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Home My WebLink About214-093Nolan Valhovich Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 11/11/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 23 (PTD 214-093) API# 50133206350000 PPROF 10/14/25 Please include current contact information if different from above. 214-093 T41087 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.12 10:20:01 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Ryan Lemay Cc:Donna Ambruz Subject:RE: BCU -23 / PLT - Commingled Production / Verbal Approval for 10 Day Extension to Execute Date:Monday, October 13, 2025 11:45:00 AM Ryan, 10 day extension for PLT was approved by me on 10/10/25. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Lemay <ryan.lemay@hilcorp.com> Sent: Monday, October 13, 2025 10:48 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: BCU -23 / PLT - Commingled Production / Verbal Approval for 10 Day Extension to Execute Good morning Bryan, Following up from our conversation on Friday 10/10/2025. We executed perf adds on this well per the approved attached Sundry up to the Bel 28 perforations from 9/10- 9/15/2025. We monitored production for 2-3 weeks to verify we had sustained production and did not want to continue to add additional sundried perforations before running a PLT. Due to commingled production between the Tyonek and Beluga, we will be required and plan to run a PLT per CO 237D Rule 5 (c). However, due to recent crew and tool availability constraints we may be unable to execute within the 30 day timeframe. On Friday 10/10/25 we discussed this and you provided verbal approval to extend the timeframe to execute the regulatory required PLT up to 10 additional days from the 30 day requirement. Verbal approval for 10 day extension to run PLT received 10/10/25 @ ~13:34 hrs. We should be able to get the PLT executed sometime this week and I will be sure to reach out should we have any additional unforeseen scheduling / tool availability to get this run. Please confirm I’ve understood our conversation correctly and let me know if you have any additional questions. Thank you, Ryan LeMay Operations Engineer Swanson River / Beaver Creek Cell: (661) 487-0871 E-mail: Ryan.lemay@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/02/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251002 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 11A 50133205210100 224123 9/23/2025 YELLOWJACKET PERF T40937 BCU 13 50133205250000 203138 8/18/2025 YELLOWJACKET GPT-PERF T40938 BCU 13 50133205250000 203138 8/26/2025 YELLOWJACKET GPT-PERF T49038 BCU 13 50133205250000 203138 8/21/2025 YELLOWJACKET GPT-PLUG T40938 BCU 23 50133206350000 214093 9/10/2025 YELLOWJACKET PERF T40939 BCU 24 50133206390000 214112 9/16/2025 YELLOWJACKET PLUG-PERF T40940 BRU 212-35T 50283200970000 198161 9/18/2025 AK E-LINE Perf T40941 BRU 224-34T 50283202050000 225044 7/29/2025 AK E-LINE CBP/Punch T40942 BRU 224-34T 50133207170000 225044 9/19/2025 AK E-LINE GPT/Perf T40942 END 1-05 50029216050000 186106 9/25/2025 YELLOWJACKET IPROF T40943 END 2-08 50029217710000 188004 8/11/2025 YELLOWJACKET PERF T40944 END 4-50 50029219400000 189044 9/8/2025 YELLOWJACKET P-PROF T40945 KBU 11-08Z 50133206290000 214044 9/15/2025 AK E-LINE Perf T40946 KU 33-08 50133207180000 224008 7/1/2025 YELLOWJACKET PERF T40947 KU 41-08 50133207170000 224005 8/28/2025 YELLOWJACKET PERF T40948 KU 41-08 50883201990100 224005 9/16/2025 AK E-LINE Perf T40948 MPU R-108 50029238210000 225062 8/14/2025 YELLOWJACKET SCBL T40949 MRU K-06RD2 50733200880200 216131 9/12/2025 AK E-LINE CBL T40950 MRU M-01 50733203880000 187046 9/20/2025 AK E-LINE Perf T40951 MRU M-25 50733203910000 187086 9/21/2025 AK E-LINE Perf T40952 NCIU A-21A 50883201990100 225075 8/21/2025 AK E-LINE CBL T40953 NFU 14-25 50231200350000 210111 9/3/2025 YELLOWJACKET PERF T40954 PBU PTM P1-08A 50029223840100 202199 9/13/2025 YELLOWJACKET SCBL T40955 PBU W-35A 50029217990200 225076 9/17/2025 YELLOWJACKET SCBL T40956 SRU 241-33 50133206630000 217047 9/17/2025 AK E-LINE Perf T40957 SRU 32A-33 50133101640100 191014 9/23/2025 AK E-LINE Perf T40958 SRU 32A-33 50133101640100 191014 9/21/2025 AK E-LINE Perf T40958 Please include current contact information if different from above. BCU 23 50133206350000 214093 9/10/2025 YELLOWJACKET PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.03 09:00:56 -08'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: CTCO, N2 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,141'N/A Casing Collapse Structural Conductor Surface 3,090 psi Intermediate Production 7,460 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan LeMay, Operations Engineer Contact Email:ryan.lemay@hilcorp.com Contact Phone: 661-487-0871 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 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: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: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 FEDA028083 214-093 50-133-20635-00-00 Hilcorp Alaska, LLC Proposed Pools: 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 N/A TVD Burst N/A 10,640 psi 3,360' 80' 3,400' MD 9-5/8" See Attached Schematic 5,750 psi 80'80' 3,400' September 4, 2025 N/A 11,128' Perforation Depth MD (ft): Beaver Creek (BCU) 23CO 237D Same 10,839'5-1/2" ~2,989 psi Beaver Creek Beluga Gas, Tyonek Gas Size See Attached Schematic Swell Pkr; N/A 3,010' MD / 2,985' TVD; N/A 11,128' See Schematic Length 10,852'9,915'9,633' 16" m n P s t 2 N 66 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:22 am, Aug 21, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.08.20 17:23:13 - 08'00' Noel Nocas (4361) 325-496 DSR-8/26/25A.Dewhurst 27AUG25BJM 9/2/25 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.02 16:40:42 -08'00'09/02/25 RBDMS JSB 090425 Well Prognosis Well: BCU-23 Well Name: BCU-23 API Number: 50-133-20635-00 Current Status: Gas Producer Permit to Drill Number: 214-093 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Ryan LeMay (661)487-0871 (M) Second Call Engineer: Scott Warner (907) 830-8863 (M) (907) 564-4506 (O) Maximum Expected BHP: 3895 psi @ 9057’ TVD Based on 0.43 psi/ft Max. Potential Surface Pressure: 2989 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.57 psi/ft using 11.0 ppg EMW LOT at 9-5/8” shoe Shallowest Allowable Perf TVD: MPSP / (0.57 - 0.1) = 2989 psi / 0.47 = 6360’ TVD Top of Applicable Gas Pool / PA: Beluga Gas Pool / PA – 5961’ MD / 5824’ TVD Tyonek Gas Pool / PA – 8979’ MD / 8730’ TVD Well Status: Gas Producer x 415 mcfd / 5 bwpd / 68 psi FTP (As of 8/17/2025) Recent Well Summary: BCU-23 is an active gas producer with multiple sets of open perforations across the Tyonek and Beluga Gas Pools / PAs. This well has commingled production in the Tyonek / Beluga from the LB17 – T3 zones currently. The most recent perforations were added back in 2016 where initial production came on at little over 3mmfcd. Since, the well has slowly declined in gas rate over time. Current production as of 8/17/2025 is 415 mcfd / 5 bwpd / 68 psi FTP. Most recent well work completed on the well was the annual PLT for commingled zones in late June of 2025. PLT analysis showed that roughly 86% of well production was coming from the Beluga zones and 14% of the well production from the Tyonek zones. The objective of this Sundry is to add additional perforations in the Beluga and Tyonek Gas Pools / PAs (Bel 16 – T5). Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low / 3,500 psi high 3. RIH and perforate the following sands: Below are proposed targeted sands in order of testing (bottom/up), but additional sands may be added depending on results of these perfs, between the proposed top and bottom perfs Well Sand Top MD Btm MD Top TVD Btm TVD Interval BCU-23 BEL16 ±7,294’ ±7,308’ ±7,106' ±7,119' ±14' BCU-23 BEL17 ±7,444’ ±7,450’ ±7,250' ±7,256' ±6' BCU-23 BEL18 ±7,470’ ±7,491’ ±7,275' ±7,296' ±21' BCU-23 BEL18 ±7,502’ ±7,508’ ±7,306' ±7312' ±6' BCU-23 BEL18 ±7,512’ ±7,518’ ±7,316' ±7,322' ±6' BCU-23 BEL19 ±7,526’ ±7,532’ ±7,330' ±7,335' ±6' BCU-23 BEL20 ±7,601’ ±7,611’ ±7,402' ±7,412' ±10' Well Prognosis Well: BCU-23 BCU-23 BEL21 ±7,757’ ±7,767’ ±7,553' ±7563' ±10' BCU-23 BEL24 ±7,932’ ±7,945’ ±7,722' ±7,734' ±13' BCU-23 BEL25 ±7,978’ ±7,985’ ±7,766' ±7,773' ±7' BCU-23 BEL26 ±8,064’ ±8,070’ ±7,849' ±7,855' ±6' BCU-23 BEL27 ±8,118’ ±8,128’ ±7,901' ±7,911' ±10' BCU-23 BEL27 ±8,135’ ±8,142’ ±7,917' ±7924' ±7' BCU-23 BEL28 ±8,240’ ±8,247’ ±8,019' ±8,026' ±7' BCU-23 BEL28 ±8,252’ ±8,258’ ±8,030' ±8,036' ±6' BCU-23 BEL28 ±8,261’ ±8,269’ ±8,039' ±8,047' ±8' BCU-23 BEL28L ±8,328’ ±8,339’ ±8,013' ±8,114' ±11' BCU-23 BEL29 ±8,370’ ±8,380’ ±8,144' ±8153' ±10' BCU-23 BEL32 ±8,597’ ±8,604’ ±8,362' ±8,369' ±7' BCU-23 T1X ±8,811’ ±8,817’ ±8,568' ±8,574' ±6' BCU-23 T1X ±8,928’ ±8,935’ ±8,681' ±8,687' ±7' BCU-23 T1 ±8,983’ ±8,987’ ±8,734' ±8,738' ±4' BCU-23 T2 ±9,023’ ±9,027’ ±8,773' ±8,776' ±4' BCU-23 T2 ±9,031’ ±9,036’ ±8,780' ±8,785' ±5' BCU-23 T2 ±9,040’ ±9,042’ ±8,789' ±8,791' ±2' BCU-23 T3 ±9,103’ ±9,112’ ±8,850' ±8,858' ±9' BCU-23 T3 ±9,124’ ±9,126’ ±8,870' ±8,872' ±2' BCU-23 T5 ±9,316’ ±9,319’ ±9,054' ±9,057' ±3' a. Correlate using 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 current or proposed zones produce sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations i. Note: A CIBP may be used instead of WRP if it is determined that no cement is needed for operational purposes. 35ft will not be placed on each plug as these zones are close together. If possible, the CIBP will be set 50’ above of the top of the last perforated sand unless zones are too close together in which case the plug will be set within 50’. f. If necessary, use nitrogen or pad gas throughout operations to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. Perform production log per CO 237D Rule 5(c) – Downhole commingling within 30 days of stabilized flow. 5. RDMO. Well Prognosis Well: BCU-23 Contingency Procedure: Coiled Tubing Cleanout 1. If throughout the job any current or proposed zones produce sand and / or water that cannot be depressed and pushed away with nitrogen or pad gas, a coil tubing unit may be rigged up to clean out fill or fluid blown down as necessary. a. MIRU Fox CTU, PT BOPE to 250 psi low / 3500 psi high i. Provide AOGCC 24hrs notice of BOP test. b. Cleanout wellbore fill and / or blowdown well with nitrogen if necessary. Attachments: 1. Current Schematic 2. Proposed Schematic 3. Coil Tubing BOP Diagram 4. Standard Well Procedure – N2 Operations State/Prov:Alaska Country:USA 160.6' 5/19/2015 11/16/2016 Well Name & Number:Beaver Creek Unit #23 A - 028083 County or Parish:Kenai Peninsula Borough Lease: 16.6º @ 6,955' Date Completed:11/23/2014 Ground Level (above MSL):RKB (above GL): N/A 18.6' Revised By:Joe Kaiser Downhole Revision Date:Schematic Revision Date: 1.0º @ 2,000'Angle/Perfs:Angle @KOP and Depth:Maximum Deviation: BCU - 23 Pad 3 1,125 FNL, 1,715' FWL, Sec. 34, T7N, R10W, S.M. TD: 11,141' MD 10,852' TVD Permit #:214-093 API #:50-133-20635-00 Prop. Des:FED A-028083 KB elevation:179.2' (18.6' AGL) Lat:N60°39' 30.892" Long:W151°1' 1.445" Spud:8/26/2014 02:30 hrs TD:9/14/2014 17:30 hrs Rig Released:9/18/2014 18:00 hrs PBTD: 11,043' MD 10,754' TVD SCHEMATIC 1 Production Casing 5-1/2" P-110 17 ppf CDC Top Bottom MD 0' 802' TVD 0' 802' 5-1/2" P-110 17 ppf GEOCONN Top Bottom MD 802' 11,128' TVD 802' 10,839' 8-1/2" hole Cmt w/ 1,875sks ( 454 bbls) of 15.3 ppg, Class G cmt w/ EASYBLOK Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore Casing/Cementing Detail - 10.9 ppg Mud - 12.5 ppg Mud Push (35 bbl) - 15.3 ppg Cement (454 bbl) - 8.5 ppg 3% KCl (256 bbl) Max Dogleg: 4.76°/100' @ 2,367' Max Inclination: 16.6°@ 6,955' RA Mkr Jt 9,917' RA Mkr Jt 10,611' Casing Shoe @ 11,128' Conductor 16" X-56 109 ppf Top Bottom MD 0' 80' TVD 0' 80' Surface Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 3,400' TVD 0' 3,360' 12-1/4" hole Lead Cmt w/ 598 sks (262 bbls) of 12.0 ppg, Class G, Tail Cmt w/ 198 sks (43 bbls) of 15.4 ppg, Class G, 37 sks (16 bbls) to surface Jewelry 1. Swell Packer (21' Long) 2. 5-1/2" CIBP (8/25/2016) 3. 5-1/2" CIBP (08/19/16) 4. 5-1/2" CIBP (08/08/16) 5. 5-1/2" CIBP (07/28/16) Depth 3,010' 9,950' 10,160' 10,440' 10,725' Perforations: Zone MD TVD Size SPF Date Status LB-17 7,390'-7,400' 7,199'-7,208' 3-1/8" 6 05/19/15 Open LB-18L 7,457'-7,467' 7,263'-7,273' 3-1/8" 6 05/19/15 Open LB-19U 7,540'-7,550' 7,344'-7,353' 3-1/8" 6 05/19/15 Open LB-19L 7,575'-7,585' 7,377'-7,387' 3-1/8" 6 05/19/15 Open LB-20 7,612'-7,622' 7,413'-7,423' 3-1/8" 6 05/19/15 Open LB-21 7,660'-7,670' 7,460'-7,469' 3-1/8" 6 05/18/15 Open LB-22 7,820'-7,860' 7,614'-7,653' 3-1/8" 6 05/02/15 Open LB-23 7,883'-7,893' 7,675'-7,685' 3-1/8" 6 05/02/15 Open LB-28 8,166'-8,182' 7,948'-7,963' 3-1/8" 6 12/11/14 Open LB-28 8,206'-8,232' 7,987'-8,012' 3-1/8" 6 12/11/14 Open LB-28 8,282'-8,301' 8,060'-8,078' 3-1/8" 6 12/11/14 Open LB-29B 8,384'-8,412' 8,158'-8,185 3-1/8" 6 12/10/14 Open LB-30 8,445'-8,455' 8,216'-8,226' 3-1/8" 6 12/10/14 Open LB-30 8,493'-8,503' 8,263'-8,272' 3-1/8" 6 11/23/14 Open LB-31 8,556'-8,566' 8,323'-8,333' 3-1/8" 6 11/23/14 Open M-50 8,646'-8,656' 8,410'-8,419' 3-1/8" 6 11/23/14 Open T-2 9,522'-9,527' 9,253'-9,258' 3-3/8" 6 10/05/16 Open T-2 9,527'-9,537' 9,258'-9,267' 3-1/8" 6 10/19/16 Open T-3 9,673'-9,693' 9,394'-9,429' 3-3/8" 6 08/31/16 Open T-3 9,696'-9,701' 9,394'-9,429' 3-3/8" 6 08/31/16 Open T-5 9,988'-9,993' 9,632'-9,761' 3-3/8" 6 08/19/16 Isolated T-11 10,197'-10,203' 9,893'-9,923' 3-3/8" 6 08/09/16 Isolated T-13 10,454'-10,459' 10,166'-10,171' 3-3/8" 6 07/30/16 Isolated T-19 10,806'-10,811' 10,512'-10,536' 2-1/8" 6 07/21/16 Isolated T-19 10,805'-10,825' 10,512'-10,536' 3-3/8" 6 07/21/16 Isolated Tag (fill) @ 10,920' SLM w/ 2.00" Bailer (2/09/15) TOC (CBL 10/30/14) - 3,052 RA Mkr Jt 6,094' RA Mkr Jt 7,704' XO Jt 802' CDC to GEOCONN M-50 BC-23 OH Log Depths RST Log Depths M50 @ 8,646'-8,656' M50 @ 8,642'-8,652' B31 @ 8,556'-8,566' B31 @ 8,552'-8,562' Fluid Level unknown LB-22 to LB-31 LB-17 to LB-21 T-2 T-3 T-5 T-11 T-13 T-19 TOC 10,690' TOC 10,405'4 5 TOC 10,125' 2 3 TOC 9,915' Proposed Perforations: Well Sand Top MD Btm MD Top TVD Btm TVD Interval BCU-23 BEL16 ±7,294’ ±7,308’ ±7,106' ±7,119' ±14' BCU-23 BEL17 ±7,444’ ±7,450’ ±7,250' ±7,256' ±6' BCU-23 BEL18 ±7,470’ ±7,491’ ±7,275' ±7,296' ±21' BCU-23 BEL18 ±7,502’ ±7,508’ ±7,306' ±7312' ±6' BCU-23 BEL18 ±7,512’ ±7,518’ ±7,316' ±7,322' ±6' BCU-23 BEL19 ±7,526’ ±7,532’ ±7,330' ±7,335' ±6' BCU-23 BEL20 ±7,601’ ±7,611’ ±7,402' ±7,412' ±10' BCU-23 BEL21 ±7,757’ ±7,767’ ±7,553' ±7563' ±10' BCU-23 BEL24 ±7,932’ ±7,945’ ±7,722' ±7,734' ±13' BCU-23 BEL25 ±7,978’ ±7,985’ ±7,766' ±7,773' ±7' BCU-23 BEL26 ±8,064’ ±8,070’ ±7,849' ±7,855' ±6' BCU-23 BEL27 ±8,118’ ±8,128’ ±7,901' ±7,911' ±10' BCU-23 BEL27 ±8,135’ ±8,142’ ±7,917' ±7924' ±7' BCU-23 BEL28 ±8,240’ ±8,247’ ±8,019' ±8,026' ±7' BCU-23 BEL28 ±8,252’ ±8,258’ ±8,030' ±8,036' ±6' BCU-23 BEL28 ±8,261’ ±8,269’ ±8,039' ±8,047' ±8' BCU-23 BEL28L ±8,328’ ±8,339’ ±8,013' ±8,114' ±11' BCU-23 BEL29 ±8,370’ ±8,380’ ±8,144' ±8153' ±10' BCU-23 BEL32 ±8,597’ ±8,604’ ±8,362' ±8,369' ±7' BCU-23 T1X ±8,811’ ±8,817’ ±8,568' ±8,574' ±6' BCU-23 T1X ±8,928’ ±8,935’ ±8,681' ±8,687' ±7' BCU-23 T1 ±8,983’ ±8,987’ ±8,734' ±8,738' ±4' BCU-23 T2 ±9,023’ ±9,027’ ±8,773' ±8,776' ±4' BCU-23 T2 ±9,031’ ±9,036’ ±8,780' ±8,785' ±5' BCU-23 T2 ±9,040’ ±9,042’ ±8,789' ±8,791' ±2' BCU-23 T3 ±9,103’ ±9,112’ ±8,850' ±8,858' ±9' BCU-23 T3 ±9,124’ ±9,126’ ±8,870' ±8,872' ±2' BCU-23 T5 ±9,316’ ±9,319’ ±9,054' ±9,057' ±3' STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 08/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250807 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 23 50133206350000 214093 6/26/2025 AK E-LINE PPROF T40741 BCU 25 50133206440000 214132 7/16/2025 AK E-LINE Plug/Cement T40742 BRU 211-35 50283201890000 223050 6/11/2025 AK E-LINE Perf T40743 BRU 211-35 50283201890000 223050 6/20/2025 AK E-LINE PPROF T40743 BRU 213-26 50283201920000 223069 7/7/2025 AK E-LINE Perf T40744 BRU 213-26T 50283202040000 225038 7/2/2025 AK E-LINE Perf T40745 BRU 213-26T 50283202040000 225038 7/4/2025 AK E-LINE Perf T40745 BRU 213-26T 50283202040000 225038 6/28/2025 AK E-LINE Perf T40745 BRU 241-23 50283201910000 223061 7/18/2025 AK E-LINE Perf T40746 GP 11-13RD 50733200260100 191133 6/2/2025 AK E-LINE PPFROF T40747 KBU 32-06 50133206580000 216137 7/1/2025 AK E-LINE PPROF T40748 MPU E-28 50029232590000 202055 5/8/2025 AK E-LINE Caliper T40749 MPU F-21 50029226940000 196135 7/10/2025 AK E-LINE Caliper T40750 MPU G-02 50029219260000 189028 7/6/2025 AK E-LINE Puncher T40751 MPU I-01 50029220650000 190090 7/7/2025 AK E-LINE TubingPunch T40752 NS-19 50029231220000 202207 6/27/2025 AK E-LINE Perf T40753 PBU J-07C 50029202410300 225026 5/29/2025 BAKER MRPM T40754 PBU N-07B 50029201370200 223122 6/7/2025 BAKER MRPM T40755 PCU-05 50283202030000 225037 7/10/2024 AK E-LINE Perf T40756 TBU D-07RD2 50733201170200 192155 7/19/2025 AK E-LINE Perf T40757 TBU M-09 50733204760000 196127 7/18/2025 AK E-LINE Perf T40758 Please include current contact information if different from above. T40741BCU 23 50133206350000 214093 6/26/2025 AK E-LINE PPROF Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 8/27/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240827 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 23 50133206350000 214093 7/18/2024 AK E-LINE PPROF BRU 222-24 50283201800000 220043 8/8/2024 AK E-LINE Perf BRU 222-26 50283201950000 224035 8/6/2024 AK E-LINE Perf BRU 222-26 50283201950000 224035 7/16/2024 AK E-LINE Perf BRU 241-26 50283201970000 224068 8/12/2024 AK E-LINE Perf BRU 241-34S 50283201980000 224077 8/2/2024 AK E-LINE Perf BRU 241-34S 50283201980000 224077 7/28/2024 HALLIBURTON CAST-CBL IRU 44-36 50283200890000 193022 8/10/2024 AK E-LINE PlugPerf PBU 18-13D 50029217560400 224039 8/2/2024 HALLIBURTON RBT PBU 18-33A 50029225980100 204070 8/13/2024 HALLIBURTON RBT PBU Z-228 50029237180000 222055 7/28/2024 HALLIBURTON PPROF PBU Z-234 50029237620000 223065 7/29/2024 HALLIBURTON IPROF PCU 2 50283200229000 179009 7/9/2024 AK E-LINE TubingCut TBU M-02 50733203890000 187061 8/6/2024 AK E-LINE CBL TBU M-02 50733203890000 187061 8/12/2024 AK E-LINE Perf Please include current contact information if different from above. T39491 T39492 T39493 T39493 T39494 T39495 T39495 T39496 T39497 T39498 T39499 T39500 T39501 T39502 T39502 BCU 23 50133206350000 214093 7/18/2024 AK E-LINE PPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.27 11:27:22 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/28/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230728 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU-23 50133206350000 214093 7/16/2023 HALLIBURTON PPROF BCU-24 50133206390000 214112 7/15/2022 HALLIBURTON PPROF BRU 223-34 50283201880000 223041 7/9/2023 HALLIBURTON RMT3D KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON EPX KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON MFC KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON EPX KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON MFC KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON EPX KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON MFC MPU B-24 50029226420000 196009 7/24/2023 HALLIBURTON WFL-TMD3D MPU B-34 50029235690000 216139 7/23/2023 HALLIBURTON WFL-TMD3D MPU B-50 50029232400000 204252 7/21/2023 HALLIBURTON WFL-TMD3D MPU E-23 50029225700000 195094 6/17/2023 HALLIBURTON COILFLAG MPU F-17 50029228230000 197196 7/2/2023 HALLIBURTON COILFLAG MPU L-13A 50029223350100 223017 6/21/2023 HALLIBURTON COILFLAG MPU L-39B 50029227860200 223037 6/30/2023 HALLIBURTON COILFLAG MPU L-39B 50029227860200 223037 6/30/2023 HALLIBURTON RBT PBU 11-07 50029206870000 181177 6/28/2023 HALLIBURTON RMT3D SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON EPX SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON MFC SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON EPX SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON MFC Please include current contact information if different from above. T37886 T37887 T37888 T37889 T37889 T37890 T37890 T37891 T37891 T37892 T37893 T37894 T37895 T37896 T37897 T37898 T37898 T37899 T37900 T37900 T37901 T37901 BCU-23 50133206350000 214093 7/16/2023 HALLIBURTON PPROF Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.01 10:05:02 -08'00' 21 4093 111 Seth Nolan Hilcorp Alaska, LL GeoTech 3800 Centerpoint Drive, Suite 100 2 0 7 8 3 Anchorage, AK 99503 Tele: 907 777-8308 tti�c,rp:u„wkm,i. .< RECEIVE k Fax: 907 777-8510 ?(j E-mail: snolan@hilcorp.com NOV 1 3 2017 DATA LOGGED t /Ia.1/201"'1 M K BENDER DATE 11/10/17 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 23 scow FEB 0 1 Z018, Prints Prints: Production Profile CD 1: BCU-23 PPROF_08SEPT17 LAS.zip 10/19120172:32 PM Compressed(zippe... 2,524 KB j BCU-23 PPROF 08SEP 17 ProcessedLog.las 10/4/20173:26 PM LAS File 1,298 KB BCU-23 PPROF 08SEP 17 Report.pdf 10/4/20173:26 PM Adobe Acrobat Doc... 1,421KB jur BCU-23 PPROF 08SEPT17.pdf 10/4/20173:26 PM Adobe Acrobat Doc... 3,041 KB i BCU-23 PPROF_08SEPT17_img.tif 10/4/20173:26 PM TIF File 10,302 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: ,e4,4G7)/) i17GV • •th Nolan Hilcorp Alaska, LLC �-1 1'7 GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 �ta,nrp tin.k...1,11 Fax: 907 777-8510 E-mail: snolan@hilcorp.com NOV 2 2 2016 DATE 11/18/16LOG` P ' 0 r+Y' •; NDFP To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 23 SCANNED APR 2 12017 Prints Prints: Production Profile 5" CD : '" BCU-23_PPROF_18SEPT16.pdf 10/26/2016 9:46 AM PDF Document 2,104 KB BCU-23 PPROF_18SEPT16_FIELD_LAS.zip 11/3/2016 10:41 AM Compressed(zippe... 1,556 KB BCU-23_PPROF_18SEPT16_img.tif 10/26/2016 9:46 AM TIF File 7,353 KB BCU-23_PPROF_18SEPT16_Report.pdf 10/26/2016 9:46 AM PDF Document 643 KB BCU-23 PPROF_18SEPT16_Results.las 10/26/2016 9:46 AM LAS File 477 KB Thumbs.db 11/18/2016 2:2D PM Data Base File 25 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: m41.4471.4ea..47) Date: STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMItION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations LI Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate 2 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC lorato❑ment Develo E Exploratory p ry ❑ 214-093 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20635-00 7.Property Designation(Lease Number): 8.Well Name and Number: A028083 Beaver Creek(BCU)23 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Beluga Gas Pool 11.Present Well Condition Summary: Total Depth measured 11,141 feet Plugs measured N/A t 'F true vertical 10,852 feet Junk measured N/A feet .� s '''Y iN O V 16 2016 Effective Depth measured 11,043 feet Packer measured 3,010 feet true vertical 10,754 feet true vertical 2,985 feet AOGCC Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 80' 80' Surface 3,400' 9-5/8" 3,400' 3,360' 5,750 psi 3,090 psi Intermediate Production 11,128' 5-1/2" 11,128' 10,839' 10,640 psi 7,460 psi Liner Perforation depth Measured depth See Attached Schematic '' "j f True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) Swell Pkr;N/A 3,010'MD 2,985'ND N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 229 0 0 211 Subsequent to operation: 0 2996 0 400 1492 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0Exploratory❑ Development❑✓ 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.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-228 Contact Joe Kaiser-777-8393 Email jkaiser@hilcorp.com Printed Name 7.-1/q/4„.- ChahaddAHeHeelllggeson Title Operations Manger Signature / - l�/ Phone 907-777-8405 Date l (eh Form 10-404 Revised 5/2015144 ` /1•2316` RBDMS ,_,,NOVL/ 1 7 201,, Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU-23 E-Line 50-133-20635-00 214-093 7/19/16 10/19/16 Daily Operations: 07/19/2016-Tuesday Obtain PTW. Hold safety meeting. Discuss JSA and talk about job procedure. Lay liner, spot equipment. Rig up CTU 12 with 1.75" CT. 24 Hr. BOPE test witness notification sent 7-18-16 @ 16:05. Witness waived by Jim Regg 7-19-16 @ 14:04 hrs. Start BOPE test. Draw down test complete.Test all Rams and valves to 250/4500 psi. BOPE test complete. Install night cap on BOPE.All ground valves closed. Wellhead secure. SDFN. Location secure crews departed. 07/20/2016-Wednesday Obtain PTW. Hold safety meeting. Review JSA and job procedure. Fire equipment. Pick injector head. make up 10' lubricator. Install BHA. 1.75" Cold roll connector. Pull test 25k. Install DFCV, 2x weight bar, Ball drop Nozzle. BHA OD 2.0" 7.5' long. Stab on well. Pt stack 250/4500 psi. Good PT. Bleed down to 1500 psi. Open master and swab valve. Initial WHP 1600 psi. Crack choke and bleed down. RIH. Cool down N2. Pt N2 lines250/4500 psi. CT wt check at 8100' 25.3K. RIH at 20 ft/min Online down CT with N2 @ 1500 scf/min. 237 psi WHP. WT chk at 10,000' 29k. RIH wt 6k. Fluid returns at surface. RIH lifting well bore fluids. Tagged PBTD at 10996.3' CTMD. (not corrected to RKB). Pick up o 10800'. RIH to confirm tag. Stacked 10k down at 10,996.7'. Blow well dry. 80-86 bbls in return tank. Estimated volume of water from previous E-line analysis was 77 bbls. POOH to surface 8000' strictly N2 at surface. Swap N2 down backside and start pressuring up well bore. Sundry requires 3000 psi . Continue POOH pressure starts breaking over and flat line on graph at about 2300-2450 psi. Look to be injecting N2. At surface. Shut down N2. Shut in well with 2341 psi SITP. Pop off well. Rig down BHA. Start rigging down CTU unit. Demobe and move equipment to Greystone 1. 80-86 bbls returned from well bore. 4000 gallons or 372,000 scf pumped. Crews off location. Well site secure. 07/22/2016- Friday PTW &JSA. Rig up lubricator. Attempt to PT to 4000 psi and well head flange leaked at 3000 psi.Tightened and PT to 250 low and 4000 psi high.TP- 1060 psi. Ran Press/Temp tool and found fluid level at 9920', tagged at 10,911',Tube press—1060 psi, BHP 1885 psi and BHT 165 deg. RIH with 2-1/8"x5' HC, 6 spf, 60 deg phase and tie into Halliburton TCMD log. Run correlation log and send to town. Get ok to perf from 10,806' to 10,811' with 1138 psi on well. Fired gun and did not see pressure change and after looking at the trend on scada looks like we lost about 8 psi. POOH. All shots fired. RIH with 3- 3/8"x20' millennium HC, 6 spf, 60 deg phase and tie into Halliburton TCMD log. Run correlation log and send to town. Get ok to perf from 10,805' to 10,825'. Fired gun with 1048 psi. Lost 4 psi the first 4 min and then started building pressure. Pressure was at 1812 psi after 33 min. POOH all shots fired. RIH with 3-3/8"x20' (loaded with first 4') millennium HC, 6 spf, 60 deg phase and tie into Halliburton TCMD log. Gun set down at 10,815' a few times and also at 10,809'. It was not sticky, it felt pretty hard.TP is at 1966.4 psi. Called town and was told to POOH and rig down. POOH.The gun didn't have any marks on it. Note: if gun was loaded at the bottom 4'we could have perfed it. Rig down lubricator and turn well over to field. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU-23 E-Line 50-133-20635-00 214-093 7/19/16 10/19/16 Daily Operations: 07/28/2016-Thursday PTW &JSA. Rig up lubricator. PT to 250 low and 4,000 psi high.TP- 190 psi. RIH w/4.6" GR/JB and tie into Halliburton perf log.Tool set down at 10,740.9'. Pulled 700 psi over tool weight to get free. POOH. GR had marks on it but figured it was from going thru Beluga perfs since we just set down once. Called town and discussed. Fluid level was close to surface. Filled lubricator as we went in hole. RIH w/Halliburton 4.3" CIBP and tie into Halliburton perf log dated 7-22-16. Run correlation log and send to town. Get ok to set plug at 10,725'. Spotted plug and set at 10,725'. Lost 150 lbs on line wt, picked up 30' and went back and tagged plug. Good set. POOH. RIH w/3" x 40' dump bailer full of cement and tag plug at 10,725'. Pick up 15' and dump bail 17.5' of cement. Lost 50 lbs of line wt. POOH. Good dump. RIH w/3" x 40' dump bailer full of cement and dump bail 17.5' of cement on top of plug (35' of cement total). Lost 60 lbs of line wt. POOH. Good dump. Est TOC at 10,690'. Cement in place at 2015 hrs. Rig down lubricator and secure well. WOC. Approx 200 psi on well. 07/29/2016- Friday Obtain PTW. Hold safety meeting and discuss JSA and job procedure. MIRU SLB CTU 12 with 1.75" CT. 24 HR. BOPE test witness notification sent to state 7/28/16 @ 0946. Witness waived by Jim Regg 7/28/16 @ 0954. Start BOPE test. Test all rams and valves to 250/4,500 psi. Draw down test accumulators. All tests good. BOPE test complete. Install night cap on BOPE. All ground valves closed. Well site secure. Crews off location. SLB headed to Greystone to pick up N2 float and CTU tool trailer. 07/30/2016-Saturday Obtain PTW. Hold safety meeting. Discuss JSA and job procedure. Pick injector head stab 10' lubricator. Make up CC 1.81", 1.75" DFCV, 2 x 1.75" stinger, 1.75" ball drop nozzle. Stab on well. PT stack 250/4,500 psi. Bleed down. Open master swab. 210 psi WHP. RIH. Start seeing fluid returns at 4,000' CTMD. Cool down N2. PT N2 lines to 250/4,500 psi. Come online down CT at 1,500 scf/min @ 5,000' CTMD. Continue IH. Tag TOC @ 10,654' CTMD. Pick up and confirm tag. Blow well dry. 215-218 bbls returned to surface. Continue to blow well dry 800 psi WHP 1,700 psi CT pressure. Only N2 at surface. POOH. Close choke. Isolate CT. Line up down 5.5" casing and bullhead N2 to build pressure. From fluid returns estimated fluid level was at 1,290'. Tagged up at surface 2,236 psi WHP of N2. Close master swab. 370,000 scf pumped. (3,973 gal.) Rig down SLB CTU. Equipment parked to edge of pad. Obtain PTW with Halliburton E-line. MIRU. Stab on well PT stack to 250/4,000 psi. Make up 5' 3.375". Gun loaded with Milennium charges 6 spf and 60* phasing. RIH. Tag TOC. Log OOH at 40 ft/min from 10,646'-10,400'. Send in correlation log to town. Daniel Taylor gave go ahead to perf 1-13 zone from 10,454'-10,459'. Pick up to 10,446.2' (CCL to top shot 7.8') WHP prior to shooting consistently dropping but at 1,438 psi. Fired guns 5 minutes pressure dropped to 1,428 psi. Pressure continues to drop as POOH with E-line. Tagged up at surface. Close master swab. Pop off. All guns confirmed fired. Rig down Halliburton E-line. Turn well over to production. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU-23 E-Line 50-133-20635-00 214-093 7/19/16 10/19/16 Daily Operations: 08/08/2016- Monday PTW/JSA and mobe to pad. Rig up SLB N2 hard lines and PT to 4,500 psi. TP-870 psi. Start pumping N2 2,000 scf/min at 870 psi. Pump quit pumping at 83,800 scf/min at 1,500 psi. Fixed pump and when we opened well back up TP was at 950 psi (1- 1/2 hrs). Started pumping N2 at 1,800 scf/min to 2,000 scf/min from 950 psi to 1,630 psi with at total of 238K scf. Slowed down building pressure from 1,530 psi to 1,630 psi.Shut pump off at 2050 hrs. PTW and JSA(Pollard E-line). Rig up lubricator and pressure test 250 psi low and 4,000 psi high. When we opened well up it was 950 psi on tubing. RIH with 4.2" CIBP and tie into Halliburton OHL. Run correlation log and send to town. Get ok to set plug at 10,440'. Spot plug and TP had bled down to 850 psi when we set plug. Picked up 30' and went back down and tagged plug. POOH. RIH w/4" x 30' cement dump bailer full of cement and tie into Pollard Plug correlation log dated today.Tag plug at 10,440' and dump bail 17.5' of cement on top of plug. POOH. Good dump. While running bailer in hole it acts like fluid level is at 7,580' (LB 19L sand). We lost weight at this depth. RIH w/4" x 30' cement dump bailer full of cement and tie into Pollard Plug correlation log dated today. Dump bail 17.5' of cement on top of plug. POOH. Good Dump. NOTE: Cement in place at 2030 hrs. Est TOC- 10,405'. Rig down lubricator, turn well over to field and will perforate in the morning.TP-850 psi. 08/09/2016-Tuesday PTW and ISA. Rig up lubricator. PT to 250 psi low and 4,000 psi high.TP-958 psi. RIH w/3-3/8" x 6' HC Razor, 6 spf, 60 deg phase and tie into Halliburton OHL. Run correlation log and send to town. Get ok to perf from 10,197' to 10,203'. Fired gun with 958 psi on tubing. Gained 1 psi to 959 psi. POOH. All shots fired and gun was wet. RIH w/GPT tool with bailer(to get water sample) and tie into PESI perf log. Found fluid level at 7,566'. Looks like cooling in the LB-29B (8,384'-8,412') and LB-31 (8,556'-8,566'). Looks like warming effect at the T-11 perfs we just shot.TP-963 psi. Got fluid sample. Rig down lubricator and turn well over to field. 08/18/2016-Thursday PTW and JSA. Rig up lubricator. PT to 250 psi low and 4,000 psi high. .Well was shut in yesterday (8-15-16 at 1037 hrs) and built up to 1,991.86 psi and broke over(8-18-16 at 0238 hrs) and started going down. Pressure was 1,921 psi at 0900 hrs 8-18- 16. RIH w/4.3" CIBP and GPT tool and tie into Halliburton OHL. Run correlation log and GPT log and send to town. Get ok to set plug at 10,160'. Found fluid level at 7,500'. Set plug and picked up 30' and went back down and tagged plug at 10,160'. Had 1,909 psi on tubing. POOH. Everything looked like a good set. Make up 3.5" x 40' bailer and mix cement. RIH w/3.5" x 40' cement dump bailer full of cement and dumped bailed 17.5' of cement on top of plug at 10,160'. POOH good dump. RIH w/ 3.5" x 40' cement dump bailer full of cement and dumped bailed 17.5' of cement on top of plug at 10,160' (35'total). POOH good dump. Cement in place at 1700 hrs. Est TOC at 10,125'. Break down cement bailer.Arm and RIH w/GPT tool, 3-3/8" x 5'millenium HC, 6 spf, 60 deg phase and tie into Halliburton OHL. Found FL at 7,478' with 1,854 psi TP. Run correlation log and send to town. Get ok to perf from 9,988ft-9,993ft. Spot shot and blow well down to 1,500 psi. Fired gun with 1,525 psi on tubing. Pressure was building as we perfed and it did not change the trend. 1,531 psi after five min.The shot shorted out the GPT tool so we did not get any reading after shooting the gun. POOH.All shots fired. Rig down lubricator and turn well over to field. ® • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU-23 E-Line 50-133-20635-00 214-093 7/19/16 10/19/16 Daily Operations: 08/24/2016-Wednesday PTW and JSA. Rig up lubricator. PT to 250 psi low and 4,000 psi high. Well is shut in.TP- 1,662 psi. RIH w/4.65 " EZ Dril CIBP and tie into Halliburton OHL. Run correlation log and send to town. Get ok to set plug at 9,950'. Set plug with 1,655 psi on well. Lost 150 lbs line wt. Picked up 30' and went back down and tagged plug. POOH. Good set. Make up 3-1/2" x 40' dump bailer and mix cement. Make up 3.5" x 40' bailer and RIH w/3.5" x 40' cement dump bailer full of HBL 17#G cement and dumped bailed 17.5' of cement on top of plug at 9,950'. POOH,good dump. RIH w/3.5" x 40' cement dump bailer full of HBL 17#G cement and dumped bailed 17.5' of cement on top of plug at 9,950' (35' total). POOH,good dump. Est TOC-9,915' and cement in place at 1800 hrs. TP- 1,684.6 psi. Rig down lubricator and secure well. WOC. 08/28/2016-Sunday Obtain PTW. Hold safety meeting. Discuss job procedure and scope of work. Review SLB JSA. Discuss mobile crane lift plan. MIRU SLB CTU 12 and associated equipment. 24 Hr BOPE test witness notification sent 8/27/16 @ 10:12 hrs. Test witness waived by Jim Regg on 8/27/16 @ 10:57 hrs. On 8/28/16 at 0330 hrs received and email from state inspector Brian Bixby that he would be at location to witness BOPE test. Fluid pack CT reel with 27.3 bbls of produced water. Start BOPE test.4 fail passes noted during BOPE test. Inside reel valve needed to be greased. #4 valve on choke skid replaced twice and retested for a pass. Choke valve#3 replaced and retested. 2nd set of blind shear rams cycled and retested. BOPE tested all rams and valves to 250/4,000 psi. Accumulator draw down test completed and passed. BOPE test complete. Bleed down. Pop off well. Stack down injector head. Install BOPE night cap. Close are ground valves. Turn well over to production to bleed down gas pressure to system throughout the night. Well site secure. Crews off location. 08/29/2016- Monday Obtain PTW. Hold safety meeting and discuss job procedure. Review SLB JSA. Pick injector head. Stab 10' lubricator. Make up BHA as follows. 1.90" x 1" CC. Pull test CC to 15k. 1.75" DFCV x 12", 1.75" MBT x 42", 1.75" BDJS Nozzle x 7". Total BHA length = 62" or 5.1'. Stab on well. Pt stack to 250/4,000 psi. Online with N2 at 1,500 scf/min for 15 minutes to blow down CT reel from previous day BOPE test. Reel blown down. Waiting to hear from Joe about acceptable BOPE test pressure of 4,000 psi. State accepts lower pressure of 4,000 vs 4,500 psi. Open master and swab. Initial WHP 778 psi. RIH with CT. Perform weight checks every 2000'. Bleeding down initial WHP. Cooling down N2 at 6,500'. Online N2 at 7,000'. Estimated fluid level 7,500'. 1,500 scf/min. Continue IH and tag TOC at 9,911' CTMD. Blow well dry. 70 bbls returned to surface. Returns dry of fluid , only N2. Start POOH to surface. Shut in CT and line up down back side of CT while pumping at 1,500 scf/min. POOH. Notice WHP start to flat line/ break over at 1,300 psi. Continue to POOH while dropping rate fronm 1,500 scf/min to 800 scf/min. WHP maintaining 1,300-1,500 psi injection pressure. 1,000'from surface shut down N2. Tagged up at surface. Shut in master swab and flow line gate valve. SITP 1,356 psi. Bleed down CT. Pop off well. Stack down injector head and BOPE . Move crane to edge of pad to make room for HES. Calculated volume to be expected at surface was 65 bbls. Actual returns to surface were 70 bbls. 313,000 scf pumped or 3,361 gallons. All ground valves closed. Location secure. SDFN. SLB off location. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU-23 E-Line 50-133-20635-00 214-093 7/19/16 10/19/16 Daily Operations: 08/30/2016-Tuesday Obtain PTW. Hold safety meeting and discuss job procedure. MIRU equipment. Stab on well with GPT tool. Pressure test lubricator to 250 low and 4,500 high. Good PT. Bleed down to slop tank. Open well and RIH. Initial WHP 930 psi. Found fluid level at 9,682'. (5.3 bbls of fluid). POOH, send log to town. Decision made to continue with the perforating. POOH to surface. Close master swab. Break down GPT. Make up 5'gun. 3-3/8" Millenuium HMX 60* phasing with 6 SPF. Stab on well. RIH log from 9,850' up to 9,611'. Send correlation log into town. Correlation log from Halliburton open hole log. Town confirms on depth. 7.5' CCL to top shot. Parked at 9,688.5'. Shoot 9,696'-9,701'. 930 psi on wellhead. Pressure slowly climbing. Hard to see on mechanical guage but from POOH to swap guns increase 166psi whp.At surface. Confirm all shots fired. Break down spent gun. Nose cone indicated water inside guns. Make up 20' 3-3/8" Millenium HMX with 60* phasing at 6 spf. Stab on well RIH. Log 2nd interval. Send correlation log into town. Parked at 9,665.5' Puts top shot at 9,673'-9,693'. Town confirms log on depth. Shot fired. WHP 1,106 psi. Pressure climbing to 1,145 psi . Pressure continues to climb as we POOH. At surface SITP 1,417 psi. Close swab. Break off guns. All shots confirmed fired. Spent gun nose cone wet. Rigging down Halliburton E-line, in 30 minutes pressure was still climbing from 1,417psi to 1,498 psi. Crews rigged down. Turn well over to production. 10/04/2016-Tuesday Arrive at office. Obtain PTW. Hold safety meeting and discuss job procedure and scope of work. MIRU E-line. Make up BHA and install 3-3/8 " HSC& 3-1/8" Razor charges (6 spf/60 deg). Stab on well. PT lubricator to 250/4,000 psi. Bleed down to slop tank. RIH, log OOH 500'from 9,750' to 9,250'. Initial WHP 2,293'. Send correlation log to town. Log is on depth. Given permission to shoot. Pick up to 9,513.5' (CCL to top shot 8.5'). Shoot 9,522'to 9,527'. WHP 2,271 psi when shots fired. No notice of increase in WHP after shot. POOH to surface, During the trip OOH to surface WHP increased from 2,271 psi when shot was fired to 2,343 psi when swab was closed. Bleed down lubricator. Pop off well. All shots fired. Bull nose plug below guns are wet. Rig down spent guns and install GPT tool and additional weight bar. RIH with GPT 2'x 5' 1-11/16" WB, 1- 11/16" GPT, 3-1/8" GG for weight BHA to look for cooling and find fluid level. Found fluid level at 9,690'.Start flowing well from 2,353 psi attempting to drop well to 2,200 psi. Log from 9,000'to TD while well is flowing. 2,000 psi fluid level found at 9,690'. Log from 8,900'to TD while well flowing 1,800 psi found fluid level at 9,700'. Log from 9,000' to TD while well flowing at 1,300 psi. Found fluid level at 9,700'. POOH. Pulling out of hole. Turn well over to production an attempt to maintain 3 MCFD. At surface swab closed. RDMO. E-line off location. • • 1:1Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU-23 E-Line 50-133-20635-00 214-093 7/19/16 10/19/16 Daily Operations: 10/19/2016-Wednesday Obtain PTW. Hold safety meeting. Review job procedure. Lay containment RU E-line. Stab on well. PT stack to 250/4,000 psi. Shut in flow line. Prior to shut in well was at 955 psi and 3.2 MCFD (shut in at 0745). RIH with 5' 1-1/16" WB, 7' 2" WB, 1- 11/16" GPT tool. Found solid fluid level at 9,700'. Gas cut fluid was found at 9,350'. POOH.At surface send static GPT log to town. Rig up gun. 3.125"x 10' with 6 SPF razor charges 22.7 grain. Stab on well. RIH, 500' interval. Perf depth 9,527'- 9,537'. CCL to top shot 7.5". CCL depth 9,519.5'. Send correlation log to town. Confirmed log is on depth. Perf 9,527'- 9,537' 2,275 psi. No notice of change in pressure after shooting guns. POOH. At suface. Rig down spent guns. All shots confirmed fired. Gun/bull nose is wet. Make up and RIH with 7'x 2" WT bar, 1-11/16" GPT. 2,350 psi WHP. Perform static log from 8,000'to TD. Send post perf static log to town. Pick up to 8,000'. Start flowing well for 30 minutes. Flow well for 30 minutes. Not to exceed 3.5 MCFD or lower than 1,100 psi.Start logging from 8,000' to TD. Stop log. Looks like fluid level is still at 9,701' with gas cut fluid from 9,350'to 9,701'. POOH to surface. OOH. PESI rigging down. Rigging back up RIH with 7' x 2" WB, 1-11/16" GPT. WHP 1,275 psi. Log from 8,000'to TD with well flowing. Looks like fluid level is still at 9,701'. Send log to town. POOH to surface. Out of hole. RDMO PESI. Turn well over to production to flow test. • ! • f HBCU - 23 Pad3 SCHEMATIC 1,125 FNL, 1,715'FWL, Sec.34, T7N, R10W, S.M. Hilcorp Alaska,LL(: Permit#: 214-093 Conductor API#: 50-133-20635-00 16" X-56 109 ppf '', ti'rA' Top Bottom Prop.Des: FED A-028083MD 0' 80' KB elevation: 179.2' (18.6'AGL) ND 0' 80' Lat: N60° 39' 30.892" Long: W151° 1' 1.445" Spud: 8/26/2014 02:30 hrs XO Jt 802' Surface Casino TD: 9/14/2014 17:30 hrs Bottom CDC to GEOCONN 9-5/8" L-80 ppf BTC Rio Released: 9/18/2014 18:00 hrs Top B MD 0' 3,400' ND 0' 3,360' F„ 1 12-1/4"hole Lead Cmt w/598 sks(262 bbls)of Tree cxn=9-1/2"Otis +'. 12.0 ppg,Class G, Tail Cmt w/198 sks(43 bbls) 8.0"Seal Diameter 0'�' of 15.4 ppg,Class G, 37 sks(16 bbls)to surface 5-1/8"Modified ID Bore 1,; TOC(CBL 10/30/14 -3,052 Production Casing ) 5-1/2" P-110 17 ppf CDC Top Bottom • Casing/Cementing Detail MD 0' 802' - 10.9 ppg Mud ND 0' 802' - 12.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(454 bbl) 5-1/2" P-110 17 ppf GEOCONN- 8.5 ppg 3%KCI(256 bbl) ••RA MkrJt 6,094' Top Bottom MD 802' 11,128' ND 802' 10,839' -4 8-1/2"hole Cmt w/1,875sks(454 bbls)of 15.3 ppg, - LB-17 Class G cmt w/EASYBLOK to LB-21 BC-23 RA MkrJt 7,704' OH Log Depths RST Log Depths I M50 @ 8,646'-8,656' M50 LB-22 @ 8,642'-8,652' to B31 @ 8,556'-8,566' B31 LB-31 = -" M-50 Perforations: Zone MD ND Size SPF Date Status T-2 - LB-17 7,390'-7,400' 7,199'-7,208' 3-1/8" 6 05/19/15 Open LB-18L 7,457'-7,467' 7,263'-7,273' 3-1/8" 6 05/19/15 Open T-3 LB-19U 7,540'-7,550' 7,344'-7,353' 3-1/8" 6 05/19/15 Open LB-19L 7,575'-7,585' 7,377'-7,387' 3-1/8" 6 05/19/15 Open LB-20 7,612'-7,622' 7,413'-7,423' 3-1/8" 6 05/19/15 Open I TOC ••RA MkrJt 9,917' LB-21 7,660'-7,670' 7,460'-7,469' 3-1/8" 6 05/18/15 Open 9,915' LB-22 7,820'-7,860' 7,614'-7,653' 3-1/8" 6 05/02/15 Open LB-23 7,883-7,893' 7,675'-7,685' 3-1/8" 6 05/02/15 Open 2 LB-28 8,166'-8,182' 7,948'-7,963' 3-1/8" 6 12/11/14 Open .. - LB-28 8,206'-8,232' 7,987'-8,012' 3-1/8" 6 12/11/14 Open T-5 LB-28 8,282'-8,301' 8,060'-8,078' 3-1/8" 6 12/11/14 Open TOC LB-29B 8,384'-8,412' 8,158'-8,185 3-1/8" 6 12/10/14 Open 10,125'_41i,, - - 3 LB-30 8,445'-8,455' 8,216'-8,226' 3-1/8" 6 12/10/14 Open T-11 - LB-30 8,493-8,503' 8,263-8,272' 3-1/8" 6 11/23/14 Open Jewelry Depth TOC LB-31 8,556'-8,566' 8,323-8,333' 3-1/8" 6 11/23/14 Open 1.Swell Packer(21'Long) 3,010' 10,405' '; -. '- - 4 M-50 8,646'-8,656' 8,410'-8,419' 3-1/8" 6 11/23/14 Open 2.5-1/2"CIBP(8/25/2016) 9,950' T-13 s - T-2 9,522'-9,527' 9,253-9,258' 3-3/8" 6 10/05/16 Open 3.5-1/2"CIBP(08/19/16) 10,160 : T-2 9,527-9,537' 9,258'-9,267' 3-1/8" 6 10/19/16 Open 4.5-1/2"CIBP(08/08/16) 10,440' • RA MkrJt 10,611' T-3 9,673'-9,693' 9,394'-9,429' 3-3/8" 6 08/31/16 Open 5.5-1/2"CIBP(07/28/16) 10,725' T-3 9,696'-9,701' 9,394'-9,429' 3-3/8" 6 08/31/16 Open TOC .t, __ T-5 9,988'-9,993' 9,632'-9,761' 3-3/8" 6 08/19/16 Isolated 10,690' y WA_ • _ 5 T-11 10,197'-10,203' 9,893-9,923' 3-3/8" 6 08/09/16 Isolated T-19 T Fluid Level T-13 10,454'-10,459'10,166'-10,171' 3-3/8" 6 07/30/16 Isolated unknown T-19 10,806'-10,811'10,512'-10,536' 2-1/8" 6 07/21/16 Isolated T-19 10,805'-10,825'10,512'-10,536' 3-3/8" 6 07/21/16 Isolated • Tag(fill)@ 10,920'SLM Casing Shoe @ 11,128' Max Dogleg: w/2.00"Bailer(2/09/15) - 4.76°/100'@ 2,367' TD: PBTD: 11,141'MD 11,043'MD Max Inclination: 10,852'ND 10,754'ND 16.6°@ 6,955' Well Name&Number: Beaver Creek Unit#23 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:IUSA Angle @KOP and Depth: 1.0°@ 2,000' Angle/Perfs:l N/A Maximum Deviation: 16.6°@ 6,955' Date Completed: 11/23/2014 Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By: Joe Kaiser Downhole Revision Date: 5/19/2015 Schematic Revision Date: 11/16/2016 Seth Nolan Hilcorp Alaska, LLC ?1f GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 Hileurp:Vaxka.LL(: Fax: 907 777-8510 DATA LOGGED E-mail: snolan@hilcorp.comloi14i2oi M.K.BENDER DATE 09/30/16 RECEIVED To: Alaska Oil & Gas Conservation Commission OCT 0 3 2016 Makana Bender Natural Resource Technician 40GCC 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 23 SCOW NOV 0 32016 Mud log data Prints: Perforation Record 5" MD Plug Setting and Perforation Record CD : PERF 30AUG16 9'9/201611:20 riF i File folder i. PLUG 24AUG16 9/M016 11:20 :M File folder j, PLUG-PERF_18AUG16 9.9/201611:21.A.M File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Date: Received")) eceived 8 '% OF nt, • • ywP ��yy s. THE STATE Alaska Oil and Gas F lif2tvih Of A T 1 Conservation Commission __=__;. krut=_ 333 West Seventh Avenue " `— GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 wh Main: 907.279.1433 ®F ALAS*P Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson SCANNED Operations Manager a Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Tyonek Gas Pool, BCU 23 Permit to Drill Number: 214-093 Sundry Number: 316-228 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this / day of May, 2016. RBDMS tdv P"v 1 1 2016 • 0 E 1 V ,L STATE OF ALASKA ' 0 8 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION Dc:-.J S/tl APPLICATION FOR SUNDRY APPROVALS AoGr 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate Q. Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5. Permit to Drill Number: Exploratory ❑ Development 0 214-093 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20635-00 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 237 D Beaver Creek(BCU)23 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ /.S'c ,lk; 9.Property Designation(Lease Number): 10.Field/Pool(s): . A028083 ' Beaver Creek/Beluga Gas,Tyonek Gas Pods - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,141' - 10,852' - 11,043' . 10,754' . 3,639 psi WA N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 80' 80' Surface 3,400' 9-5/8" 3,400' 3,360' 5,750 psi 3,090 psi Intermediate Production 11,128' 5-1/2" 11,128' 10,839' 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Swell Pkr; N/A 3,010'MD/2,985'TVD; N/A 12.Attachments: Proposal Summary ] Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: V-TZ Commencing Operations: a, OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact_ Joe Kaiser-777-8393 Email jkaiser@hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature 4�! ! Phone 907-777-8405 Date (/////�• 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: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No © Subsequent Form Required: /o '`I RBDMS Vv MAY 1 1 2016 APPROVED BY Approved by: 467 ,ay...4.11.4„---- COMMISSIONER THE COMMISSION Date: j- 1746 -ie, Submit Form and Form 10-403 Revised 11/2015 ',Irn�,�Yili is valid for 12 months from the date of approval. Attachments in Duplicate ,6<,--,-V.‘,,,_ (S `r i;:. • • Well Prognosis Well: BCU-23 Hilcorp Alaska,LL Date:4/8/2016 Well Name: BCU-23 API Number: 50-133-20635-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: April 22th, 2016 Rig: N/A Reg.Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-093 First Call Engineer: Joe Kaiser (907) 777-8393 (0) (907) 952-8897 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Maximum Expected BHP: —4,609 psi @ 10,696' TVD (Based on offset well data) Max. Potential Surface Pressure: — 3,639 psi (Based on offset well data with 0.1 ps/ft) Brief Well Summary Beaver Creek Unit#23 was drilled as a grass roots monobore completion in 2014 to target gas sands in the Sterling, Lower Beluga, and Tyonek formations.The initial perforations in the Lower Beluga were made in late November and were non-productive. Perforations were added in the Lower Beluga in December 2014 and - were brought on-line. A perf gun and tool string was lost in the well during the perforating in December 2014, but was fished out successfully in February 2015. Additional perfs were added in early May 2015 with minimal - increase in rate. The purpose of this work/sundry is to add perforations in the Tyonek Zone to increase rate. The proposed intervals are in the proposed Tyonek Gas Pool. A request for unlimited spacing has been filed and is currently pending approval from AOGCC. It is not expected to perforate these intervals until the unlimited spacing is approved by AOGCC. et° .3.m /6 Notes Regarding Wellbore Condition • Well is currently producing at 100-150 mcf/d. • Slickline will have tagged and/or bailed fill prior to E-line rig up. E-line Procedure: 1. MIRU E-line, PT lubricator to 4,000 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 2,300 psi (From gas pressure). 2. RU 3-1/8" 6 spf HC wireline guns. 3. RIH and perforate the following intervals: Zone Sands Top (MD) - Btm (MD) FT SPF Tyonek T-2 9,490'-9,545' 55' 6 Tyonek T-3 9,668'-9,704' 36' 6 Tyonek T-4 9,790'-9,833' 43' 6 Tyonek T-5 9,914'-10,046' 32' 6 Tyonek T-11 10,180'-10,310' 130' 6 • • Well Prognosis Well: BCU-23 Ilii`oru Alaska,LL Date:4/8/2016 Tyonek T-12 10,365'-10,390' 35' 6 Tyonek T-13 10,416'-10,466' 50' 6 Tyonek T-17 10,473'-10,527' 54' 6 Tyonek T-19 10,801'-10,825' 24' 6 a. Bleed tubing pressure as require by Engineer. b. Proposed perfs shown on the proposed schematic in red font. c. Correlate using PNL Log(PNL Tie-in log). d. Use Gamma/CCL/to correlate. 4. RD E-line. 5. Turn well over to production. E-line Procedure(Contingency):If any zone produces sand and/or water. 6. MIRU E-line, PT lubricator to 4,000 psi Hi 250 Low. 7. RIH and set Plug for 5-1/2" casing at depth above zone. 8. RU Bailer assembly. RIH w/assembly . Dump bail sufficient cement to cover plug adequately(+/- 35'). In cases where depth between sands are limited (<10'), only a plug will be set at Engineer's discretion. 9. Continue with Step 6 above. Attachments: 1. Actual Schematic 2. Proposed Schematic • • BCU - 23 ACTUAL Pad 3 1,125 FNL, 1,715'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. Elileorp Alaska. LLC Permit#: 214-093 Conductor API#: 50-133-20635-00 16" X-56 109 ppf Top Bottom Prop.Des: FED A-028083 MD 0' 80' KB elevation: 179.2' (18.6'AGL) TVD 0' 80' Lat: N60° 39' 30.892" Long: W151° 1' 1.445" Spud: 8/26/2014 02:30 his XO Jt 802' Surface Casing TD: 9/14/2014 17:30 his CDC to GEOCONN 9-5/8" L-80 40 ppf BTC RigReleased: 9/18/2014 18:00 hrs T� Bottom MD 0' 3,400' .aettmdsev_,.... TVD 0' 3,360' 1 12-1/4"hole Lead Cmt w/598 sks(262 bbls)of T `=9-1/2"Otis 12.0 ppg,Class G, Tail Cmt w/198 sks(43 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 37 sks(16 bbls)to surface 5-1/8"Modified ID Bore .rte TOC(CBL 10/30/14)-3,052 P5od2ctionP 110 q 17 ppf CDC + Top Bottom Casing/Cementing Detail MD 0' 802' - 10.9 ppg Mud TVD 0' 802' - 12.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(454 bbl) i 5-1/2" P-110 17 ppf GEOCONN - 8.5 ppg 3%KCI(256 bbl) '`RA Mkr Jt 6,094' Top Bottom III MD 802' 11,128' TVD 802' 10,839' . 8-1/2"hole Cmt w/1,875sks(454 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK LB-17 LB-18L -_ BC-23 LB-19U = OH Log Depths LB-19L = M50 @ 8,646'-8,656' LB-20 = B31 @ 8,556'-8,566' LB-21 = B30 @ 8,493'-8,503' I ' `RA MkrJt 7,704' RST Log Depths M50 @ 8,642'-8,652' LB-22 = - 831 @ 8,552'-8,562' LB-23 , B30 @ 8,489'-8,499' LB-28 Perforations: LB-28 = Zone MD TVD Size SPF Date Status LB-28 = LB-17 7,390'-7,400' 7,199'-7,208' 3-1/8" 6 5/19/15 Open LB-18L 7,457'-7,467' 7,265-7,273' 3-1/8" 6 5/19/15 Open LB-19U 7,546-7,550' 7,344'-7,353' 3-1/8" 6 5/19/15 Open LB-29B = LB-19L 7,576-7,585' 7,377'-7,387' 3-1/8" 6 5/19/15 Open LB-20 7,612'-7,622' 7,413'-7,423' 3-1/8" 6 5/19/15 Open LB-30 LB-21 7,665-7,670' 7,466-7,469' 3-1/8" 6 5/18/15 Open LB-22 7,826-7,860' 7,614'-7,653' 3-1/8" 6 5/02/15 Open LB-30 = LB-23 7,886-7,893' 7,675-7,685' 3-1/8" 6 5/02/15 Open Jewelry Depth a LB-28 8,166-8,182' 7,946-7,963' 3-1/8" 6 12/11/14 Open 1.Swell Packer(21'Long) 3,010' LB-31 LB-28 8,206-8,232' 7,987'-8,012' 3-1/8" 6 12/11/14 Open M-50 = LB-28 8,282'-8,301' 8,060'-8,078' 3-1/8" 6 12/11/14 Open LB-298 8,384'-8,412' 8,156-8,185' 3-1/8" 6 12/10/14 Open I 'RA MkrJt 9,917' LB-30 8,445-8,455' 8,216-8,226' 3-1/8" 6 12/10/14 Open LB-30 8,495-8,503' 8,265-8,272' 3-1/8" 6 11/23/14 Open LB-31 8,556-8,566' 8,323'-8,333' 3-1/8" 6 11/23/14 Open • Fluid Level M-50 8,646-8,656' 8,410'-8,419' 3-1/8" 6 11/23/14 Open unknown I `*RA MkrJt 10,611' Tag(fill)@ 10,920'SLM Casing Shoe @ 11,128' Max Dogleg: w/2.00"Bailer(2/09/15) • . 4.76°/100'@ 2,367' TD: PBTD: 11,141'MD 11,043'MD Max Inclination: 10,852'TVD 10,754'TVD 16.6°@ 6,955' Well Name&Number: Beaver Creek Unit#23 Lease:_ A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska - Country:IUSA Angle @KOP and Depth: 1.0°@ 2,000' Angle/Perfs:l N/A Maximum Deviation: 16.6°@ 6,955' Date Completed: 11/23/2014 Ground Level(above MSL): 160.6' _ RKB(above GL): 18.6' _____ Revised By: Stan Porhola Downhole Revision Date: 5/19/2015 Schematic Revision Date: 6/8/2015 • 0 BCU - 23 PROPOSED Pad 3 1,125FNL, 1,715'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. Ililcorp Alaska,LLC Conductor Permit#: 214-093 16" X-56 109 ppf API#: 50-133-20635-001i Bottom Prop.Des: FED A-028083 MD 0' 80' KB elevation: 179.2' (18.6'ADO ND 0' 80' Lat: N60° 39' 30.892" Long: W151° 1' 1.445" Spud: 8/26/2014 02:30 hrs XO Jt 802' Surface Casing TD: 9/14/2014 17:30 hrs CDC to GEOCONN 9-5/8" L-80 40 ppf BTC Rio Released: 9/18/2014 18:00 hrs "::.R Bottom MD 0' 3,400' ND 0' 3,360' ..soshoosos.: ..-"----- 1 12-1/4"hole Lead Cmt w/598 sks(262 bbls)of Tree cxn=9-1/2"Otis''''' , 12.0 ppg,Class G, Tail Cmt w/198 sks(43 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 37 sks(16 bbls)to surface •5-1/8"Modified ID Bore g Production Casing TOC(CBL 10/30/14)-3,052 5-1/2" P-110 17 ppf CDC Top Bottom Casing/Cementing Detail MD 0' 802' - 10.9 ppg Mud ND 0' 802' - 12.5 ppg Mud Push(35 bbl) ppf GEOCONN 1/2" P-110 17 - 15.3 ppg Cement(454 bbl) 5- Top 17 7om 8.5 ppg 3%KCI(256 bbl) RA MkrJt 6,094' MD 802' 11,128' ND 802' 10,839' 8-1/2"hole Cmt w/1,875sks(454 bbls)of 15.3 ppg, LB-17 Class G cmt w/EASYBLOK to LB-21 BC-23 ' ' RA Mkr Jt 7,704' OH Log Depths RST Log Depths M50 @ 8,646'-8,656' M50 @ 8,642'-8,652' LB-22 - B31 @ 8,556'-8,566' B31 @ 8,552'-8,562' to LB-31 = M-50 = I "4 RA Mkr Jt 9,917' Perforations: Zone MD ND Size SPF Date Status LB-17 7,390'-7,400' 7,196-7,208' 3-1/8" 6 5/19/15 Open LB-18L 7,457'-7,467' 7,263'-7,273' 3-1/8" 6 5/19/15 Open LB-19U 7,540'-7,550' 7,344'-7,353' 3-1/8" 6 5/19/15 Open LB-19L 7,576-7,585' 7,377'-7,387' 3-1/8" 6 5/19/15 Open T 2 LB-20 7,612'-7,622' 7,413'-7,423' 3-1/8" 6 5/19/15 Open LB-21 7,660'-7,670' 7,460'-7,469' 3-1/8" 6 5/18/15 Open T-3 LB-22 7,820'-7,860' 7,614'-7,653' 3-1/8" 6 5/02/15 Open LB-23 7,883'-7,893' 7,676-7,685' 3-1/8" 6 5/02/15 Open T-4 LB-28 8,166-8,182' 7,946-7,963' 3-1/8" 6 12/11/14 Open LB-28 8,206-8,232' 7,987'-8,012' 3-1/8" 6 12/11/14 Open T-5 LB-28 8,282'-8,301 8,060'-8,078' 3-1/8" 6 12/11/14 Open T-11 LB-29B 8,384'-8,412' 8,158'-8,185 3-1/8" 6 12/10/14 Open T 12 LB-30 8,445'-8,455' 8,216-8,226' 3-1/8" 6 12/10/14 Open LB-30 8,493'-8,503' 8,263'-8,272' 3-1/8" 6 11/23/14 Open Jewelry Depth T-13 LB-31 8,556-8,566' 8,323'-8,333' 3-1/8" 6 11/23/14 Open 1.Swell Packer(21'Long) 3,010' M-50 8,646-8,656' 8,410'-8,419' 3-1/8" 6 11/23/14 Open T-17 T-2 9,496-9,545' 9,222'-9,275' 3-118" 6 Proposed 1-3 9,668'-9,704' 9,394'-9,429' 3-1/8" 6 Proposed NI "RA MkrJt 10,611' T-4 9,790'-9,833' 9,512'-9,554' 3-1/8" 6 Proposed T-5 9,914'-10,046' 9,632'-9,761' 3-1/8" 6 Proposed T-19 = T-11 10,180'-10,310' 9,896-9,923' 3-1/8" 6 Proposed T-12 10,366-10,390'10,077'-10,102' 3-1/8" 6 Proposed V Fluid Level T-13 10,416-10,466'10,128'-10,178' 3-1/8" 6 Proposed tli^& = unknown T-17 10,473'-10,527'10,186-10,239' 3-1/8" 6 Proposed T-19 10,801'-10,825'10,512'-10,536' 3-1/8" 6 Proposed 4• Tag(fill)@ 10,920'SLM `'-.'',•''• ''- Casing Shoe @ 11,128' Max Dogleg: w/2.00"Bailer(2/09/15) 4.76°/100'@ 2,367' TD: PBTD: 11,141'MD 11,043'MD Max Inclination: 10,852'ND 10,754'ND 16.6°@ 6,955' Well Name&Number:_ Beaver Creek Unit#23 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: Angle @KOP and Depth: 1.0°@ 2,000' Angle/Perfs:I N/A Maximum Deviation: 16.6°@ 6,955' Date Completed: 11/23/2014 Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By: J.Kaiser Downhole Revision Date: 5/19/2015 Schematic Revision Date: 4/8/2016 STATE OF ALASKA i KA OIL AND GAS CONSERVATION COM ION �1 Ed f; GAS WELL OPEN FLOW POTENTIAL TEST REPORT, -i,--, --_, _ la.Test: U Initial U Annual U Special lb.Type Test: ❑Stabilized U Non Stabilized' ]Multipoint p Constant Time ❑Isochronal E Other: Nodal 2.Operator Name: 5.Date Completed: 11.Permit to Drill Number: Hilcorp Alaska,LLC 11/23/2014 214-093 3.Address: 6.Date TD Reached. 12.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 9/14/2014 50-133-20635-00 4a.Location of Well(Governmental Section): 7.KB Elevation above MSL(feet): 13.Well Name and Number: Surface. 1125'FNL,1715'FWL,Sec 34,T7N,R1 OW,SM,AK 179.2 Beaver Creek(BCU)23 Top of Productive Horizon: 8.Plug Back Depth(MD+TVD): 14.Field/Pool(s): 1439'FNL,2457'FWL,Sec 34,T7N,R1OW,SM,AK 11,043'MD/10,754'TVD Total Depth: 9.Total Depth(MD+TVD): Beaver Creek/Beluga Gas 1953'FNL,1565'FEL,Sec 34,T7N,R10W,SM,AK 11,141'MD/10,852'TVD 4b.Location of Well(State Base Plane Coordinates NAD 27): 10.Land Use Permit: 15.Property Designation: Surface: x- 317534 34 y-2434057 1 Zone- 4 N/A A028083 TPI: x- 318272.5 y-2433731.4 Zone- 4 16.Type of Completion(Describe): Total Depth: x- 319521.49 y-2433198.54 Zone- 4 5-1/2"Production String,Perforated 17.Casing Size Weight per foot,lb. I.D.in inches Set at ft. 19.Perforations: From To 5-1/2" 17 4,892" 11,128 7,390'-7,400' 8,166'-8,182' 18.Tubing Size Weight per foot,lb. I.D in inches Set at ft. 7,457'-7,467' 8,20W-8,232' 7,540'-7,550' 8,282'-8,301' N/A 7,575'-7,585' 8,384'-8,412' 7,612'-7,622' 8,445'-8,455' 7,660'-7,670' 8,493'-8,503' .; W.I.ANNE° 7,820'-7,860' 8,556'-8,566' 7,883'-7,893' 8,646'-8,656' 20.Packer set at ft: 21.GOR cf/bbl: 22.API Liquid Hydrocardbons: 23.Specific Gravity Flowing Fluid(G): N/A N/A N/A 0.57 24a.Producing through: 24b.Reservoir Temp: 24c.Reservoir Pressure: 24d.Barometric Pressure(Pa): ❑Tubing Q Casing 130 F° 1,969 psia©Datum 8,084 TVDSS psia 25.Length of Flow Channel(L): Vertical Depth(H): Gg: %CO2: %N2: %H2S: Prover: Meter Run: Taps: 0.57 0 0 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice Size(in.) Size(in.) psig Hw F° psig F° psig F° Hr. 1. X - 2. X 3. X 4. X 5. X Basic Coefficient Flow Temp. Super Comp. No. (24-Hour) hwPm Pressure Gravity Factor Rate of Flow Fb or Fp Pm Factor Fg Factor Q1 Mcfd 1. 2. 3. 4. 5. Temperature for Separator for Flowing No. PrT Tr z Gas Fluid Gg G 1 2. 3. Critical Pressure 4. Critical Temperature 5. Form 10-421 Rev. 7/2009 CONTINUED ON REVERSE SR8DMS iHUS 2 6 2015 Submit in Duplicate Pc Pc2 'f Pf2 No. Pt Pte Pc2-Pt2 Pw Pw2 Pc2-Pw2 Ps Ps2 Pf2-Ps2 1. 2. 3. 4. 5. 25. b AOF (Mcfd) 2 Co O Remarks: The BCU 23 is a low rate gas well flowing at high drawdown(>90%). Due to the low rates&high drawdown,we were unable to accurately measure 3 additional gas rates below the 266 Mcfd test rate. The AOF was calculated with nodal analysis utilizing flowing and SI buildup data. The attached report from Prosper summarizes the matched IPR/VLP system. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed i Title Reservoir Engineer Date Z 3�� DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfd/ - hwPm Fp Basic critical flow prover or positive choke factor Mcfd/psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air=1.000), dimensionless Gg Specific gravity of separator gas(air=1.00), dimensionless GOR Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet(TVD) L Length of flow channel, feet(MD) n Exponent(slope) of back-pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia Pf Shut-in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back-Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. 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AL,,„ KA OIL AND GAS CONSERVATION COL aSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LI Plug Perforations Li Fracture Stimulate U Pull Tubing Li Operations shutdown U Performed: Suspend ❑ Perforate ElOther Stimulate El Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well El Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development [] Exploratory ❑ 214-093 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20635-00 7.Property Designation(Lease Number): 8.Well Name and Number: A028083 Beaver Creek(BCU)23 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Beluga Gas Pool 11.Present Well Condition Summary: Total Depth measured 11,141 feet Plugs measured N/A f `, true vertical 10,852 feet Junk measured N/A f E D E 1 M D Effective Depth measured 11,043 feet Packer measured 3,010 feet J U N 1 2 2015 true vertical 10,754 feet true vertical 2,985 feet AOGCC Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16” 80' 80' Surface 3,400' 9-5/8" 3,400' 3,360' 5,750 psi 3,090 psi Intermediate Production 11,128' 5-1/2" 11,128' 10,839' 10,640 psi 7,460 psi Liner Perforation depth Measured depth See Attached Schematic SCANNED I U L 0 9 -'D True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) Swell Pkr;N/A 3,010'MD 2,985'ND N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data 011-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 216 0 0 155 • Subsequent to operation: 0 235 0 0 368 14.Attachments(required per 20 AAC 25 070,25 071,E.25 283) 15.Well Class after work: Daily Report of Well Operations ❑., Exploratory Development[] Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas [] WDSPL❑ Printed and Electronic Fracture Stimulation Data El GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP El SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-272 Contact Stan Porhola Email sporholaa.hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature _,‘I-D1_,..— Phone 907-777-8412 Date 6 (2.115-L 15- RBDMS JUN 2 5 2015 Form 10-404 Revised 5/2015 �� S Submit Original Only Y:dif& 71e� • il Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-23 50-133-20635-00 214-093 5/18/15 5/19/15 Daily Operations: 05/18/2015- Monday PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 3,000 psi high. RIH w/3-3/8" x 10' (Loaded w/3- 1/8" charges) HC Connex, 6 spf, 60 deg perf gun and tie into PNL log dated 10-29-14. Run correlation log and send to town. Get ok to perf from 7,660'to 7,670'. Spot gun.Tubing pressure 326 psi. Fired gun. Pressure was 342 psi after 5 min and 366 psi after 10 min. POOH, FL-2,030'. Rig for stand by. Turn well over to field. Will be back in AM to finish perf job. TP-425 psi. 05/19/2015-Tuesday PTW and JSA. Rig lubricator back up. PT to 250 psi low and 3,000 psi high. RIH w/3-3/8" x 10' (loaded w/3-1/8" charges) HC Connex, 6 spf, 60 deg perf gun and tie into PNL log dated 10-29-14. Run correlation log and send to town. Get ok to perf from _7,612 to 7,622' (LB-20).Spot gun. Tubing pressure 770 psi. Fired gun. Pressure went to 775 psi after 5 min and 787 psi after i 10 min. 798 psi out of well. POOH, FL-could not determine. RIH w/3-3/8" x 10' (loaded w/3-1/8" charges) HC Connex, 6 spf, 60 deg perf gun and tie into PNL log dated 10-29-14. Run correlation log and send to town. Get ok to perf from 7,575'to 17,585' (LB-19L).Spot gun.Tubing pressure 864 psi. Fired gun. Pressure went to 867.5 psi after 5 min. POOH, 884 psi out of hole. FL-could not determine. RIH w/3-3/8" x 10' (loaded w/3-1/8" charges) HC Connex, 6 spf, 60 deg perf gun and tie into PNL log dated 10-29-14. Run correlation log and send to town. Get ok to perf from 7,540'to 7,550' (LB-19U). Spot gun. Bleed tubing to 755 psi. Fired gun. Pressure went to 765 psi after 5 min. POOH, 860 psi out of hole. FL-could not determine. RIH w/3-3/8" x 10' (loaded w/3-1/8" charges) HC Connex, 6 spf, 60 deg perf gun and tie into PNL log dated 10-29-14. Run correlation log and send to town. Get ok to perf from 7,457' to 7,467' (LB-18L). Spot gun. Bleed tubing to 768 psi. Fired gun. Pressure went to 775 psi after 5 min. POOH, 805 psi out of hole. FL-could not determine. RIH w/3-3/8" x 10' (loaded w/3- 1/8" charges) HC Connex, 6 spf, 60 deg perf gun and tie into PNL log dated 10-29-14. Run correlation log and send to town. Get ok to perf from 7,390' to 7,400' (LB-17). Spot gun. Bleed tubing to 755 psi. Fired gun. Pressure went to 765 psi after 5 min. POOH, 821 psi out of hole. FL-could not determine. Rig down lubricator and turn well over to field. BCU - 23 ACTUAL Pad 3 1,125FNL, 1,715'FWL, SCHEMATIC Sec. 34, T7N, R10W, S.M. IIikorp Alaska. 1.1A: Permit#: 214-093 Conductor 16" X-56 109 ppf API#: 50-133-20635-00 , ' Top Bottom Prop.Des: FED A-028083 MD 0' 80' KB elevation: 179.2' (18.6'AGL) TVD 0' 80' Lat: N60° 39' 30.892" Long: W151° 1' 1.445" Spud: 8/26/2014 02:30 hrs XO Jt 802' Surface Casinq TD: 9/14/2014 17:30 hrs ,, CDC to GEOCONN 9-5/8" L-80 Bottom ppf BTC Rio Released: 9/18/2014 18:00 hrs Top B MD 0' 3,400' ND 0' 3,360' 1 12-1/4"hole Lead Cmt w/598 sks(262 bbls)of Tree cxn=9-1/2"Otis • 12.0 ppg,Class G, Tail Cmt w/198 sks(43 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 37 sks(16 bbls)to surface 5-1/8"Modified ID Bore .:V Production Casing TOC(CBL 10/30/14)-3,052 5-1/2" P-110 17 ppf CDC s a Top Bottom tg MD 0' 802' Casino/Cementing Detail - 10.9 ppg Mud ND 0' 802' - 12.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(454 bbl) ii 5-1/2" P-110 17 ppf GEOCONN - 8.5 ppg 3%KCI(256 bbl) •`RA Mkr Jt 6,094' Top Bottom 111 MD 802' 11,128' ND 802' 10,839' t.,� 8-1/2"hole Cmt w/1,875sks(454 bbls)of 15.3 ppg, " Class G cmt w/EASYBLOK LB-17 -' LB-18L BC-23 LB-19U = OH Log Depths LB-19L = M50 @ 8,646'-8,656' LB-20 831 @ 8,556'-8,566' LB-21 _ B30 @ 8,493'-8,503' ' • •`RA MkrJt 7,704' RST Log Depths M50 @ 8,642'-8,652' LB-22 = B31 @ 8,552'-8,562' LB-23 = 830 @ 8,489'-8,499' LB-28 LB-28 Perforations; Zone MD ND Size SPF Date Status LB-28 LB-17 7,390'-7,400' 7,196-7,208' 3-1/8" 6 5/19/15 Open LB-18L 7,457'-7,467' 7,263-7,273' 3-1/8" 6 5/19/15 Open LB-19U 7,540'-7,550' 7,344'-7,353' 3-1/8" 6 5/19/15 Open LB-29B LB-19L 7,576-7,585' 7,377'-7,387' 3-1/8" 6 5/19/15 Open LB-20 7,617-7,622' 7,413-7,423' 3-1/8" 6 5/19/15 Open LB-30 LB-21 7,666-7,670' 7,466-7,469' 3-1/8" 6 5/18/15 Open LB-22 7,820'-7,860' 7,614'-7,653' 3-1/8" 6 5/02/15 Open LB-30 = LB-23 7,883-7,893' 7,676-7,685' 3-1/8" 6 5/02/15 Open Jewelry Depth LB-28 8,166-8,182' 7,948'-7,963' 3-1/8" 6 12/11/14 Open 1 Swell Packer(21'Long) 3,010' LB-31 LB-28 8,206-8,232' 7,987'-8,012' 3-1/8" 6 12/11/14 Open M-50 = LB-28 8,282'-8,301' 8,060'-8,078' 3-1/8" 6 12/11/14 Open LB-29B 8,384'-8,412' 8,156-8,185' 3-1/8" 6 12/10/14 Open ' a RA MkrJt 9,917' LB-30 8,446-8,455' 8,216-8,226' 3-1/8" 6 12/10/14 Open LB-30 8,493-8,503' 8,263-8,272' 3-1/8" 6 11/23/14 Open LB-31 8,556-8,566' 8,323-8,333' 3-1/8" 6 11/23/14 Open • Fluid Level M-50 8,646-8,656' 8,410'-8,419' 3-1/8" 6 11/23/14 Open unknown I44 RA MkrJt 10,611' Tag(fill)@ 10,920'SLM ------"1 +4 Casing Shoe @ 11,128' Max Dogleg: w/2.00"Bailer(2/09/15) - 4.76°/100'@ 2,367' TD: PBTD: 11,141'MD 11,043'MD Max Inclination: 10,852'ND 10,754'ND 16.6°@ 6,955' Well Name&Number: Beaver Creek Unit#23 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov. Alaska Country:IUSA •Angle @KOP and Depth: 1.0°@ 2,000' Angle/Perfs:I N/A Maximum Deviation: 16.6°@ 6,955' Date Completed: 11/23/2014 Ground Level(above MSL). 160.6' _ RKB(above GL) 18.6' Revised By: Stan Porhola Downhole Revision Date 5/19/2015 Schematic Revision Date: 6/8/2015 of i w\�\ s THE STATE Alaska Oil and Gas OfA A S KA Conservation Commission " } _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main. 907.279 1433 oFALA.S* Fax• 907.276.7542 SCANNED MAY 1 4 2.1315 www.aogcc.alaska.gov Stan Porhola Operations Engineer ' 1 / _ N3 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek(BCU) 23 Sundry Number: 315-272 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this 2day of May, 2015 Encl. IVSD • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MA'Y 0 5 '11.. APPLICATION FOR SUNDRY APPROVALS 0 3_5 5/72/5 20 MC 25.280 AO G C C 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Well Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate 2 • Pull Tubing❑ Time Extension❑ Operations Shutdovn❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development 0 • 214-093 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20635-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 237A • Beaver Creek(BCU)23 Will planned perforations require a spacing exception? Yes ❑ No 0❑ • 9.Property Designation(Lease Number): 10.Field/Pool(s): A028083 • Beaver Creek/Beluga Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,141 ' 10,852 " 11,043 10,754 N/A WA Casing Length Size MD 7VD Burst Collapse Structural Conductor r 80' 16" 80' 80' Surface 3,400' 9-5/8" 3,400' 3,360' 5,750 psi 3,090 psi Intermediate Production 11,128' 5-1/2" 11,128' 10,839' 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A WA N/A Packers and SSSV Type: Packers and SSSV MD(t)and TVD(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development❑ •Service n 14.Estimated Date for 15.Well Status after propnsed work: 05/13/15 Commencing Operations: Oil ❑ Gas ❑✓ , WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phane: 907-777-8412 Email SDorhola(d hilcorD.corrl Printed Name Stan Porhola Title Operations Engineer Signature 'I7"k, ,pc Phone 907-777-8412 Date 5/0 S/I 5 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 315 - 2-r2 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: i U - '1.1-'1 APPROVED BY Approved by: ,4...... COMMISSIONER THE COMMISSION Date: J/ 7—/ Sr.'J 3ks i (-- C7-6-, S /SSubmit Form and Form 10-403(Revised 10/2012) OpRvid6plictfignisfacign4minVrom the date of a rov I- Attachments in Duplicate DMMAY 1 1 10; f//--- • . Well Prognosis Well: BCU-23 llllcorp Alaska,LLI Date:5/05/2015 Well Name: BCU-23 API Number: 50-133-20635-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: May 13th, 2015 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-093 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228(M) Second Call Engineer: Chad Helgeson (907) 777-8405(0) (907)229-4824(M) AFE Number: Current Bottom Hole Pressure: —2,700 psi @ 8,410' TVD (Based on existing perfs) Maximum Expected BHP: —2,700 psi @ 8,410' TVD (Based on existing perfs) Max. Allowable Surface Pressure: — 1,859 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#23 was drilled as a Grass roots monobore completion in 2014 to target gas sands in the Sterling, Lower Beluga,and Tyonek formations.The initial perforations in the Lower Beluga were made in late November and were non-productive. Perforations were added in the Lower Beluga in December 2014 and were brought on-line.A perf gun and tool string was lost in the well during the perforating in December 2014, but was fished out successfully in February 2015.Additional perfs were added in early May 2015 adding the LB- 22 and LB-23 with minimal increase in rate. The purpose of this work/sundry is to add perforations in the Lower Beluga to increase rate. Notes Regarding Wellbore Condition • Well is currently producing at 240 mcf/d. • Current fluid level is unknown, but is suspected to be below the existing perfs. E-line Procedure: 1. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 9.5"OTIS. b. SITP will be 800 psi (Form gas pressure). 2. RU 3-1/8" 6 spf Connex HC wireline guns. 3. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT SPF Lower Beluga LB-17 7,390' 7,400' 10' 6 Lower Beluga LB-18L 7,457' 7,467' 10' 6 • Lower Beluga LB-19U 7,540' 7,550' 10' 6 • Lower Beluga LB-19L 7,575' 7,585' 10' 6 Lower Beluga LB-20 7,612' 7,622' 10' 6 Lower Beluga LB-21 7,660' 7,670' 10' 6 a. Bleed tubing pressure to 800 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. Well Prognosis Well: BCU-23 Hilcorp Alaska,LL Date:5/05/2015 c. Correlate using PNL Log dated 10/29/14(PNL Tie-in log). d. Use Gamma/CCL/to correlate. Utilize Press/Temp tool if available. e. Record tubing pressures before and after each perforating run. f. Proposed intervals are in the Beluga Gas Pool. g. Distance to nearest well open in same sands=875'to BCU-13. h. Spacing allowance is based on CO 237A, no restrictions in Beluga Gas Pool. 4. RD E-line. 5. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic .. BCU - 23 ACTUAL Pad 3 1,125 FNL, 1,715'FWL, SCHEMATIC Sec.34, TiN, R10W, S.M- IIiIc•orp Alaska. I.1A: Permit#: 214-093 16"Conductor-56 109 ppf X API#: 50-133-20635-00Top Bottom Prop.Des: FED A-028083 MD 0' 80' KB elevation: 179.2' (18.6'AGL) TVD 0' 80' Lat: N60° 39' 30.892" Long: W151° 1' 1.445" Spud: 8/26/2014 02:30 hrs XO Jt 802' Surface Casinq TD: 9/14/2014 17:30 hrs , CDC to GEOCONN 9.5/8" L-80 40 ppf BTC Rig Released: 9/18/2014 18:00 hrsTop Bottom MD 0' 3,400' ND 0' 3,360' 1 12-1/4"hole Lead Cmt wl 598 sks(262 bbls)of Tree cxn=9-112"Otis ' 12.0 ppg,Class G, Tail Cmt wl 198 sks(43 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 37 sks(16 bbls)to surface 5-1/8"Modified ID Bore Production Casinq TOC(CBL 10/30/14)•3,052 5-1/2" P-110 17 ppf CDC Top Bottom Casinq/Cementing Detail ,- MD 0' 802' - 10.9 ppg Mud • ND 0' 802' - 12.5 ppg Mud Push(35 bbl) 5-1/2" P-110 17 ppf GEOCONN - 15.3 ppg Cement(454 bbl) Top Bottom 8.5 ppg 3%KCI(256 bbl) RA Mkr Jt 6,094' MD 802' 11,128' ND 802' 10,839' 8-1/2"hole Cmt w/1,875sks(454 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK BC-23 ' OH Log Depths RA Mkr Jt 7,704' M50 @ 8,646'-8,656' ,i 1'B31 @ 8,556'-8,566' B30 @ 8,493'-8,503' RST Log Depths M50 @ 8,642'-8,652' LB-22 = - B31 @ 8,552'-8,562' LB-23 = B30 @ 8,489'-8,499' LB-28 = LB 28 • Perforations: Zone MD ND Size SPF Date Status LB-28 = LB-22 7,826-7,860' 7,614'-7,653' 3-1/8" 6 5/02/15 Open LB-23 7,886-7,893' 7,675-7,685' 3-1/8" 6 5/02/15 Open LB-28 8,166-8,182' 7,946-7,963' 3-1/8" 6 12/11/14 Open LB-29B LB-28 8,206-8,232' 7,987'-8,012' 3-1/8" 6 12/11/14 Open LB-28 8,282'-8,301' 8,066-8,078' 3-1/8" 6 12/11/14 Open LB-30 LB-29B 8,384'-8,412' 8,158'-8,185' 3-1/8" 6 12/10/14 Open LB-30 8,445-8,455' 8,216-8,226' 3-1/8" 6 12/10/14 Open LB-30 = LB-30 8,493-8,503' 8,263'-8,272' 3-1/8" 6 11/23/14 Open Jewelry Depth LB-31 8,556-8,566' 8,323'-8,333' 3-1/8" 6 11/23/14 Open 1.Swell Packer(21'Long) 3,010' LB-31 = M-50 8,646-8,656' 8,410'-8,419' 3-1/8" 6 11/23/14 Open M-50 44 7RA MkrJt 9,917' Fluid Level unknown I ' RA Mkr Jt 10,611' Tag(fill)@ 10,920'SLMr.- Casing Shoe @ 11,128' Max Dogleg: w/2.00"Bailer(2/09/15) °, :..- 4.76°/100'@ 2,367' TD: PBTD: 11,141'MD 11,043'MD Max Inclination: 10,852'ND 10,754'ND 16.6°@ 6,955' Well Name&Number. Beaver Creek Unit#23 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:I USA Angle @KOP and Depth. 1.0°@ 2,000' Angle/Perfs.I N/A Maximum Deviation: 16.6°@ 6,955' Date Completed: 11/23/2014 Ground Level(above MSL): 160.6' RKB(above GL):_ 18.6' Revised By: Stan Porhola Downhole Revision Date: 5/2/2015 Schematic Revision Date: 5/5/2015 • , . BCU - 23 PROPOSED Pad 3 1,125 FNL, 1,715'FWL, SCHEMATIC Sec. 34, T7N, R10W, S.M. • Ilileorp Alaska. LLA. • Conductor Permit#: 214-093 109 API#: 50-133-20635-00 16 Top Bottom f Prop.Des: FED A-028083 :.: ' L MD 0' 80' KB elevation: 179.2' (18.6'AGL) TVD 0' 80' Lat: N60° 39' 30.892" Long: W151° 1' 1.445" Spud: 8/26/2014 02:30 hrs XO Jt 802' Surface Casing TD: 9/14/2014 17:30 hrs ., CDC to GEOCONN 9-5/8" L-80 40 ppf BTC Rig Released: 9/18/2014 18:00 hrs MD T0' Bottom 0' 3,400' ' '' TVD 0' 3,360' 1 12-1/4"hole Lead Cmt wl 598 sks(262 bbls)of Tree cxn=9-1/2"Otis 12.0 ppg,Class G, Tail Cmt w/198 sks(43 bbls) 8.0"Seal Diameterof 15.4 ppg,Class G, 37 sks(16 bbls)to surface 5-1/8"Modified ID Bore - - Production Casing TOC(CBL 10/30/14)-3,052 5-1/2" P-110 17 ppf CDC . Top Bottom Casing/Cementing Detail MD 0' 802' - 10.9 ppg Mud TVD 0' 802' - 12.5 ppg Mud Push(35 bbl) 5-1/2" P-110 17 ppf GEOCONN - 15.3 ppg Cement(454 bbl) 8.5 ppg 3%KCI(256 bbl) I ^RA Mkr Jt 6,094' Top Bottom MD 802' 11,128' TVD 802' 10,839' '^,ir • 8-1/2"hole Cmt w/1,875sks(454 bbls)of 15.3 ppg, �*a Class G cmt w/EASYBLOK +.i LB-17 LB-18L BC-23 LB-19U OH Log Depths LB-19L 44 - M50 @ 8,646'-8,656' LB-20 ad r B31 @ 8,556'-8,566' LB-21 630 @ 8,493'-8,503' IRA MkrJt 7,704' RST Log Depths M50 @ 8,642'-8,652' LB-22 831 @ 8,552'-8,562' LB-23 B30 @ 8,489'-8,499' LB-28 Perforations: LB-28 = Zone MD TVD Size SPF Date Status LB-28 LB-17 7,390'-7,400' 7,199'-7,208' 3-1/8" 6 Proposed LB-18L 7,457'-7,467' 7,265-7,273' 3-1/8" 6 Proposed LB-19U 7,540'-7,550' 7,344'-7,353' 3-1/8" 6 Proposed LB-29B = LB-19L 7,575-7,585' 7,377'-7,387' 3-1/8" 6 Proposed LB-20 7,612'-7,622' 7,415-7,423' 3-1/8" 6 Proposed LB-30 = LB-21 7,660'-7,670' 7,460'-7,469' 3-1/8" 6 Proposed LB-22 7,820'-7,860' 7,614'-7,653' 3-1/8" 6 5/02/15 Open LB-30 LB-23 7,883'-7,893' 7,676-7,685' 3-1/8" 6 5/02/15 Open Jewelry Depth LB-28 8,166-8,182' 7,948-7,963' 3-1/8" 6 12/11/14 Open 1.Swell Packer(21'Long) 3,010' LB-31 = LB-28 8,206-8,232' 7,987-8,012' 3-1/8" 6 12/11/14 Open M-50 = LB-28 8,282'-8,301' 8,060'-8,078' 3-1/8" 6 12/11/14 Open LB-29B 8,384'-8,412' 8,158'-8,185' 3-1/8" 6 12/10/14 Open I " RA MkrJt 9,917' LB-30 8,446-8,455' 8,216-8,226' 3-1/8" 6 12/10/14 Open LB-30 8,493'-8,503' 8,263'-8,272' 3-1/8" 6 11/23/14 Open LB-31 8,556-8,566' 8,326-8,333' 3-1/8" 6 11/23/14 Open Fluid Level M-50 8,646-8,656' 8,410'-8,419' 3-1/8" 6 11/23/14 Open unknown - ' LRAMkrJt10,611' Tag(fill)@ 10,920'SLM ". - Casing Shoe @ 11,128' Max Dogleg: w/2.00"Bailer(2/09/15) / - 4.76°/100'@ 2,367' TD: PBTD: Max Inclination: 11,141'MD 11,043'MD 10,852'TVD 10,754'TVD 16.6°@ 6,955' Well Name&Number:_ Beaver Creek Unit#23 Lease:_ A-028083 County or Parish:_ Kenai Peninsula Borough State/Prov: Alaska _ Country:IUSA Angle @KOP and Depth: 1.0°@ 2,000' Angle/Perls:I N/A - Maximum Deviation. 16.6°@ 6,955' Date Completed: 11/23/2014 Ground Level(above MSL): 160.6' _ RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date. Proposed Schematic Revision Date. 5/5/2015 STATE OF ALASKA AL _KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well Li , Plug Perforations U Perforate U Other U Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver 0 Time Extension 0 Change Approved Program 0 Operat.Shutdown❑ Stimulate-Other 0 Re-enter Suspended Well 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory E 214-093 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service 0 6.API Number: Anchorage,Alaska 99503 50-133-20635-00 7.Property Designation(Lease Number): 8.Well Name and Number: A028083 Beaver Creek(BCU)23 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Beluga Gas Pool 11.Present Well Condition Summary: Total Depth measured 11,141 feet Plugs measured N/A Qi:((17,;'- WED true vertical 10,852 feet Junk measured N/A feet "!ii/''7' 0 5 2015 Effective Depth measured 11,043 feet Packer measured 3,010 feet true vertical 10,754 feet true vertical 2,985 feet 0(3CC Casing Length Size MD ND Burst Collapse Structural Conductor 80' 16" 80' 80' Surface 3,400' 9-5/8" 3,400' 3,360' 5,750 psi 3,090 psi Intermediate Production 11,128' 5-1/2" 11,128' 10,839' 10,640 psi 7,460 psi Liner Perforation depth Measured depth See Attached Schematic s U SCANNED MAY L Val True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) Swell Pkr;N/A 3,010'MD 2,985'TVD N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 211 0 0 161 Subsequent to operation: 0 249 0 0 152 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Q✓ Service E Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil fl Gas Q WDSPL E GSTOR 0 WINJ fl WAG LI GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-244 Contact Stan Porhola Email sporholana hilcorp.com Printed Name Stan Porhola Title Operations Engineer f Signature ,,,„S-71001/6...-- Phone 907-777-8412 Date 5/05/1 Form 10-404 Revised 10/2012 � RBDM uI�rrerigi@al ly 0‘/T�� nll UU LLUU(�� Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-23 50-133-20635-00 214-093 5/2/15 5/2/15 Daily Operations: 05/02/2015-Saturday Held PJSM and obtained permit. Spot equipment and move wellhouse. MU lubricator and 10'x 3 3/8" guns, stab on well. Well flowing 290 MCFD @ 169 psi. PT lubricator to 250 psi low/3,000 psi high-good test. Shut in well. RIH w/ 10' guns+ GR/CCL and log correlation pass from 8,200'-7,600'. Correlate to SLB RST dated 10-29-14. Send in for verification. Perforate LB 23 (7,883'-7,893') with 3-3/8" HC (w/3-1/8" Connex charges) 60 deg 6 SPF guns. Positive indication of firing, little change in pressure (570 psi). POOH. OOH, all shots fired. Guns appear dry. LD spent gun and MU 20'gun. RIH w/20' guns+ GR/CCL and log correlation pass from 8,000'-7,600'. Correlate to SLB RST dated 10-29-14. Send in for verification. Perforate LB 22 (7,8401-7,860')with 3-3/8" HC (w/3-1/8" Connex charges) 60 deg 6 SPF guns. Positive indication of firing- little change in pressure (800 psi). POOH. OOH, all shots fired. Guns appear dry. LD spent gun and MU 20' gun. RIH w/20' guns+ GR/CCL and log correlation pass from 8,000'-7,600'. Correlate to SLB RST dated 10-29-14. Send in for verification. Perforate LB 22 (7,8201-7,840')with 3-3/8" HC (w/3-1/8" Connex charges) 60 deg 6 SPF guns. Positive indication of firing- little change in pressure (880 psi). POOH. OOH, all shots fired. Guns appear dry. LD spent gun and lubricator. RD Pollard. .. BCU - 23 ACTUAL Pad 3 1,125 FNL, 1,715'FWL, SCHEMATIC Sec. 34, T7N, R10W, S.M. IIili•urp Alaska. 1.IA: Permit#: 214-093 Conductor API#: 50-133-20635-00i: 16" X-56 109 ppf Top Bottom Prop.Des: FED A-028083 MD 0' 80' KB elevation: 179.2' (18.6'AGL) ND 0' 80' Lat: N60° 39' 30.892" Long: W151° 1' 1.445" Spud: 8/26/2014 02:30 hrs XO Jt 802' Surface Casing TD: 9/14/2014 17:30 hrs CDC to GEOCONN 9-5/8" L-80 40 ppf BTC Rig Released: 9/18/2014 18:00 hrs T0' Bottom MD 0' 3,,400' . ND 0' 3,360' 1 12-1/4"hole Lead Cmt w/598 sks(262 bbls)of Tree cxn=9-1/2"Otis11: 12.0 ppg,Class G, Tail Cmt w/198 sks(43 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 37 sks(16 bbls)to surface 5-1/8"Modified ID Bore , TOC(CBL 10/30/14)-3,052 Production Casing 5-1/2" P-110 17 ppf CDC . Top Bottom Casing/Cementing Detail MD 0' 802' - 10.9 ppg Mud ND 0' 802' - 12.5 ppg Mud Push(35 bbl) 5.1/2" P-110 17ppf - 15.3 ppg Cement(454 bbl) GEOCONN - 8.5 ppg 3%KCI(256 bbl) 0 •4 RA Mkr Jt 6,094' Top Bottom MD 802' 11,128' ND 802' 10,839' *h • '; 8-1/2"hole Cmt w/1,875sks(454 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK 1 ' • BC-23 II OH Log Depths '.RA Mkr Jt 7,704' M50 @ 8,646'-8,656' t/ B31 @ 8,556'-8,566' B30 @ 8,493'-8,503' N RST Log Depths LB-22 "} V'� M50 @ 8,642'-8,652' B31 @ 8,552'-8,562' LB-23 B30 @ 8,489'-8,499' LB-28 LB-28 = Perforations: Zone MD ND Size SPF Date Status LB-28 LB-22 7,820'-7,860' 7,614'-7,653' 3-1/8" 6 5/02/15 Open LB-23 7,883-7,893' 7,676-7,685' 3-1/8" 6 5/02/15 Open LB-28 8,166-8,182' 7,946-7,963' 3-1/8" 6 12/11/14 Open LB-29B = LB-28 8,206-8,232' 7,987'-8,012' 3-1/8" 6 12/11/14 Open LB-28 8,282'-8,301' 8,060'-8,078' 3-1/8" 6 12/11/14 Open LB-30 - LB-298 8,384'-8,412' 8,158'-8,185' 3-1/8" 6 12/10/14 Open LB-30 8,445'-8,455' 8,216-8,226' 3-1/8" 6 12/10/14 Open LB-30 LB-30 8,493-8,503' 8,263-8,272' 3-1/8" 6 11/23/14 Open Jewelry Depth LB-31 8,556-8,566' 8,323-8,333' 3-1/8" 6 11/23/14 Open 1.Swell Packer(21'Long) 3,010' LB-31 •= M-50 8,646-8,656' 8,410'-8,419' 3-1/8" 6 11/23/14 Open M-50 ' RA Mkr Jt 9,917' Fluid Level _ unknown RA MkrJt 10,611' Tag(fill)@ 10,920'SLM - - Casing Shoe @ 11,128' Max Dogleg: w/2.00"Bailer(2/09/15) - 4.76°/100'@ 2,367' TD: PBTD: Max Inclination: 11,141'MD 11,043'MD 10,852'ND 10,754'ND 16.6°@ 6,955' Well Name&Number: Beaver Creek Unit#23 Lease: A-028083 - County or Parish. Kenai Peninsula Borough State/Prov: Alaska Country:lUSA Angle @KOP and Depth: 1.0°@ 2,000' Angle/Perfs:J N/A Maximum Deviation 16.6°@ 6,955' Date Completed._ 11/23/2014 _ Ground Level(above MSL). 160.6' RKB(above GL): 18.6' Revised By. Stan Porhola Downhole Revision Date.• 5/2/2015 Schematic Revision Date: 5/5/2015 (cOF \��jj sem THE STATE Alaska Oil and Gas °fALA Conservation Commission . �� , S��1-1 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279.1433 OF ALAS* Fax. 907.276 7542 www.aogcc alaska gov SO O° PR 3 0 2-M5 Stan Porhola Operations Engineer Qiy - oc/ 3 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, BCU 23 Sundry Number: 315-244 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Ia Chair DATED this 3O ay of April, 2015 Encl. RECEIVED STATE OF ALASKA APR 2 2 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION eq-S 4-(2q 1 t 5 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑., • Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill l Number Exploratory ❑ Development ❑' • 214-093 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic II Service CI6.API Number. Anchorage,Alaska 99503 50-133-20635-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 237A - Will planned perforations require a spacing exception? Yes 111No CI ' Beaver Creek(BCU)23 - 9.Property Designation(Lease Number): 10.Field/Pool(s): A028083• Beaver Creek 1 Beluga Gas Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,141 d 10,852 • 11,043 - 10,754 • WA N/A Casing Length Size MD TVD Burst Campse Structural Conductor 80' 16" 80' 80' Surface 3,400' 9-5/8" 3,400' 3,360' 5,750 psi 3,090 psi Intermediate • Production 11,128' 5-1/2" 11,128' 10,839' 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)and ND(It): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: - Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development n Service n 14.Estimated Date for 15.Well Status after proposed work: Commencing05/01/15 Operations: Oil ❑ Gas ❑✓ • WDSPL El Suspended ❑ 16.Verbal Approval. Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Pothole Phone: 907-777-8412 Email soorhola( hilcorD.com Printed Name Stan Porhola Title Operations Engineer /Lc- COMMISSION Signature ✓'," Phone 907-777-8412 Date C Z(USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 7`L ^2q 14 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ �C Other: Spacing Exception Required? Yes ❑ No E Subsequent Form Required: / 73_.... i/b ty APPROVED BY Approved by. 06...i 4 COMMISSIONER THE COMMISSION Date: 4... 30 , q S/ � Submit Doan and Form'10-403(Revised 70 012) Ili o alid for 12 months f�the date of approval. Attachments in Duplicate RBDMSJ APR 1 n 7nu'�`0 "t7 -" `,1' z--- ' ) Well Prognosis Well: BCU-23 Ilikora Alaska,Lk Date:4/21/2015 Well Name: BCU-23 API Number: 50-133-20635-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: May 1st, 2015 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-093 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: - 2,700 psi @ 8,410' TVD (Based on existing perfs) Maximum Expected BHP: -2,7.00 psi-4k8,410' TVD (Based on existing perfs) Max. Allowable Surface Pressure - 1,859 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#23 was drilled as a Grass roots monobore completion in 2014 to target gas sands in the Sterling, Lower Beluga, and Tyonek formations.The initial perforations in the Lower Beluga were made in late November and were non-productive. Perforations were added in the Lower Beluga in December 2014 and were brought on-line.A perf gun and tool string was lost in the well during the perforating in December 2014, but was fished out successfully in February 2015. The purpose of this work/sundry is to add perforations in the Lower Beluga to increase rate. Notes Regarding Wellbore Condition • Well is currently producing at 240 mcf/d. • Current fluid level is unknow, but is suspected to be below the existing perfs. E-line Procedure: 1. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 1,000 psi (Form gas pressure). 2. RU 3-1/8" 6 spf Connex HC wireline guns. 3. RIH and perforate the following intervals: Zone Sands Top(MD) Btm (MD) FT SPF / Lower Beluga LB-22 7,820' 7,860' 40' 6 / Lower Beluga LB-23 7,883' 7,893' 10' 6 a. Bleed tubing pressure to 850 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Correlate using PNL Log dated 10/29/14(PNL Tie-in log). d. Use Gamma/CCL/to correlate. Utilize Press/Temp tool if available. e. Record tubing pressures before and after each perforating run. f. Proposed intervals are in the Beluga Gas Pool. g. Distance to nearest well open in same sands=875'to BCU-13. Well Prognosis • Well: BCU-23 Ililcorp Alaska,LL' Date:4/21/2015 h. Spacing allowance is based on CO 237A, no restrictions in Beluga Gas Pool. ✓ 4. RD E-line. 5. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic ,. BCU - 23 ACTUAL Pad 3 1,125 FNL, 1,715'FWL, SCHEMATIC Sec. 34, T7N, R10W, S.M. Ilileorp Alaska. 1,1.1: Permit#: 214-093 '? Conductor API#: 50-133-20635-00 16" X-56 109 ppf Tom Bottom Prop.Des: FED A-028083 MD 0' 80' KB elevation: 179.2' (18.6'AGL) TVD 0' 80' Lat: N60° 39' 30.892" i. Long: W151" 1' 1.445" Spud: 8/26/2014 02:30 hrs XO Jt 802' Surface Casing TD: 9/14/2014 17:30 hrs CDC to GEOCONN 9-5/8" L-80 40 ppf BTC Rig Released: 9/18/2014 18:00 hrs T� Bottom MD 0' 3,400400 ' TVD 0' _ 3,360' 1 12-1/4"hole Lead Cmt w/598 sks(262 bbls)of Tree cxn=9-1/2"Otis 12.0 ppg,Class G, Tail Cmt w/198 sks(43 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 37 sks(16 bbls)to surface 5-1/8"Modified ID Bore TOC(CBL 10/30/14) 3,052 - Production Casing - 5-1/2" P-110 17 ppf CDC Top Bottom MD 0' 802' TVD 0' 802' 5-1/2" P-110 17 ppf GEOCONN RA Mkr Jt 6,094' Top Bottom MD 802' 11,128' TVD 802' 10,839' 8-1/2"hole Cmt w/1,875sks(454 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK Casing/Cementing Detail - 10.9 ppg Mud I - 12.5 ppg Mud Push(35 bbl) RA Mkr Jt 7,704' - 15.3 ppg Cement(454 bbl) - 8.5 ppg 3%KCI(256 bbl) BC-23 OH Log Depths ti M50 @ 8,646'-8,656' B31 @ 8,556'-8,566' • B30 @ 8,493'-8,503' LB-28 = RST Log Depths LB-28 = M50 @ 8,642'-8,652' LB-28 = B31 @ 8,552'-8,562' B30 @ 8,489'-8,499' LB-29B LB-30 = Perforations: Zone MD ND Size SPF Date Status LB-30 L8-28 8,166-8,182' 7,946-7,963' 3-1/8" 6 12/11/14 Open Jewelry Depth LB-28 8,206-8,232' 7,987'-8,012' 3-1/8" 6 12/11/14 Open 1.Swell Packer(21'Long) 3,010' LB-31 LB-28 8,287-8,301' 8,060'-8,078' 3-1/8" 6 12/11/14 Open M-50 = LB-29B 8,384'-8,412' 8,158'-8,185' 3-1/8" 6 12/10/14 Open LB-30 8,445-8,455' 8,216-8,226' 3-1/8" 6 12/10/14 Open ' LB-30 8,493'-8,503' 8,263'-8,272' 3-1/8" 6 11/23/14 Open RA Mkr Jt 9,917' LB-31 8,556-8,566' 8,327-8,333' 3-1/8" 6 11/23/14 Open M-50 8,646-8,656' 8,410'-8,419' 3-1/8" 6 11/23/14 Open Fluid Level unknown ' RA Mkr Jt 10,611' Tag(fill)@ 10,920'SLM . Casing Shoe @ 11,128' Max Dogleg: w/2.00"Bailer(2/09/15) 4.76"/100'@ 2,367' TD: PBTD: Max Inclination: 11,141'MD 11,043'MD 10,852'ND 10,754'ND 16.6°@ 6,955' Well Name&Number Beaver Creek Unit#23 Lease: A-028083 County or Parish.. Peninsula Borough State/Prov: Alaska Country:[USA Angle @KOP and Depth. 1.0°@ 2,000' Angle/Perls:I N/A Maximum Deviation• . 16.6°@ 6,955' Date Completed. 11/23/2014 Ground Level(above MSL)._ 160.6' RKB(above GL):_ 18.6' Revised By. Stan Porhola Downhole Revision Date: 2/9/2015 Schematic Revision Date. 4/21/2015 BCU - 23 PROPOSED p 1:1Pad 3 1,125 FNL, 1,715'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. IIik•orp Alaska. LL(; i Conductor Permit#: 214-093 16" X-56 109 ppf API#: 50-133-20635-00Top Bottom Prop.Des: FED A-028083j:'... 0' 80' KB elevation: 179.2' (18.6'AGL) TVD 0' 80' Lat: N60° 39' 30.892" Long: W151° 1' 1.445" Spud: 8/26/2014 02:30 his XO Jt 802' Surface Casinq TD: 9/14/2014 17:30 hrs CDC to GEOCONN 9-5/8" L-80 40 ppf BTC ttom Rig Released: 9/18/2014 18:00 hrs MD 0'TO3g ,400' __ TVD 0' 3,360' 1 12-1/4"hole Lead Cmt w/598 sks(262 bbls)of Tree cxn=9-1/2"Otis 12.0 ppg,Class G, Tail Cmt w/198 sks(43 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 37 sks(16 bbls)to surface 5-1/8"Modified ID Bore TOC(CBL 10/30/14)-3,052 ----- Production Casinq 5-1/2" P-110 17 ppf CDC Top Bottom MD 0' 802' ND 0' 802' 5-1/2" P-110 17 ppf GEOCONN RA Mkr Jt 6,094' Top Bottom MD 802' 11,128' ND 802' 10,839' 8-1/2"hole Cmt w/1,875sks(454 bbls)of 15.3 ppg, ' Class G cmt w/EASYBLOK Casing/Cementing Detail - - 10.9 ppg Mud ' RA Mkr Jt 7,704' - 12.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(454 bbl) - 8.5 ppg 3%KCI(256 bbl) BC-23 OH Log Depths ' M50 @ 8,646'-8,656' LB-22 B31 @ 8,556'-8,566' LB-23 H - B30 @ 8,493'-8,503' LB-28 = RST Log Depths LB-28 = M50 @ 8,642'-8,652' LB-28 = 831 @ 8,552'-8,562' B30 @ 8,489'-8,499' LB-29B LB-30 Perforations: - Zone MD ND Size SPF Date Status LB-30 LB-22 7,820-7,860' 7,614-7,653' 3-1/8" 6 Proposed Jewelry Depth LB-23 7,883-7,893' 7,676-7,685' 3-1/8" 6 Proposed 1.Swell Packer(21'Long) 3.010' LB-31 = LB-28 8,166-8,182' 7,943-7,963' 3-118" 6 12/11/14 Open LB-28 8,206-8,232' 7,987-8,012' 3-1/8" 6 12/11/14 Open M-50 LB-28 8,282-8,301' 8,060-8,078' 3-1/8" 6 12/11/14 Open ILB-29B 8,384-8,412' 8,158-8,185' 3-1/8" 6 12/10/14 Open 6.6 RA MkrJt 9,917' LB-30 8,446-8,455' 8,216-8,226' 3-1/8" 6 12/10/14 Open LB-30 8,493-8,503' 8,263-8,272' 3-1/8" 6 11/23/14 Open ' LB-31 8,556-8,566' 8,323-8,333' 3-1/8" 6 11/23/14 Open , Fluid Level M-50 8,646-6,656' 8,410-8,419' 3-1/8" 6 11/23/14 Open unknown I •RA MkrJt 10,611' Tag(fill)@ 10,920'SLM - Casing Shoe @ 11,128' Max Dogleg: •w/2.00"Bailer(2/09/15) - - .. 4.76°/100'@ 2,367' TO: PBTD: Max Inclination: 11,141'MD 11,043'MD 10,852'ND 10,754'ND 16.6°@ 6,955' Well Name&Number: Beaver Creek Unit#23 Lease: A-028083 County orParish.- Kenai Peninsula Borough State/Prov: Alaska Country:lUSA Angle @KOP and Depth: 1.0°@ 2,000' Angle/Perfs:j N/A Maximum Deviation. 16.6°@ 6,955' Date Completed. 11/23/2014 Ground Level(above MSL)._ 160.6' RKB(above GL):_ 18.6' Revised By. Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 4/21/2015 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. .Q j . - (:) f_3 Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RES N: OVERSIZED: NOTES: Color Items: ❑ Maps: rayscale Items: I� -_gs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: ,ii lb BY: Maria Date: • /s/ Project Proofing BY: MS Date: asi'8/ 5" /s/ u , Scanning Preparation 7 x 30 = c I d + Is = TOTAL PAGES (lag ,J (Count does not include cover sheet) BY: MO Date: `g !S /s/ t Production Scanning Stage 1 Page Count from Scanned File: ac)--‘0(Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES IM NO BY: 410 Date: a,,,. I1'1'5 j /s/ Stage 1 If NO in stage 1, page(s)discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: dill NO TOTAL PAGES: -----)71/4 Digital version appended by: Meredith0 Michal Date: 2/ /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: 3:'3 Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc o "' o 0 O N 9 • p c0▪ o c • (i) N N N N N R co w a� W 0 0 0 0 0 a a> U ail co E E w • Q > > > > 4-) w c7 } 0 1 U m 0' °a oa E E -o a w W cu CO CO aa) ao) aa) in a I m 0 •0 x x a) •0 a D a = in m m co co b z 2 H co Co 2 H 2 H 2 H OO E E E E E 7 co 0 0 C C 0 0 0 0 0 0 J c0 N N coCN N H F. (J) C H H '= H H H H H H M C@ C C C C 4 M M MI M M M M CO M M N . 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H o IN 5 G M N CO N _ CO pas as 0 H _ Q w o m Q 6 Z E 0 io N N in oo 0 Mm • Fes- s r N m d cc .f.: C O 7 o 1 H u w C C CJ to £ y EE O E E a M °d 0 0 L' -- o )3 II Seth Nolan Hilcorp Alaska, LLC24 5S2_, GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 DATALOGGED IIih'„,i, tI.. ,,.1.1( Fax: 907 777-8510 . 'Z1i2ot E-mail: snolan@hilcorp.com K.BENDER DATE 01/23/14 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 23 Digital Survey Data CD: BCU 23 Definitive Surreys 9/26/2014 11:53 AM Text Document 12 KB El BCU-23 Definitive Surrey 9/26/2014 11:53 AM PDF Document 1577 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: ate: � �4.„/”) IAN262015 AOGCC RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS_.JN JAN 1 4 2015 REPORT OF SUNDRY WELL OPERATIONS � IGCC 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other u Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 1 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 2 Exploratory ❑ 214-093 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20635-00 7.Property Designation(Lease Number): 8.Well Name and Number: A028083 Beaver Creek(BCU)23 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Beluga Gas Pool 11 Present Well Condition Summary: Total Depth measured 11,141 feet Plugs measured N/A feet true vertical 10,852 feet Junk measured N/A feet Effective Depth measured 11,043 feet Packer measured 3,010 feet true vertical 10,754 feet true vertical 2,985 feet Casing Length Size MD ND Burst Collapse Structural Conductor 80' 16" 80' 80' Surface 3,400' 9-5/8" 3,400' 3,360' 5,750 psi 3,090 psi Intermediate Production 11,128' 5-1/2" 11,128' 10,839' 10,640 psi 7,460 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) Swell Pkr;N/A 3,010'MD 2,985'ND N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 1876 Subsequent to operation: 0 409 0 0 386 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas Q WDSPL El GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-639 Contact Stan Porhola Email sporholaCaahilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature „,d!- Al L Phone 907-777-8412 Date (/L(/If. RBDMkAk JAN 1 6 2015 Form 10-404 Revised 10/2012 /10 007/i— /- / Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-23 50-133-20635-00 214-093 12/10/14 12/11/14 Daily Operations: 12/10/2014-Wednesday PTW and JSA. Mobe to location and spot equipment. Rig up lubricator and PT to 250 psi low and 3,000 psi high.TP-1,900 psi. RIH with 3-3/8" (3-3/8" charges) x 10' Owen HC, 6 spf, 60 deg phase and found fluid level at 10,050'. POOH. PU new gun system to shoot in gas. RIH with 3-3/8" (3-1/8" charges) x 10' Owen HC, 6 spf, 60 deg phase and tied into SLB RST log dated 29-Oct-14. Sent correlation log to town and got ok. Spotted shot from 8,445'to 8,455'.TP was 1,900 psi. Fired gun and POOH. RIH with 3-3/8" (3-1/8" charges) x 28' Owen HC, 6 spf, 60 deg phase and tied into SLB RST log dated 29-Oct-14. Sent correlation log to town and got ok. Spotted shot from 8,384'to 8,412'.TP was 1,890 psi. Fired gun and POOH. RIH with 3- 3/8" (3-1/8" charges) x 19' Owen HC, 6 spf, 60 deg phase and tied into SLB RST log dated 29-Oct-14. Sent correlation log to town and got ok. 12/11/2014-Thursday Spotted shot from 8,282'to 8,301'.TP was 1,870 psi. Fired gun and POOH. While moving gun into the lubricator, rope socket broke causing guns and tool string to fall to bottom of the hole. Make up new tool string and rope socket. RIH with 3-3/8" (3- 1/8" charges)x 26' Owen HC, 6 spf, 60 deg phase and tied into SLB RST log dated 29-Oct-14. Sent correlation log to town and got ok. Spotted shot from 8,206'to 8,232'.TP was 1,825 psi. Fired gun and POOH. RIH with 3-3/8" (3-1/8" charges) x 16' Owen HC, 6 spf, 60 deg phase and tied into SLB RST log dated 29-Oct-14. Sent correlation log to town and got ok. Spotted shot from_8166'to 8,182'.TP was 1,825 psi. Fired gun and POOH. RIH with GPT Tool and found fluid level at 9,950'. Rig down lubricator and turn well over to field. Final TP was 1,790 psi. r BCU - 23 ACTUAL Pad 3 1,125 FNL, 1,715'FWL, SCHEMATIC Sec. 34, T7N, R10W, S.M. Hilcorp Alaska. I.I.( Permit#: 214-093 Conductor API#: 50-133-20635-00 4 16" �X-56 109 Bottom f Prop.Des: FED A-028083 }!, MD 0' 80' i L KB elevation: 179.2' (18.6'AGL) •L TVD 0' 80' Lat: N60° 39' 30.892" � Long: W151° 1' 1.445" Spud: 8/26/2014 02:30 hrs XO Jt 802' Surface Casing TD: 9/14/2014 17:30 hrs CDC to GEOCONN 9 5/8" L-80 40 ppf BTC Rig Released: 9/18/2014 18:00 hrs T0p Bottom MD 0' 3,400' ' ," TVD 0' 3,360' 1 12-1/4"hole Lead Cmt wl 598 sks(262 bbls)of Tree cxn=9-112"Otis 12.0 ppg,Class G, Tail Cmt wl 198 sks(43 bbls) 8.0"Seal Diameterof 15.4 ppg,Class G, 37 sks(16 bbls)to surface 5-1/8"Modified ID Bore Production Casing TOC(CBL 10/30/14)-3,052 5-1/2" P-110 17 ppf CDC • Top Bottom ' MD 0' 802' TVD 0' 802' �; 5-1/2" P-110 17 ppf GEOCONN 11 Top Bottom 11 . RA MkrJt 6,094' MD 802' 11,128' TVD 802' 10,839' "44 8-1/2"hole Cmt w/1,875sks(454 bbls)of 15.3 ppg, Class G cmt wl EASYBLOK {v b Casing/Cementing Detail +' - 10.9 ppg Mud `}r _ - 12.5 ppg Mud Push(35 bbl) I RA Mkr Jt 7,704' - 15.3 ppg Cement(454 bbl) - 8.5 ppg 3%KCI(256 bbl) tdi •11 ' BC-23 iill OH Log Depths s` . M50 @ 8,646'-8,656' B31 @ 8,556'-8,566' LB-28 = B30 @ 8,493'-8,503' LB-28 = LB-28 - RST Log Depths LB-29B M50 @ 8,642'-8,652' B31 @ 8,552'-8,562' LB-30 = B30 @ 8,489'-8,499' LB-30 Perforations: LB-31 = - Zone MD TVD Size SPF Date Status M-50 LB-28 8,166-8,182' 7,948'-7,963' 3-1/8" 6 12/11/14 Open Jewelry Depth LB-28 8,206-8,232' 7,987'-8,012' 3-1/8" 6 12/11/14 Open 1.Swell Packer(21'Long) 3,010' LB-28 8,282'-8,301' 8,060'-8,078' 3-1/8" 6 12/11/14 Open LB-29B 8,384'-8,412' 8,158'-8,185' 3-1/8" 6 12/10/14 Open LB-30 8,445'-8,455' 8,216-8,226' 3-1/8" 6 12/10/14 Open I . LB-30 8,493'-8,503' 8,266-8,272' 3-1/8" 6 11/23/14 Open RA MkrJt 9,917' LB-31 8,556-8,566' 8,323'-8,333' 3-1/8" 6 11/23/14 Open M-50 8,646-8,656' 8,410'-8,419' 3-1/8" 6 11/23/14 Open . V . Fluid Level = 9,950' . ' 6 RA MkrJt 10,611' Tag(unset cement)@ 10,984'SLM - Casing Shoe @ 11,128' Max Dogleg: wl 4.53"GR(10/21/14) --_ 4.76°1100'@ 2,367' PBTD: Fish(EL 31'Tool String) /�11,141.'MD 11,043'MD Max Inclination: Unknown Depth(12/11/14) 10,852'TVD 10,754'TVD 16.6°@ 6,955' Well Name&Number: Beaver Creek Unit#23 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: Angle @KOP and Depth: 1.0°@ 2,000' Angle/Perfs:I N/A Maximum Deviation: 16.6°@ 6,955' Date Completed: 11/23/2014 Ground Level(above MSL): 160.6' RKB(above GL):_ 18.6' Revised By: Stan Porhola Downhole Revision Date. 12/11/2014 Schematic Revision Date: 12/17/2014 RECEIVED STATE OF ALASKA OEC9014 r ALASI.,-1 OIL AND GAS CONSERVATION COMMI-,ION WELL COMPLETION OR RECOMPLETION REPORT AND . =, la.Well Status: Oil ❑ Gas 0 - SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development Q ' Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: _1 ..=,,..., Service U Stratigraphic Test ❑ 2.Operator Name: 5. Dtte Comp.,'Susp.,or 12. Permit to Drill Number: Hilcorp Alaska,LLC Aband.-:— " 11/23/2014 214-093 • 3.Address: 6. Date Spudded: 13.API Number: 3800 Centerpoint Drive.Suite 1400 Anchorage,AK 99503 8/26/2014 50-133-20635-00 - 4a. Location of Well(Governmental Section): 7. Date TD Reached: 14.Well Name and Number: Surface: 1125'FNL, 1715'FWL,Sec 34,T7N, R1OW,SM,AK - 9/14/2014 Beaver Creek Unit(BCU)23 ' Top of Productive Horizon: 8. KB(ft above MSL): 179.2 15. Field/Pool(s): 1439'FNL,2457'FWL,Sec 34,T7N,R1OW,SM,AK GL(ft above MSL): 160.6 Total Depth: 9. Plug Back Depth(MD+TVD): Beaver Creek/Beluga Gas Pool - 1953'FNL. 1565'FEL,Sec 34.T7N.R1OW,SM,AK 11,043'MD/10,754'TVD 4b. Location of Well(State Base Plane Coordinates, NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 317534.34 • y- 2434057.1 - Zone- 4 - 11,141'MD/10,852'TVD A028083 - TPI: x- 318272.5 y- 2433731.4 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 319521.49 y- 2433198.54 Zone- 4 N/A N/A 18. Directional Survey: Yes ❑� No ❑ 19.Water Depth, if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MC/TVD: FEL 2in/5in, GRL,DEL,(ROP-DGR-ADR-EWR-ALD-CTN MD/TVD 2in/5in), RST,CEL N/A 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" 109# X-56 18' 98' 18' 98' N/A N/A 9-5/8" 40# X-56 18' 3,400' 18' 3,360' 12-1/4" 305 bbl(262L 43T)12&15,G N/A 5-1/2" 17# P-110 18' 11,128' 18' 10,839' 8-1/2" 454 bbls 15.3ppg Class G N/A 24.Open to production or injection? Yes 0 No ❑ 25. TUBING RECORD If Yes, list each interval open(MD+TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): N/A N/A N/A LB-30 8,493'-8,503' 8,263'-8,272' 3-1/8" 6 11/23/14 Open LB-31 8,556'-8,566' 8,323'-8,333' 3-1/8" 6 11/23/14 Open 26. ACID, FRACTURE,CEMENT SQUEEZE, ETC. M-50 8.646'-8,656' 8,410'-8,419' 3-1/8" 6 11/23/14 Open Was hydraulic fracturing used during completion? Yes❑ No E liii 1t}; .! DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED r. i 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A Test Period — Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. N/A 24-Hour Rate . 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No❑✓ Sidewall Cores Acquired? Yes ❑ No❑., If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. t-orm-10-401 Revised i0/z0i2 C.UNI'NULL UN KtVtKSt + Iil Oliynlal only r„ j— )-6,----- z--i_fs, SECS JAN - 9 "lU` ?- . 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? El Yes 2 No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form, if Permafrost-Top needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base STERLING_B 4936 -4657 BC_B3ST 5218 -4929 BC_B3-L_ST 5265 -4974 BC_B4ST 5369 -5075 BELUGA 5970 -5653 BC_B15ST 7079 -6720 SR_LBGT 7367 -6997 BC_B19ST 7534 -7157 BC_B21ST 7646 -7266 BC_B22ST 7816 -7430 BC_B23ST 7880 -7492 BC_B28ST 8141 -7743 BC_B3OST 8442 -8034 BC_B31 ST 8532 -8120 SR_TYONEK 8936 -8509 Formation at total depth: 31. List of Attachments: Well Schematic,MW vs Depth, Days vs Depth,Definitive Directional Survey,Drilling Composite Report,Casing and Cmt reports&MIT Report 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Stan Porhola Email:_sporhola(ahilcorp.com Printed Name: Stan Porhola Title: Operations Engineer DD Signature:. 7)0'�-'L Phone: 907-777-8412 Date: I c l//� 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 1b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 BCU - 23 ACTUAL Pad 3 1,125 FNL, 1,715'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. Hilcorp Alaska. I.I.( Permit#: 214-093 Conductor 16" X-56 109 ppf API#: 50-133-20635-00 Top Bottom Prop.Des: FED A-028083 MD o' 80' KB elevation: 179.2' (18.6'AGL) ND 0' 80' Lat: N60° 39' 30.892" Long: W151° 1' 1.445" Spud: 8/26/2014 02:30 hrs XO Jt 802' Surface Casing TD: 9/14/2014 17:30 hrs CDC to GEOCONN 9-5/8" L-80 40 ppf BTC Rig Released: 9/18/2014 18:00 hrs MD TomBottom ' 3,400' ND 0' 3,360' 1 12-1/4"hole Lead Cmt wl 598 sks(262 bbls)of Tree cxn=9-1/2"Otis - 12.0 ppg,Class G, Tail Cmt wl 198 sks(43 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 37 sks(16 bbls)to surface 5-1/8"Modified ID Bore V lak---- Production Casing TOC(CBL 10/30/14)-3,052 ' + 5-1/2" P-110 17 ppf CDC V. Top Bottom ry MD 0' 802' ND 0' 802' ,,' 5-1/2" P-110 17 ppf GEOCONN Top Bottom RA Mkr Jt 6,094'MI MD 802' 11,128' ND 802' 10,839' 8-1/2"hole Cmt wl 1,875sks(454 bbls)of 15.3 ppg, Class G cmt wl EASYBLOK ' Casina/Cementing Detail - 10.9 ppg Mud - 12.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(454 bbl) r RA Mkr Jt 7,704' - 8.5 ppg 3%KCI(256 bbl) t ti BC-23 ko OH Log Depths M50 @ 8,646'-8,656' �V B31 @ 8,556'-8,566' r• B30 @ 8,493'-8,503' I RST Log Depths M50 @ 8,642'-8,652' B31 @ 8,552'-8,562' LB-30 = B30 @ 8,489'-8,499' LB-31 = Jewelry Depth M-50 1.Swell Packer(21'Long) 3,010' Perforations: Zone MD TVD Size SPF Date Status LB-30 8,493'-8,503' 8,263'-8,272' 3-1/8" 6 11/23/14 Open LB-31 8,556-8,566' 8,323'-8,333' 3-1/8" 6 11/23/14 Open •RA Mkr Jt 9,917' M-50 8,646-8,656' 8,410'-8,419' 3-1/8" 6 11/23/14 Open - VFluid Level 10,200' IRA Mkr Jt 10,611' Tag(unset cement)@ 10,984'SLM _ Casing Shoe @ 11,128' Max Dogleg: w/4.53"GR(10121/14) -- 4.76°/100'@ 2,367' TD: PBTD: 11,141'MD 11,043'MD Max Inclination: 10,852'ND 10,754'ND 16.6°@ 6,955' Well Name&Number. 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Z C N (n 00 L III- > N ((} .--- CIOmN N O O L -co— 1 0 O O - CO N c O 0 ai aci r O - 0 cm Q cn 0 o 0 a).N 3 o 0 0 (o CO CO Y ice) o v �r u) co 0 Q °) 0 - U H d i- o 2 o Z (O ai -a ai m dt ai ai `o 65 °' v v v tlE (7as Y ca E � W W (o E Z a p as 2 W W 0 0 0 0 0 Z O Q Z Q Q N N N N N c I- O Q O U .> 6) CO CO O Q U) �. o Hilcorp Energy Company Beaver Creek Unit Beaver Creek Unit BCU 23 50-133-20635-00-00 50-133-20635-00-00 Sperry Drillin+c Definitive Survey Report 23 September, 2014 fl1 ,C ti I l E." /i :1 HALLIBURTON Sperry Drilling d; Ii' Cry Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 23 Project: Beaver Creek Unit TVD Reference: Actual:BCU 23 @ 178.23usft • Site: Beaver Creek Unit MD Reference: Actual:BCU 23 @ 178.23usft Well: Beaver CK Unit 23 North Reference: True Wellbore: BCU 23 Survey Calculation Method: Minimum Curvature Design: BCU 23 Rig Surveys Database: Sperry EDM-NORTH US+CANADA Project Beaver Creek Unit Map System: US State Plane 1927(Exact solution) . System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Well Beaver CK Unit 23 Well Position +NI-S 0.00 usft Northing: 2,434,057.10 usft Latitude: 60°39'30.893 N +El-W 0.00 usft Easting: 317,534.34 usft Longitude: 151°1'1.438 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: • 160.23 usft Wellbore BCU 23 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (1 (nT) BGGM2014 8/15/2014 16.96 73.63 55,446 Design BCU 23 Rig Surveys Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 18.00 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (°) 18.00 0.00 0.00 112.48 Survey Program Date 9/23/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 196.77 3,357.77 MWD+SC+Sag(BCU 23) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 08/27/2014 3,416.01 11,099.26 MWD+SC+Sag(BCU 23) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 08/27/2014 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 18.00 0.00 0.00 18.00 -160.23 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 UNDEFINED 196.77 0.23 320.70 196.77 18.54 0.28 -0.23 2,434,057.39 317,534.11 0.13 -0.32 MWD+SC+sag(1) 253.46 0.27 356.37 253.46 75.23 0.50 -0.31 2,434,057.61 317,534.03 0.28 -0.48 MWD+SC+sag(1) 325.96 0.30 349.64 325.96 147.73 0.86 -0.35 2,434,057.97 317,534.00 0.06 -0.65 MWD+SC+sag(1) 387.28 0.58 350.91 387.28 209.05 1.32 -0.43 2,434,058.43 317,533.92 0.46 -0.90 MWD+SC+sag(1) 445.33 0.38 346.01 445.32 267.09 1.80 -0.52 2,434,058.91 317,533.84 0.35 -1.17 MWD+SC+sag(1) 506.81 0.30 353.80 506.80 328.57 2.16 -0.59 2,434,059.27 317,533.78 0.15 -1.37 MWD+SC+sag(1) 568.71 0.22 320.11 568.70 390.47 2.41 -0.68 2,434,059.52 317,533.69 0.27 -1.55 MWD+SC+sag(1) 631.39 0.00 339.37 631.38 453.15 2.50 -0.76 2,434,059.62 317,533.61 0.35 -1.66 MWD+SC+sag(1) 693.17 0.23 266.44 693.16 514.93 2.49 -0.88 2,434,059.61 317,533.49 0.37 -1.77 MWD+SC+sag(1) 754.42 0.26 255.43 754.41 576.18 2.45 -1.14 2,434,059.57 317,533.23 0.09 -1.99 MWD+SC+sag(1) 815.27 0.29 281.76 815.26 637.03 2.45 -1.43 2,434,059.57 317,532.95 0.21 -2.25 MWD+SC+sag(1) 878.26 0.01 224.27 878.25 700.02 2.47 -1.59 2,434,059.60 317,532.79 0.45 -2.41 MWD+SC+sag(1) 9/23/2014 6:43:27PM Page 2 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 23 Project: Beaver Creek Unit TVD Reference: Actual:BCU 23 @ 178.23usft Site: Beaver Creek Unit MD Reference: Actual:BCU 23 @ 178.23usft Well: Beaver CK Unit 23 North Reference: True Wellbore: BCU 23 Survey Calculation Method: Minimum Curvature Design: BCU 23 Rig Surveys Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 942.10 0.10 223.86 942.09 763.86 2.43 -1.63 2,434,059.56 317,532.74 0.14 -2.43 MWD+SC+sag(1) 1,001.23 0.33 267.27 1,001.22 822.99 2.39 -1.83 2,434,059.52 317,532.54 0.45 -2.61 MWD+SC+sag(1) 1,063.67 0.34 238.47 1,063.66 885.43 2.28 -2.17 2,434,059.42 317,532.20 0.27 -2.88 MWD+SC+sag(1) 1,125.89 0.13 256.71 1,125.68 947.45 2.17 -2.40 2,434,059.31 317,531.97 0.36 -3.04 MWD+SC+sag(1) 1,185.49 0.55 259.45 1,185.48 1,007.25 2.10 -2.75 2,434,059.25 317,531.62 0.70 -3.34 MWD+SC+sag(1) 1,249.18 0.49 271.18 1,249.16 1,070.93 2.05 -3.32 2,434,059.20 317,531.05 0.19 -3.85 MWD+SC+sag(1) 1,311.77 0.28 296.59 1,311.75 1,133.52 2.12 -3.72 2,434,059.28 317,530.65 0.42 -4.25 MWD+SC+sag(1) 1,374.18 0.36 251.84 1,374.16 1,195.93 2.13 -4.05 2,434,059.30 317,530.32 0.41 -4.55 MWD+SC+sag(1) 1,498.12 0.10 241.57 1,498.10 1,319.87 1.96 -4.51 2,434,059.13 317,529.86 0.21 -4.92 MWD+SC+sag(1) 1,622.89 0.54 239.40 1,622.87 1,444.64 1.61 -5.11 2,434,058.79 317,529.25 0.35 -5.34 MWD+SC+sag(1) 1,684.83 0.48 238.13 1,68481 1,506.58 1.32 -5.58 2,434,058.51 317,528.77 0.10 -5.66 MWD+SC+sag(1) 1,746.20 0.39 227.37 1,746.17 1,567.94 1.04 -5.96 2,434,058.24 317,528.40 0.20 -5.90 MWD+SC+sag(1) 1,808.83 0.53 247.11 1,808.80 1,630.57 0.79 -6.38 2,434,057.99 317,527.97 0.33 -6.20 MWD+SC+sag(1) 1,931.96 0.41 186.65 1,931.93 1,753.70 0.13 -6.96 2,434,057.34 317,527.38 0.39 -6.48 MWD+SC+sag(1) 1,995.68 1.05 119.02 1,995.64 1,817.41 -0.38 -6.47 2,434,056.82 317,527.86 1.52 -5.83 MWD+SC+sag(1) 2,057.05 1.66 107.33 2,057.00 1,878.77 -0.92 -5.13 2,434,056.26 317,529.19 1.09 -4.39 MWD+SC+sag(1) 2,119.33 3.57 107.01 2,119.21 1,940.98 -1.76 -2.42 2,434,055.39 317,531.89 3.07 -1.56 MWD+SC+sag(1) 2,181.93 4.70 106.02 2,181.65 2,003.42 -3.03 1.91 2,434,054.04 317,536.20 1.81 2.93 MWD+SC+sag(1) 2,244.76 6.90 101.98 2,24415 2,065.92 -4.53 8.08 2,434,052.45 317,542.34 3.56 9.20 MWD+SC+sag(1) 2,304.55 8.57 100.12 2,303.39 2,125.16 -6.06 15.98 2,434,050.80 317,550.22 2.82 17.08 MWD+SC+sag(1) 2,366.83 11.51 102.21 2,364.71 2,186.48 -8.19 26.62 2,434,048.51 317,560.83 4.76 27.73 MWD+SC+sag(1) 2,428.45 13.00 103.68 2,424.93 2,246.70 -11.13 39.37 2,434,045.37 317,573.53 2.47 40.63 MWD+SC+sag(1) 2,490.45 14.25 106.35 2,485.18 2,306.95 -14.92 53.47 2,434,041.36 317,587.56 2.26 55.11 MWD+SC+sag(1) 2,553.11 15.31 108.76 2,545.77 2,367.54 -19.75 68.70 2,434,036.29 317,602.72 1.96 71.03 MWD+SC+sag(1) 2,614.00 16.08 111.96 2,604.39 2,426.16 -25.49 84.13 2,434,030.31 317,618.06 1.90 87.49 MWD+SC+sag(1) 2,675.64 16.35 111.93 2,663.58 2,485.35 -31.93 100.10 2,434,023.63 317,633.93 0.44 104.70 MWD+SC+sag(1) 2,736.77 16.26 111.25 2,722.25 2,544.02 -38.24 116.06 2,434,017.07 317,649.78 0.35 121.86 MWD+SC+sag(1) 2,799.66 16.05 111.73 2,782.66 2,604.43 -44.65 132.34 2,434,010.41 317,665.97 0.40 139.35 MWD+SC+sag(1) 2,862.48 16.08 110.67 2,843.02 2,664.79 -50.94 148.54 2,434,003.87 317,682.07 0.47 156.73 MWD+SC+sag(1) 2,923.28 16.01 110.85 2,901.45 2,723.22 -56.89 164.26 2,433,997.68 317,697.69 0.14 173.53 MWD+SC+sag(1) 2,985.35 16.06 113.84 2,961.11 2,782.88 -63.41 180.11 2,433,990.91 317,713.44 1.33 190.67 MWD+SC+sag(1) 3,047.41 15.98 115.03 3,020.76 2,842.53 -70.49 195.70 2,433,983.59 317,728.92 0.54 207.79 MWD+SC+sag(1) 3,109.83 15.80 115.04 3,080.80 2,902.57 -77.73 211.19 2,433,976.12 317,744.29 0.29 224.86 MWD+SC+sag(1) 3,171.88 15.64 115.30 3,140.52 2,962.29 -84.88 226.40 2,433,968.73 317,759.40 0.28 241.65 MWD+SC+sag(1) 3,234.47 15.72 115.45 3,200.79 3,022.56 -92.13 241.69 2,433,961.25 317,774.57 0.14 258.55 MWD+SC+sag(1) 3,296.13 15.62 114.95 3,260.15 3,081.92 -99.22 256.75 2,433,953.93 317,789.52 0.27 275.18 MWD+SC+sag(1) 3,357.77 15.14 115.26 3,319.59 3,141.36 -106.15 271.56 2,433,946.76 317,804.22 0.79 291.51 MWD+SC+sag(1) 3,416.01 15.22 114.94 3,375.79 3,197.56 -112.62 285.37 2,433,940.08 317,817.93 0.20 306.75 MWD+SC+sag(2) 3,478.13 15.35 114.78 3,435.72 3,257.49 -119.51 300.23 2,433,932.97 317,832.68 0.22 323.11 MWD+SC+sag(2) 3,538.88 15.36 114.09 3,494.30 3,316.07 -126.16 314.87 2,433,926.09 317,847.22 0.30 339.19 MWD+SC+sag(2) 9/23/2014 6:43:27PM Page 3 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 23 Project: Beaver Creek Unit TVD Reference: Actual:BCU 23 @ 178.23usft Site: Beaver Creek Unit MD Reference: Actual:BCU 23 @ 178.23usft Well: Beaver CK Unit 23 North Reference: True Wellbore: BCU 23 Survey Calculation Method: Minimum Curvature Design: BCU 23 Rig Surveys Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,602.43 15.37 114.35 3,555.58 3,377.35 -133.07 330.23 2,433,918.94 317,862.47 0.11 356.02 MWD+SC+sag(2) 3,664.00 15.47 113.17 3,614.93 3,436.70 -139.66 345.21 2,433,912.12 317,877.34 0.53 372.38 MWD+SC+sag(2) 3,726.25 16.52 113.91 3,674.77 3,496.54 -146.52 360.94 2,433,905.02 317,892.96 1.72 389.53 MWD+SC+sag(2) 3,787.45 16.59 113.62 3,733.43 3,555.20 -153.54 376.90 2,433,897.75 317,908.81 0.18 406.97 MWD+SC+sag(2) 3,850.49 16.69 113.31 3,793.83 3,615.60 -160.73 393.45 2,433,890.30 317,925.26 0.21 425.02 MWD+SC+sag(2) 3,911.87 16.65 113.09 3,852.63 3,674.40 -167.67 409.64 2,433,883.12 317,941.33 0.12 442.62 MWD+SC+sag(2) 3,975.09 16.47 112.50 3,913.23 3,735.00 -174.65 426.25 2,433,875.88 317,957.83 0.39 460.64 MWD+SC+sag(2) 4,036.38 16.46 112.48 3,972.01 3,793.78 -181.29 442.30 2,433,868.99 317,973.78 0.02 478.01 MWD+SC+sag(2) 4,098.93 16.44 111.90 4,032.00 3,853.77 -187.98 458.70 2,433,862.04 317,990.07 0.26 495.72 MWD+SC+sag(2) 4,160.58 16.35 111.34 4,091.14 3,912.91 -194.40 474.88 2,433,855.38 318,006.15 0.30 513.12 MWD+SC+sag(2) 4,222.78 16.39 111.85 4,150.82 3,972.59 -200.85 491.18 2,433,848.68 318,022.35 0.24 530.65 MWD+SC+sag(2) 4,285.74 16.29 111.31 4,211.24 4,033.01 -207.36 507.65 2,433,841.91 318,038.71 0.29 548.36 MWD+SC+sag(2) 4,347.73 16.23 111.77 4,270.75 4,092.52 -213.74 523.79 2,433,835.29 318,054.76 0.23 565.72 MWD+SC+sag(2) 4,409.70 16.06 110.89 4,330.27 4,152.04 -220.00 539.84 2,433,828.77 318,070.71 0.48 582.94 MWD+SC+sag(2) 4,469.86 15.97 110.85 4,388.10 4,209.87 -225.92 555.35 2,433,822.62 318,086.12 0.15 599.53 MWD+SC+sag(2) 4,533.71 16.08 113.98 4,449.47 4,271.24 -232.64 571.64 2,433,815.65 318,102.31 1.36 617.15 MWD+SC+sag(2) 4,595.41 16.11 115.13 4,508.75 4,330.52 -239.75 587.20 2,433,808.30 318,117.75 0.52 634.25 MWD+SC+sag(2) 4,657.98 16.03 114.39 4,568.87 4,390.64 -247.00 602.93 2,433,800.80 318,133.37 0.35 651.55 MWD+SC+sag(2) 4,720.04 16.02 114.42 4,628.52 4,450.29 -254.08 618.53 2,433,793.49 318,148.86 0.02 668.68 MWD+SC+sag(2) 4,781.42 15.69 114.30 4,687.57 4,509.34 -261.00 633.80 2,433,786.33 318,164.02 0.54 685.44 MWD+SC+sag(2) 4,843.22 15.63 114.20 4,747.07 4,568.84 -267.85 649.01 2,433,779.25 318,179.12 0.11 702.11 MWD+SC+sag(2) 4,904.18 15.46 114.24 4,805.80 4,627.57 -274.55 663.91 2,433,772.31 318,193.92 0.28 718.44 MWD+SC+sag(2) 4,967.04 15.21 113.49 4,866.43 4,688.20 -281.28 679.11 2,433,765.35 318,209.01 0.51 735.06 MWD+SC+sag(2) 5,029.52 15.11 113.53 4,926.73 4,748.50 -287.79 694.10 2,433,758.60 318,223.89 0.16 751.39 MWD+SC+sag(2) 5,091.94 15.08 112.91 4,987.00 4,808.77 -294.20 709.03 2,433,751.97 318,238.73 0.26 767.65 MWD+SC+sag(2) 5,153.29 15.14 112.74 5,046.23 4,868.00 -300.41 723.77 2,433,745.53 318,253.37 0.12 783.64 MWD+SC+sag(2) 5,214.62 15.00 112.16 5,105.45 4,927.22 -306.50 738.51 2,433,739.22 318,268.02 0.34 799.59 MWD+SC+sag(2) 5,277.47 14.94 112.36 5,166.16 4,987.93 -312.65 753.54 2,433,732.84 318,282.94 0.13 815.82 MWD+SC+sag(2) 5,340.17 14.88 111.75 5,226.75 5,048.52 -318.70 768.49 2,433,726.55 318,297.80 0.27 831.95 MWD+SC+sag(2) 5,401.11 14.65 111.74 5,285.68 5,107.45 -324.46 782.91 2,433,720.57 318,312.14 0.38 847.48 MWD+SC+sag(2) 5,463.37 14.73 111.25 5,345.91 5,167.68 -330.24 797.60 2,433,714.56 318,326.73 0.24 863.27 MWD+SC+sag(2) 5,526.84 14.68 110.82 5,407.30 5,229.07 -336.02 812.64 2,433,708.54 318,341.68 0.19 879.37 MWD+SC+sag(2) 5,587.32 14.75 110.86 5,465.79 5,287.56 -341.49 827.00 2,433,702.86 318,355.95 0.12 894.73 MWD+SC+sag(2) 5,651.56 16.17 113.02 5,527.71 5,349.48 -347.90 842.88 2,433,696.20 318,371.73 2.38 911.85 MWD+SC+sag(2) 5,713.00 16.39 112.89 5,586.68 5,408.45 -354.62 858.74 2,433,689.24 318,387.48 0.36 929.07 MWD+SC+sag(2) 5,775.28 16.38 112.16 5,646.44 5,468.21 -361.35 874.96 2,433,682.26 318,403.60 0.33 946.64 MWD+SC+sag(2) 5,837.98 16.41 112.36 5,706.59 5,528.36 -368.05 891.34 2,433,675.30 318,419.87 0.10 964.34 MWD+SC+sag(2) 5,899.24 16.33 112.37 5,765.36 5,587.13 -374.62 907.31 2,433,668.49 318,435.74 0.13 981.61 MWD+SC+sag(2) 5,962.07 16.33 111.57 5,825.66 5,647.43 -381.23 923.69 2,433,661.63 318,452.02 0.36 999.27 MWD+SC+gag(2) 6,024.13 16.14 110.49 5,885.24 5,707.01 -387.46 939.88 2,433,655.15 318,468.11 0.57 1,016.61 MWD+SC+sag(2) 9/23/2014 6.43.27PM Page 4 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 23 Project: Beaver Creek Unit TVD Reference: Actual:BCU 23 @ 178.23usft Site: Beaver Creek Unit MD Reference: Actual:BCU 23 @ 178.23usft Well: Beaver CK Unit 23 North Reference: True Wellbore: BCU 23 Survey Calculation Method: Minimum Curvature Design: BCU 23 Rig Surveys Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) C/100') (ft) Survey Tool Name 6,085.98 16.26 110.58 5,944.64 5,766.41 -393.51 956.04 2,433,648.85 318,484.18 0.20 1,033.86 MWD+SC+sag(2) 6,148.51 16.03 109.39 6,004.70 5,826.47 -399.45 972.38 2,433,642.65 318,500.42 0.64 1,051.23 MWD+SC+sag(2) 6,210.60 15.95 109.09 6,064.39 5,886.16 -405.09 988.53 2,433,636.77 318,516.48 0.19 1,068.31 MWD+SC+sag(2) 6,271.90 15.77 109.08 6,123.36 5,945.13 -410.57 1,004.36 2,433,631.04 318,532.23 0.29 1,085.03 MWD+SC+sag(2) 6,334.70 15.81 108.54 6,183.79 6,005.56 -416.08 1,020.54 2,433,625.28 318,548.31 0.24 1,102.08 MWD+SC+sag(2) 6,395.94 15.62 109.19 6,242.74 6,064.51 -421.44 1,036.24 2,433,619.68 318,563.92 0.42 1,118.64 MWD+SC+sag(2) 6,457.18 15.37 108.52 6,301.75 6,123.52 -426.73 1,051.72 2,433,614.15 318,579.32 0.50 1,134.96 MWD+SC+sag(2) 6,519.50 16.19 111.67 6,361.72 6,183.49 -432.56 1,067.62 2,433,608.08 318,595.14 1.90 1,151.89 MWD+SC+sag(2) 6,581.94 16.29 112.69 6,421.67 6,243.44 -439.15 1,083.79 2,433,601.23 318,611.20 0.48 1,169.35 MWD+SC+sag(2) 6,644.11 15.96 112.90 6,481.40 6,303.17 -445.84 1,099.71 2,433,594.30 318,627.02 0.54 1,186.62 MWD+SC+sag(2) 6,705.56 15.63 112.67 6,540.53 6,362.30 -452.32 1,115.13 2,433,587.58 318,642.33 0.55 1,203.35 MWD+SC+sag(2) 6,767.41 15.48 112.55 6,600.11 6,421.88 -458.70 1,130.44 2,433,580.97 318,657.54 0.25 1,219.93 MWD+SC+sag(2) 6,830.20 15.51 112.86 6,660.62 6,482.39 -465.17 1,145.92 2,433,574.26 318,672.92 0.14 1,236.71 MWD+SC+sag(2) 6,892.03 16.50 116.72 6,720.05 6,541.82 -472.33 1,161.38 2,433,566.86 318,688.27 2.35 1,253.73 MWD+SC+sag(2) 6,954.60 16.64 117.36 6,780.02 6,601.79 -480.44 1,177.27 2,433,558.50 318,704.03 0.37 1,271.52 MWD+SC+sag(2) 7,016.64 16.52 115.96 6,839.48 6,661.25 -488.39 1,193.09 2,433,550.31 318,719.73 0.67 1,289.17 MWD+SC+sag(2) 7,077.88 16.22 116.26 6,898.24 6,720.01 -495.98 1,208.59 2,433,542.48 318,735.11 0.51 1,306.40 MWD+SC+sag(2) 7,140.60 15.96 117.04 6,958.50 6,780.27 -503.78 1,224.13 2,433,534.44 318,750.52 0.54 1,323.73 MWD+SC+sag(2) 7,203.09 15.66 116.11 7,018.63 6,840.40 -511.40 1,239.35 2,433,526.59 318,765.62 0.63 1,340.71 MWD+SC+sag(2) 7,265.00 15.61 115.45 7,078.25 6,900.02 -518.65 1,254.38 2,433,519.10 318,780.54 0.30 1,357.37 MWD+SC+sag(2) 7,326.58 15.48 114.83 7,137.58 6,959.35 -525.66 1,269.32 2,433,511.86 318,795.36 0.34 1,373.86 MWD+SC+sag(2) 7,387.90 15.22 114.63 7,196.71 7,018.48 -532.45 1,284.06 2,433,504.84 318,810.00 0.43 1,390.08 MWD+SC+sag(2) 7,450.41 15.13 113.95 7,257.04 7,078.81 -539.19 1,298.97 2,433,497.88 318,824.81 0.32 1,406.43 MWD+SC+sag(2) 7,511.97 15.03 113.54 7,316.48 7,138.25 -545.64 1,313.63 2,433,491.21 318,839.37 0.24 1,422.44 MWD+SC+sag(2) 7,573.61 15.01 114.17 7,376.01 7,197.78 -552.10 1,328.24 2,433,484.52 318,853.88 0.27 1,438.41 MWD+SC+sag(2) 7,636.32 14.88 113.68 7,436.60 7,258.37 -558.65 1,343.03 2,433,477.73 318,868.55 0.29 1,454.58 MWD+SC+sag(2) 7,698.22 14.73 113.11 7,496.45 7,318.22 -564.93 1,357.54 2,433,471.23 318,882.97 0.34 1,470.40 MWD+SC+sag(2) 7,760.96 14.50 113.35 7,557.16 7,378.93 -571.18 1,372.09 2,433,464.76 318,897.42 0.38 1,486.22 MWD+SC+sag(2) 7,821.03 15.39 115.91 7,615.20 7,436.97 -577.64 1,386.16 2,433,458.08 318,911.39 1.84 1,501.70 MWD+SC+sag(2) 7,885.23 15.66 115.68 7,677.05 7,498.82 -585.12 1,401.64 2,433,450.37 318,926.75 0.43 1,518.86 MWD+SC+sag(2) 7,947.52 15.54 115.67 7,737.05 7,558.82 -592.38 1,416.73 2,433,442.87 318,941.73 0.19 1,535.58 MWD+SC+sag(2) 8,006.99 15.31 115.39 7,794.38 7,616.15 -599.19 1,431.01 2,433,435.84 318,955.90 0.41 1,551.38 MWD+SC+sag(2) 8,022.19 15.26 115.45 7,809.04 7,630.81 -600.91 1,434.62 2,433,434.06 318,959.49 0.35 1,555.38 MWD+SC+sag(2) 8,087.46 15.15 115.92 7,872.02 7,693.79 -608.33 1,450.05 2,433,426.40 318,974.80 0.25 1,572.47 MWD+SC+sag(2) 8,148.31 14.99 115.03 7,930.78 7,752.55 -815.14 1,464.33 2,433,419.38 318,988.97 0.46 1,588.27 MWD+SC+sag(2) 8,211.60 14.96 113.85 7,991.92 7,813.69 -621.91 1,479.22 2,433,412.38 319,003.76 0.48 1,604.61 MWD+SC+sag(2) 8,272.40 16.00 114.50 8,050.52 7,872.29 -628.55 1,494.02 2,433,405.51 319,018.45 1.73 1,620.83 MWD+SC+sag(2) 8,335.77 16.09 114.74 8,111.42 7,933.19 -635.85 1,509.95 2,433,397.96 319,034.26 0.18 1,638.33 MWD+SC+sag(2) 8,398.20 15.93 114.60 8,171.43 7,993.20 -643.04 1,525.59 2,433,390.54 319,049.80 0.26 1,655.54 MWD+SC+sag(2) 8,459.27 15.80 114.13 8,230.17 8,051.94 -649.92 1,540.80 2,433,383.41 319,064.89 0.30 1,672.23 MWD+SC+sag(2) 9/23/2014 6:43:27PM Page 5 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 23 Project: Beaver Creek Unit TVD Reference: Actual:BCU 23 @ 178.23usft Site: Beaver Creek Unit MD Reference: Actual:BCU 23 @ 178.23usft Well: Beaver CK Unit 23 North Reference: True Wellbore: BCU 23 Survey Calculation Method: Minimum Curvature Design: BCU 23 Rig Surveys Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°I100') (ft) Survey Tool Name 8,522.86 15.65 114.32 8,291.38 8,113.15 -657.00 1,556.52 2,433,376.10 319,080.50 0.25 1,689.45 MWD+SC+sag(2) 8,583.28 16.19 112.13 8,349.48 8,171.25 -663.53 1,571.75 2,433,369.34 319,095.63 1.34 1,706.02 MWD+SC+sag(2) 8,644.96 16.30 111.86 8,408.70 8,230.47 669.99 1,587.75 2,433,362.63 319,111.52 0.22 1,723.28 MWD+SC+sag(2) 8,706.88 18.10 111.53 8,468.18 8,289.93 -676.37 1,603.80 2,433,355.99 319,127.47 0.36 1,740.55 MWD+SC+sag(2) 8,769.59 15.69 111.90 8,528.47 8,350.24 -682.73 1,619.75 2,433,349.39 319,143.33 0.67 1,757.72 MWD+SC+sag(2) 8,830.87 15.59 110.42 8,587.49 8,409.26 -688.69 1,635.16 2,433,343.19 319,158.64 0.67 1,774.24 MWD+SC+sag(2) 8,892.91 15.10 110.55 8,647.31 8,469.08 -694.44 1,650.54 2,433,337.21 319,173.93 0.79 1,790.64 MWD+SC+sag(2) 8,955.10 14.54 111.25 8,707.43 8,529.20 -700.11 1,665.40 2,433,331.31 319,188.70 0.95 1,806.54 MWD+SC+sag(2) 9,019.00 15.15 109.82 8,769.20 8,590.97 -705.85 1,680.73 2,433,325.33 319,203.94 1.11 1,822.91 MWD+SC+sag(2) 9,080.01 16.25 109.65 8,827.93 8,649.70 -711.42 1,696.27 2,433,319.52 319,219.39 1.80 1,839.40 MWD+SC+sag(2) 9,142.25 16.52 110.11 8,887.65 8,709.42 -717.39 1,712.78 2,433,313.29 319,235.81 0.48 1,856.93 MWD+SC+sag(2) 9,202.98 16.21 109.76 8,945.92 8,767.69 -723.23 1,728.87 2,433,307.21 319,251.80 0.54 1,874.03 MWD+SC+sag(2) 9,264.98 15.89 109.56 9,005.50 8,827.27 -728.99 1,745.01 2,433,301.19 319,267.85 0.52 1,891.15 MWD+SC+sag(2) 9,327.63 15.72 108.83 9,065.78 8,887.55 -734.61 1,761.12 2,433,295.33 319,283.88 0.42 1,908.18 MWD+SC+sag(2) 9,389.35 15.61 108.98 9,125.21 8,946.98 -740.00 1,776.89 2,433,289.69 319,299.56 0.19 1,924.82 MWD+SC+sag(2) 9,452.67 15.30 108.83 9,186.24 9,008.01 -745.47 1,792.85 2,433,283.98 319,315.44 0.49 1,941.66 MWD+SC+sag(2) 9,514.40 15.14 ' 108.86 9,245.80 9,067.57 -750.71 1,808.19 2,433,278.51 319,330.69 0.26 1,957.83 MWD+SC+sag(2) 9,576.48 15.02 107.93 9,305.75 9,127.52 -755.80 1,823.51 2,433,273.17 319,345.94 0.44 1,973.94 MWD+SC+sag(2) 9,638.28 14.87 107.28 9,365.46 9,187.23 -760.62 1,838.71 2,433,268.12 319,361.05 0.36 1,989.82 MWD+SC+sag(2) 9,700.87 14.80 107.51 9,425.96 9,247.73 -765.42 1,854.00 2,433,263.09 319,376.27 0.15 2,005.78 MWD+SC+sag(2) 9,762.30 14.60 107.63 9,485.38 9,307.15 -770.12 1,868.86 2,433,258.16 319,391.05 0.33 2,021.31 MWD+SC+sag(2) 9,825.29 14.60 107.02 9,546.33 9,368.10 -774.85 1,884.02 2,433,253.19 319,406.14 0.24 2,037.13 MWD+SC+sag(2) 9,885.34 14.13 106.80 9,604.51 9,426.28 -779.18 1,898.27 2,433,248.64 319,420.32 0.79 2,051.96 MWD+SC+sag(2) 9,947.94 12.67 110.08 9,665.40 9,487.17 -783.75 1,912.03 2,433,243.86 319,434.01 2.63 2,066.42 MWD+SC+sag(2) 10,009.78 11.86 112.45 9,725.83 9,547.60 -788.50 1,924.28 2,433,238.92 319,446.18 1.54 2,079.55 MWD+SC+sag(2) 10,072.73 10.81 113.45 9,787.55 9,609.32 -793.32 1,935.67 2,433,233.92 319,457.50 1.70 2,091.92 MWD+SC+sag(2) 10,134.55 9.73 114.47 9,848.38 9,670.15 -797.79 1,945.74 2,433,229.30 319,467.50 1.77 2,102.94 MWD+SC+sag(2) 10,196.48 7.52 114.51 9,909.61 9,731.38 -801.64 1,954.20 2,433,225.32 319,475.89 3.57 2,112.22 MWD+SC+sag(2) 10,258.77 6.41 112.70 9,971.44 9,793.21 -804.68 1,961.11 2,433,222.18 319,482.76 1.82 2,119.77 MWD+SC+sag(2) 10,319.97 5.36 117.34 10,032.31 9,854.08 -807.31 1,966.80 2,433,219.46 319,488.41 1.88 2,126.04 MWD+SC+sag(2) 10,383.06 4.59 119.05 10,095.16 9,916.93 -809.89 1,971.63 2,433,216.80 319,493.20 1.24 2,131.48 MWD+SC+sag(2) 10,445.29 4.22 119.31 10,157.21 9,978.98 -812.22 1,975.80 2,433,214.41 319,497.33 0.60 2,136.23 MWD+SC+sag(2) 10,506.83 3.08 120.08 10,218.62 10,040.39 -814.15 1,979.21 2,433,212.42 319,500.71 1.85 2,140.11 MWD+SC+sag(2) 10,567.52 3.09 121.62 10,279.23 10,101.00 -815.83 1,982.01 2,433,210.70 319,503.48 0.14 2,143.35 MWD+SC+sag(2) 10,630.11 2.81 121.22 10,341.73 10,163.50 -817.51 1,984.76 2,433,208.98 319,506.21 0.45 2,146.53 MWD+SC+sag(2) 10,693.09 2.77 117.66 10,404.64 10,226.41 -819.02 1,987.43 2,433,207.43 319,508.85 0.28 2,149.57 MWD+SC+sag(2) 10,754.85 2.76 120.11 10,466.33 10,288.10 -820.45 1,990.04 2,433,205.95 319,511.44 0.19 2,152.53 MWD+SC+sag(2) 10,817.19 2.67 116.01 10,528.60 10,350.37 -821.84 1,992.64 2,433,204.52 319,514.02 0.34 2,155.47 MWD+SC+sag(2) 10,878.06 2.37 120.76 10,589.41 10,411.18 -823.11 1,994.99 2,433,203.22 319,516.35 0.60 2,158.13 MWD+SC+sag(2) 10,913.31 2.18 122.67 10,624.63 10,446.40 -823.84 1,996.19 2,433,202.47 319,517.53 0.58 2,159.51 MWD+SC+sag(2) 9/23/2014 6'43'27PM Page 6 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 23 Project: Beaver Creek Unit TVD Reference: Actual:BCU 23 @ 178.23usft Site: Beaver Creek Unit MD Reference: Actual:BCU 23 @ 178.23usft Well: Beaver CK Unit 23 North Reference: True Wellbore: BCU 23 Survey Calculation Method: Minimum Curvature Design: BCU 23 Rig Surveys Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100 (ft) Survey Tool Name 10,974.80 1.45 131.70 10,686.09 10,507.86 -824.99 1,997.75 2,433,201.30 319,519.08 1.27 2,161.39 MWD+SC+sag(2) 11,036.55 1.41 138.50 10,747.82 10,569.59 -826.08 1,998.84 2,433,200.19 319,520.15 0.28 2,162.81 MWD+SC+sag(2) 11,099.26 1.06 140.77 10,810.52 10,632.29 -827.11 1,999.72 2,433,199.15 319,521.01 0.56 2,164.02 MWD+SC+sag(2) 11,141.00 1.06 140.77 10,852.25 . 10,674.02 -827.71 2,000.20 2,433,198.54 319,521.49 0.00 2,164.70 PROJECTED to TD Checked By: Approved By: Date: 9/23/2014 6:43:27PM Page 7 COMPASS 5000.1 Build 70 4. -- o G o — 6 N • - N 0 ee Cr O ITN O - N N/4 �0 Z 8 1- _ 0 .3 c'• 2>> N - O —O F 11 000,.* _ o N N N N l N It\ try h Z 7 @m / •• vU - O ""'off O cYi N N OOS6 . —rn —a. <1 r0 gmme w g 0 0 =mm- O . • 5 - o W LL ttS- U —0 z 3aa� Iq - F U d $ 0006 CaM a'a'K 0528/ —. W _ LL ?o tss ' / X0,1 -- O Op58 U - o e- �u / —o h r z 5 o> es„,, U § _ N - 3 0 00 09/ —0 o 0 v+i o 04:x, / - 0 o o OOSI _ 05Z, - o m OOOI - - o —o 059cv / - G E c N0059 =Si a ». --o a) aa))D OSe9 _ ., ten o a)Y - UUUr)cr) _o v_ N N 0009 o > > >J D aa)i a) aa)iUU0 •°01/ _ mmmmm 54 - C u 0— m mc 3 a).- - o •N 0p55 3 o��JDa - d j OSIS —c, 0905 - - 0 —o 054 004 —o 054 _ - o —o 000b Oc4 —o 0011 _ - 0 --o Ogee/p/..,' , to = m 0001 / O —o N °-f// L^ vFwvv - O,S`,e ZCO LLIyMON - „, 2u) N2 - O 2r ffi yE,8 —o FC ca�U �n _ OZ ��C mm / .0/i wu 2ta 10m 05 2 COo O •5 Ea C ,- Z o ar , -_ m _ I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I.I I I I I I I I I I I I I I I I I I I wiliiIIIIIiiiiiiiiiiiiiiiiiiiI-N J 6 o o 00 0 0 0 0 0 0 0 0 0 0 0 8 8 J V M N ‘..1 M 7 so l• n 01 o N M _ 4 0 (u►AIsn OSZ)(+)111JoN/(-)q1n:s t: Beaver Creek Unit WELL DETAILS: Beavr t23 NAD 1927(NADCONCONUS) Alaska Zone 04 HALLIBURT©N Site: Beaver Creek Unit Ground Level: 160.23 Well: Beaver CK Unit 23 +N/-S +EI-W Northing Easting Latittude Longitude Slot Sperry Drifting Servloea Wellbore: BCU 23 0.00 0.00 2434057.10 317534.34 60.6585815 -151.0170661 Plan: BCU 23 REFERENCE INFORMATION Co-ordinate(N/E)Reference:Well Beaver CK Unit 23,True North -1000— Vertical(TVD)Reference:Actual:BCU 23 178.23usf1 Measured Depth Reference:Actual:BCU 23 @j 178.23usft — Calculation Method:Minimum Curvature -500- 0- 500- 500 1000- 1000 1500- 1500 2000- 2000 2500- 25p0 3000- 30p0 3500- ---. 3500 - 9 5/8" 4000- 4000 - 45p0 4500 7 - o 5000 Lo 5000— _C 55p0 ±Z 5500- a) — o - 6000 U 6000- N - 65p0 6500- a) - ¶000 - 7000— "15p0 7500- _ g000 8000- = 65p0 8500- _ gp00 9000- 9500 9500- 10000 10000- I 10500 10500 11000 7°__ 11t41 11000- - BCU 23 BHL tgt wp2 BCU 23 11500- BCU 23 WP4.0 12000 111111111111111 I l till 11111111111111111111111111111111111111111111111111 1 111111111111111111111111 11t 1 1 1111111 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 Vertical Section at 112.48° (1500 usft/in) BCU 23 Definitive Surveys H HEADER INFORMATION H COMPANY : Hilcorp Energy Company H FIELD : Beaver Creek Unit H SITE : Beaver Creek Unit H WELL : Beaver CK Unit 23 H WELLPATH: BCU 23 H DEPTHUNT: usft H SURVDATE: 9/23/2014 H H WELL INFORMATION H WELL EW MAP : 317534.34 H WELL NS MAP : 2434057.10 H DATUM ELEVN : 178.23 H VSECT ANGLE : 112.48 H VSECT NORTH : 0.00 H VSECT EAST : 0.00 H H SURVEY TYPE INFORMATION H 196.77 - 3357.77 MWD+SC+SAG : MWD+SC+SAG H 3416.01 - 11099.26 MWD+SC+SAG : MWD+SC+SAG H H SURVEY LIST H MD INC AZI TVD NS EW 18.00 0.00 0.00 18.00 0.00 0.00 196.77 0.23 320.70 196.77 0.28 -0.23 253.46 0.27 356.37 253.46 0. 50 -0.31 325.96 0.30 349.64 325.96 0.86 -0.35 387.28 0.58 350.91 387.28 1.32 -0.43 445.33 0.38 346.01 445.32 1.80 -0.52 506.81 0.30 353.80 506.80 2.16 -0.59 568.71 0.22 320.11 568.70 2.41 -0.68 631.39 0.00 339.37 631.38 2. 50 -0.76 693.17 0.23 266.44 693.16 2.49 -0.88 754.42 0.26 255.43 754.41 2.45 -1.14 815.27 0.29 281.76 815.26 2.45 -1.43 878.26 0.01 224.27 878.25 2.47 -1.59 942.10 0.10 223.86 942.09 2.43 -1.63 1001.23 0.33 267.27 1001.22 2.39 -1.83 1063.67 0.34 238.47 1063.66 2.28 -2.17 1125.69 0.13 256.71 1125.68 2.17 -2.40 1185.49 0.55 259.45 1185.48 2.10 -2.75 1249.18 0.49 271.18 1249.16 2.05 -3.32 1311.77 0.28 296. 59 1311.75 2.12 -3.72 1374.18 0.36 251.84 1374.16 2.13 -4.05 1498.12 0.10 241.57 1498.10 1.96 -4.51 1622.89 0.54 239.40 1622.87 1.61 -5.11 1684.83 0.48 238.13 1684.81 1.32 -5. 58 1746.20 0.39 227.37 1746.17 1.04 -5.96 1808.83 0. 53 247.11 1808.80 0.79 -6.38 1931.96 0.41 186.65 1931.93 0.13 -6.96 1995.68 1.05 119.02 1995.64 -0.38 -6.47 2057.05 1.66 107.33 2057.00 -0.92 -5.13 2119.33 3.57 107.01 2119.21 -1.76 -2.42 2181.93 4.70 106.02 2181.65 -3.03 1.91 2244.76 6.90 101.98 2244.15 -4.53 8.08 2304. 55 8. 57 100.12 2303.39 -6.06 15.98 2366.83 11.51 102.21 2364.71 -8.19 26.62 2428.45 13.00 103.68 2424.93 -11.13 39.37 2490.45 14.25 106.35 2485.18 -14.92 53.47 2553.11 15.31 108.76 2545.77 -19.75 68.70 2614.00 16.08 111.96 2604.39 -25.49 84.13 2675.64 16.35 111.93 2663.58 -31.93 100.10 2736.77 16.26 111.25 2722.25 -38.24 116.06 Page 1 BCU 23 Definitive surveys 2799.66 16.05 111.73 2782.66 -44.65 132.34 2862.48 16.08 110.67 2843.02 -50.94 148. 54 2923.28 16.01 110.85 2901.45 -56.89 164.26 2985.35 16.06 113.84 2961.11 -63.41 180.11 3047.41 15.98 115.03 3020.76 -70.49 195.70 3109.83 15.80 115.04 3080.80 -77.73 211.19 3171.88 15.64 115.30 3140.52 -84.88 226.40 3234.47 15.72 115.45 3200.79 -92.13 241.69 3296.13 15.62 114.95 3260.15 -99.22 256.75 3357.77 15.14 115.26 3319. 59 -106.15 271. 56 3416.01 15.22 114.94 3375.79 -112.62 285.37 3478.13 15.35 114.78 3435.72 -119. 51 300.23 3538.88 15.36 114.09 3494.30 -126.16 314.87 3602.43 15.37 114.35 3555.58 -133.07 330.23 3664.00 15.47 113.17 3614.93 -139.66 345.21 3726.25 16.52 113.91 3674.77 -146.52 360.94 3787.45 16.59 113.62 3733.43 -153.54 376.90 3850.49 16.69 113.31 3793.83 -160.73 393.45 3911.87 16.65 113.09 3852.63 -167.67 409.64 3975.09 16.47 112. 50 3913.23 -174.65 426.25 4036.38 16.46 112.48 3972.01 -181.29 442.30 4098.93 16.44 111.90 4032.00 -187.98 458.70 4160.58 16.35 111.34 4091.14 -194.40 474.88 4222.78 16.39 111.85 4150.82 -200.85 491.18 4285.74 16.29 111.31 4211.24 -207.36 507.65 4347.73 16.23 111.77 4270.75 -213.74 523.79 4409.70 16.06 110.89 4330.27 -220.00 539.84 4469.86 15.97 110.85 4388.10 -225.92 555.35 4533.71 16.08 113.98 4449.47 -232.64 571.64 4595.41 16.11 115.13 4508.75 -239.75 587.20 4657.98 16.03 114.39 4568.87 -247.00 602.93 4720.04 16.02 114.42 4628.52 -254.08 618. 53 4781.42 15.69 114.30 4687.57 -261.00 633.80 4843.22 15.63 114.20 4747.07 -267.85 649.01 4904.18 15.46 114.24 4805.80 -274.55 663.91 4967.04 15.21 113.49 4866.43 -281.28 679.11 5029. 52 15.11 113. 53 4926.73 -287.79 694.10 5091.94 15.08 112.91 4987.00 -294.20 709.03 5153.29 15.14 112.74 5046.23 -300.41 723.77 5214.62 15.00 112.16 5105.45 -306. 50 738.51 5277.47 14.94 112.36 5166.16 -312.65 753.54 5340.17 14.88 111.75 5226.75 -318.70 768.49 5401.11 14.65 111.74 5285.68 -324.46 782.91 5463.37 14.73 111.25 5345.91 -330.24 797.60 5526.84 14.68 110.82 5407.30 -336.02 812.64 5587.32 14.75 110.86 5465.79 -341.49 827.00 5651.56 16.17 113.02 5527.71 -347.90 842.88 5713.00 16.39 112.89 5586.68 -354.62 858.74 5775.28 16.38 112.16 5646.44 -361.35 874.96 5837.98 16.41 112.36 5706.59 -368.05 891.34 5899.24 16.33 112.37 5765.36 -374.62 907.31 5962.07 16.33 111. 57 5825.66 -381.23 923.69 6024.13 16.14 110.49 5885.24 -387.46 939.88 6085.98 16.26 110.58 5944.64 -393. 51 956.04 6148.51 16.03 109.39 6004.70 -399.45 972.38 6210.60 15.95 109.09 6064.39 -405.09 988.53 6271.90 15.77 109.08 6123.36 -410.57 1004.36 6334.70 15.81 108.54 6183.79 -416.08 1020.54 6395.94 15.62 109.19 6242.74 -421.44 1036.24 6457.18 15.37 108.52 6301.75 -426.73 1051.72 6519.50 16.19 111.67 6361.72 -432. 56 1067.62 6581.94 16.29 112.69 6421.67 -439.15 1083.79 6644.11 15.96 112.90 6481.40 -445.84 1099.71 Page 2 BCU 23 Definitive Surveys 6705.56 15.63 112.67 6540.53 -452.32 1115.13 6767.41 15.48 112. 55 6600.11 -458.70 1130.44 6830.20 15. 51 112.86 6660.62 -465.17 1145.92 6892.03 16. 50 116.72 6720.05 -472.33 1161.38 6954.60 16.64 117.36 6780.02 -480.44 1177.27 7016.64 16. 52 115.96 6839.48 -488.39 1193.09 7077.88 16.22 116.26 6898.24 -495.98 1208.59 7140.60 15.96 117.04 6958.50 -503.78 1224.13 7203.09 15.66 116.11 7018.63 -511.40 1239.35 7265.00 15.61 115.45 7078.25 -518.65 1254.38 7326.58 15.48 114.83 7137. 58 -525.66 1269.32 7387.90 15.22 114.63 7196.71 -532.45 1284.06 7450.41 15.13 113.95 7257.04 -539.19 1298.97 7511.97 15.03 113. 54 7316.48 -545.64 1313.63 7573.61 15.01 114.17 7376.01 -552.10 1328.24 7636.32 14.88 113.68 7436.60 -558.65 1343.03 7698.22 14.73 113.11 7496.45 -564.93 1357. 54 7760.96 14. 50 113.35 7557.16 -571.18 1372.09 7821.03 15.39 115.91 7615.20 -577.64 1386.16 7885.23 15.66 115.68 7677.05 -585.12 1401.64 7947.52 15. 54 115.67 7737.05 -592.38 1416.73 8006.99 15.31 115.39 7794.38 -599.19 1431.01 8022.19 15.26 115.45 7809.04 -600.91 1434.62 8087.46 15.15 115.92 7872.02 -608.33 1450.05 8148.31 14.99 115.03 7930.78 -615.14 1464.33 8211.60 14.96 113.85 7991.92 -621.91 1479.22 8272.40 16.00 114. 50 8050.52 -628.55 1494.02 8335.77 16.09 114.74 8111.42 -635.85 1509.95 8398.20 15.93 114.60 8171.43 -643.04 1525.59 8459.27 15.80 114.13 8230.17 -649.92 1540.80 8522.86 15.65 114.32 8291.38 -657.00 1556.52 8583.28 16.19 112.13 8349.48 -663. 53 1571.75 8644.96 16.30 111.86 8408.70 -669.99 1587.75 8706.88 16.10 111.53 8468.16 -676.37 1603.80 8769.59 15.69 111.90 8528.47 -682.73 1619.75 8830.87 15.59 110.42 8587.49 -688.69 1635.16 8892.91 15.10 110.55 8647.31 -694.44 1650.54 8955.10 14.54 111.25 8707.43 -700.11 1665.40 9019.00 15.15 109.82 8769.20 -705.85 1680.73 9080.01 16.25 109.65 8827.93 -711.42 1696.27 9142.25 16.52 110.11 8887.65 -717.39 1712.78 9202.98 16.21 109.76 8945.92 -723.23 1728.87 9264.98 15.89 109.56 9005.50 -728.99 1745.01 9327.63 15.72 108.83 9065.78 -734.61 1761.12 9389.35 15.61 108.98 9125.21 -740.00 1776.89 9452.67 15.30 108.83 9186.24 -745.47 1792.85 9514.40 15.14 108.86 9245.80 -750.71 1808.19 9576.48 15.02 107.93 9305.75 -755.80 1823. 51 9638.28 14.87 107.28 9365.46 -760.62 1838.71 9700.87 14.80 107.51 9425.96 -765.42 1854.00 9762.30 14.60 107.63 9485.38 -770.12 1868.86 9825.29 14.60 107.02 9546.33 -774.85 1884.02 9885.34 14.13 106.80 9604. 51 -779.18 1898.27 9947.94 12.67 110.08 9665.40 -783.75 1912.03 10009.78 11.86 112.45 9725.83 -788. 50 1924.28 10072.73 10.81 113.45 9787. 55 -793.32 1935.67 10134. 55 9.73 114.47 9848.38 -797.79 1945.74 10196.48 7.52 114. 51 9909.61 -801.64 1954.20 10258.77 6.41 112.70 9971.44 -804.68 1961.11 10319.97 5.36 117.34 10032.31 -807.31 1966.80 10383.06 4.59 119.05 10095.16 -809.89 1971.63 10445.29 4.22 119.31 10157.21 -812.22 1975.80 10506.83 3.08 120.08 10218.62 -814.15 1979.21 Page 3 BCU 23 Definitive surveys 10567.52 3.09 121.62 10279.23 -815.83 1982.01 10630.11 2.81 121.22 10341.73 -817. 51 1984.76 10693.09 2.77 117.66 10404.64 -819.02 1987.43 10754.85 2.76 120.11 10466.33 -820.45 1990.04 10817.19 2.67 116.01 10528.60 -821.84 1992.64 10878.06 2.37 120.76 10589.41 -823.11 1994.99 10913.31 2.18 122.67 10624.63 -823.84 1996.19 10974.80 1.45 131.70 10686.09 -824.99 1997.75 11036.55 1.41 138. 50 10747.82 -826.08 1998.84 11099.26 1.06 140.77 10810.52 -827.11 1999.72 11141.00 1.06 140.77 10852.25 -827.71 2000.20 Page 4 BCU 23 Days Vs Depth 0 _ BCU 23 ACTUAL BCU 23 Plan 2000 — — _ 4000 6000 C11 41 8000 10000 12000 0 5 10 15 20 25 30 35 Days BCU 23 MW Vs Depth 0 - 500 1000 1500 2000 2500 3000 3500 4000 4500 -MW vs Depth 5000 - -BCU 23 Plan 5500 aJ 6000 a m 6500 7000 7500 8000 8500 9000 9500 10000 10500 I 1.%1')--2_ 11000 11500 12000 - -- 8 9 10 11 12 13 14 Mud Density(ppg) • 1 Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No BCU 23 Date 30-Aug-14 County Kenai Peninsula Borough State Alaska Supv Grubb/Sweetsir CASING RECORD TD 3410 00 Shoe Depth 3399 00 PBTD Casing(Or Liner)Detail Setting Depths No of Jts Size Wt Grade THD Make Length Bottom Top Shoe 9 5/8 BTC Davis Lynch 1.67 3,399.00 3,397.83 2 jts 9 5/8 40 L-80 BTC 82.87 3,397.83 3,314.96 Flt Or 9 5/8 BTC Davis Lynch 1.44 3,314.96 3,313.52 80 jts 9 5/8 40 L-80 BTC 3,290.05 3,313.52 23.47 Pup Jt 9 5/8 40 L-80 BTC 4.62 23.47 18.85 Hanger 0.85 18.85 18.00 RKB 18.00 18.00 0.00 Csg Wt On Hook 135k Type Float Collar Davis Lynch No Hrs to Run 12 Csg Wt On Slips Type of Shoe Bull Nose Casing Crew WFD Fluid Description 9 3 Spud Mud Liner hanger Info(Make/Model) Liner top Packer's _Yes_No Liner hanger test pressure Centralizer Placement 1 centralizer on every other joint CEMENTING REPORT Preflush(Spacer) Type Mud Push II Density(ppg) 1 5 Volume pumped(BBLs) 35 Lead Slurry — Type Lead 5q..) S Y- Density(ppg) 12 Volume pumped(BBLs) 262 Mixing/Pumping Rate(bpm) 5 7 Tall Slurry Type Tail t4 Density(ppg) 15 4 Volume pumped(BBLs) 43 Mixing/Pumping Rate(bpm) 5 w Post Flush(Spacer) `r I ! t JJ I)41 Type Density(ppg) Rate(bpm) Volume ,i,4- _ r , Displacement: ��r .] n Type Water Density(ppg) 8 32 Rate(bpm) 6 Volume(actual/calculated) 253/251 l� /�i r 1 'i FCP(psi) 1100 Pump used for disp Schlumberger Plug Bumped' x Yes No Bump press 1625•' G C F vv 1 Casing Rotated? m Yes x No Reciprocated? x Yes No 68%Retus during job C86%" n,LN" 1 , Cement returns to surface? x Yes No Spacer returns? Yes x No Vol to Surf 16 PNrY ! 1I, ^' y " Cement In Place At 0 50 Date 8/30/2014 Estimated TOC Surface • Y Method Used To Determine TOC Preflush(Spacer) Type Density(ppg) Volume pumped(BBLs) Lead Slurry Type Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm) Tall Slurry w Type a Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm) N Post Flush(Spacer) 0 o z Type Density(ppg) Rate(bpm) Volume _. 2 Displacement: to 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 WELLHEAD Make CIW Type Serial No Size 16x11 W P 5000 Test Head To 250/5000 PSIG 15 MIN test good OK Remarks • • 4 Hilcorp Energy Company CASING&CEMENTING REPORT Lease 8 Well No BCU-23 Date 17-Sep-14 County Kenai Peninsula Borough State Alaska Supv Joe Grubb/Jimmy Greco CASING RECORD TD 11141 00 Shoe Depth 11128 50 PBTD 11043 00 Casing(Or Liner)Detail Setting Depths No of Jts Size Wt Grade THD Make Length Bottom Top Shoe 51/2 I WED model 30: 1.55 11,128.48 11,126.93 2 joints 51/2 17 1 P no Geo Con 82.35 11,088.47 11,044.58 _ Flt Clr 51/2 WFD mod#40; 1.27 11,044.58 11,043.31 l5jts w/4 RA to 51/2 17 P110 Geo Con 8,012.03 11,043.31 3,031.28 Swell PKR 21.04 3,031.28 3,010.24 51 jts 51/2 17 _ P110 Geo Con 2,207.63 846.82 2,967.00 xo jt 5 1/2 17 P110 :o con X C 41.53 802.61 761.08 17 jts 51/2 17 P110 CDC 739.00 66.76 716.45 Hanger 4.08 18.75 18.75 Landing jt 18.00 18.00 0.00 Totals Csg Wt On Hook 176,279 Type Float Collar Model 402 No Hrs to Run Csg Wt On Slips Type of Shoe Bull Nose/303 Casing Crew WFD Fluid Descnption 10 9 ppg 6%kcl/polymer,PV 12,YP 17 Liner hanger Info(Make/Model) Liner top Packer? _Yes X No Liner hanger test pressure 0 Centralizer Placement 1 free floating Valant centralizer per joint T/It 91-1 every other jt F/jt 91 thrult 175 CEMENTING REPORT Preflush(Spacer) Type Mud Push II Density(ppg) 10 5 Volume pumped(BBLs) 35 Lead Slurry Type EazyBlok IV7>S4 Density(ppg) 15 3 Volume pumped(BBLs) 454 Mixing/Pumping Rate(bpm) 4 9 Tall Slurry Type j Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm) N Post Flush(Spacer) t re Type Density(ppg) Rate(bpm) Volume t"1/ IL Displacement: Type 3%kcl Density(ppg) 8 5 Rate(bpm) 6 Volume(actual/calculated) 256/257 a 3 O�j FCP(psi) 3400 Pump used for disp Schlumberger Plug Bumped? x Yes No Bump press 5076 ^G Casing Rotated? Yes x No Reciprocated? _Yes X No %Returns dunng job 100 f Imo(_) Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf Cement In Place At 21 50 Date 9/17/2014 Estimated TOC 3,000 n / (f Method Used To Determine TOC calculated bbls Ct.(�- LC(i Preflush(Spacer) Type Density(ppg) Volume pumped(BBLs) Lead Slurry Type Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm) Tall Slurry w Type a Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm) y Post Flush(Spacer) O o Type Density(ppg) Rate(bpm) Volume w Displacement: 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 dunng 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 WELLHEAD Make CIW Type Senal No Size 7 1/16 W P 5000 Test Head To 250/5000 PSIG 15 MIN test good OK Remarks ------ ------------/— --------,,,,,, ••''' __„„..- -------- _____ ,./ "P"' ,---- t ----- - --------1--- ---------*:---/ '"--„„C-s,,,Ns,,. , ' ti• ,/ / ,% r*" /7i __------i— -----: — -- '' / e,, \ \ \ --------- \ , \ 'ir , ., \., If o04 ------ 7-----..„. 7 / ,,,, , \ ',.,,. , '0 ------A-..„„ ---->‹, \- , / /7 ,-----4--- N .,„„;\ 00_ •.\“,„<" \ \ .,, , \\„/A.,(1-""\ \ \ \ \ \ \ k , \ , --x0 --\ \ '\ \ \ \ \ \ \ \ / \ \ /igi, 1 / ----- I—'-'• >k 50 / • / Q r.,, ', ,„ \ r t — ._.. 0 `---e„. 1 '-‘, 'lc \ \_.\ ‘ \ .. \ // (.0 ?.... ",„,/ , >, \ \ \ \ \ ‘,,, \ \\ /1 --- I ? .E" "2%-z- --'2, . \ \ \ \ \ • , \ Z * \ ', ,,, \ \ \ ' \ k \ \ \ A f 0 .. .„. ...,......._ ,, -, , .,_ \ i 1 , ! I 1 0 , - . - i i , I , 1 ,-.' 0 0 c) , ..4„, I 1 1 , , 0 „,„ ._;." C-1.---, ' I I i i -., .... t r ' . .- ... 1 i 41, 1 1 1 ) \ \ II\ \ \ \ \ * / / ' '4,..„ ' , • ‘,. ‘ ‘,„ \ N>,› 4.• 1 1",..,• , '," ',li \ \ ', ."-\'‘' \-. `'-.•..„, - • , / ''•• 1 i i / r ,`'`,,, ,' ' ''› ' / c,, , ''',/ '''''.---, I .._,....--."‘ ,,,,' >: / , i ,,, , , , 1 \ ' '12/ X - ' —---4.------t ,.•A''' '" '\. (13V".- •-"" r''' \ •-'' ' >'', ' ' -• ' '''," ,.° 1 -'`' 0 t•,. \ ' ''',. , - , -.,4, --------___---o- _ ,„ i , ,) 555 -,,,,,„ › ''",, '',. / """---.. ' .N. e ' '' )."-----.. -----/- / *---- ,\ ' i.'•,,t 1, ''''', ''' './\,. '---"— ---7------ --'-- -------A:: ---- ;`,,' i x -N, '-‘4.,..'c, I.".• '---7.'„ ---,- _ — - ,-,-----..______--i-cooi. "- - „ -' -- 1, ,,/ ___ 4,------— ,t,-' .„,...-- 1y/ V ,, ' b ---,_ / --__ —t---- ./ , , 1 S-S ,, ,__ / __ „ , • --- „-- .,-.- t ''''`~- ----.. ---7,-____________--2-' ------- ----.._ 7 -----------1--- - ---- -- '. I \t‘ A , NOON if 01” _____---------- • _ 1 1 s .l Nolan Hilcorp Alaska, L. GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 • Hiie.,rp ti:i.k:,.I.i.c Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 11/10/14 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 23 Elog data Prints: Reservoir Saturaton Tool Cement Evaluation Log CD: A Files Currently on the Disc (3) Ili Well Dlis 11/4!2014 8:39 AM File folder ji Well Las 11/4/2014 8:39 AM File folder Ai Well Log 11..4/2014 8:39 AM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: S . Nolan Hilcorp Alaska, L. GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 llilrurp Alaska.1.11. Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 10/22/14 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA T RA N S M ITTA BCU 23 Elog data Prints: ROP Rate of Penetration, DGR Dual Gamma Ray, EWR-Phase 4, ALD Azimuthal Lithodensity, CTN Compensated Thermal Neutron MD DGR Dual Gamma Ray, EWR-Phase 4, ALD Azimuthal Lithodensity, CTN Compensated Thermal Neutron TVD CD: ,; . CGM 9126,'20141:44 PM File folder DLIS+LAS 9126i20141:44 PM File folder , EMF 9/26/2014 1:44 PM File folder A, PDF 9126/220141:414 PM File folder TIFF 9126/2014 1:44 PM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: Nolan Hilcorp Alaska, L. GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Itarori, tl t L.i.I.I.( Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 10/22/2014 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 23 Mudlog data Prints: End of Well Report 2" MD Formation Evaluation Log 5" MD Formation Evaluation Log 2" MD Gas Ratio Log 2" MD Drilling Engineering Log CD: Final Well Data • = ies Currently on the Disc (5) 4. BEAVER CREEK UNIT 23 FINAL LOGS 10/2/2014 11:06 AM File folder . BEAVER CREEK UNIT 23 LAS EXPORTS 10/2/2014 11:06AM File folder ,j. EMF Leg Viewer 10/2,1201411:06AM File folder j, Halliburton Lcg Viewer 10/212014 11:06 AM File folder ® BEAVER CREEK UNIT 23 FINAL END OF W... PDF Document 4,447 KL Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: L .a Oudean Hilcorp Alaska, L. GeoTech II 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 IIdiri �I: t:.1.11Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 10/13/2014 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL Transmitted herewith are cuttings from BCU 23 WELL SAMPLE INTERVAL BCU 23 3440' - 4420' BCU 23 4440' - 5480' BCU 23 5500' - 6360' BCU 23 6380' - 7240' BCU 23 7260' - 8260' BCU 23 8280' - 9140' BCU 23 9160' - 10000' BCU 23 10020' - 10920' BCU 23 10940' - 11140' Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: rv,nr ryE Alaska Oil and Gas • 4``.1.,0!%y,'e I'tit: . s `'ALAS}:A Conservation Commission Ago- 333 West Seventh Avenue � 4 Anchorage,Alaska 99501-3572 �' Main:907.279.1433 Fax:907.276.7542 www.aogcc.alaska.gov Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek 23 Sundry Number: 314-639 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P.4.e_AA SLR-- Cathy P. oerster � .— Chair DATED this T�day of December, 2014. Encl. E IVED STATE OF ALASKA NOV6 �� -SM ALASKA OIL AND GAS CONSERVATION COMMISSION � ! I 0-SM ill APPLICATION FOR SUNDRY APPROVALS s l i 19L 20 MC 25.280 AO CC 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑., • Pull Tubing❑ Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development ❑] . 214-093• 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. • Anchorage,Alaska 99503 50-133-20635-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 237A / ❑ Beaver Creek(BCU)23• Will planned perforations require a spacing exception? Yes El No 9.Property Designation(Lease Number): 10.Field/Pool(s): A028083 ' Beaver Creek 1 Beluga Gas Pod• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 11,141 10,852 11,043 ' 10,754 • N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 80' 80' Surface 3,400' 9-5/8" 3,400' 3,360' 5,750 psi 3,090 psi Intermediate Production 11,128' 5-1/2" 11,128' 10,839' 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic I See Attached Schematic N/A WA N/A Packers and SSSV Type: Packers and SSSV MD(t)and ND(R): N/A;N/A .3010 n,, •r 1'14N/A;WA 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphic fl Development[] • Service n 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 12/03/14 Oil ❑ Gas ❑� WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email soorhola( hilcorD.com _ Printed Name an Porhola Title Operations Engineer /- I Signature _ 01.1—_ Phone 907-777-8412 Date (k(2_67/1( /1( 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: Spacing Exception Required? Yes ❑ No d Subsequent Form Required: {(ti,_c/0'-( l APPROVED/ lBY Approved by: 2;47� ..9rig....4,747/._- COMMISSIONER THE COMMISSION Date: /2 — g— 1 3 /`( Gil l ILA L 9. 6I i j 1 ,� ( 1/i��y Submit Form and Form 10-403(Bevis 10/2012) a c t V I r 12 months from the date of approval. Rett vents jit For ifatp 10 . . 11 Well Prognosis Well: BCU-23 llilcorp Alaska,Lb Date: 11/26/2014 Well Name: BCU-23 API Number: 50-133-20635-00 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: December 3`d, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-093 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228(M) Second Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) AFE Number: 1412150C Current Bottom Hole Pressure: —2,700 psi @ 8,410' TVD (Existing perfs w/2,000 psi SITP) Maximum Expected BHP: —3,717 psi @ 8,410' TVD (Based on offset wells, EMW=8.5ppg) Max. Allowable Surface Pressure: —2,876 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#23 was drilled as a Grass roots monobore completion in 2014 to target gas sands in the Sterling, Lower Beluga, and Tyonek formations.The initial perforations in the Lower Beluga were made in late November and were non-productive. The purpose of this work/sundry is to add perforations in the Lower Beluga. Notes Regarding Wellbore Condition • Well will be displaced with Nitrogen before initial perforating at+/- 2,000 psi SITP. • Current fluid level is at 10,200' SLM. E-line Procedure: 1. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 2,000 psi (Nitrogen pressure). 2. RU 3-1/8" 6 spf Connex HC wireline guns. 3. RIH and perforate the following intervals: Zone Sands Top(MD) Btm (MD) FT SPF Lower Beluga LB-19 7,534' 7,557' 23' 6 / Lower Beluga LB-22 7,820' 7,860' 40' 6 Lower Beluga LB-22L 7,883' 7,896' 13' 6 Lower Beluga LB-24L 7,924' 7,939' 15' 6 Lower Beluga LB-27 8,082' 8,103' 21' 6 Lower Beluga LB-28 8,166' 8,182' 16' 6 Lower Beluga LB-28 8,206' 8,232' 26' 6 Lower Beluga LB-28 8,282' 8,301' 19' 6 Lower Beluga LB-29B 8,384' 8,412' 28' 6 a. Bleed tubing pressure to 2,000 psi before perforating. Well Prognosis Well: BCU-23 1Hileorp Alaska,Li' Date: 11/26/2014 b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using Cement Bond Log (pending Tie-in log). e. Use Gamma/CCL/to correlate. Utilize Press/Temp tool if available. f. Record tubing pressures before and after each perforating run. g. Proposed intervals are in the Beluga Gas Pool. h. Distance to nearest well open in same sands=875'to BCU-13. i. Spacing allowance is based on CO 237A, no restrictions in Beluga Gas Pool. 4. RD E-line. 5. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic . 11 BCU - 23 ACTUAL Pad 3 1,125 FNL, 1,715'FWL, SCHEMATIC Sec. 34, T7N, R10W, S.M. Ililcorp .Alaska. I.I.0 " Conductor Permit#: 214-093 ppf API#: 50-133-20635-00 F, 16 Top Bottom Prop.Des: FED A-028083 MD 0' 80' KB elevation: 179.2' (18.6'AGL) ND 0' 80' Lat: N60° 39' 30.892" Long: W151° 1' 1.445" Spud: 8/26/2014 02:30 hrs XO Jt 802' Surface Casinq j 9-5/8" L-80 40 ppf BTC TD: 9/14/2014 17.30 hrs ,....4 CDC to GEOCONN Tom Bottom Rig Released: 9/18/2014 18:00 hrs .-,...„'AMD 0' 3,400' • �•ND 0' 3,360' 112-1/4"hole Lead Cmt w/598 sks(262 bbls)of Tree cxn=9-1/2"Otis y' ,. 12.0 ppg,Class G, Tail Cmt w/198 sks(43 bbls) 6.0"Seal Diameter 4;,,, .,,, of 15.4 ppg,Class G, 37 sks(16 bbls)to surface 5-1/8"Modified ID Bore a J.' rt,,,i Production Casing TOC(CBL 10/30/14)-3,052 '4, 5-1/2" P-110 17 ppf CDC a Top Bottom M !ry MD 0' 802' ND 0' 802' R7 i9' 5-1/2" P-110 17 ppf GEOCONN ,44 '4"i Top Bottom RA MkrJt 6,094' MD 802' 11,128' ND 802' 10,839' + 8-1/2"hole Cmt w/1,875sks(454 bbls)of 15.3 ppg, 1' Class G cmt w/EASYBLOK Casing/Cementing Detail 10.9 ppg Mud - 12.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(454 bbl) RA MkrJt 7,704' - 8.5 ppg 3%KCI(256 bbl) , 'g BC-23 te OH Log Depths ;;F .' M50 @ 8,646'-8,656' IV ``i B31 @ 8,556'-8,566' ''.y B30 @ 8,493'-8,503' RST Log Depths j M50 @ 8,642'-8,652' B31 @ 8,552'-8,562' • LB-30 - B30 @ 8,489'-8,499' LB-31 3 Jewelry Depth M-50 1.Swell Packer(21'Long) 3.010' " Perforations: Zone MD ND Size SPF Date Status ' LB-30 8,493'-8,503' 8,263'-8,272' 3-1/8" 6 11/23/14 Open . LB-31 8,556-8,566' 8,323'-8,333' 3-1/8" 6 11/23/14 Open RA MkrJt 9,917' M-50 8,646-8,656' 8,410'-8,419' 3-1/8" 6 11/23/14 Open V 'A Fluid Level -' ,� 10,200' IRA MkrJt 10,611' Tag(unset cement)@ 10,984'SLM _ Casing Shoe @ 11,128' Max Dogleg: w/4.53"GR(10/21/14) - 4.76°/100'@ 2,367' TD: PBTD: 11,141'MD 11,043'MD Max Inclination: 10,852'ND 10,754'ND 16.6°@ 6,955' Well Name&Number. Beaver Creek Unit#23 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:[USA Angle @KOP and Depth: 1.0°@ 2,000' Angle/Perls:I N/A Maximum Deviation: 16.6°@ 6,955' Date Completed: 11/23/2014 _ Ground Level(above MSL): 160.6' _ RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 11/23/2014 Schematic Revision Date: 11/26/2014 . 11 BCU - 23 PROPOSED Pad 3 1,125 FNL, 1,715'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. Hticorp Alaska.LLC. Permit#: 214-093 Conductor API#: 50-133-20635-00 16" X-56 109 ppf ti. y'' Top Bottom Prop.Des: FED A-028083 MD 0' 80' KB elevation: 179.2' (18.6'AGL) TVD 0' 80' Lat: N60° 39' 30.892" ii Lona: W151° 1' 1.445" Spud: 8/26/2014 02:30 hrs XO Jt 802' Surface Casinq TD: 9/14/2014 17:30 hrs ' CDC to GEOCONN 9-518" L-80 40 ppf BTC Tom Bottom Rio Released: 9/18/2014 18:00 hrs MD 0' 3,400' TVD 0' 3,360' 1 12-1/4"hole Lead Cmt w/598 sks(262 bbls)of Tree cxn=9-1/2"Otis r 12.0 ppg,Class G, Tail Cmt w/198 sks(43 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 37 sks(16 bbls)to surface 5-1/8"Modified ID Bore r' Production Casino TOC(CBL 10/30/14)-3,052 - 5-1/2" P-110 17 ppf CDC Top Bottom MD 0' 802' ND 0' 802' 5-1/2" P-110 17 ppf GEOCONN Top Bottom RA MkrJt 6,094' MD 802' 11,128' TVD 802' 10,839' 8-1/2"hole Cmt w/1,875sks(454 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK Casinq/Cementing Detail LB-19 - 10.9 ppg Mud - 12.5 ppg Mud Push(35 bbl) RA MkrJt 7,704' - 15.3 ppg Cement(454 bbl) - 8.5 ppg 3%KCI(256 bbl) LB-22L ° -- LB-22L LB-24L - BC-23 LB-Y7 OH Log Depths M50 @ 8,646'-8,656' LB 28 li 831 @ 8,556'-8,566' LB-28 LB-28 '- B30 @ 8,493'-8,503' LB-29B ,... RST Log Depths F M50 @ 8,642'-8,652' 1 B31 @ 8,552'-8,562' LB-30 B30 @ 8,489'-8,499' LB-31 3 ,I perforations: Jewelry Depth M-50 Zone MD ND Size SPF Date Status 1.Swell Packer(21'Long) 3,010' . '• , LB-19 7,534'-7,557' 7,338'-7,360' 3-1/8" 6 Propose LB-22 7,820'-7,860' 7,614-7,653' 3-1/8" 6 Proposed LB-22L 7,883'-7,896' 7,676-7,687' 3-1/8" 6 Proposed I . LB-24L 7,924-7,939' 7,714-7,729' 3-1/8" 6 Proposed RA MkrJt 9,917' LB-27 8,082'-8,103' 7,867'-7,887' 3-1/8" 6 Proposed LB-28 8,166-8,182' 7,946-7,963' 3-1/8" 6 Proposed LB-28 8,206-8,232' 7,987'-8,012' 3-1/8" 6 Proposed . Y Fluid Level LB-28 8,282'-8,301' 8,060'-8,078' 3-1/8" 6 Proposed •� 10,200' LB-29B 8,384-8,412' 8,158'-8,185' 3-1/8" 6 Proposed LB-30 8,493'-8,503' 8,263'-8,272' 3-1/8" 6 11/23/14 Open ' RA MkrJt 10,611' LB-31 8,556'-8,566' 8,323'-8,333' 3-1/8" 6 11/23/14 Open M-50 8,646'-8,656' 8,410'-8,419' 3-1/8" 6 11/23/14 Open Tag(unset cement)@ 10,984'SLM _ Casing Shoe @ 11,128' Max Dogleg: w/4.53"GR(t0121/14) . . - 4.76°/100'@ 2,367' TD: PBTD: 11,141'MD 11,043'MD Max Inclination: 10,852'TVD 10,754'ND 16.6°@ 6,955' Well Name&Number: Beaver Creek Unit#23 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:IUSA Angle @KOP and Depth: 1.0°@ 2,000' Angle/Perfs.•I N/A Maximum Deviation: 16.6°@ 6,955' Date Completed: 11/23/2014 Ground Level(above MSL). 160.6' RKB(above GL): 18.6' Revised By. Stan Porhola Downhole Revision Date, Proposed Schematic Revision Date: 11/26/2014 z\Lk .oct3 teeth Nolan Hilcorp Alaska, LLC 2'rJa�l� GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 ttatA:i. Fax: 907 777-8510 RECEIVEDE-mail: snolan@hilcorp.com NOV 10 2014 DATA LOGGED nz,i201q K.BENDER DATE 11/10/14 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 23 Elog data Prints: Reservoir Saturaton Tool Cement Evaluation Log CD: • A Files Currently on the Disc (3) . Well Ms 11./4/2014 8:39 AM File folder . Well Las 1114/2014 8:39 AM File folder Well Log 11/4.12014 8:39 AM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Receive! % V��`G Date: 1 �jP!`J 2k e4 -on - ( -,,,-51F- 1-7,r, , _, , --;,-----'--_ -,%-; 17--.1:.L) `?p / h (� .--%' 1, At i 333 We sl C V nth F', cnue la K- Anchorage Go ( Itl\�;IZ SF ;\\ )';1IZ\i}?I 1 A ichoragc Alaska 99501 3572 .. 'c) n en- -74 j3 Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, BCU 23 Sundry Number: 314-580 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, e ," Daniel T. Seamount, Jr. t Commissioner DATED this 7sday of November, 2014. Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION il( 7 2 9 2 1.:;:; p5\s")\ APPLICATION FOR SUNDRY APPROVALS IGJ5II4 20AAC 25.280 OGG • ( '; 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Weill] Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑, • Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other. Initial Completion❑✓. 2.Operator Name: r. Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development Q . 214-093 ' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20635-00 ' 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 237A Beaver Creek(BCU)23 Will planned perforations require a spacing exception? Yes ❑ No D 9.Property Designation(Lease Number): 10.Field/Pool(s): �_i..„4?- et,' b i'^ ,/P{ A028083 • Beaver Creek/ Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,141 10,852 11,043 10,754 N/A N/A Casing Length Size MD 1VD Burst Collapse • Structural Conductor 80' 16" 80' 80 Surface 3,400' 9-5/8" 3,400' 3,360' 5,750 psi 3,090 psi Intermediate Production 11,128' 5-1/2" 11,128' 10,839 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)and ND(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphic❑ Developmentn Service n 14.Estimated Date for 15.Well Status after proposed work: 11/09/14 Commencing Operations: Oil ❑ Gas ❑✓ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Pothole Phone: 907-777-8412 Email sDorhola( hilcorD.con1 Printed Name Stan Porhola Title Operations Engineer Signature / p ".^� Phone 907-777-8412 Date I 0(z i 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: r 7‘-' A t 1 T— TA -,-.-_. c_ a t (.7 i_,.)._,_f_ L' � LI ,,,,.r Q i�ePa-r Spacing Exception Required? Yes ❑ No [i Subsequent Form Required: / -- l (i 7 \ `�'z J 7 APPROVED BY / Approved by: / /COMMISSIONER THE COMMISSION Date: ( //! _ ��7 I I A L12 // Sut in Form and Form 10-403(Revised 10/28 ) AOR I OF months from th!date of�ep►roval. Attachments in Duplicate RBCMS NOV - 6 2C -�- 4 . -t:/5 /c)-30-/.1 ‘ 4, lig Well Prognosis Well: BCU-23 Hilcoru Alaska,LL) Date:10/29/2014 Well Name: BCU-23 API Number: 50-133-20635-00 Current Status: New Grassroots Gas Well Leg: N/A I Estimated Start Date: November 9th, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-093 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: 1412150C Current Bottom Hole Pressure: —0 psi @ 8,410' TVD (No open perforations) Maximum Expected BHP: —3,717 psi @ 8,410' TVD (Based on offset wells, EMW=8.5ppg) Max.Allowable Surface Pressure: —2,876 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#23 was drilled as a Grass roots monobore completion in 2014 to target gas sands in the Sterling, Lower Beluga,and Tyonek formations. The purpose of this work/sundry is to perforate the well for the initial completion in the Lower Beluga. Notes Regarding Wellbore Condition • Plan to tag with slickline before running E-line. Moderate dogleg below the KOP @ 2,366' MD. • Will run Cement Bond Log before perforating. • MIRU Coil Tubing and perform BOPE Test to 250/4,500 psi to displace well over to Nitrogen. • Well will be displaced with Nitrogen before initial perforating at+/-2,500 psi SITP. • Pressure test IA(5-1/2"x9-5/8")to 2,500 psi before perforating. E-line Procedure: / `i ,---1. 1. MIRU E-line, PT lubricator to 3,500 psi Hi 250 Low. ( L a. Tree connection is 9.5" OTIS. b. SITP will be 2,500 psi (Nitrogen pressure). I 1— 3 - /y 2. RU 3-1/8" 6 spf Connex HC wireline guns. 3. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT SPF Lower Beluga LB-30 8,493' 8,503' 10' 6 BelugaLB-31 855 ' Lower6 8,566' 10' 6 Lower Beluga M-50 8,646' 8,656' 10' 6 a. Bleed tubing pressure to 2,500 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using Cement Bond Log(pending Tie-in log). e. Use Gamma/CCL/to correlate. Utilize Press/Temp tool if available. f. Record tubing pressures before and after each perforating run. , -s H , Well Prognosis Well: BCU-23 Hilcorp Alaska,I.I. Date:10/29/2014 g. Proposed intervals are in the Beluga Gas Pool. h. Distance to nearest well open in same sands=875'to BCU-13. i. Spacing allowance is based on CO 237A, no restrictions in Beluga Gas Pool ‘e- - / nr 4. RD E-line. /SCS$ e rrpzu e---/-kii.ia.r �r�ee� d4_J 5. Turn well over to production. C.e.1c.�I- wI-c. c)I' ,,kr 8' I iiL A - Gr7v E-line Procedure (Contingency): 6.= ;tet;1-6 47 ii • 1't•k— ' G' i • /E)•'36:, h,! 6. If any zone produces sand and/or water. 7. MIRU E-line, PT lubricator to 3,500 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be+/-2,500 psi (remaining gas or applied Nitrogen pressure). 8. RIH and set 5-1/2" CIBP at depth above zone. Or 9. RIH and set 5-1/2" Casing Patch across the zone. Attachments: 1. Actual Schematic 2. Proposed Schematic • BCU — 23 ACTUAL Pad 3 1,125 FNL, 1,715'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. mem",Alaska,LLC , Permit#: 214-093 ,- I"., -� Conductor API#: 50-133-20635-00 16" X-56 109ppf Top Bottom Prop.Des: FED A-028083 $ 4 , MD 0' 80' KB elevation: 179.2' (18.6'AGL) E TVD 0' 80' Lat: N60° 39' 30.892" Long: W151° 1' 1.445" a Surface Casing Spud: 8/26/2014 02:30 hrs !;y 4<, XO Jt 802' 9-5/8" L-80 40 ppf BTC TD: 9/14/2014 17:30 hrs i;... 9;•3 CDC to GEOCONN Top Bottom Rig Released: 9/18/2014 18:00 hrs MD 0' 3,400' � � � TVD 0' 3,360' ` t` 1 12-1/4"hole Lead Cmt w/598 sks(262 bbls)of Tree cxn=9-1/2"Otis •g . li 12.0 ppg,Class G, Tail Cmt w/198 sks(43 bbls) 6.0"Seal Diameter I. ,;, '•,- - of 15.4 ppg,Class G, 37 sks(16 bbls)to surface 5-1/8"Modified ID Bore / r.r .' Production Casing TOC(EST)-3,000' 5-1/2" P-110 17 ppf CDC �ss Top Bottom „..,,x!, ' MD 0' 802' ld-R1,* TVD 0' 802' ;...- 5-1/2" P-110 17 ppf GEOCONN Top Bottom 3; MD 802' 11,128' r. TVD 802' 10,839' a 4* . 8-1/2"hole Cmt w/1,875sks(454 bbls)of 15.3 ppg, ' Class G cmt w/EASYBLOK Casing/Cementing Detail R• A MkrJt 6,094' - 10.9 ppg Mud • - 12.5 ppg Mud Push(35 bbl) ^. - 15.3 ppg Cement(454 bbl) t ,:ii- - 8.5 ppg 3%KCI(256 bbl) 4' 'I RA MkrJt 7,704' `J n R• A MkrJt 9,917' r:; Jewelry Depth 1 Swell Packer(21'Long) 3,010' x :a A '' Perforations: R• A Mkr Jt 10,611' Zone MD TVD Size SPF Date Status Y Tag(unset cement)@ 10,984'SLM Casing Shoe @ 11,128' Max Dogleg: w/4.53"GR(10/21/14) > �° ••. 4.76°/100'@ 2,367' TD: PBTD: 11,141'MD 11,043'MD Max Inclination: 10,852'TVD 10,754'TVD 16.6°@ 6,955' Well Name&Number Beaver Creek Unit#23 Lease: A-028083 County or Parish Kenai Peninsula Borough State/Prov Alaska Country: USA Angle @KOP and Depth: 1.0°@ 2,000' Angle/Perfs:' N/A Maximum Deviation: 16.6°@ 6,955' Date Completed: N/A Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By Stan Porhola Downhole Revision Date 10/21/2014 Schematic Revision Date 10/27/2014 BCU - 23 PROPOSED Pad 3 1,125 FNL, 1,715'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. Ililcorp Alaska,LLC Permit#: 214-093 I, I-t - Conductor API#: 50-133-20635-00 ,,,:'4 '' '; 16" TopX-56 Bottom Prop.Des: FED A-028083 4 *, MD 0' 80' KB elevation: 179.2' (18.6'AGL) TVD 0' 80' Lat: N60° 39' 30.892" - y' Long: W151° 1' 1.445" Spud: 8/26/2014 02:30 hrs •'., "! XO Jt 802' Surface Casinq TD: 9/14/2014 17:30 hrs �`.. L',' CDC to GEOCONN 9-5/8" L-80 40 ppf BTC m Rig Released: 9/18/2014 18:00 hrs " Bo4tt0' �•', e. 1 MD 0' 3,400' 1 TVD 0' 3,360' 1 12-1/4"hole Lead Cmt w/598 sks(262 bbls)of ilx Tree cxn=9-1/2"Otis . - ,^A; , 12.0 ppg,Class G, Tail Cmt w/198 sks(43 bbls) 8.0"Seal Diameter 1 k +,; .,.� ' of 15.4 ppg,Class G, 37 sks(16 bbls)to surface 5.1/8"Modified ID Bore y - --.. TOC(EST)- , - ti Production Casinq 3000' 5-1/2" P-110 17 ppf CDC Top Bottom rte MD 0' 802' +,.k `-+.A TVD 0' 802' t' 5-1/2" P-110 17 ppf GEOCONN '' Top Bottom to MD 802' 11,128' TVD 802' 10,839' I �+RA Mkr Jt 6,094' 8-1/2"hole Cmt w/1,875sks(454 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK Casinq/Cementing Detail 'i t«3 - 10.9 ppg Mud 4+ ,,m - 12.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(454 bbl) )` - 8.5 ppg 3%KCI(256 bbl) /,.,, RA MkrJt 7,704' h* LB-30 wa LB-31 �" n M-50 IRA MkrJt 9,917' 'v it w; Jewelry Depth l'' Perforations: 1.Swell Packer(21'Long) 3,010' Zone MD TVD Size SPF Date Status wiur 1Contingency) ! , , / ,c-.J ,.. .503' 8,20U-8,272' 3-1/8" 6 Proposed 3.CIBP(Contingency) 8,620' ' , RA M kr Jt 10,611' L13-31 8,556.8,566' 8,323.8,333' 3-1/8" 6 Proposed M-50 8,646-8,656' 8,410'-8,419' 3-1/8" 6 Proposed -r i Tag(unset cement)@ 10,984'SLM _ ' h .aa:' t. ^` Casing Shoe @ 11,128' Max Dogleg: w/4.53"GR(10/21/14) -_ •' 4.76°/100'@ 2,367' TD: PBTD: 11,141'MD 11,043'MD Max Inclination: 10,852'TVD 10,754'TVD 16.6°@ 6,955' Well Name&Number Beaver Creek Unit#23 Lease: A-028083 County or Parish Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth 1.0°@ 2,000' Angle/Perfs:I N/A Maximum Deviation:- 16.6°@ 6,955' Date Completed N/A Ground Level(above MSL): 160.6' _ RKB(above GL): 18.6' Revised By Stan Porhola Downhole Revision Date Proposed Schematic Revision Date 10/29/2014 0 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, November 03, 2014 12:17 PM To: 'Stan Porhola' Subject: RE: BCU 23 (PTD 214-093) Stan, I will make the sundries contingent on a passing MIT-IA then. Forward the CBL as soon as practical. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793-1226) or(Guy.schwartz@alaska.gov). From: Stan Porhola [mailto:sporhola@hilcorp.com] Sent: Monday, November 03, 2014 11:45 AM To: Schwartz, Guy L(DOA) Subject: RE: BCU 23 (PTD 214-093) Guy, We have run the cement bond logs in both BCU-23 (PTD 214-093) and BCU-24 (PTD 214-112). I should have the hard copy and electronic copies in my office today. Will put together copies to submit to your office. Plan to perform the MIT-IA for both wells this later this week or next. Stan From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, November 03, 2014 10:16 AM To: Stan Porhola Subject: BCU 23 (PTD 214-093) Stan, Has the CBL been run on BCU 23? Also MIT-IA results? Need to have these results before I approve perforating sundry. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 1 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 2 Carlisle, Samantha J (DOA) Jlq-o 3 From: Schwartz, Guy L (DOA) Sent: Wednesday, October 29, 2014 1:17 PM To: Tom Fouts; Carlisle, Samantha 1 (DOA) Cc: Stan Porhola; Donna Ambruz Subject: RE:Withdrawl of Sundry 314-552 for BCU 23 Sam, Please withdraw sundry 314-552 as per Hilcorp's request. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.It you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793-1225) or(Guv.schwartz@alaska.gov). From: Tom Fouts [mailto:tfouts@hilcorp.com] Sent: Wednesday, October 29, 2014 12:28 PM To: Schwartz, Guy L(DOA) Cc: Stan Porhola; Donna Ambruz Subject: Withdrawl of Sundry 314-552 for BCU 23 Guy, This email is to notify you that Hilcorp Alaska, LLC wishes to withdraw the Application for Sundry 314-552. Please feel free to contact me if you have any questions. Thanks, Tom Fouts I Senior Ops/Reg Tech Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907) 777-8398 Mobile: (907) 351-5749 1 224 .1 Nolan Hilcorp Alaska, L_ Z'41 J 5 GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 RECEIVEC Fax: 907 777-8510 E-mail: snolan@hilcorp.com OCT 2 3 2014 AOGCC DATE 10/22/2014 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 23 Mudlog data Prints: End of Well Report 2" MD Formation Evaluation Log 5" MD Formation Evaluation Log 2" MD Gas Ratio Log 2" MD Drilling Engineering Log CD: Final Well Data A Files Currently on the Disc (5) , BEAVER CREEK UNIT 23 FINAL LOGS 10/2/2014 AM File folder 3 BEAVER CREEK UNIT 23 LAS EXPORTS 10/2/2014 11:06 AM File folder EMF Log Viewer 1012.201411:06.AM File folder Halliburton Log Viewer 10/2/2014 11:06 AM File folder 13 BEAVER CREEK UNIT 23 FINAL END OF W... PDF Document 4,447 KB Please include current contact information if different from above. Please acknowledge receipt b6y signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: y� Date: zt'- 09 3 2_2-kqq II 5 .,i Nolan Hilcorp Alaska, L. GeoTech 3800 Centerpoint Drive, Suite 100 �/ Anchorage, AK 99503 RED Tele: 907 1111v„ri, tla+ki.i.i i ECE' `� Fax 907 777-85010 E-mail: snolan@hilcorp.com OCT 2 3 2014 AOGGO DATA L�Q�GGED DATE 10/22/14 ‘,9/21/2014( M.K.BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 23 Elog data Prints: ROP Rate of Penetration, DGR Dual Gamma Ray, EWR-Phase 4, ALD Azimuthal Lithodensity, CTN Compensated Thermal Neutron MD DGR Dual Gamma Ray, EWR-Phase 4, ALD Azimuthal Lithodensity, CTN Compensated Thermal Neutron TVD CD: CGM 9/26/2014 1:44 PM File folder DLIS+LAS 9/26/2014 1:44 PM File folder EMF 9/26/2014 1:44 PM File folder PDF 9,126/2014 1:44 PM File folder TIFF 9/26/2014 1:44 PM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 (17)Received Bp ��V .,,,C Date: •. =ice v = - i -' i _, i'llr - '�.-, C;i)\'Elu\ oR St: \N pARNT1_!.I, 333 West Se/Ent!, Avc:lue \ .--,i Anchorage Alas �.,�a P ka 99501-357 'AEI,- 9n7 ',7c' 1,1;C, Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Undefined Tyonek Gas Pool, Beaver Creek 23 Sundry Number: 314-552 Dear.Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ta6fip;144vs____ Cathy i Foerster Chair DATED this / day of October, 2014. Encl. A l D AIS' R a t +a► ill/' STATE OF ALASKA 0 C_I 0 9 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION to lb(/s )!4--- 61Y\ �� M APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair WeII❑ Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate❑, • Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Atter Casing❑ Other:❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development [. 214-093• 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20635-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20AAC25.055ja)j4) Beaver Creek( )23 • /� 114Will planned perforations require a spacing exception? Yes ❑ No ❑ 'o. 9.Property Designation(Lease Number): 10.Field/Pool(s): A028083 • Beaver Creek/Undef Tyonek Gas Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft). Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 11,141 10,852 11,043 10,754 N/A N/A Casing Length Size MD ND Burst Collapse _ Structural Conductor 80' 16" 80' 80' Surface 3,400' 9-5/8" 3,400' 3,360' 5,750 psi 3,090 psi Intermediate Production 11,128' 5-1/2" 11,128' 10,839' 10,640 psi 7,460 psi • Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(It): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)and ND(R): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development(n Service n 14.Estimated Date for 15.Well Status after proposed work: 10/16/14 . Commencing Operations: Oil ❑ Gas ❑✓ - WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ 0 GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email saorhola( hilcorD.com Printed Name an Porhola Title Operations Engineer Signature Phone 907-777-8412 Date (Y0 Clfrf COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: " \1*-- 5v5/ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: -4 •C-1(3 I--- £ Mi-r- « Pi ..9 Z5-no pS Spacing Exception Required? Yes ❑ No LJ Subsequent Form Required: /U —'/O7 1.1a ) APPROVED BY Approved by: /31./....4/4.--- COMMISSIONER THE COMMISSION Date: /0, /c� -/�� 9441.6,414sAIL:m �O•�S ! Submit Form ane Form 10-403(Revised 10/2012) 12 onthsfr a of a roV81. Attachments in Duplicate S OCT 2 0101 S> /0. .0_ ,,,,e Well Prognosis Well: BCU-23 llilcorp Alaska,LL Date: 10/09/2014 Well Name: BCU-23 API Number: 50-133-20635-00 Current Status: New Grassroots Gas Well _ Leg: N/A Estimated Start Date: October 16th, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-093 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: 1412150C Current Bottom Hole Pressure: — 0 psi @ 10,601' TVD (No open perforations) Maximum Expected BHP: — 5,292 psi @ 10,601' TVD (Based on offset wells, EMW= 9.5ppg) Max. Allowable Surface Pressure: —4,232 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psilft) Brief Well Summary Beaver Creek Unit#23 was drilled as a Grass roots monobore completion in 2014 to target gas sands in the Sterling, Lower Beluga, and Tyonek formations. The purpose of this work/sundry is to perforate the well for the initial completion in the Tyonek. Notes Regarding Wellbore Condition • Plan to tag with slickline before running E-line. Moderate dogleg below the KOP @ 2,366' MD. • Will run Cement Bond Log before perforating. • MIRU Coil Tubing and perform BOPE Test to 250/4,500 psi to displace well over to Nitrogen. • Well will be displaced with Nitrogen before initial perforating at+/- 3,500 psi SITP. • Pressure test IA(5-1/2"x9-5/8") to 2,500 psi before perforating. E-line Procedure: 1. MIRU E-line, PT lubricator to 4,500 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 3,500 psi (Nitrogen pressure). 2. RU 3-1/8" 6 spf Connex HC wireline guns. 3. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT SPF ...J., S cam"" , Tyonek T10 to 119 10,125' 10,901' Varies 6 ` " dv a. Bleed tubing pressure to 3,500 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using Cement Bond Log (pending Tie-in log). e. Use Gamma/CCL/to correlate. Utilize Press/Temp tool if available. f. Record tubing pressures before and after each perforating run. g. Proposed intervals are in the Undef Tyonek Gas Pool. h. Distance to nearest well open in same sands=No wells completed in Tyonek. ✓ ell:Well PrognosisBCU-23 W Ililcorp Alaska,LLQ Date: 10/09/2014 i. Spacing allowance is based on 20 AAC 25.055(a)(4); no wells within 3,000 ft. v 4. RD E-line. 5. Turn well over to production. E-line Procedure(Contingency): 6. If any zone produces sand and/or water. 7. MIRU E-line, PT lubricator to 4,500 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be+/- 3,500 psi (remaining gas or applied Nitrogen pressure). 8. RIH and set 5-1/2" CIBP at depth above zone. Or 9. RIH and set 5-1/2" Casing Patch across the zone. Attachments: 1. Actual Schematic 2. Proposed Schematic F BCU - 23 ACTUAL Pad 3 1,125FNL, 1,715'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. IIiI4•urp Alaska. 1.1.1: Permit#: 214-093 Conductor •API#: 50-133-20635-00 :.° t6 T-56• Bottomf Prop.Des: FED A-028083 MD 0' 80' KB elevation: 179.2' (18.6'AGL) TVD 0' 80' Lat: N60° 39' 30.892" Long: W151° 1' 1.445" Spud: 8/26/2014 02:30 hrs • XO Jt 802'• Surface Casing TD: 9/14/2014 17:30 hrs CDC to GEOCONN 9 Ste" L-80 40 ppf BTC Rig Released: 9/18/2014 18:00 hrs Tog Bottom MD 0' 33,,4400' ND 0' 3,360' 1 12-1/4"hole Lead Cmt w/598 sks(262 bbls)of Tree cxn=9-1/2"Otis 12.0 ppg,Class G, Tail Cmt w/198 sks(43 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 37 sks(16 bbls)to surface 5-1/8"Modified ID Bore Production Casing TOC(EST) 3,000' - - 5-1/2" P-110 17 ppf CDC Top Bottom MD 0' 802' ND 0' 802' 5-1/2" P-110 17 ppf GEOCONN Top Bottom MD 802' 11,128' ND 802' 10,839' 8-1/2"hole Cmt w/1,875sks(454 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK I RA Mkr Jt 6,094' Casing/Cementing Detail - 10.9 ppg Mud CS - 12.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(454 bbl) - 8.5 ppg 3%KCI(256 bbl) ' a'RAMkrJt7,704' • RA Mkr Jt 9,917' Jewelry Death 1.Swell Packer(21'Long) 3,010' ' Perforations: RA MkrJt 10,611' Zone MD TVD Size SPF Date Status • • Casing Shoe @ 11,128' • Max Dogleg: Unset Cement(Unknown Depth) /' 4.76°/100'@ 2,367' TD: PBTD: Max Inclination: 11,141'MD • 11,043'MD 16.6°@ 6,955' 10,852'ND 10,754'ND Well Name&Number Beaver Creek Unit#23 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:IUSA Angle @KOP and Depth: 1.0°@ 2,000' Angle/Perfs.I N/A Maximum Deviation: 16.6°@ 6,955' Date Completed: N/A Ground Level(above MSL): 160.6' RKB(above GL): 18.6' • Revised By: Stan Porhola Downhole Revision Date: 9/17/2014 Schematic Revision Date: 10/3/2014 BCU - 23 PROPOSED ItitPad 3 1,125 FNL, 1,715'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. i k•orp Alaska. IAA] Permit#: 214-093 Conductor API#: 50-133-20635-00 16" X-56 109 ppf Top Bottom Prop.Des: FED A-028083 MD 0' 80' KB elevation: 179.2' (18.6'AGL) ND 0' 80' Lat: N60° 39' 30.892" Long: W151° 1' 1.445" Spud: 8/26/2014 02:30 hrs XO Jt 802' Surface Casinq TD: 9/14/2014 17:30 hrs CDC to GEOCONN 9-5/8" L-80 40 ppf BTC Rio Released: 9/18/2014 18:00 hrs Tom 0' 3,440000 Bottom - MD ' I +' _ TVD 0' 3,360' 1 12-1/4"hole Lead Cmt w/598 sks(262 bbls)of Tree cxn=9-1/2"Otis 12.0 ppg,Class G, Tail Cmt w/198 sks(43 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 37 sks(16 bbls)to surface 5-1/8"Modified ID Bore , b EST 3,000' -- Production Casing TOC (EST)- 5-1/2" P-110 17 ppf CDC Top Bottom MD 0' 802' TVD 0' 802' • 5-1/2" P-110 17 ppf GEOCONN Top Bottom MD 802' 11,128' TVD 802' 10,839' CS RA Mkr Jt 6,094' 8-1/2"hole Cmt w/1,875sks(454 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK Casing/Cementing Detail - 10.9 ppg Mud - 12.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(454 bbl) - 8.5 ppg 3%KCI(256 bbl) ...RA MkrJt 7,704' RA MkrJt 9,917' • 0. Jewelry Depth Tyonek Perforations: 1.Swell Packer(21'Long) 3,010' - _ - 2.CIBP(Contingency) _ 2 Zone MD TVD Size SPF Date Status Tyonek 10,125-10,147' 9,839'-9,861' 3-1/8" 6 Proposed +x -' Mkr Jt 10,611' Tyonek 10,242'-10,249' 9,955-9,962' 3-1/8" 6 Proposed ° Tyonek 10,369'-10,388' 10,081'-10,100' 3-1/8" 6 Proposed Tyonek 10,494'-10,508' 10,206'-10,220' 3-1/8" 6 Proposed / -- Tyonek 10,576'-10,585' 10,288'-10,297' 3-1/8" 6 Proposed Tyonek - Tyonek 10,684'-10,704' 10,396-10,416' 3-1/8" 6 Proposed ' Tyonek 10,710'-10,751' 10,421'-10,463' 3-1/8" 6 Proposed Tyonek 10,806-10,815' 10,517'-10,526' 3-1/8" 6 Proposed Tyonek 10,851'-10,883' 10,562'-10,594' 3-1/8" 6 Proposed Tyonek 10,890'-10,901' 10,601'-10,612' 3-1/8" 6 Proposed • Max Dogleg: Unset Cement(Unknown Depth) - Casing Shoe @ 11,128' 4.76°/100@ 2,367' TD: PBTD• 11,141'MD 11,043'MD Max Inclination: 10,852'ND 10,754'ND 16.6°@ 6,955' Well Name&Number. Beaver Creek Unit#23 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:IUSA Angle @KOP and Depth. 1.0°@ 2,000' Angle/Perfs:I N/A Maximum Deviation: 16.6°@ 6,955' Date Completed: N/A Ground Level(above MSL): 160.6' _ RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 10/9/2014 02/q-oq3 Debra Oudean Hilcorp Alaska, LLC /�� GeoTech II 3800 Centerpoint Drive, Suite 100 l Anchorage, AK 99503 Tele: 907 777-8337 Hd� r�� tI:r.k:o.LTAFax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 10/13/2014 To: Alaska Oil & Gas Conservation Commission Meredith Guhl Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL Transmitted herewith are cuttings from BCU 23 WELL SAMPLE INTERVAL BCU 23 3440' - 4420' BCU 23 4440' - 5480' BCU 23 5500' - 6360' BCU 23 6380' - 7240' BCU 23 7260' - 8260' BCU 23 8280' - 9140' BCU 23 9160' - 10000' BCU 23 10020' - 10920' BCU 23 10940' - 11140' Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this rirti7 777.8510 Received 8(.4.14, Date: OCT 13 X0.4 AOGCC Davies, Stephen F (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Wednesday, September 03, 2014 6:54 AM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: BCU 25 Permit to Drill Application (PTD#214-132): Questions Good morning Steve. I named the well Beaver Creek#25 and left the "Unit" unit out on the well name because the BLM had issues with#23 and #24 when I submitted their permit to them with "Unit" in the name. For consistency, I should have named it Beaver Creek Unit#25 on the 10-401. Great catch on the 9675' depth! That was the old depth of the original plan and should have been modified to the correct depth of 8200'. MW will still range from 9-10 ppg throughout this hole section. Thank you! If you have any more questions, please let me know. Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Tuesday, September 02, 2014 5:30 PM To: Monty Myers Cc: Schwartz, Guy L (DOA) Subject: BCU 25 Permit to Drill Application (PTD # 214-132): Questions Monty, 1. Is the actual name/number of this proposed well Beaver Creek#25 or Beaver Creek Unit#25? 2. On page 30,the mud properties for the 8-1/2" hole section is given as: MD Mud Weight 3500'—9,675' 9.0—10.0 The TD of the well on Form 10-401 and in the directional survey is given at 8,200' MD. Please let me know the correct depth and mud weight ranges for this section of the planned well. Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 1 wL LmWn...m.nrisww. • s ,o:X;ersra, _ r - ... _ e.� -. - . .s.a a�.r¢ms.v®�+�•�r OF ,047, \I'/7; I HE STATE 333 West Seventh Avenue GOV'ERN'OR SF \N PARNor I Anchorage, Alcil,o 99501 3572 eipjin 907 27c G33 SL % ;_ Monty Mack Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek Unit #23 Hilcorp Alaska, LLC Permit No: 214-093 (revised) Surface Location: 1125' FNL, 1715' FWL, Sec. 34, T7N, R1 OW, SM, AK Bottomhole Location: 1838' FNL, 1558' FEL, Sec. 34, T7N, R1 OW, SM, AK Dear Mr. Myers: Enclosed is the approved application for permit to drill the above referenced development well. This permit supersedes and replaces the permit previously issued for this well dated July 3, 2014. 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 AOGCC 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 AOGCC 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 AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner n DATED this22 day of August, 2014. STATE OF ALASKA RECEIVED • i :A OIL AND GAS CONSERVATION COMI ,ON AUG 18 2014 PERMIT TO DRILL - REVISION ^ 20 AAC 25.005 A9GCC 1a.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone ❑ 1 c.Specify if we is proposed for: Drill ❑✓ Lateral ❑ Stratigraphic Test ❑ Development-Gas E Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑✓ Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244 - Beaver Creek Unit(BCU)#23 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive,STE 1400 Anchorage AK 99503 MD: 11,370' TVD: 11,079' Beaver Creek Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Beluga Gas Pool Surface: - 1125'FNL,1715'FWL,Sec 34,T7N,R1OW,SM,AK - A028083 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1591'FNL,2280'FEL,Sec 34,T7N,R1OW,SM,AK NA 7/21/2014 `/ Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1838'FNL,1558'FEL,Sec 34,T7N,R1OW,SM,AK 1920 acres 1590'FNL 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 179.2 feet - 15.Distance to Nearest Well Open Surface: x-31 Z535:135 • y-.24335.78•74—- Zone-4 GL Elevation above MSL: 160.6 feet- to Same Pool: 1 120' '3/7 3,F,3 -if:� OS 71 . ,y.r w, 16.Deviated wells: "� r i Kickoff depth: 2000 feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 16 degrees • Downhole: 3.60Q psi jgj i 0 Surface: 2747 psi (Drilling) , 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Cond 16" 109 X-56 Weld 80' Surface Surface 80' 80' r' Driven 12-1/4" 9-5/8" 40 L-80 BTC 3,559' Surface Surface 3,559' 3,278' i 310.2bbI/1741.9ft3 8-1/2" 5-1/2" 17 P-110 DWC/C HT 11,370' Surface Surface 11,370' i 11,079' 486.1bbl/2729.2ft3 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑✓ BOP Sketch ❑✓ Drilling Program 0 Time v.Depth Plot Q Shallow Hazard Analysis Diverter Sketch ❑✓ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date — 22. I hereby certify that the foregoing is true and correct. Contact Monty Mack Myers Email mmyers@hilcorp.com _ Printed Name Monty Mack Myers Title Drilling Engineer Signature ---- ' Phone (907)777-8431 Date 8/18/2014 Commission Use Only Permit to Drill API Number: ,�/�?/ Permit Approval See cover letter for other Number: 2V-k"O`k3'ILEV 5013.5-i/�'!�•,5 ( (-•Date: I requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales:0- Other: -Li ocb f, : 5c " /7s f Samples req'd: Yes❑ Nog . Mud log req'd:Yes❑ No❑ 9 H2S measures: Yes❑ No[" Directional svy req'd:Yes❑ No❑ A- + IA (� i(, / rt LLL Spacing exception req'd: Yes❑ No[/ Inclination-only svy req'd:Yes❑ No® 1 SC.-cin. (I--7 Oppr`0V,-, /co-, ef, y 0-;-n".. 12. ., r. i fil OVED BY Approved by: v, / COMMISSIONER THE APPCOMMISSION Date: V ) 2Z) ' 4---- / F'.21/i( Submit Form and Form 10-401 vised 10/2012) This per sDi fG4 A he date of approval(20 �.005(g)) Attachments iDuplicate / 7 /--7' / , ..;'6 U [ Monty Myers Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8431 p� Email mmyers@hilcorp.com Hilcorp Alaska,Il RECEIVED D 6 AUG i1_8 201d4� August 18, 2014 AOGCC Commissioner Alaska Oil &Gas Conservation Commission 333 W.7th Avenue Anchorage,Alaska 99501 Re: Beaver Creek Unit-23 Revised PTD Dear Commissioner, This is a revision to the previously submitted and approved PTD for Beaver Creek#23. The major change to this PTD is the SHL for the well.This change was necessary to accommodate 3 wells on the eastern side of the pad as opposed to the two that were already submitted for approval.A future well will be place at the southeastern end of the pad. BCU 23 is a south easterly step-out appraisal well of the lower and middle Beluga gas sands on the eastern flank of the field between the BCU 13 and BCU 16RD wells.The base plan is a 11370'"S-turn"wellbore with a shallow kickoff around 2000', building to a tangent of 16 deg,then dropping back to vertical at 10471' MD. Drilling operations are expected to commence approximately August 21st, 2014. I The Saxon Rig#169 will be used to drill the wellbore then run casing and cement. Surface casing will be run to 3,559' MD/3,278'TVD and cemented to surface to ensure protection of and shallow freshwater resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed,a Temp log will be run between 6—18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC and BLM authorities. All waste&mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I • facility for disposal/beneficial reuse depending on test results. General sequence of operations: 1. MOB Saxon Rig#169 to well site 2. N/U 21-1/4"x 2M diverter. 3. Drill 12-1/4" hole to 3559' MD. Run and cmt 9-5/8"surface casing. 4. N/D diverter, N/U&test 11"x 5M T3-Energy BOP. 5. Drill 8-1/2" hole section to 11,370' MD. Perform Wiper trip. • 6. POOH laying down drill pipe. 7. Run and cmt 5-1/2" production casing. 8. N/D BOP, N/U temp abandonment cap, RDMO. Hilcorp Alaska, LLC Page 1 of 2 • Monty Myers Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com Hilrnrp Alaska,LLC Reservoir Evaluation Plan: 1. Surface hole:GR+Res LWD. - 2. Production Hole:GR+Res+Den/Neu LWD. • 3. Mud loggers from surface casing point to TD. • If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. Sincerely, Monty Myers Drilling Engineer Hilcorp Alaska, LLC Page 2 of 2 STATE OF ALASKA Ali,- I ro ?;_,-.. ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AO2 G 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑ Change Approved Program 0• Suspend❑ Plug Perforations p Perforate ❑ Pull Tubing ❑ Time Extensi Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing ❑ Other. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: •i! Hilcorp Alaska,LLC. Exploratory ❑ Development Q 214-093 ' Z v3.Address: Stratigraphic ❑ Service El6.API Number. 3800 Centerpoint Dr.,Suite 1400,Anchorage AK 99503 50-133-20635-00 7 If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No Q Beavek Creek Unit(BCU)#23 • 9.Property Designation(Lease Number)• 10.Field/Pool(s): 1 A028083 Beaver Creek Field/Beluga Gas Pool Jl 11. PRESENT WELL CONDITION SUMMARY \ Total Depth MD(ft). Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs( �esured). Junk(measured). 80 80 80 80f 1►} Casing Length Size MD T y1 Burst Collapse Structural f/ '�' Conductor 80 16 80 _\� \,/ 1 80 N/A N/A I Surface N 1 Intermediate ��" 1 Production Liner 10 Perforation Depth MD(ft): Perforation Depth TVD(ft). Tubing Size: �, Tubing Grade: Tubing MD(ft): II Packers and SSSV Type: •'.ckers an SSSV MD(ft)and ND(ft): 12.Attachments: Description Summary of Proposal ❑ , 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q Service ❑ 14.Estimated Date for , 15.Well Status after proposed work: 8/21/2014 Commencing Operations: Oil ❑ Gas ❑., - WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date. WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to th- best of my knowledge. Contact Monty M Myers Email mmyers(r7�hilcorp.com Printed Name Monty M Myers Title Drilling Engineer Signature 'hone 907.538.1168 Date --18/15/2014 • 41kIlik COMMISSION USE ONLY Conditions of approval: Notify Commission so at a representative may witness Sundry Number: Plug Integrity ❑ BOP Tes • Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: �R� I NA Submit in Form and Form 10-403(Revised 10/2012) Appr v I I f sly' Lmonths from the date of approval. Attachments in Duplicate Hilcorp Alaska, LLC Beaver Creek #23 Drilling Program Beaver Creek Field '�`-- ro d by: M My Version 0 June 16th, 2014 ii r Beaver Creek#23 Drilling Procedure Hilcorp Energy Company Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program: 4 4.0 Drill Pipe Information: 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling/Completion Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 11 10.0 N/U 21-1/4" 2M Diverter 12 11.0 Drill 12-1/4"Hole Section 15 12.0 Run 9-5/8" Surface Casing 20 13.0 Cement 9-5/8" Surface Casing 23 14.0 BOP N/U and Test 26 15.0 Drill 8-1/2"Hole Section 27 16.0 Run 5-1/2" Production Casing 32 17.0 Cement 5-1/2" Production Casing 35 18.0 RDMO 38 19.0 BOP Schematic 39 20.0 Wellhead Schematic 40 21.0 Days Vs Depth 41 22.0 Geo-Prog 42 23.0 Anticipated Drilling Hazards 43 24.0 Saxon Rig 169 Layout 45 25.0 FIT Procedure 46 26.0 Choke Manifold Schematic 47 27.0 Casing Design Information 48 28.0 8-1/2" Hole Section MASP 49 29.0 Spider Plot(NAD 27) (Governmental Sections) 50 30.0 Surface Plat(As Built) (NAD 27) 51 31.0 Surface Plat(As Built) (NAD 83) 52 32.0 Directional Survey 53 Beaver Creek#23 111 Drilling Procedure Rev 0 Hilcorp Tinergy Company 1.0 Well Summary Well Beaver Creek#23 • Pad&Old Well Designation Beaver Creek#23 is a grass roots well on BCU Pad#3 • Planned Completion Type 5-1/2"Production tubing Target Reservoir(s) Beluga Planned Well TD, MD/TVD 11,370' MD/ 11,079' TVD PBTD, MD/TVD 11,250' MD/ 10,958' TVD Surface Location(Governmental) •1125' FNL, 1715' FWL, Sec 34,T7N,R1OW, SM,AK Surface Location(NAD 27) X=317534.335,Y=2434057.104 - Surface Location(NAD 83) Top of Productive Horizon (Governmental) 1591' FNL,2280' FEL, Sec 34,T7N,RIOW, SM,AK TPH Location(NAD 27) X=318807.62,Y=2433578.74 TPH Location(NAD 83) BHL(Governmental) 1838'FNL, 1558'FEL, Sec 34,T7N,R1 OW, SM, AK BHL(NAD 27) X=319526.70,Y=2433321.10 BHL(NAD 83) AFE Number 1412150D AFE Drilling Days 5 MOB,22 DRLG AFE Completion Days AFE Drilling Amount $5,210,720 AFE Completion Amount $300,000 Maximum Anticipated Pressure 7-7 (Surface) 14 's. (Drilling) /- Y' Maximum Anticipated Pressure (Downhole/Reservoir) 3600 psi Work String 4-1/2" 16.6# S-135 CDS-40(Saxon Owned String) RKB—GL 179.2'(160.6+ 18.6) Ground Elevation 160.6' BOP Equipment 11"5M T3-Energy Annular BOP 11"5M T3-Energy Double Ram 11" 5M T3-Energy Single Ram Page 2 Version 0 June,2014 Bea #2 Drillingver Procedure Rev 0 Hilcorp Energy Company 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp Erma Comtany Changes to Approved Permit to Drill Date: June 25,2014 Subject: Changes to Approved Permit to Drill for Beaver Creek #23 File#: Beaver Creek #23 Drilling Program Any modifications to the Drilling&Completion Program will be documented and approved below. Changes to an approved APD will be aofftewRieste4tithe AOGCC &BLM. q ,rr-t)L) �tcr std t,r u —J Date Procedure Change Approved Approved By By Approval: Drilling Manager Date Prepared: Drilling Engineer Date Page 3 Version 0 June, 2014 Beaver Drilling ProcedureCreek#23 Rev 0 Hilcorp EnergY ComMy 3.0 Tubular Program: Hole OD (in) ID (in) Drift Conn Wt Grade Conn Burst Collapse Tension Sec . �, ,,,� (in) OD (in) (#/ft) (psi) (psi) (k-lbs) Cond 16" 15" - - 109 X-56 Weld 12-1/4" 9-5/8" 8.835" 8.679" 10.625" 40 L-80 BTC 5750 3090 916 8-1/2" 5-1/2" 4.892 4.767 6.050 17 P-110 DWC/C HT 10640 7480 546 4.0 Drill Pipe Information: Hole OD (in) ID (in) TJ ID TJ OD Wt Grade Conn Burst Collapse Tension Section (in) (in) (#/ft) (psi) (psi) (k-lbs) All 4-1/2" 3.826 2.6875" 5.25" 16.6 S-135 CDS40 17,693 16,769 468k All casing will be new, PSL 1 (100%mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 0 June, 2014 Beaver Drilling PCreekrocedure#23 Rev 0 Hilcorp Emu Company 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area—this will not save the data entered, and will navigate to another data entry tab. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini@hilcorp.com , lkeller@hilcorp.com ,mmyers@hilcorp.com and jbarrett@hilcorp.com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. Each rig will be assigned a username to login with. 5.4 EHS Incident Reporting • Notify EHS field coordinator. 1. This could be one of(3) individuals as they rotate around. Know who your EHS field coordinator is at all times, don't wait until an emergency to have to call around and figure it out!!!! a. John Coston: 0: (907) 777-6726 C: (907)227-3189 b. Mark Tornai: 0: (907)283-1372 C: (907) 748-3299 c. Thad Eby: 0: (907) 777-8317 C: (907)602-5178 2. Spills: Kate Kaufman: 0:907-777-8329 C:907-244-8292 • Notify Drlg Manager 1. Paul Mazzolini: 0: 907-777-8369 C: 907-317-1275 • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final"As-Run"Casing tally to mmyers@hilcorp.com and jbarrett@hilcorp.com 5.6 Casing and Cmt report • Send casing and cement report for each string of casing to mmyers@hilcorp.com and jbarrett@hilcorp.com Page 5 Version 0 June, 2014 Beaver Creek#23 II r Drilling Procedure Rev 0 Hilcorp Energy Company 6.0 Planned Wellbore Schematic Beaver Creek PROPOSED Well BCU#23Dait II PTD: 214-093 API: 50-133-20635-00 CASING DETAIL I Mud 16'.,41 i 8 Size Type Wt Grade Conn_ ID Top Btm We ht -' * Conductor —Driven 16' 109 = X-56 Weld 16" Surf 80' Depth r 9-sir Surf.Csg 40 1-80 BTC 8.835" Surf 3559' 8.8 ppg 5 i/2' Prod Csg 17 ', P-110 DWC/C 4.892" Surf 11,370' 9.0 ppg Kr 1 �,1� Drdleg Info ,-.* Hole Section Casing MW Warkstring 1 12-1/4" 9-5/8" 8.8 ppg 4-1/2" 1. 8-1/2" 5-1/2" 9.0-9.5 ppg 4-1/2" f At„ At'..!! lyi t ",, ' JEWELRY DETAIL A. r : No. Depth ID OD Item r'.{ 1 3000` 4.892" 8.5" Baker Swell Packer 8-1/2" .... Hole 1,7 A :fi R R 1 3 4 11) L.4 'Al' #4 i "w 5-112" +, r + "' :u" „' PRTD-11.1-'9411' PET'D 11u9511' TD-11.371'!TVD-11.079' Page 6 Version 0 June, 2014 Bea #2 Drillingver Procedure Rev 0 Hilcorp Energy Company 7.0 Drilling / Completion Summary Beaver Creek#23 is a south easterly step-out appraisal well of the lower and middle Beluga gas sands on the eastern flank of the field between the BCU 13 and BCU 16RD wells. The base plan is a 11370' "S-turn" wellbore with a shallow kickoff around 2000',building to a tangent of 15 deg,then dropping back to vertical at 10470' MD. Drilling operations are expected to commence approximately July 21St, 2014. The Saxon Rig# 169 will be used to drill the wellbore then run casing and cement. Surface casing will be run to 3,559' MD / 3,483' TVD and cemented to surface to ensure protection of any shallow freshwater resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6— 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC and BLM authorities. All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal/beneficial reuse depending on test results. General sequence of operations: 1. MOB Saxon Rig# 169 to well site 2. N/U 21-1/4"x 2M diverter. 3. Drill 12-1/4"hole to 3559' MD. Run and cmt 9-5/8" surface casing. 4. N/D diverter,N/U&test 11"x 5M T3-Energy BOP. 5. Drill 8-1/2"hole section to 11,370' MD. Perform Wiper trip. 6. POOH laying down drill pipe. 7. Run and cmt 5-1/2"production casing . 8. N/D BOP,N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: 1. Surface hole: GR+Res LWD. 2. Production Hole: GR+Res+Den/Neu LWD. 3. Mud loggers from surface casing point to TD. Page 7 Version 0 June, 2014 B 11 Ir Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp Energy Company 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at (2)week intervals during the drilling of Beaver Creek#23. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/4000 psi & subsequent tests of the BOP equipment will be to 250/4000 psi for 10/10 min (annular to 50%rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements" • Ensure both AOGCC approved drilling permit and BLM sundry are posted on the rig floor and in Co Man office. Regulation Variance Requests: • Onshore Oil and Gas Order No. 1, Section III. D. 3. C. Ivo o Hilcorp requests approval to install a 3-1/8" SM HCR valve on kill line in lieu of a check valve. C� Operator suspects a freeze plug risk associated with installation of a check valve in the kill line. Jj,L_ o Hilcorp requests approval to utilize flexible choke and kill lines in lieu of hard piping. �'' v`"4(141cc e 1 .."' (Z/ ty Page 8 Version 0 June, 2014 B Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp linergy Company Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 12-1/4" • 21-1/4"x 2M Hydril MSP diverter Function Test Only • 11"x 5M T3-Energy(Model 7082)Annular BOP • 11"x 5M T3-Energy Double Ram Initial Test:250/4000 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross -- 8-1/2" • 11"x 5M T-3 Energy Single Ram • 3-1/8"5M Choke Line Subsequent Tests: • 2-1/16"x 5M Kill line 250/4000 • 3-1/8"x 2-1/16"5M Choke manifold (Annular 2500 psi) • Standpipe,floor valves,etc • Primary closing unit: Control Technologies accumulator unit, 5 station, 120 gallon (12 x 11 gal bottles). • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: • Well control event(BOPS utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPs. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Required BLM Notifications: • 48 hours before spud. Follow up with actual spud date and time. • 48 hours before casing running and cmt operations • 48 hours before BOPE tests • 48 hours before logging, coring, &testing • Any other notifications required in APD. Additional requirements may be stipulated on APD and Sundry. Page 9 Version 0 June, 2014 B Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp Emir(Company Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.regg@alaska.gov Guy Schwartz/Petroleum Engineer/(0): 907-793-1226/(C): 907-301-4533 /Email: guy.schwartz@alaska.gov Victoria Ferguson/Petroleum Engineer/(0): 907-793-1247/Email: Victoria.ferguson@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone: 907-793-1236 (During normal Business Hours) Notification/Emergency Phone: 907-659-2714 (Outside normal Business Hours) BLM Justin Miller/BLM Petroleum Engineer/ (0): 907-271-3406 (C): 907-717-4039 Use the below email address for BOP notifications to the BLM: BLM_AK_AKSO_Energy Secti on_Notifications@b l m.gov Page 10 Version 0 June, 2014 B Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp Energy Compwy 9.0 R/U and Preparatory Work 9.1 Set 16" conductor at 60' below ground level. 9.2 Dig out and set impermeable cellar. 9.3 Install Seaboard slip-on 16-3/4" 3M"A" section. Ensure to orient wellhead so that tree will line up with flowline later. 9.4 Level pad and ensure enough room for layout of rig footprint and R/U. 9.5 Layout Herculite on pad to extend beyond footprint of rig. 9.6 R/U Saxon Rig# 169, spot service company shacks, spot& R/U company man&toolpusher offices. 9.7 Mud loggers not required on surface hole section. 9.8 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.9 Mix mud for 12-1/4" hole section. 9.10 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.11 Install 5-1/2" liners in mud pumps. • TSM 1000 mud pumps are rated at 3633 psi (85%) / 333 gpm (100%) with 5-1/2" liners. Page 11 Version 0 June,2014 B 14 Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp Energy CernMY 10.0 N/U 21-1/4" 2M Diverter 10.1 N/U 21-1/4"Hydril MSP 2M diverter System. • N/U 16-3/4" 3M x 21-1/4" 2M DSA (Hilcorp) on 16-3/4" 3M wellhead. • N/U 21-1/4"diverter"T". • Knife gate, 16" diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). 10.2 Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked"warning zone" is established on each side and ahead of the vent line tip. "Warning Zone"must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set 15.375" ID wearbushing in wellhead. Page 12 Version 0 June, 2014 Bea #23 Drillingver Procedure Rev 0 Hilcorp FMBy wor 10.5 Rig and Diverter Line Orientation on Beaver Creek 3 pad: - 4#c. Akf 0,T.,,,,,,,r-...1.,-- ,,,,::'.,01,,,,,, „7,:,,f,,,,:_,.„-.., , ,::a, -z=zjzs:..-4„ Va,v,-" ' k * -77'''':11 if w�+�.�z / !kt'-':'''"-- ' --';,s-sp.'-44,4,,•• yt f fi W `1,'-.1-''‘',--4f--.4 3} � t � ,,44,4-' -} �,F 'L'''',::3'1':1;:' t-i:'41-4,1,:fflilt.::;-- 'Zrr:,:'!'W it-r-.:,;/,i1:i*:--rf'-4.irlir''' {fr , r.'''''= '''?I' Air 4 x a T�R si u x fl Beaverpad �i ut r MKfi_gyp tom{ Pad 3 I too ..,:,..:. . Fee June, 2014 Page 13 Version 0 Beaver #2 Drilling Procedure Rev 0 Hilcorp Energy Company 10.6 Diverter Schematic iii Annular Prr anter 2144"2M t l f nil in [mei Knife Gate • la- 16" Diverter line Diverter Tee, 21-1/4"x 21-1/4'x 2M w/' 16"ANSI 150 outlet ill, III 16-1/4"3M x 21-'!."2M DSA MIL 2111 41111110111�Ils i a rir ! Cls a tit Seaboard 16-/"3M 1 � t � ! Casing head Assy 16" Page 14 Version 0 June, 2014 Beaver 14 Drilling ProcedureCreek#23 Rev 0 Hilcorp Energy Company 11.0 Drill 12-1/4" Hole Section 11.1 P/U 12-1/4" directional drilling assy: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Workstring will be 4.5" 16.6# S-135 CDS40 11.2 12-1/4" BHA (GR and Res LWD are included in below BHA): Page 15 Version 0 June, 2014 Beaver Creek #23 Iii[ F Drilling Procedure Rev 0 Hilcorp Energy Company COMPONENT DATA iiiiiiiiiiirw Bern A, 00 ID Gauge Weight Top Length Cumulative Description Serval Nu # ( (6n) (in) (in) (ibpf) Connection (ft) Length (ft} HOBS-OHCIGRC Milltorath 12.200 3-000 12.250 374.30 P 5-.58"REG 1.20 120 © 8"SperraDrirl Lobe 4:5-5.3 stg 8.000 5.000 121.08 8 6-518'REG 28.99 30.19 - Stabilizer _ 11500 Ell Integral Blade Stabilzer IIIIIIIIIIII 8 000 KM 12.125 150.12 86-58'REG 6.00 3.5.-0 ® 8"DM Collar(Directional! 8.000 3.50C 147.40 8 5-518"REG 9.20 45.39 ® 8'DGR Collar (Gam-al 8.000 1.920 142.70 B 5-578'REG 4.55 49.94 ® 8"EWR-P4 Collor(Resist vett'i 8.000 2.000 151.00 B 6-5'8"REG 12.19 62.13 ® 8"HCIP,1 Collar(Processor' 8.000 1.920 149.90 8 6-58"REG 4.97 67.10 8"TM-HOC(Puller) B.150 4.000 145.20 B 6-518'REG 15.77 82.87 Orienting Sub UBHO 8.000 3.000 147.22 B 6-5/6"REG 3.50 86.37 10 Non Mag Flex Drill Collar 8.000 3.000 147.22 B 6-518"REG 30.00 116.37 EMI Non Mag Flex DWI Collar B.000 3 n00 147.22 B 6-518"REG 30.00 146.37 ® X-O 6-58 Reg Pin X 4-112"IF Box 8.000 2.813 150.12 B 4-112"IF 3.50 149.87 ® 8 Joints 5'HWDP 5.000 3.000 49.3C 240.00 389.87 m Weatherford 6-174"Hyd Jar 6.250 2.250 91.01 B 4-1(2"IF 30.00 RES 19 Joints 5"HW DP 5.000 3.000 - 49.30 570.00 989.87 Total 989.87 BIT DATA Bit Number Nozzles : 1 x 12,3x 18 Bit Size (in) : 12250 TFA (in2) :0.8560 Manufacturer : HOBS Dull Grade In .• Model Dull Grade Out .• Serial Number • MOTOR DATA MotorNumber : 2 Bend (deg) : 1.15 OD (in) : 8.000 Nozzles (32nd) Manufacturer : Sperry Drilling Avg Diff Press . Model : SperryDrili Cumul Cir Hrs . Serial Number . Page 16 Version 0 June, 2014 Bea #2 Drillingver Procedure Rev 0 Hilcorp Energy Company 11.3 Primary Bit: 12-1/4" (31'1MM) QHC1CRC PRODUCT SPECIFICATIONS IADC code 117W Total Tooth Count 67 Gage Row Tooth Count 39 Journal Angle 33° Offset(1116") 6 Jet Nozzle Types Standard 83244 Extended 302447 Center Jet (If Center Jetted)501813 T.J.Connection 6-58"(API Reg.) Recommended Make-lip Torque* 28000+2000 Fe lbs. Bit Weight(Boxed) 250 Lbs.(113 Kg.) Bit Breaker (Mat.#/'Legacy#) 515353:506463 `. PRODUCT FEATURES • New patented DiamondT1 Clawk tooth bit design. . Tungsten carbide'surf inserts in gage teeth for added gage 411P7-, , protection. 41.1 • Newly formulated,proprietary hardfacing on cutting structure and ." gage maximizes carbide and diamond volume for ultimate wear " ,, resistance. • High-speed bearing designed for high rpm and high-energy applications. . Innovative mechanical pressure compensating system provides reliable pressure equalization and relief for maximum bearing and seal life. . Raised tungsten carbide inserts and proprietary hardfacing provides maximum arm protection in abrasive and directional applications while minimizing drill string torque. . QuadPacki Plus Series incorporates its successful"longevity" features and patented engineered hydraulics system for optimal cleaning efficiency. • Center jet feature to prevent bit balling problems Material#622394 `Calculations based on recommendations from API and tool joint manufacturers. C 2012 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. Page 17 Version 0 June,2014 B #2 Drillingeaver Procedure Rev 0 Hilcorp Enemy Company 11.4 4-1/2" Workstring & HWDP will come from Saxon. Jars will come from Weatherford. 11.5 Begin drilling out from 16"conductor at reduced flow rates to avoid broaching the conductor. 11.6 Drill 12-1/4"hole section to 3,559' MD/3,483' TVD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 500 - 550 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. • TD the hole section in a good shale between 3500' MD and 3700' MD. • Take MWD surveys every stand drilled(60' intervals). 11.7 12-1/4"hole mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1)ppg above highest anticipated MW. We will start with a simple gel +FW spud mud at 8.8 ppg. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 8.8—9.5 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL pH 80-3559' 8.8-9.5• 85-150 20-40 25-45 <10 8.5-9.0 Page 18 Version 0 June, 2014 Beaver #2 Drilling Procedure Rev 0 Hilcorp Energy CemPanY System Formulation: Aquagel + FW spud mud Product Concentration Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL 12-15 ppb caustic soda 0.1 ppb (9 pH) BARAZAN D+ as needed BAROID 41 as required for weight PAC-L/DEXTRID LT if required for<12 FL ALDACIDE G 0.1 ppb X-TEND II 0.02 ppb 11.8 At TD; pump sweeps, CBU, and pull a wiper trip back to the 16" conductor shoe. 11.9 TOH with the drilling assy, handle BHA as appropriate. 11.10 No open hole logs are planned for the 12-1/4"hole section. Page 19 Version 0 June, 2014 Bea Drillingver ProcedureCreek#23 Rev 0 Hilcorp Energy Company 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull 15.375"wearbushing. 12.2 R/U Weatherford 9-5/8" casing running equipment. • Ensure 9-5/8" BTC x CDS 40 XO on rig floor and M/U to FOSV. • R/U fill-up line to fill casing while running. • Ensure all casing has been drifted on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U&thread locking shoe track assy consisting of: • (1) Shoe joint w/float shoe bucked on (thread locked). • (1)Joint with coupling thread locked. • (1)Joint with float collar bucked on pin end &thread locked. • Install (2) centralizers on shoe joint over a stop collar. 10' from each end. • Install (1) centralizer, mid tube on thread locked joint and on FC joint. • Ensure proper operation of float equipment. 12.5 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use"API Modified"thread compound. Dope pin end only w/paint brush. • M/U connections to the base of the triangle stamped on the pin end. Note M/U torque values required to achieve this position. Estimated torque to reach base of triangle: 10,750 ft-lbs. • After making up several connections, use the torque required to M/U to base of triangle as the M/U torque and continue running string. • Install (1) centralizer every other joint to 300'. Do not run any centralizers above 300' in the event a top out job is needed. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 9-5/8" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 9-5/8" 9,630 ft-lbs Page 20 Version 0 June, 2014 Beaver Creek#23 Drilling Procedure Rev 0 Hilcorp Energy Company Tenaris Casing and Tubing Performance Data Choose pipe size,wall thickness and steel grade to view API connection options and performance data. 1 Size ' Wall Grade 'w Connection V Unit Pipe Body Data GEOMETRY A Nominal OD 9.625 in Wall Thickness 0.395 in API Drift Diameter 8.679 in Nominal Weight 40.00 IbsIt Nominal ID 8.835 in Alternate Drift Diameter 8.75 in Plain End Weight 38.97 lbsift Nominal Cross Section 11.454 sq in PERFORMANCE Steel Grade L80 Minimum Yield 80.000 psi Minimum Ultimate 95.000 psi F--a Body Yield Strength 916,000 lbs Internal Yield Pressure 5,750 psi Collapse Pressure 3,080 psi Connection Data GEOMETRY Regular OD 10.625 in Threads Per Inch 5 Make-Up Thread Turns 1 PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95.000 psi Joint Strength 947.000 lbs Internal Pressure 5,750 psi Resistance ----- _ T m --- TenarisHvdrii Premium Connections ___ I Print I I Contact Us Ver 8.6 Page 21 Version 0 June, 2014 B 111 Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.7 Slow in and out of slips. 12.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. Page 22 Version 0 June, 2014 B Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp E....Company 13.0 Cement 9-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud& water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. 13.2 Document efficiency of all possible displacement pumps prior to cement job 13.3 R/U cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.4 Pump 5 bbls 10 ppg spacer. Test surface cmt lines. 13.5 Pump remaining 30 bbls 10 ppg spacer. 13.6 Drop bottom plug. Mix and pump cmt per below recipe. 13.7 Cement volume based on annular volume+ 50% open hole excess. Job will consist of lead & tail, TOC brought to surface. Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol (ft3) 12.0 ppg LEAD: 80' x .129 bpf= 10.3 57.8 16" Conductor x 9-5/8" casing annulus: 12.0 ppg LEAD: (3059' — 80') x .0558 bpf x 1.5 = 249.3 1400 12-1/4" OH x 9-5/8" Casing annulus: Total LEAD: 259.6 bbl 1457.8 ft3 TAIL: (3559'-3059') x .0558 bpf x 1.5 = 41.9 235.3 12-1/4" OH x 9-5/8" Casing annulus: TAIL: 90 x .096 bpf = 8.7 48.8 9-5/8" Shoe track: Total TAIL: 50.6 bbl 284.1 ft3 Page 23 Version 0 June, 2014 B in 1 Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp Energy Company Cement Slurry Design: Lead Slurry (3059' MD to surface) Tail Slurry (3539' to 3059' MD) System Extended Conventional Density 12 lb/gal 15.4 lb/gal Yield 2.46 ft3/sk 1.22 ft3/sk Mixed Water 14.349 gal/sk 5.507 gal/sk Mixed Fluid 14.469 gal/sk 5.507 gal/sk Code Description Concentration Code Description Concentration G Cement 94#/sk A Cement 94#/sk D110 Retarder 0.15 gal/sk BWOC D046 Anti Foam 0.2% BWOC Additives D046 Anti Foam 0.2 % BWOC D065 Dispersant 0.4% BWOC D079 Extender 2.0% BWOC S002 CaCl2 0.35% BWOC D020 Extender 3.0% BWOC D177 CaCl2 0.1% BWOC 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug and displace cement with 9.0 ppg 6% KCL PHPA. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. 13.11 Displacement calculation: 3559'-80' = 3479' x .0758 bpf=263.7 bbls 13.12 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. Page 24 Version 0 June, 2014 B #2 II Drillingeaver Procedure Rev 0 Hilcorp 13.13 Do not overdisplace by more than 'A shoe track volume. Total volume in shoe track is 8.7 bbls. • Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log between 12— 18 hours after CIP. • Be prepared with small OD top out tubing in the event a top out job is required. The AOGCC will require us to run steel pipe through the hanger flutes. The ID of the flutes is 1.5". 13.14 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.15 R/D cement equipment. Flush out wellhead with FW. 13.16 Back out and L/D landing joint. Flush out wellhead with FW. 13.17 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.18 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration a. Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement, actual displacement volume,whether plug bumped&bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure e. Note if pre flush or cement returns at surface&volume f. Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final "As-Run"casing tally & casing and cement report to mmyers@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 25 Version 0 June,2014 Beaver II Drilling ProcedureCreek#23 Rev 0 Hilcorp Energy Company 14.0 BOP N/U and Test 14.1 N/D the diverter. 14.2 N/U Seaboard multi-bowl wellhead assy. Install 9-5/8"packoff P-seals. Test to 3000 psi. 14.3 N/U 11" x 5M T3-Energy BOP as follows: • BOP configuration from Top down: 11" x 5M T3-Energy annular BOP/11"x 5M T3-Energy Model 6011i double ram/11"x 5M mud cross/11"x 5M T3-Energy Model 6011i single ram • Double ram should be dressed with 2-7/8 x 5"VBRs in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8 x 5" VBRs • N/U bell nipple, install flowline. • Install (2) manual valves & a check valve on kill side of mud cross. • Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.4 Run 4-1/2" BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/4000 psi for 10/10 min. Test annular to 250/2500 psi for 10/10 min. • Ensure to leave "B" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 9.0 ppg 6% KCL PHPA mud system. 14.8 R/U mud loggers for production hole section. ✓ 14.9 Set 10" ID wearbushing in wellhead. 14.10 Rack back as much 4-1/2" DP in derrick as possible to be used while drilling the hole section. Page 26 Version 0 June, 2014 B 11 Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp Enemy Comm, 15.0 Drill 8-1/2" Hole Section 15.1 P/U 8-1/2" directional BHA. 15.2 Ensure BHA components have been inspected previously. 15.3 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.4 TF offset is measured accurately and entered correctly into the MWD software. 15.5 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. 15.6 Workstring will be 4.5" 16.6# S-135 CDS40. Page 27 Version 0 June, 2014 Beaver Creek #23 n 1- Drilling Procedure Rev 0 Hilcorp Energy Company 15.7 8-1/2" BHA: 1 HDBS-FX65D PDC B.400 2.50C 8.50C 172 13 P 4-12-REG 1.00 1.00 2 7"SperryDritl Lobe 718-6.0 stg 7.000 4.952 93.13 B 4-1tr IF 27.38 28.38 Stabilizer 7.750 3 Nor Mag Float Sub 6.750 2.750 101.71 B 4-112'IF 3.00 31.38 4 Integral Blade Stabilizer(NM) 6.750 2.813 8.375 10077 B 4-1(2'IF 5.00 3628 5 6 34"DM(Directional) 6.750 3.125 10340 B 4-112'IF 9.20 4.558 6 5 34"BAT (Sonic) 6.750 1.905 97.70 B 4-1;2"IF 20.30 65.89 7 6 3(4'DGR(Gemmel 6.750 192C 97.80 0 4-112"IF 4.55 70.44 8 6 314'EWR-P4 (Resistivetyi 6.750 2.000 104.30 B 4-1(2"IF 12.10 82.54 9 6 314'HCIM {Processor) 6.750 1.92C 101.70 B 4-112'1F 4.97 87.51 10 6 314'ALD (Densly) 6.750 1.920 8.250 104.30 B 4-1;2"IF 14.54 102.05 Stabilizer 82.. 11 5 .. 'CTN{Neutron; 6.750 1.905 102.30 B 4-4,2"iF 11.84 113.89 12 6 3(4"TM-HOC(Puller; 6.900 3.250 103.60 B 4-1/r IF 15.59 129 48 13 Non Mag Flex Dri=ll Collar 6.750 2.813 100.77 B 4-1(2'IF 30.00 15948 14 Non Mag Flex Drill Collar 6.750 2.813 100 77 B 4-1(2'IF 30.00 189.48 15 8 Joints 5'HWDP 5.000 3.000 43 3C 240.00 429.48 16 Weatherford 6-114'Jars 6.250 2.250 91.01 B 4-112"IF 30.00 459.48 17 19 Jonts 5"HWDP 5.000 3.000 4337, 570.03 102948 ,-i 1029.48 DATA Bit Number Nozzles :5x13 Bit Size (in) : 8.570 TFA (int) : 06481 ManufacturerDull Grade In Model Dull Grade Out . Serial Number .• MOTOR DATA Motor Number : 1 Bend (deg) : 0.00 00 (in) . 7.000 Nozzles (32nd) C.0 Manufacturer : Sperry Drilling Avg Diff Press . Model : SperryDritt Cumul Cir Hrs .• Serial Number Page 28 Version 0 June, 2014 Beaver Creek#23 Drilling Procedure Rev 0 Hilcorp Energy Company 15.8 Primary Bit: HALLIBURTON 8-112" (216mm) FX55 PRO)DUCT SPECIFICATIONS Cutter Type tx-Extreme Min; 1ADC Code M4124 Body Type NIA RD% Total Cutter Count 41 Cutter Distribution .jAILM Ikon Fare 0 2te , Gauge 5 5 f fr Up Drill 5 0 Number of Large Nozzles 5 Number of Medium Norz&s a Number of Small Norrhm a • P. Number or Micro Nozzles a Number of lbtls a Junk Sloe Area 1 sq in 1176 Normalized Face Volume 37.061: F API Connection 4-1,2 REG.PIN Reco iom.-td d lltakr-Cp Tongue' 12.461-17.66 F1'I6s. Nominal Dimensions** Make-Up Face to Nose 11.11 iin.2112 ort Gauge Length 2 in-5l tette Skcve Length 0 it-0 m Shank Diameter 6in-152ms Break Out PLate tMat.M.Leeacv t 18I95,4r44040 Approximate Shipping iVeiaht. 15414.1w.-68114... SPECIAL FEATURES tip-Drill Curlers an Gage Pads.1:32"Relieved Liatp Malcnal#687916 'Bit specific mn+mnrnixl mite-up tome is a ragmen of the hit I.D.and xtml hit sub O.D.utilized as specified in API RP7G Section A./CI "D esism dimensions arc nominal and ten say slightly m mra.:acture d random.Ilallitwtcn Dual Bits and Semites models are continuously reviewed and refined Ptsslw-1 spetifcasions rmy chacze without mmccc. 201:Ilalliburt m.All rights reserved Saks of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www.halliburton.Com Page 29 Version 0 June, 2014 B Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp Energy Company 15.9 8-1/2"hole section mud program summary: Weighting material to be used for the hole section will be salt and calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1)ppg above highest anticipated MW. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.0 ppg 6%KCL PHPA fresh water based drilling fluid. Properties: MD We ght Viscosity Vis Plstic sity Yield Point pH HPHT 3559'- 11.370' 9.0—10.0 - 40-53 15-25 15-25 8.5-9.5 <11.0 System Formulation: 6% KCL EZ Mud DP Product Concentration Water 0.905 bbl KCl 22 ppb (29 K chlorides) Caustic 0.2 ppb (9 pH) BARAZAN D+ 1.25 ppb (as required 18 YP) EZ MUD DP 0.75 ppb(initially 0.25 ppb) DEXTRID LT 1-2 ppb PAC-L 1 ppb BARACARB 5/25/50 15-20 ppb(5 ppb of each) BAROID 41 as required for a 9.0—10.5 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb (maintain per dilution rate) 15.10 TIH w/ 8-1/2"directional assy to TOC. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. 15.11 R/U and test casing to 3000 psi/30 min. Ensure to record volume /pressure and plot on FIT graph. AOGCC reg is 50% of burst. 15.12 Drill out shoe track and 20' of new formation. 15.13 CBU and condition mud for FIT. Page 30 Version 0 June, 2014 B Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp Energy ComPM' 15.14 Conduct FIT to 11 ppg EMW. Note: Offset field test data predicts frac gradient at the 9-5/8"shoe to be btwn 15 - 16 ppg EMW. An 11 ppg FIT results in a 2 ppg kick margin while drilling with the planned MW of 9 ppg• 15.15 Drill 8-1/2"hole section to 11,370' MD • BHL is 1570' West from Unit boundary, DO NOT OVERSHOOT BH TARGET! / • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 400 - 500 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team, try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. • Take MWD surveys every other stand drld. Surveys can be taken more frequently if deemed necessary. • Take (3) sets of formation samples every 20'. Mud loggers should compile Pixler plots and QFT 2 analysis for Lower Tyonek to total depth. 15.16 At TD; pump sweeps, CBU, and pull a wiper trip back to the 9-5/8" shoe. 15.17 TOH with the drilling assy, laying down drill pipe and BHA. 15.18 Install 5-1/2"pipe rams in BOP stack and RU and test. Page 31 Version 0 June, 2014 B #2 11 Drillingeaver Procedure 3 Rev 0 Hilcorp I::nergy Company 16.0 Run 5-1/2" Production Casing 16.1. R/U Weatherford 5-1/2" casing running equipment. • Ensure 5-1/2" DWC/C HT x CDS 40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted prior to running. • Be sure to count the total # of joints before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 16.2. P/U shoe joint,visually verify no debris inside joint. 16.3. Continue M/U &thread locking shoe track assy consisting of: • (1) Shoe joint w/shoe bucked on &threadlocked(coupling also thread locked). • (1)Joint with float collar bucked on pin end &threadlocked (coupling also thread locked). • Solid body centralizers will be pre-installed on shoe joint an FC joint. • Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe and float collar. • Utilize a collar clamp until weight is sufficient to keep slips set properly 16.4. Continue running 5-1/2"production casing • Fill casing while running using fill up line on rig floor. • Use"API Modified"thread compound. Dope pin end only w/paint brush. • Install solid body centralizers on every joint across zones of interest, TBD after LWD. • Install solid body centralizers on every other joint to 9-5/8" shoe. Leave the centralizers free floating. • Pick up swell packer and place in string at approximately 3000'. 16.5. Continue running 5-1/2"production casing 5-1/2" DWC/C HT M/U torques Casing OD Minimum Maximum Yield Torque 5.5" 12,000 ft-lbs 13,800 ft-lbs 18,700 ft-lbs Page 32 Version 0 June, 2014 Beaver Creek#23 Drilling Procedure Rev 0 Hilcorp Energy Company Technical Specifications Connection Type: Slze(O.D.): Weight (Wall): Grade: DWC!C-HT Casing 5-112 in 17.00 lb/ft(0.304 in) P-110 standard Material P-110 Grade 110.000 Minimum Yield Strength (psi) 'USA 125.000 Minimum Ultimate Strength (psi) VAM USA 4424 W.Sam Houston Pkwy.Suite 150 Pipe Dimensions Houston,TX 77041 Phare:713-479-3200 5.500 Nominal Pipe Body O.D. (in) Fax:713-479-3234 4.892 Nominal Pipe Body I.D.(in) E-mail:VAMUSAsates(r1vam-usa.com 0.304 Nominal Wall Thickness (in) 17.00 Nominal Weight (Ibsfft) 16.89 Plain End Weight(lbslft) 4.962 Nominal Pipe Body Area (sq in) Pipe Body Performance Properties 546,000 Minimum Pipe Body Yield Strength (lbs) 7,480 Minimum Collapse Pressure (psi) 10,640 Minimum Internal Yield Pressure (psi) 9,700 Hydrostatic Test Pressure (psi) Connection Dimensions 6.050 Connection O.D. (in) 4.892 Connection I.D. (in) 4.767 Connection Drift Diameter(in) 4.13 Make-up Loss (in) 4.962 Critical Area (sq in) 100.0 Joint Efficiency(%) Connection Performance Properties 546.000 Joint Strength (lbs) 22.940 Reference String Length (ft) 1.4 Design Factor 568.000 API Joint Strength (lbs) 546.000 Compression Rating (lbs) 7.480 API Collapse Pressure Rating (psi) 10.640 API Internal Pressure Resistance (psi) 91.7 Maximum Uniaxial Bend Rating [degrees/100 ft] Appoxlmated Field End Torque Values 12,000 Minimum Final Torque (ft-lbs) 13,800 Maximum Final Torque (ft-lbs) 18,700 Connection Yield Torque (ft-lbs) For detailed information on performance properties,refer to DWC Connection Data Notes on following page(s). Page 33 Version 0 June, 2014 B II Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp 16.6. Run in hole w/ 5-1/2" casing to the 9-5/8" casing shoe. 16.7. Fill the casing with fill up line and break circulation every 1,500 feet to the window or as the hole dictates. 16.8. Obtain slack off weight, PU weight, rotating weight and torque of the casing. 16.9. Circulate 2X bottoms up at shoe, ease casing thru shoe. 16.10. Continue to RIH w/casing no faster than 1 jt./minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.11. Set casing slowly in and out of slips. 16.12. PU 5-1/2"X 8-1/2" swell packer to be placed at approximately 3000'. Swell packer should have 10' handling pups installed on both ends with bow spring centralizers on pups. 16.13. Swedge up and wash last 2 joints to bottom. P/U 5' off bottom. Note slack-off and pick-up weights. 16.14. Stage pump rates up slowly to circulating rate. Circ and condition mud with casing on bottom. Circulate 2X bottoms up or until pressures stabilize and mud properties are correct and the shakers are clean. Reduce the low end rheology of the drilling fluid by adding water and thinners. 16.15. Reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 34 Version 0 June, 2014 Beaver Drilling ProcedureCreek #23 Rev 0 Hilcorp Energy Company 17.0 Cement 5-1/2" Production Casing 17.1. Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud& water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 17.2. Attempt to reciprocate the casing during cmt operations until hole gets sticky 17.3. Pump 5 bbls of 12.5 ppg Mud Push spacer. 17.4. Test surface cmt lines to 4500 psi. 17.5. Pump remaining 30 bbls 10.5 ppg Mud Push spacer. 17.6. Mix and pump lead and tail cement per below recipe. Ensure cement is pumped at designed weight. Job is designed to pump 35% OH excess. Section: Calculation: Vol Vol (ft3) (BBLS) 9-5/8"x 5-1/2" Csg Overlap: 500' x 0.0464 = 23.2 130.4 8-1/2"OH x 5-1/2" Casing: (1 1370—3000) x 0.0408 x 1.35 = 461.0 2588.4 Shoe Track: 80' x 0.02325 = 1.9 10.4 Total Volume : 486.1 2729.2 Page 35 Version 0 June, 2014 Beaver PCreekrocedure# 3 Rev 0 Hilcorp Energy Company EASYBLOK (11370' to 3000') System Conventional Density 15.3 lb/gal Yield 1.36 ft3/sk Mixed Water 5.93 gal/sk Mixed Fluid 5.93 gal/sk Code Description Concentration Class G Cement 94#/sk D046 Foam Preventer 0.2% BWOC D202 Dispersant 1.5% BWOC Additives D400 EASYBLOK 0.8% BWOC D154 Extender 8.0% BWOC D174 Expanding Additive 1.5% BWOC D198 Retarder 0.3% BWOC 17.7. Drop wiper plug and displace with produced water. 17.8. If hole conditions allow—continue reciprocating casing throughout displacement. This will ensure a high quality cement job with 100% coverage around the pipe. 17.9. If elevated displacement pressures are encountered, position casing at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 17.10. Bump the plug and pressure up to 500 psi over final lift pressure. Hold pressure for 3 minutes. 17.11. Do not overdisplace by more than V2 shoe track. Shoe track volume is 1.9 bbls. Page 36 Version 0 June, 2014 Beaver Drilling ProcedureCreek #23 Rev 0 Hilcorp hnergy Company 17.12. Bleed pressure to zero to check float equipment. Watch for flow. Note amount of fluid returned after bumping plug and releasing pressure. 17.13. RD cementers and flush equipment. 17.14. WOC minimum of 12 hours,test casing to 3000 psi and chart for 30 minutes. Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing,bpm,note any shutdown during mixing operations with a duration i. Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid j. Note if casing is reciprocated or rotated during the job k. Calculated volume of displacement,actual displacement volume,whether plug bumped&bump pressure, do floats hold 1. Percent mud returns during job, if intermittent note timing during pumping of job.Final circulating pressure m. Note if pre flush or cement returns at surface&volume n. Note time cement in place o. Note calculated top of cement p. Add any comments which would describe the success or problems during the cement job Send final "As-Run"casing tally & casing and cement report to mmyers@hilcorp.coin. This will be included with the EOW documentation that goes to the AOGCC. Page 37 Version 0 June,2014 B 11 Drillingeaver ProcedureCreek#23 Rev 0 aim Hilcorp ox.my 18.0 RDMO 18.1. Install BPV in wellhead 18.2. N/D BOPE 18.3. N/U temp abandonment cap 18.4. RDMO Saxon Rig#169 Page 38 Version 0 June, 2014 Beaver Creek#23 I- Drilling Procedure Rev 0 Hilcorp Energy Company 19.0 BOP Schematic a ,, mini rill irn rfT in ''n •L„. i itri 'v1c dei 60111 11"-5000 r i riEft tf t[fitin L 1� J, L+ , el 1 3 mere.. I -zT.-. ' 1!1 'O5 ''Model 70822 . H ( � 11" `000 }"'.. *e4 ./ I 2.00 o . �I r 2 1/16 SM Kill Side 1/8 SM Choke Side 1 .11' "111110111111k '1 i 7082 — -Si 41Si1 . . - . ...,, J 1 ��}}--�� tw Grade sea lite iii rii epi .1 lEll '. .....P.riii:iiNemre , S, c r tv* A Page 39 Version 0 June,2014 Beaver II Drilling ProcedureCreek#23 Rev 0 Hilcorp Energy Company 20.0 Wellhead Schematic Beaver Creek New Drill-Saxon 169 16 X 95/8 X 51/2 Tree cap,Otis,5 1/8 5M FE X 9'A Otis Quick Union MI m:1E:..r Valve,Swab,WKM-M, - 51/B SM FE,HWO, �C, DD trim -ft• �, ��U,..Ut�. is.. \ 1 Valve,Wing,WKM-M J 1 �4 J _ Valve,Wing,WKM-M, 3 1/8 5M FE,HWO 1. � r 3 1/8 SM FE,HWO, DD trim '1,\ � �, : (, i ! DD trim Valve,Upper Master, n C� WKM-M,51/85M FE,HWO, 6*# ., DD trim l It 111111 Crossover spool, imrr�r r�"riir 5 1/8 5M FE X 5 1/8 10M FE r� y-P! Valve,Master,CIW-FC, t' : il 5 1/8 10M FE,HWO, i i- r!' {' EE trim \. �U vv' I r -- - Ell r -Arriiv mien ag Tubing head,Seaboard-58, lIL� 163/43MX 115M, I' `�ri�l" - i w/2-2 1/16 5M SSO, { 1 .'{ =i`,�'' . 9 5/8 P seal bottom iH , •�~ I .,. W .. 1—T i..- I Starting head,Seaboard, 16%3MX 16"SOW BTM, ill M _I : N w/2-21/165M5S0 SIS _ 4Fu 1 I A , t II 16" 9 5/8" I 5'A" Page 40 Version 0 June, 2014 B2 111 Drillingeaver ProcedureCreek# 3 Rev 0 Hilcorp Energy Company 21.0 Days Vs Depth Days Vs Depth 0 —Beaver Creek 23 2000 4000 s a 6000 on A I 8000 10 000 12000 0 5 10 15 20 25 30 Days Page 41 Version 0 June, 2014 Beaver Drilling ProcedureCreek#23 Rev 0 Hilcorp Energy Company 22.0 Geo-Prog GEOLOGICAL PROGNOSIS WELL NAME: BCU 23 (GR well from Pad 3) FIELD: Beaver Creek SURFACE X: 317534.3 STATE: Alaska SURFACE Y: 2434057.1 BHL X 319514.1 TVD REF DATUM KB BHL Y 2433200.0 TVD REF ELEV 179 18.6'KB(Saxon 169) COORD REF. SYSTEM NAD27 GROUND ELEV 160.6 PROPOSED TD MD: 11371 1 PROPOSED TD TVD: 11079 Objective: Beluga B18-B32 gas sands and Sterling B-1 to B-4 Geo Summary/ Justification: `The goal of the BCU 23 is to test the Middle and Lower Beluga gas sands(BI8-B32)on the eastern flank of the field between the BCU 10 and 13 wells ANTICIPATED FORMATION TOPS&GEOHAZARDS EXPECTED - - Critical Intersection Polnb TOP TOP NAME FORMATION FLUID MD TVD(FT) Est.Pressure X Y +/- _ SHALLOW_GAS1 Sterling water/gas 3,047 3,021 1200-1300 psi 317730.258 2433972.469 25 BC_B1 ST Sterling water/gas 4,945 ' 4,848 1900-2300 psi 318203.2 2433768.2 25 BC_B4ST Sterling water/gas 5,349 ' 5,236 1900-2300 psi 318303.9 2433724.7 25 UBC3 Beluga water/gas 6,220 ' 6,074 1000-3300 psi 318520.8 2433631.0 25 BC_B18UST Beluga gas 7,438 • _ 7,247 1000-3400 psi 318824.4 2433499.8 25 BC_B24ST Beluga gas 7,985 7,773 3000-3500 psi 318960.6 2433441.0 25 BC_B28ST Beluga gas 8,141 7,923 3000-3600 psi 318999.5 2433424.2 25 BC_B3OST Beluga gas 8,430 i _ 8,201 3000-3600 psi 319071.5 2433393.1 25 SR_TYONEK Tyonek water 8,949 • 8,701 3000-3600 psi 319200.9 2433337.2 25 TO 11371 ' 11079 =Primary Objective =Secondary Objective TARGET RADIUS 50 ft DATA COLLECTION REQUIREMENTS: Mud Logging: Full crew of 4 for production hole section. 2 sets of washed&dried samples collected every 20 ft from KOP to TD. Plxler plot! • LWD Data: Sperry Triple Combo LWD E-Line Log Data: COMPLETION TYPE ANTICIPATED RATES ARTIFICIAL LIFT EQUIPMENT OD TUBING SIZE 2-7/8" OTHER COMMENTS 2. We do not anticipate crossing any significant faults that would pose drilling problems. 3. BCU 14&01B drilled with 9.5 ppg mud through the Sterling and 9.3-9.9 ppg mud through the lower Beluga 4. We expect similar conditions encountered in the drilling of the BCU 01B well in early 2014 Page 42 Version 0 June, 20M Beaver 111 Drilling PCreekrocedure#23 Rev 0 Hilcorp ComPanY 23.0 Anticipated Drilling Hazards 12-1/4" Hole Section: Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/ gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP btwn 25 —45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole-cleaning problems. If encountered, be prepared to increase the viscosity. Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of—50 -—60 lbs/100ft2 to combat this issue. Maintain low flow rates for the intial 200' of drilling to reduce the likelihood of washing out the conductor shoe. To help insure good cement to surface after running the casing, condition the mud to a YP of 25 —30 prior to cement operations. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheologies can be achieved. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. Page 43 Version 0 June, 2014 B #2 II Drillingeaver Procedure Rev 0 Hilcorp Enemy Company 8-1/2" Hole Section: Lost Circulation: Ensure 1000 lbs of each of the different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/viscosifier as necessary. Sweep hole w/20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP btwn 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain MW as necessary using additions of Calcium Carbonate as weighting material. A torque reduction lube may be used in this hole section in concentrations up to 3% if needed. Maintain 6% KC1 in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. ' • Use asphalt-type additives to further stabilize coal seams. • Increase fluid density as required to control running coals. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: H2S is not present in this hole section. ' No abnormal temperatures are present in this hole section. Page 44 Version 0 June, 2014 Beaver Creek#23 11 0 Drilling Procedure Rev 0 Hilcorp I::nergy Company 24.0 Saxon Rig 169 Layout . ., _ ,. . _PPE r.:Ps .. .. - -- - FFiF.f UNN, I_I--=I—I_'=� III'_` _... IIIIIII ��I 1 1E-to,L,ii, I 1 III ,I I0--•--".i--I — - Inumi �. II�U�`u' -t gar "Tf e.l 1 ,t �I IIII I l�I I I- ini��_1 � u11 °. 1 v.m enry un.r.�. --Ft — _ ........w.. I A 111 i1 C I L 9 L!7 1 I H. F�»�1F.TMY/FM'x.y Page 45 Version 0 June, 2014 B Drillingeaver ProcedureCreek #23 Rev 0 Hilcorp Energy Company 25.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer(ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 46 Version 0 June,2014 Beaver Creek#23 Drilling Procedure Rev 0 Hilcorp Energy Company 26.0 Choke Manifold Schematic .y n 1 id II mil— IPTi frliv b ? _ 1 R P Zi: N 1._. it ^1.I�WN. ¢ Y � ,,, Ill le rot,44)14A4 gi —8 I w ■.r 0�a e ¢ 111111111.111111 u N }h '1., $ jai p Phn! w 4 , I)05nd C b T „.„ ,, _ , 41.4,1k,44) ti liritA. ai! �. e to '11111091 CiliNtr illtiliP :lr 0 . glif w P ., -.,. NM0 Lift ari,* a ` _fir il ink, 1"g 1 0 � om i 4.' I # o € E li -- = xril I ' — r ill Iil l 601 Page 47 Version 0 June, 2014 B II Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp Energy Company 27.0 Casing Design Information Calculation &Casing Design Factors Beaver Creek Unit DATE:6/20/2014 WELL:Beaver Creek#23 FIELD:Beaver Creek DESIGN BY:Monty M Myers Design Criteria: Hole Size 12-1/4" Mud Density: 8.8 ppg Hole Size 8-1/2" Mud Density: 9.0 ppg Hole Size Mud Density: Drilling Mode MASP: 1510 psi(see attached MASP determination&calculation) MASP: Production Mode / MASP: 2747 psi (see attached MASP determination&calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress(0.435 psi/ft)and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 r 4 i Casing OD _ . _9-5/8" 5-1/2"...__. 1. _._. Top(MD) 0 0 Top(TV EI ...._.�_.____. _ ._. 0 _... 0_.._._. -.._.. ... L. __.. _.._ Bottom(MD) ___...._ _.....___.._,. 3,559 * 11,370 € ! Bottom(ND) 3,483 11,079 Length 3,559 11,370 i Weight(ppf) 40 17 i Grade L-80 P-110 I Connection BTC DWC/C HT i i Weight w/o Bouyancy Factor(lbs) 142,360 193,290 I `•. Tension at Top of Section(lbs 142,360 193,290 Minstrength Tension(1000 lbs) 916 546 ,/ i Worst Case Safety Factor(Tension) 6.43 2.82 it Collapse Pressure at bottom Psi 1,515 4,819 I Collapse Resistance w/o tension(Psi _ 3,090 7,480 Worst Case Safety Factor(Collapse) 2.04 1.55 > i ;..___.._._..._._. MASP(psi) 1,758 2,747 Minimum Yield(psi) . 5,750 10,640 v Worst case safety factor(Burst) 3.27 3.87 ✓ I Page 48 Version 0 June, 2014 Beaver Creek#23 tit 11- Drilling Procedure Rev 0 Hilcorp Energy Company 28.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 8-1/2"Hole Section Hilc p Beaver Creek#23 Beaver Creek Unit MD ND Planned Top: 0 0 Planned TD: 11370 11079 Anticipated Formations and Pressures: Formation ND Est Pressure Oil/Gas/Wet PPG Grad Shallow Gas 3028 1300 WATER/GAS 8.3 0.429 B2 5077 2300 WATER/GAS 8.7 0.453 B4 5254 2300 WATER/GAS 8.4 0.438 UBC3 6095 2850 WATER/GAS 9.0 0.468 B18 7265 3400 GAS 9.0 0.468 B24 7782 3500 GAS 8.6 0.450 B28B 7923 3600 GAS 8.7 0.454 B30 8216 3600 GAS 8.4 0.438 Tyonek 8715 3600 GAS 7.9 0.413 TD 11079 3850 WATER 6.7 0.348 Offset Well Mud Densities Well MW range Top(ND) Bottom(ND) Date Beaver Creek 1B 9.2-9.9 ppg 5,200 10,900 2014 Beaver Creek 11 8.8-9.6 ppg 400 8,684 2003 Beaver Creek 13 8.5-10.4 ppg 0 10,182 2003 Beaver Creek 14A 9.0-9.4ppg 5,000 9,450 2014 Beaver Creek 7A 9.0-9.3 2,400 8,929 2014 Assumptions: 1. Fracture gradient at shoe is estimated at 0.65 psi/ft based on field test data. 2. Maximum planned mud density for the 8-1/2"hole section is 9.5 ppg. 3. Calculations assume"Unknown"reservoir contains 100%gas(worst case). 4. Calculations assume worst case event is 100%evacuation of wellbore to gas. Fracture Pressure at 9-5/8"shoe considering a full column of gas from shoe to surface: 3483(ft)x 0.65(psi/ft). 2264 psi 2264(psi)-[0.1(psi/ft)*3483(ft)]= 1916 psi MASP from pore pressure(unknown gas sand at TD,at 8.4 ppg,encountered while drilling) gay (11,079(ft)x 0.348(psi/ft)= 3855 psi 3855(psi)-[(2/3)*0.1(psi/ft)*11079(ft)]+[(1/3)*0.435(psi/ft)*11079(ft)]= 1510 psi W1-1 MASP from pore pressure during production mode(Complete evacuation to gas) 11,079(ft)x 0.348(psi/ft)= 3855 psi ; ' .141 (3855(-[0.1(psi/ft)*11,079(ft)j= 2747 psi Summary: 1. MASP while drilling 8-1/2"production hole is governed by pore pressure and evacuation of 2/3 wellbore to gas at 0.1 psi/ft. Page 49 Version 0 June, 2014 Beaver Creek#23 Drilling Procedure Rev 0 Hilcorp Energy Company 29.0 Spider Plot (NAD 27) (Governmental Sections) Legend BCU 23 SHL BCU 23 TPH ecu 03RD BrE, • BCU 23 BHL Other Surface N&Locations Other Bottom Hole Locations -- Well Paths Oil and Gas Unit Boundary. BcU 03 BHV ECU1; c° • ` ECU ,•• . r r / / ECU 11 9 // i // t / e' // S007NO1OW / '>>BCU23 sHLro`u,28HL A028083 BEAVER CREEK UNIT - - `fie' aaha. BCU 23 TPH BCU 04 BF�G ! \\\\ f BCU 23 BHL ie/ t d BCU 66 f r' t ECU$3 Me. ES ECU 19 EHE° ECU 05 EHL ECU t-" EHL ECU 14 EHtr / / ECU 10 BFIL,, .9cv]ORD SRL- * ECU o_1a$Ft• o •.00� 3003Beaver Creek Unit Feet BCU 23 aa:la slate Pane Zone 4 NADZT A I tle,$l...1.11 4Up Dane:0=252014 Page 50 Version 0 June, 2014 Beaver Creek#23 it F Drilling Procedure Rev 0 Hilcorp Energy Company 30.0 Surface Plat (As Built) (NAD 27) , INI • r � • .SE CTION1INE NOT TO SCALE . . ' • • ' " ' - ' E 315835A6 f -Li_ IU to v W • I§ SECTION 34 T7N R10W SM,AK 'g w •Z •J r`` 10 W i BEAVER CREEK UNIT B.C.U.NO.23 •w PAD 3 _ AS-BUILT *AL,.. 1" N:2434057.104' f 1r 1715 I ac •. . 601 P .cu 4. / E:317534.335' I/ FYVL4NTSI 1 1 •. • • / LAT:60'39'30,8932'N • • / � w / LONG:-151°(11'01.4381"W I �6 t F��. 66"..°O.r -'I I NAD27 ASP Zone 4 Akr.if• ELEV:160.23 NAVA .��` 1715FWL - • 4.. 1125•FAIL 1 A . 13 i .�"" / NOTES I ` —/ 11 BASIS OF GEODETIC COMM.ANI)NAD POSITION{EPOCH 2993y IS AN CPUS • SOLUTION FROM NGS COORDINATES STATIONS-KENT CORS ARP",'TLKA TALKEETNA CORS ARP`,AN3'POT3 POTATO POINT 3 ARP"TO ESTABLIS►4 THE POSITION OF MCI BCI.THE GEODETIC POSITION OF L+C1 WAS DETERMINED TO HAVE A LATITUDE OF 80.38'5442777"N AND A LONGITUDE OF I 151"3222.30311'W.THE ALASKA STATE PLANE tl `��ttt411 i COORDINATES24293ASP)ZONE 4 ARE OF 4 rr E*1429993.535* ��F," " ,r E*l453863.OB5 �y ELEV 131,31' NAt i 4/itt�1794n F�'1 NORTH OR 21 BASIS OF VERTICAL CONTROL Is NOS BM van I r ^"'� •i PID TTO50a LOCATED WITHIN THE KENAI SPU STAN A.Y LA E • 7.4 s HIGHWAY RIGHT OF WAY AT MILE POST 3.75 • 1// U 2`u a:li HAVING AN ELEVATION OF ISA 55 FEET NOW •%_ 1 w DL I ES ACCORDING TO NGS PUBLISHED DATA. r11'1 111W:07.% SC E 31 COORDINATES COVERTEO TO NAD 27 USING • ` CORPSCON CONVERSION SO'TA'ARE BCU 423 WELL AS-BULT SURFACE LOCATION (NAD27) BEAVER CREEK UNIT PAD 3 lit /` ENGINEERING-TESTING LOCATION:SECTION 34, TOWNSHIP 7 NORTH, 5 SURJEYING-MAPPING RANGE 10 WEST.SEWARD MERIDIAN ALASKA P y P.4 BOX 468 Ilil+w,r llurtlsu,1.1,(; tt SOLbOTNA,AKr,#,s JOB NO, 143081 VOICE:{9071283-0218 FAX:(997)283-3265 DRAWN BY Coad*/he WWW.MCLANECGCOM BMM DATE;08x08114 1 Page 51 Version 0 June, 2014 Beaver Creek#23 ti I- Drilling Procedure Rev 0 Hilcorp Energy Company 31.0 Surface Plat (As Built) (NAD 83) 4:434969.19 SECTIONLINE NOT TO SCALE E,4550t6.90 I .w J I0 L) S/I .O N IzSECTION 34T7NR1OWSM,AK LL w .z If ......._, ........._ i. BEAVER CREEK UNIT �''� B.C.U.NO.23 PAD 3 AS-BUILT I N:2433817.990' 1 tits 1 t•..11 .�'..�. / E:1457555.503' Fri&{NTSI I `• r I LAT:BO"39'28.8461'N • / "41.' / LONG:-151.'01109.4542'W • I41747 / • [[ 4w°y'�''Ott,,.'•. / NAD83ASP Zone 4 aca m ao / ELEV:160.23'NAVD88 • 1715'Mt. • •,. a<S�. a `. 1125'FNL I //\ 1141141.1 - • ......:,,...„..„_,._"/ '•` ,._,._ / r NOTES ` . 1) BASIS or GEODETIC CCNTRCL AND NW3.93 POSITION IEPOCIl2033)1S AN OPUS SOLUTION FROM NGS COORDINATES I STATIONS 9KEN1 Cons ARP-.'TLKA TALKEETNA COPS ARP',AM)TOT3 POTATO POINT 9 ARP"TO ESTABLISH THE POSITION OF MCI BC1 THE GEODETIC POS!TIQN OF SCI ` WAS DETERMINED TO HAVE A LATITL )E OF I ``%tttt%%111 00'39'50027TTNANDALONGITUDEOF '�SE(�F 4 l� 151'02'22.30311'W THE ALASKA STATE FLAW �I f„.. ,.f-?4 COORDIM4TES(ASP)T ONE 4 ARE �•J 1,. N-2427A33.x1'4• 14 DI l4,• NORTH £=1453863.065• iL,,,Y ' eLEV.131.31'/NAVOM) • �, ` �f1 + 21 SAS Of VERTICAL CONTROL IS NGS BM WO "yM+f PIO TT0506LOCATED ITHINTHE KENAISPUR ,1g_ w;>,,"� ,>r.� 2C0 4M HIGHWAY RIGHT C4 WAY AT MILE POST 3.75 I 71111%%%%%%� 9GKLt I• HAVING AN ELEVATION OF 161.55 FEET NAVD' 89 ACCORDING TO NGS PUBLISHED OATA. BCU $23 WELL AS-BULT SURFACE LOCATION (NAD83) BEAVER CHEEK UNIT PAD 3 111 ENGINEERING•TESTING LOCATION:SECTION 34, TOWNSHIP 7 NORTH, +` SURVEYING-MAPPING RANGE 10 WEST,SEWARD MERIDIAN ALASKA IIiirerp Mimic..LLA; P.Q BOX 468 SO .AK '.1669 JOB NO. 143081 VOICE:ICE.(9090 7)283-4218 FAX:(6057)283 DRAWN BY C 11A!!A/Inc +V4V'R'.MCLANECG.t Ol41 BMM DATE:08108114 FICIFIB 1 Page 52 Version 0 June, 2014 Hilcorp Energy Company Beaver Creek Unit Beaver Creek Unit Beaver CK Unit 23 BCU 23 Plan: BCU 23 WP4.0 Standard Proposal Report 11 August, 2014 HALLIBURTON Sperry Drilling Services HALLIBURTON Project: Beaver Creek Unit Site Beaver Creek Unit Sperry Drilling Well. Beaver CK Unit 23 Wellbore: BCU 23 SECTION DETAILS BCU 23 WP4.0 Sec MD Inc Azi ND +N/-S +EI-W Dleg TFace VSect Target 1 18.60 0.00 0.00 18.60 0.00 0.00 0.00 0.00 0.00 CASING DETAILS 2 2000.00 0.00 0.00 2000.00 0.00 0.00 0.00 0.00 0.00 3 2524.89 15.75 112.52 2518.31 -27.46 66.21 3.00 112.52 71.18 TVD MD Name Size 4 9945.98 15.75 112.52 9660.89 -798.91 1926.58 0.00 0.00 2071.30 3456.82 3500.00 10 3/4" 10-3/4 5 10470.88 0.00 0.00 10179.20 -826.37 1992.79 3.00 180.00 2142.48 11079.19 11370.87 5 1/2" 5-1/2 6 10947.78 0.00 0.00 10656.10 -826.37 1992.79 0.00 0.00 2142.48 BCU 23 B24 tgt wp2 7 11242.78 0.00 0.00 10951.10 -826.37 1992.79 0.00 0.00 2142.48 BCU 23 BI-IL tgt wp2 8 11370.88 0.00 0.00 11079.20 -826.37 1992.79 0.00 0.00 2142.48 iA • teS 0 WELL DETAILS: Beaver CK Unit 23 Ground Level: 160.50 +N/-S +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 2434057.10 317534.34 60.6585815 -151.0170661 - 750- REFERENCE INFORMATION 1500- Co-ordinate(N/E)Reference: Well Beaver CK Unit 23,True North Start Dir 3°/100':2000'MD,2000'TVD Vertical(ND)Reference: Plan:BCU 23 @ 179.10usft __--- Measured Depth Reference: Plan:BCU 23 @ 179.10usft --- Calculation Method: Minimum Curvature 2250- End Dir :2524.89'MD,2518.31'TVD Hilcorp Energy Company 3000- ___ Calculation Method: Minimum Curvature SHALLOW GAS Error System: ISCWSA Scan Method: Closest Approach 3D 10 3/4" Error Surface: Elliptical Conic Warning Method: Error Ratio 3750- SURVEY PROGRAM c - Date:2014-08-11T00:00:00 Validated:Yes Version: u) 4500- Depth From Depth To Survey/Plan Tool B2- 18.60 3500.00 BCU 23 WP4.0(BCU 23) MWD+SC+sag Li) - --_ 3500.00 11331.99 BCU 23 WP4.0(BCU 23) MWD+SC+sag .c 5250- B4- a) - FORMATION TOP DETAILS (0 v 6000- UBC3 TVDPath MDPath Formation 3027.50 3053.94 SHALLOW GAS 5076.50 5182.83 B2 5253.50 5366.74 B4 I- 6750- 6094.50 6240.53 UBC3 B18, 7264.50 7456.15 B18 7781.50 7993.31 B24 7922.50 8139.81 628B 8215.50 8444.23 B30 7500- B24._ 8714.50 8962.69 Tyonek B28B 8250- --- B30- Start Dir 3°/100':9945.98'MD,9660.89'TVD 9000- Tyonek -- - 9750- - 750- End Dir : 10470.88'MD, 10179.2'TVD 10500- BCU 23 B24 tgt wp2 5 1/2" _ 14 - ------- 11250- ' ____- -BCU 23BHLtgt wp2 BCU 23 WP4.0 Total Depth: 11370.88'MD, 11079.2'TVD 12000- 11111111 111111111111111111111111111111111111111111111111111 -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 Vertical Section at 105.80° (1500 usft/in) - Ca L Z N N H - v o: J J L YAC CM z Nr1� o _a Gni Qli=Np d inN-ln y o 0 - N i >,Y�e} 2Ny viNi _ A – /y� rnco / 67 C1 Q1 W N r) C O jN M .Css2 ZON J 00 _ nl 13 (Is 14 N z 7--0 o0 CO CO ) 4i� �@ 1n 0000 0� 0000 – >. 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O V tb N O� 00 r-- h C N N 7 h r-.- 00 cr., ( (ui/kisn(;15E)(+)4aioN/HuinoS Halliburton HHALLIBURTOle Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 23 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 23 @ 179.10usft Project: Beaver Creek Unit MD Reference: Plan: BCU 23 @ 179.10usft - Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 23 Survey Calculation Method: Minimum Curvature Wellbore: BCU 23 Design: BCU 23 WP4.0 Project Beaver Creek Unit Map System: US State Plane 1927(Exact solution) - System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) - Using Well Reference Point Map Zone: Alaska Zone 04 - Site Beaver Creek Unit Site Position: Northing: • 2,430,086.36 usft Latitude: 60.6475877 From: Map Easting: . 314,428.19usft Longitude: -151.0340284 Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.90 ° Well Beaver CK Unit 23 Well Position +N/-S 0.00 usft Northing: • 2,434,057.10 usft • Latitude: 60.6585815 +EI-W 0.00 usft Easting: - 317,534.34 usft • Longitude: -151.0170661 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: .160.50 usft Wellbore BCU 23 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (0) (nT) BGGM2013 6/12/2014 16.99 73.64 55,466 • Design BCU 23 WP4.0 Audit Notes: Version: Phase: PLAN Tie On Depth: 18.60 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (0) 18.60 0.00 0.00 105.80 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (usft) (0) (0) (usft) usft (usft) (usft) (°/100usft) (°1100usft) (°/100usft) (°) 18.60 0.00 0.00 18.60 -160.50 0.00 0.00 0.00 0.00 0.00 0.00 2,000.00 0.00 0.00 2,000.00 1,820.90 0.00 0.00 0.00 0.00 0.00 0.00 2,524.89 15.75 112.52 2,518.31 2,339.21 -27.46 66.21 3.00 3.00 0.00 112.52 9,945.98 15.75 112.52 9,660.89 9,481.79 -798.91 1,926.58 0.00 0.00 0.00 0.00 10,470.88 0.00 0.00 10,179.20 10,000.10 -826.37 1,992.79 3.00 -3.00 0.00 180.00 10,947.78 0.00 0.00 10,656.10 10,477.00 -826.37 1,992.79 0.00 0.00 0.00 0.00 11,242.78 0.00 0.00 10,951.10 10,772.00 -826.37 1,992.79 0.00 0.00 0.00 0.00 11,370.88 0.00 0.00 11,079.20 10,900.10 -826.37 1,992.79 0.00 0.00 0.00 0.00 8/11/2014 2.23:09PM Page 2 COMPASS 5000.1 Build 70 Halliburton HALLI B U RTO N Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 23 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 23 @ 179.10usft Project: Beaver Creek Unit MD Reference: Plan:BCU 23 @ 179.10usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 23 Survey Calculation Method: Minimum Curvature Wellbore: BCU 23 I Design: BCU 23 WP4.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (0) (0) (usft) usft (usft) (usft) (usft) (usft) -160.50 18.60 0.00 0.00 18.60 -160.50 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 100.00 0.00 0.00 100.00 -79.10 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 200.00 0.00 0.00 200.00 20.90 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 300.00 0.00 0.00 300.00 120.90 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 400.00 0.00 0.00 400.00 220.90 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 500.00 0.00 0.00 500.00 320.90 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 600.00 0.00 0.00 600.00 420.90 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 700.00 0.00 0.00 700.00 520.90 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 800.00 0.00 0.00 800.00 620.90 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 900.00 0.00 0.00 900.00 720.90 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 1,000.00 0.00 0.00 1,000.00 820.90 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 1,100.00 0.00 0.00 1,100.00 920.90 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 1,200.00 0.00 0.00 1,200.00 1,020.90 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 1,300.00 0.00 0.00 1,300.00 1,120.90 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 1,400.00 0.00 0.00 1,400.00 1,220.90 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 1,500.00 0.00 0.00 1,500.00 1,320.90 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 1,600.00 0.00 0.00 1,600.00 1,420.90 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 1,700.00 0.00 0.00 1,700.00 1,520.90 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 1,800.00 0.00 0.00 1,800.00 1,620.90 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 1,900.00 0.00 0.00 1,900.00 1,720.90 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 2,000.00 0.00 0.00 2,000.00 1,820.90 0.00 0.00 2,434,057.10 317,534.34 0.00 0.00 • Start Dir 3°/100':2000'MD,2000'TVD 2,100.00 3.00 112.52 2,099.95 1,920.85 -1.00 2.42 2,434,056.06 317,536.74 3.00 2.60 2,200.00 6.00 112.52 2,199.63 2,020.53 -4.01 9.66 2,434,052.95 317,543.94 3.00 10.39 2,300.00 9.00 112.52 2,298.77 2,119.67 -9.01 21.72 2,434,047.76 317,555.91 3.00 23.35 2,400.00 12.00 112.52 2,397.08 2,217.98 -15.99 38.55 2,434,040.52 317,572.63 3.00 41.45 2,500.00 15.00 112.52 2,494.31 2,315.21 -24.93 60.11 2,434,031.25 317,594.06 3.00 64.63 2,524.89 15.75 112.52 2,518.31 2,339.21 -27.46 66.21 2,434,028.63 317,600.11 3.00 71.18 End Dir :2524.89'MD,2518.31'TVD 2,600.00 15.75 112.52 2,590.60 2,411.50 -35.26 85.04 2,434,020.53 317,618.82 0.00 91.43 2,700.00 15.75 112.52 2,686.85 2,507.75 -45.66 110.11 2,434,009.75 317,643.72 0.00 118.38 2,800.00 15.75 112.52 2,783.09 2,603.99 -56.05 135.18 2,433,998.96 317,668.63 0.00 145.33 2,900.00 15.75 112.52 2,879.34 2,700.24 -66.45 160.24 2,433,988.18 317,693.53 0.00 172.28 3,000.00 15.75 112.52 2,975.59 2,796.49 -76.84 185.31 2,433,977.40 317,718.44 0.00 199.23 3,053.94 15.75 112.52 3,027.50 2,848.40 -82.45 198.83 2,433,971.59 317,731.87 0.00 213.77 SHALLOW GAS 3,100.00 15.75 112.52 3,071.83 2,892.73 -87.24 210.38 2,433,966.62 317,743.34 0.00 226.18 3,200.00 15.75 112.52 3,168.08 2,988.98 -97.64 235.45 2,433,955.84 317,768.25 0.00 253.14 3,300.00 15.75 112.52 3,264.33 3,085.23 -108.03 260.52 2,433,945.05 317,793.15 0.00 280.09 3,400.00 15.75 112.52 3,360.57 3,181.47 -118.43 285.59 2,433,934.27 317,818.06 0.00 307.04 3,500.00 15.75 112.52 3,456.82 3,277.72 -128.82 310.66 2,433,923.49 317,842.96 0.00 333.99 10 3/4" 3,600.00 15.75 112.52 3,553.07 3,373.97 -139.22 335.72 2,433,912.71 317,867.87 0.00 360.94 3,700.00 15.75 112.52 3,649.32 3,470.22 -149.61 360.79 2,433,901.93 317,892.77 0.00 387.89 3,800.00 15.75 112.52 3,745.56 3,566.46 -160.01 385.86 2,433,891.14 317,917.68 0.00 414.85 8/11/2014 2:23:09PM Page 3 COMPASS 5000.1 Build 70 Halliburton HALLIBURTOIllt Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 23 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 23 @ 179.10usft Project: Beaver Creek Unit MD Reference: Plan:BCU 23 @ 179.10usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 23 Survey Calculation Method: Minimum Curvature Wellbore: BCU 23 Design: BCU 23 WP4.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (0) (0) (usft) usft (usft) (usft) (usft) (usft) 3,662.71 3,900.00 15.75 112.52 3,841.81 3,662.71 -170.40 410.93 2,433,880.36 317,942.58 0.00 441.80 4,000.00 15.75 112.52 3,938.06 3,758.96 -180.80 436.00 2,433,869.58 317,967.48 0.00 468.75 4,100.00 15.75 112.52 4,034.30 3,855.20 -191.19 461.07 2,433,858.80 317,992.39 0.00 495.70 4,200.00 15.75 112.52 4,130.55 3,951.45 -201.59 486.14 2,433,848.02 318,017.29 0.00 522.65 4,300.00 15.75 112.52 4,226.80 4,047.70 -211.99 511.21 2,433,837.23 318,042.20 0.00 549.61 4,400.00 15.75 112.52 4,323.05 4,143.95 -222.38 536.27 2,433,826.45 318,067.10 0.00 576.56 4,500.00 15.75 112.52 4,419.29 4,240.19 -232.78 561.34 2,433,815.67 318,092.01 0.00 603.51 4,600.00 15.75 112.52 4,515.54 4,336.44 -243.17 586.41 2,433,804.89 318,116.91 0.00 630.46 i 4,700.00 15.75 112.52 4,611.79 4,432.69 -253.57 611.48 2,433,794.10 318,141.82 0.00 657.41 1 4,800.00 15.75 112.52 4,708.03 4,528.93 -263.96 636.55 2,433,783.32 318,166.72 0.00 684.36 4,900.00 15.75 112.52 4,804.28 4,625.18 -274.36 661.62 2,433,772.54 318,191.63 0.00 711.32 5,000.00 15.75 112.52 4,900.53 4,721.43 -284.75 686.69 2,433,761.76 318,216.53 0.00 738.27 I 5,100.00 15.75 112.52 4,996.77 4,817.67 -295.15 711.76 2,433,750.98 318,241.44 0.00 765.22 1 5,182.83 15.75 112.52 5,076.50 4,897.40 -303.76 732.52 2,433,742.04 318,262.07 0.00 787.55 1 B2 5,200.00 15.75 112.52 5,093.02 4,913.92 -305.54 736.82 2,433,740.19 318,266.34 0.00 792.17 5,300.00 15.75 112.52 5,189.27 5,010.17 -315.94 761.89 2,433,729.41 318,291.25 0.00 819.12 I 5,366.74 15.75 112.52 5,253.50 5,074.40 -322.88 778.62 2,433,722.22 318,307.87 0.00 837.11 B4 5,400.00 15.75 112.52 5,285.52 5,106.42 -326.34 786.96 2,433,718.63 318,316.15 0.00 846.08 5,500.00 15.75 112.52 5,381.76 5,202.66 -336.73 812.03 2,433,707.85 318,341.06 0.00 873.03 5,600.00 15.75 112.52 5,478.01 5,298.91 -347.13 837.10 2,433,697.07 318,365.96 0.00 899.98 5,700.00 15.75 112.52 5,574.26 5,395.16 -357.52 862.17 2,433,686.28 318,390.87 0.00 926.93 5,800.00 15.75 112.52 5,670.50 5,491.40 -367.92 887.24 2,433,675.50 318,415.77 0.00 953.88 5,900.00 15.75 112.52 5,766.75 5,587.65 -378.31 912.31 2,433,664.72 318,440.68 0.00 980.83 6,000.00 15.75 112.52 5,863.00 5,683.90 -388.71 937.37 2,433,653.94 318,465.58 0.00 1,007.79 6,100.00 15.75 112.52 5,959.24 5,780.14 -399.10 962.44 2,433,643.16 318,490.49 0.00 1,034.74 6,200.00 15.75 112.52 6,055.49 5,876.39 -409.50 987.51 2,433,632.37 318,515.39 0.00 1,061.69 6,240.53 15.75 112.52 6,094.50 5,915.40 -413.71 997.67 2,433,628.00 318,525.49 0.00 1,072.61 UBC3 6,300.00 15.75 112.52 6,151.74 5,972.64 -419.89 1,012.58 2,433,621.59 318,540.30 0.00 1,088.64 6,400.00 15.75 112.52 6,247.99 6,068.89 -430.29 1,037.65 2,433,610.81 318,565.20 0.00 1,115.59 6,500.00 15.75 112.52 6,344.23 6,165.13 -440.69 1,062.72 2,433,600.03 318,590.11 0.00 1,142.54 6,600.00 15.75 112.52 6,440.48 6,261.38 -451.08 1,087.79 2,433,589.24 318,615.01 0.00 1,169.50 6,700.00 15.75 112.52 6,536.73 6,357.63 -461.48 1,112.86 2,433,578.46 318,639.92 0.00 1,196.45 6,800.00 15.75 112.52 6,632.97 6,453.87 -471.87 1,137.92 2,433,567.68 318,664.82 0.00 1,223.40 I 6,900.00 15.75 112.52 6,729.22 6,550.12 -482.27 1,162.99 2,433,556.90 318,689.73 0.00 1,250.35 7,000.00 15.75 112.52 6,825.47 6,646.37 -492.66 1,188.06 2,433,546.12 318,714.63 0.00 1,277.30 7,100.00 15.75 112.52 6,921.72 6,742.62 -503.06 1,213.13 2,433,535.33 318,739.54 0.00 1,304.26 7,200.00 15.75 112.52 7,017.96 6,838.86 -513.45 1,238.20 2,433,524.55 318,764.44 0.00 1,331.21 7,300.00 15.75 112.52 7,114.21 6,935.11 -523.85 1,263.27 2,433,513.77 318,789.35 0.00 1,358.16 7,400.00 15.75 112.52 7,210.46 7,031.36 -534.24 1,288.34 2,433,502.99 318,814.25 0.00 1,385.11 7,456.15 15.75 112.52 7,264.50 7,085.40 -540.08 1,302.41 2,433,496.93 318,828.23 0.00 1,400.24 B18 7,500.00 15.75 112.52 7,306.70 7,127.60 -544.64 1,313.41 2,433,492.21 318,839.15 0.00 1,412.06 8/11/2014 2:23:09PM Page 4 COMPASS 5000.1 Build 70 Halliburton HALLIBURTO4 Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 23 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 23 @ 179.10usft Project: Beaver Creek Unit MD Reference: Plan:BCU 23 @ 179.10usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 23 Survey Calculation Method: Minimum Curvature Wellbore: BCU 23 Design: BCU 23 WP4.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section , (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 7,223.85 7,600.00 15.75 112.52 7,402.95 7,223.85 -555.04 1,338.47 2,433,481.42 318,864.06 0.00 1,439.01 7,700.00 15.75 112.52 7,499.20 7,320.10 -565.43 1,363.54 2,433,470.64 318,888.96 0.00 1,465.97 7,800.00 15.75 112.52 7,595.44 7,416.34 -575.83 1,388.61 2,433,459.86 318,913.87 0.00 1,492.92 7,900.00 15.75 112.52 7,691.69 7,512.59 -586.22 1,413.68 2,433,449.08 318,938.77 0.00 1,519.87 7,993.31 15.75 112.52 7,781.50 7,602.40 -595.92 1,437.07 2,433,439.02 318,962.01 0.00 1,545.02 B24 8,000.00 15.75 112.52 7,787.94 7,608.84 -596.62 1,438.75 2,433,438.29 318,963.68 0.00 1,546.82 8,100.00 15.75 112.52 7,884.19 7,705.09 -607.01 1,463.82 2,433,427.51 318,988.58 0.00 1,573.77 8,139.81 15.75 112.52 7,922.50 7,743.40 -611.15 1,473.80 2,433,423.22 318,998.50 0.00 1,584.50 B28B 8,200.00 15.75 112.52 7,980.43 7,801.33 -617.41 1,488.89 2,433,416.73 319,013.49 0.00 1,600.73 : 8,300.00 15.75 112.52 8,076.68 7,897.58 -627.80 1,513.95 2,433,405.95 319,038.39 0.00 1,627.68 8,400.00 15.75 112.52 8,172.93 7,993.83 -638.20 1,539.02 2,433,395.17 319,063.30 0.00 1,654.63 8,444.23 15.75 112.52 8,215.50 8,036.40 -642.80 1,550.11 2,433,390.40 319,074.31 0.00 1,666.55 B30 8,500.00 15.75 112.52 8,269.17 8,090.07 -648.59 1,564.09 2,433,384.38 319,088.20 0.00 1,681.58 8,600.00 15.75 112.52 8,365.42 8,186.32 -658.99 1,589.16 2,433,373.60 319,113.11 0.00 1,708.53 8,700.00 15.75 112.52 8,461.67 8,282.57 -669.39 1,614.23 2,433,362.82 319,138.01 0.00 1,735.48 8,800.00 15.75 112.52 8,557.92 8,378.82 -679.78 1,639.30 2,433,352.04 319,162.92 0.00 1,762.44 8,900.00 15.75 112.52 8,654.16 8,475.06 -690.18 1,664.37 2,433,341.26 319,187.82 0.00 1,789.39 8,962.69 15.75 112.52 8,714.50 8,535.40 -696.69 1,680.08 2,433,334.50 319,203.44 0.00 1,806.28 Tyonek 9,000.00 15.75 112.52 8,750.41 8,571.31 -700.57 1,689.44 2,433,330.47 319,212.73 0.00 1,816.34 9,100.00 15.75 112.52 8,846.66 8,667.56 -710.97 1,714.50 2,433,319.69 319,237.63 0.00 1,843.29 9,200.00 15.75 112.52 8,942.90 8,763.80 -721.36 1,739.57 2,433,308.91 319,262.54 0.00 1,870.24 9,300.00 15.75 112.52 9,039.15 8,860.05 -731.76 1,764.64 2,433,298.13 319,287.44 0.00 1,897.19 9,400.00 15.75 112.52 9,135.40 8,956.30 -742.15 1,789.71 2,433,287.35 319,312.35 0.00 1,924.15 9,500.00 15.75 112.52 9,231.64 9,052.54 -752.55 1,814.78 2,433,276.56 319,337.25 0.00 1,951.10 9,600.00 15.75 112.52 9,327.89 9,148.79 -762.94 1,839.85 2,433,265.78 319,362.16 0.00 1,978.05 9,700.00 15.75 112.52 9,424.14 9,245.04 -773.34 1,864.92 2,433,255.00 319,387.06 0.00 2,005.00 9,800.00 15.75 112.52 9,520.39 9,341.29 -783.74 1,889.99 2,433,244.22 319,411.97 0.00 2,031.95 9,900.00 15.75 112.52 9,616.63 9,437.53 -794.13 1,915.05 2,433,233.43 319,436.87 0.00 2,058.91 9,945.98 15.75 112.52 9,660.89 9,481.79 -798.91 1,926.58 2,433,228.48 319,448.32 0.00 2,071.30 Start Dir 3°/100':9945.98'MD,9660.89'TVD 10,000.00 14.13 112.52 9,713.08 9,533.98 -804.24 1,939.44 2,433,222.95 319,461.10 3.00 2,085.13 10,100.00 11.13 112.52 9,810.65 9,631.55 -812.62 1,959.63 2,433,214.26 319,481.16 3.00 2,106.83 10,200.00 8.13 112.52 9,909.23 9,730.13 -819.02 1,975.08 2,433,207.62 319,496.50 3.00 2,123.44 10,300.00 5.13 112.52 10,008.55 9,829.45 -823.44 1,985.73 2,433,203.03 319,507.09 3.00 2,134.89 10,400.00 2.13 112.52 10,108.34 9,929.24 -825.86 1,991.58 2,433,200.52 319,512.89 3.00 2,141.18 10,470.88 0.00 0.00 10,179.20 10,000.10 -826.37 1,992.79 2,433,200.00 319,514.10 3.00 2,142.48 End Dir :10470.88'MD,10179.2'TVD 10,500.00 0.00 0.00 10,208.32 10,029.22 -826.37 1,992.79 2,433,200.00 319,514.10 0.00 2,142.48 10,600.00 0.00 0.00 10,308.32 10,129.22 -826.37 1,992.79 2,433,200.00 319,514.10 0.00 2,142.48 10,700.00 0.00 0.00 10,408.32 10,229.22 -826.37 1,992.79 2,433,200.00 319,514.10 0.00 2,142.48 10,800.00 0.00 0.00 10,508.32 10,329.22 -826.37 1,992.79 2,433,200.00 319,514.10 0.00 2,142.48 8/11/2014 2:23:09PM Page 5 COMPASS 5000.1 Build 70 Halliburton HALLHALLIBURTOle Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 23 Company: Hilcorp Energy Company TVD Reference: Plan: BCU 23 @ 179.10usft Project: Beaver Creek Unit MD Reference: Plan:BCU 23 @ 179.10usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 23 Survey Calculation Method: Minimum Curvature Wellbore: BCU 23 Design: BCU 23 WP4.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-5 +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 10,429.22 10,900.00 0.00 0.00 10,608.32 10,429.22 -826.37 1,992.79 2,433,200.00 319,514.10 0.00 2,142.48 10,947.78 0.00 0.00 10,656.10 10,477.00 -826.37 1,992.79 2,433,200.00 319,514.10 0.00 2,142.48 11,000.00 0.00 0.00 10,708.32 10,529.22 -826.37 1,992.79 2,433,200.00 319,514.10 0.00 2,142.48 11,100.00 0.00 0.00 10,808.32 10,629.22 -826.37 1,992.79 2,433,200.00 319,514.10 0.00 2,142.48 11,200.00 0.00 0.00 10,908.32 10,729.22 -826.37 1,992.79 2,433,200.00 319,514.10 0.00 2,142.48 11,242.78 0.00 0.00 10,951.10 10,772.00 -826.37 1,992.79 2,433,200.00 319,514.10 0.00 2,142.48 11,300.00 0.00 0.00 11,008.32 10,829.22 -826.37 1,992.79 2,433,200.00 319,514.10 0.00 2,142.48 I i 11,370.87 0.00 0.00 11,079.19 10,900.09 -826.37 1,992.79 2,433,200.00 319,514.10 0.00 2,142.48 Total Depth:11370.88'MD,11079.2'TVD-5 1/2" . 11,370.88 0.00 0.00 11,079.20. 10,900.10 , -826.37 1,992.79 2,433,200.00 319,514.10 0.00 2,142.48 Targets Target Name 1 -hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting -Shape (°) (0) (usft) (usft) (usft) (usft) (usft) BCU 23 B24 tqt wp2 0.00 0.00 10,656.10 -826.37 1,992.79 2,433,200.00 319,514.10 -plan hits target center -Circle(radius 100.00) BCU 23 BHL tqt wp2 0.00 0.00 10,951.10 -826.37 1,992.79 2,433,200.00 319,514.10 -plan hits target center -Circle(radius 50.00) 1 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 3,500.00 3,456.82 10 3/4" 10-3/4 13-1/2 11,370.87 11,079.19 5 1/2" 5-1/2 8-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (0) (°) 5,366.74 5,253.50 B4 6,240.53 6,094.50 UBC3 5,182.83 5,076.50 B2 8,139.81 7,922.50 B28B 3,053.94 3,027.50 SHALLOW GAS 8,444.23 8,215.50 B30 7,456.15 7,264.50 B18 7,993.31 7,781.50 B24 j 8,962.69 8,714.50 Tyonek 8/11/2014 2:23:09PM Page 6 COMPASS 5000.1 Build 70 Halliburton HALLI BU RTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 23 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 23 @ 179.10usft Project: Beaver Creek Unit MD Reference: Plan:BCU 23 @ 179.10usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 23 Survey Calculation Method: Minimum Curvature Wellbore: BCU 23 Design: BCU 23 WP4.0 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 2,000.00 2,000.00 0.00 0.00 Start Dir 3°/100':2000'MD,2000'TVD 2,524.89 2,518.31 -27.46 66.21 End Dir :2524.89'MD,2518.31'TVD 9,945.98 9,660.89 -798.91 1,926.58 Start Dir 3°/100':9945.98'MD,9660.89'TVD 10,470.88 10,179.20 -826.37 1,992.79 End Dir : 10470.88'MD, 10179.2'TVD 11,370.87 11,079.19 -826.37 1,992.79 Total Depth: 11370.88'MD, 11079.2'TVD 8/11/2014 2:23:09PM Page 7 COMPASS 5000.1 Build 70 Z 1 0 3 L • m t) C Q ori t 4 L / (It U� E .' inN W c 0 i0 o a 8r N 22 o. . d ,,,2Wmt. 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(n N_ CO v- z ai a) o o .! ui sn uoi eaeda as ua o as ua Q Q /�� 0010 S c▪ V U I a) O C ❑ > 0 0 O 0) 0 E c 0 > V > > > at > > > > `>> > 5 0cc x- > o — CO CO -, CO rn y '- r U N > D > D > > = N D > > > m > > D co U Lo U m rn W.; mmmmm m mm m ,x U fx U / U U C O M CO O 00 Cn NCO 03 CO CO O Z D D D D D D D S c> r') ui m a" 1 Lm m m m m m m, m U DDDDD U U U U •. O co- (O CO OO 61 N mm mm m = LL CO- CO_ CO- O _1 C C C C C C C C C C C C C C O Y• Y YY YYY Y Y Y Y Y Y Y O 0000000000000 a) N N N N a) N a) a) a) a) N a) a) co > > > > > > > > > > > > > > fa a3 @ C6 (O (O N CO (O (a CO a3 @ (a 0 CD CD a) CD Cl) (L) Cl) a, a) Cl) 1) a) a) Cl) 0 CO CO CO CO CO m CO m CO CO CO CO CO CO CO 4 iti T o , 0 1 , 0 , -- O 0 _O - CLco ti -- 0 M -"'- -- -_- _ —O N o UM L - O 9 co M O c �� - O N _ 0 ,� o T. c co 1 - 8 in i - o a _o O N _ LID U N - L t- i - o Cti Q d M 0o L o co -— a) us 0as a OwC. __—___ F.__._._.. c ! _ ^ p o ^, •• O LL f i___ Cm o L I.... N O O .„- N ' O O O O M O N W v 1_ o _ .N m . , I I I I I I , I I I I I I , I I I 1 I I , I i , I I I I I I , I 1 , 1 , O NJ litt /O' 0 I� o N o 0 N O U n _ C p M r COO M N O I C L. (u!/OS-Z) Jo1oe- uo;Teaedas < U S Schwartz, Guy L (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Monday,August 18,2014 9:34 AM To: Davies, Stephen F(DOA) Cc: Schwartz,Guy L(DOA) Subject: RE:Another well on Saxon 169 - BCU #23 (214-093) Good morning Steve! 3'3r,c8' I wasn't sure what form I should have submitted.The major changes for BCU 23 is the SHL changed by about 20' fro �i.irr r`t / as-staked to as-built. If I need to submit the information on a revised permit to drill form I can certainly get that to you quickly. � olut On the BCU #24,the SHL shifted by approx. 120'from as-staked to as-built and the directional plan was revised quite , drastically as well. Original TMD 10808', New TMD 9675', Old TVD 10126', New TVD 9080'. I also updated all the MASP calculations and schematics for both wells. Please let me know if I need to change the form out. Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, August 18, 2014 9:09 AM To: Monty Myers Cc: Schwartz, Guy L(DOA) Subject: RE: Another well on Saxon 169 - BCU #23 (214-093) Monty, Received Hilcorp's Sundry Application for BCU 23, and I notice that this application is essentially an application for a revised Permit to Drill. Just curious as to what's changed besides the wellbore trajectory and why Hilcorp didn't submit a revised Permit to Drill form rather than a Sundry Application. Thanks, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 1 From: Monty Myers [mailto:mmvers@hilcorp.com] Sent:Tuesday,July 01, 2014 1:53 PM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L(DOA) Subject: Another well on Saxon 169 - BCU #23 Steve,Guy, Attached are the digital surveys for another well behind Saxon 169, called BCU#23. It will be a grassroots well out on pad#3 in Beaver Creek. If you have any questions please let me know!This permit was submitted last Friday,so hopefully you have received it. Our asset team would love to stay in Beaver Creek and drill this well after the current well we are on, but I don't think I will be able to get approval in time from BLM to do that. Thank you! If you need anything else please give me a shout. Monty M Myers Drilling Engineer Hilcorp Alaska Office:907.777.8431 Cell:907.538.1168 2 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Wednesday, August 20, 2014 3:53 PM To: 'Monty Myers' Cc: Schwartz, Guy L (DOA) Subject: RE: Beaver Creek#23 Monty, Any change to an approved Permit to Drill necessitates another trip through the entire review process. I'd guess that the revised Permit application will likely be finished by Friday, but I can't guarantee it. Please let me know if you have any questions or if I can help further. Regards, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Monty Myers [mailto:mmyers@hilcorp.com] Sent: Wednesday, August 20, 2014 1:20 PM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: Beaver Creek #23 Thanks Steve! I am definitely not trying to rush you guys since it was my fault on changing the surface location. But do you think it will be ready by Friday? We are currently moving the rig to Beaver Creek. Thank you. Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Wednesday, August 20, 2014 12:00 PM To: Monty Myers Cc: Schwartz, Guy L (DOA) Subject: RE: Beaver Creek #23 1 Monty, Yes, Hilcorp will need the re-issued Permit to Drill for BC 23 before drilling begins. Regards, Steve Davies AOGCC From: Monty Myers [mailto:mmyers@hilcorp.com] Sent: Wednesday, August 20, 2014 10:06 AM To: Schwartz, Guy L (DOA); Davies, Stephen F (DOA) Subject: Beaver Creek #23 Good morning gents! I want to double check with you that I am ok to move forward with drilling on Beaver Creek#23? We are only moving in with the rig starting today. After the re-submit of the 10-401, I wasn't sure if I needed to wait for re-approval on the BC#23? Please advise. Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 2 Davies, Stephen F (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Monday, August 18, 2014 10:02 AM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L(DOA); Bettis, Patricia K (DOA) Subject: RE: Another well on Saxon 169 - BCU #23 (214-093) Thanks for the clarification Steve. Will have it to you today! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, August 18, 2014 10:00 AM To: Monty Myers Cc: Schwartz, Guy L(DOA); Bettis, Patricia K (DOA) Subject: RE: Another well on Saxon 169 - BCU #23 (214-093) Monty, Thanks for your prompt reply. I look at these situations from a "clarity of records"view point: What will be clearest to a reader 10 years from now? AOGCC's Permit to Drill form concisely summarizes all critical information about a planned well. Hilcorp's Sundry Application form states only that the previously approved program is being changed, but it tells nothing about the details of the changes. It's then left to the reader to hunt for those changes in the revised, 70-page BCU 23 Drilling Program—kind of like a technical "Where's Waldo" book. So, please submit a revised Permit to Drill form for BCU 23 with a brief cover letter explaining what changes Hilcorp seeks. Note that Regulation 20 AAC 25.015(a)(1) states that the operator shall "submit and obtain the commission's approval of a new application for a Permit to Drill if the proposed surface location is changed..." (Any change to the surface location necessitates a new Permit to Drill form.) Thanks for your help, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Monty Myers [mailto:mmyers@hilcorp.com] Sent: Monday, August 18, 2014 9:34 AM To: Davies, Stephen F (DOA) 1 Cc: Schwartz, Guy L (DOA) Subject: RE: Another well on Saxon 169 - BCU #23 (214-093) Good morning Steve! I wasn't sure what form I should have submitted. The major changes for BCU 23 is the SHL changed by about 20'from as-staked to as-built. If I need to submit the information on a revised permit to drill form I can certainly get that to you quickly. On the BCU #24, the SHL shifted by approx. 120'from as-staked to as-built and the directional plan was revised quite drastically as well. Original TMD 10808', New TMD 9675', Old TVD 10126', New TVD 9080'. I also updated all the MASP calculations and schematics for both wells. Please let me know if I need to change the form out. Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, August 18, 2014 9:09 AM To: Monty Myers Cc: Schwartz, Guy L(DOA) Subject: RE: Another well on Saxon 169 - BCU #23 (214-093) Monty, Received Hilcorp's Sundry Application for BCU 23, and I notice that this application is essentially an application for a revised Permit to Drill. Just curious as to what's changed besides the wellbore trajectory and why Hilcorp didn't submit a revised Permit to Drill form rather than a Sundry Application. Thanks, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and, so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Monty Myers [mailto:mmyers@hilcorp.com] Sent: Tuesday, July 01, 2014 1:53 PM To: Davies, Stephen F (DOA) 2 Cc: Schwartz, Guy L (DOA) Subject: Another well on Saxon 169 - BCU #23 Steve, Guy, Attached are the digital surveys for another well behind Saxon 169, called BCU#23. It will be a grassroots well out on pad #3 in Beaver Creek. If you have any questions please let me know! This permit was submitted last Friday, so hopefully you have received it. Our asset team would love to stay in Beaver Creek and drill this well after the current well we are on, but I don't think I will be able to get approval in time from BLM to do that. Thank you! If you need anything else please give me a shout. Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 3 TRANSMITTAL LETTER CHECKLIST WELL NAME: 4ea z:r/6( PTD: -1D /3 Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: "' POOL: 4-7e7k--- 109411‘'-J---7e2C0/ Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - . in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. 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 Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. 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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 AOGCC 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 AOGCC 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 AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, / ---42-e--(4V-e_. Cathy '. Foerster Chair DATED this_) day of July, 2014. IWUEJVED STATE OF ALASKA JUN 2 7 2014 1 :A OIL AND GAS CONSERVATION COMP DN 2-‘4 - O''' ‘ PERMIT TO DRILL 20 AAC 25 005 AOG CV 1 a.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone ❑✓ s 1 c.Specify if well is proposed for: Drill ❑Q .Lateral ❑ Stratigraphic Test ❑ Development-Gas E• Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redril❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244 • Beaver Creek Unit(BCU)#23 • 3.Address: 6.Proposed Depth: 12 Field/Pool(s): 3800 Centerpoint Drive,STE 1400 Anchorage AK 99503 MD' 10,882' • TVD: 10,353' • Beaver Creek Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number). Beluga Gas Pool Surface. 1142'FNL,1702'FWL,Sec 34,T7N,R1OW,SM,AK • A028083 • Top of Productive Horizon. 8.Land Use Permit: 13.Approximate Spud Date: 1591'FNL,2280'FEL,Sec 34,T7N,R1 OW,SM,AK NA 7/21/2014 Total Depth. 9.Acres in Property: 14.Distance to Nearest Property: 1838'FNL,1558'FEL,Sec 34,T7N,R1 OW,SM,AK 1920 acres 1590'FNL 4b Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 179 2 feet • 15.Distance to Nearest Well Open Surface: x-317520 56 . y-2434039.88 • Zone-4 GL Elevation above MSL: 160.6 feet , to Same Pool. 1120' 16.Deviated wells: Kickoff depth: 2000 feet 17.Maximum Anticipated Pressures in psig(see 20 AA 005) -- 2 4 iy Maximum Hole Angle: 31 degrees Downhole: 3600 psi Surface: _1.442psi (Drilling) 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Cond 16" 109 X-56 Weld 80' Surface Surface 80' 80' Driven 12-1/4" 9-5/8" 40 L-80 BTC 3,559' Surface Surface 3,559' • 3,483' 310.2bbI/1741.9ft3 8-1/2" 5-1/2" 17 P-110 DWC/C HT 10,882' Surface Surface 10,882' 10,353' 459.2bbI/2578.2ft3 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft). Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft). Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft). Perforation Depth ND(ft): 20. Attachments: Property Plat ❑✓ BOP Sketch Q Drilling Program ❑✓ Time v.Depth Plot 0 Shallow Hazard Analysis❑ Diverter Sketch Q Seabed Report ❑ Drilling Fluid Program Q 20 MC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Monty Mack Myers Email mmyers@hilcorp.com Printed Name Monty Mack Myers Title Drilling Engineer Signature '"\ - Phone (907)777-8431 Date 6/26/2014 Commission Use Only Permit to Drill � / API Number. / Permit Approval / See cover letter for other Number: �/7 U/ 50-! ✓ �-� 5` Date. 7 1 requirements. Conditions of approval. If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales:Er Other. 4- /1 000 S` do e 1�,S•f Samples req'd. Yes❑ No L ' Mud log req'd.Yes❑ Nog l H2S measures. Yes❑ No Directional svy req'd Yes[' No❑ C 6 L � I.�_ /t (',{ Spacing exception req'd: Yes❑ No 2' Inclination-only svy req'd:Yes❑ No[ ' lr . ' () i4 ,574..,',I, # 6.-e-L Cc"--).14.L.,.....„.„ C.::If—e..4.-,X(.4-).-- re-- -6 c,..4..„-.2._oe, / APPROVED BY V Approved by: s, '— COMMISSIONER THE COMMISSION Date:7- 3 -/ ii.H Submit Form and Form 10-401(Revised 10/2012) Thi n�e�7Rn i G iNrr tF s from the date of approval(20 AAC 25.005(,g))) Attachments in Duplicate Monty Myers Hilcorp Alaska, LLC II Drilling Engineer P.O. Box 244027 Anchorage,AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com ItiIrnrli Alaska,ilk June 26, 2014 RECEIVED Commissioner JUN 2 7 2014 Alaska Oil &Gas Conservation Commission 333 W. 7th Avenue AOGCC Anchorage,Alaska 99501 Re: Beaver Creek Unit 23 Dear Commissioner, Beaver Creek#23 is a south easterly step-out appraisal well of the lower and middle Beluga gas sands on the eastern flank of the field between the BCU 13 and BCU 16RD wells.The base plan is a 10882'"S-turn"wellbore with a shallow kickoff around 2000', building to a tangent of 31 deg,then dropping back to vertical at 7382' MD. .. Drilling operations are expected to commence approximately July 21st,2014. , The Saxon Rig#169 will be used to drill the wellbore then run casing and cement. Surface casing will be run to 3,559' MD/3,483'TVD and cemented to surface to ensure protection of am shallow freshwater resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed,a Temp log will be run between 6—18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC and BLM authorities. All waste&mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal/beneficial reuse depending on test results. General sequence of operations: 1. MOB Saxon Rig#169 to well site 2. N/U 21-1/4"x 2M diverter. 3. Drill 12-1/4" hole to 3559' MD. Run and cmt 9-5/8"surface casing. • 4. N/D diverter, N/U &test 11"x 5M T3-Energy BOP. 5. Drill 8-1/2" hole section to 10,882' MD. Perform Wiper trip. ' 6. POOH laying down drill pipe. 7. Run and cmt 5-1/2" production casing. 8. N/D BOP, N/U temp abandonment cap, RDMO. Hilcorp Alaska, LLC Page 1 of 2 Monty Myers Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com Hilrorp Ala.ke,LLC Reservoir Evaluation Plan: 1. Surface hole:GR+Res LWD. 2. Production Hole:GR+ Res+Den/Neu LWD. 3. Mud loggers from surface casing point to TD. If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. Sincerely, Monty Myers Drilling Engineer Hilcorp Alaska, LLC Page 2 of 2 Hilcorp Alaska, LLC Beaver Creek #23 Drilling Program Beaver Creek Field wiz -c db : M IM Version 0 June 16th 2014 Beaver Creek#23 Hilcorp Drilling Procedure Energy Company Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program: 4 4.0 Drill Pipe Information: 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling/Completion Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 11 10.0 N/U 21-1/4"2M Diverter 12 11.0 Drill 12-1/4"Hole Section 15 12.0 Run 9-5/8" Surface Casing 19 13.0 Cement 9-5/8" Surface Casing 22 14.0 BOP N/U and Test 25 15.0 Drill 8-1/2"Hole Section 26 16.0 Run 5-1/2"Production Casing 31 17.0 Cement 5-1/2"Production Casing 34 18.0 RDMO 37 19.0 BOP Schematic 38 20.0 Wellhead Schematic 39 21.0 Days Vs Depth 40 22.0 Geo-Prog 41 23.0 Anticipated Drilling Hazards 42 24.0 Saxon Rig 169 Layout 44 25.0 FIT Procedure 45 26.0 Choke Manifold Schematic 46 27.0 Casing Design Information 47 28.0 8-1/2"Hole Section MASP 48 29.0 Spider Plot(NAD 27) (Governmental Sections) 49 30.0 Surface Plat(As Staked)(NAD 27) 50 31.0 Directional Survey 50 Beaver Creek#23 Drilling Procedure Rev 0 Hilcorp Energy Company 1.0 Well Summary Well Beaver Creek#23 • Pad&Old Well Designation Beaver Creek#23 is a grass roots well on BCU Pad#3 Planned Completion Type 5-1/2"Production tubing Target Reservoir(s) Beluga Planned Well TD,MD/TVD 10,882' MD/ 10,353' TVD • PBTD,MD/TVD 10,800' MD/ 10,271' TVD Surface Location(Governmental) 1142' FNL, 1702' FWL, Sec 34,T7N,R1OW, SM,AK Surface Location(NAD 27) X=317520.56,Y=2434039.88 Surface Location(NAD 83) Top of Productive Horizon (Governmental) 1591' FNL,2280' FEL, Sec 34, T7N,R1OW, SM,AK TPH Location(NAD 27) X=318807.62,Y=2433578.74 TPH Location(NAD 83) BHL(Governmental) 1838'FNL, 1558'FEL, Sec 34,T7N,RIOW, SM,AK BHL(NAD 27) X=319526.70,Y=2433321.10 BHL(NAD 83) AFE Number 1412150D AFE Drilling Days 5 MOB,22 DRLG AFE Completion Days AFE Drilling Amount $5,210,720 AFE Completion Amount $300,000 Maximum Anticipated Pressure (Surface) 1412 psi(Drilling) Maximum Anticipated Pressure (Downhole/Reservoir) 3600 psi Work String 4-1/2" 16.6# S-135 CDS-40(Saxon Owned String) • RKB—GL 179.2'(160.6+ 18.6) • Ground Elevation 160.6' • BOP Equipment 11" 5M T3-Energy Annular BOP 11"5M T3-Energy Double Ram 11"5M T3-Energy Single Ram Page 2 Version 0 June, 2014 • Beaver Creek#23 Drilling Procedure Rev 0 Hilcorp Energy Company 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp Changes to Approved Permit to Drill Date: June 25,2014 Subject: Changes to Approved Permit to Drill for Beaver Creek #23 File#: Beaver Creek #23 Drilling Program Any modifications to the Drilling&Completion Program will be documented and approved below. Changes to an approved APD will beigotsimunicatediethe AOGCC &BLM. .nr-y ed -L-- Gtc. j� 0 a('✓ G Date Procedure Change Approved Approved BY BY 3 Approval: Drilling Manager Date Prepared: Drilling Engineer Date Page 3 Version 0 June, 2014 B Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp Energy Company 3.0 Tubular Program: Hole OD (in) ID (in) Drift Conn Wt Grade Conn Burst Collapse Ten=. Section (in) OD (in) (#/ft) (psi) (psi) (k- bs),,, Cond 16" 15" - - 109 X-56 Weld 12-1/4" 9-5/8" 8.835" 8.679" 10.625" 40 L-80 BTC 5750 3090 916 8-1/2" 5-1/2" 4.892 4.767 6.050 17 P-110 DWC/C HT 10640 7480 546 4.0 Drill Pipe Information: Hole OD (in) ID (in) TJ ID TJ OD Wt Grade Conn Burst Collapse Tension Section (in) (in) (#/ft) (psi) (psi) (k-lbs) All 4-1/2" 3.826 2.6875`' 5.25" 16.6 S-135 CDS40 17.693 16,769 468k All casing will be new, PSL 1 (100%mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 0 June, 2014 Bea Drillingver ProcedureCreek#23 Rev 0 Hilcorp Energy Company 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area—this will not save the data entered, and will navigate to another data entry tab. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini@,hilcorp.com, lkeller@hilcorp.com ,mmyers@hilcorp.com and jbarrett@hilcorp.com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. Each rig will be assigned a username to login with. 5.4 EHS Incident Reporting • Notify EHS field coordinator. 1. This could be one of(3) individuals as they rotate around. Know who your EHS field coordinator is at all times, don't wait until an emergency to have to call around and figure it out!!!! a. John Coston: 0: (907) 777-6726 C: (907)227-3189 b. Mark Tornai: 0: (907)283-1372 C: (907) 748-3299 c. Thad Eby: 0: (907) 777-8317 C: (907) 602-5178 2. Spills: Kate Kaufman: 0:907-777-8329 C:907-244-8292 • Notify Drlg Manager 1. Paul Mazzolini: 0: 907-777-8369 C: 907-317-1275 • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final"As-Run"Casing tally to mmyers@hilcorp.com and jbarrett@hilcorp.com 5.6 Casing and Cmt report • Send casing and cement report for each string of casing to mmyers@hilcorp.com and jbarrett@hilcorp.com Page 5 Version 0 June,2014 Beaver Drilling ProcedureCreek#23 Rev 0 Hilcorp Energy Company 6.0 Planned Wellbore Schematic Beaver Creek sLIn`i PROPOSED Well BCa_1#23 1111 PTD: 000-000 API: 50-000-00000-00 CASING DETAIL ,�+ Sie Type Wt Grade Conn. ID Top Um Mud 16AaKe �" Weight Conductor •• 16" —Driven 109 X-56 Weld 16" Surf SO' to Set Depth • . 9-5/8" Surf.Csg 40 L-80 BTC 8.835" Surf 3559' 8.8 ppg 9; • 5-1/2" Prod Csg 17 P-110 D HT C 4.892' Surf 10,882' 9.D ppg i Ire +ti 9-5l8' 1: •: 1 a' h c�' pn 9 •,;•;.:0 'f 355 •i Drilling Info ..0". "-: Hole Section Casing MW Workstring F' 12-1/4" 9-5/8" 8.8 ppg 4-1/2" • ''4` .1t 8-1/2' 5-1/2" 9.0-9.5 ppg 4-1/2" �,.ail.' t:,'aer 'T>'f+ JEWELRY DETAIL '-: i 14. No. Depth ID OD Item. 1 i 1 3000' 4.892' 8.5' Baker Swell Packer 8-1/2" '.g„ �'; Hole ,4 i. - r .i1f•, n,�. 1-:"'-... ` ' 5-1/2" —?'f //,',a 1•:} .;fir :': 3 f:•.r ISM=10,800'/1111YD=10,271' TD=10,882'/TIT=i0,3a3' J Page 6 Version 0 June, 2014 BeaverllingProcedureCreek#23 11 Dri Rev 0 Hilcorp Energy Company 7.0 Drilling / Completion Summary Beaver Creek#23 is a south easterly step-out appraisal well of the lower and middle Beluga gas sands on the eastern flank of the field between the BCU 13 and BCU 16RD wells. The base plan is a 10882' "S-turn" wellbore with a shallow kickoff around 2000',building to a tangent of 31 deg,then dropping back to vertical at 7382' MD. Drilling operations are expected to commence approximately July 21st,2014. The Saxon Rig# 169 will be used to drill the wellbore then run casing and cement. Surface casing will be run to 3,559' MD / 3,483' TVD and cemented to surface to ensure protection of any shallow freshwater resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6— 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC and BLM authorities. All waste&mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal/beneficial reuse depending on test results. General sequence of operations: 1. MOB Saxon Rig# 169 to well site 2. N/U 21-1/4"x 2M diverter. 3. Drill 12-1/4"hole to 3559' MD. Run and cmt 9-5/8" surface casing. . 4. N/D diverter,N/U&test 11"x 5M T3-Energy BOP. 5. Drill 8-1/2"hole section to 10,882' MD. Perform Wiper trip. . 6. POOH laying down drill pipe. 7. Run and cmt 5-1/2"production casing . 8. N/D BOP,N/U temp abandonment cap,RDMO. Reservoir Evaluation Plan: 1. Surface hole: GR+Res LWD. 2. Production Hole: GR+Res+Den/Neu LWD. 3. Mud loggers from surface casing point to TD. Page 7 Version 0 June,2014 BeDr11 iProcedureCreek# 3 Rev 0 Hilcorp Energy Company 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at(2)week intervals during the drilling of Beaver Creek#23. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/4000 psi& subsequent tests of the BOP equipment will be to 250/4000 psi for 10/10 min(annular to 50%rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements" • Ensure both AOGCC approved drilling permit and BLM sundry are posted on the rig floor and in Co Man office. Regulation Variance Requests: Onshore Oil and Gas Order No. 1, Section III. D. 3. C. rJ o Hilcorp requests approval to install a 3-1/8" 5M HCR valve on kill line in lieu of a check valve. �� Operator suspects a freeze plug risk associated with installation of a check valve in the kill line. r o Hilcorp requests approval to utilize flexible choke and kill lines in lieu of hard piping. � ii Page 8 Version 0 June,2014 B Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp Energy Company Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 12-1/4" • 21-1/4"x 2M Hydril MSP diverter Function Test Only • 11"x 5M T3-Energy(Model 7082)Annular BOP • 11"x 5M T3-Energy Double Ram Initial Test:250/4000 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross 8-1/2" • 11"x 5M T-3 Energy Single Ram • 3-1/8"5M Choke Line Subsequent Tests: • 2-1/16"x 5M Kill line 250/4000 • 3-1/8"x 2-1/16"5M Choke manifold (Annular 2500 psi) • Standpipe,floor valves,etc • Primary closing unit: Control Technologies accumulator unit, 5 station, 120 gallon(12 x 11 gal bottles). • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: • Well control event(BOPS utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPs. • 24 hours notice prior to casing running &cement operations. • Any other notifications required in APD. Required BLM Notifications: • 48 hours before spud. Follow up with actual spud date and time. • 48 hours before casing running and cmt operations • 48 hours before BOPE tests • 48 hours before logging, coring, &testing • Any other notifications required in APD. Additional requirements may be stipulated on APD and Sundry. Page 9 Version 0 June,2014 B #2 11 Drillingeaver Procedure Rev 0 Hilcorp Energy Company Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.regg@alaska.gov Guy Schwartz/Petroleum Engineer/(0): 907-793-1226/(C): 907-301-4533 /Email:guy.schwartz@alaska.gov Victoria Ferguson/Petroleum Engineer/(0): 907-793-1247/Email: Victoria.ferguson@,alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone: 907-793-1236 (During normal Business Hours) Notification/Emergency Phone: 907-659-2714 (Outside normal Business Hours) BLM Justin Miller/BLM Petroleum Engineer/ (0): 907-271-3406 (C): 907-717-4039 Use the below email address for BOP notifications to the BLM: BLM AK_AKSO_EnergySection Notifications@blm.gov Page 10 Version 0 June, 2014 B 14 Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp Energy Company 9.0 R/U and Preparatory Work 9.1 Set 16" conductor at 60' below ground level. 9.2 Dig out and set impermeable cellar. • 9.3 Install Seaboard slip-on 16-3/4" 3M "A" section. Ensure to orient wellhead so that tree will line up with flowline later. 9.4 Level pad and ensure enough room for layout of rig footprint and R/U. 9.5 Layout Herculite on pad to extend beyond footprint of rig. 9.6 R/U Saxon Rig# 169, spot service company shacks, spot&R/U company man&toolpusher offices. 9.7 Mud loggers not required on surface hole section. 9.8 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.9 Mix mud for 12-1/4"hole section. 9.10 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.11 Install 5-1/2"liners in mud pumps. 1 • TSM 1000 mud pumps are rated at 3633 psi (85%) / 333 gpm(100%)with 5-1/2" liners. Page 11 Version 0 June, 2014 B ti Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp Energy Company 10.0 N/U 21-1/4" 2M Diverter 10.1 N/U 21-1/4"Hydril MSP 2M diverter System. • N/U 16-3/4" 3M x 21-1/4"2M DSA(Hilcorp) on 16-3/4" 3M wellhead. • N/U 21-1/4" diverter"T". • Knife gate, 16" diverter line. • Ensure diverter RJU complies with AOGCC reg 20.AAC.25.035(C). 10.2 Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked"warning zone" is established on each side and ahead of the vent line tip. "Warning Zone" must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set 15.375" ID wearbushing in wellhead. Page 12 Version 0 June,2014 Bea #2 Drillingver Procedure Rev 0 Hilcorp Energy Company 10.5 Rig and Diverter Line Orientation on Beaver Creek 3 pad: 1,,,i ' .,,i,,,t ft,. It titiol... . ,... ,,,:i„,w ,. r ,- 14 t 0 . ..... ,....... ,. , .. I 0 . * 0t. ,. ,4 4r t° 410'4fit It ft Ii' ; ii ,., air „.......„1,4„ .. 1, ir t A. , IF it A SPL. . 41:' .''' r E ri Bea'oerCreek Unit ,e,s-r,=,�c i. pad 3 Fret S4 tC`7 Page 13 Version 0 June, 2014 Bea Drillingver ProcedureCreek#23 Rev 0 Hilcorp Energy Company 10.6 Diverter Schematic Arril fro rn frt in Annular Preventer ..- __. TJ1 dril MSP 21-',"2M iii lii` iii Knife Gate I-UP ILL ill MO 16" Diver#rr line Diverter Tee,21-W x 21-W x 2M wl 16"ANSI 150 outlet TTI III Til III III , 16a/a"3Mx21-%"2MUSA J. Eli Now I'i-I!i; . Seaboard 16-W 3M i s t Casing head Assy 16" Page 14 Version 0 June,2014 Beaver #2 Drilling Procedure Rev 0 Hilcorp Energy Company 11.0 Drill 12-1/4" Hole Section 11.1 P/U 12-1/4"directional drilling assy: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Workstring will be 4.5" 16.6# S-135 CDS40 11.2 12-1/4"BHA (GR and Res LWD are included in below BHA): OMPONENT DATA UOD IQ Gauge Weight Top Length Cumulative 3 Description her A - (in) (in) (in) (Ibpf) Connection (ft) Length HOBS-OHCIGRC Miiltooth 12.200 3.000 12.250 374.30 P 6-58'REG 1.20 1.20 © 8-SperryDri:l Lobe 415-5.3 sig 8.000 5.000 121.08 B 6-518-REG 28.99 30.19 - Stabilizer - 11.500 _--- © Integral Blade Stabilizer 11111111=111 8.000 2.813 12.125 150.12 1 6-5I8-REG 6.00 36.19 © 8"DM Collar(Directional) 8.000 3.500 147.40 Ii . a 9.20 45.39 © 8-DGR Collar (Gamma) 8.000 1920 142.70 B 6-518"REG 4.55 49.94 • 8"EWR-P4 Collar(Resistively) 8.000 2.000 151.00 B 6-518"REG 12.19 62.13 Ell 8"HCIM Collar(Processor) 8.000 1.920 149.90 B 6-518"REG 4.97 67.10 Ell 8"TM-HOC(Pu'ser) 8.150 4.000 145-20 = 15.77 B2.87 ® Orienting S.:b UBHO 8.000 3.000 147.22 B 6-518"REG 3.50 86.37 10 Non Mag Flex Drill Collar 8.000 3.000 147.22 ri= 30.00 116.37 EMI Non Mag Flex Drill Collar 8.000 3.000 147.22 B 6-518"REG 30.00 146.37 m X-O 6-518 Reg Pin X 4-1Q-IF Box 8.000 2.813 150.12 B 4-1/2"IF 3.50 149.87 5.000 3.000 _ 49.30 240.00 389,87 ® Weatherford 6-114'Hyd Jar 6.250 2.250 91.01 B 4-112-IF 30.00 419.87 MI 19 Joints 5"HW DP 5.000 3.000 49.30 570.00 989.87 989.87 BIT DATA _. ._._�_... Bit Number Nozzles 1x12,3x18 Bit Size (in) : 12.250 TFA (in2) :0.8560 Manufacturer : HDBS Dull Grade In Model Dull Grade Out . Serial Number • W OTDR DATA Motor Number : 2 Bend (deg) : 1.15 OD (in) : 8.000 Nozzles (32nd) : 0.0 Manufacturer : Sperry Drilling Avg Diff Press . Model : SperryDrill Cumul Cir Hrs .• Serial Number . Page 15 Version 0 June,2014 Beaver ProcedureCreek# 3 Rev 0 Hilcorp Energy Company 11.3 Primary Bit: 12-114" (311MM) QH PRODUCT SPECIFICATIONS IADC Code 117W Total Tooth Count 67 Gage Row Tooth Count 39 Journal Angle 33° Offset(1116") 6 �' 111 Jet Nozzle Types Standard 83244 111 Extended 3024-17 Center Jet (If Center Jetted)501813 T.J.Connection 6-518"(API Reg.) Recommended Make-Up Torque* 23000132000 Ft*lbs. Bit Weight(Boxed) 250 Lbs.(113 Kg.) Bit Breaker (Mat. ,+Legacy#) 515353,506463 1 "f 0 ' PRODUCT FEATURES . New patented DiamondTm Claws tooth bit design. . Tungsten carbide`surf inserts in gage teeth for added gage „ . protection. . Newly formulated,proprietary hardfacing on cutting structure and gage maximizes carbide and diamond volume for ultimate wear t resistance. t. . High-speed bearing designed for high rpm and high-energy applications. r` . Innovative mechanical pressure compensating system provides reliable pressure equalization and relief for maximum bearing and seal life. . Raised tungsten carbide inserts and proprietary hardfacing provides maximum arm protection in abrasive and directional applications while minimizing drill string torque. ▪ uadPacks Plus Series incorporates its successful"longevity" features and patented engineered hydraulics system for optimal cleaning efficiency. . Center jet feature to prevent bit balling problems Material#622394 *Calculations based on recommendations from API and tool-joint manufacturers. IC!2012 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. Page 16 Version 0 June, 2014 Bea Drillingver ProcedureCreek#23 Rev 0 Hilcorp Energy Company 11.4 4-1/2"Workstring&HWDP will come from Saxon. Jars will come from Weatherford. 11.5 Begin drilling out from 16"conductor at reduced flow rates to avoid broaching the conductor. 11.6 Drill 12-1/4"hole section to 3,559' MD/3,483' TVD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 500 - 550 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. • • TD the hole section in a good shale between 3500' MD and 3700' MD. • • Take MWD surveys every stand drilled(60' intervals). 11.7 12-1/4"hole mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1)ppg above highest anticipated MW. We will start with a simple gel +FW spud mud at 8.8 ppg. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 8.8—9.5 ppg Pre-Hydrated Aquagel/freshwater spud mud - Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL pH - 80-3559' 8.8—9.5 85-150 20-40 25-45 <10 8.5-9.0 Page 17 Version 0 June, 2014 Bea2 II Drillingver ProcedureCreek# 3 Rev 0 Hilcorp Energy Company System Formulation: Aquagel + FW spud mud Product Concentration Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL 12-15 ppb caustic soda 0.1 ppb (9 pH) BARAZAN D+ as needed BAROID 41 as required for weight PAC-L/DEXTRID LT if required for<12 FL ALDAC1DE G 0.1 ppb X-TEND II 0.02 ppb 11.8 At TD; pump sweeps, CBU, and pull a wiper trip back to the 16" conductor shoe. 11.9 TOH with the drilling assy, handle BHA as appropriate. 11.10 No open hole logs are planned for the 12-1/4"hole section. Page 18 Version 0 June, 2014 Beaver Creek#23 Drilling Procedure Rev 0 Hilcorp Energy Company 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull 15.375"wearbushing. 12.2 R/U Weatherford 9-5/8"casing running equipment. • Ensure 9-5/8"BTC x CDS 40 XO on rig floor and M/U to FOSV. • R/U fill-up line to fill casing while running. • Ensure all casing has been drifted on the location prior to running. • Be sure to count the total#of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U&thread locking shoe track assy consisting of: • (1) Shoe joint w/float shoe bucked on(thread locked). • (1)Joint with coupling thread locked. • (1)Joint with float collar bucked on pin end &thread locked. • Install (2)centralizers on shoe joint over a stop collar. 10' from each end. • Install(1)centralizer, mid tube on thread locked joint and on FC joint. • Ensure proper operation of float equipment. 12.5 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use"API Modified"thread compound. Dope pin end only w/paint brush. • M/U connections to the base of the triangle stamped on the pin end. Note M/U torque values required to achieve this position. Estimated torque to reach base of triangle: 10,750 ft-lbs. • After making up several connections,use the torque required to M/U to base of triangle as the M/U torque and continue running string. • Install (1)centralizer every other joint to 300'. Do not run any centralizers above 300' in the event a top out job is needed. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 9-5/8" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 9-5/8" 9,630 ft-lbs Page 19 Version 0 June,2014 Bea #2 Drillingver Procedure Rev 0 Hilcorp Energy Company NM= WI naris Casing and Tubing Performance Data Choose pipe size,wall thickness and steel grade to view API connection options and performance data. Size Wall Grade Connection -12 Unit Pipe Body Data GEOMETRY A Nominal OD 9.625 in Wall Thickness 0.395 in API Drift Diameter 8.679 in Nominal Weight 40.00Ilbstft Nominal ID 8.835 in Alternate Drift Diameter 8.75 in Plain End Weight 38.97lbslft Nominal Cross Section 11.454 sq in PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Body Yield Strength 916,000 lbs Internal Yield Pressure 5,750 psi Collapse Pressure 3,080 psi • 4I fIlb Connection Data GEOMETRY Regular OD 10.625 in Threads Per Inch 5 Make-Up Thread Turns 1 PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Joint Strength 947,000 lbs Internal Pressure 5,750 psi Resistance TenarisHydril Premium Connections I Print I Contact Us Ver 8.6 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.7 Slow in and out of slips. 12.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. Page 20 Version 0 June, 2014 B #2 Drillingeaver Procedure Rev 0 Hilcorp Energy Company 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. Page 21 Version 0 June,2014 Beaver Drilling ProcedureCreek#23 Rev 0 Hilcorp Energy Company 13.0 Cement 9-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud& water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. 13.2 Document efficiency of all possible displacement pumps prior to cement job 13.3 R/U cmt head(if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.4 Pump 5 bbls 10 ppg spacer. Test surface cmt lines. 13.5 Pump remaining 30 bbls 10 ppg spacer. 13.6 Drop bottom plug. Mix and pump cmt per below recipe. 13.7 Cement volume based on annular volume + 50% open hole excess. Job will consist of lead& tail, TOC brought to surface. Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol(ft3) 12.0 ppg LEAD: 80' x .129 bpf= 10.3 57.8 16" Conductor x 9-5/8" 3- casing annulus: 12.0 ppg LEAD: (3059' — 80')x .0558 bpf x 1.5 = 249.3 14005 12-1/4" OH x 9-5/8" S�� L Casing annulus: Total LEAD: 259.6 bbl 1457.8 ft3 TAIL: (3559'-3059') x .0558 bpf x 1.5 = 41.9 235.3 12-1/4" OH x 9-5/8" L.i* Casing annulus: TAIL: 90 x .096 bpf = 8.7 48.8 9-5/8" Shoe track: Total TAIL: 50.6 bbl 284.1 ft3 Page 22 Version 0 June, 2014 B2 Drillingeaver PCreekrocedure# 3 Rev 0 Hilcorp Energy Company Cement Slurry Design: Lead Slurry (3059' MD to surface) Tail Slurry (3539' to 3059' MD) System Extended Conventional Density 12 lb/gal 15.4 lb/gal Yield 2.46 ft3/sk ✓ 1.22 ft3/sk Mixed Water 14.349 gal/sk 5.507 gal/sk Mixed Fluid 14.469 gal/sk 5.507 gal/sk Code Description Concentration Code Description Concentration G Cement 94#/sk A Cement 94#/sk Additives D110 Retarder 0.15 gal/sk BWOC D046 Anti Foam 0.2% BWOC D046 Anti Foam 0.2% BWOC D065 Dispersant 0.4% BWOC D079 Extender 2.0% BWOC 5002 CaCl2 0.35% BWOC D020 Extender 3.0% BWOC D177 CaCl2 0.1% BWOC 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug and displace cement with 9.0 ppg 6% KCL PHPA. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. 13.11 Displacement calculation: 3559'-80' = 3479' x .075.8 bp — 263.7 bbl 13.12 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. Page 23 Version 0 June, 2014 B2 Drillingeaver ProcedureCreek# 3 Rev 0 Hilcorp Energy Company 13.13 Do not overdisplace by more than V2 shoe track volume. Total volume in shoe track is 8.7 bbls. • Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log between 12— 18 hours after CIP. • Be prepared with small OD top out tubing in the event a top out job is required. The AOGCC will require us to run steel pipe through the hanger flutes. The ID of the flutes is 1.5". 13.14 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold,pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.15 R/D cement equipment. Flush out wellhead with FW. 13.16 Back out and L/D landing joint. Flush out wellhead with FW. 13.17 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.18 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing,bpm,note any shutdown during mixing operations with a duration a. Pump rate while displacing,note whether displacement by pump truck or mud pumps, weight&type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement,actual displacement volume, whether plug bumped&bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping of job.Final circulating pressure e. Note if pre flush or cement returns at surface&volume f. Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to mmyers cr,hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 24 Version 0 June, 2014 B Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp Energy Company 14.0 BOP N/U and Test 14.1 N/D the diverter. 14.2 N/U Seaboard multi-bowl wellhead assy. Install 9-5/8"packoff P-seals. Test to 3000 psi. 14.3 N/U 11"x 5M T3-Energy BOP as follows: • BOP configuration from Top down: 11"x 5M T3-Energy annular BOP/11"x 5M T3-Energy Model 6011i double ram/11"x 5M mud cross/11"x 5M T3-Energy Model 6011i single ram • Double ram should be dressed with 2-7/8 x 5" VBRs in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8 x 5" VBRs • N/U bell nipple, install flowline. • Install (2)manual valves & a check valve on kill side of mud cross. • Install (1)manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.4 Run 4-1/2"BOP test assy, land out test plug(if not installed previously). • Test BOP to 250/4000 psi for 10/10 min. Test annular to 250/2500 psi for 10/10 min. • Ensure to leave "B" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 9.0 ppg 6% KCL PHPA mud system. 14.8 R/U mud loggers for production hole section. 14.9 Set 10"ID wearbushing in wellhead. 14.10 Rack back as much 4-1/2"DP in derrick as possible to be used while drilling the hole section. Page 25 Version 0 June, 2014 B II Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp Energy Company 15.0 Drill 8-1/2" Hole Section 15.1 P/U 8-1/2" directional BHA. 15.2 Ensure BHA components have been inspected previously. 15.3 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.4 TF offset is measured accurately and entered correctly into the MWD software. 15.5 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. 15.6 Workstring will be 4.5" 16.6# S-135 CDS40. Page 26 Version 0 June, 2014 B II Drillingeaver ProcedureCreek #23 Rev 0 Hilcorp Energy Company 15.7 8-1/2" BHA: COMPONENT DATA Item Dascripf,r. 1 HDBS-FX65D PDC 8.400 2.500 8.500 172.13 P 4-1.2'REG 1.00 1.00 2 7"SperryOrill Lobe 718-6.0 stg 7.000 4.952 93.13 B 4-1/2'iF 27.38 28.38 Stabilizer 7.750 3 Non Mag Float Sub 6.750 2.750 101.71 B 4-112"IF 3.00 31.33 4 Integral Blade Stabilizer(NM) 5.750 2.813 8.375 100.77 B 4-112"iF 5.00 35.33 5 6 3.4"DM(Directional) 6.750 3.125 103.40 B 4-112'IF 9.20 4558 6 6 3:4"BAT (Sonic) 6.750 1.905 97.70 B 4-112"IF 2020 65.89 7 6 314'DGR(Gamma) 6.750 1.920 97.80 B 4-112"IF 4.55 70.44 B 6 3'4"EWR-P4 (Resistivety) 6.750 2.000 104.30 B 4-1/2"IF 12.10 8254 9 5 314"HCIM (Processor) 6.750 1.920 101.70 B 4-112"IF 4.97 87.51 10 6 3/4"ALD (Density) 6.750 1.920 8.250 104.30 B 4-1/2'IF 14.54 102.05 Stabilizer 8.250 11 6 34'CTN(Neutron) 6.750 1.905 102.30 B 4-1'2"IF 11.84 113.89 12 6 314"TM-HOC(Puiser) 6.900 3.250 103.60 B 4-1/2'IF 15.59 129.48 13 Non Mag Flex Drill Collar 6.750 2.813 100.77 B 4-112"IF 30.00 159.48 14 Non Mag Flex Drill Collar 6.750 2.813 100.77 B 4-1/2'IF 30.00 189.48 15 8 Joints 5"HWDP 5.000 3.000 49.30 240.00 429.48 16 Weatherford 6-1/4"Jars 6.250 2.250 91.01 B 4-112"IF 30.00 459.48 17 19 Joints 5"HWDP 5.000 3.000 49.30 570.00 1029.48 102046 BIT DATA - Bit Number Nozzles :5x13 Bit Size (in) : B.5CC TFA (in2) :0.6481 Manufacturer Dull Grade In . Model Dull Grade Out . Serial Number . Motor Number : 1 Bend (deg) : 0.00 OD (in) : 7.000 Nozzles (32nd) : 0.0 Manufacturer : Sperry Drilling Avg Diff Press .• Model SperryDrill Cumul Cir Hrs .• Serial Number . Page 27 Version 0 June, 2014 B2 111 Drillingeaver ProcedureCreek# 3 Rev 0 Hilcorp Energy Company 15.8 Primary Bit: . HALL18URTON 8-1/2" (216mm) FX55 PRODUCT SPECIFICATIONS Cromer Type :13-Extreme Drilling v. IANC Code 61:24 >✓ s Body Type MATRIX 4: Total Cutter Count 41 Cutter =9 Diseributtinn 1;mm f..mm. Er` i , 0 Face O ?6 i s+ Ciawu 5 5 Up Milli 5 it 1 Nmmher ef'Loge Nnrzlcs 5 Number of Me.ditam Nctrki 0 ; Mamba of Small Nor/523 0 N'} ° Va nher of Micro Nanrles 0 „'�� Number of Ports 0 )mak Sine Alva i ay in) 1276 * - +". Normalized Face 1'ohtme _fl .14. API Comtaoction 4-1.2 REG.PIN 1 Recenantomkd Maki L;p Torque* 11461-17.766 8971, .+01 $:i.f Nominal Dimensions" s+rNJ 41 Make-Up Face to None 11.11 it-282 nun " Cavune Length 2 in-51 tram ) S6ceseLength Din-Otrsm 1 • Shank Diameter 6 in-152 t® { Break Out Ptatc @1at.M:1 ceac%' i 18195444040 AppraxcienareShipping Weida 150Lhs.-61Kg, SPECI.11.FEATURES 1'p-Drill Cutters on Ciage Pads.1 32"Ram ed Gaffe • i Material 4687916 *kit specific recama;nied make-up rccqur is a Ruction of die hit LIl and atrial hit sub U.IA unhand as ape fiol in API RP CI SaWxi A.Si "Desks'dimensions arc nominal and mty Wray-sliAlly en nemrfxtured product.11all hwten Drill Bin and Sums mod is are n7aimurtuly reviewed and Mica Pnaductt splrirkafions may chance x ithuut native. l'i 2112!biathlon.All tights rmerneiL Saba of ILtllibtnton prodw-ts and scrvires will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that inapplicable to the sale. WWW.haliibvrton.eom Page 28 Version 0 June, 2014 B Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp Energy Company 15.9 8-1/2"hole section mud program summary: Weighting material to be used for the hole section will be salt and calcium carbonate. Additional calcium carbonate will be on location to weight up the active system(1)ppg above highest anticipated MW. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.0 ppg 6%KCL PHPA fresh water based drilling fluid. Properties: Plastic MD Wed Viscosity Viscosity Yield Point pH HPHT gh3559'-10,882' 9.0—10.0 40-53 15-25 15-25 8.5-9.5 <11.0 System Formulation: 6% KCL EZ Mud DP Product Concentration Water 0.905 bbl KC1 22 ppb (29 K chlorides) Caustic 0.2 ppb (9 pH) BARAZAN D+ 1.25 ppb (as required 18 YP) EZ MUD DP 0.75 ppb(initially 0.25 ppb) DEXTRID LT 1-2 ppb PAC-L 1 ppb BARACARB 5/25/50 15-20 ppb(5 ppb of each) BAROID 41 as required for a 9.0—10.5 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb (maintain per dilution rate) 15.10 TIH w/ 8-1/2"directional assy to TOC. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. 15.11 R/U and test casing to 3000 psi/30 min. Ensure to record volume/pressure and plot on FIT graph. AOGCC reg-t§-511%7 burst. 15.12 Drill out shoe track and 20' of new formation. 15.13 CBU and condition mud for FIT. Page 29 Version 0 June,2014 Beaver #2 Drilling Procedure Rev 0 Hilcorp Energy Company 15.14 Conduct FIT to 11 ppg EMW. Note: Offset field test data predicts frac gradient at the 9-5/8"shoe to be btwn 15- 16 ppg EMW. An 11 ppg FIT results in a 2 ppg kick margin while drilling with the planned MW of 9 ppg• 15.15 Drill 8-1/2"hole section to 10,882' MD/ • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 400 - 500 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team, try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss< 10. • Take MWD surveys every other stand drid. Surveys can be taken more frequently if deemed necessary. • Take(3) sets of formation samples every 20'. Mud loggers should compile Pixler plots and QFT 2 analysis for Lower Tyonek to total depth. 15.16 At TD;pump sweeps, CBU, and pull a wiper trip back to the 9-5/8"shoe. 15.17 TOH with the drilling assy, laying down drill pipe and BHA. 15.18 Install 5-1/2"pipe rams in BOP stack and RU and test. Page 30 Version 0 June,2014 B #2 Drieaverlling Procedure Rev 0 Hilcorp Energy Company 16.0 Run 5-1/2" Production Casing 16.1. R/U Weatherford 5-1/2"casing running equipment. • Ensure 5-1/2"DWC/C HT x CDS 40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted prior to running. • Be sure to count the total #of j oints before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 16.2. P/U shoe joint, visually verify no debris inside joint. 16.3. Continue M/U&thread locking shoe track assy consisting of: • (1) Shoe joint w/shoe bucked on&threadlocked(coupling also thread locked). • (1)Joint with float collar bucked on pin end&threadlocked(coupling also thread locked). • Solid body centralizers will be pre-installed on shoe joint an FC joint. • Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe and float collar. • Utilize a collar clamp until weight is sufficient to keep slips set properly 16.4. Continue running 5-1/2"production casing • Fill casing while running using fill up line on rig floor. • Use "API Modified"thread compound. Dope pin end only w/paint brush. • Install solid body centralizers on every joint across zones of interest, TBD after LWD. • Install solid body centralizers on every other joint to 9-5/8" shoe. Leave the centralizers free floating. • Pick up swell packer and place in string at approximately 3000'. 16.5. Continue running 5-1/2"production casing 5-1/2" DWC/C HT M/U torques Casing OD Minimum Maximum Yield Torque 5.5" 12,000 ft-lbs 13,800 ft-lbs 18,700 ft-lbs Page 31 Version 0 June,2014 Bea #2 Drillingver Procedure Rev 0 Hilcorp Energy Company Technical Specifications Connection Type: Slze(O.D.): Weight (Wall): Grade: DWC/C-HT Casing 5-1/2 in 17.00 lb/ft (0.304 in) P-110 standard Material P-110 Grade "11411 ,l '' 110,000 Minimum Yield Strength (psi) U SA 125,000 Minimum Ultimate Strength(psi) NAM USA 4424 W.Sam Houston Pkwy.Suite 150 Pipe Dimensions Houston,TX 77041 Phone: g3201 5.500 Nominal Pipe BodyO.D. (in) Fax: 3-478-3234 4.892 Nominal Pipe Body I.D.(in) E-mail:VAMUSAsatesvam-usa.com 0.304 Nominal Wall Thickness(in) 17.00 Nominal Weight(Ibslft) 16.89 Plain End Weight psi-ft) 4.962 Nominal Pipe Body Area (sq in) /:7 Pipe Body Performance Properties 546,000 Minimum Pipe Body Yield Strength (lbs) 7,480 Minimum Collapse Pressure(psi) 10,640 Minimum Internal Yield Pressure(psi) 9,700 Hydrostatic Test Pressure (psi) Connection Dimensions 6.050 Connection O.D.(in) 4.892 Connection I.D. (in) 4.767 Connection Drift Diameter(in) 4.13 Make-up Loss(in) 4.962 Critical Area (sq in) ✓ 100.0 Joint Efficiency(%) Connection Performance Properties 546,000 Joint Strength (lbs) 22,940 Reference String Length(ft) 1.4 Design Factor 568,000 API Joint Strength(lbs) 546,000 Compression Rating (lbs) 7,480 API Collapse Pressure Rating (psi) 10,640 API 'Internal Pressure Resistance (psi) 91.7 Maximum Uniaxial Bend Rating [degrees/100 ft] Appoxlmated Field End Torque Values 12,000 Minimum Final Torque (ft-lbs) 13,800 Maximum Final Torque (ft-lbs) 18,700 Connection Yield Torque (ft-lbs) For detailed information on performance properties,refer to DWG Connection Data Notes on following page(s). Page 32 Version 0 June, 2014 B II Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp Energy Company 16.6. Run in hole w/ 5-1/2" casing to the 9-5/8" casing shoe. 16.7. Fill the casing with fill up line and break circulation every 1,500 feet to the window or as the hole dictates. 16.8. Obtain slack off weight, PU weight, rotating weight and torque of the casing. 16.9. Circulate 2X bottoms up at shoe, ease casing thru shoe. 16.10. Continue to RIH w/casing no faster than 1 jt./minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.11. Set casing slowly in and out of slips. 16.12. PU 5-1/2"X 8-1/2" swell packer to be placed at approximately 3000'. Swell packer should have 10' handling pups installed on both ends with bow spring centralizers on pups. 16.13. Swedge up and wash last 2 joints to bottom. P/U 5' off bottom. Note slack-off and pick-up weights. 16.14. Stage pump rates up slowly to circulating rate. Circ and condition mud with casing on bottom. Circulate 2X bottoms up or until pressures stabilize and mud properties are correct and the shakers are clean. Reduce the low end rheology of the drilling fluid by adding water and thinners. 16.15. Reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 33 Version 0 June, 2014 Bea Drillingver ProcedureCreek#23 Rev 0 Hilcorp Energy Company 17.0 Cement 5-1/2" Production Casing 17.1. Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud& water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface,regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 17.2. Attempt to reciprocate the casing during cmt operations until hole gets sticky 17.3. Pump 5 bbls of 12.5 ppg Mud Push spacer. 17.4. Test surface cmt lines to 4500 psi. 17.5. Pump remaining 30 bbls 10.5 ppg Mud Push spacer. 17.6. Mix and pump lead and tail cement per below recipe. Ensure cement is pumped at designed weight. Job is designed to pump 35%OH excess. Section: Calculation: BLS) Vol (ft3) (B9-5/8"x 5-1/2" Csg Overlap: 500' x 0.0464= 23.2 130.4 8-1/2" OH x 5-1/2" Casing: (10882—3000)x 0.0408 x 1.35 = 434.1 2437.5 Shoe Track: 80' x 0.02325 = 1.9 10.4 Total Volume : 459.2 2578.2 f 8 15 s x Page 34 Version 0 June,2014 Bea #2 111 Drillingver Procedure Rev 0 Hilcorp Energy Company EASYBLOK (10882' to 3000') System Conventional Density 15.3 lb/gal Yield 1.36 ft3/sk ''/ Mixed Water 5.93 gal/sk Mixed Fluid 5.93 gal/sk Code Description Concentration Class G Cement 94#/sk D046 Foam Preventer 0.2%BWOC D202 Dispersant 1.5%BWOC Additives D400 EASYBLOK 0.8% BWOC D154 Extender 8.0% BWOC D174 Expanding Additive 1.5% BWOC D198 Retarder 0.3%BWOC 17.7. Drop wiper plug and displace with produced water. 17.8. If hole conditions allow—continue reciprocating casing throughout displacement. This will ensure a high quality cement job with 100% coverage around the pipe. 17.9. If elevated displacement pressures are encountered, position casing at setting depth and cease reciprocation. Monitor returns &pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 17.10. Bump the plug and pressure up to 500 psi over final lift pressure. Hold pressure for 3 minutes. 17.11. Do not overdisplace by more than %2 shoe track. Shoe track volume is 1.9 bbls. Page 35 Version 0 June, 2014 Beaverlling CreekProcedure#23 Dri Rev 0 Hilcorp Energy Company 17.12. Bleed pressure to zero to check float equipment. Watch for flow. Note amount of fluid returned after bumping plug and releasing pressure. 17.13. RD cementers and flush equipment. 17.14. WOC minimum of 12 hours,test casing to 3000 psi and chart for 30 minutes. Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing,bpm,note any shutdown during mixing operations with a duration i. Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid j. Note if casing is reciprocated or rotated during the job k. Calculated volume of displacement, actual displacement volume,whether plug bumped&bump pressure, do floats hold 1. Percent mud returns during job, if intermittent note timing during pumping of job.Final circulating pressure m. Note if pre flush or cement returns at surface&volume n. Note time cement in place o. Note calculated top of cement p. Add any comments which would describe the success or problems during the cement job Send final "As-Run"casing tally&casing and cement report to mmvers@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 36 Version 0 June,2014 Bea Drillingver ProcedureCreek#23 Rev 0 Hilcorp Energy Company 18.0 RDMO 18.1. Install BPV in wellhead v 18.2. N/D BOPE 18.3. N/U temp abandonment cap 18.4. RDMO Saxon Rig#169 KYVV � et#ct ` 4.4 `e'�X Page 37 Version 0 June,2014 B #2 II Drillingeaver ProcedureCreek3 Rev 0 Hilcorp Energy Company 19.0 BOP Schematic �l•11 )1,f. 1� VI ti Airn ffrl frti irn frti frtiNni L J 3.5" 1.11--1lP 511-.1 R/ 111 1!1 illi 1111 3.0 l' -._4:l' (�J�" ��a I 3 i .rt I r 1 D ',de,/tvlodp1 73n2 Fa [.....L1 11' 5300 , 44a '. _16 1l1 la! ilii-iii illi ii 2 2.00' rc~ �I .' ..fir.. ill altil ill ill ' 2 1/16 5M Kill Side 1/8 5M Choke Side A T-3 F nP . . -,. 1=11' ,--t. cSi s.1:1;1,.1 lCBZ It- s.._ r , C f a 2 :I' I in [ii illi Iii • 11 c r . '— Vii ` , i Y Vi i j It-IIII ,s1,, :.. , 1 IIT, I { Page 38 Version 0 June, 2014 n I- Beaver Creek#23 Drilling Procedure Rev 0 Hilcorp Energy Company 20.0 Wellhead Schematic Beaver Creek New Drill-Saxon 169 16X95/8X5 1/2 Tree cap,Otis,5 1/8 5M FE X 9%Otis Quick Union o I I Valve,Swab,WKM-M, a 51/85M FE,HWO, C DD trim O i, .� 0 0 Valve,Wing,WKM-M, I7/11111;`,_,,' / 7 iAPIIIIIIk Valve,Wing,WKM-M, 31/85M FE,HWO, + L R .1 31/85M FE,HWO, DD trim ']�' ?: �` 1 C— • -'`2— DD trim I '..%) Valve,Upper Master, WKM-M,51/8 5M FE,HWO, DD trim U 0, NM Crossover spool, MONO 5 1/8 SM FE X 5 1/8 10M FE Valve,Master,CI W-FC, 7 ,C, 5 1/810M FE,HWO, J!u': EE trim uU V'' -amgr._ o- n Tubing head,Seaboard-S8, 11 ,`i iJ it 163/43M X115M, 4l - 1 , 4, w/2-21/165M SSO, ill IRO 74111.�•1•', 9 5/8 P seal bottom 1 - I alli Dwi =.g1 X11n .4 Starting head,Seaboard, 16'/.3M X 16"SOW BTM, 111 '� '4711 � - w/2-21/165MSSO MI IIIc . I�1114... i ii. 0 16" I 9 5/8" I 5'N" Page 39 Version 0 June,2014 Bea Drillingver ProcedureCreek#23 Rev 0 Hilcorp Energy Company 21.0 Days Vs Depth Days Vs Depth 0 —Beaver Creek 23 2000 4000 r r 6000 .e 0 an 8000 10000 J 12000 0 5 10 15 20 25 30 Days Page 40 Version 0 June, 2014 B Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp Energy Company 22.0 Geo-Prog GEOLOGICAL PROGNOSIS WELL NAME: BCU 23 (GR well from Pad 3) FIELD: Beaver Creek SURFACE: X=317520.56 LONG: -151.01714138 STATE: Alaska Y=2434039.88 LAT:60.65853388 BOTTOM HOLE X=319526.7 LONG: -151.0058999 ND REF DATUM KB Y=2433321.1 LAT: 60.6566522 TVD REF ELEV 179 18.6'KB(Saxon 169) COORD REF. SYSTEM NAD27 GROUND ELEV 160.6 PROPOSED TD: 10,900'MD/10,353'TVD Objective: Beluga B18-B32 gas sands Geo Summary/ Justification: The goal of the BCU 23 is to test the Middle and Lower Beluga gas sands(B18-B32)on the eastern flank of the field between the BCU 10 and 13 wells ANTICIPATED FORMATION TOPS&GEOHAZARDS EXPECTED Critical Intersection Points TOP TOP NAME FORMATION FLUID TVD(FT) TVDSS(FT) Est.Pressure X Y +/- SHALLOW GAS Sterling water/gas 3,028 -2,849 1200-1300 psi 317665.1 2433992.1 30 B2 Sterling water/gas 5,077 -4,898 1900-2300 psi 318812.1 2433579.0 30 B4 Sterling water/gas 5,254 -5,075 1900-2300 psi 318916.1 2433541.5 30 UBC3 Beluga water/gas 6,095 -5,916 1000-3300 psi 319379.8 2433374.1 30 B18 Beluga gas 7,265 -7,086 1000-3400 psi 319524.4 2433321.9 30 B24 Beluga gas 7,782 -7,603 3000-3500 psi . 319526.7 2433321.1 30 B28B Beluga gas 7,923 -7,744 3000-3600 psi 319526.7 2433321.1 30 B30 Belugagas 8,216 -8,037 3000-3600 psi 319526.7 2433321.1 30 . .......... ... Tyonek Tyonek water 8,715 -8,536 3000-3600 psi 319526.7 2433321.1 30 TD 179 See BHL above =Primary Objective =Secondary Objective TARGET RADIUS 50 ft DATA COLLECTION REQUIREMENTS: Mud Logging: Full crew of4 for production hole section. 2 sets of washed&dried samples collected every20 ftfrom KOP to TD. Pixder plots and sh LWD Data: Sperry Triple Combo Page 41 Version 0 June, 2014 B Drillingeaver ProcedureCreek#23 Rev 0 Hilcorp Energy Company 23.0 Anticipated Drilling Hazards 12-1/4" Hole Section: Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/ gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP btwn 25 —45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole-cleaning problems. If encountered, be prepared to increase the viscosity. Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of—50 - —60 lbs/100ft2 to combat this issue. Maintain low flow rates for the intial 200' of drilling to reduce the likelihood of washing out the conductor shoe. To help insure good cement to surface after running the casing, condition the mud to a YP of 25 —30 prior to cement operations. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheologies can be achieved. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. Page 42 Version 0 June, 2014 B # Drillingeaver Procedure Rev 0 Hilcorp Energy Company 8-1/2" Hole Section: Lost Circulation: Ensure 1000 lbs of each of the different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/viscosifier as necessary. Sweep hole w/20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP btwn 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain MW as necessary using additions of Calcium Carbonate as weighting material. A torque reduction lube may be used in this hole section in concentrations up to 3% if needed. Maintain 6%KC1 in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The '/ need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt-type additives to further stabilize coal seams. • Increase fluid density as required to control running coals. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: H2S is not present in this hole section. t/ No abnormal temperatures are present in this hole section/ Page 43 Version 0 June, 2014 Bea2 II Drillingver ProcedureCreek# 3 Rev 0 Hilcorp Energy Company 24.0 Saxon Rig 169 Layout >1 I-+ - ----11,-r PPE l'.•,,e5 :Y- ma M �IiIrin;a --_ ^nF FRUT 1,14 I=I==i=ii-1=1-1 1111..- ---=-- '-®— --=-- 111111 IIIII 0. i:u1F ral,�='6 1 .: .�a.1114M 13nii�011,..j:2 SIP saaFtry i -- - - -- „ �-_ ii.•--.........4--111.1.,..--! a IN _I. 1 • ;-.ST.:��iiiilai3111 �. -s - wT..K �, _ IIIA �III11 1i4&€ " Illi __- .-i�� .1 IIp N:in P10.0 1 T - q.t.,'T-NE LI L NY h ,11 1 Et1iL__ I.__ II Iil,m iC dill iiiiElm mum I amom•=11 r ---.r 11111111�1111111111��- ii - I r.uan..n,a MANN, �. 1 ._.,... �° ti 71�� a �� a. ! lo-av,F MAT,TMx Rn.1Flayi ., Page 44 Version 0 June,2014 B Drillingeaver PCreekrocedure#23 Rev 0 Hilcorp Energy Company 25.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer(ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 45 Version 0 June,2014 Beaver Drilling ProcedureCreek#23 Rev 0 Hilcorp Energy Company 26.0 Choke Manifold Schematic g 1 1 ii N � ,_, il n 1— 15‘ .4-1Wij - 41:- to — = Er 1 (Ai la ''' '' ---' q 1 I11' ru P. J _- 'tel„ E ", J_ !, '4 ', •e• Q ■ . N ._. , . Ti u u o r. L_ L 1)1131119111 " n ra F_ 4111fn II'� r Y; I{{r I I .7a - � I�A€. I 4 . ;_ I 11EI ft ie r u 0 -Deli in). 't ri __-_1_ ,41;11.istk ,. vi i fionteri 1117 e' L.,.:,. . . ! g g ismm= Ili f �. g Y Iii I 1111111 Page 46 Version 0 June,2014 Bea #2 Drillingver Procedure Rev 0 Hilcorp Energy Company 27.0 Casing Design Information Calculation &Casing Design Factors Beaver Creek Unit DATE:6/20/2014 WELL:Beaver Creek#23 FIELD: Beaver Creek DESIGN BY:Monty M Myers Design Criteria: Hole Size 12-1/4" Mud Density: 8.8 ppg Hole Size 8-1/2" Mud Density: 9.0 ppg Hole Size Mud Density: Drilling Mode MASP: 1412 psi (see attached MASP determination&calculation) MASP: Production Mode MASP: 2568 psi (see attached MASP determination&calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.435 psi/ft)and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 4 Casing OD 9-5/8" 5-1/2" Top(MD) 0 0 Top(TVD) 0 0 Bottom (MD) 3,559 10,882 Bottom (TVD) 3,483 10,353 Length 3,559 10,882 Weight(ppf) 40 17 • Grade L-80 P-110 Connection BTC DWC/C HT Weight w/o Bouyancy Factor(lbs) 142,360 184,994 Tension at Top of Section(lbs) 142,360 184,994 Min strength Tension(1000 lbs) 916 546 Worst Case Safety Factor(Tension) 6.43 2.95 Collapse Pressure at bottom(Psi) 1,515 4,504 Collapse Resistance w/o tension(Psi) 3,090 7,480 Worst Case Safety Factor(Collapse) 2.04 1.66 MASP (psi) 1,758 2,568 Minimum Yield(psi) 5,750 10,640 Worst case safety factor(Burst) 3.27 4.14 Page 47 Version 0 June,2014 B Drillingeaver PCreekrocedure#23 Rev 0 Hilcorp Energy Company 28.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 8-1/2"Hole Section °c°rp Beaver Creek#23 Beaver Creek Unit MD TVD Planned Top: 0 0 Planned TO: 10882 10353 Anticipated Formations and Pressures: Formation ND Est Pressure Oil/Gas/Wet PPG Grad Shallow Gas 3028 1300 WATER/GAS 8.3 0.429 B2 5077 2300 WATER/GAS 8.7 0.453 B4 5254 2300 WATER/GAS 8.4 0.438 UBC3 6095 2850 WATER/GAS 9.0 0.468 B18 7265 3400 GAS 9.0 0.468 B24 7782 3500 GAS 8.6 0.450 B28B 7923 3600 GAS 8.7 0.454 B30 8216 3600 GAS 8.4 0.438 Tyonek 8715 3600 GAS 7.9 0.413 TD 10353 3600 WATER 6.7 0.348 Offset Well Mud Densities Well MW range Top(ND) Bottom(ND) Date Beaver Creek 1B 9.2-9.9ppg 5,200 10,900 2014 BeaverCreekll 8.8-9.6ppg 400 8,684 2003 Beaver Creek 13 8.5-10.4ppg 0 10,182 2003 Beaver Creek 14A 9.0-9.4 ppg 5,000 9,450 2014 BeaverCreek7A 9.0-9.3 2,400 8,929 2014 Assumptions: 1. Fracture gradient at shoe is estimated at 0.65 psi/ft based on field test data. 2. Maximum planned mud density for the 8-1/2"hole section is 9.5 ppg. 3. Calculations assume"Unknown"reservoir contains 100%gas(worst case). 4. Calculations assume worst case event is 100%evacuation of wellbore to gas. Fracture Pressure at 9-5/8"shoe considering a full column of gas from shoe to surface: 3483(ft)x 0.65(psi/ft)= 2264 psi 2264(psi)-[0.1(psi/ft)*3483(ft)]= 1916 psi MASP from pore pressure(unknown gas sand at TD,at 8.4 ppg,encountered while drilling) 10,353(ft)x 0.348(psi/ft)=3603 psi 3603(psi)-[(2/3)*0.1(psi/ft)*10353(ft)]+[(1/3)*0.435(psi/ft)*10353(ft)]= 1412 psi MASP from pore pressure during production mode(Complete evacuation to gas) 10,353(ft)x 0.348(psi/ft)=3603 psi V' 3603(psi)-[0.1(psi/ft)*10,353(ft)]= 2568 psi Summary: 1. MASP while drilling 8-1/2"production hole is governed by pore pressure and evacuation of 2/3 well bore to gas at 0.1 psi/ft. Page 48 Version 0 June,2014 Beaver Drilling PCreekrocedure#23 Rev 0 Hilcorp Energy Company 29.0 Spider Plot (NAD 27) (Governmental Sections) Legend • ecu 23 SHL X BCU 23 TPH 9CU 03RD E H. -+}- BCU 23 BHL • Other Surface Well Locations w Other Bottom Hole Locations ----—--We®Paths r' ' '` '� i cs.i Oil and Gas Unit Boundarye+cu os e- ecu 1a eHfj r BCU 11 BM ' BM, f/' r t 7. 1 � r / t / / / r S007N070W r' !/,r BCU 23 SHL 1P81-1L A028083 - .te. BEAVER CREEK-Wel 12..... -----, 7/ .„0,......„ BCU 23 TPH -^ BCU 04 BF'1L'• * _ re r ,. r1 '`,`� �`"�,e__ BCU 23 BHL f' ecu Da •.- r i \ a1 I i i/ i � / I BIM 13 WIN fa e3 is rd r BM 19 BHL- 1 BCU 09 B141,./ BCU 1 61i BCU 14 BHI f i f / +j f{'f sou 10 i ///� .4, / .......---'-..—'''' ecLunRD 131-e_Bc glut*. T_•V� 111 O 1,000 x,000 Beaver Creek Unit Feet BCU 23 Aaska Slate Pane Z[e7a 4,N0.'1327 I I,I,.wp U ...LH. Map 0d0:11.2112014 Page 49 Version 0 June,2014 Beaver Drilling ProcedureCreek#23 Rev 0 Hilcorp Energy Company 30.0 Surface Plat (As Staked) (NAD 27) 1431 4,12 _ . .,ECTIC 1;`?.F h yiT T V cr.r.LE — . _:_ _+4 — , — . E 315,B39.44 �- I , - SECTION 34 TTN RIM SM,AK " IP z •,.-,,, 1 B•G,U•N0, 3 I9 1', '�,,,,• AS-STAKED •U, 11 DEA'. R'CREEK U NIT �`.,, N:2434039AB� u PAD 3 .� E:317520,56 P • as„x..r LAT:60'39'30,722 N '1 1+<,r. / LONG:.151 O1°U1.709'W 1707�_� / NAD27 ASP Zone 4 FWL 4. r.a / ELEV:160.5' / I, * IP.'"'' ."''Oat V.4e, // NAVEI,B9 " - . I ' `t'u w re / 1702'FAIL � �" 1i42'FNL S i ,:- .,, -,� NOTES 11 BASIS OF GEODETIC CONTROL.AND Ni D,> PCS7T ON?EPOCH 26031 IS AN OPUS SOLUTION FROM WS COORDINATES 8TATICNS'KENI CORS ARE','SLIM Th KEETNA DOHS ARP',AND-1.01'3 POTATO I PUNT 3 ARP'TO ESTADLISH TME POSITION OF I MCI BC1.THE GEODETIC PO5RION OF ECT WAS DETEHNIr.ED TO HAVE A LATITUDE Cf 07•34'30.027FTN AND A LOP.Cil ILL74 OF I51'0222.30311"M 111C ALASKA STATE PLANE ,,NANX1I 11 COORDINATES(ASP),7_Cf 4 ARF [jF A 11 N.2421 33.6'0 ..0 '--"-4'7y,'?.t €.1453083.0(5 i"Ai"t4JIli_ *fi ELEV.131.31'(NAvD68) NORTH ,�s, tf .,.,. 2)OASIS OFVERTICALCONTROLISNOSBMViX' y' PID TT050B LOCATED WITHIN THE KEM41 SPUD e s- LAI A Yd.fxC _ - / � �T 8 HIGHiVAYRICHT<3F1t'AYAF074EPOST 3.7a ', I)T414 _ 4�. HAVING AN ELEVATION OF 1E-0re FEET NANO t,t """� — e8 ACCOROCNC,TO NGS PUBLISHED DATA. ---- 31 COORDINATES COVERTED TO NAD 2T UEIT 3 1 \. CORPSCCNCONVERSION SO%TYr,;RE I BCU 4123 WELL AS-STAKED SURFACE LOCATION (NAD27) BEAVER CHEEK UNIT PAD 3 i ENGINEERING r TESTING LOCATION:SEkTIU .i i, TOW.,!:-.;;-11:'-' NORTH.. ef 4 \ STIP'CYMF4 a MAPPIIIG RANC. °C WEST,SFWA ;r ° F.RIDIA AI AF.,K,A 11ikvlt•I,.ti. L n.LI.t; ''',,,:sP.OP.O BOX 4E8 , 1' S4LDOTNA,AK. 1Fj1;9 JOB NC) 14081 \logeope :OM 20-4218 FAX:i9ATp2SS3.32$5 LF AWN BY' wthgittc IA'V.W.MCLANECO.COt.I Ei>;E1 (SATE:6/2ei1d F1URE=1 Page 50 Version 0 June,2014 Hilcorp Energy Company Beaver Creek Unit Beaver Creek Unit Beaver CK Unit 23 BCU 23 Plan: BCU 23 wp1.0 Standard Proposal Report 17 June, 2014 MIK . ,ter. HALLIBURT©N Sperry Drilling Services HALLIBURTON Projer*• Beaver Creek Unit H�cor � Site: Beaver Creek Unit Sperry Drilling Well: Beaver CK Unit 23 Wellbore: BCU 23 SECTION DETAILS BCU 23 wp9.0 Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target 1 18.70 0.00 0.00 18.70 0.00 0.00 0.00 0.00 0.00 CASING DETAILS 2 2000.00 0.00 0.00 2000.00 0.00 0.00 0.00 0.00 0.00 3 3559.38 31.19 108.83 3483.51 -133.60 391.88 2.00 108.83 413.45 TVD MD Name Size 4 6342.03 31.19 108.83 5864.00 -598.58 1755.77 0.00 0.00 1852.41 3432.39 3500.00 10 3!4" 10-3/4 5 7381.61 0.00 105.80 6853.00 -687.65 2017.02 3.00 180.00 2128.04 10353.60 10882.21 5 1/2" 5-1/2 6 10882.21 0.00 105.80 10353.60 -687.65 2017.02 0.00 0.00 2128.04 BCU 23 BHL tgt 0- WELL DETAILS: Beaver CK Unit 23 Ground Level: 160.50 +N/-5 +E/-W Northing Easting Latittude Longitude Slot 750- 0.00 0.00 2434039.88 317520.56 60.6585338 -151.0171414 Start Dir 2°/100':2000'MD,2000'TVD REFERENCE INFORMATION 1500- Co-ordinate(N/E)Reference: Well Beaver CK Unit 23,True North Vertical(TVD)Reference: Prelim:BCU 23 @ 179.20usft - Measured Depth Reference: Prelim:BCU 23 @ 179.20usft Calculation Method: Minimum Curvature 2250- Hilcorp Energy Company 3000- SHALLOW GAS- Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Closest Approach 3D 10 3/4" Error Surface: Elliptical Conic -_ Warning Method: Error Ratio 3750- End Dir :3559.38'MD,3483.51'TVD 4500- o o B2- _ u7 ----_ 5250- B4 Start Dir 3°/100':6342.03'MD,5864'TVD _ - Ta FORMATION TOP DETAILS o 6000- UBC3- fTVDPath MDPath Formation 3027.50 3050.91 SHALLOW GAS End Dir :7381.61'MD,6853'TVD 5076.50 5421.49 B2 2 - _--- 5253.50 5628.39 B4 6750- _- "- 6094.50 6601.61 UBC3 7264.50 7793.11 B18 7781.50 8310.11 B24 B18 7922.50 8451.11 B28B 7500- 8215.50 8744.11 B30 B24-_ 8714.50 9243.11 Tyonek B28B- ---- 8250- ---- SURVEY PROGRAM B30- Date:2014-06-17T00:00:00 Validated:Yes Version: Tyonek- Depth From Depth To Survey/Plan Tool 9000- 18.70 3500.00 BCU 23 wp1.0(BCU 23) MWD+SC+sag 3500.00 10882.21 BCU 23 wp1.0(BCU 23) MWD+SC+sag 9750- 5 1/2" Total Depth: 10882.21'MD,10353.6'TVD BCU23BHLtgt _---- 10500- BCU 23 wp1.0 11250- 12000- I I I I I I I I I I I l l I I l I I I I I I I l I I I i l I I I l I I I I l I I I I I I I I I I I -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 Vertical Section at 105.80°(1500 U5ft/in) 1 M �C.1[ �M Z NMS b v d y N O °)'n'gn CO v-N 0) tel L. - N a ,Y U U U U Q M N cov 0.fV •�.� O _ M NmNrr O� — > M C--` z0.0 JN R R m CV z p� � _ 0 c Ti) - m m m V FUNN = N Ow - .L; ai •• O CO m U U° W N a -v d d� O mmm= p a vN 00 \\ - N to y E E o co a w oEd� z �0N U Oma \ - O ON -J CD n \ W W U coLO o N 0 H \` ro H N LL a..c ,_ Fn A , 4 I -_ W vl 00 , Q' N C c J J 0%0 • 0 \ I —9 r+N c-4 c,..; O E Wn - \N I U? F-0,- W co ,O --_ to —7 C�'�.a oo i' py - N n^ E v» 5 co r-r • rO U U>m0 00 \ N evv �g w g - O -O n p W o Q\ m 1 0 M + U - g ac co MO m7 U _ c 0 � 0 _ - w Ea71 +oO enb - 7Nt - u cUo a —e x �Uluw c O _ ti ai'ii "" N O g O U O en t�1=0 en F- 26262 �a+ —7 p •o Acoi tCt-' _ -- C CL 0 - O U —.MO . O - V 0 + —0 .. -- 00 3 0 J I OM. - _—co I.1 VOOhFVV - C y 0 0 vl 0 0 0 /Sr U O O COM NCO CO U)N N - O ,-NN M —N 0)0) 8 0 0 N 0 0 0 N CO 01\\ -CO Cr) - LL00000roo UU M \ - + + O O C 0 0 cm OJ000000 0 O p A \ - 000Nooio I2 N - 0) �O O Or NN '�+ \ O 0 or J ,o00Dr o0 ` - a W 0O-Ui r N N ` NI- WO M.r-NN ,O O _ _ 2 r No O ' p• P Zoo 0imrn ( O \ cn - 9 O re CO 1!n 0 d N N N - O-N\Z pOr00008 u- O o -> 0 OOM MM mm \} Oo - co co CI N c.�j LL7 t00 O 00 1 0 (n II- c c N L O O M M O O 03 _ F. ..OO2288 0- 3 3 `� OO.II -.--N co j 0 00 N W a'CD CD No UUUU`� UM Q. ru W M N cD cts «s N W W W 0(\ N ci CD =-OQ CO a)• N ooL. N O a N Q. N .- PI P O O N u 0 00 0 N co S O co ,O I 0 CO ! O — I 3 0' N c • • Dc, a U ,• N n , © M / - +yy W C O N p• a` o —m / - o _ r — O r� —� rl/„ / :- o \ ,. , 6/�/ —- N / . _ - O 1110 „ l / //jet ,- _ - `"" 4 _0 CIE ,--� DI N p. _- O m Lmul - 0 - o _ . > mill LI f I i I I I I i I I I D I I I D I I I D I I I D I I I I I I I I I I I I D I I I D I I I D I I I D I I I D I I I D I I I D I I I I i I Q L o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C) 00 d' O h N‘71- 00 W''''' N b f-.) 7 COcl o00 l� N N q h 00 c';' I U) (uc/8sn OS£)(+)guoN/(-)glnos Halliburton HALLI B U RTA N Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 23 • Company: Hilcorp Energy Company TVD Reference: Prelim:BCU 23 @ 179.20usft • Project: Beaver Creek Unit MD Reference: Prelim:BCU 23 @ 179.20usft Site: Beaver Creek Unit North Reference: True , Well: Beaver CK Unit 23 Survey Calculation Method: Minimum Curvature Wellbore: BCU 23 Design: BCU 23 wp1.0 Project Beaver Creek Unit Map System: US State Plane 1927(Exact solution) . System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Site Beaver Creek Unit Site Position: Northing: 2,430,086.36 usft Latitude: 60.6475877 From: Map Easting: 314,428.19usft Longitude: -151.0340284 Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.90 ° Well Beaver CK Unit 23 Well Position +N/-S 0.00 usft Northing: 2,434,039.88 usft • Latitude: 60.6585338 +E/-W 0.00 usft Easting: 317,520.56 usft . Longitude: -151.0171414 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 160.50 usft • Wellbore BCU 23 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°l (°l (nT) BGGM2013 6/12/2014 16.99 73.64 55,466 Design BCU 23 wp1.0 Audit Notes: Version: Phase: PLAN Tie On Depth: 18.70 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 18.70 0.00 0.00 105.80 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +NI-S +E/-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) 18.70 0.00 0.00 18.70 -160.50 0.00 0.00 0.00 0.00 0.00 0.00 2,000.00 0.00 0.00 2,000.00 1,820.80 0.00 0.00 0.00 0.00 0.00 0.00 3,559.38 31.19 108.83 3,483.51 3,304.31 -133.60 391.88 2.00 2.00 0.00 108.83 6,342.03 31.19 108.83 5,864.00 5,684.80 -598.58 1,755.77 0.00 0.00 0.00 0.00 7,381.61 0.00 105.80 6,853.00 6,673.80 -687.65 2,017.02 3.00 -3.00 0.00 180.00 10,882.21 0.00 105.80 10,353.60 10,174.40 -687.65 2,017.02 0.00 0.00 0.00 0.00 6/17/2014 5:37:54PM Page 2 COMPASS 5000.1 Build 70 Halliburton HALLIBURTO Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 23 Company: Hilcorp Energy Company TVD Reference: Prelim:BCU 23 @ 179.20usft Project: Beaver Creek Unit MD Reference: Prelim:BCU 23 @ 179.20usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 23 Survey Calculation Method: Minimum Curvature Wellbore: BCU 23 Design: BCU 23 wp1.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -160.50 18.70 0.00 0.00 18.70 -160.50 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 100.00 0.00 0.00 100.00 -79.20 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 200.00 0.00 0.00 200.00 20.80 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 300.00 0.00 0.00 300.00 120.80 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 400.00 0.00 0.00 400.00 220.80 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 500.00 0.00 0.00 500.00 320.80 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 600.00 0.00 0.00 600.00 420.80 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 700.00 0.00 0.00 700.00 520.80 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 800.00 0.00 0.00 800.00 620.80 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 900.00 0.00 0.00 900.00 720.80 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 1,000.00 0.00 0.00 1,000.00 820.80 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 1,100.00 0.00 0.00 1,100.00 920.80 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 1,200.00 0.00 0.00 1,200.00 1,020.80 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 1,300.00 0.00 0.00 1,300.00 1,120.80 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 1,400.00 0.00 0.00 1,400.00 1,220.80 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 1,500.00 0.00 0.00 1,500.00 1,320.80 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 1,600.00 0.00 0.00 1,600.00 1,420.80 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 1,700.00 0.00 0.00 1,700.00 1,520.80 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 1,800.00 0.00 0.00 1,800.00 1,620.80 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 1,900.00 0.00 0.00 1,900.00 1,720.80 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 2,000.00 0.00 0.00 2,000.00 1,820.80 0.00 0.00 2,434,039.88 317,520.56 0.00 0.00 Start Dir 2°/100':2000'MD,2000'TVD 2,100.00 2.00 108.83 2,099.98 1,920.78 -0.56 1.65 2,434,039.29 317,522.20 2.00 1.74 2,200.00 4.00 108.83 2,199.84 2,020.64 -2.25 6.61 2,434,037.53 317,527.13 2.00 6.97 2,300.00 6.00 108.83 2,299.45 2,120.25 -5.06 14.85 2,434,034.59 317,535.33 2.00 15.67 2,400.00 8.00 108.83 2,398.70 2,219.50 -9.00 26.39 2,434,030.48 317,546.81 2.00 27.84 2,500.00 10.00 108.83 2,497.47 2,318.27 -14.04 41.19 2,434,025.20 317,561.53 2.00 43.46 2,600.00 12.00 108.83 2,595.62 2,416.42 -20.20 59.25 2,434,018.76 317,579.49 2.00 62.51 2,700.00 14.00 108.83 2,693.06 2,513.86 -27.46 80.54 2,434,011.18 317,600.67 2.00 84.98 2,800.00 16.00 108.83 2,789.64 2,610.44 -35.81 105.04 2,434,002.45 317,625.03 2.00 110.82 2,900.00 18.00 108.83 2,885.27 2,706.07 -45.24 132.71 2,433,992.59 317,652.56 2.00 140.02 3,000.00 20.00 108.83 2,979.82 2,800.62 -55.75 163.53 2,433,981.61 317,683.20 2.00 172.53 3,050.91 21.02 108.83 3,027.50 2,848.30 -61.51 180.41 2,433,975.59 317,700.00 2.00 190.34 SHALLOW GAS 3,100.00 22.00 108.83 3,073.17 2,893.97 -67.31 197.44 2,433,969.52 317,716.94 2.00 208.31 3,200.00 24.00 108.83 3,165.21 2,986.01 -79.92 234.43 2,433,956.34 317,753.72 2.00 247.33 3,300.00 26.00 108.83 3,255.84 3,076.64 -93.56 274.42 2,433,942.09 317,793.50 2.00 289.53 3,400.00 28.00 108.83 3,344.94 3,165.74 -108.21 317.39 2,433,926.78 317,836.24 2.00 334.86 3,500.00 30.00 108.83 3,432.39 3,253.19 -123.85 363.28 2,433,910.42 317,881.88 2.00 383.27 10 3/4" 3,559.38 31.19 108.83 3,483.51 3,304.31 -133.60 391.88 2,433,900.23 317,910.33 2.00 413.45 End Dir :3559.38'MD,3483.51'TVD 3,600.00 31.19 108.83 3,518.26 3,339.06 -140.39 411.79 2,433,893.14 317,930.13 0.00 434.46 3,700.00 31.19 108.83 3,603.80 3,424.60 -157.10 460.81 2,433,875.67 317,978.88 0.00 486.17 3,800.00 31.19 108.83 3,689.35 3,510.15 -173.81 509.82 2,433,858.20 318,027.63 0.00 537.88 6/17/2014 5:37:54PM Page 3 COMPASS 5000.1 Build 70 Halliburton HALLIBURTOf Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 23 Company: Hilcorp Energy Company TVD Reference: Prelim:BCU 23 @ 179.20usft Project: Beaver Creek Unit MD Reference: Prelim:BCU 23 @ 179.20usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 23 Survey Calculation Method: Minimum Curvature Wellbore: BCU 23 Design: BCU 23 wp1.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,595.70 3,900.00 31.19 108.83 3,774.90 3,595.70 -190.52 558.83 2,433,840.74 318,076.38 0.00 589.59 4,000.00 31.19 108.83 3,860.45 3,681.25 -207.23 607.85 2,433,823.27 318,125.13 0.00 641.30 4,100.00 31.19 108.83 3,946.00 3,766.80 -223.94 656.86 2,433,805.80 318,173.88 0.00 693.02 4,200.00 31.19 108.83 4,031.54 3,852.34 -240.65 705.88 2,433,788.34 318,222.63 0.00 744.73 4,300.00 31.19 108.83 4,117.09 3,937.89 -257.36 754.89 2,433,770.87 318,271.38 0.00 796.44 4,400.00 31.19 108.83 4,202.64 4,023.44 -274.07 803.90 2,433,753.40 318,320.13 0.00 848.15 4,500.00 31.19 108.83 4,288.19 4,108.99 -290.78 852.92 2,433,735.94 318,368.88 0.00 899.86 4,600.00 31.19 108.83 4,373.73 4,194.53 -307.49 901.93 2,433,718.47 318,417.63 0.00 951.57 4,700.00 31.19 108.83 4,459.28 4,280.08 -324.20 950.95 2,433,701.00 318,466.37 0.00 1,003.29 4,800.00 31.19 108.83 4,544.83 4,365.63 -340.91 999.96 2,433,683.54 318,515.12 0.00 1,055.00 4,900.00 31.19 108.83 4,630.38 4,451.18 -357.62 1,048.97 2,433,666.07 318,563.87 0.00 1,106.71 5,000.00 31.19 108.83 4,715.92 4,536.72 -374.33 1,097.99 2,433,648.60 318,612.62 0.00 1,158.42 5,100.00 31.19 108.83 4,801.47 4,622.27 -391.04 1,147.00 2,433,631.14 318,661.37 0.00 1,210.13 5,200.00 31.19 108.83 4,887.02 4,707.82 -407.75 1,196.02 2,433,613.67 318,710.12 0.00 1,261.84 5,300.00 31.19 108.83 4,972.57 4,793.37 -424.46 1,245.03 2,433,596.21 318,758.87 0.00 1,313.56 5,400.00 31.19 108.83 5,058.11 4,878.91 -441.17 1,294.04 2,433,578.74 318,807.62 0.00 1,365.27 5,421.49 31.19 108.83 5,076.50 4,897.30 -444.76 1,304.58 2,433,574.98 318,818.10 0.00 1,376.38 B2 5,500.00 31.19 108.83 5,143.66 4,964.46 -457.88 1,343.06 2,433,561.27 318,856.37 0.00 1,416.98 5,600.00 31.19 108.83 5,229.21 5,050.01 -474.59 1,392.07 2,433,543.81 318,905.12 0.00 1,468.69 5,628.39 31.19 108.83 5,253.50 5,074.30 -479.33 1,405.99 2,433,538.85 318,918.96 0.00 1,483.37 B4 5,700.00 31.19 108.83 5,314.76 5,135.56 -491.30 1,441.09 2,433,526.34 318,953.87 0.00 1,520.40 5,800.00 31.19 108.83 5,400.31 5,221.11 -508.01 1,490.10 2,433,508.87 319,002.62 0.00 1,572.12 5,900.00 31.19 108.83 5,485.85 5,306.65 -524.72 1,539.11 2,433,491.41 319,051.37 0.00 1,623.83 6,000.00 31.19 108.83 5,571.40 5,392.20 -541.43 1,588.13 2,433,473.94 319,100.12 0.00 1,675.54 6,100.00 31.19 108.83 5,656.95 5,477.75 -558.14 1,637.14 2,433,456.47 319,148.87 0.00 1,727.25 6,200.00 31.19 108.83 5,742.50 5,563.30 -574.85 1,686.16 2,433,439.01 319,197.62 0.00 1,778.96 6,300.00 31.19 108.83 5,828.04 5,648.84 -591.56 1,735.17 2,433,421.54 319,246.37 0.00 1,830.67 6,342.03 31.19 108.83 5,864,00 5,684.80 -598.58 1,755.77 2,433,414.20 319,266.86 0.00 1,852.41 Start Dir 3°/100':6342.03'MD,5864'TVD 6,400.00 29.45 108.83 5,914.04 5,734.84 -608.02 1,783.47 2,433,404.33 319,294.40 3.00 1,881.63 6,500.00 26.45 108.83 6,002.37 5,823.17 -623.15 1,827.82 2,433,388.52 319,338.52 3.00 1,928.43 6,600.00 23.45 108.83 6,093.02 5,913.82 -636.76 1,867.74 2,433,374.30 319,378.22 3.00 1,970.54 6,601.61 23.40 108.83 6,094.50 5,915.30 -636.96 1,868.35 2,433,374.08 319,378.83 3.00 1,971.18 UBC3 6,700.00 20.45 108.83 6,185.77 6,006.57 -648.81 1,903.12 2,433,361.69 319,413.41 3.00 2,007.86 6,800.00 17.45 108.83 6,280.34 6,101.14 -659.29 1,933.85 2,433,350.74 319,443.97 3.00 2,040.29 6,900.00 14.45 108.83 6,376.48 6,197.28 -668.16 1,959.85 2,433,341.47 319,469.84 3.00 2,067.72 7,000.00 11.45 108.83 6,473.92 6,294.72 -675.39 1,981.06 2,433,333.92 319,490.93 3.00 2,090.09 7,100.00 8.45 108.83 6,572.41 6,393.21 -680.96 1,997.41 2,433,328.09 319,507.19 3.00 2,107.34 7,200.00 5.45 108.83 6,671.66 6,492.46 -684.86 2,008.86 2,433,324.01 319,518.58 3.00 2,119.42 7,300.00 2.45 108.83 6,771.41 6,592.21 -687.09 2,015.37 2,433,321.69 319,525.06 3.00 2,126.30 7,381.61 0.00 0.00 6,853.00 6,673.80 -687.65 2,017.02 2,433,321.10 319,526.70 3.00 2,128.04 End Dir :7381.61'MD,6853'TVD 6/17/2014 5:37:54PM Page 4 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 23 Company: Hilcorp Energy Company TVD Reference: Prelim:BCU 23 @ 179.20usft Project: Beaver Creek Unit MD Reference: Prelim:BCU 23 @ 179.20usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 23 Survey Calculation Method: Minimum Curvature Wellbore: BCU 23 Design: BCU 23 wp1.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 6,673.94 7,381.75 0.00 0.00 6,853.14 6,673.94 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 BCU 23 Mid Tgt 7,400.00 0.00 105.80 6,871.39 6,692.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 7,500.00 0.00 105.80 6,971.39 6,792.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 7,600.00 0.00 105.80 7,071.39 6,892.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 7,700.00 0.00 105.80 7,171.39 6,992.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 7,793.11 0.00 105.80 7,264.50 7,085.30 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 B18 7,800.00 0.00 105.80 7,271.39 7,092.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 7,900.00 0.00 105.80 7,371.39 7,192.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 8,000.00 0.00 105.80 7,471.39 7,292.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 8,100.00 0.00 105.80 7,571.39 7,392.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 8,200.00 0.00 105.80 7,671.39 7,492.19 -687.65 2,017.02 2,433,321,10 319,526.70 0.00 2,128.04 8,300.00 0.00 105.80 7,771.39 7,592.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 8,310.11 0.00 105.80 7,781.50 7,602.30 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 B24 8,400.00 0.00 105.80 7,871.39 7,692.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 8,451.11 0.00 105.80 7,922.50 7,743.30 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 B28B 8,500.00 0.00 105.80 7,971.39 7,792.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 8,600.00 0.00 105.80 8,071.39 7,892.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 8,700.00 0.00 105.80 8,171.39 7,992.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 8,744.11 0.00 105.80 8,215.50 8,036.30 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 B30 8,800.00 0.00 105.80 8,271.39 8,092.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 8,900.00 0.00 105.80 8,371.39 8,192.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 9,000.00 0.00 105.80 8,471.39 8,292.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 9,100.00 0.00 105.80 8,571.39 8,392.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 9,200.00 0.00 105.80 8,671.39 8,492.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 9,243.11 0.00 105.80 8,714.50 8,535.30 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 Tyonek 9,300.00 0.00 105.80 8,771.39 8,592.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 9,400.00 0.00 105.80 8,871.39 8,692.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 9,500.00 0.00 105.80 8,971.39 8,792.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 9,600.00 0.00 105.80 9,071.39 8,892.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 9,700.00 0.00 105.80 9,171.39 8,992.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 9,800.00 0.00 105.80 9,271.39 9,092.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 9,900.00 0.00 105.80 9,371.39 9,192.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 10,000.00 0.00 105.80 9,471.39 9,292.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 10,100.00 0.00 105.80 9,571.39 9,392.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 10,200.00 0.00 105.80 9,671.39 9,492.19 . -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 10,300.00 0.00 105.80 9,771.39 9,592.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 10,400.00 0.00 105.80 9,871.39 9,692.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 10,500.00 0.00 105.80 9,971.39 9,792.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 10,600.00 0.00 105.80 10,071.39 9,892.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 6/17/2014 5:37:54PM Page 5 COMPASS 5000.1 Build 70 Halliburton HALLI B U RTo N Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 23 Company: Hilcorp Energy Company TVD Reference: Prelim:BCU 23 @ 179.20usft Project: Beaver Creek Unit MD Reference: Prelim:BCU 23 @ 179.20usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 23 Survey Calculation Method: Minimum Curvature Wellbore: BCU 23 Design: BCU 23 wp1.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +EI-W Northing Fasting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 9,992.19 10,700.00 0.00 105.80 10,171.39 9,992.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 10,800.00 0.00 105.80 10,271.39 10,092.19 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 10,882.21 , 0.00 105.80 10,353.60 .10,174.40 -687.65 2,017.02 2,433,321.10 319,526.70 0.00 2,128.04 Total Depth:10882.21'MD,10353.6'TVD-5 1/2"-BCU 23 BHL tgt Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) BCU 23 BHL tgt 0.00 0.00 10,353.60 -687.65 2,017.02 2,433,321.10 319,526.70 -plan hits target center -Circle(radius 50.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (') C') 3,500.00 3,432.39 10 3/4" 10-3/4 13-1/2 10,882.21 10,353.60 5 1/2" 5-1/2 8-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (1 (°) 8,744.11 8,215.50 B30 6,601.61 6,094.50 UBC3 8,310.11 7,781.50 B24 9,243.11 8,714.50 Tyonek 3,050.91 3,027.50 SHALLOW GAS 5,628.39 5,253.50 B4 8,451.11 7,922.50 B28B 7,793.11 7,264.50 B18 5,421.49 5,076.50 B2 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 2,000.00 2,000.00 0.00 0.00 Start Dir 2°/100':2000'MD,2000'TVD 3,559.38 3,483.51 -133.60 391.88 End Dir :3559.38'MD,3483.51'TVD 6,342.03 5,864.00 -598.58 1,755.77 Start Dir 3°/100':6342.03'MD,5864'TVD 7,381.61 6,853.00 -687.65 2,017.02 End Dir :7381.61'MD,6853'TVD 10,882.21 10,353.60 -687.65 2,017.02 Total Depth:10882.21'MD,10353.6'TVD 6/17/2014 5:37:54PM Page 6 COMPASS 5000.1 Build 70 ZN co 0 L cc N c E. 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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: g.ea 1 . •, 6,–��i—d?f/ 2 5 PTD: 2-/ (/ Development Service Exploratory _Stratigraphic Test _Non-Conventional FIELD: Cy POOL: . Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 MC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well(name on permit). The permit is approved subject to full compliance with 20 MC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 MC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Lo ,n also required for this well: gB g Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 MC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 To u) a) a- u) o E `o _ a) c a 01 ON U > a) co O c Eli C co a) • L 6 L N w u) a) a .. 7 � n Q E 7 o m E m - O Ti5 p ° Y o F Q m co o 2 C a) n E 0 M -0 `p n n "0 (o N c N CO a) '0 O O CO a) L a a) N 0) @ co O` U C aXi L° o co N 3 -o c6 J a 4 a) a) c N "O (@ '0p W aai co -0 Ci") ° E a) co O .> L co o E co.) c Q. ° 3 o a) N .L.-• p C co _ n _ O a) N >+ co N 'O N Ct 3 0) o 'C a) 47- o �. LL 'O a) N m w L- a a) 0 co C — O @ O a3 Lt O 't +0.' 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To improve the readability of the Well History file and to simplrfy finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Technical Report Title Date Client: Hilcorp Alaska, LLC Field: Beaver Creek Rig: Saxon 169 Date: September 18, 2014 Surface Data Logging End of Well Report Beaver Creek Unit 23 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Formation Tops 6. Show Reports 7. Sample Transmittal 8. Mud Record 9. Bit Record 10. Morning Reports 11. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: Hilcorp Alaska, LLC Rig: Saxon 169 Well: Beaver Creek Unit 23 Field: Beaver Creek Borough: Kenai Peninsula Borough State: Alaska Country: United States API Number: 50-133-20635-00-00 Sperry Job Number: AK-XX-0901491779 Job Start Date: 24 August 2014 Spud Date: 25 August 2014 Total Depth: 11141’ MD, 10852’ TVD North Reference: True Declination: 16.9620° Dip Angle: 73.633° Total Field Strength: 55446 nT Date Of Magnetic Data: 21 July 2014 Wellhead Coordinates N: North 60° 39’ 30.894” Wellhead Coordinates W: West 151° 01’ 1.438“ Drill Floor Elevation 178.50’ Ground Elevation: 160.50’ Permanent Datum: Mean Sea Level SDL Engineers: Jacob Hansen, Craig Amos, Jane Grundin SDL Sample Catchers: Ashley Wilderom, Megan Cardenas Company Geologist: John Serbeck Company Representatives: Rance Pederson, Joe Grubb, James Sweetsir, Jimmy Greco Sperry Mudlogging Unit Number: 117 Monitoring Gas Equipment Summary: Baseline 9000 Gas Analyzer Baseline 8900 Gas Chromatograph Matheson Chrysalis Hydrogen Generator Critical Spare Gas Equipment Summary: Baseline 9000 Gas Analyzer Baseline 8900 Gas Chromatograph Matheson Chrysalis Hydrogen Generator HOLE DATA Dates Drilled Hole Section Total Depth Mud Weight (ppg) Inclination (degrees) Casing Shoe Depth MD TVD MD TVD 8/25 - 8/28 12.25” 3410’ 3369’ 9.1 15.14° 9.625” 3399’ 3359’ 9/2 - 9/14 8.5” 11141’ 10852’ 10.7 1.06° 5.5” 11103’ 10814’ DAILY SUMMARY 08/24/2014 SDL arrived on location and started rigging up heat trace lines, gas trap equipment, and installing air to trap. 08/25/2014 Started rigging up inside equipment while waiting on electrician to rig up power. Power was installed in unit at 12:00 am. Rigging up continued. Started picking up new bottom hole assembly until tagged bottom at 72’ MD. Spud in from 72’ MD to 256’ MD. 08/26/2014 SDL still rigging up INSITE and configuring WITS to Pason. Drilled from 225’ MD to 315’ MD and pulled out of hole. Drilled from 315’ MD to 783’ MD and was circulating to clean hole while waiting on dragon tank to empty. Drilled from 783’ MD to 1,483’ MD and greased crown block, iron roughneck and draw works. Drilled from 1,483’ MD to 1,545’ MD. 8/27/2014 SDL rigged up and services online. Drilled from 1,545’ MD to 1,790’ MD and circulated to clean hole. Performed wiper trip from 1,790’ MD to 300’ MD with no problems. Drilled from 1,790’ MD to 2,660’ MD. Serviced and inspected top drive, draw works, traveling block and crown block. Drilled from 2,660’ MD to 2,675’ MD. Gas: The max formation gas was 160 units seen at 2460’ MD, the max connection gas was 178 units seen at 2350’ MD, and there was no trip gas seen. Fluids: There were 0 barrels of water based mud lost down hole. 8/28/2014 Drilled from 2675’ MD to 3410’ MD TD. Pumped sweep. Flow checked well and pulled out of the hole from 3410’ MD to 1500’ MD. Tripped in the hole from 1500’ MD to 3410’ MD. Circulate two bottoms up for hole cleaning and saw a 200% increase in cuttings at bottoms up. Pumped walnut sweep for hole gauge and estimated 8% washout. Pump slug, pulled out of hole from 3410’ MD to 183’ MD and performed rig service. Gas: The max formation gas was 256 units seen at 3051’ MD, the max connection gas was 243 units seen at 3094’ MD, and there was no significant trip gas seen. Fluids: There were 0 barrels of water based mud lost down hole. 8/29/2014 Ran in 9 5/8” casing to 3399’ MD and cemented. Blew down cement lines and rinsed down diverter stack. Install pack-off tool in well head and lay down equipment and landing joint, nipple down diverter stack. Gas: There was a max trip gas of 62 units seen while cementing. Fluids: There were 0 barrels of water based mud lost down hole. 08/30/2014 Test neck seal at 3000 PSI for 30 minutes test void at 3000 PSI for 30 minutes test pass. Nipple up blowout preventer set stack spacer spool, kill line, choke line, and poor boy line. Make up test joint rig up test pump and chart. Fill and purge BOP and choke lines with water. Test blowout preventer equipment. 08/31/2014 Testing blowout preventer; unable to pull test plug. Nippled down BOP. Nippled up new well head, nippled up BOP. 09/01/2014 Continued nippling up and testing BOP. Picked up bottom hole assembly and ran in the hole with singles. Tag cement at 3,313’ MD. Performed casing test and passed. Displace water with 9.0 ppg water based mud. Circulate in casing. 09/02/2014 Drilled out of shoe and drilled 20 feet of new formation. Performed FIT and passed. Continued to drill ahead to 4,513’ MD. Short tripped to shoe. Performed rig service and tripped back in to bottom. Circulating on bottom. Gas: The max formation gas was 88 units seen at 4006’ MD, There was no significant connection gas seen and no significant trip gas seen. Fluids: There were 17 barrels of water based mud lost down hole. Geology: Sandstone: light grey to green grey, occasionally red brown, transparent to translucent, rarely opaque, fine grained, sub angular, sub elongate to sub spherical, occasionally spherical, moderately sorted, occasionally well sorted, loose, occasional calcareous cement, good visible porosity. Siltstone: predominantly light gray, soft, trace firm grains, good calcareous matrix, swelling, slightly calcareous, trace sand, trace coal, trace tuff. Coal: black to black brown, hard to very hard, brittle, brown streak, vitreous luster 09/03/2014 Drilled from 4,513’ MD to 5,630’ MD. Short tripped from 5,630’ MD to 4,511’ MD. Ran in the hole picking up singles. No tight spots. Circulated bottoms up. Continued to drill ahead to 5,956’ MD. Gas: The max formation gas was 639 units seen at 5342’ MD, the max connection gas was 949 units seen at 5320’ MD, and there was no significant trip gas seen. Fluids: There were 17 barrels of water based mud lost down hole. Geology: Siltstone: light grey to light brown, predominantly firm, rarely moderately hard, blocky, slightly fissile in places, swelling, moderately calcareous, coal stringers, trace sand, trace tuff. Sandstone: light grey to medium grey, occasionally red brown, occasionally dark brown, translucent to opaque, occasionally transparent, fine grained to medium grained, moderately sorted, rarely well sorted, sub rounded to sub elongate, sub spherical, trace coal, trace claystone. 09/04/2014 Continued drilling ahead from 5,956’ MD to 6,117’ MD and encountered 1,742 units of gas with no significant increase in coal. Mud weight increased to 9.2 ppg. Drilled to 6,811’ MD then short tripped to 5,629’ MD, had to pump and back ream from 5,861’ MD to 5,717’ MD before pulling the rest of the way on elevators. Picked up 32 joints of drill pipe and continued to drill ahead. Gas: The max formation gas was 1742 units seen at 6118’ MD, the max connection gas was 806 units seen at 6572’ MD, and there was no significant trip gas seen. Fluids: There were 0 barrels of water based mud lost down hole. Geology: Sandstone: light gray to gray, occasionally dark gray, blue to green, medium green, glassy, sub angular to sub elongate, trace coal, trace shale. Tuff: light gray, white, very soft to soft, glassy. 09/05/2014 Continued drilling ahead from 7,058’ MD to 8,050’ MD. Pumped sweep at 8,050’ MD and circulated bottoms up before short tripping to the shoe to cut and slip drill line. Begin tripping out of the hole. Gas: The max formation gas was 1027 units seen at 7305’ MD, the max connection gas was 444 units seen at 7404’ MD, and there was no significant trip gas seen. Fluids: There were 0 barrels of water based mud lost down hole. Geology: laystone: light gray to gray, soft to moderately hard, amorphous, swelling moderately calcareous. Coal: dark brown to black, firm, blocky. Siltstone: Light gray to gray, amorphous, soft, sub angular. 09/06/2014 Continued to trip up to 3333' MD. Lost 21 Barrels to the well while tripping. Slip and cut drill-line. Run in hole, picked up singles (64 joints). Tripped in the hole, circulated bottoms up, and continued drilling ahead to 8381' MD. Losing about 2 barrels an hour while drilling ahead. Gas: The max formation gas was 911 units seen at 8289’ MD, the max connection gas was 1021 units seen 8376’ MD, and there was no significant trip gas seen. Fluid: There were 59 barrels of water based mud lost down hole. Geology: Claystone: light gray to gray, occasionally light brown, soft to firm, swelling, slightly calcareous, trace coal. Siltstone: light gray to gray, tan to light brown, occasional black streaks, firm, blocky, arenaceous, clay matrix, swelling, slightly to moderately calcareous. 09/07/2014 Continued drilling ahead to 8,998' MD. Short trip to 7,815' MD, tripped back in to bottom and circulated bottoms up. Saw 5176 units of gas and 1-2" pieces of coal at the shakers. Continued to drill ahead. Gas: The max formation gas peak was 1001 units at 8968’ MD, the max connection gas was 604 units seen at 8945’ MD, and the max trip gas was 5176 units trip at 8998’ MD after the short trip. Fluid: There were 96 barrels of water based mud lost down hole. Geology: Siltstone: light brown to brown, occasionally light tan, soft, sub round, slight swelling, slightly to moderately calcareous, trace tuff, trace sandstone. Claystone: light gray to gray, occasionally dark gray, soft to firm, swelling, slightly to moderately calcareous. Coal: dark brown gray to black, firm, blocky to splintery, earthy to waxy luster, anthracitic. 09/08/2014 Continued drilling ahead to 9145' MD where a 12% increase in flow was identified. Picked up off bottom and observed 2476 units of gas. Circulated out remainder of the gas and weighted up to 9.6 ppg. Drilled to 9430' MD nd observed an influx in flow and gas units to 6700 units. Weighted up to 9.9 ppg. Once at 9.9 ppg gas and flow didn't drop out, weighted up to 10.1 ppg and continued to circulate out gas. Continued drilling ahead and weighting up to 10.3 ppg. Gas: The max formation gas was 6926 units seen at 9480’ MD, the max connection gas was 6301 units seen at 9495’ MD, and there was no significant trip gas seen. Fluid: There were 0 barrels of water based mud lost down hole. Geology: Siltstone: light gray to gray, occasionally light tan, soft to firm, slight swelling, slightly calcareous. Sandstone: quartz lithological sandstone, transparent to opaque, very fine grained to fine grained, sub angular to sub elongate, well sorted, visible porosity. Coal: dark gray to black, firm, blocky, brittle, occasionally splintery, vitreous lustre. 09/09/2014 Continued drilling ahead to 10034' MD and short tripped to 8993' MD. Tripped back in, circulated bottoms up and saw a max trip gas of 7778 units with very few large coal pieces. Continued to drill ahead. Gas: The max formation gas was 5457 units seen at 9704’ MD, the max connection gas was 6285 units seen at 9808’ MD, and the max trip gas was 7778 units seen at 10060’ MD. Fluid: There were 0 barrels of water based mud lost down hole. Geology: Sandstone: quartz lithological sandstone, transparent to opaque, very fine to fine grained, sub angular, well sorted, loosely consolidated. Siltstone: light gray to gray, occasionally light tan, soft to firm, slight swelling, trace shale. Coal: dark gray to black, firm to hard, blocky, brittle, occasionally splintery, vitreous luster. 09/10/2014 Continued drilling ahead to 10382’ MD then short tripped for rig service at 10237’ MD for IBOP and tripped back to bottom with no issues. Continued drilling to 10474’ MD and completed another rig service. Continued to drill ahead. Gas: The max formation gas was 3134 units seen at 10368’ MD, the max connection gas was 8389 units seen at 10424’ MD, and there was a max trip gas of 8797 units seen at 10473’ MD. Fluid: There were 0 barrels of water based mud lost down hole. Geology: Sandstone: transparent to opaque, occasionally light brown, rarely tan, loose, yellow, occasionally gray, lithology light gray to gray, very fine to fine grained, sub rounded, sub elongate, poorly sorted, visible porosity. Coal: dark brown to black, firm, brittle, blocky, splintery, vitreous luster. 09/11/2014 Continued drilling ahead to 10445’ MD and short tripped to ~10265’ MD for rig service and tripped back to bottom and circulated up 9876 units of gas with an increase in flow. Continued drilling to 10920’ MD and weighted up to 10.6 ppg before short tripping to 10,000’ MD. Tripped back in and completed a carbide test; it came up 15-20 bbls late. Begin pulling out of the hole. Gas: The max formation gas was 9876 units seen at 10749’ MD, this is a mixture of formation and trip gas after repairing IBOP, the max connection gas was 7380 units seen at 10548’ MD. Fluid: There were 0 barrels of water based mud lost down hole. Geology: Sandstone: gray, predominantly light brown, translucent, loose, fine to medium grained, sub angular, slight visible porosity, no fluorescence, slow blooming milky to light yellow cut, faint white to light yellow ring. Siltstone: light gray, light tan, soft, amorphous, well sorted, consolidated, trace coal. Coal: dark brown to black, firm, brittle, blocky, splintery, vitreous luster. 09/12/2014 Pulled out of hole with no issues from 10920’ MD to 8539’ MD. Encountered swelling clay formations, turned pumps on and back reamed out of the hole to 6380’ MD. Completed tripping out of the hole without issues. Begin laying down MWD tools and preparing to test BOPs. Gas: The max trip gas was 1625 units while pulling out of the hole. Fluid: There were 0 barrels of water based mud lost down hole. 09/13/2014 Completed BOP test, picked up MWD tools and new bit, run in hole to 6000’ MD and circulated. Continued to trip in the hole. Gas: The max trip gas was 2912 units seen while tripping in the hole. Fluid: There were 15 barrels of water based mud lost down hole 09/14/2014 Tripped in hole and pumped sweep at 10953’MD. Drilled ahead to 11141’ MD. Pump motor failed causing TD at 11141’ MD. Pumped sweep, circulated, pulled out of hole 20 stands, pumped slug, and continuing tripping out of the hole. Gas: The max formation gas was 465 units seen at 10986’ MD, there was no significant connection gas seen, and the ma trip gas was 7380 units seen after bottoms up. Fluid: There were 0 barrels of water based mud lost down hole. Geology: 20% Sandstone, 20% Siltstone, 10% Shale, 40% Coal, 10% Tuff Sandstone: translucent to gray, predominately light brown, loose, fine to medium grained, sub angular, visible porosity, no fluorescence, slow blooming milky to light yellow cut, faint white to light yellow ring. Siltstone: medium gray to dark brown gray, firm, occasionally soft, occasionally crumby, laminated, non-calcareous, SHOW: weak, white brown to yellow brown fluorescence, slight yellow white streaming cut, weak yellow residue. Tuff: white, occasionally white blue, soft to firm, occasionally visible lamentation, sandstone matrix. 09/15/2014 Finished tripping out of hole and laid down tools. Begin rigging up for casing. Gas: The max trip gas was 89 units seen while circulating while tripping out of the hole. Fluid: There was 0 barrels of water based mud lost down hole 09/16/2014 Finished rigging up casing, ran in hole to 3301’ MD and circulated bottoms up 8900 units of gas. Circulated out gas, ran in hole to 4883’ MD and circulated bottoms up 9800 units of gas. Circulated out gas, ran in hole 3665’ MD and circulated. Begin weighting up mud to 10.9 ppg. Max Gas: The max trip gas was 9861 units seen while circulating. Fluid: There were 0 barrels of water based mud lost down hole 09/17/2014 Finish running casing and complete cement job. Gas: The max trip gas was 9150 units at 11120’ MD.. Fluid: There were 0 barrels of water based mud lost down hole. 09/18/2014 SDL rigged down unit and gas equipment. SDL released from location. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 0 5 10 15 20 25 30 Me a s u r e d D e p t h Rig Days WELL NAME: Beaver Creek Unit 23 OPERATOR: Hilcorp Alaska, LLC MUD CO: Baroid RIG: Saxon 169 SPERRY JOB: AK-XX-0901491779 Days vs. Depth 24 August 2014 Sperry SDL arrived on Location LOCATION: Beaver Creek AREA: Kenai Peninsula Borough STATE: Alaska SPUD: 25-Aug-2014 TD: 14-Sep-2014 Drill 8.5" hole to 10,380' MD STP to 10,237' MD to fix IBOP 10 Sep 2014 Commenced 12.25" Surface Hole Section On Bot: 02:30 25 Aug 2014 Sperry SDL Services online 27 Aug 2014 TD Surface Hole Section 3410' MD, 3369' TVD Off Bot: 15:05 28 Aug 2014 Landed 9.625" Casing 3399' MD, 3359' TVD 09 Aug 2014 Commenced 8.50" Production Hole Section On Bot: 04:10 02 Sep 2014 Drill 8.5" hole to 5630' MD STP to 4511' MD to clean hole 3 Sep 2014 Drill 8.5" hole to 6811' MD STP to 5,629' MD to clean hole 4 Sep 2014 Drill 8.5" hole to 8050' MD STP to CSG Shoe 5 Sep 2014 Drill 8.5" hole to 8998' MD STP to 7,815' MD to clean hole 7 Sep 2014 Drill 8.5" hole to 10,034' MD STP to 8,993' MD to clean hole 9 Sep 2014 POOH to change bit 10920' MD, 10631' TVD Off Bot: 15:45 11 Sep 2014 TD Production Section 11141' MD, 10852' TVD Off Bot: 19:00 14 Sep 2014 WELL NAME:LOCATION: OPERATOR:AREA:Kenai Peninsula Borough SPERRY JOB:STATE: RIG:Saxon 169 HOLE SECTION:Surface Run 100 EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Craig Amos 23-Sep-2014 What went as, or better than, planned: The gas system, monitored throughout the section without issues and the pason to ADI system allowed acurate monitoring of the fluids. Difficulties experienced: The pason system crashed repeatedy during the first days of drilling, taking time to reboot. The problem was addressed and resolved. Recommendations: Using standard Wits sending rather than Pason specific sending gives a better connection and transfer rate. Innovations and/or cost savings: N/A AK-XX-0901491779 Alaska Beaver Creek Unit 23 Beaver Creek Hilcorp Alaska, LLC Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA:Kenai Peninsula Borough SPERRY JOB:STATE: RIG:Saxon 169 HOLE SECTION:Production Run 200 EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Craig Amos 23-Sep-2014 What went as, or better than, planned: Sampling rate was tolerable, the unit was mechanically sound and we had minimal issues with computers. Difficulties experienced: Internet and communications with rig were poor, many days of missed reports because of a lack of internet and phones. The 8900 gas chromo stopped working and needed to be replaced, fortunately this was during a top drive repair break so only 5' of gas data was missed. Recommendations: Making sure back up gas equipment is onsite prevents down time due to malfunctioning equipment. Getting MWD to data exchange FE data would stream line the lith interp to real time and prevent delays in recognizing changes. Innovations and/or cost savings: N/A AK-XX-0901491779 Alaska Beaver Creek Unit 23 Beaver Creek Hilcorp Alaska, LLC Surface Data Logging After Action Review WELL NAME:Beaver Creek Unit 23 LOCATION:Beaver Creek OPERATOR:Hilcorp Alaska, LLC AREA:Kenai Peninsula Borough MUD CO:Baroid STATE:Alaska RIG:Saxon 169 SPUD:25-Aug-2014 SPERRY JOB:AK-XX-0901491779 TD:14-Sep-2014 Marker MD INC AZ TVD TVDSS Top Permafrost 100.0 100.0 100.0 100.0 100.0 SHALLOW_GAS1 3,047.0 16.0 115.0 3,020.0 -2,841.0 STERLING_B 4,934.3 15.5 114.2 4,843.0 -4,664.0 BC_B1ST 4,978.0 15.2 113.5 4,877.0 -4,698.0 BC_B2ST 5,087.0 15.1 112.9 4,982.0 -4,803.0 BC_B2SB 5,154.2 15.1 112.7 5,046.0 -4,867.0 BC_B3ST 5,218.0 15.0 112.2 5,108.0 -4,929.0 BC_B3SB 5,247.0 14.9 112.4 5,136.0 -4,957.0 BC_B3-L_ST 5,265.0 14.9 112.4 5,154.0 -4,975.0 BC_B3-L_SB 5,299.4 14.9 112.4 5,186.0 -5,007.0 BC_B4ST 5,366.0 14.9 111.8 5,251.0 -5,072.0 BC_B4SB 5,417.0 14.7 111.7 5,301.0 -5,122.0 BELUGA 5,969.8 16.3 111.6 5,833.0 -5,654.0 U_BELUGA 6,008.6 16.1 110.5 5,870.0 -5,691.0 UBC3 6,221.3 16.0 109.1 6,074.0 -5,895.0 M_BELUGA 6,553.8 16.2 111.7 6,394.0 -6,215.0 BC_B15ST 7,003.5 16.5 116.0 6,827.0 -6,648.0 SR_LBGT 7,367.2 15.2 114.6 7,176.0 -6,997.0 BC_B18UST 7,437.9 15.1 114.0 7,245.0 -7,066.0 BC_B19ST 7,533.7 15.0 113.5 7,337.0 -7,158.0 LWR_BELUGA 7,679.1 14.7 113.1 7,477.0 -7,298.0 BC_B22ST 7,816.0 15.4 15.9 7,610.0 -7,431.0 BC_B23ST 7,868.4 15.7 115.7 7,660.0 -7,481.0 BC_B24ST 7,984.6 15.3 115.4 7,773.0 -7,594.0 BC_B26ST 8,040.2 15.3 115.5 7,826.0 -7,647.0 BC_B28ST 8,140.7 15.0 115.0 7,923.0 -7,744.0 BC_B28SB 8,305.9 16.1 114.7 8,082.0 -7,903.0 BC_B30ST 8,439.0 15.8 114.1 8,210.0 -8,031.0 BC_B30SB 8,481.4 15.8 114.1 8,251.0 -8,072.0 BC_B31ST 8,532.0 15.7 114.3 8,300.0 -8,121.0 BC_B31SB 8,570.2 16.2 112.1 8,336.0 -8,157.0 BC_B31_B_ST 8,606.2 16.2 112.1 8,371.0 -8,192.0 BC_LB_M-50 8,640.5 16.3 111.9 8,404.0 -8,225.0 BC_B31_C_ST 8,656.2 16.3 111.9 8,419.0 -8,240.0 BC_B32SB 8,783.0 15.7 111.9 8,541.0 -8,362.0 SR_TYONEK 8,949.0 14.5 111.3 8,701.0 -8,522.0 BC_T1ST 9,020.7 15.2 109.8 8,771.0 -8,592.0 BC_T1SB 9,054.2 16.3 109.7 8,802.0 -8,623.0 BC_T-O_5CT 9,061.1 16.3 109.7 8,809.0 -8,630.0 BC_T-O_75CT 9,097.4 16.3 109.7 8,844.0 -8,665.0 SR_TYNK_T1CT 9,215.6 16.2 109.8 8,958.0 -8,779.0 BC_T-1_15CT 9,332.3 15.7 108.8 9,069.0 -8,890.0 BC_T-1_25CT 9,434.5 15.3 108.8 9,168.0 -8,989.0 BC_T2ST 9,511.4 15.1 108.9 9,242.0 -9,063.0 BC_T2SB 9,543.7 15.0 107.9 9,274.0 -9,095.0 SR_TYNK_CT5 9,837.4 14.6 107.0 9,557.0 -9,378.0 SR_D1CT 10,059.8 11.9 112.5 9,775.0 -9,596.0 BC_T10ST 10,126.9 9.7 114.5 9,840.0 -9,661.0 BC_T10SB 10,147.1 9.7 114.5 9,860.0 -9,681.0 BC_T12ST 10,367.7 4.6 119.1 10,080.0 -9,901.0 BC_T12SB 10,387.5 4.6 119.1 10,100.0 -9,921.0 MID_TYONEK_T3 10,403.7 4.6 119.1 10,116.0 -9,937.0 BC_T17ST 10,478.2 4.2 119.3 10,189.0 -10,010.0 BC_T17SB 10,509.5 3.1 120.1 10,220.0 -10,041.0 Formation Tops WELL NAME:Beaver Creek Unit 23 LOCATION:Beaver Creek OPERATOR:Hilcorp Alaska, LLC AREA:Kenai Peninsula Borough MUD CO:Baroid STATE:Alaska RIG:Saxon 169 SPUD:25-Aug-2014 SPERRY JOB:AK-XX-0901491779 TD:14-Sep-2014 Marker MD INC AZ TVD TVDSS TK_TYONEK_T3 10,526.2 3.1 120.1 10,237.0 -10,058.0 BC_T18ST 10,568.8 3.1 121.6 10,280.0 -10,101.0 BC_T18SB 10,585.5 3.1 121.6 10,296.0 -10,117.0 BC_T19ST 10,684.4 2.8 117.7 10,395.0 -10,216.0 BC_T19SB 10,754.1 2.8 120.1 10,465.0 -10,286.0 BC_T20ST 10,847.8 2.7 116.0 10,559.0 -10,380.0 BC_T20SB 10,910.3 2.4 120.8 10,621.0 -10,442.0 U_E__TNK 10,953.5 1.5 131.7 10,665.0 -10,486.0 Formation Tops Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Show Report Report # 1 Beaver Creek Unit 23 5218 5247 Beaver Creek 5108 5136 Hilcorp Alaska, LLC C.Amos BC_B3ST J.Serbeck 9/15/2014 Interpretation: Very weak, very occasional yellow flouresence no cut. Cuttings Analysis: Odor None Fluorescence Cut Fluorescence Residual Cut Color None Intensity dul Color none Residual Flourescence Amount None Distribution Spot Intensity none Color Stain Amount v wk Type none Amount Oil Show Rating Free Oil in Mud Color none Color Cut Color pl yel Intensity 45112 33367 11745 1958 1 Hydrocarbon Ratios 5218 Gas Units 328 Mud Chlorides (mg/L) =30000 0 0 0 #DIV/0! 36 30 6 #DIV/0! 0 0 0 #DIV/0! 0 0 0 2 5221 Gas Units 384 Mud Chlorides (mg/L) =30000 49508 33367 16141 2018 38 30 8 #DIV/0! Hydrocarbon Ratios 0 0 0 #DIV/0! 0 0 0 #DIV/0! 30000 62933 33367 29566 1556 0 0 0 3 49 30 19 #DIV/0! 0 0 0 #DIV/0! 5227 Gas Units 427 Mud Chlorides (mg/L) = 4 5235 Gas Units 363 Mud Chlorides (mg/L) = 0 0 0 #DIV/0! 0 0 0 30000 50679 33367 17312 1574 41 30 11 #DIV/0! 0 0 0 0.00 0 0 0 #DIV/0! 0 0 0 #DIV/0! Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Show Report Report # 2 Beaver Creek Unit 23 5265 5299 Beaver Creek 5154 5186 Hilcorp Alaska, LLC BC_B3-L_ST 9/15/2014 Interpretation: No Show Cuttings Analysis: Odor Fluorescence Cut Fluorescence Residual Cut Color Intensity Color Residual Flourescence Amount Distribution Intensity Color Stain Amount Type Amount Oil Show Rating Free Oil in Mud Color Color Cut Color Intensity 69904 31982 37922 1308 1 Hydrocarbon Ratios 5272 Gas Units 466 Mud Chlorides (mg/L) =30000 0 0 0 #DIV/0! 55 26 29 #DIV/0! 0 0 0 #DIV/0! 0 0 0 2 5278 Gas Units 457 Mud Chlorides (mg/L) =30000 60651 31982 28669 1303 48 26 22 #DIV/0! Hydrocarbon Ratios 0 0 0 #DIV/0! 0 0 0 #DIV/0! 30000 41923 31982 9941 1420 0 0 0 3 33 26 7 #DIV/0! 0 0 0 #DIV/0! 5292 Gas Units 283 Mud Chlorides (mg/L) = 4 5295 Gas Units 270 Mud Chlorides (mg/L) = 0 0 0 #DIV/0! 0 0 0 30000 38552 31982 6570 2190 29 26 3 #DIV/0! 0 0 0 0.00 0 0 0 #DIV/0! 0 0 0 #DIV/0! Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH C.Amos J.Serbeck Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Show Report Report # 3 Beaver Creek Unit 23 5366 5417 Beaver Creek 5251 5301 Hilcorp Alaska, LLC BC_B4ST 9/15/2014 Interpretation: No Show Cuttings Analysis: Odor Fluorescence Cut Fluorescence Residual Cut Color Intensity Color Residual Flourescence Amount Distribution Intensity Color Stain Amount Type Amount Oil Show Rating Free Oil in Mud Color Color Cut Color Intensity 70097 18336 51761 1522 1 Hydrocarbon Ratios 5378 Gas Units 469 Mud Chlorides (mg/L) =30000 0 0 0 #DIV/0! 49 15 34 #DIV/0! 0 0 0 #DIV/0! 0 0 0 2 5382 Gas Units 462 Mud Chlorides (mg/L) =30000 65506 18336 47170 1348 50 15 35 #DIV/0! Hydrocarbon Ratios 0 0 0 #DIV/0! 0 0 0 #DIV/0! 30000 37676 18336 19340 1758 0 0 0 3 26 15 11 #DIV/0! 0 0 0 #DIV/0! 5411 Gas Units 233 Mud Chlorides (mg/L) = 4 5415 Gas Units 281 Mud Chlorides (mg/L) = 0 0 0 #DIV/0! 0 0 0 30000 41429 18336 23093 1776 28 15 13 #DIV/0! 0 0 0 0.00 0 0 0 #DIV/0! 0 0 0 #DIV/0! Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH C.Amos J.Serbeck Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 C1/C2 = C2 C1/C3 = C3 C1/C4 = C4 C1/C5 = C5 Production Analysis Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 C1/C2 = C2 C1/C3 = C3 C1/C4 = C4 C1/C5 = C5 Production Analysis Gas Oil Water Non-Producible Hydrocarbons 0.00 4 Gas Units Mud Chlorides (mg/L) = Gas Units Mud Chlorides (mg/L) = 0 0 0 3 Hydrocarbon Ratios 0 0 0 #DIV/0! 0 0 0 #DIV/0! 30000 121335 13969 107366 1206 99 10 89 #DIV/0! 0 0 0 2 6238 Gas Units 651 Mud Chlorides (mg/L) = 0 0 0 #DIV/0! 64 10 54 #DIV/0! 0 0 0 #DIV/0! 80415 13969 66446 1230 1 Hydrocarbon Ratios 6224 Gas Units 1027 Mud Chlorides (mg/L) =30000 Oil Show Rating Free Oil in Mud Color Color Cut Color Intensity Color Intensity Color Residual Flourescence Amount Distribution Intensity Color Stain Amount Type Amount Cuttings Analysis: Odor Fluorescence Cut Fluorescence Residual Cut C.Amos UBC3 J.Serbeck 9/15/2014 Interpretation: No Show Show Report Report # 4 Beaver Creek Unit 23 6221 6244 Beaver Creek 6074 6096 Hilcorp Alaska, LLC Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 C2 C3 C4 C5 Production Analysis . C1 C2 C3 C4 C5 Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Show Report Report # 5 Beaver Creek Unit 23 7534 7593 Beaver Creek 7337 7394 Hilcorp Alaska, LLC BC_B19ST 9/15/2014 Interpretation: No Show Cuttings Analysis: Odor Fluorescence Cut Fluorescence Residual Cut Color Intensity Color Residual Flourescence Amount Distribution Intensity Color Stain Amount Type Amount Oil Show Rating Free Oil in Mud Color Color Cut Color Intensity 45690 18219 27471 1962 1 Hydrocarbon Ratios 7547 Gas Units 393 Mud Chlorides (mg/L) =30000 4 0 4 #DIV/0! 26 12 14 4579 11 5 6 6868 0 0 0 2 7584 Gas Units 251 Mud Chlorides (mg/L) =30000 29723 18219 11504 2876 16 12 4 5752 Hydrocarbon Ratios 7 5 2 #DIV/0! 0 0 0 #DIV/0! 0 0 0 3 Gas Units Mud Chlorides (mg/L) = 4 0.00 Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 NPH Oil Gas NPH C.Amos J.Serbeck Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 C2 C3 C4 C5 Production Analysis . C1 C2 C3 C4 C5 Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Show Report Report # 6 Beaver Creek Unit 23 7816 7870 Beaver Creek 7610 7662 Hilcorp Alaska, LLC BC_B22ST 9/15/2014 Interpretation: No Show Cuttings Analysis: Odor Fluorescence Cut Fluorescence Residual Cut Color Intensity Color Residual Flourescence Amount Distribution Intensity Color Stain Amount Type Amount Oil Show Rating Free Oil in Mud Color Color Cut Color Intensity 29408 5739 23669 1691 1 Hydrocarbon Ratios 7833 Gas Units 248 Mud Chlorides (mg/L) =30000 0 0 0 #DIV/0! 14 0 14 3381 7 0 7 #DIV/0! 0 0 0 2 7842 Gas Units 282 Mud Chlorides (mg/L) =30000 33216 5739 27477 1446 19 0 19 3435 Hydrocarbon Ratios 8 0 8 9159 3 0 3 #DIV/0! 0 0 0 3 Gas Units Mud Chlorides (mg/L) = 4 0.00 Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 NPH Oil Gas NPH C.Amos J.Serbeck Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Show Report Report # 7 Beaver Creek Unit 23 8439 8481 Beaver Creek 8210 8251 Hilcorp Alaska, LLC C.Amos BC_B30ST J.Serbeck 9/15/2014 Interpretation: No Show. Cuttings Analysis: Odor Fluorescence Cut Fluorescence Residual Cut Color Intensity Color Residual Flourescence Amount Distribution Intensity Color Stain Amount Type Amount Oil Show Rating Free Oil in Mud Color Color Cut Color Intensity 20425 7902 12523 1252 1 Hydrocarbon Ratios 8452 Gas Units 153 Mud Chlorides (mg/L) =30000 0 0 0 #DIV/0! 10 0 10 2505 5 0 5 #DIV/0! 0 0 0 2 8459 Gas Units 138 Mud Chlorides (mg/L) =30000 18650 7902 10748 1194 9 0 9 2150 Hydrocarbon Ratios 5 0 5 #DIV/0! 0 0 0 #DIV/0! 30000 7902 5281 2621 #DIV/0! 0 0 0 3 0 0 0 #DIV/0! 0 0 0 #DIV/0! 8479 Gas Units 80 Mud Chlorides (mg/L) = 4 8480 Gas Units 87 Mud Chlorides (mg/L) = 0 0 0 #DIV/0! 0 0 0 30000 12300 7902 4398 733 6 0 6 1466 0 0 0 0.00 3 0 3 #DIV/0! 0 0 0 #DIV/0! Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons C1 C1 C1 C1 C2 C3 C4 C5 C1 C2 C3 C4 C5 Production Analysis C1 C2 C3 C4 C5 Production Analysis Show Report Report # 8 Beaver Creek Unit 23 9021 9054 Beaver Creek 8771 8802 Hilcorp Alaska, LLC C.Amos BC_T1ST J.Serbeck 9/15/2014 Interpretation: No odor, no stain, very spotty surface luminous yellow flourescence, lum yellow slow to milky white, very fast streaming white - luminous yellow cut, no residual cut, moderatly strong luminous yellow flourescene. Cuttings Analysis: Odor None Fluorescence Cut Fluorescence Residual Cut None Color None Intensity Bright Color Lum Yel -Residual Flourescence None Amount None Distribution Spotty Intensity Fast Stream Color Stain Amount Light Type Lum Yel Amount Lum Yel Oil Show Rating Free Oil in Mud Mod Strng Color Color Cut Color Lum Yel mlky wh Intensity 14395 10228 4167 2084 1 Hydrocarbon Ratios 9041 Gas Units 60 Mud Chlorides (mg/L) =30000 0 0 0 #DIV/0! 7 5 2 4167 4 3 1 #DIV/0! 0 0 0 2 9029 Gas Units 216 Mud Chlorides (mg/L) =30000 21044 10228 10816 1803 11 5 6 2704 Hydrocarbon Ratios 7 3 4 #DIV/0! 0 0 0 #DIV/0! 0 0 0 3 4 Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: None Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Show Report Report # 9 Beaver Creek Unit 23 10127 10147 Beaver Creek 9840 9860 Hilcorp Alaska, LLC C.Amos BC_T10ST J.Serbeck 9/15/2014 Interpretation: Sample had some strong yellow flourescence and a slow weak blooming cut with weak light brown residual cut and no residual fluorescence. Cuttings Analysis: Odor None Fluorescence Cut Fluorescence Residual Cut Lt Brn Color None Intensity Strong Color White Residual Flourescence Weak Amount None Distribution Weak Intensity Blmmg Color Stain Amount Weak Type Weak Amount None Oil Show Rating Free Oil in Mud None Color None Color Cut Color Lum Yel Intensity 91218 85029 6189 774 1 Hydrocarbon Ratios 10132 Gas Units 706 Mud Chlorides (mg/L) =30000 8 7 1 #DIV/0! 79 71 8 3095 41 39 2 6189 0 0 0 2 10133 Gas Units 717 Mud Chlorides (mg/L) =30000 85933 85029 904 301 74 71 3 #DIV/0! Hydrocarbon Ratios 39 39 0 -904 6 7 -1 #DIV/0! 30000 210360 85029 125331 1150 0 0 0 3 180 71 109 2199 96 39 57 8952 10143 Gas Units 2071 Mud Chlorides (mg/L) = 4 10147 Gas Units 1674 Mud Chlorides (mg/L) = 21 7 14 #DIV/0! 0 0 0 30000 184616 85029 99587 1229 152 71 81 2316 0 0 0 0.00 82 39 43 8299 19 7 12 #DIV/0! Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: No Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 C2 C3 C4 C5 Production Analysis C1 C2 C3 C4 C5 Production Analysis Show Report Report # 10 Beaver Creek Unit 23 10368 10388 Beaver Creek 10080 10100 Hilcorp Alaska, LLC J.Grundin BC_T12ST Cuttings Analysis: Amount None Distribution None Intensity None Color None Color None J.Serbeck 9/15/2014 Interpretation: No Show. Odor None Fluorescence Cut Fluorescence Residual Cut Stain Amount None Type None Amount Intensity None Color None Residual Flourescence None None Oil Show Rating Free Oil in Mud None Color None Color Cut Color None Intensity 10545 9636 909 909 1 Hydrocarbon Ratios 10374 Gas Units 138 Mud Chlorides (mg/L) =31000 0 0 0 #DIV/0! 10 9 1 -182 0 5 -5 #DIV/0! 0 0 0 2 10377 Gas Units 134 Mud Chlorides (mg/L) =31000 10029 9636 393 #DIV/0! 9 9 0 -393 Hydrocarbon Ratios 4 5 -1 #DIV/0! 0 0 0 #DIV/0! 0 0 0 3 Gas Units Mud Chlorides (mg/L) = 4 Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Show Report Report # 11 Beaver Creek Unit 23 10478 10509 Beaver Creek 10189 10220 Hilcorp Alaska, LLC C.Amos BC_17ST J.Serbeck 9/15/2014 Interpretation: Very spotty bright yellow flourescence, slow milky white streaming cut, weak yellow brown residual ring. Cuttings Analysis: Odor None Fluorescence Cut Fluorescence Residual Cut strw yel Color None Intensity bright Color mlky wh Residual Flourescence weak Amount None Distribution poor Intensity weak Color Stain Amount Weak Type streaming Amount yel brn Oil Show Rating Free Oil in Mud weak Color Color Cut Color lum yel Intensity 83693 21717 61976 795 1 Hydrocarbon Ratios 10472 Gas Units 856 Mud Chlorides (mg/L) =30000 14 3 11 30988 106 28 78 1377 61 16 45 5634 2 0 2 2 10480 Gas Units 374 Mud Chlorides (mg/L) =30000 43838 21717 22121 1475 43 28 15 4424 Hydrocarbon Ratios 21 16 5 22121 4 3 1 #DIV/0! 30000 34033 21717 12316 2053 0 0 0 3 34 28 6 12316 17 16 1 12316 10482 Gas Units 343 Mud Chlorides (mg/L) = 4 4 3 1 #DIV/0! 0 0 0 Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: No Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 0.00 4 Gas Units Mud Chlorides (mg/L) = 55 0 55 383 28 0 28 447 25 422 64 180 13 167 195 Adjusted Gas Units 2132 Mud Chlorides (mg/L) =31000 36793 26076 10717 25 15 0 15 3 Hydrocarbon Ratios 232 50 182 8827 52 13 39 22949 31000 413995 69757 344238 1199 382 95 287 1891 25 0 25 2 10753 Gas Units 7743 Mud Chlorides (mg/L) = 83 13 70 15241 829 95 734 1488 306 50 256 5443 450788 69757 381031 519 1 Hydrocarbon Ratios 10748 Gas Units 9875 Mud Chlorides (mg/L) =31000 yelsh brn Oil Show Rating Free Oil in Mud dul Color weak Color Cut Color yel/orng Intensity pl straw/bn Color none Intensity dul Color milky wh Residual Flourescence none-fnt Amount none Distribution min Intensity weak Color Stain Amount occ Type weak/none Amount Cuttings Analysis: Odor none Fluorescence Cut Fluorescence Residual Cut J.Serbeck 9/15/2014 Interpretation: This interval displays, no odor, with no visible stain, the flourescence was occasional and was not displayed on fresh surfaces only on outer dry surface. The cut was weak to none, slow ,milky white to pale yellow, slow streaming. None to faint residual cut, with a pale to light brown colour, with a dull yellowish brown risidual flouresce. Flourescence doesn't seem to appear on freshly crushed samples only on oputside of dried samples. Show Report Report # 12 Beaver Creek Unit 23 10684 10754 Beaver Creek 10395 10465 Hilcorp Alaska, LLC C.Amos BC_T19ST Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: No Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Show Report Report # 13 Beaver Creek Unit 23 10848 10910 Beaver Creek 10559 10621 Hilcorp Alaska, LLC J.Grundin BC_T20ST J.Serbeck 9/15/2014 Interpretation: No show. Cuttings Analysis: Odor None Fluorescence Cut Fluorescence Residual Cut None Color None Intensity None Color None Residual Flourescence None Amount None Distribution None Intensity None Color Stain Amount None Type None Amount None Oil Show Rating Free Oil in Mud None Color None Color Cut Color None Intensity 8285 8198 87 22 1 Hydrocarbon Ratios 10858 Gas Units 68 Mud Chlorides (mg/L) =31000 0 0 0 #DIV/0! 15 11 4 44 7 5 2 #DIV/0! 0 0 0 2 10865 Gas Units 91 Mud Chlorides (mg/L) =31000 11564 8198 3366 1683 13 11 2 1683 Hydrocarbon Ratios 7 5 2 #DIV/0! 0 0 0 #DIV/0! 30000 11929 8198 3731 746 0 0 0 3 16 11 5 1244 8 5 3 #DIV/0! 10884 Gas Units 91 Mud Chlorides (mg/L) = 4 10895 Gas Units 75 Mud Chlorides (mg/L) = 0 0 0 #DIV/0! 0 0 0 30000 9991 8198 1793 359 16 11 5 897 0 0 0 0.00 7 5 2 #DIV/0! 0 0 0 #DIV/0! Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH WELL NAME:Beaver Creek Unit 23 LOCATION:Beaver Creek OPERATOR:Hilcorp Alaska, LLC AREA:Kenai Peninsula Borough MUD CO:Baroid STATE:Alaska RIG:Saxon 169 SPUD:25-Aug-2014 SPERRY JOB:AK-XX-0901491779 TD:14-Sep-2014 API:50-133-20635-00-00 AFE:1412150D BOX/SAMPLE (DRY)TOP DEPTH BOTTOM DEPTH SAMPLE COUNT WELL Box 1 of 9 3440 4420 49 BCU 23 Box 2 of 9 4440 5480 52 BCU 23 Box 3 of 9 5500 6360 43 BCU 23 Box 4 of 9 6380 7240 43 BCU 23 Box 5 of 9 7260 8260 50 BCU 23 Box 6 of 9 8280 9140 43 BCU 23 Box 7 of 9 9160 10000 42 BCU 23 Box 8 of 9 10020 10920 45 BCU 23 Box 9 of 9 10940 11140 10 BCU 23 BOX/SAMPLE (DRY)TOP DEPTH BOTTOM DEPTH SAMPLE COUNT WELL Box 1 of 9 3440 4420 49 BCU 23 Box 2 of 9 4440 5480 52 BCU 23 Box 3 of 9 5500 6360 43 BCU 23 Box 4 of 9 6380 7240 43 BCU 23 Box 5 of 9 7260 8260 50 BCU 23 Box 6 of 9 8280 9140 43 BCU 23 Box 7 of 9 9160 10000 42 BCU 23 Box 8 of 9 10020 10920 45 BCU 23 Box 9 of 9 10940 11140 10 BCU 23 BOX/SAMPLE (DRY)TOP DEPTH BOTTOM DEPTH SAMPLE COUNT WELL Box 1 of 9 3440 4420 49 BCU 23 Box 2 of 9 4440 5480 52 BCU 23 Box 3 of 9 5500 6360 43 BCU 23 Box 4 of 9 6380 7240 43 BCU 23 Box 5 of 9 7260 8260 50 BCU 23 Box 6 of 9 8280 9140 43 BCU 23 Box 7 of 9 9160 10000 42 BCU 23 Box 8 of 9 10020 10920 45 BCU 23 Box 9 of 9 10940 11140 10 BCU 23 Sample Transmittal SAMPLE TRANSMITTAL DETAILS - Set 3 COMMENTS SAMPLE TRANSMITTAL DETAILS - Set 1 COMMENTS SAMPLE TRANSMITTAL DETAILS - Set 2 COMMENTS Beaver Creek Unit 23 Hilcorp Alaska, LLC Baroid Saxon 169 AK-XX-0901491779 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 25-Aug 76 8.80 228 31 51 48/77/92 9.9 113.0/82.0/69.0/54.0 2/0 3.4 0.0/96.3 0.20 10.2 28.0 0.10/0.50 600 40 P/U BHA 26-Aug 920 8.80 220 31 52 42/63/68 9.7 114.0/83.0/70.0/55.0 2/0 3.6 0.00/96.2 0.40 0.15 9.0 15.0 0.01/0.50 400 20 Drilling 27-Aug 2411 9.10 143 28 44 19/52/54 8.1 100.0/72.0/60.0/45.0 2/0 5.6 0.0/94.2 0.50 0.10 9.6 17.5 0.02/0.35 350 20 Drill 12-1/4" Surface Section 28-Aug 3410 9.20 89 28 35 13/42/52 7.6 91/63/51/35/12/10 2/0 6.3 0.0/93.5 0.25 0.10 9.1 15.0 0.02/0.35 400 20 TOOH to run 9-5/8" Casing 29-Aug 3410 9.30 50 23 13 5/7/10 8.1 59/36/27/17/4/3 2/0 7.0 0.0/92.8 0.10 0.10 9.0 15.0 0.02/0.35 350 7 R/D Cementers 30-Aug 3410 9.00 52 9 14 5/7/9 5.7 32/23/18/14/5/4 1/2 3.1 0.0/95.4 -0.25 8.7 -0.02/0.45 27000 200 Nipple Up BOP 31-Aug 3410 9.00 61 11 15 6/9/10 5.0 37/26/21/15/6/5 1/2 2.3 0.0/95.0 -0.30 8.8 -0.01/0.35 32000 140 Nipple Up BOP 1-Sep 3410 9.00 61 9 17 7/9/11 6.0 35/26/21/15/6/5 1/2 2.3 0.0/95.1 -0.35 8.8 -0.00/0.35 31500 120 Drill out cement 2-Sep 4513 9.15 46 11 21 9/13/18 5.2 43/32/27/21/9/8 1/2 3.3 0.0/94.2 0.10 1.55 8.6 1.3 1.20/6.50 30000 200 Drill 8-1/2" Production Section 3-Sep 5956 9.10 46 10 21 8/12/15 5.8 41/31/26/20/7/6 1/2 3.3 0.0/94.3 0.10 2.00 9.0 3.0 1.60/5.60 29500 240 Drill 8-1/2" Production Section 4-Sep 7058 9.28 46 10 19 5/8/12 4.6 39/29/24/17/6/5 1/2 3.8 0.0/93.4 0.10 1.90 9.2 3.0 1.60/4.90 34000 80 Drill 8-1/2" Production Section 5-Sep 8050 9.30 49 14 22 6/9/12 3.9 50/36/29/20/6/4 1/2 4.0 0.0/93.4 0.10 1.90 9.7 3.5 1.50/3.90 31500 100 TOOH to shoe to slip and cut 6-Sep 8381 9.3 54 15 22 *6/9/12 3.7 52/37/30/21/6/4 *1/2 4.2 0.0/93.4 0.1 1.45 9.4 3.5 1.00/3.10 29500 40 Drill 8-1/2" Production Section 7-Sep 9039 9.4 51 15 21 *6/9/13 3.8 52/37/30/21/5/4 *1/2 4.4 0.0/92.9 0.1 1.15 9.2 4 0.80/2.80 33500 30 Drill 8-1/2" Production Section 8-Sep 9670 10.2 53 20 21 *5/10/16 3.1 61/41/33/23/6/4 *1/2 7.3 0.0/90.0 0.1 1 9.2 4 0.60/2.30 34000 40 Drill 8-1/2" Production Section 9-Sep 10126 10.47 51 19 21 *5/9/15 2.9 59/40/32/21/5/4 *1/2 8.5 0.0/88.8 0.1 0.8 9.2 4.5 0.55/2.20 34500 40 Drill 8-1/2" Production Section 10-Sep 10540 10.55 45 17 20 *4/7/10 3.2 54/37/29/20/5/3 *1/2 9 0.0/88.8 0.1 1 9.8 5 0.70/2.00 29000 80 Drill 8-1/2" Production Section 11-Sep 10920 10.75 49 19 21 5/8/13 3.4 59/40/32/22/5/4 *1/2 10.2 0.0/87.4 0.1 1 9.8 5 .85/2.3 31000 40 Wiper Trip 12-Sep 10920 10.55 44 13 19 5/7/9 3.6 45/32/21/18/5/4 *1/2 9.7 0.0/88.1 0.1 1 9.4 5 0.85/2.3 29000 40 Test BOP 13-Sep 10920 10.8 45 13 19 5/7/9 3.5 45/32/21/18/5/4 *1/2 10.6 0.0/87.2 0.1 1 9.2 5 0.55/2.10 29000 40 RIH to Drill 8-1/2" Hole 14-Sep 10920 10.75 45 12 20 6/13/15 5.6 44/32/26/19/6/5 *1/2 10.4 0.0/87.4 0.1 1 9.2 5.4 0.5/2.4 29000 60 POOH w/ clean out assembly 15-Sep 10920 10.7 45 12 20 5/11/15 5.4 44/32/28/20/6/5 1/2 10 0.0/87.8 0.1 1 9.2 5.4 0.5/2.4 29000 60 POOH L/D BHA 16-Sep 10920 10.9 46 13 21 7/13/2016 5.9 47/34/28/21/7/5 1/2 10.9 0.0/86.9 0.1 0.9 9 6 0.6/2.80 29000 40 RIG with 5-1/2" Casing Casing Record SPERRY JOB:TD:14-Sep-2014 Remarks 16" Conductor @ 76' MD, 76'TVD 9.625" Casing @ 3399' MD, 3359'TVD 5.5" Casing @ 11103' MD, 10814'TVD WELL NAME:LOCATION:Beaver Creek OPERATOR:AREA:Kenai Peninsula Borough MUD CO:STATE:Alaska RIG:SPUD:25-Aug-2014 W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 1 100 1 Tricone 12.25 76 3410 3334 20.30 0.896 118.0 18 78 1200 550 1-1-BU-A-E-2-ER-TD TD Surface Section 2 200 2 HDBS MM65M PDC 8.50 3410 10920 7510 141.55 0.663 53.0 19 80 3059 500 2-2-CT-A-X-4-ER-TD POOH tp change bit 3 300 3 HDBS MM65M PDC 8.50 10920 11141 221 6.60 0.663 33.5 12 80 2890 500 -TD Production Section Alaska RIG:Saxon 169 SPUD:25-Aug-2014 WELL NAME:Beaver Creek Unit 23 LOCATION:Beaver Creek OPERATOR:Hilcorp Alaska, LLC AREA:Kenai Peninsula Borough MUD CO: SPERRY JOB:AK-XX-0901491779 TD:14-Sep-2014 Baroid STATE: B i t R e c o r d . . * 24 hr Recap:Continued drilling ahead to 1,761'MD. Began droping the viscosity from 225 to 150. Circulated a bottoms up @ Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 350.00 0 27-Aug-2014 12:00 AM Current Pump & Flow Data: 1704 Max ROP ROP (ft/hr) 3.06 @ Mud Data Depth Morning Report Report # 1 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 196 Report For: ConditionBit # 1 5.6 12.25Tricone 9.10 Size late, 10 percent increase in cuttings. Continued drilling ahead to 2,411' MD at time of report. fill seen. Continued drilling ahead to 2,300'MD. Pumped Hi-Vis sweep with Wall-Nut. Came back plus or minus 400 strokes 100' 100% Gas In Air=10,000 Units85Connection 0 Tools API FL Chromatograph (ppm) 0' WOB Conductor Avg Min Comments RPM ECD (ppg) ml/30min 53Background (max) Trip Average Mud Type Lst Type Spud Mud 8.12411'44 Depth in / out YP (lb/100ft2) 9.60 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901491779 N/A N/A Drilling PV 2411' Footage 20.00 James Sweetsir ShClyst TuffGvlCoal cP 28 Gas Summary 0 0 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 234.0 Flow In (gpm) Flow In (spm) 1062' 2411' Drilling ahead Max @ ft Current 2352'84.3 Date: Time: 1,761' MD and short tripped to 300' MD with no issues. Flow checked well and Tripped in the hole. Washed last 2 stands down no 42 in 10 1912'Minimum Depth C-5n 2351' 0.0 C-2 160 SPP (psi) Gallons/stroke TFABit Type Depth 17.5143 MBT 0' pH 0.896 0 0 0 Siltst 505 172 Units* Casing Summary Lithology (%) 07201 2403 907-283-1309Unit Phone: 0Maximum Report By:Logging Engineers:Craig Amos / Jacob Hansen Set AtSize 82.0 Grade 16.00'' (max)(current) 7 0 Cly 12496 . . * 24 hr Recap: (max)(current) 12 0 Cly 24162 Set AtSize 82.0 Grade 16.00'' 907-283-1309Unit Phone: 0Maximum Report By:Logging Engineers:Craig Amos / Jacob Hansen 39 1386 0 0 Units* Casing Summary Lithology (%) 0 MBT 0' pH 0.896 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 15.089 C-5n 3048' 0.0 C-2 256 Daily losses Down hole: 0 bbls in 9 2689'Minimum Depth Time: Pumped Hi-Vis sweep around 15% increase in cuttings. Made wiper trip to 1500'MD. No fill once on bottom. Circulated 61 Max Gas: 256 units 2411' 3411' TD for CSG Max @ ft Current 2352'84.3 Date: Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 234.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) James Sweetsir ShClyst TuffGvlCoal cP 28 2411' Footage 20.00 Ss (ppb Eq) C-1 C-5i AK-AM-0901491779 N/A N/A Drilling PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.10 000 Spud Mud 7.63411'35 Depth in / out Mud Type Lst Type Average 630Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 0' WOB Conductor 100% Gas In Air=10,000 Units243Connection 0 Pumped dry job and Tripped out of the hole at time of report. Pumped Hi-Vis with Wall Nut sweep for guage check. Came back 450 strokes late 8% washout. Flow checked well static. Bottoms up two times hole unloaded 200% at first bottoms up, mostly clay and fine sand, cleaned up by sencond Bottoms up 100' ConditionBit # 1 6.3 12.25Tricone 9.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: Morning Report Report # 2 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP ROP (ft/hr) 3.06 @ Mud Data Depth 28-Aug-2014 12:00 AM Current Pump & Flow Data: 0 Max 0 Chlorides mg/l 400.00 TD'd well at 3410' MD, casing point picked in shale rock, max gas seen in sand interval Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued to trip out of hole to surface. Flow check well static. Layed down bottom hole assembly. Rig up Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 350.00 0 29-Aug-2014 12:00 AM Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 3.06 @ Mud Data Depth Morning Report Report # 3 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: ConditionBit # 1 7.0 12.25Tricone 9.20 Size while pumping, chased with 253bbls freshwater, bumped plug and held. Dumped 16 bbls cement at surface. Flow from back side PJSM . Began pumping , 35 bbls 10.5 ppg Mud-Push, 270 bbls 12 ppg Lead Cement. 46bbls 15.4 ppg tail cement. Lost 68 bbls pumped 20 bbl LCM pill with BARACARBS, but then identified 10% flow from behind cellar at surface. Rig up cementers and hold 3399' 100' 100% Gas In Air=10,000 Units0Connection 0 Tools API FL Chromatograph (ppm) 0' 3411' WOB Conductor Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average 0 Mud Type Lst Type Spud Mud 8.13411'13 Depth in / out YP (lb/100ft2) 9.00 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901491779 N/A N/A Drilling PV 3411' Footage 20.00 James Sweetsir ShClyst TuffGvlCoal cP 23 Gas Summary 0 0 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 3411' 3411' R/D Cementers Max @ ft Current N/A0.0 Date: Time: Weatherford. Run 9 5/8 casing to bottom, landed at 3399' MD circulated bottoms up. Appeared to be losing 10 bph to formation, so 8 of cellar stopped once cement was at surface. Max Gas 62 units in 0 0'Minimum Depth C-5n 0' 0.0 C-2 62 SPP (psi) Gallons/stroke TFABit Type Depth 15.050 MBT 0' pH 0.896 0 0 0 Siltst 9.63'' 0 0 Units* Casing Summary Lithology (%) 0701 0 907-283-1309Unit Phone: 0 Jacob Hansen Maximum Report By:Logging Engineers:Craig Amos / Jacob Hansen Set AtSize 82.0 Grade 16.00'' (max)(current) Surface 0 0 Cly 792 . . * 24 hr Recap:Nipple down diverter and flow line spacer spools. Install well head with Cameron PAC well HED Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 27000.00 0 30-Aug-2014 12:00 AM Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 3.06 @ Mud Data Depth Morning Report Report # 4 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: ConditionBit # 1 3.1 12.25Tricone 9.00 Size to the location of beam in celler. Made up kill line, install flow nipple, hook up hydraulic lines, change out casing bells and and spool back down and torque to well head. Unable to torque spacer spool to stack after spool was made up to well head do kill line, choke line, and poor boy line. Detach spacer spool from well head, raise stack, torque spacer spool to stack, lower stack 3399' 100' 100% Gas In Air=10,000 Units0Connection 0 Tools API FL Chromatograph (ppm) 0' 3411' WOB Conductor Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average 0 Mud Type Lst Type Spud Mud 5.73411'14 Depth in / out YP (lb/100ft2) 8.70 000 00 CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901491779 N/A N/A Drilling PV 3411' Footage 20.00 James Sweetsir ShClyst TuffGvlCoal cP 9 Gas Summary 0 0 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 3411' 3411' Testing BOP Max @ ft Current N/A0.0 Date: Time: Test neck seal at 3000 PSI for 30 minutes test void at 3000 PSI for 30 minutes test pass. Nipple up B.O.P. set stack spacer spool, 0 elevators, funtion test BOP. Make up test joint rig up test pump and chart. Fill and purge BOP and choke lines with water. S/m over pressure testing. Test BOP Equipment. in 0 0'Minimum Depth C-5n 0' 0.0 C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 52 MBT 0' pH 0.896 0 0 0 Siltst 9.63'' 0 0 Units* Casing Summary Lithology (%) 00 0 907-283-1309Unit Phone: 0 Jacob Hansen Maximum Report By:Logging Engineers:Craig Amos / Jacob Hansen Set AtSize 82.0 Grade 16.00'' (max)(current) Surface 0 0 Cly 0 . . * 24 hr Recap:Continued Testing BOP. Unable to pull test plug. Nippled down BOP, Nippled up new well head, nippled up BOP at Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 32000.00 0 31-Aug-2014 12:00 AM Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 3.06 @ Mud Data Depth Morning Report Report # 5 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: Condition 1-1-BU-A-E-2-ER-TD Bit # 1 2.3 12.25Tricone 9.00 Size 2 3399' 100' 100% Gas In Air=10,000 Units0Connection 0 Tools API FL Chromatograph (ppm) 18.072' 3410' WOB Conductor Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max)Trip Average 0 Mud Type Lst Type 78.0 PDC Spud Mud 5.0 3410' 3410'15 Depth in / out YP (lb/100ft2) 8.80 000 00 CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901491779 N/A N/A Nippling up BOP PV 3410' 6 Footage 20.00 James Sweetsir ShClyst TuffGvlCoal cP 11 Gas Summary 0 0 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 3410' 3410' 0' Max @ ft Current N/A0.0 Date: Time: time of report. 0 in 0 0'Minimum Depth C-5n 0' 0.0 C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 61 MBT 0' pH 0.896 0 0 0 Siltst 9.63'' 0 0 Units* Casing Summary Lithology (%) 00 0 907-283-1309Unit Phone: 0 Jacob Hansen Maximum Report By:Logging Engineers:Craig Amos / Jacob Hansen Set AtSize 82.0 Grade 16.00'' (max)(current) Surface 0 0 Cly 0 . . . * 24 hr Recap: (max)(current) Surface 0 0 Cly 0 Set AtSize 82.0 Grade 16.00'' 907-283-1309Unit Phone: 0 Jacob Hansen Maximum Report By:Logging Engineers:Craig Amos / Jacob Hansen 0 0 9.63'' 274 92 Units* Casing Summary Lithology (%) 0 MBT 0' pH 0.896 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 61 C-5n 0' 0.0 C-2 0 in 0 0'Minimum Depth Time: @ 3,313' MD. Performed casing test and passed. Displace water with 9.0 ppg 6% KCL/PHPA mud. Circulating at time of report 0 3410' 3410' 0' Max @ ft Current N/A0.0 Date: Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) James Sweetsir ShClyst TuffGvlCoal cP 9 3410' 6 Footage 20.00 Ss (ppb Eq) C-1 C-5i AK-AM-0901491779 N/A N/A Circulating PV 24 hr Max 40.0 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 8.80 000 78.0 PDC Spud Mud 6.0 3410' 3410'17 Depth in / out Mud Type Lst Type Average 00Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 18.072' 3410' WOB Conductor 100% Gas In Air=10,000 Units0Connection 0 2 preparing to drill out cement/float equipment, 3399' 100' Condition 1-1-BU-A-E-2-ER-TD Bit # 1 2.3 12.25Tricone 9.00 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: Morning Report Report # 6 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP ROP (ft/hr) 3.06 @ Mud Data Depth 1-Sep-2014 12:00 AM Current Pump & Flow Data: 534 Max 0 Chlorides mg/l 31500.00 Continued Nippling up and tested BOP. Pick up bottom hole assembly and run in hole with singles. Tag cement Density (ppg) out (sec/qt) Viscosity Cor Solids % . . . * 24 hr Recap:Drilled out of shoe and drilled 20 feet of new formation. Performed FIT and passed. Continued drilling ahead to Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 30000.00 0 2-Sep-2014 12:00 AM Current Pump & Flow Data: 1089 Max ROP ROP (ft/hr) 3.06 @ Mud Data Depth Morning Report Report # 7 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: Condition 1-1-BU-A-E-2-ER-TD Bit # 1 3.3 12.25Tricone 91.50 Size 2 Max Gas: 88 units at time of report. 3399' 100' 100% Gas In Air=10,000 Units0Connection 0 Tools Gamma/ Resistivity and A API FL Chromatograph (ppm) 18.072' 3410' WOB Conductor Avg Min Comments RPM ECD (ppg) ml/30min 3Background (max) Trip Average 0 Mud Type Lst Type 78.0 PDC Spud Mud 5.2 3410' 4513'21 Depth in / out YP (lb/100ft2) 8.60 000 00 CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901491779 N/A N/A Drilling Ahead PV 3410' 6 Footage 20.00 James Sweetsir ShClyst TuffGvlCoal cP 11 Gas Summary 0 0 0 (current) Avg to3410' Yesterday's Depth: Current Depth: 24 Hour Progress: 131.0 Flow In (gpm) Flow In (spm) 3410' 4513' 1103' Max @ ft Current 4281'60.0 Date: Time: 4513' MD. Short tripped to the shoe. Performed a rig service and tripped back in to bottom. Circulating on bottom to drill ahead 4 Down hole losses: -17 bbls in 4 4425'Minimum Depth C-5n 4006' 0.0 C-2 88 SPP (psi) Gallons/stroke TFABit Type Depth 1.346 MBT 4513' pH 0.896 0 0 0 Siltst 9.63'' 469 156 Units* Casing Summary Lithology (%) 03892 2878 907-283-1309Unit Phone: 0 Jacob Hansen Maximum Report By:Logging Engineers:Craig Amos / Jacob Hansen Set AtSize 82.0 Grade 16.00'' (max)(current) Surface 0 0 Cly 10487 . . . * 24 hr Recap: (max)(current) Surface 90 0 Cly 124228 Set AtSize 82.0 Grade 16.00'' 907-283-1309Unit Phone: 0 Jacob Hansen Maximum Report By:Logging Engineers:Craig Amos / Jacob Hansen 13070 2576 9.63'' 460 157 Units* Casing Summary Lithology (%) 0 MBT 5956' pH 0.896 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 3.046 C-5n 5320' 98.0 C-2 949 in 12 5073'Minimum Depth Time: No tight spots. Circulated bottoms up and continued to drill to 5956' MD at time of report. 100 Down hole losses: 0 bbls 4513' 5956' 1443' Max @ ft Current 5756'60.4 Date: Avg to3410' Yesterday's Depth: Current Depth: 24 Hour Progress: 134.9 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) James Sweetsir ShClyst TuffGvlCoal cP 10 3410' 6 Footage 20.00 Ss (ppb Eq) C-1 C-5i AK-AM-0901491779 N/A N/A Drilling Ahead PV 24 hr Max 40.0 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.00 000 78.0 PDC KCL 5.8 3410' 5956'21 Depth in / out Mud Type Lst Type Average 4932Background (max)Trip 11.0111.04 Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma/ Resistivity / Density API FL Chromatograph (ppm) 18.072' 3410' WOB Conductor 100% Gas In Air=10,000 Units138Connection 0 2 Max Gas: 949 units 3399' 100' Condition 1-1-BU-A-E-2-ER-TD Bit # 1 3.3 12.25Tricone 9.10 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 11.05 Saxon 169 Report For: Morning Report Report # 8 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP ROP (ft/hr) 3.06 @ Mud Data Depth 3-Sep-2014 12:00 AM Current Pump & Flow Data: 1473 Max 0 Chlorides mg/l 29500.00 Drilled from 4,513' MD to 5,630' MD. Short tripped from 5,630' MD to 4,511' MD. Run in hole picked up singles. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . . * 24 hr Recap:Continued drilling ahead from 5,956' MD to 6,117' MD and encountered 1,742 units of gas with no significant Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 34000.00 0 4-Sep-2014 12:00 AM Current Pump & Flow Data: 1735 Max ROP ROP (ft/hr) 3.06 @ Mud Data Depth Morning Report Report # 9 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: Condition 1-1-BU-A-E-2-ER-TD Bit # 1 3.8 12.25Tricone 9.28 Size 2 Max Gas: 1742 units drill ahead. ream from 5,861' MD to 5,717' MD before pulling the rest of the way on elevators. Picked up 32 joints of drill pipe and continued to 3399' 100' 100% Gas In Air=10,000 Units806Connection 14 Tools Gamma/ Resistivity / Density API FL Chromatograph (ppm) 18.072' 3410' WOB Conductor Avg Min Comments RPM ECD (ppg) ml/30min 33Background (max)Trip Average 86 Mud Type Lst 70 Type 78.0 PDC KCL 4.6 3410' 7058'19 Depth in / out YP (lb/100ft2) 9.20 000 00 CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 17 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901491779 N/A N/A Drilling Ahead PV 3410' 6 Footage 20.00 James Sweetsir ShClyst TuffGvlCoal cP 10 30 Gas Summary 0 0 0 (current) Avg to3410' Yesterday's Depth: Current Depth: 24 Hour Progress: 136.7 Flow In (gpm) Flow In (spm) 5956' 7058' 1102' Max @ ft Current 6068'46.5 Date: Time: increase in coal. Mud weight increased to 9.2 ppg. Drilled to 6,811' MD then short tripped to 5,629' MD had to pump and back 188 Down hole losses: 0 bbls in 5 6715'Minimum Depth C-5n 6117' 53.7 C-2 1742 SPP (psi) Gallons/stroke TFABit Type Depth 3.046 MBT 5956' pH 0.896 0 0 0 Siltst 9.63'' 458 156 Units* Casing Summary Lithology (%) 023942 10991 907-283-1309Unit Phone: 0 Jacob Hansen Maximum Report By:Logging Engineers:Craig Amos / Jacob Hansen Set AtSize 82.0 Grade 16.00'' (max)(current) Surface 128 10 Cly 177931 . . . * 24 hr Recap:Continued drilling ahead from 7,058' MD to 8,050' MD. Pumped a sweep at 8,050' MD and circulated bottoms up, Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 31500.00 4 5-Sep-2014 12:00 AM Current Pump & Flow Data: 1622 Max ROP ROP (ft/hr) 3.06 @ Mud Data Depth Morning Report Report # 10 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: Condition 1-1-BU-A-E-2-ER-TD Bit # 1 4.0 12.25Tricone 9.30 Size 2 Down hole losses: 0 bbls Max Gas: 1027 units 3399' 100' 100% Gas In Air=10,000 Units430Connection 70 24 Tools Gamma/ Resistivity / Density API FL Chromatograph (ppm) 18.072' 3410' WOB Conductor Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max)Trip Average Mud Type Lst Type 78.0 PDC KCL 3.9 3410' 8050'19 Depth in / out YP (lb/100ft2) 9.70 000 00 CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 7 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901491779 N/A N/A STP to shoe PV 3410' 6 Footage 20.00 James Sweetsir ShClyst 10 TuffGvlCoal cP 14 Gas Summary 0 0 0 (current) Avg to3410' Yesterday's Depth: Current Depth: 24 Hour Progress: 130.9 Flow In (gpm) Flow In (spm) 7058' 8050' 992' Max @ ft Current 7330'40.5 Date: Time: before short tripping to casing shoe for slip and cut. Currently tripping at the time of report. 147 in 5 7273'Minimum Depth C-5n 7307' 0.0 C-2 1027 SPP (psi) Gallons/stroke TFABit Type Depth 3.549 MBT 8050' pH 0.896 0 9 0 Siltst 9.63'' 146 433 Units* Casing Summary Lithology (%) 0 20 12685 15633 907-283-1309Unit Phone: 0 Megan Cardenas Maximum Report By:Logging Engineers:Craig Amos / Jacob Hansen Set AtSize 82.0 Grade 16.00'' (max)(current) Surface 68 8 Cly 112494 . . . * 24 hr Recap:Continued to trip up to 3,333' MD. Lost 21 Barrels to the well while tripping . Slip and cut drill-line. Run in hole, picked Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 29500.00 7 6-Sep-2014 12:00 AM Current Pump & Flow Data: 2070 Max ROP ROP (ft/hr) 3.06 @ Mud Data Depth Morning Report Report # 11 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: Condition 1-1-BU-A-E-2-ER-TD Bit # 1 4.2 12.25Tricone 9.30 Size 2 Down hole losses: -59 Max Gas: 1021 units hour while drilling ahead. Curently drilling ahead at report time. 3399' 100' 100% Gas In Air=10,000 Units1020Connection 40 7 Tools Gamma/ Resistivity / Density API FL Chromatograph (ppm) 18.072' 3410' WOB Conductor Avg Min Comments RPM ECD (ppg) ml/30min 100Background (max) Trip Average 203 Mud Type Lst Type 78.0 PDC KCL 3.7 3410' 8381'22 Depth in / out YP (lb/100ft2) 9.40 000 00 CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 12 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901491779 N/A N/A Drilling Ahead PV 3410' 6 Footage 20.00 James Sweetsir ShClyst TuffGvlCoal cP 15 Gas Summary 0 0 0 (current) Avg to3410' Yesterday's Depth: Current Depth: 24 Hour Progress: 109.3 Flow In (gpm) Flow In (spm) 8050' 8381' 331' Max @ ft Current 8085'30.9 Date: Time: up singles (64 jnts) . Tripped in hole circulated bottoms up and continued drilling ahead to 8,381' MD. Losing about 2 barrels an 179 in 41 8195'Minimum Depth C-5n 8377' 52.0 C-2 1021 SPP (psi) Gallons/stroke TFABit Type Depth 3.554 MBT 8381' pH 0.896 0 0 0 Siltst 9.63'' 468 159 Units* Casing Summary Lithology (%) 0 60 21097 4852 907-283-1309Unit Phone: 0 Jacob Hansen Maximum Report By:Logging Engineers:Craig Amos / Jacob Hansen Set AtSize 82.0 Grade 16.00'' (max)(current) Surface 12 0 Cly 61668 . . . * 24 hr Recap:Continued drilling ahead to 8,998' MD. Short trip to 7,815' MD, tripped back in circulated bottoms up and measured Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 33500.00 3 7-Sep-2014 12:00 AM Current Pump & Flow Data: 1881 Max ROP ROP (ft/hr) 3.06 @ Mud Data Depth Morning Report Report # 12 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: Condition 1-1-BU-A-E-2-ER-TD Bit # 1 4.4 12.25Tricone 9.40 Size 2 Down hole losses: -96 bbls Max Gas: 5,176 units 3399' 100' 100% Gas In Air=10,000 Units538Connection 10 45 Tools Gamma/ Resistivity / Density API FL Chromatograph (ppm) 18.072' 3410' WOB Conductor Avg Min Comments RPM ECD (ppg) ml/30min 20Background (max)Trip Average 5176 Mud Type Lst Type 78.0 PDC KCL 3.8 3410' 9039'22 Depth in / out YP (lb/100ft2) 9.20 000 00 CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901491779 N/A N/A Drilling Ahead PV 3410' 6 Footage 20.00 James Sweetsir ShClyst 60 TuffGvlCoal cP 15 Gas Summary 0 2 0 (current) Avg to3410' Yesterday's Depth: Current Depth: 24 Hour Progress: 113.6 Flow In (gpm) Flow In (spm) 8381' 9039' 658' Max @ ft Current 8885'27.8 Date: Time: 5,176 units of gas and 1-2" pieces of coal at the shakers. Currently drilling ahead at report time. 168 in 3 8900'Minimum Depth C-5n 8392' 41.0 C-2 1778 SPP (psi) Gallons/stroke TFABit Type Depth 4.051 MBT 9039' pH 0.896 4 17 0 Siltst 9.63'' 451 152 Units* Casing Summary Lithology (%) 0 30 10363 10158 907-283-1309Unit Phone: 0 Megan Cardenas Maximum Report By:Logging Engineers:Craig Amos / Jacob Hansen Set AtSize 82.0 Grade 16.00'' (max)(current) Surface 88 6 Cly 159454 . . . * 24 hr Recap: Max Gas: 6,926 units Continued drilling ahead to 9,145' MD, a 12% increase in flow was identified. Picked up off bottom and observed Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 34000.00 83 8-Sep-2014 12:00 AM Current Pump & Flow Data: 2369 Max ROP ROP (ft/hr) 3.06 @ Mud Data Depth Morning Report Report # 13 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: Condition 1-1-BU-A-E-2-ER-TD Bit # 1 7.3 12.25Tricone 10.20 Size 2 Max Gas: 6,926 units 10.1 ppg and continued to circulate out gas. Drilling ahead at time of the report and weighting up to 10.3 ppg. influx in flow and gas units to 6,700 units and weighted up to 9.9 ppg. Once at 9.9 ppg gas and flow didn't drop out, weighted up to 3399' 100' 100% Gas In Air=10,000 Units5248Connection 348 Tools Gamma/ Resistivity / Density API FL Chromatograph (ppm) 18.072' 3410' WOB Conductor Avg Min Comments RPM ECD (ppg) ml/30min 3200Background (max)Trip Average N/A Mud Type Lst 70 Type 78.0 PDC KCL 3.1 3410' 9670'21 Depth in / out YP (lb/100ft2) 9.20 050 00 CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 150 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901491779 N/A N/A Drilling Ahead PV 3410' 6 Footage 20.00 James Sweetsir ShClyst 10 TuffGvlCoal cP 20 Gas Summary 0 18 20 (current) Avg to3410' Yesterday's Depth: Current Depth: 24 Hour Progress: 115.2 Flow In (gpm) Flow In (spm) 9039' 9670' 631' Max @ ft Current 9503'27.0 Date: Time: 2,476 units of gas. Circulated out remainder of the gas and weighted up to 9.6 ppg. Drilled to 9,430' MD, observed an 1489 Downhole Losses: 0 bbls in 3 9160'Minimum Depth C-5n 9481' 58.0 C-2 6926 SPP (psi) Gallons/stroke TFABit Type Depth 4.053 MBT 9670' pH 0.896 0 62 0 Siltst 9.63'' 455 153 Units* Casing Summary Lithology (%) 17 20 157246 2955 907-283-1309Unit Phone: 0 Megan Cardenas Maximum Report By:Logging Engineers:Craig Amos / Jacob Hansen Set AtSize 82.0 Grade 16.00'' (max)(current) Surface 485 0 Cly 476102 . . . * 24 hr Recap: (max)(current) Surface 463 179 Cly 440220 Set AtSize 82.0 Grade 16.00'' 907-283-1309Unit Phone: 0 Megan Cardenas Maximum Report By:Logging Engineers:Craig Amos / Jacob Hansen 40 222621 206594 9.63'' 493 166 Units* Casing Summary Lithology (%) 18 MBT 10126' pH 0.896 107 51 19 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 4.551 C-5n 9704' 14.0 C-2 5485 in 13 9712'Minimum Depth Time: bottoms up and had a max trip gas of 7,778 units with larger coal pieces but very few. Drilling ahead at the time of the report. 2268 Downhole Losses: 0 bbls 9670' 10126' 456' Max @ ft Current 9681'18.5 Date: Avg to3410' Yesterday's Depth: Current Depth: 24 Hour Progress: 123.1 Flow In (gpm) Flow In (spm) Gas Summary 0 16 19 (current) James Sweetsir ShClyst 20 TuffGvlCoal cP 19 3410' 6 Footage 20.00 Ss (ppb Eq) C-1 C-5i AK-AM-0901491779 N/A N/A Drilling Ahead PV 24 hr Max 40.0 Weight 182 Hours C-3 06 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.20 050 78.0 PDC KCL 2.9 3410' 10126'21 Depth in / out Mud Type Lst 40 Type Average 77781606Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma/ Resistivity / Density API FL Chromatograph (ppm) 18.072' 3410' WOB Conductor 100% Gas In Air=10,000 Units6504Connection 275 2 Max Gas: 7,778 units 3399' 100' Condition 1-1-BU-A-E-2-ER-TD Bit # 1 8.5 12.25Tricone 10.47 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: Morning Report Report # 14 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP ROP (ft/hr) 3.06 @ Mud Data Depth 9-Sep-2014 12:00 AM Current Pump & Flow Data: 2672 Max 96 Chlorides mg/l 34500.00 Continued drilling ahead to 10,034' MD and short tripped to 8,993' MD with no problems. Tripped back in, circulated Density (ppg) out (sec/qt) Viscosity Cor Solids % . . . * 24 hr Recap:Continued drilling ahead drilled to ~10,382' MD then short tripped for rig service at 10,237' MD for IBOP and tripped Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 29000.00 45 10-Sep-2014 12:00 AM Current Pump & Flow Data: 2891 Max ROP ROP (ft/hr) 3.06 @ Mud Data Depth Morning Report Report # 15 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: Condition 1-1-BU-A-E-2-ER-TD Bit # 1 9.0 12.25 10.55 Tricone 10.55 Size 2 Off Bottom Gas: 8797 units @ 10,474' MD Max Gas: 3134 units 3399' 100' 100% Gas In Air=10,000 Units8389Connection 146 Tools Gamma/ Resistivity / Density API FL Chromatograph (ppm) 18.072' 3410' WOB Conductor Avg Min Comments RPM ECD (ppg) ml/30min 291Background (max)Trip Average N/A Mud Type Lst 80 Type 78.0 PDC KCL 3.2 3410' 10486'20 Depth in / out YP (lb/100ft2) 9.80 000 9972466 CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 87 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901491779 N/A N/A Drilling Ahead PV 3410' 6 Footage 20.00 Jimmy Greco ShClyst 20 TuffGvlCoal cP 17 Gas Summary 1002 7 0 (current) Avg to3410' Yesterday's Depth: Current Depth: 24 Hour Progress: 120.0 Flow In (gpm) Flow In (spm) 10126' 10540' 414' Max @ ft Current 10372'16.8 Date: Time: back to bottom with no issues. Continued drilling to ~10,474' MD and completed another rig service. Drilling ahead at report time. 893 Downhole Losses: 0 bbls in 11 9712'Minimum Depth C-5n 10268' 48.0 C-2 3134 SPP (psi) Gallons/stroke TFABit Type Depth 5.045 MBT 10540' pH 0.896 2501 23 2499 Siltst 9.63'' 496 167 Units* Casing Summary Lithology (%) 8100313 9992 907-283-1309Unit Phone: 0 Megan Cardenas Maximum Report By:Logging Engineers:Craig Amos / Jacob Hansen Set AtSize 82.0 Grade 16.00'' (max)(current) Surface 282 4995 Cly 330977 . . . * 24 hr Recap: Downhole Losses: 0 bbls Continued drilling ahead to 10,445' MD and short tripped to ~10,265' MD for rig service and tripped back to Density (ppg) out (sec/qt) Viscosity Cor Solids %mg/l 31000.00 26 Chlorides 11-Sep-2014 12:00 AM Current Pump & Flow Data: 2891 Max Depth ROP ROP (ft/hr) 3.06 @ Mud Data Morning Report Report # 16 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: 10.2 12.25Tricone 10.75 Size before short tripping to 10,000' MD. Tripped back in and completed a carbide test to find it came up 15-20 bbls late. POOH at 3399' 100' Condition 1-1-BU-A-E-2-ER-TD Bit # 1 Max Gas: 225 units report time. 100% Gas In Air=10,000 Units7541Connection 12 Tools Gamma/ Resistivity / Density API FL Chromatograph (ppm) 18.072' 3410' WOB Conductor Avg Min Comments RPM ECD (ppg) ml/30min Background (max) Trip Average 69170 Mud Type Lst Type PDC KCL 3.4 3410' 10920'21 Depth in / out 2 YP (lb/100ft2) 9.80 000 Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 74 Hours C-3 0 Ss (ppb Eq) C-1 C-5i AK-AM-0901491779 N/A N/A Drilling Ahead PV Footage 20.00 TuffGvlCoal cP 19 3410' Cement 78.0 Gas Summary 0 0 0 (current) Avg to3410' Yesterday's Depth: Current Depth: 24 Hour Progress: 116.5 Flow In (gpm) Flow In (spm) 10540' 10920' 380' Max @ ft Current 10750'16.3 Date: bottom and circulated up 9,876 units with an increase in flow. Continued drilling to TD at 10,920' MD and weighted up to 10.6 ppg 355 010756'Minimum Depth Time:Jimmy Greco ShClyst C-5n 10583' 0.0 C-2 225 SPP (psi) Gallons/stroke TFABit Type Depth 5.049 in 4 MBT 10920' pH 0.896 25 0 4 9.63'' 496 167 Units* Casing Summary Lithology (%)Siltst 8.5 34487 53812 Craig Amos / Jacob Hansen 3 907-283-1309Unit Phone: 0 Megan Cardenas Maximum Report By:Logging Engineers: Set AtSize 82.0 Grade 16.00'' Bottoms Up Gas: 9876 units @ 10,748' MD (max)(current) Surface 24 51 Cly 26722 . . . * 24 hr Recap:POOH with no issues from 10,920' MD to 8,539' MD. Encountered swelling clay formations, turned pumps on and Density (ppg) out (sec/qt) Viscosity Cor Solids %mg/l 29000.00 Chlorides 12-Sep-2014 12:00 AM Current Pump & Flow Data: - Max Depth ROP ROP (ft/hr) 3.06 @ Mud Data Tools Gamma/ Resistivity / Density API FL Morning Report Report # 17 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: 12.25Tricone 10.55 Size 20.00 preparing to test BOPs at report time. 3399' 100' Condition 1-1-BU-A-E-2-ER-TD Bit # 1 Max Gas: 1625 units Downhole Losses: 0 bbls 100% Gas In Air=10,000 Units-Connection 75 Chromatograph (ppm) 18.072' 3410' WOB Conductor Footage Avg Min Comments RPM ECD (ppg) ml/30min 9.7 Background (max) Trip (max) Average 16250 Mud Type Lst Type PDC KCL 3.6 3410' 10920'19 Depth in / out 2 YP (lb/100ft2) 9.40 000 Cht Silt C-4i C-4n TuffGvlCoal 24 hr Max 40.0 Weight 5 Hours C-3 0 Ss (ppb Eq) C-1 C-5i AK-AM-0901491779 N/A N/A Drilling Ahead PV 13 3410' Cement 78.0 Gas Summary 0 5 0 (current) Avg to3410' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 10920' 10920' 0' Max @ ft Current -- Date: back reamed out of the hole to 6,380' MD. Completed tripping out of the hole without issues. Laying down MWD tools and 33 0-Minimum Depth Time:Jimmy Greco ShClyst C-5n - 0.0 C-2 16254 Gallons/stroke TFABit Type Depth 5.044 in cP 0 MBT 10920' pH 0.896 0 16 0 - - Units* Casing Summary Lithology (%)Siltst 8.5 SPP (psi) 3082 00 0 907-283-1309Unit Phone: 0 Megan Cardenas Maximum Report By:Logging Engineers:Craig Amos / Megan Cardenas Set AtSize 82.0 Grade 16.00'' 9.63'' (current) Surface 181 0 Cly 170164 . . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids %Depth mg/l 29000.00 8.5 Chlorides 13-Sep-2014 12:00 AM Current Pump & Flow Data: 734 Max 3.06 @ Mud Data Tools Gamma/ Resistivity / Density API FL Morning Report Report # 18 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek MWD Summary 95% Rig Activity: Saxon 169 Report For: ROP ROP (ft/hr) PDC 10.80 Size 141.55 3399' 100' Condition 2-2-CT-A-X-4-ER-TD Bit # 2 Max Gas: 2912 units Downhole Losses: 690 bbls 100% Gas In Air=10,000 Units-ConnectionBackground Completed BOP test, P/U MWD tools and new bit, RIH to 6000' and circulated, continue to RIH. 135 Chromatograph (ppm) Gas Summary 0 WOB Conductor Footage Avg Min Comments RPM ECD (ppg) ml/30min 10.6 (max) Trip (max) Average 2912122 Mud Type Lst Type KCL 3.5 10920' 10920'19 Depth in / out 3 0.663 030 C-4n TuffGvlCoal YP (lb/100ft2) 9.20 19.03410' 24 hr Max 40.0 Weight 21 Hours C-3 0 C-5i AK-AM-0901491779 RIH PV C-4i Cement 227.0 Surface Ss Cht Silt PDC 10920' 23 2 (current) Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gallons/stroke Job No.: Daily Charges: Total Charges: 10920' 10920' 0' Max @ ft Current -- Date: 102 0-Minimum Depth Time:Jimmy Greco ShClyst Avg - - C-2 2912 Bit Type Depth 5.045 in C-5n to3410' 13 7510' SPP (psi) cP 0 MBT 10920' pH 0.663 0 0 Units* Casing Summary Lithology (%)Siltst 8.5 TFA 217 73 0 (ppb Eq) C-1 0 11 907-283-1309Unit Phone: 0 9695 6 Jane Grundin Maximum Report By:Logging Engineers:Craig Amos / Jane Grundin (current) 255 Set AtSize 82.0 Grade 16.00'' 9.63'' Cly 301787 0 . . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids %Depth mg/l 29000.00 8.5 14-Sep-2014 12:00 AM Current Pump & Flow Data: 0 Max 3.06 @ Mud Data Tools Gamma/ Resistivity / Density API FL MWD Summary Chlorides Morning Report Report # 19 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek 95% Rig Activity: Saxon 169 Report For: ROP ROP (ft/hr) PDC 10.75 Size 141.55 3399' 100' Condition 2-2-CT-A-X-4-ER-TD Bit # 2 Max Gas: 7380 units Downhole Losses: 0 bbls 100% Gas In Air=10,000 Units11091ConnectionBackground Tripped in hole and pumped sweep at 10,953'MD. Drilled ahead to 11141'MD. Pump motor failed causing TD at Chromatograph (ppm) 10 Gas Summary 0 Footage 190 Avg Min Comments RPM ECD (ppg) ml/30min 10.4 WOB (max) Trip (max) Average 738015 Mud Type Lst 20 Type KCL 5.6 10920' 10920'20 Depth in / out 3 0.663 040 C-4n TuffGvlCoal YP (lb/100ft2) 9.20 19.03410' 24 hr Max 40.0 Weight 51 Hours C-3 10 0 C-5i AK-AM-0901491779 POOH PV C-4i Cement 227.0 Surface Ss Cht Silt PDC 10920' 27 4 (current) Yesterday's Depth: Current Depth: 24 Hour Progress: 100.6 Flow In (gpm) Flow In (spm) Gallons/stroke Job No.: Daily Charges: Total Charges: 10920' 11141' 221' Max @ ft Current 10922'9.1 Date: 11141'MD. Pumped sweep, circulated, POOH 20 stds, pumped slug, and continuing to trip out at time of report. 393 011109'Minimum Depth Time:Jimmy Greco ShClyst Avg 10920' 0.0 C-2 7380 Bit Type Depth 5.445 in C-5n to3410' 12 7510' SPP (psi) cP 0 MBT 11099' pH 0.663 0 0 Units* Casing Summary Lithology (%)Siltst 40 8.5 TFA 0 0 0 (ppb Eq) C-1 Conductor 2 23 907-283-1309Unit Phone: 0 53846 6 Jane Grundin Maximum Report By:Logging Engineers:Craig Amos / Jane Grundin (current) 330 Set AtSize 82.0 Grade 16.00'' 9.63'' Cly 438116 20 0 . . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids %Depth mg/l 29000.00 8.5 16-Sep-2014 12:00 AM Current Pump & Flow Data: 0 Max 3.06 @ Mud Data Tools Gamma/ Resistivity / Density API FL MWD Summary Chlorides Avg Morning Report Report # 20 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek 95% Rig Activity: Saxon 169 Report For: ROP ROP (ft/hr) PDC 10.70 Size 141.55 3399' 100' Condition 2-2-CT-A-X-4-ER-TD Bit # 2 Max Gas: 89 units Downhole Losses: 0 bbls 100% Gas In Air=10,000 Units-ConnectionBackground Finished TOOH and layed down tools. Rigging up for casing at time of report. Chromatograph (ppm) Gas Summary 0 11 10920' C-4n Surface Min Comments RPM ECD (ppg) ml/30min 10.0 WOB 227.0 (max) Trip (max) Average 892 Mud Type Lst Type KCL 5.410920'20 11141' Depth in / out 3 0.663 5 3410' Bit Type Footage 040 TuffGvlCoal YP (lb/100ft2) 9.20 19.0 Cement 65 24 hr Max 40.0 Weight 12 Hours C-3 0 C-5i AK-AM-0901491779 L/D Tools PV C-4i PDC 10920' 3 Casing Summary Lithology (%)Siltst Grade 6.55 221' 0 (current) 0 Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gallons/stroke Job No.: Daily Charges: Total Charges: 11141' 11141' 0' Max @ ft Current -- Date: 8 011141'Minimum Depth Time:Jimmy Greco ShClyst Avg 11141' - C-2 89 Depth 5.445 in C-5n to3410' 12 7510' Units* SPP (psi) cP 0 MBT 11099' pH 0.663 0 0 8.5 TFA Set AtSize 82.0 0 0 0 (ppb Eq) C-1 Conductor 0 16 907-283-1309Unit Phone: 0 10778 Jane Grundin Maximum Report By:Logging Engineers:Craig Amos / Jane Grundin (current) 14 16.00'' 9.63'' ClySsChtSilt 7654 0 . . * 24 hr Recap: 0 11129' 16.00'' 5.50'' 9.63'' ClySsChtSilt Jane Grundin Maximum Report By:Logging Engineers:Craig Amos / Jane Grundin (current) 758 0 93 907-283-1309Unit Phone: 0 217162 171 58 0 (ppb Eq) C-1 Conductor 8.5 TFA Set AtSize 82.0 SPP (psi) cP 0 MBT 11099' pH 0.663 0 0 Depth 6.046 in C-5n to3410' 13 7510' Units* 11141' - C-2 9861 11141'Minimum Depth Time: 17.0 Jimmy Greco ShClyst Avg CBU 9800 units of gas. Circulated out gas, RIH T/3655' MD and circulated more. Weighting up mud to 10.9 ppg at time of report. 1900 0 11141' 11141' 0' Max @ ft Current -- Date: Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gallons/stroke Job No.: Daily Charges: Total Charges: 5 (current) 0 PDC 10920' 50 Casing Summary Lithology (%)Siltst Grade 6.60 221' C-5i AK-AM-0901491779 Running Casing PV C-4i 24 hr Max 40.0 Weight 174 Hours C-3 0 TuffGvlCoal YP (lb/100ft2) 9.00 19.0 Cement 80 0170 10920'21 11141' Depth in / out 3 0.663 12 3410' Bit Type Footage Mud Type Lst Production Type KCL 5.9 Average 9861986 (max)Trip (max) Min Comments RPM ECD (ppg) ml/30min 10.9 WOB 227.0 320 10920' C-4n Surface 1000000 Chromatograph (ppm) Gas Summary 0 Downhole Losses: 0 bbls 100% Gas In Air=10,000 Units-ConnectionBackground Finished rigging up for casing, RIH T/3301' MD and CBU 8900 units of gas. Circulated out gas, RIH T/4883' MD and Bit # 2 Max Gas: 9861 units PDC 10.90 Size 141.55 3399' 100' Condition 2-2-CT-A-X-4-ER-TD 95% Rig Activity: Saxon 169 Report For: ROP ROP (ft/hr) Morning Report Report # 21 Customer: Well: Area: Location: Rig: Beaver Creek 23 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek @ Mud Data Tools Gamma/ Resistivity / Density API FL MWD Summary Chlorides Avg 17-Sep-2014 12:00 AM Current Pump & Flow Data: 178 Max 3.06 mg/l 29000.00 8.5 Density (ppg) out (sec/qt) Viscosity Cor Solids %Depth