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212-094
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,700' N/A Casing Collapse Structural Conductor Surface 2,470psi 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: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 2 Baker FH Prks; SSSV 5597' MD/5715' TVD, 9040' MD/7828' TVD; 372' MD/TVD 9,488' 8,998' 7,786' North Fork Tyonek Gas 16" 10-3/4" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 North Fork Unit (NFU) 22-35CO 720 Same 9,463'7" ~2316psi 10,673' 9,025' Length November 20, 2025 2-7/8" 10,673' Perforation Depth MD (ft): See Attached Schematic 4,230psi 120'120' 3,000' Size 120' 3,000' MD Hilcorp Alaska, LLC Proposed Pools: 6.4# / L-80 TVD Burst 9,065' 7,230psi 2,750' Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0391210|ADL0391211 212-094 50-231-20038-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY Tubing Grade: scott.warner@hilcorp.com 907-564-4506 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: m n P s 66 t _ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.11.10 18:07:46 - 09'00' Noel Nocas (4361) 325-690 By Grace Christianson at 9:01 am, Nov 12, 2025 A.Dewhurst 13NOV25 DSR-11/13/25 10-404 BJM 11/13/25JLC 11/13/2025 11/13/25 Well Prognosis Well Name: NFU 22-35 API Number: 50-231-20038-00-00 Current Status: Producing Gas Well Permit to Drill Number: 212-094 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 2624 psi @ 6812 TVD Based on 0.44 psi/ft Max. Potential Surface Pressure: 2316 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.702 psi/ft using 13.5 ppg EMW LOT at the 10-3/4 surf casing shoe Shallowest Allowable Perf TVD: MPSP/(0.702-0.1) = 2316 psi / 0.602 = 3847 TVD (Will not perforate above top of pool @ 4745 TVD) Top of Applicable Gas Pool: 5508 MD/ 4745 TVD Well Status: Online Gas Producer 296 mcfd, 0 bwpd, 46 psi FTP Well Summary North Fork 22-35 is a vertical well that was drilled in 2012. Multiple zones from the T-2 through T-47 were perforated before running tubing and tested post drilling which IPd at ~ 8 mmscfd. A plug was set in 2012 to isolate the T-39 through T-47 and another plug was set above that with cement on top in 2018. Perforations to the T-7A were added through tubing in 2019 and boosted rate back over 1 mmcfd which have been on decline ever since. The purpose of this Sundry is to add additional perforations in the T-1 through T-23. Notes Regarding Wellbore Deviation o Max deviation: 38° @ 5469 MD Min ID o 2.31 at 6524 MD (Baker CMD sliding sleeve x profile) Recent Tags o 6/6/25: SL RIH w/2.25 DD bailer to 8460. RIH with PT gauges for survey. RDMO E-line Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low / 3,00 psi high 3. RIH and perforate T-1 T-23 sands from bottom up: Zone Top MD Btm MD Top TVD Btm TVD Footage T1 ±5,565' ±5,590' ±4,789' ±4,809' ±25' T2A ±5,745' ±5,759' ±4,932' ±4,943' ±14' T3 ±5,834' ±5,840' ±5,003' ±5,008' ±6' T3 ±5,847' ±5,861' ±5,014' ±5,025' ±14' T3A ±5,925' ±5,945' ±5,076' ±5,092' ±20' T3A ±5,947' ±5,972' ±5,093' ±5,113' ±25' T4 ±6,027' ±6,047' ±5,157' ±5,173' ±20' Perforations are not allowed above the uppermost production packer. T1 perfs not permitted. -bjm Well Prognosis T5 ±6,225' ±6,260' ±5,314' ±5,342' ±35' T5 ±6,273' ±6,283' ±5,353' ±5,361' ±10' T6 ±6,298' ±6,310' ±5,373' ±5,382' ±12' T6 ±6,390' ±6,404' ±5,446' ±5,457' ±14' T6A ±6,437' ±6,451' ±5,484' ±5,495' ±14' T23 ±8,012' ±8,022' ±6,812' ±6,822' ±10' a. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation b. Use Gamma/CCL to correlate c. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) d. Pending well production, all perf intervals may not be completed e. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. f. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO 5. If necessary, run cap string to aid with water production if encountered post perforating. Attachments: 1. Current schematic 2. Proposed Schematic Updated by JGO 5/19/25 SCHEMATIC North Fork Unit NFU 22-35 PTD: 212-094 API: 50-231-20038-00-00 PBTD = 10,508 / TVD = 9,368 TD = 10,700 / TVD = 9,488 RKB to GL = 21 JEWELRY DETAIL No. Depth ID OD Item 1 372 2.31 Baker SSSV @ 372 2 2,498 2.44 Pollard Chemical Injection Mandrel 2 7/8 8RD EUE-M 3 5,597 2.347 6.276 Baker FH Ret. Packer 4 6,524 2.31 Baker CMD Sliding Sleeve @ 6,524 X profile Sliding Sleeve is OPEN 12/22/12 (Opens DOWN) 5 9,025 2.441 2 7/8 AD2 Stop, Packoff, and 2 7/8 AA Stop w/ 27 of cement. TOC est @ 8,998 (installed 10/29/18) 6 9,040 2.347 6.276 Baker FH Ret. Packer 7 9,065 2.313 BXN Landing Nipple BX Plug w/ prong (installed 12/12/12) OPEN HOLE / CEMENT DETAIL 13-1/2" Est. TOC @ Surface. 40 bbls spacer, lead - 237 bbl 12 ppg cement. Tail - 44 bbl 14.8 ppg cement. 60 bbls cement to surface. 8-3/4 Est. TOC @ 5,500. 40 bbl 10 ppg spacer followed by 298 bbl 12.7 ppg lead cement and 111 bbl 13.5 ppg tail cement. PERFORATIONS Sand Top MD Btm MD Top TVD Btm TVD Amt Date Comments T-2 5,663 5,681 4,859 4,867 28' 12/16/2012 Open T-2A 5,707 5,714 4,902 4,908 7' 12/16/2012 Open T-7 6,528 6,575 5,556 5,594 47' 12/16/2012 Open T-7A (shot through tbg) 6,620 6,640 5,629 5,645 20' 3/12/2019 Open T-7A (shot through tbg) 6,645 6,658 5,649 5,659 13' 3/12/2019 Open T-11 7,040 7,074 5,965 5,992 34' 12/13/2012 Open T-39 9,159 9,198 7,947 7,986 39' 12/8/2012 Isolated T-40 9,221 9,234 8,009 8,023 13' 12/8/2012 Isolated T-40 9,274 9,285 8,062 8,073 8' 12/8/2012 Isolated T-40 9,287 9,300 8,075 8,088 13' 12/7/2012 Isolated T-42 9,414 9,426 8,202 8,214 12' 12/7/2012 Isolated T-47 9,837 9,858 8,625 8,646 31' 12/7/2012 Isolated CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16 Conductor 84 X-56 Surf 120 10-3/4" Surf Csg 45.5 L-80 9.95 Surf 3000 7" Intermediate Csg 26 N-80 BTC 6.276 Surf 10,673 2-7/8 Production Tubing 6.4 L-80 2.441 Surf 9,065 (Jet Cut) 16 Conductor 7 Csg 13-1/2 hole 1 10-3/4 Csg 8-3/4 hole 3 2 4 5 6 7 Updated by SRW 11-4-25 PROPOSED SCHEMATIC North Fork Unit NFU 22-35 PTD: 212-094 API: 50-231-20038-00-00 PBTD = 10,508 / TVD = 9,368 TD = 10,700 / TVD = 9,488 RKB to GL = 21 JEWELRY DETAIL No. Depth ID OD Item 1 372 2.31 Baker SSSV @ 372 2 2,498 2.44 Pollard Chemical Injection Mandrel 2 7/8 8RD EUE-M 3 5,597 2.347 6.276 Baker FH Ret. Packer 4 6,524 2.31 Baker CMD Sliding Sleeve @ 6,524 X profile Sliding Sleeve is OPEN 12/22/12 (Opens DOWN) 5 9,025 2.441 2 7/8 AD2 Stop, Packoff, and 2 7/8 AA Stop w/ 27 of cement. TOC est 8,998 (installed 10/29/18) 6 9,040 2.347 6.276 Baker FH Ret. Packer 7 9,065 2.313 BXN Landing Nipple BX Plug w/ prong (installed 12/12/12) OPEN HOLE / CEMENT DETAIL 13-1/2" Est. TOC @ Surface. 40 bbls spacer, lead - 237 bbl 12 ppg cement. Tail - 44 bbl 14.8 ppg cement. 60 bbls cement to surface. 8-3/4 Est. TOC @ 5,500. 40 bbl 10 ppg spacer followed by 298 bbl 12.7 ppg lead cement and 111 bbl 13.5 ppg tail cement. PERFORATIONS Sand Top MD Btm MD Top TVD Btm TVD Amt Date Comments T-1 ±5,565' ±5,590' ±4,789' ±4,809' ±25' TBD Proposed T-2 5,663 5,681 4,859 4,867 28' 12/16/2012 Open T-2 5,707 5,714 4,902 4,908 7' 12/16/2012 Open T-2A ±5,745' ±5,759' ±4,932' ±4,943' ±14' TBD Proposed T-3 ±5,834' ±5,840' ±5,003' ±5,008' ±6' TBD Proposed T-3 ±5,847' ±5,861' ±5,014' ±5,025' ±14' TBD Proposed T-3A ±5,925' ±5,945' ±5,076' ±5,092' ±20' TBD Proposed T-3A ±5,947' ±5,972' ±5,093' ±5,113' ±25' TBD Proposed T-4 ±6,027' ±6,047' ±5,157' ±5,173' ±20' TBD Proposed T-5 ±6,225' ±6,260' ±5,314' ±5,342' ±35' TBD Proposed T-5 ±6,273' ±6,283' ±5,353' ±5,361' ±10' TBD Proposed T-6 ±6,298' ±6,310' ±5,373' ±5,382' ±12' TBD Proposed T-6 ±6,390' ±6,404' ±5,446' ±5,457' ±14' TBD Proposed T-6A ±6,437' ±6,451' ±5,484' ±5,495' ±14' TBD Proposed T7 6,528 6,575 5,556 5,594 47' 12/16/2012 Open T-7A (shot through tbg) 6,620 6,640 5,629 5,645 20' 3/12/2019 Open T-7A (shot through tbg) 6,645 6,658 5,649 5,659 13' 3/12/2019 Open T-11 7,040 7,074 5,965 5,992 34' 12/13/2012 Open T-23 ±8,012' ±8,022' ±6,812' ±6,822' ±10' TBD Proposed T-39 9,159 9,198 7,947 7,986 39' 12/8/2012 Isolated T-40 9,221 9,234 8,009 8,023 13' 12/8/2012 Isolated T-40 9,274 9,282 8,062 8,073 8' 12/8/2012 Isolated T-40 9,287 9,300 8,075 8,088 13' 12/7/2012 Isolated T-42 9,414 9,426 8,202 8,214 12' 12/7/2012 Isolated T-47 9,837 9,858 8,625 8,646 31' 12/7/2012 Isolated CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16 Conductor 84 X-56 Surf 120 10-3/4" Surf Csg 45.5 L-80 9.95 Surf 3000 7" Intermediate Csg 26 N-80 BTC 6.276 Surf 10,673 2-7/8 Production Tubing 6.4 L-80 2.441 Surf 9,065 (Jet Cut) 16 Conductor 7 Csg 13-1/2 hole 1 10-3/4 Csg 8-3/4 hole 3 2 4 5 6 7 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS DEC - 5 2019 1. Operations Abandon Plug Perforations ✓ Fracture Stimulate L Pull Tubing L /pA �e�at�o�pc�=s(�t�down Performed: Suspend ❑ Perforate Q Other Stimulate ❑ Alter Casing El Cba1 !PP'm`ree Rrdgram ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Cook Inlet Energy, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Exploratory ❑ Stratigraphic ❑ Service ❑ 212-094 3. Address: 188 W Northern Lights Suite 510 6. API Number: Anchorage, AK 99503 50-231-20038-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 391210, ADL 391211 North Fork Unit 22-35 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A North Fork, Tyonek Gas 11. Present Well Condition Summary: Total Depth measured 10700 feet Plugs measured 9025 feet true vertical 9488 feet Junk measured None feet Effective Depth measured 10508 feet Packer measured 559T& 9040' feet true vertical 9368 feet true vertical 4815' & 7828' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' 120' n/a n/a Surface 3000' 10-3/4" 3000' 2750' 4230 2470 Intermediate Production 10673' 7" 10673' 9463' 7240 5410 Liner Perforation depth Measured depth see attached feet True Vertical depth see attached feet Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.4# L80 9065' MD/7852'TVD Packers and SSSV (type, measured and true vertical depth) 2 Baker FH Pkr 5597'MD/5715'TVD 9040'MD/7828'TVD SSSV@372' MD/TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mof Water -Bbl Casing Pressure Tubing Pressure Prior to well operation:0 592 0 0 159 Subsequent to operation: 0 1051 0 0 184 14. Attachments (required per20 AAC 25.070, 25.071, & 25,283) 15. Well Class after work: Daily Report of Well Operations ❑✓ Exploratory ❑ Development ✓ P ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas Q WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-422, 319-160 Authorized Name: Stephen Ratcliff Stephen Contact Name: pen Ratcliff Authorized Title: VP of Drilling Contact Email: sratcliff@glacieroil.com Authorized Signature: Date: 11 I3I l9 Contact Phone: 907-433-3808 ,/ J7,—(017 Form 10-404 Revised 4/2017 /)z RBDMS�r�DEC 0 5 2019 Submit Original Only NFU 22-35 Daily Operations Summary API: 50-231-20038-00-00 PTD#:212-094 Date Activity 26 October 2018 RU Slickline. RIH w/2.30" GR — unable to pass sliding sleeve at 6524', POH. RIH w/2.29" sharp GR — unable to pass sliding sleeve. RIH w/2.25" bailer — unable to pass. RIH w/wire brush and brush sliding sleeve —improvement noted. RIH w/2.25" bailer— unable to pass. Rebrush sliding sleeve. Reattempt running bailer— unable to pass. RD for night. 27 October 2018 RU Slickline. RIH w/2.18" swage and tag plug at 9060'. RIH w/2.23" GR — unable to pass SS. RIH and brush sliding sleeve. RIH w/13042 shifting tool — unsuccessful shift. Rerun shifting tool multiple times — unable to shift SS closed. RD for night. 28 October 2018 RU Slickline. RIH w/variety of broaches and brushes to clean SS. RIH w/6042 — attempt to close sleeve. RIH w/ 21' of 2.25" bailer — pass thru SS and tag 9060'. Attempt drawdown —failed, confirms sleeve is still open. RD for night. 29 October 2018 RU Slickline. Attempt to shift sleeve — indications that sleeve is closed. Attempt drawdown test — unsuccessful. RIH w/2.29" GR — no trouble. RIH and set 2-7/8" AD2 stop at 9025'. RIH and set packoff. RIH and set 2-7/8" AA Stop on top of packoff. P/U and RIH with dump bailer (2 runs) and dump bail a total of 6.52 gallons of 17ppg cement on top of plug (26.8ft). RD for night. 30 October 2018 RU and attempt drawdown test — unsuccessful. AOGCC Rep Guy Schwartz waived requirement of drawdown test. RU Slickline. RIH w/tandem brushes to 7300' MD. RIH and open sleeve at 6539'. RD Slickline. Turn well over to production. 12 March 2019 RU Eline. RIH w/ 2" GR to 6773'. Fluid level tag at 6565'. RIH w/ 1.75" perforating gun (6 spf, 60 deg phase) and correlate. Shoot 13ft of new perfs from 6645'— 6658' MD. All shots fired. RIH w/ 1.75" perforating gun (6 spf, 60 deg phase) and correlate. Shoot 20ft of new perfs from 6620' — 6640' MD. All shots fired. RD Eline. Turn well over to production. 2 � P a g e NFU 22-35 Current Schematic GLACIER 16" Conductor 120' 10-3/4" 45.5# 3000' MD ID 9.95" L-60 2750ND 13-1/2" Hole Max deviation of 38.16° @ 5469' MD/4713' ND ("S" well) Version: V1.0 March 14, 2019 PTD: 212-094 API: 50-231-20038-00-00 Baker SSSV @ 372' MD, ID=2.31" IPollard Chem. Inj. Mandrel @ 2498' MD 2-7/8" 8RD EUE-M. In - 2 44" 1 71Y1 4# IN 63/4" Hole A w 7" 26# N-80 10673' MD ID 6.276" BTC 9463' TVD PBTD @ 10508' MD/9368' ND TD @ 10700' MD/9488' ND Baker "FH" Ret. Packer @ 5597' MD/4815' ND Perforations Drift ID=2.347" MD ND 5653'-5681' 4859'-4881' Baker CMD Sliding Sleeve @ 6524' MD/5553' ND 5707' - 5714' 4902' -4908' 6528'- 6575' 5556'-5594 6620' -6640' (thru tbg) 5629'- 5645'Sliding Sleeve is OPEN - 12/22/12 (OPENS DOWN 6645'-665s(thru lbg) 5649'-5659' 7040'- 7074' 5965'- 599Z- 992'9159'- 9159'-9198' 7947' - 79 6fi 9221'- 9234' 8009' - 8023' 9274'-9282' 8062'-8070' - 9287'- 9300' 8075- 5088' 9414'-9426' 8202'-8214' `'• 9837'- 9868' 8625- 8656' - 1 26.8ft of 17ppg cement dump bailed on top of plug .6 Z Plug set at 9025' ; �; Baker "FH" Packer @ 9040' MD/7828' ND ,� ? "BXN" Landing Nipple @ 9065' MD - 2.313" BXN Prc .., . _ "BX" Pluq w/prong installed on 12/12/12 T 1 71Y1 4# IN 63/4" Hole A w 7" 26# N-80 10673' MD ID 6.276" BTC 9463' TVD PBTD @ 10508' MD/9368' ND TD @ 10700' MD/9488' ND GLACIER Dec 5h, 2019 Commissioner Jeremy Price Alaska Oil and Gas Conservation Commission 333 West 7"' Ave., Suite 100 Anchorage, Alaska 99501 Re: Report of Sundry Cook Inlet Energy, LLC: North Fork Unit 22-35 Permit to Drill NO: 212-094 API No: 50-231-20038-00-00 Dear Commissioner, DEC - 5 201 AOCCC Cook Inlet Energy (CIE) hereby submits a Report of Sundry Well Operations for NFU 22-35. The work performed was covered under Approved Sundries 318-422 and 319-160 for adding perforations. Due to the success of the added intervals, Glacier has confirmedthat no additional perforations are required at this time. If you have any questions, please contact me at (907) 433-3808. Sincerely, 1 Stephen Ratcliff VP of Drilling Cook Inlet Energy, LLC (a Glacier Oil & Gas Corp. owned company) 10-404 601 W. 51" Avenue, Suite 310, Anchorage, AK 99501 (907) 334-6745 * (907) 334-6735 fax THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Stephen Ratcliff VP of Drilling Cook Inlet Energy, LLC 188 W Northern Lights Blvd., Suite 510 Anchorage, AK 99503 Re: North Ford Field, Tyonek Gas Pool, NFU 22-35 Permit to Drill Number: 212-094 Sundry Number: 319-160 Dear Mr. Ratcliff: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.Oogcc.aloska.gov Enclosed is the approved application for the 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, qVY J ie L. Chmielowski Commissioner DATED this J1 day of April, 2019. RBDMSL✓APR 0 4 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 2n AAr. 7F 2Rn RECEIVED rev l5ion APR_0 2 2019 A6Gc 1 I � 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well p ❑ Operations shutdown ❑ Suspend ❑ Perforate Q • Other Stimulate ❑ Pull Tubing ❑ Change Approved Prograrr _ J Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Strap Well ❑ Alter Casing ❑ Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COOK INLET ENERGY LLC Exploratory ❑ Development Q . Sfratigraphic El Service ❑ 212-094 3. Address:6. API Number: 601 W 5TH AVENUE, SUITE 310, ANCHORAGE, AK 99501 50-231-20038-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 663 & CO 720 North Fork Unit 22-35 Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 391210, ADL 391211 North Fork, Tyonek Gas 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10700 9488 10508 9368 2335 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' 120' N/A N/A Surface 3000' 10-3/4" 3000' 2750' 4230 2470 Intermediate Production 10673 7 10673 9463 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): see attached see attached 2-718" 6.4# L80 BTCM 9065' Packers and SSSV Type: (2) Baker FH Packer, Baker SSSV Packers and SSSV MD (ft) and TVD (ft): Baker FH Packer @ 5597' MD 14815' TVD Baker SSSV @ 372' MDfTVD Baker FH Packer @ 9040' MD / 7828' TVD 12. Attachments: Proposal Summary El Wellbore schematic El 13. Well Class after proposed work: Detailed Operations Program ❑� BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 4/11/2019 Operations: OIL WINJ ❑ E]WDSPL E] Suspended ElCommencing GAS 0 • WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date:,— Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: VP of Drilling Contact Email: srafcliff@glacieroil.com Contact Phone: 907433-3808 Authorized Signature: Date: 41 2 1q COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑\%/-' Other: pp ��npS�hEu/ppR 0 4 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Rp®,Y, Spacing Exception Required? Yes ❑ No Yf Subsequent Form Required: 0., ly APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: � 1' V `- r! 0 R 1,01 1 Submit Form and Form 10-443 Revised 412017 n Approved ppl i llsa YYYaaallliiilll►►►fdrdd 2 MMM6nMSSS���1RRRbb)m the date Of approval. ttach3m7e�nts inJ/DuplicateZ GLACIER April 211, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Application Cook Inlet Energy, LLC, a Glacier Oil and Gas Company (GLA): North Fork Unit 22-35 NFU 22-35 Permit to Drill: 212-094 Application for Sundry: 318-422 API No.: 50-231-20038-00-00 Dear Commissioner, Glacier Oil & Gas, on behalf of Cook Inlet Energy, hereby submits a Sundry Request to change the approved program for Sundry 318-422 by adding an additional set of perforations. If you have any questions, please contact me at (907) 433-3808. Sincerely, Stephen Ratcliff VP of Drilling Cook Inlet Energy, LLC (a Glacier Oil & Gas wholly owned company) 188 W. Northern Lights Blvd, STE 510 Anchorage, AK 99503 1 GLACIER WELL NAME — NFU 22-35 Requirements of 20 AAC 25.005(f) Well Summary Current Status: NFU 22-35 is currently producing. Existing Perforations: Scope of Work: • Rig up Eline. • Perforate selected intervals. • Rig down Eline. • Turn well over to production. General Well Information: Reservoir Pressure / TVD: MASP: Wellhead Type/Pressure Rating: BOP Configuration: Well Type: Estimated Start Date: 2 2,594 psi @ 7250' MD / 5992' TVD (0.433 psi/ft) 2,335 psi Eline Lubricator N/A Gas Producer 4/11/2019 MID _r_ -_ - - TVD I _1 . . . . .. ...... ... 5653'– 5681' 4859 –4881 1 Open 5767 – 5714' 4902'– 4908' Open 6528'– 6575'. 5556'– 5594' Open .. .. .. .. .. .. 7040 ' – 7074' 5965'– 5992' Open 9159'– 9198' 7947'– 7986' Below PX Plug L-----9.221'– .. ........ 9234' 8009'– ............ I I--.--- 8023' — Below PX Plug i L 9274'– 9282' .. . ........... ... 8062'– . . ... 8070' .----- ------ Below PX Plug 9287'– 9300' 8075 –8088 Below PX Plug 9414' – 9426 8202'– 8214' Below PX Plug j 9837'– 9868' .......... j 8625'– 8656' Below PX Plug Scope of Work: • Rig up Eline. • Perforate selected intervals. • Rig down Eline. • Turn well over to production. General Well Information: Reservoir Pressure / TVD: MASP: Wellhead Type/Pressure Rating: BOP Configuration: Well Type: Estimated Start Date: 2 2,594 psi @ 7250' MD / 5992' TVD (0.433 psi/ft) 2,335 psi Eline Lubricator N/A Gas Producer 4/11/2019 GLACIER Program 1. Rig up Eline. 2. RIH with 2", 4spf, 60 deg phase perf guns. 3. Perforate the following intervals: J a. Monitor and record surface pressure in 5 -minute intervals for 30 minutes after each perf run. 4. RD Eline. 5. Be prepared to utilize Slickline and swab with 2" swab cups, if necessary. 6. Turn well over to production through tubing. w: K lb - `tai 3 Top, MD Bottom, MD Footage Top, TVD Bottom, TVD 5720' 5738' 18' 4912' 4926' 5744' 5759' 15' 4931' 4943' 5762' 5776' 14' 4945' 4957' 5835' 5865' 30' 5004' 5028' 5920' 5924' 4' 5071' 5075' 5928' 5990' 62' 5078' 1 5127' New 6028' 6040' 12' 5158' 5167' 6216' 6226' 10' 5307' 5315' New 6226' 6242' 16' 5315' 5328' 6242' 6248' 6' 5328' 5332' New 6248' 6260' 12' 5332' 5342' 6270' 6290' 20' 5350' 5366' 6300' 6310' 10' 5374' 5382' 6385' 6405' 20' 5442' 5458' 6592' 6602' 10' 5607' 5615' 3/12/19 6620' 6640' 20' 5629' 5645' 3/12/19 1 6645' 6658' 13' 5649' 5659' 7220' 7250' 30' 6111' 6135' Total = 310' a. Monitor and record surface pressure in 5 -minute intervals for 30 minutes after each perf run. 4. RD Eline. 5. Be prepared to utilize Slickline and swab with 2" swab cups, if necessary. 6. Turn well over to production through tubing. w: K lb - `tai 3 NFU 22-35 Proposed Schematic GLACIER 16" Conductor 120' 10-3/4" 45.5# 3000'1VID to 9.95" L-80 2750' TVD 13-112" Hole Max deviation of 58.16• @ 5469' MD/4713' TVD ("S" well) Perforations 4945'- 4957' 5004'- 5028' 5920'- 5924' 592V - 5990' 5243'- 6260' 5332' - 5342' 6290' 5350'- 5366' 6300' - 6310 5374'- 5382' 6385'- 6406' 5442'- 5458' 9159'- 9198' 7947'- 7986' 9221'- 9234' 8 009' - 8023' 92M-9282 ' -8062'- 8070' 9287'- 9300' 8075'- 8088' 9414' - 9426' 8202'- 8214' 8.314" Hole 7" 126# N-8010673' MD • �� y±.=` 7L?'.. -i.:: ID 6.276" BTC 8463' TVD PBTD @ 10508' MD/9368' TVD TD @ 10700' MD/9488' TVD Baker"FI Drift ID = Version: V1.1 April 2, 201 PTD: 212-09 API: 50-231-20038-00-C Pollard Chem. Inj. Mandrel @ 2498' MD 2-7/8" BIRD EUE-M. ID - 2.44" Landing Nipple 9 9065' MD - 2.313" BXN Profile 'lug w/Prong installed on 12/12/12 6.4# L80 Tubing end (ol 9.065' (Jet cut) 10,000,000 1,000,000 r Y C c0 C CL 100,000 10,000 1,000 100 10 COOK INLET ENERGY, LLC, NORTH FORK UNIT 22-35 (212-094) NORTH FORK, TYONEK GAS Monthly Production Rates Cum. Prod Oil 1Cum.11 1 .I,II 1 Jan -2015 —� Produced Gas (MCFM) • GOR — Produced Water (aOPM) —a— Produced Oil (BOPM) 10,000,000 W a 1,000,000 0 O M O 100,000 m O 3 10,000 S 0 1 Jan -2020 SPREADSH EET_Prod-I nject_Curves_W ell_Gas_V120_2120940_NFU_22-35_20190402.xlsx 4/2/2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AA(. 2F ?Af) RECEIVE® APR 01 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑Q • Other Stimulate ❑ Pull Tubing ❑ Change Approved Progra � Plug for Retlrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COOK INLET ENERGY LLC Exploratory ❑ Development Q • Stratigraphic ❑ Service ❑ 212-094 3. Address: 6. API Number: 601 W 5TH AVENUE, SUITE 310, ANCHORAGE, AK 99501 50-231-/38-00-00 7. If perforating: 8. Well Name and/NumbeWhat Regulation or Conservation Order governs well spacing in this pool? CO 663 & CO 720 NUnit 22-35 Will planned perforations require a spacing exception? Yes ❑ No ❑Q 9. Property Designation (Lease Number): 10. Field/Pool(s): • ADL 391210, ADL 391211 North Fork, Tyone as 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 10700 • 9488 10508 9368 2335 None None Casing Length Size MD ND Burst Collapse Structural Conductor 120' 16" 120'0' WA N/A Surface 3000' 10-3/4" 3000' 2750' 4230 2470 Intermediate Production 10673 7 10673 9463 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): see attached see attached 2-7/8" 6.4# L80 BTCM 19065, Packers and SSSV Type: (2) Baker FH Packer, Baker SSSV Pac M rs and SSSV D ft and () ND MY ft ) Baker FH Packer @ 5597' MD / 4815' ND B er SSSV @ 372' MDTI VD Baker FH Packer @ 9040' MD / 7828' ND 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑� BOP Sketch ❑ Exploratory p ry ❑ Stratigraphic ❑ Development ❑� ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 10/14/2018 Commencing Operations: _ OIL ❑ WINJ E]WDSPL ❑ Suspended El16. GAS WAG ❑ GSTOR ❑ SPLUG ❑ Verbal Approval: Date— Commission Representative: ZZ GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and th dure approved herein will not be deviated from without prior written approv Authorized Name: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: VP of Drilling Contact Email: sratcliff@glacieroil.com - Contact Phone: 907433-3808 Authorized Signature: Date: 1 - r" 1, - 2619 COMMISSION USE ONLY Conditions of approval: Notify Commission s that a representative may witness Sundry Number: i7 ` h ' i U D Plug Integrity ❑ BOP at ❑ Mechanical Integrity Test ❑ Location Clearance 4 Other:'-, .14 Post Initial Injection MIT Req'd? Yes ❑ F-1 No - Spacing Exception Requirtsd? Yes ❑ No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER A THE COMMISSION Date: Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate .� 'v/ 7'/P GLACIER April 15t, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Application Cook Inlet Energy, LLC, a Glacier Oil and Gas Company (GLA): North Fork Unit 22-35 NFU 22-35 Permit to Drill: 212-094 Application for Sundry: 318-422 API No.: 50-231-20038-00-00 Dear Commissioner, Glacier Oil & Gas, on behalf of Cook Inlet Energy, hereby submits a Sundry Request to change the approved program for Sundry 318-422 by adding an additional set of perforations. If you have any questions, please contact me at (907) 433-3808. Sincerely, Stephen Ratcliff VP of Drilling Cook Inlet Energy, LLC (a Glacier Oil & Gas wholly owned company) 188 W. Northern Lights Blvd, STE 510 Anchorage, AK 99503 11 GLACIER WELL NAME — NFU 22-35 Requirements of 20 AAC 25.005(f) Well Summary Current Status: NFU 22-35 is currently producing. Existing Perforations: MD TVD Status 5653' 5681 ...........................................; 4859'-4881' ----- ----- -.,. Open 5707'— 5714' 4902' ....-...-.- — 4908' ...-.-. Open ...... 6528'— 6575' 5556'— 5594' ........ Open 7040'— 7074' 5965'— 5992' Open 9159'— 9198 7947'— 7986 Below PX f 9221'— 9234' 8009' — 8023' Below PX f 9274'— 9282' 1 --.-...-. 8062'— ........ 8070' Below PX f 9287'— 9300' -- 8075'— .......111, 1111.1111 8088' Below PX f 9414'-9426 8202-8214' Below PXI 9837'-9868' ........-.. 8625'— ........ ... -.,. 8656' Below PX f Scope of Work: • Rig up Eline. • Perforate selected intervals. • Rig down Eline. • Turn well over to production. General Well Information: Reservoir Pressure / TVD MASP: Wellhead Type/Pressure Rating: BOP Configuration: Well Type: Estimated Start Date: 2 2,594 psi @ 7250' MD / 5992' TVD (0.433 psi/ft) 2,335 psi Eline Lubricator N/A Gas Producer 4/11/2019 GLACIER Program 1. Rig up Eline. 2. RIH with 2", 4spf, 60 deg phase pert guns. 3. Perf rake the following intervals: a. Monitor and record surface pressure in 5 -minute intervals for 30 minutes after each pert run. 4. RD Eline. 5. Be prepared to utilize Slickline and swab with 2" swab cups, if necessary. 6. Turn well over to production through tubing. Top, MD Bottom, MD Footage Top, TVD Bottom, TVD 5720' 5738' 18' 4912' 4926' 5744' 5759' 15' 4931' 4943' 5762' 5776' 14' 4945' 4957' 5835' 5865' 30' 5004' 5028' 5920' 5924' 4' 5071' 5075' 5928' 5990' 62' 5078' 5127' / New 6028' 6040' 12' 5158' 5167' 6216' 6226' 10' 5307' 5315' New 6226' 6242' 16' 5315' 5328' 6242' 6248' 6' 5328' 5332' 6270' 6290' 20' 5350' 5366' 6300' 6310' 10' 5374' 5382' 6385' 6405' 20' 5442' 5458' 6592' 6602' 10' 5607' 5615' 3/12/19 6620' 6640' 20' 5629' 5645' 3/12/19 6645' 6658' 13' 5649' 5659' 7220' 7250' 30' 6111' 6135' Total = 310' a. Monitor and record surface pressure in 5 -minute intervals for 30 minutes after each pert run. 4. RD Eline. 5. Be prepared to utilize Slickline and swab with 2" swab cups, if necessary. 6. Turn well over to production through tubing. GLACIER 16" Conductor 120' 10-3/4" 45.6# 3000'MD 10 9.95- L-80 2750' ND 13.1/2" Hole Max deviation of 58.16- @ 5469' MD/4713' ND ("S" well) Perforations MD ND 5653' - 5681' 4859'-4881' 5707' - 5714' 4902'- 4908' 5720'- 5759' 4912'- 4926' 6028-6040' / 5158'-5167' 6216'- 6226' 5307'- 5315' 6226'- 6242' w 5315'- 5328' 6242'- 6248' 5328'- 5332' 6270'- 6290' 5350'- 5366' 300'- 6310' 5374'- 5382' A3A5'-AenS' reel' - A .' 6526 - 6575' 5556'- 5594' 6592'- 6602' - 560T- 5615' 6620'- 6640' 5629'- 5645' 6645'-6658' 5649'-5659' 7040'- 7074' 5965'- 5992' 7220'-7250' 6111'-6135' 91591- 9198' 7947'- 7986' NFU 22-35 Proposed Schematic Version: V1.0 April 1,V21019 PTD: 212-094 API: 50-231-20038-00-00 Baker SSSV @ 372' MID ID=2.31" Chem. Ini. Mandrel @ Baker "FH" Ret. Packer5597' MD/4815' ND Drift ID = 2.347" rsIF P1IIP, 26.8ft of 17.0 ppg cement dump bailed on top of plug Baker "FH" Packer @ 9040' MD/7828' ND a "BX N" Landing Nipple @ 9065' MD - 2.313" BXN Pro' i+. .BX" PIu'I w/Drono installed on 12/12/12 -9868' I 8625'- 8656' 8.314" Hole 7" 26# N-80 10673' MID 11136.276" IBTC 9463' TVD PBTD @ 10508' MD/9368' ND TD @ 10700' MD/9488' ND THE STATE 01ALASKA GOVERNOR BILL WALKER Stephen Ratcliff VP of Drilling Cook Inlet Energy, LLC 601 W 5`" Ave., Suite 310 Anchorage, AK 99501 Re: North Fork Field, Tyonek Gas Pool, NFU 22-35 Permit to Drill Number: 212-094 Sundry Number: 318-422 Dear Mr. Ratcliff: Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Enclosed is the approved application for the 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. DATED this i.1_ day of October, 2018. Sincerely, W2:Jl� Hollis S. French Chair, Commissioner S�Na®� V1%O D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 SEP 2 0 2018 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑� • Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑� • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COOK INLET ENERGY LLC Exploratory ❑ Development Q • Stratigraphic ❑ Service ❑ 212-094 3. Address: 6. API Number: 601 W 5TH AVENUE, SUITE 310, ANCHORAGE, AK 99501 50-231-20038-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 663 72 North Fork Unit 22-35 - Will planned perforations require a spacing exception? Yes ❑ No[J] 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 391210, ADL 391211 1 North Fork, Unde y' f<• �o 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): 10700 • 9488 10508 9368 2335 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 16" 120' 120' NIA N/A Surface 3000' 10-3/4" 3000' 2750' 4230 2470 Intermediate Production 10673 7 10673 9463 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): see attached see attached 2-7/8" 6.4# L80 BTCM 9065' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker FH Packer @ 5597' MD / 4815' TVD (2) Baker FH Packer, Baker SSSV Baker SSSV @ 372' MD/TVD Baker FH Packer @ 9040' MD / 7828' TVD 12. Attachments: Proposal Summary L:�J Wellbore schematic 141 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: 10/14/2018 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: 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: Stephen Ratcliff Contact Name: Stephen Ratcliff Authorized Title: VP of Drilling Contact Email: sratcliff@ lacieroil.com <-(� ( Contact Phone: 907-433-3808 Authorized Signature: �3x-•-- t ` Date: 9/19/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I Z Yu L/ Plug Integrity ❑ Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ ^ LBOP Other: aF '.4- /� ap/Tt'v�<-17 �t-z-✓ Zv f}A-CZ.S.IIL L:) r�FnCL..n..a�wf Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ] No Subsequent Form Required: 18- Lq0LI pQDM0�1 1 l/ APPROVED BY (� d 46G Approved by: COMMISSIONER THE COMMISSION Dale: ,� 7^ Fdl'd dr f � i f1D r1�a r/�$s ran Fo and v r,�/�\�jorm 10-403 Revised 412017 9Approved application is t f 2 h to of approval. Attachments in Duplicate I / GLACIER 09/20/2018 Mr. Hollis French, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Application Cook Inlet Energy, LLC, a Glacier Oil and Gas Company (GLA): North Fork Unit #22-35 Permit to Drill: 212-094 API No.: 50-231-20038-00-00 Dear Mr. French, Glacier Oil & Gas, on behalf of Cook Inlet Energy, hereby submits a Sundry Request to abandon existing lower perforations and add new perforations to NFU 22-35. If you have any questions, please contact me at (907) 433-3808. Sincerely, Stephen Ratcliff VP of Drilling Glacier Oil & Gas Corp. 601 W. 5th Avenue, Suite 310 Anchorage, AK 99501 sratcliff@glacieroil.com O: 907.433.3808 GLACIER WELL NAME — NFU 22-35 Requirements of 20 AAC 25.005(f) Well Summary Current Status: NFU 22-35 is currently producing. Existing Perforations: �— MD -- is TVD - Status 5653' — 5681' 4859'— 4881' Open 5707'— 5714' 4902_'_— 4908' Open 6528'— 6575' 5556'— 5594' Open 7040'— 7074' 5965'— 5992' Open 9159'— 9198' 7947'— 7986' Below PX Plug 9221'— 9234' 8009'— 8023' Below PX Plug 9274'— 9282' 8062'— 8070' Below PX Plug 9287'— 9300' 8075'— 8088' Below PX Plug l 94 9426 8202'— 8214' Below PX Plug 9837'— 9868' 8625'— 8656' i Below PX Plug Scope of Work: • Rig up Slickline. • Close sliding sleeve. • Dump bail cement. • Open sliding sleeve? • Perforate selected intervals. • Rig down Eline. • Turn well over to production. General Well Information: Reservoir Pressure / TVD: MASP: Wellhead Type/Pressure Rating: BOP Configuration: Well Type: Estimated Start Date: 2 2,594 psi @ 7250' MD / 5992' TVD (0.433 psi/ft) 2,335 psi Eline Lubricator N/A Gas Producer 10/15/18 GLACIER Program 1. Rig up Slickline and Lubricator. Test lubricator to 3000 psi. 2. RIH with 2-3/8" GR to confirm accessibility (access to plug at 9065' MD). a. Tag plug to confirm set depth. b. Document fluid level. c. RIH with brush/scraper if needed. 3. Close sliding sleeve at 6524' MD/5553'aaTVD. 4. Pressure test tubing to 2500 psi for,J5rhf s and chart same. 5. RIH and dump bail 25' of cement on top of plug. a. Regulation 20 AAC 25.112 (1)(E) 6. Rig down Slickline. 7. Rig up Eline. 8. RIH with 2-3/8", 5spf, 60 deg phase perfguns. 9. Perforate the following intervals: Top, MD Bottom, MD Footage Top, TVD Bottom, TVD 5720' 5738' id, 4912' 4926' 5744' 5759' S0' j5 4931' 4943' 5762' 5776' ' 14 4945' 4957' 5835' 5865' 3D 5004' 5028' 5920' 5924' 5071' 5075' 5928' 1 5990' 62' 5078' 1 5127' 6216' 6226' 10' 5154' 5162' 6242' 6248' 6' 5193' 5207' 6270' 6290' 20' 5259' 5307' 6300' 6310' 10' 5331' 5355' 6385' 6405' 20' 5442' 5458' 6592' 6602' 10' 5607' 5615' 6620' 6640' 20' 5629' 5645' 6645' 6658' 13' 5649' 5659' 7220' 1 7250' 30' 6111' 6135' Total= a. Monitor and record surface pressure in 5 -minute intervals for 30 minutes after each pert run. 10. RD Eline. 11. Be prepared to utilize Slickline and swab with 2" swab cups, if necessary. 12. Turn well over to production through tubing. 3 GLACIER Variance Request: A variance is requested for 20 AAC 25.112(c)(1)(D) & (E). Glacier requests to leave the "PX" plug in place at 9065' MD and dump bail at least 25' of cement on top of it to abandon the lower perfs (9159'— 9868' MD). The plug would be 94ft above the top pert, exceeding the requirement of no more than 50ft stipulated by regulation 20 AAC 25.112(c)(1)(E). This method is preferred over downsqueezing to meet 20 AAC 25.112(c)(1)(D) due to the risk of having cement left in the tubing preventing the addition of the upper planned perforations. GLACIER 16" Conductor @ 120' 10-314" 45.5# 3000- MID ID 9.95" L-80 2750'TVD 13-112" Hole Max deviation 0158.16' @ 5469' MD14713' TVD ("S" well) I Perforations NFU 22-35 Current Schematic 9274'-9282; 8062' - 8070' 9287'- 9300 8075' - 8088' 9414' -2 9426' 8202' - 8214' 9837' - 9868' 8625'- 8656' V Ik "I 8-3/4" Hole 7" 26# N-80 10673' MD 11136.276" IBTC 9463' TVD � c PBTD @ 10508' MD/9368' TVD TD @ 10700' MD/9488' TVD Version: CURF January 8, PTD: 21 API: 50-231-20038 Baker SSSV @ 372' MD Chem. Inj. Mandrel @ 2498' MD IBaker "FH" Packer 0 5597' MD/4815' TVD NFU 22-35 Proposed Schematic Version: V1.0 V/ January 8, 201 PTD: 212 -OE �(� 1 - II 11 1 V1� API: 50-231-20038-00-C GLACIER 16" Conductor 120' 10-3/4- 45.5# 3000' MD ID 9.95" L-80 2750'TVD 13-112" Hole Max deviation of 58.16' @ 5469' MD/4713' ND "S" well Perforations MD TVD 5653'- 5681' 4859'- 4881' 5107'-5714' 4902'-4908' 5720' - 5759' 4912'- 4926' 5744' - 5759' 4931'- 4943' 5762 - 5776' 4945'- 4957' "' - 5865' 5004'- 5028' :r-5924' 5071'-5075' 5928' - 5990' 5078' - 5127' 6216'- 6226' 6242'-6248' 5154'- 5162' 5193'-5207' 6270' -6290' 5259'. 5307 6300'-6310' 5331'-5355' 6385' -6406' 5442'. 5458' 6528'- 6575' 5556'- 5594' 6592' -6602 5607'- 5615' 6620' -6640' 5629'- 5645' 6645'-6658' 5649'-5659' 7040' . 7074' 5M'- 5992' 7220'-7250 6111' - 6135' 9159' - 9198' 7947'- 7986' 9221'- 9234' 80D9'- 8023' 9274'. 9282' 8062'- 8070' 9287' - 9300' 8075'- 8088' 9414'-9426' 8202'- 8214' 9837 - 9868' 8625'- 8656' 8.314" Hole 7" 26# N-80 10673' MD ID 6.276" IBTC 9463' TVD m PBTD @ 10508' MD/9368' TVD TD @ 10700' MD/9488' TVD Baker SSSV @ 372' MD [e7 25ft of cement dump bailed on top of PX plug O v 9 I o o N 9 co • . >, co O + t- 0. 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W E = Q w J 0 O m p W Q m C cg 0 0 0 0 0 0 0 a 0 0 0 0 0 0 0 0 p a) ¢ a. ar in `� J O F J W J J J J Ce J J J J J J J J W `� o I I1 .1, O 1 0 co9 (-4)q cz r.: N Z cl >- >- } w a- 0 m N _ bD L >, a • 40 N Of Q O Z L• L o F. U a 10 a m m o U 0 J �. C• ? -J 1 Q Q - u) Z Z di Ce Z U) N �JJ G Ce Y y w m 0 6_- 0 O O 3 two co UJ o0 ii 0 re N I Il E w N (n N m y N a) m co a V C9 -- E E z8 ,- vi U) Q o 0 CO -I 0 0 laa J o'al2 o E S O ') M U U Om CO o O N ti E ® w N U 7 o M 0 11 0 J I } E N Q` to 0 ECd baa P. I V N O E H N ,- 8O Z w • C N CO C Z' c co Y 0 CD co • e V/ l II !: 1 co 0 CL 1 IP QO O a3 I ZL0 co mH g •- a Q o E .E q Z o 2 y I co Z m N N • O Q O O Z N N CO CO In O N o ol1 0 G h. er ' O W >- CO N ~ W E a O m w W O o N_ d N c re 0 c N n = 4? d F. 0 N ` W as OC o O Q 0 o Q 0 co c - o a d co v m a� E O a 0 a`�i w E 0 o 0 LL E 2 o E m E E a 2 ? 0 a 0 0 U a 0 0 Guhl, Meredith D (DOA) From: Stephen Hennigan [shennigan@peiinc.com] Sent: Tuesday, March 18, 2014 3:32 AM To: Guhl, Meredith D (DOA) Subject: RE: Clarification: TD of North Fork Unit 22-35 Attachments: Rev 407 22-35 sent to AOGCC DOC112713_112713-146.pdf You are correct-the 10-407 was wrong. Attached is what we sent Mr. Davies in November. Hopefully this corrects the . rias & Biqa 242.1► 0,6 el # Project Manager/Engineer PETROLEUM ENGINEERS, INC. 500 Dover Boulevard, Suite 310 I Lafayette, LA 70503 Office: 337-984-2603 Mobile: 337-849-5345 From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Monday, March 17, 2014 3:02 PM To: Stephen Hennigan Cc: Davies, Stephen F (DOA) Subject: Clarification: TD of North Fork Unit 22-35 Dear Mr. Hennigan: In reviewing the form 10-407, "Well Completion Report" submitted for North Fork Unit 22-35, PTD 212-094,API 50-231- 20038-00-00, completed on 12/8/2012, a discrepancy was noted between the report and the a-logs/daily drilling summary.The report lists Total Depth in box 10 of 11,017 ft.The daily drilling summary on 11/29/12 notes"DRLG 88'TO TD @ 10,700" and the hole is only logged to 10,650'. Please confirm the total depth of NFU 22-35 so that I may update the well completion report as needed. Sincerely, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907) 793-1235 1 ARECEIVED ARMSTRONG DEC 0 22013 Cook In/el. LLC AOGCC November 27, 2013 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RE: 10-407 for Sundry 312-458 Armstrong Cook Inlet, LLC NFU#22-35(PTD No. 212-094) Dear Ms. Foerster, At the request of Mr. Stephen Davies, Armstrong Cook Inlet, LLC hereby submits a REVISED 10-407 for completing and testing the subject well. The updates he has requested are very valid. If you have any questions or require additional information, please contact me at(303)623-1821 or Stephen Hennigan at(337)849-5345. Sincerely, )6- -Edward Teng Vice President-Engineering Armstrong Cook Inlet, LLC Enclosures Cc: Stephen Hennigan— Petroleum Engineers for Armstrong Cook Inlet, LLC 1421 Blake Street, Denver, CO 80202 (303)-623-1821 Ph (303)-623-3019 Fax STATE OF ALASKA • AL A OIL AND GAS CONSERVATION COMI .ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil❑ Gas ❑., SPLUG ❑ Other ❑ Abandoned ❑ Suspended lb.Well Class: 20AAC 25 105 20AAC 25 110 Development 2 Exploratory ❑ GINJ ❑ WINJ❑ WAG ❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or2.Permit to Drill Number: Armstrong Cook Inlet,LLC Aband.: 1220 '�2 //4Z 212 094 3.Address: 6.Date Spudded: 13. Number: 1421 Blake Street,Denver,Colorado 80202 1](212912// 3.. '/Z -D 1Y' Al10-231-20038-00-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: '" 14.Well Name atom;, Surface: 588'FSL X 1571'FEL 26 4S 14W .11/23/2644-/f 21./2- NFU X22-351 s EIVED Top of Productive Horizon: 8.KB(ft above MSL): 6,79 15.Field/Pool(s) 1411'FNL X 2230'FWL 35 4S 14W GL(ft above MSL): ) ' 66Ze, 1 ��1)E L ��l Total Depth: 9.Plug Back Depth(MD+ND): Nprth Fork Unit �`` 2601'FNL X 1372'FWL 35 4S 14W 10,580 9368 //Ind Z�.L.d ( • �./� 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): , 16.Property Designation: Surface: x- 199,838 y-2,121,132 Zone- 4 10700 9'613 9/71Set)} [�) ADL 3 S 91210/391211 TPI: x- 1,983,618 y-2,119,146 Zone- 4 11.SSSV Depth(MD+TVD):, Land Use Permit: Total Depth: x- 197,440 y-2,117,875 Zone- 4 372'MD 372'TVD 18.Directional Survey: Yes Q No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) NA (ft MSL) NA 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: GR,RES,DEN,NEUT,DTCO,DTS 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND ' AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 " 84 X56 0' 120' 0' 120' DRIVEN NA 10 3/4" 45.5 L80 0' 3000' 0' 2750' 13 1/2" 761sx lead @12 ppg and 200 sx tail @14.8 ppg 7 " 26 L80 0' 10673' 0' 9463' 8 3/4" 582 sx lead©12.7 ppg and 344 sx tail @ 13.5 ppg 24.Open to production or injection? Yes U No LJ If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) See attached Well Bore Diagram-Upper Intervals- Shot with wireline guns 2 7/8" 9040' 5597'MD 4815'ND ©6 spf, .28"Entrance Holes. Lower Intervals behind packer and"X"plug set 9040'MD 7828'ND in profile at 9065'MD. 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED NA 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio. 12/19/2012 8.0 Test Period NA 2.162 M 0 12,24,36,48/64 NA Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 720 24-Hour Rate . 0 8.4 M 0 0 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No❑., Sidewall Cores Acquired? Yes ❑ No Q 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. Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only 29 GEOLOGIC MARKERS (List all formations and markers encountered): 30 FORMATION TESTS NAME MD TVD Well tested? Yes No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Sterling Surface and submit detailed test information per 20 AAC 25.071. Beluga 1392 1380 Tyonek 5497 4736 Tyonek 6000 SS 7039 5964 Tyonek 8500 SS 9783 8570 see attached test summary with choke sizes,well head pressure,rates and cumulative production. Formation at total depth: Tyonek 31 List of Attachments. well test,WBS,surveys,summary rpt 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Shennlgan(Q7pellnc.com Printed Na i,- Edward Teng Title: Vice President-Engineering rorA - Sig-=�R� S %�i __ Phone: (303)6231821 Date: 11/19/2013 NSTRUCTIONS General: This form is designed for submi'ing a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells. Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation. Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25 071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Ns Permit#: 212 094 NFU #22-35 API#: 231-20038-00-00 • Prop. Des:ADL-391210/391211 R 588' FSL, 1571' FEL KB elevation: 679' (21'AGL) S26 T4S R14W S.M. Latitude: 59*47'46.3626"N Longitude: 151`37'45.2584"W Spud: 11-2-2012 Armstrong Cook Inlet, LLC TD: 11-28-2012 I 1,,..,t ' Rig Released: 12-23-2012 , Structural Pipe 16" X-56 84 ppf { Top Bottom MD Surf 120' TVD Surf 120' Baker SSSV set @ 372' Surface Casing 10-3/4" L-80 45.5ppf MD. Pollard Chemical Inj. Top Bottom Nipple set @ 2498' MD. MD 0' 3,000' • 2 7/8"8RD EUE-M TVD 0' 2,750' Make up stabin tool to 5"DP and RIH;space out ,- Production Casing and land in FC-Cir csg Circulate hole staging • 7" L-80 26 ppf pumps up to 7 BPM while finish rigging up BJ lis Top Bottom and adjusting mud volume and mix water ' MD 0' 10,750' temperature Pump 37 BBL SAPP spacer wing I 1 ' TVD 0' 9,800' Pump 5 BBIs water;pressure test Cmt lines to • 3000 PSI Pump 236 BBIs of lead cement when spacer started showing at shakers;Switch to 47BBLs of tail slurry and displace w/5 BBL5 water and 47 BBL5 of mud, 761Sks Type 1 Cement;134%water(Percentages are BWOC) • Tubing 10%BA-90;.005 lbs/sk StaticFree;2% , i • 2 7/8" L-80 6.4 ppf CaCI;.5%EC-1;.2%CD-32;.1%ASA-301; Top Bottom 1GAL/100 SK FP-6L;2%Na Metasilicate @ 12.0 ppg 2.62 yld; 200 Sks Type 1 Cmt;.005% MD 0' 5600' StaticFree;2%CaCI;1 Gal/100 SksFP-6L;56.3% LW TVD 0' 4817' Water @14.8 ppg yld 1.34. tIf RD Cmt lines;Pull 1 Stand;RU returns to cellar; Pump Wiper Dart&55 BBIs mud POH laying down DP; (Cement to Surface totaled 60 BBLs) I Baker FH Packers set at .r 5597'MD 4815'TVD 9040'MD 7828'TVD - , Baker Sliding Sleeve set at 14 _ 6524'MD 5553'TVD it Test lines to 4000 psi;Pump 40 BBI Seal • Bond spacer 10 ppg;298 BBIs lead cement weighing 12.7 ppg yld 2.16;111 BBLs tail - l cement weighing 13.5 ppg,yld 1.82. dropped plug;pump 404 BBLs of water Perforations tillil bumping plug and holding for 5 minutes at 3000 psi. Bleed back 4 bbls and check for , Measured Depth True Vertical Depth floats to hold. Start rigging down Upper Interval cementers. CIP at 12:40 PM.Lead cement: • 5653-5681' 4859-4881' 582 sx Class G cmt;.4%bwoc R-3;10% 5707-5714' 4902-4908' bwoc BA-90;.05 tt/sk Static free;2.5%bwoc .__ 6528-6575' 5556-5594' BA_56;.5%bwoc EC-1;.1%bwoc ASA-301; 7040-70 4' 5965-5992' 1 gal/100 sx FP-6L;.5%bwoc Na - Metasillicate;104.1%fresh water Tail - Lower Interval Cement:344 sx Class G cmt;.4%bwoc R-3; 1I `.1 9159-9198' 7947-7986' 10%bwoc BA-90;.05%bwoc Static Free = .. _ 9221-9234' 8009-8023' 2.5%bwoc BA-56;.5%bwocEC-1;.1%bwoc TiI 9274-9282' 8062-8070' ASA-301;1 gal/100 sx FP-6L;.5%bwoc Na a _ 9287-9300' 8075-8088' Metasillicate;81.9%fresh water Pressure 9414-9426' 8202-8214' build up to 2100 psi prior to bumping plug. T■ -� 9837-9868' 8625-8656' (Note:Had full returns thru entire job-Got - @ 15 bbls of spacer back) - TDPBTD-Trilli 10700 9468 10700'MD 10,580'MD 9468'TVD 9,368'TVD I Well Name&Number: North Fork Unit#22-35 Lease: Kenai Loop County or Parish: Kenai Penisula Borough State: Alaska Country: USA Perforations(MD): Perf(TVD): Angle @KOP and Depth: Angle @ Perfs _ KOP TVD: - Date Completed: RKB: 21' Prepared By: Craig Rang/Stephen Hennigan Last Revision Date: November 18,2013 Guhl, Meredith D (DOA) 2( Z_( q From: Guhl, Meredith D (DOA) Sent: Monday, March 17, 2014 12:02 PM To: 'Stephen Hennigan' Cc: Davies, Stephen F (DOA) Subject: Clarification: TD of North Fork Unit 22-35 Dear Mr. Hennigan: In reviewing the form 10-407, "Well Completion Report" submitted for North Fork Unit 22-35, PTD 212-094,API 50-231- 20038-00-00, completed on 12/8/2012, a discrepancy was noted between the report and the a-logs/daily drilling summary.The report lists Total Depth in box 10 of 11,017 ft.The daily drilling summary on 11/29/12 notes"DRLG 88'TO TD @ 10,700' and the hole is only logged to 10,650'. Please confirm the total depth of NFU 22-35 so that I may update the well completion report as needed. Sincerely, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907)793-1235 1 Guhl, Meredith D (DOA) P 212- 9'.f From: Stephen Hennigan [shennigan@peiinc.com] Sent: Friday, March 14, 2014 11:33 AM To: Guhl, Meredith D (DOA) Cc: Davies, Stephen F (DOA) Subject: RE: Clarification: Directional Survey North Fork Unit 22-35 Meredith They all should be the same just in different formats. I would take the one from the CD as it came straight from the geologist after processing. /114 & BArtioe Strfrie..v /cam / ► ►oaN Project Manager/Engineer PETROLEUM V ENGINEERS, INC. 500 Dover Boulevard, Suite 310 I Lafayette, LA 70503 Office: 337-984-2603 Mobile: 337-849-5345 From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Friday, March 14, 2014 2:31 PM To: shennigan@peiinc.com Cc: Davies, Stephen F (DOA) Subject: Clarification: Directional Survey North Fork Unit 22-35 Dear Mr. Hennigan: I am completing the final compliance review for North Fork Unit 22-35, PTD 212-094,API 50-231-20038-00-00, completed on 12/8/2012. In regards to final definitive survey data submitted, I am unsure which file is the final definitive survey data. Is it the digital data (txt and PDF file) received via CD on 1/22/2103? Or is it the "Actual Welipath Report" supplied with the form 10-407 submitted on 2/1/2013? Please advise. Please confirm by March 21 so I may complete the compliance review. If you have any questions, please contact me. Sincerely, Meredith Guhl Meredith Guhl 1 A RECEIVED FEB 0 1 2013 ARMSTRONG Coo,(I,,/ei. LLC QOGCC January 17, 2013 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RE: 10-407 for Sundry 312-458 Armstrong Cook Inlet, LLC NFU#22-35(PTD No. 212-094) Dear Ms. Foerster, Armstrong Cook Inlet, LLC hereby submits the 10-407 for completing and testing the subject well. If you have any questions or require additional information, please contact me at(303)623-1821 or Stephen Hennigan at(337)849-5345. Sincerely, Aiwileparol Edward Teng Vice President-Engineering Armstrong Cook Inlet, LLC Enclosures Cc: Stephen Hennigan—Petroleum Engineers for Armstrong Cook Inlet, LLC 1 121 131ukr.Slrrrl. /X,n' r, CO,1'O2O2 13 13)-623-LS21 /'h (30$)-O23-3019 1•u_\ , STATE OF ALASKA ALA, OIL AND GAS CONSERVATION COMA ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas Q • SPLUG ❑ Other ❑ Abandoned ❑ Suspended lb.Well Class: 20AAC 25 105 20AAC 25110 Development Q • Exploratory ❑ GINJ ❑ WINJ❑ WAG ❑ WDSPL❑ No.of Completions: TM Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Sus r AS 12.Permit to Drill Number: Armstrong Cook Inlet,LLC Aband.: 122012 • 212 094 • 3.Address: 6.Date Spudded: 13.API Number: 1421 Blake Street,Denver,Colorado 80202 11/2/2012 • 50-231-20038-00-00 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 588'FSL X 1571'FEL ' 26 4S 14W 11/28/2012 • NFU#22-35 • Top of Productive Horizon: 8.KB(ft above MSL): 15.Field/Pool(s): t IA.51 '26Q4, FNL)(' •97.Z'FWL 35 4S 14W GL(ft above MSL): 21.2 Total Depth: Atro5 13136 A1-5 9.Plug Back Depth(MD+TVD): North Eork Unit 2601'FNL X FWL 35 4S 14W 10,580 9368 11;de4 (,A6 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: / /, Surface: x- 199,838 • y- 2,121,132 ' Zone- 4 11,017 9800 ADL-391210/391211• //'13' TPI: x- 198,288 y-2,119,159 Zone- 4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x- 197,440 y- 2,117,875 Zone- 4 372'MD 3721VD 18.Directional Survey: Yes Q No LI 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) NA (ft MSL) NA 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: GR,RES,DEN,NEUT,DTCO,DTS 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 " 84 X56 0' 120' 0' 120' DRIVEN NA 10 3/4" 45.5 L80 0' 3000' 0' 2750' 13 1/2" 761sx lead @12 ppg and 200 sx tail @14.8 ppg • 7 " 26 L80 0' 10673' 0' 9463' 8 3/4" szx lead @ 12.7 ppg and . 344 sx tail @ 13.5 ppg • 24.Open to production or injection? Yesill No❑ If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) See attached Well Bore Diagram-Upper Intervals- Shot with wireline guns 2 7/8" 9040' 5597'MD 4815'ND @ 6 spf,.28"Entrance Holes. Lower Intervals behind packer and"X"plug set 9040'MD 7828'ND in profile at 9065'MD. 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. , It�tr ,RECEIVED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED odi Al FEB 0 1 2013 NA -4""4`1411 AOGCC 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 12/19/2012 8.0 Test Period NA 2.162 M 0 12,24,36,48/64 NA Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corn): Press. 720 24-Hour Rate - 0 8.4 M 0 0 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No❑� - Sidewall Cores Acquired? Yes ❑ No❑� • If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed 41escriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. RBDMS FEB 01 2013 Form 10-407 Revised 12/2009 CUED ON REVERSE Submit original only �L.(3/3 9 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Q Yes ❑ No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form, if Sterling Surface needed,and submit detailed test information per 20 AAC 25.071. Beluga 1392 1380 Tyonek 5497 4736 Tyonek 6000 SS 7039 5964 Tyonek 8500 SS 9783 • 8570 see attached test summary with choke sizes,well head pressure,rates and cumulative production. Formation at total depth: Tyonek 31. List of Attachments: well test,WBS,surveys,summary rpt 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: shennigan(C7peiinc corn Printed Name: Edward Teng Title: Vice President-Engineering Signature . Phone: (303)623-1821 Date: 1/17/2013 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 M � CC cr) Lei y H H H H N M M m u u u u cu to V) V) V) Z Z Z UJ UJ UJN CC CC CL H H H H to Ln Ln = Iy M M m fa y V) V) vii to • Uj 0 LL LL LL LL LL O m LL N M O O In O 00 00 �-I N M M N ri ri (n J J J LL Z Z Z CO LL LL U- CO CO • M O O d tD t0 ri N N O CI 010 CA co 0 0 f0 I� i i Tr 00 d n 00 W C LL LL Y 0) • C C O 0 H (3 Q • C C — 0 = 00 u1 O1 i > -O O M Ov i O ^ih CO a O v +� `t o in +� Z 2 in 0 m ° I—Q Permit#: 212 094 • NFU #22-35 API#: 231-20038-00-00 • Prop. Des:ADL-391210/391211 R 588' FSL, 1571' FEL KB elevation: 679' (21'AGL) S26 T4S R14W S.M. Latitude: 59*47'46.3626"N Longitude: 151*37'45.2584"W Spud: 11-2-2012 Armstrong Cook Inlet, LLC TD: 11-28-2012 Rig Released: 12-23-2012 iStructural Pipe 16" X-56 84 ppf ' i'I Top Bottom I 111 MD Surf 120' 11 TVD Surf 120' I.'1; U� �� Baker SSSV set @ 372' Surface Casing r MD10-3/4" L-80 45.5ppf !!! . Pollard Chemical Inj. lop Bottom Nipple set @ 2498' MD. MD 0' 3,000' 1, \ s- . ND 0' 2,750' • 2 7/8"8RD EUE-M Make up stabin tool to 5"DP and RIH;space o�t - Production Casing and land in FC-Cir csg Circulate hole staging 7" L-80 26 ppf pumps up to 7 BPM while finish rigging up BJ ` ® Top Bottom and adjusting mud volume and mix water ♦ ® MD 0' 10,750' temperature Pump 37 BBL SAPP spacer w/rig - ND 0' 9,800' Pump 5 BBIs water;pressure test Cmt lines to • . -- 3000 PSI Pump 236 BBIs of lead cement when It nspacer started showing at shakers;Switch to A 47BBLs of tail slurry and displace w/5 BBLs , water and 47 BBLs of mud, 761Sks Type 1 4(1."' Cement;134%water(Percentages are BWOC) Tubing 10%BA-90;.005 lbs/sk StaticFree;2% 2 7/8" L-80 6.4 ppf CaCI;.5%EC-1;.2%CD-32;.1%ASA-301; Top Bottom 1GAU100 SK FP-6L;2%Na Metasilicate @ 12.0 I I r ppg 2.62 yld; 200 Sks Type 1 Cmt;.005% MD 0' 5600' StaticFree;2%CaCI;1 Gal/100 SksFP-6L;56.3% - TVD 0' 4817' Water t @14.8ineppg yld 1.34. - 55/7'W) _ RD Cmt lines;Pull 1 Stand;RU returns to cellar; Pump Wiper Dart 8 55 BBIs mud POH laying down DP; (Cement to Surface totaled 60 BBLs) -_ _ Baker FH Packers set at 5597'MD 4815'ND H Mil 11......- . ==.,, . 9040'MD 7828'ND a- Baker Sliding Sleeve set at �'� "-'.:1 V 6524'MD 5553'ND 1 Test lines to 4000 psi;Pump 40 BBI Seal Bond spacer 10 ppg;298 BBIs lead cement • _ _-, weighing 12.7 ppg yld 2.16;111 BBLs tail cement weighing 13.5 ppg,yld 1.82. Perforations dropped plug;pump 404 BBLs of water • ` bumping plug and holding for 5 minutes at 3000 psi. Bleed back 4 bbls and check for psi cjD Y D AD Measured Depth True Vertical Depth Floats to hold. Start rigging down Upper Interval cementers. CIP at 12:40 PM.Lead cement: '� 5653-5681' 4859-4881' //:4? 582 sx Class G cmt;.4%bwoc R-3;10% 5707-5714' 4902-4908' fd, bwoc BA-90;.05#/sk Static free;2.5%bwoc 6528-6575' 5556-5594' tl 1 ga156;.5%bwoc EC-1;.1%1100 Sc FP-6L;.5%bwoc Nac ASA-301; IlµgfP: I 7040-7�4' 5965-5992' Metasillicate;104.1%fresh water Tail [_ _� �..lower Interval Cement:344 sx Class G cmt;.4%bwoc R-3; 1:11II 9159-9198' 7947-7986' 10%bwoc BA-90;.05%bwoc Static Free 9221 -9234' 8009-8023' 2.5%bwoc BA-56;.5%bwocEC-1;.1%bwoc —T-4 ' ,I 9274-9282' 8062-8070' ASA-301;1 ga1/100 sx FP-6L;.5%bwoc Na 9287-9300' 8075-8088' Metasillicate;81.9%fresh water Pressure - 9414-9426' 8202-8214' build up to 2100 psi prior to bumping plug. Ti .•� 9837-9868' 8625-8656' (Note:Had full returns thru entire job-Got 15 bbls of spacer back) �.. IN 10 TD PBTD 11,017'MD 10,580'MD 9,800'ND 9,368'TVD Well Name&Number: North Fork Unit#22-35 Lease: Kenai Loop County or Parish: Kenai Penisula Borough State: Alaska Country: USA Perforations(MD): Perf(TVD). i Angle @KOP and Depth: Angle @ Perfs. KOP TVD: Date Completed: RKB: 21' Prepared By: Craig Rang/Stephen Hennigan Last Revision Date: January 8,2012 Y L U O U N c o c = a0 �[j ;ft y C 0 00 ID 0 N a) a) w 30 = 0 20 = 0 c E � N�p = 0 = O = O = O - c 0 0 Y N ON p)N aN N col[') O = ]0 = O = ON 1 ° I- N I- H H = H H = H H C 01 Y L ca 0 a) co CO CO CO co c m O)\ mo 0\ 0\ N 0 c 0 so o D 0 Q U) U c o C o C o I C o C C o ca., C - a r. (y ce p � 0 � 0 O 25O Q N a) 258 25O ;p0 25O O a) ' a) N NO N NO N 0) .. Q r 0 w O O Y O O - w E ' 00 00 00 = 0 0 = a =7 7 7 0 7 7 0 7 7 7 C C C C e- C c C C t.. 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C.9 l'' S� ----"-] ''.a: U ul •,�i 226 H i. S• 9c' cc 4 Qv (.1 E LA i= M (. C N `s) r Nc.,.................„.........N ......................„%.....:. l4 o ti.Z co. l�fH IJf I la I ‘........ i P r 0 o a o z° 1 cs old a, o ,,,. x .4.........,.........-,......a ara0 a,...laaaaai a a..,,,a a WM..0 00,301VA .10,14600119 WM *11,.. ,.-4 6`. W 0 0 0 0 0 0 0 00 l9c'I 0 0 0 0 0 0 0 o0 rs 00 R LU V1 M N i-I (p/;psW)ales seg `dHM`adMB `ad08 0 o 0 0 0 0 0 0 0 0 co O N. O O O O O 0 0 , a r. F co9c, a f ) ; 0cap F9cr 1 r k t/) u W Z 1.w r H ^ N p N li W Cr V) 9�r cu Y CI o Ln M N N a N 0 �c' D " 9c'r J Y LL Z f� d S ."."."'.""m"...a. .00.°4 cl rA i 3)C1 OZ o z `9c' g r� F a o a z WL 0 0 0 � � 0 0 0 0 0 c9crrs 1� lD t.() m N c-1 0 (p/;psw)a;eu seD'dHM'adM9 'dd08 A ARMSTRONG Conk Armstrong Cook Inlet, LLC NFU #22-35 OPERATIONS SUMMARY PTD 212-094 Sundry 312-458 Nabors Rig 99 01/05/13 Wait for Pollard. PJSM, rig up lubricator/swab cups. RIH, fluid at 550. Swab, fluid stays around 5-600'. Ran out of swabs. Well started to come on. Total water 35 bbls. Well came on fast. '1fi"� ? 1100 WH, 26 chk, 3+M. Flow to clean up. Increase to 6 M and then dropto 2 M. Total water recovered: 84.52 bbls. 01/04/13 PJSM with Pollard, Expro. Rig up to well w/lubricator and swab cups. RIH, SSV closed. Open. Swab, fluid level increasing. Decission to keep swabbing. Lowered fluid to 900', next run 850. Fluid/gas burping to rtn tank. R/up opening tool and RIH open sleeve. 325psi WH. POOH, chk pins, Good. Open choke attempt flow well. 20bbls rtns. Well dead. Soap no help. Call Pollard. 01/03/13- Well shut in. 12/25/12 12/24/12 INSTALL TREE,TEST TREE TO 5000 PSI (OK). RIG RELEASE 12:00 HRS 12-23-12. RIGGING DOWN DRILL RIG 12/23/12 ATTEMPT TO SET, LEAK W/COMMUNICATION BETWEEN ANNULUS AND TBG, RE ESTABLISH fi TOP OF PACKER, STAB IN, RE-SPACE OUT, LAND TBG, RUNING LOCK DOWNS, SET PACKER, �� ,7�✓ TEST TBG AND ANNULUS, (OK), L/D LAND JT. SET BPV, RIG DOWN WEATHERFORD, NIPPLE DN BOPE 12/22/12 ,CIRC CORROSION INHIBITOR INTO ANNULUS, SPACE OUT AND LAND TBG, RUN LOCK DOWNS IN, ATTEMPT TO SET PACKER, GOT COMMUNICATIONS FR TGB TOO ANNULUS, PULL TBG HANGER SECURE CONTROL LINES, SET TBG BACK ON LOCATOR, R/U SLICK LINE CHECK CIRC SLEEVE, CLOSE SLEEVE, MAKE UP HANGER AND LAND TBG. 12/21/12 POOH, PULL WEAR BUSHING, PICK UP SEAL ASSEMBLY, 79 JTS, SLIDING SLEEVE, 29 JTS, BAKER FH PACKER, 98 JTS, CHEMICAL INJ SUB, 67 JTS, SSSV, 9 JTS, 3 PUP JTS, 1 JT, PUP JT, HANGER. TAG UP AND SPACE OUT, CIRC CORROSION INHIBITOR. 12/20/12 FLOW WELL AS DIRECTED. SHUT WELL IN; BULLHEAD 78 BBLS DOWN TUBING; OPEN PACKER CIRCULATING PORT AND BULLHEAD 50 MORE BBLS. LINE UP DOWN TUBING TAKING RETURNS THROUGH CHOKE FOR A COMPLETE HOLE VOLUME; OPEN WELL UP AND CIRCULATE A HOLE VOLUME; WELL IS DEAD; POH W/TEST STRING. 12/19/12 REPAIR TOPDRIVE IBOP; CHANGE OUT ENCODER; RIH W/10 STANDS OF 2 7/8 TBG, PU CHAMP PKR AND OMNI TOOL, RIH TO 2386';TOOL NOT FUNCTIONING RIGHT; POH AND LD TOOLS. GET NEW PKR AND RIH W/26 STANDS OF TBG TOTAL; PU MS TOOL; RIH TO 6521'. SET PKR AT 5556'; RU HAL FLOW/TEST HEAD, EXPRO EQUIPMENT,TEST LINES. OPEN MS TOOL; BRING ON WELL. 12/18/12 FINISH REPAIR ON ACTUATOR VALVE. FINISH BOP TESTING UPPER/LOWER TOPDRIVE VALVES. FIX LEAK ON RISER. ADJUST COVER ON ACTUATOR VALVE. 12/17/12 RUN GUNS ON WIRELINE AND PERFORATE 3 DIFFERENT INTERVALS, RIG DOWN WIRELINE AND SHOOTING FLANGE, NIPPLE UP PITCHER NIPPLE AND FLOW LINE. TESTING BOPE. HAVING ISSUES WITH FREEZING. HYD ACCTUATOR VALVE ON BOPE FAILED, CHANGE OUT SAME. 12/16/12 Flow test well to 08:00. Shut well in and bleed gas off to Expro. Bull head 43 bbls of 8.7 KCL brine down tbg; start circulating conventional but go through choke with bag shut as gas increased before bottoms up; after bottoms up without the choke, slight flow; weight up brine to a solid 8.7 ppg while circulating . Monitor well; OK. POH w/tbg. Rig up shooting flange and Pollard. 12/15/12 FINISH TRIP IN HOLE, CHANGE SAVER SUB, RIG UP WIRE AND CORRELATE, POOH WITH WIRE AND PICK UP PUP JT, SET ON WIRE LINE DEPTH AND CORRELATE AGAIN. CORRELATION GOOD. RIG DOWN WIRE, RIG UP HALLIBURTON FLOW HEAD, AND FIRE GUNS AND FLOW WELL. EXPRO REPORTS WITH MORNING REPORT. 12/14/12 Flow test well. Shut well in; Rig down Expro; pull up to 5526' to open circulating tool;Tbg pressure 1940 psi; bullhead 38 bbls of 8.7 KCL brine down tbg at 1.5 bpm. Kill well pumping through choke and gas buster. Circulate conventional after well was dead. POH with tubing and RTTS tool. MU TCP's, Champ Pkr and RIH. 12/13/12 Pressure Test Expro lines/equipment; Pick up Pollard Guns and Lubricator and test 500/4000 psi. Shoot perfs f/7040-7074' MD (6 spf/0° phasing/ magnetically de-centralized/2" hollow carriers) Bring well on; flow back to Expro total of 90. bbls fluid at 05:30. Gas flowing 1.5 mmcf w/145 psi on manifold. Flow Chart in file. 12/12/12 Finish testing BOP's.Test plug in 'X' nipple at 9065' to 1000 psi. Rig up and run RTTS packer with wireline entry guide and circulating sleeve. Set RTTS packer at 5529'. Rig up Flow test manifold adding another TIW valve; rig up Expro; Swab well down to 2350'. Rig down Pollard slick line. 12/11/12 POH w/2 7/8 tubing; Stop and weave sash cord around stands to prevent excessive bowing; POH w/2 7/8 tbg. Retrieve all Pollard fishes (cups, Swab mandrel, wireline and strip gun). Rig up and test BOP's. 12/10/12 Fish two swab cups out of hole; attempt to beat other swab cups and tool out of tubing unsuccessful. Unable to go past 8955'; RIH and punch holes in the tubing at 8917-8919'; circulate hole clear; rig down flow manifold; circulate to make sure no gas after pulling out of packer while rigging up WOT; POH w/tubing. 12/09/12 Swab well with slickline to 2400'. RIH with perf guns and shoot perfs at 9177-9198' and 9159- 9177' on two runs. The line got jammed in the stuffing box and was pulled into with the rope socket at 69'. RIH w/gauge ring/2.375" to 9065'; RIH w/LIB to make sure nothing was there to 9065'. Start swabbing well with fluid at 700' on initial run. Swab tool broke; prep to fish swabs 12/08/12 Test Flow manifold and lines to Expro; Pick up lubricator and first set of guns and test again to 4200/350 psi. Run in hole and shoot perfs at 4 different intervals. Fluid in tubing moved from 2350' to approximately 1600. No pressure. Swab 12/07/12 Finish RIH w/2 7/8 Tbg. Space out; Rig up and swab 14 BBLs of brine from tubing (2400'); Install Master Valve in Flow manifold; Rig up lines to Expro. Continue with Expro rig up away from rig. 12/06/12 Rig up and make up 7" X 2 7/8" F-1 packer and seal bore extension with tubing tail/X profile nipple & wireline re-entry guide. RIH with Pollard wireline and set at 9040'. Rig up and run 2 7/8-8RD EUE tubing and seal assembly. 12/05/12 Rig up and run CBL with Pollard; Load pipe shed with 300 jts of 2.875" tubing; strap same. Change bottom rams to 2.875" and top rams to 2.875" X 5" variables. Rig up and test BOP's with Bob Noble as AOGCC witness (4 hours test time) Prepare for 2 7/8 completion 12/04/12 Circulate the hole while cleaning pits; displace to 6% KCI brine at 10,581'; POH laying down drill pipe, BHA, scraper and mill. u 12/03/12 Rig up Baker Hughes cementers and pump cement job; displace with 404 bbls of fresh water. Rig down cementers; pick up 7" casing packoff and install; Test to 5000 psi. Set short wear ring, rig down stabbing board, long bales; pick up short bales. Make up casing scraper and 6" bit; RIH. Tag cmt at 10580' - Cleaning pits 12/02/12 Rig up and_run 7" casing. Land 7" hanger in well head. Prepare to cement. 12/01/12 Make wiper trip to bottom. Circulate hole; pump weighted-HV sweep. Make a 4 std wiper trip; circulate hole clean; spot a 100 Bbl. Lotorq pill on bottom; POH. Lay down entire BHA. Change out 7" rams in top set of BOP rams; test 250/4000 psi. Make a dummy run on 7" landing jt. Rig up to run 7" casing. 11/30/12 Finish laying down BHA; LWD, motor, MWD, sources. RU and test BOP's. Make up new cleanout BHA and RIH to 5000'; break and make conn not done on previous trip. Work through tight spots as needed. 11/29/12 DRLG 88'TO TD @ 10,700', CIRC &CONDITION MUD, POH, (FOUND DAMAGED TOOL JOINTS, BROKE, CLEANED, & REDOPED ALL DP CONNECTIONS), L/D BHA 11/28/12 DRLG AHEAD, MADE 502' of NEW HOLE, HIGH TORQUE-RUNNING 18 TO 20 K 11/27/12 DRILLING AHEAD 510' NEW HOLE, TORQUE CONSISTENT AT 18-20 K 11/26/12 DRILL TO 9553', WIPER TRIP,TIGHT @8126', DRLG AHEAD TO 9600' 11/25/12 DRILLING AHEAD at 9205', BACK TO VERTICAL @ 8900' RIH TO SHOE, TEST MWD, CUT&SLIP DRLGLINE, C/O SAVER SUB, CALIBRATE BLOCK HEIGHT &MWD, C/O ENCODER ON TOP DRIVE, RIH CIRC B/U @ 5200' &700', WASH & REAM 100' to 11/24/12 8418'. DRLG AHEAD DRILLED AND ATTEMPTED TO KEEP GETTING SIGNAL FROM MWD. NO SUCCESS WITH SIGNAL. 11/23/12 POOH FOR TOOLS. HOLE IN GOOD SHAPE. WORK BHA'S BOTH DIRECTIONS. CULLED SOME PIPE WITH HARDBAND WORN OFF. DRILLING AHEAD FROM 7585' TO 8316'- HAVING SOME COMMUNICATION ISSUE WITH 11/22/12 DOWNHOLE TOOLS, RESET COMMANDS AND REBOOT. TEST BOP EQUIP, P/U BHA#4, RIH, CIRC BTTM/UP @ 3062' & 5650', GOT 370 UNITS GAS ON 11/21/12 BTTMS/UP @5650', GAS 536 UNITS ON BTTMS UP @7560', DRLG AHEAD @ 7585' WIPER TRIP TO 6092', HOLE SLICK, DRLG 35', CIRC & CONDIT MUD F/TRIP, POH F/BOP TEST& DRLG TOOLS, L/D BHA, PULL WEAR BUSHING,TEST BOP EQUIPEMENT, 250 PSI LOW, 4000 PSI 11/20/12 HIGH, ANULAR 250 PSI LOW, 2500 PSI HIGH DRLG 7250' START CURVE BACK TO VERTICAL DRLG TO7525, PUMP SWEEP, WIPER TRIP BACK 11/19/12 TO 6092' 11/18/12 DRILL TO 6098' WIPER TRIP UP TO 4577' (HOLE SLICK) CONTINUE DRILL TO 6625' 11/17/12 DRLG AHEAD 890' NEW HOLE DRLG 3622' TO 4576', CIRC& COND F/WIPER TRIP, WIPE TRIP TO SHOE, TIGHT @ 3420' 25K 11/16/12 OVER, DRLG 4576'TO 4630' POH and LD 9.875" Bit. Pick up new bit & BHA with motor, MWD and LWD. Load sources, shallow function test tools. RIH to 2958'; PU Kelly up and circulate/wash to 11/15/12 bottom. Drill to 3325' at midnight. Test BOP bottom rams. Rig down test equipment; blow down all lines, choke manifold, etc. Pick up 9.875" bit, sub, XO and HWDP; RIH. Tag FC/cement at 2948'; CBU and test casing. Test 3000 psi for 30 min. Drill to 3025'; circulate hole clean for leak off test. Rig up and perform ak 4 v 4- 11/14/12 11/14/12 Leak off Test to 16.17 ppge. Wait on Single gate rams to arrive. Pick up 75 jts of DP, stand back in derrick. Raise stack, 11/13/12 remove single gate, install new single gate. Install riser and flowline. PU DP and rack back in derrick. RU and test BOP's. Failure on bottom rams; 1 side of ram failed to close, after raising manifold psi to 1900 the ram functioned. All other components 11/12/12 tested. Rams &choke Manifold 250/4000 psi -Annular 250/2500 psi Pick up 90 joints of 4" DP; circulate hole to condition mud for CBL; rack back DP. RU and run 'v 11/11/12 CBL with Pollard. Good cement bond. Change out saver sub, install wear bushing. Pick up 90 jts of DP and rack back. NU 11 X 5000 psi stack. Readjust stack to hook up koomey lines. Cut and fit flow riser 3 times 11/10/12 due to the way the sub is built and flow line comes into riser. Sand location and run loaders over traffic areas for traction after the rain. 11/09/12 Finish welding on Vetco Multi-bowl, test void to 1970 psi (good test) Nipple up 11 X 5000 PSI BOP's. Backhaul 5" DP, Load 4" DP in pipe shed. Start mixing new mud. Fix backlash. Laydown 5" DP: clear floor of false rotary, decking, misc tools. Unbolt diverter 11/08/12 system and clean components while rigging down. Rough cut 10 3/4 csg, remove bell nipple and diverter bag. Install VETCO Multibowl wellhead. Finish RIH w/10 3/4 csg. RU and RIH w/5" DP and stab in sub. Circulate hole while rigging up 11/07/12 Baker Cementers. Cement and displace; pump wiper dart and 55 bbls of mud through DP. RU j and start laying down 5" DP - Back lash drlg line -Work on drlg line/drawworks. Circulate the hole clean; pump HV sweep w/Nut Plug, circulate clean. Make a wiper trip to the 11/06/12 HWDP. RIH slick to bottom, circulate the hole clean seeing no increase in cuttings with another HV sweep. POH; LD BHA. RU and run 10 3/4 casing. 11/05/12 Drill f/2230 to 3005'TD surface hole - Circulate hole; pump HV sweep. 11/04/12 Drill to 2009'. Make a wiper trip to the collars. Continue drilling to 2230'. 11/03/12 Spud well at 06:15 AM; Drl f/140' to 1170' at midnight. Start KO at 750' building 2.5° per hundred. Drill to 1390' at 06:00 with 15.31° angle built. Finish welding conductor. Cut and fit flow nipple. Finish installing diverter sections for 75' 11/02/12 radius clearance. Function Test diverter system. PU and rack back DP and HWDP. Finish mixing spud mud. Pressure test lines; test mud pumps. PU BHA. Canrig installing "RIG WATCH" and checking pvt,gas detectors, and general rig up for logging unit. After diverter was rigged up, had to cut conductor below starting head and add 8 .25 in to 11/01/12 allow alignment to diverter line in pipe shed - Finish dressing pumps with 6" liners and swaps- Finish plumbing pits and start mixing mud 10/31/12 Rig up; cut conductor, install and test starter head and start nipple up on diverter RIG UP LINES F/ DERRICK, INSTALL DERRICK BY SECTIONS, HANG BOARD, FINISH SET PITS, P/U 10/30/12 TOP DRIVE & MD80, HOOK UP SERICE LINES,TAKE ON FUEL&WATER, HANG WIND WALLS ON FLOOR, START SET PIPE SHED SET SUB IN AND LEVEL,SET PUMPS, GEN, BOILERS, DOG HOUSE,TOOL ROOM, DRLG LINE 10/29/12 SPOOL, A-LEGS, SET CROWN IN, STRING UP ODS MAN RIDER, STRING UP & SPOOL DRLG LINE ON DRUM, SET MUD PITS vi. ADVANTAGE Final Survey Listing HUGHES INTEQ Operator Armstrong Cook Inlet, LLC Fields North Fork API No 50-23120058 Well NF#22-35 Wellbore NF #22-35 Orig Hole Rig Nabors 99 Job 4966136 Well Origin Latitude 59.80 deg Longitude -151.63 deg North Reference True Drill Depth Zero Rig Floor Vertical Datum is Mean Sea Level Vertical Datum to DDZ 678.35 ft Vertical Section North 0.00 ft Vertical Section East 0.00 ft Vertical Section Azimuth 215.95 deg Vertical Section Depth 0.00 ft Grid Convergence 0.00 deg Magnetic Declination 17.10 deg Total Correction 17.10 deg TVD Calculation Method Minimum Curvature D-Raw Calculation Magcorrl Local Magnetic Field 55112 nT Local Magnetic Dip Angle 72.87 deg Local Gravity Field 9.819 m/s^2 Tie In nftD I deg I deg m N rtft h I Eftt I TVD I Sft ITemdegFperature CRSft LEN Ideg/100ftDLS ldeg/1OOftBuild lTurn deg/100ft U 20.55 0.00 0.00 0.00 0.00 20.55 0.00 181.00 0.90 342.19 1.20 -0.39 180.99 -0.75 -459.7 160.45 0.56 0.56 -11.10 271.00 0.80 315.99 2.33 -1.04 270.98 -1.28 93.2 90.00 0.44 -0.12 -29.10 362.00 0.79 334.35 3.35 -1.75 361.98 -1.69 96.0 91.00 0.28 -0.01 20.17 451.00 0.90 329.39 4.51 -2.37 450.97 -2.26 96.0 89.00 0.14 0.12 -5.57 540.00 0.62 315.12 5.45 -3.07 539.96 -2.61 98.7 89.00 0.37 -0.31 -16.04 629.00 1.14 171.63 4.92 -3.28 628.95 -2.06 104.1 89.00 1.88 0.58 -161.23 717.00 1.33 176.78 3.04 -3.10 716.93 -0.64 104.1 88.00 0.25 0.22 5.86 813.00 3.35 226.58 -0.00 -5.07 812.85 2.98 109.5 96.00 2.81 2.11 51.87 908.00 5.13 228.23 -4.74 -10.26 907.59 9.86 109.5 95.00 1.88 1.87 1.74 1003.00 7.45 216.36 -12.54 -17.08 1002.02 20.18 109.5 95.00 2.79 2.45 -12.49 1097.00 10.96 212.89 -24.96 -25.56 1094.79 35.21 109.5 94.00 3.78 3.73 -3.69 1192.00 13.60 214.82 -41.72 -36.84 1187.61 55.40 106.8 95.00 2.81 2.78 2.03 1287.00 15.31 210.90 -61.65 -49.67 1279.60 79.07 109.5 95.00 2.07 1.80 -4.13 1383.00 16.87 210.79 -84.50 -63.31 1371.83 105.57 112.2 96.00 1.63 1.63 -0.12 1478.00 18.79 212.96 -109.18 -78.69 1462.27 134.59 117.6 95.00 2.14 2.02 2.29 1573.00 20.70 215.49 -135.70 -96.77 1551.68 166.66 120.3 95.00 2.20 2.01 2.66 1667.00 22.45 216.02 -163.75 -116.97 1639.09 201.23 123.0 94.00 1.87 1.86 0.56 1762.00 24.57 214.98 -194.60 -138.96 1726.20 239.12 123.0 95.00 2.28 2.23 -1.09 1855.00 27.34 214.15 -228.13 -162.04 1809.81 279.81 123.0 93.00 3.00 2.97 -0.89 1949.00 29.73 215.85 -264.88 -187.81 1892.39 324.69 125.7 94.00 2.68 2.54 1.80 2047.00 31.24 217.80 -304.66 -217.62 1976.84 374.39 120.3 98.00 1.84 1.54 1.99 2142.00 33.72 217.20 -345.14 -248.66 2056.98 425.38 125.7 95.00 2.64 2.62 -0.63 2237.00 35.84 216.11 -388.62 -281.00 2135.00 479.57 131.1 95.00 2.33 2.23 -1.15 2331.00 36.44 215.64 -433.55 -313.49 2210.91 535.01 128.4 94.00 0.70 0.64 -0.50 2427.00 36.54 215.95 -479.85 -346.88 2288.09 592.10 128.4 96.00 0.22 0.10 0.33 2522.00 36.79 216.72 -525.55 -380.49 2364.29 648.82 128.4 95.00 0.55 0.26 0.81 2618.00 36.79 216.15 -571.80 -414.63 2441.18 706.31 131.1 96.00 0.36 0.01 -0.60 2715.00 36.70 216.24 -618.63 -448.90 2518.90 764.34 131.1 97.00 0.11 -0.10 0.10 2810.00 37.11 217.24 -664.34 -483.03 2594.87 821.38 131.1 95.00 0.77 0.44 1.05 2906.00 37.73 217.29 -710.77 -518.35 2671.11 879.70 131.1 96.00 0.64 0.64 0.06 2945.00 37.75 217.43 -729.74 -532.84 2701.95 903.56 131.1 39.00 0.21 0.04 0.34 3044.00 37.19 217.59 -777.51 -569.51 2780.53 963.76 85.1 99.00 0.57 -0.56 0.17 3087.00 37.00 218.09 -797.99 -585.42 2814.83 989.68 87.8 43.00 0.83 -0.44 1.17 3182.00 36.78 217.97 -842.91 -620.55 2890.81 1046.67 87.8 95.00 0.24 -0.23 -0.13 3278.00 36.52 217.67 -888.18 -655.69 2967.83 1103.95 90.5 96.00 0.33 -0.27 -0.31 3374.00 37.15 215.80 -934.30 -690.10 3044.66 1161.49 93.2 96.00 1.34 0.65 -1.95 3469.00 36.88 215.90 -980.66 -723.59 3120.52 1218.68 96.0 95.00 0.29 -0.28 0.11 3565.00 37.42 214.04 -1028.16 -756.81 3197.04 1276.64 98.7 96.00 1.30 0.56 -1.93 3659.00 37.15 213.67 -1075.45 -788.54 3271.83 1333.54 101.4 94.00 0.37 -0.28 -0.40 3757.00 36.87 213.20 -1124.68 -821.04 3350.08 1392.48 104.1 98.00 0.40 -0.28 -0.47 3853.00 36.48 212.80 -1172.77 -852.27 3427.08 1449.74 106.8 96.00 0.48 -0.41 -0.42 3949.00 37.39 214.71 -1220.72 -884.33 3503.81 1507.38 109.5 96.00 1.53 0.96 1.98 4043.00 37.22 215.68 -1267.28 -917.16 3578.58 1564.35 109.5 94.00 0.65 -0.18 1.04 4138.00 36.76 215.01 -1313.91 -950.23 3654.46 1621.51 112.2 95.00 0.65 -0.49 -0.70 4233.00 36.60 214.74 -1360.46 -982.68 3730.65 1678.24 112.2 95.00 0.23 -0.16 -0.28 4328.00 37.02 215.09 -1407.13 -1015.26 3806.71 1735.16 109.5 95.00 0.49 0.44 0.37 4424.00 36.96 215.76 -1454.20 -1048.74 3883.39 1792.91 106.8 96.00 0.42 -0.06 0.69 4519.00 37.41 216.60 -1500.54 -1082.64 3959.07 1850.33 106.8 95.00 0.72 0.48 0.89 4612.00 37.07 216.58 -1545.73 -1116.19 4033.11 1906.60 104.1 93.00 0.37 -0.37 -0.02 Page 1 tial ADVANTAGE Final Survey Listing HUGHES INTEQ Operator Armstrong Cook Inlet, LLC Fields North Fork API No 50-23120058 Well NF #22-35 Wellbore NF #22-35 Orig Hole Rig Nabors 99 Job 4966136 Tie MD Incl I North I East I TVD I 'Temperature CRS LEN IDLS lBuild lTurn In fdeg deg ft VSdgdeg/100ftdeg/1OOftdeg/100ft 4709.00 36.84 215.96 -1592.74 -1150.69 4110.62 1964.92 109.5 97.00 0.45 -0.23 -0.64 4802.00 37.07 216.80 -1637.75 -1183.86 4184.94 2020.83 112.2 93.00 0.60 0.24 0.90 4898.00 37.64 217.15 -1684.29 -1218.89 4261.25 2079.07 109.5 96.00 0.63 0.59 0.36 4994.00 37.89 216.41 -1731.37 -1254.10 4337.14 2137.85 109.5 96.00 0.54 0.26 -0.77 5090.00 37.34 215.95 -1778.66 -1288.69 4413.19 2196.44 109.5 96.00 0.64 -0.57 -0.48 5185.00 37.64 216.63 -1825.26 -1322.91 4488.57 2254.26 109.5 95.00 0.54 0.32 0.71 5280.00 36.94 217.83 -1871.10 -1357.73 4564.15 2311.80 109.5 95.00 1.06 -0.74 1.27 5374.00 37.71 217.72 -1916.15 -1392.64 4638.89 2368.77 109.5 94.00 0.81 0.81 -0.12 5469.00 38.16 217.49 -1962.41 -1428.28 4713.82 2427.14 112.2 95.00 0.50 0.48 -0.24 5565.00 37.85 217.58 -2009.29 -1464.29 4789.47 2486.23 112.2 96.00 0.33 -0.33 0.09 5659.00 37.56 217.24 -2054.95 -1499.21 4863.84 2543.70 112.2 94.00 0.38 -0.30 -0.37 5754.00 36.93 217.22 -2100.73 -1534.00 4939.46 2601.18 112.2 95.00 0.67 -0.67 -0.02 5849.00 37.11 217.82 -2146.10 -1568.83 5015.31 2658.36 112.2 95.00 0.43 0.19 0.64 5944.00 37.54 215.87 -2192.19 -1603.36 5090.86 2715.95 112.2 95.00 1.33 0.45 -2.05 6039.00 36.87 215.40 -2238.87 -1636.83 5166.53 2773.38 109.5 95.00 0.77 -0.71 -0.50 6134.00 37.62 215.65 -2285.66 -1670.24 5242.16 2830.87 112.2 95.00 0.81 0.79 0.27 6231.00 37.22 215.84 -2333.50 -1704.67 5319.20 2889.81 112.2 97.00 0.43 -0.41 0.20 6327.00 36.97 215.47 -2380.54 -1738.42 5395.77 2947.71 114.9 96.00 0.35 -0.26 -0.38 6421.00 36.46 215.63 -2426.26 -1771.09 5471.13 3003.90 114.9 94.00 0.55 -0.54 0.16 6516.00 37.73 216.28 -2472.63 -1804.74 5546.90 3061.19 114.9 95.00 1.40 1.34 0.69 6610.00 37.55 216.41 -2518.87 -1838.76 5621.34 3118.59 114.9 94.00 0.21 -0.19 0.13 6707.00 37.67 215.63 -2566.75 -1873.57 5698.18 3177.79 114.9 97.00 0.50 0.12 -0.80 6802.00 37.32 215.27 -2613.86 -1907.11 5773.56 3235.62 117.6 95.00 0.43 -0.36 -0.38 6896.00 36.76 215.58 -2660.00 -1939.93 5848.58 3292.24 117.6 94.00 0.63 -0.60 0.34 6993.00 36.25 215.90 -2706.84 -1973.64 5926.55 3349.95 117.6 97.00 0.56 -0.52 0.33 7087.00 35.79 215.97 -2751.60 -2006.08 6002.58 3405.23 117.6 94.00 0.50 -0.50 0.07 7182.00 35.33 215.87 -2796.34 -2038.49 6079.86 3460.47 117.6 95.00 0.49 -0.48 -0.10 7277.00 34.25 215.07 -2840.48 -2069.95 6157.88 3514.67 114.9 95.00 1.24 -1.14 -0.85 7372.00 32.93 215.25 -2883.44 -2100.21 6237.02 3567.22 114.9 95.00 1.39 -1.38 0.19 7467.00 30.58 216.86 -2923.87 -2129.61 6317.79 3617.21 117.6 95.00 2.63 -2.48 1.69 7501.00 29.92 216.86 -2937.58 -2139.89 6347.16 3634.34 106.8 34.00 1.95 -1.95 0.01 7588.00 28.52 215.59 -2971.83 -2164.99 6423.09 3676.80 109.5 87.00 1.76 -1.61 -1.47 7684.00 26.27 213.76 -3008.13 -2190.14 6508.32 3720.96 114.9 96.00 2.49 -2.34 -1.90 7780.00 24.08 213.95 -3042.05 -2212.89 6595.20 3761.77 114.9 96.00 2.28 -2.28 0.20 7875.00 21.10 213.69 -3072.36 -2233.20 6682.90 3798.23 123.0 95.00 3.14 -3.14 -0.27 7970.00 18.84 214.10 -3099.30 -2251.29 6772.18 3830.66 128.4 95.00 2.38 -2.37 0.42 8065.00 16.45 212.72 -3123.32 -2267.16 6862.70 3859.42 114.9 95.00 2.56 -2.52 -1.45 8160.00 14.54 214.86 -3144.42 -2281.25 6954.25 3884.78 114.9 95.00 2.10 -2.01 2.25 8256.00 12.57 214.64 -3162.91 -2294.08 7047.57 3907.27 114.9 96.00 2.05 -2.05 -0.23 8350.00 9.78 214.66 -3177.89 -2304.43 7139.78 3925.48 117.6 94.00 2.97 -2.97 0.02 8446.00 7.41 215.71 -3189.63 -2312.69 7234.69 3939.83 131.1 96.00 2.47 -2.46 1.09 8541.00 5.16 212.09 -3198.22 -2318.53 7329.11 3950.22 136.5 95.00 2.41 -2.37 -3.81 8637.00 3.26 211.26 -3204.21 -2322.24 7424.85 3957.25 139.2 96.00 1.98 -1.98 -0.86 8732.00 1.38 211.72 -3207.49 -2324.25 7519.77 3961.08 144.6 95.00 1.98 -1.98 0.48 8827.00 0.46 190.82 -3208.84 -2324.92 7614.76 3962.56 144.6 95.00 1.01 -0.96 -22.00 8921.00 0.37 191.48 -3209.51 -2325.05 7708.75 3963.18 147.3 94.00 0.09 -0.09 0.71 9019.00 0.31 190.18 -3210.09 -2325.16 7806.75 3963.71 150.0 98.00 0.07 -0.07 -1.33 9114.00 0.25 184.56 -3210.54 -2325.22 7901.75 3964.12 152.7 95.00 0.07 -0.06 -5.92 9207.00 0.26 161.15 -3210.95 -2325.17 7994.75 3964.41 155.4 93.00 0.11 0.02 -25.17 9303.00 0.22 124.60 -3211.26 -2324.95 8090.75 3964.54 152.7 96.00 0.16 -0.05 -38.06 9398.00 0.23 111.68 -3211.43 -2324.62 8185.75 3964.48 155.4 95.00 0.06 0.02 -13.60 9492.00 0.34 87.46 -3211.49 -2324.16 8279.75 3964.26 155.4 94.00 0.17 0.12 -25.77 9592.00 0.48 78.37 -3211.39 -2323.45 8379.74 3963.77 152.7 100.00 0.15 0.13 -9.10 9686.00 0.57 68.34 -3211.14 -2322.63 8473.74 3963.08 155.4 94.00 0.14 0.10 -10.67 9782.00 0.76 61.59 -3210.66 -2321.63 8569.73 3962.10 155.4 96.00 0.21 0.20 -7.03 9878.00 0.97 54.30 -3209.88 -2320.40 8665.72 3960.76 155.4 96.00 0.25 0.22 -7.59 9976.00 0.40 90.92 -3209.40 -2319.39 8763.72 3959.77 155.4 98.00 0.71 -0.58 37.36 10072.00 0.40 109.05 -3209.52 -2318.73 8859.71 3959.48 155.4 96.00 0.13 0.00 18.89 10166.00 0.59 149.61 -3210.05 -2318.17 8953.71 3959.58 155.4 94.00 0.41 0.20 43.15 10262.00 0.68 188.87 -3211.04 -2318.01 9049.70 3960.28 158.1 96.00 0.45 0.09 40.89 Page 2 "II ADVANTAGE Final Survey Listing BAKER GHES INTEQ Operator Armstrong Cook Inlet, LLC Fields North Fork API No 50-23120058 Well NF#22-35 Wellbore NF #22-35 Orig Hole Rig Nabors 99 Job 4966136 Tie ft MD I Incl Azim deg I deg Northft I East I TVD I VS Temperature CRSft LEN IDLS deg/100ftldeg/1Build OOftlTurn deg/100ft 10358.00 0.85 211.23 -3212.21 II -2318.47 9145.70 3961.50 160.8 96.00 0.35 0.17 23.30 10453.00 0.73 203.29 -3213.37 -2319.07 9240.69 3962.80 160.8 95.00 0.17 -0.13 -8.36 10549.00 0.43 222.95 -3214.19 -2319.56 9336.68 3963.75 160.8 96.00 0.37 -0.32 20.47 10642.00 0.18 246.46 -3214.50 -2319.93 9429.68 3964.22 160.8 93.00 0.29 -0.27 25.28 Projection to TD 10700.00 0.18 246.46 -3214.58 -2320.09 9487.68 3964.37 58.00 0.00 0.00 0.00 Tie Column Legend: I- interpolated tie-point, S-survey station, U- user-defined,T-Surface Page 3 W LIN 333 4, 0 in o kg � ; N O i3ign ria, so o v� v, = n n n . 4.4. 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Q.,..>. 7 2 _ N Nr L i X 17 e ' E" �� Ua 3 " ti Z O ci .WC NQb el u OO rn r�r o 7 O ti :i vO A 01 O F G g = .0wQ! a F NN b 4. a U Q w Q Q a 0 w g 0,0 ,s C O O CA N N a O W L G7r GTi CV wp A O O Z S s s •U +4.+ �+ O V.,- I. O O O O C O tit Z U vt O o zQU Z Z Li 00 ' LL; nHo kr> U d 5 a cA e cl g a wl :n O WI Y4, E on e CF kr) N in N if)Nd N AL GL . I� bD 't71' a� a C/� W K. w w 2 v�" . C 0 d ER GL Gii N G* w fZ 0 dx � N F z Z .-. Z .r Z CA Buccaneer Alaska Operations, LLC CASING& CEMENTING REPORT Permit to Drill(PTD) 212 094 Lease&Well No. ADL-391210/391211 NFU#22-35 Date 7-Nov-12 County Kenai Peninsula Bor. State Alaska Co Supv. CASING RECORD Surface TD MD 3005 TVD 2755 Shoe Depth: MD 3000 TVD 2750 PBTD. MD na TVD na Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe/jt 10 3/4 45.5 L-80 BTC Wfd 43.40 3,000.00 2,956.60 F.Collar 10 3/4 45.5 L-80 BTC Wfd 1.88 2,956.60 2,954.72 76 jts 10 3/4 45.5 L-80 BTC 2,954.72 2,954.72 0.00 Totals 3,000.00 Csg Supv. Csg Wt.On Hook: na Type Float Collar: Stab-in Float No.Hrs to Run• 13 Csg Wt.On Slips: <146000 Type of Shoe: Float Casing Crew: Wfd Fluid Description: 9.8 ppg water base Spud mud/ PV 15/ YP 17/ Gels 8-19-26 Liner hanger Info(Make/Model): na Liner top Packer? Yes X No Liner hanger test pressure: na Lnr Hgr Tech Centralizer Placement: 2 centralizers on btm jt,-1 centralizer every 3 jts to conductor shoe CEMENTING REPORT Preflush(Spacer) Type: Mud Clean II Density(ppg) 8.4 Volume pumped(BBLs) 40 Lead Slurry Type: Type1 Blend Yield(Ft3/sack). 2.62 Density(ppg) 12.0 ppg Volume (BBLs/sacks): 342 bbls/733 sx Mixing/Pumping Rate(bpm): 4 Tail Slurry Type: Type1 Blend Yield(Ft3/sack): 1 34 1 Density(ppg) 14.8 Volume (BBLs/sacks): 48 bbls/200 sx Mixing/Pumping Rate(bpm): 4 I- Post Flush(Spacer) c% Type: fresh water Density(ppg) 8.4 Rate(bpm): 4 Volume: 5 cc LL Displacement: Type: Mud Density(ppg) 9.8+ Rate(bpm): 8 bpm Volume(actual/calculated): 47/48 FCP(psi): 870 psi Pump used for disp: Rig pumps Plug Bumped? Yes No Bump press 0 Casing Rotated? Yes X No Reciprocated? Yes x No %Returns during lob 100 Cement returns to surface? X Yes No Spacer returns? X Yes No Vol to Surf: 60 bbl cmt+spacer Cement In Place At: 21:30 Date: 11/6/2012 Estimated TOC: Surface Method Used To Determine TOC: Cement sample taken&weighed @ surface Cmtg Supv. Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Yield(Ft3/sack): Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): 4.5 Tail Slurry w Type: Yield(Ft3/sack): F Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): 4.5 N Post Flush(Spacer) 0 z Type : Density(ppg) Rate(bpm): Volume: w Displacement: cn Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes No Reciprocated? Yes No %Returns during job Cement returns to surface? Yes No Spacer returns? Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Cmtg Supv. Remarks: Buccaneer Alaska Operations, LLC CASING& CEMENTING REPORT Permit to Drill(PTD) 212 094 Lease&Well No. ADL-391210/391211 NFU#22-35 Date 7-Nov-12 County Kenai Peninsula Bor. State Alaska Co Supv. CASING RECORD Intermediate/Prod TD MD 10700 TVD 9488 Shoe Depth: MD 10673 TVD 9463 PBTD: MD 10580 TVD 9368 Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Flt Shoe 7 BTC 1.64 10,673.00 10,671.36 4 7 26 1-80 BTC 161.20 10,671.36 10,510.16 Flt Collar 7 BTC _ 1.29 10,510.16 10,508.87 264 jts* 7 26 L-80 BTC 10,508.87 10,508.87 0.00 * 'ncludes pup Totals 10,673.00 Csg Supv. Csg Wt.On Hook: na Type Float Collar: Stab-in Float No Hrs to Run: 18.5 Csg Wt.On Slips: <146000 Type of Shoe: Float Casing Crew: Wfd Fluid Description: 9.5 ppg water base mud/ PV 17/ YP 11/ Gels 5-7-9 Liner hanger Info(Make/Model): na Liner top Packer?: Yes X No Liner hanger test pressure: na Lnr Hgr Tech Centralizer Placement: 2 centralizers on btm jt,-1 centralizer every 3 jts to conductor shoe CEMENTING REPORT Preflush(Spacer) Type: Seal Bond Density(ppg) 10 Volume pumped(BBLs) 40 Lead Slurry Type: Class G Blend Yield(Ft3/sack): 2.16 Density(ppg) 12.7 Volume (BBLs/sacks): 298 bbls/776 sx Mixing/Pumping Rate(bpm): 6 Tail Slurry Type: Class G Blend Yield(Ft3/sack). 1.82 1 Density(ppg) 13.5 Volume (BBLs/sacks): 113 bbls/350 sx Mixing/Pumping Rate(bpm). 6 Post Flush(Spacer) cn Type: none Density(ppg) Rate(bpm): Volume' w EL Displacement: Type: Mud Density(ppg) 9.5 Rate(bpm): 6.00 Volume(actual/calculated): 404/408 FCP(psi): 1900 Pump used for disp: Rig pumps Plug Bumped? X Yes No Bump press 3200 Casing Rotated? Yes X No Reciprocated? Yes x No %Returns during job 100 Cement returns to surface? Yes X No Spacer returns? X Yes No Vol to Surf. 15 bblspacer Cement In Place At: 13:00 Date: 12/3/2012 Estimated TOC: near surface Method Used To Determine TOC: 15 bbls spacer back Cmtg Supv. Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Yield(Ft3/sack): Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): 4 5 Tail Slurry Type: Yield(Ft3/sack): L Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): 4.5 u) Post Flush(Spacer) 0 z Type:_ Density(ppg) Rate(bpm): Volume. w Displacement: co Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? Yes No Bump press Casing Rotated? Yes No Reciprocated? Yes No %Returns during job Cement returns to surface? Yes No Spacer returns? Yes No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: / Cmtg Supv. /� Remarks: GJ G e 4.14.1.1.., ) RECEIVED WaalAN 222013--J BAKER PRINT DISTRIBUTION LIST 1 ` COMPANY Armstrong Cook Inlet, LLC INTERMEDIATE FINAL Yes (mandatory) WELL NAME NFU#22-35 RUN NUMBER (mandatory) FIELD North Fork Unit BH SALESMAN Woods,Jim (mandatory) (mandatory) COUNTY Kenai Peninsula Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF mandatory) LOG DATE: November,2012 TODAYS DATE: 1/17/2013 (mandatory) I DISTRIBUTION LIST AUTHORIZED BY: Colby VanDenburg (mandatory) • HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? NA COMPANY CD FIELD FINAL (digital/ __ _ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Ur I'KIN I S #OF COPIES #OF COPIES 1 Armstrong Cook Inlet, LLC 2 2 Attn: Colby VanDenburg 2„ 1421 Blake Street Denver, CO 80202 303 623 1821 2 GMT Exploration Comp 2 1 ATTN: Phil Wood 1560 Broadway 0 Suite 800 1 Denver, Colorado 80202 Phone: (720) 946-3032 3 Dale Resources, LLC 2 1 I —,_I ATTN: Kyle Thompson -- 2100 Ross Avenue Suite 1870 Dallas, TX 75201 Phone: (817) 451-5353 4 Nerd Gas Company, LLC 2 1 1 ATTN: Edie Hardy P.O. Box 3003 441 Landmark Drive Casper, Wyoming 82602 Phone: (307) 234-0583 # e): - --- 5 Alaska Oil &Gas Conservation Commission 1 1 ---H ATTN: Steve Davies 333 W 7th Ave Suite 100 Anchorage, AK 99501 TOTALS FOR THIS PAGE: 0 9 6 0 0 0 TOTALS FOR ALL PAGES: 0 9 6 0 0 0 _ ? t 2'. 4qL Page 1 of 8 Schwartz, Guy L (DOA) From: Stephen F. Hennigan [shennigan@peiinc.com] Sent: Wednesday, December 26, 2012 6:12 AM To: Schwartz, Guy L (DOA); McMains, Stephen E (DOA); Davies, Stephen F(DOA) Subject: RE: PTD 212-094 Summary for Armstrong NFU #22-35 Nabors Rig 99 Weekly Report 12/24/2012 CORRECTION ON ENDING DATE Rbaih Project Manager/Engineer Petroleum Engineers Inc a Hamilton Company 500 Dover Boulevard, Suite 310 I Lafayette, LA 70503 Office: 337-984-2603 Cell: 337-849-5345 From: Stephen F. Hennigan [mailto:shennigan@peiinc.com] Sent: Wednesday, December 26, 2012 9:10 AM To: Guy Schwartz (guy.schwartz@alaska.gov); Steve Mcmains (steve.mcmains@alaska.gov); Stephen F Davies (steve.davies@alaska.gov) Subject: RE: PTD 212-094 Summary for Armstrong NFU #22-35 Nabors Rig 99 Weekly Report 12/16/2012 12/24/12 INSTALL TREE,TEST TREE TO 5000 PSI (OK). RIG RELEASE 12:00 HRS 12-23-12. RIGGING DC DRILL RIG 12/23/12 ATTEMPT TO SET, LEAK W/COMMUNICATION BETWEEN ANNULUS AND TBG, RE ESTABLISI- OF PACKER, STAB IN, RE-SPACE OUT, LAND TBG, RUNING LOCK DOWNS,SET PACKER, TEST- AND ANNULUS, (OK), LID LAND JT. SET BPV, RIG DOWN WEATHERFORD, NIPPLE DN BOPE 12/22/12 CIRC CORROSION INHIBITOR INTO ANNULUS, SPACE OUT AND LAND TBG, RUN LOCK DOW1' ATTEMPT TO SET PACKER, GOT COMMUNICATIONS FR TGB TOO ANNULUS, PULL TBG HANG SECURE CONTROL LINES,SET TBG BACK ON LOCATOR, R/U SLICK LINE CHECK CIRC SLEEVE, SLEEVE, MAKE UP HANGER AND LAND TBG. 12/21/12 POOH, PULL WEAR BUSHING, PICK UP SEAL ASSEMBLY, 79 JTS, SLIDING SLEEVE, 29 JTS, BAK PACKER, 98 JTS, CHEMICAL INJ SUB, 67 JTS, SSSV, 9 JTS, 3 PUP JTS, 1 JT, PUP JT, HANGER.TA AND SPACE OUT, CIRC CORROSION INHIBITOR. 12/20/12 FLOW WELL AS DIRECTED. SHUT WELL IN; BULLHEAD 78 BBLS DOWN TUBING; OPEN PACKE CIRCULATING PORT AND BULLHEAD 50 MORE BBLS. LINE UP DOWN TUBING TAKING RETUI THROUGH CHOKE FOR A COMPLETE HOLE VOLUME; OPEN WELL UP AND CIRCULATE A HOL VOLUME; WELL IS DEAD; POH W/TEST STRING. 12/19/12 REPAIR TOPDRIVE !BOP; CHANGE OUT ENCODER; RIH W/10 STANDS OF 2 7/8 TBG, PU CHAP AND OMNI TOOL, RIH TO 2386';TOOL NOT FUNCTIONING RIGHT; POH AND LD TOOLS. GET PKR AND RIH W/26 STANDS OF TBG TOTAL; PU MS TOOL; RIH TO 6521'. SET PKR AT 5556'; FLOW/TEST HEAD, EXPRO EQUIPMENT,TEST LINES. OPEN MS TOOL; BRING ON WELL. 12/18/12 FINISH REPAIR ON ACTUATOR VALVE. FINISH BOP TESTING UPPER/LOWER TOPDRIVE VALVE 12/26/2012 Page 2 of 8 LEAK ON RISER. ADJUST COVER ON ACTUATOR VALVE. 12/17/12 RUN GUNS ON WIRELINE AND PERFORATE 3 DIFFERENT INTERVALS, RIG DOWN WIRELINE AND SHOOTING FLANGE, NIPPLE UP PITCHER NIPPLE AND FLOW LINE.TESTING BOPE. HAVING ISSUES WITH FREEZING. HYD ACCTUATOR VALVE ON BOPE FAILED, CHANGE OUT SAME. T atries s, /s. / -ei . Project Manager/Engineer Petroleum Engineers Inc a Hamilton Company 500 Dover Boulevard, Suite 310 I Lafayette, LA 70503 Office: 337-984-2603 Cell: 337-849-5345 From: Stephen F. Hennigan [mailto:shennigan@peiinc.com] Sent: Monday, December 17, 2012 6:47 AM To: Guy Schwartz (quy.schwartz@alaska.gov); Steve Mcmains (steve.mcmains@alaska.gov); Stephen F Davies (steve.davies©alaska.qov) Subject: RE: PTD 212-094 Summary for Armstrong NFU #22-35 Nabors Rig 99 Weekly Report 12/16/2012 12/16/12 Flow test well to 08:00. Shut well in and bleed gas off to Expro. Bull head 43 bbls of 8.7 KCL brine down tbg; start circulating conventional but go through choke with bag shut as gas increased before bottoms up; after bottoms up without the choke, slight flow; weight up brine to a solid 8.7 ppg while circulating. Monitor well; OK. POH w/tbg. Rig up shooting flange and Pollard. 12/15/12 FINISH TRIP IN HOLE, CHANGE SAVER SUB, RIG UP WIRE AND CORRELATE, POOH WITH WIRE AND PICK UP PUP JT, SET ON WIRE LINE DEPTH AND CORRELATE AGAIN. CORRELATION GOOD. RIG DOWN WIRE, RIG UP HALLIBURTON FLOW HEAD, FIRE GUNS AND FLOW WELL. EXPRO REPORTS WITH MORNING REPORT. 12/14/12 Flow test well. Shut well in; Rig down Expro; pull up to 5526'to open circulating tool;Tbg pressure 1940 psi; bullhead 38 bbls of 8.7 KCL brine down tbg at 1.5 bpm. Kill well pumping through choke and gas buster. Circulate conventional after well was dead. POH with tubing and RTTS tool. MU TCP's, Champ Pkr and RIH. 12/13/12 Pressure Test Expro lines/equipment; Pick up Pollard Guns and Lubricator and test 500/4000 psi. Shoot perfs f/7040-7074' MD(6 spf/0° phasing/magnetically de-centralized/ 2" hollow carriers) Bring well on; flow back to Expro total of 90. bbls fluid at 05:30. Gas flowing 1.5 mmcf w/145 psi on manifold. Flow Chart in attached file. 12/12/12 Finish testing BOP's. Test plug in 'X' nipple at 9065' to 1000 psi. Rig up and run RTTS packer with wireline entry guide and circulating sleeve. Set RTTS packer at 5529'. Rig up Flow test manifold adding another TIW valve; rig up Expro; Swab well down to 2350'. Rig down Pollard slick line. 12/10/12 POH w/2 7/8 tubing; Stop and weave sash cord around stands to prevent excessive bowing; POH w/2 7/8 tbg. Retrieve all Pollard fishes(cups, Swab mandrel, wireline and strip gun). Rig up and test BOP's. 12/09/12 Fish two swab cups out of hole; attempt to beat other swab cups and tool out of tubing unsuccessful. Unable to go past 8955'; RIH and punch holes in the tubing at 8917-8919'; circulate hole clear; rig down flow manifold; circulate to make sure no gas after pulling out of packer while 12/26/2012 Page 3 of 8 II rigging up WOT; POH w/tubing. Tkeis Project Manager/Engineer Petroleum Engineers Inc a Hamilton Company 500 Dover Boulevard, Suite 310 I Lafayette, LA 70503 Office: 337-984-2603 Cell: 337-849-5345 From: Stephen F. Hennigan [mailto:shennigan@peiinc.com] Sent: Monday, December 10, 2012 10:25 AM To: Stephen F Davies (steve.davies@alaska.gov); Guy Schwartz(guy.schwartz@alaska.gov); Steve Mcmains (steve.mcmains@alaska.gov) Subject: RE: PTD 212-094 Summary for Armstrong NFU #22-35 Nabors Rig 99 Weekly Report 12/09/2012 12/09/12 Swab well with slickline to 2400'. RIH with perf guns and shoot perfs at 9177-9198' and 9159- 9177'on two runs. The line got jammed in the stuffing box and was pulled into with the rope socket at 69'. RIH w/gauge ring/2.375" to 9065'; RIH w/LIB to make sure nothing was there to 9065'. Start swabbing well with fluid at 700' on initial run. Swab tool broke; prep to fish swabs 12/08/12 Test Flow manifold and lines to Expro; Pick up lubricator and first set of guns and test again to 4200/350 psi. Run in hole and shoot perfs at 4 different intervals. Fluid in tubing moved from 2350' to approximately 1600. No pressure.Swab 12/07/12 Finish RIH w/2 7/8 Tbg. Space out; Rig up and swab 14 BBLs of brine from tubing(2400'); Install Master Valve in Flow manifold; Rig up lines to Expro. Continue with Expro rig up away from rig. 12/06/12 Rig up and make up 7" X 2 7/8" F-1 packer and seal bore extension with tubing tail/X profile nipple &wireline re-entry guide. RIH with Pollard wireline and set at 9040'. Rig up and run 2 7/8-8RD EUE tubing and seal assembly. 12/05/12 Rig up and run CBL with Pollard; Load pipe shed with 300 jts of 2.875" tubing; strap same. Change bottom rams to 2.875" and top rams to 2.875" X 5"variables. Rig up and test BOP's with Bob Noble as AOGCC witness (4 hours test time) Prepare for 2 7/8 completion 12/04/12 Circulate the hole while cleaning pits; displace to 6% KCI brine at 10,581'; POH laying down drill pipe, BHA, scraper and mill. 12/03/12 Rig up Baker Hughes cementers and pump cement job; displace with 404 bbls of fresh water. Rig down cementers; pick up 7" casing packoff and install;Test to 5000 psi. Set short wear ring, rig down stabbing board, long bales; pick up short bales. Make up casing scraper and 6" bit; RIH.Tag cmt at 10580'-Cleaning pits 12/26/2012 Page 4 of 8 c5ftefriew /st ttel0;1-emote-law Project Manager/Engineer Petroleum Engineers Inc a Hamilton Company 500 Dover Boulevard, Suite 310 I Lafayette, LA 70503 Office: 337-984-2603 Cell: 337-849-5345 From: Stephen F. Hennigan Imailto:shennigan@peiinc.com] Sent: Monday, December 03, 2012 6:11 AM To: Stephen F Davies (steve.davies@alaska.gov); Guy Schwartz (quy.schwartz@alaska.gov); Steve Mcmains (steve.mcmains@alaska.gov) Subject: RE: PTD 212-094 Summary for Armstrong NFU #22-35 Nabors Rig 99 Weekly Report 12/02/2012 12/02/12 Rig up and run 7" casing. Land 7" hanger in well head. Prepare to cement. 12/01/12 Make wiper trip to bottom. Circulate hole; pump weighted-HV sweep. Make a 4 std wiper trip; circulate hole clean; spot a 100 BBI Lotorq pill on botttom; POH. Lay down entire BHA. Change out 7" rams in top set of BOP rams;test 250/4000 psi. Make a dummy run on 7" landing jt. Rig up to run 7" casing. 11/30/12 Finish laying down BHA; LWD, motor, MWD, sources. RU and test BOP's. Make up new cleanout BHA and RIH to 5000'; break and make conn not done on previous trip. Work through tight spots as needed. 11/29/12 DRLG 88'TO TD @ 10,700', CIRC&CONDITION MUD, POH, (FOUND DAMAGED TOOL JOINTS, BROKE,CLEANED, & REDOPED ALL DP CONNECTIONS), L/D BHA 11/28/12 DRLG AHEAD, MADE 502' of NEW HOLE, HIGH TORQUE-RUNNING 18 TO 20 K 11/27/12 DRILLING AHEAD 510' NEW HOLE,TORQUE CONSISTENT AT 18-20 K 11/26/12 DRILL TO 9553', WIPER TRIP,TIGHT @8126', DRLG AHEAD TO 9600' r4adf 64140 5.ftetgej04/.emettjga-of Project Manager/Engineer Petroleum Engineers Inc a Hamilton Company 500 Dover Boulevard, Suite 310 I Lafayette, LA 70503 Office: 337-984-2603 Cell: 337-849-5345 From: Stephen F. Hennigan [mailto:shennigan@peiinc.com] Sent: Monday, November 26, 2012 9:19 AM To: Stephen F Davies(steve.davies@alaska.gov); Guy Schwartz (guy.schwartz@alaska.gov); Steve Mcmains (steve.mcmains@alaska.gov) Subject: RE: PTD 212-094 Summary for Armstrong NFU #22-35 Nabors Rig 99 Weekly Report 11/25/2012 11/25/12 DRILLING AHEAD at 9205', BACK TO VERTICAL @ 8900' RIH TO SHOE,TEST MWD,CUT&SLIP DRLGLINE,C/O SAVER SUB,CALIBRATE BLOCK HIEGHT&MWD, C/O 12/26/2012 Page 5 of 8 11/24/12 ENCODER ON TOP DRIVE, RIH CIRC B/U @ 5200'&700',WASH&REAM 100'to 8418' DRLG AHEAD DRILLED AND ATTEMPTED TO KEEP GETTING SIGNAL FROM MWD NO SUCCESS WITH SIGNAL POOH FOR TOOLS HOLE IN GOOD SHAPE WORK BHA'S BOTH DIRECTIONS CULLED SOME PIPE WITH HARDBAND WORN 11/23/12 OFF DRILLING AHEAD FROM 7585'TO 8316'-HAVING SOME COMMUNICATION ISSUE WITH DOWNHOLE TOOLS, 11/22/12 RESET COMMANDS AND REBOOT TEST BOP EQUIP, P/U BHA#4, RIH,CIRC BTTM/UP @ 3062'&5650'.GOT 370 UNITS GAS ON BTTMS/UP @5650', 11/21/12 GAS 536 UNITS ON BTTMS UP @7560', DRLG AHEAD @ 7585' WIPER TRIP TO 6092', HOLE SLICK, DRLG 35', CIRC&CONDIT MUD F/TRIP, POH F/BOP TEST&DRLG TOOLS. L/D BHA, PULL WEAR BUSHING.TEST BOP EQUIPEMENT,250 PSI LOW,4000 PSI HIGH,ANULAR 250 PSI LOW, 2500 11/20/12 PSI HIGH 11/19/12 DRLG 7250'START CURVE BACK TO VERTICAL DRLG TO7525, PUMP SWEEP,WIPER TRIP BACK TO 6092' rkes s, /s, /arur, .e.p Project Manager/Engineer Petroleum Engineers Inc a Hamilton Company 500 Dover Boulevard, Suite 310 I Lafayette, LA 70503 Office: 337-984-2603 Cell: 337-849-5345 From: Stephen F. Hennigan [mailto:shennigan@peiinc.com] Sent: Monday, November 19, 2012 10:12 AM To: Stephen F Davies (steve.davies@alaska.gov); Guy Schwartz (guy.schwartz@alaska.gov); Steve Mcmains (steve.mcmains@alaska.gov) Subject: RE: Summary for Armstrong NFU #22-35 Nabors Rig 99 Weekly Report 11/18/2012 11/18/12 DRILL TO 6098'WIPER TRIP UP TO 4577'(HOLE SLICK)CONTINUE DRILL TO 6625' 11/17/12 DRLG AHEAD 890'NEW HOLE DRLG 3622'TO 4576'.CIRC&COND F/WIPER TRIP,WIPE TRIP TO SHOE,TIGHT @ 3420'25K OVER, DRLG 4576' 11/16/12 TO 4630' POH and LD 9 875"Bit Pick up new bit&BHA with motor, MWD and LWD Load sources, shallow function test tools RIH 11/15/12 to 2958', PU kelly up and circulate/wash to bottom Drill to 3325'at midnight Test BOP bottom rams Rig down test equipment, blow down all lines, choke manifold,etc Pick up 9 875"bit,sub,XO and HWDP,RIH Tag FC/cement at 2948',CBU and test casing Test 3000 psi for 30 min Drill to 3025',circulate hole clean for 11/14/12 leak off test Riq up and perform a Leak off Test to 16 17 ppge Wait on Single gate rams to arrive Pick up 75 jts of DP,stand back in derrick Raise stack, remove single gate, install new 11/13/12 single gate Install riser and flowline PU DP and rack back in derrick RU and test BOP's Failure on bottom rams, 1 side of ram failed to close, after raising manifold psi to 1900 the ram functioned All other components tested Rams&choke Manifold 250/4000 psi-Annular 11/12/12 250/2500 psi Tie c942.60, Oteeceio;fut,tiff.aof Project Manager/Engineer Petroleum Engineers Inc a Hamilton Company 12/26/2012 Page 6 of 8 500 Dover Boulevard, Suite 310 I Lafayette, LA 70503 Office: 337-984-2603 Cell: 337-849-5345 From: Stephen F. Hennigan [mailto:shennigan©peiinc.coml Sent: Monday, November 12, 2012 10:15 AM To: Stephen F Davies (steve.davies@alaska.gov); Guy Schwartz (quy.schwartz@alaska.gov); Steve Mcmains (steve.mcmains@alaska.gov) Subject: RE: Summary for Armstrong NFU #22-35 Nabors Rig 99 Weekly Report 11/11/2012 11/05/2012 Drill f/2230 to 3005' TD surface hole- Circulate hole; pump HV sweep. 11/06/2012 Circulate the hole clean; pump HV sweep w/Nut Plug, circculate clean. Make a wiper trip to the HWDP. RIH slick to bottom, circulate the hole clean seeing no increase in cuttings with another HV sweep. POH; LD BHA. RU and run 10 3/4 casing. 11/07/2012 Finish RIH w/10 3/4 csg. RU and RIH w/5" DP and stab in sub. Circulate hole while rigging up Baker Cementers. Cement and displace; pump wiper dart and 55 bbls of mud through DP. RU and start laying down 5" DP- Back lash drlg line-Work on drlg line/ drawworks. 11/08/2012 Fix backlash. Laydown 5" DP: clear floor of false rotary, decking, misc tools. Unbolt diverter system and clean components while rigging down. Rough cut 10 3/4 csg, remove bell nipple and diverter bag. Install VETCO Multibowl wellhead. 11/09/2012 Finish welding on Vetco Multi-bowl, test void to 1970 psi (good test) Nipple up 11 X 5000 PSI BOP's. Backhaul 5" DP, Load 4" DP in pipe shed. Start mixing new mud. 11/10/2012 NU 11 X 5000 psi stack. Readjust stack to hook up koomey lines. Cut and fit flow riser 3 times due to the way the sub is built and flow line comes into riser. Sand location and run loaders over traffic areas for traction after the rain. 11/11/2012 Pick up 90 joints of 4" DP; circulate hole to condition mud for CBL; rack back DP. RU and run CBL with Pollard. Good cement bond. Change out saver sub, install wear bushing. Pick up 90 jts of DP and rack back. 12/26/2012 Page 7 of 8 T S4 I€. /s. .e/of, s Project Manager/Engineer Petroleum Engineers Inc a Hamilton Company 500 Dover Boulevard, Suite 310 I Lafayette, LA 70503 Office: 337-984-2603 Cell: 337-849-5345 From: Stephen F. Hennigan (mailto:shennigan@peiinc.com] Sent: Monday, November 05, 2012 12:25 PM To: Stephen F Davies (steve.davies@alaska.gov); Guy Schwartz (quy.schwartz@alaska.gov); Steve Mcmains (steve.mcmains@alaska.qov) Subject: RE: Summary for Armstrong NFU #22-35 Nabors Rig 99 Weekly Report 11/04/2012 10/29/2012 SET SUB IN AND LEVEL,SET PUMPS, GEN, BOILERS, DOG HOUSE,TOOL ROOM, DRLG LINE SPOOL, A-LEGS, SET CROWN IN, STRING UP ODS MAN RIDER,STRING UP&SPOOL DRLG LINE ON DRUM, SET MUD PITS 10/30/2012 RIG UP LINES F/ DERRICK, INSTALL DERRICK BY SECTIONS, HANG BOARD, FINISH SET PITS, P/U TOP DRIVE & MD80, HOOK UP SERICE LINES,TAKE ON FUEL&WATER, HANG WIND WALLS ON FLOOR,START SET PIPE SHED 10/31/2012 Rig up; cut conductor, install and test starter head and start nipple up on diverter 11/01/2012 After diverter was rigged up, had to cut conductor below starting head and add 8 .25 in to allow alignment to diverter line in pipe shed - Finish dressing pumps with 6" liners and swaps- Finish plumbing pits and start mixing mud 11/02/2012 Finish welding conductor. Cut and fit flow nipple. Finish installing diverter sections for 75' radius clearance. Function Test diverter system. PU and rack back DP and HWDP. Finish mixing spud mud. Pressure test lines; test mud pumps. PU BHA. Canrig installing "RIG WATCH" and checking pvt, gas detectors, and general rig up for logging unit. 11/03/2012 Spud well at 06:15 AM; DrI f/140'to 1170' at midnight. Start KO at 750' building 2.5° per hundred. Drill to 1390' at 06:00 with 15.31°angle built. 11/04/2012 Drill to 2009'. Make a wiper trip to the collars. Continue drilling to 2230'. Tams Project Manager/Engineer Petroleum Engineers Inc a Hamilton Company 12/26/2012 Page 8 of 8 500 Dover Boulevard, Suite 310 I Lafayette, LA 70503 Office: 337-984-2603 Cell: 337-849-5345 From: Stephen F. Hennigan [mailto:shennigan@peiinc.com] Sent: Monday, October 29, 2012 8:23 AM To: Stephen F Davies (steve.davies(aalaska.gov); Guy Schwartz (quy.schwartz@alaska.gov); Steve Mcmains (steve.mcmains@alaska.gov) Subject: First Summary fo Armstrong NFU #22-35 Nabors Rig 99 Weekly Report 10/28/2012 10/26/2012 First rpt. 18 HRS: RIGGING DOWN, REMOVED TOP DRIVE AND RAIL, BRIDLED UP TO BOOT STRAP DERRICK DOWN. 10/27/2012 24 HRS DEMODE: SET DERRICK OUT IN SECTIONS,SET CROWN & BLOCKS OUT,SPOOL UP DRLG LINE ON REEL, SPOOL UP ALL MANRIDER, TUGGER LINES OUT OF DERRICK, SET A-LEGS OFF RIG. 10/28/2012 24HRS: SET RIG OUT, PICK UP MAT BOARDS OFF 23-25, PICK UP AND DISCARD HERCULITE OFF 23-25, LEVEL PAD @ 22-35, SPREAD FELT AND HERCULITE OUT FOR THE SUB SET MATTING BOARDS FOR 22-35. auk Project Manager/Engineer Petroleum Engineers Inc a Hamilton Company 500 Dover Boulevard, Suite 310 I Lafayette, LA 70503 Office: 337-984-2603 Cell: 337-849-5345 12/26/2012 Permit#: 212 094 NFU #22-35 API#: 231-20038-00-00 588' FSL, 1571' FEL Prop.Des:ADL-391210/391211 S26 T4S R14W S.M. KB elevation: 679' (21'AGL) Latitude: 59*47'46.3626"N--1 Longitude: 151*37'45.2584"W Armstrong Cook Inlet,LLC Spud: 111-2-2012 TD: 111-28-2012 �. Riq Released: Structural Pipe ____a3 i - 16" X-56 84 ppf Top Bottom r 0M Surf 120' TVD Surf 120' I' I Ili ,` Baker SSSV set @ approx.350' Surface Casing li,..\ MD. Pollard Chemical In]. 10-3/a L-80 45.5ppf Nipple set @ 2500' MD. T(1)_,-)80 op Bottom MD 0' 3,000' 2 7/8"8RD EUE-M TVD 0' 2,750' Production Casing 7" L-80 26 ppf Top Bottom N MD 0' 10,750' II it TVD 0' 9,800' I* . Tum �.) 2 7/8" L-80 6.4 ppf t I try Top Bottom MD 0' 5600' TVD 0' 4817 L.lic , it i�---1 Baker FH Packers set at approx. Jr-- 5600'MD 4817'TVD +p� Baker Sliding Sleeve set at approx. / 5640'MD 4849'TVD .. 7c,•Eo-767K' 10/3-4952-4i Proposed Perforations fit(t.c_ Lit111M 4) Measured Depth True Vertical Depth 9040'MD 7828'TVD Upper Interval P5653-5681' 4859-4881' 5707-5714' 4902-4908' 6528-6575' 5556-5594' _ ' 7040-7074' 5965-5992' 8013-8024' 6813-6824' Lower Interval ^-\ 9159-9198' 7947-7986' ' 9221 -9234' 8009-8023' 9274-9282' 8062-8070' ,aiiiiri . TD PBTD II11,017'MD 'MD 9,800'TVD 'TVD Well Name&Number: North Fork Unit#22-35 _ Lease. Kenai Loop — County or Parish: Kenai Penisula Borough State: Alaska Country: USA Perforations(MD): Perf(TVD): Angle @KOP and Depth K>P TVD Date Completed: RKB: 21' Prepared By: Craig Rang Last Revision Date: December 6,2012 &fp?'OF I j/j�s� THESTATE A A Alaska Oil and Gas �0 � O�i L a����� �i i 0 0 -_----.4* Conservation Commission 'ift •tt_ _ --- Z'"... -rM GOVERNOR SEAN PARNELL 333 West Seventh Avenue OpALAS�� Main: 90 Anchorage, 972079.3572 433 Fax: 907.276.7542 Edward Teng ata- ��1 t a- © 1 Lt Vice President - Engineering Armstrong Cook Inlet, LLC 1421 Blake Street Denver, CO 80202 Re: North Fork Field, Undefined Gas Pool, North Fork No. 22-35 Sundry Number: 312-458 Dear Mr. Teng: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /°-)4L/v,---- l'el4i Cathy . Foerster Chair DATED this (pay of December, 2012. Encl. RECEIVE \� STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ° APPLICATION FOR SUNDRY APPROVALS 7 DECc �gZ%61%/ Z �y 20 AAC 25.280 AOGCC 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations❑ Perforate Q • Pull Tubing❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Prepare Well for Prod.171, 2.Operator Name. 4.Current Well Class: 5.Permit to Drill Number Armstrong Cook Inlet,LLC Exploratory ❑ Development 0 212 094 , 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 1421 Blake St,Denver,CO 80202 50- 231-20038 00 00 1 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 663 ' North Fork No. 22-35 I Will planned perforations require a spacing exception? Yes ❑ No ❑., 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL-391210/391211 Undefined gas 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): 10700' 9,538' 10,589'est 9,377' Casing Length Size MD TVD Burst Collapse Structural 140' 16" 140' 140' na na Conductor Surface 3000' 10 3/4" 3000' 2746' 4230 2470 Intermediate Production 10700' 7 " 10700' 9,488' 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): see attached WBD see attached WBD 2 7/8" L80 5600' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SSSV 2500'MD 2347'MD Packer-Baker FH SSSV-Baker TE-5 Packer 9100'MD 7,888'TVD Packer 5600'MD 4817'TVD 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program E BOP Sketch ❑ Exploratory E ' Stratigraphic❑ Development❑ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: December 4,2012 Commencing Operations: Oil ❑ Gas ❑✓ • WDSPL ❑ Suspended ❑ 16 Verbal Approval: Date: /Z. 1/./Z WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative. ```� S1 ---'__ GSTOR El SPLUG ❑ 17. I hereby certify that the foregoing isltrue and correct to the best of my knowledge. Contact Stephen Hennigan Email/PH shennlgan(C�peiinc.com (337)849-5345 Printed Name Edward Teng Title Vice President-Engineenng Si;;r.,i,"�-- 1 Phone Date �� (303)623-1821 November 29,2012 - � i • --'� COMMISSION USE ONLY Conditions of approval: Notify Comm" sion so that a representative may witness Sundry Number: ' (15$' Plug Integrity ❑ BOP Test LYS Mechanical Integrity Test ❑ Location Clearance ❑ Other. ` V riFi .vkc DEC 0 6 20:icin_ Spacing Exception Required? Yes ❑ No 2 Subsequent Form Required: /0 —LID 7 1_,...,,j rr / APPROVED BY Approved by: /Q 'A / / COMMISSIONER THE COMMISSION Date: /Z -Cy _ 7 L Submit Form and Form 10-403( e s d�0 oG I NAtc r application is valid for 12 months from the date of approval. m tsinDuplicateJ \V RR lz-wr>✓ �z �� ry,tti A EC D DEC ( ARMSTRONG ('00x hole!,LL(' AOG'� November 30, 2012 Ms. Cathy Foerster, Chair R-i ED Alaska Oil and Gas Conservation Commission _ 333 West 7`"Avenue, Suite 100 Dt `_�12 Anchorage, AK 99501 AO G CC OGCC RE: Request for Sundry Approvals to complete Armstrong Cook Inlet, LLC NF#22-35(PTD No. 212-094) Dear Ms. Foerster, Armstrong Cook Inlet, LLC hereby applies for Sundry Approval to complete and test the subject well. • The well was drilled to test the production potential of the Lower Tyonek sands near Anchor Point on the Kenai Peninsula. Total depth was reached on November 29, 2012 and the hole is presently being conditioned to run 7" production casing. Armstrong's completion prognosis calls for multiple intervals in the Tyonek to be completed using conventional thru tubing wireline guns to perforate, swab and then flow test. Additional zones of interest will be added with additional wireline perforations, swabbing and then flow testing. This will be repeated until all zones of interest are tested, then co-mingled to be put on production through 2 7/8"tubing.. A production packer is scheduled to be set @ approx. 5600' MD with 2-7/8" production tubing back to the surface. A subsurface safety valve(SSSV) is scheduled to be installed in the tubing string at 350' MD and a chemical injection nipple with dual check valves set at 2500' MD. If you have any questions or require additional information, please contact me at(303)623-1821 or Stephen Hennigan at(337) 849-5345. Sincerely, Edward Teng Vice President-Engineering Armstrong Cook Inlet, LLC Enclosures Cc: Stephen Hennigan— Petroleum Engineers for Armstrong Cook Inlet, LLC Craig Rang—All American Oilfield i), ii t9 (. i i \(,'(J_ /303,-()2,;-- Ili i_tii l_i Permit#: 212 094 ' NFU #22-35 API#: 231-20038-00-00 Prop. Des: ADL-391210/391211 588' FSL, 1571' FEL • KB elevation: 679' (21'AGL) S26 T4S R14W S.M. Latitude: 59"47'46.3626"N Longitude: 151*37'45.2584"W Spud: 11-2-2012 Armstrong Cook Inlet, LLC ' TD: 11-28-2012 II!Y T I Rig Released: Structural Pipe -$ 16" X-56 84 ppf x r Top Bottom .0 y I " 1MD Surf 120' TVD Surf 120' r III f, 1 1.6 Baker SSSV set @ approx.350' Surface Casing ' E. / MD. Pollard Chemical In 10-3/4" L-80 45.5ppf i, \ \ j' Top Bottom Nipple set @ 2500' MD. MD 0' 3,000' 2 7/8"8RD EUE-M TVD 0' 2,750' It. Production Casing 10p 7" L-80 26 ppf Top Bottom lk \ 1 11 MD 0' 10,750' TVD 0' 9,800' II I Tubing • 2 7/8" L-80 6.4 ppf �£+ I Top Bottom MD 0' 5600' I , TVD 0' 4817 I _ �� ar Baker FH Packers set at approx. '015600'MD 4817'TVD 9100'MD 7888'TVD == I I Baker Sliding Sleeve set at approx. 5640'MD 4849'TVD 11111). 14 Proposed Perforations i Measured Depth True Vertical Depth Upper Interval e s� �, P c v ( �l 5654-5680' 4860-4881' tt II .yin .)-6530-6580' 5558-5598' Cr [Oo 7040-7074' 5965-5992' • 016-8023' 6816-6823' *'k is I Lower Interval 9160-9198' 7948-7986' I 9226-9233' 8014-8024' .•1 9234-9236' 8022-8024' 9290-9299' 8078-8087' I-= TD PBTD 11,017'MD 'MD 9,800'TVD 'TVD Well Name&Number: North Fork Unit#22-35 Lease: Kenai Loop County or Parish: Kenai Penisula Borough State: Alaska Country: USA Perforations(MD): Perf(TVD): Angle @KOP and Depth: Angle @ Perfs: KOP TVD: Date Completed: RKB: 21' Prepared By: Craig Rang Last Revision Date: November 29,2012 Armstrong Oil and Gas 1421 Blake Street, Denver, Colorado 80202 Well: NFU 22-25 588'FSL X 1571'FEL S26-T4S—R14W Kenai Peninsula Burrough,Alaska Well History- Second of two wells drilled in the 2012 drilling program on the Kenai Peninsula of Alaska. The drilling prognosis calls for two intervals with multiple zones of interest in each interval to be completed using conventional wireline guns to perforate,swab and then flow test. Additional zones of interest will be added with additional wireline perforations, swabbing and then flow testing. This will be repeated until all zones of interest are tested, co-mingled, isolated then moving up to the second interval. The second interval will be completed in a similar manner then placed on production with production coming through a packer for the lower interval and a sliding sleeve in the production tubing for the upper interval. Drilling commenced on November 2, 2012;with completion scheduled 30 days after drilling commences. Surface casing is sixteen (16) inch drive pipe set at 140' wireline depth. The intermediate casing string is 10%" set at 3000' MD or 2750'ND and cemented back to surface. The production string is 7" 26# N80 set at 10,700' MD or 9,488'ND. The 7 in casing is cemented with sufficient cement to cover all zones of interest for hydraulic isolation. The intermediate and production casing strings will be MIT tested by the drilling rig prior to commencing the well completion/testing. No variances are requested. North Fork Unit 22-35 Well Completion Procedure Cement should have 24 hours curing time from time the top plug bumped collar. Note: do not pump down the top plug with drilling mud. Pump down plug with fresh water. Perform rig maintenance. 1. Run bit and scraper on 4-1/2" drill pipe from surface to TD—10,497' MD. Casing is 7"—26# N80 with a Buttress Thread Connection—Modified (BTC-M). Drift ID is 6.151" 2. Circulate out any drilling mud or cement removed by the bit and scraper run. Displace w/8.7 KCL and POOH. 3. Rig up Expro testing. Wellhead connection is 1502 union to Pollard Wireline connection. 4. Run Pollad Wireline CBL/GR tied into OH logs. Evaluate cement bond. If bond good, continue with step 5,otherwise prepare to squeeze cement(supplemental procedure). 5. Run 2-7/8" 8RD EUE-M production tubing into hole with Baker Sliding Sleeve (In closed `o,..,.. Pli- position) above Baker FH production packer, "XN" profile and wireline re-entry guide. Set packer at 9100' MD. 6. RU Pollard slickline swabbing unit for 2-7/8"8RD tubing 7. Swab 2-7/8"tubing down to sufficient depth to maintain 1000#underbalance of formation pressure. Example: First interval to test is 9290—9299' MD (8078—8087'ND). 6%KCL completion fluid weight(8.7#)x.052 x 8087'ND= 3659 PSI expected pressure of formations. To reduce hydrostatic pressure by 1000#=8.7#x.052 x 2210'ND (2331' MD), swab down tubing from surface to 2331' MD 8. Rig up wireline to perforate first interval of interest. Pressure test lubricator and wireline BOP to 1.5 times the maximum anticipated shut in pressure. (Example MASP= 3659#x 1.5= 5000 psi). Be sure to test the connection to the rig BOP's. Maintain the 5000#of pressure for 15 minutes with no more than 50#loss. If pressure loss is greater than 50#, determine leak, repair and retest until results are satisfactory. Tie wire-line perforation guns into OH logs using gun GR and CCL. Perforate using 2" 6 spf, 0 degree phasing magnetically de-centralized, deep penetrating hollow carrier guns from 9,290' -A I . MD to 9,299 'MD. 9. Attemp t` yell through Expro flow back equipment and tanks. Monitor fluid level in tanks. In the event,well will not flow, proceed with step 10. 10. Rig up Pollard Wireline slickline unit and proceed to swab 2-7/8" inch tubing. Monitor fluid level to determine fluid entry. Continue to swab well until conclusive fluid or gas entry is determined. If gas entry into well, continue to next interval beginning at step 8. 11. In the event of a fluid entry, rig up Pollard Wireline to set a through tubing bridge plug within 50 feet of the top of the interval making water. 12. Using the Pollard Wireline slickline unit swab the 2-7/8"tubing to maintain the 1000# underbalance. Roughly 2300' of 2-7/8"tubing needs to be swabbed. • 13. Continue perforating intervals of interest as in Step 8. The next zone of interest is 9226'—9233' # Z. and 934—9236' MD combined in one ten foot interval and 9160—9198' MD. All zones completed through tubing will be perforated with 2" hollow carrier 0 deg phasing, magnetically de-centralized 6 spf guns. 14. Once all intervals of interest have been shot and tested, Rig Up Pollard Slickline to set an — plug in the profile below the packer set at 9100'MD. Bleed off 1000#of pressure at surface to determine plug is not leaking. 15. Pull tubing out of seal assembly. If there is a problem pulling the seal assembly out of the packer PBR,the sliding sleeve can be opened via slickline to equalize the pressures in the tubing and the annulus. Pull tubing out of hole. 16. Upper interval. Prepare to run tubing completion. Bottormeftu ng will be seal assembly t at ha- -. . . - .•. ' use, •I o tu•ing, si.ings --.- • -. .. •. . •• 2049=-aftatbing,RIH with 5500'of tubing. Rc4' "t- PK- w;(( i c. -tQt- t3' ' ' - 17. Perforate zones of interest in the upper interval using the same procedures as step 8—13.All zones will be perforated using the 2" hollow carrier,0 deg phasing, magnetically de-centralized, 6 spf guns. Interval of interest are listed on the WBD. 18. Once all intervals of interest have been shot and tested,well will be killed with kill fluid of sufficient weight to hold back formation pressure. (Example: Well head pressure=2300 psi and downhole pressure should be approx. 3000# 6%KCL has a density of 8.7#/gal x.052 x 6823'TVD= 3087#). Fluid level will be back to surface in order to kill this pressure with this weight of fluid. P b PK/2 loss-c. a. (2 (-f ,ilA 19. Use rig to run 2 7/8" production tubing wireline re-entry guide, seal assembly,sliding sleeve in closed position, "X" profile with "X" plug installed and 7"X 2 7/8" packer. Install chemical injection nipple at 2500 feet MD and SSSV at 350' MD 20. Sting into lower packer at 9100' MD and set upper packer at 5600" � Z'S-°t).S o 21. Install tree and BPV L—�y p T. �� 22. Move rig off welldt.4} 23. Pull BPV /36 24. RU Pollard Wireline to swab well in 25. Remove "X" plug from upper packer and open sliding sleeve. 26. Flow upper interval to clean up. Swab well if necessary. Close sliding sleeve. 27. Remove "XN" plug from lower packer 28. Flow lower interval to clean up. Swab well if necessary. 29. Place well onto production . Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, December 04, 2012 3:48 PM To: 'Stephen Hennigan'; Ferguson, Victoria L (DOA) Cc: Davies, Stephen F(DOA) Subject: RE:Armstrong 22-35 Sundry for Completion (PTD 212-094) Steve, You have verbal approval to complete well NF 22-35 as proposed in your sundry application. Sundry number is 312-458. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) Original Message From: Stephen Hennigan [mailto:shennigan@peiinc.com] Sent: Tuesday, December 04, 2012 9:52 AM To: Ferguson, Victoria L (DOA) ; Schwartz, Guy L (DOA) Subject: Armstrong 22-35 Sundry for Completion Re Same we will deliver this afternoon. We finally found the equipment we needed based on G&G perf calls - took a while for them too. We may need a preliminary verbal to start as we may have a rig waiting Would you have a couple of min this afternoon so we can discuss 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF Armstrong ) Docket Number: CO-12-16 Cook Inlet, LLC for an exception to the ) Conservation Order No. 663 spacing requirements of 20 AAC 25.055 to ) drill and complete a development gas well ) North Fork Unit No. 22-35 within the same governmental section and ) Development Gas Well within 3,000 feet of wells that are, or may ) North Fork Undefined Gas Pool be capable of, producing from the same ) North Fork Unit pool. ) Kenai Peninsula Borough, Alaska ) September 27, 2012 IT APPEARING THAT: 1. By letter received June 14, 2012, Armstrong Cook Inlet, LLC (Armstrong) requested an exception to the spacing provisions of 20 AAC 25.055 to allow drilling and completion of the planned North Fork Unit No. 22-35 (NFU 22-35) development gas well within the same governmental section and within 3,000 feet of wells that are, or may be capable of, producing from the same pool. 2. On August 6, 2012, by certified mail, Armstrong sent notice of the application to all owners, landowners, and operators of all properties within 3,000 feet of the planned NFU 22-35 well. Armstrong provided the AOGCC the notice, date of mailing, addresses to which the notice was sent, and proof of mailing. 3. Pursuant to 20 AAC 25.540, the AOGCC tentatively scheduled a public hearing for September 26, 2012. On August 21, 2012, the AOGCC mailed printed copies of the notice of the opportunity for public hearing to all persons on the AOGCC's mailing distribution list, published notice of the opportunity for that hearing on the State of Alaska's Online Public Notice website and on the AOGCC's website, and electronically transmitted the notice to all persons on the AOGCC's email distribution list. On August 22, 2012,the notice was published in the ANCHORAGE DAILY NEWS. 4. No protest to the application or request for hearing was received. 5. The tentatively scheduled public hearing was vacated on September 13, 2012. 6. Because Armstrong provided sufficient information upon which to make an informed decision, the request can be resolved without a hearing. Order 663 September 27,2012 Page 2 of 3 FINDINGS: 1. Armstrong is the operator of the North Fork Unit and the planned NFU 22-35 development gas well, which are located in the Kenai Peninsula Borough,Alaska. 2. NFU 22-35 will be an onshore, deviated development gas well with a surface location 588' from the south line and 1,573' from the east line of Section 26, TO4S, R14W, Seward Meridian (S.M.). The estimated top of the productive interval is 2,601' from the north line and 1,372' from the west line of Section 35, TO4S, R14W, S.M. The projected bottom-hole location is 2,601' from the north line and 1,372' from the west line of Section 35, TO4S, R14W, S.M. 3. NFU 22-35 will be located within State of Alaska leases ADL-391210 and ADL-391211. 4. Other potentially affected owners, landowners, and operators—those within a 3,000-foot radius of the well—are the State of Alaska; Armstrong; Dale Resources Alaska, LLC; GMT Exploration Company LLC; Jonah Gas Company, LLC; and Nerd Gas Company, LLC. Armstrong sent notice of its application to these entities by certified mail on August 6, 2012. 5. Development gas well NFU 32-35 currently produces within 3,000 feet of, and within the same governmental section as, the planned well NFU 22-35. Armstrong plans to drill additional gas development wells within this same governmental section. 6. The reservoir sands accessed by NFU 22-35 are discontinuous fluvial sands. 7. The AOGCC received no comments, objections or protests in response to the public notice regarding NFU 22-35 or to the notification sent by Armstrong to all known owners, landowners and operators within 3,000 feet of NFU 22-35. CONCLUSIONS: 1. An exception to the well spacing provisions of 20 AAC 25.055(a)(4) is necessary to allow drilling and completion of the NFU 22-35 development well in gas reservoirs in order to maximize recovery of reserves. 2. NFU 22-35 will recover reserves that are not accessible to other existing wells. 3. A spacing exception to allow drilling and completion of NFU 22-35 is consistent with sound engineering and geoscience principles and will not result in waste or jeopardize correlative rights of adjoining or nearby owners. 4. An exception to the requirements of 20 AAC 25.055(a)(4) will not promote waste or jeopardize correlative rights. Order 663 September 27,2012 Page 3 of 3 NOW THEREFORE IT IS ORDERED: Armstrong's June 14, 2012 application for an order granting an exception to the well spacing provisions of 20 AAC 25.055(a)(4) to allow drilling and completion of the NFU 22-35 development gas well is hereby approved. Armstrong may proceed with regular production as long as it complies with the terms of the North Fork Unit Agreement, applicable Alaska laws, and all other legal requirements. DONE at Anchorage, Alaska and dated September 27, 2012. ....` /71/ 9:4.6,,,Lize„......_ 0 P. %% Cathy P/Foerster Daniel T. Seamount, Jr. Chair, Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE i As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the AOGCC grants for good cause shown,n person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to he erroneous The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon dental,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days alter the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days atter the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or deciston on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. As provided in AS 31 05.080(b),"[t]he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above,the date of the event or default atter which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5'00 p.m.on the next day that does not fall on a weekend or state holiday. "OiII:„.4Nti ! ,� V V Villi •-4 9TION"' MEMO = PETROLEUM ENGINEERS, INC. A Hamilton Company www.hamiltongroup.org Lafayette Houston 500 Dover Blvd., Ste. 310 337.984.2603 Main 777 Post Oak Blvd., Ste.400 713.975.1971 Main Lafayette, LA 70503 337.984.0854 Fax Houston,TX 77056 713.975.6271 Fax AOGCC 333 W. 7th Ave, Suite 100 Anchorage,AK 99501 (907)793-1221 TO: FROM: Stephen Hennigan for Armstrong Cook Inlet, LLC DATE: August 14,2012 SUBJECT: Armstrong Cook Inlet, LLC 10-407 '33 1 ` 9 33 1 ENCLOSED IS THE SUNDRY PACKET FOR NF 22-35 APPRECIATE YOUR HELP STEPHEN F.(STEVE)HENNIGAN Fr LL -„ r-7-7 A:1 A C I �J' 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 Edward Teng Vice President - Engineering Armstrong Cook Inlet, LLC 1421 Blake Street Denver, CO 80202 Re: North Fork Field, North Fork Pool, North Fork #22-35 Armstrong Cook Inlet, LLC Permit No: 212-094 Surface Location: 588' FSL, 1571' FEL, SEC. 26, 4S, 14W, SM Bottomhole Location: 2601' FNL, 1372' FWL, SEC. 35, 4S, 14W, SM Dear Mr. Teng: 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 produce is contingent upon issuance of a conservation order approving a spacing exception. Armstrong Cook Inlet, LLC assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy . Foerster Chair DATED this 25-11-y of July, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA Al. A OIL AND GAS CONSERVATION COMMI N PERMIT TO DRILL 20 AAC 25.005 1a.Type of Work: lb.Proposed Well Class: Development-Oil LJ Service- Winj Li Single Zone ❑ lc.Specify if well is proposed for. Drill ❑✓ • Redrill ❑ Stratigraphic Test [ Development-Gas43ervice-Supply III Multiple Zone ECoalbed Gas I=1 Gas Hydrates 111Re-entry ❑ Exploratory(Gas Service- WAG Service-Disp ❑ Shale Gas ❑ 2.Operator Name: ,r! 10,2/ 5. Bond: Blanket❑✓ SingleNumber. Well 11.Well Name and Armstrong Cook I let,LLC Bond No. S /T) North Fork ##22-35 3.Address: 6.Proposed Depth: - -/-(7/Z.- 12.Field/Pool(s)' 1421 Blake St,Denver,CO 80202 MD: 11,017 TVD: 9,800 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): North Fork 0 Surface. 588'FSL 8 1571'FEL 26 4S 14W SM ADL-391210/2,895-131( 4 uif, 7 (7 rz Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2601'FNL 8 1372'FWL 35 4S 14W SM 15-Sep-12 Total Depth. 9.Acres in Property:„CC�� 14.Distance to Nearest Property: 2601'FNL 8 1372'FWL 35 4S 14W SM f t 2C, , P 7_t 7 (2- 588 Section Line 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elev above MSL: 679 feet 15.Distance to Nearest Well Open Surface: x- 199,838 . y 2,121,132•• Zone- 4 GL Eiev above MSL: 658 feet ' to Same Pool: 16.Deviated wells: Kickoff depth: 750 feet . 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 37 03 degrees . Downhole: 4586 , Surface: 3606 • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 0 16 0.5 x56 Welded R3 0 0 120 120 Driven 13 1/2 10 3/4 45.50 N/L 80 BTC R3 0 0 3,000 2,750 720sx Lead @ 12ppg+240sx Tail @ 14 8ppg 8 3/4 7 26.00 N/L 80 BTC-M R3 0 0 11,017 9,800 300sx Lead @ 12 7ppg+280sx Tail @ 13.8ppg ✓ 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effect Depth MD(ft): Effect.Depth ND(ft): Junk(measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat Q BOP Sketch ❑✓ Drilling Program Q Time v.Depth Plot 0 Shallow Hazard Analysis Diverter Sketch Q Seabed Report 'Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative' Date 7/7/12 22. I hereby certify that the foregoing is true and correct Contact Stephen Hennigan 337 849 5345 Printed Name Edward Teng Title Vice President-Engineering /I Signatu �� - - Phone (303)623-1821 Date __/to �a/� Commission Use Only Permit to Drill r� API Number: Permit Appy{ See cover letter for other Number 7. (�T/ 50-Z 31 ��� �" �'C �Date: 1 (� requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or producelbed methane,gas hydrates,or gas contained irfies: Other: *U00D s '- 8o P j1 t S r \ Samples req'd. Yes[i] No[� Mud log req❑Yes[•�No I 7;:r14(1'"`^'+) H2S measures: Yes❑ No[ Directional svy req[]Yes❑ No .pit. Z 500 S /4 n., ..� — 7 441 (3or e/ e - c( Te. ., 64...x...S.J tti ,...ef,rau t_e ogle- Co oil, it-p at-N. f , (1) 9 10 APPROV BY THE COMMISSION DATE. -2_5-i Z— -eOMMISSIONER 76, ?•2y•iL '1,0°` 2-- RECEIVED �. �', ORIGINAL JUL 122012 'ti ” -O Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) 6m..in—plicate A ARMSTRONG Cool In/el. ILC RECEIVED July 8, 2012 JUL 1 2 2012 AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 RE: Application for Permit to Drill—Armstrong Cook Inlet, LLC—NF #22-35 Dear Ms. Foerster, Armstrong Cook Inlet, LLC hereby applies for a Permit to Drill an onshore gas exploration well near Anchor Point on the Kenai Peninsula. Armstrong plans to spud the well in September, 2012. Armstrong plans on using the Nabors Rig 99 for the drilling of this well. If the well test results are sufficiently encouraging,the well will be placed on long-term production. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill 2) Plats showing the surface location of the well 3) Aerial map 4) Proposed Wellbore Diagram 5) Plan Plot 6) Drilling Time vs. Depth Plot 7) Program Details with calculations 8) Cementing Program Summary 9) Directional Plans 10)Wellhead diagram 11)Diagrams and Descriptions of the BOP Equipment to be used 12)Proposed Solids handling 13)Rig Layout 1421 Blake Street,Denver,CO 80202 (303)-623-1821 Ph (303)-623-3019 Fax Page 2 Following are Armstrong's designated contacts for reporting responsibilities to the Commission: 1) Completion Report(20 AAC 25.070) - Stephen Hennigan, (337)-849-5345 2) Geologic Data and Logs (20 AAC 25.071) - Colby VanDenburg, (303)-623-1821 If you have any questions or require additional information,please contact one of the following: Stephen Hennigan 337-849-5345 Edward Teng 303-623-1821 Colby Vandenburg 303-623-1821 Thank you. Sincerely, 44/VNIPP Edward Teng Vice President-Engineering Armstrong Cook Inlet, LLC Enclosures Cc: Colby Vandenburg—G&G Stephen Hennigan—Petroleum Engineers for Armstrong Cook Inlet, LLC • • �• �� PFA44 II? � � Q SII — _ _ cP-2 _ _ter E 13400612, 60700 r^ ,. �'' 7 I/ CP-1 ELEV 666.07' or * : 49 TH i'‘ * / N 2121137.2190 — '\ O • E EV 656,6100 ' / ,/,_1 4C-ZO//(L� Al t . ELEV 656§$__ ^ //�/� C� OH655 -ELEC.METE PANEL POSr660 OHE i �, m��. STA 4637McSLANE .../Lif 653 POST J� 0- , • ���.. X55 - �-- m II/F-PFop.3/30/12..�P�o�`� //� x --X --\ 1 j 1 ROFess I or�a� 0:41 4.11,�'/ /1/� fib.. CONEX Q 11,����� /t ti e�l Tract'18 ¶ o GATE gi 73 7.7 I /� \ G 0 • ) . --CII'llm - — — \ - \\ - __,I : 34-26 WELL 32-35 WELL 14-25 WELL N \ %I Ii co 111 I�I If x ( 'I/ / DRILLING PAD ' „7_______________ XNFU 22-35 WELL 1 I FEL • li N:2121131.74 - . 'i ', . ( g_� �1 E:199838.02 - LATITUDE: 59°47'46.3626" N / (9 LONGITUDE: -151°37'47.2584"W "' " NAD27 ASP ZONE 4 - zo- i '� QHE-L W ELEV. 657.8' NAVD88 in U 1' Tract 19o 0 North Fork Acres Subd. No. 2 I o / �8HAINLINK FENCE 1 '� O �. x. X x\� x W � /L 552 655 s . , Q v ( _ f 60— \, �6� \ C\ 665 bb \ (O TOP OF BERM , i(� cU • 665 ,_(.1I \ 66U f ff . I N 2120261.15 — Section 26,T04S, RT4W,S.M.,AK. — — — E 1341421.67 S26 S25 — S35 S36 NOTES 1.BASIS OF HORIZONTAL COORDINATES ARE ALASKA STATE PLANE NAD 83 ZONE 4 EPOCH 2003 DETERMINED BY AN NGS OPUS SOLUTION FROM CORS NORTH BASE STATIONS"KENS","TSEA"AND"KOD5" OBSERVED DEC 13,2007 ON _ NF1 3 1/2"ALUM.CAP SET N 2121137.137 E.1339704.533 ELEV.6566g '411101.'011P' 2)BASIS OF ELEVATION IS NGS BENCHMARK N86 1T0195 ELEV.18084 FT. -..61,E..- NAVD88 DATUM. SCALE200 3)SOUTHEAST CORNER SEC.26 COORDINATES DETERMINED FROM DIRECT 0100 SURVEY TIE TO THE TO EXISTING BLM SECTION CORNER TIE PER HM91-57 II FEET I I AND NOT THE PROTRACTED SECTION CORNER VALUES. PROJECT REVISION. _ ARMSTRONG COOK INLET, LLC NORTH FORK 22-35 WELL DATE 300/12 700 17TH STREET#1400 AS-STAKED SURFACE LOCATION DIAGRAM DRALNNBY: BOB DENVER,C080202 NAD27 FOR INFORMATIONAL PURPOSES SCALE. 1'=100' ONLY PROJECT NO. 12021 • 10914ENGINEERING/MAPPING/SURVEYING ITESTING BOOK NO. ConwLt n9 Inc P.O.BOX 468 SOLOOTNA PA 99669 LOCATION VOICE (907)2834218 FAX 19071283-3255 SW 1/4 SE 1/4 SHEET EMAIL SAMCLANE®MCUWECGCOM S26 T4S R14W SEWARD MERIDIAN, ALASKA - OF 1 �.a.�%A.‘111 N 2121143 9950 C- T H%\ ,I CP-1 E 1340068.0700 * : 49 * , ELEV 66607' ir N 2121137 2190 Na % E EV 656 6100 \ / 1//�Z�./��/6ZiOk _ 00 Z ELEV 656,�,q'_ � 1 /�/ ( ,,' �Y,LIL oil 4' �T�—OHE C o PANE. POSfi660—OHE ry� 0 STAN A. McLANE ,13 .• _/ 65'3 O.METER _r 0, sl 4637-S ,�, 65 A6 '' _ _ 4� �PFo •.3•/30/12.. • �R1 A 0 P(// t-'i X Pp, I ONA� �� 56 i CONEX \7\,\� I11`xx•N`` /i p Q b� // Tract 8 63.9 o GATE��, J � A Crs • I I — 1i0 0 0 \ r \I il, .7/7 . If 34-26 WELL 32-35 WELL 14-25 WELL /ul I/ m DRILLING PAD J x 573' NFU 22-35 WELL 1FEL/ Itil1.11 N:2120886.900 / ) i' 1 E: 1339863.440 / LATITUDE: 59°47'44.162" N / 0 -151°37'55.028"W NAD 83 ASP ZONE 4 j \ 'u'� dHE— W ELEV. 657.8' NAVD88 Lr'co J•, g x Tract 19 lL o I1...North Fork Acres Subd. No. 2 1 1 o CNl11NLWK FENCE 2 I X -- X X0 W �,�¢„_ 655 ' -c .�__. - �1 =_�"�_ 660 1 0 p b� 665— b 65 b bb i U W TOP OF BERM 1 ________--,.., s. ' \ \ -665 0- N.\\ , 1 N 2120261.15 Section 26,TO4S,R14W,S.M.,AK. — — — E 1341421.67 _ S26 S25 I S35 S36 I NOTES 1 BASIS OF HORIZONTAL COORDINATES ARE ALASKA STATE PLANE NAD 83 ZONE 4 EPOCH 2003 DETERMINED BY AN NGS OPUS SOLUTION FROM CORS NOR T H BASE STATIONS"KENS","TSEA"AND"KOD5" OBSERVED DEC 13,20070N _ NF1 3 1/2"ALUM.CAP SET N:2121137 137 E'.1339704 533 ELEV.656.69' '`)11111 2)BASIS OF ELEVATION IS NGS BENCHMARK N86 TTO195 ELEV 180.84 FT. NAVD88 DATUM SCALEa200 3)SOUTHEAST CORNER SEC.26 COORDINATES DETERMINED FROM DIRECT 0 SURVEY TIE TO THE TO EXISTING BLM SECTION CORNER TIE PER HM91-57 1 I FEET I I AND NOT THE PROTRACTED SECTION CORNER VALUES. ` J PROJECT REVISION: _ ARMSTRONG COOK INLET, LLC NORTH FORK 22-35 WELL700 17TH STREET# DATE mom DENVER,CO 802021400 AS-STAKED SURFACE LOCATION DIAGRAM DRAWN BY: BOB SCALE: 1'=100' NAD83 PROJECT NO. 12023 / ENGINEERING)MAPPING/SURVEYING/TESTING BOOK NO. - CA Consulting Inc P O BOX 468 SOLDOTNA AK 99669 LOCATION VaCE.(9071283.4218 FAX (907)283.3265 SW 1/4 SE 1/4 SHEET EMAIL SAMCLANE®MCIANECGCOM S26 T4S R14W SEWARD MERIDIAN, ALASKA of 1 Exception Plats (Previously applied for exception) N e— `' M m - Z A Cr) ~`s' N M 1 i l • ' � Z a �� e N 3 ....LeY to J W o IX M o t amu. 01— CV LLt i C O � _ • LL 1 M z O E , Z i r O z -) ; %o i • 1 0 • % 4 i lam r •\ • r r `s. c) 1 r''' z • • (N 7L ,fly , t ' ''' il ' i i t i a i'll-Y1 .w ;I 0:Ifil' I 111 i 1 ;,11, 1 /1$014/P1 ea I I" \ il .kt to -IC CNJ IR i J T. .........,,.......... .,_ , v. 1 i o =r ',3 X Ri qt " „, Al / ; Ii- r y w ,,-111; I 1 I ,,..9 • r o I RD CD o r'• � N w' Ori w / - , ...• w C 0 E Q o N. tD LL cu a o 0 m CO rn CL 0 °7 W3 - co Z o as r. til o 'n LO CO X. Ale N ° QaLi C e e O \\*4 .. -,... ,... 0 so in_ Ln ILn 8 (Oa' Z M U _ A M Q ,f) A . I Q / iQ a) so t 4f O N N , i A ilim T m co o C C 1 C A :ARMSTR0\(i i„i,-c LLC' Armstrong Cook Inlet, LLC () Exploration North Fork # #22-35 NF Summer 2012 Block/Sec 26 4S 14W • North Fork () Kenai Peninsula Bor. () Alaska Ser#.: 212??? 2(2-09`1 USDW: ' Prepared By: Armstrong Cook Inlet, LLC 0 PETROLEUM ENGINEERS and Petroleum Engineers, Inc (337) 984-2603 Armstrong Cook Inlet, LLC 0 North Fork ##22-35 Block/Sec 26 4S 14W North Fork 0 Kenai Peninsula Bor. () Alaska Ser#.:212??? FMTN. P ) FG Comments/ CSG ' TOPS/ DIR. (p 4 ,,,,, EVALUATI MDITVD TOt CsgDescr. CASING& LSDW Est Rkb 20' AlrGap 0' Wtr.Dpth 8.3 8.6 9.8 100'pen 1201 0.5#x56 Welded Drive Szv> 16 " ROP/Gas log Cond/Drive to TD. 8.3 8.8 16.0 Mud Logging 3000' 45.5#N/L 80 BTC 13 1/2" Alm 2756 10 3/4" 2750' Casing 1 5950' Upper Target 7600' Tgt 9800' TD Mud Logging: Manned: 2 sx every 10',0'to TD >5 Est TOC S spM left. .r TA L.. 9,0 10.n 16.5 QuadLWD 11017' 26#`iu 80 BTC-M 8 3/4" 9800' Bicenter CR' 7 " CO N. 2 o `r° o �/ w w �r C Q. o W N V3 c E 0- C , - U o J o J r o -a LO i co o m � ftt o O a a O =° () rn OCO w r . 4 0r O C4 0 0 '� e4 t, o ,- 'CCQ .................. 0 A O ti. CI. H O U a a+ d .. 0. o L A a' CD O. 14 LII t,, N 'Q , . H OQ ` g aa .n r u o uj a Y I 81 O O O O O O O O O O O O N M o rO co N o O }}`y;daa -- Armstrong Cook Inlet, LLC 0 North Fork ##22-35 Block/Sec 26 4S 14W North Fork 0 Kenai Peninsula Bor. 0 Alaska Ser#.:212??? Time vs Depth Casing Size& Depth 0 —Days vs MD —ND vs Days -Prod Csg/Inr 1,000 — i 2.000 —_ 3,000 4,000 - d 5.000 6000 7,000 8,000 j I 9.000 10,000 11.000 12,000 0 5 10 15 20 25 30 35 76, 7o 1 Emergency response Information 1.1 Directions to Location Method Directions Air Latitude: 59.7962121 Longitude: -151.6297943 NAD 27 Directions from Kenai •Start out going north on Maw St toward Highland Ave.travel 0.1 mi •Take the 2nd right onto Kenai Spur Hwy.Kenai Spur Hwy is just past Frontage Rd travel 0.7 mi •Turn right onto Bridge Access Rd.Bridge Access Rd is 0.1 miles past Spur View Dr travel 3.3 •Turn right onto Ka lifornsky Beach Rd.travel 16.2 mi Ground •Turn right onto Sterling Hwy/AK-1/I-A1.Sterling Hwy is 0.2 miles past Heine Berger Ln trave145.7 mi •Turn left onto N Fork Rd.N Fork Rd is just past Williams Way travel 8.4 mi •Turn Right on Epic rd.travel 120' •Pad on right hand side of road 35315 North Fork Road Anchor Point,Alaska 99556 1.2 Rig Contact Numbers(Tentative depending on rig and communications available at time of MIRU)) Rig Phone List Cell#'s Co.Man: See below Tool Pusher: Mud Engr: Directional: Expediter: Rig Fax: CM Backup: See below TP Backup: 1.3 Emergency Response Contact Numbers Company Contact Numbers Position Office Cell Larry Driskill Co Man (907)598-1650 Larry MacAlester Co Man (907)240-6244 Tool Pusher: Pete Berga Superintendent (573)201-3861 Response Service Location Contact Phone Ambulance Homer,AK Front desk (907)235-8121 Fire Anchor Point,AK Station (907)235-6700 (907)399-1482 Homer,AK (907)235-3155 Hospital Homer,AK South Peninsula (907)235-8101 Police Homer,AK Front desk (907)283-7879 (907)235-3150 Anchor Point,AK Alaska State (907)235-8239 Spill&Contamination Alaska Alaska State Spill Reporting Refer to Facility chart National Response Center Oil/Toxic Spills,etc (800)424-8802 Coast Guard (800)479-5555 AOGCC (907)793-1226 (907)279-1433 Main Single Point (866)942-6564 1.4 Company Emergency Response Name Position Office Mobile Ed Teng Vice Pres.-Engineering (303)981-9957 Steve Hennigan Drilling Engineer (337)849-5345 Pete Dickinson Operation Manager (907)230-6541 Pete Berga Superintendent (573)201-3861 Drilling Supervisor Drilling Supervisor Prepared by Stephen F.Henniganq 7/11/2012 Page 5 2 Regulatory Agency Contacts by phone or email Agency Office M-F (8AM-5PM) Contact 24 hr AOGCC (907)793-1236 Inspection Supervisor(Jim Regg) See Industry Guidance 10-01 doa.aogcc.prudhoe.bav@alaska.gov 3 Regulatory Compliance Regulation New Requirement 20 AAC 25 BOP testing every 7 days 24hr notice required 4 Drilling Program Summary 4.1 General Well data Name North Fork##22-35 Lease/Lic ADL-391210/2095 Surface Lcn 588'FSL&1571'FEL 26 4S 14W WBS Code Slt/Pad Exstg pad Field North Fork () Spud Date(est) 09/15/12 KB(above MSL) 679 County/Prov Kenai API No. GL(above MSL) 658 State AK Permit No. Perm Datum KB Total MD 11,017 Well Class Exploration WD na Total TVD 9,800 Drlg Contractor Nabors Alaska USDW <+-2700' Rig Name Rig 99 4.2 Working Interest Owners Company Working Interest Address Primary Phone Fax Armstrong Operator Cook Inlet, 1421 Blake St.,Denver,CO 80202 (303)623-1821 LLC Prepared by Stephen F.Henniganq 7/11/2012 Page 6 4.3 Geologic Program Summary NAD 27 NAD 83 NFU 22-35 WELL NFU 22-35 WELL N:2121131.74 N:2120886.900 E:199838.02 E:1339863.440 LATITUDE: 59°47'46.3626"N LATITUDE: 59°47'44.162"N LONGITUDE -151°37'47.2584"W LONGITUDE -151°37'55.028"W NAD27 ASP ZONE 4 NAD 83 ASP ZONE 4 ELEV. 657.8'NAVD88 ELEV. 657.8'NAVD88 NAD 27;Alaska Zone 4 X Co-ord. Y Co-ord. Surface Location Co-ordinates 199,838 2,121,132 Bottom Hole Location co-ordinates 197,430 2,117,978 Pore Pressure Targets M.D.(ft) T.V.D.(ft) X Co-ord. Y Co-ord. (ppg)est Target#2 REVISED 7016.11 5950.00 197,809 2,118,474 8.3 Target#1 Horizon 8817.38 7600.00 197,430 2,117,978 8.4 TD Horizon • 11017.38 9800.00 197,430 2,117,978 9 4.4 Formation Evaluation Summary LWD OH WL LOGGING OH TESTING/CORE MUD LOGGING FULL MUDLOGGING NONE NONE NONE CREW SURFACE TO TD GR, RES SURFACE CP TO , 5700'MD NONE NONE GR, RES, DEN, NEUT, SONIC(P&S) Possible NMR 5700'MD TO TD NONE NONE V V Prepared by Stephen F.Henniganq 7/11/2012 Page 7 4.5 Summary of Potential Drilling Hazards Hazard Event Depth Discussion Precautions /interval Wildcat Well ALL Monitor all paramters for exploratory well Balling Surface Maintain high gpm/rpm to keep bit/BHA clean Perform aditional circulating times Boulders/rocks/sand Surface Control penetration,add Icm,high vis sweeps Monitor for loss of rtns Possible depleted zones Intm Wells off of same pad had no issues Monitor for loss of rtns and differential sticking. Discontinuity of formations minimizes potential. Monitor for connections in hole. Circulate hole High drill gas Intm Wells off of same pad had no issues. f clean to clear wellbore of gas before proceeding. Be sure degassing egpmt is operating properly prior to spud. Potential Hazards Statement To comply with state regulations the Potential Hazards section and the well shut-in procedures must be costed in the drillers dog house The man on the brake,driller or relief driller is responsible for shutting the well in BOPE or diverter as applicable as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC inspector. This well's primary objective is gas and no oil sands are expected to be encountered. No H2S is anticipated. Gas / sands MAY be encountered from±3000'TVD to total depth of the well. These sands will run from slightly depleted 7 to normal pressure. The drilling mud system will be properly weighted to control control the pressure of all sands and lost circulation materials will be available on location if required. Prepared by Stephen F.Henniganq 7/11/2012 Page 8 4.6 Drilling Program Summary 4.6 General Summary Well Name North Fork ##22-35 Permit to Drill No. Location Surface: 588'FSL&1571'FEL 26 4S 14W Top of Productive Horizon:2601'FNL&1372'FWL 35 4S 14W Bottom Hole: 2601'FNL&1372'FWL 35 4S 14W Planned TD MD: 11,017 TVD: 9,800 Directional Plan As per program Well Summary A 16"conductor will be driven/drilled to±120'and a cellar will be constructed and installed. Using water-based mud,approximately 1000'MD of 13-1/2"hole will be drilled as a straight hole prior to kicking off and drilling directionally to the first casing point at±2700'TVD where 10-%"surface casing will be set and cemented to surface. Then a 8 3/4"hole will be directionally drilled to a planned TD of 10839'/9700'MD/TVD. If electric logs indicate zones that are encouraging, 7"production casing will be set and cemented. Then the well will be tested,completed,and then suspended for production hook-up. The entire production hole will be drilled in the Beluga and Tyonek Formations,which contain coal beds of varying thickness.The well will be drilled using PDC bits.These bits exhibit a reverse drilling break upon encountering coals,allowing time for these bits to work the coals as they distress and swell. Based upon the near offsets, gas cut mud may occur. Therefore there will be close monitoring and more circulation of mud to insure proper conditions for progressing. Based on offsetting well information,there are no shallow gas or H2S risks anticipated for this well. KEY DEPTHS Start Depth Seat Depth Interval Hole Size MD TVD MD TVD Drive/Structural Driven 0 0 120 120 NO Conductor Surface 13 1/2" 0 0 3000 2750 Intm/Prod 8 3/4" 0 0 11017 9800 Pore Pressure/Mud Program The well will be drilled to TD using water-base mud with a weight of 9.3 to 9.9 ppg in the production hole section and adjusted as necessary while drilling to TD. Mud Logging Gas monitoring will be provided in the surface hole. Basic mud logging services will be provided from the surface casing depth to TD. Services will consist of cuttings description and construction of a lithology log.The mud loggers will tie their well monitoring system into a PVT system to help monitor fluid • levels and system gains/losses. Logging Program Electric logging(either LWD or/and open hole)will be performed at each casing depth. If hydrocarbons are indicated to be potentially economic,then the testing phase will begin after casing is run at TD. BOP Testing BOP testing will be conducted at least every seven days. AOGCC Field Inspectors will be notified 24 hours in advance of spud and all diverted BOP Tests. It `, will be noted on drilling report and on IADC sheet whether the test was witnessed by the AOGCC inspector or waived. Waste Disposal All solid waste,including drill cuttings,will be disposed of in a nearby permitted facility. Excess mud and fluids will be disposed of as permitted. Completion/Well Testing After the production casing/liner is run,it will be cleaned out and tested. A completion/test string and packer will be run. Each potential zone will be perfed, tested,and then isolated. Following the tests,zones to be produced will be identified and then put to completion. Prepared by Stephen F.Henniganq 7/11/2012 Page 9 4.7 Casing program Summary Start Depth Seat Depth Seat Depth Casing Interval Hole Size MD TVD MD TVD Size Wt(Ib/ft) Grade Conn Burst Collapse Tension Drive/ Driven 0 0 120 120 16 0.5 x56 Welded N/A N/A N/A Structural NO Conductor Surface 13 1/2" 0 0 3000 2750 10.75 45.5 N/L 80 BTC 4230 2470 845 Intm/Prod 8 3/4" 0 0 11017 9800 7 26 N/L 80 BTC-M 7240 5410 604 Buck on float equipment @ yard MU casing to optimum torque 4.8 Calculation of Maximum Anticipate Pressures(MASP and MADP) Note: In this program,MASP for each hole section is defined as the pore pressure(in psi)at the next casing point(or TD)less a gas column to surface. The MADP is defined as the maximum pp WITHOUT a gas gradient. Gas gradient is assumed to be 0.1 psi/ft. 13 1/2" Hole Section-estimated pore pressure of 8.3 ppg emw This hole section will be drilled to depth with a diverter only(no BOP's)arid-18.7-9.1 ppg mw. While MASP will equal the formation pore pressure at the next shoe,less a gas gradient to surface,it cannot be shut in,only diverted. Calculations: MASP(pp)=((PP ppge)x.052 x TVD)-(gg x TVD) MASP03,,7•/= 2750'TVD x((8.3ppge*.052)-0.1 psi/ft) 912 psi MADP=((PP ppg)x.052 x TVD) MADP= 2750'TVD x(8.8ppg*0.052) 1258 psi 8 3/4" Hole Section-estimated MAXIMUM pore pressure of 9 i ppg emw (G/ This hole section will be drilled to TD with BOP's and related equipment installed and tested and with a 9.3-9.9 ppg mud weight. Based on available offset information the most likely maximum pore pressure is anticipated to b-<8.6 ppg E r TT. 1111111,...01 Calculations: -----,,,,,,‘ _.----- 1- MASP(pp)=((PP ppg)x.052 x TVD)-(gg x TVD) } MASP= 9800'TVD x((9ppge".052)-0.1 psi/ft) 3606 psi ' J1\ MADP=((PP ppge)x.052 x TVD) MADP= 9800'TVD x(9ppg*0.052) 4586 psi Prepared by Stephen F.Henniganq 7/11/2012 Page 10 4.9 Casing Design and Calculations Note: In this program,MASP for each hole section is defined as the pore pressure(in psi)at the next casing point(or TD)less a gas column to surface. Gas gradient is assumed to be 0.1 psi/ft. MADP is defined as the maximum pore pressure in the hole section. Start Depth Seat Depth Casing ` Interval Hole Size MD TVD MD ND Size Wt(Ib/ft) Grade Conn Burst Collapse Tension Drivel Driven 0 0 120 120 16 0.5 x56 Welded N/A N/A N/A Structural NO Conductor Surface 13.5 0 0 3000 2750 10.75 45.5 N/L 80 BTC 4230 2470 845 Intm/Prod 8.75 0 0 11017 9800 7 26 N/L 80 BTC-M 7240 5410 604 =minimum of body and connection strengths RECOMMENDED Casing Design Factors BURST(from internal pressure) 1.1 COLLAPSE(from external pressure) 1 TENSILE(joint body and connection)strength 1.6 Prepared by Stephen F.Henniganq 7/11/2012 Page 11 BURST REQUIREMENTS 10 3/4" Surface 8 3/4" Hole Section—estimated pore pressure of 9 ppg emw This hole section will be drilled to 9800'TVD with BOP's and related equipment installed and tested and with a 9.3-9.9 ppg mud weight. Based on available offset information the most likely maximum pore pressure is anticipated to be 8.6 ppg EMW. Estimated fracture gradient(FG)at the 10'/." shoe is 14.5 ppg emw and safety factor(SF)of.5 ppg emw. from above MASP= 9800'TVD x((9ppge*.052)-0.1 psi/ft) 3606 psi MADP= 9800'TVD x(9ppg*0.052) 4586 psi MASP(fg)=((FG+SF ppg)x.052 x TVD)-(gg x TVD) MASP Csg Design= 2750'TVD x((16ppge+.5 ppge)-0.1 psi/ft) 2085 psi Burst Stress= MASP Csg Design is used since in case of a kick in excess of 2085 psi,shoe would break down. Design Factor Burst Strength/Burst Stress= 4230/2084.5 2.03 SF 7 " Intm/Prod Since this is a production design,MASP of 3606 psi is used for highest pp. Design Factor Burst Strength/Burst Stress= 7240/3606.4 2.01 SF Prepared by Stephen F.Henniganq 7/11/2012 Page 12 COLLAPSE REQUIREMENTS Use an external pressure that the casing could possibly be put under. One design methodology uses pore pressure at the casing shoe with a gas gradient internally. 10 3/4" Surface External Pore Pressure less gas gradient MASP(pp)=((PP ppge)x.052 x TVD)-(gg x TVD) MASP(13 1/2")= 2750'TVD x((8.3ppge*.052)-0.1 psi/ft) 911.9 psi Design Factor Collapse Rating/Collapse stress= 2470/911.9 2.71 SF 7 " lntm/Prod External Pore Pressure less gas gradient MASP(pp)=((PP ppg)x.052 x TVD)-(gg x TVD) MASP= 9800'TVD x((9ppge*.052)-0.1 psi/ft) 3606 psi Design Factor Collapse Rating/Collapse stress= 5410/3606.4 1.50 SF TENSILE REQUIREMENTS Tension is usually defined as the body or connection tensile strength(whichever is least)compared to the buoyed weight of casing in mud when run. Buoyed weight is defined as weight in air minus the weight of displaced fluid that it is run in. Buoyed weight formula=MD*Csg Wt(lb/ft)*(1-mw/ 65.45)where 65.5 is the avg wt per cu ft of iron in air. 10 3/4" Surface Buoyed weight= 3000'MD x 45.5 ppf*(1-8.8ppg/65.45) 118148 pounds Design Factor= tensile strength/buoyed wt = 845000/118148 7.15 SF 7 " lntm/Prod Buoyed weight= 11017'MD x 26 ppf*(1-10ppg/65.45) 242677 pounds Design Factor= tensile strength/buoyed wt = 604000/242677 2.49 SF Prepared by Stephen F.Henniganq 7/11/2012 Page 13 4.10 Casing Test Pressure Calculations Casing test pressures are based on the maximum of MASP or 50%of the BOP ram rating In this well,formation pressure is assumed to be the backup. See Casing design and MAWP calculations. BOP PROGRAM,Test Pressures and Casino Test Pressures MASP= Maximum Anticiapted Surface Pressure(psi) MADP=Maximum Anticipated Downhole Pressure(psi)@ TD Casing Size Casing Equipment Test Pressure Low/ High 16 " Structural Casing @ 120 ' 21-1/4" 2000 Diverter Function Test 70%of Burst N/A Test Pressure Function Test NO Conductor ;••----------••—••----••—••--•-----•—••—••—••—••--, 70%of Burst, Test Pressure' 10.75 " Surface Casing @ 3000 ' (1) 13-5/8" 5000 Annular 250/ 2500 70%of Burst_ 2961 Min. (2) 13-5/8" 5000 Pipe Rams 250/ 4000 Test Pressure 3000 (1) 13-5/8" 5000 Blind Rams 250/ 4000 MASP 3606 MADP 4586 MASP Casing Design 2085 7 " Production @ 11017 ' (1) Will not drill out Annular 250/ 2500 70%of Burst 5068 Min. (2) Will not drill out Pipe Rams 250/ 4000 Recommended Test Pressure 3000 (1) Will not drill out Blind Rams 250/ 4000 Test Pressure 4000 MASP 3606 MADP 4586 MASP Casing Design 3606 BOP Test Pressures for Completion 7 " Production (1) Annular 250/ 2500 70%of Burst 5068 Min. (2) Pipe Rams 250/ 4000 Test Pressure 4000 (1) Blind Rams 250/ 4000 Prepared by Stephen F.Henniganq 7/11/2012 Page 14 4.11 Blowout prevention Equipment Details,Testing and General Procedures SEE ATTACHED DRAWINGS Testing: Onsite supervisor will verify all pressure tests. All tests are to be recorded on the IADC and DDR reports. ALL are to be charted. AOGCC to verify BOP tests(24 hr notice) Casing Test BOPS Test Casing Casing Size I MADP(psi) MASP(psi) Pressure Test Fluid 250 psi Pressure Density Size&Rating Low/high (psi) (lb/gal) (psi) Surface 10 3/4" 4,586 3,606 3000 8.8 (1)13 5/8"5M annular 2500 (1)13-5/8"5M pipe ram ? 4000 (1)13-5/8"5M blind ram w (1)13-5/8"5M drilling spool w/3—1/8"5M outlets (1)13-5/8"5M pipe ram lntm/Prod 7 " 4,586 3,606 4000 10 (1)13 5/8"5M annular 2500 (1)13-5/8"5M pipe ram 4000 (1)13-5/8"5M blind ram (1)13-5/8"5M drilling spool w/3—1/8"5M outlets For (1)13-5/8"5M pipe ram COMPLETION 7 " 4,586 3,606 4,000 8.6 (1)13 5/8"5M annular 2500 (1)13-5/8"5M pipe ram 4000 (1)13-5/8"5M blind ram (1)13-5/8"5M drilling spool w/3—1/8"5M outlets (1)13-5/8"5M pipe ram 4.11a The choke manifold will be rated 3 1/8"x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also on the location is a poor-boy gas buster and a vacuum type degasser. Flow sensors will be installed in the flowline and the mud pits will have a PVT system. All data will be available to the driller, company men and key individuals. 4.11b Function Testing: Function on each tour. Report test on daily drilling report(DDR). Prepared by Stephen F.Henniganq 7/11/2012 Page 15 4.12 Wellhead Equipment Summary Component Description BASEPLATE KIT,24 OD X 14 ID X 1.50 THK W/6 NUMBER 1 GUSSETS,W/TWO 2-1/2 GROUT Casing Head SLOTS.F/13-5/8 CSGHD HSG.WG.SH2-LWR,11 5M X 10-3/4 SOW W/ORING.W/2 2-1/16 5M FPO,6A-PU-M-1-2 CSGHGRWGSH2.11 X 7 23.0 Casing Hanger -26.0 LC BOX BTM X 7.375-4 ACME LH PIN TOP,MIN BORE 6.276.6A-PU-M-1-2 TBGHGR,WG,T-M40-CCL11 X 2-7/8 EU BTM AND Tubing Hgr TOP,w/2-1/2 HBPV THD AND TWO OHCV PORTS,4130 80K6A-LU-DO-NL-1-2 Tree 5k-TBD USE SPACER SPOOL AS NECESSARY SEE ATTACHED DRAWING Prepared by Stephen F.Henniganq 7/11/2012 Page 16 4.13 Directional Program Summary Well is to be drilled as a directional hole. Surveys will be taken per AOGCC regulations or more frequently as needed. Inclinatio Comments MD n Azimuth TVD Grid East Grid North DLS Build Rate Turn Rate Vert Sect [ft] [°] [°] [ft] [US ft] [US ft] [°/100ft] [°/100ft] [°/100ft] [ft] Est.RTE:21' 0.00 0.00 215.95 0.00 199838.02 2121131.74 0.00 0.00 0.00 0.00 KOP 750.00 0.00 215.95 750.00 199838.02 2121131.74 0.00 0.00 0.00 0.00 End of Build 2231.29 37.03 215.95 2130.28 199557.49 2120764.32 2.50 2.50 0.00 462.27 Surface csg 3000.00 37.03 215.95 2743.95 199276.53 2120396.35 0.00 0.00 0.00 925.24 Target#2 REVII- 7016.11 37.03 215.95 5950.00 197808.69 2118473.90 0.00 0.00 0.00 3343.99 Begin Angle Dry 7229.20 37.03 215.95 6120.11 197730.81 2118371.90 0.00 0.00 0.00 3472.33 Target#1 Horiz 8817.38 0.00 215.95 7600.00 197430.04 2117977.97 2.33 -2.33 0.00 3967.95 TD Horizon 11017.38 0.00 215.95 9800.00 197430.04 2117977.97 0.00 0.00 0.00 3967.95 Plots Well Profile A Armstrong Cook Inlet, LLC �IS� eM.b.k Masa(0ea Mr Wa) ho.Fort.,2-36 BAKER Mif5.440 Nunn How Web NFL-1012-3e ARMSTRONG Fao*N Nath Fork tat 64AO2Tl We bcr. NFU.12.36 of/,ca,,/.r 'lot roMwa.*loath m NFU.12.36 V.rson.3 Tna wenn.~On ae wl.rw,wa b Nabors 106E(RTE) lane Sy.Y,b NA021 TM Mamba SP Zone.;5004).US Net M..su.a~ens are r.ta••,aa b Nabors,06E,RTE) NM,Radom.Thor,ono Nabors 106E(RTE)M Moan S..1...y.1 200 Not Soy.Tn.0Ranw Mann Sea Lomb to Mob 1n.IM Slot Nor.Fort.12-351 0 Not 0.0.ns w n Not Coa.naes w n NM,eNr.neeo to Slot Ca..a.o by lone...,on 26F.5-12 ,_,--,., Eastlnp(ft) 5101 l o/.3X35 toy e .. Eno of BA / /1 // .11111/ •x / ' gm.- .RTE 2 r // Gepp -KOP / F 2.60')100/1 / Eno or Bob / 1M •sBa /a NFU 12-36 17.".'0,2'2IREVGDNALI2T) Feb-12 Been Argo Drop Ja00 t re-u12-36 Tap s..(NA027w,ree 22-FM 12 •OO C' sF1-112-16 TD°INA ET 31-.Ja,-12 n=u.2aa Tarp. e2 REVS SI1? a.p.02(NSO211 Ry.o 26.FebI Bpn AnpN PeV -NM 7000 12.03':10011 Hobson NFV12a6Target Two... .l INAO2711t,r.O 22F.-12 1000 TO Mormon ..... NPU1240 TO(*400255 31-Jan-1 \'ertiWI SecOorl(fl) A.m..,215 05•rem r.NNnce 200 N.000 E Prepared by Stephen F.Henniganq 7/11/2012 Page 17 Spider ANathFark Armstrong Cook Inlet, LLC "�" Lamar, Cos inet Alaska,NeRa, �asuI3l Felt ol« ',CMFm tt:.` BAKER W N}ll#t2.36 .%k M 1 1 R 0 Y G Faddy Nosh Fort 1kit tNAD271 Maar NFU#1215 HUGHES Pat Werra 44410:Wt..t'.:1<1Man 03 Tr4 rtNai doped are rettercea t%Or.'CSE dTti ata Sear-1/41:' 1.1A ua 5t.:at a 530. - te. wont sept wee/mac t Mets'.0 I1 1j. tom weera T,Le nrT soon IOSF rat t woo Sas Lem noted Sc.Tait 070+3 New Sea leve t WO we.At Sat+trT at$t.35,.O1r Cevtn:art•Re' CaNwls ie r tetnetrettNt 50 Cams 0,Sec:A US Pus* ;JtYeCO�JY.o•v:..,. • . 11. 4100 . •ffi .tom . •ffi .ffi 1 0 >00 WO 400 1 ffi- tall fot$i2-J.! + - ffi Nall fal#W- it t1 NuF litres:f . NOT Fpl»-3;''f-� m CO. soli Fat;33-35 - m Nati hat ten Pon 042,X im WO Rot 04145 �1 r 000- -.r/ . CO e, 31111 - KO . i o 0. t am ,W• :`.� .400 .m. — -.103 400. tm+ -.00 'lip J. l 1 aii 1Avis i t L 41. .it 1 .1h :� 0a .� o 104 A 100 Eassn ift See attached directional program for more details 4.14 Directional Surveying Summary Downhole realtime surveying tool. Magnetic Interval MD(ft) MWD/LWD Multi Gyro Multi Elog Other Remarks Drive/Structural 0 120 NO Conductor 120 Surface 3000 x Intm/Prod 3000 11017 x Prepared by Stephen F.Henniganq 7/11/2012 Page 18 4.15-4.16 Drilling Fluids Program Summary and Specifications ud Progran Drive 16"pipe to 120'.Build Spud Mud&drill 13.5"hole to 3,000' Set 10.75"C.' luid Type: Spud Mud-Lower Fluid loss after 2000' i...ooperties tiste• below: Depth Mud Wt. Funnel PV Yield Point Gels pH API FL HTHP FL Chloride SLDS (MD) Visc l0sec/10min 1S F "UUO' ppg sec/qt cp Ihf/100 ft2 03f/100 02 ct cc mg/I 01)I. 0'-3,000'± 8.8-9.5 60.100 15-24 30+ 20/35 8.0-9.0 <18 N/A 5 5000 <7 1 Pre-hydrate all Bentonite additions.Mix&pump prehydrated gel slurry in case of pea-gravel&massive sands,add Gelex to sweeps for added viscosity. 2 Run all available solids control equipment for maximum solids control. 3 Reduce fluid loss with additions of PolyPac Supreme UL prior to reaching 2000' 4 pH should be controlled with Caustic and/or Soda Ash 5 Add 2-5ppb MIX II to mud system if seapage losses become a problem. 6 Maintain low gravity solid at<8%with dilution and solids control. Mud Progran Drill 8.75" to±11,017'MD.Set 7"Casio'- Fluid Type: Fluid properties listed below: Depth Mud Wt. Funnel PV Yield Point Gels pH API FL HTHP FL Chloride SLDS vise 10 sec/10 me 250°F "000" ppg sec/gt cp Ibf/10002 Ibf/100 ff2 cc cc mg/1 %NOL 3,000-11,017'± 8.8-9.9 40-50 10-16 12-18 10-14 9-9.5 7.00 N/A 28k-32k <6 1 Drill out 10.75"casing shoe with previous mud and displace to new KlaShield while drilling shoe before FIT The WBM should be maintained with KCI,Flowzan and PolyPac with sweeps as needed for additional hole cleaning.Maintain 2 concentrations of KlaStop for inhibition. Prior to drilling cement,pretreat the mud system with.25 ppb Sodium Bicarbonate to minimize effects of cement 3 contamination. 4 Begin adding Asphasol and Resinex as coal are drilled,coal stringers will be drilled thru this section. 5 Add MIX II and sized SafeCarb(20,40,250)to the mud for seepage(<15 bph). 6 Run solids control equipment continuously to maintain low gravity solids below 6%. 7 Lower yield point/gel strengths prior to logging,running casing,and cementing. Note: Production casing plug will be bumped with water. Prepared by Stephen F.Henniganq 7/11/2012 Page 19 4.17 Solids Control Equipment-closed loop Interval Shaker Desander Desitter Mud Cleaner Centrifuge Cuttings Cuttings Zero Discharge Comments Dryer Injection Closed Loop System,Full Containment, 0-Total Depth x x x x run shakers with finest screens possible Equipment S Specifications (typical but maynot be exact de Item p depending on rig) (quality,design type,brand,model,flow capacity,etc.) Shaker 2-Brandt King Cobra Degasser Demco style Vacuum Desander N/A Desilter N/A Mud Cleaner N/A Centrifuge N/a Cuttings Dryer N/A Cuttings Injection N/A Zero Discharge N/A Best Practices: Have vacuum trucks pull fluids from trough above the cuttings tank to more efficiently pull fluids for disposal.This minimizes water added to the solids to suspend for pick up by the trucks,thus minimizing total volume to be disposed of. Cuttings will be pulled from holding area per diagram. Prepared by Stephen F.Henniganq 7/11/2012 Page 20 4.18 Cement Program Summary(Brief vendor prog is attached) Cementing Summary 0 0 0 #VALUE! Surface I Size: 10.75 Setting Depth: 3000 ft. Annular Volume(No Washout): 1115.24 cu.ft. Lead Slum Density: 12 ppg Yield: 2.62 cu.ft./sx No.Sxs: 720 Specifications:Tvoe I Desired Top of Cement: 0 ft. Tall Slur/ Density: 14.8 ppg Yield: 1.34 cu.ft./sx No.Sxs: 240 ✓ Specifications: 1 8 Hour Compressive Strength of Tail Slurry: 1000+ psi Total Volume: 2208 cu.ft. Desired Top of Cement: 2660 ft. 960 Intim Prod.Casing I Size: 7 Setting Depth: 11017 ft. Annular Volume(No Washout): 829.04 cu.ft. Lead Slum( Density: 12.7 ppg Yield: 2.18 CU.ft./SX No.Sxs:I300 I Specifications: a Desired Top of Cement: 5500 ft.✓ Tall Slurn( Density: 13.8 ppg Yield: 1.85 CU.ft./SX No.Sxs: 280 Specifications: G, Desired Top of Cement: 8599 ft. Total Volume: 1172 cu.ft. 8 Hour Compressive Strength of Tail Slurry: 1000+ psi 580 II II #VALUE! Comments: See cement prognosis tor aetaits ana spacer specmcatrons. Actuat eetnent volume pumpea writ oe determined by elog caliper and other parameters. Prepared by Stephen F.Henniganq 7/11/2012 Page 21 4.19 Bit Summary NO. Size Model Type Surface Hole 1 13 1/2" GTX-C1 or similar tooth Intm/Prod 2 8 3/4" HCD504ZX or similar PDC Prepared by Stephen F.Henniganq 7/11/2012 Page 22 4.20 Casing Test,FIT,Lot procedure Perform Casing Test(CIT) -the pressure to which the casing should be tested should be 300-400 psi above the expected surface pressure needed for the leak off test.It is NOT necessary to retest to the APD casing test pressure 1 GIH and clean out to the top of the float collar for casing test. 2 Circulate and condition mud until shaker is free of cuttings and mud weight in is within +/-0.1 ppg of weight out for several consecutive measurements. 3.Rig up,pressure test and check for leaks.Make sure air is purged from the system. 4.Pumping down the dnllpipe,break circulation with cementing unit(or low vol/high press pump). 5 Close annular BOP or pipe rams 6 Pump down drillaiae at 1/2 bpm.Do not exceed this rate and maintain constant rate as well as possible.Record pressure at each 1/2 bbl increment pumped NOTE: Larger than 11 3/4"use.75-1 bpm,11 3/4-9 5/8 use.75-.5 bpm-plot should be tgreater than 45• 7 Continue until the test pressure(as described above)is reached.Do not exceed test pressure Stop pump and shut in valve 8 Monitor and record shut in pressure,hold for at least 5 minutes,or as specified.Troubleshoot problems if desired test pressure cannot be obtained. 9.Release pressure and record volume of fluid recovered during flow back. 10.Input recorded pressures and corresponding volumes on the Casing Test section of the"CSG-FIT'worksheet(in the yellow shaded area) This is the minimum volume line for the subsequent leak off test Enter flow back when pressure is released. Prepared by Stephen F.Henniganq 7/11/2012 Page 23 Perform Formation Test(LOT. FIT,etc) -enter all the header information for the well,ng,casing size,shoe depth,mud weight,date and your name at the top of the form on the"CSG-FIT"worksheet. 1.Drill shoe track and+20'of new formation POOH into the casing shoe Circulate and condition mud until shaker is free of cuttings and mud weight in is within+/-0.1 ppg of weight out for several consecutive measurements. 2 Rig up lines,pressure test and check for leaks.Make sure air is purged from the system. 3 Pumping down the drillpipe,break circulation with cementing unit(or low vol/high press pump). 4 Close annular BOP or pipe rams 5 SLOWLY pump down drilloipe and maintain constant rate as well as possible.Required rate may vary,but first attempt should be at 1/2 bpm(OR same rate as casing test). Record pressure at each 1/2 bbl increment pumped and plot on the FORM INTEG TEST(FIT)section of the"CSG-FIT"worksheet(in the blue shaded area). This will require teamwork among at least two,but better with three individuals If the FORM INTEG TEST(FIT) plot curves BELOW the Maximum Volume Line,stop and bleed off pressure then re-run the test at a higher pump rate(suggest 1/4 bpm higher). Note-also have someone record casing pressure from the choke manifold at the same--bbl increments. If these pressures differ from the drillpipe recorded pressures by more than 10%,notify the office. 6.Continue until leak off(fracture initiation)is detected as indicated by a change in the rate of pressure increase. This is determined by the leak off test chart and observation of the pressure behavior Once leak off indications are noted continue to pump at constant rate to confirm.If the pressure resumes a constant rate of increase, continue pumping and watch for subsequent leak off indications.If the rate of pressure increase continues to decline,continue pumping for 3 more_bbl increments to insure fracture has occurred(a noticable pressure drop should be evident).If a sudden pressure drop occurs,stop pumping immediately 7 Record instantaneous shut in pressure(ISIP) Monitor and record shut in pressure every minute for at least 10 minutes. See#11 below 8.Release pressure and record volume of fluid recovered during flow back. 9 If the measured leak off pressure is less than the predicted leak off,then a cement channel may exist.Whenever a cement channel is suspected,the LOT should be repeated for confirmation.If a channel exists there should be little or no improvement seen LOT or FIT or PIT (in EMW)=pressure(psl)/.0521 casino shoe depth('TVD) +current mud weight(ppa) 10 If the Leak Off plot falls between the Minimum and Maximum Volume Lines,this is a good leak off plot.Pick the point on the curve where the line begins to break over(the rate of pressure increase has changed from a straight line) This is the leak off value.On a"jug"test,there is no bend PPG equivalents are calculated on the nght 11.Input recorded pressures and corresponding volumes on the FORM INTEG TEST(FIT)section of the"CSG-FIT" worksheet Values should initially fall between the Maximum volume line and the Csg Test line 12.Input recorded shut in pressures and corresponding times on the Shut In Pressure(ISIP)section of the "CSG-FIT'worksheet(in the yellow shaded area). This is indicated by ISIP and incremental time @ the bottom of FORM INTEG TEST(FIT)section Prepared by Stephen F.Henniganq 7/11/2012 Page 24 ARMSTRONG COOK INLET LLC. North Fork Unit #22-35 Cementing 10-3/4" Surface Casing: 1. Prior to cementing casing: • Check cement lab test for sufficient pumping time, free water and fluid loss. • Discuss job with cementer, check calculations and additives. • Verify cementing lines (chicksans, flexhose, etc.) are made up ready to go. • Confirm Stab-In collar placement is correct and drill pipe nipple matches Stab-In collar. • Drift Casing prior to running. • Assure extra hoses are available for water and mud. Cement the casing as follows; Immediately prior to shutting the pumps down record and report the pump pressure ON A RATE/TIME/PRESSURE basis +5-10 minutes. Hold pressure for 1 minute. Bleed pressure down to 0 psi.and pull out of tool. Load wiper plug into drill pipe and pump with rig with total displacement plus 5 bbls. to clean drill pipe. Spacer: 5 BBL Use Fresh Water to pressure test cementing iron Spacer: 24 BBL Mud Clean II Lead: 733 sx Type I Cement+Additives 12.00ppg Excess 100% Over calculated volume or 20% over caliper volume Tail: 200 sx Type I Cement+Additives 14.8 ppg Excess 100% Over calculated volume or 20% over caliper volume Displacement Spacer: 5 BBL Use Fresh Water Displacement Mud: 285 BBL 8.8 ppg WBM - 290 bbl.total displacement Estimated Top Lead Surface of Cement Tail 2,660 ft PROPERTIES LEAD TAIL Weight 12.0 14.80 ppg Yield 2.62 • 1.34 • Water 15.13 6.34 Pump time 5:35 2:31 Water loss N/A N/A Free water N/A N/A Comp. Strength 8 hours 106 500 12 hours 224 743 24 hours 423 1198 48 hours 661 Note: The final slurry design will be provided after testing cement, additive and mix water samples prior to performing the job. 2. After cementing, record the following: • Time cement in place. • Pressure used to displace. • RATE/TIME/PRESSURE after slowing down in anticipation of bumping plug. • Amount of barrels pumped behind cement. • Amount of barrels bled back to check floats. • When and if returns were lost while cementing. • Amount of cement(in barrels) circulated to surface. Cementing 7" Production Casing: 1. Prior to cementing casing: • Check cement lab test for sufficient pumping time, free water and fluid loss. • Discuss job with cementer, check calculations and additives. • Verify cementing lines (chicksans, flexhose, etc.) are made up ready to go. • Verify that wiper plugs are loaded in cementing plug assembly. • Drift casing prior to run. • Assure extra hoses are available for water and mud. Cement the casing as follows; Bump the plug with 500 psi over circulating pressure. Immediately prior to shutting the pumps down record and report the pump pressure ON A RATE/TIME/PRESSURE basis +5-10 minutes. Hold pressure for 5 minutes. Release the pressure and confirm the floats are holding. Do not over displace by more than half of the shoe volume. Spacer: 5 BBL Use Fresh Water to pressure test cementing iron Spacer: 40 BBL 10.0 ppg Seal bond Spacer Drop bottom plug Lead: 320 sx Class"G"+Additives Excess 50% Over calculated volume or 20%over caliper volume Tail: 300 sx Class"G"+Additives Excess 50% Over calculated volume or 20%over caliper volume Drop top plug Displacement Spacer: 5 BBL Fresh water to drop Top Rubber Plug Displacement Mud: 420 BBL Fresh Water or KCL Brine. Estimated Top Lead 5,500' of Cement Tail 8,599' PROPERTIES LEAD TAIL Weight 12.7 13.5 ppg Yield 2.18 • 1.85 • Water 11.84 9.31 Pump time 4-5 hrs 4-5 hrs Water loss <50 <50 Free water 0 0 Comp. Strength 8 hours 100 —500 24 hours 524 1034 48 hours 1011 1772 Note: The final slurry design will be provided after testing cement, additive and mix water samples prior to performing the job. 2. After cementing, record the following: • Time cement in place. • Pressure used to displace. • RATE/TIME/PRESSURE after slowing down in anticipation of bumping plug. • Amount of barrels pumped behind cement. • Amount of barrels bled back to check floats. • When and if returns were lost while cementing. WELL DATA ANNULAR GEOMETRY ANNULAR I.D. I DEPTH(ft) (in) f MEASURED TRUE VERTICAL 16000 CASING I 120 120 13 500 HOLE I 3 000 2 750 SUSPENDED PIPES DIAMETER (in) WEIGHT DEPTH(ft) O.D. iffi Ohs/ft) MEASURED I TRUE VERTICAL 10 750 9 950 15 5 I 3 000 1 2 750 FloatiLanding Collar set @ 2 960 ft Mud Density 8 30 pRg E -LS.141tdc Temp. 85 `F Est.Circ. Temp. 82 `F VOLUME CALCULATIONS 120 k x 0.5969 at %pith, 0% excess = 71 6 of 2.540,ft, 0.3637 glitt with 100% excess = 1847 7 a 340 ft X 0.3637 aft with 100% excess = 247 3 cf 4011 0.5400 avil with, 0% excess = 21 6 cf(insisie pipe) TOTAL SLURRY VOLUME = 2188 3 a = 390 blaa WELL DATA ANNULAR GEOMETRY ANNULAR I.D. DEPTH(ft) (in) MEASURED TRUE VERTICAL 9 950 CASING 3 000 2 750 8 750 HOLE 11 017 9 600 SUSPENDED PIPES DIAMETER_jin) WEIGHT DEPTH(ft) O.D. I I.D. (lbs/ft) MEASURED I TRUE VERTICAL 7 000 6 276 I 26 j 11 017 I 9 800 FloaULanding Collar set @ 10 977 ft Mud Density 9 00 pp.g Est. StAtitcaempi, 163 ' F Est.Circ. Temp. 128 ' F VOLUME CALCULATIONS 3 099 ft x 0 1503= with 50% excess = 698 9 gi 2 418 ft x 0 1503011 with 50% excQs = 545.2 at 40 ft x 0 2148 eft with 0% ex.0@0s = 8 6(ansidat pipe) TOTAL SLURRY VOLUME = 1252.6 pf 223 Mk X33E 0a N N N C I (1) pi t.: m U 7 0 M o M M :-J O N n H m 0 mr re ° a 0 w 0 c o w Y W N CT v p pp a 0)-vn0)NNNO NN 1) f0 0 0 0 O 0 S O O S U O) 7,0 ai S1 2 m 8 • N tS N 2(+2� 2p P r O N V CO CO CO m CO m r n UI r P- _, P- C 000c 000O O V�A V V-W OISCNDM a i606NO11466O44.6 Nmge W f4gX°W V°3 )p ; N N M M V N N m m r m m 0 cif Q d W W J r ON N o co d pp p p p H N L L 10 w O S O O O O O O O S O O S O S O S O O S O O S O O O O O O O O O O S O 0 0 0 0 0 0 S S S O O o 2 ao�o m g$ $ $ g N E O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o c o o o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o d F ZF- .-0ZZMnrowZN ZZZ d ($�n a. v MN u., mxp pp pppp Ui00 CS 8888888888i.8f•14i,14i•14i•14i,1Qi1qi1Fi,14i•14i1Qi1Qi1Qi1gi888888888888888888888 v., D O O O 0 0 0 Ci O Ci N N N N N N N N N N N N N N N N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O 0 O O TJ 1.:77' m.°.. 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Cp O O O- a so m" ^ 88 o` o 0 o 88 Jp - 0O • N-n • N N C co Eo C SD O PI* N U) Z Z d N N 0 S r Y C 0 c 1-f- C J Y V 0 El,0 O N Co' 0)0) 'O j r m N N N,� 0 O O 111.P O O v r M P- i r W" {+)c,) N N t O O Ni N O Z C M O N tD 0O o m Q.3 w LL 00)W N0 O r 0 0 • `r op 1 0 L N U) C O)O) vi6 Q N N C O C o O O • -" O D C o to O , 8 p ARMSTRONG CookIn/e!,LLC DRILLING OPERATIONS SUMMARY North Fork 22-35 Start Seat Depth Casing Depth Hole Wt Collaps Tension Interval Size MD TVD MD TVD Size (lb/ft) Grade Conn Burst e Drive/ Structural Driven 0 0 120 120 16 0.5 x56 Welded N/A N/A N/A NO Conductor Surface 13.5 0 0 3000 2750 10.75 45.5 N/L 80 BTC 4230 2470 845 Intm/Prod 8.75 0 0 11017 9800 7 26 N/L 80 BTC-M 7240 5410 604 * =minimum of body and connection strengths Note: AOGCC MUST be notified 24 hrs prior to each diverter function and BOPe test. Conductor: 1. Drill/Drive 16" conductor to +/- 120ft. RKB. RD conductor rig. 2. MIRU drilling rig. 3. Install starting head 16" SLC x 21 '/4", 2M flange. 4. Nipple up 21 3/4", 2M diverter, 16" diverter valve and 16" diverter line. 5. Function test diverter and diverter valve. (AOGCC 24 hr notice) 6. Build spud mud. 7. Install mud logging. 8. Inspect bha equipment. Surface: 1. PU 4" drill pipe, bit and DIRECTIONAL BHA per bit/directional proposal. Set up WEEKLY STATUS Report for the Commission. 2. Drill w/ low rpm, gpm until stabilizers have exited drive pipe. Run max gpm, rotary, etc as allowed. 3. Continue to directionally drill a 13 1/2" hole to ±3000' MD/2750' TVD short tripping and pumping sweeps as considered necessary. At hole section TD, pump a HIGH VIS sweep and circulate the hole clean. 4. Short trip. Circulate hole clean. Repeat. 5. Condition mud to lower YP and gels. Monitor pill lag and mud log lag times to aid in adjusting cement volumes for hole washout. 6. Prep for excess mud, cement, rinse water, etc disposal. 7. Calculate landing equipment to have proper space out with top of landing jt ±4-6' above rotary. Run 10 3/" surface casing as follows Baker-Locking the shoe track: a) Shoe b) Sting-in collar c) Casing With centralizers placed as follows: d) 2 bow-springs with stop collars in center of bottom 2 jts e) Centralizers across the bottom 2 couplings f) 1 centralizer across the coupling of every third jt g) NO CENTRALIZER INSIDE CONDUCTOR AS CASING NEEDS TO BE CENTERED IN ROTARY h) ESTIMATED TOTAL centralizers = ±35 w/2 stop collars . 8. Perform a running tag. Reciprocate casing. Circulate and condition mud at a rate not to exceed the AV around the collars while drilling. 9. RU cementing head and lines. Test to 500/5000psi. Cement 10 3/" casing PER cementing proposal with an inner string, cut off cementing when cement reaches ✓ surface, dump 2-5 bbls on top of sting-in collar. Circulate clean. Cement volumes are presently designed with 100% excess. Adjust as necessary to allow for cement returns to surface. 10. ND Diverter. Cut off 10 3/" casing. Prep to install mud loggers per logging program. Instruct same re dry ditch samples for AOGCC. 11. Install 10 3/" slip lock connection X 11" 5M flanged multibowl wellhead. Test to 50% of casing collapse or 1600 psi whichever is greater. 12. NU adapter spool. NU 13 5/8" 5M BOPs. Test BOPs and choke manifold to 300/4000 psi, hydril to 300/2500 psi. (AOGCC 24 hr notice) If AOGCC approves, casing may be tested here while testing BOPe. That is, pull test plug and perform casing test under the blinds. Test casing to 3000 psi. NOTE: If AOGCC does not approve of casing test under blinds then test before drilling out float equipment. NOTE: (BOPe MUST be tested every 7 days during the remainder of the well. AOGCC must be notified at least 24 hours before) NOTE: Maintain good communications with regulatory. Communicate with the inspector every couple of days just to let them know what is going on. 13. Set wear bushing. Run CBL. Production: 1. PU 8 3/4" PDC bit and directional BHA w/ LWD. Drill out float equipment and at least 20' of new formation. Circulate hole clean. 2. Contact AOGCC. Test shoe to LEAK OFF on a chart. Email results. Estimated Leak Off EMW is 16.5 ppg ernw. If test is less, discuss with office. A minimum of 13.5 is acceptable. 3. Drill ahead per directional plan. 4. Continue to directionally drill to ±11017'MD / 9800' TVD as per program, short tripping and pumping HIGH VIS sweeps as required. MINIMUM flow rate should be 500gpm. Higher if possible. 5. At hole section TD, pump a HIGH VIS sweep and circulate the hole clean. Make wiper trip. Again pump a sweep and circulate hole clean. Make sure pump is at MAX rate. Hole will require more than just circulating bottoms up. POOH. 6. TIH. Condition hole as before. Condition mud to lower YP and gels. Monitor pill lag and mud log lag times to aid in adjusting cement volumes for hole washout and compare to log value (LWD). 7. TOOH. Pull wear bushing. Install test plug. Close blind rams. 8. Change out pipe ram with 7" casing rams in upper ram. Run test joint and test casing ram to 250/4000 psi. 9. Calculate space out and prep as per previous. Run casing as follows Baker-Locking the shoe track: a) Shoe b) 2 jts casing c) Collar d) casing With centralizers placed as follows: e) 3 bow-springs with stop collars in the centers of bottom 3 jts f) Centralizers across the bottom 3 couplings g) 1 centralizer across the coupling of every third jt for the next ±3600' casing (±30) but will be adjusted across potentially productive zones h) 1 centralizer across the coupling of every third jt to ±5000' (±15) i) ESTIMATED TOTAL centralizers = 42 w/3 stop collars 10. Run and cement 7" casing per cementing procedure while rotating and/or reciprocating. Land hanger. Cement volumes are presently designed for±5500' of fill (TOC ±5000'MD) with 40% excess. Adjust as necessary to insure top of cement to +-5000'. 11. Back out landing joint. Install packoff and test to 5000 psi. Change out casing rams with pipe rams. Run test plug and test BOPs to 300/4000 psi, hydril to 300/2500 psi. (AOGCC 24 hr notice) If AOGCC approves, casing may be tested here while testing BOPe. 12. Set wear bushing. 13. Clean out and test casing to 4000 psi adjusted for mud wt in use at test. POOH. t 14. Run CBL. Well Test/Completion: V 1. Detailed Procedure will be provided with a completion/well test sundry. je 2. Rig down and move out drilling rig. Coil @GE Oil & Gas I- 47.7" 0 COMMIS 1 30.2" ik,O 2-9/16"5M - iliii% 1411.:."1.9 _ 2-9/16"5M _, (CIO 1 - A ir[ 1 , _ .4_,,,,„4_,. 1 ).07 . i 11.4' 2-9/16"5M 2-9/16"5M ('1�, IIIW10-04 l 45.8" ii�[' 2-9/16"SM - ' ,i. 123.5" illiel 4.MI ii!•ii • I _ 4 , / 11"5M ' r -1 0 ;af�-30 ---l• . i ❑ • H 28.5"to c 19.0" ND iIL Er r fro'Illi r'.7 1:51:41 r •i a% 11"5M ( -_ i 'il j 1-13/16"10M _ , !� ,. 25.1'to c [ l , • 0 28.0" N:-I��' l'�O�'la ,� ' I T ri. 2-1/16"5M Y! II [l 1 24"O.D.Base Plate 10-3/4"Casing 7-5/8"Casing 2-7/8"Tubing 1/4"Control Line This drawing is the property of GE Oil&Gas Pressure Control LP and is considered confidential.Unless otherwise approved in writing, BUCCANEER ALASKA neither it nor its contents may be used,copied,transmitted or reproduced except for the sole purpose of GE Oil&Gas Pressure Control LP. ARMSTRONG COOK INLET 10-3/4" x 7-5/8" x 2-7/8" 5M SH2/LRC2 Wellhead Assembly DRAWN - VJK 24MAY12 APPRV KN 24MAY12 With T-M40-CCL Tubing Hanger and M40-CCLAdapter Flange FOR REFERENCE ONLY DRAWING NO. AE21797-B } q xgi % o piml \�\, te Rt. ao� a1. lig 1 g g 1111111;111111ar I E zo UIIiII1H aF I J R o aW en cc CC ujm > 4I C3 e Z @ 3(t g El T., vI Ii II 1' II II ...II II 1 1 "i="'''':'1 i= m l H .. .i II I 1 Mr=1 111111111M/len " W..r.:o; MOGI " :m1�m��ao RNII - •=.C.O :Zff. 411 Linn Fl ee .. cc i � ihI ���i....143 E1i� � iii � tl II ■ jX11, I W _ r. ll pliThr=aid' kr. Erg �iIIIIII„„.1c iil ,m .w. 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NFORK ROAD H 100' RNV .;2231.0106.10].00 / N21CP. EL 3400607 2 N212113]]190 0 L_17 B2 E 1339]066100 EDGE OF R O W 7. U ELEV 6...•' IDrth Fork Acres /��0 ea° ANE POST Di1E ^ P ME PMETER m Subd. No.6 POST ^O 5"PIPE Tract 18 GATE O O 'SWELL I E e 36.26 WELL 3235 WELL 1a. LL ] FEL LL 62-35 WE L S 4 X pRiLL�NG PAD e O 'i 1 'i °a ��� � ° > FEL �' \ s C7 Diverter Line Ext+7 ' � J - -J Tra 19 J LL Tract 20 I North Fo s Subd. No. 2 North Fork Acres 6'CHAIN..NH FENCE U. Subd. No. 2 0 Q 0 CC TOP OF BERM ^U_ LL Lu Section 26,1114S,R14W,S.M.,AK. Page 1 of 1 Schwartz, Guy L (DOA) From: Stephen F. Hennigan [shennigan@peiinc.com] Sent: Tuesday, July 24, 2012 11:28 AM To: Schwartz, Guy L (DOA) Subject: RE: NF 22-35 (PTD 212-094) 1. Is coming but the well is shown on the tornado for the previous well. Sorry I forgot. 2. Yes on the cbl ride 36, 0.tcaeloa,v Project Manager/Engineer 500 Dover Boulevard, Suite 310 I Lafayette, LA 70503 w: 337-984-2603 : 337-849-5345 X Description: Description:Description: Description:pei_logo-OUTLOOK Hamilton Confidentiality Notice: The information transmitted is intended only for the person(s) or entity to which it is addressed. It may contain confidential and/or privileged information or material. Any review, retransmission, dissemination to other use of, or taking of any action in reliance upon this information by persons or entities other than the intended recipient is prohibited. If you received this in error, please contact the sender and delete the material from any computer. From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, July 24, 2012 2:07 PM To: Stephen F. Hennigan Subject: NF 22-35 (PTD 212-094) Steve, 1)Can you supply the traveling cylinder plot for anti collision. 2)Are you planning on running a CBL after both the surface and production casing jobs??That is the way you have it written... Note: your procedure is actually just the right level of detail... thankyou. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433(cell) 7/24/2012 AArmstrong Cook Inlet, LLC Ird Location: Cook Inlet,Alaska(Kenai Peninsula) Slot North Fork#22-35 BAKER Field North Fork Well: NFU#22-35 HUGHES ARMSTRONG Facility: North Fork Unit(NAD27) Wellbore: NFU#22-35 :rf, rn, Plot reference wellpath is NFU#22-35 Version#4 True vertical depths are referenced to Nabors 99(RTE) Grid System:NAD27/TM Alaska SP,Zone 4(5004),US feet Measured depths are referenced to Nabors 99(RTE) North Reference:True north Nabors 99(RTE)to Mean Sea Level:678.35 feet Scale:True distance Mean Sea Level to Mud line(At Slot:North Fork#22-35):0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by:jonethoh on 24-Jul-12 Traveling Cylinder:Map North ?TP Ni dep0r are Measured Depths on Reference Wellpath hb F 380_ 80' roan NFJ,iy46 120Ir �s NfJi'_ 300' 90If NO .1011 2702 a, loon ante ante enfr .mf mIr r..,r WM, • .Ofr a0ft • 9. 240- /' j! o. 120,1 210 150' 2 G 190' Scale 1 inch=60 ft Davies, Stephen F (DOA) From: Colby VanDenburg [colby@armstrongoilandgas.com] Sent: Tuesday, July 17, 2012 2:11 PM To: Davies, Stephen F (DOA); Schwartz, Guy L (DOA) Cc: Edward Teng Subject: RE: Armstrong North Fork Unit 23-25 Steve, Sorry for the confusion again. The NFU 22-35 should be classified as a development gas well, not an exploratory well. The 'development gas well' designation should be used for all of our 2012 permit applications at North Fork. Colby VanDenburg Geologist Armstrong Oil and Gas 1421 Blake Street Denver, CO 80202 (303) 623-1821 From: Davies, Stephen F (DOA) [mailto:steve.davies©a alaska.gov] Sent: Tuesday, July 17, 2012 2:31 PM To: Colby VanDenburg; Schwartz, Guy L(DOA) Cc: Edward Teng Subject: RE: Armstrong North Fork Unit 23-25 Colby, I'm reviewing Armstrong's Permit to Drill Application for the proposed NFU 22-35 well. Could you please justify why this well should be classified as an exploratory gas well rather than a development gas well? Thanks, Steve Davies AOGCC 907-793-1224 From: Colby VanDenburg [mailto:colby@armstrongoilandgas.com] Sent: Tuesday, July 10, 2012 2:14 PM To: Schwartz, Guy L (DOA); Davies, Stephen F (DOA) Cc: Edward Teng Subject: Armstrong North Fork Unit 23-25 Steve, We have discussed the well classification for this year's drilling program at North Fork, and we're comfortable with the designation of'Development Well'for the NFU 23-25. Please let me know if we need to make changes to the APD or if you can handle it internally. We will make sure to stay consistent with any subsequent APD filings. Sorry for the confusion. 1 Colby VanDenburg Geologist Armstrong Oil and Gas 1421 Blake Street Denver, CO 80202 (303) 623-1821 2 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME ' ` att: 2-Z PTD# Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD• A/c/,"71 r POOL: A/'-,-r✓ Fc:14 ci tJ/ice o Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approve. •'ect to full compliance with 20 AAC EXCEPTION 25.055. Approval t. .roduce in'ect is contingent upon issuance of a4conset}'ation . := pprovin a spacing exception. �1 eve) �?/c� ,LJ a umes the liability of any protest to the*acing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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Bleys Distribution Date: February 25, 2013 T.D Date: November 28, 2012 North Fork Unit #22-35 2 TABLE OF CONTENTS Table of Contents 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................ 3 1.1 Equipment Summary ...................................................................................................................... 3 1.2 Crew................................................................................................................................................ 3 2 GENERAL WELL DETAILS ................................................................................................................... 4 2.1 Well Objectives ............................................................................................................................... 4 2.2 Well Resume .................................................................................................................................. 4 2.3 Hole Data ........................................................................................................................................ 5 3 GEOLOGICAL DATA ............................................................................................................................. 6 3.1 Formation Tops ............................................................................................................................... 6 3.2 Lithology Review ............................................................................................................................. 7 3.2.1 STERLING FORMATION ........................................................................................................ 7 3.2.2 BELUGA FORMATION ........................................................................................................... 9 3.2.3 TYONEK FORMATION ......................................................................................................... 10 4 Sampling Program/Sample Distribution ............................................................................................... 12 5 DRILLING DATA .................................................................................................................................. 27 5.1 Daily Activity Summary ................................................................................................................. 27 5.2 Surveys ......................................................................................................................................... 34 5.3 Bit Record ..................................................................................................................................... 46 5.4 Mud Record .................................................................................................................................. 47 5.5 Drilling Progress Chart .................................................................................................................. 49 6 SHOW REPORTS ............................................................................................................................... 50 7 DAILY REPORTS ................................................................................................................................ 51 Enclosures: 2”/100’ Formation Log (MD/TVD) 2”/100’ LWD Combo Log (MD/TVD) 2”/100’ Gas Ratio Log (MD/TVD) 2”/100’ Drilling Dynamics Log (MD/TVD) Final Data CD North Fork Unit #22-35 3 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Computer – Drill Floor Monitor Azonix 0.25 hrs Cluster packing due to rig power failure Computer – Pit Monitor Azonix 0 Computer for Company Man Rigwatch Remote (HP Compaq) 0 Computer for Tool Pusher Rigwatch Remote (HP Compaq) 0 Computers for Mudloggers (2) Data editing, Rigwatch Master, and Rigwatch Remote (all HP Compaq) 0 Ditch gas Air-Driven Agitator (mounted in possum belly) Flame ionization total gas & chromatography. 0 Hook Load / Weight on bit Drilling Line Sensor on Dead Man 0 Mud Flow In Derived from Strokes/Minute and Pump Output 0 Mud Flow Out Flow line Sensor 0 Pit Volumes, Pit Gain/Loss 8 Ball-Float sensors. 0 Pump Pressure Standpipe Transducer 0 Pump Stroke Counters (2) 2 Digital Micro switches 0 Rate of Penetration Calculated by RIGWATCH 0 RPM Feed from Canrig Top Drive 0 Torque Feed from Canrig Top Drive 0 1.2 Crew Mud Logging Unit Type: Arctic Mud Logging Unit Number: ML057 Logging Geologists Years *1 Days *2 Sample Catchers Years *1 Days Technician Days James Foradas. 5 32 Steve Franzen 5 30 Allen Williams 1 Tollef Winslow 4 12 Omar Hinostroza 5 15 Josh Dubowski 4 31 Debra Bomar 1 12 Britten Adams 1 12 Harry E. Bleys 12 12 *1 Years experience as Mudlogger *2 Days at wellsite between rig up and rig down of logging unit. North Fork Unit #22-35 4 2 GENERAL WELL DETAILS 2.1 Well Objectives The objective of NORTH FORK UNIT #22-35 is to drill and log a combination gas and oil exploratory well in the North Fork Unit, with a minimum of hole problems or other concerns. 2.2 Well Resume Operator: Armstrong Oil and Gas, Inc. Well Name: NFU 22-35 Field: North Fork Unit County: Kenai Borough State: Alaska Company Representatives: Larry Driskill, Al Lunda, Jim Hickel, Jim Brown Location: Surface Coordinates 588’ FSL, 1571’ FEL, Sec 26 T4S R14W SM X=199838, Y=2121132, Zone 4, ASBPCS Rotary Table Elevation 21.36’ AMSL Classification: Exploratory API #: 50-231-20038-00-00 Permit #: 212-094 Activity Code: AFE # ACILLC 0531 2012-1 Rig Name / Type: Nabors Alaska 99E / Arctic Triple Spud Date November 2, 2012 Total Depth Date: November 28, 2012 Total Depth 10,700’ Primary Targets Tyonek Primary Target Depths Multiple, Unknown Discovery Zones Total Depth Formation: Tyonek Completion Status: 7” OD 6.28” ID casing set at 10,643’ LWD-MWD Services. Baker Hughes Inteq Directional Drilling Baker Hughes Inteq Wireline Logging Services None Drilling Fluids Service MI Swaco Logging Geologists: James Foradas, Joshua Dubowski, Tollef Winslow, Harry E. Bleys Sample Catchers: Steve Franzen, Omar Hinostroza North Fork Unit #22-35 5 2.3 Hole Data Hole Section (in) Maximum Depth TD Form Mud Weight (ppg) Dev. (oinc) Casing (dia “) Shoe Depth LOT (ppg) MD (ft) TVD (ft) MD (ft) TVD (ft) Conductor 140 140 N/A N/A N/A 16 120 120 N/A 13.5 3005 2749 Beluga 8.85 37.17 10.75 3000 2745 16.1 9.875 3025 2765 Beluga 8.85 NA N/A N/A N/A N/A 8.75 10700 9487 Tyonek 9.45 0.18 7” 10643 9431 N/A North Fork Unit #22-35 6 3 GEOLOGICAL DATA 3.1 Formation Tops Zone or Horizon Prognosed Depth (ft) Actual Depth (ft) MD TVD TVD SS MD TVD TVD SS 13.5" Surface Borehole: Sterling 0 0 Surface 0 0 Surface First Gas 719 719 -40 690 690 -11 Beluga 1377 1369 -690 1392 1380 -701 8.75" Production Borehole: Tyonek 5545 4776 -4097 5497 4736 -4057 Ty 4900 5689 4891 -4212 5649 4856 -4177 Ty 5600 6539 5569 -4890 6526 5556 -4876 Tyonek Red 6927 5879 -5200 6935 5880 -5201 Ty 6000 7029 5961 -5282 7038 5963 -5284 Ty 6800 7980 6779 -6100 8011 6811 -6126 Ty 7200 8448 7232 -6553 NP NP NP Ty 7800 9134 7916 -7237 9158 7946 -7267 Ty 8000 9251 8034 -7355 NP NP NP Tyonek Blue 9626 8409 -7730 9641 8429 -7750 Ty 8500 9776 8558 -7879 9783 8571 -7891 Ty 9200 10556 9339 -8660 10581 9369 -8690 TD 11017 9800 -9121 10700 9487 -8809 Horizons, Zones, and Depths provided by the Armstrong Geologist. North Fork Unit #22-35 7 3.2 Lithology Review 3.2.1 STERLING FORMATION (0' MD /O’ TVDSS to 1392’ MD /-701 TVDSS) Sterling Interval Depth (ft MD) Drill Rate (ft/hr) Total Gas (units) Top Base Maximum Minimum Average Maximum Minimum Average Gas pockets above First Gas 120 690 650.09 0.00 133.37 5.39 0.00 0.33 First Gas to formation base 690 1392 299.82 0.00 84.11 136.25 0.00 35.02 Gas Peaks Depth(MD) TG C1 C2 C3 iC4 nC4 iC5 nC5 332’ 5 1078.4 1151’ 136 25143.14 1240’ 49 19777.59 Gas is generally low in the Sterling formation, with the first gas in the Sterling predicted at 719’ MD. However, coal bed methane ranging between 1-5 units (1unit =200ppm methane) was detected in several thin coal beds after 300’ MD was reached. Background gas did not rise and remain consistently above 1 unit until a depth of 690’ MD. Background gas in the First Gas interval within the Sterling averaged 35.02 units with mud weights between 8.6 at spud, and 9.1 ppg above the top of the underlying Beluga. Gas shows in the range of 40-100 units were detected in sand and sandstone between 750’ and 1100’ MD. The highest show peaked in the range of 80-100 units, and all of the shows were apparently associated with methane migration from coal beds the basal Sterling formation. Coal beds in the Sterling below the First Gas line also produced gas shows in the range of 20-130 units. For the purposes of this report the formations in surface hole are described as a whole. The rocks in this interval are composed of claystone, siltstone, tuffaceous siltstone, coal, carbonaceous shales, unconsolidated sands, sandstone, and tuffaceous sandstone. Claystone is present higher in the interval and often intergrades with siltstone. One such intergrade was described at 1020’ to 1140’. The claystone was medium gray; cohesive and sticky; and lumpy to clumpy. It was pulverulent to malleable with an irregular blocky fracture, and in a massive to tabular cuttings habit. The claystone had a dull earthy luster, smooth texture and massive to thick structure. The cuttings were impregnated with sand grains and coal fragments. This claystone was intergraded and/or interbedded with dark gray, dense to soft siltstone. It had a dull luster, gritty texture, and common to laminar structure. Thin to thick coal and sand stringers and beds also occurred at this level. There was intergrading with siltstone and interbedding with sand sandstone, carbonaceous shale and occasionally thin stringers and beds of coal and ash. The claystone becomes more common with depth in this interval. Generally, in this well, claystone is more abundant than siltstone in the Sterling. Siltstone (including coarse claystone and tuffaceous siltstone) is present throughout the interval in varying quantities. In several areas the siltstone intergrades with finer clays and claystone and is described as North Fork Unit #22-35 8 claystone/siltstone or as above as claystone/siltstone. One example of a typical clay-silt intergrade is a Claystone/Siltstone sample obtained between 305’ and 390’ MD. It was medium gray to dark medium gray in color; with moderate to poor induration; and crumbly to pulverulent to rarely dense. It displayed earthy to irregular fracture; resinous to dull luster; and was commonly interbedded with micro thin laminae of carbonaceous shale. Sample was noncalcareous and became dominated by clay towards the end of the interval. It ranged from tacky to clumpy; and was pulverant to somewhat dense with an earthy fracture, and no discernable cuttings habit. The luster ranged from dull to earthy to slightly waxy. It had good cohesiveness and poor to moderate adhesiveness. It was also hydrophilic and slightly expansive. Sands in this section were common, and generally appear as thin stringers in other rocks, but may also represent easily friable grain supported sandstones (see below). Sands sampled between 1200’ and 1290’ were black to dark gray with light gray and greenish hues, and were fine to medium grained. These sands were poor to well sorted; and angular to sub-round with low to moderate sphericity. Proof of common mechanical abrasion was present –including impact and grinding features. The sand was unconsolidated to soft; mostly gray quartz with some translucent quartz. Common dark lithics including grains of coal were present. They were compositionally and texturally submature and occurred in thin stringers with more common claystone. Sandstone/Tuffaceous sandstone cuttings appear rarely in this section, and they were often observed with stringers of gravel when they did occur. Sandstone cuttings were generally tuffaceous sandstone, and due to their trace volume in samples, no sandstone/tuffaceous sandstone descriptions were logged in the Sterling. Textural and compositional maturity increased with depth. All rocks in this interval were also non- calcareous. North Fork Unit #22-35 9 3.2.2 BELUGA FORMATION (1392’ MD /-701’ TVDSS to 5497’ MD /-4057’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 409.67 0.00 91.54 127.66 0.00 34.52 Gas Peaks Depth(MD) TG C1 C2 C3 iC4 nC4 iC5 nC5 1541 44 19027 139 2505 45 33030.97 685.696 42.661 2350 34 34338.03 640.071 35.909 3090 91 16501.77 156.968 3331 80 14560.63 116.448 3882 127 23798.91 271.875 5429 76 44048.22 710.044 38.195 Gas is generally low to moderate in the Beluga formation. Generally background gas throughout the interval averaged 34.52 units with mud weights between 8.8 and 9.9 ppg and varied throughout the drilling of the Beluga, as shown in the table above. Chromatography detected primarily methane (C1) and ethane (C2), with traces of propane (C3) associated with these peaks. Subsequent review of traces of butane and pentane recorded on the log were attributed to noise caused by oil-based mud additives (e.g. Kla- stop®). The additives were added to reduce torque. Sand sampled between 1640’ and 1740’ was of medium gray to dark medium gray color with light green and brown hues. It was predominantly unconsolidated with occasional poor consolidation in a clay and ash matrix. The grain size was lower medium to upper fine and upper medium, with commonly lower fine and lower coarse grains as well. This sand was poorly sorted; had subrounded to subangular and occasionally rounded grains, and poor to moderate sphericity. It was dominated by translucent to smoky gray to clear quartz with the presence of dark lithics being common. Moderate coal cuttings were present further down the interval. Sandstone sampled between 2790’ and 2940’ was dark to medium gray with lighter gray, pale yellow, and greenish hues; lower very fine to lower very coarse grained and moderately sorted. Sandstone was angular to subrounded; very low to moderate sphericity; and showing common signs of mechanical abrasion including frosting and grinding. Sandstone was hard to easily friable; and the grains were supported by a fine ashy to tuffaceous silty matrix -visible on harder cuttings. The sandstone was predominantly of quartz composition with common dark lithics such as biotite. It also included plagioclase, volcanic rocks, and traces of glauconite. The sandstone was compositionally submature; texturally immature; interbedded with carbonaceous shale, coal, and brown gray siltstone occurring in thin beds and stringers. Coal/carbonaceous shales at 4440’ to 4450’ were black with brownish hues; dense to brittle; blocky to planar with splintery and sometimes sub conchoidal fracture. Cuttings habit was tabular to wedge like with coarse cuttings over the shaker; dull to resinous luster; smooth and matte textures; laminar to thin banded structure; fracture consistent with more developed coals; interbedded with sand/sandstone, siltstone, and carbonaceous shale; off-gassing was often observed in coal cuttings. Some pyritic laminae and “wood- grained lamination was seen. Coal grade is bituminous for the most part, with some cuttings possibly North Fork Unit #22-35 10 higher grade. Clay was mostly light to medium gray with brownish hues; clumpy to stiff; dense to pulverulent; amorphous to blocky fracture; massive to wedge-like cuttings habit; dull luster; smooth to clayey textures; some denser specimens exhibit laminae; soft cuttings impregnated with sand; interbedded with sandstone, carbonaceous shale and thin stringers of coal. The Claystone between 3330 and 3510 was medium gray to medium brownish gray; curdy to mushy; crumbly to malleable in tenacity; and had irregular blocky fracture. Cuttings habit was tabular to nodular, and the sample had dull to greasy luster and smooth texture. Structure varied between thin to thick; some cuttings were impregnated with fine to medium sand grains; and there was intergrading with siltstone and interbedding with sand, sandstone, carbonaceous shale and there were occasionally thin stringers and beds of coal and ash. The claystone becomes more common with depth in this interval. The transition to tuffaceous siltstone became evident in the Siltstone sample of 3510’ to 3540’. This siltstone was medium gray to light brownish gray with pale pink and yellow hues; curdy to mushy; and crumbly to pulverant in tenacity. Fracture was irregular to blocky in a tabular to wedge-like cuttings habitat. Luster was waxy to dull earthy; texture gritty to clayey; and thin to laminar banded structure on some specimens. There were some tuffaceous specimens; primarily in pink and yellow hues. 3.2.3 TYONEK FORMATION (5497’ MD /-4057’ TVDSS TO 10700’ MD /-8809TVDSS ) Tyonek Member or Interval Depth (ft MD) Drill Rate (ft/hr) Total Gas (units) Top Base Maximum Minimum Average Maximum Minimum Average Tyonek Top to Ty4900 5497 5649 156.37 45.02 99.01 195.32 18.94 72.70 Ty 4900 5649 6526 529.17 0.00 97.60 295.27 6.71 61.89 Ty 5600 6526 6935 200.33 11.49 95.46 274.77 7.84 45.94 Tyonek Red 6935 7038 166.37 23.39 104.15 79.63 7.46 36.24 Ty 6000 7038 8011 253.93 0.00 66.51 455.95 1.38 62.80 Ty 6800 8011 9158 237.09 0.00 43.63 301.16 8.21 50.63 Ty 7800 9158 9641 92.89 0.00 28.98 343.11 4.26 43.99 Tyonek Blue 9641 9783 85.78 2.34 37.00 177.14 4.52 18.52 Ty 8500 9783 10581 144.16 0.00 32.17 288.31 7.34 37.12 Ty 9200 to TD 10581 10700 77.43 0.00 28.76 331.76 18.37 70.05 Tyonek Top to TD 5497 10700 529.17 0.00 60.28 455.95 1.38 51.71 North Fork Unit #22-35 11 Gas Peaks Depth(MD) TG C1 C2 C3 iC4 nC4 iC5 nC5 5582 195.32 51642.26 1022.810 53.496 5677 295.27 77622.87 1667.405 104.025 6545 274.77 293133.50 4232.863 6948 79.63 50697.43 710.326 7981 455.95 36025.00 817.000 51.000 8676 301.16 55366.28 909.795 57.476 39.002 9220 343.11 47009.65 776.196 65.164 9770 177.14 19617.65 260.492 10338 288.31 24653.10 492.659 40.983 10630 331.76 29171.98 510.161 74.401 Gas in the Tyonek formation was generally higher than it was in the Beluga and Sterling formations. The highest peaks occurred in the Ty6000 and Ty7800 members though the Ty6800 and Ty9200 also produced gas shows of over 300 units. The Tyonek formation average gas overall was 51.71 units, with averages ranging between 36 and 72 units, with the highest averages (above 60 units) in the Tyonek above the Ty5600, the Ty6000 and the Ty9200. Many of the gas peaks were attributed to coal bed methane as determined by spot samples, and a 10-foot sampling interval. The cuttings samples often produced cuttings of coal, many of which were off-gassing. The gassy coals were predicted to occur in thin beds and stringers of methane bearing coal common throughout the formation. Preliminary evaluation of gamma and resistivity data in combination logs appended to this manuscript also supports this conclusion. However, gassy sandstones and tuffaceous sandstones were also detected, and some are described in show reports appended to this manuscript. Due to the generally thin structure of the interbedded sandstone, coal, and related rocks; it was not uncommon to find coal and sandstone within a 10-foot interval; thus making it difficult to attribute the presence of gas to a specific rock type. Chromatography at regular intervals in the Tyonek indicated that gas in this interval is dominated by the light fraction, with methane, ethane, and traces of propane being common in gas chromatography samples. Heavier butane and propane were much rarer and only detected with coal gas shows. Tests for sample fluorescence when the heavies were detected proved negative, suggesting oil is negligible in this interval. Contamination by additives, or minor C4 and C5 trapped in carbonaceous shale or coal may be responsible for their presence. In addition, the traces of butane logged in some intervals correlated with periods when mud oil-water ratios were greater than or equal to 4 percent. This, and Pixler plots in gas show reports indicated dry gas and little condensate. This suggests contamination by mud additives as the likely reason for the presence of butane and pentane as opposed to natural oil. There is a general depositional cycle which progresses with depth, of coals and carbonaceous shale underlain by clay, siltstone, and sand/sandstone. This cycle is repeated throughout the formation. A typical sequence was largely tuffaceous and could occur in a span of a few feet to tens of feet. The Tuffaceous siltstone from 9030’ to 9130’ was dark brownish gray to medium gray with yellowish brown and olive hues; adhesive clayey specimens; brittle to pulverulent tenacity; with blocky to planar fracture. Cuttings habitat was tabular; texture was smooth to gritty; and some carbonaceous laminae were present. The siltstone grew increasingly fissile as it graded to shale; and, it was interbedded with tuffaceous sandstone, carbonaceous shale, and coal. The Coal in the 9030’ to 9130’ sample was mostly black with reddish hues; tough to brittle in tenacity; and had blocky to planar fracture. Cuttings habitat was tabular to wedge-like with some elongated cuttings. Luster was vitreous to resinous; texture was matte and some was brownish mottled. Coal had common laminae and off- North Fork Unit #22-35 12 gassing from cuttings. Tuffaceous sandstone was a typical gas producer in much of the Tyonek, along with methane rich coals. A typical example of Tuffaceous sandstone was described in the 10300’ to 10400’ range. This sample was pale brown to pale orange and medium gray with lighter gray hues; most very fine quartz with coarser grains of dark and light volcanic and sedimentary rock. It was moderate to very well-sorted; angular to round; and of low to high sphericity, higher in finer grains. Coarser grained surfaces showed signs of abrasion and impact; and were friable to easily friable. Some silica cement was present, but most grains were supported in an ash- silt matrix. This sandstone had thin bedding with common laminae; was compositionally and texturally submature; and intergraded to siltstone. It was interbedded in many places with thin stringers and beds of carbonaceous shale and coal as described below. The Coal in aforementioned 10300’ to 10400’ tuffaceous sandstone sample was black with some brownish gray hues in places; dense to crunchy; with blocky planar to subconchoidal fracture. Cuttings were tabular and wedge-like and sometimes elongated; displaying a resinous luster; and having a brownish mottled and matte texture. Structure was finely laminated with some pyrite laminae. Out-gassing ranged from zero to vigorous. 4 Sampling Program/Sample Distribution SAMPLE MANIFEST: ARMSTRONG COOK INLET LLC NFU 22-35: BOXED WASHED & DRIED SAMPLES TOTAL 2 SETS of 11 BOXES Operator: Armstrong Oil and Gas, Inc. Well Name: NFU 22-35 Field: North Fork Unit County: Kenai Borough State: Alaska Company Representatives: Larry Driskill, Jim Brown, Allan Lunda, Jim Hickel Location: Surface Coordinates 588’ FSL, 1571’ FEL, Sec 26 T4S R14W SM X=199838, Y=2121132, Zone 4, ASBPCS Classification: Exploratory API #: 50-231-20038-00-00 Permit #: 212-094 Activity Code: AFE # ACILLC 0503 2012 Rig Name / Type: Nabors Alaska 99E / Arctic Triple Total Depth 10700’ MD Total Depth Formation: Tyonek Total Depth Date: November 28, 2012 Logging Geologists: James Foradas, Joshua Dubowski, Tollef Winslow Sample Catchers: Steve Franzen, Omar Hinostroza North Fork Unit #22-35 13 Set Type and Purpose Interval Frequency Distribution A Washed and Dried Reference Samples 120’ – 5540’ 5540’ – 10700’ 30’ Intervals 10’ Intervals* Att: Colby VanDenburg Armstrong Oil and Gas 1421 Blake Street Denver, Colorado 80202 B Washed and Dried Reference Samples 120’ – 5540’ 5540’ – 10700’ 30’ Intervals 10’ Intervals* Att: Howard Okland AOGCC 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501 *20’ sample when ROP was greater than 60 FPH. BOX INTERVALS: 120’ - 1740’; 1740’ - 3120’; 3120’ - 4470’; 4470’ - 6060’; 6060’ - 7240’; 7240’ - 7990’; 7990’ - 8480’; 8480’ – 9030’; 9030’ – 9530’; 9530’ – 10180’; 10180’ – 10700’; (2 Sets, 22 Boxes Total) North Fork Unit #22-35 27 5 DRILLING DATA 5.1 Daily Activity Summary 11/02/2012: Completed rigging up mudlogging unit (started yesterday) and began drilling at 0600 hours. Drilled ahead from conductor at 140' MD to 1175' MD. Today's cost reflects billing for yesterday and today. 11/03/2012: Drilled ahead to 2,009' and circulated hole clean, max gas 45u; pumped 23bbl slug weighing 11.7ppg and pulled out for a short trip; reamed through a tight spot from 950' to 900'; once back on bottom drilling, screen shaker #1 up to 230API; currently slide drilling at 2040' MD. 11/04/2012: Drilled ahead from 2040' at 650 gpm, 70 rpm, 2250-2350 psi pump pressure, torque 7-11K; currently at 2846'. Change in daily cost due to work during change to fall daylight savings time. 11/05/2012: Rotary drilling from 2820’ to TD at 3005’ MD, GPM=640 RPM=70 PSI=2300 WOB=20-25 UP=115 DN=100 ROT=103 ADT=4 JAR HRS= 51.5; Circulate and Condition; CBU X 2 6060 strokes; pump 30bbl HiVis sweep at GPM=640 PSI= 2200 RPM=70 STKS= 7000; TOOH from 3005’ to 776’ SLM out of hole; TIH from 776 to 3005’. Wash down from 2869’ to 3005’; UP WT 115 DN WT 100, no tight spots Circulate and Condition 650GPM 2300PSI; CBU 1X, pump 30bbl 80 Vis walnut sweep around, circulate until shakers clean, 1+ B.U.S.; TOOH from 3005’; UP WT 115 DN WT 100 to BHA; L/D BHA, 3rd party tools, subs and tools; clean floor for trip out; rig up Weatherford to run casing; Run Casing PJSM; M/U 10¾” shoe joint and float. 11/06/2012: Run casing PJSM; M/U shoe track; check floats, M/U 10 ¾” casing to 3000’ fill every 5/10 down WT=120 UP= 160 , average; M/U TQ 8500 ft/lbs; rig down Weatherford tools, install circulating head/hoses; circulate and condition, circulate casing volume, 4000 strokes, 45spm; RIG up raised flooring, false table; TIH make up stinger for cementing RIH to 1710'; TIH with nose seal on bottom of 5" D.P. from 1710'; tag up and sting into top of float collar; circulate and condition; R/U circ hose, TIW valve, head pin; circulate and condition, break circulation slowly .75bpm-40psi; stage pumps up slowly to 7bpm-200psi; R/U BJ cement lines; prep for cement job; primary cementing PJSM for cement job; pump 40bbl SAPP pill with red dye with rig primary cementing pump 5 bbls water, Pressure test lines to 3000psi, pump cement per BJ, 237bbls 12ppg lead, 44bbls 14.8ppg tail; displace with 5 bbls water and 53 bbls mud; check floats- holding circulate/cement/displace drain stack and flush with retarder pill; flush flow-line; refill riser with retarder; unstring from float collar; R/B 1 stand; drop wiper dart and pump drill pipe volume to flush D.P..; R/D flow nipple and hose. 11/07/2012: TOOH; clean up floor rig down cementers; L/D D.P. from 2856’ to 2347, UP= 75K; downtime draw-works slipped and cut 300 feet of drilling; TOOH from 2347’ to 1234’; L/D/ D.P. from 1234’; L/D nose seal; RIH 2 stands from derrick and L/D; L/D 3rd party tools; clean up and L/D false table, bowl, and slips; nipple up/down diverter system: clean floor, pressure wash diverter, N/D diverter line and knife valve; un- flange diverter tee to starting head; P/U stack to cut casing; cut casing; L/D cut joint; set stack back down; N/D bell nipple; N/D annular preventer. 11/08/2012: N/U/D diverter system, remove diverter T and starter head; clean up well head for welder; bring well head into cellar; welder cut 16" and 10 3/4" to install and weld wellhead; N/U BOPs; N/U single gate, mud X; install 2 7/8x 5 VBR single gate; N/U double gate, annular preventer; install kill and choke HCR and manual valves; C/O pulsation dampener bladder on #2 Mud Pump; clean pits;. backload D.P., load shed w/ 4" D.P. North Fork Unit #22-35 28 11/09/2012: N/U BOPs: plumb in hydraulic lines for upper and shear rams; change upper rams to 4"; pick up double stack and bag, turn mud cross; install choke extension and hose; start torqueing BOPs; torque all studs; hook up choke; kill and Koomey lines; install riser and flow-line, attempt to install riser, did not fit; L/D same; flow-line welder modify riser; service rig: grease crown, blocks, top drive, roughneck; change saver sub to 4" HT38; change gripper, and grease same. 11/10/2012: Install riser and flow-line: welder modifying riser, change out stabbing guide and make up saver sub; install riser and rig up flow line; clean up cellar and draw-works area; TIH to 2863’ UP=70 DN= 55; Circulate and Condition; M/U head pin and circ. hose, circ. 3622 BUS, 6bpm, 350psi, 298gpm; R/D head pin and hose blow down same; TOOH from 2863' to surface racking back in derrick, UPW= 65K; cased hole logs: R/U Pollard wire line; start in hole from CBL; OOH R/D Pollard wire line tools; Install/Remove wear bushing; Install W/R OD 103/4" ID 10", change saver sub; P/U 4" DP from shed, to 1056'. 11/11/2012: P/U D.P. from 1056’ to 2800’, DN= 60 UP= 65; TOOH from 2800’, UP= 65 DN= 55; R/B 30 stands in derrick SLM; P/U D.P. blow down kill line; RIH to 2800’; TOOH from 2800’ UP=65 DN=55; clean up for BOP Test; currently testing BOP’s. 11/12/2012: LD test tool; blow down choke; kill and gas buster; downtime-BOP – choke: drain stack; remove variable rams; replace door seal; install variables attempt to test; test failed; change to 4" rams; test 4"; test failed; R/U to pick up 4"; P/U drill pipe from 95' to 2375’; TOOH with 4" D.P.; rack back in derrick; SLM OOH from2375' to surface, 60k UPW; clear and clean rig floor and stack; N/D BOPs; pull W/R set test plug; remove lower set of rams; prep BOP to change lower single gate; P/U BOPs s remove single gates out from under set on cart. 11/13/2012: Downtime-BOP: choke remove and install single gates, N/U same; install riser, flow line, hole fill; install kill choke and 2 7/8 x 5" variable rams; test same, failed; changed to 4" rams tested; change packing in variables, prepped to change rams; choke void stack; change rams from 4" fixed to 2 7/8 X 5”, test same, failed; change back to 4", fixed, test same, good; change rams R/D and B/D all test equipment, choke manifold, choke and kill lines, top drive; pull test plug; set W/R; P/U BHA #2; TIH; change elevators to 4"; TIH from 635' to 2948', tag cement; stand 1 stand back; circulate and condition; break circulation; stage up to 8bpm, 324gpm, 465psi, pump 4500 strokes; pressure test casing/shoe; test casing to 3000psi for 30 minutes; chart MW 9.3 ppg; bleed off 3.5bbls back; R/D test equipment; rotary drilling: P/U stand; drill out shoe track. Currently drilling out shoe track at 2944’ MD. 11/14/2012: Drill cement float collar, shoe & 8' new hole; displace to New Kla-Shield system; cont drilling new hole to 3,025' MD; circulate and condition for LOT test; perform LOT to 13.5 ppg EMW; pump dry job; POOH; L/D BHA#2; P/U directional BHA; shallow hole test at 951', pump 425gpm, 161spm,640psi; calibrate blocks; TIH from 951' to 3020', break circulation; set parameters; drill from 3025', RPM 75, GPM 475, WOB 5-12, PSI 1500, TQ 9-15; currently drilling at 3025'. 11/15/2012: Drill ahead, back reaming each stand and performing flow check before each connection; drilled to 4576' MD; currently circulating and conditioning on bottom in preparation for TOOH to shoe on wiper trip. 11/16/2012: Short trip to 2,953' (inside shoe); worked through tight spot at 3,420' w/25K over pull; tight spot not seen TIH; TIH w/proper hole fill; trip gas 7 units, wiper gas 73 units; drill ahead at 575gpm, 1,850 psi, 40-80 rpm, 10-15.5K TQ, 128-150 FPH ROH (except when sliding); back ream each stand before connection; begin increasing lubes to 3% at 4,800'; drilling ahead from 4861', 530gpm, 200spm, 1850psi- on 1750-off, 80rpm, TQ-on 10-15 TQ-off 8-9, back ream full stand and flow check every connection, currently drilling ahead at 5260'. North Fork Unit #22-35 29 11/17/2012: Drill ahead at 530gpm, 2100 psi, 9-15K TQ, 6-10 WOB, 120 fph ROP, sliding on occasion; back ream every stand before connection; drill to 6,097' MD; pump 75 viscosity sweep and circulate and clean; short trip to 4577' good hole, TIH from 4577' DWN=90 to 6004'; fill pipe wash down to 6097', wiper gas 77 units; drill ahead 80rpm, 200spm, 530 gpm, psi on 2250, psi off 2000, TQ off 8-9; currently drilling ahead. 11/18/2012: Drill ahead at 530gpm, 2200 psi, 80 RPM, 10-14K TQ, back ream each stand on connections. At 7,239' reduce pump rate due to high vibration to 475gpm, 180spm, 2350psi-on, 2150psi-off, 80rpm 9-10 TQ-off, 12-14TQ-on; currently drilling ahead at 7439'. 11/19/2012: Drill ahead at 475 gpm (reduced rate due to vibration), 2300 psi, 13-15 K TQ, 8-10 WOB; drill to 7,525'; pump sweep; perform short trip to 6090' with no problems; drill ahead at 550 gpm, 2350 psi, 80 RPM, trouble sliding; decision to POOH; circulate and condition mud; pump sweep; circulate clean; pump dry job and POOH; currently L/D down BHA, and removing sources. 11/20/2012: Continue to POOH; L/D remaining BHA; Test B.O.P.'s; P/U new bit and BHA and RIH; currently at 3045'. 11/21/2012: Continue to RIH; CBU at 3040' 27 units max gas; CBU at 5600' 337 units max gas; drilling ahead rotating and sliding (CBU at 7560' 536 units max gas); started to drop angle at ~7500'; drilling ahead from 7818' to 8162' 550gpm, 210spm, PSI-off=3450, PSI-on=3300, 60rpm, 11-12 TQ-off, TQ-on 14-16 UPW= 185, DNW= 130 RTW= 155 MWT=9.4, WOB= 5-6, sliding on occasion, back reaming every stand; currently at 8173' MD. 11/22/2012: Drilled ahead to 8418'; Unable to get a signal from the MWD tool; cycled pumps and trouble shoot tool signal; stand back 1 stand; pump sweep; CBU, 33 units max gas; POOH; currently laying down BHA. Note additional DML cost due to Holiday rate (Thanksgiving). 11/23/2012: L/D BHA to malfunctioning tool; clear rig floor; P/U up new MWD tool; RIH (Bit#4-RR1); shallow test MWD, max gas 74 units; continue to RIH to the shoe; Circulate at the shoe while cut and slip drilling line; service top drive and encoder on top drive; continue to RIH pump btms up @ 5200' (max gas 28 units) and 7500' (max gas 233 units) per Co. man, no tight spots encountered; wash down from 8312' to 8418' (max gas 219 units); trouble rotating due to high torque; pump 30bbl hi-vis sweep; rotate and recip. pipe slowly down to bottom; commenced drilling at 22:20 hours, mostly sliding; currently at 8463' MD. 11/24/2012: Drilling ahead; drop angle and sliding complete by approximately 8800'; rotating ROP at 40' to 50' per hour; pumped high viscosity sweep at 8,886' with minimal increase in cuttings 80rpm TQ-16-18k, WOB=2-10k, 525gpm,3800psi, MWT-9.4ppg; currently drilling at 9082' MD. 11/25/2012: Drilling ahead - rotating, 530 GPM, 200 SPM, 3900psi-on, 3700psi-off, 80RPM, 16-17k TQ- on, 14-15 TQ-off, 9.4+MWT, 2-8WOB, 10-30FPH, back ream every stand, pumping sweeps as needed; drilled to 9553' MD; TOOH on wiper trip from 9553'; currently at 9233' MD on wiper trip. 11/26/2012: Short trip back to 8000'; worked through tight spot at 8126', pulled 25K over; cleaned up; service top drive; TIH, no tight spots; pre-cautionary wash down from 9554' to bottom (66 units max gas); drilling ahead 50RPM, TQ=16-20k, WOB=6-12k, 500GPM, 3725PSI, MWT=9.4ppg; currently at 10,014'. 11/27/2012: Drilling ahead from 10,014' back ream every stand, 10-40FPR, 190SPM, 50rpm, TQ=17-21k, WOB=6-12k, 503GPM, 3850PSI, MWT=9.4ppg; currently at 10,500' MD. North Fork Unit #22-35 30 11/28/2012: Drilled to TD at 10700', reached at 0900 hrs; CBU; Pump sweep around (max 51 units gas); POOH, tight spot at 10559' - pump and ream through (22 units gas); continue to POOH on elevators; pump slug at 9615' (9 units gas); continue to POOH, currently at 2875' MD. 11/29/2012: Continued POOH to surface; L/D BHA#4; clear rig floor; test BOP's with no problems; P/U BHA#5; RIH at 1800hrs, currently running in at 5450' MD. 11/30/2012: Continue to RIH with clean-out assembly; wash and ream through several tight spots while running in the hole; CBU when on bottom (186 units max gas); pump sweep around; POOH; wash and ream tight spot from 10560' to 10540'; Continue to POOH to 10270'; run back to bottom; CBU (259 units max gas); pump and spot lubricant pill; pump slug; POOH on elevators; trip out was slick. POOH nearly complete. 12/01/2012: Lay down clean-out BHA; change rams and test; dummy run hanger; R/U and run 7" casing; CBU at 2982' (46 units max gas); started transferring mud to storage to make room for cement displacement at 1945hrs; currently running casing at 8598' MD without any problems. 12/02/2012: Run casing from 8298’-10673’ MD. Rig up and down to run casing tools, spider slips, cables, and fill up tools. Circulate and condition rig up circulating head, plug valves, transducer. Install cement lines. Pre- job safety meeting (going over pumping schedule). Primary cementing test lines to 400 PSI and check for leaks. Finish displacing cement with 404BBLS of water. Blow down and rig down cementing lines and cement head. Rig up/down to run casing set packoff. Test packoff and hanger void to 5000PSI. Rig up/down to run casing set wearing ring. Run down stabbing board. Run down long bales and install short bales. Pick up BHA M/U mill, 7” casing scraper, bit sub with ported float. 12 joints 4” HWDP. Trip in hole to 4094’ MD. Service rig, blocks, and draw works. Trip in hole continually. Max gas 97.5u. 12/03/2012: Trip in hole from 7340’-10581’MD. Clean out mud system, clean pits, clean under shakers, and clean out mud lines to brine. Circulate and condition hole with 80 strokes per minute. 650PSI, 215GPM while cleaning pits for displacement. Clean out mud system and build 30BBLS sweeps. Offload dirty mud and water from pits to make room for displacement. Displace to water base pump with 30BBLS sweep. Trip out of hole from 10581’-195’MD. Pull out sideways. Cleaning pits. 12/04/2012: Lay down drill pipe from 3712’-382’MD. Lay down BHA, Lay down 12 HT40 heavy wall, scraper, mill, float sub, and crossovers. Cased hole log PJSM and rig up wire liners to do bond logs. Cased hole logs wire line bond logs and drift, strap 2 7/8” with tubing. Cased hole log finish with cement bond log. Run down pollard e-line. Pressure test casing shoe with 7”. Pressure casing to 4000PSI for 30 minutes. Record test on chart. Change rams pull wear ring. Set test plug. C/O BTM to 2 7/8” and C/O top rams to 2 7/8”x 5 VBR. Pull up test tools and move up test joints. Fill system with water and purge air. Test BOPS and gas alarms. Record BOPS and gas alarms test on chart. Lay down test tools and test joints. Drain water and blow down lines. Pull test plug. Set wear rings. 12/05/2012: Service rig clean, service top drive, crown, and PMS till order are given. Cut drilling line by 100ft. Service rig and prepare for wire liners. Continue PMS, cleaning, and gathering crossovers for tuning run. Completion of PU, LD, make-up tools, and BHA spot baker tools in shed. Run up pollard e-line. Completion of stick line and wireline worked e-line; make a gauge ring run. Set packer @ 9040’ MD. Completion of PU, LD, make-up tools, and BHA run down pollard e-line. Completion of PU, LD, make-up tools, and BHA run up (Weatherford) to run tubing. Completion of trip tubing/drill pipe, pull up tubing per tally and running orders. 12/06/2012: Completion-trip tubing drill pipe from 668’ to 4620’MD. Completion-trip tubing drill pipe from 4620’ to 9028’MD. Completion-trip tubing drill pipe rig up cross over to 2 7/8 to circulate. Completion-trip tubing drill pipe BRK circulation-1 BPM 40PSI. S/O until pressure increase seen. Shut down pumps; North Fork Unit #22-35 31 continue to S/O until setting 10K down. Take space out measurements. Add 2’ pup from space out. Land tubing setting 10K down. Completion-trip tubing drill pipe R/U 2 TIW valves and XO’s flange up flow cross to top TIW valves. R/U displacement hose. Completion-slick line wireline work R/U pollard slick line. Completion-slick line wireline work swab fluid out of 2 7/8” tubing with slickline. Completion-slick line wireline work R/D slickline. Completion-P/U, L/D, makeup tools, BHA remove flow cross and upper TIW valve, and install gate below flow cross. 12/07/2012: Slick line/wireline work. Finishing tightening flow cross, valve, hose to stand pipe, and rig up expo hard line. Install cap on lubricator crossover and test via expo to 4200PSI–350PSI. Pick up lubricator rig up, rig up guns in doghouse install lubricator test 4200PSI-350PSI. Run in to perforate 7” via pollard wire line. Pollard wire line shoot PERF guns from 9837’-9858’ MD. POOH, and L/D PERF guns to shed. Monitor well, and pollard prep guns from run #2. RIH with gun and run #2 shoot @ 9414’-9426’ MD. POOH and L/D spent gun to shed. Prep for next run and monitor well. P/U gun #3 and M/U lubricator. RIH shoot @ 9274’-9285’ MD. From 9287’-9300’ MD POOH and L/D to shed. Monitor well and prep gun for run #4. 12/08/2012: Service rig equipment. Removed damage finger, safe out off driller’s side tuber, and damaged line. Pollard wire line run with baler, swab tubing, and total of 7BBLS swabbed. Rig down slick line and prep for e-line. Rig up pollard lubricator and pollard loading guns in the pipe shed. P/U lubricator gun run #5. RIH shot @ 9177’-9198’ MD. POOH and lay down spent gun to shed. M/U new gun and run shoot #6 @ 9159’-9177’ MD. POOH to 69’ MD because of hung up in hole. All hands attempt to pump and wash free pump with 8-10BBLS @ 7-8BPM and 65PSI. Try to work line (No good). Pull with blocks line parted @ sheave, and R/U stuffing box on e-line BOP. Found bad line in lubricator, attempt to pull tools, pull 4’ of line, and no tools. R/D pollard e-line. Clean rig platform clear. R/U pollard slick line and RIH with 2.25 gauge ring. 12/09/2012: Completion slick line/wireline work PJSM. Run 2.25” gauge on pollard slick line, impression block. Swab well, via pollard taking returns to expo, and lost swab tool at 9400’MD. Waiting on tools, clean floor, mezzanine, stack, and work on 50# checklist. Fishing for swab tools. Attempt to run 2.25 magnet and pat TIW. Second attempt with 1 ¼ magnet can’t get past TIW. Change to stabbing tool and attempt to stab cups to retrieve swab. Retrieve only two cups. Continue to fish and 1.25” magnet will not pass through TIW. Change tool and attempt to push swabs to bottom. Push swabs from 8935’-8940’MD and POOH. Pollard slick line M/U weight bars, RIH; attempt to push down on swab. Attempt failed and POOH. R/D slick line. Cleaning rig and platform clear and clean rig floor. Pollard e-line on location, prep tools and rig up to perforate tubing. 12/10/2012: Circulate and condition hole. Rig down EXPO hard line and move unit out of way. Rig down flow cross, bleed/pump hose, and valves. Circulate and condition 6400 strike, monitor well, blow down top drive, and rig up safety valves. Trip tubing drill pipe 2 7/8” from 9040’-7333’ MD. Trip tubing drill pipe weave 2 7/8” and tubing together at the “L” with sash cord. Trip tubing drill pipe from 7333’-3941’ MD. Continue POOH from 5145’ MD at 45K UPW. Lay down six joints; retrieve spent gun, e-line, and swabs. Lay down seal assembly and run down Weatherford tool. Run up pollard slick line, run in hole and set pug @ 9077’ MD. Wire line depth, POOH, and move up prong. RIH, set tool, and POOH. Run down slick line. Test BOPS void stack, pull W/R, M/U test joints, and set test plug for BOPS. 12/11/2012: Test BOPS from 250 psi to 400 psi. Test BOPS blow down kill, choke, and top drive install wear ring. Pressure test casing shoes to 1000 psi for five minutes and test plug in packer. Pull, lay down, and make up tools for BHA, Packer and make up joints for #1. Clean up and prep for packer run while waiting on new packer. Make up RTTS with crossover single in with 6 joints. Run in hole out to derrick. Continue to TIH with 2 7/8”. MOD tubing from 189’-5529’ MD. Change seal rings on TIH. Set RTTS packer @ 5529’ MD. Test back side to 1000PSI. Work wire line and Expo-well testing on manifold. North Fork Unit #22-35 32 12/12/2012: Rig up expro flow testers, and pollard slick line. Prepare to swab well. Run swab tool on Pollard slick line to 2300 ft. Finished swab and pulled out and rigged down. Rigged up to test Expro hard line. Tested 500psi to 4000psi. Completed test and rigged down. Rigged up to run Pollard Slick line and perforate casing. Ran in hole to 7060 ft., and began perforation to 7074 ft. Pulled Out of hole with spent perforation guns. Picked up lubricator and guns for perforation run Number 2. Started to test with rig pump off. Test failed. The e-line and rope socket parted. Laid down gun and lubricator rehead. Picked up gun and lubricator. Retest keeping test pump Staged up to 4000 psi. Completed good test. Began perforation run number 2 from 7040 ft. with rig Pump off. Test failed. The e-line and rope socket parted. Laid down gun and lubricator Rehead. Picked up gun and lubricator. Retest keeping test pump staged up to 4000 psi. Completed Good test. Began perforation run number 2 from 7040 ft. 12/13/2012: Formation testing through expro. Rig maintenance and clean rig. Take on brine to prep For well kill. Rig down expro, close bag and rig up to bull head. Open to well and Circulate. Bleed off and shut in. Secure well rig down pump and expro testing. Rig up to Kill well. Open bypass to packer. Stage up pumps. Shut down monitors and pump dry job. Rig down pump in subs, cross overs, topdrive, choke manifold, and drain gas buster. Rig up Weatherford. Trip out of hole from 5529 ft. Lay down BHA and place in pipe shed. Prepare And load guns in shed for next perforation run. 12/14/2012: Make up Halliburton guns, firing head and RA sub. Run in hole from 87 ft to 3785 ft., than continue to 6999 ft. Change out saver sub, guides, die blocks. Break connection on TIW than verify torque on Halliburton head. Rig up Pollard e-line. Run in hole to correlate and confirm correct depth. Found to be 7 ft high. Pull out of hole and rig down wire. Change out elevators to 2 7/8 inch and Make up 10. Run in hole and set packer at 6950 ft. Top. Change elevators to 5 inch and make up line To run in hole checking depth. At correct depth. Pulled out of hole and rigged down wire. Make Up and pick up flow back tree. Rig up expro well testers. Test surface equally to 4000 psi. Pressure up back side to 1800 psi., and open valve bleed off same, and drop rod, to fire guns. Testing Expro monitor well at several intervals noting pressure. Final pressure is 107 psi at 22:39 hours. 12/15/2012: Monitoring well bore as fluid returns to tank and flaring of gas. Shut in and bleed off expro unit. Kill well, rig down hard line and release packer. Circulate and condition mud. Shut Well in, line up and circulate back up through choke and gas buster. Hold back pressure and circulate and condition. Shut pumps off and bleed off pressure. Open rams and monitor well. Continue to circulate through gas buster. Shut down monitoring well. Circulate and weight up To 8.7 ppg. Shut down monitoring after 10 minutes. Wait monitor and well static so pump dry job. Rig down test tree, and lay down pipe in pipe shed. Change out elevators to 2 7/8 inch. Blow down through choke manifold, and top drive and rig up Weatherford casing equipment. Pull out of Hole from 7074 ft and lay down 10 ft. pup joint and 2 singles in pipe shed. Continue to pull out of hole. 12/16/2012: Diverter system cut conductor pipe and raise with top drive and bridge so peak can add to Conductor. Cut off bell nipple and make up diverter line. Make up flow nipple and flow line. Install turnbuckles and center stack. Install hole fill and bleeder lines. Hook up Komey lines to annular and knife valve. Function test diverter. Pickup and rack back thirty stands of five Inch drill pipe. Mixing spud mud and building volume. Load heavy weight drill pipe in shed than Strap and tally. Install MWD transducer at top of standpipe and route cable to it. Pick up Drill pipe, heavy drill pipe, and jars to rack back in derrick. North Fork Unit #22-35 33 12/17/2012: Pick up test tools and pull test plug. Blow down 2 7/8 inch TIW, Dart and XO. Make up 4.5 inch IF TIW, Port sub on 2 7/8 inch test joint. Install test plug and refill BOP lines. Close annular. Test Annular. Annular flange leaks. Torque flange down tighter. Test annular and lower blind rams. Attempt to test topdrive on floor. Test failed high pressure. Prepare for test of Hydrill, and Savar Sub. Lay-down test tool and blow down lay-down test. Pull test plug and install wear Bushing. Blow down choke, and lines. Drain stack. And steam topdrive valve and grease. Fluid Pack topdrive. Attempt to test again, and still failed. Service topdrive and blow down testing equipment. Break Saver Sub clamps and replace Hydrill IBOP valve on topdrive. Service topdrive And change out Saver Sub and rebuild IBOP. Diagnosed topdrive timing issues and corrected. Test bops and attempted to test upper IBOP on topdrive. North Fork Unit #22-35 34 5.2 Surveys Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 20.55 0 0 20.55 0 0 0 0 181 0.9 342.19 180.99 1.2 -0.39 1.26 0.56 271 0.8 315.99 270.98 2.33 -1.04 2.57 0.44 362 0.79 334.35 361.98 3.35 -1.75 3.81 0.28 451 0.9 329.39 450.97 4.51 -2.37 5.12 0.14 540 0.62 315.12 539.96 5.45 -3.07 6.29 0.37 629 1.14 171.63 628.95 4.92 -3.28 6.87 1.88 717 1.33 176.78 716.93 3.04 -3.1 8.75 0.25 813 3.35 226.58 812.85 0 -5.07 12.38 2.81 908 5.13 228.23 907.59 -4.74 -10.26 19.41 1.88 1003 7.45 216.36 1002.02 -12.54 -17.08 29.77 2.79 1097 10.96 212.89 1094.79 -24.96 -25.56 44.8 3.78 1192 13.6 214.82 1187.61 -41.72 -36.84 65.01 2.81 1287 15.31 210.9 1279.6 -61.65 -49.67 88.71 2.07 1383 16.87 210.79 1371.83 -84.5 -63.31 115.32 1.63 1478 18.79 212.96 1462.27 -109.18 -78.69 144.41 2.14 1573 20.7 215.49 1551.68 -135.7 -96.77 176.5 2.2 1667 22.45 216.02 1639.09 -163.75 -116.97 211.06 1.87 1762 24.57 214.98 1726.2 -194.6 -138.96 248.96 2.28 1855 27.34 214.15 1809.81 -228.13 -162.04 289.65 3 1949 29.73 215.85 1892.39 -264.88 -187.81 334.55 2.68 2047 31.24 217.8 1976.84 -304.66 -217.62 384.25 1.84 2142 33.72 217.2 2056.98 -345.14 -248.66 435.26 2.64 2237 35.84 216.11 2135 -388.62 -281 489.45 2.33 2331 36.44 215.64 2210.91 -433.55 -313.49 544.89 0.7 2427 36.54 215.95 2288.09 -479.85 -346.88 601.98 0.22 2522 36.79 216.72 2364.29 -525.55 -380.49 658.7 0.55 2618 36.79 216.15 2441.18 -571.8 -414.63 716.19 0.36 2715 36.7 216.24 2518.9 -618.63 -448.9 774.22 0.11 2810 37.11 217.24 2594.87 -664.34 -483.03 831.27 0.77 2906 37.73 217.29 2671.11 -710.77 -518.35 889.61 0.64 2945 37.75 217.43 2701.95 -729.74 -532.84 913.48 0.21 3044 37.19 217.59 2780.53 -777.51 -569.51 973.7 0.57 3087 37 218.09 2814.83 -797.99 -585.42 999.63 0.83 3182 36.78 217.97 2890.81 -842.91 -620.55 1056.66 0.24 3278 36.52 217.67 2967.83 -888.18 -655.69 1113.96 0.33 3374 37.15 215.8 3044.66 -934.3 -690.1 1171.51 1.34 North Fork Unit #22-35 35 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 3469 36.88 215.9 3120.52 -980.66 -723.59 1228.7 0.29 3565 37.42 214.04 3197.04 -1028.16 -756.81 1286.67 1.3 3659 37.15 213.67 3271.83 -1075.45 -788.54 1343.61 0.37 3757 36.87 213.2 3350.08 -1124.68 -821.04 1402.61 0.4 3853 36.48 212.8 3427.08 -1172.77 -852.27 1459.95 0.48 3949 37.39 214.71 3503.81 -1220.72 -884.33 1517.63 1.53 4043 37.22 215.68 3578.58 -1267.28 -917.16 1574.6 0.65 4138 36.76 215.01 3654.46 -1313.91 -950.23 1631.76 0.65 4233 36.6 214.74 3730.65 -1360.46 -982.68 1688.51 0.23 4328 37.02 215.09 3806.71 -1407.13 -1015.26 1745.43 0.49 4424 36.96 215.76 3883.39 -1454.2 -1048.74 1803.19 0.42 4519 37.41 216.6 3959.07 -1500.54 -1082.64 1860.6 0.72 4612 37.07 216.58 4033.11 -1545.73 -1116.19 1916.88 0.37 4709 36.84 215.96 4110.62 -1592.74 -1150.69 1975.2 0.45 4802 37.07 216.8 4184.94 -1637.75 -1183.86 2031.11 0.6 4898 37.64 217.15 4261.25 -1684.29 -1218.89 2089.36 0.63 4994 37.89 216.41 4337.14 -1731.37 -1254.1 2148.15 0.54 5090 37.34 215.95 4413.19 -1778.66 -1288.69 2206.74 0.64 5185 37.64 216.63 4488.57 -1825.26 -1322.91 2264.55 0.54 5280 36.94 217.83 4564.15 -1871.1 -1357.73 2322.11 1.06 5374 37.71 217.72 4638.89 -1916.15 -1392.64 2379.11 0.81 5469 38.16 217.49 4713.82 -1962.41 -1428.28 2437.51 0.5 5565 37.85 217.58 4789.47 -2009.29 -1464.29 2496.62 0.33 5659 37.56 217.24 4863.84 -2054.95 -1499.21 2554.11 0.38 5754 36.93 217.22 4939.46 -2100.73 -1534 2611.6 0.67 5849 37.11 217.82 5015.31 -2146.1 -1568.83 2668.8 0.43 5944 37.54 215.87 5090.86 -2192.19 -1603.36 2726.4 1.33 6039 36.87 215.4 5166.53 -2238.87 -1636.83 2783.84 0.77 6134 37.62 215.65 5242.16 -2285.66 -1670.24 2841.33 0.81 6231 37.22 215.84 5319.2 -2333.5 -1704.67 2900.27 0.43 6327 36.97 215.47 5395.77 -2380.54 -1738.42 2958.16 0.35 6421 36.46 215.63 5471.13 -2426.26 -1771.09 3014.36 0.55 6516 37.73 216.28 5546.9 -2472.63 -1804.74 3071.65 1.4 6610 37.55 216.41 5621.34 -2518.87 -1838.76 3129.05 0.21 6707 37.67 215.63 5698.18 -2566.75 -1873.57 3188.25 0.5 6802 37.32 215.27 5773.56 -2613.86 -1907.11 3246.07 0.43 6896 36.76 215.58 5848.58 -2660 -1939.93 3302.7 0.63 6993 36.25 215.9 5926.55 -2706.84 -1973.64 3360.41 0.56 7087 35.79 215.97 6002.58 -2751.6 -2006.08 3415.69 0.5 North Fork Unit #22-35 36 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 7182 35.33 215.87 6079.86 -2796.34 -2038.49 3470.93 0.49 7277 34.25 215.07 6157.88 -2840.48 -2069.95 3525.13 1.24 7372 32.93 215.25 6237.02 -2883.44 -2100.21 3577.69 1.39 7467 30.58 216.86 6317.79 -2923.87 -2129.61 3627.68 2.63 7501 29.92 216.86 6347.16 -2937.58 -2139.89 3644.81 1.95 7588 28.52 215.59 6423.09 -2971.83 -2164.99 3687.27 1.76 7684 26.27 213.76 6508.32 -3008.13 -2190.14 3731.44 2.49 7780 24.08 213.95 6595.2 -3042.05 -2212.89 3772.28 2.28 7875 21.1 213.69 6682.9 -3072.36 -2233.2 3808.77 3.14 7970 18.84 214.1 6772.18 -3099.3 -2251.29 3841.21 2.38 8065 16.45 212.72 6862.7 -3123.32 -2267.16 3870.01 2.56 8160 14.54 214.86 6954.25 -3144.42 -2281.25 3895.38 2.1 8256 12.57 214.64 7047.57 -3162.91 -2294.08 3917.88 2.05 8350 9.78 214.66 7139.78 -3177.89 -2304.43 3936.09 2.97 8446 7.41 215.71 7234.69 -3189.63 -2312.69 3950.44 2.47 8541 5.16 212.09 7329.11 -3198.22 -2318.53 3960.84 2.41 8637 3.26 211.26 7424.85 -3204.21 -2322.24 3967.88 1.98 8732 1.38 211.72 7519.77 -3207.49 -2324.25 3971.72 1.98 8827 0.46 190.82 7614.76 -3208.84 -2324.92 3973.23 1.01 8921 0.37 191.48 7708.75 -3209.51 -2325.05 3973.92 0.09 9019 0.31 190.18 7806.75 -3210.09 -2325.16 3974.5 0.07 9114 0.25 184.56 7901.75 -3210.54 -2325.22 3974.96 0.07 9207 0.26 161.15 7994.75 -3210.95 -2325.17 3975.37 0.11 9303 0.22 124.6 8090.75 -3211.26 -2324.95 3975.75 0.16 9398 0.23 111.68 8185.75 -3211.43 -2324.62 3976.12 0.06 9492 0.34 87.46 8279.75 -3211.49 -2324.16 3976.58 0.17 9592 0.48 78.37 8379.74 -3211.39 -2323.45 3977.3 0.15 9686 0.57 68.34 8473.74 -3211.14 -2322.63 3978.16 0.14 9782 0.76 61.59 8569.73 -3210.66 -2321.63 3979.27 0.21 9878 0.97 54.3 8665.72 -3209.88 -2320.4 3980.72 0.25 9976 0.4 90.92 8763.72 -3209.4 -2319.39 3981.84 0.71 10072 0.4 109.05 8859.71 -3209.52 -2318.73 3982.51 0.13 10166 0.59 149.61 8953.71 -3210.05 -2318.17 3983.28 0.41 10262 0.68 188.87 9049.7 -3211.04 -2318.01 3984.28 0.45 10358 0.85 211.23 9145.7 -3212.21 -2318.47 3985.54 0.35 10453 0.73 203.29 9240.69 -3213.37 -2319.07 3986.85 0.17 10549 0.43 222.95 9336.68 -3214.19 -2319.56 3987.8 0.37 10642 0.18 246.46 9429.68 -3214.5 -2319.93 3988.29 0.29 46 5.3 Bit Record BIT NO. SIZE TYPE S/N JETS/ TFA IN OUT FT HRS AVE ROP COND 1 13 ½” HTC MXL-1X 5196664 14, 3x16 0.7394 120’ 3005’ 2885’ 51.5 55.7 1-2-WT-A 2 9 7/8” HTC TGXA971 5085654 3X20 0.920 3005’ 3025’ 20’ 0.6 33.3 1-2-WT-A 3 8 ¾” HCC Q505X 7016082 7X12 0.773 3025’ 7560’ 4535’ 62.9 72.1 1-1-ER-N-X 4 8 ¾” HCC QD 506FX 7138043 6X14 0.9020 7560’ 8418’ 858’ 21.1 40.7 1-1-NO-A- 4-RR 8 ¾” HCC QD 506FX 7138043 6X14 0.9020 8418’ 10700 ’ 2282’ 81.4 28.1 1-1-WT-A 4-RR1 8 ¾” HCC QD 506FX 7138043 6X14 0.9020 10700 ’ 10700 ’ 0 0 0 1-1-1-WT-A 47 5. 4 M u d R e c o r d Co n t r a c t o r : M i S w a c o Mu d T y p e : G e l S p u d M u d 1 2 0 ’ – 3 0 0 0 ’ ; K l a - S h i e l d 3 0 0 0 ’ – 1 1 6 6 7 ’ Da t e D e p t h MW (p p g ) VI S (s / q t ) PV Y P G e l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) MB T p H Cl (ml/l) Ca (ml/l) 11 / 2 / 2 0 1 2 2 1 3 8 . 6 5 5 1 1 1 7 1 1 / 2 5 / 3 3 N C 2 / 5 / 9 5 T R C 2 2 . 5 9 . 3 4 0 0 8 0 11 / 3 / 2 0 1 2 2 0 0 9 9 . 6 4 6 1 5 1 2 4 / 3 0 / 3 6 1 1 . 3 2 / 1 0 / 9 0 0 . 1 5 2 2 . 5 9 . 7 5 0 0 - 11 / 4 / 2 0 1 2 2 7 6 4 9 . 8 4 9 1 4 1 2 5 / 1 5 / 2 5 7 . 8 2 / - 1 0 . 5 / 9 0 0 . 2 5 2 3 . 7 5 9 . 9 4 0 0 - 11 / 5 / 2 0 1 2 3 0 0 5 9 . 9 4 7 1 5 1 7 7 / 1 5 / 2 3 7 . 9 2 / - 1 0 . 7 5 / 8 9 0 . 1 5 2 3 . 7 5 1 0 . 0 4 5 0 1 0 11 / 6 / 2 0 1 2 3 0 0 5 - - - - - - - - - - - - - - 11 / 7 / 2 0 1 2 3 0 0 5 9 . 9 4 5 1 0 6 3 / 1 1 / 1 7 1 0 . 3 2 / - 1 0 . 5 / 9 0 0 . 1 5 2 3 . 7 5 8 . 4 5 0 0 4 0 11 / 8 / 2 0 1 2 3 0 0 5 9 . 9 4 5 1 0 6 3 / 1 1 / 1 7 1 0 . 3 2 / - 1 0 . 5 / 9 0 0 . 1 5 2 3 . 7 5 8 . 4 5 0 0 4 0 11 / 9 / 2 0 1 2 30 0 5 9 . 9 4 5 1 0 6 3 / 1 1 / 1 7 1 0 . 3 2 / - 1 0 . 5 / 9 0 0 . 1 5 2 3 . 7 5 8 . 4 5 0 0 4 0 11 / 1 0 / 2 0 1 2 3 0 0 5 8 . 8 4 3 6 1 5 5 / 5 / 5 1 0 . 2 1 / - 3 . 0 / 9 7 - - 1 0 . 2 3 0 5 0 0 6 5 11 / 1 1 / 2 0 1 2 3 0 0 5 8 . 8 4 6 7 1 6 6 / 7 / 7 1 0 . 5 1 / - 3 . 0 / 9 7 - - 1 0 . 4 3 0 5 0 0 6 0 11 / 1 2 / 2 0 1 2 3 0 0 5 9 . 7 4 3 1 0 7 4 / 1 7 / 3 0 1 3 . 8 2 / - 1 0 . 5 / 9 0 T R C 2 3 . 7 5 8 . 7 1 1 0 0 7 2 11 / 1 3 / 2 0 1 2 3 0 0 5 9 . 3 3 0 4 2 / / 1 9 . 3 2 / - 1 0 . 0 / 9 0 T R C 2 2 . 5 9 . 2 1 6 0 0 4 0 11 / 1 4 / 2 0 1 2 3 3 2 5 8 . 8 4 3 6 1 4 5 / 5 / 6 1 0 . 0 1 / 1 3 . 0 / 9 7 - - 1 0 . 5 3 0 0 0 0 1 4 0 11 / 1 5 / 2 0 1 2 4 5 7 6 9 . 4 3 8 7 1 2 4 / 6 / 7 8 . 9 1 / 1 6 . 0 2 / 9 2 0 . 2 2 . 2 5 1 0 . 0 2 9 0 0 0 4 0 11 / 1 6 / 2 0 1 2 5 1 7 1 9 . 3 4 8 1 1 1 9 6 / 1 1 / 1 4 6 . 2 1 / 1 1 0 . 0 3 / 8 7 0 . 2 5 2 . 5 9 . 8 3 0 0 0 0 6 0 11 / 1 7 / 2 0 1 2 6 1 2 4 9 . 2 4 7 9 1 7 6 / 9 / 1 1 6 . 8 1 / 1 1 2 . 0 3 / 8 5 0 . 2 3 . 5 9 . 5 2 8 5 0 0 4 0 11 / 1 8 / 2 0 1 2 7 3 7 2 9 . 5 5 0 1 1 1 7 6 / 1 0 / 1 5 6 . 8 1 / 1 1 3 . 0 3 / 8 5 0 . 2 3 . 5 9 . 7 2 9 0 0 0 8 0 11 / 1 9 / 2 0 1 2 7 5 6 0 9 . 2 4 7 1 0 1 7 6 / 1 1 / 1 6 5 . 9 1 / 1 1 0 . 5 3 / 8 7 0 . 1 5 3 . 5 1 0 . 1 3 0 5 0 0 8 0 11 / 2 0 / 2 0 1 2 7 5 6 0 9 . 2 4 7 9 1 6 5 / 1 0 / 1 5 5 . 8 1 / 1 1 0 . 5 3 / 8 7 0 . 1 5 3 . 5 1 0 . 1 3 0 5 0 0 8 0 11 / 2 1 / 2 0 1 2 8 1 2 1 9 . 5 4 8 1 1 1 9 7 / 1 1 / 1 7 5 . 2 1 / 1 1 2 . 0 3 / 8 5 0 . 1 5 4 . 0 9 . 9 3 1 5 0 0 8 0 11 / 2 2 / 2 0 1 2 8 4 1 8 9 . 4 4 8 1 1 1 7 4 / 5 / 6 4 . 9 1 / 1 1 1 . 0 4 / 8 6 0 . 1 5 . 0 9 . 2 2 9 0 0 0 8 0 11 / 2 3 / 2 0 1 2 8 4 1 8 9 . 4 4 8 1 2 1 6 4 / 4 / 5 4 . 9 1 / 1 1 1 . 0 4 / 8 4 0 . 2 4 . 7 5 9 . 3 2 9 5 0 0 6 0 11 / 2 4 / 2 0 1 2 9 0 2 2 9 . 4 4 5 1 3 1 6 4 / 4 / 5 4 . 7 1 / 1 1 2 . 0 4 / 8 4 0 . 1 5 4 . 5 9 . 3 3 4 0 0 0 6 0 11 / 2 5 / 2 0 1 2 9 5 5 2 9 . 4 4 6 1 3 1 7 4 / 4 / 5 4 . 5 1 / 1 1 2 . 0 4 / 8 4 0 . 1 5 5 . 0 9 . 4 3 3 0 0 0 6 0 11 / 2 6 / 2 0 1 2 9 9 7 2 9 . 3 4 8 1 7 1 8 4 / 4 / 5 3 . 8 1 / 1 1 2 . 0 4 / 8 4 0 . 1 5 4 . 7 5 9 . 3 3 3 0 0 0 4 0 No r t h F o r k U n i t # 2 2 - 3 5 48 Co n t r a c t o r : M i S w a c o Mu d T y p e : G e l S p u d M u d 1 2 0 ’ – 3 0 0 0 ’ ; K l a - S h i e l d 3 0 0 0 ’ – 1 0 7 0 0 ’ Da t e D e p t h MW (p p g ) VI S (s / q t ) PV Y P G e l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) MB T p H Cl (ml/l) Ca (ml/l) 11 / 2 7 / 2 0 1 2 1 0 4 2 2 9 . 4 5 0 1 9 2 1 5 / 7 / 8 3 . 5 1 / 1 1 2 . 0 4 / 8 4 T R C 4 . 5 9 . 3 3 3 0 0 0 4 0 11 / 2 8 / 2 0 1 2 1 0 7 0 0 9 . 4 4 7 1 8 2 2 5 / 7 / 8 3 . 4 1 / 1 1 2 . 0 4 / 8 4 T R C 6 . 0 9 . 3 3 3 0 0 0 4 0 11 / 2 9 / 2 0 1 2 1 0 7 0 0 9 . 4 4 8 1 8 2 2 5 / 7 / 8 3 . 8 1 / 1 1 2 . 0 4 / 8 4 T R C 6 . 0 9 . 2 3 4 0 0 0 4 0 11 / 3 0 / 2 0 1 2 1 0 7 0 0 9 . 5 4 6 1 7 2 0 5 / 7 / 9 3 . 6 1 / 1 1 2 . 5 4 / 8 4 T R C 6 . 0 9 . 2 3 2 0 0 0 4 0 12 / 0 1 / 2 0 1 2 1 0 7 0 0 9 . 5 4 8 1 7 2 1 5 / 7 / 9 3 . 6 1 / 1 1 2 . 5 4 / 8 4 T R C 6 . 0 9 . 2 3 2 0 0 0 4 0 12 / 0 2 / 2 0 1 2 1 0 7 0 0 9 . 6 4 3 1 4 1 7 4 / 4 / 6 3 . 8 1 / 1 1 3 4 / 8 3 T R C 6 9 . 1 3 0 0 0 0 4 0 12 / 0 3 / 2 0 1 2 1 0 7 0 0 8 . 7 - - - - - - - - T R C - - - - 12 / 0 4 / 2 0 1 2 1 0 7 0 0 - - - - - - - - - - - - - - 12 / 0 5 / 2 0 1 2 1 0 7 0 0 - - - - - - - - - - - - - - 12 / 0 6 / 2 0 1 2 1 0 7 0 0 - - - - - - - - - - - - - - 12 / 0 7 / 2 0 1 2 1 0 7 0 0 - - - - - - - - - - - - - - 12 / 0 8 / 2 0 1 2 1 0 7 0 0 - - - - - - - - - - - - - - 12 / 0 9 / 2 0 1 2 1 0 7 0 0 - - - - - - - - - - - - - - 12 / 1 0 / 2 0 1 2 10 7 0 0 - - - - - - - - - - - - - - 12 / 1 1 / 2 0 1 2 10 7 0 0 - - - - - - - - - - - - - - Ab b r e v i a t i o n s : MW = M u d W e i g h t V I S = F u n n e l V i s c o s i t y PV = P l a s t i c V i s c o s i t y Y P = Y i e l d P o i n t G e l s = G e l S t r e n g t h F L = W a t e r o r F i l t r a t e Lo s s F C = F i l t e r C a k e O / W = O i l t o W a t e r r a t i o S o l s = S o l i d s S d = S a n d c o n t e n t M B T = M e t h y l e n e B l u e A l , P m = A l k a l i n i t y , M u d p H = A c i d i t y / B a s i c i t y C l = C h l o r i d e s C a = H a r d n e s s C a l c i u m n r = N o t R e c o r d e d No r t h F o r k U n i t # 2 2 - 3 5 49 5. 5 D r i l l i n g P r o g r e s s C h a r t D A Y S V E R S U S D E P T H 0 10 0 0 20 0 0 30 0 0 40 0 0 50 0 0 60 0 0 70 0 0 80 0 0 90 0 0 10 0 0 0 11 0 0 0 12 0 0 0 1 0 / 1 2 / 2 0 1 0 1 0 / 1 3 / 2 0 1 0 1 0 / 1 4 / 2 0 1 0 1 0 / 1 5 / 2 0 1 0 1 0 / 1 6 / 2 0 1 0 1 0 / 1 7 / 2 0 1 0 1 0 / 1 8 / 2 0 1 0 1 0 / 1 9 / 2 0 1 0 1 0 / 2 0 / 2 0 1 0 1 0 / 2 1 / 2 0 1 0 1 0 / 2 2 / 2 0 1 0 1 0 / 2 3 / 2 0 1 0 1 0 / 2 4 / 2 0 1 0 1 0 / 2 5 / 2 0 1 0 1 0 / 2 6 / 2 0 1 0 1 0 / 2 7 / 2 0 1 0 1 0 / 2 8 / 2 0 1 0 1 0 / 2 9 / 2 0 1 0 1 0 / 3 0 / 2 0 1 0 1 0 / 3 1 / 2 0 1 0 1 1 / 1 / 2 0 1 0 1 1 / 2 / 2 0 1 0 1 1 / 3 / 2 0 1 0 1 1 / 4 / 2 0 1 0 1 1 / 5 / 2 0 1 0 1 1 / 6 / 2 0 1 0 1 1 / 7 / 2 0 1 0 1 1 / 8 / 2 0 1 0 1 1 / 9 / 2 0 1 0 1 1 / 1 0 / 2 0 1 0 1 1 / 1 1 / 2 0 1 0 1 1 / 1 2 / 2 0 1 0 1 1 / 1 3 / 2 0 1 0 1 1 / 1 4 / 2 0 1 0 1 1 / 1 5 / 2 0 1 0 1 1 / 1 6 / 2 0 1 0 1 1 / 1 7 / 2 0 1 0 1 1 / 1 8 / 2 0 1 0 1 1 / 1 9 / 2 0 1 0 1 1 / 2 0 / 2 0 1 0 1 1 / 2 1 / 2 0 1 0 1 1 /2 2 /2010 1 1 /2 3 /2010 1 1 /2 4 /2010 1 1 /2 5 /2010 1 1 /2 6 /2010 1 1 /2 7 /2010 1 1 /2 8 /2010 DA T E D E P T H ( F T ) 12 1 / 4 " H o l e 8 1 / 2 " H o l e 6 1 / 8 " H o l e N F U 3 2 - 3 5 50 6 SHOW REPORTS 51 7 DAILY REPORTS Hydrocarbon Show Report # 1 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 1487 MD 1537 MD Country: 1440 TVD 1484 TVD Averages Before During After Maximum ROP (fph) 99 160 79 361 WOB 43 43 36 51 RPM 13 78 - 77 Mud Weight 9 9 9 9 Chloride Total Gas 42 105 32 164 C1 (ppm) 18,455 26,862 10,897 42,386 C2 (ppm) 314 337 172 654 C3 (ppm) 9 31 25 57 C4 (ppm) 1 42 0 97 C5 (ppm) Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount NONE Type NONE Amount Amount NONE Distribution NONE Intensity NONE Color Color NONE Intensity NONE Color NONE Residual Fluorescence Cut Color NONE Intesity Color NONE Color Show Rating Free Oil in Mud Comments Report by: NONE DYLAN MULLER GAS SHOW. NO CUT OR FLUORESENCE. 0 NONE Kenai Peninsula Borough Alaska USA ARMSTRONG COOK INLET, LLC 50-231-20037-00-00 NFU 23 - 25 North Fork Unit Nabors 99E September 16, 2012 1800 Sand = medium gray to grayish black; upper very fine to lower medium grains; spherical and some subprismoidal; subrounded to subangular; moderately to well sorted; mostly unconsolidated with some friable moderately sorted sandstones; sandstones are grain supported; texturally submature, compositionally very mature; interbedded lignitic coal and carbonaceous shale. NONE NONE Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 10 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 10140 MD 10200 MD Country: 8976 TVD 9036 TVD Averages Before During After Maximum ROP (fph) 100.0 100.0 50.0 100.0 WOB 15.2 15.0 15.4 15.4 RPM 86.0 86.0 86.0 86.0 Mud Weight 9.60 9.60 9.60 9.60 Chloride Total Gas 80.0 150.0 90.0 150.0 C1 (ppm) 5,000.0 8,000.0 12,000.0 12,000.0 C2 (ppm) 120.0 100.0 70.0 120.0 C3 (ppm) 6.5 120.0 100.0 120.0 C4 (ppm) - C5 (ppm) - Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount NONE Type NONE Amount Amount NONE Distribution NONE Intensity NONE Color Color NONE Intensity NONE Color NONE Residual Fluorescence Cut Color NONE Intesity Color NONE Color Show Rating Free Oil in Mud Comments Report by: NONE NONE GAS SHOW Tuffaceous sandstone = light to medium olive gray; lower very fine to lower medium grains; spherical; angular to subangular, occasional round; moderately sorted; easily friable to sometimes firm; tuff matrix supported; texturally submature to immature; compositionally immature; abundant coal flake inclusions and intermixed/interbedded siltstone/tuffaceous silt. Kenai Peninsula Borough Alaska USA ARMSTRONG COOK INLET, LLC 50-231-20037-00-00 NFU 23 - 25 North Fork Unit Nabors 99E October 8, 2012 11:20 AM NONE JAMES FORADAS Before interval = 10140' - 10145': After interval =10195' - 10200' . This show started with what was likely a coal gas based on cuttings sample analysis and spot samples, followed by broader peaks associated with sands underlying the coal. The gas curves in the sand interval were broader than the distinctive narrow "spikes" associated with the coal gas curve. 0 NONE Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 11 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 10210 MD 10250 MD Country: 9046 TVD 9086 TVD Averages Before During After Maximum ROP (fph) 50.0 50.0 45.0 50.0 WOB - - - - RPM 82.0 82.0 82.0 82.0 Mud Weight 9.60 9.60 9.60 9.60 Chloride Total Gas 150.0 100.0 102.0 150.0 C1 (ppm) 70,000.0 15,000.0 9,000.0 70,000.0 C2 (ppm) 1,000.0 250.0 200.0 1,000.0 C3 (ppm) 90.0 - 50.0 90.0 C4 (ppm) - C5 (ppm) - Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount NONE Type NONE Amount Amount NONE Distribution NONE Intensity NONE Color Color NONE Intensity NONE Color NONE Residual Fluorescence Cut Color NONE Intesity Color NONE Color Show Rating Free Oil in Mud Comments Report by: NONE JAMES FORADAS Before interval = 10210' - 10215': After interval =10245' - 10250' . This show started with what was likely a coal gas based on cuttings sample analysis and spot samples, followed by broader peaks associated with sands underlying the coal. The gas curves in the sand interval were broader than the distinctive narrow "spikes" associated with the coal gas curve. 0 NONE Kenai Peninsula Borough Alaska USA ARMSTRONG COOK INLET, LLC 50-231-20037-00-00 NFU 23 - 25 North Fork Unit Nabors 99E October 8, 2012 12:40 PM GAS SHOW Siltstone / tuffaceous siltstone = medium olive; very soft to moderately firm; moderate to poor induration; tough and dense to crumbly and crunchy tenacity; irregular and some planar fracturing; massive to platy, some tabular cutting habit; earthy and dull and sometimes micro-sparkling luster; silty to very gritty and granular texture, sometimes very sandy with inclusions of sand grains; massive structure; occasional veins of coal and sometimes carbonaceous shale and flakes of coal 10/10 to 1/2 mm thick cuttings are dark gray to dark brown. NONE NONE Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 2 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 6213'MD 6281'MD Country: 5113'TVD 5172'TVD Averages Before During After Maximum ROP (fph) 66 160 79 186 WOB 18 43 11 16 RPM 4 78 9 88 Mud Weight Chloride Total Gas 22 58 49 74 C1 (ppm) 5,612 25,184 13,220 32,291 C2 (ppm) 176 423 259 574 C3 (ppm) 96 12 9 23 C4 (ppm) C5 (ppm) Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount NONE Type NONE Amount Amount NONE Distribution NONE Intensity NONE Color Color NONE Intensity NONE Color NONE Residual Fluorescence Cut Color NONE Intesity Color NONE Color Show Rating Free Oil in Mud Comments Report by: NONE NONE Sand = medium dark gray to dark gray; upper very fine to lower coarse grains; very spherical to sub Prismoidal; rounded to subrounded, occasional subangualr; poorly to moderately sorted; unconsolidated; texturally very mature; compositionally very mature; quartz, translucent, frosted. Sandstone = medium gray to light gray; upper very fine to upper fine grain size; sub spherical to prismoidal; rounded to subrounded; moderate to poor sorting; very friable and abundant unconsolidated sands matrix supported; texturally moderately mature; compositionally moderately mature; quartz, white, frosted; imbedded with some siltstone and occasional tuff; very poor porosity Kenai Peninsula Borough Alaska USA ARMSTRONG COOK INLET, LLC 50-231-20037-00-00 NFU 23 - 25 North Fork Unit Nabors 99E October 2, 2012 7:54 AM NONE DYLAN MULLER Possible show 0 NONE Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 3 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 7052 MD 7128 MD Country: 5893 TVD 5968 TVD Averages Before During After Maximum ROP (fph) 16.5 25.5 21.5 25.5 WOB 15.0 15.0 21.8 21.8 RPM 88.0 60.0 80.0 88.0 Mud Weight 9.80 9.70 9.60 9.70 Chloride Total Gas 30.0 65.0 15.0 65.0 C1 (ppm) 13,000.0 14,000.0 5,000.0 14,000.0 C2 (ppm) 150.0 200.0 70.0 200.0 C3 (ppm) C4 (ppm) - C5 (ppm) - Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount NONE Type NONE Amount Amount NONE Distribution NONE Intensity NONE Color Color NONE Intensity NONE Color NONE Residual Fluorescence Cut Color NONE Intesity Color NONE Color Show Rating Free Oil in Mud Comments Report by: NONE JAMES FORADAS Before interval = 7052' - 7057' : After interval = 7121' - 7128' . This show started with what was likely a coal gas based on cuttings sample analysis and spot samples, followed by broader peaks associated with sands underlying the coal. The gas curves in the sand interval were broader than the distinctive narrow "spikes" associated with the coal gas curve. 0 NONE Kenai Peninsula Borough Alaska USA ARMSTRONG COOK INLET, LLC 50-231-20037-00-00 NFU 23 - 25 North Fork Unit Nabors 99E GAS SHOW Sandstone = light gray to medium light gray; very fine to fine grained with some coarser grains; fair to well sorted; angular to well rounded; low to very high; some impact and frosting features; soft to friable; top of interval more grain supported, bottom more silty matrix supported; composition mostly quartz but common dark fines; compositional and textural submaturity; lamina of carbonaceous shale and siltstone; thin structure. NONE NONE Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 4 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 8529 MD 8574 MD Country: 7366 TVD 7410 TVD Averages Before During After Maximum ROP (fph) 91 67 164 WOB 11 10 11 RPM 75 72 75 Mud Weight Chloride Total Gas 126 42 291 C1 (ppm) 28,796 5,330 117,664 C2 (ppm) 814 110 3,398 C3 (ppm) C4 (ppm) C5 (ppm) Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount NONE Type NONE Amount Amount NONE Distribution NONE Intensity NONE Color Color NONE Intensity NONE Color NONE Residual Fluorescence Cut Color NONE Intesity Color NONE Color Show Rating Free Oil in Mud Comments Report by: NONE DYLAN MULLER The interval immediately before was a coal stringer which explains the much higher gasses. 0 NONE Kenai Peninsula Borough Alaska USA ARMSTRONG COOK INLET, LLC 50-231-20037-00-00 NFU 23 - 25 North Fork Unit Nabors 99E October 6, 2012 11:30 AM Sand = dark olive gray to dark gray; lower very fine to lower fine grains; spherical to very prismoidal, almost flakes; subangular to well rounded; very well sorted; unconsolidated; texturally very mature; compositionally submature; quartz grains are translucent, buff, and light brown; some grains have etched faces; abundant Equaly sized coal and siltstone accompanied these samples. Tuffaceous sandstone = upper very fine to upper medium grains; very spherical to very prismoidal; moderate to poor sorting; very well consolidated, very friable to very hard; very matrix supported; texturally immature; compositionally submature; no porosity; inclusions of ash, sparse micro coal flakes, and silt. NONE NONE Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 5 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 8897 MD 8980 MD Country: 7735 TVD 7820 TVD Averages Before During After Maximum ROP (fph) 37 43 74 169 WOB 9 8 11 46 RPM 69 70 90 87 Mud Weight 10 10 10 Chloride Total Gas 26 39 59 229 C1 (ppm) 8,836 15,944 14,806 64,892 C2 (ppm) 189 3,118 126 1,482 C3 (ppm) 42 9 228 541 C4 (ppm) 48 13 15 268 C5 (ppm) Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount NONE Type NONE Amount Amount NONE Distribution NONE Intensity NONE Color Color NONE Intensity NONE Color NONE Residual Fluorescence Cut Color NONE Intesity Color NONE Color Show Rating Free Oil in Mud Comments Report by: NONE DYLAN MULLER The intervals immediately before and after were coal stringers which explain the much higher gasses outside of the show interval. Before and after intervals are MD 8863' - 8896' and 8981' - 9012' respectively. 0 NONE Kenai Peninsula Borough Alaska USA ARMSTRONG COOK INLET, LLC 50-231-20037-00-00 NFU 23 - 25 North Fork Unit Nabors 99E October 5, 2012 2:45 AM Sand = medium dark gray to dark gray, some light olive gray; lower very fine to lower medium grains, Grains are very well sorted per 10' interval, but increase from lower to upper fine, to upper fine to lower medium; very spherical to very prismoidal, in all footages spherical grains are more rounded, and prismoidal more angular; well sorted per 10' range; unconsolidated; texturally very Immature; compositoinally very mature; quartz, tranluscent, white, buff. Sandstone = medium dark gray to dark gray, some light olive gray lower fine to upper mdeium; very spherical to bery prismoidal; mostly angular to subangular, some subrounded to rounded; poorly sorted; very friable to slightly firm, firm sandstones have more coal inclusions and are darker from carbonaceous materials; matrix supported; texturally immature; compositionally submature; very poor porosity; rare glauconitic staining, quartz tranluscent, milky, very pale orange; micro coal flake inclusions. NONE NONE Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 6 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 9055 MD 9080 MD Country: 7893 TVD 7922 TVD Averages Before During After Maximum ROP (fph) 81 75 46 124 WOB 15 17 10 17 RPM 91 90 9 87 Mud Weight 10 10 10 10 Chloride Total Gas 48 40 24 99 C1 (ppm) 13,949 13,151 10,410 29,160 C2 (ppm) 316 301 165 695 C3 (ppm) C4 (ppm) C5 (ppm) Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount NONE Type NONE Amount Amount NONE Distribution NONE Intensity NONE Color Color NONE Intensity NONE Color NONE Residual Fluorescence Cut Color NONE Intesity Color NONE Color Show Rating Free Oil in Mud Comments Report by: NONE NONE Sandstone = medium dark gray to dark gray, some light olive gray lower fine to upper mdeium; very spherical to bery prismoidal; mostly angular to subangular, some subrounded to rounded; poorly sorted; very friable To slightly firm, firm sandstones have more coal inclusions and are darker from carbonaceous materials; matrix Supported; texturally immature; compositionally submature; very poor porosity; rare glauconitic staining, quartz tranluscent, milky, very pale orange; micro coal flake inclusions. Siltstone = medium gray to medium dark gray; slightly firm to very soft; poor induration; crumbly To pulverulent; irrevular to blocky fracturing; tabular and platy cutting habit; earthy to dull luster; silty and Sometimes gritty texture; laminae to thin structure with buttercurling; sometimes very large grains, sandy, Generally very carbonaceous; abundant inslusions of coal microflakes less than 1/10 to 1/4 mm thick. Sandstone olive to dark gray; lower very fine to lower medium grains; prismoidal; angular; moderately Sorted; friable to slightly firm; grain supported; texturally immature; compositionally immature; laminated beds of 1-2 grains of sand and a micro layer of coal less than 1/10 mm thick. Kenai Peninsula Borough Alaska USA ARMSTRONG COOK INLET, LLC 50-231-20037-00-00 NFU 23 - 25 North Fork Unit Nabors 99E October 6, 2012 2:45 AM NONE DYLAN MULLER The intervals immediately before and after were coal stringers which explain the much higher gasses outside of the show interval. Before interval = 9038' - 9054' : After interval = 9081' - 9100'. 0 NONE Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 7 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 9310 MD 9380 MD Country: 8147 TVD 8217 TVD Averages Before During After Maximum ROP (fph) 93.4 85.2 87.1 132.2 WOB 0.2 2.0 1.6 16.0 RPM 87.6 70.8 73.6 85.0 Mud Weight 9.60 9.55 9.60 9.60 Chloride Total Gas 66.0 64.1 73.8 227.0 C1 (ppm) 22,122.1 28,709.9 26,938.3 123,802.0 C2 (ppm) 643.8 705.0 703.5 2,757.0 C3 (ppm) - 21.0 23.9 114.0 C4 (ppm) C5 (ppm) Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount NONE Type NONE Amount Amount NONE Distribution NONE Intensity NONE Color Color NONE Intensity NONE Color NONE Residual Fluorescence Cut Color NONE Intesity Color NONE Color Show Rating Free Oil in Mud Comments Report by: NONE NONE GAS SHOW Sandstone = light olive to dark olive and olive gray; upper very fine to lower ledum grains; prismoidal to subspherical; angular to subangular; moderately well sorted; very friable and many loose grains detatched from sandstone; grain supported; texturally immature; compositionally very mature; grains milky, moderate orange pink; seemingly poor porosity, grains are almost blocky and fitted together, more unconsolidated sands with increasing Depth and more translucent colorless grains which are larger and rounder. Sand = olive gray; lower very fine to upper fine grains, sparse lower medium in lower depths; prismoidal To subspherical; angular to subangular some subroudned; mostly unconsolidated some very friable sandstones from above description; texturally moderately mature; compositionally submature; 90% quartz translucent, milky, moderate orange pink, trace amounts of bluish green and rose; some intervals exhibit abundant micro coal flakes. Tuffaceous sandstone = light olive gray to olive gray; lower very fine to lower medium; very prismoidal; angular, some subangular; grains resemble broken glass shards; easily friable to unconsolidated, occasional slightly firm; grain to matrix supported; abundant tuff, some coal flakes, sometimes almost silty very poor to sometimes poor porosity; pale orange pink, white, and transluc Kenai Peninsula Borough Alaska USA ARMSTRONG COOK INLET, LLC 50-231-20037-00-00 NFU 23 - 25 North Fork Unit Nabors 99E October 7, 2012 1:37 PM NONE DYLAN MULLER Before interval = 9285' - 9309' : After interval = 9381' - 9400'. 0 NONE Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 8 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 9410 MD 9490 MD Country: 8246 TVD 8326 TVD Averages Before During After Maximum ROP (fph) 57.9 84.5 49.8 162.2 WOB - - - - RPM 84.0 86.0 97.0 97.0 Mud Weight 9.55 9.55 9.60 9.60 Chloride Total Gas 28.5 89.2 20.1 89.2 C1 (ppm) 5,323.3 27,259.5 14,237.1 27,259.5 C2 (ppm) 129.2 675.4 247.9 675.4 C3 (ppm) 13.7 43.1 29.3 43.1 C4 (ppm) - C5 (ppm) - Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount NONE Type NONE Amount Amount NONE Distribution NONE Intensity NONE Color Color NONE Intensity NONE Color NONE Residual Fluorescence Cut Color NONE Intesity Color NONE Color Show Rating Free Oil in Mud Comments Report by: NONE NONE GAS SHOW Tuffaceous sandstone = Light olive gray to olive gray; lower very fine to lower medium; very prismoidal; angular, some subangular; grains resemble broken glass shards; easily friable to unconsolidated, occasional slightly firm; grain to matrix supported; abundant tuff, some coal flakes, sometimes almost silty very poor to sometimes poor porosity; pale orange pink, white, and translucent quartz composition; thin structure; dark banding from interbedded thin to laminar stringers of black carbonaceous shale with common pyrite laminae, and medium to dark gray shaly to gritty siltstone; compositionally and texturally mature; intergrading and interbedded with more thin siltstone, carbonaceous shale, and coal stringers beyond 9490' MD. Kenai Peninsula Borough Alaska USA ARMSTRONG COOK INLET, LLC 50-231-20037-00-00 NFU 23 - 25 North Fork Unit Nabors 99E October 7, 2012 14:34:00 PM NONE JAMES FORADAS Before interval = 9,410' - 9,420' : After interval = 9,480' - 9,490' . This show was preceded by a coal with typical high methane in sand. Immediately after drilling through the coal and the underlying sand, the sandstone appeared. The gas curves in this interval were broader than the distinctive narrow "spikes" associated with typical coal gas curves. 0 NONE Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 9 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 9550 MD 9580 MD Country: 8386 TVD 8416 TVD Averages Before During After Maximum ROP (fph) 91.5 98.8 64.8 162.2 WOB 0.9 6.6 4.8 17.0 RPM 86.0 86.0 86.0 86.0 Mud Weight 9.60 9.60 9.60 9.60 Chloride Total Gas 249.8 134.4 126.7 134.4 C1 (ppm) 2,871.9 34,164.0 22,803.4 34,164.0 C2 (ppm) 86.3 1,148.2 397.3 1,148.2 C3 (ppm) 4.6 60.0 16.5 60.0 C4 (ppm) 2.3 25.9 25.9 C5 (ppm) Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount NONE Type NONE Amount Amount NONE Distribution NONE Intensity NONE Color Color NONE Intensity NONE Color NONE Residual Fluorescence Cut Color NONE Intesity Color NONE Color Show Rating Free Oil in Mud Comments Report by: NONE NONE GAS SHOW Tuffaceous sandstone = light gray to pale yellowish orange with pale brown and pink hues; upper very fine to lower fine grain with some finer and coarse grains; angular to subrounded grains; moderate to high sphericity with finer grains more rounded and spherical; common conchoidal fracture apparently caused by bit; unconsolidated to firm friable; grain supported, with common tuffaceous matrix; predominantly quartz in composition, with some dark fines of carbonaceous material; banded with thin siltstone and carbonaceous shale; compositionally and texturally mature; intergrading and interbedded with siltstone and carbonaceous shale. Kenai Peninsula Borough Alaska USA ARMSTRONG COOK INLET, LLC 50-231-20037-00-00 NFU 23 - 25 North Fork Unit Nabors 99E October 8, 2012 11:16 PM NONE DYLAN MULLER Before interval = 9,45' - 9,550' : After interval = 9,580' - 9,600' . This show was preceded by similar rocks well above and below this gassy interval. The gas curve in this interval was broader than the distinctive narrow "spikes" associated with typical coal gas curves, and produced traces of C4. 0 NONE Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT NFU 22-35 REPORT FOR Larry Driskill/Jim Brown DATE Nov 02, 2012 DEPTH 1175' PRESENT OPERATION Drilling TIME 23:59:01 YESTERDAY 121' 24 HOUR FOOTAGE 1054' CASING INFORMATION 16" @ 140' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 717' 1.33 176.78 716.93' 813' 3.35 226.58 812.85' 908' 5.13 228.23 907.59' 1003' 7.45 216.36 1002.02' 1097' 10.96 212.89 1094.79' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 1 13.5" HTC MLX-1X 5196654 3x16,1x14/0.7394 140' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 499.9 @ 124' 9.7 @ 1041' 113.1 29.66308 FT/HR SURFACE TORQUE 14841 @ 1149' 28 @ 1163' 2362.1 94.00000 FT-LBS WEIGHT ON BIT 25 @ 1153' 0 @ 206' 9.6 14.39500 KLBS ROTARY RPM 75 @ 788' 2 @ 606' 45.5 0.00000 RPM PUMP PRESSURE 1671 @ 455' 524 @ 175' 1182.8 1133.00000 PSI DRILLING MUD REPORT DEPTH 108' MW 9.0 VIS 62 PV 11 YP 17 Gels 11/25/33 FL NC CL- 400 FC 2/ SOL 5.0 SD Tr OIL -/95 MBT 22.5 pH 9.3 Ca+ 80 Alk MWD SUMMARY INTERVAL 140' TO 1175' TOOLS Bit, mudmotor and directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 136 @ 1151' 0 @ 298' 20.2 TRIP GAS 0 CUTTING GAS 0 @ 1175' 0 @ 1175' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 33566 @ 1150' 192 @ 688' 4675.0 CONNECTION GAS_HIGH 0 ETHANE (C-2) 130 @ 1175' 0 @ 683' 21.6 CONNECTION GAS_AVG 0 PROPANE (C-3) 0 @ 1175' 0 @ 1175' 0.0 CONNECTION GAS_CURRENT 0 BUTANE (C-4) 0 @ 1175' 0 @ 1175' 0.0 CURRENT BACKGROUND/AVG 21/20 PENTANE (C-5) 0 @ 1175' 0 @ 1175' 0.0 HYDROCARBON SHOWS minor shows associated with coal beds and some sands INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand, sandstone, siltstone, claystone, coal and minor carbonaceous shale PRESENT LITHOLOGY Sterling formation DAILY ACTIVITY SUMMARY Completed rigging up mudlogging unit (started yesterday) and began drilling at 0600 hours. Drilled ahead from conductor at 140' MD to 1175'. Today's cost reflects billing for yesterday and today. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen DAILY COST DML $5350 RW $1190 REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larry Driskill/Jim Brown DATE Nov 11, 2012 DEPTH 3005' PRESENT OPERATION Testing BOP's (thru midnight) TIME 21:00:21 YESTERDAY 3005' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3005'/2749' MW 8.8 VIS 46 PV 7 YP 16 Gels 6/7/7 FL 10.5 CL- 30500 FC 1/- SOL 3 SD - OIL -/97 MBT - pH 10.4 Ca+ 60 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS_HIGH N/A ETHANE (C-2) @ @ CONNECTION GAS_AVG N/A PROPANE (C-3) @ @ CONNECTION GAS_CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A PRESENT LITHOLOGY Beluga formation DAILY ACTIVITY SUMMARY P/U D.P. from 1056’ to 2800’, DN= 60 UP= 65; TOOH from 2800’, UP= 65 DN= 55; R/B 30 stands in derrick SLM; P/U D.P. blow down kill line; RIH to 2800’; TOOH from 2800’ UP=65 DN=55; clean up for BOP Test; currently testing BOP’s (tests will continue through midnight). CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Winslow DAILY COST $3795 Total (DML $3200/ RW $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larry Driskill/Jim Brown DATE Nov 12, 2012 DEPTH 3005' PRESENT OPERATION R/U for Testing BOPs TIME 23:59:32 YESTERDAY 3005' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3005'/2749' MW 9.7 VIS 43 PV 10 YP 7 Gels 4/17/30 FL 13.8 CL- 1100 FC 2/- SOL 10.5 SD Trc OIL -/90 MBT 23.75 pH 8.7 Ca+ 72 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS_HIGH N/A ETHANE (C-2) @ @ CONNECTION GAS_AVG N/A PROPANE (C-3) @ @ CONNECTION GAS_CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A PRESENT LITHOLOGY Beluga formation DAILY ACTIVITY SUMMARY LD test tool; blow down choke; kill and gas buster; downtime-BOP – choke: drain stack; remove variable rams; replace door seal; install variables attempt to test; test failed; change to 4" rams; test 4"; test failed; R/U to pick up 4"; P/U drill pipe from 95' to 2375’; TOOH with 4" D.P.; rack back in derrick; SLM OOH from2375' to surface, 60k UPW; clear and clean rig floor and stack; N/D BOPs; pull W/R set test plug; remove lower set of rams; prep BOP to change lower single gate; P/U BOPs s remove single gates out from under set on cart. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Winslow DAILY COST $3795 (DML $3200, RW$595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larry Driskill/Jim Brown DATE Nov 13, 2012 DEPTH 3005' PRESENT OPERATION Drilling out shoe track TIME 23:59:51 YESTERDAY 3005' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 2 9 7/8" HTC TGXA971 5085654 3x20/0.920 3005' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3005'/2749' MW 9.3 VIS 30 PV 4 YP 2 Gels // FL 19.3 CL- 1600 FC 2/- SOL 10 SD Tr OIL -/90 MBT 22.5 pH 9.2 Ca+ 40 Alk 0.4 MWD SUMMARY INTERVAL 3005' TO 3025' estd. TOOLS Bit and "dumb iron" BHA for drilling shoe track and 20 additional feet for FIT. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS_HIGH N/A ETHANE (C-2) @ @ CONNECTION GAS_AVG N/A PROPANE (C-3) @ @ CONNECTION GAS_CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A PRESENT LITHOLOGY Beluga formation DAILY ACTIVITY SUMMARY Downtime-BOP: choke remove and install single gates, N/U same; install riser, flow line, hole fill; install kill choke and 2 7/8 x 5" variable rams; test same, failed; changed to 4" rams tested; change packing in variables, prepped to change rams; choke void stack; change rams from 4" fixed to 2 7/8 X 5”, test same, failed; change back to 4", fixed, test same, good; change rams R/D and B/D all test equipment, choke manifold, choke and kill lines, top drive; pull test plug; set W/R; P/U BHA #2; TIH; change elevators to 4"; TIH from 635' to 2948', tag cement; stand 1 stand back; circulate and condition; break circulation; stage up to 8bpm, 324gpm, 465psi, pump 4500 strokes; pressure test casing/shoe; test casing to 3000psi for 30 minutes; chart MW 9.3 ppg; bleed off 3.5bbls back; R/D test equipment; rotary drilling: P/U stand; drill out shoe track. Currently drilling out shoe track at 2944’ MD. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Winslow DAILY COST $3795 Total (DML $3200, RW $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Al Lunda/Jim Brown DATE Nov 14, 2012 DEPTH 3325' PRESENT OPERATION Drilling TIME 23:59:32 YESTERDAY 3005' 24 HOUR FOOTAGE 320' CASING INFORMATION 16" @ 140' 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3044' 37.19 217.59 2780.53' 3087' 37.00 218.09 2814.83' 3182' 36.79 217.97 2890.80' 3278' 36.52 217.67 2967.82' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 2 9 7/8" HTC TGXA971 5085654 3x20/0.920 3005' 3025' 20' 0.6 1-2-WT-A-E-I-NO-TD TD 3 8 3/4" HCC Q505X 7016082 7X12//0.773 3025' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 286.2 @ 3088' 13.8 @ 3021' 129.3 170.89067 FT/HR SURFACE TORQUE 15526 @ 3071' 3576 @ 3011' 11357.7 11959.00000 FT-LBS WEIGHT ON BIT 55 @ 3021' 2 @ 3054' 7.0 4.31482 KLBS ROTARY RPM 81 @ 3011' 48 @ 3167' 74.9 76.00000 RPM PUMP PRESSURE 2368 @ 3005' 372 @ 3015' 1409.0 1699.00000 PSI DRILLING MUD REPORT DEPTH 3050'/2795' MW 8.8 VIS 43 PV 6 YP 14 Gels 5/5/6 FL 10.0 CL- 30000 FC 1/1 SOL 3.0 SD - OIL -/97 MBT - pH 10.5 Ca+ 140 Alk 2.2 MWD SUMMARY INTERVAL 3025' TO 3325' TOOLS Bit, mudmotor, and quad combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 105 @ 3124' 1 @ 3009' 44.9 TRIP GAS 0 CUTTING GAS 0 @ 3325' 0 @ 3325' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 117190 @ 3026' 2586 @ 3051' 11661.9 CONNECTION GAS_HIGH 0 ETHANE (C-2) 293 @ 3026' 2 @ 3033' 91.4 CONNECTION GAS_AVG 0 PROPANE (C-3) 0 @ 3325' 0 @ 3325' 0.0 CONNECTION GAS_CURRENT 0 BUTANE (C-4) 0 @ 3325' 0 @ 3325' 0.0 CURRENT BACKGROUND/AVG 21u/44u PENTANE (C-5) 0 @ 3325' 0 @ 3325' 0.0 HYDROCARBON SHOWS Minor shows associated with coal bed methane INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sandstone, sand, siltstone, claystone, coal, carbonaceous shale, ash PRESENT LITHOLOGY Beluga formation DAILY ACTIVITY SUMMARY Drill cement float collar, shoe & 8' new hole; displace to New Kla-Shield system; cont drilling new hole to 3,025' MD; circulate and condition for LOT test; perform LOT to 13.5 ppg EMW; pump dry job; POOH; L/D BHA#2; P/U directional BHA; shallow hole test at 951', pump 425gpm, 161spm,640psi; calibrate blocks; TIH from 951' to 3020', break circulation; set peramiters; drill from 3025', RPM 75, GPM 475, WOB 5-12, PSI 1500, TQ 9-15; currently drilling at 3025' CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Winslow, Hinostroza DAILY COST $3795 Total (DML $3200 / RW $595 REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Al Lunda/Jim Brown DATE Nov 15, 2012 DEPTH 4576' PRESENT OPERATION C&C prep to TOOH TIME 23:25:05 YESTERDAY 3325' 24 HOUR FOOTAGE 1251' CASING INFORMATION 16" @ 140' 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4138' 36.76 215.01 3654.46' 4233' 36.60 214.74 3730.65' 4328' 37.02 215.09 3806.71' 4424' 36.96 215.76 3883.39' 4519' 37.41 216.6 3959.07' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 8 3/4" HCC Q505X 7016082 7x12/0.773 3025' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 409.7 @ 4525' 1.0 @ 4412' 120.2 56.48269 FT/HR SURFACE TORQUE 16042 @ 3396' 28 @ 4512' 11110.4 11837.00000 FT-LBS WEIGHT ON BIT 39 @ 3624' 0 @ 4548' 11.6 0.00000 KLBS ROTARY RPM 83 @ 4421' 2 @ 4511' 64.7 82.00000 RPM PUMP PRESSURE 2197 @ 4518' 1228 @ 3353' 1711.3 1602.00000 PSI DRILLING MUD REPORT DEPTH 4499'/3942' MW 9.4 VIS 38 PV 7 YP 12 Gels 4/6/7 FL 8.9 CL- 29000 FC 1/1 SOL 6.0 SD 0.2 OIL 2/92 MBT 2.25 pH 10.0 Ca+ 40 Alk 1.6 MWD SUMMARY INTERVAL 3025' TO 4576' TOOLS Bit, mudmotor, directional and quad combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 127 @ 3882' 2 @ 3540' 48.0 TRIP GAS 0 CUTTING GAS 0 @ 4576' 0 @ 4576' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 51213 @ 3752' 657 @ 3540' 12954.5 CONNECTION GAS_HIGH 0 ETHANE (C-2) 554 @ 4561' 10 @ 4416' 143.2 CONNECTION GAS_AVG 0 PROPANE (C-3) 0 @ 4576' 0 @ 4576' 0.0 CONNECTION GAS_CURRENT 0 BUTANE (C-4) 0 @ 4576' 0 @ 4576' 0.0 CURRENT BACKGROUND/AVG 7/48 PENTANE (C-5) 0 @ 4576' 0 @ 4576' 0.0 HYDROCARBON SHOWS Only minor shows associated with coal bed methane INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sandstone, sand, siltstone, tuffaceous siltstone, claystone, tuffaceous claystone, coal, carbonaceous shale PRESENT LITHOLOGY Beluga formation DAILY ACTIVITY SUMMARY Drill ahead, back reaming each stand and performing flow check before each connection; drilled to 4576' MD; currently circulating and conditioning on bottom in prepation for TOOH to shoe on wiper trip. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Hinostroza DAILY COST $3795 Total (DML $3200/ RW $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Al Lunda / Jim Brown DATE Nov 16, 2012 DEPTH 5260' PRESENT OPERATION Drilling ahead TIME 23:59:23 YESTERDAY 4576' 24 HOUR FOOTAGE 684' CASING INFORMATION 16" @ 140' 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4898' 37.64 217.15 4261.25' 4994' 37.89 216.41 4337.14' 5090' 37.34 215.95 4413.19' 5185' 37.64 216.63 4488.56' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 8 3/4" HCC Q505X 7016082 7x12/0.773 3025 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 248.9 @ 4577' 1.6 @ 5170' 99.3 7.95731 FT/HR SURFACE TORQUE 16071 @ 4698' 28 @ 5259' 10236.9 56.00000 FT-LBS WEIGHT ON BIT 47 @ 5180' 0 @ 4690' 10.7 29.43259 KLBS ROTARY RPM 83 @ 4904' 18 @ 4774' 67.1 0.00000 RPM PUMP PRESSURE 2364 @ 4785' 1436 @ 4577' 1928.5 1860.00000 PSI DRILLING MUD REPORT DEPTH 5171'/4478' MW 9.3 VIS 48 PV 11 YP 19 Gels 6/11/14 FL 6.2 CL- 30000 FC 1/1 SOL 10.0 SD 0.25 OIL 3/87 MBT 2.5 pH 9.8 Ca+ 60 Alk 1.35 MWD SUMMARY INTERVAL 3025' TO 5260' TOOLS Bit, mudmotor, directional and quad combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 116 @ 5034' 4 @ 4700' 44.6 TRIP GAS 7u CUTTING GAS 0 @ 5260' 0 @ 5260' 0.0 WIPER GAS 73u CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 43199 @ 5034' 1515 @ 4700' 15597.3 CONNECTION GAS_HIGH 0 ETHANE (C-2) 832 @ 5034' 18 @ 4700' 181.1 CONNECTION GAS_AVG 0 PROPANE (C-3) 0 @ 5260' 0 @ 5260' 0.0 CONNECTION GAS_CURRENT 0 BUTANE (C-4) 0 @ 5260' 0 @ 5260' 0.0 CURRENT BACKGROUND/AVG 16u/44u PENTANE (C-5) 0 @ 5260' 0 @ 5260' 0.0 HYDROCARBON SHOWS Minor gas shows associated with coal bed methane INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sandstone, sand, siltstone, tuffaceous siltstone, claystone, tuffaceous claystone, coal, carbonaceous shale PRESENT LITHOLOGY Beluga formation DAILY ACTIVITY SUMMARY Short trip to 2,953' (inside shoe); worked through tight spot at 3,420' w/25K over pull; tight spot not seen TIH; TIH w/proper hole fill; trip gas 7 units, wiper gas 73 units; drill ahead at 575gpm, 1,850 psi, 40-80 rpm, 10-15.5K TQ, 128-150 FPH ROH (except when sliding); back ream each stand before connection; begin increasing lubes to 3% at 4,800'; drilling ahead from 4861', 530gpm, 200spm, 1850psi-on 1750-off, 80rpm, TQ-on 10-15 TQ-off 8-9, back ream full stand and flow check every connection, currently drilling ahead at 5260'. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Hinostroza DAILY COST $3795 Total (DML $3200, RW $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Al Lunda/Larry Driskill DATE Nov 17, 2012 DEPTH 6288' PRESENT OPERATION DRILLING AHEAD TIME 23:59:37 YESTERDAY 5260' 24 HOUR FOOTAGE 1028' CASING INFORMATION 16" @ 140' 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5849' 37.11 217.82 5015.31' 5944' 37.54 215.87 5090.86' 6039' 36.87 215.40 5166.52' 6134' 37.62 215.65 5242.15' 6231' 37.22 215.84 5319.19' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 8 3/4" HCC Q505X 7016082 7X12/0.773 3025' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 360.3 @ 5837' 2.8 @ 5848' 97.0 119.77482 FT/HR SURFACE TORQUE 16099 @ 5836' 28 @ 6128' 10163.4 11743.00000 FT-LBS WEIGHT ON BIT 48 @ 5373' 0 @ 6182' 7.4 0.00000 KLBS ROTARY RPM 85 @ 5955' 6 @ 5349' 71.0 82.00000 RPM PUMP PRESSURE 2520 @ 6213' 1775 @ 5266' 2127.1 2126.00000 PSI DRILLING MUD REPORT DEPTH 8124'/5233' MW 9.2 VIS 47 PV 9 YP 17 Gels 6/9/11 FL 8.5 CL- 28500 FC 1/1 SOL 12.0 SD 0.2 OIL 3/85 MBT 3.5 pH 9.5 Ca+ 40 Alk 0.7 MWD SUMMARY INTERVAL 3025' TO 6288' TOOLS Bit, mudmotor, directional and quad combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 295 @ 5677' 6 @ 5491' 63.0 TRIP GAS 3u CUTTING GAS 0 @ 6288' 0 @ 6288' 0.0 WIPER GAS 77u CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 99023 @ 5517' 2293 @ 5849' 20343.6 CONNECTION GAS_HIGH 0 ETHANE (C-2) 1833 @ 5517' 46 @ 5849' 360.6 CONNECTION GAS_AVG 0 PROPANE (C-3) 104 @ 5677' 0 @ 6094' 14.2 CONNECTION GAS_CURRENT 0 BUTANE (C-4) 0 @ 6288' 0 @ 6288' 0.0 CURRENT BACKGROUND/AVG 97u/63u PENTANE (C-5) 0 @ 6288' 0 @ 6288' 0.0 HYDROCARBON SHOWS Gas in tuffaceous sandstone (Show report in preparation); also many coal gas shows INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 6250-6288+ Tuffaceous ss. 163u Show REport #1 in prep. LITHOLOGY Tuffaceous sandstone and siltstone, siltstone, coal, carbonaceous shale, trace ash. PRESENT LITHOLOGY Tyonek formation (Ty 4900) DAILY ACTIVITY SUMMARY Drill ahead at 530gpm, 2100 psi, 9-15K TQ, 6-10 WOB, 120 fph ROP, sliding on occation; back ream every stand before connection; drill to 6,097' MD; pump 75 vis sweep and circulate and clean; short trip to 4577' good hole, TIH from 4577' DWN=90 to 6004'; fill pipe wash down to 6097', wiper gas 77 units;drill ahead 80rpm, 200spm, 530 gpm, psi on 2250, psi off 2000, TQ off 8-9; currently drilling ahead. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Hinostroza DAILY COST $3795 Total (DML $3200, RW $595) REPORT BY James.Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Al Lunda / Larry Driskill DATE Nov 18, 2012 DEPTH 7439' PRESENT OPERATION DRILLING AHEAD TIME 23:59:37 YESTERDAY 6288' 24 HOUR FOOTAGE 1151' CASING INFORMATION 16" @ 140' 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6993' 36.25 215.90 5926.54' 7087' 35.79 215.97 6002.56' 7182' 35.33 215.87 6079.85' 7277' 34.25 215.07 6157.87' 7372' 32.93 215.25 6237.00' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 8 3/4" HCC Q505X 7016082 7x12/0.773 3025' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 529.2 @ 6512' 2.8 @ 7388' 92.1 109.87380 FT/HR SURFACE TORQUE 16042 @ 6329' 28 @ 7388' 12175.8 13818.00000 FT-LBS WEIGHT ON BIT 49 @ 6511' 0 @ 7336' 8.4 0.00000 KLBS ROTARY RPM 84 @ 7374' 37 @ 7201' 73.1 78.00000 RPM PUMP PRESSURE 2776 @ 7082' 1778 @ 7283' 2282.7 2294.00000 PSI DRILLING MUD REPORT DEPTH 7372'/6238' MW 9.5 VIS 50 PV 11 YP 17 Gels 6/10/15 FL 6.8 CL- 29000 FC 1/1 SOL 13.0 SD 0.2 OIL 5/85 MBT 3.5 pH 9.7 Ca+ 80 Alk 0.8 MWD SUMMARY INTERVAL 3025' TO 7439' TOOLS Bit, mudmotor, directional and quad combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 274 @ 6545' 2 @ 7388' 40.1 TRIP GAS 0 CUTTING GAS 0 @ 7439' 0 @ 7439' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 293133 @ 6545' 3964 @ 7289' 32895.7 CONNECTION GAS_HIGH 0 ETHANE (C-2) 4232 @ 6545' 45 @ 7388' 473.7 CONNECTION GAS_AVG 0 PROPANE (C-3) 97 @ 6409' 0 @ 7039' 5.6 CONNECTION GAS_CURRENT 0 BUTANE (C-4) 44 @ 6409' 0 @ 6440' 0.6 CURRENT BACKGROUND/AVG 6u/40u PENTANE (C-5) 0 @ 7439' 0 @ 7439' 0.0 HYDROCARBON SHOWS Several gas shows in tuffaceous sandstone (detailed in Show Reports #3-8) and in coal. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone, silstsone and shale; siltstone, ash, coal and carbonaceous shale. PRESENT LITHOLOGY Tyonek formation (Ty 7200) DAILY ACTIVITY SUMMARY Drill ahead at 530gpm, 2200 psi, 80 RPM, 10-14K TQ, back ream each stand on connections. At 7,239' reduce pump rate due to high vibration to 475gpm, 180spm, 2350psi-on, 2150psi-off, 80rpm 9-10 TQ-off, 12-14TQ-on; currently drilling ahead at 7439'. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Hinostroza DAILY COST $3795 Total (DML $3200, RW $595 REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Al Lunda/Larry Driskill DATE Nov 19, 2012 DEPTH 7560' PRESENT OPERATION L/D BHA TIME 23:59:24 YESTERDAY 7439' 24 HOUR FOOTAGE 121' CASING INFORMATION 16" @ 140' 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7467' 30.58 216.86 6317.79' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 8 3/4" HCC Q505X 7016082 7x12/0.773 3025' 7560' 4535' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 126.0 @ 7491' 2.6 @ 7442' 51.1 28.21620 FT/HR SURFACE TORQUE 16071 @ 7442' 28 @ 7559' 7743.1 56.00000 FT-LBS WEIGHT ON BIT 45 @ 7480' 0 @ 7449' 12.0 27.68831 KLBS ROTARY RPM 81 @ 7486' 1 @ 7456' 39.4 0.00000 RPM PUMP PRESSURE 3572 @ 7473' 1986 @ 7513' 2385.9 2488.00000 PSI DRILLING MUD REPORT DEPTH 7560'/6397' MW 9.2 VIS 47 PV 10 YP 17 Gels 6/11/16 FL 5.9 CL- 30500 FC 1/1 SOL 10.5 SD 0.15 OIL 3/87 MBT 3.5 pH 10.1 Ca+ 80 Alk 3 MWD SUMMARY INTERVAL 3025' TO 7560' TOOLS Bit, mudmotor, directional, quad combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 34 @ 7486' 1 @ 7560' 10.6 TRIP GAS 2u CUTTING GAS 0 @ 7560' 0 @ 7560' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 48005 @ 7525' 3401 @ 7480' 14680.6 CONNECTION GAS_HIGH 0 ETHANE (C-2) 721 @ 7485' 43 @ 7455' 192.6 CONNECTION GAS_AVG 0 PROPANE (C-3) 45 @ 7485' 0 @ 7523' 6.2 CONNECTION GAS_CURRENT 0 BUTANE (C-4) 0 @ 7560' 0 @ 7560' 0.0 CURRENT BACKGROUND/AVG N/A /10u PENTANE (C-5) 0 @ 7560' 0 @ 7560' 0.0 HYDROCARBON SHOWS Minor shows in coal interbedded with tuffaceous sandstone INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone, siltstone and shale; coal and carbonaceous shale PRESENT LITHOLOGY Tyonek formation (Ty 6000) DAILY ACTIVITY SUMMARY Drill ahead at 475 gpm (reduced rate due to vibration), 2300 psi, 13-15 K TQ, 8-10 WOB; drill to 7,525'; pump sweep; perform short trip to 6090' with no problems; drill ahead at 550 gpm, 2350 psi, 80 RPM, trouble sliding; decision to POOH; circulate and condition mud; pump sweep; circulate clean; pump dry job and POOH; currently L/D down BHA, and removing sources. CANRIG PERSONNEL ON BOARD ondition mud; pump sweep; circulate clean; pump dry job and POOH; currently L/D down BHA, and removing sources. DAILY COST Foradas, Dubowski, Franze, Hinostroza REPORT BY $3795Total (DML $3200, RW $595) Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Al Lunda/Larry Driskill DATE Nov 20, 2012 DEPTH 7560' PRESENT OPERATION RIH TIME 23:59:07 YESTERDAY 7560' 24 HOUR FOOTAGE 0' CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 3 8 3/4" HCC Q505X 701682 7x12/.773 3025' 7560' 4535' 62.9 1-1-ER-N-X-I-WT-PR PR 4 8 3/4" HCC Q506FX 7138043 6x14/0.902 7560' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7560'/6397' MW 9.2 VIS 47 PV 9 YP 16 Gels 5/10/15 FL 5.6 CL- 30500 FC 1/1 SOL 10.5 SD 0.15 OIL 3/87 MBT 3.5 pH 10.1 Ca+ 80 Alk 3 MWD SUMMARY INTERVAL 7560' TO 7560' TOOLS Bit, mudmotor, directional and quad combo (BHA#4) GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 7u CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS_HIGH N/A ETHANE (C-2) @ @ CONNECTION GAS_AVG N/A PROPANE (C-3) @ @ CONNECTION GAS_CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A PRESENT LITHOLOGY Tyonek (Ty 6000) DAILY ACTIVITY SUMMARY Continue to POOH; L/D remaining BHA; Test BOP's; P/U new bit and BHA and RIH; currently at 3045'. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Hinostroza DAILY COST $6795 Total (DML $3200, RW $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larry Driskill/Jim Brown DATE Nov 03, 2012 DEPTH 2040' PRESENT OPERATION Drilling Ahead TIME 23:59:43 YESTERDAY 1175' 24 HOUR FOOTAGE 865' CASING INFORMATION 16" @ 140' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1573' 20.70 215.49 1551.68' 1667' 22.45 216.02 1639.09' 1762' 24.57 214.98 1726.20' 1855' 27.34 214.15 1809.82' 1949' 29.73 215.85 1892.39' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 1 13.5" HTC MLX-1X 5196654 3x16,1x14/0.7394 140' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 299.8 @ 1360' 6.3 @ 1192' 72.4 28.88606 FT/HR SURFACE TORQUE 19854 @ 1986' 28 @ 2023' 4866.1 479.00000 FT-LBS WEIGHT ON BIT 36 @ 1360' 2 @ 1537' 21.2 22.12494 KLBS ROTARY RPM 73 @ 1297' 1 @ 1934' 46.3 0.00000 RPM PUMP PRESSURE 2417 @ 1982' 1093 @ 1184' 1914.8 1893.00000 PSI DRILLING MUD REPORT DEPTH 2009'/1945' MW 9.6 VIS 46 PV 15 YP 12 Gels 4/30/36 FL 11.3 CL- 600 FC 2/- SOL 10 SD 0.15 OIL -/90 MBT 22.5 pH 9.7 Ca+ Alk MWD SUMMARY INTERVAL 140' TO 2040' TOOLS Bit, mudmotor and directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 108 @ 2004' 1 @ 2025' 26.6 TRIP GAS 45u CUTTING GAS 0 @ 2040' 0 @ 2040' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 47063 @ 2005' 1086 @ 1708' 13068.4 CONNECTION GAS_HIGH 0 ETHANE (C-2) 967 @ 2005' 0 @ 1362' 125.0 CONNECTION GAS_AVG 0 PROPANE (C-3) 55 @ 2003' 0 @ 1767' 3.7 CONNECTION GAS_CURRENT 0 BUTANE (C-4) 74 @ 2005' 4 @ 1990' 0.8 CURRENT BACKGROUND/AVG 7u/26u PENTANE (C-5) 0 @ 2040' 0 @ 2040' 0.0 HYDROCARBON SHOWS Minor gas shows associated with coal bed methane INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sandstone and sand, siltstone, claystone, coal and carbonaceous shale PRESENT LITHOLOGY Beluga formation DAILY ACTIVITY SUMMARY Drilled ahead to 2,009' and circulated hole clean, max gas 45u; pumped 23bbl slug weighing 11.7ppg and pulled out for a short trip; reamed through a tight spot from 950' to 900'; once back on bottom drilling, screen shaker #1 up to 230API; currrently slide drilling at 2040' MD. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Winslow DAILY COST DML $3200 RW $595 REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Al Lunda/Larry Driskill DATE Nov 21, 2012 DEPTH 8173' PRESENT OPERATION Drilling TIME 23:59:42 YESTERDAY 7560' 24 HOUR FOOTAGE 613' CASING INFORMATION 16" @ 140' 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7684' 26.27 213.76 6508.30' 7780' 24.08 213.95 6595.18' 7875' 21.10 213.69 6682.88' 7970' 18.84 214.14 6772.16' 8065' 16.45 212.72 6862.69' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4 8 3/4" HCC 506FX 7138043 6x14/0.902 7560' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 253.9 @ 7971' 4.0 @ 7978' 54.3 5.31902 FT/HR SURFACE TORQUE 16071 @ 8098' 28 @ 8149' 9376.0 15798.00000 FT-LBS WEIGHT ON BIT 32 @ 7975' 0 @ 8009' 10.0 1.17508 KLBS ROTARY RPM 83 @ 7632' 2 @ 8133' 47.4 81.00000 RPM PUMP PRESSURE 3773 @ 8146' 2488 @ 7560' 3234.9 3341.00000 PSI DRILLING MUD REPORT DEPTH 8121'/6919' MW 9.5 VIS 48 PV 11 YP 19 Gels 7/11/17 FL 52 CL- 31500 FC 1/1 SOL 12.0 SD 0.15 OIL 3/85 MBT 4.0 pH 9.9 Ca+ 80 Alk 3 MWD SUMMARY INTERVAL 7560' TO 8173' TOOLS Bit, mudmotor, directional and quad combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 455 @ 7980' 1 @ 7560' 93.3 TRIP GAS 22u CUTTING GAS 0 @ 8173' 0 @ 8173' 0.0 WIPER GAS 536u CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 325181 @ 7615' 1107 @ 7560' 18282.0 CONNECTION GAS_HIGH 0 ETHANE (C-2) 6022 @ 7615' 17 @ 7560' 299.1 CONNECTION GAS_AVG 0 PROPANE (C-3) 334 @ 7615' 0 @ 7923' 16.3 CONNECTION GAS_CURRENT 0 BUTANE (C-4) 16 @ 8038' 0 @ 8057' 0.2 CURRENT BACKGROUND/AVG 27u/93u PENTANE (C-5) 0 @ 8173' 0 @ 8173' 0.0 HYDROCARBON SHOWS Shows associated with coal bed methane INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone, siltstone and shale; coal and carbonaceous shale. PRESENT LITHOLOGY Tyonek formation (Ty 6800) DAILY ACTIVITY SUMMARY Continue to RIH; CBU at 3040' 27 units max gas; CBU at 5600' 337 units max gas; drilling ahead rotating and sliding (CBU at 7560' 536 units max gas); started to drop angle at ~7500'; drilling ahead from 7818' to 8162' 550gpm, 210spm, PSI-off=3450, PSI-on=3300, 60rpm, 11-12 TQ-off, TQ-on 14-16 UPW= 185, DNW= 130 RTW= 155 MWT=9.4, WOB= 5-6, sliding on occasion, back reaming every stand; currently at 8173' MD. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Hinostroza DAILY COST $3795 Total (DML $3200, RW $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Al Lunda/Jim Hickel DATE Nov 22, 2012 DEPTH 8418' PRESENT OPERATION POOH TIME 23:57:03 YESTERDAY 8173' 24 HOUR FOOTAGE 245' CASING INFORMATION 16" @ 140' 10.75' @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8160' 14.54 214.86 6954.23' 8256' 12.57 214.64 7047.55' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4 8 3/4" HCC 506FX 7138043 6x14/0.902 7560' 8418' 858' Lost communication DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 181.8 @ 8352' 4.0 @ 8315' 47.5 5.47388 FT/HR SURFACE TORQUE 16042 @ 8175' 28 @ 8363' 10439.1 15263.00000 FT-LBS WEIGHT ON BIT 26 @ 8228' 0 @ 8206' 3.7 5.01253 KLBS ROTARY RPM 82 @ 8176' 23 @ 8229' 53.4 82.00000 RPM PUMP PRESSURE 3922 @ 8342' 3213 @ 8218' 3530.5 3530.00000 PSI DRILLING MUD REPORT DEPTH 8418'/7206' MW 9.4 VIS 48 PV 11 YP 17 Gels 4/5/6 FL 4.9 CL- 29000 FC 1/1 SOL 11.0 SD 0.1 OIL 4/86 MBT 5.0 pH 9.2 Ca+ 80 Alk 2.1 MWD SUMMARY INTERVAL 7560' TO 8418' TOOLS Bit, mudmotor, directional and quad combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 140 @ 8197' 13 @ 8343' 49.2 TRIP GAS 0 CUTTING GAS 0 @ 8418' 0 @ 8418' 0.0 WIPER GAS 33u CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 34474 @ 8196' 3267 @ 8343' 10572.4 CONNECTION GAS_HIGH 0 ETHANE (C-2) 631 @ 8196' 38 @ 8412' 152.3 CONNECTION GAS_AVG 0 PROPANE (C-3) 41 @ 8196' 1 @ 8214' 2.8 CONNECTION GAS_CURRENT 0 BUTANE (C-4) 0 @ 8418' 0 @ 8418' 0.0 CURRENT BACKGROUND/AVG 0u/49u PENTANE (C-5) 0 @ 8418' 0 @ 8418' 0.0 HYDROCARBON SHOWS Shows associated with coal bed methane INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous siltstone and sandstone, coal and carbonaceous shale. PRESENT LITHOLOGY Tyonek (Ty 6000) DAILY ACTIVITY SUMMARY Drilled ahead to 8418'; Unable to get a signal from the MWD tool; cycled pumps and trouble shoot tool signal; stand back 1 stand; pump sweep; CBU, 33 units max gas; POOH; currently laying down BHA. Note additional DML cost due to Holiday rate (Thanksgiving). CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Hinostroza DAILY COST $4859 Total (DML $4264, RW $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Al Lunda/Jim Hickel DATE Nov 23, 2012 DEPTH 8463' PRESENT OPERATION Drilling TIME 23:59:43 YESTERDAY 8418' 24 HOUR FOOTAGE 45 CASING INFORMATION 16" @ 140' 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8350' 9.78 214.66 7139.76 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR1 8 3/4" HCC 506FX 7138043 6x14/0.902 8414' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 237.1 @ 8448' 5.5 @ 8418' 56.0 23.21672 FT/HR SURFACE TORQUE 16014 @ 8454' 28 @ 8453' 3927.2 16014.00000 FT-LBS WEIGHT ON BIT 67 @ 8450' 5 @ 8418' 49.4 33.43532 KLBS ROTARY RPM 82 @ 8418' 24 @ 8459' 16.6 68.00000 RPM PUMP PRESSURE 3995 @ 8422' 3530 @ 8418' 3823.2 3575.00000 PSI DRILLING MUD REPORT DEPTH 8418'/7206' MW 9.4 VIS 48 PV 12 YP 16 Gels 4/4/5 FL 4.9 CL- 29500 FC 1/1 SOL 12.0 SD 0.2 OIL 4/84 MBT 4.75 pH 9.3 Ca+ 60 Alk 1.9 MWD SUMMARY INTERVAL 8414' TO 8463' TOOLS Bit, mudmotor, directional and quad combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 251 @ 8450' 23 @ 8418' 65.3 TRIP GAS 98u CUTTING GAS 0 @ 8463' 0 @ 8463' 0.0 WIPER GAS 233u CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 24051 @ 8450' 3901 @ 8459' 10170.9 CONNECTION GAS_HIGH 0 ETHANE (C-2) 459 @ 8450' 56 @ 8459' 138.8 CONNECTION GAS_AVG 0 PROPANE (C-3) 30 @ 8422' 0 @ 8459' 12.6 CONNECTION GAS_CURRENT 0 BUTANE (C-4) 0 @ 8463' 0 @ 8463' 0.0 CURRENT BACKGROUND/AVG 39u/65u PENTANE (C-5) 0 @ 8463' 0 @ 8463' 0.0 HYDROCARBON SHOWS Minor shows associated with coal bed methane INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone, siltstone and shale; coal and carbonaceous shale. PRESENT LITHOLOGY Tyonek (Ty 7200) DAILY ACTIVITY SUMMARY L/D BHA to malfunctioning tool; clear rig floor; P/U up new MWD tool; RIH (Bit#4-RR1); shallow test MWD, max gas 74 units; continue to RIH to the shoe; Circulate at the shoe while cut and slip drilling line; service top drive and encoder on top drive; continue to RIH pump btms up @ 5200' (max gas 28 units) and 7500' (max gas 233 units) per Co. man, no tight spots encountered; wash down from 8312' to 8418' (max gas 219 units); trouble rotating due to high torque; pump 30bbl hi-vis sweep; rotate and recip. pipe slowly down to bottom; commenced drilling at 22:20 hours, mostly sliding; currently at 8463' MD. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Hinostroza DAILY COST $3795 Total (DML $3200, RW $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Al Lunda/Jim Hickel DATE Nov 24, 2012 DEPTH 9082' PRESENT OPERATION Drilling TIME 23:59:48 YESTERDAY 8463' 24 HOUR FOOTAGE 619' CASING INFORMATION 16" @ 140' 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8637' 3.26 211.26 7424.84' 8732' 1.38 211.72 7519.75' 8827' 0.46 190.82 7614.74' 8922' 0.37 191.48 7709.74' 9019' 0.31 190.18 7806.74' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR1 8 3/4" HCC 506FX 7138043 6X14/0.902 8414' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 168.3 @ 8650' 1.3 @ 8627' 40.7 10.68481 FT/HR SURFACE TORQUE 17967 @ 8795' 28 @ 8728' 13921.6 14963.00000 FT-LBS WEIGHT ON BIT 34 @ 8731' 0 @ 8698' 7.3 6.46307 KLBS ROTARY RPM 82 @ 8608' 11 @ 8632' 65.5 80.00000 RPM PUMP PRESSURE 3972 @ 9070' 3360 @ 8478' 3694.3 3658.00000 PSI DRILLING MUD REPORT DEPTH 9022'/7809' MW 9.4 VIS 45 PV 13 YP 16 Gels 4/4/5 FL 4.7 CL- 34000 FC 1/1 SOL 12.0 SD 0.15 OIL 4/84 MBT 4.5 pH 9.3 Ca+ 60 Alk 2.4 MWD SUMMARY INTERVAL 8414' TO 9082' TOOLS Bit, mudmotor, directional, and quad combo. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 301 @ 8676' 11 @ 8667' 45.1 TRIP GAS N/A CUTTING GAS 0 @ 9082' 0 @ 9082' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 55366 @ 8676' 1266 @ 8783' 6717.2 CONNECTION GAS_HIGH 0 ETHANE (C-2) 909 @ 8676' 14 @ 8783' 100.7 CONNECTION GAS_AVG 0 PROPANE (C-3) 57 @ 8676' 0 @ 8794' 6.2 CONNECTION GAS_CURRENT 0 BUTANE (C-4) 39 @ 8676' 0 @ 8794' 1.5 CURRENT BACKGROUND/AVG 26u/45u PENTANE (C-5) 0 @ 9082' 0 @ 9082' 0.0 HYDROCARBON SHOWS Shows associated with coal bed methane INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone, siltstone and shale; carbonaceous shale, coal. PRESENT LITHOLOGY Tyonek formation (Ty 7200) DAILY ACTIVITY SUMMARY Drilling ahead; drop angle and sliding complete by approximately 8800'; rotating ROP at 40' to 50' per hour; pumped high vis sweep at 8,886' with minimal increase in cuttings 80rpm TQ-16-18k, WOB=2-10k, 525gpm,3800psi, MWT-9.4ppg; currently drilling at 9082' MD. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Hinostroza DAILY COST $3795 Total (DML $3200, RW $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Al Lunda/Jim Hickel DATE Nov 25, 2012 DEPTH 9553' PRESENT OPERATION TOOH on wiper trip TIME 23:59:43 YESTERDAY 9082' 24 HOUR FOOTAGE 471' CASING INFORMATION 16" @ 140' 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9114' .25 184.56 7901.47' 9207' .26 161.15 7994.74' 9303' .22 124.60 8090.73' 9398' .23 111.68 8185.73' 9492' .34 87.46 8279.73' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR1 8 3/4" HCC 506FX 7138043 6X14/0.0902 8414' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 92.9 @ 9363' 1.5 @ 9096' 30.9 15.99350 FT/HR SURFACE TORQUE 17967 @ 9095' 14390 @ 9322' 17329.6 17779.00000 FT-LBS WEIGHT ON BIT 35 @ 9270' 0 @ 9538' 7.3 4.09451 KLBS ROTARY RPM 83 @ 9149' 23 @ 9095' 78.5 77.00000 RPM PUMP PRESSURE 4208 @ 9226' 2506 @ 9304' 3837.5 3936.00000 PSI DRILLING MUD REPORT DEPTH 9552'/8340' MW 9.4 VIS 46 PV 13 YP 17 Gels 4/4/5 FL 4.5 CL- 33000 FC 1/1 SOL 12.0 SD 0.15 OIL 4/84 MBT 5.0 pH 9.4 Ca+ 60 Alk 2.8 MWD SUMMARY INTERVAL 8414' TO 9533' TOOLS Bit, mudmotor, directional and quad combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 343 @ 9220' 4 @ 9250' 48.2 TRIP GAS 7u CUTTING GAS 0 @ 9553' 0 @ 9553' 0.0 WIPER GAS 22u CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 59883 @ 9130' 580 @ 9250' 8631.0 CONNECTION GAS_HIGH 200u ETHANE (C-2) 1121 @ 9130' 10 @ 9250' 139.1 CONNECTION GAS_AVG 0 PROPANE (C-3) 107 @ 9130' 0 @ 9452' 13.0 CONNECTION GAS_CURRENT 0 BUTANE (C-4) 15 @ 9537' 0 @ 9531' 0.7 CURRENT BACKGROUND/AVG N/A /48u PENTANE (C-5) 0 @ 9553' 0 @ 9553' 0.0 HYDROCARBON SHOWS Minor shows associated with coal bed methane INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone, siltstone, and shale; coal and carbonaceous shale. PRESENT LITHOLOGY Tyonek formation (Ty 8000) DAILY ACTIVITY SUMMARY Drilling ahead - rotating, 530 GPM, 200 SPM, 3900psi-on, 3700psi-off, 80RPM, 16-17k TQ-on, 14-15 TQ-off, 9.4+MWT, 2- 8WOB, 10-30FPH, backream every stand, pumping sweeps as needed; drilled to 9553' MD; TOOH on wiper trip from 9553'; currently at 9233' MD on wiper trip. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Hinostroza DAILY COST $3795 (DML $3200, RW $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Al Lunda/Jim Hickel DATE Nov 26, 2012 DEPTH 10014' PRESENT OPERATION DRILLING TIME 23:59:16 YESTERDAY 9553' 24 HOUR FOOTAGE 461' CASING INFORMATION 16" @ 140' 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9592' 0.48 78.37 8379.73' 9696' 0.57 68.34 8473.73' 9782' 0.76 61.54 8569.72' 9878' 0.97 54.30 86685.71' 9976' 0.40 90.92 8763.70' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR1 8 3/4" hcc 506FX 7138043 6x14/0.0902 8414' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 125.9 @ 10007' 2.3 @ 9602' 32.2 45.69704 FT/HR SURFACE TORQUE 19976 @ 9845' 28 @ 9958' 17550.0 19769.00000 FT-LBS WEIGHT ON BIT 17 @ 9960' 0 @ 9735' 6.8 10.02509 KLBS ROTARY RPM 84 @ 9595' 7 @ 9960' 53.9 49.00000 RPM PUMP PRESSURE 4033 @ 9779' 3352 @ 9954' 3722.6 3617.00000 PSI DRILLING MUD REPORT DEPTH 9972'/8760' MW 9.4 VIS 4.8 PV 17 YP 18 Gels 4/4/5 FL 3.8 CL- 33000 FC 1/1 SOL 12.0 SD 0.15 OIL 4/84 MBT 4.75 pH 9.3 Ca+ 40 Alk 3.1 MWD SUMMARY INTERVAL 8414' TO 10014' TOOLS Bit, mudmotor, directional and quad combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 177 @ 9770' 4 @ 9741' 22.8 TRIP GAS 7u CUTTING GAS 0 @ 10014' 0 @ 10014' 0.0 WIPER GAS 66u CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 23777 @ 9908' 826 @ 9801' 4666.2 CONNECTION GAS_HIGH 41u ETHANE (C-2) 321 @ 9600' 0 @ 9841' 56.8 CONNECTION GAS_AVG 0 PROPANE (C-3) 28 @ 9908' 0 @ 9918' 0.3 CONNECTION GAS_CURRENT 0 BUTANE (C-4) 3 @ 9558' 3 @ 9558' 0.0 CURRENT BACKGROUND/AVG 10u/22u PENTANE (C-5) 0 @ 10014' 0 @ 10014' 0.0 HYDROCARBON SHOWS Minor shows associated with coal bed methane. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone, siltstone and shale; coal and carbonaceous shale. PRESENT LITHOLOGY Tyonek formation (Ty 8500). DAILY ACTIVITY SUMMARY Short trip back to 8000'; worked through tight spot at 8126', pulled 25K over; cleaned up; service top drive; TIH, no tight spots; pre-cautionary wash down from 9554' to bottom (66 units max gas); drilling ahead 50RPM, TQ=16-20k, WOB=6-12k, 500GPM, 3725PSI, MWT=9.4ppg; currently at 10,014'. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Hnostroza DAILY COST $3795 Total (RW $3200, RW $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Al Lunda/Jim Hickel DATE Nov 27, 2012 DEPTH 10500' PRESENT OPERATION Drilling TIME 23:59::55 YESTERDAY 10014' 24 HOUR FOOTAGE 486' CASING INFORMATION 16" @ 140' 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10072' 0.40 109.05 8859.70' 10166' 0.59 149.61 8953.70' 10262' 0.68 188.87 9049.69' 10358' 0.85 211.23 9145.68' 10453' 0.73 203.29 9240.67' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR1 8 3/4" HCC 506FX 7138043 6X14/0.0902 8414' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 144.2 @ 10150' 2.7 @ 10072' 32.1 42.21948 FT/HR SURFACE TORQUE 21121 @ 10266' 28 @ 10350' 17452.5 20332.00000 FT-LBS WEIGHT ON BIT 46 @ 10051' 0 @ 10088' 8.6 8.18900 KLBS ROTARY RPM 82 @ 10165' 4 @ 10047' 40.4 50.00000 RPM PUMP PRESSURE 4076 @ 10473' 2320 @ 10187' 3711.9 3834.00000 PSI DRILLING MUD REPORT DEPTH 10422'/9210' MW 9.4 VIS 50 PV 19 YP 21 Gels 5/7/8 FL 3.5 CL- 33000 FC 1/1 SOL 12.0 SD Tr OIL 4/84 MBT 4.5 pH 9.3 Ca+ 40 Alk 3.3 MWD SUMMARY INTERVAL 8414' TO 10500' TOOLS Bit, mudmotor, directional and quad combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 288 @ 10338' 12 @ 10445' 41.2 TRIP GAS N/A CUTTING GAS 0 @ 10500' 0 @ 10500' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 31501 @ 10191' 1684 @ 10445' 5637.8 CONNECTION GAS_HIGH 0 ETHANE (C-2) 499 @ 10339' 25 @ 10074' 90.7 CONNECTION GAS_AVG 0 PROPANE (C-3) 51 @ 10191' 0 @ 10303' 5.6 CONNECTION GAS_CURRENT 0 BUTANE (C-4) 17 @ 10242' 0 @ 10157' 0.7 CURRENT BACKGROUND/AVG 13u/41u PENTANE (C-5) 0 @ 10500' 0 @ 10500' 0.0 HYDROCARBON SHOWS Minor gas shows associated with coal bed methane INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone, siltstone, and shale; carbonaceous shale and coal. PRESENT LITHOLOGY Tyonek formation (Ty8500) DAILY ACTIVITY SUMMARY Drilling ahead from 10,014' back ream every stand, 10-40FPR, 190SPM, 50rpm, TQ=17-21k, WOB=6-12k, 503GPM, 3850PSI, MWT=9.4ppg; currently at 10,500' MD. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Hinostroza DAILY COST $3795 Total (DML $3200, RW $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Al Lunda/Larry Driskill DATE Nov 28, 2012 DEPTH 10700' PRESENT OPERATION POOH TIME 23:59:21 YESTERDAY 10500' 24 HOUR FOOTAGE 200' CASING INFORMATION 16" @ 140' 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10549' 0.43 222.95 9336.67' 10642' 0.18 246.46 9429.67' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR1 10 3/4" HCC 506FX 7138043 6x14/0.0902 8414' 10700' 2286' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 105.9 @ 10526' 2.3 @ 10528' 29.5 21.40707 FT/HR SURFACE TORQUE 21121 @ 10524' 28 @ 10533' 18567.8 20755.00000 FT-LBS WEIGHT ON BIT 38 @ 10608' 0 @ 10699' 4.5 0.00000 KLBS ROTARY RPM 53 @ 10538' 3 @ 10526' 47.7 51.00000 RPM PUMP PRESSURE 4024 @ 10677' 3341 @ 10528' 3793.7 3756.00000 PSI DRILLING MUD REPORT DEPTH 10700'/9487' MW 9.4 VIS 47 PV 18 YP 22 Gels 5/7/8 FL 3.4 CL- 33000 FC 1/1 SOL 12.0 SD Tr OIL 4/84 MBT 6.0 pH 9.3 Ca+ 40 Alk 3.3 MWD SUMMARY INTERVAL 8414' TO 10700' TOOLS Bit, mudmotor, directional and quad combo GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 331 @ 10630' 16 @ 10506' 59.6 TRIP GAS 20u CUTTING GAS 0 @ 10700' 0 @ 10700' 0.0 WIPER GAS 51u CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 55596 @ 10621' 1752 @ 10653' 8556.1 CONNECTION GAS_HIGH 0 ETHANE (C-2) 866 @ 10627' 24 @ 10593' 135.4 CONNECTION GAS_AVG 0 PROPANE (C-3) 122 @ 10627' 0 @ 10601' 16.9 CONNECTION GAS_CURRENT 0 BUTANE (C-4) 18 @ 10574' 0 @ 10601' 0.6 CURRENT BACKGROUND/AVG N/A/59u PENTANE (C-5) 0 @ 10700' 0 @ 10700' 0.0 HYDROCARBON SHOWS Gas shows associated with coal bed methane. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone, siltstone, shale; coal and carbonaceous shale. PRESENT LITHOLOGY Tyonek formation (Ty9200) DAILY ACTIVITY SUMMARY Drilled to TD at 10700', reached at 0900 hrs; CBU; Pump sweep around (max 51 units gas); POOH, tight spot at 10559' - pump and ream through (22 units gas); continue to POOH on elevators; pump slug at 9615' (9 units gas); continue to POOH, currently at 2875' MD. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Hinostroza DAILY COST $3795 Total (DML $3200, RX $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Al Lunda/Larry Driskill DATE Nov 29, 2012 DEPTH 10700' PRESENT OPERATION RIH TIME 23:59:21 YESTERDAY 10700' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR1 10 3/4" HCC 506FX 7138043 6x14/0.0902 8418’ 10700’ 2282’ 81.4 1-1-WT-A-X-I-CT-TD TD 4-RR2 10 3/4" HCC 506FX 7138043 6x14/0.0902 10700' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10700'/9487' MW 9.4 VIS 48 PV 18 YP 22 Gels 5/7/8 FL 3.8 CL- 34000 FC 1/1 SOL 12.0 SD Tr OIL 4/84 MBT 6.0 pH 9.2 Ca+ 40 Alk 3.1 MWD SUMMARY INTERVAL 10700' TO 10700' TOOLS Bit and dumb iron for wiper trip - no MWD tools in hole GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 4u CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS_HIGH 0 ETHANE (C-2) @ @ CONNECTION GAS_AVG 0 PROPANE (C-3) @ @ CONNECTION GAS_CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY None - not drilling PRESENT LITHOLOGY Tyonek formation (Ty 9200) DAILY ACTIVITY SUMMARY Continued POOH to surface; L/D BHA#4; clear rig floor; test BOP's with no problems; P/U BHA#5; RIH at 1800hrs, currently running in at 5450' MD. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Hinostroza DAILY COST $3795 Total (DML $3200, RW $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larry Driskill/Jim Brown DATE Nov 30, 2012 DEPTH 10700' PRESENT OPERATION POOH TIME 23:59:02 YESTERDAY 10700' 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 140' 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR2 10 3/4" HCC 506FX 7138043 6x14/0.09092 10700' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10700'/9487' MW 9.5 VIS 46 PV 17 YP 20 Gels 5/7/9 FL 3.6 CL- 32000 FC 1/1 SOL 12.5 SD Tr OIL 4/84 MBT 6.0 pH 9.2 Ca+ 40 Alk 3.0 MWD SUMMARY INTERVAL 10700' TO 10700' TOOLS Bit and dumb iron for wiper trip - no MWD tools in hole GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 70 CUTTING GAS @ @ WIPER GAS 259 CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS_HIGH 0 ETHANE (C-2) @ @ CONNECTION GAS_AVG 0 PROPANE (C-3) @ @ CONNECTION GAS_CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A - not drilling PRESENT LITHOLOGY Tyonek formation (Ty 9200) DAILY ACTIVITY SUMMARY Continue to RIH with clean-out assembly; wash and ream through several tight spots while running in the hole;CBU when on bottom (186 units max gas); pump sweep around; POOH; wash and ream tight spot from 10560' to 10540'; Continue to POOH to 10270'; run back to bottom; CBU (259 units max gas); pump and spot lubricant pill; pump slug; POOH on elevators; trip out was slick. POOH nearly complete. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Hinostroza DAILY COST $3795 Total (DML $3200, RW $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larry Driskill/Jim Brown DATE Nov 04, 2012 DEPTH 2846' PRESENT OPERATION Drilling ahead TIME 23:59:28 YESTERDAY 2040' 24 HOUR FOOTAGE 806' CASING INFORMATION 16" @ 140' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2427' 36.54 215.95 2288.10' 2522' 36.79 216.72 2364.30' 2618' 36.79 216.15 2441.18' 2715' 36.70 216.24 2518.91' 2810' 37.11 217.24 2594.87' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 1 13.5" HTC MLX-1X 5196654 3x16,1x14/0.7394 140' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 155.4 @ 2488' 0.8 @ 2207' 46.9 36.01596 FT/HR SURFACE TORQUE 21233 @ 2381' 28 @ 2798' 9060.4 11114.00000 FT-LBS WEIGHT ON BIT 37 @ 2651' 8 @ 2774' 27.5 23.00625 KLBS ROTARY RPM 75 @ 2160' 58 @ 2673' 60.7 70.00000 RPM PUMP PRESSURE 2557 @ 2548' 1688 @ 2191' 2207.7 2318.00000 PSI DRILLING MUD REPORT DEPTH 2764'/2551' MW 9.8 VIS 49 PV 14 YP 12 Gels 5/15/25 FL 7.8 CL- 400 FC 2/- SOL 10.5 SD 0.25 OIL -/90 MBT 23.75 pH 9.9 Ca+ - Alk MWD SUMMARY INTERVAL 140' TO 2846' TOOLS Bit, mudmotor and directional GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 73 @ 2384' 0 @ 2827' 11.2 TRIP GAS N/A CUTTING GAS 0 @ 2846' 0 @ 2846' 0.0 WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 78627 @ 2312' 2081 @ 2827' 15588.5 CONNECTION GAS_HIGH 0 ETHANE (C-2) 1384 @ 2312' 32 @ 2827' 247.5 CONNECTION GAS_AVG 0 PROPANE (C-3) 97 @ 2382' 0 @ 2200' 11.8 CONNECTION GAS_CURRENT 0 BUTANE (C-4) 0 @ 2846' 0 @ 2846' 0.0 CURRENT BACKGROUND/AVG 3u/11u PENTANE (C-5) 0 @ 2846' 0 @ 2846' 0.0 HYDROCARBON SHOWS Minor gas shows associated with coal beds INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sandstone, siltstone, claystone, coal, carbonaceous shale and thin ash beds PRESENT LITHOLOGY Beluga formation DAILY ACTIVITY SUMMARY Drilled ahead from 2040' at 650gpm, 70rpm, 2250-2350psi pump pressure, torque 7-11K; currently at 2846'. Change in daily cost due to work during change to fall daylight savings time. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Winslow DAILY COST $3895 total (DML $3200/RW $595) REPORT BY James. Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larr Driskill/Jim Brown DATE Dec 1, 2012 DEPTH 10700' PRESENT OPERATION Running Casing TIME 23:59:38 YESTERDAY 10700' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' 7" RIH @ 8598' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR2 8 3/4" HCC 506FX 7138043 6x10/0.0902 10700' 10700' 0' 0' 1-1-WT-A-XI-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10700'/9487' MW 9.5 VIS 48 PV 17 YP 21 Gels 5/7/8 FL 3.6 CL- 32000 FC 1/1 SOL 12.5 SD Tr OIL 4/84 MBT 6.0 pH 9.2 Ca+ 40 Alk 3.0 MWD SUMMARY INTERVAL 10700' TO 10700' TOOLS Bit with dumbiron on wiper trip GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 37u CUTTING GAS @ @ WIPER GAS 46u CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS_HIGH 0 ETHANE (C-2) @ @ CONNECTION GAS_AVG 0 PROPANE (C-3) @ @ CONNECTION GAS_CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 29u/21u PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A - not drilling. PRESENT LITHOLOGY Tyonek formation (Ty9200) DAILY ACTIVITY SUMMARY Lay down clean-out BHA; change rams and test; dummy run hanger; R/U and run 7" casing; CBU at 2982' (46 units max gas); started transferring mud to storage to make room for cement displacement at 1945hrs; currently running casing at 8598' MD without anu problems. CANRIG PERSONNEL ON BOARD Foradas, Bomar DAILY COST $2945 Total (DML $2350, RW $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larr Driskill/Jim Brown DATE Dec 2, 2012 DEPTH 10700' PRESENT OPERATION Trip in hole. TIME 23:59:38 YESTERDAY 10700' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' 7" RIH @ 8598' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR2 8 3/4" HCC 506FX 7138043 6x10/0.0902 10700' 10700' 0' 0' 1-1-WT-A-XI-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10700'/9487' MW 9.5 VIS PV YP Gels FL CL- FC SOL SD Tr OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 10700' TO 10700' TOOLS Bit with dumbiron on wiper trip GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 94u CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS_HIGH 0 ETHANE (C-2) @ @ CONNECTION GAS_AVG 0 PROPANE (C-3) @ @ CONNECTION GAS_CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A - not drilling. PRESENT LITHOLOGY Tyonek formation (Ty9200) DAILY ACTIVITY SUMMARY Run casing from 8298’-10673’ MD. Rig up and down to run casing tools, spider slips, cables, and fill up tools. Circulate and condition rig up circulating head, plug valves, transducer. Install cement lines. Pre-job safety meeting (going over pumping schedule). Primary cementing test lines to 400 PSI and check for leaks. Finish displacing cement with 404BBLS of water. Blow down and rig down cementing lines and cement head. Rig up/down to run casing set packoff. Test packoff and hanger void to 5000PSI. Rig up/down to run casing set wearing ring. Run down stabbing board. Run down long bales and install short bales. Pick up BHA M/U mill, 7” casing scraper, bit sub with ported float. 12 joints 4” HWDP. Trip in hole to 4094’ MD. Service rig, blocks, and draw works. Trip in hole continually. CANRIG PERSONNEL ON BOARD B.Adams, D. Bomar DAILY COST $2945.00 REPORT BY Britten Adams Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larr Driskill/Jim Brown DATE Dec 3, 2012 DEPTH 10700' PRESENT OPERATION POOH TIME 23:59:38 YESTERDAY 10700' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' 7" RIH @ 8598' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR2 8 3/4" HCC 506FX 7138043 6x10/0.0902 10700' 10700' 0' 0' 1-1-WT-A-XI-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10700'/9487' MW 8.7 VIS PV YP Gels FL CL- FC SOL SD Tr OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 10700' TO 10700' TOOLS Bit with dumbiron on wiper trip GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS_HIGH 0 ETHANE (C-2) @ @ CONNECTION GAS_AVG 0 PROPANE (C-3) @ @ CONNECTION GAS_CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A - not drilling. PRESENT LITHOLOGY Tyonek formation (Ty9200) DAILY ACTIVITY SUMMARY Trip in hole from 7340’-10581’MD. Clean out mud system, clean pits, clean under shakers, and clean out mud lines to brine. Circulate and condition hole with 80 strokes per minute. 650PSI, 215GPM while cleaning pits for displacement. Clean out mud system and build 30BBLS sweeps. Offload dirty mud and water from pits to make room for displacement. Displace to water base pump with 30BBLS sweep. Trip out of hole from 10581’-195’MD. Pull out sideways. Cleaning pits. CANRIG PERSONNEL ON BOARD D. Bomar, B. Adams DAILY COST $2945.00 REPORT BY B.Adams Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larr Driskill/Jim Brown DATE Dec 4, 2012 DEPTH 10700' PRESENT OPERATION L/D test tools TIME 23:59:38 YESTERDAY 10700' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' 7" RIH @ 8598' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR2 8 3/4" HCC 506FX 7138043 6x10/0.0902 10700' 10700' 0' 0' 1-1-WT-A-XI-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10700'/9487' MW VIS PV YP Gels FL CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 10700' TO 10700' TOOLS Bit with dumbiron on wiper trip GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS_HIGH 0 ETHANE (C-2) @ @ CONNECTION GAS_AVG 0 PROPANE (C-3) @ @ CONNECTION GAS_CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A - not drilling. PRESENT LITHOLOGY Tyonek formation (Ty9200) DAILY ACTIVITY SUMMARY Lay down drill pipe from 3712’-382’MD. Lay down BHA, Lay down 12 HT40 heavy wall, scraper, mill, float sub, and crossovers. Cased hole log PJSM and rig up wire liners to do bond logs. Cased hole logs wire line bond logs and drift, strap 2 7/8” with tubing. Cased hole log finish with cement bond log. Run down pollard e-line. Pressure test casing shoe with 7”. Pressure casing to 4000PSI for 30 minutes. Record test on chart. Change rams pull wear ring. Set test plug. C/O BTM to 2 7/8” and C/O top rams to 2 7/8”x 5 VBR. Pull up test tools and move up test joints. Fill system with water and purge air. Test BOPS and gas alarms. Record BOPS and gas alarms on chart. Lay down test tools and test joints. Drain water and blow down lines. Pull test plug. Set wear rings. CANRIG PERSONNEL ON BOARD D. Bomar, B. Adams DAILY COST $2945.00 REPORT BY B. Adams Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larr Driskill/Jim Brown DATE Dec 5, 2012 DEPTH 10700' PRESENT OPERATION E-line TIME 23:59:38 YESTERDAY 10700' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' 7" RIH @ 8598' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR2 8 3/4" HCC 506FX 7138043 6x10/0.0902 10700' 10700' 0' 0' 1-1-WT-A-XI-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10700'/9487' MW VIS PV YP Gels FL CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 10700' TO 10700' TOOLS e-line GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS_HIGH 0 ETHANE (C-2) @ @ CONNECTION GAS_AVG 0 PROPANE (C-3) @ @ CONNECTION GAS_CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A - not drilling. PRESENT LITHOLOGY Tyonek formation (Ty9200) DAILY ACTIVITY SUMMARY Service rig clean, service top drive, crown, and PMS till order are given. Cut drilling line by 100ft. Service rig and prepare for wire liners. Continue PMS, cleaning, and gathering crossovers for tuning run. Completion of PU, LD, make-up tools, and BHA spot baker tools in shed. Run up pollard e-line. Completion of stick line and wireline worked e-line; make a gauge ring run. Set packer @ 9040’ MD. Completion of PU, LD, make-up tools, and BHA run down pollard e-line. Completion of PU, LD, make-up tools, and BHA run up (Weatherford) to run tubing. Completion of trip tubing/drill pipe, pull up tubing per tally and running orders. CANRIG PERSONNEL ON BOARD D. Bomar, B. Adams DAILY COST $2945.00 REPORT BY B. Adams Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larr Driskill/Jim Brown DATE Dec 6, 2012 DEPTH 10700' PRESENT OPERATION P/U and L/D tools TIME 23:59:38 YESTERDAY 10700' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' 7" RIH @ 8598' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR2 8 3/4" HCC 506FX 7138043 6x10/0.0902 10700' 10700' 0' 0' 1-1-WT-A-XI-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10700'/9487' MW VIS PV YP Gels FL CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 10700' TO 10700' TOOLS e-line GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS_HIGH 0 ETHANE (C-2) @ @ CONNECTION GAS_AVG 0 PROPANE (C-3) @ @ CONNECTION GAS_CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A - not drilling. PRESENT LITHOLOGY Tyonek formation (Ty9200) DAILY ACTIVITY SUMMARY Completion-trip tubing drill pipe from 668’ to 4620’MD. Completion-trip tubing drill pipe from 4620’ to 9028’MD. Completion-trip tubing drill pipe rig up cross over to 2 7/8 to circulate. Completion-trip tubing drill pipe BRK circulation-1 BPM 40PSI. S/O until pressure increase seen. Shut down pumps; continue to S/O until setting 10K down. Take space out measurements. Add 2’ pup from space out. Land tubing setting 10K down. Completion-trip tubing drill pipe R/U 2 TIW valves and XO’s flange up flow cross to top TIW valves. R/U displacement hose. Completion-slick line wireline work R/U pollard slick line. Completion-slick line wireline work swab fluid out of 2 7/8” tubing with slickline. Completion-slick line wireline work R/D slickline. Completion-P/U, L/D, makeup tools, BHA remove flow cross and upper TIW valve, and install gate below flow cross. CANRIG PERSONNEL ON BOARD D. Bomar, B. Adams DAILY COST $2945.00 REPORT BY B. Adams Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larr Driskill/Jim Brown DATE Dec 7, 2012 DEPTH 10700' PRESENT OPERATION Monitor Well TIME 23:59:38 YESTERDAY 10700' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' 7" RIH @ 8598' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR2 8 3/4" HCC 506FX 7138043 6x10/0.0902 10700' 10700' 0' 0' 1-1-WT-A-XI-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10700'/9487' MW VIS PV YP Gels FL CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 10700' TO 10700' TOOLS e-line GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS_HIGH 0 ETHANE (C-2) @ @ CONNECTION GAS_AVG 0 PROPANE (C-3) @ @ CONNECTION GAS_CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A - not drilling. PRESENT LITHOLOGY Tyonek formation (Ty9200) DAILY ACTIVITY SUMMARY Slick line/wireline work. Finishing tightening flow cross, valve, hose to stand pipe, and rig up expo hard line. Install cap on lubricator crossover and test via expo to 4200PSI–350PSI. Pick up lubricator rig up, rig up guns in moushouse install lubricator test 4200PSI-350PSI. Run in to perforate 7” via pollard wire line. Pollard wire line shoot PERF guns from 9837’-9858’ MD. POOH, and L/D PERF guns to shed. Monitor well, and pollard prep guns from run #2. RIH with gun and run #2 shoot @ 9414’-9426’ MD. POOH and L/D spent gun to shed. Prep for next run and monitor well. P/U gun #3 and M/U lubricator. RIH shoot @ 9274’-9285’ MD. From 9287’-9300’ MD POOH and L/D to shed. Monitor well and prep gun for run #4. CANRIG PERSONNEL ON BOARD D. Bomar, B. Adams DAILY COST $2945.00 REPORT BY B. Adams Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larr Driskill/Jim Brown DATE Dec 8, 2012 DEPTH 10700' PRESENT OPERATION RIH with 2.25 guage ring. TIME 23:59:38 YESTERDAY 10700' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' 7" RIH @ 8598' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR2 8 3/4" HCC 506FX 7138043 6x10/0.0902 10700' 10700' 0' 0' 1-1-WT-A-XI-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10700'/9487' MW VIS PV YP Gels FL CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 10700' TO 10700' TOOLS e-line GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS_HIGH 0 ETHANE (C-2) @ @ CONNECTION GAS_AVG 0 PROPANE (C-3) @ @ CONNECTION GAS_CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A - not drilling. PRESENT LITHOLOGY Tyonek formation (Ty9200) DAILY ACTIVITY SUMMARY Service rig equipment. Removed damage finger, safeout off driller’s side tuber, and damaged line. Pollard wire line run with baler, swab tubing, and total of 7BBLS swabbed. Rig down slick line and prep for e-line. Rig up pollard lubricator and pollard loading guns in the pipe shed. P/U lubricator gun run #5. RIH shot @ 9177’-9198’ MD. POOH and lay down spent gun to shed. M/U new gun and run shoot #6 @ 9159’-9177’ MD. POOH to 69’ MD because of hung up in hole. All hands attempt to pump and wash free pump with 8-10BBLS @ 7-8BPM and 65PSI. Try to work line (No good). Pull with blocks line parted @ sheave, and R/U stuffing box on e-line BOP. Found bad line in lubricator, attempt to pull tools, pull 4’ of line, and no tools. R/D pollard e-line. Clean rig platform clear. R/U pollard slick line and RIH with 2.25 guage ring. CANRIG PERSONNEL ON BOARD D. Bomar, B. Adams DAILY COST $2945.00 REPORT BY B. Adams Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larr Driskill/Jim Brown DATE Dec 9, 2012 DEPTH 10700' PRESENT OPERATION Prepare tools for e-line. TIME 23:59:38 YESTERDAY 10700' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' 7" RIH @ 8598' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR2 8 3/4" HCC 506FX 7138043 6x10/0.0902 10700' 10700' 0' 0' 1-1-WT-A-XI-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10700'/9487' MW VIS PV YP Gels FL CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 10700' TO 10700' TOOLS e-line GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS_HIGH 0 ETHANE (C-2) @ @ CONNECTION GAS_AVG 0 PROPANE (C-3) @ @ CONNECTION GAS_CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A - not drilling. PRESENT LITHOLOGY Tyonek formation (Ty9200) DAILY ACTIVITY SUMMARY Completion slick line/wireline work PJSM. Run 2.25” gauge on pollard slick line, impression block. Swab well, via pollard taking returns to expo, and lost swab tool at 9400’MD. Waiting on tools, clean floor, mezzanine, stack, and work on 50# checklist. Fishing for swab tools. Attempt to run 2.25 magnet and pat TIW. Second attempt with 1 ¼ magnet can’t get past TIW. Change to stabbing tool and attempt to stab cups to retrieve swab. Retrieve only two cups. Continue to fish and 1.25” magnet will not pass through TIW. Change tool and attempt to push swabs to bottom. Push swabs from 8935’-8940’MD and POOH. Pollard slick line M/U weight bars, RIH; attempt to push down on swab. Attempt failed and POOH. R/D slick line. Cleaning rig and platform clear and clean rig floor. Pollard e-line on location, prep tools and rig up to perforate tubing. CANRIG PERSONNEL ON BOARD D. Bomar, B. Adams DAILY COST $2945.00 REPORT BY B.Adams Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larr Driskill/Jim Brown DATE Dec 10, 2012 DEPTH 10700' PRESENT OPERATION Set test plug TIME 23:59:38 YESTERDAY 10700' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' 7" RIH @ 8598' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR2 8 3/4" HCC 506FX 7138043 6x10/0.0902 10700' 10700' 0' 0' 1-1-WT-A-XI-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10700'/9487' MW VIS PV YP Gels FL CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 10700' TO 10700' TOOLS e-line GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS_HIGH 0 ETHANE (C-2) @ @ CONNECTION GAS_AVG 0 PROPANE (C-3) @ @ CONNECTION GAS_CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A - not drilling. PRESENT LITHOLOGY Tyonek formation (Ty9200) DAILY ACTIVITY SUMMARY Circulate and condition hole. Rig down EXPO hard line and move unit out of way. Rig down flow cross, bleed/pump hose, and valves. Circulate and condition 6400 strike, monitor well, blow down top drive, and rig up safety valves. Trip tubing drill pipe 2 7/8” from 9040’-7333’ MD. Trip tubing drill pipe weave 2 7/8” and tubing together at the “L” with sash cord. Trip tubing drill pipe from 7333’-3941’ MD. Continue POOH from 5145’ MD at 45K UPW. Lay down six joints; retrieve spent gun, e-line, and swabs. Lay down seal assembly and run down Weatherford tool. Run up pollard slick line, run in hole and set pug @ 9077’ MD. Wire line depth, POOH, and move up prong. RIH, set tool, and POOH. Run down slick line. Test BOPS void stack, pull W/R, M/U test joints, and set test plug for BOPS. CANRIG PERSONNEL ON BOARD D. Bomar, B. Adams DAILY COST $2945.00 REPORT BY B. Adams Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larry Driskill/Jim Brown DATE Nov 05, 2012 DEPTH 3005' PRESENT OPERATION R/U Run Casing TIME 23:59:56 YESTERDAY 2846' 24 HOUR FOOTAGE 159' CASING INFORMATION 16" @ 140' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2810' 37.11 217.24 2594.87' 2906' 37.73 217.29 2671.12' 2945' 37.75 217.43 2701.96' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 1 13.5" HTC MLX-1X 5196654 1x14,3x16/0.7394 120' 3005' 2885' 51.5 1-2-WT-A-E-1-BT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 246.1 @ 2917' 8.6 @ 2853' 50.3 32.87812 FT/HR SURFACE TORQUE 21055 @ 2914' 5050 @ 3002' 12685.6 10992.00000 FT-LBS WEIGHT ON BIT 51 @ 2888' 15 @ 2963' 26.7 21.73938 KLBS ROTARY RPM 71 @ 2856' 66 @ 3001' 69.3 67.00000 RPM PUMP PRESSURE 2670 @ 2914' 2095 @ 2966' 2346.8 2196.00000 PSI DRILLING MUD REPORT DEPTH 3005'/2749' MW 9.9 VIS 47 PV 15 YP 17 Gels 7/15/23 FL 7.9 CL- 450 FC 2/- SOL 10.75 SD 0.15 OIL -/89 MBT 23.75 pH 10.0 Ca+ 10 Alk MWD SUMMARY INTERVAL 120 TO 3005' TOOLS Bit, mudmotor and directional tools laid down, bit graded. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 11 @ 2858' 0 @ 2852' 3.0 TRIP GAS 2 CUTTING GAS 0 @ 3004' 0 @ 3004' 0.0 WIPER GAS 4 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 104436 @ 2858' 2471 @ 2850' 18426.4 CONNECTION GAS_HIGH 0 ETHANE (C-2) 1896 @ 2858' 47 @ 2849' 250.1 CONNECTION GAS_AVG 0 PROPANE (C-3) 84 @ 2963' 0 @ 2978' 2.5 CONNECTION GAS_CURRENT N/A BUTANE (C-4) 50 @ 2963' 0 @ 2978' 1.5 CURRENT BACKGROUND/AVG 0u/3u PENTANE (C-5) 0 @ 3004' 0 @ 3004' 0.0 HYDROCARBON SHOWS minor gas shows associated with coal beds INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sandstone, siltstone, claystone, coal, carbonaceous shale and ash PRESENT LITHOLOGY Beluga formation DAILY ACTIVITY SUMMARY Rotary drilling from 2820’ to TD at 3005’ MD, GPM=640 RPM=70 PSI=2300 WOB=20-25 UP=115 DN=100 ROT=103 ADT=4 JAR HRS= 51.5; Circulate and Condition; CBU X 2 6060 strokes; pump 30bbl HiVis sweep at GPM=640 PSI= 2200 RPM=70 STKS= 7000; TOOH from 3005’ to 776’ SLM out of hole; TIH from 776 to 3005’. Wash down from 2869’ to 3005’; UP WT 115 DN WT 100, no tight spots Circulate and Condition 650GPM 2300PSI; CBU 1X, pump 30bbl 80 Vis walnut sweep around, circulate until shakers clean, 1+ B.U.S.; TOOH from 3005’; UP WT 115 DN WT 100 to BHA; L/D BHA, 3rd party tools, subs and tools; clean floor for trip out; rig up Weatherford to run casing; Run Casing PJSM; M/U 10¾” shoe joint and float. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Winslow DAILY COST $3795 Total (DML $3200/RW $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larr Driskill/Jim Brown DATE Dec 11, 2012 DEPTH 10700' PRESENT OPERATION Expo-well testing on manifold. TIME 23:59:38 YESTERDAY 10700' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' 7" RIH @ 8598' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR2 8 3/4" HCC 506FX 7138043 6x10/0.0902 10700' 10700' 0' 0' 1-1-WT-A-XI-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10700'/9487' MW VIS PV YP Gels FL CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 10700' TO 10700' TOOLS e-line GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS_HIGH 0 ETHANE (C-2) @ @ CONNECTION GAS_AVG 0 PROPANE (C-3) @ @ CONNECTION GAS_CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A - not drilling. PRESENT LITHOLOGY Tyonek formation (Ty9200) DAILY ACTIVITY SUMMARY Test BOPS to 250PSI to 400PSI. Test BOPS blow down kill, choke, and top drive install wear ring. Pressure test casing shoes to 1000PSI for five minutes and test plug in packer. Pull, lay down, and make up tools for BHA. Packer and make up joints for #1. Clean up and prep for packer run while waiting on new packer. Make up RTTS with crossover single in with 6 joints. Run in hole out to derrick. Continue to TIH with 2 7/8”. MOD tubing from 189’-5529’ MD. Change seal rings on TIH. Set RTTS packer @ 5529’ MD. Test back side to 1000PSI. Work wire line and Expo-well testing on manifold. CANRIG PERSONNEL ON BOARD D. Bomar, B. Adams DAILY COST $2945.00 REPORT BY B. Adams Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larr Driskill/Jim Brown DATE Dec 12, 2012 DEPTH 10700' PRESENT OPERATION TESTING THROUGH EXPRO TIME 24:00:00 YESTERDAY 10700' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' 7" RIH @ 8598' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR2 8 3/4" HCC 506FX 7138043 6x10/0.0902 10700' 10700' 0' 0' 1-1-WT-A-XI-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10700'/9487' MW VIS PV YP Gels FL CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 10700' TO 10700' TOOLS e-line GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS_HIGH 0 ETHANE (C-2) @ @ CONNECTION GAS_AVG 0 PROPANE (C-3) @ @ CONNECTION GAS_CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A - not drilling. PRESENT LITHOLOGY Tyonek formation (Ty9200) DAILY ACTIVITY SUMMARY RIG UP EXPRO FLOW TESTERS, AND POLLARD SLICK LINE. PREPARE TO SWAB WELL. RUN SWAB TOOL ON POLLARD SLICK LINE TO 2300 FT. FINISHED SWAB AND PULLED OUT AND RIGGED DOWN. RIGGED UP TO TEST EXRO HARD LINE. TESTED 500psi TO 4000psi. COMPLETED TEST AND RIGGED DOWN. RIGGED UP TO RUN POLLARD SLICK LINE AND PERFERATE CASING. RAN IN HOLE TO 7060 FT. AND BEGAN PERFORATION TO 7074 FT. PULLED OUT OF HOLE WITH SPENT PERFORATION GUNS. PICKED UP LUBRICATOR AND GUNS FOR PERFORATION RUN NUMBER 2. STARTED TO TEST WITH RIG PUMP OFF. TEST FAILED. THE E-LINE AND AND ROPE SOCKET PARTED. LAID DOWN GUN AND LUBRICATOR REHEAD. PICKED UP GUN AND LUBRICATOR. RETEST KEEPING TEST PUMP STAGED UP TO 4000 psi. COMPLETED GOOD TEST. BEGAN PERFERATON RUN NUMBER 2 FROM 7040 FT. ITH RIG PUMP OFF. TEST FAILED. THE E-LINE AND AND ROPE SOCKET PARTED. LAID DOWN GUN AND LUBRICATOR REHEAD. PICKED UP GUN AND LUBRICATOR. RETEST KEEPING TEST PUMP STAGED UP TO 4000 psi. COMPLETED GOOD TEST. BEGAN PERFERATON RUN NUMBER 2 FROM 7040 FT. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2945.00 REPORT BY HARRY E. BLEYS Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larr Driskill/Jim Brown DATE Dec 13, 2012 DEPTH 10700' PRESENT OPERATION PREPARING FOR NEXT PERFORATION RUN. TIME 24:00:00 YESTERDAY 10700' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' 7" RIH @ 8598' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR2 8 3/4" HCC 506FX 7138043 6x10/0.0902 10700' 10700' 0' 0' 1-1-WT-A-XI-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10700'/9487' MW VIS PV YP Gels FL CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 10700' TO 10700' TOOLS e-line GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS_HIGH 0 ETHANE (C-2) @ @ CONNECTION GAS_AVG 0 PROPANE (C-3) @ @ CONNECTION GAS_CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A - not drilling. PRESENT LITHOLOGY Tyonek formation (Ty9200) DAILY ACTIVITY SUMMARY FORMATION TESTING THROUGH EXPRO. RIG MAINTENANCE AND CLEAN RIG. TAKE ON BRINE TO PREP FOR WELL KILL. RIG DOWN EXPRO, CLOSE BAG AND RIG UP TO BULL HEAD. OPEN TO WELL AND CIRCULATE. BLEED OFF AND SHUT IN. SECURE WELL RIG DOWN PUMP AND EXPRO TESTING. RIG UP TO KILL WELL. OPEN BYPASS TO PACKER. STAGE UP PUMPS. SHUT DOWN MONITORS AND PUMP DRY JOB. RIG DOWN PUMP IN SUBS, CROSS OVERS, TOPDRIVE, CHOKE MANIFOLD, AND DRAIN GAS BUSTER. RIG UP WEATHERFORD. TRIP OUT OF HOLE FROM 5529 FT. LAY DOWN BHA AND PLACE IN PIPE SHED. PREPARE AND LOAD GUNS IN SHED FOR NEXT PERFORATION RUN. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2945.00 REPORT BY HARRY E. BLEYS Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larr Driskill/Jim Brown DATE Dec 14, 2012 DEPTH 10700' PRESENT OPERATION PREPARING FOR NEXT PERFORATION RUN. TIME 24:00:00 YESTERDAY 10700' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' 7" RIH @ 8598' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR2 8 3/4" HCC 506FX 7138043 6x10/0.0902 10700' 10700' 0' 0' 1-1-WT-A-XI-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10700'/9487' MW VIS PV YP Gels FL CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 10700' TO 10700' TOOLS e-line GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS_HIGH 0 ETHANE (C-2) @ @ CONNECTION GAS_AVG 0 PROPANE (C-3) @ @ CONNECTION GAS_CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A - not drilling. PRESENT LITHOLOGY Tyonek formation (Ty9200) DAILY ACTIVITY SUMMARY MAKE UP HALLIBURTON GUNS, FIRING HEAD AND RA SUB. RUN IN HOLE FROM 87 FT TO 3785 FT. THAN CONTINUE TO 6999 FT. CHANGE OUT SAVER SUB, GUIDES, DIE BLOCKS. BREAK CONNECTION ON TIW THAN VERIFY TORQUE ON HALLIBURTON HEAD. RIG UP POLLARD E-LINE. RUN IN HOLE TO CORRELATE AND CONFIRM CORRECT DEPTH. FOUND TO BE 7 FT HIGH. PULL OUT OF HOLE AND RIG DOWN WIRE. CHANGE OUT ELEVATORS TO 2 7/8 INCH AND MAKE UP 10. RUN IN HOLE AND SET PACKER AT 6950 FT. TOP. CHANGE ELEVATORS TO 5 INCH AND MAKE UP LINE TO RUN IN HOLE CHECKING DEPTH . AT CORECT DEPTH. PULLED OUT OF HOLE AND RIGGED DOWN WIRE. MAKE UP AND PICK UP FLOW BACK TREE. RIG UP EXPRO WELL TESTERS. TEST SURFACE EQUALY TO 4000 psi. PRESSURE UP BACK SIDE TO 1800 psi. OPEN VALVE BLEED OFF SAM E, AND DROP ROD, TO FIRE GUNS. TESTING EXPRO MONITOR WELL AT SEVERAL INTERVALS NOTING PRESSURE. FINAL PRESSURE 107 PSI AT 22:39 HOURS. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2945.00 REPORT BY HARRY E. BLEYS Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larr Driskill/Jim Brown DATE Dec 15, 2012 DEPTH 10700' PRESENT OPERATION CONTINUING TO PULL OUT OF HOLE. TIME 24:00:00 YESTERDAY 10700' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' 7" RIH @ 8598' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR2 8 3/4" HCC 506FX 7138043 6x10/0.0902 10700' 10700' 0' 0' 1-1-WT-A-XI-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10700'/9487' MW VIS PV YP Gels FL CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 10700' TO 10700' TOOLS e-line GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS_HIGH 0 ETHANE (C-2) @ @ CONNECTION GAS_AVG 0 PROPANE (C-3) @ @ CONNECTION GAS_CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A - not drilling. PRESENT LITHOLOGY Tyonek formation (Ty9200) DAILY ACTIVITY SUMMARY MONITORING WELL BORE AS FLUID RETURNS TO TANK AND FLARING OF GAS. SHUT IN AND AND BLEED OFF EXPRO UNIT. KILL WELL, RIG DOWN HARD LINE AND RELEASE PACKER. CIRCULATE AND CONDITION MUD. SHUT WELL IN , LINE UP AND CIRCULATE BACK UP THROUGH CHOKE AND GAS BUSTER. HOLD BACK PRESSURE AND CIRCULATE AND CONDITION. SHUT PUMPS OF AND BLEED OFF PRESSURE. OPEN RAMS AND MONITOR WELL. CONTINUE TO CIRCULATE THROUGH GAS BUSTER. SHUT DOWN MOITORING WELL. CIRCULATE AND WEIGHT UP TO 8.7 ppg. SHUT DOWN MONITORING AFTER 10 MINUTES. WAIT MONITOR AND WELL STATIC SO PUMP DRY JOB. RIG DOWN TEST TREE. LAY DOWN PIPE IN PIPE SHED. CHANGE OUT ELEVATORS TO 2 7/8 INCH. BLOW DOWN THROUGH CHOKE MANIFOLD, AND TOP DRIVE AND RIG UP WEATHERFORD CASING EQUIPMENT. PULL OUT OF HOLE FROM 7074 FT AND LAY DOWN 10 FT .PUP JOINT. 2 SINGLES IN PIPE SHED. CONTINUE TO PULL OUT OF HOLE. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2945.00 REPORT BY HARRY E. BLEYS Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larr Driskill/Jim Brown DATE Dec 16, 2012 DEPTH 10700' PRESENT OPERATION FINISH TESTING BOP'S AND RIGGING UP TOP DRIVE. TIME 24:00:00 YESTERDAY 10700' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' 7" RIH @ 8598' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR2 8 3/4" HCC 506FX 7138043 6x10/0.0902 10700' 10700' 0' 0' 1-1-WT-A-XI-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10700'/9487' MW VIS PV YP Gels FL CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 10700' TO 10700' TOOLS e-line GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS_HIGH 0 ETHANE (C-2) @ @ CONNECTION GAS_AVG 0 PROPANE (C-3) @ @ CONNECTION GAS_CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A - not drilling. PRESENT LITHOLOGY Tyonek formation (Ty9200) DAILY ACTIVITY SUMMARY WAITING ON THIRD PARTY TOOLS. WAITING ON POLLARD SHOOTING FLANGE. PREPARING CELLAR TO INSTALL. CLEAN AND ORGANIZE RIG. SERVICE TOP DRIVE, CROWN AND HANDLING EQUIPMENT. PICKUP AND MAKE UP DOUBLE FLANGE / SHOOT FLANGE TO HYDRILL. PICKUP AND MAKEUP E-LINE LUBRICATOR, SHEAVES AND BOP'S AS INSTRUCTED BY POLLARD REPRESENTATIVES. MAKEUP AND PICKUP PERFERATION GUNS. TEST LUBRICATOR AND SHOOT FLANGE AT 2600 psi. RUN IN HOLE PERFERATION GUNS ON E-LINE. FIRE SHOTS FROM 6547 FT TO 6575 FT. NO PRESSURE INCREASE. PULL OUT OF HOLE WITH E-LINE AND LAYDOWN GUNS. RUN IN HOLE AND PERFERATE FROM 6528 FT. TO 6548 FT. PULL OUT OF HOLE AND LAY DOWN GUNS. RUN IN HOLE AND FIRE PERFERATION GUNS AT 5707 FTO TO 5714 FT. NO PRESSURE INCREASE. PULL OUT OF HOLE AND LAY DOWN GUNS. MAKE UP NEW PERFERATTION GUNS AND RUN IN HOLE TO 5663 FTO AND PERFERATE TO 5681 FT. PULL OUT OF HOLE AND LAY DOWN GUNS. RIG DOWN POLLARD E-LINE. INSTALL RISER AND FLOWLINE MONITOR WELL. RIG DOWN SHOOTING FLANGE, MAKE UP RISER AND FLOWLINE. PICKUP TEST TOOLS AND MAKE UP JT. PULL WARE RING AND SET TEST PLUG. RIG UP TEST AND FILL STACK AND CHOKE MANIFOLD, THAN PURGE AIR FROM SYSTEM. TEST BOP'S COMPLETE CHOKE MANIFOLD, DART VALVE FROZE. LAY DOWN TEST TOOL. PULL TEST PLUG AND LAY DOWN TEST JOINT AND RIG UP TOP DRIVE. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2945.00 REPORT BY HARRY E. BLEYS Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larr Driskill/Jim Brown DATE Dec 17, 2012 DEPTH 10700' PRESENT OPERATION TESTING UPPE IBOP ON TOP DRIVE. TIME 24:00:00 YESTERDAY 10700' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' 7" RIH @ 8598' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4-RR2 8 3/4" HCC 506FX 7138043 6x10/0.0902 10700' 10700' 0' 0' 1-1-WT-A-XI-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10700'/9487' MW VIS PV YP Gels FL CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL 10700' TO 10700' TOOLS e-line GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS_HIGH 0 ETHANE (C-2) @ @ CONNECTION GAS_AVG 0 PROPANE (C-3) @ @ CONNECTION GAS_CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A - not drilling. PRESENT LITHOLOGY Tyonek formation (Ty9200) DAILY ACTIVITY SUMMARY PICK UP TEST TOOLS AND PULL TEST PLUG. BLOW DOWN 2 7/8 INCH TIW, DART AND XO. MAKE UP 4.5 INCH IF TIW , PORT SUB ON 2 7/8 INCH TEST JOINT. INSTALL TEST PLUG AND REFILL BOP LINES. CLOSE ANNULAR. TEST ANNULAR. ANNULAR FLANGE LEAKS. TORQUE FLANGE DOWN TIGHTER. TEST ANNULAR AND LOWER BLIND RAMS. ATTEMPT TO TEST TOPDRIVE ON FLOOR. TEST FAILED HIGH PRESSURE. PREPARE FOR TEST OF HYDRILL, AND SAVAR SUB. LAYDOWN TEST TOOL AND BLOW DOWN LAYDOWN TEST. PULL TEST PLUG AND INSTALL WEAR BUSHING. BLOW DOWN CHOKE, AND LINES. DRAIN STACK. AND STEAM TOPDRIVE VALVE AND GREASE. FLUID PACK TOPDRIVE. ATTEMPT TO TEST AGAIN. STILL FAILED. SERVICE TOPDRIVE AND BLOW DOWN TESTING EQUIPMENT. BREAK SAVER SUB CLAMPS AND REPLACE HYDRILL IBOP VALVE ON TOPDRIVE. SERVICE TOPDRIVE AND CHANGE OUT SAVER SUB AND REBUILD IBOP. DIAGNOSED TOPDRIVE TIMEING ISSUES AND CORRECTED THEM. TEST BOPS AND ATTEMPTED TO TEST UPPER IBOP ON TOPDRIVE. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2945.00 REPORT BY HARRY E. BLEYS Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larry Driskill/Jim Brown DATE Nov 06, 2012 DEPTH 3005' PRESENT OPERATION cementing TIME 23:59:58 YESTERDAY 3005' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140" 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH N/A (cement) MW VIS PV YP Gels FL CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL TO TOOLS N/A GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 2u CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS_HIGH N/A ETHANE (C-2) @ @ CONNECTION GAS_AVG N/A PROPANE (C-3) @ @ CONNECTION GAS_CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A PRESENT LITHOLOGY Beluga formation DAILY ACTIVITY SUMMARY Run casing PJSM; M/U shoe track; check floats, M/U 10 ¾” casing to 3000’ fill every 5/10 down WT=120 UP= 160 , average; M/U TQ 8500 ft/lbs; rig down Weatherford tools, install circulating head/hoses; circulate and condition, circulate casing volume, 4000 strokes, 45spm; RIG up raised flooring, false table; TIH make up stinger for cementing RIH to 1710'; TIH with nose seal on bottom of 5" D.P. from 1710'; tag up and sting into top of float collar; circulate and condition; R/U circ hose, TIW valve, head pin; circulate and condition, break circulation slowly .75bpm-40psi; stage pumps up slowly to 7bpm-200psi; R/U BJ cement lines; prep for cement job; primary cementing PJSM for cement job; pump 40bbl SAPP pill with red dye with rig primary cementing pump 5 bbls water, Pressure test lines to 3000psi, pump cmt per BJ, 237bbls 12ppg lead, 44bbls 14.8ppg tail; displace with 5 bbls water and 53 bbls mud; check floats-holding circulate/cement/displace drain stack and flush with retarder pill; flush flowline; refill riser with retarder; unsting from float collar; R/B 1 stand; drop wiper dart and pump drill pipe volume to flush D.P..; R/D flow nipple and hose. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Winslow DAILY COST $3795 Total (DML $3200/RW $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larry Driskill/Jim Brown DATE Nov 07, 2012 DEPTH 3005' PRESENT OPERATION N/U/D Diverter TIME 23:59::41 YESTERDAY 3005' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140" 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3005'/2749' MW 9.9 VIS 45 PV 10 YP 6 Gels 3/11/17 FL 10.3 CL- 500 FC 2/- SOL 10.5 SD 0.15 OIL -/90 MBT 23.75 pH 8.4 Ca+ 40 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS_HIGH N/A ETHANE (C-2) @ @ CONNECTION GAS_AVG N/A PROPANE (C-3) @ @ CONNECTION GAS_CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A PRESENT LITHOLOGY Beluga formation DAILY ACTIVITY SUMMARY TOOH; clean up floor rig down cementers; L/D D.P. from 2856’ to 2347, UP= 75K; downtime - drawworks slipped and cut 300 feet of drilling; TOOH from 2347’ to 1234’; L/D/ D.P. from 1234’; L/D nose seal; RIH 2 stands from derrick and L/D; L/D 3rd party tools; clean up and L/D false table, bowl, and slips; nipple up/down diverter system: clean floor, pressure wash diverter, N/D diverter line and knife valve; unflange diverter tee to starting head; P/U stack to cut casing; cut casing; L/D cut joint; set stack back down; N/D bell nipple; N/D annular preventer. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Winslow DAILY COST $3795 Total (DML $3200/ RW $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larry Driskill/Jim Brown DATE Nov 08, 2012 DEPTH 3005' PRESENT OPERATION Load 4" DP TIME 23:59:21 YESTERDAY 3005' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3005'/2749' MW 9.9 VIS 45 PV 10 YP 6 Gels 3/11/17 FL 10.3 CL- 500 FC 2/- SOL 10.5 SD 0.15 OIL /90 MBT 23.75 pH 8.4 Ca+ 40 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS_HIGH N/A ETHANE (C-2) @ @ CONNECTION GAS_AVG N/A PROPANE (C-3) @ @ CONNECTION GAS_CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A PRESENT LITHOLOGY Beluga formation DAILY ACTIVITY SUMMARY N/U/D diverter system, remove diverter T and starter head; clean up well head for welder; bring well head into cellar; welder cut 16" and 10 3/4" to install and weld wellhead; N/U BOPs; N/U single gate, mud X; install 2 7/8x 5 VBR single gate; N/U double gate, annular preventer; install kill and choke HCR and manual valves; C/O pulsation dampener bladder on #2 Mud Pump; clean pits;. backload D.P., load shed w/ 4" D.P. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Winslow DAILY COST $3795 Total (DML $3200/ RW $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larry Driskill/Jim Brown DATE Nov 09, 2012 DEPTH 3005' PRESENT OPERATION Service Rig TIME 23:49:21 YESTERDAY 3005' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75" @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3005'/2749' MW 8.9 VIS 45 PV 10 YP 6 Gels 3/11/17 FL 10.3 CL- 500 FC 2/- SOL 10.5 SD 0.15 OIL -/90 MBT 23.75 pH 8.4 Ca+ 40 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS_HIGH N/A ETHANE (C-2) @ @ CONNECTION GAS_AVG N/A PROPANE (C-3) @ @ CONNECTION GAS_CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A PRESENT LITHOLOGY Beluga formation DAILY ACTIVITY SUMMARY N/U BOPs: plumb in hydraulic lines for upper and shear rams; change upper rams to 4"; pick up double stack and bag, turn mud cross; install choke extension and hose; start torquing BOPs; torque all studs; hook up choke; kill and Koomey lines; install riser and flowline, attempt to install riser, did not fit; L/D same; flowline welder modify riser; service rig: grease crown, blocks, top drive, roughneck; change saver sub to 4" HT38; change gripper, and grease same. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Winslow DAILY COST $3795 Total (DML $3200, RW $595) REPORT BY James Foradas Armstrong Cook Inlet, LLC. DAILY WELLSITE REPORT North Fork Unit 22-35 REPORT FOR Larry Driskill/Jim Brown DATE Nov 10, 2012 DEPTH 3005' PRESENT OPERATION P/U 4" DP from Pipe Shed TIME 23:59:21 YESTERDAY 3005' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 140' 10.75' @ 3000' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3005'/2749 MW 8.8 VIS 43 PV 6 YP 15 Gels 5/5/5 FL 10.2 CL- 30500 FC 1/ SOL 3 SD - OIL -/97 MBT - pH 10.2 Ca+ 65 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS_HIGH N/A ETHANE (C-2) @ @ CONNECTION GAS_AVG N/A PROPANE (C-3) @ @ CONNECTION GAS_CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0/0 PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY N/A PRESENT LITHOLOGY Beluga formation DAILY ACTIVITY SUMMARY Install riser and flowline: welder modifying riser, change out stabbing guide and make up saver sub; install riser and rig up flow line; clean up cellar and draworks area; TIH to 2863’ UP=70 DN= 55; Circulate and Condition; M/U head pin and circ. hose, circ. 3622 BUS, 6bpm, 350psi, 298gpm; R/D head pin and hose blow down same; TOOH from 2863' to surface racking back in derrick, UPW= 65K; cased hole logs: R/U Pollard wire line; start in hole from CBL; OOH R/D Pollard wire line tools; Install/Remove wear bushing; Install W/R OD 103/4" ID 10", change saver sub; P/U 4" DP from shed, to 1056'. CANRIG PERSONNEL ON BOARD Foradas, Dubowski, Franzen, Winslow DAILY COST $3795 Total (DML $3200 / RW $595) REPORT BY James.Foradas
