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Home My WebLink About214-0011. 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): 11,150'N/A Casing Collapse Structural Conductor 520 psi Surface 1,540 psi Intermediate 3,090 psi Production 5,410 psi Liner 10680/7500 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG 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 See Attached Schematic 5,238' 9,560' & 10,200' Length Swell Packer; N/A 4,543' MD - 4,339' TVD; N/A 10,233'9,519'8,610' 20" Beaver Creek Unit (BCU) 01BCO 237C Same 4,873'7" ~2,800psi Beaver Creek Beluga Gas Size September 1, 2025 11,107'11,107' 4-1/2" 10,190' 5,238' Perforation Depth MD (ft): 5,134' 4-1/2" See Attached Schematic 5,750 psi 1,530 psi 3,090 psi 530' 4,787' 530' 2,224' 530' 9-5/8"5,134' 2,224' MD 13-3/8" 13.5# / P-110 ; 12.6# / L-80 TVD Burst 10,860' / 11,107' 7,240 psi 2,224' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028083; FEDA028118 214-001 50-133-20006-01-00 Hilcorp Alaska, LLC Proposed Pools: 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 AOGCC USE ONLY 12,410/8,430 psi Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: 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 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 3:48 pm, Aug 15, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.08.15 15:43:33 - 08'00' Noel Nocas (4361) 325-484 BJM 8/19/25 DSR-8/19/25 10-404 SFD 8/21/2025*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.21 16:26:40 -08'00'08/21/25 RBDMS JSB 082225 Well Prognosis Well: BCU-01B Well Name: BCU-01B API Number: 50-133-20006-01 Current Status: Gas Producer Permit to Drill Number: 214-001 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: 3649 psi @ 8484’ TVD Based on 0.43 psi/ft Max. Potential Surface Pressure: 2800 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 5275’ - Milled ST Window Depth Shallowest Allowable Perf TVD: MPSP / (0.57 - 0.1) = 2800 psi / 0.47 = 5958’ TVD Top of Applicable Gas Pool / PA: Beluga Gas Pool / PA – 6375’ MD / 5835’ TVD Well Status: Gas Producer x 376 mcfd / 13 bwpd / 68 psi FTP as of 8/13/2025 Recent Well Summary: BCU 01B is an active gas producer open in multiple sands of the Beluga Gas Pool / PA from the B11 – B31 intervals. Most recent perforations were added in 2021 where production increased from ~850 mcfd to just under 3 mmfcd after perforations were added. Since, the well has gradually declined in gas rate and current well status as of August 13, 2025 is 376 mcfd / 13 bwpd / 68 psi FTP. The objective of this Sundry is to add additional perforations in the Beluga Gas Pool / PA in the Bel 16L – Bel 33 intervals. Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low / 3,000 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-01B BEL16L ±7,982 ±7,996 ±7,173' ±7,185' ±14' BCU-01B BEL17 ±8,016 ±8,030 ±7,202' ±7,215' ±14' BCU-01B BEL18 ±8,088 ±8,102 ±7,266' ±7,279' ±14' BCU-01B BEL18 ±8,127 ±8,133 ±7,301' ±7,307' ±6' BCU-01B BEL19 ±8,137 ±8,142 ±7,310' ±7,315' ±5' BCU-01B BEL19 ±8,154 ±8,159 ±7,326' ±7,330' ±5' BCU-01B BEL19 ±8,177 ±8,202 ±7,346' ±7,369' ±25' BCU-01B BEL20 ±8,227 ±8,233 ±7,392' ±7,397' ±6' BCU-01B BEL20 ±8,240 ±8,257 ±7,403' ±7,419' ±17' BCU-01B BEL20 ±8,370 ±8,375 ±7,521' ±7,525' ±5' BCU-01B BEL22 ±8,506 ±8,512 ±7,645' ±7,650' ±6' Well Prognosis Well: BCU-01B BCU-01B BEL28 ±8,884 ±8,889 ±7,997' ±8,001' ±5' BCU-01B BEL28 ±8,897 ±8,903 ±8,009' ±8,015' ±6' BCU-01B BEL28L ±8,995 ±8,999 ±8,102' ±8,106' ±4' BCU-01B BEL29 ±9,042 ±9,047 ±8,147' ±8152' ±5' BCU-01B BEL29L ±9,092 ±9,100 ±8,195' ±8,203' ±8' BCU-01B BEL29L ±9,107 ±9,123 ±8,210' ±8,225' ±16' BCU-01B BEL33 ±9,373 ±9,390 ±8,468' ±8,484' ±17' 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. RDMO. 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 / 3000 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 Lease: State/Prov:Alaska Country:USA Angle/Perfs:N/A 138.4' 18.6' 9/16/2021Revised By:Donna Ambruz Downhole Revision Date:Schematic Revision Date: Angle @KOP and Depth:34º @ 5,238'Maximum Deviation:40.6º @ 5,3880' Date Completed:3/5/2014 Ground Level (above MSL):RKB (above GL): Well Name & Number:Beaver Creek Unit #1B A - 028083 County or Parish:Kenai Peninsula Borough BC-01B Pad 1A 117' FSL, 1,338' FEL Sec. 33, T7N, R10W, S.M.Permit #: 214-001 API #: 50-133-20006-01-00 Property Des: A-028083 KB Elevation: 157.0' (18.6' AGL) Spud Date: 02/15/14 Rig Released: 03/07/14 Tree cxn = 6-1/2" Otis PBTD 9,519' MD 8,610' TVD TD 11,150' MD 10,233' TVD Conductor 20" H-40 94 ppf Top Bottom MD 0' 530' TVD 0' 530' 26" hole cmt w/ 1,000 sks of Class G Surface Casing 13-3/8" J-55 61 ppf BTC MD 0' 2,224' TVD 0' 2,224' 18-5/8" hole cmt w/ 3,500 sks of Class G Intermediate Casing 9-5/8" N-80 40/43.5 ppf BTC MD 0' 5,134' TVD 0' 4,787' 12-1/4" hole cmt w/ 1,100 sks of Class G Cmt w/ 700 sks thru DV Collar @ 2,080' Production Liner 4-1/2" L-80 / P-110 12.6 / 13.5 ppf BTC / DWC/C MD 0' 11,107' TVD 0' 10,190' 4-1/2" P-110 13.5 ppf 0'-10,860' 4-1/2" L-80 12.6 ppf 10,860'-11,107' 6"x7" hole cmt w/ 205 bbls 15.8 ppg Class G SCHEMATIC Swell Packer @ 4,543'-4,565' MD TOC (3/08/14 SCMT) - 4,312' Max Dogleg: 8.98°/100' @ 5,318' Production Casing 7" N-80 / P-110 26 / 29 ppf BTC MD 0' 5,238' TVD 0' 4,873' 7" N-80 26 ppf 0'-4,700' 7" N-80 29 ppf 4,700'-5,328' 8-1/2" hole cmt w/ 730 sks of Class G Openhole Casing 43' off bottom Tag (sticky) @ 10,905' SLM w/ 3.75" GR (3/08/14) Max Inclination: 40.6°@ 5,380' Casing Shoe @ 11,107' Tyonek Perforations: Zone MD TVD Size SPF Date B11 7,034'-7,040' 6,374'-6,379' 2-7/8" 6 09/09/21 B20_Up 8,215'-8,220' 7,379'-7,384' 2-7/8" 6 06/22/21 B20_Lwr 8,289'-8,302' 7,444'-7,458' 2-7/8" 6 06/22/21 B22 8,425'-8,433' 7,569'-7,577' 2-7/8" 6 06/22/21 B22_Lwr 8,478'-8,487' 7,618'-7,626' 2-7/8" 6 09/09/21 B23 8,530'-8,555' 7,665'-7,688' 2-7/8" 6 10/28/19 B24_Up 8,588'-8,595' 7,719'-7,725' 2-7/8" 6 10/28/19 B24 8,645'-8,657' 7,612'-7,624' 2-7/8" 6 08/21/18 B26_Up 8,673'-8,682' 7,797'- 7,806' 2-7/8" 6 06/22/21 B26 8,758'-8,763' 7,878'-7,883' 2-7/8" 6 04/02/21 B27 8,789'-8,800' 7,907'-7,917' 2-7/8" 6 04/02/21 B28 8,931'-8,939' 8,041'-8,049' 2-7/8" 6 04/02/21 B29_Up 9,027'-9,033' 8,131'-8,137' 2-7/8" 6 09/09/21 B29 9,179'-9,189' 8,280'-8,290' 2-7/8" 6 08/27/15 B30 9,216'-9,226' 8,315'-8,325' 2-7/8" 6 08/27/15 B31 9,276'-9,291' 8,374'-8,388' 2-7/8" 6 08/27/15 Isolated Perfs: B32 9,617'-9,625' 8,707'-8,715' 2-7/8" 12 04/03/14 Tyonek 10,231'-10,251' 9,317'-9,337' 2-7/8" 12 03/15/14 B32 Plug @ 10,200' MD Capped w/ 10' of cement Plug @ 9,560' MD Capped w/ 41' of cement B11 B20-B24 B26-B29 B30-B31 Superseded Superseded Lease: State/Prov:Alaska Country:USA Angle/Perfs:N/A 138.4' 18.6' 8/18/2025Revised By:Ryan LeMay Downhole Revision Date:Schematic Revision Date: Angle @KOP and Depth:34º @ 5,238'Maximum Deviation:40.6º @ 5,3880' Date Completed:3/5/2014 Ground Level (above MSL):RKB (above GL): Well Name & Number:Beaver Creek Unit #1B A - 028083 County or Parish:Kenai Peninsula Borough BC-01B Pad 1A 117' FSL, 1,338' FEL Sec. 33, T7N, R10W, S.M.Permit #: 214-001 API #: 50-133-20006-01-00 Property Des: A-028083 KB Elevation: 157.0' (18.6' AGL) Spud Date: 02/15/14 Rig Released: 03/07/14 Tree cxn = 6-1/2" Otis PBTD 9,519' MD 8,610' TVD TD 11,150' MD 10,233' TVD Conductor 20" H-40 94 ppf Top Bottom MD 0' 530' TVD 0' 530' 26" hole cmt w/ 1,000 sks of Class G Surface Casing 13-3/8" J-55 61 ppf BTC MD 0' 2,224' TVD 0' 2,224' 18-5/8" hole cmt w/ 3,500 sks of Class G Intermediate Casing 9-5/8" N-80 40/43.5 ppf BTC MD 0' 5,134' TVD 0' 4,787' 12-1/4" hole cmt w/ 1,100 sks of Class G Cmt w/ 700 sks thru DV Collar @ 2,080' Production Liner 4-1/2" L-80 / P-110 12.6 / 13.5 ppf BTC / DWC/C MD 0' 11,107' TVD 0' 10,190' 4-1/2" P-110 13.5 ppf 0'-10,860' 4-1/2" L-80 12.6 ppf 10,860'-11,107' 6"x7" hole cmt w/ 205 bbls 15.8 ppg Class G SCHEMATIC Swell Packer @ 4,543'-4,565' MD TOC (3/08/14 SCMT) - 4,312' Max Dogleg: 8.98°/100' @ 5,318' Production Casing 7" N-80 / P-110 26 / 29 ppf BTC MD 0' 5,238' TVD 0' 4,873' 7" N-80 26 ppf 0'-4,700' 7" N-80 29 ppf 4,700'-5,328' 8-1/2" hole cmt w/ 730 sks of Class G Openhole Casing 43' off bottom Tag (sticky) @ 10,905' SLM w/ 3.75" GR (3/08/14) Max Inclination: 40.6° @ 5,380' Casing Shoe @ 11,107' Tyonek Perforations: Zone MD TVD Size SPF Date B11 7,034'-7,040' 6,374'-6,379' 2-7/8" 6 09/09/21 B20_Up 8,215'-8,220' 7,379'-7,384' 2-7/8" 6 06/22/21 B20_Lwr 8,289'-8,302' 7,444'-7,458' 2-7/8" 6 06/22/21 B22 8,425'-8,433' 7,569'-7,577' 2-7/8" 6 06/22/21 B22_Lwr 8,478'-8,487' 7,618'-7,626' 2-7/8" 6 09/09/21 B23 8,530'-8,555' 7,665'-7,688' 2-7/8" 6 10/28/19 B24_Up 8,588'-8,595' 7,719'-7,725' 2-7/8" 6 10/28/19 B24 8,645'-8,657' 7,612'-7,624' 2-7/8" 6 08/21/18 B26_Up 8,673'-8,682' 7,797'- 7,806' 2-7/8" 6 06/22/21 B26 8,758'-8,763' 7,878'-7,883' 2-7/8" 6 04/02/21 B27 8,789'-8,800' 7,907'-7,917' 2-7/8" 6 04/02/21 B28 8,931'-8,939' 8,041'-8,049' 2-7/8" 6 04/02/21 B29_Up 9,027'-9,033' 8,131'-8,137' 2-7/8" 6 09/09/21 B29 9,179'-9,189' 8,280'-8,290' 2-7/8" 6 08/27/15 B30 9,216'-9,226' 8,315'-8,325' 2-7/8" 6 08/27/15 B31 9,276'-9,291' 8,374'-8,388' 2-7/8" 6 08/27/15 Isolated Perfs: B32 9,617'-9,625' 8,707'-8,715' 2-7/8" 12 04/03/14 Tyonek 10,231'-10,251' 9,317'-9,337' 2-7/8" 12 03/15/14 B32 Plug @ 10,200' MD Capped w/ 10' of cement Plug @ 9,560' MD Capped w/ 41' of cement B11 B20-B24 B26-B29 B30-B31 20" 13-3/8" 9-5/8" 7" (Sidetrack Window) TOW = 5238' MD BOW = 5251' MD 4-1/2" 7" Proposed Perforations: Well Sand Top MD Btm MD Top TVD Btm TVD Interval BCU-01B BEL16L ±7,982’ ±7,996’ ±7,173' ±7,185' ±14' BCU-01B BEL17 ±8,016’ ±8,030’ ±7,202' ±7,215' ±14' BCU-01B BEL18 ±8,088’ ±8,102’ ±7,266' ±7,279' ±14' BCU-01B BEL18 ±8,127’ ±8,133’ ±7,301' ±7,307' ±6' BCU-01B BEL19 ±8,137’ ±8,142’ ±7,310' ±7,315' ±5' BCU-01B BEL19 ±8,154’ ±8,159’ ±7,326' ±7,330' ±5' BCU-01B BEL19 ±8,177’ ±8,202’ ±7,346' ±7,369' ±25' BCU-01B BEL20 ±8,227’ ±8,233’ ±7,392' ±7,397' ±6' BCU-01B BEL20 ±8,240’ ±8,257’ ±7,403' ±7,419' ±17' BCU-01B BEL20 ±8,370’ ±8,375’ ±7,521' ±7,525' ±5' BCU-01B BEL22 ±8,506’ ±8,512’ ±7,645' ±7,650' ±6' BCU-01B BEL28 ±8,884’ ±8,889’ ±7,997' ±8,001' ±5' BCU-01B BEL28 ±8,897’ ±8,903’ ±8,009' ±8,015' ±6' BCU-01B BEL28L ±8,995’ ±8,999’ ±8,102' ±8,106' ±4' BCU-01B BEL29 ±9,042’ ±9,047’ ±8,147' ±8152' ±5' BCU-01B BEL29L ±9,092’ ±9,100’ ±8,195' ±8,203' ±8' BCU-01B BEL29L ±9,107’ ±9,123’ ±8,210' ±8,225' ±16' BCU-01B BEL33 ±9,373’ ±9,390’ ±8,468' ±8,484' ±17' 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. 1 Christianson, Grace K (OGC) From:Ryan Lemay <ryan.lemay@hilcorp.com> Sent:Monday, August 18, 2025 2:20 PM To:McLellan, Bryan J (OGC) Cc:Donna Ambruz Subject:RE: [EXTERNAL] BCU 1B (PTD 214-001) wellbore diagram Attachments:BCU-01B Schematic 08-15-25 -Proposed.pdf; BCU-01B Schematic 09-02-21.pdf; 4 5 Casing Tally_Final.xls Bryan, Attached are the revised Wellbore Schematics (Current and proposed) to clarify your email below. Apologies for the discrepancy on this. x BCU 1B was sidetracked (parent wellbore BCU 1A) in 2014. x A whipstock was set just below the 9-5/8” shoe in the 7” parent production casing: o Top of Window at 5238’ MD / 4873’ TVD o Bottom of Window is at 5251’MD, o They drilled rat hole to 5275’ MD and performed a 11.0 ppg EMW LOT x The 4-1/2” swell packer depth of 4543’ MD is correct per the Ʊnal casing tally (attached for reference). The revised and corrected schematics should now accurately reƲect where everything sets relative to one another especially more clearly around the sidetrack window in the 7”, 9-5/8” shoe, and 4-1/2” swell packer in the 7” Let me know if you have further questions reviewing this. Thanks, Ryan LeMay OperaƟons Engineer Swanson River / Beaver Creek Cell: (661) 487-0871 E-mail: Ryan.lemay@hilcorp.com To help protect your privacy, Microsoft Office prevented automatic download of this picture from the Internet. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, August 18, 2025 10:09 AM To: Ryan Lemay <ryan.lemay@hilcorp.com> Subject: [EXTERNAL] BCU 1B (PTD 214-001) wellbore diagram Ryan, I’m looking at the sundry application for perforations on this well and noticed there are some issues with the wellbore diagram. The diagram shows a 9-5/8” casing to 5134’ MD but what I assume is a 4-1/2” x 7” swell packer is at 4543’ MD. The diagram doesn’t show what I believe is the 9-5/8” casing shoe in the correct place relative to the swell packer, so I’m not really sure what’s what on the diagram. You also mentioned a sidetrack at 5275’, but there’s no indication of a sidetrack on the diagram. Can you provide a wellbore diagram that indicates which casing string is which and indicates that this well was sidetracked and where, MD & TVD? Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 11/02/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 01B (PTD 214-001) Perf 09/09/2021 Please include current contact information if different from above. 37' (6HW Received By: d 12/07/2021 By Abby Bell at 3:29 pm, Dec 07, 2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,150 feet 9,560 & 10,200 feet true vertical 10,233 feet N/A feet Effective Depth measured 9,519 feet 4,543 feet true vertical 8,610 feet 4,339 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 13.5# / P-110 10,860' MD 9,944' TVD Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 11,107' MD 10,190' TVD Packers and SSSV (type, measured and true vertical depth)Swell Packer; N/A 4,543' MD 4,339' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email:todd.sidoti@hilcorp.com Contact Phone:777-8442 WINJ WAG 673 Water-Bbl MD 530' 2,224' 7 Oil-Bbl measured true vertical Packer 7"5,238' 4,787' 4,873' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Beaver Creek / Tyonek Gas PoolN/A measured TVD Tubing Pressure 884 Beaver Creek Unit (BCU) 01B N/A FEDA028083; FEDA028118 5,134' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-001 50-133-2006-01-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-428 1,191 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 50 Authorized Signature with date: Authorized Name: 110 Casing Pressure Liner 3,062 0 Representative Daily Average Production or Injection Data 530' 2,224' 5,134' 5,238' Conductor Surface Intermediate Production 5,410psi Casing Structural 20" 13-3/8" 9-5/8" Length 3,090psi Collapse 520psi 1,540psi 3,090psi Senior Engineer:Senior Res. Engineer: Burst 1,530psi 7,240psi 530' 2,224' 5,750psi t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 1:36 pm, Sep 30, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.09.30 12:57:12 -08'00' Taylor Wellman (2143) SFD 10/5/2021 50-133-20006-01-00 SFD 10/5/2021 RBDMS HEW 10/1/2021 DSR-9/30/21 SFD 10/5/2021 BJM 11/4/21 Beluga Gas Pool Rig Start Date End Date E-Line 9/9/21 9/9/21 09/09/2021 - Thursday Sign in. Mobe to location. PTW, JSA and SIMOPS. Spot equipment and rig up lubricator. PT lubricator tp 250 psi low and 3,000 psi high. FTP/Rate - 105 psi/1mm. RIH w/ Gun #1, 2-7/8" x 6' HC, 6 spf, 60 deg phase and tie into OHL LAS. Run correlation log and send to town. Get ok to perf from 9,027' to 9,033' (B29_Upper). Spotted and fired shot with 102 FTP/915mcf rate. After 5 min - 102/920mcf, 10 min - 104/878mcf and 15 min - 105/940 mcf. POOH. All shots fired/gun wet. RIH w/Gun #2, 2-7/8" x 9' HC, 6 spf, 60 deg phase and tie into OHL LAS. Run correlation log and send to town. Get ok to perf from 8,478' to 8,487' (B22_Lwr). Spot gun and fire w/105 FTP/960mcf. After 5 min - 105/963mcf, 10 min - 104/900mcf and 15 min - 104 FTP/901mcf. POOH. All shots fired/Gun Wet. Waiting on Yellowjacket to build a 6' gun and bring it out to location. RIH w/Gun #3, 2-7/8" x 6' HC, 6 spf, 60 deg phase and tie into OHL LAS. Run correlation log and send to town. Got ok to perf (B11_1 sand) w/106 FTP/937 mcf from 7,034' to 7,040'. Spot and fire gun. Started building fast going from 392 psi/2mm, 725 FTP/4.2mm and 750 psi/6.2mm. POOH. All shots fired/Gun wet. Rig down lubricator and equipment. Turn over to field. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU-01B 50-133-20006-01-00 214-001 o perf (B11_1 sand) w/106 FTP/937 mcf from 7,034' to f 7,040'. Spot and fire gun. S o perf from 8,478' to 8,487' (B22_Lwr). Spot gun and fire w o perf from 9,027' to 9,033' (B29_Upper). Spotted and fired shot w Lease: State/Prov:Alaska Country:USA Angle/Perfs:N/A 138.4' 18.6' 9/16/2021Revised By:Donna Ambruz Downhole Revision Date:Schematic Revision Date: Angle @KOP and Depth:34º @ 5,238'Maximum Deviation:40.6º @ 5,3880' Date Completed:3/5/2014 Ground Level (above MSL):RKB (above GL): Well Name & Number:Beaver Creek Unit #1B A - 028083 County or Parish:Kenai Peninsula Borough BC-01B Pad 1A 117' FSL, 1,338' FEL Sec. 33, T7N, R10W, S.M.Permit #: 214-001 API #: 50-133-20006-01-00 Property Des: A-028083 KB Elevation: 157.0' (18.6' AGL) Spud Date: 02/15/14 Rig Released: 03/07/14 Tree cxn = 6-1/2" Otis PBTD 9,519' MD 8,610' TVD TD 11,150' MD 10,233' TVD Conductor 20" H-40 94 ppf Top Bottom MD 0' 530' TVD 0' 530' 26" hole cmt w/ 1,000 sks of Class G Surface Casing 13-3/8" J-55 61 ppf BTC MD 0' 2,224' TVD 0' 2,224' 18-5/8" hole cmt w/ 3,500 sks of Class G Intermediate Casing 9-5/8" N-80 40/43.5 ppf BTC MD 0' 5,134' TVD 0' 4,787' 12-1/4" hole cmt w/ 1,100 sks of Class G Cmt w/ 700 sks thru DV Collar @ 2,080' Production Liner 4-1/2" L-80 / P-110 12.6 / 13.5 ppf BTC / DWC/C MD 0' 11,107' TVD 0' 10,190' 4-1/2" P-110 13.5 ppf 0'-10,860' 4-1/2" L-80 12.6 ppf 10,860'-11,107' 6"x7" hole cmt w/ 205 bbls 15.8 ppg Class G SCHEMATIC Swell Packer @ 4,543'-4,565' MD TOC (3/08/14 SCMT) - 4,312' Max Dogleg: 8.98°/100' @ 5,318' Production Casing 7" N-80 / P-110 26 / 29 ppf BTC MD 0' 5,238' TVD 0' 4,873' 7" N-80 26 ppf 0'-4,700' 7" N-80 29 ppf 4,700'-5,328' 8-1/2" hole cmt w/ 730 sks of Class G Openhole Casing 43' off bottom Tag (sticky) @ 10,905' SLM w/ 3.75" GR (3/08/14) Max Inclination: 40.6°@ 5,380' Casing Shoe @ 11,107' Tyonek Perforations: Zone MD TVD Size SPF Date B11 7,034'-7,040' 6,374'-6,379' 2-7/8" 6 09/09/21 B20_Up 8,215'-8,220' 7,379'-7,384' 2-7/8" 6 06/22/21 B20_Lwr 8,289'-8,302' 7,444'-7,458' 2-7/8" 6 06/22/21 B22 8,425'-8,433' 7,569'-7,577' 2-7/8" 6 06/22/21 B22_Lwr 8,478'-8,487' 7,618'-7,626' 2-7/8" 6 09/09/21 B23 8,530'-8,555' 7,665'-7,688' 2-7/8" 6 10/28/19 B24_Up 8,588'-8,595' 7,719'-7,725' 2-7/8" 6 10/28/19 B24 8,645'-8,657' 7,612'-7,624' 2-7/8" 6 08/21/18 B26_Up 8,673'-8,682' 7,797'- 7,806' 2-7/8" 6 06/22/21 B26 8,758'-8,763' 7,878'-7,883' 2-7/8" 6 04/02/21 B27 8,789'-8,800' 7,907'-7,917' 2-7/8" 6 04/02/21 B28 8,931'-8,939' 8,041'-8,049' 2-7/8" 6 04/02/21 B29_Up 9,027'-9,033' 8,131'-8,137' 2-7/8" 6 09/09/21 B29 9,179'-9,189' 8,280'-8,290' 2-7/8" 6 08/27/15 B30 9,216'-9,226' 8,315'-8,325' 2-7/8" 6 08/27/15 B31 9,276'-9,291' 8,374'-8,388' 2-7/8" 6 08/27/15 Isolated Perfs: B32 9,617'-9,625' 8,707'-8,715' 2-7/8" 12 04/03/14 Tyonek 10,231'-10,251' 9,317'-9,337' 2-7/8" 12 03/15/14 B32 Plug @ 10,200' MD Capped w/ 10' of cement Plug @ 9,560' MD Capped w/ 41' of cement B11 B20-B24 B26-B29 B30-B31 09/09/21B11 7,034'-7,040' 6,374'-6,379' 2-7/8" 6 09/09/21 06/22/21B20_Up 8,215'-8,220' 7,379'-7,384' 2-7/8" 6 006/22/21 06/22/21B20_Lwr 8,289'-8,302' 7,444'-7,458' 2-7/8" 6 0 06/22/21B22 8,425'-8,433' 7,569'-7,577' 2-7/8" 6 09/09/21B22 Lwr 8,478'-8,487' 7,618'-7,626' 2-7/8" 6 009/09/21_,, ,, ,, ,, 06/22/21B26_Up 8,673'-8,682' 7,797'- 7,806' 2-7/8" 6 006/22/21 08/21/18B24 8,645 8,657 7,612 7,624 27/8 6 _p ,, ,, 09/09/21B29_Up 9,027'-9,033' 8,131'-8,137' 2-7/8" 6 009/09/21 04/02/21B28 8,931 8,939 8,041 8,049 27/8 6 08/27/15B29 9 179' 9 189' 8 280' 8 290' 2 7/8" 6 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 11,150'N/A Casing Collapse Structural Conductor 520 psi Surface 1,540 psi Intermediate 3,090 psi Production 5,410 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: September 10, 2021 4-1/2" 5,238' Perforation Depth MD (ft): 5,134' See Attached Schematic 5,238' 4,873'7" 20" 13-3/8" 530' 9-5/8"5,134' 2,224' 1,530 psi 3,090 psi 530' 2,224' 4,787' 530' 2,224' P-110 / L-80 (13.5# / 12.6#) TVD Burst 10,860' / 11,107' 7,240 psi MD 5,750 psi Length Size CO 237B.000 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028083; FEDA028118 214-001 50-133-20006-01-00 Beaver Creek Unit (BCU) 01B Beaver Creek / Beluga Gas COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic todd.sidoti@hilcorp.com 10,233'9,560'8,651'2,073 9,560' & 10,200' Swell Packer; N/A 4,543' MD - 4,339' TVD; N/A Perforation Depth TVD (ft): Tubing Size: wwnn amamm eee d ed ss No ss No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:27 am, Aug 26, 2021 321-428 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.08.25 22:32:34 -08'00' Taylor Wellman (2143) 10-404 BJM 9/1/21 DSR-8/26/21SFD 8/26/2021 dts 9/1/2021 JLC 9/2/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.02 13:55:36 -08'00' RBDMS HEW 9/3/2021 Well Prognosis Well: BCU-1B Date: 08/25/2021 Well Name: BCU-1B API Number: 50-133-20006-01 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: September 10, 2021 Rig: N/A (E-line) Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-001 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (C) Second Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) AFE Number: 212-00327 Maximum Expected BHP: ~ 2710 psi @ ±6,373’ TVD Max. Potential Surface Pressure: ~ 2073 psi (Based on offset RFT data minus a gas gradient to surface (0.10 psi/ft)) Well Status BCU-01B is currently a Lower Beluga gas producer currently producing 900 MCFD @ 115 psi with ~5 bbls of water Brief Well Summary BCU-01B drilled and completed in 2014 initially targeting the Tyonek formation. However, the Tyonek proved to be non-productive and was plug backed to the Lower Beluga. The well came online in the B32 making just over 3.5 MMCFD with little to no water. The zone cum’d just over 300 MMCF and 1100 bbls of water before dying off. The well was plug back and three LB sands (B29, B30 & B31) were perforated with only the B29 being productive. The LB-24 lower sand was added when the well had declined to about 350 MCFD in September 2018. The well was making about 720 mcfd and has declined to ~ 500 mcfd. In October 2019, the LB-24 sand and the LB-23 were perforated while flowing at 400 mcfd @ 75 psi. The tbg pressure eventually climbed to about 130 psi and 1.1 MCFD. In April 2021, the LB 28, 27 and 26 were perforated while flowing adding a combine 240 MCFD. Again in June, three more Beluga sands were added taking the rate back up to about 930 MCFD. Attached below is the critical velocity calcs which show we are below the critical unloading rate. BCU-01B has cum’d 1.85 BCF to date. The objective of this work is to add the Lower Beluga sands thru tbg. RIH w/ perf guns on Eline and selectively perforate while flowing; evaluating each prior to moving to next interval. Notes Regarding Wellbore Condition x Last tag @ 9,455’ KB drift w/ 2.25” gauge ring on 7/27/2018 x Minimum ID is 3.920” E-line Procedure: 1. RU E-Line, PT Lubricator 250 low/3000 psi high. Perforate below zones from the bottom up using 2-7/8” HSC guns with the well flowing: Lower Beluga gas producer c add the Lower Beluga sands thru tbg. Well Prognosis Well: BCU-1B Date: 08/25/2021 Sand TOP MD BOT MD Total TOP TVD BOT TVD B11_1 ±7,032’ ±7,041’ ±9’ ±6,373’ ±6,380’ B11_2 ±7,055’ ±7,064’ ±9’ ±6,391’ ±6,399’ B11_3 ±7,157’ ±7,179’ ±22’ ±6,474’ ±6,493’ B11_4 ±7,224’ ±7,235’ ±11’ ±6,530’ ±6,539’ B14 ±7,550’ ±7,584’ ±34’ ±6,800’ ±6,829’ B22_Mid ±8,440’ ±8,457’ ±17’ ±7,583’ ±7,598’ B22_Lwr ±8,475’ ±8,488’ ±13’ ±7,615’ ±7,628’ B26 ±8,687’ ±8,705’ ±18’ ±7,810’ ±7,818’ B29_Upper ±9,027’ ±9,034’ ±7’ ±8,131’ ±8,138’ a. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. b. Use GR/CCL to correlate against Open Hole Log provided by Geologist. Send the correlation pass to the following for confirmation. Reservoir Engineer Trudi Hallett 907.301.6657 Geologist Jeff Nelson 307.760.8065 2. POOH and RD E-line. 3. Turn well over to production. E-Line Procedure (Contingency) 1. If these zones produce sand and/or water and need to be isolated: 2. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 3,000 psi High. 3. RIH and set 4-1/2” CIBP (or tubing patch) and dump 35’ of cement on top of the plug. Attachments: 1. Actual Schematic 2. Proposed Schematic Lease: State/Prov:Alaska Country:USA Angle/Perfs:N/A 138.4' 18.6' 6/30/2021Revised By:Donna Ambrz Downhole Revision Date:Schematic Revision Date: Angle @KOP and Depth:34º @ 5,238'Maximum Deviation:40.6º @ 5,3880' Date Completed:3/5/2014 Ground Level (above MSL):RKB (above GL): Well Name & Number:Beaver Creek Unit #1B A - 028083 County or Parish:Kenai Peninsula Borough BC-01B Pad 1A 117' FSL, 1,338' FEL Sec. 33, T7N, R10W, S.M.Permit #: 214-001 API #: 50-133-20006-01-00 Property Des: A-028083 KB Elevation: 157.0' (18.6' AGL) Spud Date: 02/15/14 Rig Released: 03/07/14 Tree cxn = 6-1/2" Otis PBTD 9,519' MD 8,610' TVD TD 11,150' MD 10,233' TVD Conductor 20" H-40 94 ppf Top Bottom MD 0' 530' TVD 0' 530' 26" hole cmt w/ 1,000 sks of Class G Surface Casing 13-3/8" J-55 61 ppf BTC MD 0' 2,224' TVD 0' 2,224' 18-5/8" hole cmt w/ 3,500 sks of Class G Intermediate Casing 9-5/8" N-80 40/43.5 ppf BTC MD 0' 5,134' TVD 0' 4,787' 12-1/4" hole cmt w/ 1,100 sks of Class G Cmt w/ 700 sks thru DV Collar @ 2,080' Production Liner 4-1/2" L-80 / P-110 12.6 / 13.5 ppf BTC / DWC/C MD 0' 11,107' TVD 0' 10,190' 4-1/2" P-110 13.5 ppf 0'-10,860' 4-1/2" L-80 12.6 ppf 10,860'-11,107' 6"x7" hole cmt w/ 205 bbls 15.8 ppg Class G SCHEMATIC Swell Packer @ 4,543'-4,565' MD TOC (3/08/14 SCMT) - 4,312' Max Dogleg: 8.98°/100' @ 5,318' Production Casing 7" N-80 / P-110 26 / 29 ppf BTC MD 0' 5,238' TVD 0' 4,873' 7" N-80 26 ppf 0'-4,700' 7" N-80 29 ppf 4,700'-5,328' Openhole Casing 43' off bottom Tag (sticky) @ 10,905' SLM w/ 3.75" GR (3/08/14) Max Inclination: 40.6°@ 5,380' Casing Shoe @ 11,107' Tyonek Perforations: Zone MD TVD Size SPF Date B20_Upper 8,215' - 8,220' 7,379' - 7,384' 2-7/8" 6 06/22/21 B20_Lower 8,289' - 8,302' 7,444' - 7,458' 2-7/8" 6 06/22/21 B22 8,425' - 8,433' 7,569' - 7,577' 2-7/8" 6 06/22/21 B26_Upper 8,673' - 8,682' 7,797' - 7,806' 2-7/8" 6 06/22/21 B-26 8,758'-8,763' 7,878'-7,883' 2-7/8" 6 04/02/21 B-27 8,789'-8,800' 7,907'-7,917' 2-7/8" 6 04/02/21 B-28 8,931'-8,939' 8,041'-8,049' 2-7/8" 6 04/02/21 LB-23 8,530'-8,555' 7,665'-7,688' 2-7/8" 6 10/28/19 LB-24_Up 8,588'-8,595' 7,719'-7,725' 2-7/8" 6 10/28/19 LB-24 8,645'-8,657' 7,612'-7,624' 2-7/8" 6 08/21/18 LB-29 9,179' - 9,189' 8,280'-8,290' 2-7/8" 6 08/27/15 LB-30 9,216' - 9,226' 8,315'-8,325' 2-7/8" 6 08/27/15 LB-31 9,276' - 9,291' 8,374'-8,388' 2-7/8" 6 08/27/15 Isolated Perfs: LB-32 9,617' - 9,625' 8,707'-8,715' 2-7/8" 12 04/03/14 Tyonek 10,231' - 10,251' 9,317'-9,337' 2-7/8" 12 03/15/14 LB-32 Plug @ 10,200' MD Capped w/ 10' of cement Plug @ 9,560' MD Capped w/ 41' of cement B20_U B20_L B-27 B-26 B-28 LB-23 LB-31 LB-30 LB-24 LB-29 LB-24_U B-22 B-26_U Lease: State/Prov:Alaska Country:USA Angle/Perfs:N/A 138.4' 18.6' 8/25/2021Revised By:Todd Sidoti Downhole Revision Date: Schematic Revision Date: Angle @KOP and Depth:34º @ 5,238'Maximum Deviation:40.6º @ 5,3880' Date Completed:3/5/2014 Ground Level (above MSL): RKB (above GL): Well Name & Number:Beaver Creek Unit #1B A - 028083 County or Parish:Kenai Peninsula Borough BC-01B Pad 1A 117' FSL, 1,338' FEL Sec. 33, T7N, R10W, S.M.Permit #: 214-001 API #: 50-133-20006-01-00 Property Des: A-028083 KB Elevation: 157.0' (18.6' AGL) Spud Date: 02/15/14 Rig Released: 03/07/14 Tree cxn = 6-1/2" Otis PBTD 9,519' MD 8,610' TVD TD 11,150' MD 10,233' TVD Conductor 20" H-40 94 ppf Top Bottom MD 0' 530' TVD 0' 530' 26" hole cmt w/ 1,000 sks of Class G Surface Casing 13-3/8" J-55 61 ppf BTC MD 0' 2,224' TVD 0' 2,224' 18-5/8" hole cmt w/ 3,500 sks of Class G Intermediate Casing 9-5/8" N-80 40/43.5 ppf BTC MD 0' 5,134' TVD 0' 4,787' 12-1/4" hole cmt w/ 1,100 sks of Class G Cmt w/ 700 sks thru DV Collar @ 2,080' Production Liner 4-1/2" L-80 / P-110 12.6 / 13.5 ppf BTC / DWC/C MD 0' 11,107' TVD 0' 10,190' 4-1/2" P-110 13.5 ppf 0'-10,860' 4-1/2" L-80 12.6 ppf 10,860'-11,107' 6"x7" hole cmt w/ 205 bbls 15.8 ppg Class G PROPOSED SCHEMATIC Swell Packer @ 4,543'-4,565' MD TOC (3/08/14 SCMT) - 4,312' Max Dogleg: 8.98°/100' @ 5,318' Production Casing 7" N-80 / P-110 26 / 29 ppf BTC MD 0' 5,238' TVD 0' 4,873' 7" N-80 26 ppf 0'-4,700' 7" N-80 29 ppf 4,700'-5,328' 8-1/2" hole cmt w/ 730 sks of Class G Openhole Casing 43' off bottom Tag (sticky) @ 10,905' SLM w/ 3.75" GR (3/08/14) Max Inclination: 40.6° @ 5,380' Casing Shoe @ 11,107' Tyonek Perforations: Zone MD TVD Size SPF Date B-11 7,032'-7,235' 6,373'-6,539' 2-7/8" 6 B-14 7,550'-7,584' 6,800'-6,829' 2-7/8" 6 B-18 8,069'-8,100' 7,248'-7,277' 2-7/8" 6 B-19 8,196'-8,197' 7,344'-7,365' 2-7/8" 6 B20_Upper 8,215' - 8,220' 7,379' - 7,384' 2-7/8" 6 06/22/21 B20_Mid 8,320'-8,225' 7,393'-7,415' 2-7/8" 6 B20_Lower 8,289' - 8,302' 7,444'-7,458' 2-7/8" 6 06/22/21 B22 8,425' - 8,433' 7,569'-7,577' 2-7/8" 6 06/22/21 B22_Mid 8,440'-8,457' 7,583'-7,598' 2-7/8" 6 B22_Lwr 8,475'-8,488' 7,615'-7,628' 2-7/8" 6 B26_Upper 8,673' - 8,682' 7,797' - 7,806' 2-7/8" 6 06/22/21 B-26 8,758'-8,763' 7,878'-7,883' 2-7/8" 6 04/02/21 B-27 8,789'-8,800' 7,907'-7,917' 2-7/8" 6 04/02/21 B-28 8,931'-8,939' 8,041'-8,049' 2-7/8" 6 04/02/21 LB-23 8,530'-8,555' 7,665'-7,688' 2-7/8" 6 10/28/19 LB-24_Up 8,588'-8,595' 7,719'-7,725' 2-7/8" 6 10/28/19 LB-24 8,645'-8,657' 7,612'-7,624' 2-7/8" 6 08/21/18 B26 8,687'-8,705' 7,810'-7,818' 2-7/8" 6 B28_Up 8,894'-8,904' 8,004'-8,014' 2-7/8" 6 B29_Up 9,027'-9,034' 8,131'-8,138' 2-7/8" 6 LB-29 9,179' - 9,189' 8,280'-8,290' 2-7/8" 6 08/27/15 LB-30 9,216' - 9,226' 8,315'-8,325' 2-7/8" 6 08/27/15 LB-31 9,276' - 9,291' 8,374'-8,388' 2-7/8" 6 08/27/15 Isolated Perfs: LB-32 9,617' - 9,625' 8,707'-8,715' 2-7/8" 12 04/03/14 Tyonek 10,231' - 10,251' 9,317'-9,337' 2-7/8" 12 03/15/14 LB-32 Plug @ 10,200' MD Capped w/ 10' of cement Plug @ 9,560' MD Capped w/ 41' of cement David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Hilcorp North Slope, LLC DATE: 07/21/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 1B (PTD 214-001) PERFORATING RECORD (Switch Guns) 06/22/2021 Please include current contact information if different from above. 37' (6HW eceived By: 07/21/2021 By Abby Bell at 2:20 pm, Jul 21, 2021 David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Hilcorp North Slope, LLC DATE: 07/21/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 1B (PTD 214-001) PERFORATING RECORD (Switch Guns) 06/22/2021 Please include current contact information if different from above. 37' (6HW eceived By: 07/21/2021 By Abby Bell at 2:20 pm, Jul 21, 2021 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 11,150'N/A Casing Collapse Structural Conductor 520 psi Surface 1,540 psi Intermediate 3,090 psi Production 5,410 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. W ell Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng todd.sidoti@hilcorp.com 10,233'9,560'8,651'1,775 9,560' & 10,200' Swell Packer; N/A 4,543' MD - 4,339' TVD; N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028083; FEDA028118 214-001 50-133-20006-01-00 Beaver Creek Unit (BCU) 01B Beaver Creek / Beluga Gas Length Size CO 237B.000 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY P-110 / L-80 (13.5# / 12.6#) TVD Burst 10,860' / 11,107' 7,240 psi MD 5,750 psi 1,530 psi 3,090 psi 530' 2,224' 4,787' 530' 2,224' 4,873'7" 20" 13-3/8" 530' 9-5/8"5,134' 2,224' 5,238' Perforation Depth MD (ft): 5,134' See Attached Schematic 5,238' Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: June 20, 2021 4-1/2" B No No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 7:49 am, Jun 07, 2021 321-282 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.06.04 16:14:16 -08'00' Taylor Wellman (2143) DSR-6/7/21DLB 06/09/2021 BJM 6/16/21 X 10-404 dts 6/16/2021 JLC 6/16/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.16 15:31:23 -08'00' RBDMS HEW 6/17/2021 Well Prognosis Well: BCU-1B Date: 06/3/2021 Well Name: BCU-1B API Number: 50-133-20006-01 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: June 20, 2021 Rig: N/A (E-line) Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-001 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (C) Second Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) AFE Number: 212-00327 Maximum Expected BHP: ~ 2500 psi @ ±7,248’ TVD Max. Potential Surface Pressure: ~ 1775 psi (Based on offset RFT data minus a gas gradient to surface (0.10 psi/ft)) Well Status BCU-01B is currently a Lower Beluga gas producer currently producing 660 MCFD with 3-5 bbls of water. Brief Well Summary BCU-01B drilled and completed in 2014 initially targeting the Tyonek formation. However, the Tyonek proved to be non-productive and was plug backed to the Lower Beluga. The well came online in the B32 making just over 3.5 MMCFD with little to no water. The zone cum’d just over 300 MMCF and 1100 bbls of water before dying off. The well was plug back and three LB sands (B29, B30 & B31) were perforated with only the B29 being productive. The LB-24 lower sand was added when the well had declined to about 350 MCFD in September 2018. The well was making about 720 mcfd and has declined to ~ 500 mcfd. In October 2019, the LB-24 sand and the LB-23 were perforated while flowing at 400 mcfd @ 75 psi. The tbg pressure eventually climbed to about 130 psi and 1.1 MCFD. In April 2021, the LB 28, 27 and 26 were perforated while flowing adding a combine 240 MCFD. The rate is falling off and appears to be loading up. Attached below is the critical velocity calcs which show we are well below the critical unloading rate. BCU-01B has cum’d 1.80 BCF to date. The objective of this work is to add the Lower Beluga sands thru tbg. RIH w/ perf guns on Eline and selectively perforate while flowing; evaluating each prior to moving to next interval. Notes Regarding Wellbore Condition x Last tag @ 9,455’ KB drift w/ 2.25” gauge ring on 7/27/2018 x Minimum ID is 3.920” (Drift is 3.795”) E-line Procedure: 1. RU E-Line, PT Lubricator 250 low/3000 psi high. Perforate below zones from the bottom up using 2-7/8” HSC guns with the well flowing: Well Prognosis Well: BCU-1B Date: 06/3/2021 Sand TOP MD BOT MD Total TOP TVD BOT TVD B18_Upper 8069 8077 8 7248 7256 B18_Mid 8087 8100 13 7264 7277 B19 8176 8197 21 7344 7365 B20_Upper 8213 8222 9 7376 7385 B20_Mid 8230 8255 25 7393 7415 B20_Lower 8289 8302 13 7445 7458 B22 8423 8435 12 7567 7578 B26_Upper 8668 8685 17 7798 7808 B28_Upper 8894 8904 10 8004 8014 a. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. b. Use GR/CCL to correlate against Open Hole Log provided by Geologist. Send the correlation pass to the following for confirmation. Reservoir Engineer Trudi Hallett 907.301.6657 Geologist Jeff Nelson 307.760.8065 2. POOH and RD E-line. 3. Turn well over to production. E-Line Procedure (Contingency) 1. If these zones produce sand and/or water and need to be isolated: 2. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 3,000 psi High. 3. RIH and set 4-1/2” CIBP (or tubing patch) and dump 35’ of cement on top of the plug. Attachments: 1. Actual Schematic 2. Proposed Schematic Lease: State/Prov:Alaska Country:USA Angle/Perfs:N/A 138.4' 18.6' 5/11/2021Revised By:Jake Flora Downhole Revision Date:Schematic Revision Date: Angle @KOP and Depth:34º @ 5,238'Maximum Deviation:40.6º @ 5,3880' Date Completed:3/5/2014 Ground Level (above MSL):RKB (above GL): Well Name & Number:Beaver Creek Unit #1B A - 028083 County or Parish:Kenai Peninsula Borough BC-1B Pad 1A 117' FSL, 1,338' FEL Sec. 33, T7N, R10W, S.M.Permit #: 214-001 API #: 50-133-20006-01-00 Property Des: A-028083 KB Elevation: 157.0' (18.6' AGL) Spud Date: 02/15/14 Rig Released: 03/07/14 Tree cxn = 6-1/2" Otis PBTD 11,023' MD 10,107' TVD TD 11,150' MD 10,233' TVD Conductor 20" H-40 94 ppf Top Bottom MD 0' 530' TVD 0' 530' 26" hole cmt w/ 1,000 sks of Class G Surface Casing 13-3/8" J-55 61 ppf BTC MD 0' 2,224' TVD 0' 2,224' 18-5/8" hole cmt w/ 3,500 sks of Class G Intermediate Casing 9-5/8" N-80 40/43.5 ppf BTC MD 0' 5,134' TVD 0' 4,787' 12-1/4" hole cmt w/ 1,100 sks of Class G Cmt w/ 700 sks thru DV Collar @ 2,080' Production Liner 4-1/2" L-80 / P-110 12.6 / 13.5 ppf BTC / DWC/C MD 0' 11,107' TVD 0' 10,190' 4-1/2" P-110 13.5 ppf 0'-10,860' 4-1/2" L-80 12.6 ppf 10,860'-11,107' 6"x7" hole cmt w/ 205 bbls 15.8 ppg Class G SCHEMATIC Swell Packer @ 4,543'-4,565' MD TOC (3/08/14 SCMT) - 4,312' Max Dogleg: 8.98°/100' @ 5,318' Production Casing 7" N-80 / P-110 26 / 29 ppf BTC MD 0' 5,238' TVD 0' 4,873' 7" N-80 26 ppf 0'-4,700' 7" N-80 29 ppf 4,700'-5,328' Openhole Casing 43' off bottom Tag (sticky) @ 10,905' SLM w/ 3.75" GR (3/08/14) Max Inclination: 40.6°@ 5,380' Casing Shoe @ 11,107' Tyonek Perforations: Zone MD TVD Size SPF Date B-26 8,758'-8,763' 7,878'-7,883' 2-7/8" 6 04/02/21 B-27 8,789'-8,800' 7,907'-7,917' 2-7/8" 6 04/02/21 B-28 8,931'-8,939' 8,041'-8,049' 2-7/8" 6 04/02/21 LB-23 8,530'-8,555' 7,665'-7,688' 2-7/8" 6 10/28/19 LB-24_Up 8,588'-8,595' 7,719'-7,725' 2-7/8" 6 10/28/19 LB-24 8,645'-8,657' 7,612'-7,624' 2-7/8" 6 08/21/18 LB-29 9,179' - 9,189' 8,280'-8,290' 2-7/8" 6 08/27/15 LB-30 9,216' - 9,226' 8,315'-8,325' 2-7/8" 6 08/27/15 LB-31 9,276' - 9,291' 8,374'-8,388' 2-7/8" 6 08/27/15 LB-32 9,617' - 9,625' 8,707'-8,715' 2-7/8" 12 04/03/14 Tyonek 10,231' - 10,251' 9,317'-9,337' 2-7/8" 12 03/15/14 LB-32 Plug @ 10,200' MD Capped w/ 10' of cement Plug @ 9,560' MD Capped w/ 41' of cement Lease: State/Prov:Alaska Country:USA Angle/Perfs:N/A 138.4' 18.6' 6/1/2021Revised By:Trudi Hallett Downhole Revision Date: Schematic Revision Date: Angle @KOP and Depth:34º @ 5,238'Maximum Deviation:40.6º @ 5,3880' Date Completed:3/5/2014 Ground Level (above MSL): RKB (above GL): Well Name & Number:Beaver Creek Unit #1B A - 028083 County or Parish:Kenai Peninsula Borough BC-1B Pad 1A 117' FSL, 1,338' FEL Sec. 33, T7N, R10W, S.M.Permit #: 214-001 API #: 50-133-20006-01-00 Property Des: A-028083 KB Elevation: 157.0' (18.6' AGL) Spud Date: 02/15/14 Rig Released: 03/07/14 Tree cxn = 6-1/2" Otis PBTD 11,023' MD 10,107' TVD TD 11,150' MD 10,233' TVD Conductor 20" H-40 94 ppf Top Bottom MD 0' 530' TVD 0' 530' 26" hole cmt w/ 1,000 sks of Class G Surface Casing 13-3/8" J-55 61 ppf BTC MD 0' 2,224' TVD 0' 2,224' 18-5/8" hole cmt w/ 3,500 sks of Class G Intermediate Casing 9-5/8" N-80 40/43.5 ppf BTC MD 0' 5,134' TVD 0' 4,787' 12-1/4" hole cmt w/ 1,100 sks of Class G Cmt w/ 700 sks thru DV Collar @ 2,080' Production Liner 4-1/2" L-80 / P-110 12.6 / 13.5 ppf BTC / DWC/C MD 0' 11,107' TVD 0' 10,190' 4-1/2" P-110 13.5 ppf 0'-10,860' 4-1/2" L-80 12.6 ppf 10,860'-11,107' 6"x7" hole cmt w/ 205 bbls 15.8 ppg Class G PROPOSED Swell Packer @ 4,543'-4,565' MD TOC (3/08/14 SCMT) - 4,312' Max Dogleg: 8.98°/100' @ 5,318' Production Casing 7" N-80 / P-110 26 / 29 ppf BTC MD 0' 5,238' TVD 0' 4,873' 7" N-80 26 ppf 0'-4,700' 7" N-80 29 ppf 4,700'-5,328' Openhole Casing 43' off bottom Tag (sticky) @ 10,905' SLM w/ 3.75" GR (3/08/14) Max Inclination: 40.6° @ 5,380' Casing Shoe @ 11,107' Tyonek Perforations: Zone MD TVD Size SPF Date B20_Upper ±8,213' - ±8,222' ±7,376' - ±7,385' TBD B22 ±8,423' - ±8,435' ±7,567' - ±7,578' TBD B26_Upper ±8,668' - ±8,685' ±7,798' - ±7,808' TBD B-26 8,758'-8,763' 7,878'-7,883' 2-7/8" 6 04/02/21 B-27 8,789'-8,800' 7,907'-7,917' 2-7/8" 6 04/02/21 B-28 8,931'-8,939' 8,041'-8,049' 2-7/8" 6 04/02/21 LB-23 8,530'-8,555' 7,665'-7,688' 2-7/8" 6 10/28/19 LB-24_Up 8,588'-8,595' 7,719'-7,725' 2-7/8" 6 10/28/19 LB-24 8,645'-8,657' 7,612'-7,624' 2-7/8" 6 08/21/18 LB-29 9,179' - 9,189' 8,280'-8,290' 2-7/8" 6 08/27/15 LB-30 9,216' - 9,226' 8,315'-8,325' 2-7/8" 6 08/27/15 LB-31 9,276' - 9,291' 8,374'-8,388' 2-7/8" 6 08/27/15 LB-32 9,617' - 9,625' 8,707'-8,715' 2-7/8" 12 04/03/14 Tyonek 10,231' - 10,251' 9,317'-9,337' 2-7/8" 12 03/15/14 LB-32 Plug @ 10,200' MD Capped w/ 10' of cement Plug @ 9,560' MD Capped w/ 41' of cement David Douglas Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: Hilcorp North Slope, LLC Date: 05/26/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Log Vendor BCU 10 50133204820000 200192 2/25/2021 PERF GAMMA RAY/GPT Yellowjacket BCU 10 50133204820000 200192 3/2/2021 SET PLUG/GPT Yellowjacket BCU 10 50133204820000 200192 3/9/2021 PERF Yellowjacket BCU 01B 50133200060100 214001 4/2/2021 PERF GAMMA RAY Yellowjacket Please include current contact information if different from above. PTD: 2140010 E-Set: 35168 06/01/2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,150 feet 9,560 & 10,200 feet true vertical 10,233 feet N/A feet Effective Depth measured 9,519 feet 4,543 feet true vertical 8,610 feet 4,339 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 13.5# / P-110 10,860' MD 9,944' TVD Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 11,107' MD 10,190' TVD Packers and SSSV (type, measured and true vertical depth)Swell Packer; N/A 4,543' MD 4,339' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Jake Flora Authorized Title:Operations Manager Contact Email: Contact Phone:777-8442 jake.flora@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 1,530psi 7,240psi 530' 2,224' 5,750psi 3,090psi Collapse 520psi 1,540psi 3,090psi 5,410psi Casing Structural 20" 13-3/8" 9-5/8" Length 530' 2,224' 5,134' 5,238' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 50 Casing Pressure Liner 769 0 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-141 107 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 45 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-001 50-133-2006-01-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 1000 Beaver Creek Unit (BCU) 01B N/A FEDA028083; FEDA028118 5,134' Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Beaver Creek / Tyonek Gas PoolN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 7"5,238' 4,787' 4,873' WINJ WAG 628 Water-Bbl MD 530' 2,224' 7 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:56 pm, May 19, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.05.19 15:13:50 -08'00' Taylor Wellman (2143) SFD 5/21/2021RBDMS HEW 5/20/2021 11,107' DSR-5/19/21 10,190' SFD 5/21/2021 4-1/2" BJM 9/27/21 Rig Start Date End Date 4/2/21 4/30/21 Sign in. Mobe to location. PTW and JSA. Spot and rig up equipment. PT lubricator to 250 psi low and 3,000 psi high. RIH w/3.60" GR and tie into OHL. Tag at 9,259'. Run correlation log and send to town. Told to add 2'. Added 2' and POOH. RIH w/ 2-7/8" x 8', Razar HC. 6 spf, 60 deg phase perf gun #1 and tie into OHL. Run correlation log and send to town. Get ok to perf from 8,931' to 8,939'. Spot and fire gun w/ 113 psi/750 mcfd. After 5 min - 113 psi/755 mcfd, 10 min - 113 psi/750 mcfd and 15 min - 112 psi/747 mcfd. POOH. All shots/gun was wet. RIH w/ 2-7/8" x 11', Razar HC. 6 spf, 60 deg phase perf gun #2 and tie into OHL. Run correlation log and send to town. Get ok to perf from 8,789' to 8,800'. Spot and fire gun w/112 psi/738 mcfd. After 5 min - 114 psi/952 mcfd, 10 min - 115 psi/956 mcfd and 15 min - 116 psi/932 mcfd. POOH. All shots/gun was wet. RIH w/ 2-7/8" x 5', Razar HC. 6 spf, 60 deg phase perf gun #3 and tie into OHL. Run correlation log and send to town. Get ok to perf from 8,758' to 8,763'. Spot and fire gun w/ 116 psi/899 mcfd. After 5 min - 117 psi/960 mcfd, 10 min - 117 psi/977 mcfd and 15 min - 117 psi/965 mcfd mcfd. POOH. All shots/gun was wet. Rig down lubricator and equipment. Turn well over to field. 04/30/2021- Friday Evaluating production curve for additional perforating. 04/02/2021- Friday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU-01B 50-133-20006-01 214-001 o perf from 8,758' to 8,763'. Spot and fire gun w perf from 8,789' to 8,800'. Spot and fire gun w o perf from 8,931' to 8,939'. Spot and fire gun w Lease: State/Prov:Alaska Country:USA Angle/Perfs:N/A 138.4' 18.6' 5/11/2021Revised By:Jake Flora Downhole Revision Date:Schematic Revision Date: Angle @KOP and Depth:34º @ 5,238'Maximum Deviation:40.6º @ 5,3880' Date Completed:3/5/2014 Ground Level (above MSL):RKB (above GL): Well Name & Number:Beaver Creek Unit #1B A - 028083 County or Parish:Kenai Peninsula Borough BC-1B Pad 1A 117' FSL, 1,338' FEL Sec. 33, T7N, R10W, S.M.Permit #: 214-001 API #: 50-133-20006-01-00 Property Des: A-028083 KB Elevation: 157.0' (18.6' AGL) Spud Date: 02/15/14 Rig Released: 03/07/14 Tree cxn = 6-1/2" Otis PBTD 11,023' MD 10,107' TVD TD 11,150' MD 10,233' TVD Conductor 20" H-40 94 ppf Top Bottom MD 0' 530' TVD 0' 530' 26" hole cmt w/ 1,000 sks of Class G Surface Casing 13-3/8" J-55 61 ppf BTC MD 0' 2,224' TVD 0' 2,224' 18-5/8" hole cmt w/ 3,500 sks of Class G Intermediate Casing 9-5/8" N-80 40/43.5 ppf BTC MD 0' 5,134' TVD 0' 4,787' 12-1/4" hole cmt w/ 1,100 sks of Class G Cmt w/ 700 sks thru DV Collar @ 2,080' Production Liner 4-1/2" L-80 / P-110 12.6 / 13.5 ppf BTC / DWC/C MD 0' 11,107' TVD 0' 10,190' 4-1/2" P-110 13.5 ppf 0'-10,860' 4-1/2" L-80 12.6 ppf 10,860'-11,107' 6"x7" hole cmt w/ 205 bbls 15.8 ppg Class G SCHEMATIC Swell Packer @ 4,543'-4,565' MD TOC (3/08/14 SCMT) - 4,312' Max Dogleg: 8.98°/100' @ 5,318' Production Casing 7" N-80 / P-110 26 / 29 ppf BTC MD 0' 5,238' TVD 0' 4,873' 7" N-80 26 ppf 0'-4,700' 7" N-80 29 ppf 4,700'-5,328' Openhole Casing 43' off bottom Tag (sticky) @ 10,905' SLM w/ 3.75" GR (3/08/14) Max Inclination: 40.6°@ 5,380' Casing Shoe @ 11,107' Tyonek Perforations: Zone MD TVD Size SPF Date B-26 8,758'-8,763' 7,878'-7,883' 2-7/8" 6 04/02/21 B-27 8,789'-8,800' 7,907'-7,917' 2-7/8" 6 04/02/21 B-28 8,931'-8,939' 8,041'-8,049' 2-7/8" 6 04/02/21 LB-23 8,530'-8,555' 7,665'-7,688' 2-7/8" 6 10/28/19 LB-24_Up 8,588'-8,595' 7,719'-7,725' 2-7/8" 6 10/28/19 LB-24 8,645'-8,657' 7,612'-7,624' 2-7/8" 6 08/21/18 LB-29 9,179' - 9,189' 8,280'-8,290' 2-7/8" 6 08/27/15 LB-30 9,216' - 9,226' 8,315'-8,325' 2-7/8" 6 08/27/15 LB-31 9,276' - 9,291' 8,374'-8,388' 2-7/8" 6 08/27/15 LB-32 9,617' - 9,625' 8,707'-8,715' 2-7/8" 12 04/03/14 Tyonek 10,231' - 10,251' 9,317'-9,337' 2-7/8" 12 03/15/14 LB-32 Plug @ 10,200' MD Capped w/ 10' of cement Plug @ 9,560' MD Capped w/ 41' of cement 04/02/21B-26 8,758'-8,763' 7,878'-7,883' 2-7/8" 6 04/02/21B-27 8,789'-8,800' 7,907'-7,917' 2-7/8" 6 04/02/21B-28 8,931'-8,939' 8,041'-8,049' 2-7/8" 6 04/02/21 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5. Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 11,150'N/A Casing Collapse Structural Conductor 520 psi Surface 1,540 psi Intermediate 3,090 psi Production 5,410 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Jake Flora Operations Manager Contact Email: Contact Phone: 777-8442 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: April 5, 2021 4-1/2" 5,238' Perforation Depth MD (ft): 5,134' See Attached Schematic 5,238'4,873'7" 20" 13-3/8" 530' 9-5/8"5,134' 2,224' 1,530 psi 3,090 psi 530' 2,224' 4,787' 530' 2,224' P-110 / L-80 (13.5# / 12.6#) TVD Burst 10,860' / 11,107' 7,240 psi MD 5,750 psi Length Size CO 237A.000 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028083; FEDA028118 214-001 50-133-20006-01 Beaver Creek Unit (BCU) 01B Beaver Creek / Tyonek Undef Gas COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic jake.flora@hilcorp.com 10,233'9,560'8,651'1,775 9,560' & 10,200' Swell Packer; N/A 4,543' MD - 4,339' TVD; N/A Perforation Depth TVD (ft): Tubing Size: Perforate Reppair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Wellbore schematic Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:51 am, Mar 22, 2021 321-141 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.03.22 07:51:14 -08'00' Taylor Wellman (2143) B SFD 3/22/2021SFD 3/22/2021 -00 SFD 3/22/2021 DSR-3/22/21BJM 3/26/21 10-404 dts 3/26/2021 3/26/21 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.03.26 15:11:35 -08'00' RBDMS HEW 3/26/2021 Well Prognosis Well: BCU-1B Date: 03/19/2021 Well Name: BCU-1B API Number: 50-133-20006-01 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: April 5th, 2021 Rig: N/A (E-line) Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-001 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) AFE Number: Maximum Expected BHP: ~ 2500 psi @ ±7,248’ TVD Max. Potential Surface Pressure: ~ 1775 psi (Based on offset RFT data minus a gas gradient to surface (0.10 psi/ft)) Well Status BCU-01B is currently a Lower Beluga gas producer currently producing 700 MCFD with little to no water. Brief Well Summary BCU-01B drilled and completed in 2014 initially targeting the Tyonek formation. However, the Tyonek proved to be non-productive and was plug backed to the Lower Beluga. The well came online in the B32 making just over 3.5 MMCFD with little to no water. The zone cum’d just over 300 MMCF and 1100 bbls of water before dying off. The well was plug back and three LB sands (B29, B30 & B31) were perforated with only the B29 being productive. The LB-24 lower sand was added when the well had declined to about 350 MCFD in September 2018. The well was making about 720 mcfd and has declined to ~ 500 mcfd. In October 2019, the LB-24 sand and the LB-23 were perforated while flowing at 400 mcfd @ 75 psi. The tbg pressure eventually climbed to about 130 psi and 1.1 MCFD. BCU-01B has cum’d 1.74 BCF to date. The objective of this work is to add the Lower Beluga sands thru tbg. RIH w/ perf guns on Eline and selectively perforate while flowing; evaluating each prior to moving to next interval. Notes Regarding Wellbore Condition x Last tag @ 9,455’ KB drift w/ 2.25” gauge ring on 7/27/2018 x Minimum ID is 3.920” (Drift is 3.795”) E-line Procedure: 1. RU E-Line, PT Lubricator 250 low/3000 psi high. Perforate below zones from the bottom up: 2. Sand TOP MD BOT MD Total TOP TVD BOT TVD B18_Upper 8069 8077 8 7248 7256 B18_Mid 8087 8100 13 7264 7277 B19 8176 8197 21 7344 7365 B20_Upper 8213 8222 9 7376 7385 B20_Mid 8230 8255 25 7393 7415 B22 8423 8435 12 7567 7578 B26_Upper 8668 8685 17 7798 7808 B26_Lower 8759 8765 6 7877 7883 B27 8789 8805 16 7906 7921 Well Prognosis Well: BCU-1B Date: 03/19/2021 B28_Upper 8894 8904 10 8004 8014 B28_Mid 8929 8942 13 8038 8050 a. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. b. Use GR/CCL to correlate against Open Hole Log provided by Geologist. Send the correlation pass to the following for confirmation. Reservoir Engineer Trudi Hallett 907.301.6657 Geologist Ben Siks 907.229.0865 3. POOH and RD E-line. 4. Turn well over to production. E-Line Procedure (Contingency) 1. If these zones produce sand and/or water and need to be isolated: 2. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 3,000 psi High. 3. RIH and set 4-1/2” CIBP (or tubing patch) and dump 35’ of cement on top of the plug. Attachments: 1. Actual Schematic 2. Proposed Schematic Lease: State/Prov:Alaska Country:USA Angle/Perfs:N/A 138.4' 18.6' 11/13/2019Revised By:Donna Ambruz Downhole Revision Date:Schematic Revision Date: Angle @KOP and Depth:34º @ 5,238'Maximum Deviation:40.6º @ 5,3880' Date Completed:3/5/2014 Ground Level (above MSL):RKB (above GL): Well Name & Number:Beaver Creek Unit #1B A - 028083 County or Parish:Kenai Peninsula Borough BC-1B Pad 1A 117' FSL, 1,338' FEL Sec. 33, T7N, R10W, S.M.Permit #: 214-001 API #: 50-133-20006-01-00 Property Des: A-028083 KB Elevation: 157.0' (18.6' AGL) Spud Date: 02/15/14 Rig Released: 03/07/14 Tree cxn = 6-1/2" Otis PBTD 11,023' MD 10,107' TVD TD 11,150' MD 10,233' TVD Conductor 20" H-40 94 ppf Top Bottom MD 0' 530' TVD 0' 530' 26" hole cmt w/ 1,000 sks of Class G Surface Casing 13-3/8" J-55 61 ppf BTC Top Bottom MD 0' 2,224' TVD 0' 2,224' 18-5/8" hole cmt w/ 3,500 sks of Class G Intermediate Casing 9-5/8" N-80 40/43.5 ppf BTC Top Bottom MD 0' 5,134' TVD 0' 4,787' 12-1/4" hole cmt w/ 1,100 sks of Class G Cmt w/ 700 sks thru DV Collar @ 2,080' Production Liner 4-1/2" L-80 / P-110 12.6 / 13.5 ppf BTC / DWC/C Top Bottom MD 0' 11,107' TVD 0' 10,190' 4-1/2" P-110 13.5 ppf 0'-10,860' 4-1/2" L-80 12.6 ppf 10,860'-11,107' 6"x7" hole cmt w/ 205 bbls 15.8 ppg Class G SCHEMATIC Swell Packer @ 4,543'-4,565' MD TOC (3/08/14 SCMT) - 4,312' Max Dogleg: 8.98°/100' @ 5,318' Production Casing 7" N-80 / P-110 26 / 29 ppf BTC Top Bottom MD 0' 5,238' TVD 0' 4,873' 7" N-80 26 ppf 0'-4,700' 7" N-80 29 ppf 4,700'-5,328' 8-1/2" hole cmt w/ 730 sks of Class G Openhole Casing 43' off bottom Tag (sticky) @ 10,905' SLM w/ 3.75" GR (3/08/14) Max Inclination: 40.6°@ 5,380' Casing Shoe @ 11,107' Casing/Cementing Detail - 9.9 ppg Mud - 11.0 ppg Mud Push (35 bbl) - 15.8 ppg Cement (205 bbl) - 8.3 ppg Fresh Water (165 bbl) - 7.2 ppg Diesel (0.5 bbl) Tyonek Perforations: Zone MD TVD Size SPF Date LB-23 8,530'-8,555' 7,665'-7,688' 2-7/8" 6 10/28/19 LB-24_Up 8,588'-8,595' 7,719'-7,725' 2-7/8" 6 10/28/19 LB-24 8,645'-8,657' 7,612'-7,624' 2-7/8" 6 08/21/18 LB-29 9,179' - 9,189' 8,280'-8,290' 2-7/8" 6 08/27/15 LB-30 9,216' - 9,226' 8,315'-8,325' 2-7/8" 6 08/27/15 LB-31 9,276' - 9,291' 8,374'-8,388' 2-7/8" 6 08/27/15 LB-32 9,617' - 9,625' 8,707'-8,715' 2-7/8" 12 04/03/14 Tyonek 10,231' - 10,251' 9,317'-9,337' 2-7/8" 12 03/15/14 LB-32 Plug @ 10,200' MD Capped w/ 10' of cement Plug @ 9,560' MD Capped w/ 41' of cement LB-31A (LB-29) LB-31B (LB-30) LB-31C (LB-31) LB-24 LB-24_upper LB-23 Lease: State/Prov:Alaska Country:USA Angle/Perfs:N/A 138.4' 18.6' 3/17/2021 Well Name & Number:Beaver Creek Unit #1B A - 028083 County or Parish:Kenai Peninsula Borough Revised By:Trudi Hallett Downhole Revision Date: Schematic Revision Date: Angle @KOP and Depth:34º @ 5,238'Maximum Deviation:40.6º @ 5,3880' Date Completed:3/5/2014 Ground Level (above MSL): RKB (above GL): BC-1B Pad 1A 117' FSL, 1,338' FEL Sec. 33, T7N, R10W, S.M.Permit #: 214-001 API #: 50-133-20006-01-00 Property Des: A-028083 KB Elevation: 157.0' (18.6' AGL) Spud Date: 02/15/14 Rig Released: 03/07/14 Tree cxn = 6-1/2" Otis PBTD 11,023' MD 10,107' TVD TD 11,150' MD 10,233' TVD Conductor 20" H-40 94 ppf Top Bottom MD 0' 530' TVD 0' 530' 26" hole cmt w/ 1,000 sks of Class G Surface Casing 13-3/8" J-55 61 ppf BTC Top Bottom MD 0' 2,224' TVD 0' 2,224' 18-5/8" hole cmt w/ 3,500 sks of Class G Intermediate Casing 9-5/8" N-80 40/43.5 ppf BTC Top Bottom MD 0' 5,134' TVD 0' 4,787' 12-1/4" hole cmt w/ 1,100 sks of Class G Cmt w/ 700 sks thru DV Collar @ 2,080' Production Liner 4-1/2" L-80 / P-110 12.6 / 13.5 ppf BTC / DWC/C Top Bottom MD 0' 11,107' TVD 0' 10,190' 4-1/2" P-110 13.5 ppf 0'-10,860' 4-1/2" L-80 12.6 ppf 10,860'-11,107' 6"x7" hole cmt w/ 205 bbls 15.8 ppg Class G PROPOSED Swell Packer @ 4,543'-4,565' MD TOC (3/08/14 SCMT) - 4,312' Max Dogleg: 8.98°/100' @ 5,318' Production Casing 7" N-80 / P-110 26 / 29 ppf BTC Top Bottom MD 0' 5,238' TVD 0' 4,873' 7" N-80 26 ppf 0'-4,700' 7" N-80 29 ppf 4,700'-5,328' 8-1/2" hole cmt w/ 730 sks of Class G Openhole Casing 43' off bottom Tag (sticky) @ 10,905' SLM w/ 3.75" GR (3/08/14) Max Inclination: 40.6° @ 5,380' Casing Shoe @ 11,107' Casing/Cementing Detail - 9.9 ppg Mud - 11.0 ppg Mud Push (35 bbl) - 15.8 ppg Cement (205 bbl) - 8.3 ppg Fresh Water (165 bbl) - 7.2 ppg Diesel (0.5 bbl) Tyonek Perforations: Zone MD TVD Size SPF Date New Beluga (11 sands) Proposed Perf Adds ±8,069' to ±8,942' MD LB-23 8,530'-8,555' 7,665'-7,688' 2-7/8" 6 10/28/19 LB-24_Up 8,588'-8,595' 7,719'-7,725' 2-7/8" 6 10/28/19 LB-24 8,645'-8,657' 7,612'-7,624' 2-7/8" 6 08/21/18 LB-29 9,179' - 9,189' 8,280'-8,290' 2-7/8" 6 08/27/15 LB-30 9,216' - 9,226' 8,315'-8,325' 2-7/8" 6 08/27/15 LB-31 9,276' - 9,291' 8,374'-8,388' 2-7/8" 6 08/27/15 LB-32 9,617' - 9,625' 8,707'-8,715' 2-7/8" 12 04/03/14 Tyonek 10,231' - 10,251' 9,317'-9,337' 2-7/8" 12 03/15/14 LB-32 Plug @ 10,200' MD Capped w/ 10' of cement Plug @ 9,560' MD Capped w/ 41' of cement LB-31A (LB-29) LB-31B (LB-30) LB-31C (LB-31) LB-24 LB-24_upper LB-23 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED NOV 15 2015 1. Operations Abandon Li Plug Perforations LJ Fracture Stimulate LJ Pull Tubing Li Operations shutdown Li Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well [ J T Re-enter Susp Well ❑ Other: Nitrogen ❑✓ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: ment Develo P ❑ Ex p lorato ry❑ 214-001 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6. API Number: AK 99503 50-133-2006-01 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028083; FEDA028118 Beaver Creek Unit (BCU) 01B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Beaver Creek/ Tyonek Gas Pool 11. Present Well Condition Summary: Total Depth measured 11,150 feet Plugs measured 9,560 & 10,200 feet true vertical 10,233 feet Junk measured N/A feet Effective Depth measured 11,023 feet Packer measured 4,543 feet true vertical 10,107 feet true vertical 4,339 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 530' 20" 530' 530' 1,530 psi 520 psi Surface 2,224' 13-3/8" 2,224' 2,224' 3,090 psi 1,540 psi Intermediate 5,134' 9-5/8" 5,134' 4,787' 5,750 psi 3,090 psi Production 5,238' T' 5,238' 4,873' 7,240 psi 5,410 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 13.5# / P-110 10,860' MD 9,944' TVD Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# / L-80 11,107' MD 10,190' TVD Packers and SSSV (type, measured and true vertical depth) Swell Packer; N/A 4,543' MD 4,339' TVD 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: 0 525 0 0 79 Subsequent to operation: 10 1017 11 109 1 0 14. Attachments (required Per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development ❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil LJ Gas LZ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-476 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerf�hilcom.com Authorized Signature:ZZ4,&�v ,014 Date: Contact Phone: 777-8420 Form 10-404 Revised 4/2017 C V Submit Original Only �'BDMS� NOV 18 2019 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU -0113 E -Line 50-133-20006-01 1 214-001 10/28/19 10/28/19 Daily Operations: 10/28/2019 - Monday Sign in. Mobe to location. PTW and JSA. Spot and rig up lubricator. Arm gun. PT to 250 psi low and 3,000 psi high. Well flowing 452K at 77 psi. Will be perforating well flowing. RIH w/ 2-7/8" x7' Razor HC, 6 spf, 60 deg phase, tie into OHL and sat down at 9,400'. Pulled 300 Ib over to get free. Ran correlation log and send to town. Get ok to pert from 8,588' to 8,595'. Spotted and fired gun with well flowing 400K at 75 psi. After 5 min - 425K at 75 psi, 10 min - 318K at 73 psi and 408K at 75 psi. POOH All shots fired and gun was wet. RIH w/ 2-7/8" x 25' Razor HC, 6 spf, 60 deg phase and tie into OHL . Ran correlation log. Get ok to correlate myself and perf from 8,530' to 8,555'. Spotted and fired gun with well flowing 430K at 75 psi. After 5 min - 590K at 82 psi, 10 min - 680K at 85 psi and 638K at 82 psi. POOH All shots fired and gun was wet. Rig down, turn well over to field and move to BCU -07A. Hilcorp Alaska, LLC Permit #: 214-001 API #: 50-133-20006-01-00 Property Des: A-028083 KB Elevation: 157.0' (18.6' AGL) Spud Date: 02115/14 Rig Released. 03/07/14 Tree cxn = 6-1/2" Otis TOC (3/08/14 SCMT) - 4,312' Swell Packer @ 4,543'-4,565' MD Max Dogleg: 8.98°/100' @ 5,318' Max Inclination: 40.6° @ 5,380' BC -1 B Pad 1A 117' FSL, 1,338' FEL Sec. 33, T7N, R10W, S.M. LB -23 LB-24_upper LB -24 v �r Casing Shoe @ 11,107' ? Openhole Casing 43' off bottom TD 11,150' MD 10,233' TVD PBTD 11,023' MD 10,107' TVD SCHEMATIC LB -31A (LB -29) Plug @ 9,560' MD LB -31 B (LB -30) Capped w! a1' of cement _31 C (LB -31) State/Provi Plug @ 70,200' MD Country: USA Capped w/ 10' of cement LB -32 26" hole cmt w/ 1,000 sks of Class G 40.6° @ 5,3880' Tyonek Surface Casing Tag (sticky) @ 10,905' SLM 134/8" J55 61 ppf BTC w/3.75" GR (3/08/14) Top Bottom Revised By: v �r Casing Shoe @ 11,107' ? Openhole Casing 43' off bottom TD 11,150' MD 10,233' TVD PBTD 11,023' MD 10,107' TVD SCHEMATIC LB -24 Up 8,588'-8,595' 7,719'-7,725' 2-7/8" LB -247 8,645'-8,657' 7,612'-7,624' 2-7/8" LB -29 9,179'- 9,189' 8,280'-8,290' 2-7/8" LB -30 9,216'-9,226' 8,315'-8,325' 2-7/8" LB -31 9,276' - 9,291' 8,374'-8,388' 2-7/8" LB -32 9,617' - 9,625' 8,707'-8,715' 2-7/8" Tyonek 10,231'- 10,251' 9,317'-9,337' 2-7/8" 6 10/28/19 6 10/28/19 6 08/21/18 6 08/27/15 6 08/27/15 6 08/27/15 12 04103/14 12 03/15/14 Well Name 8 Number: Conductor Lease: 20" H-40 94 ppf County or Parish: Too Bottom State/Provi MD 0' 530' Country: USA TVD 0' 530' 34° @ 5,238' 1 Angle/Perfs:j NIA 26" hole cmt w/ 1,000 sks of Class G 40.6° @ 5,3880' Date Completed: Surface Casing Ground Level (above MSL): 134/8" J55 61 ppf BTC RKB (above GL): Top Bottom Revised By: MD 0' 2,224' Downhole Revision Date: TVD 0' 2,224' I Schematic Revision Date:1 185/8" hole cmt w/ 3,500 sks of Class G Intermediate Casing 9.518" N-80 40/43.5 ppf BTC Top Bottom MD 0' 5,134' TVD 0' 4,787' 12-1/4" hole cmt w/ 1,100 sks of Class G Cmt w/ 700 sks thru DV Collar @ 2,080' Production Casing 7" N-80 / P-110 26129 ppf BTC Top Bottom MD 0' 5,238' TVD 0' 4,873' 7" N-80 26 ppf 0'-4,700- 7" N-80 29 ppf 4,700'-5,328' 8-1/2" hole cmt w/ 730 sks of Class G Production Liner 4-112" L-80 / P-110 12.6 f 13.5 ppf BTC / DWC/C Top Bottom MD 0' 11,107' TVD 0' 10,190' 4-1/2" P-110 13.5 ppf 0'-10,860' 4-1/2" L-80 12.6 ppf 10,860'.11,107' S'W" hole cmt w/ 205 bbls 15.8 ppg Class G Casing/Cementing Detail - 9.9 ppg Mud - 11.0 ppg Mud Push (35 bbi) - 15.8 ppg Cement (2Q5 bbl) - 8.3 ppg Fresh Water (165 bbl) - 7.2 ppg Diesel (0.5 bbt) LB -24 Up 8,588'-8,595' 7,719'-7,725' 2-7/8" LB -247 8,645'-8,657' 7,612'-7,624' 2-7/8" LB -29 9,179'- 9,189' 8,280'-8,290' 2-7/8" LB -30 9,216'-9,226' 8,315'-8,325' 2-7/8" LB -31 9,276' - 9,291' 8,374'-8,388' 2-7/8" LB -32 9,617' - 9,625' 8,707'-8,715' 2-7/8" Tyonek 10,231'- 10,251' 9,317'-9,337' 2-7/8" 6 10/28/19 6 10/28/19 6 08/21/18 6 08/27/15 6 08/27/15 6 08/27/15 12 04103/14 12 03/15/14 Well Name 8 Number: Beaver Creek Unit #1B Lease: A - 028083 County or Parish: Kenai Peninsula Borough State/Provi Alaska Country: USA Angle @KOP and Depth: 34° @ 5,238' 1 Angle/Perfs:j NIA Maximum Deviation: 40.6° @ 5,3880' Date Completed: 315/2014 Ground Level (above MSL): 138.4' RKB (above GL): 18.6' Revised By: Donna Ambruz Downhole Revision Date: I Schematic Revision Date:1 11 /1 312 01 9 THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Tyonek Undefined Gas Pool, BCU 0 1 B Permit to Drill Number: 214-001 Sundry Number: 319-476 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely %JerePrice Chair 1171 DATED this I'l-day of October, 2019. RBDMS1�' 0CT 22 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 R OCT 17 2019 AOGCC q 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Q Operations shutdown ❑ Suspend Q Perforate Q Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Nitrogen ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: is PL—W Hilcorp Alaska, LLC Exploratory ❑ Development ' Q Strati ra hic g p ❑ Service ❑ 214-001 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: , Anchorage Alaska 99503 50-133-20006-01 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 237A.000 Will planned perforations require a spacing exception? Yes Q No Q Beaver Creek Unit (BCU) 01 B 9. Property Designation (Lease Number): ��ng 1 �^^OO 10. Field/Pool(s): FEDA028083 ` OVia IL I (g Beaver Creek / Tyonek Undef Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11,150' 10,233' 11,023' 10,107' 2,604 9,560'& 10,200' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 530' 20" 530' 530' 1,530 psi 520 psi Surface 2,224' 13-3/8" 2,224' 2,224' 3,090 psi 1,540 psi Intermediate 5,134' 9-5/8" 5,134' 4,787' 1 5,750 psi 3,090 psi Production 5,238' 7" 5,238' 4,873' 7,240 psi 5,410 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): tngize: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic4-1/2" P-110 / L-80 (13.5# / 12.6#) 10,860'/ 11,107' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Swell Packer; N/A 4,543' MD - 4,339' TVD; N/A 12. Attachments: Proposal Summary r Wellbore schematic r 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory Q Stratigraphic ❑ Development 0 Service Q 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: October 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Christina Twogood Authorized Title: Operations Manager Contact Email: Ctwo Ood hiIcOf .Com /' l Contact Phone: 777-8443 Authorized Signature:/ -- I � Zr `�%8) Date: � COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 q - Plug Integrity ❑ BOP Test Mechanical Integrity Test Q Location Clearance Q Other: �+ Post Initial Injection MIT Req'd? Yes Q No E]RBDMS f�OCT 2 2 2019 I Spacing E epbon Required? Yes ❑ No Q/ Subsequent Form Required: C] 0 1 APPROVED 'O Approved by: COMMISSIONER THE COMMISSION VI Date: r l� 22 ��}Q%C�/ / Submit Form and For, -,AE 3 Revised 4/207 t Approved applicatioQ a Io r�o s the date of approval. �yChTenls in Duplicate ��/�.l._ H Hikor Ala ka, M Well Prognosis Well: BCU -16 Date: 10/14/2019 Well Name: BCU -18 API Number: 50-133-20006-01 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: October SO, 2019 Rig: N/A (E -line) Reg. Approval Req'd? 403 I .Jr Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-001 First Call Engineer: Christina Twogood (907) 777-8443 (0) (907) 378-7323 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) AFE Number: Current BHP: — 756 psi @ 9,244' TVD (Based on 8/20/15 SBHP Survey) Max. Expected BHP: — 3,377 psi @ 7,727' TVD (Based on normal gradient) Max. Potential Surface Pressure: — 2,604 psi (Based on expected pressure and gas gradient to surface (0.10psi/ft)) Brief Well Summary Beaver Creek #16 was drilled as a sidetrack in early 2014 to target the Sterling, Lower Beluga and Tyonek gas sands. This well was completed as a 4-1/2" monobore to surface. In March 2014 the initial zone (Tyonek) was perforated, tested and showed poor performance. In April 2014, the well was plugged back and perforated in the Lower Beluga LB -32 sand. This zone was productive but IPR curve analysis shows this well to be a small reservoir and rapidly depleting. In August 2015 the BCU 1B was plugged back to the Lower Beluga and three sands tested (629, B30, and B31). Only the B-29 turned out to be productive. In August 2018 the B-24 was perforated. The purpose of this sundry/work is to perforate the Beluga B-23 and B-24 Upper sands. Notes Regarding Wellbore Condition Last tag @ 9,548' KB drift w/ 3.73" gauge ring on 9/2/2015 Minimum ID is 3.920" (Drift is 3.795") Safety Concerns V/9 Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. • Consider tank placement based on wind direction and current weather forecast (venting nitrogen during this job). • Ensure all crews are aware of stop job authority. E -line Procedure: 6 t` 1. MIRU E -line and pressure control equipment. PT lubricator to 250 psi Low / ,000 psi Hi a. Tree connection is 6.5" OTIS. 2. RIH with GPT tool and find f I vel. If fluid level is over the depth to shoot the perfs, discuss using Nitrogen with the Operations Engineer. 3. If needed, RU Nitrogen Truck and pressure up on well to push water back into formation. Use GPT Tool to confirm fluid level. 4. RU perf guns. U 11ilcom Alaska, LL 5. RIH and perforate the following intervals: Well Prognosis Well: BCU -1B Date:10/14/2019 Zone Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Lower Beluga LB -23 +8,530' +8,555' +7,667' +7,690' 25' Lower Beluga LB -24 Upper +8,588' +8,595' +7,721' +7,727' 7' a. We may use a 2' gun as the first run to allow the well to equalize to avoid being blown up the hole. b. Pressure up well to 2700 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 Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer and Geologist for confirmation. e. Use Gamma/CCL to correlate. f. Spacing allowance is based on Conservation Order 237A. g. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. h. Record tubing pressures before and after each perforating run. Record 5, 10 and 15 minute pressures after firing guns. 6. POOH and RD E -line. 7. Turn well over to production. E -Line Procedure (Contingency) 1. If these zones produce sand and/or water and need to be isolated: 2. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low/ 3,000 psi High. 3. RIH and set 4-1/2" CIBP (or tubing patch) and dump 35' of cement on top of the plug. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Standard Well Procedure —Nitrogen Operations Hilcm'p Alaska, LLC Permit#: 214-001 API #: 50-133-20006-01-00 Property Des: A-028083 KB Elevation: 157.0' (18.6' AGL) Spud Date. 02/15/14 Rig Released: 03/07/14 Tree txn = 6-112" 0ti$ TOC (3108/14 SCMT) - 4,31 Swell Packer @ 4,543'-4,565' MD _7 Max Dogleg: 8.98"1100' @ 5,318' Max Inclination: 40.6° @ 5,380' BC -1 B Pad 1A 117' FSL, 1,338' FEL Sec. 33, T7N, R10W, S.M. LB -24 Casing Shoe @ 11,107' Openhole Casing 43' off bottom TD PBTD 11,150' MD 11,023' MD 10,233' TVD 10,107' TVD SCHEMATIC Conductor 20" 1-140 94 ppf Toter Bottom MD 0' 630' TVD 0' 530' 26" hole cmt w/ 1,000 sks of Class G Surface Casing 13-3/8" J-55 61 ppf BTC Too Bottom MD 0' 2,224' TVD 0' 2,224' 18-6/8" hole cmt w/ 3,500 sks of Class G Intermediate Casing 9-5/8" N-80 40/43.5 ppf BTC Top Bottom MD 0' 5,134' TVD 0' 4,787' 12-114" hole cmt w/ 1,100 sks of Class G Cmt w/ 700 sks thru DV Collar @ 2,080' Production Casing 7" N-801 P-110 26 / 29 ppf BTC Top Bottom MD 0' 5,238' TVD 0' 4,873' T' N-80 26 ppf 0'-4,700- 7" N-80 29 ppf 4,700'-5,328' 8-112" hole cmtw/ 730 sks of Class G Production Liner 4-112" L-80 / P-110 12.6 113.5 ppf BTC / DWC/C Top Bottom MD 0' 11,107' TVD 0' 10,190- 4-1/2" P-110 13.5 ppf 0'.10,860' 4-1/2" L-80 12.6 ppf 10,860'-11,107' 6"x7" hole cmt w/ 205 bible 15.8 ppg Class G Casing/Cementing Detail - 9.9 ppg Mud - 11.0 ppg Mud Push (35 bbl) - 15.8 ppg Cement (205 bbl) - 8.3 ppg Fresh Water (165 bbl) - 7.2 ppg Diesel (0.5 bbl) LB -24 LB -31A (LB -29) Plug @ 9,560' MD 1 B (LB -30) Capped w141' of cement Z31C(LB -31) Plug @ 10,200' MD 9,179'-9,189' Capped w/ 10' of cement LB -32 6 08/27/15 Tyonek 9,216'-9,226' Tag (sticky) @ 10,905' SLM 2-718" 6 w/ 3.75" GR (3/08114) LB -31 9,276 - 9,291' Casing Shoe @ 11,107' Openhole Casing 43' off bottom TD PBTD 11,150' MD 11,023' MD 10,233' TVD 10,107' TVD SCHEMATIC Conductor 20" 1-140 94 ppf Toter Bottom MD 0' 630' TVD 0' 530' 26" hole cmt w/ 1,000 sks of Class G Surface Casing 13-3/8" J-55 61 ppf BTC Too Bottom MD 0' 2,224' TVD 0' 2,224' 18-6/8" hole cmt w/ 3,500 sks of Class G Intermediate Casing 9-5/8" N-80 40/43.5 ppf BTC Top Bottom MD 0' 5,134' TVD 0' 4,787' 12-114" hole cmt w/ 1,100 sks of Class G Cmt w/ 700 sks thru DV Collar @ 2,080' Production Casing 7" N-801 P-110 26 / 29 ppf BTC Top Bottom MD 0' 5,238' TVD 0' 4,873' T' N-80 26 ppf 0'-4,700- 7" N-80 29 ppf 4,700'-5,328' 8-112" hole cmtw/ 730 sks of Class G Production Liner 4-112" L-80 / P-110 12.6 113.5 ppf BTC / DWC/C Top Bottom MD 0' 11,107' TVD 0' 10,190- 4-1/2" P-110 13.5 ppf 0'.10,860' 4-1/2" L-80 12.6 ppf 10,860'-11,107' 6"x7" hole cmt w/ 205 bible 15.8 ppg Class G Casing/Cementing Detail - 9.9 ppg Mud - 11.0 ppg Mud Push (35 bbl) - 15.8 ppg Cement (205 bbl) - 8.3 ppg Fresh Water (165 bbl) - 7.2 ppg Diesel (0.5 bbl) LB -24 8,645'-8,657' 7,612'-7,624' 2-7/8" 6 08/21/18 LB -29 9,179'-9,189' 8,280'-8,290' 2-718" 6 08/27/15 LB -30 9,216'-9,226' 8,315'-8,325' 2-718" 6 08127/15 LB -31 9,276 - 9,291' 8,374'-8,388' 2.7/8" 6 08/27/15 LB -32 9,617'- 9,625' 8,707'-8,715' 2-7/8" 12 04/03/14 Tyonek 10,231'- 10,251' 9,317'-9,337' 2-7/8" 12 03/15/14 Well Name & Number: Beaver Creek Unit #1B Lease: A - 028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34° @ 5,238' Angle/Perfs: NIA Maximum Deviation: 40.6° @ 5,3880' Date Completed: 3/5/2014 Ground Level (above MSL): '38'4' RKB (above GL): 18.6' Revised By: Donna Ambruz Downhole Revision Date: Proposed Schematic Revision Date: 10/2412018 BC -1 B Pad 1A Hilcorp Alaska.I,l,( 117' FSL, 1,338' FEL Permit* 214-001 Sec. 33, T7N, R10W, S.M. API #: 50-133-20006-01-00 'Property Des: A-028083 �, KB Elevation: 157.0' (18.6'A9 'it I I I,, I TOC (3108114 SCMT)-4,312M Swell Packer @ Conductor 4,543'-4,565' MD 20" H40 94 ppf Max Dogleg: Toe Bottom 8.98°/100' @ 5,318' MD 0' 530' Max Inclination: TVD 0' 530' 40.6° @ 5,380' 26" hole cmt w/ 1,000 sks of Class G 8,588'-8,595' Date Completed: Surface Casing LB -23 13-3/8" J-55 61 ppf BTC LB-24_upper T -o Bottom LB -24 LB -31A (LB -29) Plug@ 9,560, MD LB -31B (LB -30) o Capped w/ 41' of cement -31C (LB -31) Plug @ 10,200' MD Capped w/ 10' of cement LB -32 Tyonek Tag (sticky) @ 10,905' SLM wl 3.75" GR (310 3114) Casing Shoe Openhole Casing 43' off bottom WTD PBTD 11,150' MD 11,023' MD 10,233' TVD 10,107' TVD PROPOSED Perforations: Zane MD Conductor Size 20" H40 94 ppf Date Toe Bottom 8,530'-8,555' MD 0' 530' Couniry: USA TVD 0' 530' TBD 26" hole cmt w/ 1,000 sks of Class G 8,588'-8,595' Date Completed: Surface Casing Ground Level (above MSL): 13-3/8" J-55 61 ppf BTC LB -24 T -o Bottom 7,612'-7,624' MD 0' 2,224' 6 TVD 0' 2,224- LB -29 18-6/8" hole cmt w/ 3,500 sks of Class G Intermediate CzigM 9-5/8" N-80 40143.5 ppf BTC Top Bottom MD 0' 5,134' TVD 0' 4,787' 12-1/4" hole cmt wl 1,100 sks of Class G Celt w/ 700 sks thru DV Collar @ 2,080' 2-7/8" Production Casino 7" N-80 / P-110 26 / 29 ppf BTC Top Bottom MD 0' 5,238' TVD 0' 4,873' 7" N-80 26 ppf 0'4,700' 7" N-80 29 ppf 4,700'-5,328' 8-1/2" hole cmt w/ 730 sks of Class G LB -32 Production Liner 4-1/2" L-80 / P-110 12.6 113.5 ppf BTC / DWC/C Top Bottom MD 0' 11,107' TVD 0' 10,190- 4-1/2" P-110 13.5 ppf 0'-10,860' 4-1/2" L-80 12.6 ppf 10,860'-11,107' 6"x7" hole Cmt w/ 205 bbls 15.8 poll Class G 2-7/8" Casing/Cementing Detail 03/15/14 - 9.9 ppg Mud - 11.0 ppg Mud Push (35 bbl) - 15.8 ppg Cement (205 bbl) - 8.3 ppg Fresh Water (165 bbl) - 7.2 ppg Diesel (0.5 bbl) Perforations: Zane MD TVD Size SPF Date LB -23 8,530'-8,555' Alaska Couniry: USA Angle @KOP and Depth: TBD LB-24_Up 8,588'-8,595' Date Completed: 315/2014 Ground Level (above MSL): TBD LB -24 8,645'-8,657' 7,612'-7,624' 2-7/8" 6 08/21/18 LB -29 9,179'-9,189' 8,280'-8,290' 2-7/8" 6 08/27/15 LB -30 9,216'-9,226' 8,315'-8,325' 2-7/8" 6 08/27/15 LB -31 9,276'- 9,291' 8,374'-8,388' 2-7/8" 6 08/27/15 LB -32 9,617'-9,625' 8,707'-8,715' 2-718" 12 04/03/14 Tyonek 10,231'- 10,251' 9,317'-9,337' 2-7/8" 12 03/15/14 Well Name & Number: Beaver Creek Unit #1B Lease: A- 028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Couniry: USA Angle @KOP and Depth: 340 @ 5,238' Angle/Peds: N/A Maximum Deviation: 40.60 @ 5,3880' Date Completed: 315/2014 Ground Level (above MSL): 138.4' RKB (above GL): 18.6' Revised By: Trudi Hallett Downhole Revision Date: Proposed Schematic Revision Date: 10/3/2019 0 STANDARD WELL PROCEDURE thicorp Alaska. LIA NITROGEN OPERATIONS 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 02 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. 12/08/2015 FINAL vi Page 1 of 1 • STATE OF ALASKA • ALOA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend E Perforate ❑✓ Other Stimulate El Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: N2 Work 2 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Name: Development 0 Exploratory ❑ ' 214-001 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 ' 50-133-2006-01 7.Property Designation(Lease Number): ' 8.Well Name and Number: FEDA028083;FEDA028118 Beaver Creek Unit(BCU)01B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A ' Beaver Creek/Tyonek Undef Gas 11.Present Well Condition Summary: Total Depth measured 1 11,150 feet Plugs measured 9,560&10,200 feet true vertical 1 10,233 feet Junk measured N/A feet SEP 1 6 2015 Effective Depth measured 11,023 feet Packer measured 4,543 feet O0C true vertical 10,107 feet true vertical 4,339 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 530' 20" 530' 530' 1,530 psi 520 psi Surface 2,224' 13-3/8" 2,224' 2,224' 3,090 psi 1,540 psi Intermediate 5,134' 9-5/8" 5,134' 4,787' 5,750 psi 3,090 psi Production 5,238' 7" 5,238' 4,873' 7,240 psi 5,410 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 13.5#/P-110 10,860'MD 9,944'TVD Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 11,107'MD 10,190'ND Packers and SSSV(type,measured and true vertical depth) Swell Packer;N/A 4,543'MD 4,339'ND N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A �&sip "'�:�--;~ .- r• r Treatment descriptions including volumes used and final pressure: N/A 'ic,ANWErt DEC i. i. 2° 15 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 49 203 Subsequent to operation: 0 2,189 0 0 1,402 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run El 16.Well Status after work: Oil ❑ Gas LI, 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: 315-500 Contact Joe Kaiser Email jkaiser(a'�.hilcorp.com Printed Name y Joe Kaiser Title Operations Engineer � Signature(_ /�,," �n/( Phone 907-777-8354 Date 1 I6 I(-6:3 l _ r �s Form 10-404 Revised 5/2015 /S RBDM °. ,rP 1 7 2015 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date • BCU-01B 50-133-20006-01 214-001 8/22/15 8/27/15 Daily Operations: 08/22/2015-Saturday Obtain PTW. Hold safety meeting and discuss job procedures. Review SLB JSA.Spot in N2 pump unit. Rig up SLB ambient nitrogen float. Pressure test 1502 Iron to 250 psi low and 4,500 psi high. Pressure test complete. Open well. Initial WHP 270 psi. Online with N2 @ 800 scf/min. Pressure increase from 270 psi to 1,100 psi. Did not see a break over in pressure indicating fluid had entered reservoir. Calculated N2 volume is calculated using an average temperature of 100 degrees F with a WHP of 1,100 psi. SCF per bbl of space is 332 scf. Wellbore volume is 135 bbls. By calculations fluid should have been displaced by pumping 45,000-47,000 scf. Could possibly be pumping too fast due to tight formation. Dropped rate to 500 scf/min to attempt to create consistent injection pressure. 980 psi at 500 scf/min for 20 minutes. No pressure break over. Slowly climbing. Increased rate to 1,000 scf/min. Still no break over in pressure. Total scf pumped 62,863 or 6756 gallons. Over displaced by 15,863 scf. Down on N2. Shut in well with 1,160 psi WHP. Rig down SLB CTU and stack at edge of pad. Awaiting bridge plug to be set with E line. 08/25/2015-Tuesday Arrive on location,sign in, permit, layout containment,spot equipment, rig up. PJSM, PT 3,000 psi,test good. RIH,3.72"junk basket. Pass 9,600', POOH. MU 3.5"CIBP and GPT tool. OOH,check fire,arm set tool. RIH w/3.5" CIBP and GPT tool. Log correlation log 9,610'to 9,190',fluid level 9,600'. Send correlation log to town. Log into position,CLL depth 9,545.5', plug depth 9,560'. Set plug,good indication of set,finish log. Tag plug, POOH. MU 3" bailer. OOH,fill bailer with casing cleaner. RIH w/30 x 3" bailer. Dump cleaner @ 9,560'. POOH. Surface,check fire,arm new glass. Fill bailer w/cement, neo 17#ppg class H, (9.8 Gal). RIH w/cement bailer#1. Tag plug at 9,560'. Pick up 1 ft and dump, POOH. Surface,check fire, arm new • glass,fill bailer(9.8 gal). RIH w/cement bailer#2. Dump cement at 9,548', POOH. Surface,check fire, arm new glass,fill bailer(3 Gal). RIH w/cement bailer#3. Dump cement, POOH. Surface, rig down,wait on cement. 08/27/2015-Thursday Obtain PTW. Hold safety meeting and discuss hazards and job steps. MIRU SLB N2 float. Rig up iron. Cool down N2. Pressure test N2 lines to 3,500 psi. Open well to pressure test CIBP with 35'of cement. 400 psi whp. Online down well. 2,300 scf/min. 1,844 gallons of N2 pumped. Bleed N2 off well head from 2,787 psi to 2,350 psi. Shut in master and swab. Rig down SLB N2 float. Stack at edge of pad. Pick up Pollard E-line lubricator and 15 ft gun. 15'2.875 6 spf, 60 degree phasing, hollow carrier Razor charge. Stab on well. Pressure test to 250 low and 3,000 psi high for 5 minutes. Good test. Bleed down to 2,350 psi and open wellhead. RIH with 15'2-7/8"gun. 7.5'ccl to topshot. 22'to bottom of gun. Tag top of cement at 9,519'. POOH to log correlation log to 9,000 ft. Send log to town. 2.2 ft high on log. Correct log to 2.2 ft deeper. Re log interval. Send log to town. PU into position. CCL depth 9,268.5 puts top shot at 9,276 ft shoot 15 foot gun from 9,276'-9,291' _ 2,322 psi WHP. Fired guns. Watched Crystal gauge. No sign of pressure change. PU OOH. At surface. Close in pop off. Nose cone of 1st gun dry. All shots confirmed fired. Make up gun run#2 10' (9,216'-9,226'). Open swab. RIH,7.5'CCL to top shot. Log correlation pass. Send to town. Town confirmed on depth by Dan Taylor. PU into positon CCL depth 9,208.5', puts top shot 9,216-9,226 ft. 2,209 psi whp. Fired shot. No change in Crystal gauge pressure. POOH. At suface breaking down 2nd gun run. No indication of fluid inside bull nose or end of gun.All shots confirmed fired. Make up gun run#3 10' (9,179'- 9,189'). Stab on well. RIH. 7.5'from CCL to top shot. Send log to town. Confirmed on depth. PU to ccl depth 9,208.5'. Puts top shot at 9,179'. 2,025 psi WHP. Fired Guns. Good indication guns fired. POOH. WHP increasing. At surface. 2,473 psi WHP. Increased 448 psi. Pop off well. Break down gun. All shots confirmed fired. No indication of fluid inside bull nose. 2,473 psi when well shut in. E-line rigging down. Turn well over to production. i # n 40 • BC-1 B SCHEMATIC Pad 1A 1111 orp Alaska,LLC 117' FSL, 1,338' FEL Sec. 33, T7N, R10W, S.M. Conductor Permit#: 214-001 20" H-40 94 ppf API#: 50-133-20006-01-00 Top Bottom Property Des: A-028083 F : I MD 0' 530' KB Elevation: 157.0' (18.6'AGL) - TVD 0' 530' Spud Date: 02/15/14 Rig Released: 03/07/14 26"hole cmt w/1,000 sks of Class G Surface Casing 13-3/8" J-55 61 ppf BTC i,; Ica Bottom V MD 0' 2,224' TVD 0' 2,224' 18-5/8"hole cmt w/3,500 sks of Class G 1.,. - • Intermediate Casing "r,"". 9-5/8" N-80 40/43.5 ppf BTC Tree cxn=6-1/2"Otis Top Bottom MD 0' 5,134' TVD 0' 4,787' TOC(3/08114 SCMT)-4,312' ` «��,� 12-1/4"hole cmt w/1,100 sks of Class G Cmt w/700 sks thru DV Collar @ 2,080' . Production Casing Swell Packer @ 7" N-80/P-110 26/29 ppf BTC 4,543'4,565'MD - Top Bottom MD 0' 5,238' ND 0' 4,873' Max Dogleg: A 7" N-80 26 ppf 0'-4,700' 8.98°/100'@ 5,318' 7" N-80 29 ppf 4,700'-5,328' Max Inclination: 8-1/2"hole cmt w/730 sks of Class G 40.6°@ 5,380' Production Liner 4-1/2" L-80/P-110 12.6/13.5 ppf BTC/DWC/C Top Bottom MD 0' 11,107' ND 0' 10,190' 4-112" P-110 13.5 ppf 0'-10,860' 4-1/2" L-80 12.6 ppf 10,860'-11,107' LB-31A = _ - Plug @ 9,560'MD LB-31B 6"x7"hole cmt w/205 bbls 15.8 ppg Class G Capped w/41'of cement \ LB-31C Casing/Cementing Detail - 9.9 ppg Mud Plug @ 10,200'MD kW 40 - 11.0 ppg Mud Push(35 bbl) Capped w/10'of cement \ -LB-32 .. - 15.8 ppg Cement(205 bbl) 8.3 ppg Fresh Water(165 bbl) 7.2 ppg Diesel(0.5 bbl) Y Tyonek - _ Perforations: Tag(sticky)@ 10,905'SLM Zone MD TVD Size SPF Date w/3.75"GR(3/08/14) •--t............ LB-31A 9,179'-9,189' 8,280'-8,290' 2-7/8" 6 08/27/15 'r•5;f• r ,• LB-31B 9,216'-9,226' 8,315'-8,325' 2-7/8" 6 08/27/15 Casing Shoe @ 11,107' ' .Oh, LB-31C 9,276'-9,291' 8,374'-8,388' 2-7/8" 6 08/27/15 LB-32 9,617'-9,625' 8,707'-8,715' 2-7/8" 12 04/03/14 Openhole • , Tyonek 10,231'-10,251' 9,317'-9,337' 2-7/8" 12 03/15/14 Casing 43'off bottom - TD PBTD 11,150' MD 11,023'MD 10,233'TVD 10,107'TVD Well Name&Number: Beaver Creek Unit#1B Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34°@ 5,238' Angle/Perfs: N/A Maximum Deviation: 40.6°@ 5,3880' Date Completed: 3/5/2014 Ground Level(above MSL): 138.4' RKB(above GL): 18.6' Revised By: Donna Ambruz Downhole Revision Date: Proposed Schematic Revision Date: 8/31/2015 s� THE STATE Alaska Oil and Gas mwrOF //7 THE--s-�—'a of T Conservation Commission iAsKA it• x -:_ 333 West Seventh Avenue \Tti: GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279.1433 OFALASJ 4 Fax 907.276 7542 NEU �,IJH h 1�•'� www.aogcc alaska.gov SCAN Joe Kaiser Operations Engineer c1 -00 ( —0 0 I Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Tyonek Undefined Gas Pool, BCU O1B Sundry Number: 315-500 Dear Mr. Kaiser: 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 /`l day of August, 2015 Encl. RECEIVED • STATE OF ALASKA AUG 17 4)15ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGC (i 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑� 4 Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend 0 Perforate ❑� . Other Stimulate 0 Alter Casing ❑ Change Approved Program ❑ Plug for Redril 0 Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other: N2 Work Q • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development Q • 214-001 ' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-20006-01 ' 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 237A.000 Beaver Creek Unit(BCU)01 B Will planned perforations require a spacing exception? Yes 0 No Q 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028083 q ( VW .,,,:.,;IV, ,fly ,.,i,f 5 Beaver Creek/Tyonek Undef Gas - 11. PRESENT IIUELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft). Effective Depth ND(ft): Plugs(measured). Junk(measured): / 11,150 ' 10,233 11,023 10,107 10,190' N/A Casing Length Size MD ND Burst Collapse Structural Conductor 530' 20" 530' 530' 1,530 psi 520 psi Surface 2,224' 13-3/8" 2,224' 2,224' 3,090 psi 1,540 psi Intermediate 5,134' 9-5/8" 5,134' 4,787' 5,750 psi 3,090 psi Production 5,238' 7" 5,238' 4,873' 7,240 psi 5,410 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" P-110/L-80(13.5#/12.6#) 10,860'/11,107' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Swell Packer;N/A 4,543'MD-4,339'ND;N/A 12.Attachments: Description Summary of Proposal 0 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: 08/31/15 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑., WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Kaiser Email jkaiserahilcorD.com Printed Name Joe Kaiser Title Operations Engineer Signature it- ( Phone 907-777-8393 Date Eli-7/2-0 PS- -COMMISSION USE ONLY Conditions of approve• otify Commission so that a representative may witness Sundry Number: I5 1 1) Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No 2 Subsequent Form Required: re) " 7 04 APPROVED BY Approved by: 7�` COMMISSIONER THE COMMISSION Date: 8-(9,., /S-' �'��'IS— OrRdiaeltNsAltr Submit Form and Form 10-403 evised 512015 12 months from ate of ap roval. Attachments in Duplicate RBDM�� AUG 1 1 2015 .'4 :Yt /,r p s.it;,/ Well osis Well: BCU-1BProgn llileorp Alaska,LL Date:8/14/2015 Well Name: BCU-1B API Number: 50-133-20006-01 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: August 31st, 2015 Rig: N/A (E-line) Reg.Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-001 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: Current Bottom Hole Pressure: — 755 psi @ 9,204' TVD (Based on PT Survey 8/12/2015) Maximum Expected BHP: — 3,000 psi @ 8,278' TVD (Based on offset wells in the Beluga) Max. Allowable Surface Pressure: —2,080 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft)) Brief Well Summary Beaver Creek#1B was drilled as a sidetrack in early 2014 to target the Sterling, lower Beluga, and Tyonek gas sands. This well was completed as a 4-1/2" monobore to surface.The initial zone (Tyonek) was perforated and tested and showed poor performance.The well was plugged back and perforated in the Lower Beluga LB-32. - This zone was productive but IPR curve analysis shows this well to be a small reservoir and repidly depleting. - The purpose of this work/sundry is to plugback the existing sand LB-32 and perforate Lower Beluga LB-31 sands. T CGNGN' -11113 l,✓ee,r _ft.()M t�imcF,P TO E-line Procedure: ZO ) /SCF/p r4,'q D hl eV' p�U ,^ ,c4 —yam, i'4.e- 2 /sty'qty Pry�c ru CO Mak 1. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. � a^OT(Pr ZcMc 51 "'- a. Tree connection is 6.5" OTIS. 64-0w--1,, 7�111 Weo b. SITP will be 400 psi. OSf1h/ + f' 7v :orove /Cis2. MIRU Nitrogen Tank/Pump 1 , , o. � //.5 3. Pressure well with nitrogen to push water column into formation. Watch pressure gau to verify ;fes gas pressure stablizes. Do NOT exceed 2500psi at surface. ��✓ 4. RU 4 1/2" CIBP. ca'"" 2. RIH and set CIBP at+/-9,560' MD. 3. RIH and dump bail 10' of cement on top of plug (est. 6.5 gallons). 4. RD Nitrogen Tank/Pump and E-line Slickline Procedure (24 hr post e-line work): 5. MIRU Slickline, PT lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 6.5" OTIS. b. SITP will be 400 psi. 6. RIH w/3.0" DD bailer and tag cement at+/-9,550' MD. 7. Confirm cement is hard. If soft, dump additional 10ft of cement. 8. RD Slickline. E-line Procedure: 9. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. 111 Well Prognosis Well: BCU-1B Hilcorp Alaska,LL Date:8/14/2015 c. Tree connection is 6.5" OTIS. 10. RU 2-7/8" 6 spf wireline guns. 11. Bleed nitrogen pressure as per Reservoir Engineer to achieved desired underbalance. 12. RIH and perforate the following Lower Beluga intervals: Zone MD TVD Length Size SPF LB-31A 9,179'-9,189' 8,280'-8,290' 10' 2-7/8" 6 LB-31B 9,216' -9,226' 8,315'-8,325' 10' 2-7/8" 6 LB-31C 9,276' -9,291' 8,374'-8,388' 15' 2-7/8" 6 d. Proposed perfs shown on the proposed schematic in red font. e. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. f. Correlate using OHL/PNL/GR/CCL log dated 3/14/14. g. Use Gamma/CCL/to correlate. h. Record tubing pressures before and after each perforating run. 13. RD E-line. 14. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic 11 BC-1 B ACTUAL Pad 1A SCHEMATIC Hi!corn Alaska.LLC 117' FSL, 1,338' FEL Sec. 33, T7N, R10W, S.M. Conductor Permit#: 214-001 ppf API#: 50-133-20006-01-00 20" T 90 Too4 p Bottom Property Des: A-028083 ' MD 0' 530' KB Elevation: 157.0' (18.6'AGL) s • TVD 0' 530' Spud Date: 02/15/14 Rig Released: 03/07/14 26"hole cmt w/1,000 sks of Class G Surface Casing 13-3/8" J-55 61 ppf BTC ] Bottom MD 0' 2,224' TVD 0' 2,224' 18-5/8"hole cmt w/3,500 sks of Class G • Intermediate Casing 1 9-5/8" N-80 40/43.5 ppf BTC Tree cxn=6-1/2"Otis TOp Bottom • MD 0' 5,134' TVD 0' 4,787' TOC(3/08/14 SCMT)-4,312' , . 12-1/4"hole cmt w/1,100 sks of Class G - Cmt w/700 sks thru DV Collar @ 2,080' Production Casing Swell Packer @ 7" N-80/P-110 26/29 ppf BTC 4,543'4,565'MD Top Bottom MD 0' 5,238' - TVD 0' 4,873' Max Dogleg: , ' 7" N-80 26 ppf 0'-4,700' 8.98°/100'@ 5,318' 7" N-80 29 ppf 4,700'-5,328' 1' Max Inclination: 't 8-1/2"hole cmt w/730 sks of Class G 40.6°@ 5,380' Production Liner .:r • 4-1/2" L-80/P-110 12.6/13.5 ppf BTC/DWC/C Top Bottom MD 0' 11,107' TVD 0' 10,190' 4-1/2" P-110 13.5 ppf 0'-10,860' ,* 4-1/2" L-80 12.6 ppf 10,860'-11,107' 1 t 6"x7"hole cmt w/205 bbls 15.8 ppg Class G i• Casing/Cementing Detail - 9.9 ppg Mud Plug @ 10,200'MD - 11.0 ppg Mud Push(35 bbl) Capped w/10'of cement LB-32 - 15.8 ppg Cement(205 bbl) - 8.3 ppg Fresh Water(165 bbl) • - 7.2 ppg Diesel(0.5 bbl) Tyonek = - Perforations: Tag(sticky)@ 10,905'SLM Zone MD TVD Size SPF Date w/3.75"GR(3/08/14) Ail'ir�}f LB-32 9,617'-9,625' 8,707'-8,715' 2-7/8" 12 4/03/14 ...g.P r 'r • Tyonek 10,231'-10,251' 9,317'-9,337' 2-7/8" 12 3/15/14 Casing Shoe @ 11,107' - Openhole Casing 43'off bottom TD PBTD 11,150'MD 11,023'MD 10,233'TVD 10,107'TVD Well Name&Number: Beaver Creek Unit#1 B Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 34°@ 5,238' Angle/Perfs: N/A Maximum Deviation: 40.6°@ 5,3880' Date Completed: 3/5/2014 Ground Level(above MSL): 138.4' RKB(above GL): 18.6' •Revised By: Stan Porhola Downhole Revision Date: 4/3/2014 Schematic Revision Date: 5/9/2014 , 14 BC-1 B PROPOSED 1€ Pad 1A SCHEMATIC Hilcorp Alaska,LLC. 117' FSL, 1,338' FEL Sec. 33, T7N, R10W, S.M. Conductor Permit#: 214-001 20" H-40 94 ppf API#: 50-133-20006-01-00 Top Bottom Property Des: A-028083 I MD 0' 530' KB Elevation: 157.0' (18.6'AGL) TVD 0' 530' Spud Date: 02/15/14 Rig Released: 03/07/14 26"hole cmt w/1,000 sks of Class G Surface Casinq 13-3/8" J-55 61 ppf BTC r,.. Tog Bottom V MD 0' 2,224' il• TVD 0' 2,224' t 18-5/8"hole cmt wl 3,500 sks of Class G - d' Intermediate Casing Tree cxn=6-1/2"Otis 9-5/8" N-80 40/43.5 ppf BTC • Top Bottom t« MD 0' 5,134' TVD 0' 4,787' TOC(3/08/14 SCMT)-4,312' ii:. 12-1/4"hole cmt wl 1,100 sks of Class G \�+w Cmt w/700 sks thru DV Collar @ 2,080' K . e, , 4Production Casing Swell Packer @ 7" N-80/P-110 26/29 ppf BTC 4,543'-4,565'MD a aTop Bottom MD 0' 5,238' - I ND 0' 4,873' Max Dogleg: ' . 7" N-80 26 ppf 0'-4,700' 8.98°/100'@ 5,318' 7" N-80 29 ppf 4,700'-5,328' Max Inclination: 8-1/2"hole cmt w/730 sks of Class G 40.6°@ 5,380' Production Liner y'r 4-1/2" L-80/P-110 12.6/13.5 ppf BTC/DWC/C ;i Top Bottom MD 0' 11,107' • TVD 0' 10,190' y 4-1/2" P-110 13.5 ppf 0'-10,860' 4-1/2" L-80 12.6 ppf 10,860'-11,107' LB-31At/ 6"x7"hole cmt w/205 bbls 15.8 ppg Class G Plug @ 9,560'MD LB-31B =II ::-4t, Sapped w/10'of cement LB-31CCasing/Cementing Detail y - 9.9 ppg Mud Plug @ 10,200'MD j - 11.0 ppg Mud Push(35 bbl) Capped w/10'of cement - 15.8 ppg Cement(205 bbl) LB-32 - 8.3 ppg Fresh Water(165 bbl) ..a."1") i ,' ," - 7.2 ppg Diesel(0.5 bbl) Tyonek ,dig- ,{ Perforations: Tag(sticky)@ 10,905'SLM • Zone MD TVD Size SPF Date w/3.75"GR(3/08/14) S 3 3::7 °i LB-31A 9,179'-9,189' 8,280'-8,290' 2-7/8" 6 Proposed ....%.....},44., • LB-31B 9,216'-9,226' 8,315-8,325' 2-7/8" 6 Proposed Casing Shoe @ 11,107' LB-31C 9,276'-9,291' 8,374'-8,388' 2-7/8" 6 Proposed LB-32 9,617'-9,625' 8,707'-8,715' 2-7/8" 12 4/03/14 Openhole .: .•.‘,",';•.' Tyonek 10,231'-10,251' 9,317'-9,337' 2-7/8" 12 3/15/14 Casing 43'off bottom TD PBTD 11,150' MD 11,023'MD 10,233'ND 10,107'TVD Well Name&Number: Beaver Creek Unit#113 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: - 34°@ 5,238' Angle/Perfs: N/A Maximum Deviation: 40.6°@ 5,3880' Date Completed: 3/5/2014 _ Ground Level(above MSL): 138.4' RKB(above GL): 18.6' Revised By: Joe Kaiser Downhole Revision Date: Proposed Schematic Revision Date: 8/14/2015