clear Pipe Deck for Dismantling Support Skid - Remove Top Support Structure - Remove Vertical Supports and Stack on Tops - Load Support Skid Top Caps and Vertical Supports - Load Oil Tank Room, #1 HPU, #2 HPU, Upper Spacer, Centrigure Building, Hot Well Lube Room, TSM Pump, Pump Building, Lower Spacer, Mud Pit, Support Skids #1 & 2, Cleaned Equipment as Needed 00:00 12:00 12.00 0 0 DEMOB MOVE DMOB P Clear Pipe Deck for Dismantling Support Skid - Remove Top Support Structure - Remove Vertical Supports and Stack on Tops 12:00 00:00 12.00 0 0 DEMOB MOVE DMOB P Load Support Skid Top Caps and Vertical Supports - Load Oil Tank Room, #1 HPU, #2 HPU, Upper Spacer, Centrigure Building, Hot Well Lube Room, TSM Pump, Pump Building, Lower Spacer, Mud Pit, Support Skids #1 & 2, Cleaned Equipment as Needed 05/29/2009 Skid Rig & Clean Top Deck - Pull Generator #3 and 4 Buildings - Remove and Cap #4 Generator for Shipment - Pull Support Structure Deck & Vertical Supports then Stack and Make Ready for Loading - Wash White Iron and Buildings - Boat Unavailable due to Marathon Oil Company Use 00:00 12:00 12.00 0 0 DEMOB MOVE DMOB P Pre -Tour Safety Meeting - Skid Rig & Clean Top Deck - Pull Generator #3 and 4 Buildings - Remove and Cap #4 Generator for Shipment Page3of5 • Date r:. S. * � •th ; Phase , C�!�� ' Subcode • .•"C., , Comrrierit 12:00 00:00 12.00 0 0 DEMOB MOVE DMOB P Pull Support Structure Deck & Vertical Supports then Stack and Make Ready for Loading - Wash White Iron and Buildings - Boat Unavailable due to Marathon Oil Company Use 05/30/2009 Load baot w/ Support Structure Decks 1 -6, Vertical Supports, Two Generators, Miscellaneous Pallets, Stairs and Landings, and Top Buildings - Power Wash Loser Buildings and White Iron - Load Boat w/ Boiler Bldg., Parts House, Upper Suction Enclosure, Suction Tank, Spacers, #1 Mud Pump, Compressor Building, Fule Tank, Hooper Room, 2 Roof Caps, and White Iron Bases 00:00 12:00 12.00 0 0 DEMOB MOVE DMOB P PJSM - Load baot w/ Support Structure Decks 1-6, Vertical Supports, Two Generators, Miscellaneous Pallets, Stairs and Landings, and Top Buildings - Power Wash Loser Buildings and White Iron 12:00 00:00 12.00 0 0 DEMOB MOVE DMOB P Load Boat w/ Boiler Bldg., Parts House, Upper Suction Enclosure, Suction Tank, Spacers, #1 Mud Pump, Compressor Building, Fule Tank, Hooper Room, 2 Roof Caps, and White Iron Bases 05/31/2009 Loaded boat w/ Support Skid Pieces 2 -6, Generators 1 -2, MCC Building, Tool Pusher Office, Hydraulic Jacks, Stairways and Miscellaneous Piping - Shovel and Power Wash the Deck - Assemble Loads of Miscellaneous Equipment - Roll up Kuukpik Generator Cables - Service Vacuum System - Prep Mud Dock for Removal - Clean Platform Decks 00:00 12:00 12.00 0 0 DEMOB MOVE DMOB P Loaded boat w/ Support Skid Pieces 2 -6, Genrators 1 -2, MCC Building, Tool Pusher Office, Hydraulic Jacks, Stairways and Miscellaneous Piping - Shovel and Power Wash the Deck - Assemble Loads of Miscellaneous Equipment. BJ Injection hands here injecting 130 BBLS of rain & wash water. Flush A -12 with 60 BBLS fresh water. 12:00 00:00 12.00 0 0 DEMOB MOVE DMOB P Roll up Kuukpik Generator Cables - Service Vacuum System - Prep Mud Dock for Removal - Clean Platform Decks 06/01/2009 Clean Drill Deck - Inject Waste Water from Production Pits 1 & 7 - Remove Mezzanine - Install Hand Rails - Make Loads Ready for Boat - Remove MI Filtering Equipment - Load Boat w/ MI Filter Press, Mezzanine, MI Slurry Skid, MI Vacuum Unit, MI Small & Large Filter Units, MI RVT Tank, MI Tool Box & Miscellaneous Bundled Iron, Hand rails & Slings - Completed Injecting Fluid from Production Pits 1 & 7 - Clean Production Pits 1 & 7 00:00 12:00 12.00 0 0 DEMOB MOVE DMOB P Clean Drill Deck - Inject Waste Water from Production Pits 1 & 7 - Remove Mezzanine - Install Hand Rails - Make Loads Ready for Boat Page 4 of 5 • Date . . es.Frc m.. Der � ®a Depth ';Phase bode.....;. Subcode ..T Corgi . 12:00 00:00 12.00 0 0 DEMOB MOVE DMOB P Remove MI Filtering Equipment - Load Boat w/ MI Filter Press, Mezzanine, MI Slurry Skid, MI Vacuum Unit, MI Small & Large Filter Units, MI RVT Tank, MI Tool Box & Miscellaneous Bundled Iron, Hand rails & Slings - Completed Injecting Fluid from Production Pits 1 & 7 - Clean Production Pits 1 & 7 06/02/2009 Skid BJ Cement into place for removal in pump room. Remove spill lip around unit. With crane, pick the BJ unit and set onto boat. Continue with clean up in pump room and pits. Continue load boat with remaining loads. Boat headed back to OSK at 0600 HRS. Continue pack up office supplies. Load all remaining personnel and equipment. Fly back to OSK. Demob complete @ 2400 HRS. 00:00 06:00 6.00 0 0 DEMOB MOVE DMOB P Skid BJ Cement into place for removal in pump room. Remove spill lip around unit. With crane, pick the BJ unit and set onto boat. Continue with clean up in pump room and pits. Continue load boat with remaining loads. Boat headed back to OSK at 0600 HRS. 06:00 00:00 18.00 0 0 DEMOB MOVE DMOB P Continue pack up office supplies. Load all remaining personnel and equipment. Fly back to OSK. Demob complete @ 2400 HRS. Page 6f5 • NCI A -16 Well Events Summary • DATE SUMMARY 5/8/09 Move rig. Wireline work 5/9/09 Rig up SWS & attempting to set IBP. 5/10/09 Wait on Baker parts. Rig up & rRIH w/ IBP 5/11/09 Set IBP, Circ. & nipple down tree. Nipple up BOPE. 5/12/09 Test BOPE. Circ. Lay down tbg. 5/13/09 Lay down 4.5" tbg. RIH fish PBR POH lay down PBR RIH w/ Sump Packer 5/14/09 Run & set Sump packer. Circ. POH. Pick up Premier packer & RIH. 5/15/09 RIH w/ packer. Pressure to 2200 psi & PBR separated from string. Fish out same. 5/16/09 POH recovered fish. Run 4.5" tbg. Pump corr. inhibitor. Wireline work. NOTE( Total fluids lost to well 3218 bbls.) 5/17/09 Set Packer. Wireline work. Nipple down BOPE & nipple up tree. 5/18/09 Load Boat, Lay down 4" drill pipe. Clean rig. 5/19/09 Clean Rig and Grey Iron - Disocoonect and Lay Down CPAI Tesco Top Drive - Remove Hardware and Begin Removing Tesco Top Drive Torque Tube 5/20/09 Rig Down Torque Tube - Grease Threads and Bag All 1502 Fittings - Load Boat - Remove Derick House - Remove Kelley Hose - P/U Kuukpik Top Drive - Remove Beaver Slide, Landings & Walkways - Skid Rig - Change Bridle Lines- Install Skid Rams on Tank Farm - Install Derrick Guides - Remove Geronimo Line - Scope Down the Derrick - L/D Kuukpik Top Drive - Prep Loads for Boat - Clean the Derrick - Pull BOP Dolly - Hook Up Hydraulics for Tank Farm Skid. Release rig from A -16 @ 24:00 5/20/09. De -mob. 6/8/09 PERFORATED FROM 7364'- 7382'. CORRELATED TO SLB USIT LOG RECORDED 28 -OCT -2008 PERFORATED INTERVAL USING 2 -7/8: POWER JET OMEGA, 2906, MAX 6 SPF, 60 DEG PHASE 6/9/09 PERFORATED THE FOLLOWING INTERVALS WITH 2 -7/8" POWERJET OMEGA, 6 SPF, 60 DEG PHASING. CORRELATED TO SLB USIT LOG DATED 28 -OCT- 2008 7329' -7337' 7289' -7301' 7046' -7066' 7038' -7046' 6/20/09 MIRU SLB E -LINE UNIT. MADE FOUR PERF GUN RUNS WITH 2.875" HSD POWER JET OMEGA 6 SPF GUNS. SHOT PERF INTERVALS @ 6921' TO 6941', 6911' TO 6921', AND 6856' TO 6876' MD. ON FOURTH RUN, GUNS MISFIRED. POOH W/ LIVE GUNS. RDFN. JOB IN PROGRESS. 6/21/09 SHOT PERF INTERVALS USING 2.875" HSD POWER JET OMEGA MAX 6 SPF 60% PHASE @ 6642' TO 6655' MD, 6663' TO 6671' MD, 6755' TO 6766' MD, 6766' TO 6776' MD, 6806' TO 6814' MD, 6846' TO 6856' MD. JOB SUSPENDED DUE TO HIGH WINDS, SECURE WELLHEAD, RDFN, JOB IN PROGRESS. 6/22/09 SHOT PERF INTERVALS USING 2.875" HSD POWER JET OMEGA MAX 6 SPF 60% PHASE @ 6361' TO 6366' MD, 6366' TO 6386' MD, 6427' TO 6734' MD, 6467' TO 6475' MD. PERFORATING COMPLETE. RD SLB E -LINE EQUIPMENT, SECURE WELLHEAD, PREP SLB EQUIPMENT FOR DEMOB. No-- ''. SAK • NCI A -16 ConocoPhillips a Max Angle MD TD C " ` Well Attributes i'1(3,: t'' 1 i,x W Ilbore APUUWI Field Berne Well Status 'Inc! 0) MD(11K B) Act Btm (ftKB) Ci ,, Il p, , 508832012700 COOK INLET SHUT - IN _ 9,314.0 Comment H25 Last Ta l OMB) (PPm) � tat on E d Date KB -Grd (ftl Rig Relapse Dab SSSV NIPPLE 1 l Last WO 1 5/18/2009 10/27/2008 �` T >j • ' 7 7ji, .,) 3 `: A too tat Depth KB) I End Date Ann t t Last Mod By End Date ,uwoea.9 _ ___.9� Rev Reason: CASING ADJUSTMENT Imosbor 7/14/2009 Casing Strings Casing Description Siring 0... String ID ... Top (ftKB) Set Depth (1.. Set Depth (ND) String Wt... String String Top Thrd e ' CONDUCTOR 30 28.000 45 0 400.0 400.0 Casing Description String 0... String ID ... Top (MB) Set Depth (1... Set Depth (N ng D) .. String Wt... Stri ... String Top Thrd CbOLKT017,iN00 SURFACE 9 5/8 8.835 48.6 4,535.8 3A57.2 40.00 L-80 BTCM - aaxc9m te•f ti Casing Description i _ String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) String Wt... String ... String Top Thnt ° PRODUCTION 7 6276 44 S 9,301.0 7,617 8 2600 L-80 BTCM Tubing Strings I 111111t Tubing Description String 0 .. IString ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) String Wt.. String ... String Top Thrd : TUBING I 41/2 I 3.958 426 6,291.5 4,644 I 12.60 L -80 IBTM oN an.9ar9 -- ka Completion Details I a me ) i Top Depth owe `sT � . (ND) Top Inc! 7i To ftKB) (KB) r) Item Description Comment ID (in) 42.6 42.6 -0.12 HANGER TUBING HANGER 3.958 euarACe,.9.55r 503.0 502.9 4.40 NIPPLE CAMCO BP-6i LANDING NIPPLE 3.813 a9s ,,,. aza4 - -- tl 6 ,258.5 4,607.3 2 5.22 NIPPLE 'V NIPPLE 3.813 f PACKER Baker Premier mier Packer 3.890 6,278.9 4,632.4 23.22 NIPPLE "DB' Landing Nipple 3.750 67i90.3 4,642.8 - 22.90 WLEG W reline Entry Guide 3.930 NIPPLE. am - . - . T bing D . - escription S on l _ 0... - -� u tring O. String ID ... Top (HKB) Set Depth (i... Set Depth (ND) String Wt.. I Str g .. Sfrirg Top Thld SUMP PACKER 2 4 1 3 450 I 7,390.8 7 430 1 �.. 5,751.5 11.00 1 1 3 String P.caea an eenr.4: „ -_- __ Completion Details Top Depth' 000 bt - (TVD) Top Intl Ink, n, aceies -- ; Top (RICE) (ftKB) ('1 Item Description Comment ID (in) 7,390.8 5,712.4 4.75 PACKER Baker SC-2 Pkr 708-40 Nitrle 4.000 Pear 4.274,69. _ xw,a ,6a7- a ,6>a - - 7,395.0 5,716.6 4.74 MILL OUT EXT Mill Out extension 4.650 7,416.1 5,737.5 4.69 NIPPLE R- Nipple 3.250 aASt -� -- 7,417.1 5,738.5 4.69 Snap Latch Snap Latch 82-40 S -22B 3.260 �'"" . 7,423 1 5,744.5 4 68 SEAL Seal Unit 3.260 e wer ,.m . .. _ - eia o16 c ti_ -- 7 ,426.2 5,747.6 467 Spacer 3.260 9u - -- "aPa "" 7 , 4 30 1 5 751.5 4 67 SHOE Mule Shoe 2.410 sour Tubing Description String 0... .. String ID ...Top (f8(B) Set Depth (L.. Set Depth (ND) .. 'String Wt... String ... String Top Thrd TueiNa 7,415 cx. 0. mere= GRAVEL PACK I 459 3.430 I 7,426.4 I 8,805.1 7,122.9 11.00 P-110 SLHT - ,,, m, " ",t ` � \ - Completion Details T , u ,,, eHO ' � Top Depth a "�uangi ,699 - �- (ND) Topincl heM. >,6 a 4av Top (ftKB) OWES CZ„ Description Comment ID(in) s<i9>ne9 7,426.4 5,747.8 4.67 PACKER Packer SC-2 706-40 Nitrite 4.000 7,433.7 5,755.1 4.61 SBE Seal Bore 80-40 CK -250 4.000 . s9. - 949 ac: 7,457.9 5,779.2 4.54 SLEEVE KGB /C -2 isolation sleeve 3.340 11,8.0 7.017 a 1: 7,460.5 5,781.8 453 KOIV KOIV C -2 - - - -- - -- - -- 3.310 7031,46. :41 TC -755w f` 7,463.5 5,784.8 4.52 SOS Shear out Safety joint GPR -24 3.430 c r, a. _.._ _. C 4,0. -- a' 7,715.9 6,036.5 4.28 SBR SBRs @ 7716' 8007', 8318', 8540' 8613 3.250 w_ _ __._.._�.. -... _._ �..._- - 8,796.0 7,113.8 3.83 SNAP Latch Snap Latch 8240 5-223 3.260 e - - -_ tom . _ Tubing Description !String O._ 'Siring ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd '' t `1 SUMP PACKER 1 5.51 1 4.890 I 8,797.0 8,820.0 I 7.137.7 - -.- I -_. ..a r ! Completion Details _ (TVD) ND) Top Intl AP I y . y e - ( ' Top (HKB) ( (1 Hem Description Comment ID 4 (in C, 8,797.0 7,11 3.83, PACKER Packer - FS - - 0 - - "W Fr " 1._ -- "1 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) ,. _ SPA TUFINO, a e- T (790) h' ' 9 s,9 ) .. P( 4 1 ) 447 z9. (TVD) Top Inc! aiti 1 - ' To ftKB ( ) ( °) Description _ _ Comment Run Date ID (in) - 1 as - PLUG BAKER IBP DSSS 5/10/2009 1.000 trowvo a , u . ° r �� 5g ,�,, 8,991 I 91 7,308 4 83 PLUG (BAKER CIBP (OAL 2.54'00=5 69", I0=4 57") 12/27/2005 4.670 , , - „g 9eze ! Perforations & a,* /.481 3 �,�,.,,�anc,. 44" Slots s>.,n ..1.7.2404 ^ 4 Top 6 Shot cr _ Top (ND) Btm (TVD) Dens , ....en e a,6� y ) Btm (HKB) (HKB) (ftKB) Zone Date (h ..• Type Comment " ,u�w9 6,366 4,708.5 4,713.2 Beluga B, NCI 6/22/2009 6.0 IPERF 2.875" HSD PJ OMEGA MAX, 60 deg 9�� i•i -4 A -16 phase 174:.1n,,,, �.. - haw 6,366 6,386 4,713.2 4,732.0 Beluga B, NCI 6/22/2009 6.0 IPERF 2 875" HSD PJ OMEGA MAX, 60 deg w - A -16 phase ee4 6,427 6,434 4,770.4 4,777.1 Beluga B, NCI 6/22/2009 6.0 IPERF 2.875" HSD PJ OMEGA MAX, 60 deg a. A-16 phase 5. `44 lit Mandrel Details -_ -- �9sm = . y � 4/111i,„ Top Depth Top Port _. Tua 14941 (rVD) Intl OD Valve Latch Size TRO Run IP.,959>2599-- _ - ._.. • ME crow. «TIN Sin ToP lfiK< (HKB) ( °) Make Motlel (in) Sary TYPe Type (in) (Psi) Run Dab Coin._ i - -- 1 1,747.4 1688.9 CAMCO,KBG -2 -1R 1 GAS LIFT GLV BK 0.188 970.0 5/172009 9&+erve ry» i _._5 3.03 s«.« �- - -- -r 2 3,258.9 2,691.6 5' -2 -1R 1 GAS LIFT GLV BK 0.186 960.0 5/17/2009 + a9+TUa+'o 9p+a'� _ _ 9.a> - � 4 5,266.4 3,893.5 53.36 CAMCO KBG -2 iR 1 GAS LIFT GLV BK 0.188 941.0 5/17/2009 4 w . _ _ _ 3 4,431.6 3,392 6 51.65' we>n CAMCO KBG -2 -1R 1 GAS LIFT GLV BK 0.188 890.0 5/17/2009 - 0.375 _- �Pew.97.497 ° --_- 5 6.160.2 4,525.2 28.13 CAMCO KBG2 -1R 1 GAS LIFT OV BK 0.375 0.0 5/17/2009 acw.974 :9:7 9a�ti.ezaiu7. - -- " e r 9 - - Ii ,‘,,,7„,F: -_-. 'fr.' v'l°Y SAK • NCI A -16 Concert / hi p s 04 ' . Aiasi,a Irw 0,..Ylklhp. _.... - - - - KBGrd (fn Rig Release Dab • • • 10/27/2008 ,nTi ropey o vw"rE n, 9i .A0 W aF2UPy tp;69; AM. 4. _ - - _.. _. J it P er forations & Slots II caaD�cTOH a..90 6,467 6,475 4,808 4 4,8 6.0 Shot n- Top (TVD) Btm D Dens Top (ftKB) Bon (ftK6) (ftK8) (ftKB) Zone Dale _ Ish... Te Comment Beluga C, NCI 6/22/2009 CO IPERF 2.875" HSD PJ OMEGA MAX, 60 deg �_ A -16 phase I r„e sw = 7,500 7,524 5,821.2 5,845.1 Beluga M, NCI 2/10/2009 14.0 TCP HES 4 5/8" SH guns Am. .� .. A -16 1 _ 1 7,677 7,694 5,997.7 6,014/ Beluga 0, NCI 2/10/2009 14.0 TCP HES 4 5/8" SH guns A -16 7,797 7,810 6,117.4 6,130.4 Beluga P, NCI 2/10/2009 14.0 TCP HES 45/8" SH guns 0...31.,•,492 A-16 : � A -,6 7,880 7,885 6,200.2 6,205.2 Beluga Q, NCI 2/10/2009 14.0 IPERF HES 4 5/8" SH guns A - 16 swafuB,wum iii' 7,912 7,922 6 232.1 6,242.1 Beluga Q, NCI 2/10/2009 14 0 IPERF HES 4 5/8" SH guns 1 ' A -16 4wE' 7,946 7,978 6,266.0 - 6,297.9 Beluga 0, NCI 2/70/2009 � 14.0 IPERF HES 4 518' SH guns A -16 7,958 7,978 6,278 0 6,297.9 Beluga Q, NCI 1/31/2009 6.0 RPERF 3 1/8 Hi Vol PowerFrac 3106 -20.1g wm�aloe -- �9r A -t6 Chrg 8,278 8,284 6,597.1 6,603.1 Beluga S, NCI 2/10/2009 14.0 IPERF HES 4 5/8" SH guns aACaa, an, - - - -- A -16 NIPPLE, CAR, • w.o, aria ` 8,291 8,300 6,610.0 6,619.0 Beluga T, NCI 2/10/2009 14 IPERF HES S 4 5l8" SH guns A -16 mew.eaa,caae • .� __. mew.aaaeeam- 6291 8,300 6,610.0 6,619.0 Beluga T, NCI 1/31/2009 6.0 RPERF 3 118" Hi Vol PowerFrac 3106 -20.1g mew. 4n27 ae94 -- - A -16 Chrg . cew, sna.ae - • _ >s 8 8,424 6,732.7 6,742.7 Beluga T, NCI 2/10/2009 14.0 0 I PERF HES 4 5/8" SH guns A -16 9 a ;Tee ' -- 1 ■ 1 8,464 8,490 6 782.6 6,808.5 Beluga T. NCI 2/10/2009 14.0 IPERF HES 4 5/8" SH guns a29 [ A -16 e ", o ,q�,, 8,517 8,523 6,835.5 6841.5 Beluga U, NCI 2/10/2009 14.0 IPERF HES 4 5/8' SH guns 7.1.1.7 amp A-16 ex„nOr -- LA ro 8,564 8,576 6.882.3 6,894.3 Beluga U, NCI 2/10/2009 14.0 IPERF HES 4 5/8' SH guns • APAR C no _ 8,565 8,571 6,883.3 6,889.3 Beluga U, NCI 129/2009 - 6.6 RPERF 3 1/8" Hi Vol Powernac 3106 -20.1g e. " � A -16 Chrg a 8,587 8,593 6,905.3 6,911.3 Beluga U, NCI 2/10/2009 14.0 IPERF HES 4 5/8" SH guns ....., " a r q _.. t.' A -16 ] 8,709 8,724 7,027.0 7,041.9 Beluga U, NCI 1/26/2009 6.0 RPERF 3 1/8" Hi Vol PowerFrac 3106 -20.1g -..74 D ac, - A -16 Chrg sn.- e.,ra. so :._ -- Be_ P ...v...- :_.,.. ., 4 0 """ 8,709 8,724 7, 027.0 - 7,041.9 Beluga U, NCI 2110/2009 14.0 IPERF HES 4 5!8" SH guns Sowan DMA. 200111 A-16 D T0 ° aw r ` ^-° 8,734 8,741 7,051.9 7,058.9 Beluga U, NCI 2/10/2009 14.0 IPERF HES - 4 5/8" SH guns ash !' a A -16 s. 9 2 e m os v � Sara. -- -_ - -- ! 8,746 8,756 7,063.9 7,073.9 Beluga U, NCI 2/10/2009 14.0 IPERF HES 4 5/8" SH guns rte A -16 , - a o� -_ . 8,767 8,771 7,084.8 7,088.8 Beluga Ubase, 2/10 /2009 14.0 IPERF HES 4 5/8" SH guns a - NCI A-16 R .... u Notes: General & Safety a> 1K 1 . End Date Annotation we 9e f ~ -- • f ' , "A 2/28/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9. u erv469as--''' •_:::. W E ABAcr RAN, AAR1 -- .yar .020 , rv4eA W e /,aeAR. _- �P Ii7FirSea99-',-. L % r- 10,471.181., ease Brv49a -� r ' .. mew 9s, >- 9s29 • 9,2e f " larrlleina '''''er ss9$t t-' - 9817 TUBA, 9940 -_.___ 9 - en B.....ea,9 �__ ae TUBrvc 9aa9- __ ___- - - - F 9,,689 }„ -`- tilt V 988'95e9 - Crawieer,11 _ _�, 'T, TUerv4 ea,A t""4 9.,W29 ''''',=',.,T.----... r P EW, 0,724-8,1A • ilit ffortI 4� at rces..er TA 0, - S' uax4enT--N- • 0. �eq A go _. 11 n TUBING SHOE, eaot - -. -. wioOUY:Tqu. . . TD PaCIM41. - - Tyonek • • Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, June 18, 2009 12:18 PM To: 'Reimer, David J' Subject: RE: NCIU A -16 (208 -098) Dave, Thanks much for your diligence. Your reply answers my questions. No need for new paperwork. I will make what corrections are necessary by hand. Best regards, Tom Maunder, PE AOGCC From: Reimer, David 3 [mailto: David .J.Reimer @conocophillips.com] Sent: Thursday, June 18, 2009 12:14 PM To: Maunder, Thomas E (DOA) Subject: RE: NCIU A -16 (208 -098) Tom: Sorry for the delay in addressing your note, but I wanted to review the job files once they came in from the rig and talk with the company men to get some insight into your questions before responding. 1) When was the diverter system formally function tested? There are actions mentioned on 7/11 and 7/12 but there is no mention of an Inspector being notified, witnessing or declining witness. Please clarify. The diverter was nippled up and functionally tested initially on 7/12 during the mobilization phase of the project. The NU of the diverter was part of a turn key rate from Kuukpik. The diverter and Koomey unit were functionally tested on 7/16 after picking up the BHA and before going in the hole. Notification of the diverter test on 7/16 was made to and waived by Jeff Jones. Attached is the AOGCC Diverter System Inspection Report that was included in the well file. Company reps are continually reminded to make sure pertinent information such as this are included in the data base for future reference. In this case it was not entered at the rig or upon review. 2) When the well is plugged back due to directional issues, it is noted on 7/25 that cement is drilled out of the 30" conductor to 450'. This is 50' deeper than the depth given on the front of the 407. Is the difference due to the RKB height differences? The depth given on the 407 was in error. The conductor shoe was set at 450' MD. Per your instruction a revised 407 can be submitted with the correct depth or this note can serve as clarification on this issue. 3) On 10/29, the 7" casing was tested to 4500 psi. How was this accomplished? It is not stated if the blind rams were closed. If this is the case, the BOP was not tested to the casing test pressure. It is stated in the 10/28 narrative that the BOP was tested to 3500 psi. The drilling procedure called for rigging up the BJ unit and pressure testing the casing to 4500 psi for 30 minutes as soon as possible after bumping the plugs. This was done using through the landing joint. The detailed daily report from 10/30 references laying down the landing joint after the test. This report can be sent to you if needed. 4) On 1/07 a BOP test is accomplished. It appears that an RTTS is employed to hang the tubing string below the wellhead. Is this the case? Please check the summary for 1/07 and 1/08. The multiple movements of the RTTS seem "out of place ". The RTTS was set and tested on 1/7 before the BOP test. After the BOP test, the RTTS was laid down. In preparation to warm stack the rig, the RTTS was set again on 1/8, the wear ring was pulled, then the RTTS was laid down. The landing joint and tubing hanger were made up and the hanger was landed and tested. The rig was then warm stacked. 5) With 4 exceptions, when the BOP was tested (9 occasions) it is not noted which Inspector witnesses or (in most cases) waived witnessing. I am checking on this through Jim. For future reference, please have the Rig 6/18/2009 Tyonek • Page 2 of 3 Supervisors not in the narrative who witnessed or waived witness of the BOP or diverter test. Looking at the well file here is a list of BOP tests: Date Waived By Witnessed By 9/29/08 L Gramaldi 10/12/08 C Scheve 10/2//08 J Regg 12/14/08 J Regg 12/28/08 J Regg 1/7/09 J Regg 1/22/09 J Regg 2/5/09 J Regg 2/20/09 J Crisp As mentioned earlier we continually remind rig supv to include all pertinent information. We'll continue to do so. Hope this clarifies the issues regarding A -16. Let me know if you need anything else. Thanks Dave From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, June 10, 2009 1:06 PM To: Reimer, David 3 Subject: RE: NCIU A -16 (208 -098) Thanks, I may have printed off your reply, but haven't gotten it to the file. If I print it off, then 1 nuke the message. Thanks much Dave. Tom From: Maunder, Thomas E (DOA) Sent: Wednesday, April 22, 2009 11:09 AM To: Reimer, David 3 Subject: RE: NCIU A -16 (208 -098) Dave, 1 have completed reviewing the 407 for this well and have a couple of questions. 1. When was the diverter system formally function tested? There are actions mentioned on 7/11 and 7/12 but there is no mention of an Inspector being notified, witnessing or declining witness. Please clarify. 2. When the well is plugged back due to directional issues, it is noted on 7/25 that cement is drilled out of the 30" conductor to 450'. This is 50' deeper than the depth given on the front of the 407. Is the difference due to the RKB height differences? 3. On 10/29, the 7" casing was tested to 4500 psi. How was this accomplished? It is not stated if the blind rams were closed. If this is the case, the BOP was not tested to the casing test pressure. It is stated in the 10/28 narrative that the BOP was tested to 3500 psi. 4. On 1/07 a BOP test is accomplished. It appears that an RTTS is employed to hang the tubing string below the wellhead. Is this the case? Please check the summary for 1/07 and 1/08. The multiple movements of the RTTS seem "out of place ". 5. With 4 exceptions, when the BOP was tested (9 occasions) it is not noted which Inspector witnesses or (in most cases) waived witnessing. I am checking on this through Jim. For future reference, please have the Rig Supervisors not in the narrative who witnessed or waived witness of the BOP or diverter test. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 6/18/2009 ffi) STATE OF ALASKA 22008 ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Submit to: tiro reggt'a),a;aska.gov doe aogcc. rp udhoe.bsy alaska.ac v Ixb.feckensteir a aiaska goy Date: 7/16/2008 Operation: Development X Exploratory: Drlg Contractor: Kuukpik Rig No. 5 PTD # 208-095 Rig Ph. # 776 -2353 Operator: Conoco/Phillips Oper. Rep.: Morris / Ross Field/Unit & Well No.: North Gook Inlet Unit, NCIU A-16 Rig Rep.: Peters/ Knutson Operators E -Mail: kuuidpPconon ;)r?,iii s.ccs MISC. INSPECTIONS: ACCUMULATOR SYSTEM: FIP /FP Location Gen.: P Well Sign: NA Systems Pressure: 2850 psig P Housekeeping: P (Gen.) Dag. Rig: P Pressure After Closure: 1400 psig P Reserve Pit NA Flare Pit NA 200 psi Recharge Time: 12 Sec min:sec P Full Recharge Time: 1 :12 min:sec P DIVERTER SYSTEM INSPECTION: Nitrogen Bottles: 2400 Diverter Size: 20 in. Vent Line(s) Size: 16 in. Vent Line(s) Length: 40 ft MUD SYSTEM INSPECTION: Light Alarm Line(s) Bifurcated: NO Trip Tanlc P P Line(s) Down Wind: YES Mud Pits: P P Line(s) Anchored: P Flow Monitor P P Turns Targeted / Long Radius: NA Divert Valve(s) Full Opening: P GAS DETECTORS: Light Alarm Valve(s) Auto & Simultaneous: P Methane P P Annular Closed Time: 30 Sec Hydrogen Sulfide: P P Knife Valve Open Tine: 2 Sec 4 - = � - "" "v' -=° { :` r- is � . +.: ;' ....: ^`:_ Z as+3" ,. �. _.- ¢ ;a- _....., .: ... t .r. -�- cry %. 3 �. � . ... Y ..... _ .... .. .. .. ... ... c F , 201 l j -. M 4 . i -- _ , :m- zwassew-:-._ i V A 16' BkAe Lire L V -E - 1 1 Non Compile nce Items 0 Repair Items Withi NA Day (s) And contact the Inspector @ 659 -3607 Remarks: Diverter Test (for rigs) AOGCC REP.: Waived by Jeff Jones BFL 2/06/08 . OPERATOR REP.: Mike Ross Div Kuukpik 5 07- 16-08.xis 1 I _ ' i Si SARAH PALM, 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 David Reimer Drilling Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage AK 99510 -0360 Re: North Cook Inlet /Tertiary System Gas Pool, NCIU A -16 Sundry Number: 309 -151 Dear Mr. Reimer: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, / Daniel T. Seamount, Jr. Chair 571" 1a) DATED this 1 day of . F3n,009 Encl. OCAY—cAW 411 i RECEIVE l I 5 STATE OF ALASKA `" ,' / ALASKA OIL AND GAS CONSERVATION COMMISSION APR 2 3 2O v git l y APPLICATION FOR SUNDRY APPROVAL mdsica Oil & Gas Cons. Com ; N; 20 AAC 25.280 1. Type of Request: Abandon El Suspend El Operational Shutdown III Perforate ❑ Waiver - Other ❑ Alter casing ❑ D Repair well ❑ Plug Perforations 0 Stimulate ID Time Extension Change approved program 4„. Pull Tubing ® Perforate New Pool © Re -enter Suspended Well ❑ 2. Operator Name: (07 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. , . %, ) Development IS - Exploratory ❑ 208 - 098 ' 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 883 - 20127 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Yes ❑ No 0 • NCIU A -16 • 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): ADL 17589, 37831 RKB 120.6' • North Cook Inlet / Tertiary System Gas Pool • 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9314' ' 7631' • 8991' 7308' 9100' Casing Length Size MD TVD Burst Collapse CONDUCTOR 400' 30" 400' 400' SURFACE 4536' 9 -5/8" 4536' 3457' PRODUCTION 9302' 7" 9302' 7619' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7500' -8771' 5821' -7089' 4.5" L -80 7426' Packers and SSSV Type: Packers and SSSV MD (ft) SC - 2 pkr, Sump pkr @ 7426', 8797' landing nipple @ 511' 13. Attachments: Description Summary of Proposal isi 14. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development El . Service ❑ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat May 4, 2009 Oil ❑ Gas 0 ' Plugged ❑ Abandoned ❑ 17. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dave Reimer @ 263 -4347 Printed Name David Reimer Title: Drilling Engineer Signature ---Dairiok, %� � Phone 263 -4347 Date 4/23/o' Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness '. o — / 6 / Plug Integrity ❑ BOP Test VI Mechanical Integrity Test ❑ Location Clearance ❑ Other: 350C) 9 t fuM cSA t SOS]) .rS i t�,\ n,,ki..‘s) v.2mwc s__ S' Subsequent Form Required: LQ LA / APPROVED BY / Approved by: ' COMMISSIONER THE COMMISSION Date: , Form 10 -40 Revised 06/2006 s ? I fts C �0L//`/� Submit inupica, I y ,. 56. ,--1 • • ConocoPhi Post office Box 100360 Anchorage, Alaska 99510 -0360 April 23, 2009 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry approval to Change Approved Program: NCIU A -16 Permit to Drill: 208-098 API Number: 50 -883- 20127 -00 Property Designation: ADL 17589, 37831 Field / Pool: North Cook Inlet t Tertiary System Gas Pool Dear Commissioner: ConocoPhillips Alaska, Inc. would like to a sundry to change the approved program on the NCIU A -16 welibore, located in the North Cook Inlet / Tertiary System Gas Pool drilled on the Tyonek Platform with - the rig Kuukpik #5. The NCIU A -16 well was originally completed in February 2009. This sundry to change the approved program on NCIU A -16 involves moving the Kuukpik #5 back over to NCIU A -16 and de- completing the • upper Beluga interval by pulling the existing liner and completion, then recompleting the well by running a liner and completion with a packer and perforating select zones within the interval. No gravel pack will be performed. If you have any questions or require any further information, please contact me at 263 -4347 or Chip Alvord at 265 -6120. Sincerely, David Reimer Staff Drilling Engineer cc: Chip Alvord ATO -1570 • • 8 ConocoPhillips Post Office Box 100360 Anchorage, Alaska 99510-0360 April 30, 2009 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry approval to Change Approved Program: NCIU A -16 Permit to Drill: 208-098 API Number: 50- 883 - 20127 -00 Property Designation: ADL 17589/ADL 37831 Field / Pool: North Cook Inlet / Tertiary System Gas Pool Dear Commissioner: Per your request, the following detailed de- completion / recompletion procedures are being provided by ConocoPhillips Alaska, Inc. to supplement the 10-403 sundry submitted to change the approved program on the NCIU A -16 wellbore. Estimated start date for this work is May 5, 2009. NCIU A -16 Completion Procedures: 1. Skid rig from A -15 to A -16 2. Load pits w/ 8.6 KCI brine 3. RU slickline 4. Pull SSSV 5. Bleed off pressure in inner annulus 6. Pull lowest dummy valve in GLM 7. RD slickline, RU E -line 8. Run inflatable bridge plug to isolate lower completion 9. Circ 8.6 brine down tubing through lowest GLM up IA. Pressure test IBP 10. Set BPV in hanger, ND tree 11. NU BOP, test to 3500 psi 12. Pull hanger, straight pull to unlatch from PBR, POOH w/ tubing, LD 13. RIH, w/ PBR retrieving tool, release anchor, POOH, LD 14. RIH Premier Packer & PBR assembly on DP; set & test; shear off PBR; POOH 15. RIH with Upper completion 16. MU tubing hanger and landing joint. Pressure up control line to 5,000 psi prior to landing hanger. 17. Land tubing hanger and run in all the lock down screws. Pressure test hanger to 5000 psi. 18. RU slickline and retrieving toolstring. 19. RIH with slickline, pull dummy in SSSV 20. Drop RHC ball and rod 21. Back out and recover landing joint. 22. Close blind rams, pressure test tubing to 3500 psi. Hold for 5 minutes. 23. Pressure up annulus to 3500 and monitor for 30 minutes. 24. Install BPV in the tubing hanger. ND BOP's and NU tree. Pull BPV. 25. Run two -way check. Pressure test tree to 5000 psi. Bleed off pressure, retrieve two way check 26. Retrieve the RHC ball and rod. RIH and retrieve the RHC plug. 27. PU and RIH with SSSV assembly to safety valve nipple depth. Set SSSV, POOH. 28. Test SSSV; R/D Slickline. 29. Bleed off annulus to zero. Shut in the well. 30. RDMO • If you have any questions or require any further information, please contact me at 263 -4347 or Chip Alvord at 265 -6120. Sincerely, David Reimer Staff Drilling Engineer cc: Chip Alvord ATO -1570 Tyonek • Page 1 of 2 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, April 22, 2009 10:21 AM To: Reimer, David J Subject: RE: Tyonek Dave, This confirms our conversation of a few minutes ago. Since the 407 has been filed for NCIU A -16 (208 -098), it is appropriate to file a 403. Since NCIU A -15 (208 -097) has not been completed, no sundry is needed. Call or message with any questions. Tom Maunder, PE AOGCC From: Reimer, David 3 [mailto: David .].Reimer @conocophillips.com] Sent: Wednesday, April 22, 2009 8:18 AM To: Maunder, Thomas E (DOA) Subject: RE: Tyonek no problem - thanks! From: Maunder, Thomas E (DOA) [mailto:tom.maunder @ alaska.gov] Sent: Wednesday, April 22, 2009 8:14 AM To: Reimer, David 3 Subject: RE: Tyonek Dave, I just got the 407 for NCIU 16. I will look at the files and get back to you shortly. Tom From: Reimer, David J [mailto:DavidJ .Reimer @conocophillips.com] Sent: Wednesday, April 22, 2009 7:18 AM To: Maunder, Thomas E (DOA) Subject: FW: Tyonek Tom: I know you have been hooked up with the issues on Pioneer, I was just wondering if you had any further insight into what information needs to be submitted before we move back over A -15 & A -16 to complete the upper zones. Thanks Dave From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, April 20, 2009 11:39 AM To: Reimer, David J Subject: RE: Tyonek Hi Dave, What is the timing to finish A -14? Tom kv 6/19/2009 Tyonek • Page 2 of 2 From: Reimer, David 3 [mailto: David .].Reimer @conocophillips.com] Sent: Monday, April 20, 2009 11:13 AM To: Maunder, Thomas E (DOA) Subject: Tyonek Tom: After we finish completing A -14, we are planning to move back to A -15 & A -16 and complete the upper Beluga. We only completed the lower zones on these 2 wells when we were on them the first time. One of the wells will be completed with a gravel pack. The other will be completed with tubing and a packer. The tubing will be perforated with wireline and no gravel pack will be run. The application for permit stated that we would be completing the upper zones in both A -15 & 16. My question is this: The completion report has already been submitted for A -16. Since we are planning to move back to A -16, do we need to submit a sundry indicating this or what type of paperwork does the AOGCC require for A -16 or A -15? Thanks for the help Dave 6/19/2009 • G. L. Alvord Alaska Drilling Manager Drilling & Wells P. O. Box 100360 /PSIV Anchorage, AK 99510 -0360 ConocoPhi !l lips Phone: 907 - 265 -6120 April 2, 2009 Commissioner R NED State of Alaska ANi ?On Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Alaska ;ail & Gas Gons. Con nissioR Anchorage, Alaska 99501 Anchorage Subject: Well Completion Report for NCIU A -16 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the North Cook Inlet well NCIUA -16. If you have any questions regarding this matter, please contact me at 265 -6120 or Philip Hayden at 265 -6481. Sincerely, Ot_ G. L. Alvord Alaska Drilling Manager CPAI Drilling GLA/skad • STATE OF ALASKA • APR 0 6 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION Ai•` • CM & Gas Cans. Cot nission WELL COMPLETION OR REC() MP LETION REPO AN la. Well Status: Gi l ❑ Gas U Plu ❑ Abandoned Suspended lb. Well Class: 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WDSPL ❑ WAG ❑ Other ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: February 24, 2009 • 208 - 098 ' 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 July 18, 2008 ' 50 883 - 20127 - 00 • 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: 1 Surface: 1304' FNL, 1016' FWL, Sec. 6, T11 N, R9W, SM • October 16, 2008 NCIU A - 16 • Top of Productive Horizon: 8. KB (ft above MSL): 120.6' RKB • 15. Field /Pool(s): 1086' FSL, 2095' FEL, Sec. 36, T12N, R1OW, SM Ground (ft MSL): not applicable North Cook Inlet Total Depth: 9. Plug Back Depth (MD + TVD): 1140' FSL, 2208' FEL, Sec. 36, T12N, R1OW, SM 8991' MD / 7308' TVD Tertiary System Gas Pool • 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 332035. y 2586675 • Zone 4 • 9314" MD / 7631' TVD • ADL 17589, 37831 TPI: x - 328959 y - 2589111 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 328847 • y 2589167 • Zone 4 511' MD / 511' TVD n/a 18. Directional Survey: Yes i0 No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) 101' MD • (ft MSL) not applicable 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/RES, USIT, Dens /Neu /MDT 22. CASING, LINER AND CEMENTING RECORD Se- e- ( r.-` SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM .NTOP BOTTOMA SIZE PULLED 30" na na 46' _ 4 l j 46' �4etrc 50 n/a driven 9 -5/8" 40# L -80 46' 4536' 46' 3457' 12.25" 1405 sx Class G 7" 26# L -80 46' 9302' 46' 7619' 8.75" 385 sx Class G 23. Open to production or injection? Yes i0 No ❑ If Yes, list each 24. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 7426' 7426', 8797' see attached list • 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED frac 1 from 8709 - 8724' attempted frac, 0 # sand behind csg frac 2 from 8565-8571' not treated frac 3 from 8291' -8300' 20597# 20/40 Econoprop frac 4 from 7958' - 7978' 40871# 20/40 Econoprop 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 2, 2009 Gas Production - waiting on facility hook - up Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) press. psi 24 -Hour Rate -> 27. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 . Sidewall Cores Acquired? Yes U No in If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 1 ° Otti +dni I ION NONE ..,' lED w Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE `�- U) 0 , \ , , R. I . b BFL APR 2 1 2009 ,---: ---- ....;,./14 28. GEOLOGIC MARKERS (List all formations and mar • encountered): 29. FORMATION TESTS NAME MD 7VD Well tested? Yes Q No • If yes, list intervals and formations tested, Permafrost - Top not applicable not applicable briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom not applicable not applicable needed, and submit detailed test information per 20 AAC 25.071. see attached list N/A Formation at total depth: Beluga • 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, perforation list, schematic, geologic markers 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Phili y yden @ 265 - 6481 Printed Name G. L. Alvord Title: Alaska Drilling Manager / Signature / � Phone us_ G (20 Date 4 1 3��'.�1 Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 la: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of. Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 2/2007 • NCIU A -16 1 1110 )IP" Grassroots Well ConocoPh 5 Completion Schematic Conductor: 30" Set @ 400 ft MD BP6i hydraulic landing nipple for a SCSSSV with 1 /4" SS control line to surface p +1- 500' MD TOC 500' Planned TOC +/- 4230' MD / 3263' TVD above top Sterling Surface Casino: L 9-5/8", 40 # #, L -80, BTC Set © 4535.81' MD / 3457.21' TVD (200' TVD A L above Sterling -A) L 4'/2" Camco KGB -2 GLM w/ 1" DV set @ 1525' MD 4 -'W Camco KGB -2 GLM w/ 1" DV set 2705' MD 4' /s" Camco KGB -2 GLM w/ 1" DV set as 3625' MD 4-W Camco KGB -2 GLM w/ 1" DV set (5 4285' MD 3.813" X Nipple PBR Anchor SC -2 Packer w/ Alternate Bore @ 7426' MD 4 -1/2" Blank Pipe (10.25' long) + 3.25" Seal Bore Receptacles between Screen Placement: Blank # 4 - 8306 ft MD Blank # 3 - 8529 ft MD Blank # 2 - 8602 ft MD :•: .•:• Blank # 1 - 8775 ft MD Beluga M through U will Hydraulic Fracture Picks require 4 Fracs followed by Frac 4: 7958 — 7978 ft MD HRWP Frac 3: 8291 — 8300 ft MD Frac 2: 8564 — 8571 ft MD Frac 1: 8709 — 8724 ft MD • Model FS Sump Packer @ +/- 8797 ft MD ice' Cast Iron Bridge Plug @ +/ -9000 ft MD Production Casino: 7 ", 26.00 #, L -80, BTC -Mod Set @ 9301.76' MD / 7618.55' TVD 1 E ( +/- 380' MD Below Beluga I Base) _; TD at 9314' MD / 7631' TVD '% NCIU A -16 prepared by Rami Jasser 4/2/2009 Sperry Drilling Services Directional Actual Surveys, depths of intervals estimated by geologist I S WELL DEPTH ZONE FEET TOPS MD NCI_A -16 4728 Stray NCI_A -16 4798 C.I. A NCI_A-16 4856 C.I. B NCI_A-16 5160 C.I. 1 NCI_A -16 5292 C.I. 2 NCI_A -16 5413 C.I. 3 NCI_A -16 5493 C.I. 4 NCI_A -16 5609 C.I. 5 NCI_A -16 5721 C.I.6 NCI_A -16 5776 C.I. 7 NCI_A -16 5894 C.I. 8 NCI_A -16 5976 C.I. 9 NCI_A -16 6015 C.I. 10 NCI_A -16 6057 C.I. 11 NCI_A -16 6116 Beluga A NCI_A -16 6216 Beluga B NCI_A -16 6418 Beluga C NCI_A -16 6525 Beluga D NCI_A -16 6630 Beluga E NCI_A -16 6792 Beluga F NCI_A -16 6911 Beluga G NCI_A -16 7009 Beluga H NCI_A -16 7170 Beluga I NCI_A -16 7286 Beluga J NCI_A -16 7343 Beluga K NCI_A-16 7400 Beluga L NCI_A-16 7475 Beluga M NCI_A -16 7607 Beluga N NCI A-16 7673 Beluga 0 NCI A -16 7730 Beluga P NCI_A -16 7829 Beluga Q NCIA-16 8013 Beluga R NCI__A-16 8126 Beluga S NCI_A -16 8292 Beluga T NCI_A -16 8492 Beluga U NCI_A -16 8760 Beluga U base NCI_A -16 9162 Tyonek • • PERFORATIONS FOR NCI A -16 7500' -7524' MD 5821' -5845' TVD 14 spf 7677' -7694' MD 5998' -6015' TVD 14 spf 7797' -7810' MD 6117' -6130' TVD 14 spf 7880' -7885' MD 6200' -6205' TVD 14 spf 7912' -7922' MD 6232' -6242' ND 14 spf 7946' -7978' MD 6266' -6298' TVD 14 spf 7958' -7978' MD 6278' -6298' TVD 6 spf 8278' -8284' MD 6597' -6603' ND 14 spf 8291' -8300' MD 6610' -6619' ND 14 spf 8291' -8300' MD 6610' -6619' TVD 6 spf 8414' -8424' MD 6733' -6743' ND 14 spf 8464' -8490' MD 6783' -6809' ND 14 spf 8517' -8523' MD 6836' -6842' TVD 14 spf 8564' -8576' MD 6882' -6894' ND 14 spf 8565' -8571' MD 6883' -6889' ND 6 spf 8587' -8593' MD 6905' -6911' ND 14 spf 8709' -8724' MD 7027' -7042' ND 6 spf 8709' -8724' MD 7027' -7042' ND 14 spf 8734' -8741' MD 7052' -7059' ND 14 spf 8746' -8756' MD 7064' -7074' ND 14 spf 8767' -8771' MD 7085' -7089' ND 14 spf • • ConocQPhillips Time Log & Summary Weeview Web Reporting Report Well Name: NCI A - 16 Rig Name: KUUKPIK 5 Job Type: DRILLING ORIGINAL Rig Accept: 7/12/2008 1:00:00 PM Rig Release: 8/2/2008 6:00:00 PM Date \ .Deoit t. Pha e Sube T Co nvent \ c . ! i . .�� . ��" bur x 06/16/2008 24 hr Summary Prepare rig modules for mobiliztion to boat & to platfrom. 12:00 00:00 12.00 MIRU MOVE MOB P Continue arrange U load Kuupik #5 rig units on boat for transfer to Platform. 06/17/2008 Load Kuupik #5 Rig equipment on boat. Travel to Platfrom. Offload 9 loads of rig equipment, hauling backloads tto beach. 00:00 14:30 14.50 MIRU MOVE MOB P Continue arrange & load Kuupik #5 rig units on boat for transfer to Platfrom. 14:30 17:30 3.00 MIRU MOVE MOB P Travel with boat to platfrom. 17:30 22:30 5.00 MIRU MOVE MOB P Held PJSM with Crane operators and rig crew. Discuss safety & hazard recognition issues. Discuss procedures, signals for crane pics. Pick a total of 9 rig loads from boat to loacte & stack on platfrom deck. Load boat with back haul equipment. Equipment loaded on deck - Hydraulic powwer unit, support skids Generator #1 & #2. MCC Building, Centrifugal Building, and parts house. 22:30 00:00 1.50 MIRU MOVE MOB P Travel with boat back to beach, to off load backhaul equipment. 06/18/2008 Travel with boat back to beach and off load back hauled equipment. Load rig modules and support skids. Travel to platfrom to load modules on deck. Continue building rig modules on platfrom deck. 00:00 01:30 1.50 MIRU MOVE MOB P Continue Travel with boat back to Nikiski beach and off load back hauled equipment. Load rig module equipment. 01:30 03:30 2.00 MIRU MOVE MOB P Travel with boat back toTyonek Platfrom. 03:30 07:30 4.00 MIRU MOVE MOB P Held PJSM with Crane operator & rig crew. Obtain Hot work permit. Discuss safety & hazard recognition issues. Pick jacks from boat and pin same to support skid on deck. Make up hydraulic hoses to skid support skids with modules across deck. Continue off load more support skids, and modules. 07:30 09:30 2.00 MIRU MOVE MOB P Travel with boat back to Nikiski beach. 09:30 15:30 6.00 MIRU MOVE MOB P Off load back haul equipment. Load rig modules, and skid support iron. Page 1 of 78 • _ 't 15:30 18:00 2.50 MIRU MOVE MOB P Travel with boat back to Tyonek Platfrom with load #3. 18:00 00:00 6.00 MIRU MOVE MOB P Held PJSM with crane operator and rig crew. Discuss safety & hazard recognition issues. Obtain hot work & lift permits. Off load rig modules, and skid support iron. Equipment off loaded = Support structures # 3, #4, #5, #6. Suction tank, Upper Suction tank enclosure, Both Boilers, and Vertical supports # 5,6,7 and 8. 06/19/2008 00:00 06:00 6.00 MIRU MOVE MOB P Contniue loading modules and support skids, support structures. _ Rig up on platfrom deck. 06:00 12:00 6.00 MIRU MOVE MOB P Held PJSM with new crane operator, obtaining lift permits, and hot work permit. Continue rigging up on platfrom deck. 12:00 18:00 6.00 MIRU MOVE MOB P Travel with boat back to Nikiski beach, off load backhaul equipment. Load Kuupik rig #5 modules and support iron skids. Travel back to Tyonek Platform. 18:00 00:00 6.00 MIRU MOVE MOB P Held PJSM with crane operator, obtaining lift permits, and hot work permit. Continue rigging up on platform deck. Equipment pulled to deck - Lube/Tool Building, Electrical mud pump building, TSM Mud Pump, Lower spacer building, Volume mud tank, Oil Cooler & tank with landing, HPU #1 & #2, Upper spacer building, Vertical supports # 9,10,11, & 12. 06/20/2008 00:00 02:30 2.50 MIRU MOVE MOB P Contniue loading modules and support skids, support structures. Rig up on platfrom deck. 02:30 08:30 6.00 MIRU MOVE MOB P Travel with boat back to Nikiski beach, off load backhaul equipment. Load Kuupik rig #5 modules and support iron skids. Travel back to Tyonek Platform. 08:30 16:30 8.00 MIRU MOVE MOB P Contniue loading modules and support skids, support structures. Rig up on platfrom deck. 16:30 00:00 7.50 MIRU MOVE MOB P Travel with boat back to Nikiski beach, off load backhaul equipment. Load Kuupik rig #5 modules and support iron skids. 06/21/2008 Travel with boat back to beach and off load back hauled equipment. Load rig modules and support skids. Travel to platfrom to with load #7 to load modules & subbase on deck. Continue building rig modules on platfrom deck. Page 2 of 78 s � t Code od ub ode Comment . Fro��Ta :� I:IUr°.,. , S. ®pth •ptt�ha>�. ' e�s�� T � - 00:00 12:00 12.00 MIRU MOVE MOB P Travel with boat back to Nikiski beach, off load backhaul equipment. Load Kuupik rig #5 modules and support iron skids. HAul Skid baswes # 1,2. Landing enrty, CO. Man office, Camp Medic Room, Parts houses # 2 & 3. and Locker house on on load #6. 12:00 00:00 12.00 MIRU MOVE MOB P Travel with boat back to Nikiski beach, off load backhaul equipment. Load Kuupik rig #5 modules and support iron skids. Haul Acetylene & oxygen racks, Sub skid BOP Guard, Sub Skid beams #1 & 2. Sub Skid base #1 ODS> Sub Skid base #2 ODS Middle, 2- Hydraulic jacks for moving, Sub Base cellar area, and Sub Skid base #3 & 4 for load #7. 06/22/2008 Travel with boat back to beach and off load back hauled equipment. Load rig modules and support skids. Travel to platfrom to with load #8 to load modules & subbase on deck. Continue building rig modules on platfrom deck. Perform welding projects in pits and on rig. 00:00 18:00 18.00 MIRU MOVE MOB P Travel with boat back to Nikiski beach, off load backhaul equipment. Load Kuupik rig #5 modules and support iron skids. 18:00 22:00 4.00 MIRU MOVE MOB P Held PJSM with Crane operator& crew. Discuss safety & hazard recognition issues. Discuss crane pics and placement. Obtain Hot work and crane lift permits. Load 2 welders & OXY/ ACY rack, Sub skid bases # 3, #4. Floor plates for cellar, 2 - Sub base ODS sub boxes, Rear landing & handrails. Supports fro grating & landing between Choke & Koomey modules. Choke manifold module, Acumulator Module, Substructure legs, and stabilization legs. Sub base rails, stairs, and landings. Continue with welding projects in pits, and on rig. 22:00 00:00 2.00 MIRU MOVE MOB P Travel with boat back to Nikiski beach, off load backhaul equipment. Load Kuupik rig #5 modules and support iron skids. Continue with rig up and welding projects in pits and rig. Crew Change 06/23/2008 Travel with boat back to beach and off load back hauled equipment. Load rig modules and support skids. Travel to platfrom to with load #9 to load modules & subbase on deck. Continue building rig modules on platfrom deck. Perform welding projects in pits and on rig. 00:00 12:00 12.00 MIRU MOVE MOB P Held Pre -Tour meeting. Discuss safety & hazard recognition issues. Discuss rig up. Obtain Hot work and crane lift permits. Continue rig up on platfrom deck. Crew Change Page 3 of 78 • L,...Fr&n . o T ti %r th � _ n� • - • � Ph Code . �� . � • • T ,., � rttent 12:00 \ 22:00 10.00 MIRU MOVE MOB P Held Pre -Tour meeting. Discuss safety & hazard recognition issues. Discuss rig up. Obtain Hot work and crane lift permits. Continue rig up on platfrom deck. Boat in route to Nikiski beach. 22:00 00:00 2.00 MIRU MOVE MOB P Held PJSM with crew. Discuss boat load configuration. Offload boat, installing modules on rig. This boat load consisted of Sub base hydraulic raising cylinders, Rig floor, Rotary table with drive motor. Shaker mud tank, Shaker building & landing, Gas buster, ODS toolhouse, ODS roofcap, Water tank walkway, Derrick stands, Pit module, North slope telecom freight and misc tools. Crew Change 06/24/2008 Travel with boat back to beach and off load back hauled equipment. Load rig modules and support skids. Travel to platfrom to with load #10 to load modules & subbase on deck. Continue building rig modules on platfrom deck. Perform welding projects in pits and on rig. 00:00 03:30 3.50 MIRU MOVE MOB P Held Pre -Tour meeting. Discuss safety & hazard recognition issues. Discuss rig up. Obtain Hot work and crane lift permits. Continue rig up on platfrom deck. Continue off load boat, loading modules on rig and on deck. 03:30 05:00 1.50 MIRU MOVE MOB P Load back haul equipment on boat. Travel with boat back to Nikiski beach. 05:00 17:00 12.00 MIRU MOVE MOB P Continue rig up Kuukpik #5 on platform deck. Continue with pit modifications and welding projects. Rig cable trays and power cords. 17:00 23:30 6.50 MIRU MOVE MOB P Unload rig equipment from supply boat. Drawworks slide upper @ lower wind walls, change room, drillers dog house, D S roof cape, derrick top section with crown and torque tube, derrick stand, drawworks and other rig parts. Set derrick on derrick stand 23:30 00:00 0.50 MIRU MOVE MOB P Held pre -Tour safety meeting. discuss what loads go where and how to do it safely. 06/25/2008 Travel with boat back to beach and off load back hauled equipment. Load rig modules and support skids. Travel to platfrom to with load #10 to load modules & subbase on deck. Continue building rig modules on platfrom deck. Perform welding projects in pits and on rig. At 1500 HRS. Sent boat back to beach as it was unable to unload due to high winds. 00:00 15:00 15.00 MIRU MOVE MOB P Continue rig up Kuukpik #5 on platform deck. Continue with pit modifications and welding projects. Rig cable trays and power cords. Page 4 of 78 . • Date From te ® or *8. Depth E. [tooth Phase `Code So to T Othment. '.\ 15:00 00:00 9.00 MIRU MOVE WOW T The Champion was waiting to offload equipment. Weather was 35 knot winds, and seas pushing boat under platform. Safety issues concerning personnel & crane operation determined decision to turn boat back to beach to anchor up and wait on weather. Meanwhile the men kept working on electric lines, scaffolding, fuel lines to generators and drains. 06/26/2008 The supply boat could not finish unload load #12 due to high winds. Continue work on connecting power to modules, phones and rigging up. Held safety stand down with both crews.and all supervisors. Note : Generator on line at 1300 HRS. Test all 4 generators and leave 1 online. 00:00 08:00 8.00 MIRU MOVE WOW T Could not unload Champion (load #11) due to high winds. Proceed with rig up, electric lines, scaffolding, fuel line to generator and drain lines 08:00 10:00 2.00 MIRU MOVE MOB P Continue offload boat. Equipment hauled - Hydraulic hoses, Hydraulic top drive unit & blocks, Spool drill line, Pipe racks with Mud tank flow lines, catwalk, walkways for platform & support modules, BOP stand, BOP skid, Dumpster, and lower derrick section. 10:00 14:00 4.00 MIRU MOVE SFTY P Held safety stand down with all crews and safety personal, CPAI safety rep, and drilling superintendant. Discuss working in close quarters with production personal, keeping a clean and tidy work location and living quarters, and issues concerning forward progress accident & incident free. 14:00 00:00 10.00 MIRU MOVE WOW T Continue with rig up. Work on flow lines, hydraulic lines, stabbing board, and continue to run electric cables, and communication lines. Start Generators & verify no fuel line leaks and operational. Crew change 06/27/2008 The supply boat could not finish unloading load #12 due to high winds. Continue work on connecting power to modules, and phones. Continue connecting modules and rigging up. At 05:00 hrs the wind died down and the derrick was brought on board, pined into position and raised into position with no problems at all. 00:00 12:00 12.00 MIRU MOVE MOB P Weather improved and the Champion came along side platform. Derrick section was unloaded and set in place. Set draw works on derrick and secure. Rig up the rest of the derrick lines and make ready to raise derrick. Continue to work on electrical lines, flow lines and walk ways. Crew Change Page 5 of 78 • Date Front. rf,,,. Lour. th . �i P..h � .. Su boode F C men - .. .., 12:00 00:00 12.00 MIRU MOVE MOB P Continue to rig up a • der lines and secure draw works onto derrick section. Held pre -Job safety meeting on deck with all hands involved with raising derrick. Double check complete derrick section to be raised to make sure all is ready for raising the derrick. Raise derrick section from derrick horse at 20:00 hrs, with no problems. (from 23:00 hrs to 24:00 hrs X -Ray work was being done on production deck. All hands were sent to the other side of the rig to work in a safe place.Crew Change 06/28/2008 When winds died down enough the derrick was raised. Work continued on rigging up to raise the drill floor untill X -Ray crews started to X -Ray at 23:00 hrs till 01:30 hrs. wind picked up and could not raise drill floor. At 06:00 this morning we are waiting on winds to die down so the drill floor can be raised. 00:00 01:00 1.00 MIRU MOVE MOB P X -Ray crew working on deck in front of drill floor, all worked stoped in this area. Work continued in other areas, run electrical cables between shacks, run rig lights, flow lines, etc, etc. 01:00 06:00 5.00 MIRU MOVE MOB P When X -Ray crew was done the wind had picked up to 15 MPH, to high to raise derrick.Work continued in other areas, run electrical cables between shacks, run rig lights, flow lines, etc, etc. 06:00 12:00 6.00 MIRU MOVE MOB P Wind died down after breakfeast, rig floor was raised into place and pinned. Crew Change 12:00 18:00 6.00 MIRU MOVE MOB P Continue rig up on platfrom, attaching lines and communication lines. 18:00 00:00 6.00 MIRU MOVE MOB P Champion came along side and rig components were unloaded. top drive, beaver slide, BOP's, top drive torque tubes, portable vac system, centerfuge and misc. rig parts. Set mezzanine with crane and weld into place. Continue with rigging up electric lines to koomey unit, flow lines, electric lines to rig floor, etc, etc. Crew Change 06/29/2008 Raise drill floor into position, set mezzanine into position and secure, set catwalk, work on wind walls and run electric cables. Page 6 of 78 • • TitltfF � :.Date . " • "From •. To Dur S. r ED Phase Code Sub 4 ' T Com ° nt . , .. ` 00:00 00:00 24.00 MIRU MOVE MOB P Continue with unloading Champion, cat walk, mouse hole and pipe rack beams, basket suitcase covers. torque tube guides, Oxygen and acetylene bottles and misc rig components. Attach wind walls - front and back of rig floor. Rig up steam lines, electric lines and hydraulic lines ti rig floor. Continue on with hand rails and walkways between all rig sections. Rig up rig lights in substructure, derrick and rig floor. Skid rig back into place. 06/30/2008 Set rig floor wind walls, rig up lights, steam and electrical lines to floor.Continue work on communication lines. 00:00 00:00 24.00 MIRU MOVE MOB P Rig up electrical lines, steam lines and hydraulic lines to floor. Work on stairs and hand rails to rig floor. Hook up AC power to top drive. Slip and cut drilling line, restring blocks and hook up top drive. Make derrick ready to extend. Continue to work on hand rails and stairways through rig. Ron Hablutzel (Conoco safety) did a walk through today, all appears OK. 07/01/2008 Rig up electrical lines, steam lines and hydraulic lines to floor. Work on stairs and hand rails to rig floor. Hook up AC power to top drive. Slip and cut drilling line, restring blocks and hook up top drive. Make derrick ready to extend. Continue to work on hand rails and stairways through rig. Skid rig over well. Ron Hablutzel (Conoco safety' did a walk through today, all appears OK. 00:00 00:00 24.00 MIRU MOVE MOB P Rig up electrical lines, steam lines and hydraulic lines to floor. Work on stairs and hand rails to rig floor. Hook up AC power to top drive. Slip and cut drilling line, restring blocks and hook up top drive. Make derrick ready to extend. Continue to work on hand rails and stairways through rig. Skid rig over well. Ron Hablutzel (Conoco safety) did a walk through today, all appears OK. 07/02/2008 Continue rigging up service lines & top drive. 00:00 06:00 6.00 MIRU MOVE MOB P Continue rig up, installing beaver slide & catwalk. 06:00 00:00 18.00 MIRU MOVE MOB P Finish installing beaver slide & catwalk, continue rigging up Tesco topdrive. Hooking up service lines, air water steam electrical etc.. Hooking up communications. 07/03/2008 Continue rigging up service lines & hooking up top drive. Page 7 of 78 • • Da. -" e T. 34 S ® P }code ,:. .e 00:00 00:00 24.00 MIRU MOVE MOB P Continue rigging up service lines, communications etc. & hooking up tesco top drive. Continue with welding projects, installing, modifying handrails, steps, and lines. Fabricate hangers for service loops on Top Drive. 07/04/2008 Continue rigging up Tesco service lines, etc. Continue RU COM lines. Welders fabricating lines, and brackets. Continue with handrail, and stairway work. 00:00 00:00 24.00 MIRU MOVE MOB P Rigging up Tesco equipment. Hook up service loop for same. Hooking up service lines to rig. Welders working on stairways,mezzanine - building brackets for tesco set up etc. Clearing platform deck for unloading boat tomorrow. 07/05/2008 Continue rigging up Kuukpik #5 & checking out Tesco components. 00:00 00:00 24.00 MIRU MOVE MOB P Finish hooking up Tesco equipment- Testing & trouble shooting Tesco components. Hooking up service lines to rig. Welders building hand rails- steps -etc. Boat arrived with Epoch unit -spot same. Received diverter system including Annular & risers. Received swaco fabricated pump manifolds. Received office supplies & mist iron for welding projects. Backhauled garbage & Top drive framing & miscequipment. Continue work on clearing pipe deck for next load. 07/06/2008 Rigging up service lines. 00:00 00:00 24.00 MIRU MOVE MOB P Continue fine tuning Tesco Top Drive. Continue hooking up all service lines for drlg. welders making cable trays & working on mud lines- stairs - handrails -etc. Received on boat -1 MI building -1 20' crane section -4= 12 1/4" drill bits & breaker -1 pallet office supplies. 07/07/2008 00:00 00:00 24.00 MIRU MOVE MOB P Fine tuning Tesco top drive. Hooking up service lines for drilling. Welders building lines for mud discharge. Working on well covers. Prepare Crane for new boom extention. Rigging up in general. 07/08/2008 Page 8 of 78 • • Date From To *Our f S. Depth" E. <D t PhasioStode SubCode T > : 3.. menf ... , -? . 00:00 00:00 24.00 MIRU MOVE MOB P Compacting service loop on tesco top drive. Change hydraulic hoses on top drive. Making & hooking up mud lines from shakers & mud return. Hooking up mud lines on Swaco pumps. Hooking up other service lines. Working on communications. Hook up 'U' tube on poor boy degasser. 07/09/2008 Rigging up 00:00 00:00 24.00 MIRU MOVE MOB P Continue hooking up mud lines from rig to mud tanks. Hooking up charge pumps. Hooking up Exhaust pipe from BJ cementing unit. Install 20' section in crane boom. Prepare to weld on Landing ring. Rigging up electrical lines. 07/10/2008 00:00 00:00 24.00 MIRU MOVE MOB P Finish tying up hydraulic lines to top drive. Hooking up swaco pump lines. Finish mud line to platform mud tanks. Grind top of 30" conductor & set landing rings on well #16 & 15. Welding same. Hook up escape line in derrick. 07/11/2008 Rigging up. 00:00 12:00 12.00 MIRU MOVE MOB P Clean Platform mud tanks. Finish hookup to swaco pumps. Building rig floor to leak proof same. Welders working on overboard line. 12:00 00:00 12.00 0 0 MIRU WELCTI NUND P Nipple up diverter system with 20" annular preventer. (NOTE) On 7 -11 -08 @ 12:00 Kuukpik went to turn key rate for the nipple up of the diverter system. (12 hrs. on 7- 11 -08) 07/12/2008 00:00 12:00 12.00 MIRU WELCTI BOPE P Continue nipple up on diverter system. Make up bolts, tighten lock down screws, make up knife valve & bell nipple. Function tested system (OK) 12:00 00:00 12.00 MIRU MOVE MOB P Plumbing rig fuel system & rigging up in general. Calibrate gas detectors. Weld on cutting chute. Start plumbing seawater for overboard line. Install plyboard on rig floor. Plumbing in drill water. (NOTE) On turn key rate for nipple up diverter system until 12:00 hrs. (12 hrs. for 7- 12 -08) From 12 noon on operating rate. ACCEPT KUUKPIK RIG 5, THIS DATE 1200 HRS. 07/13/2008 Page 9 of 78 • s D a m Front T b -- D ' u r ftelyttils. . DetItt a e � e , $u . C nt 00:00 12:00 12.00 MIRU MOVE MOB P Laying plyboard on rig floor. Continue working on overboard cuttings line. Hook up mud line from volume pits to shaker pit.Finish drill water to rig water tank. Build mounting bracket for remote bop controls.Hook up mud line from pumps to standpipe. Hooked up gun line to sub section pits. Hooked up adgitators & function tested. Cleared grating & handrails from upper deck. 12:00 00:00 12.00 MIRU MOVE MOB P Weld on cuttings overboard line. Rig up floor to pick up drill pipe. Install gas alarms- strobes & horn. Check out hopper mix pumps - centrifuge feed pump & air pump for degasser. Fix handrails around diverter line. 07/14/2008 Rigging up & unloading 4.5" DP from boat. 00:00 12:00 12.00 MIRU MOVE MOB P Rebuild mud pump shear relief valves. Pressure IBOP to 1200 psi OK. Hooked up remote for Koomey & tested same OK. Welded on cable tray for service loop. Working on plumbing for seawater jet. Work on vacume system. Removed turnbuckles from top drive & adjust bails. Securing service loop. Removed drillers side fingers for adjustment. Get pipe deck ready for 4.5" drill pipe & start unloading boat. 12:00 00:00 12.00 MIRU MOVE MOB P Off load 4.5" drill pipe from boat. Fill pits with drill water.Modify & reinstall front fingers on derrick board. Working on cuttings chute. Weld 2" collars on 30" conductor. Install saver sub on top drive. Rig up to slip & cut drlg. line.. 07/15/2008 Rigging up & finish picking up Drill Pipe 00:00 12:00 12.00 MIRU MOVE MOB P Slip & Cut 420' of drilling line, Get floor ready to rabbit and pick up drill pipe. Pick up drill pipe. Safety standown, weld safety chains on beaver slide. Continue picking up drill pipe. 12:00 00:00 12.00 MIRU MOVE MOB P Finish picking up drill pipe. Work on Sperry Sun equiptment. Work on Top Drive, break out, dope and torque IBOP to 27K. Mix drilling mud. Pick up HWDP 07/16/2008 Finish picking up BHA, unload boat with cement silos and set 00:00 01:00 1.00 MIRU MOVE MOB P Finish picking up HWDP 01:00 09:00 8.00 MIRU MOVE MOB P Clean up rig floor and install rig tongs, Pick up BHA. 09:00 13:00 4.00 MIRU MOVE MOB P Work on top drive Wage 10 of 78 • • ®.ate From To ; s ur ; S. I. E. I[j Phases Code Subs . ;a. CammeM . 13:00 17:00 4.00 MIRU MOVE MOB P Finish with top drive, calibrate weight p 9 indicator, RPM and torque on Pason 17:00 21:00 4.00 MIRU MOVE MOB P Finish picking up BHA, plug in and test MWD 21:00 21:30 0.50 MIRU MOVE MOB P Function test diverter and then test Koomey unit 21:30 00:00 2.50 MIRU MOVE MOB P Offload boat, cement silo, work on centrifuge and dump lines. 07/17/2008 RIH with HWDP and tag bottom at 345' MD. POOH and pick up kick off assembly. Offload boat with BJ cement and equiptment. 00:00 02:00 2.00 MIRU MOVE MOB P Offload Boat, work on BJ cement silos 02:00 06:00 4.00 MIRU MOVE OTHR P Make up Motor, Stabilizer, 3- DC's and jars. Rack back in derrick. Continue working on BJ cement silos. 06:00 09:00 3.00 MIRU MOVE OTHR P RIH with HWDP and tag bottom at 345'. POOH with HWDP and rack back in derrick. Make up BHA. Continue working on BJ cement silos. 09:00 10:30 1.50 MIRU MOVE OTHR P Make adjustments on top drive. Continue working on BJ cement silos. 10:30 12:00 1.50 MIRU MOVE RURD P Rig up Gyro data equipment on rig. Continue working on BJ cement silos. 12:00 18:00 6.00 MIRU MOVE RURD P Work on seawater line, change shaker screens and lay down mouse hole to weld collar on bottom. Continue working on BJ cement silos. 18:00 21:00 3.00 345 MIRU MOVE OTHR P RIH with bit, motor and drill collars, pick up jars. RIH and tag bottom at 345' MD. Continue working on BJ cement silos. 21:00 00:00 3.00 345 345 MIRU MOVE RGRP T One of the two, two inch pipe collars that were welded on the conductor just below the starting head leaked. Confirmed with production that it was OK to drain stack into drain system. Drain stack and start to weld pipe collars back on. Continue working on BJ cement silos. 07/18/2008 Work on BJ cement tanks. RIH with HWDP and tag bottom at 345' MD. POOH and make up BHA. RIH to 345 MD and start to circulate, knife valve on bluie line leaked, fix. 00:00 04:00 4.00 345 345 MIRU MOVE RURD P Continue working on BJ cement silos. Finish rewelding two inch collars on conductor. Finish hooking up salt water lines to over board lines. 04:00 10:15 6.25 345 345 MIRU MOVE RURD T Knife blade valve on bluie line leaked excessively when circulation was started, shut down to fix. Page 11 of 78 S • Los Fib Al Dur? S.13e0tlt E fle tF .fsha c CCKt Subcocfe .FT Cr n ent* 10:15 10:45 0.50 345 345 SURFA( DRILL CIRC P Circulate and condition mud, displace well at 343' MD, 163 bbls of mud 10:45 14:30 3.75 345 443 SURFA( DRILL DRLG P SPUD at 10:45 hrs, Rotary drill from 343' MD to 443' MD. 14:30 15:00 0.50 443 443 SURFA( DRILL CIRC P Circulate and condition mud, condition hole for Gyro survey run. 15:00 18:30 3.50 443 443 SURFA( DRILL KOST P Clear cat walk, rig up wire line unit on cat walk and run Gyro 18:30 20:00 1.50 443 530 SURFA( DRILL DDRL P Drill ahead. Rotate from 443' MD to 450' MD, Slide from 450' MD to 465' MD, Rotate from 465' MD to 530' MD. 20:00 22:30 2.50 530 530 SURFA( DRILL CIRC T Overboard line plugged while drilling, clean out. In future more sea water will be pumped down overboard line to prevent line from plugging again. 22:30 23:30 1.00 530 530 SURFA( DRILL CIRC P Circulate bottoms up, clean hole for Gyro run 23:30 00:00 0.50 530 530 SURFA( DRILL SRVY P Run Gyro Survey, survey depth 475' MD, angle .22 degrees, azmuth 21.61 de•rees 07/19/2008 Work on Diverter valve, get ready to drill. Rig up Gyro Data and start Kick off. 00:00 00:45 0.75 530 530 SURFA( DRILL SRVY P Run Gyro suevey at 534' MD. 00:45 01:30 0.75 530 530 SURFA( DRILL CIRC T Had trouble downloading survey from survey tool. Survey at 475' was .22 degrees angle with an azmuth of 21.61 degrees 01:30 01:45 0.25 530 550 SURFA( DRILL DDRL P Drill. Slide from 530' MD to 550' MD 01:45 02:00 0.25 550 593 SURFA( DRILL DDRL P Drill. Rotate from 550' MD to 593' MD 02:00 02:15 0.25 593 593 SURFA( DRILL CIRC P Circulate hole clean before Gyro run. 02:15 03:30 1.25 593 593 SURFA( DRILL SRVY P Gyro Survey at 593' MD, Survey at 534' MD was .10 degrees angle with an angle of 45.06 degrees 03:30 04:15 0.75 593 593 SURFA( DRILL OTHR T Work on top drive. Grabber stuck 04:15 15:30 11.25 593 831 SURFA( DRILL DDRL P Drill ahead drctnl 12 -3/4 hole 593 - 831 ft. Gyro survey at 60 ft intervals. ART = 7 hrs, AST = 2.1 hrs. WOB 3K, RPM 50, SPP 1000, SPM 130, GPM 375. Up 49, Dn 48, Rot 49. Connections free, no fill, no torque, up / do drag normal. Normal quantity / quality cuttings return. 15:30 16:00 0.50 831 831 SURFA( DRILL CIRC T CBU, shaker clean. 16:00 18:30 2.50 831 831 SURFA( DRILL TRIP T POH for BHA / motor adjust. 18:30 19:00 0.50 831 831 SURFA( DRILL OTHR T Service Rig & Top Drive 19:00 22:00 3.00 831 831 SURFA( DRILL TRIP T Make up BHA #2, work on Top drive 22:00 23:30 1.50 831 831 SURFA( DRILL TRIP T RIH to 831', no problems. 23:30 00:00 0.50 831 831 SURFA( DRILL CIRC T Circulate hole clean for Gyro run. Page 12of78 • T "Lo t4ev, ,. :. DaT Fror _ D4(• S. Depth Matzoth Pharr Code Suede T ''' Comment fqt .. 07/20/2008 2 ry 4 hr S uma m Stark kick off at 530' MD and run gyro surveys. Having trouble building angle. POOH and change motor bend to 1.83 degrees. No tight hole problems. 00:00 02:30 2.50 831 831 SURFA( DRILL CIRC T Circulate hole clean for Gyro run 02:30 06:00 3.50 831 831 SURFA( DRILL OTHR T Lay down two joints of drill pipe with bad threads. POOH to shoe. Then change out saver sub. 06:00 07:30 1.50 831 831 SURFA( DRILL TRIP T RIH to 806' MD, No tight hole. 07:30 16:30 9.00 831 964 SURFA( DRILL DDRL P Drill ahead directionaly 12.25" hole, Gyro Survey every 30', ART = .2 hrs, AST = 2 hrs, WOB = 6K, RPM = 0, SPM =110, GPM = 300, DRAG up 56K DN = 56K, PSI = 350 on, 450 off 16:30 17:30 1.00 964 964 SURFA( DRILL CIRC T Circulate bottoms up to clean hole. 17:30 20:30 3.00 964 964 SURFA( DRILL TRIP T POOH from 964' MD, No tight hole. 20:30 00:00 3.50 964 964 SURFA( DRILL TRIP T Work on Top Drive, change saver sub, install spiral guard on service loop, work on grabber. 07/21/2008 Try and kick well off with Gyro surveys. Could not get the build rate needed to clear restricted areas. POOH for BHA change. 00:00 02:15 2.25 964 964 SURFA( DRILL DRLG T Work on top drive. Finish with spiral rap on service hook up. Finish with grabber. 02:15 05:00 2.75 964 964 SURFA( DRILL TRIP T Make up BHA #3, Change to a 2.38 degree motor bend. 05:00 06:00 1.00 964 964 SURFA( DRILL TRIP T Change out tongs and tong heads. 06:00 06:30 0.50 964 964 SURFA( DRILL TRIP T RIH to 964' MD. 06:30 17:00 10.50 964 1,120 SURFA( DRILL DDRL P Drill ahead directionaly 12 1/4" hole. Run Gyro surveys at 913'. 978', 1010' and 1073'. ART = 0 hrs, AST = 1.25 hrs. WOB = 8K, GPM = 280, PSI On = 300, Off = 475, String Weight 56K, Torque = 1. 17:00 21:00 4.00 1,120 1,120 SURFA( DRILL TRIP T POOH to 1120' MD. No tight hole encountered. Rack BHA back in derrick. 21:00 22:30 1.50 1,120 1,120 SURFA( DRILL OTHR P Pick up and run landing ioint in hole, no problems. Landing joint taged up at 48.60'. 22:30 00:00 1.50 1,120 1,120 SURFA( DRILL TRIP T Pick up BHA. Adjust motor bend to 2.12 degrees 07/22/2008 Bha #3 would not build at a desired of rate 5 deg per /100'. POOH and change motor bend to 2.38 degrees. BHA #3 produced 7+ DLS. POOH at 1120' MD and drop motor bend to 2.12 degrees. 00:00 03:30 3.50 1,120 1,120 SURFA( DRILL TRIP T Make up BHA #4, set motor bend at 2.12 degrees and test MWD 03:30 04:45 1.25 1,120 1,120 SURFA( DRILL TRIP T RIH to 458' MD to start MWD mad pass. 04:45 09:00 4.25 1,120 1,120 SURFA( EVALWE DLOG T Mad Pass from 458' MD to 1104' MD Page 13 of 78 • • Time togs , Date From To f. ur t. Depth Eibeoth Phase Code _ . , Subcode Vi i' . Comrrea ` 0 ,T„ 09:00 10:00 1.00 1,120 1,120 SURFA( DRILL REAM T Ream old hole. Ream up from 1103' to 1087, then down from 1087' to 1100', then up from 1076' to 1042' and then down from 1042' to 1104'. 10:00 10:30 0.50 1,120 1,168 SURFA( DRILL DDRL T Drill ahead rotating at this point from 1120' MD to 1146' MD. Observed we were not achieving our directional parameters as planned, calculating that the well was side tracked at this point. Stopped drilling. 10:30 12:00 1.50 1,168 1,168 SURFA( PLUG TRIP T POOH and set back two stands drill pipe 12:00 13:30 1.50 1,168 1,168 SURFA( PLUG CIRC T Circulate and wait on orders from town 13:30 14:00 0.50 1,168 1,168 SURFA( PLUG TRIP T POOH to 1157' MD 14:00 15:30 1.50 1,168 1,168 SURFA( PLUG CIRC T Circulate and take surveys at 1157', 1112', 1047' and 1007'. 15:30 16:00 0.50 1,168 1,168 SURFA( RIGMNT RGRP T Repair top drive compensator. 16:00 17:30 1.50 1,168 1,168 SURFA( PLUG TRIP T RIH from 1007' to 1168' and take Gyro Survey 17:30 19:30 2.00 1,168 1,168 SURFA( PLUG TRIP T POOH, No tight hole encountered. 19:30 22:30 3.00 1,168 1,168 SURFA( PLUG TRIP T Dump MWD data and lay down BHA #4. 22:30 00:00 1.50 1,168 1,168 SURFA( PLUG TRIP T _ Clear floor, start to RIH open ended for pluq job. 07/23/2008 Make up BHA #4, RIH and perform mad pass from 458' MD to 1104' MD. Ream old hole from 1042' MD to 1103' MD. Bad communication between driller and directional driller lead to side tracking hole, from 1120' MD to 1146' MD. POOH and lay down BHA #4. Make ready to RIH and set cement plug from 1168' MD to 745' MD. 00:00 01:00 1.00 1,168 1,168 SURFA( PLUG OTHR T Lay down four joints of drill pipe. 01:00 03:30 2.50 1,168 1,168 SURFA( PLUG TRIP T RIH with open ended drill pipe. Tag bottom at 1168' MD 03:30 08:00 4.50 1,168 1,168 SURFA( PLUG CIRC T Circulate while rigging up cement lines from cement unit. Pump nut plug down the hole to estimate annulus volume. Estimated total barrels of mud to pump slug around to surface was 390 bbls, slug came back with 226 bbls pumped. Did this two times with the same results. 08:00 08:30 0.50 1,168 1,168 SURFA( CEMEN PLUG T Held Pre -Job safetuy meeting for cementing. Pump bottom plug for sidetrack. Set bottom of plug at 1168' MD, 65 BBL slurry of 165 sacks cement at 12 PPG. 08:30 09:30 1.00 1,168 445 SURFA( PLUG TRIP T POOH to shoe at 445' MD 09:30 11:00 1.50 445 445 SURFA( PLUG CIRC T Circulate at 445' MD 11:00 11:30 0.50 445 698 SURFA( PLUG TRIP T RIH to 698' MD 11:30 13:00 1.50 698 698 SURFA( PLUG CIRC T Circulate at 698' MD. No cement to surface on bottoms up. 13:00 14:00 1.00 698 750 SURFA( PLUG TRIP T RIH to 750' MD and circulate bottoms up. No cement to surface. Page', 14 of 78 • • 1m a r,, fe ;484n ;46 ��,Dur :. �� , s. Deoth; E. itelf,hase cue '; subcode..�.� Comment .. 14:00 15:30 1.50 750 775 SURFA( PLUG TRIP T RIH to 775' MD and circulate, no cement to surface. 15:30 16:30 1.00 775 800 SURFA( PLUG TRIP T RIH to 800' MD and circulate, no cement to surface. 16:30 18:00 1.50 800 823 SURFA( PLUG TRIP T RIH to 823' MD and circulate, no cement to surface. 18:00 20:00 2.00 823 889 SURFA( PLUG TRIP T RIH and taa cement at 889' MD. Circulate hole clean. 20:00 21:30 1.50 889 889 SURFA( PLUG OTHR T Held Pre -Job safety meeting for number two plug. Set bottom of #2 plug (446 sx) for sidetrack at 889' MD. 166 BBL slurry of 446 sacks cement at 12 PPG. Expected TOC @ 323' MD.____ 21:30 22:30 1.00 889 300 SURFA( PLUG TRIP T POOH to 300" MD. Drop wiper ball and circulate hole clean. Estimated 10 barrels of cement was pumped to surface. 22:30 23:00 0.50 300 300 SURFA( PLUG TRIP T POOH and rack back drill pipe 23:00 00:00 1.00 300 300 SURFA( PLUG CIRC T RIH with 5 stands of drill pipe and drop wiper ball, circulate bottoms up and POOH 07/24/2008 Set two plugs. Plug #1 - 1189' to 889', Plug one in place at 08:00 hrs. Plug #2 - 889' to 300', Plug 2 in place at 21:00 hrs ,POOH to 300' MD and circulate bottoms up. Estimated 10 barrels of cement came to surface at bottoms up. Pump nerf ball down drill pipe and circulate till hole is clean. POOH 00:00 00:30 0.50 300 0 SURFA( PLUG TRIP T Finish POOH and rack back drill pipe in derrick. 00:30 01:00 0.50 0 250 SURFA( PLUG CIRC T RIH with 4 stands of drill pipe, drop wiper ball and chase with 279 barrels of mud to clean cement out of drill pipe. 01:00 01:30 0.50 250 0 SURFA( PLUG TRIP T POOH and rack back last of drill pipe. 01:30 06:00 4.50 0 0 SURFA( PLUG WOC T Wait on cement 06:00 12:00 6.00 0 0 SURFA( PLUG WOC T Continue WOC. Break bit off of motor, inspect & gauge same. Bit gauge = 1 /1/WT /O /E /I /NO /HP. Load & ship out needed equipment for next BHA. Fly out new MWD probe & install same. Clean sand trap under shakers. 12:00 13:00 1.00 0 0 SURFA( PLUG WOC T Continue WOC, Prep rig floor for MU of BHA #5. Offload boat. Pull tools to rig floor. Obtain MWD probe, & install same in new assembly. 13:00 20:00 7.00 0 0 SURFA( DRILL PULD T Breakout & lay down stabilizer on mud motor. MU kick pad with spacers. Continue MU bit, and remaining BHA #5. MU MWD assembly. 20:00 20:30 0.50 0 0 SURFA( DRILL OTHR T Plug in and upload MWD assembly. Pulse test same with 300 GPM's - 425 PSI. 20:30 21:00 0.50 0 300 SURFA( DRILL OTHR T Service Rig and Top Drive Page 15 of 78 • • f rom To, Dur S." Depth • 1 Phan Code Subcode Comment ....., 0—< 21:00 21:30 0.50 300 408 SURFA( DRILL TRIP T RIH from 300' MD to 408' MD, tag cement. 21:30 22:30 1.00 408 421 SURFA( DRILL REAM T Drill cement from 408' MD to 421' MD. Good solid cement. 22:30 23:00 0.50 421 421 SURFA( DRILL CIRC T Circulate out cement contaminated mud. 23:00 00:00 1.00 421 421 SURFA( DRILL SRVY T Rig up and run GYRO to start Kickoff. 07/25/2008 Make up BHA #5 (sidetrack assembly) and RIH. Tag hard cement inside conductor at 408' MD. Rotary drill from 408' MD to 450' MD (30" conductor shoe) and circulate hole clean. Orient BHA #5 with Gyro survey to an Azimuth of 300 degrees. Slide from 450' MD to 517' MD with 25 Kips WOB, 225 GPM with an ROP of 500+ ft per /hr. Gyro survey at 508' MD, 4.6 degrees angle and 353.06 Azimuth. Maximum dogleg severity + 4.8 degrees. It appears we were kicked off at 450' MD with no problems. Drill ahead as per directional plan. 00:00 00:30 0.50 421 450 SURFA( DRILL REAM T Drill cement inside 30" conductor from 421' MD to 450' MD 00:30 01:30 1.00 450 450 SURFA( DRILL CIRC T Circulate hole clean for Gyro survey run. Orient motor to a 300 azmuth 01:30 01:45 0.25 450 517 SURFA( DRILL DDRL T Slide from 450' MD to 517' MD, GPM = 250, WOB = 25 K, ROP = 500+ 01:45 03:00 1.25 517 517 SURFA( DRILL SRVY T Circulate and run Gyro Survey 03:00 04:15 1.25 517 636 SURFA( DRILL DDRL T Rotary Drill from 517' MD to 547' MD, them slide from 547' MD to 562' MD, then rotate from 562' MD to 577' MD. Continue slide from 577' - 602' MD. Rotate from 602' -636'. 04:15 05:15 1.00 636 636 SURFA( DRILL CIRC T Circulate and run Gyro Survey 05:15 06:00 0.75 636 700 SURFA( DRILL DDRL T Rotate from 636' - 669'. Obtain MWD checkshot. Rotate to 700'. 06:00 06:45 0.75 700 700 SURFA( DRILL SRVY T Circulate and run Gyro Survey 06:45 18:00 11.25 700 1,168 SURFA( DRILL DDRL T Continue directional drill from 700'MD to 1168' MD. Run Gyro surveys every 60 to 90 ft. Drill ahead with 425 GPM, 10 to 25K WOB. No excess torque or hole drag. Total slide time = 3.4 hrs, Total rotate time = .75 hrs. Pump sweeps as needed. 18:00 00:00 6.00 1,168 1,453 SURFA( DRILL DDRL P Continue directional drill from 1168 'MD to 1453' MD. Run Gyro surveys every 60 to 90 ft. Drill ahead with 425 GPM, 10 to 25K WOB. No excess torque or hole drag. Total slide time = 5.4 hrs, Total rotate time = 1 hrs. Pump sweeps as needed. 07/26/2008 Sidetrack well and drill ahead as /per directional plan. Drilling in very soft sand with high ROP rates. To attain doglegs needed we are sliding 90% of the time with as much weight as we can get to the bit. Also having to cut back pumps to 250 GPM to keep the hole angle from washing out. The 2.1 deg motor bend with kick pad is giving us 4 to 5 degree doglegs. Page 18 of 78 • • � .i3gs to Dat Dur. . S ; �. ' 'Ettterith "Phase, Code' W11bcode " T Comi»ent. 00:00 01:00 1.00 1,453 1,488 SURFA( DRILL DDRL P Drill ahead as /per directional plan. 1453' MD to 1488' MD. While sliding, WOB = 10K, GPM = 400 and ROP = 400 + ft/hr. Total drilling 6.5 hrs, Total slide time 5.4 hrs. At 1470 it appears we hit a coal seam. High torque and hole drag. Directional objective met at this point, it was decided to POOH. 01:00 03:00 2.00 1,488 1,488 SURFA( DRILL CIRC P Work out tight spot at 1470' MD, (asuming it is a coal seam). Pump 25 barrel sweep to clean hole. Circulate two complete circulation, POOH when shakers cleaned up. 03:00 08:30 5.50 1,488 1,071 SURFA( DRILL TRIP P POOH back reaming to 450' MD (shoe). Other than the coal seam on bottom there has been no tight hole. 08:30 11:30 3.00 1,071 450 SURFA( DRILL TRIP P POOH from shoe at 450' MD to surface, Then lay down BHA. 11:30 19:00 7.50 450 0 SURFA( RIGMNT RGRP T Work on top drive, change out off driller side link tilt. Trouble shoot link tilt float system. 19:00 21:30 2.50 0 0 SURFA( DRILL TRIP P Pick up BHA #6, set motor bend and pick up stabilizer. 21:30 23:00 1.50 0 0 SURFA( RIGMNT RGRP T Change out relief valves on top drive. 23:00 00:00 1.00 0 0 SURFA( DRILL TRIP P Make up BHA #6 07/27/2008 Met directional objective with BHA #5. Circulate bottoms up at 1488' MD. Backreem out to shoe, no tight hole encountered. Finish POOH and lay down BHA #6. Work on top drive. Make up BHA #6 and RIH. 00:00 04:00 4.00 0 265 SURFA( DRILL TRIP P Finish making up BHA # 5 and RIH. Test MWD 04:00 06:00 2.00 265 1,380 SURFA( DRILL TRIP P RIH to 1380' MD. No tight spots at all, hole in very good condition.. 06:00 07:00 1.00 1,380 1,489 SURFA( DRILL TRIP P Continue work to bottom observing tight spot at 1388' MD. Taking checkshot surveys at 1435', and 1483' MD. Verify the 11.8 deg dogleg at survey station 1483'. 07:00 08:30 1.50 1,489 1,489 SURFA( DRILL CIRC T Work drill string, attempting to wipe the dogleg. Pumps at 480 GPM's - 1350 PSI. 08:30 19:00 10.50 1,489 1,738 SURFA( DRILL DRLG P Drill & slide from 1489' MD to 1737' MD. Adjusted drilling time = 17.5 hrs. Hole Drag Up = 76K, DN = 58K, RT = 63K, Torque off bottom = 5K, On = 7K, Pump PSI On = 1900, Off = 1700 19:00 21:00 2.00 1,738 1,738 SURFA( DRILL REAM P POOH and rack back two singles, then ream back to bottom. Tight hole 1699' MD to 1710' MD. Hole cleaned up realy good. Page 17 of 78 • S ti me Logs 414 # i , Oa tiNbit D.ur :: S. Depth toet tt :f asir'Code - Subc.ade T....`• Comment zz 21:00 00:00 3.00 1,738 2,090 SURFA( DRILL DDRL P Drill & Slide from 1737' MD to 2090' MD. Adjusted drilling time = 19.5 hrs. Hole Drag Up= 76K, Dn = 58K, RT = 63K, Torque off bottom = 5K, On = 7K, Pump PSI On = 1900, Off = 1700. At 1738' MD a 25 barrel sweep at 10.5 lb per /gal weight, 10 lb per /bbl nut plug and 150 vis was pumped down hole. A large increase in cuttings returns were observed. Another sweep was ordered and will be pumped ASAP. 07/28/2008 Make up BHA #6 and RIH to 1380' MD. No problems when tripping in. When on bottom, drill ahead as /per directional plan. Steering BHA #6 was no problem, 15 ft sets were giving 5 degree dog legs. When on bottom 450 GPM was used while rotary drilling ahead, this was raised to 600 GPM by 2200' MD. Sweeps were pumped as needed and seamed to work very well. Sweeps were 25 barrels with 10 PPG mud, 10.5 PPB nut plug with 150 vis. 00:00 07:30 7.50 2,090 2,500 SURFA( DRILL DDRL P Drill ahead as /per directional plan, From 2090' MD to 2500' MD. No problems sliding BHA #6. Pump sweeps as needed, 25 barrels of 10 PPG mud, 10.5 PPB nut plug and 150 vis, sweeps are bringing back extra cuttings Hole drag Up 68K, Dn 62K and Rotating 65K. Torque On Bottom 9K, Off 7. Psi On Bottom 1900 Ibs, Off Bottom 1700 lbs. 07:30 08:30 1.00 2,500 2,500 SURFA( DRILL CIRC P Condition mud and circulate for short trip, pump another sweep. 08:30 10:30 2.00 2,500 2,500 SURFA( DRILL TRIP P Short trip out of hole from 2500' MD to 1500' MD. Pull 10K over from 2337' MD to 2312' MD. The hole took the right amount of fluid. 10:30 13:00 2.50 2,500 2,500 SURFA( DRILL TRIP P Short trip back to bottom, no tight hole. 13:00 17:30 4.50 2,500 2,903 SURFA( DRILL DDRL P Drill ahead as /per directional plan. From 2500' MD to 2903' MD. No problems stearing BHA #6. 17:30 19:00 1.50 2,903 2,903 SURFA( DRILL CIRC T Viscosity coming out of hole jumped up to 125 sec. Circulate and condition mud. 19:00 00:00 5.00 2,903 3,220 SURFA( DRILL DDRL P Drill ahead as /per directional plan. From 2903' MD to 3220' MD. Pump sweeps as needed, 25 barrels of 10 PPG mud, 10.5 PPB nut plug and 150 vis, sweeps are bringing back extra cuttings Hole drag Up 68K, Dn 62K and Rotating 65K. Torque On Bottom 9K, Off 7. Psi On Bottom 1900 Ibs, Off Bottom 1700 lbs. 07/29/2008 Drill from 3201' To TD of 12 1/4" hole @ 4546' MD. 3464 TVD. 00:00 06:00 6.00 3,220 3,800 SURFA( DRILL DDRL P Rotate from 3201' to 3232. Slide to 3249'. Rotate to 3296'. Slide to 3310'. Rotate to 3800'. MD. 06:00 07:00 1.00 3,800 3,800 SURFA( DRILL OTHR T Tighten belt on #2 pump. Circulate hole with #1 pump. Page 18 of 78 Datt4i„ From - T6- 4 '••- . D a _ S..tpth Etteoth Phase Code ° Sub \c c T Comment 07:00 12:00 5.00 3,800 4,217 SURFA( DRILL DDRL P Rotate to 4217' MD. RT wt. 75k UP 110k DN 58k WOB 10k GPM 600 TQ on 12k off 13k. ADT 6.18 ART 5.78. 12:00 18:30 6.50 4,217 4,546 SURFA( DRILL DDRL P Drill rotating from 4217' to 4546' MD. TD of 12 1/4" hole. UP wt 88k DN 78k TQ 15k Hoist wt. 90k Slide 4.68 hrs. ROT 16.26 18:30 21:30 3.00 4,546 4,546 SURFA( DRILL CIRC P Condition mud & circ. @ 4546' MD. Pump 2 hi -vis sweeps @ 580 GPM. 21:30 23:30 2.00 4,546 4,432 SURFA( DRILL TRIP T POH to 4432'. Work on top drive. Circ. & rotate @ 30 rpm 480 gpm. 23:30 00:00 0.50 4,432 4,307 SURFA( DRILL TRIP P BROOH to 4307' MD. 07/30/2008 Finish wiper trip. Condition mud & hole. POH to run 9 5/8" csg. 00:00 05:00 5.00 4,307 2,400 SURFA( DRILL REAM P BROOH to 2400' MD. 580 GPM 60 RPM. 6 -10K drag. 05:00 06:00 1.00 2,400 2,400 SURFA( DRILL PULD T Lay down bad pipe from derrick & clean floor. 06:00 08:00 2.00 2,400 4,546 SURFA( DRILL TRIP P RIH to 4546' MD. No Fill. 08:00 12:00 4.00 4,546 4,546 SURFA( DRILL CIRC P Circ. hole clean for 9 5/8" csg. 2500 bbls. 60 rpm 12k tq 550 gpm 1750 psi. 12:00 12:30 0.50 4,546 4,546 SURFA( DRILL CIRC P Finish circ. & condition hole. 12:30 15:30 3.00 4,546 3,613 SURFA( DRILL TRIP P POH to run 9 5/8" csg. Back reamed to 3613' MD. 15:30 20:00 4.50 3,613 400 SURFA( DRILL TRIP P POH from 3613' to 400' MD on elevators. 20:00 20:30 0.50 400 400 SURFA( DRILL SFTY P PJSM on cutting drilling line. 20:30 22:00 1.50 400 400 SURFA( DRILL OTHR P Cut & slip 100' drilling line. 22:00 00:00 2.00 400 154 SURFA( DRILL TRIP P POH to 154' MD. 07/31/2008 Finish POH. Rig up & run 9 5/8" csg. 00:00 04:00 4.00 154 0 SURFA( DRILL PULD P Download MWD & lay down BHA. 04:00 08:30 4.50 0 0 SURFA( CASING RURD P Clean up rig floor. Lay down DD tongs. & rig up to run 9 5/8" csg. PJSM. 08:30 09:00 0.50 0 0 SURFA( CASING SFTY P Held PJSM with crew, crane operator, riggers, TP's & Weatherford casing crew. Discuss safety & hazard recognition issues. 09:00 18:30 9.50 0 2,717 SURFA( CASING RNCS P Pick up shoe track, fill pipe with 9.2 ppg mud & check floats. Floats OK. Continue pick up and run 9 5/8" casing installing bowspring centralizers on every collar as per detail. Observed make up torque = 8 -9 K ft/lbs. Monitor for proper displacement & capacity while run in hole to 2717' MD. 18:30 19:30 1.00 2,717 2,717 SURFA( CASING CIRC P Circulate & reciprocate while conditioning mud. Up wt 130k do 60k. Page 19 of 78 S TA* Logs 40 14th a ` . Pram TO :,. ,„ Our.:: •4 ' S. DeOlitt. Detot Phase COOe ":. Subcode . T ' Comment \. . 19:30 22:30 3.00 2,717 3,629 SURFA( CASING RNCS P Run 9 5/8" 40# csg. from 2717' to 3629' MD. Up wt 140k do 65k. 22:30 23:30 1.00 3,629 3,629 SURFA( CASING CIRC P Circ. & condition @ 3629'. 23:30 00:00 0.50 3,629 4,535 SURFA( CASING RNCS P Run csg. & make up landing jt. Run total of 110 jts. 9 5/8" 40# L -80 BTC 1MOD csg. to 4535' MD. 08/01/2008 Land casing. Circ. condition & cement csg. 00:00 00:30 0.50 4,535 4,535 SURFA( CASING OTHR P Land hanger in landing ring. 00:30 02:30 2.00 4,535 4,535 SURFA( CASING CIRC P Circ. & condition mud. Reciprocate 15' stroke while circ. 02:30 03:30 1.00 4,535 4,535 SURFA( CASING RURD P Rig down csg. equipment & back out pup on top of landing jt. 03:30 08:00 4.50 4,535 4,457 SURFA( CASING OTHR P Rig up to run in hole with drill pipe & cement stinger. Make up same & RIH & tag stab in float collar @ 4457' MD. 08:00 09:30 1.50 4,457 4,455 SURFA( CASING CIRC P Rig up bail extensions & circ. head & circ. inside 9 5/8" csg. till clean. 09:30 13:30 4.00 4,455 4,457 SURFA( CASING CIRC P Sting into float collar. Set 20k down & circ. 9 5/8" X 12 1/4" annulus (a7 5.5 bpm 295psi. Condition mud. 13:30 15:30 2.00 4,457 4,535 SURFA( CEMEN" DISP P PJSM= Mix & pump 20 bbls. spacer. water & sapp. Pump 3 bbls. water & test lines 3500 psi. OK mix & pump 524 bbls. 12.# cement. Returns to surface 70 bbls cement returns. Displaced with 63 bbls. mud. Cement in place @ 15:25 hrs. 8 -1 -2008. 15:30 17:30 2.00 4,535 4,535 SURFA( CEMEN CIRC P Circ. contaminated mud from inside csg. Pump nerf ball @ 6.5 bpm 275 psi. Pump 400 bbls. 17:30 18:30 1.00 4,535 4,535 SURFA( CEMEN' OTHR P Flush out 20" riser. 18:30 00:00 5.50 4,535 4,535 SURFA( CEMEN" TRIP P POH w/ cement stinger on 4.5" drill pipe. 08/02/2008 Nipple down. Nipple up wellhead. Prep rig, & skid rig.Rig released from A -16 at 1800 HRS. 00:00 02:30 2.50 4,535 4,535 SURFA( CEMEN" RURD P Pick up bails & elevators. Lay down landing jt. Lay down bails & elevators. 02:30 03:00 0.50 4,535 4,535 SURFA( CEMEN' OTHR P Clear & clean rig floor & lay down mouse hole. 03:00 10:30 7.50 4,535 4,535 SURFA( CEMEN OTHR P Nipple down annular preventer & 20" riser. Clean pits. Remove starting head. Clean up wellhead. Observed cement on top of hanger. Run rod through fluted hanger to tag cement 6' from top of conductor pipe. Prep hanger for well head installation. 10:30 15:00 4.50 4,535 4,535 SURFA( CEMEN OTHR P Nipple up flange wellhead, upper & lower valves on annulus. Install starting head on A -15. Install landing ring on A -14 and weld up same. Allow to cool. Page 20 of 78 r .. . i'l Fri ' To \ : Dt N S. •th . ® i:14, ase • • - Su s .• e T' . truer \`.. 15:00 17:00 2.00 SURFA( MOVE OTHR il Prepare rig to skid to A -9. Disconnect hoses, lines, and tem•oera walkwa s. 17:00 18:00 1.00 SURFA( MOVE SFTY 1 PJSM on moving rig. (Rig released from A -16 to A -15 • 18:00 hrs. 8 -2 -2008. 09/28/2008 Move rig. Nipple up & begin testing bope. 00:00 06:00 6.00 0 0 PROD1 MOVE DMOB I Finish install of dry hole tree & test hanger seal 5000 psi 15 mins. OK. BPV installed Hold PJSM on moving rig & move same from A -15 to A -16. (Rig Accepted on A -16 @ 00:01) Spotted over well #A -16 @ 04:00 hrs. 9- 28 -08. Rigging up over well #A -16. (Rotary Table to Lower Lock Down Screws 44.40' Rotary Table to Upper Lock Down Screws 42.50' 06:00 12:00 6.00 0 0 PROD1 MOVE RURD PJSM on nipple up bope. Remove flange from A -16. Install riser & bop,s. Reinstall stairs - landings & walkways. Hook up koomey lines & kill line. Work on ri• electrical. 12:00 20:30 8.50 0 0 PROD1 MOVE OTHR Nipple up BOPE. 20:30 22:30 2.00 0 0 PROD1 MOVE RURD - Install flow lines -upper windwalls on sub & fill sits w/ mud. 22:30 00:00 1.50 0 0 PROD1 DRILL OTHR 1 Ri• us to test BOPE. Fill BOP,s & choke manifold & testing BOPE 250 -3500 •si. 09/29/2008 Test bope. Fix rig. RIH & testing csg. 00:00 03:00 3.00 0 0 PROD1 DRILL OTHR P Test BOPE & Koomey test 250 low 3500 psi high. All valves -choke manifold ibop etc. (Witness test waived by Lou Gramaldi AOGCC) 03:00 08:00 5.00 0 0 PROD1 DRILL OTHR T Repair brakes on drawworks. Brakes won't release. (Test blind rams 250 low 3500 psi high) 08:00 09:30 1.50 0 0 PROD1 DRILL OTHR P Pull test plug - install wear ring -lay down test jt. install mouse hole. 09:30 15:00 5.50 0 841 PROD1 DRILL PULD P Pick up & make up BHA #7. 15:00 15:30 0.50 841 841 PROD1 DRILL OTHR P Service rig. 15:30 20:00 4.50 841 4,463 PROD1 DRILL TRIP P RIH w/ BHA #7 to 4463' MD tag up on stab in float collar @ 4463' MD. 20:00 22:30 2.50 4,463 4,463 PROD1 DRILL CIRC P Old mud clabbered & plugging flowline. Displace well to new mud & circ. around. 22:30 00:00 1.50 4,463 4,463 PROD1 DRILL DHEQ P Attempting to test csg. to 3000 psi. Bleeding off. Check all surface equipment. OK. Assume leaking A, shoe or new mud aired u•. 09/30/2008 Attempt csg. test. POH RIH w/ RTTS & test csg. POH 00:00 00:30 0.50 4,463 4,463 PROD1 DRILL DHEQ T Attempting to get 9 5/8" csg. Test. Leaking off. Page 21 of 78 : Timms I Dad From i o Dur S. pth E;.Depth" Phase" Code Subeo e "T Cohithent 00:30 04:00 3.50 4,463 4,463 PROD1 DRILL CIRC T Circ. new mud mixing defoamer & running thru degasser to get air out of mud. 04:00 05:00 1.00 4,463 4,463 PROD1 DRILL DHEQ T Attempting 9 5/8" csq. test. Bleeds off 1200 psi in 15 mins. Double check for surface leaks. Surface holding good. 05:00 10:30 5.50 4,463 870 PROD1 DRILL TRIP T Mix & pump dry job & POH for RTTS to test csg. Assume leak @ shoe. 10:30 12:30 2.00 870 0 PROD1 DRILL PULD T Flow check, Handle BHA #8, LD motor. 12:30 14:30 2.00 0 0 PROD1 CASING DHEQ T PJSM, Close blind rams, attempt re -test 9 -5/8 csq. No qo. Bleed 510 psi / 30 min. Bleed, re -test, identical results. 14:30 16:30 2.00 0 0 PROD1 DRILL PULD T PJSM, MU RTTS. 16:30 19:30 3.00 0 4,430 PROD1 DRILL TRIP T Flow check, Follow RTTS with 4 -1/2 DP to 4430' MD.... 19:30 21:30 2.00 4,430 4,430 PROD1 DRILL DHEQ P Set RTTS packer (a7 4430' MD. Test rsg 3000 psi 31) mins Chart same. Held OK lost 30 psi. 21:30 00:00 2.50 4,430 1,758 PROD1 DRILL TRIP T 7dpressure-release RTTS packer H. 10/01/2008 POH lay down RTTS RIH run LOT. 00:00 01:30 1.50 1,758 0 PROD1 DRILL TRIP T Finish POH & lay down RTTS in good condition. 01:30 02:00 0.50 0 0 PROD1 DRILL OTHR T Clear & clean rig floor. 02:00 05:00 3.00 0 500 PROD1 DRILL TRIP T PJSM. Make up BHA #9 load nukes & sources, surface test drctnl assy. 05:00 08:00 3.00 500 4,450 PROD1 DRILL TRIP T RIH 4 -1/2 DP w/ BHA #9 to 4450 ft. 08:00 10:00 2.00 4,450 4,450 PROD1 RIGMNT SVRG P Slip / cut drlg line 10:00 12:00 2.00 4,450 4,450 PROD1 RIGMNT SVRG P Service rig, C/O compensator at top drive 12:00 13:00 1.00 4,450 4,450 PROD1 RIGMNT RGRP T Repair wt indicator wiring connection. 13:00 14:00 1.00 4,450 4,546 PROD1 CEMEN "DRLG P Drill shoe track (float / shoe, cmt) Approx 10% cmt in shoe track. Dense cmt below shoe. 14:00 14:30 0.50 4,546 4,566 PROD1 DRILL DRLG P Drill ahead 8 -3/4 new formation for lot. Drill 20' new hole from 4546' to 4566' MD. 3476' ND. 14:30 19:00 4.50 4,566 4,566 PROD1 DRILL CIRC P Circ / cond fluids for LOT. Drop mud wt. from 9.3 heavy to 9.2 ppg. 19:00 20:00 1.00 4,566 4,566 PROD1 DRILL LOT P Rig up & run LOT. 14.8 ppg. pump 3.1 bbls. bleed back .9 bbls. Rig down lines. 20:00 00:00 4.00 4,566 4,566 PROD1 DRILL OTHR T Top drive running hot. Blower motor working. Trouble shooting problem. (Assume we may need new drive motor.) 10/02/2008 Pull motor off top drive & send in. Page 22of7 1 Gate dtr S« t?epth E Phase .:?od�� SuEarade xT ��ment 00:00 12:00 12.00 4,566 4,566 PROD1 DRILL OTHR T Trouble shooting top drive. Working with Tesco by telephone. Possibly drive motor or bearings. Motor heats up with very little rotating. Bearings heat up first. 12:00 18:30 6.50 4,566 4,566 PROD1 DRILL OTHR T Remove top drive guard & pull motor off top drive. Reinstall top drive guard & rehook service cables. 18:30 00:00 5.50 4,566 4,566 PROD1 DRILL TRIP T POH w/ BHA #9 to lay down BHA due to daily costs of BHA while in hole & pssibility of being down a few days. 10/03/2008 Finish POH lay down Sperry tools RIH & circ. 00:00 02:30 2.50 4,566 0 PROD1 DRILL TRIP T Finish POH Remove nukes, down load MWD & lay down motor. 02:30 03:00 0.50 0 0 PROD1 DRILL WOEQ T Clean & clear rig floor after trip. 03:00 07:00 4.00 0 0 PROD1 DRILL WOEQ T Waiting on top drive motor to be repaired or replaced. (cleaning rig) 07:00 09:00 2.00 0 4,480 PROD1 DRILL TRIP T RIH open ended to 4480' MD. 09:00 10:30 1.50 4,480 4,480 PROD1 DRILL WOEQ T Clean floor & rig up & circ. bottoms up. 10:30 00:00 13.50 4,480 4,480 PROD1 DRILL WOEQ T Clean rig & rig maintenance. Work on various projects. Build containment for BJ cement unit fuel tank. Calibrate PLC gauges, hook up boiler & fire same, hook up steam lines to rig heaters & run same. Running 1 boiler. Cleaned up landing outside mud hopper room. Clean up cellar area. 10/04/2008 Work on rig while waiting on motor. 00 :00 00:00 24.00 4,480 4,480 PROD1 DRILL WOEQ T Circ. bottoms up to turn mud. while waiting on top drive motor. Various projects around rig. Clean up around gray iron, work on centifuge,s. Hang upper windwall,s on board. Lay down RLL -pick up new RLL. Up load tool. Clean lower well head room. Install lower wind walls. Monitor well. 10/05/2008 Install top drive motor & test same. 00:00 10:00 10.00 4,480 4,480 PROD1 DRILL WOEQ T Waiting on top drive motor to come out on boat. Will arrive here @ approximatly 08:00 today. Circulate bottoms up to keep mud from clabbering in hole. Working on various jobs around rig. Cleaning etc. 10:00 14:00 4.00 4,480 4,480 PROD1 RIGMNT RGRP T Take delivery top drive motor.PJSM Remove guard off top drive & install top drive motor. page 23 of 78 j 0 g Po Ti me )� s O Frorr To fur .th EdbeitIth Piae Code' - 'Sbbcode T4, Comment \ \. ... .. 14:00 22:00 8.00 4,480 4,480 PROD1 RIGMNT RGRP T Testing top drive motor. Erratic RPM with no load. During slow 50 RPM motor heats up, fast 110 RPM motor runs cool. Continue troubleshoot. Bypass encoder & motor runs fine. Run motor 2 hrs. @ 95 RPM & 340 GPM 1175 PSI. Temperature on motor run 112 deg. Circ. & rotating open ended drill pipe @ 4480' MD. 22:00 00:00 2.00 4,480 4,480 PROD1 RIGMNT RGRP T PJSM on lock out tag out. Drop power to top drive - install guard - safety wire same. Hook up power cables to drive motor. 10/06/2008 Finish top drive. Trip for BHA & Drill. 00:00 03:00 3.00 4,480 4,480 PROD1 RIGMNT RGRP T Finish hooking up power cables to drive motor. Test run top drive. All systems operational. Temps / RPMs stable and normal. 03:00 07:00 4.00 4,480 0 PROD1 DRILL TRIP T Pump dry job & POH for BHA #10. 07:00 07:30 0.50 0 0 PROD1 DRILL OTHR T Clear floor, prep for BHA. 07:30 12:30 5.00 0 845 PROD1 DRILL PULD T PJSM, MU BHA #10, 8 -3/4 dretnl assy. RIH same, surface test. 12:30 14:00 1.50 845 845 PROD1 RIGMNT RGRP T Troubleshoot link tilt system on top drive. 14:00 18:00 4.00 845 4,566 PROD1 DRILL TRIP T Follow BHA with 4 -1/2 DP to 4566' MD. 18:00 18:30 0.50 4,566 4,566 PROD1 DRILL OTHR P Reboot MWD computer & set bit depth. 18:30 00:00 5.50 4,566 4,899 PROD1 DRILL DDRL P Cott. 8 3/4" directional hole from 4566' MD to 4899' MD. 3674' TVD. Up wt. 115k do 67k rot 84k PP 1900 psi tq 10k max gas 330 units. rpm 90 gpm 530 wob 5k ecd 10.2 ppg 10/07/2008 Drill to 5563, POH for BHA 00:00 14:30 14.50 4,899 5,535 PROD1 DRILL DDRL P Drlg. 8 3/4" directional hole from 4899' MD.to 5563' MD 4073' TVD. Bring mud wt. to 9.4 ppg. drlg. coal zones & getting gas increases. Max gas @ 415 units. 14:30 17:30 3.00 5,535 5,535 PROD1 DRILL DDRL T No ROP. Multiple attempts / varied parameters. No results. Motor stalling with light wt. 17:30 19:00 1.50 5,535 4,772 PROD1 DRILL TRIP T Prepare / POH for motor & possible bit change to 4772 ft. 19:00 19:30 0.50 4,772 4,772 PROD1 DRILL SRVY T Check shot survey at 4772 ft. 19:30 22:00 2.50 4,772 4,772 PROD1 DRILL CIRC T Flow check, circ / clean up slight packoff. 20% excess cuttings to shaker. No clays. 22:00 00:00 2.00 4,772 2,365 PROD1 DRILL TRIP T Flow check, PJSM, resume POH to 2365 ft at 00:00 hrs. 10/08/2008 Drill to 6015', Flow chesk every connection. 00:00 02:00 2.00 2,365 843 PROD1 DRILL TRIP T Cont POH to BHA at 843 ft. Page 24 of 78 l f Date Role ,Tti' '' . Dur '; . .'8. Depth E. D .Phase Gode.. Subcode T Co - • .. 02:00 04:00 2.00 843 0 PROD1 DRILL PULD T Flow check at BHA, Remove source, LD drctnl components, break bit / inspect & grade same. No clay, no balling, entire BHA clean. One chipped outer cutter. Bit / all components in gauge. 04:00 07:30 3.50 0 843 PROD1 DRILL PULD T MU bit, 8 -3/4 drctnl assy. RIH same. Surface test. 07:30 08:30 1.00 843 843 PROD1 RIGMNT SVRG P PJSM, Service rig. 08:30 13:00 4.50 843 5,505 PROD1 DRILL TRIP T Flow check, follow BHA with 4 -1/2 DP to 5505 ft. Check shot at 4743 ft. 13:00 13:30 0.50 5,505 5,563 PROD1 DRILL SRVY T Survey, orient drctnl assy. Precaution wash to 5563. 13:30 00:00 10.50 5,563 6,015 PROD1 DRILL DDRL P Drill ahead 8 -3/4 drctnl hole 5563 - 6015 ft. Check flow every connection. No excess connection gas. 10/09/2008 Drill from 6015' MD to 6551' MD, Check flow on connections. At 6551' MD the hole started to lose mud at 40 bbl /hr. Spot 50 bbl pill on bottom (sack black 5 lb/bbl, dyna red fine 5 lb /bbl and nut plug 5 lb /bbl) and POOH to shoe. Had to back ream from 5910' MD to 5540' MD. After LCM pill was spotted on bottom no loss of fluid was encountered. 00:00 17:00 17.00 6,504 6,551 PROD1 DRILL DDRL P Directionally drill ahead from 6015' MD to 6551' MD. Check flow on connections. 17:00 19:00 2.00 6,551 6,551 PROD1 DRILL CIRC T Total losses momentarily. Decrease pump rate to 150 gpm. Cease drlg, PU off btm. Regain circ. Slow ramp to 470 gpm / losses 40 bph. Decrease to 450 gpm / minimal losses / 10 bph. Mix / pump LCM pill. (50 bbl total, 5 ppb Dyna Red fine, 5 ppb nut plug fine, 5 ppb Sack Black). Spot same on btm. Slow pull out of pill. 19:00 23:00 4.00 6,551 4,536 PROD1 DRILL TRIP T POOH from 6551' MD to shoe at 4536 ft. Had to back ream out of hole from 5910' MD to 5540' MD, minor tight hole. No loss fluid encountered. 23:00 00:00 1.00 4,536 4,536 PROD1 DRILL CIRC T Circ 300 gpm, Observe well for losses. No loss. 10/10/2008 Directionally drill ahead from 6015' MD to 6551' MD. Check flow on connections. Directionally drill from 6551ft MD to 6805 ft. Encounter drlg break 15 ft. ROP increase to 200 fph. Attempt precaution backream. drag / complete packoff at 6785 ft. Work free, regain 100% returns. Slowly inch upwards through obstruction. Large amounts coal to shakers. Continue free up wellbore. Shaker clean. Flow check. Drill ahead 8 -3/4 hole, 6805 ft - 7130 ft. No tight hole or gas kicks. 00:00 01:00 1.00 4,536 4,536 PROD1 DRILL TRIP T Pull BHA back into shoe and observe well for loss of fluids. 01:00 03:00 2.00 4,536 6,551 PROD1 DRILL TRIP T RIH from 4536' MD to 6551' MD. No tight spots and no loss of circulation. 03:00 10:30 7.50 6,551 6,805 PROD1 DRILL DDRL P Directionally drill from 6551ft MD to 6805 ft. Encounter drlg break 15 ft. ROP increase to 200 fph. Page 25 of 78 Time Lt s e Date.. ', From N'To '%ur oth E. e th Phase Code Subcode �1 Comment 10:30 11:30 1.00 6,785 6,788 PROD1 DRILL REAM P Attempt precaution backream. drag / complete packoff at 6785 ft. Work free, regain 100% returns. Slowly inch upwards through obstruction. Large amounts coal to shakers. Continue free up wellbore. Shaker clean. 11:30 00:00 12.50 6,805 7,130 PROD1 DRILL DDRL P Flow check, drill ahead 8 -3/4 hole drctnl 6805 - 7130 ft. No tight hole or gas kicks. Maxinum ECD = 10.97. Maxinum gas = 107 units at 6803 ft MD. 10/11/2008 Drill from 7130' MD to 7156' MD. Check for flow on connections. MWD quit working. NO pulse from MWD, try and work free. Pump sweep around to try and clear up MWD, clean suction screens on mud pump. MWD started to work. Drill from 7156' MD to 7250' MD. Check for flow on connections. MWD quit working. MWD lost pulse. Try to get MWD to work again, no success. Circulate hole clean, check for flow and POOH. POOH to 4742' MD. No tight spots and the hole took the right amount of fluid. Observe well for flow and rack back flex drill collars. PJSM, Remove nuke sources from MWD tool and down load MWD data. Lay dowm BHA and observe well. Test all BOPE to AOGCC specifications. Test choke manifold, kill line valves, choke valve, HCR valve, IBOP valves, floor valve, dart valve, upper and lower pipe rams, blind rams and install wear ring. 00:00 01:00 1.00 7,130 7,156 PROD1 DRILL DDRL P Drill from 7130' MD to 7156' MD. Check for flow on connections. MWD quit working 01:00 01:30 0.50 7,156 7,156 PROD1 DRILL CIRC T NO pulse from MWD, try and work free. Pump sweep around to try and clear up MWD, clean screens on mud pump suction. 01:30 06:00 4.50 7,156 7,250 PROD1 DRILL DDRL P Drill from 7156' MD to 7250' MD. Check for flow on connections. MWD quit working. 06:00 06:30 0.50 7,250 7,250 PROD1 DRILL CIRC T MWD lost pulse. Try to get MWD to work again, no success. 06:30 08:00 1.50 7,250 4,742 PROD1 DRILL CIRC T Circulate hole clean, check for flow and POOH 08:00 14:30 6.50 4,742 250 PROD1 DRILL TRIP T POOH to 4742' MD. No tight spots and the hole took the right amount of fluid. 14:30 15:00 0.50 250 0 PROD1 DRILL TRIP T Observe well for flow and rack back flex drill collars. 15:00 16:30 1.50 0 0 PROD1 DRILL TRIP T PJSM, Remove nuke sources from MWD tool and down load MWD data. 16:30 18:00 1.50 0 0 PROD1 DRILL TRIP T Lay dowm BHA and observe well. 18:00 00:00 6.00 0 0 PROD1 WELCTI BOPE P Test all BOPE to AOGCC specifications. Test choke manifold, kill line valves, choke valve, HCR valve, IBOP valves, floor valve, dart valve, upper and lower pipe rams, blind rams and install wear ring. 10/12/2008 Make up BHA #12 and test MWD. RIH with BHA # 12 to shoe. The hole gave back the right amount of fluid. Observe well. Continue RIH to 6732' MD. Mad Pass from 6732' MD to 7250' MD. No tight hole. Drill as /per directional plan from 7250' MD to 7643' MD. Check flow every connection. No tight hole or excess gas. 00:00 06:00 6.00 0 235 PROD1 WELCTL TRIP T Make up BHA #12 and test MWD Page 26 of 7 41110 111 Dat f 4Fron'2 TU ° 41,Our th -.;E. Depth `f h`�"�� ode . ; T . Commmtettt^ ;k,..., o 06:00 11:00 5.00 235 6,732 PROD1 WELCTL TRIP T RIH with BHA # 12 to shoe. The hole gave back the right amount of fluid. Observe well. Continue RIH to 6732' MD. 11:00 12:30 1.50 6,732 7,250 PROD1 WELCTL TRIP T Mad Pass from 6732' MD to 7250' MD. No tight hole. 12:30 00:00 11.50 7,250 7,643 PROD1 WELCTL TRIP P Drill as /per directional plan from 7250' MD to 7643' MD. Check flow every connection. No tight hole or excess gas. 10/13/2008 Directioaly Drill from 7643' MD to 8340' MD. Check flow on connections. No tight hole or loss drilling fluids while drilling. At 8340' MD hole drag was UP = 175K, DN = 100K and rotating = 127K. Off bottom rotary torque is 17K and on bottom torque was 18K. Crews checked crown -o- matic, Kick drill 57 sec. Maxiun gas 484 units. 00:00 00:00 24.00 7,643 8,340 PROD1 DRILL DDRL P Directioaly Drill from 7643' MD to 8340' MD. Check flow on connections. No tight hole or loss drilling fluids while drilling. At 8340' MD hole drag was UP = 175K, DN = 100K and rotating = 127K. Off bottom rotary torque is 17K and on bottom torque was 18K. Crews checked crown -o- matic, Kick drill 57 sec. Maxiun gas 484 units. 10/14/2008 Directioaly Drill from 8340' MD to 8592' MD. Check flow on connections. No tight hole or loss drilling fluids while drilling. At 8488' MD hole drag was UP = 175K, DN = 100K and rotating = 127K. Off bottom rotary torque is 17K and on bottom torque was 18K. Crews checked crown -o- matic, Kick drill 58 sec. Maxiun gas 484 units. 00:00 06:00 6.00 8,340 8,503 PROD1 DRILL DDRL P Directioaly Drill from 8340' MD to 8503' MD. Check flow on connections. No tight hole or loss drilling fluids while drilling. At 8503' MD hole drag was UP = 175K, DN = 100K and rotating = 127K. Off bottom rotary torque is 17K and on bottom torque was 18K. Crews checked crown -o- matic, Kick drill 58 sec. Maxiun gas 484 units. 06:00 07:00 1.00 8,503 8,503 PROD1 RIGMNT RGRP T Circ / re -cip pipe while repair rig hyd system 07:00 11:30 4.50 8,503 8,592 PROD1 DRILL DDRL P Resume drill ahead 8 -3/4 hole dretnl 8503 - 8592 ft 11:30 12:30 1.00 8,592 8,592 PROD1 DRILL CIRC T Rig hyd system continues dropping pressure, will not operate drawworks / top drive. Decision made to POH to 9 -5/8 shoe for repairs. CBU, shakers clean. No gain / losses. 12:30 17:30 5.00 8,592 7,200 PROD1 DRILL TRIP T PJSM, flow check, POH for repairs. Backream various intervals btm to 7200 ft. 17:30 20:00 2.50 7,200 5,390 PROD1 DRILL TRIP T Continue POOH without pumps 7200' MD to 5390' MD. 20:00 21:30 1.50 5,390 5,390 PROD1 RIGMNT RGRP T Repair rig, run mud pumps and perform test to assure problems are taken care of. Page 27of78' Time Dat• .... ' From TiV Dur r S. DeptitilE. ,Det Phase Cadiv T Gorittiant \ 21:30 00:00 2.50 5,390 8,457 PROD1 DRILL TRIP T RIH to 8457'. No tight spots, the hole took the right amount of fluid. 10/15/2008 Circ / re -cip pipe while repair rig hyd system. Resume drill ahead 8 -3/4 hole drctnl 8503 - 8592 ft. Rig hyd system continues dropping pressure, will not operate drawworks / top drive. Decision made to POH to 9 -5/8 shoe for repairs. CBU, shakers clean. No gain / losses. PJSM, flow check, POH for repairs. Backream various intervals btm to 7200 ft. Continue POOH without pumps 7200' MD to 5390' MD. Repair rig, run mud pumps and perform test to assure problems are taken care of. RIH to 8457'. No tight spots, the hole took the right amount of fluid. Wash and ream from 8457' MD to 8593' MD. No tight spots and no loss of drilling fluid. Drill from 8593' MD to 9270' MD. No excess gas detected and no loss circulation. 00:00 00:30 0.50 8,457 8,593 PROD1 DRILL TRIP T Wash and ream from 8457' MD to 8593' MD. No tight spots and no loss of drilling fluid. 00:30 12:00 11.50 8,593 8,950 PROD1 DRILL DDRL P Drill from 8593' MD to 8950' MD. No excess gas detected and no loss circulation. Check flow on connections. No tight hole. Slow pump rate, Pump #1 30 SPM = 215 PSI, 40 SPM = 240 PSI. Pump #2, 30 SPM = 250 PSI, 40 SPM = 310 PSI 12:00 00:00 12.00 8,950 9,270 PROD1 DRILL DDRL P Drill from 8950' MD to 9270' MD. No excess gas detected and no loss circulated Check flow on connections. No tight hole . Slow Pump rate, Pump #1 30 SPM = 286 PSI, 40 SPM = 340 PSI. Pump #2, 30 SPM = 283 PSI, 40 SPM = 398 PSI 10/16/2008 Drill from 9270' MD to 9314' MD. At 01:30 hrs geology called TD at 9314'. No tight hole on connections and no loss of circulation while drilling. Circulate while making ready to short trip. Slow Pump Rate at 9314' MD. Pump #1, 30 SPM = 281 PSI, 40 SPM = 327 PSI. Pump #2, 30 SPM = 343 PSI, 40 SPM = 410 PSI. Observe well before POOH. POOH back reaming from 9314' MD to 8290' MD. Backream with 100 PRM and 500 GPM. No tight hole, the hole took the right amount of fluid. POOH (no back reaming) from 8290' MD to 7248' MD. No tight spots, hole took the right amount of fluid. Break circulation and pump up check shot survey. Shut down pumps and check for flow before tripping in hole. RIH from 7248' MD to 9304' MD. No tight hole, the hole gave back the right amount of fluid. Wash and ream to bottom from 9304' MD to 9314' MD, then circulate to clean hole at 500 GPM and rotating at 60 RPM. POOH two stands to 9215' MD, over pull 245K, backream while POOH to 8706' MD then POOH to shoe. Slip and cut drilling line. POOH from 4480' MD to 3150' MD. No tight hole and the well took the right amount of fluid. 00:00 02:30 2.50 9,270 9,314 PROD1 DRILL DDRL P Drill from 9270' MD to 9314' MD. At . 01:30 hrs geology called TD at 9314'. No tight hole on connections and no loss of circulation while drilling. 02:30 03:00 0.50 9,314 9,314 PROD1 DRILL CIRC P Circulate while making ready to short trip. Slow Pump Rate at 9314' MD. Pump #1, 30 SPM = 281 PSI, 40 SPM = 327 PSI. Pump #2, 30 SPM = 343 PSI, 40 SPM = 410 PSI. Observe well before POOH. 03:00 06:00 3.00 9,314 8,600 PROD1 DRILL TRIP P POOH back reaming from 9314' MD to 8290' MD. Backream with 100 PRM and 500 GPM. No tight hole, the hole took the right amount of fluid. Page; 28 of 78 z ` ' �t�.. ��.. frerr tn...... Dur S.;. • E.Deth ... dtite :.. Suboode.. ". ', t;ommen# ...:<..... 06:00 07:30 1.50 8,600 7,248 PROD1 DRILL TRIP P POOH (no back reaming) from 8290' MD to 7248' MD. No tight spots, hole took the right amount of fluid. 07:30 08:00 0.50 7,248 7,248 PROD1 DRILL CIRC P Break circulation and pump up check shot survey. Shut down pumps and check for flow before tripping in hole. 08:00 10:30 2.50 7,248 9,304 PROD1 DRILL TRIP P RIH from 7248' MD to 9304' MD. No tight hole, the hole gave back the right amount of fluid. 10:30 13:30 3.00 9,304 9,314 PROD1 DRILL CIRC P Wash and ream to bottom from 9304' MD to 9314' MD, then circulate to clean hole at 500 GPM and rotating at 60 RPM. 13:30 20:30 7.00 9,314 4,480 PROD1 DRILL TRIP P POOH two stands to 9215' MD, over pull 245K, backream while POOH to 8706' MD then POOH to shoe 20:30 22:30 2.00 4,480 4,480 PROD1 RIGMNT SVRG P Slip and cut drilling line 22:30 00:00 1.50 4,530 3,150 PROD1 DRILL TRIP P POOH from 4480' MD to 3150' MD. No tight hole and the well took the right amount of fluid. 10/17/2008 POOH (no back reaming) from 8290' MD to 7248' MD. No tight spots, hole took the right amount of fluid. Break circulation and pump up check shot survey. Shut down pumps and check for flow before tripping in hole. RIH from 7248' MD to 9304' MD. No tight hole, the hole gave back the right amount of fluid. Wash and ream to bottom from 9304' MD to 9314' MD, then circulate to clean hole at 500 GPM and rotating at 60 RPM. POOH two stands to 9215' MD, over pull 245K, backream while POOH to 8706' MD then POOH to shoe. Slip and cut drilling line. POOH from 4480' MD to 0' MD. No tight hole and the well took the right amount of fluid. Down load MWD data and remove nuke sources. 00:00 04:00 4.00 3,150 0 PROD1 DRILL TRIP P Continue to POOH from 3150' MD. Hole took the right amount of fluid. 04:00 07:00 3.00 0 0 PROD1 DRILL TRIP P Down load MWD data and remove Nuke sources from MWD. Lay down MWD and rack back the rest of the BHA. 07:00 08:00 1.00 0 0 PROD1 RIGMNT SVRG P Service top drive and rig 08:00 13:00 5.00 0 0 PROD1 EVALFN OTHR T Riq up and run Schlunberger wire line _tools. Run #1 DSI Sonic and FMI Imager. Hit bridge at 4630' MD 13:00 15:30 2.50 0 0 PROD1 EVALFN OTHR T POOH with loggong tools, lay down bull nose and make up new tools. 15:30 18:00 2.50 0 0 PROD1 EVALFN OTHR T RIH with new tools and hit bridge at, 4630' MD. POOH and lay down all Schlumberger wireline equipment. 18:00 19:30 1.50 0 0 PROD1 DRILL TRIP T Make up new clean out BHA. 19:30 00:00 4.50 0 0 PROD1 DRILL TRIP T RIH to 2080' MD. Perform kick drill while trip in hole, 30 seconds. 10/18/2008 Down load MWD data and remove Nuke sources from MWD. Lay down MWD and rack back the rest of the BHA. Service top drive and rig. Rig up and run Schlunberger wire line tools, Run #1 DSI Sonic and FMI Imager. Hit bridge at 4630' MD. POOH with loggong tools, lay down bull nose and make up new tools. RIH with new tools and hit bridge at 4630' MD. POOH and lay down all Schlumberger wireline equipment. Make up new clean out BHA. RIH to 2080' MD. Perform kick drill while trip in hole, 30 seconds. RIH from 2080' MD to 4525' MD. Fill pipe at shoe and break circulation. Tag bridge at 4650' MD, kelly up and break circulation. Ream hole cleam from 4600' MD to 4700' MD. Some coal was pumped to surface while reaming out bridge at 4650' MD. No problem with bridge after it was reamed out. Page, 29 of 78 • Timeless u *A s a \. �\ Date 'our TO ..�`:' b4ptfl E. �: ESflasB Code .., `,' SUtinOffE: 4' 'Cosnrr 9 '-�\, v� ��' 00:00 02:30 2.50 0 4,525 PROD1 DRILL TRIP T RIH from 2080' MD to 4525' MD. Fill pipe at shoe and break circulation. 02:30 03:00 0.50 4,525 4,650 PROD1 DRILL REAM T Tag bridge at 4650' MD, kelly up and break circulation. 03:00 04:00 1.00 4,650 4,700 PROD1 DRILL CIRC T Ream hole cleam from 4600' MD to 4700' MD. Some coal was pumped _ to surface while reaming out bridge at 4650' MD. No problem with bridge after it was reamed out. 04:00 07:30 3.50 4,700 8,970 PROD1 DRILL TRIP T RIH to from 4700' MD to 8970' MD, No tight hole and the hole gave back the right amount of fluid. 07:30 10:00 2.50 7,000 9,314 PROD1 DRILL REAM T Wash and ream from 8970' MD to 9314' MD. Observed drill string "sticking" at 9150', continuing to work and clean up. 10:00 15:30 5.50 9,314 9,314 PROD1 DRILL CIRC T Reciprocate & rotate drill string conditioning mud @ 500 GPM with 80 RPM. Balance mud weight to 9.4 ppg. Observed 30 BBL losses, and up 660 units of gas on bottoms up. Pump safe carb, LCM material & nut plug sweep, observing hole unload when sweep returned. Fluid losses stabled out. 15:30 16:00 0.50 9,314 9,314 PROD1 DRILL OTHR T Monitor well - Static. 16:00 00:00 8.00 9,314 2,550 PROD1 DRILL TRIP T POOH slow off bottom observing drag of 40 -55K over upweight initially and no swabbing issues. Continue POOH with proper displacement observed 9314' MD to 2550' MD. 10/19/2008 RIH to from 4700' MD to 8970' MD, No tight hole and the hole gave back the right amount of fluid. Wash and ream from 8970' MD to 9314' MD. Condition mud and circulate, 500 GPM with 80 RPM. Monitor well before trip to surface. POOH to run logs, 9314' MD to 0' MD. Rig up and run Schlumberger E -Line logs. 00:00 04:00 4.00 2,550 0 PROD1 DRILL TRIP T POOH with BHA # 13. Check flow at shoe and surface 04:00 06:00 2.00 0 0 PROD1 EVALWE ELOG P Rig up and run Schlumberger E -Line logs. 06:00 10:30 4.50 0 0 PROD1 EVALWE ELOG P Continue to RIH with wire line, tag_ bridge at 4620' MD. Try to work past tight spot with no success. POOH with wire line tools and lay down same. 10:30 12:00 1.50 0 0 PROD1 EVALWE PULD P Pick up logging tools and make up to drill pipe. 12:00 18:30 6.50 0 0 PROD1 EVALWE ELOG P Held safety meeting. RIH with E -Line logs on drill pipe. RIH at 90 seconds a stand. 18:30 00:00 5.50 0 4,688 PROD1 EVALWE RURD P Rig up wire line shive in derrick, RIH with socket latch and sting into logging tools. Continue RIH with drill pipe. Tag bridge at 4619' MD, work through easily, proceed with logging to 4688' MD. Page 30 of 78 • • ,,Date Fit.. k D ` .. Depth d epth PheS ct€ie:. SubcodekaT *4amment 10/20/2008 24 hr Summary Continue to RIH with wire line logs, tag bridge at 4620' MD. Try to work past tight spot with no success. POOH with wire line tools and lay down same. Pick up logging tools and make up to drill pipe. Held safety meeting. RIH with E -Line logs on drill pipe. RIH at 90 seconds a stand. Rig up wire line shive in derrick, RIH with socket latch and sting into logging tools. Continue RIH with drill pipe. Tag bridge at 4619' MD, work through easily, proceed with logging to 4688' MD. Held PJSM, Continue to RIH with Schlumberger wire line MBT logs. Logging depths 4894', 4948', 4981', 5032',5096', 5255', 5304', 5326' and 5394'. 00:00 10:30 10.50 4,688 6,477 PROD1 EVALWE DLOG P Held PJSM, Continue to RIH with Schlumberger wire line MDT logs. Logging depths 4894', 4948', 4981', 5032',5096', 5255', 5304', 5326', 5394', 5447', 5630', 6108', 6160', 6262', 6325', 6374', 6387', 6438', and 6477'. 10:30 14:00 3.50 6,477 4,500 PROD1 EVALWE TRIP P POOH to shoe and unlatch from logging tool. No tight hole, hole took the right amount of fluid. 14:00 15:00 1.00 4,500 4,500 PROD1 EVALWE TRIP P Pull wireline out of hole and lay down side entry sub. 15:00 19:30 4.50 4,500 6,627 PROD1 EVALWE TRIP P RIH with logging tool on drill pipe to 6627' MD. 19:30 22:30 3.00 6,627 6,627 PROD1 EVALWE TRIP P Install side entry sub / RIH with wire line and latch up at 6586' MD 22:30 00:00 1.50 6,627 6,906 PROD1 EVALWE ELOG P Continue to RIH with MDT logs, logging depths 6705', 6848' and 6906'. 10/21/2008 Finish MDT log run. POOH with drill pipe to side entry sub. RD wireline. Finish POOH with drill pipe. 00:00 11:00 11.00 6,906 8,754 PROD1 EVALWE DLOG P Continue RIH with Schlumberger MDT logs, Log at 6957', 7088', 7163', 7330', 7405', 7544', 7721', 7839', 7879', 7998', 8329', 8330', 8452', 8601', 8754' MD. Up wt = 198k, do wt = 96k at 8754' MD 11:00 14:00 3.00 8,754 6,661 PROD1 EVALWE DLOG P POOH from 8754' to 6661' MD (side entry sub). 14:00 16:30 2.50 6,661 6,661 PROD1 EVALWE DLOG P Unlatch tool and RD wireline tools and sheave in derrick. 16:30 18:30 2.00 6,661 4,498 PROD1 EVALWE DLOG P POOH to shoe. Move drill collars to ODS (off drillers side). 18:30 23:00 4.50 4,498 86 PROD1 EVALWE DLOG P POOH from 4498' MD to logging tools (86' MD). 23:00 00:00 1.00 86 0 PROD1 EVALWE DLOG P Lay down Schlumberger logging tools. 10/22/2008 TIH to 9314' MD. Circulate hole clean. Add 2.5% lub to mud system. Check for flow. Begin POOH. 00:00 00:30 0.50 0 0 PROD1 EVALWE DLOG P Hold PJSM. Monitor well. Continue to RD wireline. 00:30 01:00 0.50 0 0 PROD1 EVALWE OTHR P Clear and clean rig floor. 01:00 06:00 5.00 0 4,990 COMPZ DRILL TRIP P MU BHA. TIH to 4490' MD. Fill pipe every 1000'. 06:00 08:00 2.00 4,990 4,990 COMPZ RIGMNI OTHR P Monitor well. Hold PJSM. Slip and cut 62.5' of drill line. 08:00 09:30 1.50 4,990 5,430 COMPZ DRILL TRIP P TIH from 4490' to 5430' MD. 09:30 11:00 1.50 5,430 5,430 COMPZ DRILL CIRC P Circulate one hole volume. Page', 31 of 78 • • 'Date \ From ,door ...... b S. D 6 E. lath , Ptthawse 'COde Code "r' AGeWreent 11:00 14:30 3.50 5,430 9,255 COMPZ DRILL TRIP P TIH from 5430' to 9255' MD. Fill hole every 15 stands 14:30 15:00 0.50 9,255 9,314 COMPZ DRILL REAM P Wash and ream from 9255' to 9314' MD. 15:00 23:00 8.00 9,314 9,314 COMPZ DRILL CIRC P Circulate and balance mud in and out to 9.4 ppg. Add 2.5% Drill Zone (lubricant) into system. Pump high visc sweep. Saw very little cutting increase with BU from sweep. 23:00 00:00 1.00 9,314 8,693 COMPZ DRILL TRIP P Monitor well for flow. Well static. POOH from 9314' to 8693' MD. Rot wt up 150k, rot wt down 130k. Rot trq on bottom 22k. Pump 515 GPM. Rot 90 RPM. 10/23/2008 Finished POOH and LD BHA. Test annular and VBR to 250/3500 psi. Run 7" casing. 00:00 11:00 11.00 8,693 0 COMPZ DRILL TRIP P POOH from 8693' to 9 -5/8" casing shoe. Monitor well. POOH and LD BHA. 11:00 11:30 0.50 0 0 COMPZ DRILL OTHR P Clear and clean rig floor. 11:30 16:30 5.00 0 0 COMPZ CASING OTHR P Pull wear ring and drain stack. Make dummy run with 7" landing joint. 16:30 21:00 4.50 0 0 COMPZ WELCTI BOPE P Make up 7" test joint. Test annular and VBR to 250 psi low / 3500 psi high. 21:00 21:30 0.50 0 0 COMPZ CASING RURD P Hold PJSM on rigging up to run casing. RU to run 7" casing. 21:30 00:00 2.50 0 0 COMPZ CASING RNCS P Hold PJSM on running casing. PU and run float shoe, two joints of 7 ", 26 # /ft, L -80, BTCM casing, and float collar. Run one bow spring centralizer 15' above the float shoe. Run one bow spring centralizer 10' below the float collar. Run two joints of 7 ", 26#/ft, L -80, BTCM casing. Run one bow spring centralizer on the casing coupling. 10/24/2008 Run 7" casing from 163' to 4501' MD. Circulate BU at 9 -5/8" shoe. Run 7" casing from 4501' to 5444' MD. Break circulation. Run 7" casing from 5444' to 7244' MD. Circulate mud and lose partial returns. Mix and pump LCM. _ 00:00 11:30 11.50 163 4,501 COMPZ CASING RNCS P Hold PJSM on running casing for new crew. Running 7 ", 26 # /ft, L -80, BTCM casing to from 163' to 4501' MD. Install one bow spring centralizer on every coupling and one rigid centralizer in middle of each joint from joint 48 to joint 91. Make up torque 7500 ft-Ibs. At shoe - up wt 110k, down wt 37k. Make up Torque = 7500 Ft/Lbs 11:30 12:00 0.50 4,501 4,501 COMPZ CASING CIRC P Circulate BU at the 9 -5/8" shoe. No fluid losses observed. 12:00 15:00 3.00 4,501 5,444 COMPZ CASING RNCS P RIH with 7" casing to 5444' MD. Make up torque = 7500 Ft/Lbs 15:00 15:30 0.50 5,444 5,444 COMPZ CASING CIRC P Break circulation @ 68 strokes /min, 530 psi. Up wt 180k, down wt 60k. Page 32 of 7 • . L y ; 3ate `, T ... Dur $ S. Debi th Phan Code Subcode T'4 . meat ,... 15:30 18:30 3.00 5,444 7,244 COMPZ CASING RNCS P RIH with 7" casing to 7244' MD. Up wt 180k, down wt 60k. Make up torque = 7500 Ft/Lbs 18:30 00:00 5.50 7,244 7,244 COMPZ CASING CIRC T Bring pumps up slowly from 1.5 bbls /min to 3.5 bbls /min. Began losing mud. Slow pumps to 1.5 bbls /min. Losses range from 45 to 60 bbls /hr. Mix and pump LCM (Sack Black, DynaRed, Nut plug). Total losses 230 bbls. Max gas 656 units. 10/25/2008 Finish running 7" casing to 9301' MD. Circulate hole. Hold safety stand down. Cement well. Drill line parted. Suspend operations. 00:00 00:30 0.50 7,244 7,244 COMPZ CASING CIRC T Continue to pump LCM at 1.5 BPM. Entire open hole covered with LCM. 00:30 01:30 1.00 7,244 7,244 COMPZ CASING CIRC T Shut pumps off and monitor well. Well flowing slightly (ballooning). Initially 11% flow, reduced gradually to 2% flow. Gained back 28 bbls. 01:30 06:00 4.50 7,244 9,301 COMPZ CASING RNCS P Running 7 ", 26 # /ft, L -80, BTCM casing from 7244' to 9256' MD. PU landing joint. Run landing joint with casing hanger. Tag up approximately 15' from TD. Wash casing to planned casing depth of 9301' MD. 06:00 10:00 4.00 9,301 9,301 COMPZ CASING CIRC P Circulate well at 1 bbl /min, increase rate to 3 bbls /min. Losses at 45 bbls /hr. Pump 25 bbl LCM pill. Circulate and pump second LCM pill. Increase circulating rate to 4 bbls /min, 636 psi. Observed losses of 2 -4 BBLS /HR, increasing pump rate to 5 BPM. Losses at 12 -15 BBLS / HR. Shut down pumps, monitor well, observed once again well ballooning - flowing back 30 bbls, observing flow slowing to 2 %. 10:00 10:30 0.50 9,301 9,301 COMPZ CEMEN" RURD P Held PJSM with BJ & Rig crew. Discuss safety & hazard recognition issues. Discuss cementing procedure. RU cement head. 10:30 13:30 3.00 9,301 9,301 COMPZ CEMEN" CIRC P Continue to circulate well at 4 - 5 BPM. Monitor well for losses. Observed losses at 4 -8 BBL / HR with full 30% flow at the flow nipple. Page j33 of 7 • • TfrJL Date '' rsrrr T2 ,, Du S. . • Phase b 13:30 16:30 3.00 9,301 9,301 COMPZ CEMEN' DISP P RU and test lines to 4500 psi. Pump 80 bbls Seal Bond spacer mixed at 10 ppg. Drop bottom plug. Mix and pump 385 sacks 222 bbls of Class G cement plus additives mixed at 10.5 ppg. Drop top plug. Displace cement with 349 bbls of water using rig pumps. Observed full returns throughout pumping. Observed good lift pressure when cement on back side with pressure increase to 975 PSI from 550 PSI. Bump plugs on calculated strokes with 349 BBLS pumped. Pressure up 500 psi over circulating pressure. Bleed pressure and test floats. Floats holding. Reciprocate casing 15' to 20' strokes during cement job. Note: At 1545 hrs, drill line parted. Top drive dropped on top cement head. No Injuries. The cement was 13 BBLS from the shoe at the time of line parting, and we were unable to reciprocate casing string when cement turning the corner and pumped in place. CIP at 1600 HRS. 16:30 00:00 7.50 9,301 9,301 COMPZ RIGMNT RGRP T Drilling operations suspended due to parted drill line. Rig floor area, flagged off. AOGCC notified of suspended planned BOP test. 10/26/2008 Continue suspended operations. Cut frayed drilling line. Attach drilling line to drum. Secure drilling line on deadman. 00:00 14:00 14.00 9,301 9,301 COMPZ RIGMNT RGRP T Drilling operations suspended due to parted drill line. Wait on cement. Hold PJSM. Secure rig floor. Inspect drawworks, derrick, blocks, and top drive for damage. Clean drill deck and clean rig. 14:00 15:30 1.50 9,301 9,301 COMPZ RIGMNT RGRP T Hold PJSM on unstringing blocks, unrolling bad cable off drum, and restringing blocks with new line on drum. 15:30 00:00 8.50 9,301 9,301 COMPZ RIGMNT RGRP T Cut off frayed drilling line where line parted. Reved up string -up line from drilling line to drum. Pulled drilling line to drum and cut off 250' more of damaged line. Attach drilling line to drum. Wind up 46 raps on drum. Secure drilling line on deadman. 10/27/2008 LD cement head and landing joint. Continue to inspect top drive. 00:00 02:30 2.50 9,301 9,301 COMPZ RIGMNT RGRP T Hold PJSM. Install load cells on dead line. Reinspect derrick, blocks, top drive, and drawworks. 02:30 03:30 1.00 9,301 9,301 COMPZ CEMEN' PULD P LD cement head and landing joint. Page 34 of 78 • • Time , Log y; , Data _ From To .s Our stbeeth' E' De011:Pt Code Subcoc e T Comment ;, . 03:30 12:00 8.50 9,301 9,301 COMPZ RIGMNT RGRP T Hold PJSM. Lower blocks. Perform detailed inspection of crown sheaves, blocks, top drive, torque tube, and related equipment following manufacture's guidelines for Type A inspection. Realign torque tube and top drive. Clean out saver sub and drilling line spool. Function test top drive hydraulic components. Run top drive and check for internal damage and overheating (Top drive good). 12:00 16:00 4.00 9,301 9,301 COMPZ RIGMNT RGRP T Hold PJSM. Slip oln new drilling line f rom s pool . Spool new line on block dum. 16:00 00:00 8.00 9,301 9,301 COMPZ RIGMN1 RGRP T Inspect top drive using Tesco pr ocedures. Change out grabber dies. 10/28/2008 Run casing hanger packoff and test to 5000 psi. Test BOP's. Run GR/JB. Run USIT log. Run Sonic Scanner log. 00:00 02:00 2.00 9,301 9,301 COMPZ CASING DHEQ P Run casing hanger packoff. Test to 5000 psi. Hold test for 15 minutes. Test good. 02:00 07:30 5.50 9,301 9,301 COMPZ WELCTI BOPE P Hold PJSM to '. BOP' to 2 RU psi low , 3500 BOP psi s high Test RD test equipment. 07:30 11:00 3.50 9,301 9,301 COMPZ EVALWE ELOG P Hold PJSM. RU Schlumberoer wireline. Run Gauge rinq / Junk _ basket. 11:00 20:00 9.00 9,301 9,301 COMPZ EVALWE ELOG P RU USIT log. RIH with log. Log on the way up. Lay down USIT tools. 20:00 22:00 2.00 9,301 9,301 COMPZ EVALWE ELOG P RU Sonic g ools RIH Could Scanner not get loggin past 22 MD 22:00 23:00 1.00 9,301 9,301 COMPZ EVALWE ELOG T Pl. R OOH with one centralizer Sonic with Scanner too another of smaller OD. 23:00 00:00 1.00 9,301 9,301 COMPZ EVALWE ELOG P RIH with Sonic Scanner logging tools 10/29/2008 Finish running Sonic Scanner log. RD Schlumberger. Test casing to 4500 psi. RU to run 4 -1/2" kill string. WO plate to pick up tubing. Run 4 -1/2" kill string. 00:00 07:00 7.00 9,301 9,301 COMPZ EVALWE ELOG P Running Sonic Scanner log. 07:00 09:00 2.00 9,301 9,301 COMPZ EVALWE ELOG P PJSM, RD Schlum wireline. LD all components. Prepare for boat load out. 09:00 10:30 1.50 9,301 9,301 COMPZ CASING DHEQ P PJSM, test 7" csg to 4500 psi / 30 min. Test successful, no re- tests. 10:30 13:00 2.50 9,301 9,301 COMPZ RPCOM OTHR P PJSM RU to run 4 -1/2" kill string. Tubing elevator slips biting on bevel of the tubing collar instead of the tube due to the wrong half -moon plate on top of the dies in the elevators. 13:00 19:30 6.50 9,301 9,301 COMPZ RPCOM WOEQ T Waiting on correct plate for the elevators. 19:30 22:00 2.50 9,301 9,301 COMPZ RPCOM PULD P Install correct plate on elevators. PU and RIH with 4 -1/2" tubing kill string. Page 35 of 78 • Time Logs Date" Fror* To Dur 8. Depth E. Dep hase. S ubcode ,T .Comhent ..,. 22:00 23:00 1.00 9,301 9,301 COMPZ RPCOM WOEL T Weatherford power pack failed. Changed to back up unit. 23:00 00:00 1.00 9,301 9,301 COMPZ RPCOM PULD P Finish RIH with 4 -1/2" tubing kill string. Ran total 40 joints (1224'). Make up torque 3400 ft -Ibs. Make up tubing hanger. 10/30/2008 Land tubing hanger and test to 5000 psi. Install BPV. Inspect top drive. Prep to move to A -14. NU dry hole tree and test to 5000 psi. 00:00 01:30 1.50 9,301 9,301 COMPZ RPCOM HOSO P Land tubing hanger and test to 5000 psi for 15 minutes. Test good. Lay down landing joint. Install BPV. 01:30 14:00 12.50 9,301 9,301 COMPZ RIGMNIOTHR T Clean and perform mag particle inspection on top drive, bails, and elevators. (Prep to ND stack.) 14:00 18:00 4.00 9,301 9,301 COMPZ RIGMNT OTHR T Install bales. Change out all keepers on top drive pins. (Unhook mud lines in cellar. Clean trip tank.) 18:00 22:30 4.50 9,301 9,301 COMPZ RPCOM RURD P Pull rotary table. ND BOP's. (Unhook mud flowlines.) 22:30 00:00 1.50 9,301 9,301 COMPZ RPCOM NUND P Nipple up dry hole tree. Test tree to 5000 psi for 15 minutes. Test good. Release rig at 2400 hrs on 10/30/08. 12/01/2008 Cleaning Pits & rig maintenance 12:00 00:00 12.00 9,314 9,314 COMPZ RPCOM OTHR P Cleaning mud tanks for completion fluids & rig maintenance. Working on top drive. (Accept rig on A -16 @ 12:00 12- 1 12/02/2008 Cleaning rig mud tanks for completion fluids. Working on top drive & rig maintenance. Finish relocating compensator cylinders. Shuffle vacuome system from deck to dry sack room, fire watch as needed in production pits. Install lighted wind sock on crown section. Change top variable pipe rams to 2 7/8" X 5 1/2 ". Lay down beaver slide. Work on platform pits, finish cleaning pits #4 & #7. Vac unit was put in platform pit room and nippled up. Hook up trash pump in platform pit room. 00:00 06:00 6.00 9,314 9,314 COMPZ RPCOM OTHR P Cleaning rig mud tanks for completion fluids. Working on top drive & rig maintenance. 06:00 12:00 6.00 9,314 9,314 COMPZ RPCOM OTHR P Cleaning rig mud tanks for completion fluid. Relocating compensator cylinders. 12:00 18:00 6.00 9,314 9,314 COMPZ RPCOM OTHR P Cleaning rig mud tanks for completion fluid. Finish relocating compensator cylinders. Shuffle vacuome system from deck to dry sack room, fire watch as needed in production pits. Install lighted wind sock on crown section. 18 :00 00:00 6.00 9,314 9,314 COMPZ RPCOM OTHR P Cleaning rig mud tanks for completion fluid. Change top variable pipe rams to 2 7/8" X 5 1/2 ". Lay down beaver slide. Work on platform pits, finish cleaning pits #4 & #7. Vac unit was put in platform pit room and nippled up. Hook up trash pump in platform pit room. Page 36 of 78 Mile Logs T. �o la. From . TO [fur. .w•- epth eDeoth nee Code :.:.',Subco e T CoMinent 12/03/2008 24 hr Summary Cleaning rig mud tanks for completion fluid. Set MI Swaco skid section. Finish changing rams on BOP. Skid and secure BOP's. Install herculite and plywood on rig floor. Load out boat with rig equipment. Offload Swaco equipment from boat and put inside platform mud room, All Swaco equipment spotted in place. Filter press, large and small, booster pump, slurry skid and large tool box. Swaco vac unit is completely hooked up, tested and ready to go. All platform pits should be clean by tomorrow. Two welders working on skid on main pipe deck. Rig down 6" cement line, cuttings line and cut flow lines off to make ready for rig move. 00:00 12:00 12.00 9,314 9,314 COMPZ RPCOM P Cleaning rig mud tanks for completion fluid. Set MI Swaco skid section. Finish changing rams on BOP. Skid and secure BOP's. Install herculite and plywood on rig floor. Load out boat with rig equipment. 12:00 00:00 12.00 9,314 9,314 COMPZ RPCOM P Cleaning rig mud tanks for completion fluid. Offload Swaco equipment from boat and put inside platform mud room, All Swaco equipment spotted in place. Filter press, large and small, booster pump, slurry skid and large tool box. Swaco vac unit is completely hooked up, tested and ready to go. All platform pits should be clean by tomorrow. Two welders working on skid on main pipe deck. Rig down 6" cement line, cuttings line and cut flow lines off to make ready for rig move. 12/04/2008 Prep rig for skid, remove landings and stairways. Skid rig, clean pipe deck, remove sea -water jet line and install cuttings tank. Skid back over well A -16, install walk ways and landings and install luricane clamps to sub structure. Remove rig skid cylinders, put drilling line spool on sub structure, remove skid pads from gray iron, install cuttings tank hoses, gun lines looked up, change out valve on #2 shaker and work on top drive link tilt. Work on top drive with Alaska Hydraulics mechanic, assist in cleaning and welding in platform pit room, modify hand rails and prep pipe deck for MI tanks. Continue work in production pits, clear walk ways and safety exits in platform pump room, continue to weld on MI skid on main pipe deck and assist crane in prepping back loads for boat. Pits 2 & 3 in platform pit room should be clean buy tomorrow evening. 00:00 02:00 2.00 9,314 9,314 COMPZ RPCOM P Prep rig for skid, remove landings and stairways. 02:00 04:00 2.00 9,314 9,314 COMPZ RPCOM P Skid rig, clean pipe deck, remove sea- waterjet line and install cuttings tank. 04:00 06:00 2.00 9,314 9,314 COMPZ RPCOM P Skid back over well A 16, install walk ways and landings and install luricane clamps to sub structure. 06:00 12:00 6.00 9,314 9,314 COMPZ RPCOM P Remove rig skid cylinders, put drilling line spool on sub structure, remove skid pads from gray iron, install cuttings tank hoses, gun lines looked up, change out valve on #2 shaker and work on top drive link tilt. 12:00 18:00 6.00 9,314 9,314 COMPZ RPCOM P Work on top drive with Alaska Hydraulics mechanic, assist inn cleaning and welding in platform pit room, modify hand rails and prep pipe deck for MI tanks. �__ Page 37 of 78 • • TimetogS � � Date From ,1 Di S ,Depsth EAteoth Phase Code Subcode T ,Comment ....,. 18:00 00:00 6.00 9,314 9,314 COMPZ RPCOM P Continue work in production pits, clear walk ways and safety exits in platform pump room, weld on MI skid on main pipe deck and assist crane in prepping back loads for boat. Pits 2 & 3 in platform pit room should be clean buy tomorrow evening. 12/05/2008 Set up scaffold to install flow line. Finish installing plywood on rig floor. Continue welding skid on main pipe deck. Slip and cut 320 feet of drilling line. Service top drive, drawworks and rig tongs. Continue with completion rig up. Inspect mud pits. Assist welders in dry sack room, unload boat, reweld flow line from rig to pits and prep mud lab for move. Install 4" rams in bottom rams of BOP, continue assisting welders in dry sack room and on skid on main pipe deck, finish installing flow line, Stand up and set 400 barrel tank on skid on main pipe deck, get back loads ready for boat. 00:00 03:30 3.50 COMPZ RPCOM P Set up scaffold to install flow line. Finish installing plywood on rig floor. Continue welding on skid on main pipe deck. 03:30 06:00 2.50 COMPZ RPCOM P Slip and cut 320 feet of drilling line. 06:00 07:30 1.50 COMPZ RPCOM P Service top drive, drawworks and rig tongs. 07:30 12:00 4.50 COMPZ RPCOM P Continue with completion rig up. Inspect mud pits, assist welders in dry sack room. 12:00 18:00 6.00 COMPZ RPCOM P Assist welders in dry sack room, unload boat, reweld flow line from rig to pits and prep mud lab for move. 18:00 00:00 6.00 COMPZ RPCOM P Install 4" rams in bottom rams of BOP. continue assisting welders in dry sack room and on skid on main pipe deck, finish installing flow line, Stand up and set 400 barrel tank on skid on main pipe deck, get back loads ready for boat. 12/06/2008 Continue to weld on main pipe deck skid. Assist crain spotting 400 bbl tanks, pump house and MI mud man's house on skid. Relocate caustic tank, unload and back load boat. Adjust clamps on elevator bails. Nipple up riser and then start on BOP nipple up. Help clean platform pits. Continue to weld on main pipe deck skid. Assist in running electrical wire to Swaco tank skid. Rig up hydraulic rams and run hydraulic hose's to tank skid. Work on BOP nipple up, install choke, kill lines and flow line. Work in platform pit room. Platform pits are 75% done. 00:00 06:00 6.00 COMPZ RPCOM P Continue to weld on main pipe deck skid. Assist crain spotting 400 bbl tanks, pump house and MI mud man's house on skid. Relocate caustic tank, unload and back load boat. 06:00 12:00 6.00 COMPZ RPCOM P Adjust clamps on elevator bails. Nipple up riser and then start on BOP nipple up. Help clean platform pits. Continue to weld on main pipe deck skid. 12:00 18:00 6.00 COMPZ RPCOM P Continue to weld on main pipe deck skid. Assist in running electrical wire to Swaco tank skid. Rig up hydraulic rams and run hydraulic hose's to tank skid. Page 38 of 78 • 1 me Lo �� `" s". � - 3 0, 'tea Date ' ti "t..: Qur: IS. DeOitt. Deotl4hase Code .arSadoce 18:00 00:00 6.00 COMPZ RPCOM P Work on BOP nipple up, install choke, kill lines and flow line. Work in platform pit room. Platform pits are 75% done. 12/07/2008 Skid Swaco tanks into place on main pipe deck. Continue to weld on Swaco tank skid. Nipple up BOP's. Continue working in platform pit room. Continue to help clean platform pits, change out bad valves in mud lines. Prep upper mezzanine deck for BJ pump skids. Off load BJ pump from boat and slide into place. Unload monitor shed from boat and put into placed. 00:00 06:00 6.00 COMPZ RPCOM P Skid Swaco tanks into place on main pipe deck. Continue to weld on Swaco tank skid. Nipple up BOP's. Continue working in platform pit room. 06:00 18:00 12.00 COMPZ RPCOM P Continue to help clean platform pits, change out bad valves in mud lines. Continue to work on main deck pipe skid. 18:00 00:00 6.00 COMPZ RPCOM P Prep upper mezzanine deck for BJ pump skids. Off load BJ pump from boat and slide into place. Unload monitor shed from boat and put into placed. 12/08/2008 Continue to weld on Swaco tank skid on main pipe deck. Continue to clean platform pits, 95% complete. Off load boat, set cat walk and V -Door slide. Attempt to offload the second BJ pump skid. Job was aborted when winds started gusting to 30 MPH. Finish welding floor grating on Swaco skid on main pipe deck. Run electric line to transfer pump on Swaco tank skid. Cut and place 3" X 6" boards for cribbing under sand silo. Plum in steam to 400 barrel brine tanks. Continue welding in dry sack room. 00:00 06:00 6.00 COMPZ RPCOM P Continue to weld on Swaco tank skid on main pipe deck. Continue to clean platform pits, 95% complete. Off load boat, set cat walk and V -Door slide. Attempt to offload the second BJ pump skid. Job was aborted when winds started gusting to 30 MPH. 06:00 12:00 6.00 COMPZ RPCOM P Assist in cleaning and rebuilding platform pits. 12:00 18:00 6.00 COMPZ RPCOM P Finish welding floor grating on Swaco skid on main pipe deck. Run electric line to transfer pump on Swaco tank skid. 18:00 00:00 6.00 COMPZ RPCOM P Cut and place 3" X 6" boards for cribbing under sand silo. Plum in steam to 400 barrel brine tanks. Continue welding in dry sack room. 12/09/2008 Wait on boat due to weather. Prep pipe decks for completion equipment. Assist welders working in platform pit room. Move iron rack and rig down stairs from mezzanine deck. Unload boat and spot BJ units. Blender, hydrator, sand silo and other equipment needed. Start to rig up hoses and lines to BJ Frac units and chemical pumps. Unload Swaco equipment and start to rig up. 00:00 14:00 14.00 COMPZ RPCOM P Wait on boat due to weather. Prep pipe decks for completion equipment. Assist welders working in platform pit room. Move iron rack and rig down stairs from mezzanine deck. Page 39 of 78 4( • • From ".: 1riiNR•c. ra.• . .De ; th . c t, Subcode E�.� t ment \ .5 Y ..� : .. r.':j 14:00 21:00 7.00 COMPZ RPCOM P Unload boat and spot BJ units. Blender, hydrator, sand silo and other equipment needed. 21:00 00:00 3.00 COMPZ RPCOM P Start to rig up hoses and lines to BJ Frac units and chemical pumps. Unload Swaco equipment and start to rig up. 12/10/2008 Held pre -tour meeting. Discuss plan forward, safety & hazard recognition issues. Obtain hot work permits. Continue working with welder in platform pit room changing out valves, fabrication & installing Swaco waste pump assembly. Continue with rig maintenance & painting projects. Continue to work with BJ, rigging up Frac units. Prepare pipe deck for unloading of 4" DP. Boat at 1400 HRS. Held PJSM, obtained lift plan. Offload & spot 315 joints of 4" drill pipe and misc tools and equipment, tubing running equipment, remaining equipment for BJ Services and misc piping for the production crew. 00:00 12:00 12.00 0 0 COMPZ RPCOM P Held pre -tour meeting. Discuss plan forward, safety & hazard recognition issues. Obtain hot work permits. Rig up Swaco hose's on tank slid. Continue working with welder in platform pit room changing out valves, fabrication & installing Swaco waste pump assembly. Install lines & hoses in the filtration assembly. Continue with rig maintenance & painting projects. Continue to work with BJ, rigging up Frac units. RU Communication Gaitronics in Monitor Skid. Prepare pipe deck for unloading of 4" DP. Crew Change 12:00 18:00 6.00 0 0 COMPZ RPCOM P Held pre -tour meeting. Discuss plan forward, safety & hazard recognition issues. Obtain hot work permits. Continue working with welder in platform pit room changing out valves, fabrication & installing Swaco waste pump assembly. Continue with rig maintenance & painting projects. Continue to work with BJ, rigging up Frac units. Prepare pipe deck for unloading of 4" DP. Boat at 1400 HRS. Held PJSM, obtained lift plan. Offload & spot 315 joints of 4" drill pipe and misc tools and equipment, tubing running equipment, remaining equipment for BJ Services and misc piping for the production crew. Crew Change Page; 40 of 78 • • ; True ©s, Date , z . >=rom eTo i AZt. V S. Deoili 1 .lthlAase Code ....;• .>. alb:.. T , Comment 18:00 00:00 6.00 0 COMPZ RPCOM P Held pre -tour meeting. Discuss plan forward, safety & hazard recognition issues. Obtain hot work permits. Continue working with welder in platform pit room changing out valves, fabrication & installing Swaco waste pump assembly. Continue with rig maintenance & painting projects. Continue to work with BJ, rigging up Frac units. Unload boat, 315 jts 4" drill pipe, BJ generator, BJ chemical pellets, weatherford tubing tongs and equipment, hopper extension, Frac -Head, three 4" pup joints and assorted production equipment 12/11/2008 Held pre -tour meeting. Discuss plan forward, safety & hazard recognition issues. Obtain hot work permits. Continue working with welder in platform pit room changing out valves, fabrication & installing Swaco waste pump assembly. Continue with rig maintenance & painting projects. Continue to work with BJ, rigging up Frac units. Finish unloading boat. Rig up and pick up 4" drill pipe and rack back in derrick, 157 stands. 00:00 12:00 12.00 COMPZ RPCOM P Held pre -tour meeting. Discuss plan forward, safety & hazard recognition issues. Obtain hot work permits. Continue working with welder in platform pit room changing out valves, fabrication & installing Swaco waste pump assembly. Continue with rig maintenance & painting projects. Continue to work with BJ, rigging up Frac units. Finish unloading boat. Rig up and start to pick up 4" drill pipe and rack back in derrick. 12:00 00:00 12.00 COMPZ RPCOM P Held pre -tour meeting. Discuss plan forward, safety & hazard recognition issues. Obtain hot work permits. Continue working with welder in platform pit room changing out valves, fabrication & installing Swaco waste pump assembly. Continue with rig maintenance & painting projects. Finish picking up 4" drill pipe and racking it all back in derrick. Page; 41 of 78 • s Time Logs 'gate Fr64 . T .. DT r ? . Dept E. Depth ' Ptaase Codec .i de T Co Amid, .... � 12/12/2008 24 hr Summary Rig up and start to test all BOP's. Fill lines and choke manifold with fresh water. Test all choke valves, Top Drive IBOP valves and safety valves. Test BOP equipment to 250 PSI low pressure and 5000 PSI high pressure, recorded on Pason chart. Observed and repair leaks in the lower IBOP, and 2 flanges on the choke line, and on the riser.Continue with rig up of BJ frac equipment installing hard lines and hoses on the pipe deck and main decks, including frac manifold, and lines to A -12 injection well, and A -16 well head room. Continue test BOP's installing 4 1/2" landing joint. Installed Vetco inside test dart. Trouble shoot leaks at the test dart and the landing joint. Pull each, check and re- install. Continue testing. Test Blind rams, Annular, Upper pipe rams VBR's 2 7/8" x 5 ", Choke manifold, upper IBOP, floor valves, Kill & choke line valves. Continue with rig up of BJ frac equipment installing hard lines and hoses on the pipe deck and main decks, including frac manifold, and lines to A -12 injection well, and A -16 well head room.Standpipe valve failed on high pressure test. Change out valve and test. High pressure test (5000 PSI) passed. Boat out at 1900 HRS, off load MI products, XO basket, and BHA equipment. Backhaul BJ pipe baskets and iron racks and misc. equip including iron rack for platform. 00:00 03:00 3.00 COMPZ RPCOM P Held pre -tour meeting. Discuss plan forward, safety & hazard recognition issues. Obtain hot work permits. Continue working with welder in platform pit room changing out valves, and misc welding projects. Continue with rig up of BJ frac equipment installing hard lines and hoses on the pipe deck and main decks, including frac manifold, and lines to A -12 injection well, and A -16 well head room. 03:00 10:00 7.00 COMPZ WELCTL BOPE P Rig up and start to test all BOP's. Fill lines and choke manifold with fresh water. Test all choke valves, Top Drive IBOP valves and safety valves. Test BOP equipment to 250 PSI low pressure and 5000 PSI high pressure, recorded on Pason chart. Observed and repair leaks in the lower IBOP, and 2 flanges on the choke line, and on the riser.Continue with rig up of BJ frac equipment installing hard lines and hoses on the pipe deck and main decks, including frac manifold, and lines to A -12 injection well, and A -16 well head room. 10:00 19:00 9.00 COMPZ WELCTL BOPE P Continue test BOP's installing 4 1/2" landing joint. Installed Vetco inside test dart. Trouble shoot leaks at the test dart and the landing joint. Pull each, check and re- install. Continue testing. Test Blind rams, Annular, Upper pipe rams VBR's 2 7/8" x 5 ", Choke manifold, upper IBOP, floor valves, Kill & choke line valves. Continue with rig up of BJ frac equipment installing hard lines and hoses on the pipe deck and main decks, including frac manifold, and lines to A -12 injection well, and A -16 well head room. Page 42 of 78 • • Time Logra k E, ;;Date ..:`:.. From to Dur .... S. Depth E. Oe °'Phase,.. Code Sttlacode ., :T Comment 19:00 20:00 1.00 COMPZ WELCTL BOPE P Standpipe valve failed on high pressure test. Change out valve and test. High pressure test (5000 PSI) passed. 20:00 00:00 4.00 COMPZ WELCTL P Continue testing BOP's including inside kill line, HCR and manual choke valve and retest both dart valves. Boat out at 1900 HRS, off load MI products, XO basket, and BHA equipment. Backhaul BJ pipe baskets and iron racks and misc. equip including iron rack for platform. 12/13/2008 Pick up test joint, make up XO's and test plug. RIH and set test plug. Install head pin to test BOP. Test bottom 4" pipe rams, upper variable pipe rams and hydrill. For safety reasons, move drill pipe in derrick to make more room on drill floor. Continue working with welder in platform pit room changing out valves, and misc welding projects. Bring Weatherford tubing equipment onto rig floor. Make ready to pull kill string. Break down 4" and 4 1/2" landing joints and lay down same. Change out elevators, then pick up Weatherford tubing tongs to rig floor. Continue with cleaning platform and rig pit systems for caustic pre -flush. Hole Pre -Job safety meeting. Rig up and pull back pressure valve in tubing hanger. Then pick up 4" tubing landing joint and pull tubing hanger to floor. Redress tubing hanger and then lay down same. Wait on Weatherford casing hand, chopper down because of weather. Work on instulation of tamers for derrick and drawworks. Continue welding in platform pit room, and clean the other pits that all welding has been completed in. Hold Pre -Job safety meeting. POOH laying down 4" kill string. Monitor fluid in well while POOH. Rig down Weatherford 4" tubing tongs and hydraulic unit. Pick up test joint, make up XO's and test plug. RIH and set test plug. Install head pin to test BOP. Test bottom 4" pipe rams, upper variable pipe rams and hydrill. Test variable pipe rams to 250 PSI low 'pressure and 5000 PSI high pressure. Attempt to test hydrill, pressure bleeding off. 00:00 01:00 1.00 COMPZ WELCTL P Held pre -tour meeting. Discuss plan forward, safety & hazard recognition issues. Obtain hot work permits. Continue working with welder in platform pit room changing out valves, and misc welding projects. Start detailing rig and platform pit systems for caustic wash. Blow down choke and choke lines. Change out elevators for 4" drill pipe. 01:00 02:30 1.50 COMPZ WELCTL P For safety reasons, move drill pipe in derrick to make more room on drill floor. Continue working in platform and rig pit rooms performing clean up operations. 02:30 04:00 1.50 COMPZ WELCTL P Continue working with welder in platform pit room changing out valves, and misc welding projects. Start detailing rig and platform pit systems for caustic wash. Bring Weatherford tubing equipment onto rig floor. Make ready to pull kill string. 04:00 06:00 2.00 COMPZ WELCTL P Break down 4" and 4 1/2" landing joints and lay down same. Change out elevators, then pick up Weatherford tubing tongs to rig floor. Continue with cleaning platform and rig pit systems for caustic pre - flush. Page 43 of 78 Time LOgS,,„ Lath From To �.... Qu3.0 r . L fa :.Qer Gods , . • ode T.• ', Comment 06:00 09:00 0 COMPZ WELCTL P Hole Pre -Job safety meeting. Rig up and pull back pressure valve in tubing hanger. Then pick up 4" tubing landing joint and pull tubing hanger to floor. Redress tubing hanger and then lay down same. 09:00 14:00 5.00 COMPZ WELCTL T Wait on Weatherford casing hand, chopper down because of weather. Work on instulation of camers for derrick and drawworks. Continue welding in platform pit room, and clean the other pits that all welding has been completed in. 14:00 15:00 1.00 COMPZ WELCTL T Rig up Weatherford hydraulic unit for tongs on rig floor. Unit would not start, dead battery. 15:00 20:00 5.00 COMPZ WELCTL P Hold Pre -Job safety meeting. POOH laying down 4" kill string. Monitor fluid in well while POOH 20:00 20:30 0.50 COMPZ WELCTL P Rig down Weatherford 4" tubing tongs and hydraulic unit. 20:30 22:30 2.00 COMPZ WELCTL P Pick up test joint, make up XO's and test plug. RIH and set test plug. Install head pin to test BOP. Test bottom 4" pipe rams, upper variable pipe rams and hydrill. 22:30 00:00 1.50 COMPZ WELCTL P Test variable pipe rams to 250 PSI low pressure and 5000 PSI high pressure. Attempt to test hydrill, pressure bleeding off. 12/14/2008 Continue with cleaning platform and rig pit systems for caustic pre - flush. Hole Pre -Job safety meeting. Rig up and pull back pressure valve in tubing hanger. Then pick up 4" tubing landing joint and pull tubing hanger to floor. Redress tubing hanger and then lay down same. Wait on Weatherford casing hand, chopper down because of weather. Work on instulation of camers for derrick and drawworks. Continue welding in platform pit room, and clean the other pits that all welding has been completed in. Hold Pre -Job safety meeting. POOH laying down 4" kill string. Monitor fluid in well while POOH. Rig down Weatherford 4" tubing tongs and hydraulic unit. Pick up test joint, make up XO's and test plug. RIH and set test plug. Install head pin to test BOP. Test bottom 4" pipe rams, upper variable pipe rams and hydrill. Test variable pipe rams to 250 PSI low •ressure and 5000 PSI hiqh pressure. Attempt to test hydrill, pressure bleeding off. 00:00 02:00 2.00 COMPZ WELCTL P Test hydrill to 250 PSI low pressure and 3500 PSI high pressure, 4" lower pipe rams and koomey to 250 PSI low pressure and 5000 PSI high pressure. Pressure was leaking slowly through HCR valve. Greased HCR valve and then work valve several times. Pressure test passed after that. 02:00 03:00 1.00 COMPZ WELCTL P Rig down all BOPE testing equipment while flushing platform and rig pits with fresh water. Also start to mix caustic for caustic wash in entire pit system. Page; 44 of 78 • • Time Logs Date4 From - To . Der EAe Phase bode Sitcode ..170 d&ntnent 03:00 10:30 7.50 COMPZ WELCTL P Fill platform and rig pits with fresh water. Circulate fresh water through all pits, mud lines, gun lines, suction lines, discharge lines, mud cleaning equipment and all other areas, while looking for leaks. Found two minor leaks, fixed them. 10:30 16:00 5.50 COMPZ WELCTL P Continue with platform and rig pit cleaning procedure. Following MI /Swaco clean up guide lines. 16:00 18:00 2.00 COMPZ WELCTL P Get rid of and clean out all excess fluid in platform and rig pit from pre -flush. All work done as /per MI /Swaco instructions. 18:00 23:00 5.00 COMPZ WELCTL P Hold Pre -Job safety meeting for caustic wash. Flush platform pits, rig pits, choke, top drive, degasser and all lines with caustic soda wash. 23:00 00:00 1.00 COMPZ WELCTL P Held Pre -Job safety meeting. Flush platform pits, rig pits, choke, top drive, degasser and all lines with Safe Sure with defoamer. 12/15/2008 Fill platform and rig pits with fresh water. Circulate fresh water through all pits, mud lines, gun lines, suction lines, discharge lines, mud cleaning equipment and all other areas, while looking for leaks. Found two minor leaks, fixed them. Continue with platform and rig pit cleaning procedure. Following MI /Swaco clean up guide lines. Get rid of and clean out all excess fluid in platform and rig pit from pre -flush. Hold Pre -Job safety meeting for caustic wash. Flush platform pits, rig pits, choke, top drive, degasser and all lines with caustic soda wash. Held Pre -Job safety meeting. Flush platform pits, rig pits, choke, top drive, degasser and all lines with Safe Sure with defoamer. Pick up Mi /Swaco casing clean out assembly (BHA #16) and RIH. Simultaneous operations. Keep flushing rig pits, platform pits, all mud cleaning equipment and all related mud lines with fresh water. 00:00 05:00 5.00 COMPZ RPCOM CIRC P Held Pre -Job safety meeting. Flush platform pits, rig pits, choke, top drive, degasser and all rig lines with Safe Sure with defoamer. 05:00 15:30 10.50 0 9,100 COMPZ RPCOM TRIP P Pick up Mi /Swaco casing clean out assembly (BHA #16) and RIH. Simultaneous operations. Keep flushing rig pits, platform pits, all mud cleaning equipment and all related mud lines with fresh water. 15:30 20:30 5.00 9,100 9,100 COMPZ RPCOM WOP T Waiting on personnel to arrive from OSK. We need to get the BJ Injection hands, Filtration hands. Weather would not allow any helicopter flights today. No crew change etc... Page 45 of 78 • Time Logs e Dad.. Fronu, 1b Dui* S. Depth Elteot base Code Subcbde. T Comment ..... . 20:30 00:00 3.50 9,100 9,100 COMPZ RPCOM T At 20:30 hrs the supply boat (Champion) was unloading cargo onto the platform. At this time a large chunk of ice pushed the supply boat up against the platform. As the supply boat went under the platform the mast on the champion hit the #2 life boat punching a large hole in it. It was decided shortly after to downsize the platform personal by 21 people. To a point where the two remaining life boats could safely handle all personal left. As soon as weather permits OSK will dispatch helicopters to shuttle personal back to the beach. The communitions network was also knocked out at this time. 12/16/2008 Monitor well. Well shut in. Champion boat Struck lifesphere #2 & damadged same. Platform supervisor evacuating personal down to 49 to accomodate lifesphere capacity. Well work on hold until) further orders. 00:00 00:00 24.00 9,100 9,100 COMPZ RPCOM WOP T At 20:30 hrs 12/15/08 the supply boat (Champion) was unloading cargo onto the platform. At this time a large chunk of ice pushed the supply boat up against the platform. As the supply boat went under the platform the mast on the champion hit the #2 life boat punching a large hole in it. It was decided shortly after to downsize the platform personal by 21 people. To a point where the two remaining life boats could safely handle all personal left. As soon as weather permits OSK will dispatch helicopters to shuttle personal back to the beach. The phone communitions were also knocked out at this time. Stand by waiting for helicopter to come and reduce platform personal numbers by 21. Well work on hold untill further notice. 12/17/2008 Monitor well & stanby for repairs to Lifesphere. 00:00 00:00 24.00 9,100 9,100 COMPZ RPCOM WOEQ T Monitor well, Rig maintenance. Assist crane operator as needed. Well work on hold as directed by Conoco /Phillips due to needing repairs or replacement of damaged Lifesphere. ( Assist in unloading boat) Drill line inpection. Up wt. on drill string 180k Dn 80k. 12/18/2008 Monitor well & standby for repairs to Lifesphere. Page 46 of 78 41 Date r \ .. To Deoth . tberrth Phase Code - Subcode T . =Comr \` A': \ 00:00 00:00 24.00 9,100 9,100 COMPZ RPCOM WOEQ T Monitor well. Rig Maintenance. Assist crane as needed. Well work on hold due to damaged Lifesphere. BJ pumped 581 bbls. wash water & 123 bbls. Flush down Well #A -12 @ 1.9 bpm & 1490 psi.) Total -704 bbls. 12/19/2008 Monitor well. Inject waste water & flush. Filter water & fix leak. 00:00 00:00 24.00 9,100 9,100 COMPZ RPCOM WOEQ T Monitor well. Rig maintenance while waiting on Life sphere to be repaired or replaced. Send BJ hands to town & bring out Swaco Filtration hands. Filterina water to displace inhibited fluid out of well. Fix leak in production tanks. 12/20/2008 Rig Maintenance. Transfered filtered water to rig pits. NTU,s to high. Inject fluid & clean pits. 00:00 00:00 24.00 9,100 9,100 COMPZ RPCOM WOEQ T Monitor well. Rig maintenance. Filtering water to displace inhibited water in well. Transferred water to rig pits. Repaired leaks in production pits. Filtered water to rig pits was 5.5 NTU comming out of filter to rig pits. When NTU,s were checked in rig pits, they were 55 NTU,s. Lots of rust settled in bottom of test cup. BJ come out & injected rig pit water down A -12 Total 500 bbls.. Filtered 400 bbls. & put in upright Tank. Cleaning rig pits & production pits. 12/21/2008 Rig Maintenance. Displace well & wiper trip. 00:00 06:00 6.00 9,100 9,100 COMPZ RPCOM WOEQ T Monitor well. Rig Maintenance. Filter surface volume in production pits. 06:00 08:00 2.00 9,100 9,100 COMPZ RPCOM TRIP P Hold PJSM. Displace well with filtered water. 08:00 16:30 8.50 9,100 9,100 COMPZ RPCOM WOEQ P Wiper Trip from 9100' to 4508' & back to bottom. 16:30 00:00 7.50 9,100 9,100 COMPZ RPCOM T Monitor well. Rig Maintenance. Need BJ to pump acid pickle. Weather foggy & cannot fly chopper. 12/22/2008 Rig maintenance. Inject fluid. Acid Pickle. 00:00 18:00 18.00 9,100 9,100 COMPZ RPCOM WOEQ T Monitor well. Rig maintenance. Prepare lines for Acid pickle. BJ arrived, rigged up & injected 135 bbls. waste water followed with 60 bbl. flush @ 1.5 bpm 1475 psi. down A -12 well. [ Page 47 of 78 .0 Atr ie To Dur ® •th E. °.fsase e T Gom \. -,y, 18:00 00:00 6.00 9,100 9,100 COMPZ RPCOM WOEQ P PJSM on acid pickle.= Test lines to 1000 psi. pump 20 bbls. flo -vis 420 gals. safe -T- pickle 550 gals. 15% HCL followed with 73 bbls. filtered water. Reverse same out plus 1 extra drill pipe volume. Clean filtered water on returns. Rig down displacing manifold. BJ injecting fluid down A -12 while reversing out. Injected 243 bbls. waste water followed with 60 bbls. flush. 12/23/2008 Rig maintenance Caustic wash. Inject fluid. 00:00 15:30 15.50 9,100 9,100 COMPZ RPCOM WOEQ T Monitor well. Rig maintenance. Assist crane as needed. Well work on hold due to damaged Lifesphere. Cleaning rig tanks for caustic wash & prepare to filter water & tranfer to rig pits. Mix caustic wash. 15:30 17:00 1.50 9,100 9,100 COMPZ RPCOM WOEQ P PJSM= Pump70 bbls. caustic wash 75 bbls. safe -surf 25 bbls. flo -vis 120 bbls. filter -floc. Displace well with filtered water while reciprocating 60' & rotating 60 rpm. Rotating wt. up 125k Down 100k. Torque 14.5k 17:00 00:00 7.00 9,100 9,100 COMPZ RPCOM WOEQ T Filtering water. Plugged filter press. Cleaning same. BJ injecting fluid down A -12. 1490 psi 1.5 bpm. Cleaning mud tanks. 12/24/2008 Rig Maintenance. Displace well to 6% KCL. 00:00 20:30 20.50 9,100 9,100 COMPZ RPCOM WOEQ T Monitor well. Rig maintenance. Cleaning mud tanks. After unplugging filter press. Filter water to fill pits. Cleaning shakers. 20:30 00:00 3.50 9,100 9,100 COMPZ RPCOM WOEQ P PJSM = Unload upright tank to production pits with water. Filter to 20 ntu,s. Mix 6% KCL & circ. hole @ 8 bpm 1300 psi. Circ. complete hole with 17 ntu,s coming out. Hole & rig tanks are 6% kcl @ 17 ntu,s. Up wt 180k do 80k. Drill line inspected. 12/25/2008 Rig Maintenance. Build volume & POH. Lay down tools. 00:00 02:30 2.50 9,100 9,100 COMPZ RPCOM WOEQ T Monitor well. Rig Maintenance. Circulate brine in well, build volume in mud tanks. 02:30 12:00 9.50 9,100 9,100 COMPZ RPCOM WOEQ T Monitor well. Rig Maintenance. Organize dry sack room. 12:00 00:00 12.00 9,100 0 COMPZ RPCOM WOEQ P POH & lay down Swaco casing clean up tools. All tools in good condition. 12/26/2008 Rig Maintenance. Rig up & run CIBP on wire line. 00:00 12:00 12.00 0 0 COMPZ RPCOM WOEQ T Monitor Well. Rig Maintenance. Prepare for Schlumberger to run bridge plug. Page 48 of 78 1 M Dad„ ` From 4o „ Dtlr,s ` Depth E.3tth. Phase Code Subcode 12:00 00:00 12.00 0 0 COMPZ RPCOM WOEQ T PJSM =Rig up Schlumberger & run Cast Iron Bridge Plug on wire line. Run #1 Misrun. Plug did not set. (Drilling line inspected.) 12/27/2008 Rig Maintenance. Run CIBP. Cut Drlg. line. 00:00 03:00 3.00 0 0 COMPZ RPCOM WOEQ P Run #2 with Schlumberger 'E' Line with Baker cast iron bridge plug. Set same 8991' WLM poh & rig down Schlumberger. 03:00 10:30 7.50 0 0 COMPZ RPCOM WOEQ T Monitor well. Rig Maintenance. Gather up crossovers & valves for completion. 10:30 13:30 3.00 0 0 COMPZ RPCOM WOEQ T PJSM =Slip & cut 72' drilling line. 13:30 00:00 10.50 0 0 COMPZ RPCOM WOEQ T Monitor well. Rig Maintenance. Assist crane. Rig up heater by BJ tanks. Install seal rings in 40 jts. 4.5" tbg. 12/28/2008 Rig maintenance. Test BOPE 250 -5000 psi. 00:00 16:30 16.50 0 0 COMPZ RPCOM WOEQ T Monitor well. Rig Maintenance. Assist crane. 16:30 00:00 7.50 0 0 COMPZ RPCOM WOEQ P Rig up to test BOPE. Pull wear bushing. Make up test plug & set same. Tested Rams 250 -5000 psi. Tested Annular preventer 250 -3500 psi.. Tested all valves, upper & lower ibop, floor safety valve & dart valve. Perform Koomey unit test. All tests 250 -5000 psi. Rig down 4" test joint. 12/29/2008 Finish BOPE test. Rig Maintenance. 00:00 08:00 8.00 0 0 COMPZ RPCOM WOEQ P Monitor well. Rig Maintenance. Finish testing BOPE. Replace HCR valve. Load & unload boat. 08:00 00:00 16.00 0 0 COMPZ RPCOM WOEQ T Monitor well. Rig Maintenance. Assist crane. 12/30/2008 Monitor well. Rig Maintenance. Assist crane. Check 4.5" FOSV. Needs Repair.Monitor well. Rig Maintenance. Assist crane. Off -Load 4 1/2" tubing from supply boat. Work on pulling off all thread protectors and rabbit tubing. 00:00 06:00 6.00 0 0 COMPZ RPCOM WOEQ T Monitor well. Rig Maintenance. Assist crane. Check 4.5" FOSV. Needs Repair. 06:00 17:00 11.00 0 COMPZ RPCOM WOEQ T Monitor well. Rig Maintenance. Assist crane. 17:00 00:00 7.00 0 COMPZ RPCOM WOEQ T Monitor well. Rig Maintenance. Assist crane. Off -Load 4 1/2" tubing from supply boat. Work on pulling off all thread protectors and rabbit tubing. Page 49 of 7 11t Logs From To Dur S. Depth E, Death Phase -Code Subcocie T Comment 12/31/2008 24 hr Summary Monitor well. Rig Maintenance. Assist crane. After off- loading 4 1/2" tubing from supply boat. Work on pulling off all thread protectors, rabbit and strap tubing. Held Pre -Job safety meeting. Rig up Weatherford tubing tongs and related equipment. Held pre -Job safety meeting. Make up guide shoe on 4 1/2" tubing string and RIH. Use crane to set bundles of tubing on cat walk. Unit crane guit working. It appears to be a frozen fuel line to crane engine. Rig and platform mechanic are both working on this problem. Continue picking up 4 1/2" tubing. Pick up tubing without using crane. 00:00 12:00 12.00 0 COMPZ RPCOM WOEQ T Monitor well. Rig Maintenance. Assist crane. After off- loading 4 1/2" tubing from supply boat. Work on pulling off all thread protectors, rabbit and strap tubing. 12:00 13:00 1.00 0 COMPZ RPCOM WOEQ T Held Pre -Job safety meeting. Rig up Weatherford tubing tongs and related equipment. 13:00 18:00 5.00 0 COMPZ RPCOM WOEQ P Held pre -Job safety meeting. Make up guide shoe on 4 1/2" tubing string and RIH. Use crane to set bundles of tubing on cat walk. 18:00 20:00 2.00 0 COMPZ RPCOM WOEQ T Unit crane guit working. It appears to be a frozen fuel line to crane engine. Rig and platform mechanic are both working on this problem. 20:00 00:00 4.00 0 COMPZ RPCOM WOEQ P Continue picking up 4 1/2" tubing. Pick up tubing without using crane. 01/01/2009 Held pre -Job safety meeting. Make up guide shoe on 4 1/2" tubing string and RIH. Use crane to set bundles of tubing on cat walk. Unit crane guit working. It appears to be a frozen fuel line to crane engine. Rig and platform mechanic are both working on this problem. Continue picking up 4 1/2" tubing. Pick up tubing without using crane. Finish RIH with 4 1/2" tubing to 8401' MD. Rig down casing equipment. Supply boat cannot get to the platform because of heavy ice flow. Still waiting on life boat. Continue to monitor well and perform rig maintenance. 00:00 08:00 8.00 6,650 COMPZ RPCOM WOEQ P Held Pre -Tour safety meeting. Continue picking up 4 1/2" tubing. Pick up tubing without using crane. Unit crane down due to frozen fuel line. Rig and platform mechanics are working on the problem right now. 08:00 00:00 16.00 8,401 COMPZ RPCOM WOEQ T Finish RIH with 4 1/2" tubing to 8401' MD. Rig down casing equipment. Supply boat cannot get to the platform because of heavy ice flow. Still waiting on life boat. Continue to monitor well and perform rig maintenance. 01/02/2009 Supply boat cannot get to the platform because of heavy ice flow. Still waiting on life boat. Continue to monitor well and perform rig maintenance. 00:00 00:00 24.00 8,401 COMPZ RPCOM WOEQ T Supply boat cannot get to the platform because of heavy ice flow. Still waiting on life boat. Continue to monitor well and perform rig maintenance. Page 50 of 78 1 L 3 t-�® < F ,Wie Date .. From To Dur S. a a• • . E. Depth Phase Code. s... ... e T Gordirr ... 01/03/2009 24 h S ummary Supply boat cannot get to the platform because of heavy ice flow. Still waiting on life boat. Continue to monitor well and perform rig maintenance. Supply boat expected to be at platform at 09:00 hrs. Clean hopper room and blow down top drive and mud lines for a precautionary reasions. At 12:00 hrs assist in unloading Brucker life capsule. Monitor well. Perform safety meeting and assist crane operator with off loading Brucker life boat. 00:00 12:00 12.00 8,401 COMPZ RPCOM WOEQ T Supply boat cannot get to the platform because of heavy ice flow. Still waiting on life boat. Continue to monitor well and perform rig maintenance. Supply boat expected to be at platform at 09:00 hrs. Clean hopper room and blow down top drive and mud lines for a precautionary reasions. 12:00 00:00 12.00 8,401 COMPZ RPCOM WOEQ T Monitor well. Perform safety meeting and assist crane operator with off loading Brucker life boat. 01/04/2009 Supply boat expected to be at platform at 09:00 hrs. Clean hopper room, blow down top drive and mud lines for precautionary reasions. Monitor well. Perform safety meeting and assist crane operator with off loading Brucker life boat. Monitor well and rig maintenance. Finish off loading boat, then load boat for back hall. Change out blower motor on #2 boiler. 00:00 00:00 24.00 8,401 COMPZ RPCOM WOEQ T Work on life boat. Monitor well and rig maintenance. Finish off loading boat, then load boat for back hall. Change out blower motor on #2 boiler. Make up FOSV valve in tubing string. 01/05/2009 Work on life boat, Monitor well and perform rig maintenance. Held weekly safety meeting. Mix brine and continue with basic cleaning of rig. Monitor well, assist crane and continue with rig maintenance and cleaning. Mix salt„ check crown saver, fire drill two minutes and inspect drill line. 00:00 12:00 12.00 8,401 COMPZ RPCOM WOEQ T Work on life boat, Monitor well and perform rig maintenance. Held weekly safety meeting. Mix brine and continue with basic cleaning of rig. 12:00 00:00 12.00 8,401 COMPZ RPCOM WOEQ T Monitor well, assist crane and continue with rig maintenance and cleaning. Mix salt„ check crown saver, fire drill two minutes and inspect drill line. 01/06/2009 Held Pre -Tour safety meeting. Monitor well, continue with rig maintenance and cleaning. Gather items from around the rig to be back loaded onto supply boat. Clean pump roon and lower parts room. Work on making places to store super sacks of salt. Held Pre -Tour safety meeting. Monitor well, continue with rig maintenance and cleaning. Transfer injection fluid from production pits to sand trap. Lay down FOSV valve and install floor valve. Continue to arrange platform, so as many bags of salt as possible can be stored on board. 00:00 12:00 12.00 COMPZ RPCOM WOEQ T Held Pre -Tour safety meeting. Monitor well, continue with rig maintenance and cleaning. Gather items from around the rig to be back loaded onto supply boat. Clean pump roon and lower parts room. Work on making places to store super sacks of salt. Page 51 of 78 1 t z Date.. , Fit To Dur . S. Dep E. Depth Pha ' Code Subcode . T mtt rat 12:00 00:00 12.00 COMPZ RPCOM WOEQ T Held Pre -Tour safety meeting. Monitor well, continue with rig maintenance and cleaning. Transfer injection fluid from production pits to sand trap. Lay down FOSV valve and install floor valve. Continue to arrange platform, so as many bags of salt as possible can be stored on board. 01/07/2009 Held Pre -Tour safety meeting. Monitor well. Continue making rig ready for completion project. Continue with weatherising rig and brine transfer lines. Rig up and run Halliburton storm packer. test to 1000 PSI. Pull wear ring and make up 4" test joint. Install wear ring. Lou Grimaldi waved the BOP test witness at 10:30 hrs on 1 -7 -09. Test choke manifold, Bottom pipe rams, variable pipe rams, floor valve, manual IBOP valve, HYD IBOP valve and Dart valve. Test HYDRII to 250 PSI low pressure test and 3500 PSI high pressure test. Test all other BOP equipment to 250 PSI low pressure test and 5000 PSI high pressure test. Perform KOOMEY test. Rig down 4" test joint and then rig up 4 1/2" test joint. Finish testing BOP's, blind rams, manual choke valve, HCR valve and variable pipe rams. Test to 250 PSI low pressure test and 5000 PSI high pressure test. Install wear ring and rig down test joint. Retreive storm packer, SSC valve and lay down. Change out elevators. Monitor well, assist crane operator and perform rig maintenance. 00:00 12:00 12.00 8,401 COMPZ RPCOM WOEQ T Held Pre -Tour safety meeting. Monitor well. Continue making rig ready for completion project. Continue with weatherising rig and brine transfer lines. 12:00 13:00 1.00 8,401 COMPZ RPCOM WOEQ P Rig up and run Halliburton storm packer. test to 1000 PSI 13:00 14:30 1.50 8,401 COMPZ RPCOM WOEQ P Pull wear ring and make up 4" test joint. Install wear ring. 14:30 18:00 3.50 8,401 COMPZ RPCOM WOEQ P Lou Grimaldi waved the BOP test witness at 10:30 hrs on 1 -7 -09. Test choke manifold, Bottom pipe rams, variable pipe rams, floor valve, manual IBOP valve, HYD IBOP valve and Dart valve. Test HYDRII to 250 PSI low pressure test and 3500 PSI high pressure test. Test all other BOP equipment to 250 PSI low pressure test and 5000 PSI high pressure test. Perform KOOMEY test. 18:00 19:00 1.00 8,401 COMPZ RPCOM WOEQ P Rig down 4" test joint and then rig up 4 1/2" test joint. 19:00 21:00 2.00 8,401 COMPZ RPCOM WOEQ P Finish testing BOP's, blind rams, manual choke valve, HCR valve and variable pipe rams. Test to 250 PSI low pressure test and 5000 PSI high pressure test. Install wear ring and rig down test joint. 21:00 22:00 1.00 8,401 COMPZ RPCOM WOEQ P Retreive storm packer, SSC valve and lay down. Change out elevators. 22:00 00:00 2.00 8,401 COMPZ RPCOM WOEQ T Monitor well, assist crane operator and perform rig maintenance. 01/08/2009 Monitor well, assist crane operator and perform rig maintenance. Work on pluming projects, continue painting and remove all ice from stairs and walkways. Make up Halliburton RTTS and SSC valve, RIH and set at 55 feet. Pull wear ring. Retrieve RTTS and SSC valve, lay down. Change elevators, make up landing joint and tubing hanger. Land hanger and test to 5000 PSI. Perform rig maintenance, hook up steam line to upright tanks. Inject 249 bbls of waste fluid down well A -12 Page 52 of 78 Time0 Date From Dur S. Depth E. Depth, Code Subcode T Comm iii t. 00:00 12:00 12.00 8,402 COMPZ RPCOM WOEQ T Monitor well, assist crane operator and perform rig maintenance. Work on pluming projects, continue painting and remove all ice from stairs and walkways. 12:00 13:00 1.00 8,402 COMPZ RPCOM WOEQ T Monitor well, assist crane operator when needed and perform rig maintenance. 13:00 14:30 1.50 8,402 COMPZ RPCOM WOEQ T Make up Halliburton RTTS and SSC valve, RIH and set at 55 feet. 14:30 15:00 0.50 8,402 COMPZ RPCOM WOEQ T Pull wear ring. 15:00 15:30 0.50 8,402 COMPZ RPCOM WOEQ T Retrieve RTTS and SSC valve, lay down. 15:30 18:30 3.00 8,402 COMPZ RPCOM WOEQ T Change elevators, make up landing joint and tubing hanger. Land hanger and test to 5000 PSI. 18:30 00:00 5.50 8,402 COMPZ RPCOM WOEQ T Rig maintenance, hook up steam line to upright tanks. Inject 249 bbls of waste fluid down well A -12. 01/09/2009 Rig warm stacked on 01- 08 -09. Continue with winterizing platform pits and outside steam lines. 00:00 00:00 24.00 8,401 COMPZ RPCOM WOEQ T Rig warm stacked on 01- 08 -09. Continue with winterising platform pits and outside steam lines. 01/10/2009 Monitor well, Rig maintenance. Assist crane operator as needed. Well work on hold as directed by Conoco /Phillips due to excessive ice in Cook Inlet, not allowing resupply of equipment by boat. 00:00 12:00 12.00 8,401 8,401 COMPZ RPCOM WOEQ T Rig warm stacked. Held PJSM discussing safety & hazard recognition issues. Continue with rig maintenance and winterizing. Continue with miscellaneous projects and monitoring equipment, tanks & pits preventing freezing issues. 12:00 00:00 12.00 8,401 8,401 COMPZ RPCOM WOEQ T Rig warm stacked. Held PJSM discussing safety & hazard recognition issues. Continue with rig maintenance and winterizing. Continue with miscellaneous projects and monitoring equipment, tanks & pits preventing freezing issues. 01/11/2009 00:00 12:00 12.00 8,401 8,401 COMPZ RPCOM WOEQ T Rig warm stacked. Held PJSM discussing safety & hazard recognition issues. Continue with rig maintenance and winterizing. Continue with miscellaneous projects and monitoring equipment, tanks & pits preventing freezing issues. 12:00 00:00 12.00 8,401 8,401 COMPZ RPCOM WOEQ T Rig warm stacked. Held PJSM discussing safety & hazard recognition issues. Continue with rig maintenance and winterizing. Continue with miscellaneous projects and monitoring equipment, tanks & pits preventing freezing issues. Page `,53 of 78 1[ ° �� _�,. Thee Le! a a.. From f,-- . Dur S. Depth Er =• m :Phase ode Subcode T Co men# : • , - -', .. 01/12/2009 24 hr S ummary Monitor well, Rig maintenance. Assist crane operator as needed. Well work on hold as directed by Conoco /Phillips due to excessive ice in Cook Inlet, not allowin• resupply of equipment by boat. 00:00 12:00 12.00 8,401 8,401 COMPZ RPCOM WOEQ T Rig warm stacked. Held PJSM discussing safety & hazard recognition issues. Continue with rig maintenance and winterizing. Continue with miscellaneous projects and monitoring equipment, tanks & pits preventing freezing issues. 12:00 00:00 12.00 8,401 8,401 COMPZ RPCOM WOEQ T Rig warm stacked. Held PJSM discussing safety & hazard recognition issues. Continue with rig maintenance and winterizing. Continue with miscellaneous projects and monitoring equipment, tanks & pits preventing freezing issues. 01/13/2009 00:00 12:00 12.00 8,401 8,401 COMPZ RPCOM WOEQ T Rig warm stacked. Held PJSM discussing safety & hazard recognition issues. Continue with rig maintenance and winterizing. Continue with miscellaneous projects and monitoring equipment, tanks & pits preventing freezing issues. 12:00 00:00 12.00 8,401 8,401 COMPZ RPCOM WOEQ T Rig warm stacked. Held PJSM discussing safety & hazard recognition issues. Continue with rig maintenance and winterizing. Continue with miscellaneous projects and monitoring equipment, tanks & pits. 01/14/2009 00:00 00:00 24.00 8,401 8,401 COMPZ RPCOM WOEQ T Rig warm stacked. Held PJSM discussing safety & hazard recognition issues. Continue with rig maintenance and winterizing. Continue with miscellaneous projects and monitoring equipment, tanks & pits. RU & Vac up rain & snow melt water on decks. Replace hydraulic hose on drawworks. Inspect derrick & drlg. line. Inspect pins & shackles in derrick. 01/15/2009 Monitor well. Rig maintenance. Assist crane. 00:00 00:00 24.00 8,401 8,401 COMPZ RPCOM WOEQ T Rig warm stacked. Rig maintenance. Boat got within 1/4 mile of platform. Heavy ice kept it from getting in. Drain water from upper deck & pump room. Clean up parts house. Assist crane as needed. Finish checking derrick pins due to thick ice rocking the derrick. 01/16/2009 Page' 54 of 78 Tire Logs t.:.. Date ... , : F . To Dur 8. Death. E. Depth Phase Code Subcode 1 .....a. , . 00:00 00:00 24.00 8,401 8,401 COMPZ RPCOM WOEQ T Wait on ice to settle down in Cook Inlet to get boat to platform & bring_ supplies to continue with completion. Warm stacked & rig maintenance. Assist crane w/ minor platform work. Assist BJ Injecting Waste fluid down A 12 @ 1.5 bpm 1490 psi 141 bbls.. Change oil in #3 generator. 01/17/2009 00:00 00:00 24.00 8,401 8,401 COMPZ RPCOM WOEQ T Monitor well. Rig Maintenance. General housekeeping. Wait on ice to clear to get supplies in to finish completion. Hold safety meeting. Do another derrick inspection. 01/18/2009 00:00 00:00 24.00 8,401 8,401 COMPZ RPCOM WOEQ T Monitor well. Rig Maintenance. Assist Crane. Sweep & mop floors. Assist swaco repair. Unload & backload boat. Boat pumped off 1550 bbls. water to platform. 01/19/2009 00:00 00:00 24.00 8,401 8,401 COMPZ RPCOM WOEQ T Monitor well. Rig maintenance. Assist crane. Run all pumps, generators, hpu,s & top drive. Check drlg. line. Change out charge pump #3 mechanical packing. Install agitator motor on pit 4 gear box. 01/20/2009 00:00 00:00 24.00 8,401 8,401 COMPZ RPCOM WOEQ T Monitor well. Rig Maintenance. Assist crane. Plumbed in blow down for pump suction. Paint hopper room floor. 01/21/2009 00:00 00:00 24.00 8,401 8,401 COMPZ RPCOM WOEQ T Monitor well. Rig Maintenance. Assist crane in unloading boat w/ frac sand,salt, acid, etc. Assist BJ with loading sand in hopper. General housekeeping. Prepare deck for boat offload. 01/22/2009 Monitor well. Assist crane. Test BOPE 00:00 11:00 11.00 8,401 8,401 COMPZ RPCOM WOEQ T Monitor well. Rig maintenance. Assist crane. Unload boat w/ Schlumberger unit,parts house, generator, cable drum & perf guns, several BJ chemical tote,s, metal basket & pallets rig parts. Several pallets misc. materials. 11:00 16:00 5.00 8,401 8,401 COMPZ WELCTL BOPE T Made several attempts to get the Vetco test dart to seal with no success. It was finally determined that the wrong tool had been sent to the platform. Page 55 of 78 Tim togs ‘‘&W' DateN14 Fri T r \v ?c r S ® ®� E. DeofhAdise ; Code Subcode T 4mment 16:00 22:30 6.50 8,401 8,401 COMPZ WELCTL BOPE P Pink rip 4.5" tba. landing it. Test annular preventer 250 -3500 psi -upper variables 250 -5000 psi. Manual choke -upper & lower IBOP,s -floor valve -dart valve 250 -5000 psi. Test lower pipe rams 250 -5000 psi. 22:30 00:00 1.50 8,401 8,401 COMPZ RPCOM PULD P Rig up -back out lock down screws -lay down test jt. & hanger. 01/23/2009 Circ. & Filter all fluids. Rig up for acid wash. 00:00 02:00 2.00 8,401 8,401 COMPZ RPCOM RURD P Blow down top drive. Rig up to circulate. 02:00 06:00 4.00 8,401 8,401 COMPZ RPCOM CIRC P Circulate all rig & production pit fluid across well & filter same. 06:00 09:30 3.50 8,401 8,401 COMPZ RPCOM CIRC P Rig up. Circulate well & filter all fluids from well to get ntu,s below 20. 09:30 10:00 0.50 8,401 8,401 COMPZ RPCOM OTHR P Blow down outside mud lines. 10:00 00:00 14.00 8,401 8,401 COMPZ RPCOM OTHR P Rig up for acid wash down tbq Make up BJ 3" line to rig floor. Clean pit 6 & mix 20 bbl. Flo -vis sweep. Assist crane crew unloading boat. Inject 117 bbls. fluid down A -12 w/ BJ @ 1.3 bpm 1450 psi. 01/24/2009 Pump Acid. Pull 10 stds. tbg. Rig up to pert. 00:00 02:30 2.50 8,401 8,401 COMPZ RPCOM CIRC P PJSM =Pump 19 bbls. flo -vis. Test lines 3000 psi. Pump 13 bbls.15% acid followed with 113 bbls. brine. @ 1.5 bpm. 02:30 03:30 1.00 8,401 8,401 COMPZ RPCOM CIRC P Blow down BJ lines. Reverse out acid @ 2.5 bpm 200 psi 03:30 04:30 1.00 8,401 8,401 COMPZ RPCOM CIRC P Reverse out 2 tbg. volumes @ 4 bpm 230 psi. 04:30 05:30 1.00 8,401 8,401 COMPZ RPCOM RURD P Rig up floor to pull 10 stands 4.5" tbg. Blow down mud lines. 05:30 06:00 0.50 8,401 8,401 COMPZ RPCOM RURD P Break down FOSV assembly. 06:00 08:00 2.00 8,401 7,786 COMPZ RPCOM TRIP P Pull 10 stands 4.5" tbg. & stand in derrick. Mule shoe @ 7786' MD. 08:00 12:00 4.00 7,786 7,786 COMPZ RPCOM RURD P Make up FOSV assembly assist in rigging up schlumberger. 12:00 20:00 8.00 7,786 7,786 COMPZ RPCOM RURD P Make up BJ frac head & assist in rigging up Schlumberger. Need SWS BOP from Beluga to complete rig up. Assume chopper will fly it here in AM. 20:00 00:00 4.00 7,786 7,786 COMPZ RPCOM OTHR P Mixing KCL in production pits. 270 bbl. filtered. Rigging up heater to upright tanks/ heat manifold. Change out 6" valve on suction pod in hopper room. Run Steam hose to production pits to heat fluid. 01/25/2009 Wait on bop. Rig up same. Change FOSV. 00:00 10:00 10.00 7,786 7,786 COMPZ RPCOM WOEQ T Heating KCL fluid while waiting on SWS BOP to be flown in from Beluga. Page 66 of 78 • Logs p From To Dar S. Depth Phase Code Subcode \.`*`` qj meat .. " 10:00 12:00 2.00 7,786 7,786 COMPZ RPCOM RURD P PJSM =Rig up SWS wire line tools. 12:00 14:30 2.50 7,786 7,786 COMPZ RPCOM WOEQ T Wait on wire line BOP from Beluga. 14:30 18:00 3.50 7,786 7,786 COMPZ RPCOM RURD P Make up wire line BOP. Install same on BJ frac head. 18:00 18:30 0.50 7,786 7,786 COMPZ RPCOM SFTY P PJSM with BJ & SWS. 18:30 20:30 2.00 7,786 7,786 COMPZ RPCOM RURD P Make up SWS Lubricator, stand back. Rig up BJ lines to frac head. 20:30 21:00 0.50 7,786 7,786 COMPZ RPCOM SFEQ P PJSM =Test FOSV to 6000 psi. Attempt 3 tests, Valve failed test. 21:00 00:00 3.00 7,786 7,786 COMPZ RPCOM OTHR T Rig down frac head. Change out FOSV & rig up frac head. 01/26/2009 Make up fracture head. Rig up & perf. Frac 00:00 02:30 2.50 7,786 7,786 COMPZ RPCOM OTHR T Finish make up fracture head assembly. Rig up lubricator & lines. 02:30 04:00 1.50 7,786 7,786 COMPZ RPCOM SFEQ P Test 4.5" FOSV 6000 psi. Test Lubricator 1500 psi & Bottom of FOSV 3500 psi. OK. Blow down BJ lines. 04:00 06:00 2.00 7,786 7,786 COMPZ RPCOM OTHR P PJSM =Pick up & make up SWS perforating guns. 06:00 10:00 4.00 7,786 7,786 COMPZ RPCOM OTHR P RIH w/ SWS pert guns to 8700 MD. Correlate guns, hold 450 psi on well. Perforate well @ 8709' to 8724'MD. Pressure fell to 400 psi POH w/ guns. 10:00 14:00 4.00 7,786 7,786 COMPZ RPCOM OTHR P Close master valve, break lubricator & check guns. All shots fired. Make up lubricator. Monitor well & prep for frac job. Charge lines & fix leaks. 14:00 16:30 2.50 7,786 7,786 COMPZ RPCOM SFEQ T Pump 3 bbls. Attempt to test lines & frac. Master valve leaking. Grease valves fix leaks & test to 6000 psi. 16:30 19:00 2.50 7,786 7,786 COMPZ RPCOM STIM P Pump diagnostic injection test with 5 bbls 6% KCI at 5 BPM. Shut -in and monitor pressure leakoff and evaluate results. 19:00 00:00 5.00 7,786 7,786 COMPZ RPCOM STIM P Pump mini -frac with 3000 gal Lightning 2000 at 14.2 BPM. Shut -in and monitor pressure leakoff and evaluate results. Results showed higher stresses than anticipated and discussed with office personnel. Moved forward with main frac. COMPZ RPCOM P 01/27/2009 Frac #1 Tag sand at 8977'. Spot sand and tag at 8905'. Spot sand and tag at 8628'. 00:00 01:30 1.50 7,786 7,786 COMPZ RPCOM STIM P Pumped frac at 9.2 BPM with Lightning 2000. Pressure limited on annulus at 4000 psi and unable to initiate fracture. Cut sand with 3513 Ibs of 20/40 proppant in the casing and pumped to perforations. Maximum proppant concentration 2 PPg Page',57 of 78 i flrole Los's a � _ Date Frei T `' `� Dur S. Depth E. Debt, H ise Code : .a l e T Cent • ; 01:30 13:30 12.00 7,786 7,786 COMPZ RPCOM OTHR P Blow down BJ frac lines & rig lines. Monitor well. Bleed down pressure to 1500 psi. Presure build back to 2800 psi. Bleed down to 1500 psi. pressure build to 2450 psi. Bleed down to 600 psi pressure build to 2120 psi. Continue bleeding down pressure. Attempt to get pressure below 1000 psi to run wire line. 13:30 16:00 2.50 7,786 7,786 COMPZ RPCOM OTHR P RIH w/ SWS wire line bleeding pressure to 1000 psi. Taq sand A 8977 MD.POH Bleed & drain lubricator. 16:00 17:00 1.00 7,786 7,786 COMPZ RPCOM OTHR P Monitor well. Pressure built from 1036 psi to 1262 psi. 17:00 20:30 3.50 7,786 7,786 COMPZ RPCOM OTHR P Pumped sand plug #1 with BJ. Pumped 1484 Ibs (based on densiometer reading) at 2.5 ppg and 7 BPM. BJ had problems with the blender screw which misrepresented the sand volume at 4248 Ibs. 20:30 21:30 1.00 7,786 7,786 COMPZ RPCOM OTHR P Wait on sand to settle. 21:30 00:00 2.50 7,786 7,786 COMPZ RPCOM OTHR P RIH w /SWS wireline. Tagged sand at 8905'. POOH, bleed and drain lubricator. 01/28/2009 Spot 4531' LBS of sand in well A -16 with BJ pumping unit. Blow down lines and let sand settle. Run in hole with Schlumberger wire line and tag sand at 8628'. Held safety meeting and lay down spent perforating guns. Pick u • new •erforatinq guns and test lubricator to 1200 PSI. Run in hole with perforating guns. 00:00 01:00 1.00 COMPZ RPCOM OTHR P PJSM =Pump sand plug #2 with BJ. Pumped 4531 Ibs of sand at 4 ppg and 8.1 BPM. 01:00 02:30 1.50 COMPZ RPCOM OTHR P Wait on sand to settle. 02:30 05:00 2.50 COMPZ RPCOM OTHR P RIH with SWS to tag sand. Tag sand (cil 8628'. 05:00 17:00 12.00 COMPZ RPCOM OTHR P Monitor well, observe wellbore pressure. 17:00 19:30 2.50 COMPZ RPCOM OTHR P Held safety meeting. Lay down spent perforation guns, pick up new perforating guns. Strap and record measurments. 19:30 21:30 2.00 COMPZ RPCOM OTHR P Pressure test lubricator to 1200 PSI, bleed pressure down to 870 PSI. RIH with perforating guns. Tag sand on first try at 8551'. Pick perfortating guns up 300', then run back to bottom and tag sand at 8559'. 21:30 23:00 1.50 COMPZ RPCOM PERF T POOH with perforating guns and lay down same. 23:00 00:00 1.00 COMPZ RPCOM PERF T Pressure up annulus to 4000 PSI, then let it bleed off to 3000 PSI. Pressure up annulus to 4000 PSI again and let it bleed off to 1000 PSI at 100 PSI loss per 5 minutes. Page 58 of 78 • Tun �`. ... - ;rate From o Dur'', S. Depth ` Dth Phase "Code...:: <Subcode .; ' Comme nt A' 01 /29/2009 24 hr Summa Continue to bleed off casing pressure at 100 PSI every 5 minutes till we reached 1000 PSI. Continue to hold casing pressure at 1000 PSI. Held safety meeting on perforating guns with Schlumberger. Pick up perforating guns, test lubricator and RIH with guns to 8571'. Perforating guns would not go any farther than 8571'. POOH with perforating guns. Lay down and disarm Schlumberger perforating guns. Held safety meeting and monitor well. Shorten perforating gun to 6'. Arm and pick up perforating gun. Test lubricator to 1200 PSI, RIH, Bleed and hold casing PSI at 600 PSI. Perforate from 8565' to 8571'. After casing shot PSI dropped from 604 PSI to 521 PSI. POOH and check guns. Next, BJ performed break down FRAC. Pump 17 bbls of 8.6 brine at 5 bbls per /minute. Pressure up casing to 3950 PSI, then watch pressure bleed off for two hours. Attempt to perform Mini Frac with BJ. Seventy one barrels of viscous cross - linked polymer was pumped down hole and chased with 20 bbls of 8.6 ppg brine. When the cross - linked polymer was spotted at the bottom of the tubing the choke was shut in to begin the mini Frac. Shortly thereafter a pop off blew and sent 8.6 ppg brine water to the platform pit room. The end of the Schlumberger hose that was used to carry fluid from the pop off to the platform pit room was not tied down properly. The line came undone and pulled out of the mud tank it was secured to. A two barrel spill occurred because of this action, Kuparuk securi was notified. 00:00 02:00 2.00 COMPZ RPCOM PERF T Continue to bleed off casing pressure at 100 PSI every 5 minutes till we reached 1000 PSI. Continue to hold casing pressure at 1000 PSI. 02:00 06:00 4.00 COMPZ RPCOM PERF T Held safety meeting on perforating guns with Schlumberger. Pick up perforating guns, test lubricator and RIH with guns to 8571'. Perforating • uns would not go any farther than 8571'. POOH with perforating guns. 06:00 07:00 1.00 COMPZ RPCOM PERF T Lay down and disarm Schlumberger perforating guns. 07:00 13:30 6.50 COMPZ RPCOM PERF T Held safety meeting and monitor well. Shorten perforating gun to 6'. 13:30 16:00 2.50 COMPZ RPCOM PERF P Arm and pick up perforating gun. Test lubricator to 1200 PSI, RIH, Bleed and hold casing at 600 PSI. 16:00 17:30 1.50 COMPZ RPCOM PERF P Perforate from 8565' to 8571'. After casing shot PSI dropped from 604 PSI to 521 PSI. POOH and check guns. 17:30 21:00 3.50 COMPZ RPCOM OTHR P BJ pumped break down FRAC. Pump 17 bbls of 8.6 brine at 5 bbls per /minute. Pressure up casing to 3950 PSI, then watch pressure bleed off for two hours. 21:00 00:00 3.00 COMPZ RPCOM OTHR T Attempt to perform Mini Frac with BJ. Seventy one barrels of viscous cross - linked polymer was pumped down hole. When the cross - linked polymer was spotted at the bottom of the tubing the choke was shut in to begin the mini Frac. Shortly thereafter a pop off blew and sent 8.6 ppg brine water to the platform pit room. The end of the BJ hose that was used to carry fluid from the pop off to the platform pit room was not tied down properly. The line came undone and pulled out of the mud tank it was secured to. A two barrel spill occurred because of this action, Kuparuk security was notified. Pa 59 of 78 0 • • I t6, rom o .'. S. D? i .: E. Dett%Phas ACode Subcode 4-;� . , nient 01/30/2009 24 hr Summary Shorten perforating gun to 6'. RIH, Bleed and hold casing PSI at 600 PSI. Perforate from 8565' to 8571'. POOH and check guns. Pump 17 bbls of 8.6 brine at 5 bbls per /minute w/ 3950 psi annulus pressure. Monitor well. BJ pumped 71 bbls of viscous cross - linked polymer was pumped down hole and chased with 20 bbls of 8.6 ppg brine at 15 bpm. Annulus ,op off blew with unsecured line. Shut down operation. 00:00 06:00 6.00 COMPZ RPCOM OTHR T Monitor well. Inject waste fluid, filter dirty brine fluid and build 8.6 brine fluid in platform pits. Secure BJ pop -off line in platform pit room. 06:00 09:30 3.50 COMPZ RPCOM OTHR T Monitor well, Label and secure hose's from BJ pumping unit 09:30 10:30 1.00 COMPZ RPCOM OTHR P Reverse circulate 160 bbls of old data FRAC fluid, at 210 GPM, 1150 PSI and 850 PSI on back side. 10:30 11:00 0.50 COMPZ RPCOM OTHR P Blow down mud lines. 11:00 12:30 1.50 COMPZ RPCOM OTHR P Rig up Schlumberger wire line and RIH with spent perforating gun to tag sand. Tag sand at 8573'. 12:30 15:00 2.50 COMPZ RPCOM OTHR P POOH with spent Schlumberger perforating guns and test lubricator to 3000 PSI. Bleed lubricator and lay down same. 15:00 19:00 4.00 COMPZ RPCOM OTHR P Monitor well and perform safety walk through. Change out wire line head on Schlumberger wire line. 19:00 20:30 1.50 COMPZ RPCOM OTHR P Held safety meeting and pressure test BJ lines. BJ pumped and spotted 2400 Ibs of sand. Blow down lines. 20:30 21:30 1.00 COMPZ RPCOM OTHR P Monitor well and let sand settle. 21:30 23:00 1.50 COMPZ RPCOM OTHR P Pressure up annulus to 3000 PSI and monitor well for one hour. 23:00 00:00 1.00 COMPZ RPCOM OTHR P Bleed of annulus pressure to 750 PSI. Rig up Schlumberger for dummy run to find sand. 01/31/2009 RIH with Schlumberger spent perforating gun to tag sand plug. Tag sand plug at 8399' MD. Pump 118 barrels of 9.9 PPG brine down tubing. Arm and pick up perforating gun, RIH. Corelate perforating gun to previous well logs. Perforate from 8291' MD to 8300' MD. POOH and verify perforating gun has fired, all appears OK. Reverse circulate 118 barrels of 9.9 brine out of hole to rig pits. Continue reverse circulating well to platform pits untill well fluid is clean. Pump D -Fit test at 5.1 bbls /min, pump 6.8 bbls max. Shut in and annualize pressure decline. Pump Mini Farc at a rate of 13.1 bbls /min step down rate at end. Pump 75 barrels of Lighting 2000 and flush with 138 barrels of 8.6 brine. Max annulus pressure was 3770 PSI. 00:00 05:00 5.00 COMPZ RPCOM OTHR P RIH with Schlumberger dummy tool to locate top of sand plug. Top of sand plug at 8399' MD. POOH with dummy tool. 05:00 07:00 2.00 COMPZ RPCOM OTHR P Weight up kill weight fluid to 10 ppg 07:00 09:00 2.00 COMPZ RPCOM CIRC P Filter kill fluid and transfer from production pits to rig pits. 09:00 10:00 1.00 COMPZ RPCOM CIRC P Spot 119 bbls of 9.9 brine down 4 1/2" tubing. 10:00 12:00 2.00 COMPZ RPCOM OTHR T Break off lubricator and attempt to lower spent perforating gun. Pack off and wire line iced up, thaw out with steam and lay down. PageSoof7 • • Lo gs � x‘o#*4-„ ..� AkiMka4 �. ) From . To '. Dury -1. � E. Et& Phase Gade ;', Suhtlade,k Comment 12:00 13:30 1.50 COMPZ RPCOM PERF P Held safety meeting. Arm and pick up Schlumberger perforating gun. Test lubricator to 3000 PSI. 13:30 15:00 1.50 COMPZ RPCOM PERF P RIH with perforating gun, corelate with logs. Pressure up annulus to 3400 PSI and tubing to 3000 PSI. 15:00 18:00 3.00 COMPZ RPCOM PERF P Perforate well from 8291' MD to 8300' MD. POOH and verify perforating gun has fired. All appears OK. 18:00 20:00 2.00 COMPZ RPCOM CIRC P Reverse circulate 119 bbls of 9.9 PPG brine in tubing to rig pits. Continue reverse circulating to platform pits until fluid in well is clean with a 8.6 PPG in and out. 20:00 21:00 1.00 COMPZ RPCOM OTHR P Pump D -Fit test at 5.1 bbls /min, pump 6.8 bbls max. Shut in and annualize pressure decline. 21:00 00:00 3.00 COMPZ RPCOM OTHR P Pump mini farc at a rate of 13.1 bbls /min step down rate at end. Pump 75 barrels of lighting 2000 and flush with 138 barrels of 8.6 brine. Max annulus pressure was 3770 PSI. 02/01/2009 Pump data Frac on perforations at 8291' MD to 8300' MD. Frac rate of 13.2 bbl /min. with 75 bbls of Lighting 2000 and flush with 138 bbls of 8.6 brine. Perform main frac on same perforations. Maximum pump rate of 11.8 bbl /min with 385 bbls of Lighting 2000 and 33,360 lbs of 20/40 Econo =Prop with maximum contraction of 6 lb/gal. Screen out with 20,597 Ibs of sand in formation. Maximum annulus pressure at screen out was 3985 PSI. Reverse out 200 bbls at 7 bbls /min holding 850 PSI back pressure. RIH with Spent perforating gun to locate top of sand. Top of sand at 8165' MD. POOH and rearm perforating gun. RIH and shoot perforations from 7958' MD to 7978' MD. POOH with perforating gun, and verify gun has fired. All appears OK. 00:00 01:00 1.00 COMPZ RPCOM CIRC P Pump data FRAC at a rate of 13.1 bbls /min, step down rate at end. Pump 75 barrels of Lighting 2000 and flush with 138 barrels of 8.6 brine. Max annulus pressure 3770 PSI. 01:00 02:00 1.00 COMPZ RPCOM OTHR P Analyze test data, prepare for main FRAC. 02:00 04:00 2.00 COMPZ RPCOM CIRC P Perform Main Frac. Pump at a maximum rate of 11.8 bbls /min. Pump 387.5 barrels of lighting 2000 and 33368 pounds of 20 -40 econo -prop at a maximum contraction of 6 Ibs /gal. Screen out with 4.5 Ibs /gal on formation and 26 barrels into a 138 barrel flush. Placed 20,597 pounds of sand in formation with a maximum annulus pressure at screenout of 3985 PSI. Reverse out. 04:00 06:00 2.00 COMPZ RPCOM OTHR P Blow down lines and build volume. Wait on crosslinked fluid to break. 06:00 10:00 4.00 COMPZ RPCOM OTHR P Clean out sand traps and trip tank. Build volume and filter brine fluid. 10:00 11:00 1.00 COMPZ RPCOM CIRC P Held safety meeting. Reverse circulate at 7 bbls /min. Circulate at 1500 PSI annulus, with 850 PSI on tubing. Page 61 of 78 • • Date From .,71b -katitZ S. Depth , E. Depth Phase ode Subcode • = mment .� 11: 12:00 1.00 COMPZ RPCOM OTHR P Blow down all fluid lines and prepare to RIH and tag fill with Schlumberger wire line. 12:00 14:00 2.00 COMPZ RPCOM SFEQ P Held safety meeting. Test lubricator to 2000 PSI, RIH with Schlumberger wire line. 14:00 16:00 2.00 COMPZ RPCOM OTHR P e Tag sand plug at 8165 MD. POOH with Schlumberger wire line and bleed down lubricator. 16:00 18:00 2.00 COMPZ RPCOM OTHR P Lay down spent perforating gun, arm and pick up new perforating gun. Test lubricator to 3000 PSI. 18:00 19:30 1.50 COMPZ RPCOM PERF P RIH with perforating gun, bleed down annulus to 750 PSI and hold, while spotting gun. Perforate from 7958' MD to 7978' MD. The guns were fired with 750 PSI being held on the annulus. When the guns were fired the annulus pressure dropped to 710 PSI for one minute and then increased back to 750 PSI within one minute. 19:30 21:00 1.50 COMPZ RPCOM PERF P POOH with Schlumberger perforating gun and verify gun has fired, all appears OK. 21:00 00:00 3.00 COMPZ RPCOM OTHR P Load BJ sand hopper with 49,500 Ibs of sand. Rig down Schlumberger wire line and lubricator. 02/02/2009 Monitor well while cleaning Frac sand from sand traps and trip tank. Perform Break Down Frac. Pumped DFIT with 5 bbls of 6% KCL @ 5.1 bbls /min. Maximum annulus pressure was 2270 PSI and maximum treating pressure was 2350 PSI. Shut in an analyze pressure decline. Perform Mini Frac. Pumped Mini Frac with 75 bbls of lighting 2000 at 15.1 bbls /min with step down rate. Then flushed with 125 bbls of 6% KCL. Maximum annulus pressure was 2300 PSI with a maximum treating pressure of 3150 PSI. Shut in to annalize pressure decline. Perform Main Fracjob. Pumped main Fracjob with 387 bbls of lighting 2000 and 40,871 pounds of 20/40 Econo -Prop with a maximum concentration of 8 ppg at a maximum rate of 19.4 barrels per /min. Flushed with 125 barrels of 6% KCL and placed all sand in formation. Maximum annular pressure was 2400 PSI with a maximum treating pressure of 3300 PSI. 00:00 06:00 6.00 COMPZ RPCOM P Monitor well, shovel frac sand from sand traps. Offload and back load boat. 06:00 08:30 2.50 COMPZ RPCOM P Monitor well, check lines and connections while waiting on Frac crew. 08:30 11:30 3.00 COMPZ RPCOM P Perform Break Down Frac,. Pumped DFIT with 5 bbls of 6% KCL @ 5.1 bbls /min. Maximum annulus pressure was 2270 PSI and maximum treating pressure was 2350 PSI. Shut in an analyze pressure decline. Page' 62 of 78 • • Time Logs Date . •• '' Froth Tikit Drat .$.: Depth ; 0 9 Phase ... 7 Subcode" T 'Comment . • . 11:30 15:30 4.00 COMPZ RPCOM P Perform Mini Frac Pumped Mini Frac with 75 bbls of Lighting 2000 at 15.1 bbls /min with step down rate. Then flushed with 125 bbls of 6% KCL. Maximum annulus pressure was 2300 PSI with a maximum treating pressure of 3150 PSI. Shut in to annalize pressure decline. 15:30 17:00 1.50 COMPZ RPCOM P Perform Main Frac iob. Pumped main Frac job with 387 bbls of Lighting 2000 and 40,871 pounds of 20/40 Econo -Prop with a maximum concentration of 8 ppg at a maximum rate of 19.4 barrels per /min. Flushed with 125 barrels of 6% KCL and placed all sand in formation. Maximum annular pressure was 2400 PSI with a maximum treating pressure of 3300 PSI. 17:00 18:30 1.50 COMPZ RPCOM P Circulate BJ clean up through all Frac lines and continue with cleanup. 18:30 21:30 3.00 COMPZ RPCOM P Rig down Schlumberger and BJ equipment from rig floor. 21:30 00:00 2.50 COMPZ RPCOM P Thaw lines comming from upright tanks, monitor well. SIP on annulus - 339 psi. 02/03/2009 Monitor well bore pressure. Continue to work on MI fluid press. Finish rigging down Schlumberger and BJ Frac equipment. 00:00 12:00 12.00 COMPZ RPCOM OWFF P Monitor well, keep track of well bore pressure. Continue with rig work. Work on MI fluid filter press. Time PSI EWM 00:00 339 9.64 04:00 235 9.32 08:00 183 9.16 12:00 142 9.04 12:00 00:00 12.00 COMPZ RPCOM OWFF T Monitor well, keep track of well bore pressure. Continue with rig work. Work on MI fluid filter press. East side crane is down, harmonic balancer is starting to come off of crane engine. Time PSI EWM 13:00 136 9.02 16:00 121 8.97 20:00 107 8.93 24:00 96 8.89 02/04/2009 Monitor well bore pressure. Continue to work on MI fluid press. Finish rigging down Schlumberger and BJ Frac equipment. Begin utilizing filter pods, and bring 9.6 PPG fluid down to 9.0 PPG for calculated kill weight fluid. Pump 283 barrels of 9 ppg kill weight brine to kill well while holding 100 PSI back pressure on choke. Observe well for flow, all appears OK. Rig down BJ Frac head and all other Frac equipment on rig floor. Continue to monitor well using trip tank. Page 63 of 78 • • 4 *W Date:' FrarnW, TO Dor bepth E.'Depth # ase Code- ..: °-St[bde , `4 ... -C+ ment 00:00 08:00 8.00 COMPZ RPCOM OWFF T Monitor well, keep track of well bore pressure. Continue with rig work. Work on MI fluid filter press. Unit crane is down, harmonic balancer is starting to come off of crane engine. Trouble shoot issues with the filter press and the crane. Time PSI EMW 00:00 98 8.89 02:00 90 8.88 04:00 84 8.86 05:00 82 8.85 06:00 81 8.85 07:00 79 8.84 0800 78 8.84 08:00 17:30 9.50 COMPZ RPCOM KLWL P Begin filtering 9.6 PPG fluids and bringing weight down to 9.0 PPG for , calculated kill weight. Utilize fluids in rig and platform pits running fluid through the filter pods, and not the press. Continue monitor well while building kill weight fluid. 17:30 19:30 2.00 COMPZ RPCOM KLWL P Held safety meeting. Pump 283 barrels of 9 ppg, 6% KCL kill weight brine at 5 barrels a minute down tubing and out choke. 100 PSI back pressure was held on the choke at all times while killing the well. No gas was observed at the choke when bottoms up hit the surface. 19:30 21:00 1.50 COMPZ RPCOM OWFF P When pumps were shut off no pressure was opbserved on the choke manifold. Open pipe rams and observed no flow. Continue to watch well using trip tank, no losses or flow was observed. 21:00 00:00 3.00 COMPZ RPCOM RURD P Held safety meeting. Rig down BJ Frac head and all other Frac equipment from rig floor. Continue to monitor well with trip tank. Hole appears to be stable. 02/05/2009 Finish testing all BOPE as /per AOGCC specifications. Stab floor valve in tubing work string. Monitor well. Boat continued on standby to off load remaining equipment as per manifest. Continue filter fluids and mix salt & KCL for building volume for upcoming cleanout run. Boat came along side at 21:00 hrs and preceded to unload cargo. 00:00 02:30 2.50 COMPZ RPCOM RURD P Lay down FOSV valve and pick up Halliburton Storm Packer. Set packer 60' below rotary table. Test packer set to 1000 PSI for 5 minutes. All appears OK. Page 64of78' • • �. Log. ''� ro �: -'�� r ‘., .�� its ,Tram 4o Our S DeathOEt : Death Phase Code Subcode T Comment 02:30 14:30 12.00 COMPZ RPCOM BOPE P RU & test all BOPE to AOGCC specifications. 31 Components. Witness of test by AOGCC was waived by Jim Regg at 14:00 hrs, 2/4/09. Perform Koomey test with 200 PSI attained in 23 seconds and full pressure at 1 min 44 sec. 4 Nitrogen bottles @ 2425 PSI. Observed #3 Choke manifold valve failed on first attempt, and tested after servicing valve. Pull test plug and rig down test equipment. 14:30 16:30 2.00 COMPZ RPCOM BOPE P Make up Haliburton retieving tool, and RIH to tag & engage Storm valve. Observed no pressure when screwed into packer. Monitor well - 15 minutes. Pull storm valve to rig floor. Breakout & lay down same. 98K upweight, 64K downweight. Note: SIMOPS - Boat at the platform with equipment & products. Only able to offload a partial Toad as the ice conditions allowed. Continue standby with boat monitoring tides, and ice conditions. Conrtinue filter fluids and mix salt & KCL for building volume for upcoming cleanout run. 16:30 17:00 0.50 COMPZ RPCOM BOPE P Make up floor valve & test same to 250K / 5000 K, for final test. 17:00 00:00 7.00 COMPZ RPCOM COND P Stab floor valve in tubing work string. Monitor well. Boat continued on standby to off load remaining equipment as per manifest. Continue filter fluids and mix salt & KCL for building volume for upcoming cleanout run. Boat came along side at 21:00 hrs and preceded to unload cargo. 02/06/2009 Wash from 8144' MD to tag BP @ 9009 ' MD. Difference from wireline measurement = 18'. At 8144' MD start to circulate 9 ppg brine with 6% KCL at 6 bbls /minute, increasing rate to 7 BPM. RIH with one stand of drill pipe and then circulate bottoms up. Repeat this procedure each stand while circulating until shakers clear up. Monitor well each connection for well control. No loss of fluids while circulating were encountered. Continue to monitor well and make ready to POOH. POOH laying down 4 1/2" tubing. 00:00 01:30 1.50 7,786 7,786 COMPZ RPCOM COND P Continue filter fluids and mix salt & KCL for building volume for upcoming cleanout run. Rig up MI volume for vac system. Held safety meeting for a personal involved. Start ti RIH. 01:30 02:30 1.00 7,786 8,144 COMPZ RPCOM TRIP P RIH slowly and tag sand at 8144' MD, expected depth of tagging sand was 8165' MD. Page 65of78' • • Time Lugs a �.: Date From ° To Dur ., A eptrf . f=. , Phase Code :'.. SubOode . T Comment . 02:30 16:00 13.50 8,144 9,009 COMPZ RPCOM WASH P Wash from 8144' MD to tag BP A 9009' MD. Difference from wireline measurement = 18'. At 8144' MD start to circulate 9 ppg brine with 6% KCL at 6 bbls /minute, increasing rate to 7 BPM. RIH with one stand of drill pipe and then circulate bottoms up. Repeat this procedure each stand while circulating until shakers clear up. Monitor well each connection for well control. No loss of fluids while circulating were encountered. Recovered a total of 44 BBLS of Carbolyte sand. 16:00 17:30 1.50 9,009 9,009 COMPZ RPCOM OWFF P Monitor well. Bled back approx 2 BBLS. Observed well - static. While monitor well, clean filter press screens to increase rate for next circulation & clean up.Observed no gas, or fluid losses or gains. NOTE: The boat was able to get the final offload, and the give the platform water. Released boat & tug back to OSK for offload and take on next load.. 17:30 20:30 3.00 9,009 9,009 COMPZ RPCOM CIRC P Close annular, reverse circulate @ 7 BPM while filtering fluids to bring the NTU's down to less than 10. Pumps @ 7 BPM - 645 PSI. 20:30 00:00 3.50 9,009 9,009 COMPZ RPCOM OWFF P Monitor well. It appears well was giving back fluid from perforations. The well started to give back aprox. one barrel per /hr, them reduced returnes to zero. 02/07/2009 Lay down all 4 1/2" tubing. Continue to monitor fluid in well. Average fluid loss was 3 bbls per /hr. 00:00 01:00 1.00 9,009 7,784 COMPZ RPCOM TRIP P Monitor well. POOH with 4 1/2" tubing from 8663' MD to 7784' MD. I•sses at 3.6 bbls •er /hr. 01:00 02:00 1.00 7,784 7,784 COMPZ RPCOM TRIP P Blow down top drive and rig up Weatherford tubing tongs. Held safety meeting. Continue to observe well. 02:00 03:00 1.00 7,784 8,402 COMPZ RPCOM TRIP P RIH with 10 stands of tubing from derrick. 03:00 19:30 16.50 8,402 0 COMPZ RPCOM TRIP P Held safety meeting and start to POOH laying down 4 1/2" tubing from 8402' MD to surface.. Continue to monitor well with trip tank, average 3 bbls /hr fluid loss. 19:30 21:30 2.00 0 0 COMPZ RPCOM OWFF T Monitor well. Boat here but can not unload because of ice. All brine pits and tanks are full of 9 ppg, 6% KCL brine, 1500 bbls total. 21:30 00:00 2.50 0 0 COMPZ RPCOM OTHR P Unload perforating gun and all Halliburton from boat. Continue to monitor well. 2 barrel per /hr loss average. Page 66of78 • • — TuneLo r �, ... .z � 4 Date terh To Dur $ DOOth e Phase' Code Subcade T ,Comment 02/08/2009 24 hr Su mmary Held safety meeting with all personal involved with picking up Halliburton perforating guns. Pick up all perforating guns as /per Halliburton field hand orders. RIH with TCP guns at 60 feet per /min while filling pipe every five stands. 00:00 03:00 3.00 0 0 COMPZ RPCOM OTHR P Finish loading 4 1/2" tubing onto boat then finish off loading all Halliburton perforating equipment and Schlumberger wire line equipment. Continue monitoring well, average fluid loss was 2 barrels per /hr. 03:00 14:00 11.00 0 1,465 COMPZ RPCOM PERF P Held safety meeting. Pick up all Halliburton tubing convied perforating guns. Continue monitoring well. 14:00 17:00 3.00 1,465 1,465 COMPZ RPCOM PERF T Monitor well while standing by for PIP tag installation. Kick Drill = 90 seconds 17:00 00:00 7.00 1,465 6,822 COMPZ RPCOM PERF P Check Crown -o- Matic. Decision was made not to run PIP tags. RIH from 0' MD to 6822' MD with TCP guns on drill pipe. RIH at 30 feet per /min and fill drill pipe every 5 stands. At 6822' MD UP weight = 110K, Down weight = 60 K. 02/09/2009 Could not unload boat due to thick ice. At 22:00 hrs ice conditions were such as to let the Champion alongside to unload Schlumberger wire line unit. Rig up and run Schlumberger orienting tool. 00:00 03:30 3.50 6,822 8,776 COMPZ RPCOM PERF P RIH from 6822' MD to 8776' MD. RIH slowly at 30 feet per /hr while filling drill pipe every five stands. Did not fill last thirteen stands of drill pipe keeping a 500 PSI underbalance. At 8776' MD Drag up = 166K Down = 67K 03:30 22:00 18.50 8,776 8,776 COMPZ RPCOM OTHR T Monitor well waiting on boat for Schlumberger wire line unit to arrive. Average fluid losses = 1.5 barrels per /hr. Unload partial loads with small windows of time due to ICE conditions for boat. 22:00 00:00 2.00 8,776 8,766 COMPZ RPCOM PERF P Held safety meeting with Schlumberger for umcomming E -Line run. Finish Schlumberger wire line rig up. Continue to monitor well, average fluid loss = 1.4 bb /hr. 02/10/2009 Perforate well. POH & laying down guns. 00:00 02:30 2.50 8,766 8,771 COMPZ RPCOM PERF P RIH with Schlumberger to correlate depth of perforating guns. Set guns to shoot from 7500' MD to 8771' MD. Page 67 of 78 • • Time Logs Da 3 From TcP Dui . $ .' ® : E. Depth . Pitirroa ' :°ode Subcocie . T Comir4Ot 02:30 06:00 3.50 8,771 8,771 COMPZ RPCOM PERF P Held safety meeting. Set Chamo Packer at 7357' MD. Rig up BJ and test lines to annulus to 3500 PSI for 5 minutes. Then close annular preventer and slowly pressure annulus up to 3000 PSI. While pressuring up annulus perforating guns fired after 2.5 barrels of 9 ppg brine was pumped at 2700 PSI. Keep building pressure to 3200 PSI and stop, then bleed off pressure to 500 PSI. Start POOH, pull approximately 10 feet and pressure dropped from 500 PSI to 0 PSI. Rig up to reverse circulate with rig pumps and return brine through top drive to platform pits. Reverse circulate 241 barrels of 9 ppg brine with no gas cut brine returning. 06:00 12:00 6.00 8,771 8,771 COMPZ RPCOM PERF P Monitor well, open up annular. Circulate the long way staging pumps to 5 BPM, 775 PSI. Observed CO measurements of 800 - 1000 PPM. LEL level increase of 6 PPM. NTU's out 20 +, and in - 4. UP WT = 172K, DN WT = 68K. Circulate a toatl of 4 circulations. Reciprocate string to verify no stuck pipe issues. Free movement in string. Observed well took a 30 BBL drink, and then no more losses observed. Observed no gas issues when bottoms up each tiime other than expected spent gas from the perf guns. 12:00 12:30 0.50 8,771 8,771 COMPZ RPCOM OWFF P Monitor well. Observed fluid bubbling, with flow, and pit gain of 1/2 BBL in 15 minutes. 12:30 13:30 1.00 8,771 8,771 COMPZ RPCOM CIRC P Continue circulate bottms up at 5 BPM - 700 PSI. Observed no gas on bottoms up. 13:30 14:30 1.00 8,771 8,771 COMPZ RPCOM OWFF P Monitor well. Allow for .2 BBLS to blled into trip tank observing well static. No gas. No bubbling in the flow nipple. Continue monitor to ensure well static. Continue to periodically reciprocate drill string to verify free movement in string. Total losses for circulation and day = 44 BBLS. 14:30 00:00 9.50 8,771 1,381 COMPZ RPCOM TRIP P POOH racking back 4" drill pipe at a 60 ft/minute string speed. Observed proper hole fill. No losses. Boat here attempting to unload gun baskets on the deck, and will as the ice allows. 02/11/2009 Lay down guns. RIH & ream perfs. (Total fluid losses for 2 -11 -09 6 bbl. Total to date 1708 bbl. ) Page 68of78 • Time Date 19IFfora To W %ur S. Depth E.,,Deoth''Phase' Code Suboode T Comment . ,..; k . 00:00 03:00 3.00 1,381 1,100 COMPZ RPCOM OWFF P Monitor well. Guns unloading. Shut down trip pump & flow check well. Cont. POH to guns. 03:00 10:00 7.00 1,100 0 COMPZ RPCOM PULD P PJSM= Bleed gas while laying down pert guns. 10:00 11:30 1.50 0 0 COMPZ RPCOM OTHR P Clear & clean rig floor. Monitor well. 11:30 19:00 7.50 0 5,789 COMPZ RPCOM TRIP P Pick up Swaco clean out tools & RIH to 5789' 19:00 20:00 1.00 5,789 5,789 COMPZ RPCOM CIRC P Check for flow. Circ. bottoms up @ 5789' MD. Monitor well. 20:00 22:00 2.00 5,789 7,414 COMPZ RPCOM TRIP P RIH from 5789' to 7414' MD. Monitor well before rotating. 22:00 00:00 2.00 7,414 7,980 COMPZ RPCOM OTHR P Ream down thru perf,s from 7414' to 7980' w/ no pump making 3 passes per stand. 60 rpm. 02/12/2009 Reverse circ. below & above perfs. (Fluid loss daily 8 bbl. Total loss 1716 bbl.) 00:00 03:30 3.50 7,980 8,900 COMPZ RPCOM OTHR P Rotating thru perf,s without pump @ 60 rpm making 3 passes each stand from 7980' MD to 8900' MD. 03:30 08:00 4.50 8,900 8,900 COMPZ RPCOM CIRC P Reverse circ. well after scraping perforations. Condition mud to -20 NTU,S & weight to 9.0 ppg. 08:00 08:30 0.50 8,900 8,900 COMPZ RPCOM OTHR P Clean filter press & monitor well. NTU,S @ 57. 08:30 16:00 7.50 8,900 8,900 COMPZ RPCOM CIRC P Continue reverse circ. Increase pump rate to 252 gpm psi increased from 570 to 1135 psi. NTU's had stabled out at 38 -40, and began to trend up. 16:00 16:30 0.50 8,900 8,900 COMPZ RPCOM OWFF P Monitor well. 16:30 18:30 2.00 8,900 7,450 COMPZ RPCOM TRIP P POH from 8914' to 7450'. to circ. above perforations. 18:30 22:30 4.00 7,450 7,450 COMPZ RPCOM CIRC P Reverse circ. @ 7450' @ 4 bpm 418 psi. Cut drlg. line while circ. Blow down kill lines. 22:30 00:00 1.50 7,450 7,032 COMPZ RPCOM TRIP P BROOH from 7450' to 7032'. RPM 40 BPM 4 CBU every 10 stands. 02/13/2009 BROOH lay down MI tools. 00:00 17:30 17.50 7,032 1,608 COMPZ RPCOM TRIP P BROOH from 7032' 40 rpm 4 bpm to 1608' MD. Circ. bottoms up every 10 stands. Observed proper displacement. 17:30 18:00 0.50 1,608 1,608 COMPZ RPCOM PULD P Lay down MI screen patroller /razor back tool. Observed the patroller was partially full of debris making it unable to empty because debris wedged between parts. 18:00 00:00 6.00 1,608 0 COMPZ RPCOM TRIP P Continue back ream out of hole @ 40 rpm 4 bpm. Circ. bottoms up every 10 stands. Observed proper displacement. 02/14/2009 Lay down swaco tools. RIH w/ sump packer. Page 69 of 78 • e Dur S. Depth' Depth Phase Code(• Subtode T Comment Date. ; x�.,� ?® 00:00 01:00 1.00 0 0 COMPZ RPCOM PULD P Lay down MI Swaco clean out assembly. Observed the magnet was covered with gun debris, and the junk basket had minimal debris. Clean & clear rig floor. 01:00 17:00 16.00 0 8,830 COMPZ RPCOM TRIP P Held PJSM with crew & BOT reps. Discuss safety & hazard recognition issues. Discuss procedure for making up & running Sump packer assembly & running speeds.Pick up BOTsump packer assembly with the RA sub & PIP Tag installed 2 stands above assembly & RIH to 3000' @ 2 mins. per stand drifting drill pipe with 2 7/16" drift. When assembly at the top of perfs, obtain parameters, and continue TIH at running speed of 5 -7 ft/minute. Run assembly to 8843' DPM. Up WT = 197K, SO WT = 71 K. Pull back up to locate bottom of assembly at 8830' DPM. Observed proper displacement on TIH. 17:00 17:30 0.50 8,830 8,830 COMPZ RPCOM SFTY P Held PJSM with crew, BOT reps, and SWS reps. Discuss safety & hazard recognition issues. Discuss RU of SWS with lubricator. 17:30 23:00 5.50 8,830 8,830 COMPZ RPCOM ELOG P RU SWS wireline assembly, with lubricator, pump in sub & grease head. WLIH with CCL, to locate & verify depths of drill string and sump packer assembly. Locate same & POH w/ wireline. Rig down SWS. 23:00 00:00 1.00 8,830 8,797 COMPZ RPCOM OTHR P Pull up 6.08' & drop ball. Allow ball to fall & pressure up to 850 psi. Set packer @ 8797' pick up 10' & circ. COMPZ RPCOM 02/15/2009 Circ. work on NTU,S. Build fluid density to 9.2 ppg. to control gas. 00:00 03:00 3.00 8,797 8,792 COMPZ RPCOM CIRC P Circ. @ 8772' 9 ppg 6% KCL brine @ 4 bpm 440 psi attempting to achieve less than 20 ntu returns. Observed - NTU readings stable at 38 out of well, 1 -2 NTU's out of the press. Stop pumping. 03:00 04:30 1.50 8,792 7,450 COMPZ RPCOM TRIP P POH from 8772' to 7450', to above the perforations. 04:30 08:00 3.50 7,450 7,450 COMPZ RPCOM CIRC P Circ. @ 4 bpm 340 psi. working on NTU's.Observed NTU readings straight lined at 50. Total fluid loss since midnight = 84 BBLS - all while pumping. The boat was here to off load equipment back and then load screen baskets but ice conditions were of concern. Page 70of78 • Da e` . 'From To Dur S. , Depth E. 1% thPhase Code _Subcode E 1 Comment R , 08:00 16:00 8.00 7,450 7,450 COMPZ RPCOM CIRC T Waiting on ice conditions to off load boat & back haul equipment. Circulate for NTU's while on bottom, and possible well control. Boat was loaded and headed back to OSK at 1600 HRS. Shut down pumps. 16:00 17:00 1.00 7,450 7,450 COMPZ RPCOM OWFF P Monitor well. Observed 2 BBL flow _ back in 1 HR. LEL levels at the nipple 10 -12 %, with flow slowing but not stopped, and LEL levels, dropping as well to 5 -6 %. Discussed the options for next run, and considered trip margin as well as time to make up gravel pack screens. Decision to weight up to 9.2 PPG. 17:00 19:30 2.50 7,450 8,772 COMPZ RPCOM TRIP P Trip back to 10' above the sump packer assembly, and below the perforations.- 15 stands. 19:30 22:30 3.00 8,772 8,772 COMPZ RPCOM CIRC P Circulate to increase fluid weight from 9.0 PPG to 9.2 PPG for trip margin, and consideration of next assembly - gravel pack screens.Pumps at 4 BPM - 410 PSI. 22:30 23:30 1.00 8,772 8,772 COMPZ RPCOM OWFF P Monitor well after building fluid density to 9.2 ppg. Losses .6 bph. 23:30 00:00 0.50 8,772 8,700 COMPZ RPCOM TRIP P POH for production screens. 02/16/2009 POH. Rig up & run baker screens. 00:00 08:30 8.50 8,700 0 COMPZ RPCOM TRIP P Monitor well. Drop drill pipe drift & POH for screens to surface. Inspect, breakout & lay down running tools assembly. All good. 08:30 09:00 0.50 0 0 COMPZ RPCOM OTHR P Clean & clear rig floor area. 09:00 12:00 3.00 0 0 COMPZ RPCOM RURD P Remove 8' bales from top drive. Install 16' Bales. Hold PJSM with Weatherford. Discuss safety & hazard recognition issues. Discuss procedure to rig up and run rave pack Screens. Rig up Weatherford power tongs and equipment. 12:00 23:00 11.00 0 1,329 COMPZ RPCOM SCRN P RIH w/ baker screens as planned. Pick up wt. of screens 8k. 23:00 00:00 1.00 1,329 1,329 COMPZ RPCOM OWFF P Well began perculating on last 2 screens. Monitor well. Make up cross overs to 2 7/8" 511 on bottom of stand w/ safety valve on top to be prepared for kick.. Losses in hole for 12 hrs. 7.0 bbls. Well perculating but not flowing. 02/17/2009 P/U 2 7/8" & RIH w/ Screens. 00:00 04:30 4.50 1,329 1,329 COMPZ RPCOM SCRN P PJSM =Pick up 2 7/8" 511 hydril 43 jts. 3 pups & packer assembly. Rig down csg. equipment. Page 71 of 78 • • Titer L ©gsc Date , .. from To , .Du DeWLDeput Phase, ..Code:. i , r ::..T. . i rn 0 04:30 05:00 0.50 1,329 1,392 COMPZ RPCOM SCRN P Rig up to run drill pipe. RIH w/ baker screens on 4" DP to 1392'. 05:00 07:00 2.00 1,392 1,392 COMPZ RPCOM OWFF T After running 1 stand 4" dp. Well began flowing over drill pipe. Stab safety valve, pick up & observe well. Well began flowing gain of 1.5 bbl. Shut annular preventer & monitor csq. pressure while making preparations to strip in hole. Csg. pressure @ 90 psi Pump down DP thru ports on top of screen assembly @ 1.5 bpm 120 psi. Shut down obseved 10 % LEL & diminished. Bleed pressure to 0. Open annular. Fluid perculatinq but dropping. 07:00 11:00 4.00 1,392 5,547 COMPZ RPCOM TRIP P RIH w/ gravel pack assembly. Observed .8 bbl loss each 5 stands. Begin weight up system 9.4 ppg. Well perculating while trip in hole to 5547'. 11:00 13:00 2.00 5,547 5,547 COMPZ RPCOM CIRC P Circ. 9.4 ppg brine @ port depth 4167'. Circ. thru choke & weight up to 9.4 ppg. Monitor well. 13:00 19:00 6.00 5,547 8,797 COMPZ RPCOM TRIP P RIH w/ gravel pack assembly to 8797' & latch to sump packer 19:00 23:30 4.50 8,797 8,797 COMPZ RPCOM OTHR P Monitor well. Offload boat. Salt & 4.5" tbg. Back load baker equipment. Mixing all fluids to 9.4 ppg. 23:30 00:00 0.50 8,797 8,797 COMPZ RPCOM CIRC P Circ. spotting 9.4 ppg fluid in hole © 7426' 3 bpm 125 psi. 02/18/2009 Build volume. Set Packer. Run Injection test. 00:00 01:00 1.00 8,797 8,797 COMPZ RPCOM CIRC P Circulate 9.4 ppg brine in well. 01:00 09:30 8.50 8,797 8,797 COMPZ RPCOM OTHR P Building 9.4 ppg brine in complete pit system & upright tanks. Not circ. well due to element on packer. 09:30 15:30 6.00 8,797 8,797 COMPZ RPCOM RURD P PJSM =Rig up to set packer, drop 1 3/4" ball & continue to rig up BJ. 15:30 17:00 1.50 8,797 8,797 COMPZ RPCOM PACK P Set Gravel Pack Packer @ 7427 ft MD by pressuring up on the tubing to 1,900 psi hold for 5 minuites then bleed to zero / 2,500 psi hold for 5 minuites then bleed to zero / 3,100 psi hold for 5 minuites then bleed to zero. Pickup 20,000 lbs and set 5,000 lbs down to test the packer. Packer Tested good. Pressure up on the backside to 2,000 psi and hold for 5 minuites then bleed to zero to release the crossover tool from the Gravel Pack assembly. Marked tool positions. 17:00 18:00 1.00 8,797 8,797 COMPZ RPCOM CIRC P Position the Crossover tool to reverse. Reverse out ball @ 5 bpm 120 bbl. Page 72 of 78 . . Time Lo Date Fr - Tq': \. :..0 S". Depth E. Deoth_Phase Code Eubcode " T Comment 18:00 20:00 2.00 8,797 8,797 COMPZ RPCOM GRVL T Attempted to test BJ lines to 6000 psi. 2" Valves on Gravel Pack Manifold was leaking. Repair Leak after 1.5 hours of troubleshooting. 20:00 21:00 1.00 8,797 8,797 COMPZ RPCOM CIRC P Performed Circulation and Injection tests. Circulation tested up to 18 BPM (Tubing pressure 3210 spi / Annulus pressure 782 psi) with 6.5 BPM return rate. Tubing and Annulus Pressures broke back (Tubing pressure dropped 1000 psi / Annulus pressure dropped 80 psi) at 16.6 BPM with 6.4 BPM return rate. Injection rate test was tested up to 15 BPM (Tubing pressure 4250 psi / Annulus pressure 1938 psi) with zero returns. Attempted to pumped over 15 BPM but the electron pump kickouts went off. 21:00 00:00 3.00 8,797 8,797 COMPZ RPCOM GRVL T Fill rig pits w/ 9.4 ppg brine. Strap all tanks. Total Completion fluid prior to starting the gravel pack was approx. 950 bbls. Deicded to start pumping the gravel pack at 10 BPM @ 1PPA and choke return to 3 BPM. First attempt to choke returns - Gravel Pack Manifold starting vibrating. Shut down and repair Choke. Found choke rigged backward (No indications on manifold present identifying flow direction. Pressure test BJ Lines - Tested Good. Second attempt to choke returns - Leak on swivel downstream of manifold. Replaced swivel. Third attempt to choke returns - Leak on swivel downstream of manifold. Decision was made to shutdown for the night. Placed the Gravel Pack crossover tool in the reverse position. Blow down BJ lines & monitor well while repairing lines. 02/19/2009 Mix volume. Gravel pack. POH. (Daily losses downhole 639 bbl. Total for completion 3095 bbl.) 00:00 09:00 9.00 8,797 8,797 COMPZ RPCOM EQRP T Repair to BJ hi- pressure lines & mixing volume in all tanks. Monitor well keeping hole full. Hole taking .5 bph. 09:00 10:00 1.00 8,797 8,797 COMPZ RPCOM SFTY P PJSM w/ BJ crew -Rig Crew - Completion Engineer,s- Platform Supervisor -Rig Supervisor -Swaco crew & Baker rep, s. 10:00 10:30 0.50 8,797 8,797 COMPZ RPCOM CIRC P Reverse out 110 bbls. (small amount of gas.) 10:30 12:00 1.50 8,797 8,797 COMPZ RPCOM OTHR P Fill BJ lines & pressure test to 6000 psi. _Transfer fluid to upright tanks. 12:00 12:30 0.50 8,797 8,797 COMPZ RPCOM SFTY P Safety meeting to discuss gravel pack procedure after crew change. Page 73of78 Time Lo gs � � � • �,... � Dat e*`` � Frorn :' To Dor S. Depth f=. D�q#t , . ' ' Cotle 'Su icode . T Comment ` ,,. " , 12:30 15:00 2.50 8,797 8,797 COMPZ RPCOM GRVL P Move tools into circulating position. Line up surface valves and close annular preventor. Begin pumping brine at 10 b/m taking returns through wide open choke. Tbg P -3016 psi; Ann P- 578 psi; Rtns -6.4 b /m. Pinch back to to lower returns to 3 b/m with 71 bbls clean fluid away. Tbg P -3016 psi; Ann P 619 psi; Rate -10.7 b /m; Rtns -6.6 b /m. Start 20/40 sand at 1 ppg with 93 bbls clean brine pumped. Tbg P -3069 psi; Ann P -1573 psi; Rate -10.4 b /m; Rtns -3.1 b /m. Sand slurry at port with 186 bbls clean fluid pumped. NTU's of fluid 7.85. Tbg P -2836 psi; Ann P -1520 psi; Rate -10 b /m; Rtns- 3.1 b /m. With 344 bbls clean fluid pumped Ntu's are 6.91. Tbg P -2877 psi; Ann P -1561 psi; Rate -10.4 b /m. Rtns -3.1 b /m. Sand conc -1 ppg. 445 bbls clean fluid pumped- Tbg P -2989 psi; Ann P -1549 psi; Rate -10.3 b /m; Rtns -3.1 b /m; sand conc -1 ppg. With 652 bbls clean brine pumped switch to flush. Tbg P -3122 psi; Ann P -1442 psi; Rate -10.3 b /m; Rtns -3.1 b /m. Redue rate and open choke for full return to induce screen out. Tbg P -2936 psi; Ann P -780 psi; Rate -8.9 b /m; Flush fluid away- 77 bbls. SD pumping and move tool to reverse position. Tbg P -1913 psi; AnnP -255 psi. 720 bbls clean brine pumped for this stage of gravel pack. with 22049 lbs of 20/40 sand. No screen out seen. Page 74 of 7 • • T>rr Legs Date From To Dur .. .S. Lth E. Depth Phaatt6e.: T COrfto �n# 15:00 16:30 1.50 8,797 8,797 COMPZ RPCOM GRVL P Complete reverse out . Small amounts of sand seen. Transfer fluid to upright tanks, move tool into circulating position. Dump last two bags of sand. Pump remainder of the sand at 10.4 b/m with a concentration of 1.5 ppg. On line with tbg P -3398 psi; Ann P- 339 psi; Rate- 10.3 b /m; Rtns- 4.6 b /m. Sand concentration 1.5 ppg. Sand slurry at port Tbg P -3136 psi; Ann P -313 psi; Rate -10.4 b /m; Rtns -4.7 b /m; conc -1.5 ppg.NTU's on fluid is 8.34. Swap to flush with 127 bbls clean fluid pumped. Tbg P -3697 psi; Ann P -347 psi; Rate- 10.4 b /m;Rtns -4.7 b /m. Cut rate to 8.9 b /m. Tbg P -3800 psi; AnnP -347 psi; Rtns -4.7 b /m. Cut rate to 5.6 b /m. Tbg P -3604 psi; Ann P 320 psi; Rtns -4.6 b /m. Screen out with 3500 psi. SD pumping. For two phases of gravel pack: 911 bbls clean brine; 27304 Ibs of 20/40 sand in formation; 695 tbs sand reversed out of pipe; Estimate 577 bbls fluid left in formation. Pick tool up and reverse out sand. 16:30 18:00 1.50 8,797 8,797 COMPZ RPCOM CIRC P Reverse out sand &circ. complete circ. Well perculating slightly. 18:00 20:30 2.50 8,797 6,000 COMPZ RPCOM TRIP P POH from 8797' to 7400'. Pull thru KOIV. Run back & break KOIV w/ 6000 wt. Pull to 6000'. 20:30 21:30 1.00 6,000 6,000 COMPZ RPCOM CIRC P Circ. surface to surface volume @ 5.5 bpm 380 psi. Well perculating heavy on bottoms up then smoothed out. Blow down BJ lines. 21:30 00:00 2.50 6,000 6,000 COMPZ RPCOM PULD P Change out long bails. Lay down space out pups, head pin & safety valve. Monitor well. 02/20/2009 Finish POH. Test BOPE (Total daily fluid loss 85 bbls. Total 3180 bbls.) 00:00 01:30 1.50 6,000 6,000 COMPZ RPCOM PULD P Finish changing out Bails & elevators. 01:30 05:00 3.50 6,000 1,470 COMPZ RPCOM TRIP P POH to Packer 1470' 05:00 06:00 1.00 1,470 1,470 COMPZ RPCOM RURD P Rig up to lay down setting tool. 06:00 07:30 1.50 1,470 1,470 COMPZ RPCOM OWFF P Monitor well for loss or flow. Fluid loss to formation = .5 bph. 07:30 08:00 0.50 1,470 1,470 COMPZ RPCOM PULD P Break and lay down setting tool. 08:00 12:00 4.00 1,470 0 COMPZ RPCOM PULD P PJSM =Lay down 43 jts. 2 7/8" tbg. & rig down equipment. Page 75 of 78 • Time Logs Date From: bud .. ®. •th - L nth Phased Code . ':'i\AIgtxiii4 T Comment : . 12:00 22:00 10.00 0 0 COMPZ WELCTI BOPE P Performing 2 week BOPE test. Test Annular preventer to 250 -3500 psi. Test all rams & valves 250 -5000 psi w/ annular to 3500 psi. Upper IBOP valve would not test. Repair bonnet leaks on 2 choke manifold valves and actuator valve on HCR. Witness of test was witnessed by AOGCC rep John Crisp. 22:00 00:00 2.00 0 0 COMPZ WELCTI RGRP T Change out upper IBOP valve on topdrive. 02/21/2009 Repair IBOP. Run 4.5" Completion. (Daily fluid loss 38 bbls. Total loss 3218 bbls.) 00:00 07:00 7.00 0 0 COMPZ WELCTI BOPE T Change out IBOP on topdrive & test same 250 -5000 psi. (Hole taking .8 bph) 07:00 09:30 2.50 0 0 COMPZ RPCOM RURD P Rig up to run 4.5" 12.6# tbg. 09:30 00:00 14.50 0 6,800 COMPZ RPCOM RCST P Run 4.5" 12.6# L -80 IBTM completion string to 6800' Up wt. 88k Dn 56k. 4 GLM,s. -PBR seal assembly -X nipple. 02/22/2009 Finish tbg run. Land & test same. Nipple down BOPE. 00:00 01:30 1.50 6,800 7,434 COMPZ RPCOM RCST P Finish running 4.5" 12.6# tbg. Tag SC -2 pkr at 7426' with total of 237 jts. Pressure annulus to 1500 psi for 5 min to verify seals. OK. Sheared PBR c(7, 45k over string wt. Pinned to _ shear @ 36k. Up wt 90k Dn 58k. 01:30 02:00 0.50 7,434 7,434 COMPZ RPCOM OTHR P Monitor well. Unload DE off boat. 02:00 03:30 1.50 7,434 7,434 COMPZ RPCOM CIRC P Circ. well surface to surface thru choke manifold. No gas on bottoms up. 03:30 05:00 1.50 7,434 7,434 COMPZ RPCOM CIRC P Mix & pump 139 bbls. inhibited 9.4 brine & chase w/ 110 bbls. Filtered 9.4 brine. 05:00 06:00 1.00 7,434 6,900 COMPZ RPCOM TRIP P Lay down 3 jts. 4.5" tbg. & pull 7 stands. 06:00 10:00 4.00 6,900 7,434 COMPZ RPCOM SSSV P MU BP -6i nipple. RU and attach control line. Test line to 5000 psi. PJSM =Run control line & tbg. in hole. Space out with pups. 10:00 12:00 2.00 7,434 7,434 COMPZ RPCOM THGR P PJSM. Make up hanger. Drain stack. Land hanger with tbg tail at 7437'. Test MTM hanger seals to 5000 psi. OK. 12:00 13:30 1.50 7,434 7,434 COMPZ RPCOM PRTS P Rig up & test downhole packer 3500, psi 30. mins. OK, 13:30 14:00 0.50 7,434 7,434 COMPZ RPCOM OTHR P Install BPV. 14:00 20:30 6.50 7,434 7,434 COMPZ RPCOM NUND P PJSM = Nipple down BOPE & all equipment related to BOPE. 20:30 00:00 3.50 7,434 7,434 COMPZ RPCOM NUND P Install master valve and test bonnet flange to 5000 psi 10 mins.. Set actuator valve and 4 way block w/ wing valve. Page 76of Loge �e From To . Dur: S. Depth E. Depth Phaniwode Subcde T Comment 02/23/2009 24 hr Summary Nipple up tree. Test same. Slick line work. (Total fluid loss to well 3218 bbls.) 00:00 03:30 3.50 7,434 7,434 COMPZ RPCOM NUND P Finish nipple up tree assembly. 03:30 04:00 0.50 7,434 7,434 COMPZ RPCOM PRTS P Test tree to 5000 psi OK. Pull BPV. 04:00 06:00 2.00 7,434 7,434 COMPZ RPCOM OTHR P Clean well head room & install rotary table. 06:00 11:30 5.50 7,434 7,434 COMPZ RPCOM OTHR P Clean & clear rig floor. Prepare for rigging up Pollard wire line. Rig Maintenance. 11:30 15:00 3.50 7,434 7,434 COMPZ RPCOM RURD P Rig up Pollard wireline lubricator & unit. Test lubricator. 15:00 18:00 3.00 7,434 7,434 COMPZ RPCOM SLKL P Open well SIWHP -100 psi. Pull dummy SSSV from 470' WLM. Set slip stop at 4470' WLM. 18:00 00:00 6.00 7,434 7,434 COMPZ RPCOM SLKL P RIH with kick over tool and find fluid level at 2000'. Pull back into lubricator with KOT. Gradually fill well with fluid. Pump and let as migrate. 02/24/2009 Retreive dunny valves # 1,2,3 & 4. Set valves 2,3 &4. Retreive catcher sub then set SSSV. SSSV would not hold pressure. Keep changing out SSSV until it held 4000 PSI. Rig down pollard wire line unit. 00:00 05:00 5.00 7,434 7,434 COMPZ RPCOM SLKL T Attempt to sit down and latch dummy GLV. No luck. POH. Tool sheared. Repin and RIH with same. Locate on GLM #4 is difficult. Pressure up well to 400 psi to ensure equalized across dummy. Unable to latch. POH. Tool not sheared. Repin with steel and rerun. Unable to locate. POH. Change out pulling tools and rerun. Still not able to get good locate on dummy #4. Pull up hole and locate and pull dummy #3 at 3620 MD . Good indication with IAP rising to 200 psi. OOH. 05:00 06:00 1.00 7,434 7,434 COMPZ RPCOM SLKL P Repin pulling tool and RIH for GL dummy in station #2, 2709 MD. SIWHP -50 psi. 06:00 07:00 1.00 7,434 7,434 COMPZ RPCOM SLKL P Retrieve dummy valve from station #1 07:00 08:00 1.00 7,434 7,434 COMPZ RPCOM SLKL P Install live valve in station #1 MD -1510 (TVD 1487') TRO -805 psi 3/16" port. 08:00 09:00 1.00 7,434 7,434 COMPZ RPCOM SLKL P Retrieve dummy valve from station #4 09:00 10:00 1.00 7,434 7,434 COMPZ RPCOM SLKL P Install live valve in station #2- 2702 MD (TVD 2346') TRO -793 psi. 3/16" port 10:00 11:00 1.00 7,434 7,434 COMPZ RPCOM SLKL P Install live valve in station #3 at 3614' MD (TVD 2900') TRO -772 psi. 3/16" port 11:00 11:30 0.50 7,434 7,434 COMPZ RPCOM SLKL P Install orifice valve in station #4 at 4265' MD (TVD 3290'). 3/8" orifice. SIWHP -0. 11:30 13:00 1.50 7,434 COMPZ RPCOM SLKL P RIH with pulling tool to 4470n WLMD. Latch and pull slip stop. Page 77of78 1111 • — Logy Tale Frnrn To' Dar S pth E Ph Gods Subcode T Gommera`` 13:00 20:00 7.00 COMPZ RPCOM SLKL P MU and RIH with SSSV. Puge control line with hydraulic fluid. Set SSSV. Unable to pressure up on control line and get a test. PO Rerun with valve. Rearrange packing. Rerun with same results. Modify packing stack and rerun. Good pressure test to 4000 psi. OOH with setting tool. Close all tree valves. Left control line pressured to to panel to allow operator to monitor. SIWHP -0 20:00 22:00 2.00 COMPZ RPCOM SLKL P Rig down Pollard slick line unit and lubricator. Released rig at 22:00 hrs 2 -24 -09 Page 78 of 78 • ConocoPhillips(Alaska) Inc. North Cook Inlet Unit North Cook Inlet Unit NCIU A -16 Permit to Drill: 208 -098 API: 50- 883- 201 -27 -00 Sperry Drilling Services Definitive Survey Report 21 October, 2008 HALLIBURTON . _ Sperry Drilling Services • 0 ConocoPhillips or its affiliates Definitive Survey Report Company ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well NCIU A -16 Project: North Cook Inlet Unit TVD Reference: NCIU A -16 @ 120.58ft (Kuukpik 5) • Site: North Cook Inlet Unit MD Reference: NCIU A -16 @ 120.58ft (Kuukpik 5) Weil: NCIU A -16 North Reference: True Welibore : ' NCIU A-16 Survey Caicutatkrn Method: Minimum Curvature Design: NCIU A -16 Database: EDM Alaska Prod v16 Project" North Cook Inlet Unit Map System: US State Plane 1927 (Exact solution) System Datum: MLLW Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well NCIU A -16 Well Position +N /-S 0.00 ft Northing: 2,586,675.42 ft • Latitude: 61° 4' 35.846 N +E/ -W 0.00 ft Easting: 332,034.57 ft • Longitude: 150° 56' 54.802 W Position Uncertainty 0.00 ft Wellhead Elevation: 71.90 ft Water Depth: 101.00ft • Vltelibore NCIU A 16 Magnetics Mo del Name Sample Date Declina lfpAngle F St BGGM2007 7/16/2008 19.07 73.90 55,657 BGGM2007 9/27/2008 19.01 73.90 55,659 Design NCIU A -16 Aud No Version: 1.0 Phase: ACTUAL Tie On Depth: 389.00 Vertical Section: Depth Fro (T1/C►) + Nfw + St ] W Direc ( ft) (ft) (ft) £ ° J. 221.58 0.00 0.00 307.12 Survey . Program D ate From To (ft) (ft) Survey (Wet#borej Too Name Descr Survey Date 389.00 389.00 NCIU A -16PB1 Gyro (NCIU A- 16PB1) GYD -GC -SS Gyrodata gyro single shots 7/19/2008 t 446.00 1,581.00 NCIU A -16 Gyro (NCIU A -16) GYD -GC -SS Gyrodata gyro single shots 7/25/2008 1: 1,626.86 9,242.31 NCIU A -16 MWD +SCC +SAG (NCIU A -1 MWD +SCC +SAG MWD + Short Collar correction + BHA SAG Co 7/28/2008 t Survey Map Map Vertiat MD " : , Inc Pat TVD TVDSS +N1 +EF-W No rthing Easting DLS Section (ft) "£ °) £°) £ft) ! £#t) (ft) (ft) (ft) (ft) ( (ft ssrrvey as Name 221 0. 0 221.58 10 0 .00 0.00 2,586,675.42 332,034.57 0.00 0.00 UNDEFINED 389.00 0.46 47.08 389.00 268.42 0.72 0.50 2,586,676.13 332,035.08 0.21 0.04 GYD -GC -SS (1) 446.00 2.15 353.06 445.98 325.40 1.94 0.53 2,586,677.35 332,035.14 3.37 0.74 GYD -GC -SS (2) 508.00 4.60 319.81 507.87 387.29 5.00 -1.21 2,586,680.43 332,033.43 4.90 3.98 GYD -GC -SS (2) 569.00 6.27 304.70 568.60 448.02 8.76 -5.53 2,586,684.26 332,029.17 3.58 9.70 GYD -GC -SS (2) 630.00 7.09 297.04 629.19 508.61 12.37 -11.62 2,586,687.96 332,023.13 1.98 16.73 GYD -GC -SS (2) 690.00 7.34 296.66 688.71 568.13 15.77 -18.34 2,586,691.46 332,016.46 0.42 24.15 GYD -GC -SS (2) 752.00 7.00 292.19 750.23 629.65 18.98 -25.38 2,586,694.76 332,009.47 1.05 31.69 GYD -GC -SS (2) 815.00 7.70 272.97 812.72 692.14 20.65 -33.15 2,586,696.54 332,001.73 4.04 38.89 GYD -GC -SS (2) 880.00 6.48 236.94 877.25 756.67 18.87 -40.58 2,586,694.87 331,994.27 6.96 43.75 GYD -GC -SS (2) 943.00 6.30 206.16 939.88 819.30 13.83 -45.08 2,586,689.90 331,989.70 5.38 44.29 GYD -GC -SS (2) 10/21/2008 2 :39 :03PM Page 2 COMPASS 2003.16 Build 42F • • ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well NCIU A -16 Project: North Cook Inlet Unit TVD Reference: NCIU A -16 @ 120.58ft (Kuukpik 5) Site: North Cook Inlet Unit MD Reference` NCIU A -16 @ 120.58ft ( Kuukpik 5) Well; NCIU A -16 North Reference: True W NCIU A -16 Survey Calculation Method: Minimum Curvature Design: ` NCIU A - Database: EDM Alaska Prod v16 Surrrey Map Ma Vertical M D Inc AZi TYD TV DSS +N1 -S +EI W Northing Irastin DL Section (ft) r) r (f (ft) (ft) (ft) (ft) (ft) (°`1041 (ft ) Survey Tool Name 3,532.71 54.20 312.13 2,851.94 2,731.36 927.04 -1,327.69 2,587,621.53 330,720.54 0.24 1,618.13 MWD +SCC +SAG (3) 3,595.16 54.10 311.62 2,888.51 2,767.93 960.82 - 1,365.38 2,587,655.86 330,683.35 0.68 1,668.57 MWD +SCC +SAG (3) 3,658.41 54.11 311.44 2,925.60 2,805.02 994.80 - 1,403.74 2,587,690.38 330,645.49 0.23 1,719.66 MWD +SCC +SAG (3) 3,721.21 53.70 311.41 2,962.60 2,842.02 1,028.37 - 1,441.79 2,587,724.50 330,607.93 0.65 1,770.26 MWD +SCC +SAG (3) 3,786.61 53.62 311.59 3,001.35 2,880.77 1,063.28 - 1,481.25 2,587,759.98 330,568.99 0.25 1,822.78 MWD +SCC +SAG (3) 3,849.81 53.35 311.65 3,038.96 2,918.38 1,097.01 - 1,519.22 2,587,794.26 330,531.51 0.43 1,873.42 MWD +SCC +SAG (3) 3,913.31 52.85 311.85 3,077.08 2,956.50 1,130.83 - 1,557.10 2,587,828.61 330,494.12 0.83 1,924.04 MWD +SCC +SAG (3) 3,976.11 52.81 311.31 3,115.03 2,994.45 1,164.04 - 1,594.54 2,587,862.36 330,457.18 0.69 1,973.93 MWD +SCC +SAG (3) 4,039.76 52.74 311.73 3,153.53 3,032.95 1,197.63 - 1,632.48 2,587,896.50 330,419.73 0.54 2,024.46 MWD +SCC +SAG (3) 4,103.91 52.62 311.30 3,192.42 3,071.84 1,231.45 - 1,670.68 2,587,930.86 330,382.02 0.56 2,075.32 MWD +SCC +SAG (3) 4,167.91 52.61 311.37 3,231.28 3,110.70 1,265.03 - 1,708.87 2,587,965.00 330,344.33 0.09 2,126.04 MWD +SCC +SAG (3) 4,230.31 52.43 311.81 3,269.25 3,148.67 1,297.90 - 1,745.90 2,587,998.40 330,307.78 0.63 2,175.41 MWD +SCC +SAG (3) 4,287.71 52.55 311.75 3,304.20 3,183.62 1,328.24 - 1,779.86 2,588,029.22 330,274.27 0.22 2,220.79 MWD +SCC +SAG (3) 4,354.26 51.88 312.26 3,344.98 3,224.40 1,363.44 - 1,818.94 2,588,064.98 330,235.70 1.17 2,273.19 MWD +SCC +SAG (3) 4,421.26 51.85 312.39 3,386.35 3,265.77 1,398.92 - 1,857.90 2,588,101.02 330,197.26 0.16 2,325.67 MWD +SCC +SAG (3) 4,483.11 51.75 312.37 3,424.60 3,304.02 1,431.68 - 1,893.81 2,588,134.30 330,161.84 0.16 2,374.07 MWD +SCC +SAG (3) 4,498.11 51.78 312.52 3,433.88 3,313.30 1,439.64 - 1,902.50 2,588,142.37 330,153.26 0.81 2,385.80 MWD +SCC +SAG (3) 4,549.98 51.77 312.32 3,465.98 3,345.40 1,467.12 - 1,932.58 2,588,170.29 330,123.58 0.30 2,426.38 MWD +SCC +SAG (3) 4,613.33 53.01 309.85 3,504.64 3,384.06 1,500.09 - 1,970.40 2,588,203.80 330,086.25 3.65 2,476.43 MWD +SCC +SAG (3) 4,675.88 53.52 308.92 3,542.06 3,421.48 1,531.90 - 2,009.15 2,588,236.17 330,047.97 1.46 2,526.52 MWD +SCC +SAG (3) 4,738.83 53.20 308.97 3,579.62 3,459.04 1,563.65 - 2,048.44 2,588,268.48 330,009.15 0.51 2,577.01 MWD +SCC +SAG (3) 4,801.78 53.86 307.89 3,617.04 3,496.46 1,595.11 - 2,088.09 2,588,300.51 329,969.96 1.72 2,627.62 MWD +SCC +SAG (3) 4,865.58 53.74 307.81 3,654.72 3,534.14 1,626.71 - 2,128.74 2,588,332.69 329,929.77 0.21 2,679.10 MWD +SCC +SAG (3) 4,930.73 53.66 308.14 3,693.29 3,572.71 1,659.02 - 2,170.13 2,588,365.59 329,888.86 0.43 2,731.60 MWD +SCC +SAG (3) 4,994.43 53.34 308.12 3,731.18 3,610.60 1,690.63 - 2,210.41 2,588,397.79 329,849.05 0.49 2,782.79 MWD +SCC +SAG (3) 5,057.98 53.12 308.38 3,769.22 3,648.64 1,722.15 - 2,250.39 2,588,429.88 329,809.53 0.48 2,833.69 MWD +SCC +SAG (3) 5,122.78 53.81 306.85 3,807.80 3,687.22 1,753.92 - 2,291.63 2,588,462.24 329,768.75 2.18 2,885.75 MWD +SCC +SAG (3) 5,186.63 53.33 306.76 3,845.71 3,725.13 1,784.70 - 2,332.77 2,588,493.61 329,728.07 0.77 2,937.12 MWD +SCC +SAG (3) 5,249.68 53.24 306.78 3,883.41 3,762.83 1,814.95 - 2,373.25 2,588,524.44 329,688.03 0.14 2,987.66 MWD +SCC +SAG (3) 5,311.78 53.13 305.95 3,920.62 3,800.04 1,844.42 - 2,413.28 2,588,554.49 329,648.43 1.08 3,037.37 MWD +SCC +SAG (3) 5,376.58 52.80 306.58 3,959.65 3,839.07 1,875.02 - 2,454.99 2,588,585.69 329,607.17 0.93 3,089.10 MWD +SCC +SAG (3) 5,437.68 52.55 306.22 3,996.69 3,876.11 1,903.86 - 2,494.10 2,588,615.09 329,568.49 0.63 3,137.68 MWD +SCC +SAG (3) 5,530.10 50.53 307.50 4,054.18 3,933.60 1,947.25 - 2,552.01 2,588,659.31 329,511.22 2.44 3,210.04 MWD +SCC +SAG (3) 5,593.40 49.55 307.37 4,094.83 3,974.25 1,976.74 - 2,590.53 2,588,689.36 329,473.13 1.56 3,258.56 MWD +SCC +SAG (3) 5,657.90 48.53 305.71 4,137.12 4,016.54 2,005.75 - 2,629.66 2,588,718.92 329,434.43 2.50 3,307.26 MWD +SCC +SAG (3) 5,720.15 46.68 307.39 4,179.09 4,058.51 2,033.12 - 2,666.59 2,588,746.82 329,397.90 3.57 3,353.22 MWD +SCC +SAG (3) 5,784.20 44.78 308.94 4,223.79 4,103.21 2,061.45 - 2,702.65 2,588,775.67 329,362.26 3.43 3,399.08 MWD +SCC +SAG (3) 5,847.00 42.45 309.58 4,269.26 4,148.68 2,088.86 - 2,736.19 2,588,803.56 329,329.12 3.79 3,442.36 MWD +SCC +SAG (3) 5,910.75 39.19 310.71 4,317.50 4,196.92 2,115.71 - 2,768.05 2,588,830.87 329,297.66 5.24 3,483.97 MWD +SCC +SAG (3) 5,973.40 35.72 310.63 4,367.23 4,246.65 2,140.53 - 2,796.94 2,588,856.11 329,269.13 5.54 3,521.99 MWD +SCC +SAG (3) 10/21/2008 2 :39 :03PM Page 4 COMPASS 2003.16 Build 42F • • ConocoPhillips or its affiliates Definitive Survey Report Comp ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well NCIU A -16 Project North Cook Inlet Unit TVd Reference: NCIU A -16 @ 120.58ft (Kuukpik 5) Sh North Cook Inlet Unit MD Reference: NCIU A -16 @ 120.58ft (Kuukpik 5) W ell: NCIU A -16 North Reference :. True lfiteilbore: NCIU A -16 Survey Calculation Method: Minimum Curvature Design: NCIU A -16 Database: EDM Alaska Prod v16 Survey Map M a u r Vrtical e Mt3 Inc Azi TVf TV OSS +N /-S * lat - N orthing Easting DLS section , (ft) ` )" (°) (ft) ' (ft) (ft) (ft) (ft) (ft) f°/100 (f Survey Tool Name 6,038.40 33.37 311.01 4,420.76 4,300.18 2,164.62 - 2,824.84 2,588,880.60 329,241.59 3.62 3,558.77 MWD +SCC +SAG (3) 6,102.70 31.10 310.37 4,475.14 4,354.56 2,186.99 - 2,850.84 2,588,903.34 329,215.92 3.57 3,593.00 MWD +SCC +SAG (3) 6,166.05 27.83 307.02 4,530.30 4,409.72 2,206.50 - 2,875.12 2,588,923.20 329,191.92 5.79 3,624.13 MWD +SCC +SAG (3) 6,229.10 24.63 306.77 4,586.85 4,466.27 2,223.23 - 2,897.40 2,588,940.25 329,169.89 5.08 3,651.99 MWD +SCC +SAG (3) 6,291.30 22.87 309.64 4,643.78 4,523.20 2,238.70 - 2,917.09 2,588,956.00 329,150.43 3.38 3,677.03 MWD +SCC +SAG (3) 6,355.75 20.82 310.68 4,703.60 4,583.02 2,254.16 - 2,935.42 2,588,971.73 329,132.32 3.24 3,700.98 MWD +SCC +SAG (3) 6,419.10 19.48 311.63 4,763.07 4,642.49 2,268.52 - 2,951.86 2,588,986.32 329,116.09 2.18 3,722.75 MWD +SCC +SAG (3) 6,483.30 17.93 311.33 4,823.87 4,703.29 2,282.16 - 2,967.28 2,589,000.18 329,100.87 2.42 3,743.28 MWD +SCC +SAG (3) 6,544.05 17.43 308.14 4,881.76 4,761.18 2,293.95 - 2,981.46 2,589,012.18 329,086.87 1.80 3,761.70 MWD +SCC +SAG (3) 6,608.25 16.18 305.90 4,943.21 4,822.63 2,305.14 - 2,996.27 2,589,023.57 329,072.23 2.19 3,780.26 MWD +SCC +SAG (3) 6,672.45 15.39 305.50 5,004.99 4,884.41 2,315.33 - 3,010.45 2,589,033.97 329,058.19 1.23 3,797.72 MWD +SCC +SAG (3) 6,736.60 14.53 305.55 5,066.97 4,946.39 2,324.95 - 3,023.93 2,589,043.79 329,044.85 1.34 3,814.28 MWD +SCC +SAG (3) 6,800.15 13.82 308.11 5,128.58 5,008.00 2,334.27 - 3,036.39 2,589,053.29 329,032.53 1.50 3,829.84 MWD +SCC +SAG (3) 6,864.05 13.19 306.44 5,190.72 5,070.14 2,343.31 - 3,048.26 2,589,062.50 329,020.80 1.16 3,844.75 MWD +SCC +SAG (3) 6,928.50 11.32 307.02 5,253.69 5,133.11 2,351.49 - 3,059.22 2,589,070.83 329,009.95 2.90 3,858.43 MWD +SCC +SAG (3) 6,991.25 9.02 309.79 5,315.46 5,194.88 2,358.35 - 3,067.92 2,589,077.81 329,001.36 3.74 3,869.50 MWD +SCC +SAG (3) 7,050.35 7.94 308.12 5,373.91 5,253.33 2,363.83 - 3,074.69 2,589,083.40 328,994.66 1.88 3,878.22 MWD +SCC +SAG (3) 7,114.70 6.90 307.53 5,437.72 5,317.14 2,368.93 - 3,081.26 2,589,088.59 328,988.17 1.62 3,886.53 MWD +SCC +SAG (3) 7,181.05 6.36 307.70 5,503.62 5,383.04 2,373.61 - 3,087.33 2,589,093.35 328,982.17 0.82 3,894.19 MWD +SCC +SAG (3) 7,242.61 6.13 307.71 5,564.82 5,444.24 2,377.70 - 3,092.62 2,589,097.52 328,976.94 0.37 3,900.88 MWD +SCC +SAG (3) 7,305.26 5.29 307.65 5,627.16 5,506.58 2,381.51 - 3,097.56 2,589,101.40 328,972.06 1.34 3,907.12 MWD +SCC +SAG (3) 7,368.31 4.79 307.05 5,689.96 5,569.38 2,384.87 - 3,101.96 2,589,104.83 328,967.71 0.81 3,912.65 MWD +SCC +SAG (3) 7,433.46 4.66 307.97 5,754.89 5,634.31 2,388.14 - 3,106.21 2,589,108.15 328,963.50 0.23 3,918.02 MWD +SCC +SAG (3) 7,497.66 4.42 305.90 5,818.89 5,698.31 2,391.19 - 3,110.27 2,589,111.26 328,959.49 0.45 3,923.09 MWD +SCC +SAG (3) 7,561.11 4.23 306.92 5,882.16 5,761.58 2,394.03 - 3,114.12 2,589,114.16 328,955.68 0.32 3,927.88 MWD +SCC +SAG (3) 7,624.86 4.12 307.90 5,945.74 5,825.16 2,396.85 - 3,117.81 2,589,117.03 328,952.03 0.20 3,932.52 MWD +SCC +SAG (3) 7,687.76 4.09 306.84 6,008.48 5,887.90 2,399.59 - 3,121.39 2,589,119.82 328,948.49 0.13 3,937.03 MWD +SCC +SAG (3) 7,751.01 4.25 307.27 6,071.56 5,950.98 2,402.36 - 3,125.06 2,589,122.64 328,944.87 0.25 3,941.62 MWD +SCC +SAG (3) 7,815.06 4.19 305.97 6,135.44 6,014.86 2,405.17 - 3,128.84 2,589,125.51 328,941.13 0.17 3,946.33 MWD +SCC +SAG (3) 7,879.41 4.18 304.47 6,199.62 6,079.04 2,407.87 - 3,132.67 2,589,128.27 328,937.33 0.17 3,951.03 MWD +SCC +SAG (3) 7,942.21 4.05 303.55 6,262.26 6,141.68 2,410.39 - 3,136.41 2,589,130.84 328,933.63 0.23 3,955.53 MWD +SCC +SAG (3) 8,004.91 4.11 301.47 6,324.80 6,204.22 2,412.79 - 3,140.17 2,589,133.29 328,929.91 0.25 3,959.97 MWD +SCC +SAG (3) 8,068.66 4.52 300.67 6,388.37 6,267.79 2,415.26 - 3,144.28 2,589,135.83 328,925.84 0.65 3,964.74 MWD +SCC +SAG (3) 8,131.71 4.58 300.55 6,451.22 6,330.64 2,417.81 - 3,148.58 2,589,138.43 328,921.57 0.09 3,969.71 MWD +SCC +SAG (3) 8,196.81 4.29 299.16 6,516.12 6,395.54 2,420.32 - 3,152.94 2,589,141.00 328,917.24 0.46 3,974.70 MWD +SCC +SAG (3) 8,259.86 4.21 298.11 6,579.00 6,458.42 2,422.56 - 3,157.04 2,589,143.30 328,913.18 0.19 3,979.32 MWD +SCC +SAG (3) 8,321.66 4.16 296.05 6,640.63 6,520.05 2,424.61 - 3,161.06 2,589,145.41 328,909.19 0.25 3,983.76 MWD +SCC +SAG (3) 8,386.96 4.05 295.66 6,705.77 6,585.19 2,426.65 - 3,165.27 2,589,147.51 328,905.02 0.17 3,988.35 MWD +SCC +SAG (3) 8,449.71 4.00 292.65 6,768.36 6,647.78 2,428.45 - 3,169.29 2,589,149.37 328,901.02 0.35 3,992.64 MWD +SCC +SAG (3) 8,513.01 4.08 293.93 6,831.50 6,710.92 2,430.22 - 3,173.39 2,589,151.20 328,896.95 0.19 3,996.97 MWD +SCC +SAG (3) 10/21/2008 2:39 :03PM Page 5 COMPASS 2003.16 Build 42F • • ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPh Inc. Local Co- ordinate Reference: : Well NCIU A -16 Project North Cook Inlet Unit TVD Reference: NCIU A -16 @ 120.58ft (Kuukpik 5) Site: North Cook Inlet Unit MD Reference: NCIU A -16 @ 120.58ft (Kuukpik 5) Weil. NCIU A -16 North Reference; True Yfteltbore: NCIU A -16 Survey Calculation Method: Minimum Curvature Design: NCIU A -16 Database: EDM Alaska Prod v16 Survey Map Ma Vertical MD Inc AAzi- ND TVDSS +Nth +E1 -W Northing Fasting DLS Section (ft) t ( °) (D) (ft) (ft) (ft) (ft) (ft) (‘11 0 0•1 (ft) Survey Tool Name 8,576.31 4.06 291.71 6,894.64 6,774.06 2,431.96 - 3,177.53 2,589,153.00 328,892.84 0.25 4,001.33 MWD +SCC +SAG (3) 8,640.16 4.07 289.62 6,958.33 6,837.75 2,433.56 - 3,181.76 2,589,154.66 328,888.62 0.23 4,005.67 MWD +SCC +SAG (3) 8,702.71 4.06 288.25 7,020.73 6,900.15 2,434.99 - 3,185.95 2,589,156.16 328,884.45 0.16 4,009.88 MWD +SCC +SAG (3) 8,767.26 3.82 286.08 7,085.12 6,964.54 2,436.31 - 3,190.19 2,589,157.53 328,880.24 0.43 4,014.05 MWD +SCC +SAG (3) 8,831.01 3.84 286.61 7,148.73 7,028.15 2,437.50 - 3,194.27 2,589,158.79 328,876.17 0.06 4,018.02 MWD +SCC +SAG (3) 8,895.26 3.78 285.63 7,212.84 7,092.26 2,438.69 - 3,198.37 2,589,160.03 328,872.09 0.13 4,022.01 MWD +SCC +SAG (3) 8,957.01 3.70 284.37 7,274.46 7,153.88 2,439.73 - 3202.26 2,589,161.13 328,868.21 0.19 4,025.74 MWD +SCC +SAG (3) 9,019.96 3.76 284.61 7,337.27 7,216.69 2,440.76 - 3,206.23 2,589,162.21 328,864.26 0.10 4,029.53 MWD +SCC +SAG (3) 9,083.31 3.60 283.91 7,400.49 7,279.91 2,441.76 - 3,210.17 2,589,163.27 328,860.33 0.27 4,033.28 MWD +SCC +SAG (3) 9,146.86 3.50 283.37 7,463.92 7,343.34 2,442.69 - 3,214.00 2,589,164.25 328,856.53 0.16 4,036.88 MWD +SCC +SAG (3) 9,209.56 3.38 280.64 7,526.51 7,405.93 2,443.47 - 3,217.67 2,589,165.09 328,852.86 0.32 4,040.29 MWD +SCC +SAG (3) 9,242.31 3.40 283.49 7,559.20 7,438.62 2,443.88 - 3,219.57 2,589,165.52 328,850.97 0.52 4,042.04 MWD +SCC +SAG (3) 9,314.00 3.40 283.49 7,630.77 .7,510.19 2,444.87 - 3,223.70. 2,589,166.57 • 328,846.86 0.00 4,045.93 PROJECTED to TD 10/21/2008 2:39:03PM Page 6 COMPASS 2003.16 Build 42F • 0 s fil g a h i ConocoPhillips(Alaska) Inc. North Cook Inlet Unit North Cook Inlet Unit NCIU A -16PB1 50 -883- 20127 -70 Sperry Drilling Services Definitive Survey Report i - ' 31 July, 2008 ' : k 1 I 4 k 1 I 1111 ti HALLIBURTON : ,- : -,3 1 Sperry Drilling Services • ConocoPhillips or its affiliates Definitive Survey Report p y ConocoPhillips(Alaska) Inc. Local Co-d f, `" R rend W ell NCIU A -16 a . ; North Cook Inlet Unit iVD Refe NCIU A -16 @ 120.58ft (Kuukpik 5) Bite: North Cook Inlet Unit Mi * ierenCe7 F NCIU A -16 © 120.58ft ( Kuukpik 5) Nnr� True NCIU A -16 Welltx>rs NCIU A - 16PB1 utation echo M Curvature 1kgf' NCIU A 16PB1 Database `, `' EDM Alaska Prod v16 5urvey'� �� , e �! j�ya;'' � Map VO e t J i�YZt d® E �' �� d +E! -W No in 3 S E ( {ft} � Y #1 1 Narr[e • 913.00 4.09 279.53 912.77 792.19 8.40 -6.87 2,586,683.92 332,027.82 1.98 9.69 GYD -GC -SS (1) 976.00 5.13 274.60 975.56 854.98 9.00 -11.90 2,586,684.59 332,022.81 1.77 14.52 GYD -GC -SS (1) 1,010.00 6.55 272.31 1,009.38 888.80 9.20 -15.35 2,586,684.84 332,019.36 4.23 17.76 GYD -GC -SS (1) 1,073.00 10.84 259.95 1,071.65 951.07 8.31 -24.78 2,586,684.09 332,009.92 7.39 26.02 GYD -GC -SS (1) 1,120.00 14.00 250.00 1,117.55 996.97 5.60 -34.48 2,586,681.51 332,000.19 8.10 33.78 GYD - GC - SS (1) 7/31/2008 12 :42:23PM Page 3 COMPASS 2003.16 Build 42F • • N ConocoPhillips(Alaska) Inc. North Cook Inlet Unit North Cook Inlet Unit NCIU A -16PB2 50 -883- 20127 -71 i t Sperry Drilling Services Definitive Survey Report 31 July, 2008 3 1 I HALLIBURTON 3 Ill 1 Sperry Drilling Services • 0 ConocoPhillips or its affiliates Definitive Survey Report compan 1 ConocoPhillips(Alaska) Inc. Local C©- ordinate Refer Itce Well NCIU A -16 PrOject North Cook Inlet Unit TVD Reference: NCIU A -16 @ 120.58ft (Kuukpik 5) 'ilia North Cook Inlet Unit Mt) Reference: :; NCIU A -16 @ 120.58ft (Kuukpik 5) Weil NCIU A - Nortft i tllerence True Well NCIU A 51r Gam If� Me�rot � E Minimum Curvature Das E NCIU A 16PB2 ''� ' Alaska Prod v16 Sur+ : ' I.4h: uE '.., Map R V IC ;af E e Inc AA TVD I VD S +N].$ Etaili 881.00 3.52 283.68 880.84 760.26 7.98 -4.79 2,586,683.47 332,029.90 3.31 7.62 GYD -GC -SS (1) 913.00 4.09 279.53 912.77 792.19 8.40 -6.87 2,586,683.92 332,027.82 1.98 9.69 GYD -GC -SS (1) 976.00 5.13 274.60 975.56 854.98 9.00 -11.90 2,586,684.59 332,022.81 1.77 14.52 GYD -GC -SS (1) 1,010.00 6.55 272.31 1,009.38 888.80 9.20 -15.35 2,586,684.84 332,019.36 4.23 17.76 GYD -GC -SS (1) 1,045.00 8.89 263.98 1,044.07 923.49 9.00 -20.03 2,586,684.71 332,014.67 7.39 21.96 GYD -GC -SS (2) 1,071.00 6.37 278.49 1,069.84 949.26 9.00 -23.46 2,586,684.76 332,011.25 12.13 25.09 GYD -GC -SS (2) 1,168.00 6.37 278.49 1,166.24 1,045.66 10.59 -34.10 2,586,686.50 332,000.63 0.00 35.47 PROJECTED to TD 7/31/2008 12.44:11PM Page 3 COMPASS 2003.16 Build 42F i Page 1 of 1 • Maunder, Thomas E (DOA) From: Hayden, Philip [Philip .Hayden ©conocophillips.com] Sent: Monday, April 06, 2009 11:14 AM To: Maunder, Thomas E (DOA); Braden, John C Cc: Regg, James B (DOA) Subject: RE: Inlet Operations Tom, We have had to stop operations only intermittently since the volcano first erupted. Looking at our daily reports we have recorded just -20 hours of down time due to this. The biggest impact so far has been the limited number of helicopter flights. However, we are able to manage our personnel transfers via our supply boat MN Champion. Regards Philip From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, April 06, 2009 11:03 AM To: Braden, John C; Hayden, Philip Cc: Regg, James B (DOA) Subject: Inlet Operations John and Philip, Could you please provide information of how Mt. Redoubt's activity is or is not affecting CPAI's production and drilling operations on Tyonek Platform? Thanks in advance. Tom Maunder, PE AOGCC 4/22/2009 • Page 1 of 1 Maunder, Thomas E (DOA) From: Braden, John C [ John .C.Braden @conocophillips.com] Sent: Monday, April 06, 2009 11:13 AM To: Maunder, Thomas E (DOA); Hayden, Philip; Tyonek Supervisor Cc: Regg, James B (DOA) Subject: RE: Inlet Operations Philip can weigh in as well. It is mostly affecting helicopter traffic, delaying crew changes. Barge traffic has slowed a bit. We are making some crew changes by boat. John Braden From: Maunder, Thomas E (DOA) [mailto :tom.maunder @alaska.gov] Sent: Monday, April 06, 2009 11:03 AM To: Braden, John C; Hayden, Philip Cc: Regg, James B (DOA) Subject: Inlet Operations John and Philip, Could you please provide information of how Mt. Redoubt's activity is or is not affecting CPAI's production and drilling operations on Tyonek Platform? Thanks in advance. Tom Maunder, PE AOGCC 4/22/2009 NCIU A -16 (PTD 208 -098) Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, April 02, 2009 11:23 AM To: Braden, John C Cc: Allsup- Drake, Sharon K; Tyonek Supervisor; Chambers, Mark A Subject: RE: NCIU A -16 (PTD 208 -098) John, et al, Submitting the report now and following up with the production test information once the well is capable of production is acceptable. I will place a copy of this message in the well file. Call or message with any questions. Tom Maunder, PE AOGCC From: Braden, John C [mailto:John.C.Braden @conocophillips.com] Sent: Thursday, April 02, 2009 11:09 AM To: Maunder, Thomas E (DOA) Cc: Allsup- Drake, Sharon K; Tyonek Supervisor; Chambers, Mark A Subject: NCIU A -16 (PTD 208 -098) Dear Tom - North Cook Inlet Unit well A -16 (PTD 208 -098, API 50- 883 - 20127 -00) was completed on 2/24/09 with a gravel pack in the lower Beluga zone. We are having trouble unloading the well. It will require remedial operations, most likely a CTU nitrogen lift. However, the rig is over the well leg, blocking access to the tree. This precludes us from getting a representative well test for the completion report. We would like to delay the initial test until July 2009, after we have a chance to work on the well. With your approval, we will submit the completion report now and delay the well test until July 09. I look forward to your reply, Sincerely, John Braden 4/22/2009 Tyonek platform activity Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, March 23, 2009 10:56 AM To: Hayden, Philip Subject: RE: Tyonek platform activity Thanks much Philip. From: Hayden, Philip [mailto:Philip .Hayden ©conocophillips.com] Sent: Monday, March 23, 2009 10:55 AM To: Maunder, Thomas E (DOA) Subject: Tyonek platform activity Tom, Currently we are running completion operations on well A -15. We finished TCP ops over the weekend and today should be PU the clean out assembly prior to running gravel pack screens. We finished operations on A -16 on 2/24/09. We should be moving onto A -14 at the end of the month. No impact from Mt Redoubt just yet apart from some delayed flights from Anchorage & potential helicopter flight restrictions. Regards Philip V" cpv t+� 4/22/2009 RECLivp.-p- PI, • •••-•, ••,-- 02/20/09 FED ma* 011 rA cios cm. f 4 sail ‘iii'l,'! Andnar NO. 5094 Schlumberger -DCS 2525 Gambell Street, Suite 400 0/...g-------- Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: North Cook inlet • Well Job # Log Description Date BL Color CD NCIU A-16 AXML-00015 PERFORATING RECORD 01/25109 1 NCIU A-16 AXML-00017 TCP CORRELATION S 02/10/09 1 NCIU A-16 AV1P-00014 PLUG RECORD 12126/08 1 e9Ofs - r'n t 11 110 _ - -- '''Iri return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Closed well operation A -16 2 -1-09 0500 HRS • Page 1 of 2 Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Tuesday, February 17, 2009 11 :44 AM To: Maunder, Thomas E (DOA) Subject: FW: Closed well operation A -16 2 -17 -09 0500 HRS � v looks like every one (some more than once) were notified except you. Chuck mentioned this in our call this morning; more detail included below. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Kuukpik 5 Company man [ mailto :KUUK5CM @ConocoPhillips.com] Sent: Tuesday, February 17, 2009 10:21 AM To: aogcc_prudhoe _bay @admin.state.ak.us; Alvord, Chip; Chambers, Mark A; Hayden, Philip; Jasser, Rami ; Regg, James B (DOA); Eggemeyer, Jerome C.; Zhou, Leon; DOA AOGCC Prudhoe Bay; Fleckenstein, Robert J (DOA); Larry Ross; Tyonek Supervisor; Kuukpik 5 Tool Pusher Subject: Closed well operation A -16 2 -17 -09 0500 HRS Gents, On NCIU - A16 this morning, we shut in on the well. The situation is as follows: We had 9.2 PPG brine in the hole. We had run all of the 4" gravel pack assembly, including the inner wash pipe. approximately 1400'. During the run, we had the first stand of DP in the derrick made up with a safety valve in the closed position, for any well control issues. After the packer was made up, we picked up and ran the first stand of DP. When at the floor, the valve was quickly opened and we observed flow through the DP. A quick look in the annulus, proved fluid bubbling, not boiling, but flow was observed with approximately 2 BBL gain in the trip tank. The annular was shut in and system closed. After 1.5 HRS, observed casing pressure at 90 PSI. The DP showed the same because the only port to communicate was only 90' in the hole. The pressure stabilized at 90 PSI. We discussed the situation, and decided to rig up and circulate through the port on the packer assembly, and then through the choke manifold, gas buster and to the shakers. We were able to circulate at 1.5 BPM -120 PSI. Observed a 10% LEL reading at the shakers, with a half open choke, and then diminished to only 4 %. After 20 BBLS pumped, we bled pressures to zero, and opened the annular. We observed the same thing we had been seeing, with fluid bubbling, but falling in the stack. We observed this for 15 minutes. The decision to continue in the hole was made by me, as I had no indication that we need to strip into the hole. As we ran the DP and assembly we have observed .5 BBLS loss every 5 stands, indicating the hole is taking fluid. When movement of the string is stopped the fluid continues to bubble, and still drop in the stack very slowly. AOGCC was notified at 0830 HRS, and I spoke with Chuck Sheave. 2/18/2009 Closed well operation A -16 2 -1209 0500 HRS • Page 2 of 2 At this time we are tripping in the hole with the assembly with 9.2 PPG observing a fluid loss of .5 BBLS every 5 stands. Our pits are being weighted up to 9.4 PPG, to accommodate gas migration and we plan to continue with our gravel pack operations as planned. Thank you, Scott Heim 907- 776 -2350 2/18/2009 NCIU A -16, Permit to Drill #43-098, Update 1/9/09 • Page 1 of ; Maunder, Thomas E (DOA) From: Hayden, Philip [Philip .Hayden @conocophillips.com] Sent: Wednesday, January 21, 2009 5:39 PM To: Maunder, Thomas E (DOA) Cc: Chambers, Mark A Subject: RE: NCIU A -16, Permit to Drill # 208 -098, Update 1/9/09 Tom, It was decided this evening to resume completion operations on the Tyonek on NCIU A -16. The drilling supervisor has placed a call to the AOGCC inspector giving him the 24 hour notice of our intended BOP test. We hope to be up and running in a couple of days. Regards Philip From: nder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tues•.y, January 20, 2009 1:26 PM To: Hayden, • • ip Cc: Chambers, . k A Subject: RE: NCIU -16, Permit to Drill # 208 -098, Update 1/9/09 Philip, Thanks for calling. I had no . estions or comment regarding your message of January 9. However, due to the Monarch incident, I now have s• e. 1. When does it look like oper_ ions will be resuming on NCIU A -16 and the other wells? 2. If this is in the short term, I do ' believe that any sundry paperwork is needed. It had been stated in the plans that the wells would be "ba , ed" and that is what you have /are accomplishing, although the entire process has been delayed by the br. en Whitaker and now the Monarch. 3. If it looks like operations won't be resu -d until toward 2nd quarter, then some paperwork might need to be submitted. 4. For my info, could you summarize how the o.: ations were accomplished on the 3 wells? Thanks in advance. Call or message with any questio Tom Maunder, PE AOGCC From: Hayden, Philip [mailto:Philip .Hayden @conocophillips.com] Sent: Friday, January 09, 2009 9:16 AM To: Maunder, Thomas E (DOA) Subject: NCIU A -16, Perm' to Drill # 208 -098, Update 1/9/09 Tom, I wanted to • ing you up to speed with operations on the Tyonek. Due to the ice in the inlet - are unable to get supplies : equipment to the rig in order to continue with completion operations. We have deci• = • to "warm stack" the rig until next week when we will revisit the situation. The well status is as follows: 7" production casing set at 9301' MD, cemented & pressure tested to 4500 psi 1/22/2009 NCIU A -16, Permit to Drill # 24 098, Update 1/9/09 Page 1 of 2 Maunder, Thomas E (DOA) From: Hayden, Philip [Philip .Hayden @conocophillips.com] Sent: Wednesday, January 21, 2009 10:16 AM To: Maunder, Thomas E (DOA) Cc: Chambers, Mark A Subject: RE: NCIU A -16, Permit to Drill # 208 -098, Update 1/9/09 Attachments: Operations Summary 1- 21- 09.xls Tom, With reference to your note below: 1. At this time we are still looking at ice conditions & boat availability in the Inlet in order to determine the best path forward. We expect to have a decision made some time this week whether to proceed with completion operations or to suspend until later in the Spring. I will send you an update when we have that decision. 4. Please see the attached spreadsheet for a summary of operations so far on the Tyonek for all three wells. Please let me know if you need any more information Regards Philip From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, January 20, 2009 1:26 PM To: Hayden, Philip Cc: Chambers, Mark A Subject: RE: NCIU A -16, Permit to Drill # 208 -098, Update 1/9/09 Philip, Thanks for calling. I had no questions or comment regarding your message of January 9. However, due to the Monarch incident, I now have some. 1. When does it look like operations will be resuming on NCIU A -16 and the other wells? 2. If this is in the short term, I don't believe that any sundry paperwork is needed. It had been stated in the plans that the wells would be "batched" and that is what you have /are accomplishing, although the entire process has been delayed by the broken Whitaker and now the Monarch. 3. If it looks like operations won't be resumed until toward 2nd quarter, then some paperwork might need to be submitted. 4. For my info, could you summarize how the operations were accomplished on the 3 wells? Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC From: Hayden, Philip [mailto:Philip .Hayden @conocophillips.com] Sent: Friday, January 09, 2009 9:16 AM To: Maunder, Thomas E (DOA) Subject: NCIU A -16, Permit to Drill # 208 -098, Update 1/9/09 Tom, 1/22/2009 NCIU A -16, Permit to Drill # 4-098, Update 1/9/09 Page 2 of 2 I wanted to bring you up to speed with operations on the Tyonek. Due to the ice in the inlet we are unable to get supplies & equipment to the rig in order to continue with completion operations. We have decided to "warm stack" the rig until next week when we will revisit the situation. The well status is as follows: 7" production casing set at 9301' MD, cemented & pressure tested to 4500 psi 4 1/2" tubing string run to 8400' MD Casing displaced to 6% KCI brine @ 8.6 ppg Tubing hanger run, landed & tested BPV installed BOPs still installed If our "warm stack" period is extended we are not planning on any further BOP tests until we recommence operations. Our rationale is that the formations are currently isolated with two barriers - cemented & tested 7" casing and the tested tubing hanger /BPV - and that the BOPs are not required for well control at this time. Please let me know if you have any comments on this or need any further information. Regards Philip 1/22/2009 Hole Section (inc Batch Interval Time Drilling Depths (ft) Casing Mud Weight (ppg) Well Start End Start End Section TD Reached Size (in) )epth Set (f Date Set Start End �ti A -16 12 1/4 7/11/2008 8/2/2008 400 4546 7/29/2008 9 5/8 4535 8/1/2008 8.9 9.3 A -15 12 1/4 8/2/2008 8/14/2008 400 4303 8/10/2008 9 5/8 4291 8/13/2008 8.8 9.2 A -14 12 1/4 8/14/2008 8/29/2008 400 4756 8/22/2008 9 5/8 4747 8/25/2008 8.8 9.1 A -15 8 3/4 8/29/2008 9/27/2008 4303 8867 9/12/2008 7 8832 9/25/2008 9.15 10.1 ---tt ■ A -16 8 3/4 9/28/2008 10/30/2008 4546 9314 10/16/2008 7 9256 10/25/2008 9.35 9.4 A -14 8 3/4 10/31/2008 12/1/2008 4756 11501 11/13/2008 7 9978 11/26/2008 9.2 9.9 --tr A -16 Completions 12/1/2008 Ongoing • • Tyonek Progress 1/5/09 • Page 1 of 2 Maunder, Thomas E (DOA) From: Hayden, Philip [Philip .Hayden @conocophillips.com] Sent: Tuesday, January 06, 2009 9:50 AM To: Maunder, Thomas E (DOA) Subject: RE: Tyonek Progress 1/5/09 I believe the next BOP test is due on Monday, 1/12, but we may try and bring that forward so as not to clash with fracing operations. Yet to be decided though. Yes, you are correct. The work on A -16 was severely curtailed due to the damaged lifesphere. We did manage to pickle our DP, caustic wash the casing and displace to brine while waiting for the lifesphere to be replaced. But instead of hours each of these operations took days instead due to the reduced man count. The lifesphere was damaged on the night of Monday 12/15 and I can confirm that the new one was certified good for use yesterday, 1/5. Again, please let me know if you need any more info Philip From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, January 06, 2009 9:25 AM To: Hayden, Philip Subject: RE: Tyonek Progress 1/5/09 Philip, Thanks for the summary/update. I'd expect that there will be a BOP test coming as operations resume. I presume that the work on A -16 was interrupted by the damage to the life sphere? When was the sphere damaged? Tom From: Hayden, Philip [mailto:Philip .Hayden @conocophillips.com] Sent: Tuesday, January 06, 2009 9:18 AM To: Maunder, Thomas E (DOA) Subject: RE: Tyonek Progress 1/5/09 Please see below a summary status of the wells: A -14, Permit to Drill # 208 -096: 8 3/4" hole drilled to 11501' MD. 7" casing set & cemented at 9980' MD. Temporarily suspended while continuing with batch completion operations on A -16. A -15, Permit to Drill # 208 -097: 8 3//4" hole drilled to 8867' MD. 7" casing set & cemented at 8833' MD. Temporarily suspended while continuing with batch completion operations on A -16. A -16, Permit to Drill # 208 -098: 8 3/4 hole drilled to 9314' MD. 7" casing set & cemented at 9301' MD. Pumped acid pickle for 4" drill pipe. Pumped caustic wash for 7" casing. Well displaced to 6% KCI brine. 4 1/2" treating string run to 8400' MD. Currently waiting on equipment in order to begin perforating & fracing operations. As you can see none of the wells have been completed at this point. The plan is to complete A -16 first followed by A -15 & 14. If operations resume soon we will hopefully have A -16 finished by the end of this month. Please let me know if you need any of this filled out. 1/6/2009 Tyonek Progress 1/5/09 Philip Page 2 of 2 • From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, January 06, 2009 8:15 AM To: Hayden, Philip Subject: RE: Tyonek Progress 1/5/09 Thanks Philip. If you wouldn't mind, could you give a status update on the wells? I show the permits were issued about July 4 and there has been some 403 and 404 activity since then, however I don't show that I have seen a 407 yet. That doesn't mean that a 407 may not have been filed, just that I haven't gotten to it yet. Tom From: Hayden, Philip [mailto:Philip .Hayden @conocophillips.com] Sent: Monday, January 05, 2009 7:14 PM To: Maunder, Thomas E (DOA) Subject: Tyonek Progress 1/5/09 Tom, Sorry for not getting back to you sooner. I tried your office phone but it was late so I didn't catch you. The replacement life sphere was offloaded from the boat on Saturday and should have been certified for use earlier today. The plan is to start manning up as soon as possible. However, operations are still waiting on two boat loads that we are struggling to deliver to the platform due to the ice. At this point a resumption of operations doesn't look likely until Wednesday /Thursday at the earliest. Please let me know if you need any more information. Philip 1/6/2009 • • Conoco Phillips TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. State of Alaska P.O. Box 100360 AOGCC Anchorage AK 99510 -0360 333 W. 7 Ave. Suite 100 Anchorage, Alaska 99501 -3539 RE: North Cook Inlet A -16 DATE: 12/22/2008 US MAIL Transmitted: Upper Cook Inlet, Alaska NCI Unit A -16 508832012700 Report and CDROM Final Well Report, Mud Logging Data, NCUI A -16; Epoch, report date: 9/20/2008; table of contents, equipment and crew, well data, geological data, pressure /strength data, drilling data, daily reports, formation logs; Color log prints: Formation Log MD and TVD 4483 -9314 LWD Combo Log MD and TVD 4483 -9314 Gas Ratio Log MD and TVD 4483 -9314 Drilling Dynamics MD and TVD 4483 -9314 CDROM contains: well report, morning reports, LAS data, PDF and tiff format color log image files; DML and Iithology remarks. CDROM Halliburton final directional survey 10/01/2008; NCIU A -16; 0 -9314' and CC: Rick Levinson, P I Geologist Receipt: 1�__.w__ - Date: r a I ' ''1 i .1 Alaska E Ph: 907.265.6947 �i'; .,.�, �r:.� ,_ �, asp• ; CIS c �la'%�.7 d�l�!'l��s d,la}� � °,Xll9i.ft,?�v ,r- ';Cf,dlG.a /�i'$. e�,1 Alaska 7 h: Sandra.D.Lemke &ConacaphiUips com 70 °1` - 0 13/' . • WELL LOG TRANSMITTAL To: State of Alaska November 17, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: NCIU A -16 AK -MW- 5744252 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 NCIU A -16 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50- 883 - 20127 -00 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50- 883 - 20127 -00 Digital Log Images 1 CD Rom 50- 883 - 20127 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 907 - 273 -3536 Date: Signed: ( • • WELL LOG TRANSMITTAL To: State of Alaska November 17, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: NCIU A -16 PB2 AK -MW- 5744252 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 NCIU A -16 PB2 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50- 883 - 20127 -71 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50- 883 - 20127 -71 Digital Log Images 1 CD Rom 50- 883 - 20127 -71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 907 - 273 -3536 i Date: Signed: 1 Oqt / • • • WELL LOG TRANSMITTAL To: State of Alaska November 14, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West '7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 RE: MWD Formation Evaluation Data: NCIU A -16 AK- MW- 5744252 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API #: 50- 883 - 20127 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 (907)273-3536 Date: Signed: Ob/r"' d �� 1 --31 2 11/24/08 Schheeherger NO. 4957 Schlurnberger -DCS 2525 Gambol! Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave. Suite 100 Anchorage, AK 99501 Field: North Cook Inlet Well Job it Log Description Date BL Color CD NCIU A -16 12092166 MDT 10/20/08 1 - NCIU A - 16 12105141 CEMENT EVALUATION/USIT 10/28/08 1 NCIU A -16 12105141 CEMENT EVALUATION/SONIC SCANNER 10/29/08 1 NCIU A -16 12105141 ANALYSIS BEHIND CASING/SONIC SCANNER 10/29/09 1 NCIU A -16 12105141 LDWG CH EDIT 10/29/08 2 - 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561 -8317. Thank you. • • • Halliburton Sperry Drilling Services 6900 Arctic Blvd Anchorage, AK 99518 October 22, 2008 Christine Mahnken State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave Suite 100 Anchorage, AK 99501 -3539 Dear Sir or Madam: Subject: NCIU A -16 Definitive Survey Enclosed is one hard copy of the definitive well path. Also enclosed is a disc containing an electronic export of the survey data. Please acknowledge receipt by sending an email to Steve.Parkinson @Halliburton.com or by signing and returning a copy of this letter to the following address: Halliburton Sperry Drilling Services ATTN: Steve Parkinson 6900 Arctic Blvd Anchorage, AK 18 Received by: - �,.,.� 61U Date: . Y �-�' , Please contact me at 907.632.3620 with questions or concerns. Regards, Steve Parkinson Enclosure(2) r {cam r �E E 1�� 3 -pct.' BOP Close in Kuukpik 5 • I Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, September 08, 2008 10:20 AM To: DOA AOGCC Prudhoe Bay Subject: FW: BOP Close in Kuukpik 5 —NCIU A -15 (208 -097) FYI From: Hayden, Philip [mailto:Philip .Hayden @conocophillips.com] Sent: Monday, September 08, 2008 10:06 AM To: Maunder, Thomas E (DOA) Cc: Chambers, Mark A Subject: RE: BOP Close in Kuukpik 5 Surface casing is set & cemented on all three wells. A -14 (208 -096) @ 4748 ft MD A -15 (208 -097) @ 4290 ft MD --+, A -16 (208 -098) @ 4536 ft MD A -15 is currently the only well drilled beyond the surface pipe. Plan ahead is to drill A -15 to TD. Log, run & cement pipe. Run a kill string. Skid to A -16 & repeat. Skid to A -14 and repeat. Completion operations will be conducted in the following order: A -16, A -15 & A -14. This is the current plan but there are ongoing discussions about changing it for gas delivery optimisation etc. Philip From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, September 08, 2008 9:51 AM To: Hayden, Philip Cc: Chambers, Mark A Subject: RE: BOP Close in Kuukpik 5 Thanks Philip. I sort of figured it likely was the Beluga. I know doing the jack up work that there always was the risk of finding a virgin sand due to the discontinuous nature of the intervals. If you wouldn't mind, could you provide a status of where the 3 wells are out there and the forward plans? As I remember batch drilling was planned. Thanks in advance. Tom Maunder, PE AOGCC From: Hayden, Philip [mailto:Philip .Hayden @conocophillips.com] Sent: Monday, September 08, 2008 9:42 AM To: Maunder, Thomas E (DOA) Cc: Chambers, Mark A Subject: RE: BOP Close in Kuukpik 5 Tom, 9/8/2008 BOP Close in Kuukpik 5 • Page 2 of 3 Well: A -15 on Tyonek Depth of initial shut -in: 7245 ft MD / 5946 ft TVD Last casing shoe: 4290 ft MD FIT at shoe: 16 ppg Formation: Logs correlate this depth to a coal section with potential sand in the Oeluga formation Let me know if you need any more information. Philip 1 . ...,_ .._. ._._... _ ... ........ ... From: Maunder, Thomas E (DOA) [mailto:tom.maunder ©alaska.gov] Sent: Monday, September 08, 2008 9:26 AM To: Hayden, Philip Cc: Chambers, Mark A Subject: RE: BOP Close in Kuukpik 5 Philip or Mark, What well was being drilled and what are the specifics regarding depth, last cas ng shoe, formation being drilled and anything else of interest. Thanks in advance. Tom Maunder, PE AOGCC From: Regg, James B (DOA) Sent: Monday, September 08, 2008 8:49 AM To: Maunder, Thomas E (DOA); Grimaldi, Louis R (DOA) Subject: FW: BOP Close in Kuukpik 5 fyi Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Kuukpik 5 Company man [ mailto :KUUK5CM ©conocophillips.com] Sent: Saturday, September 06, 2008 5:10 PM To: Regg, James B (DOA) Cc: Chambers, Mark A; Hayden, Philip Subject: BOP Close in Kuukpik 5 Mr Regg, As you requested, here is brief review of BOP shut in Kuukpik 5, 9/5/08. At approximately 10:00 AM, gas bubbling was noted during connection. No attending flow. Annular BOP was closed as precautionary measure. No pre sure. Several rounds circulation were made through choke, increasing mud wt 9.2 to 9.8 ppg. At one point, ceased pumping to clear plugged chokes. Pressure built to 360 on DP / 240 on csg. Four more complete circulations were made afterwards. Checked pressures, open well, flow check. Well static. Three more complete circulations, insure wellbore balanced. 9/8/2008 BOP Close in Kuukpik 5 • Page 3 of 3 Resumed drilling ahead 0200 hrs 9/6/08. Plans are to test all components held against pressures as instructed by Mr Lou Grimaldi first trip out of hole.. Regards Dave Morris Co Man Tyonek Platform, Kuukpik 5, well A -15 9/8/2008 • • August 6, 2008 Alaska Oil and Gas Conservation Commission Christine Mahnken 333 W. 7 Ave. #100 Anchorage, AK 99501 -3539 Re: Distribution of Survey Data for Well NCIU A- 16PB1, NCIU A- 16PB2, and NCIU A -16 Dear Sir /Madam: Enclosed is one survey hard copy and one disk. NCIU A -16PB1 NCIU A -16PB2 NCIU A -16 Tie -on Survey: 221.58' MD Tie -on Survey: 1,010' MD Tie -on Survey: 389' MD Window Survey: 0.00' MD Window Survey: 0.00' MD Window Survey: 0.00' MD Projected Survey: 0.00' MD Projected Survey: 1,168' MD Projected Survey: 0.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen @HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry -Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date � Signed S fl Please call me at 273 -3534 if you have any questions or concerns. Regards, Tim Allen Survey Manager Attachment(s) Ci" �l f 2\d ° 6(kA NCIU A -16 plug back Page 1 of 2 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, July 23, 2008 10:14 AM To: 'Hayden, Philip' Subject: RE: NCIU A -16 (208 -098) plug back This is close to bottom and likely will be isolated when you fill up the hole with cement. Nothing further is needed. I will place a copy of this message in the file. Please include the permit number in the title of your messages. Call or message with any questions. Tom Maunder, PE AOGCC From: Hayden, Philip [mailto:Philip .Hayden @conocophillips.com] Sent: Wednesday, July 23, 2008 10:11 AM To: Maunder, Thomas E (DOA) Subject: RE: NCIU A -16 plug back The driller reamed down from -1040 to 1120' MD so this is where we suspect we have wiped out our dogleg or sidetracked. Philip From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, July 23, 2008 9:55 AM To: Hayden, Philip Subject: RE: NCIU A -16 plug back Philip, Thanks for the information. Do you have depth with regard to your "Accidentally ..." comment? Tom Maunder, PE AOGCC From: Hayden, Philip [mailto:Philip .Hayden @conocophillips.com] Sent: Wednesday, July 23, 2008 9:53 AM To: Maunder, Thomas E (DOA) Subject: NCIU A -16 plug back Tom, As per our telephone conversation yesterday here is our update on operations on NCIU A -16: Spudded the well @ 10:45 18/7/08 Drilled to 1120' MD with various bend settings on the motor Not getting required doglegs to avoid close approaches Changed out motor bend to 2.38 deg and RIH Accidentally wiped out dogleg or sidetracked the well while reaming to bottom Drilled ahead to 1168' MD. Stopped drilling at this depth due to close approach with existing well 7/23/2008 NCIU A -16 plug back Page 2 of 2 • With expected doglegs it was not possible to avoid the close approach Decision made to plug back to the conductor shoe and sidetrack We plan on filling the open hole with 12 ppg cement slurry in two plugs. TOC is planned to be -350' MD with conductor shoe at 400' MD. WOC 24 hours. Prognosed compressive strength after 24 hours - 1500 psi. With a more aggressive directional assembly than originally used we plan to side track off the cement plug and drill the original wellplan that we were unable to accomplish first time around. Please let me know if you need any more information Regards Philip 7/23/2008 Page 1 of 1 • S Maunder, Thomas E (DOA) From: Hayden, Philip [Philip .Hayden ©conocophillips.com] Sent: Thursday, July 03, 2008 11:38 AM ^� To: Maunder, Thomas E (DOA) Subject: RE: Updated Directional Profiles for NCIU A -15 & 16 We increased the planned doglegs slightly in order to lower the sail angles while also making minor changes to optimise our anti - collision planning in the shallow surface hole. Philip From: Maunder, Thomas E (DOA) [mailto :tom.maunder @alaska.gov] Sent: Thursday, July 03, 2008 11:35 AM To: Hayden, Philip Subject: RE: Updated Directional Profiles for NCIU A -15 & 16 Thanks Philip, Could you comment on the nature of the changes? From our discussions, I gathered that "tweaks" were necessary in the trajectories to improve collision avoidance. I look forward to your reply. Tom Maunder, PE AOGCC From: Hayden, Philip [mailto: Philip .Hayden @conocophillips.com] Sent: Thursday, July 03, 2008 11:17 AM To: Maunder, Thomas E (DOA) Subject: Updated Directional Profiles for NCIU A -15 & 16 Tom, Attached are the updated directional plans for NCIU wells A -15 & 16. The changes are minor and don't require a formal communication from us as I understand the regulations. The files are in NAD 27. Let me know if you have any comments or requests. Regards Philip 7/7/2008 • ConocoPhillips (Alaska) Inc. -Expl North Cook Inlet Unit North Cook Inlet Unit Plan: NCI A -16 PIan:NCI A -16 Plan: A- 16wp15 Standard Planning Report - Geographic 01 July, 2008 Project: North Cook Inlet Unit REFERENCE INFORMATION SECTION DETAILS Site: North Cook Inlet Unit Coordinate (N/E) Reference: Well Plan: NCI A -16, True North Sec MD Inc AzI WO +N / -S +E/ -W DLeg TFace VSec Target Well: Plan: NCI A -16 Vertical (TVD) Reference: Plan: A -16 @ 116.0ft (Kuupik 5) 1 217.0 0.00 0.00 217.0 0.0 0.0 0.00 0.00 0.0 Wellbore: Plan: NCI A -16 Measur Depth Reference: Plan: A -16 @ 116.Oft (Kuupik 5) 2 450.0 0.00 0.00 450.0 0.0 0.0 0.00 0.00 0.0 Calculation Method: Minimum Curvature 3 550.0 2.00 310.00 550.0 1.1 -1.3 2.00 310.00 1.7 Plan: A - 16wp15 4 680.0 2.00 310.00 679.9 4.0 -4.8 0.00 0.00 6.3 5 947.4 9.00 255.00 946.0 1.6 -28.6 3.00 -66.69 23.7 6 1230.8 15.00 295.00 1223.5 11.4 -83.4 3.50 74.95 73.1 WELL DETAILS: Plan: NCI A - 16 7 1663.4 31.12 290.00 1620.2 73.7 -240.2 3.75 -9.28 235.5 8 2295.1 52.69 310.35 2089.8 295.8 -590.8 4.00 40.39 648.8 Water Depth: 101.0 9 5495.9 52.69 310.35 4030.0 1944.1 - 2530.9 0.00 0.00 3191.4 +N / - +E / - Noshing East ng Latittude Longitude Slot 10 5819.6 40.00 306.75 4253.0 2090.3 - 2713.1 4.00 - 169.64 3425.0 A- 16wp13 C18 Drilling Target 0.0 0.0 2586675.15 332034.57 61 4' 35.844 N I50° 56' 54.802 W 11 6186.7 25.31 306.61 4561.3 2208.3 - 2871.5 4.00 - 179.76 3622.5 12 6309.6 25.31 306.61 4672.3 2239.7 - 2913.7 0.00 0.00 3675.0 - 13 7122.2 5.00 307.40 5452.5 2366.1 - 3083.1 2.50 179.80 3886.4 - - 14 7522.2 5.00 307.40 5851.0 2387.3 - 3110.8 0.00 0.00 3921.2 A- 16wp13 M Drilling Target 15 7522.5 5.00 307.50 5851.4 2387.3 - 3110.8 2.50 88.90 3921.3 - talk 18 8566.1 5.00 307.50 6891.0 2442.7 - 3182.9 0.00 0.00 4012.2 A- 16wp13 U Drilling Target 0- 9293.9 5.00 307.50 7616.0 2481.3 - 3233.3 0.00 0.00 4075.6 - F - SHL: 1301.5 FNL, 4010.1 FEL, SEC 06, T11 N, RO9W CASING DETAILS FORMATION TOP DETAILS 650 - TVD MD Name Size 3566.0 4730.5 Top Sterling 3416.0 4483.0 9 5/8" 9 -5/8 3609.0 4801.4 CI -A 7615.9 9293.8 7" 7 3808.0 5129.7 CI -1 3832.0 5169.3 C.I. 2 1300- 4078.0 557Z 5 CI-5 4253.0 5819.6 C.I. I. 8 _ 4455.0 6066.7 Beluga -A 5851.0 7522.2 Beluga M - 6331.0 8004.0 Beluga Q - 6486.0 8159.6 Beluga S 1950- 7216 0 8892.4 Beluga Ubase C _ 2600- -2600 N p _ 9 -5/8" © 5162.2 FNL, 900 FEL, SEC 36, T12N, R10W _ m M - - S. 3250- 9 5/8" -3250 0 CD - CD = Top Sterling 1E 3900- -3900 - 0) - _ CI -1 - 0 - 0 N - - C1-5 - 1 - 7 g l 4550- , , -4550 _ Beluga -A - A- 16wp13 CI8 Drilling Target _ 5200- -5200 A- 16wp13 M Drilling Target 5850 -5850 _ Beluga M - 6500- Beluga CI - 6500 © 9292.9' MD; 7616' TVD, 4103.6 FNL, 2217.3 FEL, SEC 36, T12N, R1OW A- 16wp13 U Drilling Target _ 7150- Beluga U -7150 - Beluga Ubase - 7 ,. - 7800- - 7800 l l l l 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 i 1 1 1 1 1 1 1 1 1 1 1 1 I 1 i l 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 -2600 -1950 -1300 -650 0 650 1300 1950 2600 3250 3900 4550 5200 5850 6500 7150 7800 8450 Vertical Section at 307.50° (1300 Win) ConocoPhillips Project: North Cook Inlet Unit REFERENCE INFORMATION WELL DETAILS: Plan: NCI A -I6 Site North Cook Inlet Unit Co-ordinate (NIE) Reference: Web Plan: NCI A -16, True North Water Depth: 101.0 Vertical (TVD) Reference: Plan: A -16 @ 116.08 (Kuupik 5) • +N /•S +F/ -W Northing Fasting Latittude Longitude Slot Well: Plan: NCI A -16 Measured Depth Reference: Plan: A -16 4 116. M (Kuupik 5) 0.0 0.0 2586675.15 332034.57 61 4' 35.844 N50 56' 54.802 W Wellbore: PIan:NCI A -16 Calculation Method: Minimum Curvature Plan: A- 16wp15 3000 BHL (a, 9292.9' MD; 7616' TVD, 4103.6 FNL, 2217.3 FEL, SEC 36, TI2N, RIOW 2857 2714 257) 95% cont. 2429 ho y 0 2286 Ry � • • 2143 RS 1 95 %conf.l A - 16wp I3 U Drilling Target • 2000 • • • 1857 A - 16wp13 M Drilling Target • • 1714 !A C13 Drilling Target 9 - 5/8" L 5162.2 FNL, 900 FEL, SEC 36, TI2N, RIO W 1571 • � X58 im 1429 9 5/8" ry • o 1286 0 1143 o cA tt O 1000 857 714 ti cA ti 571 SHL: 1301.5 FNL, 4010.1 FEL, SEC 06, TI IN, R09\ y o 429 286 ti dy' 143 f ,.A • � -0 -143 -286 -429 -4143 -4000 -3857 -3714 -3571 -3429 -3286 -3143 -3000 -2857 -2714 -2571 -2429 -2286 -2143 -2000 -1857 -1714 -1571 -1429 -1286 -1143 -1000 -857 -714 -571 -429 -286 -143 -0 143 286 429 571 714 857 West( -) /East( +) (500 ft/in) Cotwt oPhi ")ps • ConocoPhillips Planning Report - Geographic Database EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan: NCI A -16 Company: ConocoPhillips (Alaska) Inc. -Expl TVD Reference: Plan: A -16 @ 116.0ft (Kuupik 5) Project: North Cook Inlet Unit MO Reference: Plan: A -16 @ 116.0ft (Kuupik 5) Site: North Cook Inlet Unit North Reference: True Welt: Plan: NCI A -16 Survey Calculation Method: Minimum Curvature 1Nelibore: Plan:NCI A -16 Design: A- 16wp15 Project North Cook Inlet Unit, Alaska, USA Map System: US State Plane 1927 (Exact solution) System Datum: MLLW Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor ' Site North Cook Inlet Unit Site Position: Northing: 2,586,726.15ft Latitude: 61° 4' 36.355 N From: Map Easting: 332,100.01ft Longitude: 150° 56' 53.487 W Position Uncertainty: 0.0 ft Slot Radius: 0" Grid Convergence: -0.83 ° C Well Plan: NCI A -16 Well Position +N /-S 0.0 ft Northing: 2,586,675.15ft Latitude: 61° 4' 35.844 N +E / -W 0.0 ft Easting: 332,034.57 ft Longitude: 150° 56' 54.802 W Position Uncertainty 0.0 ft Wellhead Elevation: 73.0ft Water Depth: 101.0ft Welibore Plan:NCI A -16 Magnetics abet blame Sample Date Declination Dip Angle Field Strength { ( ( (nT) bggm2007 9/12/2006 16.83 72.83 54,912 Design . A- 16wp15 Audit Notes: Version: 1 Phase: PLAN Tie On Depth: 217.0 Vertical Section; Depth from (TVD) +N!-S +El W Direction (ft ) (ft) (ft) (1 217.0 0.0 0.0 307.50 7/1/2008 2 :05 :43PM Page 2 COMPASS 2003.16 Build 42F • ConocoPhillips Planning Report - Geographic Database: EDM 2003.16 Single User Db Local Co- ordinate Reference: Well Plan: NCI A -16 Company: ' ConocoPhillips (Alaska) Inc. -Expl TVD Reference: Plan: A -16 @ 116 Oft (Kuupik 5) Project: North Cook Inlet Unit MD Reference: Plan: A -16 @ 116.0ft (Kuupik 5) Site: North Cook Inlet Unit North Reference: True Well: Plan: NCI A -16 Survey Calculation Method: Minimum Curvature Wellbore: PIarr:NCI A -16 Design: A- 16wp15 Plan Sections Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N /-S +E/ -W Rate Rate Rate TFO (ft) ( °) ( °) (ft) (ft) (ft) (° /1oOft) (°lloOft); ( °/1OOft) ( °) Target 217.0 0.00 0.00 217.0 0.0 0.0 0.00 0.00 0.00 0.00 450.0 0.00 0.00 450.0 0.0 0.0 0.00 0.00 0.00 0.00 550.0 2.00 310.00 550.0 1.1 -1.3 2.00 2.00 0.00 310.00 680.0 2.00 310.00 679.9 4.0 -4.8 0.00 0.00 0.00 0.00 947.4 9.00 255.00 946.0 1.6 -28.6 3.00 2.62 -20.57 -66.69 1,230.8 15.00 295.00 1,223.5 11.4 -83.4 3.50 2.12 14.11 74.95 1,663.4 31.12 290.00 1,620.2 73.7 -240.2 3.75 3.73 -1.16 -9.28 2,295.1 52.69 310.35 2,089.8 295.8 -590.8 4.00 3.41 3.22 40.39 5,495.9 52.69 310.35 4,030.0 1,944.1 - 2,530.9 0.00 0.00 0.00 0.00 5,819.6 40.00 306.75 4,253.0 2,090.3 - 2,713.1 4.00 -3.92 -1.11 - 169.64 A- 16wp13 CI8 Drilii 6,186.7 25.31 306.61 4,561.3 2,208.3 - 2,871.5 4.00 -4.00 -0.04 - 179.76 6,309.6 25.31 306.61 4,672.3 2,239.7 - 2,913.7 0.00 0.00 0.00 0.00 7,122.2 5.00 307.40 5,452.5 2,366.1 - 3,083.1 2.50 -2.50 0.10 179.80 7,522.2 5.00 307.40 5,851.0 2,387.3 - 3,110.8 0.00 0.00 0.00 0.00 A- 16wp13 M Drillin< 7,522.5 5.00 307.50 5,851.4 2,387.3 - 3,110.8 2.50 0.05 28.68 88.90 8,566.1 5.00 307.50 6,891.0 2,442.7 - 3,182.9 0.00 0.00 0.00 0.00 A- 16wp13 U Drillin 9,293.9 5.00 307.50 7,616.0 2,481.3 - 3,233.3 0.00 0.00 0.00 0.00 7/1/2008 2:05:43PM Page 3 COMPASS 2003.16 Build 42F 1 0 ConocoPhillips Planning Report - Geographic Database: EDM 2003.16 Single User Db Local Co- ordinate Reference: Well Plan: NCI A -16 Company:; ConocoPhillips (Alaska) Inc. -Expl TVD Reference: Plan: A -16 @ 116.0ft (Kuupik 5) Project: North Cook Inlet Unit MD Reference: Plan: A -16 @ 116.0ft (Kuupik 5) Site: North Cook Inlet Unit North Reference: True Well: Plan: NCI A -16 Survey Calculation Method: Minimum Curvature Wellbore: PIan:NCI A -16 Design: A- 16wp15 Planned Survey Measured Vertical Map Map Depth inclination Azimuth Depth +N/-S +E /-W Northing Easting (ft) ( ( (f) (ft) (ft) (ft) (ft) Latitude Longitude 217.0 0.00 0.00 217.0 0.0 0.0 2,586,675.15 332,034.57 61 150° 56' 54.802 W 217.1 0.00 0.00 217.1 0.0 0.0 2,586,675.15 332,034.57 61° 4' 35.844 N 150° 56' 54.802 W SHL: 1304.5 FNL, 4010.1 FEL, SEC 06, T11 N, RO9W 300.0 0.00 0.00 300.0 0.0 0.0 2,586,675.15 332,034.57 61° 4' 35.844 N 150° 56' 54.802 W 400.0 0.00 0.00 400.0 0.0 0.0 2,586,675.15 332,034.57 61° 4' 35.844 N 150° 56' 54.802 W 450.0 0.00 0.00 450.0 0.0 0.0 2,586,675.15 332,034.57 61° 4' 35.844 N 150° 56' 54.802 W 500.0 1.00 310.00 500.0 0.3 -0.3 2,586,675.44 332,034.24 61° 4' 35.847 N 150° 56' 54.809 W 550.0 2.00 310.00 550.0 1.1 -1.3 2,586,676.29 332,033.25 61°4'35.855N 150° 56' 54.829 W 600.0 2.00 310.00 599.9 2.2 -2.7 2,586,677.43 332,031.93 61° 4' 35.866 N 150° 56' 54.857 W 680.0 2.00 310.00 679.9 4.0 -4.8 2,586,679.26 332,029.82 61° 4' 35.884 N 150° 56' 54.900 W 700.0 2.30 296.16 699.9 4.4 -5.4 2,586,679.67 332,029.20 61°4'35.887N 150° 56' 54.913 W 800.0 4.76 265.97 799.7 5.0 -11.4 2,586,680.35 332,023.26 61° 4' 35.893 N 150° 56' 55.034 W 900.0 7.62 257.20 899.1 3.3 -22.0 2,586,678.74 332,012.64 61 150° 56' 55.249 W 947.4 9.00 255.00 946.0 1.6 -28.6 2,586,677.19 332,005.98 61° 4' 35.860 N 150° 56' 55.384 W 1,000.0 9.64 265.68 997.9 0.2 -37.0 2,586,675.91 331,997.58 61° 4' 35.846 N 150° 56' 55.554 W 1,100.0 11.59 281.59 1,096.2 1.6 -55.2 2,586,677.56 331,979.41 61° 4' 35.860 N 150° 56' 55.924 W 1,200.0 14.14 292.43 1,193.7 8.3 -76.3 2,586,684.55 331,958.38 61° 4' 35.925 N 150° 56' 56.354 W 1,230.8 15.00 295.00 1,223.5 11.4 -83.4 2,586,687.77 331,951.34 61° 4' 35.956 N 150° 56' 56.498 W 1,300.0 17.57 293.61 1,289.9 19.4 -101.1 2,586,695.99 331,933.76 61° 4' 36.035 N 150° 56' 56.858 W 1,400.0 21.29 292.19 1,384.2 32.3 -131.8 2,586,709.34 331,903.31 61° 4' 36.162 N 150° 56' 57.481 W 1,500.0 25.02 291.17 1,476.2 46.8 -168.3 2,586,724.36 331,866.99 61° 4' 36.304 N 150° 56' 58.223 W 1,600.0 28.75 290.40 1,565.3 62.8 -210.6 2,586,740.99 331,824.95 61° 4' 36.462 N 150° 56' 59.083 W 1,663.4 31.12 290.00 1,620.2 73.7 -240.2 2,586,752.33 331,795.45 61° 4' 36.570 N 150° 56' 59.686 W 1,700.0 32.25 291.78 1,651.4 80.6 -258.2 2,586,759.46 331,777.58 61° 4' 36.637 N 150° 57' 0.051 W 1,800.0 35.44 296.11 1,734.5 103.2 -309.0 2,586,782.86 331,727.08 61° 4' 36.860 N 150° 57' 1.084 W 1,900.0 38.76 299.80 1,814.2 131.6 -362.3 2,586,811.95 331,674.28 61° 4' 37.139 N 150° 57' 2.166 W 2,000.0 42.19 302.98 1,890.3 165.4 -417.6 2,586,846.60 331,619.42 61°4'37.473N 150° 57' 3.292 W 2,100.0 45.69 305.77 1,962.3 204.6 -474.8 2,586,886.63 331,562.78 61° 4' 37.859 N 150° 57' 4.455 W 2,200.0 49.26 308.24 2,029.9 249.0 -533.7 2,586,931.85 331,504.62 61° 4' 38.296 N 150° 57' 5.650 W 2,295.1 52.69 310.35 2,089.8 295.8 -590.8 2,586,979.47 331,448.18 61° 4' 38.756 N 150° 57' 6.812 W 2,300.0 52.69 310.35 2,092.7 298.3 -593.8 2,586,982.04 331,445.24 61° 4' 38.781 N 150° 57' 6.872 W 2,400.0 52.69 310.35 2,153.4 349.8 -654.4 2,587,034.40 331,385.38 61° 4' 39.288 N 150° 57' 8.105 W 2,500.0 52.69 310.35 2,214.0 401.3 -715.0 2,587,086.77 331,325.52 61° 4' 39.795 N 150° 57' 9.337 W 2,600.0 52.69 310.35 2,274.6 452.8 -775.6 2,587,139.13 331,265.67 61° 4' 40.302 N 150° 57' 10.569 W 2,700.0 52.69 310.35 2,335.2 504.3 -836.2 2,587,191.50 331,205.81 61° 4' 40.810 N 150° 57' 11.801 W 2,800.0 52.69 310.35 2,395.8 555.8 -896.8 2,587,243.86 331,145.95 61° 4' 41.317 N 150° 57' 13.034 W 2,900.0 52.69 310.35 2,456.4 607.3 -957.4 2,587,296.23 331,086.10 61° 4' 41.824 N 150° 57' 14.266 W 3,000.0 52.69 310.35 2,517.1 658.8 - 1,018.1 2,587,348.59 331,026.24 61° 4' 42.331 N 150° 57' 15.498 W 3,100.0 52.69 310.35 2,577.7 710.3 - 1,078.7 2,587,400.95 330,966.38 61° 4' 42.838 N 150° 57' 16.731 W 3,200.0 52.69 310.35 2,638.3 761.8 - 1,139.3 2,587,453.32 330,906.53 61° 4' 43.345 N 150° 57' 17.963 W 3,300.0 52.69 310.35 2,698.9 813.3 - 1,199.9 2,587,505.68 330,846.67 61° 4' 43.852 N 150° 57' 19.195 W 3,400.0 52.69 310.35 2,759.5 864.8 - 1,260.5 2,587,558.05 330,786.81 61° 4' 44.359 N 150° 57' 20.428 W 3,500.0 52.69 310.35 2,820.1 916.3 - 1,321.1 2,587,610.41 330,726.96 61° 4' 44.866 N 150° 57' 21.660 W 3,600.0 52.69 310.35 2,880.7 967.8 - 1,381.7 2,587,662.77 330,667.10 61° 4' 45.373 N 150° 57' 22.892 W 3,700.0 52.69 310.35 2,941.4 1,019.3 - 1,442.3 2,587,715.14 330,607.24 61° 4' 45.880 N 150° 57' 24.125 W 3,800.0 52.69 310.35 3,002.0 1,070.8 - 1,503.0 2,587,767.50 330,547.39 61° 4' 46.387 N 150° 57' 25.357 W 3,900.0 52.69 310.35 3,062.6 1,122.3 - 1,563.6 2,587,819.87 330,487.53 61° 4' 46.894 N 150° 57' 26.589 W 4,000.0 52.69 310.35 3,123.2 1,173.7 - 1,624.2 2,587,872.23 330,427.67 61° 4' 47.401 N 150° 57' 27.822 W 4,100.0 52.69 310.35 3,183.8 1,225.2 - 1,684.8 2,587,924.59 330,367.81 61 150° 57' 29.054 W 4,200.0 52.69 310.35 3,244.4 1,276.7 - 1,745.4 2,587,976.96 330,307.96 61° 4' 48.415 N 150° 57' 30.287 W 4,300.0 52.69 310.35 3,305.1 1,328.2 - 1,806.0 2,588,029.32 330,248.10 61° 4' 48.922 N 150° 57' 31.519 W 4,400.0 52.69 310.35 3,365.7 1,379.7 - 1,866.6 2,588,081.69 330,188.24 61° 4' 49.429 N 150° 57' 32.752 W 4,483.0 52.69 310.35 3,416.0 1,422.5 - 1,917.0 2,588,125.16 330,138.55 61° 4' 49.849 N 150° 57' 33.775 W 9 -5/8" @ 5162.2 FNL, 900.9 FEL, SEC 36, T12N, R10W - 9 5/8" 7/1/2008 2 :05 :43PM Page 4 COMPASS 2003.16 Build 42F 1 ConocoPhillips Planning Report - Geographic Database: EDM 2003.16 Single User Db Local Co- ordinate Reference: Well Plan: NCI A -16 Company: ConocoPhillips (Alaska) Inc. -Expl TVD Reference: Plan: A -16 @ 116.0ft (Kuupik 5) Project: North Cook Inlet Unit MD Reference: Plan: A -16 @ 116.0ft (Kuupik 5) Site: North Cook Inlet Unit North Reference: True Well: Plan: NCI A -16 Survey Calculation Method: Minimum Curvature Wellbore: Plan :NCI A -16 Design: A- 16wp15 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth ; +N /-S +Ef -W Northing Fasting (ft) (°) f °) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 4,500.0 52.69 310.35 3,426.3 1,431.2 -1,927.3 2,588,134.05 330,128.39 61°4'49.935N 150° 57' 33.984 W 4,600.0 52.69 310.35 3,486.9 1,482.7 - 1,987.9 2,588,186.42 330,068.53 61° 4' 50.442 N 150° 57' 35.217 W 4,700.0 52.69 310.35 3,547.5 1,534.2 - 2,048.5 2,588,238.78 330,008.67 61° 4' 50.949 N 150° 57' 36.449 W 4,730.5 52.69 310.35 3,566.0 1,549.9 - 2,067.0 2,588,254.74 329,990.43 61° 4' 51.104 N 150° 57' 36.825 W Top Sterling 4,800.0 52.69 310.35 3,608.1 1,585.7 - 2,109.1 2,588,291.14 329,948.82 61° 4' 51.456 N 150° 57' 37.681 W 4,801.4 52.69 310.35 3,609.0 1,586.4 - 2,110.0 2,588,291.89 329,947.97 61° 4' 51.464 N 150° 57' 37.699 W CI-A 4,900.0 52.69 310.35 3,668.8 1,637.2 - 2,169.7 2,588,343.51 329,888.96 61° 4' 51.963 N 150° 57' 38.914 W 5,000.0 52.69 310.35 3,729.4 1,688.7 - 2,230.3 2,588,395.87 329,829.10 61° 4' 52.470 N 150° 57' 40.147 W 5,100.0 52.69 310.35 3,790.0 1,740.2 - 2,290.9 2,588,448.24 329,769.25 61° 4' 52.977 N 150° 57' 41.379 W 5,129.7 52.69 310.35 3,808.0 1,755.5 - 2,308.9 2,588,463.80 329,751.46 61 150° 57' 41.745 W CI-1 5,169.3 52.69 310.35 3,832.0 1,775.9 - 2,332.9 2,588,484.53 329,727.76 61° 4' 53.329 N 150° 57' 42.233 W C.I. 2 5,200.0 52.69 310.35 3,850.6 1,791.7 - 2,351.6 2,588,500.60 329,709.39 61 150° 57' 42.612 W 5,300.0 52.69 310.35 3,911.2 1,843.2 - 2,412.2 2,588,552.96 329,649.53 61° 4' 53.991 N 150° 57' 43.844 W 5,400.0 52.69 310.35 3,971.8 1,894.7 - 2,472.8 2,588,605.33 329,589.68 61° 4' 54.498 N 150° 57' 45.077 W 5,495.9 52.69 310.35 4,030.0 1,944.1 - 2,530.9 2,588,655.55 329,532.27 61 150° 57' 46.259 W 5,500.0 52.53 310.31 4,032.5 1,946.2 - 2,533.4 2,588,657.69 329,529.82 61° 4' 55.005 N 150° 57' 46.309 W 5,572.5 49.67 309.63 4,078.0 1,982.4 - 2,576.6 2,588,694.57 329,487.10 61° 4' 55.362 N 150° 57' 47.189 W CI-5 5,600.0 48.60 309.35 4,096.0 1,995.6 - 2,592.7 2,588,708.01 329,471.27 61° 4' 55.492 N 150° 57' 47.515 W 5,700.0 44.67 308.27 4,164.6 2,041.2 - 2,649.3 2,588,754.40 329,415.31 61° 4' 55.941 N 150° 57' 48.666 W 5,800.0 40.76 307.02 4,238.1 2,082.7 - 2,703.0 2,588,796.61 329,362.23 61° 4' 56.349 N 150° 57 49.758 W 5,819.6 40.00 306.75 4,253.0 2,090.3 - 2,713.1 2,588,804.38 329,352.20 61° 4' 56.424 N 150° 57' 49.964 W C.I. 8 - A- 16wp13 CI8 Drilling Target 5,900.0 36.78 306.73 4,316.0 2,120.1 - 2,753.1 2,588,834.82 329,312.62 61° 4' 56.718 N 150° 57' 50.778 W 6,000.0 32.78 306.70 4,398.1 2,154.2 - 2,798.9 2,588,869.58 329,267.41 61° 4' 57.053 N 150° 57' 51.708 W 6,066.7 30.12 306.67 4,455.0 2,175.0 - 2,826.8 2,588,890.76 329,239.82 61° 4' 57.258 N 150° 57' 52.275 W Beluga -A 6,100.0 28.78 306.66 4,484.0 2,184.8 - 2,839.9 2,588,900.73 329,226.82 61° 4' 57.354 N 150° 57' 52.542 W 6,186.7 25.31 306.61 4,561.3 2,208.3 - 2,871.5 2,588,924.72 329,195.52 61° 4' 57.586 N 150° 57' 53.186 W 6,200.0 25.31 306.61 4,573.3 2,211.7 - 2,876.1 2,588,928.17 329,191.02 61° 4' 57.619 N 150° 57' 53.278 W 6,300.0 25.31 306.61 4,663.6 2,237.2 - 2,910.4 2,588,954.16 329,157.07 61°4'57.870N 150° 57' 53.976 W 6,309.6 25.31 306.61 4,672.3 2,239.7 - 2,913.7 2,588,956.65 329,153.82 61° 4' 57.894 N 150° 57' 54.043 W 6,400.0 23.05 306.63 4,754.8 2,261.8 - 2,943.4 2,588,979.17 329,124.42 61° 4' 58.112 N 150° 57' 54.648 W 6,500.0 20.55 306.66 4,847.6 2,283.9 - 2,973.2 2,589,001.77 329,094.94 61° 4' 58.330 N 150° 57' 55.254 W 6,600.0 18.05 306.69 4,942.0 2,303.7 - 2,999.7 2,589,021.89 329,068.72 61° 4' 58.524 N 150° 57' 55.793 W 6,700.0 15.55 306.74 5,037.7 2,321.0 - 3,022.9 2,589,039.51 329,045.80 61° 4' 58.694 N 150° 57' 56.264 W 6,800.0 13.05 306.80 5,134.6 2,335.7 - 3,042.7 2,589,054.58 329,026.23 61° 4' 58.840 N 150° 57' 56.666 W 6,900.0 10.55 306.89 5,232.5 2,348.0 - 3,059.1 2,589,067.08 329,010.04 61° 4' 58.961 N 150° 57' 56.999 W 7,000.0 8.05 307.03 5,331.2 2,357.7 - 3,072.0 2,589,076.98 328,997.27 61° 4' 59.056 N 150° 57' 57.262 W 7,100.0 5.55 307.30 5,430.5 2,364.9 - 3,081.4 2,589,084.27 328,987.93 61° 4' 59.127 N 150° 57' 57.454 W 7,122.2 5.00 307.40 5,452.5 2,366.1 - 3,083.1 2,589,085.53 328,986.33 61° 4' 59.139 N 150° 57' 57.487 W 7,200.0 5.00 307.40 5,530.1 2,370.2 - 3,088.5 2,589,089.72 328,981.00 61° 4' 59.179 N 150° 57' 57.597 W 7,300.0 5.00 307.40 5,629.7 2,375.5 - 3,095.4 2,589,095.12 328,974.15 61° 4' 59.232 N 150° 57' 57.737 W 7,400.0 5.00 307.40 5,729.3 2,380.8 - 3,102.3 2,589,100.51 328,967.31 61° 4' 59.284 N 150° 57' 57.878 W 7,500.0 5.00 307.40 5,828.9 2,386.1 - 3,109.2 2,589,105.90 328,960.46 61° 4' 59.336 N 150° 57' 58.019 W 7,522.2 5.00 307.40 5,851.0 2,387.3 - 3,110.8 2,589,107.10 328,958.94 61° 4' 59.347 N 150° 57' 58.050 W Beluga M - A- 16wp13 M Drilling Target 7,522.5 5.00 307.50 5,851.4 2,387.3 - 3,110.8 2,589,107.12 328,958.92 61° 4' 59.348 N 150° 57' 58.051 W 7,600.0 5.00 307.50 5,928.5 2,391.4 - 3,116.1 2,589,111.31 328,953.62 61° 4' 59.388 N 150° 57' 58.160 W 7/1/2008 2:05 :43PM Page 5 COMPASS 2003.16 Build 42F • ConocoPhillips Planning Report - Geographic Database: EDM 2003.16 Single User Db Local Co- ordinate Reference: Well Plan: NCI A -16 Company: ConocoPhillips (Alaska) Inc. -Expl TVD Reference: Plan: A -16 @ 116.0ft (Kuupik 5) Project: North Cook Inlet Unit MD Reference: Plan: A -16 @ 116.0ft (Kuupik 5) Site: North Cook Inlet Unit North Reference: True Well: Plan: NCI A -16 Survey Calculation Method: Minimum Curvature Wellbore: PIan:NCI A -16 Design: A- 16wp15 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N /-S +E/40/ Northing Easting (ft) ( ( (ft) (ft) (ft) (ft) (ft) Latitude Longitude 7,700.0 5.00 307.50 6,028.2 2,396.7 -3,123.1 2,589,116.71 328,946.78 61"4'59.440N 150° 57' 58.300 W 7,800.0 5.00 307.50 6,127.8 2,402.0 - 3,130.0 2,589,122.12 328,939.95 61° 4' 59.492 N 150° 57' 58.441 W 7,900.0 5.00 307.50 6,227.4 2,407.3 - 3,136.9 2,589,127.52 328,933.11 61° 4' 59.545 N 150° 57' 58.582 W 8,000.0 5.00 307.50 6,327.0 2,412.6 - 3,143.8 2,589,132.93 328,926.28 61° 4' 59.597 N 150° 57' 58.722 W 8,004.0 5.00 307.50 6,331.0 2,412.9 - 3,144.1 2,589,133.15 328,926.00 61° 4' 59.599 N 150° 57' 58.728 W Beluga Q 8,100.0 5.00 307.50 6,426.6 2,418.0 - 3,150.7 2,589,138.34 328,919.44 61° 4' 59.649 N 150° 57' 58.863 W 8,159.6 5.00 307.50 6,486.0 2,421.1 - 3,154.8 2,589,141.56 328,915.36 61° 4' 59.680 N 150° 57' 58.947 W Beluga S 8,200.0 5.00 307.50 6,526.3 2,423.3 - 3,157.6 2,589,143.74 328,912.60 61° 4' 59.701 N 150° 57 59.003 W 8,300.0 5.00 307.50 6,625.9 2,428.6 - 3,164.5 2,589,149.15 328,905.77 61° 4' 59.754 N 150° 57' 59.144 W 8,400.0 5.00 307.50 6,725.5 2,433.9 - 3,171.5 2,589,154.55 328,898.93 61° 4' 59.806 N 150° 57' 59.285 W 8,500.0 5.00 307.50 6,825.1 2,439.2 - 3,178.4 2,589,159.96 328,892.09 61° 4' 59.858 N 150° 57 59.425 W 8,566.1 5.00 307.50 6,891.0 2,442.7 - 3,182.9 2,589,163.53 328,887.57 61° 4' 59.893 N 150° 57' 59.518 W Beluga U - A- 16wp13 U Drilling Target 8,600.0 5.00 307.50 6,924.7 2,444.5 - 3,185.3 2,589,165.36 328,885.26 61° 4' 59.910 N 150° 57' 59.566 W 8,700.0 5.00 307.50 7,024.4 2,449.8 - 3,192.2 2,589,170.77 328,878.42 61° 4' 59.963 N 150° 57' 59.707 W 8,800.0 5.00 307.50 7,124.0 2,455.1 - 3,199.1 2,589,176.18 328,871.58 61° 5' 0.015 N 150° 57' 59.847 W 8,892.4 5.00 307.50 7,216.0 2,460.0 - 3,205.5 2,589,181.17 328,865.27 61° 5' 0.063 N 150° 57' 59.977 W Beluga Ubase 8,900.0 5.00 307.50 7,223.6 2,460.4 - 3,206.0 2,589,181.58 328,864.75 61° 5' 0.067 N 150° 57' 59.988 W 9,000.0 5.00 307.50 7,323.2 2,465.7 - 3,212.9 2,589,186.99 328,857.91 61° 5 0.119 N 150° 58' 0.128 W 9,100.0 5.00 307.50 7,422.8 2,471.0 - 3,219.9 2,589,192.39 328,851.07 61° 5 0.171 N 150° 58' 0.269 W 9,200.0 5.00 307.50 7,522.5 2,476.3 - 3,226.8 2,589,197.80 328,844.24 61° 5' 0.224 N 150° 58' 0.410 W 9,293.8 5.00 307.50 7,615.9 2,481.3 - 3,233.3 2,589,202.87 328,837.83 61° 5' 0.273 N 150° 58' 0.541 W 7 . 9,293.9 5.00 307.50 7,616.0 2,481.3 - 3,233.3 2,589,202.87 328,837.82 61° 5 0.273 N 150° 58' 0.542 W BHL @9293.9' MD; 7616, TVD,4103.6 FNL, 2217.3 FEL, SEC 36, T12N, R10W Targets Target Name - hit/miss target Di p Angle Dip a Di Dir. TV W D +NI-S +E /. North Easti Shape ( ") ( °) (ft) (ft) ; (ft) (ft) ; •(ft) Lattittarie Longitude A- 16wp13 M Drilling 1 0.00 0.00 5,851.0 2,387.3 - 3,110.8 2,589,107.10 328,958.94 61° 4' 59.347 N 150° 57' 58.050 W - plan hits target - Circle (radius 140.0) A- 16wp13 U Drilling T 0.00 0.00 6,891.0 2,442.7 - 3,182.9 2,589,163.53 328,887.57 61° 4' 59.893 N 150° 57' 59.518 W - plan hits target - Circle (radius 140.0) A- 16wp13 CI8 Drilling 0.00 0.00 4,253.0 2,090.3 - 2,713.1 2,588,804.38 329,352.20 61° 4' 56.424 N 150° 57' 49.964 W - plan hits target - Circle (radius 123.0) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name ( ") ( ") 4,483.0 3,416.0 9 5/8" 9 -5/8 12 -1/4 9,293.8 7,615.9 7" 7 7 -1/2 7/1/2008 2:05:43PM Page 6 COMPASS 2003.16 Build 42F 0 9 ConocoPhillips Planning Report - Geographic Database: EDM 2003.16 Single User Db Local Coordinate Reference: Well Plan: NCI A -16 Company: ConocoPhillips (Alaska) Inc. -Expl TVD Reference: Plan: A -16 @ 116.0ft ( Kuupik 5) Project: North Cook Inlet Unit MD Reference: Plan: A -16 @ 116.0ft (Kuupik 5) Site: North Cook Inlet Unit North Reference: True Well: Plan: NCI A -16 Survey Calculation Method: Minimum Curvature Wellbore: PIan:NCI A -16 Design: A- 16wp15 Formations Measured % Vertical Dip Depth Depth Dip Direction (ft) (ft) Name ' Lithology ( °) (1 6,066.7 4,455.0 Beluga -A 0.00 0.00 5,129.7 3,808.0 CI -1 0.00 0.00 4,730.5 3,566.0 Top Sterling 0.00 0.00 7,522.2 5,851.0 Beluga M 0.00 0.00 8,892.4 7,216.0 Beluga Ubase 0.00 0.00 8,004.0 6,331.0 Beluga Q 0.00 0.00 5,819.6 4,253.0 C.I. 8 0.00 0.00 5,169.3 3,832.0 C.I. 2 0.00 0.00 8,566.1 6,891.0 Beluga U 0.00 0.00 4,801.4 3,609.0 CI -A 0.00 0.00 5,572.5 4,078.0 CI -5 0.00 0.00 8,159.6 6,486.0 Beluga S 0.00 0.00 i Plan Annotations Measured Vertical Local Coordinates ■ Depth Depth = +N!-S +Et-W (ft} (ft) (ft) (ft) Comment 217.1 217.1 0.0 0.0 SHL: 1304.5 FNL, 4010.1 FEL, SEC 06, T11N, R09W 4,483.0 3,416.0 1,422.5 - 1,916.9 9 -5/8" @ 5162.2 FNL, 900.9 FEL, SEC 36, T12N, R10W 9,293.9 7,616.0 2,481.3 - 3,233.3 BHL @ 9293.9' MD; 7616, TVD,4103.6 FNL, 2217.3 FEL, SEC 36, T12 7/1/2008 2:05:43PM Page 7 COMPASS 2003.16 Build 42F ConocoPhillips (Alaska) Inc. -Expl North Cook Inlet Unit North Cook Inlet Unit Plan: NCI A -16 PIan:NCI A -16 A- 16wp15 • Sperry Drillin Services Clearance Summary Anticollision Report 01 July, 2008 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: North Cook Inlet Unit - Plan: NCI A -16 - PIan:NC1 A -16 - A- 16wp15 Well Coordinates: 2,586,436.84 N, 1,472,059.88 E (61° 04' 33.84" N, 150° 57' 02.83" W) • Datum Height: Plan: A -16 © 116.00ft (Kuupik 5) Scan Range: 0.00 to 9,293.79 ft. Measured Depth. Scan Radius is 1,107.68 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: AN wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services SURVEY PROGRAM ConocoPhillips (Alaska) Inc. -Expl I Date: 2008- 06- 27T00:00:00 Validated: Yes Version: 1 Engineering MD, interval: 25.00 Calculation Method: Minimum Curvature 217.00 To 9293.79 Depth From Depth To Survey /Plan Tool Error System: ISCWSA Centre Distance; 1107.68 217.00 1700.00 A- 16wp15 (PIan:NC1 A -16) GYD -GC -SS Scan Method: Tray. Cylinder North Plan: A- 16wp15 (Plan: NCI A- 16 /PIan:NCI A -1f 1700.00 9293.79 A- 16wp15 (PIan:NC1 A -16) MWD+SCC+SAG Error Surface: Elliptical Conic Warning Method: Rules Based A -13 PB1 Nom Colour To MD 0 VS Centre to Centre Separation 120 f 217 250 330 ' 180 /\ 30 -4 1 r , ' i ; - 250 500 _ r, \ .' NCIU A -11 L _. � ;. 1 �; '/ // r * NCIU B -0' NCIU B -01 • 500 750 % ��. i �� i . / �, �j� 9 I ' ' NCIU A - 11 joi. 300 ��\ �' 60 750 1000 ♦ � � =� J 1000 1250 d' ,, tiu 1250 1500 1A. IU A•141 y � / � \ �� = i NCIUA -10 � '�• � 4 , 1 �; { i aa �� 5. ah.�.�' 3° iClUA05 I / j ` / f ' 4 ` . \� � • 1500 1750 �S� i ir a < s /d ( 3 1 �°,� ' `1!'►J a., a a>7 ; t ` 11 11v io 1 , ‘ •',.;..:.... inq s ? _ 270 '. A � � /' 1750 2000 ` '. �' 3 %ii V \ �� I 4 % / �J �►� Mt r 0 : _� NCIU A -0i \ �� I0,,A g 0 i er' • 000 2500 VS . 174 r, F • I r � ,� S Plen: NCI A-14J f r r r- . ` ' prll /�u �,� 3500 4019► ; litt ,p'i� ri ,:i. NCIU A - 12' 240 � � � s ` QA /� � n ; ti 1PIIIn: NCI A -15 • 3000 4500 \ ' ► II r 1i. � z . c; `�s�f .t n d . -,5 ~ = Z ° + - NCIU A -04 ,�•• �� , ` `,, � �� 3500 5000 • ►� • ti � �E y ra , ,5 a •- h am •\ ,, . NCIU 8 03 � ` . t � ` , - 5000 6000lj�', y p NCIUA - 07, , 3000 7000 } I, � � � � ' , , mo t ,, t r ` R v�' Plan: NCI A45' L NCIU B -03 J 3, NCIUA 09 7 000 8000 �. 'IA.- i 3 . ` . 4 y4 ,1: _ " NCIU B -01 240 3000 9000 �\ \ 'C.,� i 4 P �,� , - =�• 120 Travelling Cylinder Azimuth (TFO+AZ1) 1 t /inI �� . , ' �f- ' a*�t � U B - 3000 10000 =tb.. ;+ r, � " - , ..15r ° e 'r - - 1 )000 12000 �� /4* r., 1' _ '' ' 1 ?000 14000 �i```\ 11 ( + y� 4 �! NCIU A -06 1 3000 16000 �� :�� a, - ' • f,a��" 13000 18000 210 /f" 150 NCIU B-03 l . -4 r o l -• ! , 13000 20000 • � , NCIU B-11 X 000 25000 180 NCIU A -131 NCIU A -13' L - SECTION DETAILS . Sec MD Inc Az: TVD +N / -S +E / -W DLeg TFace VSec Target 1 217.00 0.00 0.00 21700 0.00 000 0.00 000 000 2 45000 0.00 000 450.00 000 000 000 0.00 0.00 3 550.00 2.00 310.00 549.98 1.12 -1.34 2.00 310.00 1.74 NAD 27 ASP Zone 4 : WELL DETAILS: Plan: NCI A -16 4 680.00 2.00 310.00 679.90 4.04 x.81 000 0.00 6.28 5 947.35 9.00 255.00 945.96 1.62 -2862 3.00 -66.69 23.70 Water Depth. 101.00 6 1230.78 15.00 295.00 1223.51 11.41 -83.42 3.50 74.95 73.12 P 7 1663.35 31.12 290.00 1620.24 73.71 - 240.23 3 75 -9.28 235.46 +NI -S •EI -W Northing Easting Latittude Longitude Slot 8 2295.02 52.69 310.35 2089.72 295.76 - 590.75 4.00 40.38 648.72 0.00 0.00 2586436.84 1472059.88 61° 4' 33.842 N 150° 57' 2.834 W 9 5495.85 5269 310.35 4030.00 194364 - 2530.97 000 0.00 3191.29 10 5819.49 40.00 306.75 4253.00 2090.03 - 2713.17 4.00 - 169.65 3424.83 A- 16wp13 CI8 Drilling Target REFERENCE INFORMATION 11 6186.82 25.31 306.61 4561.43 2208.14 - 2871.66 4.00 - 179.75 3622.47 12 6309.75 25.31 306.61 4672.56 2239.47 - 2913.84 0.00 0.00 3675.01 Co-ordinate (N /E) Reference: Well Plan: NCI A -16, True North 13 7122.05 5.00 307.40 5452.52 2365.83 - 3083.11 2.50 179.80 3886.22 TVD Reference: Plan: A-16 A-16 (Kuupik 5) 14 7522.05 5.00 307.40 5851.00 2387.00 - 3110.81 0.00 0.00 3921.08 A- 16wp13 M Drilling Target Vertical (TVD) C ( P ) 15 7522.40 5.00 307.50 5851.35 2387.02 - 3110.83 2.50 90.05 3921.11 Section (VS) Reference: Slot - (0.00N, 0.00E) 16 8566.02 5.00 307.50 6891.00 2442.39 - 3182.99 0.00 0.00 4012.07 A- 16wp13 U Drilling Target Measured Depth Reference. Plan: A -16 @ 116.00ft (Kuupik 5) 17 9293.79 5.00 307.50 7616.00 2481.01 - 3233.32 0.00 0.00 4075.50 Calculation Method: Minimum Curvature ConocoPhillips (Alaska) Inc. -Expl HALLIBURTON North Cook Inlet Unit Anticollision Report for Plan: NCI A -16 - A- 16wp15 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: North Cook Inlet Unit - Plan: NCI A -16 - PIan:NCI A -16 - A- 16wp15 Scan Range: 0.00 to 9,293.79 ft. Measured Depth. Scan Radius is 1,107.68 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft North Cook Inlet Unit • NCIU A -01 - N COOK INLET UNIT A -01 - N COOK INI 225.00 85.81 225.00 84.22 225.00 54.052 Centre Distance Pass - Major Risk NCIU A -01 - N COOK INLET UNIT A -01 - N COOK INI 349.98 87.47 349.98 83.94 350.00 24.776 Clearance Factor Pass - Major Risk NCIU A -02 - N COOK INLET UNIT A -02 - N COOK INI 225.00 89.71 225.00 88.13 225.00 56.497 Centre Distance Pass - Major Risk 14.2 6 Clearance Factor Pass - Major Risk - - 8 Major A -02 - N COOK INLET UNIT A 02 N COO K INI 524.31 91.64 524.31 85.23 525.00 NCIU A -03 - N COOK INLET UNIT A -03 - N COOK INI 1,304.47 51.47 1,304.47 30.36 1,325.00 2.438 Centre Distance Pass - Major Risk NCIU A -03 - N COOK INLET UNIT A -03 - N COOK INI 1,327.97 51.68 1,327.97 30.02 1,350.00 2.386 Clearance Factor Pass - Major Risk NCIU A-04 - N COOK INLET UNIT A -04 - N COOK INI 499.55 85.00 499.55 78.62 500.00 13.318 Centre Distance Pass - Major Risk NCIU A -04 - N COOK INLET UNIT A -04 - N COOK INI 698.13 86.88 698.13 76.88 700.00 8.684 Clearance Factor Pass - Major Risk NCIU A -05 - N COOK INLET UNIT A -05 - N COOK INI 225.00 92.29 225.00 90.05 225.00 41.130 Centre Distance Pass - Major Risk NCIU A -05 - N COOK INLET UNIT A -05 - N COOK INI 524.24 94.26 524.24 86.32 525.00 11.864 Clearance Factor Pass - Major Risk NCIU A -06 - N COOK INLET UNIT A -06 - N COOK INI 524.16 80.28 524.16 73.84 525.00 12.479 Centre Distance Pass - Major Risk NCIU A -06 - N COOK INLET UNIT A -06 - N COOK INI 697.77 81.55 697.77 72.26 700.00 8.775 Clearance Factor Pass - Major Risk NCIU A-07 - N COOK INLET UNIT A -07 - N COOK INI 225.00 88.96 225.00 87.37 225.00 56.018 Centre Distance Pass - Major Risk NCIU A -07 - N COOK INLET UNIT A -07 - N COOK INI 449.97 90.08 449.97 84.70 450.00 16.763 Clearance Factor Pass - Major Risk NCIU A -08 - N COOK INLET UNIT A -08 - N COOK INI 450.00 82.08 450.00 76.61 450.00 15.014 Centre Distance Pass - Major Risk NCIU A -08 - N COOK INLET UNIT A -08 - N COOK INI 698.39 83.56 698.39 73.51 700.00 8.313 Clearance Factor Pass - Major Risk NCIU A -09 - N COOK INLET UNIT A -09 - N COOK INI 217.60 10.21 217.60 8.78 175.00 7.133 Centre Distance Pass - Major Risk • NCIU A -09 - N COOK INLET UNIT A -09 - N COOK INI 492.43 11.39 492.43 5.41 450.00 1.905 Clearance Factor Pass - Major Risk NCIU A -10 - N COOK INLET UNIT A -10 - N COOK INI 442.69 8.44 442.69 3.04 400.00 1.563 Centre Distance Pass - Major Risk NCIU A -10 - N COOK INLET UNIT A -10 - N COOK INI 517.55 8.99 517.55 2.34 ' 475.00 1.351 Clearance Factor Pass - Major Risk NCIU A -10 - N COOK INLET UNIT A -10A - N COOK It 442.69 8.44 442.69 3.04 400.00 1.563 Centre Distance Pass - Major Risk NCIU A -10 - N COOK INLET UNIT A -10A - N COOK It 517.55 8.99 517.55 134 475.00 1.351 Clearance Factor Pass - Major Risk NCIU A -11 - N COOK INLET UNIT A -11 - N COOK INI 217.70 7.87 217.70 6.18 175.00 4.639 Centre Distance Pass - Major Risk NCIU A - 11 - N COOK INLET UNIT A - 11 - N COOK INI 517.57 9.71 517.57 3.06 475.00 1.459 Clearance Factor Pass - Major Risk NCIU A -12 - N COOK INLET UNIT A -12 - N COOK INI 1,103.10 45.37 1,103.10 27.08 1,100.00 2.480 Centre Distance Pass - Major Risk NCIU A -12 - N COOK INLET UNIT A -12 - N COOK INI 1,128.01 45.50 1,128.01 26.71 1,125.00 2.421 Clearance Factor Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13 - N COOK INI 1,416.49 50.30 1,416.49 26.09 1,425.00 2.077 Centre Distance Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13 - N COOK INI 1,489.89 51.15 1,489.89 25.41 1,500.00 1.987 Clearance Factor Pass - Major Risk 01 July, 2008 - 12 :50 Page 2 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Expl HALLIBURTON North Cook Inlet Unit Anticollision Report for Plan: NCI A -16 - A- 16wp15 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: North Cook Inlet Unit - Plan: NCI A -16 - PIan:NCI A -16 - A- 16wp15 Scan Range: 0.00 to 9,293.79 ft. Measured Depth. Scan Radius is 1,107.68 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft NCIU A -13 - N COOK INLET UNIT A -13PB1 - N COO/ 1,416.54 49.27 1,416.54 22.41 1,425.00 1.834 Centre Distance Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB1 - N COO/ 1,514.46 50.88 1,514.46 21.15 1,525.00 1.711 Clearance Factor Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB2 - N COO/ 1,416.54 49.27 1,416.54 22.41 1,425.00 1.834 Centre Distance Pass - Major Risk • NCIU A -13 - N COOK INLET UNIT A -13PB2 - N COO/ 1,514.46 50.88 1,514.46 21.15 1,525.00 1.711 Clearance Factor Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB3 - N COO/ 1,416.54 49.27 1,416.54 22.41 1,425.00 1.834 Centre Distance Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB3 - N COO/ 1,514.46 50.88 1,514.46 21.15 1,525.00 1.711 Clearance Factor Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB4 - N COO/ 1,416.54 49.27 1,416.54 22.41 1,425.00 1.834 Centre Distance Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB4 - N COO/ 1,514.46 50.88 1,514.46 21.15 1,525.00 1.711 Clearance Factor Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB5 - N COO/ 1,416.54 49.27 1,416.54 22.41 1,425.00 1.834 Centre Distance Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB5 - N COO/ 1,514.46 50.88 1,514.46 21.15 1,525.00 1.711 Clearance Factor Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB6 - N COO/ 1,416.54 49.27 1,416.54 22.41 1,425.00 1.834 Centre Distance Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB6 - N COO/ 1,514.46 50.88 1,514.46 21.15 1,525.00 1.711 Clearance Factor Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB7 - N COO/ 1,416.54 49.27 1,416.54 22.41 1,425.00 1.834 Centre Distance Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB7 - N COO/ 1,514.46 50.88 1,514.46 21.15 1,525.00 1.711 Clearance Factor Pass - Major Risk NCIU B -01 - N COOK INLET UNIT B -01 - N COOK INI 1,059.32 24.55 1,059.32 9.66 1,075.00 1.649 Clearance Factor Pass - Major Risk NCIU B -01 - N COOK INLET UNIT B -01A - N COOK!! 1,059.32 24.55 1,059.32 9.66 1,075.00 1.649 Clearance Factor Pass - Major Risk NCIU B -02 - N COOK INLET UNIT B -02 - N COOK INI 760.40 57.51 760.40 47.39 775.08 5.685 Centre Distance Pass - Major Risk NCIU B -02 - N COOK INLET UNIT B -02 - N COOK INI 809.80 58.03 809.80 47.13 825.00 5.323 Clearance Factor Pass - Major Risk NCIU B -02 - SUNFISH 3 - SUNFISH 3 760.40 57.51 760.40 47.82 775.08 5.939 Centre Distance Pass - Major Risk NCIU B -02 - SUNFISH 3 SUNFISH 3 809.80 58.03 809.80 47.56 825.00 5.543 Clearance Factor Pass - Major Risk NCIU B -03 - N COOK INLET UNIT B -03 - N COOK INI 1,290.75 28.47 1,290.75 9.60 1,300.00 1.509 Clearance Factor Pass - Major Risk NCIU B -03 - N COOK INLET UNIT B -03PB1 - N COO/ 1,290.75 28.47 1,290.75 9.60 1,300.00 1.509 Clearance Factor Pass - Major Risk Plan: NCI A - 14 - PIan:NCI A - 14 - A - 14wp17 450.00 4.01 450.00 1.75 450.00 1.774 Centre Distance Pass - Minor 1/200 Plan: NCI A -14 - Plan:NCI A -14 - A- 14wp17 499.98 4.14 499:98 1,57 500.00 1.614 Clearance Factor Pass - Minor 1/200 Plan: NCI A -15 - PIan:NCI A -15 - A- 15wp15 450.00 7.53 450.00 5.27 450.00 3.330 Centre Distance Pass - Minor 1/200 Plan: NCI A -15 - PIan:NCI A -15 - A- 15wp15 474.95 7.59 474.95 5.19 475.00 3.163 Clearance Factor Pass - Minor 1/200 01 July, 2008 - 12 :50 Page 3 of 6 COMPASS Conocon.._ _ HALLIBURTON North Anticollision Report for Plan: NCI A -16 - A- 16wp15 Survey tool proaram From To Survey /Plan Survey Tool ( ft) (ft) 217.00 1,700.00 A- 16wp15 GYD -GC -SS 1,700.00 9,293.79 A- 16wp15 MWD +SCC +SAG • Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. • , Page 4 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Expl HALLIBURTON North Cook Inlet Unit Anticollision Report for Plan: NCI A -16 - A- 16wp15 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan: A -16 @ 116.00ft (Kuupik 5). Northing and Easting are relative to Plan: NCI A -16. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is - 150,00 °, Grid Convergence at Surface is: -0.83 °. -=- NCIL A -01, N COOKINLEI UNIT A -D1, N COOK INLET UNIT Ladder Plot -e- NCIL A -02, N COOK INLET UNIT A -02, N COOK INLET -e- NMI A -03, N COOK INLET UNIT A -03, N COOK INLET UN i , NCR A -04, N COOK INLET UNIT A-04, N COOK INLET UNIT I I I O NCR A- 05,NCOOK INLET UNIT A- 05,N COOK INLET UNi 1 1 I 1 I n 1 o NCIL A -06,N COOK INLET UNIT A- 06.N COOK INLET UNi 1050 ' h U p NCIL A•07, N COOK INLET UNIT A -07, N COOK INLET UN i 1 ra Fr I 1 NCIL A -08, N COOK INLET UNITA -08, N COOK INLET UN i O m I I � �; � NCIL A -00, N COOK INLET UNIT A -09, N COOK INLET UN i - ! _ i -- 1 I I NCIL A -10, N COOK INLET UNIT A -10, N COOK INLET UN i , � 1 O I I �� ! ; I 1 1 I NCIL A -10, N COOK INLET UNIT A -10A, N COOK INLET U II" , I 1 i I 1 ` ' •' j 1 1. 1 1 { ` 0 1 NCIL A- 11, N COOK INLET UNIT A- 11.N COOK INLET UNi 700 i!V 1 NCIL A -12, N COOK INLET UNIT A -12, N COOK INLET UNIT 4 NCIL IL A -13, N COOK INLET UNIT A -13, N COOK INLET UN i NCA -13,N COOK INLET UNITA- 13PB1,NCOOKINLETL I ' 1 NCILA- 13NCOOKINLETUNITA- 13PB2,NCOOKINLETL 0) � A' 1 I f IL 1 1 NCA -13,N COOK INLET UNIT A- 13PB3,N COOK INLET L (,_) I , .1 j �Z /' + I ; ' I I I - NCR A- 13, N COOK INLET UNIT A- 13PB4,N COOK INLET L 0 350 IV .V 4) 1 I 11; : , : - ' I I I NCIL A -13,N COOK INLET UNIT A-13 P B5 ,N COOK INLET L 1 NCILA -13,N COOK INLET UNIT A-13 P 86 ,N CO OK INLET L III • 1 I I I 1 f . ' ; ' X ,1 I I I I I U 1 ifs r �� r 1•' : I 1 I I NCIL A -13,N COOK INLET UNIT A- 13PB7,N COOK INLET L '' // 1 1 I i NCIL B-01, N COOK INLET UNIT B-01, N COOK INLET UN i "i' a I I I I »;^' I I 1 1 I NCIIB- 01, N COOK INLET UNIT B- D1A,N COOK INLET UWI" 0' I I I I I NCI'. 9-02, N COOK INLET UNIT 8.02, N COOK INLET UNIT 0 1500 3000 4500 6000 7500 -e- NCII B- 02, SUNFISH 3,SUNFISH3 V0 Measured Depth (1500 ft/in) NCR B -03, N COOK INLET UNIT B -03, N COOK INLET UN i �- NCIL B -03, N COOK INLET UNIT 9-03P 81, N COOK INLET L --*- Plvn•Nr1A.1a Plan•Nr1 a- tdwnl7 Lel 01 July, 2008 - 12:50 Page 5 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Expl HALLIBURTON North Cook Inlet Unit Anticollision Report for Plan: NCI A -16 - A- 16wp15 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor `� / N IUA -01,N COOK INLET UNITA -01,N COOK INLET UNIT A- - I! N IU A -02, N COOK INLET UNIT A -02, N COOK INLET UNIT A- . _ 1 1_, _,;_ - i , x _ ____._.- -_____ ___.___ _-_____-_-_-_ _,_..,_- �_____•______ »_-_,_�_ -_ N IU A -03,N COOK INLET UNITA -03,N COOK INLET UNIT A- _ M � r ! r ►1 - €i--iN IU A -04,N COOK INLET UNIT A -04,N CO OK INLET UNIT A- ti 1 1' 0. ' -4 -' N IU A -05,N COOK INLET UNIT A -05, N COOK INLET UNIT A- 575 i " * 1 Zu '� r - N IU A•06,N COOK INLET UNITA -06,N OOK INLET UNITA- _ i ii i -�i 44- N IUA -07,N C INLET UNITA -07,N COOK INLET UNITA- _ (l • f N IU A -08, N COOK INLET UNIT A -08, N COOK INLET UNIT A- +ll +ll I. .4- N IU A-09, N COOK INLET UNIT A•09,NCOOK INLET UNIT A- c* _ 1 f . -A- N I U U N I T C O U N I T cy _ r X-- N IU A -1D, COOK INLET UNITA -10A, N COOK INLET UNIT -. I -}- N I U IUA -12,N COOK INLET UNIT A-12,N COOK INLET UNIT A- " - +i � ; f C 5.00 _ __ -�_ N IUA -13,N COOK INLET UNIT A -13,N COOK INLET UNIT A- -. - k - • ! N IUA -13,N COOK INLET UNIT A- 13PB1,N COOK INLET UN to 1 ; N IU A -13,N COOK INLET UNITA•13PB2,N COOK INLET UN n ;75 - flp i fT I N IUA -13, COOK INLET UNITA•13PB3,N COOK INLET UN _ ; 1 I --- N IUA -13,N COOK INLET UNITA- 13P94,N COOK INLET UN _ I. t ' ; ', e N IU A -13,N COOK INLET UNITA- 13PB5,N COOK INLET UN i (! N IU A -13,N COOK INLET UNITA- 13PBB,N COOK INLET UN - I 1, 14 � L I ° Y N IU A -13,N COOK INLET UNITA•13PB7,N COOK INLET UN - - ` * N IUB -01,N COOK INLET UNIT B- D1,N COOK INLET UNIT B- IN IU 9.01,N COOK INLET UNIT B•01A, N COOK INLET UNIT 1 -40- IN IU 8.02,N COOK INLET UNIT B -02,N COOK INLET UNIT B- - j 1 -1D-IN IU B-02, SUNFIS H 3, SUNFISH 3 V0 - •- - I I' I 1I I I I I I 1 1 1 I I' 1I I I' I I I I I I I I 1 1 1 1 I 1 1 1 1 1 1 l I l I 1 1 1 I 1 1 1 1 I 1 1 1 1 1 I 0 750 1500. - -5 - 3000 374 0500 5.0 • 5 3v0V 37 d@ 750,0 e s , - _ N IU 8.03.N COOK INLET UNIT B -03,N COOK INLET UNIT B- Measured Depth (1500ftlin) -- N IU 9.03,N COOK INLET UNIT B- 03PB1,N COOK INLET UN -4- P n NI:I A -14 PIan•NV;l A -14 A- 141n17 V 01 July, 2008 - 12 :50 Page 6 of 6 COMPASS I • 0 S 7 F r 7 I gar (RA , 4 U J [ L 1 \ [) /\ ' 1) LS ±, SARAH PALIN, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION / ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 C. Alvord FAX (907) 276-7542 Drilling Team Lead ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 -0360 Re: North Cook Inlet Field, Tertiary System Gas Pool, NCIU A -16 ConocoPhillips Alaska Inc. Permit No: 208 -098 Surface Location: 1304' FNL, 1016' FWL, SEC. 6, T11N, R9W Bottomhole Location: 4104' FNL, 2217' FEL, SEC. 36, T12N, R1 OW Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. ConocoPhillips assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, 6 ' Daniel T. Seamount, Jr. >~ J Chair DATED this ? day of July, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA RECtivLu ALA OIL AND GAS CONSERVATION COMOSION PERMIT TO DRILL '` C l JUN 1 2 2008 20 AAC 25.005 ,qs� b O;! P ( la. Type of Work: 1b. Current Well Class: Exploratory ❑ Development Oil El lc. Specify if we propos" d is Th ,- Co mmission Drill 0 . Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas All Coalbed Methane ❑ An, C s vdrates ❑ Re -entry ❑ Multiple Zone 151 ' Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska Inc. Bond No. 5952180 NCIU A -16 • 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 -0360 MD: 9298 TVD: 7616 North Cook Inlet 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1304' FNL 1016' FWL SEC 6 T11N R9W • ADL 17589 / ADL 37831 ' Tertiary System Gas Pool • Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4988' FNL 1100' FEL SEC 36 T12N R10W N/A 7/1/2008 Total Depth: 9. Acres in Property: 14. Distance to Nearest 4104' FNL 2217 FEL SEC 36 T12N R10W 3326 (ADL 37831) • Property: 2184' (ADL 17589) 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface: x- 332035 y- 2586675 Zone- 4 (Height above GL): 116 feet . Within Pool: 1826' (NCIU A -01) . 16. Deviated wells: Kickoff depth: o' met x. /6.07. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 54 degrees Downhole: 3744 psi ° Surface: 2600 psi 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) NA 30" 354 46 46 400 400 Existing 12 1/4" 9 5/8" 40# L -80 BTCM 4486 46 46 4532 3416 2026 sx 12 ppg Lightweight 8 3/4" 7" 26# L -80 BTCM 9252 46 46 9298 7616 357 sx 10.5 ppg Lightweight 4 1/2" 12.6# L -80 IBTM 4738 46 46 4784 3566 Production Tubing 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 TVD Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee 0 BOP Sketch 0 Drilling Program Ea Time v. Depth Plot❑ Shallow Hazard Analysis ❑ Property Plat IS Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Programs 20 AAC 25.050 requirements IS 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact P. Hayden Printed Name C. Alvord Title Drilling Team Lead Signature "i � ; ry r /'6 4 ! c �, r /� Phone 6S - �' ' Date C� Z� r s Only Commission Use y Permit to Drill API Number: Q Permit Approv See cover letter for other Number: 50- oes - 2412_7-0o Date: q- 1- . C3 requirements. Conditions of approval :If box is checked, well may not be used to explore for, test, or produce of3albed methane, gas hydrates, or gas contained in shales: g Other. bi r V. . ,. ` \ILS 1 . \ Li k-C 0\ �`�, Samples r_eq'd: Yes No[✓� Mud log req'd: Yes ❑ No[v] ] , t H measures: Yes No OK Directional svy req'd: Yes No 3SC '� ■ C'> �. C? °=,\ 1vh.\c v 1. \ \.,∎ 1 �� (� r, \ l', (N �t✓ C)( < '\ Q�c. VN, Gc. z.N.,, `) `(c�� ..--.'''--- APPROVED BY THE COMMISSION 7/2/7 DATE: / , COMMISSIONER Form 10 -401 Revised 12/2005 1 ! N f !\ L S i uplicate —.. i. \ i G l.� 6. /G_' ,,,„<„,,,,25;, ConocoPhillips Alaska, Inc. Post Office Box Anchorage, Conoco Phillips Anchooraage e, Alaska ka 995 99510 -0360 Telephone 907 -276 -1215 June 10, 2008 y .. Alaska Oil and Gas Conservation Commission JUN ; 2008 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Akid,a ull va UP is arc i n. orb issio Re: Application for Permit to Drill: NCIU A -14, Planned spud 7/15/08 NCIU A -15, Planned spud 7/8/08 ::ft4CIV A- 16,xPCahlned spud 711108 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill three offshore development gas wells from the Tyonek platform in the Cook Inlet. The wells are designed to penetrate the Beluga sands, log, evaluate and be completed as gravel pack gas producers. Please note that due to the fact that we are drilling from a platform we are unable to meet the requirement set out in 20 AAC 25.035 (c) (2) (C) (ii) that the diverter vent line extend to a point at least 75 ft beyond the drill rig substructure. While drilling on diverter the vent line will extend beyond the rig substructure and the platform structure but will not meet the above requirement. In addition we propose to test the BOPE to 3500 psi during the drilling phase of this program, raising this to 5000 psi when completion operations begin. The higher completion test pressure is due to the planned high formation treatment pressures. Please find attached for the review of the Commission Forms 10 -401 and the information required by 20 ACC 25.005 for these wells. If you have any questions or require further information, please contact Philip Hayden at 265 -6481 or Chip Alvord at 265 -6120. S' ce ly, . Philip ay. : 1 Drilling Engineer cc: NCIU A -14 Well File NCIU A -15 Well File NCIU A -16 Well File Chip Alvord ATO -1570 Mark Chambers ATO -1566 John Braden ATO -1392 Marta Czarneski Kenai LNG plant • Application for Permierill, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 Permit It - NCIU Wells A -14, A -15, A -16 Application for Permit to Drill Document MoxWell M c'xirnize Well Value Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005 (t) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005 (c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 5 Requirements of 20 AAC 25.005 (c)(5) 5 6. Casing and Cementing Program 5 Requirements of 20 AAC 25.005(c)(6) 5 7. Diverter System Information 7 Requirements of 20 AAC 25.005(c)(7) 7 8. Drilling Fluid Program 7 Requirements of 20 AAC 25.005(c)(8) 7 9. Abnormally Pressured Formation Information 8 Requirements of 20 AAC 25.005 (c)(9) 8 10. Seismic Analysis — g— Requirements of 20 AAC 25.005 (c)(10) 8 11. Seabed Condition Analysis 8 Requirements of 20 AAC 25.005 (c)(11) 8 12. Evidence of Bonding 8 Requirements of 20 AAC 25.005 (c)(12) 8 Tyonek 2008 PERMIT IT.doc Page 1 of 19 Printed: 9- Jun -08 OR131NAL • Application for Permit tdfl, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9-Jun-08 13. Proposed Drilling Program 9 Requirements of 20 AAC 25.005 (c)(13) 9 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 11 Requirements of 20 AAC 25.005 (c)(14) 11 15.Attachments 11 1. Well Name Requirements of 20 AA C 25.005 (t) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The wells for which this Application is submitted will be designated as: NCIU A -14 NCIU A -15 ' NCIU A -16. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the fo /lowing items, except for an item already on file with the commission and identified in the application; (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; We I I A -14 A -15 A -16 RKB Elevation (ft AMSL) 116 116 116 1302' FNL, 1311' FNL, 1304' FNL, Section Lines 1019' FWL, 1018' FWL, 1016' FWL, Location at Section 6, Section 6, Section 6, Surface T11 N, R9W, T11 N, R9W T11 N, R9W ASP Zone 4 2586677 N, 2586668 N, 2586675 N, NAD 27 332038 E 332037 E 332035 E Coordinates 4303' FNL, 2904' FNL, 4988' FNL, Section Lines 2661 FEL, 2752' FEL, 1100' FEL, Section 31, Section 6, Section 36, T-12N, R9W- T11 N,_ R9W _- _ _T.12N, R10W_ _– — _.___ Location at ASP Zone 4 2588937 N, 2585057 N, 2588302 N, Top Cook NAD 27 333410 E 333274 E 329942 E Inlet Coordinates True Vertical 3599 3591 3566 Depth (ft) Measured 4892 4458 4784 Depth (ft) Tyonek 2008 PERMIT 1T.doc Page 2 of 19 ' 6 2 e� B . ; Printed: 9- Jun -08 Application for PermeriII, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 4001' FNL, 4874' FNL, 4104' FNL, Section Lines 1045' FEL, 1318' FEL, 2217' FEL, Section 30, Section 6, Section 36, T12N, R9W T11 N, R9W T12N, R1 OW Location at ASP Zone 4 2594495 N, 2583067 N, 2589202 N, TD NAD 27 335092 E 334684 E 328838 E Coordinates True Vertical 7916 7741 7616 Depth (ft) Measured 12277 9285 9298 Depth (ft) and (D) other information required by 20 AAC 25.050(6); Requiremen of 20 AAC 25.050(b) If a well is to be i ntentionally deviated, th application for a Permit to Drill (Form 10 -401) must (1) include a plat, drawn to a suitable scale, showing The path of the proposed wel /bore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1 for the Directional Plans and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AA C 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (ROPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 RAC 25.037, as applicable; An API 13 -5 /8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete all three wells. Please see Attachment 2 for details on this equipment. It is our intention to test the BOPE to 3500 psi during the drilling phase of operations and increase this to 5000 psi during completion. The higher completion test pressure is due to the high treatment pressures of the completion operations (reverse circulating after screen out of the gravel pack). 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the Cook Inlet sands in the area of interest are expected to be as low as 0.1 psi /ft, or 2 ppg EMW (equivalent mud weight). In the Beluga sands the expected pore pressure • ranges from 0.312 to 0.44 psi /ft. (6 to 8.5 ppg EMW). These pressures are based on actual field pressure measurements taken in existing wells. Maximum Anticipated Surface Pressure and Casing Design: The following information is used for calculation of the maximum anticipated surface pressures for the planned well: Tyonek 2008 PERMIT IT.doc Page 3 of 19 G i Printed: 9,lun -08 1. 1\l • Application for Permit tl, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 Casing Size Casing Setting Depth Maximum Pore Pore Pressure MASP Drilling Pressure Gradient 30" 400' MD / 400' TVD 8.6 ppg 180 NA 9 -5/8" 3600' TVD 9.0 ppg 1685 206 psi 7" 8000' TVD 9.0 ppg 3744 2600 psi Expected Maximum Mud Weights: • 12 -1/4" surface hole to 3600' TVD (maximum): 10.0 ppg MW, pore pressures of up to 9.0 ppg may be present. • 8 -3/4" production hole to 8000' TVD (maximum): 9.6 ppg. The pore pressure is not expected to be above 9 ppg from offset drilling data and depletion due to production Procedure for Calculating Maximum Anticipated Surface Pressure: MASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point Tess a gas gradient to the surface as follows: 1) MASP = [(FG x 0.052) — 0.11] x D Where: MASP = Maximum Anticipated Surface Pressure FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion factor from lb/gal to psi /ft 0.11 = Gas Gradient in psi /ft (above 10,000' TVD) D = True vertical depth to casing seat in ft from RKB OR 2) MASP = FPP — (0.11 x D) Where: FPP = Formation Pore Pressure at the next casing seat MASP Calculations 1. Drilling below 30" Conductor Casing MASP = [(FG x 0.052) — 0.11] x D = [(12.0 x 0.052) — 0.11] x 400' =206 psi OR MASP = FPP — (0.11 x D) = 1685 — (0.11 x 3600') = 1289 psi 2. Drilling below 9 -5/8" Surface Casing MASP= [(FG x 0.052) — 0.11] x D = [(16 x 0.052) — 0.11] x 3600' = 2600 psi OR MASP = FPP — (0.11 x D) = 3744 — (0.11 x 8000') 5 f i , k Tyonek 2008 PERMIT IT.doc a� t I Page 4of19 - y� Printed: 9- Jun -08 S Application for Perrri "Drill, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 = 2864 psi (8) data on potential gas zones; All the wells are planned to be gas producers. There should be no gas zones above the top of the Cook Inlet formation. and (C) data concerning potential causes of hole problems such as abnormaly geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Well Proximity Risks: Due to the close well spacing of the wells on the platform and the congestion immediately underneath the conductors there are several well proximity risks.. The following tabulates the proximity risks and some of the mitigating measures to be used when drilling these three wells: Drilling Does plan Well(s) at Status of Close Approach Wireline Tubing & Annuli Well: pass Major Risk Wells at Risk Depth (ft TVD) plugs set annuli Monitoring Risk? in tubing bled down A -16 Yes None NA NA NA NA NA A -15 No A -09 Producing 467 Yes Yes Yes A -10A Producing 468 Yes Yes Yes A -14 No A -11 P&A'd 743 No No Yes A -16 Surface Pipe 425 -500 NA NA Yes In addition to the above the probability of collision is reduced by: 1. A high accuracy gyro MI be used when drilling the surface hole of all three wells in order to closely monitor their trajectories 2. Wells with proximity risks have been resurveyed using a high accuracy gyro to verify their position with respect to the planned well paths. Wells resurveyed are: a. A -09 . b. A -10A c. A -11 d. A -13 3. Rig site anti- collision diagrams (traveling cylinders) will be prepared 4. Close approach will be discussed and highlighted in the well plan, at pre -spud meetings, and rig site planning, daily ops and tour meetings For other drilling hazards please see Attachment 3. 5. Procedure for Conducting Foomattoni Integrity/Vests Requirements of 20 AAC 25.005 (c) (5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission, and identified in the a;plication: (5) a description of the procedure 16r conducting formation integrity test as required under 20 AAC 25:030(0; All wells will be completed with 9 5/8" intermediate casing landed above the Cook Inlet. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program] Requirements of 20 AAC 25.005(c)(6) An app / /cation for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application; Tyonek 2008 PERMIT IT.doc 1 1 � r Printed -Jun- 8 Application for Permit to rill, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre - perforated liner, or screen to be installed; Casing Design Performance Properties Internal Tensile Strength Size Hole Weight Grade Conn. Yield Collapse Joint Body 30" NA 9 -5/8" 12.25 40 ppf L -80 BTCM 5750 psi 3090 947 M 916 M 7" . 8.75 26 ppf L -80 BTCM 7240 psi 5410 641 M 604 M Casing Setting Depth Rational: 30" @ 400' TVD RKB Conductor casing (platform leg pile) provides sufficient anchor for diverter system and subsequent wellhead. 9 -5/8" © 3450' TVD RKB Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling 8 -3/4" hole through the reservoir sands 7" @ 7600 - 8000' TVD RKB Production casing is near the bottom of the Beluga sands to provide pressure integrity and zonal isolation. Cementing Program: 9 5/8" Surface Casing Cement from surface hole TD to surface with a lightweight 12 ppg slurry. Assumed 100% excess annular volume. Slurry Density 12.0 Yield (ft /sack) 2.1 Volumes ft /ft 400 ft 30" Conductor 4.08 12 1 /4" Open hole (add 100% excess) 0.3132 Shoe track 0.4257 System: Type I Cement + 0.9% bwoc BA -90 + 0.05% bwoc Static Free + 25% bwoc LW -6 + 0.6% bwoc CD -32 + 0.1% bwoc FL -52 + 1 gal /100sk FP -6L + 0.4% bwoc Sodium Metasilicate + 5% bwoc MPA -1 + fresh water 7" Production Cement from production hole TD to 500' MD above the Top of the Cook Inlet formation with Lightweight 10.5 ppg cement. Assume 40% excess annular volume. Slurry • Density 10.5 Tyonek 2008 PERMIT IT.doc ! , a t ;, Page 6 of 19 Printed: 9- Jun -08 Application for PermiSri II, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 Yield (ft /sack) 2.99 Volumes ft /ft 9 5/8" Cased hole 0.1585 8 3 /4" Open hole (add 40% excess) 0.1503 Shoe track 0.2148 System: Class G Cement + 15% bwoc BA -90 + 0.05% bwoc Static Free + 1% bwoc CD -32 + 1.2% bwoc FL -52 + 1 gals /100 sack FP -6L + 0.6% bwoc Sodium Metasilicate + 22% bwoc LW -7 -6 + Fresh Water If there are problems with lost circulation during drilling, logging or tripping, consideration will be made to including a hydraulic opening stage tool in the casing string to help ensure cement coverage of the Cook Inlet formation. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC25.035(h)(2); A 21 -1/4 ", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of these wells. Please note that due to the fact that we are drilling from a platform we are unable to meet the requirement set out in 20 MC 25.035 (c) (2) (C) (ii) that the diverter vent line extend to a point at least 75 ft beyond the drill rig substructure. While drilling on diverter the vent line will extend beyond the rig substructure and the platform structure but will not meet the above requirement. Please see Attachment 2 for details of the diverter arrangement. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling Fluid Program Surface Interval Fluid Properties Funnel API Fluid Drill Interval Mud Wt. Viscosity Yield Point Lo pH Solids MBT (lb/gal) (cp) (Ib /100ft) (m1/30min) ( %) 0- 150'TVD above Cook - 8.8 - 10 - 50 - 90 -- - - - - 30 - 40 - NC - <10 - +/- 9.5- < 7% <35 Inlet Tyonek 2008 PERMIT IT.doc 11 ! 19 N L Page 7 of Printeed: 9 Ju of 08 • Application for Permit tiT6rill, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 Production Interval Fluid Properties Mud Wt. Yield Point API Fluid Solids Interval (PP9) 6 RPM (Ib/100ft2) (ml /30min) pH ( %) Surface: Casing 9.2 — 9.6 10 18 - 25 <6 9.0 — 9.5 <5 to TD Surface Hole: - A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec /qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: The Production Interval mud system will be an inhibitive water based mud system. The primary inhibitors are NaCI &KCI, which will be maintained at 10% and 2% by wt respectively, and a proprietary shale inhibitor designed to enhance the inhibition of of the salts as well as provide inhibition on it's own. Other components of the system are Well Bore Strengthening materials designed to prevent lost circulation in low pressure depleted zones of the upper hole section while drilling to TD for long string casing. The system also includes additives for aiding in the stabilization of coal seams and minimizing fluid invasion to prevent reservoir damage. If well control becomes an issue, enough barite to increase the mud weight by one pound per gallon will be on location at all times. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see Attachment 4 for diagrams and descriptions of the fluid system of Kuukpik 5. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo pressurectstrata as required by 20 AAC25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10.Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item a /ready on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom- founded structure, jack -up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25061(6); Not applicable: The wells are being drilled from the Tyonek platform. The 30" conductors are preinstalled and there are no plans for conducting work on the sea bed. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: Tyonek 2008 PERMIT IT.doc Page 8 of 19 . 1` Printed: 9- Jun -08 A ft Application for Perm Jrill, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 (12) evidence showing that the requirements of 20 AAC 25.025 (Bonding)have been met; Evidence of bonding for ConocoPhillips Alaska, Inca is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematics. General Procedure: 1. Mobilise Kuukpik Rig 5 over well room #2. 2. Skid to the relevant well(s) and with wireline, set downhole plugs in existing wells that fail to pass Major Risk for anti - collision. 3. Skid rig substructure over well to be drilled. 4. Install diverter on existing 30" conductor & function test same. Notify regulatory agencies 48 hours prior to test. 5. Spud well and drill 12 1/4" hole to the surface casing point at N 150ft TVD above the Cook Inlet sands. Run MWD / LWD logging tools (GR/RES) in drill string as required for directional monitoring and formation data gathering. 6. Condition hole for casing, trip out. 7. Run 9 5/8" 40# L80 BTCM casing string to TD and land same. 8. RU false rotary and PU & RIH with cement stinger. Cement surface casing through cement stinger. • Employ lightweight cement slurry to ensure cement returns to surface. Returns will be monitored during the cement job to make sure the casing is cemented to surface. 9. POOH with cement stinger & ND diverter. 10. Skid to the relevant well(s) and recover downhole plugs with wireline. 11. Repeat steps 2 to 10 for all three surface hole sections. 12. After cementing the third surface casing ND the diverter. 13. Skid to the next well and nipple up BOP's. Test BOP's. Notify all regulatory agencies 48 hours prior to test 14. Make up 8 3 /4" bit and BHA and RIH to top of float equipment. • Pressure test casing to 3000 psi for 30 minutes • Record results and fax to town 15. Drill float equipment and approximately 20' of new hole • Perform LOT (or FIT if gradient reaches 16 ppg equivalent) • Record results and fax to town 16. Drill 8 3 /4" hole to TD. Run MWD / LWD (GR / RES / DENS / POROSITY) logging tools in drill string as required for directional monitoring and formation data gathering. POOH with drilling assembly. • Condition hole and mud for logging operations. 17. Log 8 3 /4" open hole with electric line tools (SP /SBL, DSI, FMI, RSWC, MDT). Tyonek 2008 PERMIT IT.doc Page 9 of 19 n ` � 1 .\ ! Printed: 9- Jun -08 � . Application for Permit tI, Wells NCIU A -14, A -15, A -16 Revision No.O - Saved: 9- Jun -08 18. Run and cement 7" casing per program to TD. Cement casing to bring cement +/- 500' above Cook Inlet sand. • If there are signs of lost circulation prior to running casing, a Haliiburton HES stage cementing tool may be used. 19. RIH with a 4 1/2" kill string and land the tubing hanger in the wellhead. Test the casing to 3000 psi. Set BPV in the tubing hanger. ND the BOPs and NU a dry tree. 20. Repeat steps 13 to 19 for all three production hole sections. 21. Skid to the next well. 22. ND the dry tree, NU the BOPs & test. Retrieve the BPV. Pull the kill string. 23. Run in hole with casing cleanup assembly on drilipipe. 24. Clean casing and pickle drillpipe. 25. Displace well to clean filtered brine. 26. Test casing to 5000 psi. 27. Rig up eline and run cement bond log GR / CCL. 28. Pick up and run in hole with tubing frac string (4 -1/2" tubing). 29. Set tubing in slips, close pipe rams, and rig up electric line 30. Perforate with wireline tools 31. Fracture Stimulate 1 zone 32. Sand Back 33. Repeat perforating and fracturing 2 -3 times as needed 34. Clean out proppant 35. POOH with tubing frac string 36. Pick up tubing conveyed perforating guns on drillpipe. 37. Perforate with large hole perforations- 4 -5/8" guns 38. Run Conventional gravel pack equipment with 2 -7/8" inner string to gravel pack lower interval. 39. Pump high rate water pack (HRWP). 40. Run inner string to isolate pack. 41. Continue with conventional / multizone gravel packing operations as planned for the relevant well. 42. Run Upper completion per completion schematics. (Latch into anchor, shear PBR, space out, etc.) 43. Land tubing and test tubing hanger. 44. Test inner annulus to 2500 psi for 30 minutes. (Note: This will test our tubing integrity.) 45. Pressure up on IA to shear SOV at 3000 psi. 46. Set BPV and ND BOP. 47. Nipple up tree and test same. 48. Repeat steps 21 to 47 for all three wells. 49. RDMO. Tyonek 2008 PERMIT IT.doc OM G Page10of19 Printed: 9- Jun -08 Application for Perm.Drill, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the app lication: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well; Waste fluids generated during the drilling process will be disposed of by discharge to the Inlet. The mud has been formulated and tested to meet the requirements of EPA NPDES permit number AKG -31 -5000. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments • Attachment 1 Directional Plans • Attachment 2 BOPE and Diverter • Attachment 3 Drilling Hazards Summary • Attachment 4 Fluid System • Attachment 5 Well Schematics Tyonek 2008 PERMIT IT.doc Page 11of19 . k Printed: 9- Jun -08 Application for Permit till, Wells NCIU A-14, A-15, A-16 Revision No.O Saved: 9-Jun-08 Attachment 1. Directional Plans • • . DJ)" o" - T I ASP 2dNE 4 NAD81, FEET NAD83 GEOGRAPHIC - 1 MLLW _.__ DESCRIPTION - 36 31 31 32 . z A e ( POINT NO.) I NORTHING EASTING LATITUDE LONGITUDE ELEVATION NCIU WELL TAG NO. T 12 N 4 R / L WELL HOUSE NO. 1 y _ _7001 2586492 1472018 61 04 3438 150 57 03.71 72.0 CONDUCTOR 1 9 4. 1 1 6 T 11 N 6 -..__ -T 5 & � j. 10 02 2586489 1472017 61 04 34.34 150 57 03.72 73.8 63 N 4 ' 1 9 11003 2586485 1472019 61 04 3431 150 57 0167 74.1 Al2 ne w� � 0 1004 2586485 1472023 61 04 34.31 150 57 03.59 73.8 01 ar` Ni° .0 1005 2585487 1472027 ! 61 04 34.33 150 57 03.52 72.0 CONDUCTOR 5' c . S 1006 2586491 1472027 161 04 34.37 150 57 03.52 73_7 82 C1 g 1007 2586495 1472025 61 04 34.41 150 57 03.57 721 CONDUCTOR 7 1206 Dc .10082566495 1472021 61 04 34.41 150 57 03.65 73.7 - A13 WELL HOUSE NO. 2 2001 I 25864.37 1472060 1 81 04 33.84 150 57 02.133 71.9 CONDUCTOR 1 2002 I 2586433 I 1472059 61 04 03.38 150 57 02.84 71.9 i CONDUCTOR 2 ESD 600 -50 2003 I 2588430 1472062 61 04 33.77 150 57 02.79 71.8 CONDUCTOR 3 2004 2566429 1472066 61 04 33.77 150 57 02.71 73.4 AN 6 2005 2586431 1472069 61 04 33.79 150 57 02.65 71.9 CONDUCTOR 5 2006 2586435 1472069 61 04 34.83 150 57 02.64 73.3 A10 ESD 600 -51 2007 2566439 1472067 61 04 33.86 150 57 02.69 73.3 All 2008 I 2586439 1472063 61 04 33.87 150 57 02.77 71.9 CONDUCTOR 8 I j WELL HOUSE NO. 3 m p13 Al AJ ,,,,_, _3001 2586486 1472128 61 04 34.38 150 57 01.47 73.0 Al 7 Al 3002 2586484 1472127 61 04 34.32 150 57 01.48 73.1 AN _ 02 3003 2586481 1472130 61 04 34.29 150 57 01.43 73.1 A6 1 03 p6 � 5 3004 I 2586480 1472133 61 04 34.28 150 57 01.35 73.0 I A4 A4 612 et 3005 I 2586483 1472137 ? 61 04 34.31 150 57 01.29 I 73.0 I A2 3006 I 2586487 1472137 61 04 34.34 150 57 01.28 ' 73.0 I A5 3007 f 2586490 j_1472135 61 04 34.38 150 57 01.33 73.0 A3 -- I • 3008 { 2586490 1472131 61 04 34.38 150 57 01.41 73.3 A7 ' - � - - 6 6 I 5 50 I 2586540 1472069 61 04 34.86 150 57 02.69 1 72.7 ISO VALVE 900 -50 �'� `.-, 7 7 , 8 - 51 I 2586501 I 1472011 61 04 34.46 150 57 03.861 72.6 ESD VALVE 600 -51 Illj WELL HOUSE 2 I I 100 I 2586572 I 1472123 161 04 35.18 150 57 01.58 I 115.3 TOP CENTER HEUPAD 1 I SCALE: 1 "= 1320' =/ MILE e All I I ! -191' MUD LINE . , 1 A10 GENERAL NOTES: zJ AN 1. ALL COORDINATES ARE ASP ZONE 4, NAD83, US SURVEY FEET. 1. SECTION LINES AND TIES ARE BASED GEOGRAPHICS ARE NAD83. ON PROTRACTED VALUES. 2. ELEVATIONS ARE IN FEET, BASED ON MLLW, REFERENCED TO DRAWING NO. MPD -TY04 -2021, SHEET 1 OF 1, REV 2. SCALE: 1 " =30' LEGEND: 3. ALL AS BUILTS ARE TO THE CENTER OF EXISTING STRUCTURE. 4 WELL CONDUCTOR ARE VERTICALLY AS BUILT TO THE TOP OF WELL A 1 /4" STEEL LID. TACK WELDED TO THE TOP OF THE CONDUCTOR. WELL CONDUCTOR 5 WELLS ARE VERTICALLY AS BUILT TO THE TOP OF THE LOWEST HORIZONTAL FLANGE ON THE WELL. ESD (EMERGENCY SHUT GENERAL NOTES: OFF VALVE) 1. NO WELLS EXIST IN WELL HOUSE NO 4 AND IT WAS NOT AS BUILT I FORM: BSIZE DRAWN: DESIGN: ECM NO: y/ TYONEK MODULE: UNIT: TY CHECKED: APPROVAL: CC NO: ' -. - • ConocoPhillips Alaska, Inc. 1 3 -11 -08 ISSUED PER DC0001APD MGO FNS SCALE DATE: CADD FILENAME: JOB NO: SUB JOB NO: DRAWING NO:. PART: REV: REV DATE REVISION BY CHK JOB PROJ as noted 3 - - NGED- 304 -M -310 -" 001 OF 1 ConocoPhillips (Alaska) Inc. -Expl North Cook Inlet Unit North Cook Inlet Unit Plan: NCI A -16 - 2001 Plan:NCI A -16 Plan: A- 16wp14 perry ri l Services Combo Report 09 June, 2008 Well Coordinates: 2,586,436.84 N, 1,472,059.88 E (61° 04' 33.84" N, 150° 57' 02.83" W) Water Depth: 101.00 ft Local Coordinate Origin: Centered on Well Plan: NCI A -16 - Slot 2001 Viewing Datum: Plan: A -16 @ 116.00ft (Kuupik 5) TVDs to System: N North Reference: True Unit System: API - US Survey Feet New Geodetic Scale Factor Applied Version: 2003.16 Build: 42F ■per■ /� ® ® ep. ■ ■A L LJ R ! w�gw Sperry Drilling Services dk. 7..�, -. - r;mr,: seNrerx.�r,- ='+ .. ; >.an�«*'es „ *-.<: xss�."..r• °, uu,:s^5.. - . +wY+�* "r'r�. °5'�^a.., �:�-`, rrxsai.fi'^^ � , " ,:, -..�. , ., e7:: Project: North Cook Inlet Unit SECTION DETAILS Site: North Cook Inlet Unit l a Sec 0..10 Inc Azi TVD +N / -S +E •W DLeg TFace VSec Target Well: Plan: NCI A-16 SHL: 1304.49 FNL, 1016.14 FWL - SEC 6 - T11 N - ROE 1 217.00 0.00 0.00 217.00 0.00 0.00 0.00 0.00 0.00 Wellbore: Plan: NCI A -16 _ - - -- - • 2 450.00 0.00 0.00 450.00 0.00 0.00 0.00 0.00 0.00 Plan: A- 16wp14 - 3 550.00 2.00 310.00 549.98 1.12 -1.34 2.00 310.00 1.74 4 690.00 2.00 310.00 689.89 4.26 -5.08 0.00 0.00 6.62 480 500 5 990.05 10.00 255.00 988.19 0.88 -34.32 3.00 -65.38 27.76 - 61267.43 15.00 295.00 1259.38 9.84 -90.24 3.50 80.61 77.58 - 7 1894.57 40.00 300.00 1811.32 147.12 - 342.39 4.00 7.59 361.20 _ 8 2274.20 53.45 309.77 2071.29 306.60 - 566.57 4.00 31.36 636.14 980 1000 9 5177.03 53.45 309.77 3800.00 1798.37 - 2358.96 0.00 0.00 2966.27 - 10 7114.60 5.15 298.90 5440.71 2370.03 - 3078.04 2.50 - 178.47 3884.76 _ 11 7488.27 5.15 296.90 5812.88 2385.21 - 3107.95 0.00 0.00 3917.73 12 7526.54 5.00 307.60 5851.00 2387.00 •3110.81 2.50 104.29 3921.08 A- 16wp13 M Drilling Target 1440 15 137527.42 5.00 307.50 5851.87 2387.05 - 3110.87 1,00 -90.05 3921.16 14 8570.52 5.00 307.50 6891.00 2442.39 - 3182.99 0.00 0.00 4012.07 A- 16wp13 U Drilling Target 00 0 15 9298.29 5.00 307.50 7616.00 2481.01 - 3233,32 0.00 0.00 4075.50 L 1920- - 0 0 - c ll WELL DETAILS: Plan: NCI A - 16 0 0 9 - 5/8" @ 5117.46, 4335.22 FWL - SEC 36 - T12N - R1 C 2400 3 Water Depth: 10100 O i� +N / -S +E / -W Northing Easting Lalitlude Longitude Slot r'o 4) / 0.00 0.00 2586436.84 1472059.88 61° 4' 33.842 N 150' 57'2.834 W 2001 fil 2880- O � / CASING DETAILS FORMATION TOP DETAILS c a TVD MD Name Size TVDPath MDPath Formation o '9 5/8" 3416.00 4532.22 9 5/8" 9 -5/8 3566.00 478410 Top Sterling 0 3360- 00 7615.99 9298.28 7" 7 3609.00 4856,31 CI-A N 3808,00 5190.42 01 -1 v ` _ Y _______.__- -- .___________ _ ____ ---- _-- --__ -- _ h 3832.00 5229.95 C.I.2 Top Sterling 4078.00 5594.93 C1 -5 ®0 3840 -�°-� X00 4253.00 5823.96 C.I.8 "°"1 / _ CI -1 4455.00 6068.40 Beluga -A /� 5851.00 7526.54 Beluga M �..i / 4320 = = CI -5 co 6486.00 8163 97 Beluga S G 6891.00 8570.52 Beluga U �,.�.■ a1 - Beluga -A 7216.00 0896.76 Beluga Ubase =i`- 4800- y 0 >e 5280- 7000 IA- 16wp13M DrillingTaniget i - 5760- -x500 - Beluga M 6240- -- - 8000 - -\ Beluga a------ - --- -. -. -- "- IA- 16wp13UDrilling Target 6720 - - eQ - Beluga U BHL @ 9298.28' MD, 7615.99; 4103.61 FNL, 3062.66 FWL - SEC 36 - T12 - R1 OW 7200- - - - Beluga Ubase _ - - - - - A - -- 7680 - - A- 16wp 8160 - - 1 1 1 1 0 1 1 3 3 I I 1 1 I 1 1 I I I I 1 I I 1 1 1 1 1 I 1 1 I 1 1 1 1 1 1 I 1 1 I I 1 1 1 1 I I 1 1 1 1 I I I 1 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 1 1 11 1 I I 1 1 1 1 1 1 1 1 1 1 1 1 I 1 I 1 1 1 I I 1 1 1 I 1 1 1 1 1 I 1 1 1 1 I 1 1 I 1 11 -1440 -960 -480 0 480 960 1440 1920 2400 2680 3360 3840 4320 4800 5280 5760 6240 6720 7200 7680 8160 8640 9120 9600 Vertical Section at 307.50° (1200 ft/in) ConocoPhillips ■ Project: North Cook inlet Unit REFERENCE INFORMATION WELL DETAILS: Plan: NCI A -16 Site: North Cook Inlet Unit Co- ordinate (N /E) Reference: Well Plan: NCI A -16 - Slot 2001, True North Water Depth: 101.00 Well: Plan: NCI A-16 Vertical (TVD) Reference: Plan: A -16 116.008 (Kuupik 5) +N / - +E/ - Northing Easting Latittude Longitude Slot Welibore: Plan: NCI A-16 Measured Depth Reference : Plan: A -16 0 116.0011 (Kuupik 5) Calculation Method: Minimum Curvature 0.00 0.00 2586436.84 1472059.88 61° 4' 33.842 N 150° 57'2.834 W 2001 Plan: A- 16wp14 3000- 2857 - - MIL C 9298.28' MD, 7615.99; 4103.61 FNL, 3062.66 FWL - SEC 36 - T12 - R 10 \V 2714 — 1955E conf. - - - - - r b 2571— a• I _ - ice5 2429 — \1i hh•i 955°0 cont. 2286 ,} _ b 2143 = IA- 16wp13 U Drilling Target 1 1 . �ry ° � 2000 _ > _ �i 1857— 1 9 -5/8" 4 5117.46, 4335.22 FWL - SEC 36 - T12N - RI OW - L16wp13 M Drilling Target j 'e - - - 1714— A - — 1571 `'� _? _ 95/8•- - - P. 1429 - - , ,N 1286 — r , • 1143 — 4 I(r 1000- 0 857 714 — 45 SHL: 1304.49 FNL,1016.14 FWL - SEC 6- TIIN -R09 \V 571 — r • rt r 429 — � _ 286 — ti t o r 143 — .. - 1. -143- -286- -429 TT1 1 T11r Fri EFErr n 11111 r11 n r1111Jl111 [FT rrlrT11111r11 n 11 El Ir11 rm rEm 111111111111111111111111111111111111111r 111111111111111111111 111111111111111 11111111 -4143 -4000 -3857 -3714 -3571 -3429 -3286 -3143 -3000 -2857 -2714 -2571 -2429 -2286 -2143 -2000 -1857 -1714 -1571 -1429 -1286 -1143 -1000 -857 -714 -571 -429 -286 -143 -0 143 286 429 571 714 857 West( -) /East(+) (500 ft/in) Conoco-Phillips ConocoPhillips (Alaska) Inc. -Expl HALLIrczYU'tiTON North Cook Inlet Unit Plan Report for Plan: NCI A -16 - A- 16wp14 Measured TVD below Vertical Local Coordinates Map Coordinates Dogleg Build Turn Vertical Horizontal Depth Inclination Azimuth System Depth Northing Easting Northing Easting Rate Rate Rate Section Departure (ft) (0) ( °) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) ( °/100ft) ( ° /100ft) (ft) (0.00) 217.00 0.00 0.00 101.00 217.00 0.00 N 0.00 W 2,586,436.84 1,472,059.88 0.00 0,00 0.00 0.00 0.00 . SHL: 1304.49 FNL, 1016.14 FWL - SEC 6 - T11N - RO9W 300.00 0.00 0.00 184.00 300.00 0.00 N 0.00 W 2,586,436.84 1,472,059.88 0.00 0.00 0.00 0.00 0.00 400,00 0.00 0.00 284.00 400.00 0.00 N 0.00 W 2,586,436.84 1,472,059.88 0.00 0,00 0.00 0.00 0.00 450,00 0.00 0.00 334.00 450.00 0.00 N 0.00 W 2,586,436.84 1,472,059.88 0.00 0.00 0.00 0.00 0.00 500.00 1.00 310.00 384.00 500.00 0.28 N 0.33 W 2,586,437.13 1,472,059.55 2.00 2.00 0.00 0.44 0.44 550,00 2.00 310.00 433.98 549.98 1.12 N 1.34 W 2,586,437.98 1,472,058.56 2.00 2.00 0.00 1.74 1.75 • 600.00 2.00 310.00 483.95 599.95 2.24 N 2.67 W 2,586,439.12 1,472,057.24 0.00 0.00 0.00 3.49 3.49 690.00 2.00 310.00 573.89 689.89 4.26 N 5.08 W 2,586,441.18 1,472,054.86 0.00 0.00 0.00 6.62 6.63 700.00 2.14 302.68 583.89 699.89 4.48 N 5.37 W 2,586,441.39 1,472,054.57 3.00 1.42 -73.16 6.99 6.99 800.00 4.51 268.33 683.72 799.72 5.37 N 10.88 W 2,586,442.37 1,472,049.08 3.00 2.37 -34.35 11.90 12.80 900.00 7.36 258.85 783.18 899.18 4.02 N 21.10 W 2,586,441.16 1,472,038.84 3.00 2.85 -9.48 19.19 23.14 M--i 990.05 10.00 255.00 872.19 988.19 0.88 N 34.32 W 2,586,438.22 1,472,025.58 3.00 2.93 -4.28 27.76 36.73 - 1,000.00 10.06 256.97 881.99 997.99 0.46 N 36.00 W 2,586,437.82 1,472,023.90 3.50 0.63 19.77 28.84 38.46 O 1,100.00 11.28 274.79 980.28 1,096.28 0.70 S 54.26 W 2,586,436.93 1,472,005.62 3.50 1.22 17,82 42.62 56.98 .,,,,.... 1,200.00 13.32 288.21 1,078.00 1,194.00 3.72 N 74.95 W 2,586,441.65 1,471,984.99 3.50 2.04 13.42 61.73 78.28 e.,.... .. 1,267.43 15.00 295.00 1,143.38 1,259.38 9.84 N 90.24 W 2,586,447.99 1,471,969.80 3.50 2.49 10.08 77.58 94.78 1,300.00 1629 295.61 1,174.75 1290.75 1359 N 98.18 W 2,586,451.86 1,471,961.91 4.00 3.97 1.88 86.17 103.56 r 1,400.00 20.27 297.02 1,269.68 1,385.68 27.53 N 126.27 W 2,586,466.20 1,471,934.03 4.00 3.98 1.41 116.94 134.92 1,500,00 24.25 297.98 1,362.21 1,478.21 45.04 N 159.85 W 2,586,484.20 1,471,900.71 4.00 3.98 0.96 154.24 172.80 1,600.00 28.24 298.68 1,451.88 1,567.88 66.04 N 198.76 W 2,586,505.76 1,471,862.11 4.00 3.99 0.70 197.89 217.01 1,700.00 32.23 299.23 1,538.26 1,654.26 90.43 N 242.81 W 2,586,530.78 1,471,818.43 4.00 3.99 0.54 247.68 267.35 1,800.00 36.22 299.66 1,620.93 1,736.93 118.08 N 291.77 W 2,586,559.14 1,471,769.87 4.00 3.99 0.43 303.36 323.59 1,894,57 40.00 300.00 1,695.32 1,811.32 147.12 N 342.39 W 2,586,588.90 1,471,719.68 4.00 3.99 0.36 361,20 381.95 1,900.00 40.19 300.18 1,699.48 1,815.48 148.87 N 345.42 W 2,586,590.70 1,471,716.68 4.00 3.42 3.23 364.67 385.44 2,000.00 43.65 303.18 1,773.89 1,889.89 183.99 N 402.22 W 2,586,626.64 1,471,660.40 4.00 3.46 3.00 431.11 452.24 2,100.00 47.18 305.82 1,844.08 1,960.08 224.35 N 460.86 W 2,586,667.85 1,471,602.35 4.00 3.53 2.64 502,20 523.44 2,200.00 50.76 308.17 1,909.72 2,025.72 269.77 N 521.07 W 2,586,714.13 1,471,542.82 4.00 3.58 2.35 577.62 598.87 2,274.20 53.45 309.77 1,955.29 2,071.29 306.60 N 566.57 W 2,586,751.62 1,471,497.86 4.00 3.62 2.15 636.14 657.42 2,300.00 53.45 309.77 1,970.66 2,086.66 319.86 N 582.51 W 2,586,765.11 1,471,482.12 0.00 0.00 0.00 656.85 678.14 2,400.00 53.45 309.77 2,030.21 2,146.21 371,25 N 644.25 W 2,586,817.38 1,471,421.13 0.00 0.00 0.00 737.12 758.48 09 June, 2008 - 8 :45 Page 2 of 8 COMPASS ConocoPhillips (Alaska) Inc. -Expl °.;:I BLI r4 North Cook Inlet Unit Plan Report for Plan: NC,I A -16 - A- 16wp14 Measured TVD below Vertical Local Coordinates Map Coordinates Dogleg Build Turn Vertical Horizontal Depth Inclination Azimuth System Depth Northing Easting Northing Easting Rate Rate Rate Section Departure (ft) ( °) (0) (ft) (ft) (ft) (ft) (ft) (ft) ( °/100ft) ( °/100ft) ( ° /100ft) (ft) (53.45) 2,500.00 53.45 309.77 2,089.76 2,205.76 422.64 N 706.00 W 2,586,869.66 1,471,360.14 0.00 0.00 0.00 817.39 838.81 2,600.00 53.45 309.77 2,149.31 2,265.31 474.03 N 767.74 W 2,586,921.94 1,471,299.15 0.00 0.00 0.00 897.66 919.15 2,700.00 53.45 309.77 2,208.87 2,324.87 525.42 N 829.49 W 2,586,974.22 1,471,238.16 0.00 0.00 0.00 977.93 999.48 2,800.00 53.45 309.77 2,268.42 2,384.42 576.81 N 891.24 W 2,587,026.50 1,471,177.18 0.00 0.00 0.00 1,058.21 1,079.81 2,900.00 53.45 309.77 2,327.97 2,443.97 628.20 N 952.98 W 2,587,078.77 1,471,116.19 0.00 0.00 0.00 1,138.48 1,160.15 3,000.00 53.45 309.77 2,387.52 2,503.52 679.59 N 1,014.73 W 2,587,131.05 1,471,055.20 0.00 0.00 0.00 1,218.75 1,240.48 3,100.00 53.45 309.77 2,447.08 2,563.08 730.98 N 1,076.47 W 2,587,183.33 1,470,994.21 0.00 0.00 0.00 1,299.02 1,320.81 3,200.00 53.45 309.77 2,506.63 2,622.63 782.37 N 1,138.22 W 2,587,235.61 1,470,933.22 0.00 0.00 0.00 1,379.29 1,401.15 3,300.00 53.45 309.77 2,566.18 2,682.18 833.76 N 1,199.97 W 2,587,287.89 1,470,872.23 0.00 0.00 0.00 1,459.56 1,481.48 3,400.00 53.45 309.77 2,625.73 2,741.73 885.15 N 1,261.71 W 2,587,340.16 1,470,811.24 0.00 0.00 0.00 1,539.83 1,561.82 3,500.00 53.45 309.77 2,685.29 2,801.29 936.54 N 1,323.46 W 2,587,392.44 1,470,750.25 0.00 0.00 0.00 1,620.10 1,642.15 3 3,600.00 53.45 309.77 2,744.84 2,860.84 987.93 N 1,385.20 W 2,587,444.72 1,470,689.26 0.00 0.00 0.00 1,700.37 1,722.48 3,700.00 53.45 309.77 2,804.39 2,920.39 1,039.32 N 1,446.95 W 2,587,497.00 1,470,628.28 0.00 0.00 0.00 1,780.64 1,802.82 . 3,800.00 53.45 309,77 2,863.94 2,979.94 1,090.71 N 1,508.70 W 2,587,549.28 1,470,567.29 0.00 0.00 0.00 1,860.91 1,883.15 3,900.00 53.45 309.77 2,923.50 3,039.50 1,142.10 N 1,570.44 W 2,587,601.55 1,470,506.30 0.00 0.00 0.00 1,941.18 1,963.48 4,000.00 53.45 309.77 2,983.05 3,099.05 1,193.49 N 1,632.19 W 2,587,653.83 1,470,445.31 0.00 0.00 0.00 2,021.45 2,043.82 ;" 4,100.00 53.45 309.77 3,042.60 3,158.60 1,244.88 N 1,693.93 W 2,587,706.11 1,470,384.32 0.00 0.00 0.00 2,101.72 2,124.15 4,200.00 53.45 309.77 3,102.15 3,218.15 1,296.27 N 1,755.68 W 2,587,758.39 1,470,323.33 0.00 0.00 0.00 2,182.00 2,204.49 4,300.00 53.45 309.77 3,161.70 3,277.70 1,347.66 N 1,817.43 W 2,587,810.66 1,470,262.34 0.00 0.00 0.00 2,262.27 2,284.82 4,400.00 53.45 309.77 3,221.26 3,337.26 1,399.05 N 1,879.17 W 2,587,862.94 1,470,201.35 0.00 0.00 0.00 2,342.54 2,365.15 4,500.00 53.45 309.7,7 3,280.81 3,396.81 1,450.44 N 1,940.92 W 2,587,915.22 1,470,140.36 0.00 0.00 0.00 2,422.81 2,445.49 4,532.22 53.45 309.77 3,300.00 3,416.00 1,467.00 N 1,960.82 W 2,587,932.07 1,470,120.71 0.00 0.00 0.00 2,448.67 2,471.37 9 -5/8" CO 5117.46, 4335.22 FWL - SEC 36 - T12N - R1 OW - 9 5/8" 4,600.00 53.45 309.77 3,340.36 3,456.36 1,501.83 N 2,002.66 W 2,587,967.50 1,470,079.37 0.00 0.00 0.00 2,503.08 2,525.82 4,700.00 53.45 309.77 3,399.91 3,515.91 1,553.22 N 2,064.41 W 2,588,019.78 1,470,018.39 0.00 0.00 0.00 2,583.35 2,606.15 4,784.10 53.45 309.77 3,450.00 3,566.00 1,596.44 N 2,116.34 W 2,588,063.74 1,469,967.09 0.00 0.00 0.00 2,650.86 2,673.72 Top Sterling 4,800.00 53.45 309.77 3,459.47 3,575.47 1,604.61 N 2,126.16 W 2,588,072.05 1,469,957.40 0.00 0.00 0.00 2,663.62 2,686.49 4,856.31 53.45 309.77 3,493.00 3,609.00 1,633.55 N 2,160.92 W 2,588,101.49 1,469,923.05 0.00 0.00 0.00 2,708.82 2,731.72 CI -A 4,900.00 53.45 309.77 3,519.02 3,635.02 1,656.00 N 2,187.90 W 2,588,124.33 1,469,896.41 0.00 0.00 0.00 2,743.89 2,766.82 5,000.00 53.45 309.77 3,578.57 3,694.57 1,707.39 N 2,249.65 W 2,588,176.61 1,469,835.42 0.00 0.00 0.00 2,824.16 2,847.16 09 June, 2008 - 8 :45 Page 3 of 8 COMPASS ConocoPhillips (Alaska) Inc. -Expl ALLI S Li iRTOird North Cook Inlet Unit Plan Report for Plan: NCI A -16 - A- 16wp14 Measured TVD below Vertical Local Coordinates Map Coordinates Dogleg Build Turn Vertical Horizontal Depth Inclination Azimuth System Depth Northing Easting Northing Eastlug Rate Rate Rate Section Departure (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ( °/100ft) (°I100ft) ( °/100ft) (ft) (53.45) 5,100.00 53.45 309.77 3,638.12 3,754.12 1,758.78 N 2,311.39 W 2,588,228.89 1,469,774.43 0.00 0.00 0.00 2,904.43 2,927.49 5,177.03 53.45 309.77 3,684.00 3,800.00 1,798.37 N 2,358.96 W 2,588,269.16 1,469,727.45 0.00 0.00 0.00 2,966.27 2,989.37 5,190.42 53.12 309.76 3,692.00 3,808.00 1,805.23 N 2,367.21 W 2,588,276.14 1,469,719.30 2.50 -2.50 -0.08 2,976.99 3,000.10 CI -1 5,200.00 52.88 309.75 3,697.77 3,813.77 1,810.13 N 2,373.09 W 2,588,281.12 1,469,713.49 2.50 -2.50 -0.08 2,984.63 3,007.75 5,229.95 52.13 309.73 3,716.00 3,832.00 1,825.32 N 2,391.36 W 2,588,296.57 1,469,695.44 2.50 -2.50 -0.09 3,008.38 3,031.51 C.I. 2 5,300.00 50.38 309.66 3,759.84 3,875.84 1,860.21 N 2,433.40 W 2,588,332.07 1,469,653.92 2.50 -2.50 -0.09 3,062.97 3,086.15 5,400.00 47.88 309.57 3,825.27 3,941.27 1,908.42 N 2,491.64 W 2,588,381.12 1,469,596.39 2.50 -2.50 -0.09 3,138.53 3,161.76 5,500.00 45.38 309.47 3,893.94 4,009.94 1,954.68 N 2,547.71 W 2,588,428.18 1,469,541.00 2.50 -2.50 -0.10 3,211.17 3,234.44 5,594.93 43.01 309.36 3,962.00 4,078.00 1,996.69 N 2,598.83 W 2,588,470.93 1,469,490.50 2.50 -2.50 -0.11 3,277.30 3,300.61 _ CI -5 Y_,. 5,600.00 42.88 309.36 3,965.71 4,081.71 1,998.88 N 2,601.50 W 2,588,473.16 1,469,487.86 2.50 -2.50 -0.12 3,280.75 3,304.07 -`: ° 5,700.00 40.38 309.24 4,040.45 4,156.45 2,040.95 N 2,652.91 W 2,588,515.97 1,469,437.07 2.50 -2.50 -0.12 3,347.15 3,370.49 -' ',...- 5,800.00 37.88 309.10 4,118.01 4,234.01 2,080.81 N 2,701.83 W 2,588,556.53 1,469,388.74 2.50 -2.50 -0.13 3,410.23 3,433.60 D 5,823.96 37.28 309.07 4,137.00 4,253.00 2,090.03 N 2,713.18 W 2,588,565.91 1,469,377.53 2.50 -2.50 -0.14 3,424.83 3,448.21 . ,,,..,.e C.1.8 .,, ,, 5,900.00 35.38 308.95 4,198.25 4,314.25 2,118.38 N 2,748.18 W 2,588,594.77 1,469,342.94 2.50 -2.50 -0.15 3,469.87 3,493.26 6,000.00 32.89 308.78 4,281.02 4,397.02 2,153.59 N 2,791.87 W 2,588,630.61 1,469,299.77 2.50 -2.50 -0.17 3,525.96 3,549.38 6,068.40 31.18 308.65 4,339.00 4,455.00 2,176.28 N 2,820.18 W 2,588,653.71 1,469,271.80 2.50 -2.50 -0.19 3,562.23 3,585.65 4 Beluga -A 6,100.00 30.39 308.58 4,366.15 4,482.15 2,186.38 N 2,832.81 W 2,588,663.98 1,469,259.31 2.50 -2.50 -0.20 3,578.40 3,601.83 6,200.00 27.89 308.36 4,453.49 4,569.49 2,216.67 N 2,870.93 W 2,588,694.82 1,469,221.64 2.50 -2.50 -0.23 3,627.09 3,650.52 IP 6,300.00 25.39 308.09 4,542.86 4,658.86 2,244.42 N 2,906.15 W 2,588,723.08 1,469,186.83 2.50 -2.50 -0.27 3,671.92 3,695.36 6,400.00 22.90 307.77 4,634.11 4,750.11 2,269.56 N 2,938.41 W 2,588,748.69 1,469,154.94 2.50 -2.50 -0.32 3,712.82 3,736.26 6,500.00 20.40 307.37 4,727.04 4,843.04 2,292.06 N 2,967.65 W 2,588,771.61 1,469,126.03 2.50 -2.50 -0.40 3,749.71 3,773.15 6,600.00 17.91 306.87 4,821.50 4,937.50 2,311.87 N 2,993.80 W 2,588,791.79 1,469,100.17 2.50 -2.49 -0.50 3,782.52 3,805.96 6,700.00 15.41 306.22 4,917.30 5,033.29 2,328.95 N 3,016.83 W 2,588,809.20 1,469,077.40 2.50 -2.49 -0.66 3,811.18 3,834.62 6,800.00 12.92 305.31 5,014.25 5,130.25 2,343.27 N 3,036.68 W 2,588,823.81 1,469,057.76 2.50 -2.49 -0.90 3,835.65 3,859.10 6,900.00 10.44 303.99 5,112.17 5,228.17 2,354.80 N 3,053.32 W 2,588,835.57 1,469,041.29 2.50 -2.49 -1.32 3,855.87 3,879.34 7,000.00 7.96 301.85 5,210.87 5,326.87 2,363.52 N 3,066.71 W 2,588,844.49 1,469,028.03 2.50 -2.48 -2.14 3,871.80 3,895.33 09 June, 2008 - 8:45 Page 4 of 8 COMPASS ConocoPhillips (Alaska) Inc. -Expl HALLiatigiTCVS1 North Cook Inlet Unit Plan Report for Plan: NCI A -16 - A- 16wp14 Measured TVD below Vertical Local Coordinates Map Coordinates Dogleg Build Turn Vertical Horizontal Depth Inclination Azimuth System Depth Northing Easting Northing Easting Rate Rate Rate Section Departure (ft) ( °) (0) (ft) (ft) (ft) (ft) (ft) (ft) ( ° /100ft) ( °I100ft) ( °I100ft) (ft) (5.50) 7,100.00 5.50 297.81 5,310.18 5,426.18 2,369.41 N 3,076.84 W 2,588,850.53 1,469,017.99 2.50 -2.46 -4.04 3,883.42 3,907.05 7,114.60 5.15 296.90 5,324.71 5,440.71 2,370.03 N 3,078.04 W 2,588,851.17 1,469,016.79 2.50 -2.43 -6.23 3,884.76 3,908.41 7,200.00 5.15 296.90 5,409.77 5,525.77 2,373.50 N 3,084.88 W 2,588,854.73 1,469,010.01 0.00 0.00 0.00 3,892.29 3,916.07 7,300.00 5.15 296.90 5,509.37 5,625.36 2,377.56 N 3,092.88 W 2,588,858.91 1,469,002.06 0.00 0.00 0.00 3,901.12 3,925.05 7,400.00 5.15 296.90 5,608.96 5,724.96 2,381.62 N 3,100.89 W 2,588,863.09 1,468,994.12 0.00 0.00 0.00 3,909.94 3,934.03 7,488.27 5.15 296.90 5,696.88 5,812.88 2,385.21 N 3,107.95 W 2,588,866.77 1,468,987.11 0.00 0.00 0.00 3,917.73 3,941.95 • 7,500.00 5.09 300.11 5,708.56 5,824.56 2,385.71 N 3,108.87 W 2,588,867.29 1,468,986.20 2.50 -0.55 27.34 3,918.76 3,943.00 7,526.54 5.00 307.60 5,735.00 5,851.00 2,387.00 N 3,110.81 W 2,588,868.61 1,468,984.28 2.50 -0.32 28.23 3,921.08 3,945.33 Beluga M - A- 16wp13 M Drilling Target 7,527.42 5.00 307.50 5,735.87 5,851.87 2,387.05 N 3,110.87 W 2,588,868.66 1,468,984.22 1.00 0.00 -11.47 3,921.16 3,945.41 7,600.00 5.00 307.50 5,808.18 5,924.18 2,390.90 N 3,115.89 W 2,588,872.58 1,468,979.26 0.00 0.00 0.00 3,927.49 3,951.73 j 7,700.00 5.00 307.50 5,907.80 6,023.80 2,396.21 N 3,122.80 W 2,588,877.99 1,468,972.42 0.00 0.00 0.00 3,936.20 3,960.45 7,800.00 5.00 307.50 6,007.42 6,123.42 2,401.51 N 3,129.72 W 2,588,883.39 1,468,965.59 0.00 0.00 0.00 3,944.92 3,969.16 7,900.00 5.00 307.50 6,107.03 6,223.03 2,406.82 N 3,136.63 W 2,588,888.80 1,468,958.75 0.00 0.00 0.00 3,953.63 3,977.88 8,000.00 5.00 307.50 6,206.65 6,322.65 2,412.12 N 3,143.54 W 2,588,894.20 1,468,951.91 0.00 0.00 0.00 3,962.35 3,986.59 ' --- 8,008.38 5.00 307.50 6,215.00 6,331.00 2,412.57 N 3,144.12 W 2,588,894.65 1,468,951.34 0.00 0.00 0.00 3,963.08 3,987.33 "' Beluga Q 8,100.00 5.00 307.50 6,306.27 6,422.27 2,417.43 N 3,150.46 W 2,588,899.61 1,468,945.08 0.00 0.00 0.00 3,971.06 3,995.31 8,163.97 5.00 307.50 6,370.00 6,486.00 2,420.82 N 3,154.88 W 2,588,903.06 1,468,940.70 0.00 0.00 0.00 3,976.64 4,000.89 Beluga S 8,200.00 5.00 307.50 6,405.89 6,521.89 2,422.74 N 3,157.37 W 2,588,905.01 1,468,938.24 0.00 0.00 0.00 3,979.78 4,004.03 8,300.00 5.00 307.50 6,505.51 6,621.51 2,428.04 N 3,164.29 W 2,588,910.42 1,468,931.40 0.00 0.00 0.00 3,988.50 4,012.74 • 8,400.00 5.00 307.50 6,605.13 6,721.13 2,433.35 N 3,171.20 W 2,588,915.82 1,468,924.57 0.00 0.00 0.00 3,997.21 4,021.46 8,500.00 5.00 307.50 6,704.75 6,820.75 2,438.65 N 3,178.12 W 2,588,921.23 1,468,917.73 0.00 0.00 0.00 4,005.93 4,030.17 8,570.52 5.00 307.50 6,775.00 6,891.00 2,442.39 N 3,182.99 W 2,588,925.04 1,468,912.91 0.00 0.00 0.00 4,012.07 4,036.32 Beluga U - A- 16wp13 U Drilling Target l 8,600.00 5.00 307.50 6,804.37 6,920.37 2,443.96 N 3,185.03 W 2,588,926.63 1,468,910.89 0.00 0.00 0.00 4,014.64 4,038.89 8,700.00 5.00 307.50 6,903.99 7,019.99 2,449.26 N 3,191.95 W 2,588,932.04 1,468,904.06 0.00 0.00 0.00 4,023.36 4,047.60 8,800.00 5.00 307.50 7,003.61 7,119.61 2,454.57 N 3,198.86 W 2,588,937.44 1,468,897.22 0.00 0.00 0.00 4,032.08 4,056.32 8,896.76 5.00 307.50 7,100.00 7,216.00 2,459.70 N 3,205.55 W 2,588,942.67 1,468,890.61 0.00 0.00 0.00 4,040.51 4,064.75 Beluga Ubase 8,900.00 5.00 307.50 7,103.23 7,219.23 2,459.88 N 3,205.78 W 2,588,942.85 1,468,890.39 0.00 0.00 0.00 4,040.79 4,065.04 i 09 June, 2008 - 8:45 Page 5 of 8 COMPASS ■ 1 ConocoPhillips (Alaska) Inc. -Expi Hi, TN North Cook Inlet Unit Plan Report for Plan: NCI A -16 - A- 16wp14 Measured TVD below Vertical Local Coordinates Map Coordinates Dogleg Build Turn Vertical Horizontal Depth Inclination Azimuth System Depth Northing Easting Northing Easting Rate Rate Rate Section Departure (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ( ° /100ft) (° /100ft) ( ° /100ft) (ft) (5.00) 9,000.00 5.00 307.50 7,202.85 7,318.85 2,465.18 N 3,212.69 W 2,588,948.25 1,468,883.55 0.00 0.00 0.00 4,049.51 4,073.75 9,100.00 5.00 307.50 7,302.47 7,418.47 2,470.49 N 3,219.61 W 2,588,953.66 1,468,876.71 0.00 0.00 0.00 4,058.22 4,082.47 9,200.00 5.00 307.50 7,402.09 7,518.09 2,475.79 N 3,226.52 W 2,588,959.07 1,468,869.88 0.00 0.00 0.00 4,066.94 4,091.18 9,298.28 5.00 307.50 7,499.99 7,615.99 2,481.01 N 3,233.32 W 2,588,964.38 1,468,863.16 0.00 0.00 0.00 4,075.50 4,099.75 BHL @ 9298.28' MD, 7615.99; 4103.61 FNL, 3062.66 FWL - SEC 36 - T12 - R10W - 7" 9,298.29 5.00 307.50 7,500.00 . 7,616.00 2,481.01 N 3,233.32 W 2,588,964.38 1,468,863.16 0.00 0.00 0.00 4,075.50 4,099.75 Plan Annotations I Measured Vertical Local Coordinates Depth Deptli +N / -S +E / -W Comment (ft) (ft) (ft) (ft) . - 217.00 217.00 0.00 0.00 SHL: 1304.49 FNL, 1016.14 FWL - SEC 6- T11N -RO9W - 4,532.22 3,416.00 1,467.00 - 1,960.81 9 -5/8" @ 5117.46, 4335.22 FWL - SEC 36 - T12N - R1 OW 9,298.28 7,615 2,481.01 - 3,233.32 BHL @ 9298.28' MD, 7615.99; 4103.61 FNL, 3062.66 FWL - SEC 36 - ° ° T12 -R1OW "" Vertical Section Information Angie' Origin Origin Start Type Target Azimuth Type +N /_S +E / -W TVD ( °) (ft) (ft) (ft) TD No Target (Freehand) 307.50 Slot 0.00 0.00 217.00 Survey tool aroaram From To Survey /Plan Survey Tool II (ft) (ft) 217.00 690.00 A- 16wp14 GYD -GC -SS 1,000.00 9,298.29 A- 16wp14 MWD+SCC Casing Details Measured Vertical Casing Hole Depth Depth Name Diameter Diameter (ft) (ft) ( °) (") 4,532.22 3,416.00 9 5/8" 9 -5/8 12 -1/4 9,298.28 7,615.99 7" 7 7 -1/2 1 09 June, 2008 - 8:45 Page 6 of 8 COMPASS ConocoPhillips (Alaska) Inc. -Expl HI _. North Cook Inlet Unit Plan Report for Plan: NCI A -16 - A- 16wp14 Formation Details Measured Vertical Dip Depth Depth TVDSS Name Lithology Dip Direction (ft) (ft) (ft) ( °) ( °) 4,784.10 3,566.00 3,450.00 Top Sterling 0.00 0.00 4,856.31 3,609.00 3,493.00 CI -A 0.00 0.00 5,190.42 3,808.00 3,692.00 CI -1 0.00 0.00 5,229.95 3,832.00 3,716.00 C.l.2 0.00 0.00 5,594.93 4,078.00 3,962.00 CI -5 0.00 0.00 5,823.96 4,253.00 4,137.00 C.I. 8 0.00 0.00 III 6,068.40 4,455.00 4,339.00 Beluga -A 0.00 0.00 7,526.54 5,851.00 5,735.00 Beluga M 0.00 0.00 8,008.38 6,331.00 6,215.00 Beluga Q 0.00 0.00 8,163.97 6,486.00 6,370.00 Beluga S 0.00 0.00 8,570.52 6,891.00 6,775.00 Beluga U 0.00 0.00 8,896.76 7,216.00 7,100.00 Beluga Ubase 0.00 0.00 2J Targets Target Name Dip Dip - hlt/miss target Angle Dir. TVD +NI -S +E/ -W Northing Easting - Shape ( ( (ft) (ft) (ft) (ft) (ft) Latitude Longitude oe A- 16wp13 M Drilling 0.00 0.00 5,851.00 2,387.00 - 3,110.81 2,588,868.61 1,468,984.28 61° 4' 57.343 N 50° 58' 6.085 W ,�j•: - plan hits target r.1 - Circle (radius 140.00) t A- 16wp13 U Drilling 0.00 0.00 6,891.00 2,442.39 - 3,182.99 2,588,925.04 1,468,912.91 61° 4' 57.888 N 50° 58' 7.553 W - plan hits target - Circle (radius 140.00) • 09 June, 2008 - 8:45 Page 7 of 8 COMPASS ConocoPhillips (Alaska) Inc. -Expl HALLIIiBURTOINI North Cook Inlet Unit North Reference Sheet for North Cook Inlet Unit - Plan: NCI A -16 - Plan:NCI A -16 All data is in US Feet unless otherwise stated. Directions and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan: A -16 @ 116.00ft (Kuupik 5). Northing and Easting are relative to Plan: NCI A -16 - Slot 2001 Coordinate System is US State Plane 1983, Alaska Zone 4 using datum North American Datum 1983, ellipsoid GRS 1980 Projection method is Transverse Mercator (Gauss- Kruger) Central Meridian is 150° 0' 0.000 W °, Longitude Origin:0° 0' 0.000 E °, Latitude Origin:0° 0' 0.000 N° False Easting: 1,640,416.67ft, False Northing: 0.00ft, Scale Reduction: 0.99993224 Grid Coordinates of Well: 2,586,436.84 ft N, 1,472,059.88 ft E Geographical Coordinates of Well: 61° 04' 33.84" N, 150° 57' 02.83" W Grid Convergence at Surface is: -0.83° Based upon Minimum Curvature type'calculations, at a Measured Depth of 9,298.29ft the Bottom Hole Displacement is 4,075.50ft in the Direction of 307.50° (True). Magnetic Convergence at surface is: - 20.50° (12 September 2006, , bggm2007) X tvlagnetic Mt3 M Date: odel: 1 381>013 Gtv12007 °--.° Declination: 19.60° Inc p: 73.80° Field Strength: 55041 Grid North Is 0 .83° West of True North (Grid Convergence) 3neticNorth is19.66° East of True North (Magnetic Declination) netic North Is 20.50° East of Grid North (Magnetic Convergence) To convert a True Direction to a Grid Direction, Add 0.83° onvert a tylagnetieDiredion to a True Direction, ALid 19.66° East convert a 141agneticDiredion to a Grid Direction, Add 20.50° 09 June, 2008 - 8:45 Page 8 of 8 COMPASS "{ I ConocoPhillips (Alaska) Inc. -Expl North Cook Inlet Unit North Cook Inlet Unit Plan: NCI A -16 PIan:NCI A -16 A- 16wp14 • perry Drilling _ Clearance Summary Anticollision Report 09 June, 2008 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: North Cook Inlet Unit - Plan: NCI A -16 - PIan:NCI A -16 - A- 16wp14 Well Coordinates: 2,586,436.84 N, 1,472,059.88 E (61° 04' 33.84" N, 150° 57' 02.83" W) • Datum Height: Plan: A -16 @ 116.00ft (Kuupik 5) Scan Range: 0.00 to 9,298.29 ft. Measured Depth. Scan Radius is 1,108.13 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100 /1000 of reference Scan Type: 25.00 , �,..;;y ,...;2 .. ,"46" +. x.n:3.'atleS.. .,.-iv �,7w,v, ' .., .t.L •• „ ...am. ,.A <a s.i.:"o'.a r Gi1:c+, :ry°” .•E.?s- .'In"iv xc"'Nrm= :+'F#F+T'§ q p p T Sperry Drilling rr, 1�, Services SURVEY PROGRAM j ConocoPhillips (Alaska) Inc. -Expl Date: 2008.06- 09T(ttt:OU:uu Validated: Yes Version: 1 Engineering MD, Interval: 25.00 Calculation Method: Minimum Curvature 217.00 To 9298.29 Depth ►'rum Depth' 1., Sur%ey /Plan 'foul Error System: ISCWSA Centre Distance: 1108.13 217.99 699.00 A-16wp14 (Plan:NCI A -16) GYD -GC -SS Scan Method: Tray. Cylinder North Plan: A- 16wp14 (Plan: NCI A- 16 /PIan:NCI A -1 ) 1000.09 9298.29 A- 16wp14 (Plait:NCI A -16) t111VD +SCC Error Surface: Elliptical Conic Warning Method: Rules Based 0 330 r -` 30 From Colour To MD t4C1U A NCIU A -1 217 250 fo � �� r r 250 500 � ��'* l ; 500 750 r � . 1> J `'( r� ° y i' 300 - ♦.4p. ` etti#6° • _ 750 1000 �� A `'��A�A�� •a ' , '1 NCIU A -Og ► GER w• NCI B -0} , i 4r f 11 ' 4,11 , 1 000 1250 , I � '� - a '' ' 4 / 1� WA� l �� ' 4 i. 0 4 4 s ik } i NCIU A -D ) � 41 NCIU B -0 '' „�%a � r a a r ., 4 N q J' � '►�'�� \, ��I � �8 1250 1500 . p t 1500 1750 ' �� ) /i/ T ti 1� y o4 ° ' ` 71��\� 40�� ` " 1 1 ►� • ., x' / 11 &' �, -;40 N * .°: � .z I 300 ��, _��;� + � _ 1750 ..- -- -__...._ 2000 e ;N Z . ! ;, J j K' " '� a '_ � " �� 2000 2500 ,, , .,'',P'Y ,,- 44, '' •, • f :, ,. -" i ft , . .f ' z,,, i � �`. �� _ 2500 3000 �, � If r . D m,�, 1 -' 44,- ' , 3 0 as ; II �" , ♦ k� 0, s � ,' t ,,,e y€ * i ••vit y - 4 ' 1 811811/ ;� � , . 71 1, . JCK1 A - 1 `y ��A I r* , i 1 A ` ` -�y 9 z ri 6 ` ' %i �t e c • 3000 3500 ► �� ew a ay /I� 1 /: ��"` 70 � �1ril �� ;'e✓i P � '�n, � j'f 9 � ?� .,� n. � .? r � +'(: i� U ¢ \ , ' �� .�� r• 3500 4000 *4; 1'171 ( s 3 t ' ^ v„ ! r` .,,�. 1V 90 G o �f ■.r ,' r I ) pr e °°. ►- 1' / �,rl�e in Ifs r�,rr d' v i!( 270 V I I � ' _ +w )` )� ' OJT 4000 4500 111 � ' x� �.N�y'+��" "` +. t�� • ' 4500 5000 ' • t`' ' ` i A !► v � ;. , ; $ NCIU A -04 .�� l r, j ,.k lAgi ! , ' ` j /' 5000 - ._�.�. - 6000` � _'8, srl`J.cL�`n��l�;�F.��" ,4 •�� ` \\ �� : 6000 7000 �� <�u r 1104 gi �!i�i ti ir� � i 7 >� , i \ �, ,/ �1 t M� f . klIt‘ F %tir" a4 �y s r1�, 1 : NCIU A -0 , � ✓ . t �.�' 7000 8000 �N" 6 ' ,(� � idt f. • .� ° ♦ �� '+ 1 �Jly. ' v b 1 c � � 3 • t O�A h: - ! 240 ,� `/�� 11 ` = 44,411 120 8000 9000 �v .tt �i� v s� /� ° . �c = ... I NCIU A - 12 � � ' j ` .� o s C�i � 9000 10000 . ►�� ° '� f °i o 0 , r�� c `' .��'��1 \ ) � `� :� F YsI° 2 40 i (\` .; " - - �+ v *, . . : .44. 1 20 , , ' �, IM.„ � '� r -10000 12000 \ II '�' -�/ a, . � - --IA...., : - \ °� ) Q � °. . .+9/ �S� F NCIUB -03 12000 14000 \ � 1 a\v ;VS S ' i. .' : ; ' ' , _ , Cw B -0 t h i 14000 16000 8 0o III4 1,i@ 4 , 4 7 " : NCIU B o1 NCIU A -0 la , 16000 18000 111-;:!--....`,. w �� , � t 11 y �! � d: 9 ` ��0 - now A-0 1 8000 20000�`o =� � ' r/ )� - Travelling Cylinder Azimuth (TFO +AZI) [°] vs Centre to Centre Separation [20 Win) • • 20000 25000 �= - Q _ = 210 -'G ) %t a l li " °.�t7 ' 9 - 150 „ >.pt �- . ..,.;',- .z . , , 1 SECTION DETAILS 180 / 1 NCIU B - 0$ Sec MD Inc Azl TVD +N / -S +E/ -W DLeg TFace VSec Target 1 1 217.00 0.00 0.00 217.00 0.00 0.00 0.00 0.00 0.00 NCR") A 1 2 450.00 0.00 0.00 450.00 0.00 0.00 0.00 0.00 0.00 i NCIU A - 3 550.00 2.00 310.00 549.98 1.12 -1.34 2.00 310.00 1.74 4 690.00 2.00 310.00 689.89 4.26 -5.08 0,00 0.00 6.62 NAD 27 ASP Zone 4 : WELL DETAILS: Plan: NCI A - 5 990.05 10.00 255.00 988.19 0.88 -34.32 3.00 -65.38 27.76 6 1267.43 15.00 295.00 1259.38 9.84 -90.24 3.50 80.61 77.58 Water Depth: 101.00 7 1894.57 40.00 300.00 1811.32 147.12 - 342.39 4.00 7.59 361.20 +14/ +E/ Northing Easting Latittude Longitude Slot 8 2274.20 53.45 309.77 2071.29 306.60 - 566.57 4.00 31.36 636.14 9 9 9 9 5177.03 53.45 309.77 3800.00 1798.37 - 2358.96 0.00 0.00 2966.27 0.00 0.00 2586436.84 1472059.88 61° 4' 33.842 N 150° 57' 2.834 W 2001 10 7114.60 5.15 296.90 5440.71 2370.03 - 3078,04 2.50 - 178.47 3884.76 11 7488.27 5.15 296.90 5812.88 2385.21 - 3107.95 0.00 0.00 3917.73 REFERENCE INFORMATION 12 7526.54 5.00 307.60 5851.00 2387.00 - 3110.81 2.50 104.29 3921.08 A- 16wp13 M Drilling Target 13 7527.42 5.00 307.50 5851.87 2387.05 - 3110.87 1.00 -90.05 3921.16 Co - ordinate (N /E) Reference: Well Plan: NCI A - - Slot 2001, True North 14 8570.52 5.00 307.50 6891.00 2442.39 - 3182.99 0.00 0.00 4012.07 A- 16wp13 U Drilling Target Vertical (TVD) Reference: Plan: A 116.0011 (Kuupik 5) 15 9298.29 5.00 307.50 7616.00 2481.01 - 3233.32 0.00 0.00 4075.50 Section (VS) Reference: Slot - 2001(0.00N, 0.00E) Measured Depth Reference: Plan: A -16 @ 116.00ft (Kuupik 5) Calculation Method: Minimum Curvature . ConocoPhillips (Alaska) Inc. -Expl HALLIOLIV-1TrecN North Cook Inlet Unit Anticollision Report for Plan: NCI A-16- A- 16wp14 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: North Cook Inlet Unit - Plan: NCI A -16 - PIan:NCI A -16 - A- 16wp14 Scan Range: 0.00 to 9,298.29 ft. Measured Depth. Scan Radius is 1,108.13 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Welibore Name - Design (ft) (ft) (ft) (ft) ft North Cook Inlet Unit ID NCIU A -01 - N COOK INLET UNIT A -01 - N COOK INI 225.00 85.81 225.00 84.22 225.00 54.052 Centre Distance Pass - Major Risk NCIU A -01 - N COOK INLET UNIT A -01 - N COOK INI 349.98 87.47 349.98 83.94 350.00 24.776 Clearance Factor Pass - Major Risk NCIU A -02 - N COOK INLET UNIT A -02 - N COOK INI 225.00 89.71 225.00 88.13 225.00 56.497 Centre Distance Pass - Major Risk NCIU A -02 - N COOK INLET UNIT A -02 - N COOK INI 524.31 91.64 524.31 85.23 525.00 14.286 Clearance Factor Pass - Major Risk NCIU A -03 - N COOK INLET UNIT A -03 - N COOK INI 1,329.93 47.12 1,329.93 26.60 1,350.00 2.297 Centre Distance Pass - Major Risk NCIU A -03 - N COOK INLET UNIT A -03 - N COOK INI 1,353.42 47.18 1,353.42 26.12 1,375.00 2.241 Clearance Factor Pass - Major Risk NCIU A -04 - N COOK INLET UNIT A -04 - N COOK INI 499.55 85.00 499.55 78.62 500.00 13.318 Centre Distance Pass - Major Risk NCIU A -04 - N COOK INLET UNIT A -04 - N COOK INI 698.35 86.83 698.35 76.83 700.00 8.685 Clearance Factor Pass - Major Risk ( NCIU A -05 - N COOK INLET UNIT A -05 - N COOK INI 225.00 92.29 225.00 90.05 225.00 41.130 Centre Distance Pass - Major Risk NCIU A -05 - N COOK INLET UNIT A -05 - N COOK INI 524.24 94.26 524.24 86.32 525.00 11.864 Clearance Factor Pass - Major Risk =. NCIU A -06 - N COOK INLET UNIT A -06 - N COOK INI 524.16 80.28 524.16 73.84 525.00 12.479 Centre Distance Pass - Major Risk .Z NCIU A -06 - N COOK INLET UNIT A -06 - N COOK INI 698.00 81.50 698.00 72.21 700.00 8.776 Clearance Factor Pass - Major Risk NCIU A -07 - N COOK INLET UNIT A -07 - N COOK INI 225.00 88.96 225.00 87.37 225.00 56.018 Centre Distance Pass Major Risk NCIU A-07 N COOK INLET UNIT A -07 - N COOK INI 449.97 90.08 449.97 84.70 450.00 16.763 Clearance Factor Pass - Major Risk NCIU A -08 - N COOK INLET UNIT A -08 - N COOK INI 450.00 82.08 450.00 76.61 450.00 15.014 Centre Distance Pass - Major Risk NCIU A -08 - N COOK INLET UNIT A -08 - N COOK INI 698.59 83.52 698.59 73.47 700.00 8.315 Clearance Factor Pass - Major Risk NCIU A -09 - N COOK INLET UNIT A -09 - N COOK INI 217.60 10.21 217.60 8.78 175.00 7.133 Centre Distance Pass - Major Risk e NCIU A -09 - N COOK INLET UNIT A -09 - N COOK INI 492.43 11.39 492.43 5.41 450.00 1.905 Clearance Factor Pass - Major Risk NCIU A -10 - N COOK INLET UNIT A -10 - N COOK INI 442.69 8.44 442.69 3.04 400.00 1.563 Centre Distance Pass - Major Risk NCIU A -10 - N COOK INLET UNIT A -10 - N COOK INI 517.55 8.99 517.55 2.34 475.00 1.351 Clearance Factor Pass - Major Risk NCIU A -10 - N COOK INLET UNIT A -10A - N COOK If 442.69 8.44 442.69 3.04 400.00 1.563 Centre Distance Pass - Major Risk NCIU A -10 - N COOK INLET UNIT A -10A - N COOK If 517.55 8.99 517.55 2.34 475.00 1.351 Clearance Factor Pass - Major Risk NCIU A -11 - N COOK INLET UNIT A -11 - N COOK INI 217.70 7.87 217.70 6.18 175.00 4.639 Centre Distance Pass - Major Risk NCIU A -11 - N COOK INLET UNIT A -11 - N COOK INI 517.57 9.71 517.57 3.06 475.00 1.459 Clearance Factor Pass - Major Risk NCIU A -12 - N COOK INLET UNIT A -12 - N COOK INI 976.56 46.69 976.56 31.13 975.00 3.000 Centre Distance Pass - Major Risk NCIU A -12 - N COOK INLET UNIT A -12 - N COOK INI 1,102.23 47.40 1,102.23 29.60 1,100.00 2.662 Clearance Factor Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13 - N COOK INI 1,617.01 43.34 1,617.01 14.91 1,625.00 1.524 Centre Distance Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13 - N COOK INI 1,641.41 43.34 1,641.41 14.51 1,650.00 1.503 Clearance Factor Pass - Major Risk 09 June, 2008 - 8:16 Page 2 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Expl ALL LILT North Cook Inlet Unit Anticollision Report for Plan: NCI A -16 - A- 16wp14 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: North Cook Inlet Unit - Plan: NCI A -16 - PIan:NCI A -16 - A- 16wp14 Scan Range: 0.00 to 9,298.29 ft. Measured Depth. Scan Radius Is 1,108.13 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Welibore Name - Design (ft) (ft) (ft) (ft) ft NCIU A -13 - N COOK INLET UNIT A -13PB1 - N COOP 1,617.15 42.49 1,617.15 9.59 1,625.00 1.292 Centre Distance Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB1 - N COOL 1,641.56 42.55 1,641.56 9.12 1,850.00 1.273 Clearance Factor Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB2 - N COOL 1,617.15 42.49 1,617.15 9.59 1,825.00 1.292 Centre Distance Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB2 - N COOF 1,641.56 42.55 1,641.56 9.12 1,650.00 1.273 Clearance Factor Pass - Major Risk • NCIU A -13 - N COOK INLET UNIT'A -13PB3 - N COOP 1,617.15 42.49 1,617.15 9.59 1,625.00 1.292 Centre Distance Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB3 - N 0001. 1,641.56 42.55 1,641.56 9.12 1,650.00 1.273 Clearance Factor Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB4 - N COOF 1,617.15 42.49 1,617.15 9.59 1,625.00 1.292 Centre Distance Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB4 - N COOP 1,641.56 42.55 1,641.56 9.12 1,650.00 1.273 Clearance Factor Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB5 - N COOP 1,617.15 42.49 1,617.15 9.59 1,625.00 1.292 Centre Distance Pass - Major Risk ''' NCIU A -13 - N COOK INLET UNIT A -13PB5 - N COOP 1,641.56 42.55 1,641.56 9.12 1,650.00 1.273 Clearance Factor Pass - Major Risk NCIU A -13 - N COOK INLET UNIT A -13PB6 - N 0001 1,617.15 42.49 1,617.15 9.59 1,625.00 1.292 Centre Distance Pass - Major Risk ..- NCIU A -13 - N COOK INLET UNIT A -13PB6 - N 0001 1,641.56 42.55 1,641.56 9.12 1,650.00 1.273 Clearance Factor Pass - Major Risk '-.. NCIU A -13 - N COOK INLET UNIT A -13PB7 - N COOP 1,617.15 42.49 1,617.15 9.59 1,625.00 1.292 Centre Distance Pass - Major Risk ' x NCIU A -13 - N COOK INLET UNIT A -13PB7 - N COOP 1,641.56 42.55 1,641.56 9.12 1,650.00 1.273 Clearance Factor Pass - Major Risk NCIU B -01 - N COOK INLET UNIT B -01 - N COOK INI 1,058.90 25.27 1,058.90 10.82 1,075.00 1.749 Clearance Factor Pass - Major Risk -- NCIU B -01 - N COOK INLET UNIT B -01A - N COOK II 1,058.90 25.27 1,058.90 10.82 1,075.00 1.749 Clearance Factor Pass - Major Risk `"--- ° NCIU B -02 - N COOK INLET UNIT B -02 - N COOK INI 760.38 57.58 760.38 47.53 775.08 5.727 Centre Distance Pass - Major Risk NCIU B -02 - N COOK INLET UNIT B -02 - N COOK INI 809.92 58.03 809.92 47.23 825.00 5.373 Clearance Factor Pass - Major Risk NCIU B -02 - SUNFISH 3 - SUNFISH 3 760.38 57.58 760.38 47.96 775.08 5.985 Centre Distance Pass - Major Risk NCIU B -02 - SUNFISH 3 - SUNFISH 3 809.92 58.03 809.92 47.66 825.00 5.597 Clearance Factor Pass - Major Risk NCIU B -03 - N COOK INLET UNIT,B -03 - N COOK INI 1,290.87 28.01 1,290.87 10.12 1,300.00 1.566 Centre Distance Pass - Major Risk IIII NCIU B -03 - N COOK INLET UNIT B -03 - N COOK INI 1,314.86 28.55 1,314.86 10.12 1,325.00 1.549 Clearance Factor Pass - Major Risk NCIU B -03 - N COOK INLET UNIT B -03PB1 - N 0001 1,290.87 28.01 1,290.87 10.12 1,300.00 1.566 Centre Distance Pass - Major Risk NCIU B -03 - N COOK INLET UNIT B -03PB1 - N COOP 1,314.86 28.55 1,314.86 10.12 1,325.00 1.549 Clearance Factor Pass - Major Risk 09 June, 2008 - 8:16 Page 3 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Expl H;a L U T N North Cook Inlet Unit Anticollision Report for Plan: NCI A-16- A- 16wp14 Survey tool oroaram From To Survey /Plan Survey Tool (ft) (ft) 217.00 690.00 A- 16wp14 GYD -GC -SS 1,000.00 9,298.29 A- 16wp14 MWD +SCC Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. • Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 09 June, 2008 - 8 :16 Page 4 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Expl D-1].A.LLISUATEDN North Cook Inlet Unit Anticollision Report for Plan: NCI A -16 - A- 16wp14 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan: A -16 @ 116.00ft (Kuupik 5). Northing and Easting are relative to Plan: NCI A -16 - Slot 2001. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is - 150,00 °, Grid Convergence at Surface is: -0.83 °. LEGEND Ladder Plot I CIU A -01, II COOK INLET UNIT A -01, N COOK INLE I CIIJ A-02, N COOK INLET UNIT A-02, 11 COOK INLE •- hCIIJA -03, U COOK INLET UNIT A•03, N COOK INLE` i • I i i I I I I - �4- FCIUA.04,11 COOKINLETUNITA:04,N COOK INLE - -_ _ 0 I ; I I H I CIU A -OS, N COOK INLET UNIT A -05, N COOK INLE -.f-- f CIUA•06, N COOK INLET UNITA -O6,N COOK INLE CD ; a l-n I =�{- t, CIU A -07, t1 COOK INLET UNIT A -07, I1 COOK R1LE I 3 I ' -A- I CIU A -OS, N COOK INLET UNIT A -OS, N COOK INLE = s -a- I CIU Atha, N COOK INLET UNIT A -DO, N COOK INLE I �t;• L ICIUA- 10, NCOOK, INLET UNIT A- 10,N COOK II.ILE +�� 1 1, : Afii' '" r cm A•10, N C O O K UIJIT A•10A, N COOK INLC1 } � �� a ..- t CIU A -11, N CO 0 K INLET UNIT A -11, N COOK INLE` ;` {','i ' -]-I, CIIJA•12,NCOOK INLET IJNITA•12,N COOK IIILE 47 I ' , : 1 . ' ' F C I U A -13, F1 COOK INLET UNIT A•13, I1 COOK INLE` _ - -- I � - C I U C O O K C O O K a, �' ,, I * i i -;-- I•CIU A -13, N COOK INLET UNIT A- 13PB2, N COOK la / 0 ' I f I CIU A-13, N COOK INLET UNIT A-131 N COOK I It - 350 il, . sI d f? �� LC:IU A -13, N COOK: INLET UNIT A- 13PB4, I.1 COOK I a e a s t I , ,;, I A -1:3, N COOK INLET UNIT A- 1:3P05, N COOK I IL C r r : � : I l - I l l • 0 � � ^ I . . J'i I " - I C I L I A - 1 3 , COOK INLET __ C ''' 1 ' I I CIU 0.01, N COOK INLET UNIT 0.01, N COOK INLE I I I I I .ai_ I CIU B -01, N COOK INLET UNIT 0•01A, N COOK INLE1 3,s I• CIU B -02, II COOL; INLET UNIT B -02, N COOK INLE 0 1500 3000 4500 6000 7500 I CIU 8.02, SUNFISH 3, SUNFISH 3 VO Measured Depth (1 500 i�� -{3•- hC ILI B -0:3, N COOK INLET UNIT 8 -03, N COOK INLE •. - h C IU 0-03, N COOK INLET UNIT B- 03P01, N COOK I it -R- A•16wo14 09 June, 2008 - 8 :16 Page 5 of 6 COMPASS ■ ConocoPhillips (Alaska) Inc. -Expl 1-1ALLIE3URTC1INI North Cook Inlet Unit Anticollision Report for Plan: NCI A -16 - A- 16wp14 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor _ - i Tri f 1 4 : t f 1 1 I 1 1 11 1 I ! ( t 1 I t 1 1 1, 1 LEGEND _ t ,, IOSID - - - 1 . 1 : + 7 1- , 1 i, ' i 1 ..- ' _' ' I , -, NCIU A -01, N COOT: INLET LINIT A -01, N COOK INLET UN ; I'i 1 i 1 r NCIU .A•02, PJ COOK INLET UNIT A -02, N COOK INLET UN - , 5 1 1 p LS - ( .1 1 ' I••. N • II t l k N A -03, N COOK INLET UNIT A•03, II COOK INLET UN >a75 � , ! _i ' __ ___ _ - _. _ NC' A -U4, N COOK INLET UNIT A•D�, N COOK INLET UN _ , !..;� �' I NCIU UNIT A -05, N COOK INLET UN K INLET UNIT , N COOK INLET _ ..: NCIU COO 0 " ' INLET IT 4 IICI A•06 N I ItJL IT A- 6 LET FI 0 -- -; I.Ali J_ t 4 __ NCIU A•07, N COOK INLET UNIT A•07, N COOK INLET UN . r � 1 � NCIU A•0B, N 000K INLET } y UFJI T A•00, N COOK IN UN U f - r I ! ` NCIU ADD, N COOK INLET UNIT A -DO, N COOK. INLET UN ` .. - 5 NCIU A -1D, 1 COOK INLET UNIT A•10, I1. COOK INLET UN o ' j ,. _ a, I �;:. NCIU A -1D, N COOK INLET UNIT A -10A, N COOK INLET UI C W - f `,4 k : ` NCIU A•11, N COOK INLET UNIT A -11, II COOL. INLET UN G 5.00 -- • - 1 ' - - _ - _ tea' NCIU A -12, N COOK INLET UNIT A -12, N COOK INLET UN ;,; ra NCIU A•13, II COOK. INLET UNIT A•13, N COOK INLET UN ' r cc - 4 .. � NCIU A•13, N COOK INLET UNIT A- 13PB1, N COOK INLET - - - -- - co 3.75 r + "F I , i �.6' -I � NCIU A -13, N COOK INLET UNIT A- 13PB2, N COOK, INLET - . 9 a A _ 3 COOK INLET , , , INLET - '' r '. �` �` I NCIU A•13, N COOK INLET UNIT A•13PO4, N COOT: INLET 250 � 1 - , 1 i ' i' '"i . rr _ � - ' '• • NCIU A -13, N COOK INLET UNIT A- 13PB5, N COOK INLET D � NCIU A•13, N COOK INLET UNIT A•13PB6, N COOK INLET 1 J'.. 't / . " n:u - NCIU A -13, II COOK INLET UNIT A- 13Pb7, N COOK INLET <, y ,, Al s , i _ IBS -- _ - 1 -- - NCIU B -01, N COOK INLET UNIT B•01, t J COOL: INLET UN I S I IL: °'. NCIU B•U1, N COOK INLET UNIT B-01A, N COOT: INLET UI I , NCIU B -02, N COO INLET UNIT 0.02, II COO INLET UN DL1U 1 1 1 1 1 1 1 1 1 1 I I 1 1 1 1 I 1 1 1 1 I 1 1 1 1 1 1 1 1 1 I I 1 1 1 1 1 1 I I 1 1 1 1 1 1 1 1 1 I i '. , I NCIU B -u2, SUNFISH 3, SUNFISH 3 LO 1 D 750 1500 2250 3000 3750 1.500 5250 5000 5750 7500 5250 9000. NCIU b - U3, N L: 0401; INLET UNIT H•G3, P: II COOK INLET UtJ tvte�SUI0�1 Depth (1500 Min) B -03, N COOK INLET UNIT 0- 03PB1, N COOK INLET - , t A- 16w p14 09 June, 2008 - 8:16 Page 6 o(6 COMPASS Application for Per•Drill, Wells NCIU A -14, A -15, A -16 Revision No.0 Saved: 9- Jun -08 Attachment 2. BOPE & Diverter • • • • • • • Revised 5 -08 Rig Floor ■ 21" Bottom of Rota Table 1 i 5? Flow Nipple 45" 13 5/8" Annular $ 121" 1 10'? 34 1/4" 13 5/8" Double Gate 24" L — 13 5/8" Mud Cross i r 1 8 ° 1 ° 0 17 3/4" 13 5/8" Single Gate o ; B" 1 • 36" Sub Base Skid 8 2 4" Kuukpik Skid Base 82" Phillips Sub Skid Base 6" Pin Rails I Drill Deck - - 154" from wellhead to drill deck 2 I' 3 " To Shaker 3" Panic To Gasbuster rn. ( ' L : 1 ) 3 1/8" _ 2 1/16" O 21/16" r -�- I C 1 --f - I j_l t N CP) 2 1/1 + 2 1/16" + Zo / 3 1 /8" • ai.o o ? ' " L I 0 Mll =M MIMI -k....60...111 D I ii 1 21/16" 21/16" G) Manual Choke w Automatic Choke = 2 1116" Inlet Pressure Sensor • 3" 5,000 PSI Choke Manifold Kuukpik Drilling Rig 5 RED = 3 1/18" 5,000 PSI VALVES AND LINES BLUE = 2 1/16" 5,000 PSI VALVES Kuukpik Drilling Rig 5 Choke Manifold Drawn By: L Ross Date: 8/1/04 • • Revised 5-08 Rig Floor 21" Bottom of Rotary Table 1 7.5" 14" ottom of Rotary Beams § 20" Annular 50.5" I L Diverter opening center line 1 0 oc't ° Diverter Line Openir g 72" Diverter Spool m g 74 • , r 21 1/4" 2,000 Flange 36" Sub Base Skid S 24" Kuukpik Skid Base ."2 82° Phillips Sub Skid Base 0 ;,- t d I o 0 o:i 8 6" Pin Rails Drill Deck 208" from Wellhead to drill deck ;*-) rl l‘l14. : fv p Application for Pe• Drill, Wells NCIU A -14, A -15, A -16 • Revision No.0 Saved: 9- Jun -08 Attachment 3. Drilling Hazards Summary 12 -1/4" Hole / 9 -5/8" Casing Interval Event Risk Level Mitigation Strategy / Contingency Collision with existing platform High Re- survey existing wells with high accuracy gyro, wells set downhole plugs in wells that do not pass Major Risk and present possibility of uncontrolled flow, pressure surveys in existing wells, existing well monitoring & shut -in plan Clay Balling Medium Maintain planned mud parameters, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP. Running sands & gravel Moderate Maintain planned mud parameters, Increase mud weight/viscosity, Use weighted sweeps, monitor fill on connections Abnormal Pressure in Surface Low Diverter drills, increased mud weight. Offset drilling Formations does not indicate abnormal pressures in the surface hole. Hole swabbing /Tight hole on Moderate Circulate hole clean prior to trip, proper hole filling trips (use of trip sheets), pumping out of hole as needed Stuck surface casing Low Clean the hole before running casing, pump high density high viscosity sweeps, wiper trip Lost circulation Low Keep hole clean. If losses occur — reduce pump rates and mud rheology, use LCM, controlled running speeds 8 -3/4" Hole / 7" Casing Interval Event Risk Level Mitigation Strategy / Contingency Insufficient or Low Importance of LOT communicated to all parties, undetermined LOT all parties familiar with LOT procedure. Test will be carried out until leak off is observed or to an FIT of 18 ppg MW equivalent High ECD / Tight hole on Moderate ; Condition mud & clean hole prior to trips. trips/ Swabbing Reduced trip speeds. Monitor ECDs with PWD tool. Hole cleaning best practices. Backream out on trips as a last resort, proper hole filling (use of trip sheets) Differential sticking High Keep hole clean, periodic wiper trips, keep pipe moving /rotating with pumps on whenever possible Unstable coals High Communicate warning signs & expectations, follow best practices, PU immediately when detected, control drill one to two feet at a time. Keep surge and swab effects under control. Sloughing shale, tight hole High • Increased mud density to control the shales and . fluid composition according to plan, controlled trip speeds, sweeps, ECD monitoring. • Application for Permit to7Rfl, Wells NCIU A -14, A -15, A -16 Revision No.O Saved: 9- Jun -08 Event Risk Level Mitigation Strategy / Contingency Lost circulation High Pretreat mud before drilling low pressured sections, keep hole clean — use PWD to monitor hole cleaning, reduced trip speeds. If losses occur — reduce pump rates and mud rheology, use LCM Abnormal Reservoir Low Well control drills, increased mud weight, offset Pressure well data does not indicate abnormal pressures in the area. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers • Application for Permiarill, Wells NCIU A -14, A -15, A -16 Revision No.0 Saved: 9- Jun -08 Attachment 4. Fluid System • • nirINIA Volume Tank T Suction Tank • • Groan . ;taw My. Mud Tanks With Mud Flow 3t. §t' Mud Tanks With Tank Compartments and Agitators Volume Tank Suction Tank Agt.enrs '777% -- E r 4 A Degasser Tank Centrifuge Tank Stmt. Tank I 70 BBLS 130 BBLS VnkaoaTank 80 5131.5 Pill Tank SO SOILS OS SSLS 520 SaLS Action Volume 30 BBLS Trip Tank 30 BOILS Fill Tank 1111111 In i ' 1=Ot-T.:7 71 ! !111 11111 mud Talk:: With Stadion Unes Gun Unes in Tanks re-- — 0 0 C From Mud Gun Pump t -7 7-77777777 . Volume Tank Suction Tank Upper Building With Solids Equipment S Vaccom Ogoasser IF Chair OSI uenthruge Swaco 516 Kuukplk Drilling Rig 5 Rigs Mud System ,v/Solids Equipment/Flow/Volumes Drawings Mud System on Leg 2 Tyonek glatloms Drawn Sys L Ross Leg 2 Tyonolt Pladomi Date: 6/15/03 ( ieNIK1 L 11# • Application for Pere) Drill, Wells NCIU A-14, A-15, A-16 Revision No.0 Saved: 9-Jun-08 Conductor tExisitinal: AO 30F set ii. - 400 It f.: .4.,,,.... NCIU 1 8,_16 3C. _ 3.3.V 14 with " SS control line to surface ..,_ ■•'' +k- 460" MD .;?., 5 TOC 600' .:j above top 5 TOC +1 4284 MD f 3268' TVD ji. Cook Inlet Surface Cauina: go 5 9-518", 40ff, L-80, BTCM r ' 5 Set g 4532' MD / 3416' 'ND 6: 5 t5� TVD above Cook Inlet) 5 .; .t 1 ,- a ilari HES HO stage tool a. +/- 4784' MD -CC; \i,7N GEMCY iF THERE ARE LOST CIRCULATION • CD 0 o; 4,14" CWITCO KGB-2 GLM w/ 1" DCK2 shear valve f, III SC-2 PaOl \Iv/ WIWI Extension 5 ,wwwil w ..:: - .m...... I■sr— r ill.111 0 C- .J.LAS $ ■•=11•1■11. 11I■1 ; ; ■ SC-i twaliioc1 Pacer 5 ......., 11.1. ..: 3 Zone MZ Pack :5 5 . 5 s r, r, Um. Beluga A - U •i !WOW IFS Seam Packer ,5 SC-2 Packev wif.41ennate SoTe 5 5 5 Lower Beluga will require 4 '12" r, `;- Conventional Gravel Pack Fracs followed by HRWP I. SI VloattAi FS SGIWID Padker : =0 SigorIstetiort Casino: gill C 7, "".` &X, p....-so, 3TCM 5 Pli - IN e # Tyonek 2008 PERMIT IT.doc ORIGINAL P rinted: 9-Jun-08 • TRANSMITTAL LETTER CHECKLIST WELL NAME A PTD# 21 d /Development, Service Exploratory Stratigraphic Test Non- Conventional Well FIELD: ti ;-\\-- AAA- POOL: \ Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conser n der approving a spacing / exception. (� 4 y� � i""��S assumes the V 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 (Companv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Companv Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/112008 WELL PERMIT CHECKLIST Field & Pool NORTH COOK INLET, TERTIARY GAS - 564570 Well Name: N COOK INLET UNIT A-16 Program D , EV _ Well bore seg U PTD#: 2080980 Company CONOCOPHLLLIPS ALASKA INC Initial Class/Type DEV / PEND Geo Area 820 Unit 11450 On/Off Shore Off Annular Disposal Ei Administration 1 Permit fee attached NA 2 _Lease_number _appropriate Yes Surface location in AIX-17589, top prod int & TD in.AOL_ 3_7831 3 Unique well name and number Yes 4 Well_located in a defined pool Yes NORTH COOK INLET, TERTIARY GAS - 564570 govemed by CO 68. 5 Well located proper_distance_fro_m_ drilling unit boundary No SPACING EXCEPTION REQUIRED: will be in same section as, and within 6 Well located proper distance from other wells No 3000' of, other gas producers. Spacingexception in progress, will be in 7 Sufficient acreage available in drilling unit No effect prior to spud of well. 8 If deviated, is_ wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has_appropriate_ bond inforce Yes 11 _Permit can be issued without conservation order No Appr Date 12 Permit can be issued without administrative_approval Yes SFD 6/16/2008 13 Can permit be approved before 15-day wait Yes • 14 _Welllocated within area and_strata _authorized by Injection Order # (put IO# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service_weil only) NA 16 Pre-produ_ced injector; duration_of pre-production Less than 3 months (For seryice welt only) NA 17 Nonconven, gas conforms o AS31,06,030(j,1„A),(j,2.A-D) NA Engineering 18 Conductor string provided Yes 19 Surface casing protects all_known_ USDWs Yes AEO 4 exempts all aquifers below 2900' rnd in well _NOW A-12._ Surface csg _planned at 3416' tvd. 20 _C_MT_v_ol adequate_ to circulate_on _conductor & surf csg Yes 21 _C_IVIT voi adequate to tie-intongatring to_stof sag No 22 _CMT will coverall known_productive horizons Yes 23 Casing de_signs adequate for C,_T, B & permafrost Yes 24 _Adequate_tan_kage_ Of reserve pit Yes Platform rig with steel pits. Wastes to bedis_charged as allowed. Class 2 disposal well available if needed. 25 _Ife re-drill, has_a 1_0403 for abandowne_nt been approved NA 26 _Adequate wellbore separatio_n_proposed Yes Proximity analysis performed Traveling cylinder path calculated. Gyros likelyin surface hole. 27 lfdiverterreq_uired, does it meet regulations Yes Diverter line is "short' but extends beyond platform edge. Appr Date 28 Drilling fluid_ program schernatic_& equip list adequate Yes Maximum expected formation pressure up to 9.Q in virgin Beluga. Planned MW up to 9.6 ppg. TEM 7/1/2008 29 _BOPEs„d_o_they meet regulation Yes , ,.0. 30 _BOPE_press rating ap_propriate; _test to_(put psig in comments) Yes MASP calculated at 2600 psi, 35Q0_psidrilling testproposed and 5000 _psifor _completions. -IIIk 31 _C_hoke_ manifold complies_ w/A_ P_ I_ RP-63 (May 84) Yes 32 Work will occur withoutoperation shutdown No 3 wells will be batch drilled resulting in some SD time on all wells. 33 is presence of H25 gas probable No H2S is not reported in CI gas production. 34 Mechanical condition of wells within AOR verified (For service well only) NA Geology 35 _Permit can be issued _w/o_ hydrogen sulfide measures Yes None expected, but sensors and alarms will be utilized. 36 _D_ata_p_resented on potential overpressure _zones Yes Reservoir pressure in overlying_ CO_OiC inlet sands may be 2 pp_g_EMW,_b_ut Appr Date 37 _Seismic analysis of shallow gas zones NA expected to be 6.0 - 9.0 in Beluga; will be drilled with 9.6 ppg mud. SFD 6/16/2008 38 Seabed condition survey (if off-shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA 1 ' Geologic Engineering - Date: Date Date Commissioner: Commissioner: siiire oner 1 • , . • . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically • organize this category of information. • NCIU A -16 PB2 LDWG.tapx Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Nov 14 13:31:14 2008 Reel Header Service name LISTPE Date 08/11/14 Origin STS Reel Name UNKNOWN continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 08/11/14 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER North cook Inlet MWD /MAD LOGS WELL NAME: NCIU A -16PB2 API NUMBER: 508832012771 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 14- NOV -08 JOB DATA MWD RUN 1 JOB NUMBER: MW- 000574425 LOGGING ENGINEER: A. MENEZES OPERATOR WITNESS: D. MORRIS SURFACE LOCATION SECTION: 6 TOWNSHIP: 11N RANGE: 9W FNL: 1304 FSL: FEL: FWL: 1016 ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 120.58 GROUND LEVEL: .00 WELL CASING RECORD Page 1 Oohs' 69 19-316 • • • NCIU A -16 PB2 LDWG.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 30.000 400.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER - MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR4), AND DRILLSTRING DYNAMICS SENSOR (DDSr) . 4. PRIOR TO MWD RUN 1 THE SURFACE SECTION HAD BEEN DRILLED TO 1120' MD, 1118' TVD WITHOUT MWD TOOLS. WHILE PERFORMING A MAD PASS AN UNINTENTIONAL SIDETRACK OCCURED AT 1045' MD, 1044' TVD. MAD DATA FROM SURFACE TO 1045' MD, 1044' TVD HAVE BEEN MERGED WITH DRILLING DATA. SROP FROM 460' MD TO 1045' MD IS RUNNING SPEED WHILE PERFORMING THE MAD PASS. 5. NCIU A -16PB2 EXITS WELLBORE NCIU A -16PB1 FROM AN OPENHOLE SIDETRACK AT 1045' MD, 1044' TVD. 6. MWD DATA IS CONSIDERED PRIMARY DEPTH CONTROL (PDC) PER WAYNE CAMPAIGN OF CONOCOPHILLIPS ALASKA, INC. IN A PHONE CALL WITH BRYAN BURINDA OF SPERRY DRILLING SERVICES ON NOVEMBER 13, 2008. THIS ONLY APPLIES TO NCIU A -16PB2 AS NCIU A -16 IS SHIFTED TO A USIT WL LOG WHICH DOES NOT COVER THE INTERVAL LOGGED IN NCIU A -16 PB2. 7. MWD RUN 1 REPRESENT NCIU A -16 PB2 WITH API #: 50 883 - 20127 - 71. THIS WELL REACHED A TOTAL DEPTH OF 1168 FT MD, 1166 FT MD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT- DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT- DERIVED RESISTIVITY (DEEP SPACING). Page 2 • NCIU A -16 PB2 LDWG.tapx SFXE = SMOOTHED FORMATION EXPOSURE TIME. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service sub Level Name Version Number 1 0 0 Date of Generation 08/11/14 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPD 396.0 1105.0 RPS 396.0 1105.0 RPX 396.0 1105.0 FET 396.0 1105.0 GR 403.5 1113.0 ROP 460.5 1168.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 396.0 1168.5 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .11N Max frames per record undefined Absent value -999 Depth units Datum specification Block sub- type...0 Page 3 • NCIU A -16 PB2 LDWG.tapx Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPS MWD OHMM 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 FET MWD HR 4 1 68 16 5 GR MWD API 4 1 68 20 6 ROP MWD FPH 4 1 68 24 7 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 396 1168.5 782.25 1546 396 1168.5 RPD MWD OHMM 11.53 322.11 71.2069 1419 396 1105 RPS MWD OHMM 6.93 72.16 26.1596 1419 396 1105 RPX MWD OHMM 5.16 39.65 15.3566 1419 396 1105 FET MWD HR 0.51 82.8 58.4045 1419 396 1105 GR MWD API 19.36 60.55 38.1854 1420 403.5 1113 ROP MWD FPH 0.79 1093.85 233.769 1417 460.5 1168.5 First Reading For Entire File 396 Last Reading For Entire File 1168.5 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/11/14 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/11/14 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SEDP 396.0 1105.0 SEMP 396.0 1105.0 SESP 396.0 1105.0 SEXP 396.0 1105.0 Page 4 4► NCIU A -16 PB2 LDWG.tapx SFXE 396.0 1105.0 SGRC 403.5 1113.0 SROP 460.5 1168.5 LOG HEADER DATA DATE LOGGED: 22- JUL -08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 1168.0 TOP LOG INTERVAL (FT): 460.0 BOTTOM LOG INTERVAL (FT): 1168.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .2 MAXIMUM ANGLE: 10.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 216261 EWR4 EWR Phase -4 81797 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 400.0 BOREHOLE CONDITIONS MUD TYPE: Native /Spud Mud MUD DENSITY (LB /G): 8.90 MUD VISCOSITY (S): 93.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 450 FLUID LOSS (C3): 14.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 3.500 71.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.249 77.0 MUD FILTRATE AT MT: 4.000 71.0 MUD CAKE AT MT: 3.250 71.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .AIN Max frames per record Undefined Absent value -999 Depth Units Page 5 4 • NCIU A -16 PB2 LDWG.tapx Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD010 OHMM 4 1 68 4 2 RPM MWD010 OHMM 4 1 68 8 3 RPS MWD010 OHMM 4 1 68 12 4 RPX MWD010 OHMM 4 1 68 16 5 FET MWD010 HR 4 1 68 20 6 GR MWD010 API 4 1 68 24 7 ROP MWD010 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 396 1168.5 782.25 1546 396 1168.5 RPD MWD010 OHMM 11.53 322.11 71.2069 1419 396 1105 RPM MWD010 OHMM 10 148.55 47.6942 1419 396 1105 RPS MWD010 OHMM 6.93 72.16 26.1596 1419 396 1105 RPX MWD010 OHMM 5.16 39.65 15.3566 1419 396 1105 FET MWD010 HR 0.51 82.8 58.4045 1419 396 1105 GR MWD010 API 19.36 60.55 38.1854 1420 403.5 1113 ROP MWD010 FPH 0.79 1093.85 233.769 1417 460.5 1168.5 First Reading For Entire File 396 Last Reading For Entire File 1168.5 File Trailer Service name STSLIB.002 service Sub Level Name Version Number 1 0 0 Date of Generation 08/11/14 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.003 Physical EOF Tape Trailer Service name LISTPE Date 08/11/14 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 08/11/14 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. scientific Technical Services Page 6 NCIU A -16 PB2 LDWG.tapx Physical EOF Physical EOF End of LIS File Page 7 1 NCIU A -16 LDWG.tapx Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Nov 13 17:40:43 2008 Reel Header Service name LISTPE Date 08/11/13 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 08/11/13 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER North Cook Inlet MWD /MAD LOGS WELL NAME: NCIU A -16 API NUMBER: 508832012700 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 13- NOV -08 JOB DATA MWD RUN 3 MWD RUN 6 MWD RUN 7 JOB NUMBER: MW- 000574425 MW- 000574425 MW- 000574425 LOGGING ENGINEER: A. MENEZES A. MENEZES A. MENEZES OPERATOR WITNESS: S. HEIM D. MORRIS D. MORRIS MWD RUN 8 JOB NUMBER: MW- 000574425 LOGGING ENGINEER: A. MUNRO OPERATOR WITNESS: D. MORRIS SURFACE LOCATION SECTION: 6 TOWNSHIP: 11N RANGE: 9W FNL: 1304 FSL: FEL: FWL: 1016 Page 1 80`r— (3 / NCIU A -16 LDWG.tapx ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 120.58 GROUND LEVEL: .00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 30.000 447.0 2ND STRING 8.750 9.625 4536.0 3RD STRING 8.750 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. NCIU A -16 EXITS NCIU A -16 PB1 AT 446' MD, 446' TVD DURING MWD RUN 2 THE RUN WAS DIRECTIONAL ONLY - NO DATA PRESENTED. 4. MWD RUN 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER - MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR4), AND DRILLSTRING DYNAMICS SENSOR (DDSr). 5. MWD RUN 4 NO FOOTAGE DRILLED. 6. MWD RUN 5 DRILLED 20' OUT OF CASING SHOE - ONLY SROP PRESENTED. 7. MWD RUN 6 -8 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER - MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR4), DRILLSTRING DYNAMICS SENSOR (DDSr) COMPENSATED THERMAL NEUTRON (CTN), AZIMUTHAL LITHO DENSITY (ALD), AND PRESSURE WHILE DRILLING (PWD). 8. ALD DATA FROM 6650' MD, 4983' TVD TO 6750' MD, 5080' TVD AND 6910' MD, 5236' TVD TO 7166', 5489' TVD WAS ACQUIRED AT THE START OF MWD RUN 8 DURING MAD PASSES TO FILL IN GAPS. 9. MWD DATA IS DEPTH SHIFTED TO THE PDC GR LOG (USIT) OF 17 -OCT -2008 PROVIDED BY WAYNE CAMPAIGN OF CONOCOPHILLIPS ALASKA, INC. LOG HEADER AND REMARKS SECTIONS RETAIN ORIGINAL DRILLER'S DEPTH REFERENCE. 10. MWD RUNS 2 -8 REPRESENT NCIU A -16 WITH API #: 50- 883 - 20127 -00. THIS WELL REACHED A TOTAL DEPTH OF 9314 FT MD, 7631 FT MD. Page 2 410 411 NCIU A -16 LDWG.tapx SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY- COMPENSATED (LOW -COUNT RATE BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW -COUNT RATE BIN). SNP2 = SMOOTHED NEAR - DETECTOR -ONLY PHOTOELECTRIC ABSORPTION FACTOR LOW -COUNT RATE BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: HOLE SIZE INDICATOR (RAPID SAMPLE) (8 3/4" NOMINAL) AVG OFFSET: FIXED (.3" NOMINAL) MUD WEIGHT: 9.2 - 9.4 PPG MUD SALINITY: 29,000 - 50,000 PPM CHLORIDES MUD TYPE: WATER BASED FORMATION WATER SALINITY: 345 PPM CHLORIDES FLUID DENSITY: 1.0 G /CC MATRIX DENSITY: 2.65 G /CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL I5 SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 service Sub Level Name version Number 1 0 0 Date of Generation 08/11/13 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH Page 3 411 410 NCIU A -16 LDWG.tapx RFD 1420.5 9270.0 RPM 1420.5 9270.0 FT 1420.5 9270.0 R 1420.5 9270.0 R X 1420.5 9270.0 G 1428.5 9276.0 R P 1483.0 9314.0 F NT 4519.0 9221.0 N HI 4519.0 9221.0 P F 4519.0 9235.0 N NT 4519.0 9221.0 ROB 4519.0 9235.0 D HO 4519.0 9235.0 $' # BASE INE CURVE FOR SHIFTS: CURV SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH B SELINE DEPTH GR 535.0 4541.0 540.5 4546.0 r 591.5 4597.5 773.5 4778.0 159.0 5165.5 279.5 5285.5 '454.0 5459.0 "560.5 5566.5 "591.0 5594.5 '678.0 5682.5 "753.0 5759.5 '919.5 5925.5 ;055.5 6062.0 ;205.5 6212.5 ;266.0 6272.0 ;342.5 6348.5 ;501.0 6507.5 ;702.5 6707.5 ;722.5 6728.5 6782.5 6789.5 794.0 6800.0 848.0 6855.0 859.0 6866.5 878.5 6885.0 925.0 6932.5 061.5 7067.0 080.0 7084.0 104.5 7105.0 140.5 7143.0 150.5 7151.5 187.0 7193.0 280.5 7285.0 310.0 7313.0 429.5 7433.0 450.5 7453.0 7470.0 7471.0 7'517.0 7521.0 7546.0 7548.5 557.5 7560.0 609.0 7612.5 619.0 7622.0 657.0 7661.0 706.5 7709.0 933.0 7935.0 Page 4 NCIU A -16 LDWG.tapx 7970.5 7973.0 7985.5 7988.5 8010.5 8012.0 8051.0 8052.5 8113.0 8115.0 8154.0 8156.0 8191.0 8190.5 8212.5 8215.0 8338.0 8338.5 8396.5 8398.0 8448.5 8446.0 8490.0 8489.5 8492.0 8492.0 8523.0 8523.5 8534.0 8534.0 8559.0 8561.0 8581.5 8581.0 8594.5 8595.0 8671.5 8673.0 8724.0 8725.0 8784.5 8785.0 8925.5 8926.5 8989.0 8987.5 9069.5 9067.5 9080.5 9079.5 9107.0 9104.5 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 1489.0 4546.0 MWD 6 4567.0 5563.0 MWD 7 5563.0 7250.0 MWD 8 7250.0 9314.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type 0 Data specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point undefined Frame spacing 60 .AIN Max frames per record undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G /CC 4 1 68 12 4 DRHO MWD G /CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 Page 5 III III NCIU A -16 LDWG.tapx PEF MWD B/E 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 NPHI MWD PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1420.5 9314 5367.25 15788 1420.5 9314 FCNT MWD CP30 405.62 2470.9 898.616 9405 4519 9221 NCNT MWD CP30 94436.7 169613 121994 9405 4519 9221 RHOB MWD G /CC 0.682 2.992 2.26959 9433 4519 9235 DRHO MWD G /CC -2.095 0.533 0.0741984 9433 4519 9235 RPD MWD OHMM 0.33 2000 20.3239 15619 1420.5 9270 RPM MWD OHMM 0.32 2000 19.0693 15619 1420.5 9270 RPS MWD OHMM 0.31 722.78 17.8873 15619 1420.5 9270 RPX MWD OHMM 0.26 2000 14.6105 15619 1420.5 9270 FET MWD HR 0.25 1657.5 7.24474 15619 1420.5 9270 GR MWD API 10.32 108.72 65.5816 15696 1428.5 9276 PEF MWD B/E -9.17 92.8 2.42752 9433 4519 9235 ROP MWD FPH 0.02 704.97 122.478 15663 1483 9314 NPHI MWD PU 13.25 108.88 36.2341 9405 4519 9221 First Reading For Entire File 1420.5 Last Reading For Entire File 9314 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/11/13 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/11/13 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SEDP 1426.5 4484.0 SEMP 1426.5 4484.0 SFXE 1426.5 4484.0 Page 6 • NCIU A -16 LDWG.tapx SESP 1426.5 4484.0 SEXP 1426.5 4484.0 SGRC 1434.5 4491.5 SROP 1489.0 4545.5 LOG HEADER DATA DATE LOGGED: 29- JUL -08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL- TIME): Memory TD DRILLER (FT): 4546.0 TOP LOG INTERVAL (FT): 1489.0 BOTTOM LOG INTERVAL (FT): 4546.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 23.8 MAXIMUM ANGLE: 54.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 216261 EWR4 EWR Phase -4 81797 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 447.0 BOREHOLE CONDITIONS MUD TYPE: Native /Spud Mud MUD DENSITY (LB /G): 9.40 MUD VISCOSITY (S): 78.0 MUD PH: 8.2 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): 7.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.700 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.731 113.0 MUD FILTRATE AT MT: 4.000 70.0 MUD CAKE AT MT: 4.000 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .11N Max frames per record undefined Absent value -999 Page 7 III NCIU A -16 LDWG.tapx Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1426.5 4545.5 2986 6239 1426.5 4545.5 RPD MWD030 OHMM 6.68 71.37 29.2401 6116 1426.5 4484 RPM MWD030 OHMM 5.94 66.14 27.8402 6116 1426.5 4484 RPS MWD030 OHMM 5.64 63.84 26.4946 6116 1426.5 4484 RPX MWD030 OHMM 5.2 45.32 21.5519 6116 1426.5 4484 FET MWD030 HR 0.29 35.73 1.83782 6116 1426.5 4484 GR MWD030 API 20.99 104.26 56.1656 6115 1434.5 4491.5 ROP MWD030 FPH 22.68 704.97 187.978 6114 1489 4545.5 First Reading For Entire File 1426.5 Last Reading For Entire File 4545.5 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/11/13 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 service Sub Level Name Version Number 1 0 0 Date of Generation 08/11/13 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH Page 8 NCIU A -16 LDWG.tapx SGRC 4492.0 5523.5 SFXE 4525.0 5515.5 SNP2 4525.0 5488.5 SBD2 4525.0 5488.5 SEXP 4525.0 5515.5 SEDP 4525.0 5515.5 SCO2 4525.0 5488.5 CTFA 4525.0 5475.5 SESP 4525.0 5515.5 CTNA 4525.0 5475.5 TNPS 4525.0 5475.5 SEMP 4525.0 5515.5 SROP 4567.0 5563.0 LOG HEADER DATA DATE LOGGED: 07- OCT -08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 5563.0 TOP LOG INTERVAL (FT): 4546.0 BOTTOM LOG INTERVAL (FT): 4567.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 51.8 MAXIMUM ANGLE: 53.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 10718512 EWR4 EWR Phase -4 216787 CTN Comp Thermal Neutron 231173 ALD Azimuthal Litho Dens 105252 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 4536.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB /G): 9.00 MUD VISCOSITY (S): 68.0 MUD PH: 9.8 MUD CHLORIDES (PPM): 39000 FLUID LOSS (C3): 13.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .190 75.0 MUD AT MAX CIRCULATING TERMPERATURE: .133 110.0 MUD FILTRATE AT MT: .150 75.0 MUD CAKE AT MT: .180 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Page 9 1 . NCIU A -16 LDWG.tapx $ # Data Format specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .AIN Max frames per record undefined Absent value -999 Depth units Datum Specification Block sub- type...0 Name Service order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD060 CP30 4 1 68 4 2 NCNT MWD060 CP30 4 1 68 8 3 RHOB MWD060 G /CC 4 1 68 12 4 DRHO MWD060 G /CC 4 1 68 16 5 RPD MWD060 OHMM 4 1 68 20 6 RPM MWD060 OHMM 4 1 68 24 7 RPS MWD060 OHMM 4 1 68 28 8 RPX MWD060 OHMM 4 1 68 32 9 FET MWD060 HR 4 1 68 36 10 GR MWD060 API 4 1 68 40 11 PEF MWD060 B/E 4 1 68 44 12 ROP MWD060 FPH 4 1 68 48 13 NPHI MWD060 PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4492 5563 5027.5 2143 4492 5563 FCNT MWD060 CP30 405.62 1515.03 830.105 1902 4525 5475.5 NCNT MWD060 CP30 95324.1 137279 118127 1902 4525 5475.5 RHOB MWD060 G /CC 0.682 2.698 2.0911 1928 4525 5488.5 DRHO MWD060 G /CC -2.095 0.248 0.0190654 1928 4525 5488.5 RPD MWD060 OHMM 0.33 2000 31.8283 1982 4525 5515.5 RPM MWD060 OHMM 0.32 2000 25.2244 1982 4525 5515.5 RPS MWD060 OHMM 0.31 184.25 19.5264 1982 4525 5515.5 RPX MWD060 OHMM 0.26 2000 15.5283 1982 4525 5515.5 FET MWD060 HR 0.25 1657.5 40.9705 1982 4525 5515.5 GR MWD060 API 10.32 95.31 66.0406 2064 4492 5523.5 PEF MWD060 B/E 0.23 14.07 2.23629 1928 4525 5488.5 ROP MWD060 FPH 0.02 386.6 137.411 1993 4567 5563 NPHI MWD060 PU 19.11 105.05 38.521 1902 4525 5475.5 First Reading For Entire File 4492 Last Reading For Entire File 5563 File Trailer Service name sTSLIB.003 service Sub Level Name Version Number 1 0 0 Date of Generation 08/11/13 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.004 Page 10 • • NCIU A -16 LDWG.tapx Physical EOF File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/11/13 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TNPS 5476.0 7153.0 CTNA 5476.0 7153.0 CTFA 5476.0 7153.0 SNP2 5489.0 7135.5 SBD2 5489.0 7135.5 SCO2 5489.0 7135.5 SEMP 5516.0 7202.5 SFXE 5516.0 7202.5 SEXP 5516.0 7202.5 SESP 5516.0 7202.5 SEDP 5516.0 7202.5 SGRC 5524.0 7209.5 SROP 5563.5 7249.5 $ # LOG HEADER DATA DATE LOGGED: 11- OCT -08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 7250.0 TOP LOG INTERVAL (FT): 5563.0 BOTTOM LOG INTERVAL (FT): 7250.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 6.4 MAXIMUM ANGLE: 50.5 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 10718512 EWR4 EWR Phase -4 216787 CTN Comp Thermal Neutron 231173 ALD Azimuthal Litho Dens 105252 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 4536.0 Page 11 III 410 NCIU A -16 LDWG.tapx # BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB /G): 9.00 MUD VISCOSITY (S): 68.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 32000 FLUID LOSS (C3): 14.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .170 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .097 127.4 MUD FILTRATE AT MT: .140 70.0 MUD CAKE AT MT: .270 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .1IN Max frames per record undefined Absent value -999 Depth Units Datum specification Block sub- type...0 Name service order units Size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 FCNT MWD070 CP30 4 1 68 4 2 NCNT MWD070 CP30 4 1 68 8 3 RHOB MWD070 G /CC 4 1 68 12 4 DRHO MWD070 G /CC 4 1 68 16 5 RPD MWD070 OHMM 4 1 68 20 6 RPM MWD070 OHMM 4 1 68 24 7 RPS MWD070 OHMM 4 1 68 28 8 RPX MWD070 OHMM 4 1 68 32 9 FET MWD070 HR 4 1 68 36 10 GR MWD070 API 4 1 68 40 11 PEF MWD070 B/E 4 1 68 44 12 ROP MWD070 FPH 4 1 68 48 13 NPHI MWD070 PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5476 7249.5 6362.75 3548 5476 7249.5 FCNT MWD070 CP30 406.52 2470.9 887.661 3355 5476 7153 NCNT MWD070 CP30 97447.3 169613 121673 3355 5476 7153 RHOB MWD070 G /CC 1.325 2.839 2.21004 3281 5489 7135.5 DRHO MWD070 G /CC -1.735 0.533 0.0665982 3270 5489 7135.5 RPD MWD070 OHMM 3.82 68.12 9.14836 3374 5516 7202.5 Page 12 NCIU A -16 LDWG.tapx RPM MWD070 OHMM 3.53 1132.52 10.0462 3374 5516 7202.5 RPS MWD070 OHMM 3.39 706.91 9.57536 3374 5516 7202.5 RPX MWD070 OHMM 3.13 1884.39 7.88538 3374 5516 7202.5 FET MWD070 HR 0.43 24.17 2.39761 3374 5516 7202.5 GR MWD070 API 10.33 93.69 66.8892 3372 5524 7209.5 PEF MWD070 B/E -9.17 92.8 2.30585 3281 5489 7135.5 ROP MWD070 FPH 0.47 248.05 82.2602 3373 5563.5 7249.5 NPHI MWD070 Pu 13.25 108.88 37.0082 3355 5476 7153 First Reading For Entire File 5476 Last Reading For Entire File 7249.5 File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/11/13 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.005 Physical EOF File Header Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/11/13 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SCO2 7136.0 9232.5 SBD2 7136.0 9232.5 SNP2 7136.0 9232.5 CTNA 7153.5 9218.5 CTFA 7153.5 9218.5 TNPS 7153.5 9218.5 SEDP 7203.0 9267.5 SEMP 7203.0 9267.5 SEXP 7203.0 9267.5 SFXE 7203.0 9267.5 SESP 7203.0 9267.5 SGRC 7210.0 9273.5 SROP 7250.0 9314.0 LOG HEADER DATA DATE LOGGED: 16- OCT -08 Page 13 i • NCIU A -16 LDWG.tapx SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 9314.0 TOP LOG INTERVAL (FT): 7250.0 BOTTOM LOG INTERVAL (FT): 9314.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 3.4 MAXIMUM ANGLE: 6.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 253600 EWR4 EWR Phase -4 105242 CTN Comp Thermal Neutron 185457 ALD Azimuthal Litho Dens 146830 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 4536.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB /G): 9.40 MUD VISCOSITY (S): 64.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 27500 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .260 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .138 136.0 MUD FILTRATE AT MT: .180 69.0 MUD CAKE AT MT: .440 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type 0 Data specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .AIN Max frames per record undefined Absent value -999 Depth Units Datum specification Block sub- type...0 Name Service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD080 CP30 4 1 68 4 2 Page 14 III NCIU A -16 LDWG.tapx NCNT MWD080 CP30 4 1 68 8 3 RHOB MWD080 G /CC 4 1 68 12 4 DRHO MWD080 G /CC 4 1 68 16 5 RPD MWD080 OHMM 4 1 68 20 6 RPM MWD080 OHMM 4 1 68 24 7 RPS MWD080 OHMM 4 1 68 28 8 RPX MWD080 OHMM 4 1 68 32 9 FET MWD080 HR 4 1 68 36 10 GR MWD080 API 4 1 68 40 11 PEF MWD080 B/E 4 1 68 44 12 ROP MWD080 FPH 4 1 68 48 13 NPHI MWD080 Pu 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7136 9314 8225 4357 7136 9314 FCNT MWD080 CP30 415.35 2165.15 939.023 4131 7153.5 9218.5 NCNT MWD080 CP30 94436.7 157708 124040 4131 7153.5 9218.5 RHOB MWD080 G /CC 1.291 2.992 2.39733 4194 7136 9232.5 DRHO MWD080 G /CC -0.265 0.346 0.104961 4194 7136 9232.5 RPD MWD080 OHMM 2.99 66.89 10.7823 4130 7203 9267.5 RPM MWD080 OHMM 2.76 582.45 10.5363 4130 7203 9267.5 RPS MWD080 OHMM 2.6 722.78 11.1793 4130 7203 9267.5 RPX MWD080 OHMM 2.16 321.95 9.41969 4130 7203 9267.5 FET MWD080 HR 0.6 32.94 2.63089 4130 7203 9267.5 GR MWD080 API 18.39 108.72 78.1417 4128 7210 9273.5 PEF MWD080 B/E 0.67 7.49 2.6072 4194 7136 9232.5 ROP MWD080 FPH 0.45 312.23 51.3029 4129 7250 9314 NPHI MWD080 Pu 16.69 102.61 34.5521 4131 7153.5 9218.5 First Reading For Entire File 7136 Last Reading For Entire File 9314 File Trailer Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 08/11/13 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.006 Physical EOF Tape Trailer Service name LISTPE Date 08/11/13 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. scientific Technical Services Reel Trailer Service name LISTPE Date 08/11/13 Page 15 • • NCIU A -16 LDWG.tapx Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 16 • IIP o no co Phil l Alaska, Inc. FINAL WELL REPORT 0-1 MUDLOGGING DATA NCIU -A16 • Provided by: El EPOCH Approved by: Compiled by: Lees Browne Jr. Mainuddin Chowdhury James G. Foradas Date: 09/20/2008 Distribution:11 /25/08 • / ConocoPhillips Alaska, Inc. NCIU A -16 • TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW 2 1.1 Equipment Summary 2 1.2 Crew 2 2 WELL DETAILS 3 2.1 Well Summary 3 2.2 Hole Data 3 2.3 Daily Activity Summary 4 3 GEOLOGICAL DATA 6 3.1 Lithostratigraphy 6 3.2 Mud log Summary 8 3.3 Trip (Wiper) Gases 26 3.4 Sampling Program / Sample Dispatch 27 4 PRESSURE / FORMATION STRENGTH DATA 28 5 DRILLING DATA 29 5.1 Survey Data 29 5.2 Bit Record 33 5.3 Mud Record 34 6 DAILY REPORTS 36 Enclosures: 2 "/100' Formation Log (MD) 2 "/100' Drilling Dynamics Log • 2 "/100' Gas Ratio Log 2 "/100' LWD / Lithology Log \:\‘\€' \\" S PI EPOCH 1 ConocoPhillips Alaska, Inc. NCIU A -16 • 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Comments Downtime QGM Agitator (Mounted in possum belly) Rig Power box gas as Flame ionization total gas & 1 failure chromatography. Effective Circulating Density From Sperry-Sun 4304' to 8865' 0 (ECD) Hook Load / Weight on bit Pason Sensors 0 Mud Flow In Pason Sensors 0 Mud Flow Out Pason Sensors 0 Mudlogging unit computer HP Compaq Pentium 4 (X2, DML & 0 system Rigwatch) Mudlogging unit DAC box In -unit data collection /distribution 0 center Pit Volumes, Pit Gain /Loss Pason Sensors 0 Pump Pressure Pason Sensors 0 Pump stroke counters Pason Sensors 0 Pason Well Monitoring Pason Sensors 0 Components Rate of penetration Pason Sensors 0 RPM Pason Sensors 0 • Torque Pason Sensors 0 1.2 Crew Unit Type • Steel Arctic Unit Number : ML030 Mudloggers Years Days Sample Catchers Years Days Technician Days James Foradas 1 25 Jeff McBeth 0 18 Manudin 2 34 Chowdhury Lees Browne 28 24 Years experience as Mud logger *2 Days at well site between spud (of current section of well) and total depth of well • El EPOCH 2 ConocoPhillips Alaska, Inc. NCIU A -16 2 WELL DETAILS 2.1 Well Summary Well: NCIU A -16 API Index #: 50- 883 - 20127 -00 Field: North Cook Inlet Surface Co- Ordinates: 2586436.84'N 1472059.88E Borough: Kenai Primary Target Depth: 9294' State: Alaska TD Depth: 9314' Rig Name / Type: Kuukpik #5, Arctic Triple Suspension Date: Primary Target: Beluga Sands License: 7/18/08 (Batch) Spud Date: 10/1/08 (A -16) Ground Elevation: Completion Date: KB Elevation: 120.58' Completion Status: Secondary Target: NONE Depth: Classification: TD Date: 10/16/08 TD Formation: Base Beluga Days Testing: NONE Days Drilling: 16 It should be noted that the Spud Date of 7/18/2008 reflects the fact that the first 4546'/3463 (MD/TVD) of this well were batch drilled along with the upper sections of two other wells (NCIU -A14 and NCIU -A15). 2.2 Hole Data Maximum Depth Mud Shoe Depth Hole TD Dev. Casing/ LOT Section MD TVDSS Formation Weight ( °inc Coring Liner MD TVDSS (ppg) (ft) (ft) (Ppg) (ft) (ft) 8.75" 9314' 7630.8' L. Beluga 9.3 3.4 NONE 7" 4536' 3343' 14.8 Additional Comments • Ell EPOCH 3 ConocoPhillips Alaska, Inc. NCIU A -16 • 2.3 Daily Activity Summary 9/29/2008 Rig move finished. Nipple up and test BOP. 9/30/2008 BOP Test completed. Rig repairs. M/U BHA #7. TIH while conditioning mud. Spud mud being displaced with new mud was very clabbered but did not affect QGM operation. 10/01/2008 Test casing, circulated and conditioned mud, tried to test casing again, rigged down, built and pumped a dry job, POOH to BHA, LD BHA and Motor, test casing, close blinds, M/U RTTS, RIH, Set RTTS at 4430', test casing for 30 minutes, bleed pressure, release RTTS, POOH, M/U BHA ( #7 same as last). 10/02/2008 Finished M/U BHA, RIH, Slip and cut drilling line. Service the rig. Drill out cement to 4556'. Circulate and condition mud, then drill to 4566', circulate and condition mud, R/U for LOT. LOT at 14.8 ppg, R/D test equipment and trouble -shoot the top drive. Circulate and conditioned mud and monitor well 10/03/2008 Continue to trouble shoot the top drive. Remove the top drive guard and motor. Reinstalled the top drive guard, and hooked the service cables. POOH without motor, Laying down BHA. 10/04/2008 TIH to 4480', circulate BU. Waiting for top drive repair. 10/05/2008 Circulate for approximately 1 -hour. Waiting for top drive repair. 10/06/2008 Monitoring well, break circulation, monitoring well, removed guard start installing drive motor on the top drive, install the motor, test and service the top drive. Circulated at approximately 4480' MD. Monitoring well. 10/07/2008 Finish repair work on the top drive, pump a dry job, POOH, MU and PU BHA, shallow test MWD, work on top drive hydraulics, adjust bell clamp, TIH, Drill ahead. 10/08/2008 Drilled ahead to 5563' MD. ROP's slowed down considerably. Decide to POOH to check BHA. POOH. Periodic stops for survey, to circulate and pack off hole. Worked through tight spot at approx 4530 -4550' MD until full circulation was established. Circulated bottoms up, max gas 51 units. Shakers cleaned during POOH. Monitored gas during POOH. 10/09/2008 Continue to POOH. C/O BHA, service rig. RIH with same bit, drill from 5563' to 6050'. Smooth hole, more sliding than rotating. (Connection gasses high at 233u, but generally much lower in <10 to 40u range.) Drilling ahead. 10/10/2008 Drill from 6051' to 6551'. Circulate B/U for short trip. Encountered 60 bbl losses. Monitored well, no static losses. POOH to shoe working tight spots as needed. Circulate at shoe, seeing losses of less than 1 bbl per hour. TIH to bottom. 10/11/2008 Circulate at shoe to establish loss rate (less than 1 bbl per hour). RIH and drilled from 6551' to 7158'. Seepage losses @ 5 -7 bbls an hour resulted in adding Nut Plug Fine to reduce losses. LCM affected sample quality below 7000' MD. Sampling interval reduced to 30' intervals, though 30' spot samples were taken higher in section. 10/12/2008 Monitored gas during drilling to 7157' to 7250 feet. Problems with LWD /MWD followed by total LWD failure. Pump slug and POOH. L/D BHA, Test BOP's. Repair /inspect LWD /MWD Tools. M/U BHA. • 10/13/2008 M/U BHA, RIH to the shoe. Cut and Slip drilling line. Perform MAD PASS from 6732' to 7250'. Drill from 7250' to 7723'. Drilling ahead. El EPOCH 4 ConocoPhillips Alaska, Inc. NCIU A -16 • 10/14/2008 Drill formation to 8322' with no over pulls on connections. 10/15/2008 Drill formation to 8594' and have trouble with the HPU on rig. Stop to troubleshoot. Short trip to the shoe and back ream out during tight spots. Trouble shoot and repair rig and trip back to bottom and wash down the last two stands to bottom. 10/16/2008 Finish washing to bottom and drill to 9279' with 20K over pull on connections. 10/17/2008 Continue POH, lay down BHA, rig up wire line, not able to make it to bottom, make it just past shoe to 4750', attempt run # 2 with different wire line assembly, failed, pull out BHA for another clean- out run. 10/18/2008 RIH, Tag Bridge @ 4650', work through bridge, ream to 4700', RIH to 8970', wash to bottom, much full of cuttings and air begin to pour over shaker and bell nipples, begin transferring over new mud to maintain volume, conditioned well, POOH. 10/19/2008 Continue POOH, stand back BHA, RU to wire line, wire line unsuccessful at getting past bridge (coal) seam suspected, RIH with wire line tool on DP to 5650, latch on with wire line, and begin logging. 10/20/2008 Continue with drill pipe conveyed logs. 10/21/2008 Continue with MDT logs, continue to monitor the well and log depths, POOH from 8754' to 7920', POOH to wire line sub, unlatch tool, rig down wire line tools, POOH, lay down logging tools. 10/22/2008 Continue R/D wire line, MU BHA, RIH, monitor well, slip and cut drilling line, RIH, circulate, RIH, circulate, pumped at 60 bbls Hi Vis sweep, notice a slight return of cuttings, POOH . 10/23/2008 Continue to POH, lay down BHA, pull wear ring and drain stack, dummy run with landing joint, make up test joint, test choke manifold, RU to run 7" casing, RIH. 10/24/2008 RIH with 7" casing, circulate bottoms up at the shoe, continue RIH , circulate at 7244', experiencing fluid losses, pumping LCM, lost approximately 230 bbls to the formation. 10/25/2008 RIH with 7" casing to 9290'. Well breathing equal in and out. Pump LCM sweep. Rig up cement head. Cement casing to hole. Start on rig repair. El EPOCH 5 ConocoPhillips Alaska, Inc. NCIU A -16 • 3 GEOLOGICAL DATA 3.1 Lithostratigraphy All tops provided by the ConocoPhillips Alaska, Inc. (CPAI) well site geologist. FORMATION PROGNOSED LWD TOP MD SSTVD MD SSTVD (ft) (ft) (ft) (ft) Stray NA NA 4728 NA CI -A 4805.66 3613.58 4798 NA CI -B NA NA 4856 NA CI -1 5133.91 3812.58 5160 NA CI -2 5173.50 3836.58 5292 NA CI -3 NA NA 5413 NA CI -4 NA NA 5493 NA CI -5 5576.68 4082.58 5609 NA • CI -6 NA NA 5721 NA CI -7 NA NA 5776 NA CI -8 5823.74 4257.58 5894 NA CI -9 NA NA 5976 NA CI -10 NA NA 6015 NA CI -11 NA NA 6057 NA Beluga A 6070.82 4459.58 6116 NA Beluga B NA NA 6216 NA Beluga C NA NA 6418 NA Beluga D NA NA 6525 NA Beluga E NA NA 6630 NA Beluga F NA NA 6792 NA Beluga G NA NA 6911 NA Beluga H NA NA 7009 NA Beluga I NA NA 7170 NA II Beluga J NA NA 7286 NA El EPOCH 6 ConocoPhillips Alaska, Inc. NCIU A -16 • Beluga K NA NA 7343 NA Beluga L NA NA 7400 NA Beluga M 7526.31 5855.58 7475 NA Beluga N NA NA 7607 NA Beluga 0 NA NA 7673 NA Beluga P NA NA 7730 NA Beluga Q 8008.14 6335.58 7829 NA Beluga R NA NA 8013 NA Beluga S 8163.73 6490.58 8126 NA Beluga T NA NA 8292 NA Beluga U 8570.28 6895.58 8492 NA Beluga U Base 8896.52 7220.58 8760 NA Tyonek NA NA 9162 NA TD NA NA 9314 NA IP 0 El EPOCH 7 ConocoPhillips Alaska, Inc. NCIU A -16 3.2 Mud Ioq Summary C.I. A Group (4798' to 4855' MD) Drill Rate ( ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 225 83 174 230 36 117 The C.I. A Group has a thickness of 58' consisting of gradation tuffaceous siltstone and claystone with two coal sections. The coal is thinly to thick bedding grading from less than one foot to over ten feet in parts and interbedded with tuffaceous siltstones and claystones. Overall the coal is black with brownish black hues becoming dense to brittle with irregular blocky to planner fractures in carbonaceous shale's (thin beds). Shapes are tabular to wedge like with a resinous to earthy dull luster. Textures are smooth with some woody textures throughout. Coal is predominantly lignitic to sub lignitic with scattered thin sections of bituminous cuttings. Common visible out gassing is noted during high gas peaks on fresh cuttings. Tuffaceous siltstone is light bluish gray to olive gray with brownish hues and overall, clumpy to mushy, dense to crumbly with various consistency and tenacity with irregular to blocky fractures with platy to wedge like cuttings habit. Luster's are dull earthy with gritty to some granular. Grading downward to brownish olive tuffaceous silts and periodically interbedded with thin beds of coal and carbonaceous shale and carbon clay. Trace amounts of lower very fine sands and scattered sand. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 4826 230 48288 C.I. B Group (4856' to 5159' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 218 13 146 328 10 102 This interval is 304' thick consisting of conglomerate sand and sand interbedded with tuffaceous siltstone and tuffaceous claystones. The sands are divided into two beds: Conglomeratic Sand /Sand (4920- 4960') is composed of approximately two parts quartz to one part siliceous mudstones with the quartz is medium gray, translucent to clear with smokey hues. Clast size ranges from coarse lower to medium lower with rounded to sub rounded grains with moderate to high sphericity. The mudstones are dark gray with mottles of light gray. Pitting is evident on the sand and is moderate to poorly sorted. Grains are unconsolidated and interbedded with claystone and siltstone. The basal contact of this section with the underlying claystone appears abrupt (as indicated by the steep decrease in background gas and resistivity). The second bed of Sand and Conglomerate Sand (4980- 5090') is translucent to light gray with smokey hued quartz with dark gray silic mudstones. Clast size ranges from medium upper to fine upper (being more uniform than the upper zone) with coarse grains becoming less abundant with depth. Sorting is moderate with grains being sub angular to some well rounded in parts. Sphericity is low to high with pitted grains with some polished. Minor accessories include traces of greenstone. Sands are interbedded with light gray tuffaceous 411 siltstones which also form the basal contact which is abrupt with tuffaceous siltstone becoming 100 %. El EPOCH 8 ConocoPhillips Alaska, Inc. NCIU A -16 A basal coal is noted at 5153 to 5158' giving off 204 units of gas. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 4899 328 64883 C.I. 1 Group (5160 to 5291' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 183 18 136 414 54 99 Consists of 132' of tuffaceous siltstones with minor tuffaceous clays interbedded with two thin coal beds. The tuffaceous siltstone is gray to light gray showing poor induration and being crumbly to mushy and displaying slight cohesiveness and being non adhesive. Fracture is earthy with an amorphous habit. Luster is sparkly and has a silty texture. Overall massive gradational silts composed of 60 -80% silt and 10- 20% tuffaceous clay and various detrital material. Coal is black to grayish black and brittle to some firm hardness in carbon clay /shale beds (thin). Lusters are earthy becoming resinous in lignitic coals, overall silty and somewhat mottled textures. Fracture are irregular in coal and planar to sub blocky in carbonaceous shale's (thin). Thin lenses of sand and carbonaceous shale are noted and interbedded with the tuffaceous silts. No visible out gasses in the samples. • Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 5186 415 43836 C.I. 2 Group (5292' to 5412' MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 210 32 93 68 4 22 This interval (121') consists of alternating sequences of tuffaceous claystone and tuffaceous siltstone conglomerate sand and sand. Sands tend to interbedded and becoming slightly dense with depth. The sand and conglomerate sand is light gray to medium light gray with clast size ranging from medium upper to fine upper to scattered very coarse grains. Sorting is poor with sub angular to sub round with moderate developed sphericity with traces of well developed sphericity in parts. Textures display impaction and have a sub mature nature about them. Sand is unconsolidated with some silty matrix loosely attached. Towards the base is an increase in micro crystalline quartz with silic materials (feldspars). Composition is composed of >90% quartz with <10% lithic materials. Sands display poor porosity and permeability with no visible oil fluorescence or oil cuts. Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 5292 68 13091 El EPOCH 9 ConocoPhillips Alaska, Inc. NCIU A -16 410 C.I. 3 Group (5413' to 5492' MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 201 6 (slide) 138 122 2 37 The C.I. 3 interval (80') consists of gradational and thin to thick beds of tuffaceous siltstone, conglomerate sand, sand and coal and thin beds of carbonaceous shale. The coals are represented with a thin coal and carbonaceous shale zone at the top of the formation giving a 20 unit kick over background. The second coal was 10' thick and giving off a total gas amount of 122 units. The coal was grayish black to black and brittle with irregular to earthy fractures in carbonaceous clays. Cuttings habit was wedge like with a resinous luster and silty texture. Throughout the zone interbedded lenses of fine grained white sands were noted grading to thin beds of conglomerate sand in parts. No visible out gassing from the coals. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 5460 122 22645 C.I.4 Group (5493' to 5608' MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average • 243 14 (slide) 94 116 1 16 This interval (116') consists of continued sand, conglomerate sand and tuffaceous claystone and tuffaceous siltstone with a small coal near the base (116 units). The sand and (minor) conglomerate sand is gray to light medium gray, sub angular to sub round with clast size ranging from fine upper to fine lower (sand). Sphericity is moderate with a polished texture with some etched texture. Sand samples are composed of 70 -80% quartz and 10 -20% lithic materials with black carbon fragments. Porosity and permeability are poor with no visible oil fluorescence or oil cuts. The coal near the base of the C.I. 4 (5580- 5595') is black to grayish black. Consistency is crumbly in parts with patchy to wedge like habit displaying a resinous to earthy luster and irregular fracture. Interbedded tuffaceous siltstones with thin sand stringers with no visible out gassing from the coal. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 5587 122 23183 C.I. 5 Group (5609' to 5720' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 411 206 18 (slide) 129 143 25 63 El EPOCH 10 ConocoPhillips Alaska, Inc. NCIU A -16 This interval is (112') and consists of tuffaceous claystone /tuffaceous siltstone, thin sands and a minor coal. • The tuffaceous claystone /tuffaceous siltstone is light gray, brittle to slightly crumbly to crunchy (when interbedded with sand). The fracture is earthy with an amorphous to platy cuttings habit with a dull earthy luster. Textures are silty to gritty. The silts are interbedded with thin coals and sand laminae with black carbon fines. Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 5655 143 28035 C.I. 6 Group (5721' to 5775' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 222 59 151 158 36 72 This interval (55') consists of continued tuffaceous siltstone and tuffaceous claystone, minor sands and very thin coal. The tuffaceous siltstone is light olive gray and clumpy to mushy with some being tough to crunchy. Samples display an irregular to earthy fracture with wedge like to platy cuttings habit. The luster is a dull earthy with some resinous in parts. Texture is silty to gritty. Samples are interbedded with thin coals and thin sand laminae with continued black carbon fines. _ P Depth Depth TG C1 C2 C3 C41 C4N C51 C5N 5767 158 30983 2 C.I. 7 Group (5776' to 5893' MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 237 21 (slide) 141 208 58 90 This interval (118 ") consists of predominant tuffaceous siltstone, tuffaceous claystone, and very minor sand. Connection gases were noted starting with the C.I. 7 zone. A small sand bed 5800 -5805' displayed a small gas kick (40 units over background). The sand was light gray, clear to translucent with clast size ranging from very fine to fine grains with a trace amount of coarse grains (cavings ?). Samples were poorly sorted with rounded to angular shape and high to low sphericity. Textures were pitted to polished and largely unconsolidated with possible weak silic cement. Composed of >90% quartz with minor light and dark litics and greenstone. Occurs as thin lenses and stringers interbedded with thick siltstones and clays. Tuffaceous siltstones are light gray to light olive gray. Consistency is clumpy and mushy and overall crumbly. Samples display an irregular to earthy fracture and an amorphous to sub platy cuttings habit. Luster is dull to earthy with a silty to gritty texture. Some banding becoming clayer with depth and interbedded with thin sands and clays. Peaks • Depth TG Cl C2 C3 C41 C4N C51 C5N 5851 208 405901 11 7 El EPOCH 11 ConocoPhillips Alaska, Inc. NCIU A -16 • C.I. 8 Group (5894' to 5975' MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 169 23 (slide) 89 198 23 62 This interval (82') consists of predominantly tuffaceous silt and tuffaceous clay with very thin coal and sand intervals with continued connection gases. The sand formation is translucent to clear with some light gray to white; predominantly quartz grain sand with abundant dark colored lithic fragments; upper very fine to upper fine grain; moderate sorted throughout; sub rounded with some slightly angular to sub angular; moderate to high sphericity; abundant volcanic lithics; 10 % -20% multicolored lithics. No sample fluorescence was present. A small sand gas kick was noted at the base of the C.I. 8 at 5968 -5980' giving a 50 unit kick over the background gas. The coal at the top of the formation is black to brownish black stiff to very firm; blocky to planar fracture; earthy to slightly resinous; mostly smooth texture; weak out gassing present and grading to thin carbonaceous shale. Continued silts and grading to a moderate amount of tuffaceous silty claystone being light gray to light olive gray. Samples are soft to brittle and some crumbly with increased silt content. Fractures are irregular to sub blocky with an amorphous cuttings habit. Luster is dull to earthy with a gritty to clayey texture. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 5909 198 38726 8 C.I. 9 Group (5976' to 6014' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 152 14 (slide) 79 59 17 34 This interval (39') consists of predominant tuffaceous siltstone and claystone with minor carbonaceous matter. The tuffaceous silty claystone is light gray to light olive gray. Hardness is stiff to dense in parts with some being crumbly with increased silt content. Fractures are irregular blocky with a dull earthy luster and a silty to gritty texture. Some banding noted and common fine laminae are noted. The claystone grades and interbeds with tuffaceous siltstone and very minor coals and carbonaceous material. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 6003 59 11821 6 C.I. 10 Group (6015' to 6056' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 170 10 (slide) 74 52 5 29 El S EPOCH 12 ConocoPhillips Alaska, Inc. NCIU A -16 This interval (42')consists of tuffaceous siltstone and tuffaceous claystone with minor carbonaceous clay, • shale and detrital material with continued connection gases through the zone. The tuffaceous siltstones are grading to carbonaceous silts and clays and are medium to dark brownish gray with lighter gray and olive gray hues. Hardness is tough to dense with irregular blocky fracture and amorphous cuttings habit. Luster is dull to earthy with a fine silty to fine gritty texture. Common dark carbonaceous matter noted in largely tuffaceous matrix with Interbedded with tuffaceous claystone, carbon shale in gradational laminated structures. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 6039 52 9839 10 C.I. 11 Group (6057' to 6115' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 150 8 (slide) 69 70 8 35 This interval (42') consists of continued tuffaceous claystone, tuffaceous siltstone and scattered thin beds of very carbonaceous shale and clays. The tuffaceous claystone is light gray to light olive gray. Hardness is stiff to dense to crumbly in parts. Fracture is irregular blocky with amorphous cuttings habit. Luster is dull to earthy with a silty to gritty texture. Some banding and common fine laminae is noted. Samples grades and interbeds with tuffaceous • siltstone with minor coals and carbonaceous shale. Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 6075 70 13628 15 Beluga A Group (6116' to 6215' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 195 9 77 141 9 72 This interval (100') consists of tuffaceous siltstone, tuffaceous claystone, various thin carbonaceous zones and thin sand. Overall samples are generally composed of tuffaceous siltstone, with a general light gray with some pale olive hue. Samples display a crumbly to crunchy to mushy and slightly pasty consistency and tenacity. Fracture is irregular and earthy with an amorphous to platy cutting habit. Luster is earthy to resinous with a clayey to silty and gritty texture. Dark carbon material is interbedded with very thin coal beds. Minor beds of sand are noted with a 3 -5' sand at the base of the Beluga A. El EPOCH 13 ConocoPhillips Alaska, Inc. NCIU A -16 Peaks • Depth TG C1 C2 C3 C41 C4N C51 C5N 6160 141 27002 2 Beluga B Group (6216' to 6417' MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 249 9 (slide) 88 384 21 134 This interval (202') consists of continued tuffaceous siltstone, tuffaceous claystone and a increase in carbonaceous material giving the background gas average an increase to over 100 units throughout the Beluga B. Minor sand is noted in thin beds. Continued connection gases noted with increases in carbon material giving off gas. Note: increase in background gas. The tuffaceous siltstone is a gray to light gray with poor induration and crunchy to slightly mushy. Samples display slight cohesiveness and are non adhesive. Fractures are earthy with a amorphous habit and a light sparkly luster. Texture is silty with massive gradational silts and clay. Generally composed of 60 -80% silt and 40 -20% tuffaceous silty clay and various detrital material. Coal and carbonaceous material (carbon clay, silt and detrital) is black to grayish black with some olive brownish hues. Samples are dense to brittle displaying a resinous luster in coal to earthy lusters in carbon clays and shale. Texture is gritty to silty to clayey with earthy to platy to irregular fractures. Overall carbon material is interbedded with massive thick tuffaceous silts. No visible gas bleeding of cuttings Peaks 411 Depth TG C1 C2 C3 C41 C4N C51 C5N 6349 384 76489 18 5 Beluga C Group (6418' to 6524' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 162 13 (slide) 75 278 47 100 This interval (107') consists of continuing tuffaceous clay and tuffaceous siltstone with decreasing carbonaceous material and continued connection gases. Tuffaceous siltstone is gray to light gray with scattered dark grays and brownish hues towards the base of the formation and contacts with carbon clay. Consistency is crumbly to crunchy with irregular to blocky fractures. Silts are friable with dull to earthy lusters. Textures are silty to gritty with interbedded laminae of very carbonaceous material and tuffaceous clay throughout. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 6420 278 40754 24 6 411 El EPOCH 14 ConocoPhillips Alaska, Inc. NCIU A -16 Beluga D Group (6525' to 6629' MD) • Drill Rate ( ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 160 11 (slide) 60 105 10 33 This interval (105') consists of continued tuffaceous siltstone and tuffaceous clay, with minor sand and very thin coal and carbonaceous shale. Background gases are decreasing with the decrease in coal and increase in silt and clay. Lost circulation at 6551'. Short trip to the shoe with 60 bbl /hr mud losses. Wiper gas was 107 units at 6551'. Tuffaceous siltstone is light gray and crumbly with irregular blocky fracture. Cuttings are amorphous with a dull earthy luster and gritty texture. Banding and laminae are noted observed in samples with interbedded tuffaceous claystone and minor lignitic coals. Abundant lost circulation material in samples. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 6546 105 17716 10 15 2 Beluga E Group (6630' to 6791' MD) Drill Rate ( ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 185 12 (slide) 72 54 10 27 This interval (162') consists of alternating sequences of tuffaceous claystone, tuffaceous siltstone with minor amounts of sand and conglomerate sand. The tuffaceous claystone is gray to light gray with olive gray hues. Samples display a crumbly to crunchy consistency with a earthy fracture. Cuttings are amorphous with a dull earthy luster and silty to gritty texture. Some banding and common fine laminae are noted. The clay grades and is interbedded with tuffaceous siltstone and minor carbon shale and coal. The tuffaceous siltstone is gray to light gray with some medium gray in parts. Samples are crumbly to crunchy and mushy to pasty in parts. Fractures are earthy to irregular with a amorphous to platy cuttings habit. Luster is resinous with a clayey to silty to gritty texture. Samples are interbedded with thin coal and laminae of silt to fine lower sand with dark carbon materials in thin beds of sand with a few very thin clean beds of sand with no gas increases. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 6770 54 10558 4 1 Beluga F Group (6792' to 6910' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 229 18 (slide) 74 107 13 28 Ell EPOCH 15 ConocoPhillips Alaska, Inc. NCIU A -16 This interval (119') consists of alternating sequences of tuffaceous claystone, tuffaceous siltstone with lesser amounts of sand and conglomerate sand in gradational beds. Continued connection gases throughout the zone. Sand and conglomerate sand are gray to light gray showing moderate sorting. Samples display sub angular to sub rounded shapes with clast size ranging from fine upper to fine lower to scattered coarse. Sphericity is moderately developed with a polished texture with some grains etched. Silica materials noted through the zone. Sands are composed of 90% quartz and 10% various Iithic materials and black carbon fines throughout. Porosity and permeability is estimated to be poor to fair with no visible fluorescence or oil cut. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 6803 107 20941 21 9 Beluga G Group (6911' to 7008' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 150 24 65 54 12 28 This section (98') is comprised of alternating beds of tuffaceous siltstone and tuffaceous claystone, with very thin lenses of sand and coal. The average sand in this formation consists of mostly gray to light gray with clast size ranging from upper fine • to lower medium; dominantly sub angular to sub rounded; moderate sphericity; moderate sorted with polished textures. Samples consist of a sub mature nature with a clay structured matrix loosely attached with silt. Composed of predominantly quartz grains with scattered dark colored Iithic fragments throughout. Sand is thickly interbedded with tuffaceous siltstones and secondary silty claystone and very minor coal beds. Poor porosity and permeability with no visible sample fluorescence was observed with no solvent cut. Tuffaceous siltstones make up the bilk of the formation with continued light to medium gray hues being brittle throughout the section. Fractures are irregular blocky with a tabular cuttings habit. Luster is dull to earthy with a silty texture and thinly banded to laminated with dark carbon fines. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 6932 54 10835 Beluga H Group (7009' to 7169' MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 218 4 (slide) 73 49 1 16 This section (167') is predominantly comprised of tuffaceous siltstone and tuffaceous claystone. Very few carbon beds were encountered in this section and mostly regarded as carbon clay and silt in thin beds. Continued connection gas running 30 to 50 units over background was noted with minor sand was seen in this section and regulated to very thin beds of less than five feet thick. Continued tuffaceous siltstone and secondary silty tuffaceous claystones continued displaying light gray hues with secondary brownish hues near carbon stringers. Silts displayed poor induration and are crumbly Ell EPOCH 16 ConocoPhillips Alaska, Inc. NCIU A -16 to the touch. Fractures are irregular blocky fractures with some platy cuttings habits. Lusters are dull to earthy with silty textures. A decreasing carbon fines in the silts with very minor interbedded carbon fines and very thin stringers of coal are noted and grading to tuffaceous claystones. Sands towards the bottom of the formation are light gray to translucent to some clear quartz. Clast size ranges from coarse lower to very fine lower and poorly sorted. Grains are well rounded to angular with various sphericity. Some grains are polished with minor traces of friable sandstones being matrix supported and grading to siltstones. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7150 49 18196 Beluga I Group (7170' to 7285' MD) Drill Rate ( ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 203 9 (slide) 55 106 3 17 This interval (116') consists predominantly of tuffaceous siltstone and tuffaceous claystone with very thin beds of coal. Continued connection gas was noted showing 27 units over background gases. The tuffaceous siltstone in this section is comprised of gray to light gray hues with secondary brownish hues near carbon beds. Samples are slightly crumbly to crunchy with occasionally mushy to slightly pasty near increased clay content. Fractures are earthy to irregular with amorphous to platy cuttings habits. Luster is resinous with textures ranging from clayey to silty to gritty. All silts are interbedded with minor dark carbon materials and thin coal beds giving off minor gas kicks. Tuffaceous claystone in this formation is mostly medium gray to light gray to olive gray hues and being lumpy to clumpy to dense to brittle. Fractures are hackly to earthy with some wedge like cuttings in parts. Samples displayed mostly earthy to slightly dull lusters with a clayey to slightly earthy texture and interbedded with thick beds of tuffaceous siltstone with minor amounts of black carbon laminae. No visible sample fluorescence was observed, with a solvent cut, and no other petroleum indicators were observed. Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 7182 106 30300 16 9 Beluga J Group (7286' to 7342' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 193 18 97 72 17 38 The Beluga J group (57') is mostly made up of tuffaceous siltstone and tuffaceous claystone with lesser amounts of sand and coal. Very little sand was noted with one coal seam observed in this section. Predominantly the tuffaceous siltstone in this formation is comprised of medium gray to light gray with some brownish gray hues and being very pasty to slightly mushy; brittle to crumbly tenacity with a irregular fracture and amorphous cuttings habit; very earthy to somewhat dull luster and mostly silty to slightly ashy to gritty S texture with massive interbedded with thick beds of tuffaceous claystone and lesser amounts of sand. No visible sample fluorescence and solvent cut. Cl EPOCH 17 ConocoPhillips Alaska, Inc. NCIU A -16 • Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7317 72 14032 22 6 1 Beluga K Group (7343' to 7399' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 143 21 62 63 20 39 This section (57') is comprised of tuffaceous siltstone, tuffaceous claystone and gradational sand stringers. The tuffaceous siltstone is light gray with pale olive gray hues. Overall lumpy to clumpy with some dense but overall brittle with fractures are hackly to earthy with a wedge like cuttings habit. Luster is dull earthy with a clayey to gritty texture. Common carbon fines with black laminations are noted with samples grading to tuffaceous silty claystone and stringers of quartz rich sands. The sands in this formation is predominantly made up of gray to light gray with clast size ranging from fine lower to fine upper ranging to medium upper with moderate sphericity and sub angular to angular to sub rounded and poor to moderate sorting. Composed of 90% clear to translucent quartz; 10% black carbonaceous material and occasional dark lithics. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 7376 63 12376 45 23 9 Beluga L Group (7400' to 7474' MD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 106 21 60 57 15 33 This section (75') is predominantly comprised of tuffaceous siltstone, tuffaceous claystone and with lesser amounts of sand. The sand lenses in this section are thinner, with trace coal seams. The sand in this formation (stringers and gradationally) is mostly comprised of gray to light gray with clast size ranging from fine lower to fine upper to medium upper with moderate sphericity. Sub angular to angular to sub rounded with poor to moderate sorting. Samples are composed of 90% clear to translucent quartz; 10% black carbonaceous material and occasional lithics. The tuffaceous siltstone is light gray and clumpy with some crumbly and rare toughness. Fractures are sub blocky with wedge like cuttings habit. Luster is earthy to dull with generally smooth texture with scattered gritty textures with minor sand laminae. Very carbon fines are noted with brownish black carbonaceous claystone noted toward the base in very thin coal. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 7402 57 11119 20 14 6 • El EPOCH 18 ConocoPhillips Alaska, Inc. NCIU A -16 Beluga M Group (7475' to 7606' MD) 41110 Drill Rate ( ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 153 15 60 97 7 32 This section (132') is comprised predominantly of tuffaceous siltstone and tuffaceous claystone and sands in this section were noted at the base in minor amounts. In addition, more coal beds were encountered in this section giving off distinct coal gas kicks. The ROP is erratic drilling through multiple sequences of lithology. The tuffaceous siltstones in this section are comprised of light gray to medium olive gray hues with brownish hues near carbon contacts. The samples were clumpy in clay sections to crumbly in silty sections. Fractures were sub blocky with sub nodular cuttings habit. Lusters were dull to earthy with a smooth to gritty texture. Common laminae of carbon fines are noted and interbedded with brownish black carbonaceous claystone The coals in this formation consists of black with brownish hues; stiff to very firm and some becoming somewhat brittle in carbonaceous shale's. Fractures were blocky to irregular with resinous luster. Textures ranged from smooth to woody. The coals become interbedded with tuffaceous siltstones and carbonaceous clays and have an increase in carbonaceous shale's towards the base. Some out gassing is noted in mostly "true" coals. Tuffaceous clay in this section is made up of dark gray to medium dark gray hues and is very clumpy to crumbly with slightly blocky to irregular fractures. Samples are mostly amorphous to slightly platy cuttings habit with very earthy to somewhat dull luster and a very clayey texture throughout. Very thick interbedded with thick beds of tuffaceous siltstone and thin beds of siltstone and carbon shale with varying amounts of immature coal. No visible sample fluorescence was observed. 4110 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 7550 97 15410 11 11 Beluga N Group (7607' to 7672' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 123 9 65 375 28 102 This section (66') is comprised predominantly of many more coal beds with an increase in background gas compared to the "M" section. Secondary lithology is tuffaceous siltstone and tuffaceous claystones with gradation carbonaceous shale's. The coal is black with brownish hues near carbonaceous shale and carbon clay contacts. Overall samples are tough to dense with a irregular to blocky fracture and wedge like cuttings. Lusters were resinous in coals to earthy in carbon shale and clay. Textures were smooth to woody. The coal beds were short and interbedded with tuffaceous siltstone and tuffaceous claystone. Some out gassing noted in coal. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 7663 375 66152 33 15 • Beluga 0 Group (7673' to 7729' MD) PI EPOCH 19 ConocoPhillips Alaska, Inc. NCIU A -16 • Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 175 5 50 390 23 99 This section (57') is comprised predominantly of tuffaceous siltstone and tuffaceous claystone and increased amounts of coal. Background gases increased throughout the zone, the result of coal out gassing. Coals descriptions are the same as the "N" zone. The tuffaceous clay in this section consists of gray with light olive hues. Samples are very clumpy to crumbly with slightly blocky to planar fractures in carbon zones. Mostly amorphous to slightly wedge like cuttings habit are noted with very earthy to somewhat dull luster and a very clayey texture throughout. Black carbon fines are very common throughout this zone very thick interbedded with thick beds of tuffaceous siltstone and thin beds of siltstone and carbon shale with varying amounts of immature coal. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7694 390 72245 31 70 Beluga P Group (7730' to 7828' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 88 11 39 207 19 58 This section (99') is comprised predominantly of tuffaceous siltstone and tuffaceous claystone, with thin beds of coal. The coal is less than the '0" section and occurs as many thin beds. Tuffaceous siltstone in this section is comprised of light gray to very light gray some brownish gray hues with poor to moderate induration. Consistency is crunchy to crumbly with a mostly irregular fracture and amorphous cuttings habit. A dull to earthy luster and overall silty texture with some slightly clayey textures abound and occurs as very thick interbedded with thick beds of tuffaceous claystone and thin beds of tuffaceous siltstone. The coal is black to grayish black and is brittle displaying a crumbly "to the touch ". Cuttings are flaky to wedge like with a resinous to earthy luster. Fractures are irregular with interbedded thick tuffaceous siltstones with no bleeding of gas noted from the coals. Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 7743 207 38055 39 29 Beluga Q Group (7829' to 8012' MD) Drill Rate (ft/hr) Total Gas (units) • Maximum 1 Minimum 1 Average Maximum 1 Minimum l Average El EPOCH 20 ConocoPhillips Alaska, Inc. NCIU A -16 217 11 56 479 (sand) 14 58 This section (184') is comprised predominantly of tuffaceous siltstone and tuffaceous claystone, with sands. In addition, few coal beds were encountered in this section. A maximum Gas kick of 470 units was noted at 7984' (in sand) with continued connection gases throughout this zone. The sand in this section is located towards the base of the formation from 7950 to 8000' and is comprised of gray to medium light gray grains with grain size dominantly fine upper to fine lower to some scattered medium upper. Grains appear sub rounded to sub angular and becoming angular in parts and appear moderately sorted to well sorted. Some weakly consolidated grains are present with very weak loosely attached grayish brown tuffaceous clay matrix. Samples are composed of 90% translucent quartz with 10% various lithic fragments and overall poor possible fair visible porosity and permeability. No show of oil fluorescence or cut was noted. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 7986 479 87589 301 99 Beluga R Group (8013' to 8125' MD) • Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 135 12 57 135 9 34 This section (113') is comprised predominantly of tuffaceous siltstone and tuffaceous claystone, with lesser amounts of sands lenses in this section and were thinner than the "Q" zone, but still giving off sharp gas kicks from the thin beds. The sand in this section is comprised of light gray to gray with grain size dominantly fine upper to fine lower ranging to medium upper with a high to moderate sphericity and sub rounded to sub angular becoming angular shape. Samples are moderately sorted to locally well sorted, with trace friable to poorly consolidated in the lower section only. Light gray to grayish brown tuffaceous clay matrix with the sand matrix supported. The sand is composed of 90% translucent to quartz; 10% coal fragments and gray volcanic lithics and interbedded with siltstone and tuffaceous claystone; grades to very fine lower to silt size clasts. No sample fluorescence was observed. Tuffaceous claystone in this formation is composed of gray to gray with occasional medium gray hues and is poorly indurated showing brittle to malleable when hydrated. Earthy fracture and wedge like cuttings habit. A very dull to earthy luster is observed with a overall clayey to silty texture and interbedded with thick beds of tuffaceous siltstone. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 8103 135 36756 113 48 24 El EPOCH 21 ConocoPhillips Alaska, Inc. NCIU A -16 Beluga S Group (8126' to 8291' MD) • Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 115 13 55 50 10 25 This section (168') is comprised predominantly of tuffaceous siltstone and tuffaceous claystone, with lesser amounts of coal beds were encountered in this section. Sand beds are minor to thin with no real gas kicks noted and grade to weak sandstone towards the base of the "S ". The sand in this section is comprised of white to light yellowish gray with some translucent to clear grains of predominantly quartz grain sand. Clast size ranges from lower medium to generally fine grains. Sorting is poor to some moderate with sub rounded with scattered angular to sub angular and moderate sphericity. Samples are composed of 90% quartz with 10% dark colored lithic fragments. Samples note a fair to poor overall porosity. No visible sample fluorescence was observed. The tuffaceous siltstone in this formation consists of medium gray to light olive gray with some light yellowish gray hues. Overall samples are mostly crumbly to crunchy; stiff in parts with a slight to moderate cohesiveness and non adhesive. Earthy to sub blocky fracture with a sub nodular to sub tabular cuttings habit with a dull luster is noted in most silts. A silty to gritty texture massive gradational beds of tuffaceous silt interbedded with tuffaceous claystone and very thin beds of coal and carbonaceous shale. Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 8256 50 9983 28 19 NA 411 Beluga T Group (8292' to 8491' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 117 12 48 89 10 27 This section (200') and is comprised predominantly of tuffaceous siltstone and tuffaceous claystone, with sands lenses in this section were more prevalent than the "S" section, but overall thin beds grading to siltstones. Coal beds were encountered in this section, but also they are very thin and only a few feet thick. Continued small connection gases were noted throughout the section. The tuffaceous siltstone in this formation consists of Tight olive gray with brownish hues near carbon stringers. Consistency is clumpy to crumbly to some very brittle sections with moderate cohesiveness to slightly adhesive. Dull earthy mottled luster to clayey silty gritty texture noted. interbedded with and grading to tuffaceous claystone and thin beds of coal and some thin lenses of sand. The sand and sandstone in this section is comprised of gray to Tight olive gray with predominantly quartz grain sand with clast size ranges from upper very fine to upper fine. Shapes are sub rounded to rounded with fair to well sorting and moderate to high sphericity. Some grains appear to polished and easily to firmly friable. Composed of >90% quartz with small lithic materials. Generally grain supported with weak silic cement in firmer clusters. Occurs as thin beds or stringers interbedded with tuffaceous siltstone and tuffaceous claystones. Minor coals are noted with thickness of a few inches to a few feet. Samples appear to have fair to poor apparent porosity and display no visible sample fluorescence and no solvent cut. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 8307 89 17304 34 10 3 El I EPOCH 22 ConocoPhillips Alaska, Inc. NCIU A -16 • Beluga U Group (8492' to 8759' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 165 7 56 139 5 25 This formation (268') is comprised predominantly of tuffaceous siltstone and tuffaceous claystone, with sands beds in this section were slightly more prevalent and slightly thicker. In addition, minor coal beds were encountered in this section. Tuffaceous siltstone in this section is comprised of light gray to yellowish gray. Samples show moderate induration and are crumbly with irregular to blocky fractures. Some becoming very stiff in parts. Samples are moderate cohesive and non to very slightly adhesive. Samples are dull and earthy lusters with a smooth clayey to fine gritty texture. Common carbon fines are in most cuttings suggesting carbon shale laminae and or thin coal beds. The sand in this unit is made up of light gray to clear and some translucent fragments that are very fine to lower coarse grain size with moderate sphericity and poorly sorted. Samples are predominantly sub round to angular with estimate well developed sphericity to low sphericity. Samples are pitted to some polished with some matrix supported by dull gray tuffaceous claystone matrix which washes away readily. Composed of 95% clear to translucent quartz; 5% carbonaceous material and trace coal fragments with various lithic fragments. Samples are interbedded with thicker tuffaceous siltstones and claystone and thin coal beds scattered. Samples have no visible sample fluorescence. Coal in this section is comprised of black; dense to brittle to crumbly fragments which are earthy to carbon resinous luster and have a slightly planar to irregular to bird's eye cuttings habit. Coals are interbedded with thick beds of tuffaceous siltstone and tuffaceous claystone with trace out gassing visible. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 8581 139 27792 71 39 Beluga U Base Group (8760' to 9161' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 118 9 48 85 4 17 This formation (401') is comprised of predominantly tuffaceous siltstone and gradational tuffaceous claystone with thin beds of sand and thin coals near the base. The sands are thin beds to laminae displaying gray to light gray hues with some brownish hues. Clast size ranges from scattered coarse lower to fine upper with abundant factions being medium grains. Shapes are sub angular to sub round with a moderate developed sphericity with a slight silty to clayey matrix. Surface appear to be etched and some polished with a sub mature nature. The matrix material is loosely attached and found mostly on the coarse lower grains. The sand is composed of >90% translucent quartz with trace litics materials. Porosity and permeability is poor with no oil fluorescence or oil cuts. Tuffaceous claystones are gray to medium light gray with some brownish gray hues. Samples display a crumbly to crunchy (in silty zones) to mushy and pasty consistency. Fractures are irregular earthy fractures • with a general amorphous habit. Lusters are resinous with a silty to gritty texture. Towards the base the clays are interbedded with carbon shale and lignitic coals. El EPOCH 23 ConocoPhillips Alaska, Inc. NCIU A -16 • Tuffaceous siltstones are light olive gray with brownish hues showing poor induration and are crumbly to crunchy. Fractures are earthy to irregular with a dull earthy luster. Textures are clayey to gritty grading between siltstone and claystone. The basal coals are thinly bedded (less than five feet thick) and overall black in color. Samples are brittle with an irregular to splintery and sometimes blocky fracture. Samples are fine with the PDC bit grinding coals to fines. Luster is resinous on fresh surfaces with a smooth to wood grain texture. The coal occurs as thin alternating beds grading to tuffaceous siltstones and silty claystones with scattered carbon shale's at contacts. Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 9152 85 16440 49 25 Tyonek to TD (9162' to 9314' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 96 10 33 78 9 20 The Tyonek formation is not easily defined by samples. Samples continue with abundant tuffaceous siltstone and tuffaceous claystone with thin coal beds scattered through the zone. Sample descriptions are a • continuation of the basal "U" formation with no sand noticed in the samples but possibly occurs as very thin beds or as stringers. Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 9199 78 15237 43 21 Geologic Discussion The NCIU A -16 well was drilled with few problems. Good hole cleaning was observed, in which cuttings beds were kept in check. Sample quality was good to excellent with a minimal observance of cavings and re circulated cuttings. The fast drill rate of the upper hole gave a slight problem with samples on the shakers, sample mixing in the hole and hurried sample collection. Rotating and sliding added slight to some moderate sample cavings but nothing out of the ordinary. The breaching of the C.I. 7 formation saw the continuation of connection gases, but without any major gas kicks or mud circulation. Connection gas was high from the C.I. 7 to the Beluga "C" mostly activated by numerous coal and carbonaceous material bleeding gas into the hole. Mud weight was kept at 9.3 to 9.4 with no increases of mud weight. The Beluga "D" saw a zone of lost circulation (25' into the "D" zone [6551']), in which a short trip was utilized and the hole lost 60 bbl /hr. Once the hole was stabilized losses were very minimal (over the shaker with the addition of LCM ?). Gas Shows • The C.I. "B" zone displayed four gas kicks but the sand was very interbedded with silt and clay. Resistivity El EPOCH 24 ConocoPhillips Alaska, Inc. NCIU A -16 was high but the gamma ray showed no real deflection. • The best gas show was in the Beluga "Q" zone from 7950' to 8000'. The ROP shows a good drill break from 7950' to 7985' with an increase in resistivity and decrease in Gamma. Sand appears interbedded with silt and clay. A maximum gas reading of 475 units over a background of 20 units was observed with a slow bleed off of gas for over fifty feet. Sand body is estimated at 20'. Smaller sand gas are noted in the Beluga "R" formation. With gas kicks of 81 and 103 units maximum. Below the Beluga "R" formation sands are very thinly bedded and grading to silt or clay. A gas kick of 190 units was observed in the Beluga "U" at 8580' to 8590' with a fair erratic drill break with sand being in small stringers. There was no bleed off of gas. Connection Gases 1 unit = 0.05% Methane Equivalent Depth Gas over BGG Depth Gas over BGG (feet) (units) (feet) (units) 4586' 8 5411' 6 5538' 8 5665' 7 5728' 42 5855' 233 • 6236' 157 6299' 127 6426' 147 6490' 28 7061' 28 7125' 34 7188' 27 7315' 43 7379' 37 7442' 29 7569' 14 7760' 23 7823' 12 7887' 8 7950' 12 8014' 18 8077' 12 8141' 28 8204' 57 8268' 8 8331' 14 8395' 13 8458' 23 8522' 19 8585' 18 PI EPOCH 25 ConocoPhillips Alaska, Inc. NCIU A -16 3.3 Trip (Wiper) Gases • 1unit = 0.05% Methane Equivalent Depth Trip to Gas Downtime (feet) (feet) (units) (hours) 6551' 4012' 107 8.4 7245' Surface 67 21.2 8594' 5350' 703 12.0 • El I EPOCH 26 ConocoPhillips Alaska, Inc. NCIU A -16 • 3.4 Sampling Program / Sample Dispatch Set Type / Purpose Frequency Interval Dispatched to CPAI Washed Samples 50' 4548' — 6500' Bayview Geologic Facility A Set owner: CPAI 30' 4580' -8865' Anchorage, A Creek Ave Ste 14 Anorage, AK 99501 Attn: D. Przywojski 265 -6340 Set Type / Purpose Frequency Interval Dispatched to CPAI Washed Samples 50' 4548' — 6500' Bayview Geologic Facility B Anchorage, or ate , A Creek Ave Ste 14 Set owner: CPAI 30' 4580' -8865' Anchorage, AK 99501 Attn: D. Przywojski 265 -6340 • Sample frequency was locally altered according to drill rate constraints and zones of interest. • El • EPOCH 27 Cono hillips • Alaska, Inc, • NCIU A -16 4 PRESSURE / FORMATION STRENGTH DATA The mud weight was 9.3 ppg to 9.4 drilling the A -16 well. No abnormal pressure trends were encountered throughout the well. ECD averaged 10.9 during drilling. No abnormal connection or trip gasses were noted. El EPOCH 28 ConocoPhillips Alaska, Inc. NCIU A -16 0 5 DRILLING DATA 5.1 Survey Data Measured Incl. Azim. True Latitude Departure Vertical Dogleg Depth ° ° Vertical (ft) (ft) Section Rate (ft) () () Depth (ft) N( +), S( -) E( +), W( -) (ft) ( ° /100ft) 221.58 0.18 0.86 221.58 ON OE 0.00 TIE -IN 389.00 0.46 47.08 389.00 0.72N 0.5E 0.05 0.21 446.00 2.15 353.06 445.98 1.94N 0.53E 0.76 3.37 508.00 4.60 319.81 507.87 5N 1.21W 4.00 4.90 569.00 6.27 304.70 568.60 8.76N 5.53W 9.72 3.58 630.00 7.09 297.04 629.19 12.37N 11.62W 16.75 1.98 690.00 7.34 296.66 688.71 15.77N 18.34W 24.16 0.42 752.00 7.00 292.19 750.23 18.98N 25.38W 31.69 1.05 815.00 7.70 272.97 812.72 20.65N 33.15W 38.87 4.04 880.00 6.48 236.94 877.25 18.87N 40.58W 43.68 6.96 943.00 6.30 206.16 939.88 13.83N 45.08W 44.18 5.38 1008.00 7.00 209.90 1004.44 7.19N 48.63W 42.96 1.27 1070.00 7.79 236.74 1065.94 1.61N 54.03W 43.84 5.66 1134.00 8.72 265.97 1129.31 1.11S 62.50W 48.91 6.64 1198.00 10.79 287.39 1192.40 0.34N 73.06W 58.17 6.47 1262.00 13.36 290.05 1254.98 4.67N 85.73W 70.85 4.11 1325.00 15.81 297.29 1315.95 11.1N 100.19W 86.24 4.84 • 1389.00 19.76 299.82 1376.88 20.48N 117.33W 105.55 6.29 1452.00 23.83 303.52 1435.37 32.81N 137.19W 128.82 6.82 1517.00 25.93 301.85 1494.33 47.56N 160.22W 156.06 3.41 1581.00 28.84 300.39 1551.15 62.76N 185.42W 185.31 4.67 1626.86 31.78 298.71 1590.74 74.16N 205.56W 208.22 6.67 1724.06 37.89 294.55 1670.50 98.88N 255.21W 262.67 6.74 1783.91 38.08 293.52 1717.67 113.88N 288.85W 298.49 1.11 1817.91 37.99 293.82 1744.45 122.29N 308.04W 318.83 0.60 1881.11 39.44 295.53 1793.76 138.80N 343.95W 357.37 2.85 1942.01 41.73 299.51 1840.02 157.13N 379.05W 396.38 5.67 2007.71 43.39 302.30 1888.41 179.96N 417.16W 440.51 3.82 2067.86 43.83 302.60 1931.96 202.22N 452.17W 481.84 0.81 2130.26 44.48 303.92 1976.73 226.06N 488.52W 525.18 1.80 2195.46 45.83 303.15 2022.71 251.6N 527.05W 571.30 2.23 2258.36 47.27 304.33 2065.97 276.96N 565.02W 616.86 2.66 2321.56 49.02 305.56 2108.14 303.93N 603.60W 663.89 3.13 2390.06 51.63 308.90 2151.87 335.84N 645.54W 716.59 5.35 2452.36 50.73 309.75 2190.93 366.60N 683.09W 765.10 1.79 2515.46 51.29 310.23 2230.63 398.12N 720.67W 814.10 1.07 2579.66 51.67 310.89 2270.61 430.78N 758.83W 864.26 1.00 2643.86 51.93 310.72 2310.31 463.75N 797.02W 914.63 0.46 2705.71 51.73 310.76 2348.54 495.48N 833.86W 963.18 0.33 2770.11 51.11 310.06 2388.70 528.12N 872.19W 1013.45 1.28 III 2833.46 50.86 310.17 2428.58 559.83N 909.83W 1062.62 0.42 2894.56 51.10 310.61 2467.05 590.59N 945.99W 1110.03 0.68 El EPOCH 29 ConocoPhillips Alaska, Inc. NCIU A -16 2961.21 51.04 310.53 2508.93 624.31N 985.37W 1161.81 0.13 • 3019.16 51.81 311.11 2545.06 653.93N 1019.66W 1207.04 1.54 3078.71 52.28 310.68 2581.69 684.67N 1055.15W 1253.91 0.97 3148.76 52.35 311.75 2624.51 721.20N 1096.85W 1309.23 1.21 3213.06 52.31 311.43 2663.81 754.98N 1134.92W 1359.99 0.40 3277.06 53.32 311.57 2702.49 788.77N 1173.1W 1410.86 1.59 3340.91 54.55 311.27 2740.07 822.91N 1211.81W 1462.35 1.96 3404.36 54.37 311.80 2776.96 857.14N 1250.45W 1513.85 0.74 3468.41 54.22 312.32 2814.34 891.99N 1289.07W 1565.69 0.70 3532.71 54.20 312.13 2851.94 927.04N 1327.69W 1617.67 0.24 3595.16 54.10 311.62 2888.51 960.83N 1365.38W 1668.15 0.68 3658.41 54.11 311.44 2925.60 994.80N 1403.74W 1719.26 0.23 3721.21 53.70 311.41 2962.60 1028.37N 1441.79W 1769.88 0.65 3786.61 53.62 311.59 3001.35 1063.28N 1481.25W 1822.44 0.25 3849.81 53.35 311.65 3038.96 1097.02N 1519.22W 1873.1 0.43 3913.31 52.85 311.85 3077.08 1130.83N 1557.10W 1923.74 0.83 3976.11 52.81 311.31 3115.03 1164.04N 1594.53W 1973.65 0.69 4039.76 52.74 311.73 3153.53 1197.64N 1632.48W 2024.21 0.54 4103.91 52.62 311.3 3192.42 1231.45N 1670.68W 2075.1 0.56 4167.91 52.61 311.37 3231.28 1265.04N 1708.86W 2125.84 0.09 4230.31 52.43 311.81 3269.25 1297.91N 1745.90W 2175.23 0.63 4287.71 52.55 311.75 3304.2 1328.25N 1779.85W 2220.64 0.22 4354.26 51.88 312.26 3344.98 1363.44N 1818.94W 2273.07 1.17 4421.26 51.85 312.39 3386.35 1398.93N 1857.90W 2325.58 0.16 4483.11 51.75 312.37 3424.6 1431.69N 1893.80W 2374.01 0.16 4498.11 51.78 312.52 3433.88 1439.64N 1902.50W 2385.75 0.81 4549.98 51.77 312.32 3465.98 1467.13N 1932.58W 2426.35 0.3 4613.33 53 309.85 3504.64 1500.10N 1970.40W 2476.43 3.65 4675.88 53.52 308.92 3542.06 1531.90N 2009.14W 2526.53 1.46 4738.83 53.2 308.97 3579.62 1563.65N 2048.43W 2577.02 0.51 4801.78 53.86 307.89 3617.04 1595.12N 2088.09W 2627.64 1.72 4865.58 53.74 307.81 3654.72 1626.71N 2128.74W 2679.12 0.21 4930.73 53.65 308.14 3693.29 1659.02N 2170.13W 2731.62 0.43 4994.43 53.34 308.12 3731.18 1690.64N 2210.40W 2782.83 0.49 5057.98 53.12 308.38 3769.22 1722.15N 2250.38W 2833.73 0.48 5057.98 53.12 308.38 3769.22 1722.15N 2250.38W 2833.73 0.48 5122.78 53.82 306.85 3807.80 1753.93N 2291.63W 2885.79 2.18 5186.63 53.33 306.76 3845.71 1784.70N 2332.76W 2937.16 0.77 5249.68 53.24 306.78 3883.41 1814.95N 2373.25W 2987.70 0.14 5311.78 53.13 305.95 3920.62 1844.43N 2413.28W 3037.40 1.08 5376.58 52.80 306.58 3959.65 1875.03N 2454.99W 3089.12 0.93 5437.68 52.55 306.22 3996.70 1903.86N 2494.10W 3137.70 0.63 5530.10 50.53 307.50 4054.18 1947.26N 2552.00W 3210.06 2.44 5593.40 49.54 307.37 4094.83 1976.75N 2590.53W 3258.57 1.56 5657.90 48.53 305.71 4137.12 2005.75N 2629.65W 3307.27 2.50 5720.15 46.68 307.39 4179.09 2033.12N 2666.58W 3353.23 3.57 5784.20 44.78 308.94 4223.80 2061.46N 2702.65W 3399.09 3.43 5847.00 42.45 309.58 4269.26 2088.86N 2736.19W 3442.39 3.79 5910.75 39.19 310.71 4317.50 2115.72N 2768.05W 3484.00 5.24 Ell EPOCH 30 ConocoPhillips Alaska, Inc. NCIU A -16 5973.40 35.72 310.63 4367.23 2140.54N 2796.94W 3522.04 5.54 6038.40 33.37 311.01 4420.76 2164.63N 2824.83W 3558.83 3.62 6102.70 31.11 310.37 4475.15 2187.00N 2850.83W 3593.08 3.57 6166.05 27.83 307.02 4530.30 2206.51N 2875.11W 3624.22 5.79 6229.10 24.63 306.77 4586.85 2223.24N 2897.39W 3652.08 5.08 6291.30 22.87 309.64 4643.78 2238.71N 2917.08W 3677.12 3.37 6355.75 20.82 310.68 4703.60 2254.17N 2935.42W 3701.08 3.24 6419.10 19.48 311.63 4763.07 2268.53N 2951.85W 3722.86 2.18 6483.30 17.93 311.33 4823.88 2282.17N 2967.28W 3743.39 2.42 6544.05 17.43 308.14 4881.77 2293.94N 2981.46W 3761.69 1.79 6608.24 16.18 305.90 4943.22 2305.12N 2996.27W 3780.25 2.19 6672.44 15.39 305.50 5004.99 2315.31N 3010.45W 3797.71 1.24 6736.59 14.53 305.55 5066.97 2324.93N 3023.92W 3814.26 1.34 6800.14 13.82 308.11 5128.58 2334.25N 3036.38W 3829.82 1.49 6864.05 13.18 306.44 5190.73 2343.29N 3048.25W 3844.74 1.17 6928.5 11.32 307.02 5253.71 2351.47N 3059.21W 3858.41 2.89 6991.25 9.02 309.79 5315.47 2358.32N 3067.91W 3869.48 3.75 7050.35 7.94 308.12 5373.93 2363.81N 3074.68W 3878.19 1.87 7114.70 6.9 307.53 5437.72 2368.94N 3081.25W 3886.64 1.62 7181.05 6.36 307.7 5503.62 2373.61N 3087.32W 3894.30 0.82 7305.26 5.29 307.65 5627.19 2381.32N 3097.30W 3906.90 0.86 7368.30 4.78 307.05 5689.97 2384.84N 3101.94W 3912.62 0.81 7433.45 4.66 307.97 5754.90 2388.11N 3106.19W 3917.98 0.22 7497.66 4.42 305.90 5818.91 2391.16N 3110.25W 3923.07 0.45 7561.11 4.23 306.92 5882.18 2394.00N 3114.11W 3927.85 0.32 7624.86 4.12 307.90 5945.76 2396.82N 3117.79W 3932.49 0.21 7687.76 4.08 306.84 6008.48 2399.58N 3121.37W 3937.13 0.13 7751.01 4.25 307.27 6071.56 2402.35N 3125,04W 3941.72 0.25 7815.06 4.19 305.97 6135.44 2405.16N 3128.82W 3946.43 0.17 7942.21 4.05 303.55 6262.26 2410.39N 3136.38W 3955.61 0.22 8004.91 4.11 301.47 6324.80 2412.78N 3140.14W 3960.05 0.25 8068.66 4.52 300.67 6388.37 2415.27N 3144.27W 3964.84 0.65 8131.71 4.58 300.55 6451.22 2417.82N 3148.58W 3961.81 0.09 8196.81 4.29 299.16 6516.12 2420.32N 3152.94W 3974.79 0.46 8259.86 4.21 298.11 6579.00 2422.56N 3157.04W 3979.41 0.19 8321.66 4.16 296.05 6640.64 2424.61N 3161.05W 3983.84 0.25 8386.96 4.05 295.66 6705.77 2426.65N 3165.26W 3988.42 0.17 8449.71 4.00 292.65 6768.36 2428.46N 3169.28W 3992.71 0.35 8513.01 4.08 293.93 6831.50 2430.22N 3173.38W 3997.04 0.19 8576.31 4.06 291.71 6894.65 2431.97N 3177.52W 4001.38 0.25 8640.16 4.07 289.62 6958.33 2433.56N 3181.76W 4005.72 0.23 8702.71 4.06 288.25 7020.73 2435.00N 3185.95W 4009.92 0.16 8767.26 3.82 286.09 7085.13 2436.31N 3190.18W 4014.07 0.43 8831.01 3.84 286.61 7148.73 2437.51N 3194.27W 4018.04 0.06 8895.26 3.78 285.63 7212.84 2438.70N 3198.37W 4022.02 0.13 8957.01 3.70 284.37 7274.46 2439.74N 3202.26W 4025.74 0.19 9019.96 3.76 284.61 7337.28 2440.77N 3206.23W 4029.52 0.10 • 9083.31 3.60 283.91 7400.49 2441.77N 3210.17W 4033.25 0.28 9146.86 3.50 283.37 7463.92 2442.69N 3213.99W 4036.85 0.16 E 1 EPOCH 31 ConocoPhillips Alaska, Inc. NCIU A -16 • 9209.56 3.38 280.64 7526.51 2443.48N 3217.67W 4040.24 0.32 9242.31 3.40 283.49 7559.20 2443.88N 3219.56W 4041.99 0.52 9314 PROJECT 7630.76 • El EPOCH 32 . Cono.illips • Alaska, Inc. NCIU A -16 5.2 Bit Record Jets / Depth In Total Bit Avg. WOB PP Bit Size Make Type / S# TFA MD / TVD Footage Hrs (ftlOh�) Wear BHA (Klbs) RPM (psi) 1 NA NA NA NA NA NA _ NA NA NA NA NA NA NA 5x13, 1- 3 -T -A X -I- 2 8.75 Christe nsen B T- A - HC605Z/7117476 2x12/0 4546'/3463' 0' 0.25 0 0 0 1290 C #7 .869 5x13, 0- 5- BT- G -X -O- 2rr1 8.75" Christie nsen HC 2x12/0 4546'/3463' 20' 20 133 0.5 56 1890 NO -RIG #9 .869 2X12, PDC 3 8.75" Christensen D 4X14/ 4566'/3476' 863' 2.42 137 3.9 100 1927 RR #10 0.822 2X12, PDC uhe 3rr1 8.75" Christie nsen DP504/7119827 4X14/ 5429'/4073' 1820' 32.4 85 7.8 55.4 2053 RR #11 0.822 PDC Hughes 2X12' CT 1- 2- - G -X -1- 3rr2 8.75" Christensen DP504/7119827 4X14/ 7249'/5571' 2065' 53.6 53 5.8 98.9 2392 CT -TD #12 0.822 El EPOCH 33 9 COn0 i lips • Alaska, Inc. NCIU A -16 5.3 Mud Record Contractor: MI SWACO Mud Type: Kla- Sheild Date Depth MW ECD VIS PV YP Gels FL FC SoIs O/W Sd CI Ca pH (ppg) (ppg) (s /qt) (cc) ( /o) Ratio (/o) (m1 /1) (m1 /1) 9/28/08 4546' 9.3 - 45 17 13 - 4.7 - - - - - - - 9/29/08 4546' 9.4 9.94 78 22 23 9/11/14 5.2 1/- 6 -/94 - 10.0 55000 10 9/30/08 4546' 9.3 9.3 68 16 26 7/8/10 5.6 1/1 4 /96 tr 9.8 45000 10 10/01/08 4566' 9.2 9.2 61 17 24 7/8/9 5.4 1/1 6 /94 0 9.9 45000 10 10/02/08 4566' 9.2 9.2 64 18 23 7/8/9 5.4 1/2 1 1/98 - 9.9 45000 10 10/03/08 4566' 9.2 9.2 61 16 25 7/8/9 5.4 1/2 1 1/98 - 9.9 45000 10 10/04/08 4566' 9.2 9.2 63 18 23 7/8/9 5.4 1/2 6 1/93 - 9.9 45000 10 10/05/08 4566' 9.2 9.2 62 18 23 7/8/9 5.6 1/2 6 1/93 - 9.9 45000 20 10/06/08 4625' 9.2 9.88 68 11 24 7/9/11 5.4 1/1 6 1/93 tr 10.1 44000 10 10/07/08 5563' 9.3 14.22 70 21 _ 34 9/12/14 4.4 1/2 7 1/92 - 9.7 35000 20 10/08/08 5952' 9.3 10.33 70 23 34 10/13/15 4.2 1/2 5 1/94 0.3 9.6 35500 20 10/09/08 5238' 9.3 11.05 58 21 24 7/9/12 4.6 1/2 5 1/94 0.5 9.4 32000 20 10/10/08 7117' 9.4 10.23 56 24 25 9/10/13 5.2 1/2 6.5 1/93 0.5 9.4 32000 10 10/11/08 7250' 9.4 - 54 23 26 9/11/12 5.2 1/2 6.5 1/93 0.5 9.4 32000 20 10/12/08 7655' 9.4 11.96 58 20 24 8/10/12 5.2 1/2 5.5 1/94 0.5 9.5 32500 10 10/13/08 8322' 9.4 9.3 56 21 23 7/9/11 4.8 _ 1/2 5.0 1/94 0.5 9.5 31000 10 10/14/08 8594' 9.3 54 17 18 7/9/10 5.2 1/2 5.0 1/94 0.5 9.4 30000 10 10/15/08 9267' 9.4 10.9 64 21 24 8/10/11 4.6 1/2 6 1/93 0.5 9.4 27500 10 10/16/08 9315' 9.4 9.4 62 26 29 7/9/10 4.4 1/2 6 1/93 0.4 5 27000 10 10/17/08 9315' 9.4 9.4 63 26 27 7/9/10 4.4 1/2 6 1/93 0.4 5 28000 10 10/18/08 9315' 9.3 9.3 63 25 28 7/9/10 4.8 1/2 6 1/93 0.5 4 21000 10 10/19/08 9315' 9.2 9.2 67 21 26 7/9/11 4.6 1/2 5 1/94 0.3 4 22000 10 10/20/08 9315' 9.3 9.2 68 22 23 7/9/10 4.8 1/2 5 1/94 0.3 4 22000 10 10/21/08 9315' 9.2 9.2 65 18 26 7/9/10 5.2 1/2 5 1/94 0.5 4 22000 10 10/22/08 9315' 9.4 9.4 68 21 26 6/8/10 4.2 1/2 6.5 1/93 0.5 5 19000 10 10/23/08 9315' 9.3 9.3 70 21 28 7/9/10 4.2 1/2 6 1/92 0.4 4 20000 10 10/24/08 9315' 9.4 9.4 85 19 24 6/8/9 4.2 1/2 6.5 2/92 0.4 4 20000 10 Abbreviations MW = Mud Weight Gels = Gel Strength Sd = Sand content ECD = Effective Circulating Density WL = Water or Filtrate Loss CI = Chlorides VIS = Funnel Viscosity FC = Filter Cake HI EPOCH 34 • Conohillips • Alaska, Inc. • NCIU A -16 Ca = Hardness Calcium PV = Plastic Viscosity Sols = Solids O/W = Oil to Water ratio YP = Yield Point III EPOCH 35 6 DAILY REPORTS • • • U EPOCH 36 ConocoPhillips Alaska Inc. NCUI A -16 Daily Report Report for: Scott Heim Dink H. Date: 9/29/08 Time: 02:30 Current Depth (MD): 46' Current Test BOP Current Depth (TVD): Operations: 24 hr Footage (MD): 46' Note: ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf -to Strokes: Time: Surf: ECD: Current: Max: Mud Properties @ 23:30 hrs 092808/0046' MW: 9.3 FV: 45 PV: 17 YP: 13 FL: 4.7 GELLS - Sol: - pH: - CI - Ca + +: - MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): AvgBG: Ou Gas Events Depth ( MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas Connection C1 C2 C3 C4I C4N C5I C5N Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Rig move finished. Nipple up and test BOP. Calibrations: Failures: • PI EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report II Report for: Scott Heim Dink H. Date: 9/30/08 Time: 02:19 Current Depth (MD): 4442' Current Conditioning mud inside Current Depth (TVD): Unavail Operations: casing 24 hr Footage (MD): No new Note: ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf -to Strokes: Time: Surf: ECD: Current: Max: Mud Properties @ 22:30 hrs 092808/4440' MW: 9.4 FV: 78 PV: 22 YP: 23 FL: 5.2 GELLS 9/11/14 Sol: 6 pH: 10.0 CI 55000 Ca + +: 10 MW Change: Depth: 4440' From: 9.3 To: 9.4 Reason: Conditioning Mud Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD /TVD): Ask Avg BG: lir Gas Events Depth (MD /TVD) C1 C2 C3 C41 C4N C5I C5N Trip Gases 3890'/NA 6u 4453'/NA Connection C1 C2 C3 C41 C4N C51 C5N Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C51 C5N Lithologies: Current: Last 24 hrs: BOP Test completed. Rig repairs. M/U BHA #7. TIH while conditioning mud. Operational Summary: Spud mud being displaced with new mud was very clabbered but did not affect QGM operation. Calibrations: THA and integrator spanned and calibrated and QGM tested between 1221- 1347hrs 9/29/08. Failures: El EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report • Report for: Scott Heim Dink H. Date: 10/01/08 Time: 03:25 Current Depth (MD): 148' Current Current Depth NA Operations: Making up BHA #7 (TVD): 24 hr Footage (MD): No new Note: ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-to Strokes: Time: Surf: ECD: Current: Max: Mud Properties @ 22:30 hrs 092808/4440' MW: 9.3 FV: 68 PV: 16 YP: 26 FL: 5.6 GELLS 7/8/10 Sol: 4 pH: 9.8 CF 45000 Ca + +. 10 MW Change: Depth: 4546' From: 9.3 To: 9.4 Reason: Conditioning Mud Mud Loss event: Depth: Volume: Gas Data • Ditch Gas: Current: Max: Depth ( MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gases Ou Connection C1 C2 C3 C41 C4N C51 C5N Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: Test casing, circulated and conditioned mud, tried to test casing again, rigged Operational Summary: down, built and pumped a dry job, POOH to BHA, LD BHA and Motor, test casing, close blinds, M/U RTTS, RIH, Set RTTS at 4430', test casing for 30 minutes, bleed pressure, release RTTS, POOH, M/U BHA ( #7 same as last). Calibrations: Failures: • PI EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report • Report for: Scott Heim Dink H. Date: 10/02/08 Time: 02:32 Current Depth (MD): 4566' Current Current Depth (TVD): 3475.9 Operations: Circulating 24 hr Footage (MD): 20' Note: ROP: Current: 0 Max: 182 Torque: Current: 19 Max: 19 WOB: Current 0 Max: 31 RPM: Current: 89 Max: 154 PP: Current: 212 Max: 1491 Lag: Strokes: 4551 Time: 21.6 Surf-to Strokes: Time: Surf: ECD: Current: 0 Max: 9.2 Mud Properties @ 22:30 hrs 092808/4440' MW: 9.2 FV: _61 PV: 17 YP: 24 FL: 5.4 GELLS 7/8/9 Sol: 6 pH: 9.9 Cr 45000 Ca + +: 10 MW Change: Depth: 4566' From: 9.3 To: 9.2 Reason: Conditioned mud Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG Ou Ou 4566'/3343' • Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gases 4566'/3343' Ou Connection C1 C2 C3 C41 C4N C51 C5N Gases Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C41 C4N C5I C5N Lithologies: Current: Tuffaceous claystone and ash (also much cement in samples) Last 24 hrs: Tuffaceous claystone and ash (also much cement in samples) Finished M/U BHA, RIH, Slip and cut drilling line. Service the rig. Drill out cement Operational Summary: to 4556'. Circulate and condition mud, then drill to 4566', circulate and condition mud, R/U for LOT. LOT at 14.8 ppg, R/D test equipment and trouble -shoot the top drive. Circulate and conditioned mud and monitor well. Calibrations: Butane tests of gas detection system conducted between 1750 -1800 hours on 10/01/08. Failures: • NI EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report • Report for: Scott Heim Dink H. Date: 10/03/08 Time: 02:02 Current Depth (MD): 4566' Current Current Depth (TVD): 3475.9 Operations: Laying down BHA 24 hr Footage (MD): 0' Note: ROP: Current: 0 Max: 182 Torque: Current: 0 Max: 19 WOB: Current 0 Max: 31 RPM: Current: 0 Max: 154 PP: Current: 0 Max: 1491 Lag: Strokes: 4551 Time: 21.6 Surf-to Strokes: Time: Surf: ECD: Current: 0 Max: 9.2 Mud Properties @ 22:30 hrs 092808/4440' MW: 9.2 FV: 64 PV: 18 YP: 23 FL: 5.4 GELLS 7/8/9 Sol: 1 pH: 9.9 Cr 45000 Ca + +: 10 MW Change: Depth: 4566' From: 9.3 To: 9.2 Reason: Conditioning mud Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth ( MD/TVD): • Avg BG : Ou Ou 4566'/3343' Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gases Ou Connection Gases C1 C2 C3 C4I C4N C51 C5N Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C51 C5N Lithologies: Current: NA Last 24 hrs: Tuffaceous claystone and ash (also much cement in samples) Continue to trouble shoot the top drive. Remove the top drive guard and motor. Operational Summary: Reinstalled the top drive guard, and rehooked the service cables. POOH without motor, Laying down BHA. Calibrations: Failures: • El EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report • Report for: Scott Heim Dink H. Date: 10/04/08 Time: 02:09 Current Depth (MD): 4566' Current Current Depth (TVD): 3475.9 Operations: Top Drive Repair 24 hr Footage (MD): 0' Note: ROP: Current: 0 Max: 0 Torque: _ Current: 0 Max: 1 WOB: Current 0 Max: 37 RPM: Current: 25 Max: 26 PP: Current: 0 Max: 185 Lag: Strokes: Time: Surf-to Strokes: Time: Surf: ECD: Current: 0 Max: 0 Mud Properties @ 22:30 hrs 092808/4440' MW: 9.2 FV: 61 PV: 16 YP: 25 FL: 5.4 GELLS 7/8/9 Sol: 1 pH: 9.9 CI 45000 Ca + +: 10 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth ( MD/TVD): Avg BG : Ou Ou Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gases Ou Connection C1 C2 C3 C41 C4N C51 C5N Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C5I C5N Lithologies: Current: NA Last 24 hrs: NA Operational Summary: TIH to 4480', circulate BU. Waiting for top drive repair. Calibrations: Failures: • EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report • Report for: Scott Heim Dink H. Date: 10/05/08 Time: 01:52 Current Depth (MD): 4566' Current Current Depth (TVD): 3475.9 Operations: Top Drive Repair 24 hr Footage (MD): 0' Note: ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 27 Max: 28 PP: Current: 0 Max: 238 Lag: Strokes: Time: Surf-to Strokes: Time: Surf: ECD: Current: 0 Max: 0 Mud Properties @ 22:30 hrs 092808/4440' MW: 9.2 FV: 63 PV: 18 YP: 23 FL: 5.4 CELLS 7/8/9 Sol: 6 pH: 9.9 Cr 45000 Ca + + 10 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD /TVD): AvgBG: Ou Ou • Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C5I C5N Trip Gases Ou Connection C1 C2 C3 C41 C4N C5I C5N Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C5I C5N Lithologies: Current: NA Last 24 hrs: NA Operational Summary: Circulate for approximately 1 -hour. Waiting for top drive repair. Calibrations: Failures: • EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report 4110 Report for: Scott Heim Dink H. Date: 10/06/08 Time: 01:57 Current Depth (MD): 4566' Current Current Depth (TVD): 3475.9 Operations: M/U BHA 24 hr Footage (MD): 0' Note: ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 2 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 149 PP: Current: 0 Max: 238 Lag: Strokes: 4513 Time: 29min Surf-to Strokes: 5666 Time: 40min Surf: ECD: Current: 0 Max: 9.2 Mud Properties @ 22:30 hrs 092808/4440' MW: 9.2 _ FV: 62 PV: 18 YP: 23 FL: 5.6 GELLS 7/8/9 Sol: 6 pH: 9.9 CI 45000 Ca + +: 10 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD /TVD): AvgBG: Ou Ou • Gas Events Depth (MD /TVD) C1 C2 C3 C4I C4N C51 C5N Trip Gases 4480' MD 1u Connection C1 C2 C3 C41 C4N C51 C5N Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: NA Last 24 hrs: NA Monitoring well, break circulation, monitoring well, removed guard start installing Operational Summary: drive motor on the top drive, install the motor, test and service the top drive. Circulated at approximately 4480' MD. Monitoring well. Calibrations: Failures: 411 Li EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report 1110 Report for: Dave Morris Dink Heim Date: 10/07/08 Time: 03:15 Current Depth (MD): 4566' Current Current Depth (TVD): 5105 Operations: Drilling 24 hr Footage (MD): 539 Note: ROP: Current: 43 Max: 511 Torque: Current: 0 Max: 13 WOB: Current 6 Max: 13 RPM: Current: 18 Max: 119 PP: Current: 1931 Max: 2056 Lag: Strokes: 5199 Time: 24min Surf-to Strokes: 654 Time: 30min Surf: ECD: Current: 9.88 Max: 9.88 Mud Properties @ 22:30 hrs 092808/4440' MW: 9.2 FV: 62 PV: 18 YP: 23 FL: 5.6 GELLS 7/8/9 Sol: 6 pH: 9.9 CT 45000 Ca + +: 10 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 1 Max: Depth (MD /TVD): Avg BG : 29u 328u 4899'/3674' Gas Events Depth ( MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gases 4480'/3424' 1u Connection C1 C2 C3 C41 C4N C51 C5N Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Sands, tuffaceous siltstone and claystone Last 24 hrs: Sand, conglomeratic sand, coal, tuffaceous claystone and siltstone. Finish repair work on the top drive, pump a dry job, POOH, MU and PU BHA, Operational Summary: shallow test MWD, work on top drive hydraulics, adjust bell clamp, TIH, Drill ahead. Calibrations: Failures: • Ell EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report • Report for: Dave Morris Dink Heim Date: 10/08/08 Time: 01:40 Current Depth (MD): 5563' Current Current Depth (TVD): 4073' Operations: POOH 24 hr Footage (MD): 458' Note: ROP: Current: 0 Max: 243 Torque: Current: 0 Max: 14 WOB: Current 19 Max: 13 RPM: Current: 18 Max: 125 PP: Current: 0 Max: 2149 Lag: Strokes: NA Time: NA Surf -to Strokes: NA Time: NA Surf: ECD: Current: NA Max: 14.22 Mud Properties @ 22:00 hrs 100708/5563' MW: 9.3 FV: 70 PV: 21 YP: 34 FL: 4.4 GELLS 9/12/14 Sol: 7 pH: 9.7 Cr 35000 Ca + +: 20 MW Change: Depth: 5563 From: 9.2 To: 9.3 -9.4 Reason: Gas Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Ou 414u 5186'/3843' • Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gases Connection C1 C2 C3 C4I C4N C51 C5N Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: NA Last 24 hrs: Sand, conglomeratic sand, coal, carbonaceous shale, tuffaceous claystone and siltstone. Drilled ahead to 5563' MD. ROP's slowed down considerably. Decide to POOH to check BHA. POOH. Periodic stops for survey, to circulate and pack off hole. Operational Summary: Worked through tight spot at approx 4530 -4550' MD until full circulation was established. Circulated bottoms up, max gas 51 units. Shakers cleaned during POOH. Monitored gas during POOH. Calibrations: Gas detection system spanned and calibrated. Failures: PI EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report • Report for: Dave Morris Dink Heim Date: 10/08/08 Time: 01:56 Current Depth (MD): 6082' Current Current Depth (TVD): 4459' Operations: Drilling ahead 24 hr Footage (MD): 519' Note: ROP: Current: 0 Max: 238 Torque: Current: 0 Max: 14 WOB: Current 4 Max: 24 RPM: Current: 0 Max: 102 PP: Current: 1913 Max: 3324 Lag: Strokes: 6119 Time: 28 Surf -to Strokes: 7728 Time: 36 Surf: ECD: Current: 10.15 Max: 10.15 Mud Properties @ 22:00 hrs 100808/5952' MW: 9.3 FV: 70 PV: 23 YP: 34 FL: 4.2 GELLS 10/13/15 Sol: 5 pH: 9.6 Cr 35500 Ca' +: 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth ( MD/TVD): Avg BG : Ou 208u 5851'/4270' 411 Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gases 5563'/4071' 51u Connection C1 C2 C3 C41 C4N C51 C5N Gases 233u (Max) 5853'/4272' Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C51 C5N Lithologies: Current: Tuffaceous claystone and siltstone, minor coal and sand. Last 24 hrs: Sand, conglomeratic sand, coal, carbonaceous shale, tuffaceous claystone and siltstone. Continue to POOH. C/O BHA, service rig. RIH with same bit, drill from 5563' to Operational Summary: 6050'. Smooth hole, more sliding than rotating. (Connection gasses high at 233u, but generally much lower in <10 to 40u range.) Drilling ahead. Calibrations: Failures: El EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report Report for: Dave Morris Mike Ross Date: 10/10/08 Time: 01:30 Current Depth (MD): 6551' Current Current Depth (TVD): 4889' Operations: Tripping into Hole 24 hr Footage (MD): 500' Note: ROP: Current: 0 Max: 249 Torque: Current: 0 Max: 14 WOB: Current 0 Max: 30 RPM: Current: 0 Max: 100 PP: Current: 0 Max: 2435 Lag: Strokes: 6612 Time: 34 Surf-to Strokes: 8361 Time: 43 Surf: ECD: Current: 10.04 Max: 11.05 Mud Properties @ 22:00 hrs 100808/5952' MW: 9.3 FV: 58 PV: 21 YP: 24 FL: 4.6 GELLS 7/9/12 Sol: 5 pH: 9.4 Cr 33000 Ca + +: 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: 6551' Volume: 60bb1 Gas Data Ditch Gas: Current: Max: Depth ( MD/TVD): Avg BG 106u 385u 6349'/4696' • Gas Events Depth ( MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gases Connection C1 C2 C3 C41 C4N C51 C5N Gases 157u (Max) 6236'/4589' Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Tuffaceous claystone and siltstone, minor coal and carbonaceous material. Last 24 hrs: Sand, conglomeratic sand, coal, carbonaceous shale and siltstone, tuffaceous claystone and siltstone. Drill from 6051' to 6551'. Circulate B/U for short trip. Encountered 60 bbl loss. Operational Summary: Monitored well, no static losses. POOH to shoe working tight spots as needed. Circulate at shoe, seeing losses of less than 1 bbl per hour. TIH to bottom. Calibrations: Swapped out H2 regulator; spanned, flowed and calibrated gas detection equipment. Failures: • El EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report Report for: Dave Morris Mike Ross Date: 10/11/08 Time: 02:29 Current Depth (MD): 7158' Current Current Depth (TVD): 5479' Operations: Circulating 24 hr Footage (MD): 607' Note: ROP: Current: 13 Max: 229 Torque: Current: 0 Max: 15 WOB: Current 0 Max: 28 RPM: Current: 0 Max: 102 PP: Current: 2077 Max: 2423 Lag: Strokes: 7464 Time: 34 Surf-to Strokes: 9451 Time: 43 Surf: ECD: Current: 10.1 Max: 10.23 Mud Properties @ 22:00 hrs 100808/5952' MW: 9.4 FV: 56 PV: 24 YP: 25 FL: 5.2 GELLS 9/10/13 Sol: 6.5 pH: 9.4 CI 32000 Ca + +. 10 MW Change: Depth: 6867' From: 9.5 To: 9.4 Reason: Drill plan Mud Loss event: Depth: 7143' Volume: 1 bbl Gas Data Ditch Gas: Current: Max: Depth ( MD/TVD): _ Avg BG : 25u 107u 6803'/5131' • Gas Events Depth ( MD/TVD) C1 C2 C3 C4I C4N C51 C5N Trip Gases 6551'/4889' 107u Connection C1 C2 C3 C4I C4N C51 C5N Gases 34u (Max) 7125'/5445' Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N H Lithologies: Current: Tuffaceous claystone and siltstone, minor tuffaceous sand /sandstone. Last 24 hrs: Sand, conglomeratic sand, coal, carbonaceous shale and siltstone, tuffaceous claystone and siltstone; sandstone, tuffaceous sandstone. Circulate at shoe to establish loss rate (less than 1 bbl per hour). RIH and drilled from 6551' to 7158'. Seepage losses @ 5 -7 bbls an hour resulted in adding Operational Summary: NutPlug Fine to reduce losses. LCM affected sample quality below 7000' MD. Sampling interval reduced to 30' intervals, though 30' spot samples were taken higher in section. Calibrations: Failures: • PI EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report • Report for: Dave Morris Mike Ross Date: 10/12/08 Time: 02:42 Current Depth (MD): 7250' Current Current Depth (TVD): 5571' Operations: Prep to M/U BHA 24 hr Footage (MD): 92' Note: ROP: Current: 0 Max: 107 Torque: Current: 0 Max: 15 WOB: Current 0 Max: 25 RPM: Current: 0 Max: 102 PP: Current: 0 Max: 2284 Lag: Strokes: NA Time: NA Surf -to Strokes: NA Time: NA Surf: ECD: Current: Max: Mud Properties @ 22:00 hrs 100808/5952' MW: 9.4 FV: 54 PV: 23 YP: 26 FL: 5.0 GELLS 9/11/12 Sol: 6 pH: 9.4 Cr 32500 Ca + +: 20 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth ( MD/TVD): Avg BG : 0 49u 7241'/5563' 12u • Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C51 C5N Trip Gases Connection C1 C2 C3 C41 C4N C5I C5N Gases 27u (Max) 7188'/5511' Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: NA Last 24 hrs: Sand, conglomeratic sand, coal, carbonaceous shale and siltstone, tuffaceous claystone and siltstone; sandstone, tuffaceous sandstone. Monitored gas during drilling to 7157' to 7250 feet. Problems with LWD /MWD Operational Summary: followed by total LWD failure. Pump slug and POOH. L/D BHA, Test BOP's. Repair /inspect LWD /MWD Tools. M/U BHA. Calibrations: Failures: • HI EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report • Report for: Dave Morris Mike Ross Date: 10/13/08 Time: 03:05 Current Depth (MD): 7723' Current Current Depth (TVD): 6044' Operations: Drilling ahead 24 hr Footage (MD): 474' Note: ROP: Current: 0 Max: 203 Torque: Current: 16 Max: 17 WOB: Current .3 Max: 28 RPM: Current: 100 Max: 105 PP: Current: 2169 Max: 2864 Lag: Strokes: 7880 Time: 36 Surf-to Strokes: 9987 Time: 46 Surf: ECD: Current: 10.15 Max: 11.96 Mud Properties @ 22:00 hrs 101208/7655' MW: 9.4 FV: 58 PV: 20 YP: 24 FL: 5.2 GELLS 8/10/12 Sol: 5.5 pH: 9.5 Cr 32500 Ca + +: 10 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 118 411u 7694'/6016' 49u Gas Events Depth (MD /TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gases 7245'/5568' 67u Connection C1 C2 C3 C41 C4N C51 C5N Gases 43u (Max) 7312'/5635' Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Coals and tuffaceous claystone and siltstone Last 24 hrs: Sand, conglomeratic sand, coal, carbonaceous shale and siltstone, tuffaceous claystone and siltstone; sandstone, tuffaceous sandstone. Operational Summary: M/U BHA, RIH to the shoe. Cut and Slip drilling line. Perform MAD PASS from 6732' to 7250'. Drill from 7250' to 7723'. Drilling ahead. Calibrations: Failures: • El EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report • Report for: Dave Morris Mike Ross Date: 10/14/08 Time: 01:54 Current Depth (MD): 8411' Current Current Depth (TVD): 6730' Operations: Drilling ahead 24 hr Footage (MD): 688' Note: ROP: Current: 29 Max: 217 Torque: Current: 17 Max: 19 WOB: Current 6 Max: 26 RPM: Current: 108 Max: 109 PP: Current: 2360 Max: 2608 Lag: Strokes: 7880 Time: 36 Surf-to Strokes: 9987 Time: 46 Surf: ECD: Current: 10.0 Max: 10.9 Mud Properties @ 22:00 hrs 101308/8276' MW: 9.4 FV: 54 PV: 21 YP: 21 FL: 5.5 GELLS 7/9/10 Sol: 5 pH: 9.4 CI 29000 Ca + +: 10 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD /TVD): Avg BG : 24 479u 7986'/6306' S 41u Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C5I C5N Trip Gases Connection C1 C2 C3 C41 C4N C51 C5N Gases 57u (Max) 8204'/6523' Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Tuffaceous claystone and siltstone, sand and coal Last 24 hrs: Sand, conglomeratic sand, coal, carbonaceous shale and siltstone, tuffaceous claystone and siltstone; sandstone, tuffaceous sandstone. Operational Summary: Drilled ahead from 7723' MD through 8411' MD. Currently drilling. Calibrations: Failures: • El EPOCH ConocoPhillips Alaska Inc. NCUI A -16 • Daily Report Report for: Dave Morris Mike Ross Date: 10/15/08 Time: 02:36 Current Depth (MD): 8622' Current Current Depth (TVD): 6940' Operations: Drilling ahead 24 hr Footage (MD): 211' Note: ROP: Current: 36 Max: 126 Torque: Current: 19.5 Max: 20 WOB: Current 2.5 Max: 10 RPM: Current: 102 Max: 109 PP: Current: 2400 Max: 2635 Lag: Strokes: 9057 Time: 40 Surf -to Strokes: 11494 Time: 50 Surf: ECD: Current: 10.06 Max: 10.74 Mud Properties @ 22:00 hrs 101408/6219' MW: 9.3 FV: 58 PV: 20 YP: 20 FL: 5.6 GELLS 7/9/10 Sol: 4.5 pH: 9.4 CI 28000 Ca + +: 20 MW Change: Depth: 8594' From: 9.4 To: 9.3 Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth ( MD/TVD): AvgBG:28u 24 190u 8589'/6907' • Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C51 C5N Trip Gases 8594'/6914 703u (max) Connection C1 C2 C3 C41 C4N C5I C5N Gases 23u (Max) 8458'/6777' Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Tuffaceous claystone and siltstone, sand. Last 24 hrs: Sand, conglomeratic sand, coal, carbonaceous shale and siltstone, tuffaceous claystone and siltstone; sandstone, tuffaceous sandstone. Drilled ahead from 7723' MD through 8594' MD. HPU trouble at approximately Operational Summary: 1230 hrs. Short trip to the shoe, with maximum swab gas during POOH at 702 units. Troubleshooting successful; RIH at 2120 hours. Circulated on bottom at 0029 hrs with wiper gases at 703 units maximum. Drilling ahead. Calibrations: Failures: 411 El I EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report e Report for: Dave Morris Mike Ross Date: 10/16/08 Time: 04:23 Current Depth (MD): 9314' Current Current Depth (TVD): 7631' Operations: POOH 24 hr Footage (MD): 692' Note: ROP: Current: 0 Max: 166 Torque: Current: 0 Max: 23 WOB: Current 0 Max: 10 RPM: Current: 0 Max: 109 PP: Current: 2701 Max: 2746 Lag: Strokes: 9380 Time: 46 Surf-to Strokes: 11916 Time: 58 Surf: ECD: Current: NA Max: 10.16 Mud Properties @ 22:00 hrs 101508/9267' MW: 9.4 FV: 64 PV: 21 YP: 24 FL: 4.6 CELLS 8/10/11 Sol: 6 pH: 9.4 Cr 27500 Ca + +: 10 MW Change: Depth: 8994' From: 9.3 To: 9.4 Reason: Wellbore stability Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): AvgBG:17u 0 85u 9152'/7469' Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gases Connection C1 C2 C3 C41 C4N C51 C5N Gases 24u (Max) 9284'/7601' Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Tuffaceous claystone and siltstone, coal. Last 24 hrs: Tuffaceous claystone and siltstone, with sand, coal, and minor carbonaceous shale. Operational Summary: Drilled to 9314' MD /7631'TVD. Well TD at 0221 hours. POOH. Calibrations: Failures: Power failure disabled gas sampling system between 1525 -1618 hrs 4 Ell EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report • Report for: Scott Heim Mike Ross Date: 10/17/08 Time: h400 Current Depth (MD): 9314' Current Current Depth (TVD): 7631' Operations: POOH 24 hr Footage (MD): 0' Note: ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 9380 Time: 46 Surf-to Strokes: 11916 Time: 58 Surf: ECD: Current: 0 Max: 0 Mud Properties @ 22:00 hrs 101508/9267' MW: 9.4 FV: 64 PV: 21 YP: 24 FL: 4.6 GELLS 8/10/11 Sol: 6 pH: 9.4 Cr 27500 Ca + +: 10 MW Change: Depth: 8994' From: 9.3 To: 9.4 Reason: Wellbore stability Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD /TVD): • AvgBG:17u 0 0 0 Gas Events Depth (MD /TVD) C1 C2 C3 C41 C4N C5I C5N Wiper Gas 185 @ 9314/7630 Connection C1 C2 C3 C41 C4N C51 C5N Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Tuffaceous claystone and siltstone, coal. Last 24 hrs: Tuffaceous claystone and siltstone, with sand, coal, and minor carbonaceous shale. Operational Summary: Circ @ TD and pull to the shoe (Wiper Trip) and trip to bottom. Wiper Gas = 185 units. Circulate and POOH to 4380' cut and slip and continue to POOH. Calibrations: Failures: El EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report Report for: Scott Heim Mike Ross Date: 10/18/08 Time: h400 Current Depth (MD): 9314' Current Current Depth (TVD): 7631' Operations: TIH Clean out run 24 hr Footage (MD): 0' Note: ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 9380 Time: 46 Surf -to Strokes: 11916 Time: 58 Surf: ECD: Current: 0 Max: 0 Mud Properties @ 22:00 hrs 101508/9267' MW: 9.4 FV: 59 PV: 25 YP: 27 FL: 4.5 GELLS 7/9/10 Sol: 6 pH: 9.5 Cl 26500 Ca + +. 10 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): AvgBG:17u 0 0 0 Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Wiper Gas Connection C1 C2 C3 C41 C4N C51 C5N Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: Operational Summary: Finish pulling out of the hole. Rig up for wire line logs. Logs would not go. Pull out of the hole and make up clean out run BHA. Start to trip into the hole. Calibrations: Failures: • Li EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report • Report for: Scott Heim Mike Ross Date: 10/19/08 Time: h400 Current Depth (MD): 9314' Current Current Depth (TVD): 7631' Operations: POOH after clean out 24 hr Footage (MD): 0' Note: ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 9380 Time: 46 Surf-to Surf: Strokes: 11916 Time: 58 ECD: Current: 0 Max: 0 Mud Properties @ 22:00 hrs 101508/9267' MW: 9.4 FV: 61 PV: 25 YP: 25 FL: 4.3 GELLS 7/9/10 Sol: 6 pH: 9.4 Cr 27500 Ca + +: 10 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): AvgBG: 0 0 0 Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas 665 units @ TD Connection C1 C2 C3 C41 C4N C51 C5N Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: Trip into hole with Clean Out Run BHA, circulate @ 1820' = 34 units, TIH to 4600' Operational Summary: circ out 147 units, TIH to 9152' and circulated out 665 units of trip gas, circulate 7 hours and begin to pull out of the hole. Background gas average after TG was 15 -25 units. Calibrations: Failures: • LI EPOCH ConocoPhillips Alaska Inc. NCUI A -16 • Daily Report Report for: Scott Heim Mike Ross Date: 10/20/08 Time: h400 Current Depth (MD): 9314' Current Current Depth (TVD): 7631' Operations: TIH to Log 24 hr Footage (MD): 0' Note: ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 _ RPM: _ Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 9380 Time: 46 Surf -to Strokes: 11916 Time: 58 Surf: ECD: Current: 0 Max: 0 Mud Properties @ 22:00 hrs 101508/9267' MW: 9.4 FV: 61 PV: 25 YP: 25 FL: 4.3 GELLS 7/9/10 Sol: 6 pH: 9.4 CI 27500 Ca + +: 10 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): AvgBG: 0 0 0 Gas Events Depth ( MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas 6 units @ 4295' Connection C1 C2 C3 C41 C4N C51 C5N Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Pull out of the hole with bit BHA clean out assembly. Rig up wire line tools. Wire Operational Summary: line will not pass window. Rig up and run in the hole with drill pipe logging (MPT). Circulate briefly @ 4295' = 6 units of gas. Calibrations: Failures: El EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report • Report for: Scott Heim Mike Ross Date: 10/21/08 Time: h400 Current Depth (MD): 9314' Current Current Depth (TVD): 7631' Operations: Logging 24 hr Footage (MD): 0' Note: ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 9380 Time: 46 Surf-to Strokes: 11916 Time: 58 Surf: ECD: Current: 0 Max: 0 Mud Properties MW: 9.2 FV: 65 PV: 21 YP: 26 FL: 4.5 GELLS 7/9/11 Sol: 5 pH: 9.5 Cr 22000 Ca + +: 10 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): ink AvgBG: 0 0 0 Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C5I C5N Trip Gas 3lunits Connection C1 C2 C3 C41 C4N C51 C5N Gases • Gas Samples No. Depth (MD /TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: Continue to wire line log. Circulate at 5580' = 11 units, Circulate at 6070' = 19 Operational Summary: units, Circulate at 6535' = 31 units. Circulation times around 6 minutes with rig pumps only. Calibrations: Failures: • Ell EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report Report for: Scott Heim Mike Ross Date: 10/22/08 Time: 2400 Current Depth (MD): 9314' Current hrs Operations: POOH w/ Logging Current Depth (TVD): 7631' Tools 24 hr Footage (MD): 0' Note: ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 9380 Time: 46 Surf -to Strokes: 11916 Time: 58 Surf: ECD: Current: 0 Max: 0 Mud Properties MW: 9.3 FV: 66 PV: 21 YP: 24 FL: 4.7 GELLS 7/9/10 Sol: 5 pH: 9.5 Cl 21500 Ca 10 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): • AvgBG: 0 0 0 Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas 122 units Connection C1 C2 C3 C41 C4N C51 C5N Gases Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: Operational Summary: Continue to wire line log. Circulate approx 30 mins @ 6673' max gas was 122 units with general bleed off. Calibrations: Failures: • Eli EPOCH ConocoPhillips Alaska Inc. NCUI A -16 • Daily Report Report for: Scott Heim Mike Ross Date: 10/23/08 Time: 2400 Current Depth (MD): 9314' Current hrs POOH after Clean Current Depth (TVD): 7631' Operations: Out Run 24 hr Footage (MD): 0' Note: ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 _ RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 9380 Time: 46 Surf-to Strokes: 11916 Time: 58 Surf: ECD: Current: 0 Max: 0 Mud Properties MW: 9.3 FV: 66 PV: 21 YP: 24 FL: 4.7 GELLS 7/9/10 Sol: 5 pH: 9.5 CI 21500 Ca + +: 10 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: _ Depth (MD /TVD): AvgBG: 0 0 0 Gas Events Depth (MD/TVD) C1 C2 C3 C41 C4N C5I C5N Trip Gas 648 units Connection C1 C2 C3 C41 C4N C5I C5N Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: Finish POOH with wire line tools. TIH with "Clean Out Run" BHA. Maximum gas observed through gas migration up the hole during wire line Togs: 53 units at surface, circ @ 2030' = 18 u, circ @ 2990' = 116 u, circ @ 3950' = 297 u, circ @ Operational Summary: 4708' = 645 u, Gas 648 units @ 6367', Gas @ 6601' = 404 u, Gas @ 7567' = 620 u, Trip gas from 9315 -9253' Max was 638 units, circulated approx. five hours with gas decreasing slowly from 600 units to a background of 15 units as the hole was circulated out @ 116 + 107 SPM. Calibrations: Failures: • NI EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report Report for: Scott Heim Mike Ross Date: 10/24/08 Time: 2400 Current Depth (MD): 9314' Current hrs Prepare to run casing Current Depth (TVD): 7631' Operations 24 hr Footage (MD): 0' Note: ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 9380 Time: 46 Surf-to Surf: Strokes: 11916 Time: 58 ECD: Current: 0 Max: 0 Mud Properties MW: 9.3 FV: 66 PV: 21 YP: 24 FL: 4.7 GELLS 7/9/10 Sol: 5 pH: 9.5 Cl 21500 Ca + +. 10 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): AvgBG: 0 0 0 • Gas Events Depth ( MD/TVD) C1 C2 C3 C41 C4N C51 C5N Trip Gas 0 units Connection C1 C2 C3 C41 C4N C5I C5N Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: Operational Summary: Finish circulating the hole with background gas at 10 -15 units. Pull out of the hole. Prep to run casing. Calibrations: Failures: • El EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report • Report for: Scott Heim Mike Ross Date: 10/25/08 Time: h400 Current Depth (MD): 9314' Current TIH w/ csg Circ @ Current Depth (TVD): 7631' Operations: 7220' 24 hr Footage (MD): 0' Note: ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 9380 Time: 46 Surf-to Strokes: 11916 Time: 58 Surf: ECD: Current: 0 Max: 0 Mud Properties MW: 9.4 FV: 72 PV: 21 YP: 28 FL: 4.0 GELLS 7/9/10 Sol: 6 pH: 9.6 Cr 20000 Ca + +: 10 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD /TVD): AvgBG: 0 0 0 r Gas Events Depth (MD/TVD) C1 ppm C2 C3 C41 C4N C51 C5N Trip Gas 656units @ 7720' 93054 581 367 150 Connection C1 C2 C3 C4I C4N C51 C5N Gases Gas Samples No. Depth ( MD/TVD) TG C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: Last 24 hrs: Run csg in the hole to 4435'. Circulate 45 mins max gas 208 units. Run in hole to 5381' circ. 30 mins max gas 205 units. RIH to 7220' with gas increasing as RIH to Operational Summary: ave 445 to 639 units. Start pumping at 7220' @ 33 spm / flow out 4 -5% bottoms up is 5 hours. Circulate 5.5 hours gas slowly decreasing from 656 unit max to 129 units after complete hole circulation and Trip Gas. MW in 9.4 / MW out 9.5 Calibrations: Failures: • El EPOCH ConocoPhillips Alaska Inc. NCUI A -16 Daily Report • Report for: Scott Heim Mike Ross Date: 10/26/08 Time: 2400 Current Depth (MD): 9314' Current hrs Csg cement/rig repair Current Depth (TVD): 7631' Operations: 24 hr Footage (MD): 0' Note: ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: 9380 Time: 46 Surf -to Strokes: 11916 Time: 58 Surf: ECD: Current: 0 Max: 0 Mud Properties MW: 9.3 FV: 68 PV: 22 YP: 28 FL: 4.2 GELLS 7/9/11 Sol: 6.5 pH: 9.6 CI 20000 Ca + +: 10 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): AvgBG: 0 0 0 Gas Events Depth (MD/TVD) C1 ppm C2 C3 C4I C4N C51 C5N Trip Gas 607 @ 9290' Connection C1 C2 C3 C4I C4N C5I C5N Gases Gas Samples No. Depth (MD /TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Run in the hole with casing from 7220' to 9290'. Circ @ 1 bpm and incr to 3 bpm. Operational Summary: Pump LCM sweep = well breathing with equal loss and gain. Rig up cement head. Maximum Trip Gas noted from 7220' to 9290' was 607 units. Gas circulated out of the hole and background gas 7 to 15 units. Cement casing to hole. Start rig repair. Calibrations: Failures: • El EPOCH