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Home My WebLink About214-132CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Ryan Lemay Cc:Marshall Farris; Guhl, Meredith D (OGC) Subject:RE: BCU-25 / P&A / Sundry Number: 325-268 / Request to Leave Cellar and Backfill / Surface P&A work due 10- 1-2025 Date:Thursday, September 4, 2025 1:33:00 PM Ryan, The request to cut off the well at the bottom of the cellar instead of 3’ below original ground level is conditionally approved with the following conditions: 1. The well will be considered plugged, but site clearance is not considered finished, so this will remain on Hilcorp’s well count for bonding purposes until it is cut off 3’ below ground level. 2. A marker plate per 20 AAC 25.120 must be installed, even though it’s a temporary fixture. 3. Another sundry must be submitted for final site clearance within 1 year of cessation of production or injection from the drill site, where the well will need to be cut off 3’ below original ground level and another marker plate installed per 20 AAC 25.120 and 25.170. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Lemay <ryan.lemay@hilcorp.com> Sent: Monday, August 25, 2025 11:25 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Marshall Farris <Marshall.Farris@hilcorp.com> Subject: BCU-25 / P&A / Sundry Number: 325-268 / Request to Leave Cellar and Backfill / Surface P&A work due 10-1-2025 Importance: High Good morning Bryan, Field: Beaver Creek Well: BCU-25 PTD: 214-132 Sundry Number: 325-268 API: 50-133-20644-00-00 Operation: P&A Request: Leave and backfill cellar during surface P&A Hilcorp was successful in completing subsurface P&A work on BCU-25 on 7/18/2025 bringing cement to surface and the well is now ready for surface P&A well work (cut, cap, backfill). During a recent BLM field visit Sharon Yarawsky had communicated to our field team that we have a deadline of 10/1/2025 to have the surface P&A work completed on this well on the BLM side. In late 2023, Hilcorp received approval from BLM and AOGCC for P&A well BCU-06 to leave the cellar in place, cut / cap well as close to cellar bottom as possible, and backfill cellar with gravel. Cellar removal and cutting the well down to final grade / elevation requirements (as necessary) would be completed when the pad is removed / reclaimed. We are in a similar position currently with BCU-25 being on the same pad as BCU-06. There are 14 wells on BCU pad 3 where BCU-25 is located (7 of which are active wells). Removing the cellar now would require an extensive excavation that would encroach on existing infrastructure supporting the active production coming off the pad. Request: Hilcorp is requesting to cut and cap BCU-25 as close to the cellar bottom as possible and backfilling the cellar with gravel. Cellar removal and cutting wellhead to necessary final grade / elevation requirements (if not already met) would occur when the pad is removed / reclaimed at a future date. Attachments: AOGCC and BLM approvals of same request for P&A BCU-06 on the same BCU Pad 3 as BCU-25. Thank you for your time and consideration, Ryan LeMay Operations Engineer Swanson River / Beaver Creek Cell: (661) 487-0871 E-mail: Ryan.lemay@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 08/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250807 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 23 50133206350000 214093 6/26/2025 AK E-LINE PPROF T40741 BCU 25 50133206440000 214132 7/16/2025 AK E-LINE Plug/Cement T40742 BRU 211-35 50283201890000 223050 6/11/2025 AK E-LINE Perf T40743 BRU 211-35 50283201890000 223050 6/20/2025 AK E-LINE PPROF T40743 BRU 213-26 50283201920000 223069 7/7/2025 AK E-LINE Perf T40744 BRU 213-26T 50283202040000 225038 7/2/2025 AK E-LINE Perf T40745 BRU 213-26T 50283202040000 225038 7/4/2025 AK E-LINE Perf T40745 BRU 213-26T 50283202040000 225038 6/28/2025 AK E-LINE Perf T40745 BRU 241-23 50283201910000 223061 7/18/2025 AK E-LINE Perf T40746 GP 11-13RD 50733200260100 191133 6/2/2025 AK E-LINE PPFROF T40747 KBU 32-06 50133206580000 216137 7/1/2025 AK E-LINE PPROF T40748 MPU E-28 50029232590000 202055 5/8/2025 AK E-LINE Caliper T40749 MPU F-21 50029226940000 196135 7/10/2025 AK E-LINE Caliper T40750 MPU G-02 50029219260000 189028 7/6/2025 AK E-LINE Puncher T40751 MPU I-01 50029220650000 190090 7/7/2025 AK E-LINE TubingPunch T40752 NS-19 50029231220000 202207 6/27/2025 AK E-LINE Perf T40753 PBU J-07C 50029202410300 225026 5/29/2025 BAKER MRPM T40754 PBU N-07B 50029201370200 223122 6/7/2025 BAKER MRPM T40755 PCU-05 50283202030000 225037 7/10/2024 AK E-LINE Perf T40756 TBU D-07RD2 50733201170200 192155 7/19/2025 AK E-LINE Perf T40757 TBU M-09 50733204760000 196127 7/18/2025 AK E-LINE Perf T40758 Please include current contact information if different from above. T40742BCU 25 50133206440000 214132 7/16/2025 AK E-LINE Plug/Cement Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.08 11:16:55 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Ryan Lemay Cc:Donna Ambruz Subject:RE: Hilcorp / BCU-25 / PTD 214-132 / Sundry Number 325-268 Date:Tuesday, May 27, 2025 11:17:00 AM Ryan, Approved. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Lemay <Ryan.Lemay@hilcorp.com> Sent: Friday, May 23, 2025 1:23 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: Hilcorp / BCU-25 / PTD 214-132 / Sundry Number 325-268 Good afternoon Bryan, Thank you for providing AOGCC approval for BCU-25 P&A today. I have just recently received BLM approval for this updated Sundry program as well. As part of BLM’s condition of approval, they will be requiring me to have 100’ of cement on top of CIBP at 2936’ . Therefore, in Step 2 of the procedure 100’ of cement will be placed above the CIBP as opposed to the 50’ stated. I don’t know if this requires your approval or not as you have already approved the procedure and meets the intent of the AOGCC regs. However, I wanted to ensure you were aware of this change to satisfy the requirements of BLM. Please let me know if you require approval for this change and reach out should you have any questions. Thanks, Ryan LeMay Operations Engineer Swanson River / Beaver Creek Cell: (661) 487-0871 E-mail: Ryan.lemay@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,208'N/A Casing Collapse Structural Conductor Surface 3,090psi Intermediate Production 7,460psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Lemay, Operations Engineer Contact Email:ryan.lemay@hilcorp.com Contact Phone: 661-487-0871 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Swell Pkr; N/A 2,936' MD / 2,770' TVD; N/A, N/A 5,264'3,500'3,280' Beaver Creek Sterling Gas 16" 9-5/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beaver Creek Unit (BCU) 25CO 237D Same 5,264'5-1/2" ~1,690psi 8,196' 3500; 6350 Length May 7, 2025 N/A 8,196' Perforation Depth MD (ft): See Attached Schematic 5,750psi 78"78" 3,488' Size 78' 3,488' MD N/A TVD Burst N/A 10,640psi 3,270' Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028083 214-132 50-133-20644-00-00 Hilcorp Alaska, LLC Proposed Pools: AOGCC USE ONLY Tubing Grade: Noel Nocas, Operations Manager 907-564-5278 Tubing MD (ft):Perforation Depth TVD (ft): 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 66 t _ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:11 pm, Apr 29, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.04.29 12:58:23 - 08'00' Noel Nocas (4361) 325-268 10-404 DSR-4/29/25 All conditions of approval on original sundry 324-335 apply. A.Dewhurst 22MAY25BJM 5/2/25 X *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.05.23 08:49:51 -08'00'05/23/25 RBDMS JSB 052325 Well Prognosis Well: BCU 25 Date: 04/2/25 Rev5 Well Name: Beaver Creek Unit #25 API Number: 50-133-20644-00 Current Status: Partially Plug and Abandoned Permit to Drill Number: 214-132 First Call Engineer: Ryan LeMay (661) 487-0871 Second Call Engineer: Scott Warner (907) 564-4506 (O)(907) 830-8863 (C) Current Bottom Hole Pressure: ~ 2,216 psi @ 5,264’ TVD (Calc from 9/10/19 fluid level) Maximum Expected BHP: ~ 2,216 psi @ 5,264’ TVD (Calc from 9/10/19 fluid level) Max. Potential Surface Pressure: ~ 1,690 psi (Based on the Calc. BHP and a 0.10 psi/ft gas gradient to surface) Brief Well Summary: BCU 25 was drilled in 2014 as a grassroots horizontal monobore completion to target the Sterling B4. The well was perforated with 20 sets of 10’ clusters spaced approximately 100’ apart. The well produced high water cut from the start. In 2014, a 2-7/8” tubing velocity string was run to help unload the water. Gas lift mandrels and a chemical injection line were installed and further attempts were made to unload the water. A survey was run in 2015 to identify the source of the water. In 2016 an inflatable bridge plug was set below the third set of perforations to attempt to shut off the water production. The gas production declined quickly, and the well was shut in on June 1, 2016. In 2019, a workover was performed to decomplete the well and swap the wellhead to enable drilling the BCU 19 sidetrack. The inflatable bridge plug was tagged at 6,351’ with tubing. A 5.5” VS1X packer was made up on tubing and set mechanically at 3,500’. The casing was filled with produced water and pressure tested to 1,500 psi for 30 minutes. The purpose of this updated Sundry is to complete the permanent P&A of BCU 25 wellbore. Summary of P&A Operations Completed to Date: x MIRU Rig # 401. x RIH, release VS1X packer @ 3500’ MD, TOH and laydown. x Make up 5-1/2” CIBP and set at 6142’ (BLM rep Quinn Sawyer Witnessed). Attempt to pressure test to 1500 psi. Unable to get a successful pressure test. x Make up 5-1/2” CIBP and set at 6132’. x Lay cement plug from 6132’ MD to ETOC 5358’ with 18 bbls of 15.3 ppg class G slurry. x Turn hole over to corrosion inhibited fresh water. x RDMO Rig # 401 x Test CIBP / cement to 1500 psi for 30 min. Good test. AOGCC Jim Regg and BLM Allie Schoessler waived witness. x MIRU E-line unit. x RIH and tag TOC at 5362’ MD. x Pick up and set CIBP @ 2936’ and shoot tubing punches from 2926’ – 2930’ MD x Attempt to establish communication / circulation between 5-1/2” tubing and 5-1/2” x 9-5/8” annulus. Pressure up to 3000 psi and unable to establish circulation in 5-1/2” x 9-5/8” annulus x Run CBL and find TOC in 5-1/2” x 9-5/8” annulus at + 1540’ MD. Well Prognosis Well: BCU 25 Date: 04/2/25 Rev5 Procedure - Eline/Cementers: 1. MIRU E-line unit and cement unit. PT lubricator 250 psi low / 2000 psi high 2. RIH and dump bail cement from CIBP set depth of 2936’ to 2876’ MD (50’ above casing punch holes shot from 2926’ – 2930’ MD) a. 5-1/2” volume from 2936’ to 2876’ MD = 1.4 bbls 3. Tag TOC at 2876’. 4. Make up 5-1/2” CIBP and set at + 1540’ MD 5. Shoot casing punches from + 1535’ – 1531’ MD 6. Establish circulation in 5-1/2” x 9-5/8” annulus. 7. Mix and pump 107 bbls cement down 5-1/2” casing and up the 5-1/2” x 9-5/8” annulus leaving cement at surface in both the 5-1/2” casing and 5-1/2” x 9-5/8” casing. a. 5-1/2” x 9-5/8” annulus volume = 71.3 bbls (1535’ to surface) b. 5-1/2” volume = 35.7 bbls (1535’ to surface) 8. RDMO E-line and cement unit. Post Rig Abandonment Procedures: 9. Cut off casing 6’ below current pad surface elevation. This will meet the cutoff depth requirement of 3’ below original ground elevation per survey results that were completed on BCU pad 3 for BCU #6 P&A in 2023. 10. Notify AOGCC & BLM 48hrs in advance. 11. Create well abandonment marker per 20 AAC 25.120. The following must be bead-welded directly to the marker plate: a. Hilcorp Alaska, LLC b. PTD: 214-132 c. Well Name: Beaver Creek 25 d. API: 50-133-20644-0000 12. Set marker plate per 20 AAC 25.120 and collect GPS coordinates. 13. Photo document casing cut-off, with cement tops, and Welded Plate install. 14. Backfill location as necessary, close out location. Attachments: 1. Current Schematic (Aligned to P&A operations completed to date) 2. Proposed Schematic (Final well P&A state) 3. 5-1/2” x 9-5/8” CBL ran 11/2/2024 oCDLgnr State/Prov:Alaska Country:USA 160.6' 12/12/2014Revised By: Date Completed: 0.5º @ 659' RKB (above GL): Scott Warner County or Parish:Kenai Peninsula Borough 6/4/2024 90.6º @ 6,999' 18.6' Angle/Perfs: 12/6/2015 Downhole Revision Date:Schematic Revision Date: Well Name & Number:Beaver Creek #25 Angle @KOP and Depth:90ºMaximum Deviation: Ground Level (above MSL): Lease:A - 028083 Beaver Creek #25 Pad 3 1246' FNL, 1,656' FWL, Sec. 34, T7N, R10W, S.M. Current SCHEMATIC Perforations (Sterling B4):Zone MD TVD Size SPF Date Status Sterling B4 8,045'-8,055' 5,264'-5,264' 3-1/8" 6 11/19/14 Open Sterling B4 7,990'-8,000' 5,264'-5,264' 3-1/8" 6 11/19/14 Open Sterling B4 7,890'-7,900' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,790'-7,800' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,690'-7,700' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,590'-7,600' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,490'-7,500' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,390'-7,400' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,290'-7,300' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,190'-7,200' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Sterling B4 7,090'-7,100' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Sterling B4 6,990'-7,000' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,890'-6,900' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,790'-6,800' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,690'-6,700' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,590'-6,600' 5,262'-5,262' 3-1/8" 6 11/21/14 Open Sterling B4 6,490'-6,500' 5,260'-5,260' 3-1/8" 6 11/21/14 Open Sterling B4 6,390'-6,400' 5,260'-5,260' 3-1/8" 6 11/22/14 Open Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore TOC (CBL 11/14/14) - 3,475' Permit #:214-132 API #:50-133-20644-00 Prop. Des:FED A-028083 KB elevation:179.2' (18.6' AGL) Lat:N60°39' 29.694" Long:W151°1' 2.615" Spud:10/19/2014 21:30 hrs TD:11/02/2014 15:30 hrs Rig Released:11/07/2014 18:00 hrs Casing/Cementing Detail - 9.9 ppg Mud - 10.5 ppg Mud Push (45 bbl) - 15.3 ppg Cement (283 bbl) - 8.5 ppg 3% KCl (190 bbl) Conductor 16" X-56 109 ppf Top Bottom MD 0' 78' TVD 0' 78' Surface Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 3,488' TVD 0' 3,270' 12-1/4" hole Lead Cmt w/ 570 sks (250 bbls) of 12.0 ppg, Class G, Tail Cmt w/ 221 sks (48 bbls) of 15.4 ppg, Class G, cement to surface Jewelry 1. Swell Packer (21' Long) 2. Weatherford Inflatable Bridge Plug 5-1/2" 3. CIBP 4. CIBP w/ 18 bbs cement- TOC at 5,362' 5. CIBP 6. Casing punch Depth 2,936' 6,350' 6,142' 6,132' 2,936' 2,926'-2,930' TD: 8,208' MD 5,264' TVD PBTD: 8,105' MD 5,264' TVD Casing Shoe @ 8,196' Production Casing 5-1/2" P-110 17 ppf GeoConn Top Bottom MD 0' 8,196' TVD 0' 5,264' 8-1/2" hole Cmt w/ 1,157sks (283 bbls) of 15.3 ppg, Class G. 11/14/14 CBL shows ToC = 3472' MD RA #8 Short RA Marker Joints #1 @ 6,183'-6,193' MD #2 @ 6,450'-6,460' MD#3 @ 6,680'-6,695' MD #4 @ 6,914'-6,924' MD #5 @ 7,186'-7,201' MD #6 @ 7,460'-7,470' MD #7 @ 7,686'-7,701' MD #8 @ 7,917'-7,927' MD RA #7RA #6RA #5RA #4RA #3RA #2RA #1 Tag (unset cement) @ 8,090' CTM w/ 2.0" Jet Nozzle (11/16/14) 3 2 1 4 TOC (CBL 11/02/24) - 1,540' 5 6 22 TOC (EL Tag on 9/27/24) - 5,362' corrosion inhibited FW corrosion inhibited FW State/Prov:Alaska Country:USA 160.6' 12/12/2014 Maximum Deviation: Ground Level (above MSL): Lease:A - 028083Well Name & Number:Beaver Creek #25 Angle @KOP and Depth:90º 4/2/2025 90.6º @ 6,999' 18.6' Angle/Perfs: 12/6/2015 Downhole Revision Date:Schematic Revision Date:Revised By: Date Completed: 0.5º @ 659' RKB (above GL): Ryan LeMay County or Parish:Kenai Peninsula Borough Beaver Creek #25 Pad 3 1246' FNL, 1,656' FWL, Sec. 34, T7N, R10W, S.M. Proposed SCHEMATIC Perforations (Sterling B4):Zone MD TVD Size SPF Date Status Sterling B4 8,045'-8,055' 5,264'-5,264' 3-1/8" 6 11/19/14 Open Sterling B4 7,990'-8,000' 5,264'-5,264' 3-1/8" 6 11/19/14 Open Sterling B4 7,890'-7,900' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,790'-7,800' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,690'-7,700' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,590'-7,600' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,490'-7,500' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,390'-7,400' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,290'-7,300' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,190'-7,200' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Sterling B4 7,090'-7,100' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Sterling B4 6,990'-7,000' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,890'-6,900' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,790'-6,800' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,690'-6,700' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,590'-6,600' 5,262'-5,262' 3-1/8" 6 11/21/14 Open Sterling B4 6,490'-6,500' 5,260'-5,260' 3-1/8" 6 11/21/14 Open Sterling B4 6,390'-6,400' 5,260'-5,260' 3-1/8" 6 11/22/14 Open Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore TOC (CBL 11/14/14) - 3,475' Permit #:214-132 API #:50-133-20644-00 Prop. Des:FED A-028083 KB elevation:179.2' (18.6' AGL) Lat:N60°39' 29.694" Long:W151°1' 2.615" Spud:10/19/2014 21:30 hrs TD:11/02/2014 15:30 hrs Rig Released:11/07/2014 18:00 hrs Casing/Cementing Detail - 9.9 ppg Mud - 10.5 ppg Mud Push (45 bbl) - 15.3 ppg Cement (283 bbl) - 8.5 ppg 3% KCl (190 bbl) Conductor 16" X-56 109 ppf Top Bottom MD 0' 78' TVD 0' 78' Surface Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 3,488' TVD 0' 3,270' 12-1/4" hole Lead Cmt w/ 570 sks (250 bbls) of 12.0 ppg, Class G, Tail Cmt w/ 221 sks (48 bbls) of 15.4 ppg, Class G, cement to surface Jewelry 1. Swell Packer (21' Long) 2. Weatherford Inflatable Bridge Plug 5-1/2" 3. CIBP 4. CIBP w/ 18 bbs cement- TOC at 5,362' 5. CIBP w/ 60' of cement - Proposed TOC +2876' MD 6. Casing punch 7. CIBP - Proposed +1540' MD 8. Casing punch - Proposed +1531' - 1535' MD Depth 2,936' 6,350' 6,142' 6,132' 2,936' 2,926'-2,930' TD: 8,208' MD 5,264' TVD PBTD: 8,105' MD 5,264' TVD Casing Shoe @ 8,196' Production Casing 5-1/2" P-110 17 ppf GeoConn Top Bottom MD 0' 8,196' TVD 0' 5,264' 8-1/2" hole Cmt w/ 1,157sks (283 bbls) of 15.3 ppg, Class G. 11/14/14 CBL shows ToC = 3472' MD RA #8 Short RA Marker Joints #1 @ 6,183'-6,193' MD #2 @ 6,450'-6,460' MD#3 @ 6,680'-6,695' MD #4 @ 6,914'-6,924' MD #5 @ 7,186'-7,201' MD #6 @ 7,460'-7,470' MD #7 @ 7,686'-7,701' MD #8 @ 7,917'-7,927' MD RA #7RA #6RA #5RA #4RA #3RA #2RA #1 Tag (unset cement) @ 8,090' CTM w/ 2.0" Jet Nozzle (11/16/14) 3 2 1 4 TOC (CBL 11/02/24) - 1,540' 5 6 TOC (EL Tag on 9/27/24) - 5,362' 7 8 corrosion inhibited FW corrosion inhibited FW Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/8/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240208 Well API #PTD #Log Date Log Company Log Type BCU 09A 50133204450100 224113 11/13/2024 YELLOWJACKET GPT-PERF BCU 09A 50133204450100 224113 10/30/2024 YELLOWJACKET GPT BCU 11A 50133205210100 224123 11/9/2024 YELLOWJACKET SCBL BCU 25 50133206440000 214132 11/2/2024 YELLOWJACKET SCBL END 2-74 REVISED 50029237850000 224024 12/5/2024 HALLIBURTON MFC24 HVA 10 50231200280000 204186 11/13/2024 YELLOWJACKET GPT-PERF KU 23-07A 50133207300000 224126 11/23/2024 YELLOWJACKET SCBL NCIU A-21 50883201990000 224086 11/29/2024 AK E-LINE CaliperSurvey PAXTON 6 50133207070000 222054 11/7/2024 YELLOWJACKET PERF PBU 01-37 50029236330000 219073 11/23/2024 BAKER MRPM PBU 06-15A 50029204590200 224108 12/26/2024 BAKER MRPM PBU 06-19B 50029207910200 224095 12/10/2024 BAKER MRPM PBU 07-29E 50029217820500 213001 11/26/2024 BAKER SPN PBU 14-31A 50029209890100 224090 11/10/2024 BAKER MRPM PBU 14-41A 50029222900100 224076 11/9/2024 BAKER MRPM SRU 241-33B 50133206960000 221053 11/5/2024 YELLOWJACKET GPT-PERF Revision Explanation: Annotations added to processed log. Please include current contact information if different from above. T40053 T40053 T40054 T40055 T40056 T40057 T40058 T40059 T40060 T40061 T40062 T40063 T40064 T40065 T40066 T40067 BCU 25 50133206440000 214132 11/2/2024 YELLOWJACKET SCBL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.07 13:25:23 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/05/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241217 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 50133205300100 214070 8/17/2024 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 9/26/2024 YELLOWJACKET PERF-GPT BCU 24 50133206390000 214112 8/19/2024 YELLOWJACKET PERF BCU 25 50133206440000 214132 9/27/2024 YELLOWJACKET PLUG-PERF BLOSSOM 1 50133206480000 215015 9/30/2024 YELLOWJACKET GPT-PLUG-PERF HV B-17 50231200490000 215189 9/23/2024 YELLOWJACKET GPT KU 24-7 50133203520100 205099 10/3/2024 YELLOWJACKET PERF KU 13-06A 50133207160000 223112 12/5/2024 AK E-LINE Plug Setting KU 22-6X 50133205800000 208135 12/8/2024 AK E-LINE Perf KU 23-07A 50133207300000 224126 12/7/2024 AK E-LINE CBL MPU L-17 50029225390000 194169 10/5/2024 YELLOWJACKET PERF MPU R-103 50029237990000 224114 10/14/2024 YELLOWJACKET CBL MPU C-23 50029226430000 196016 11/29/2024 AK E-LINE Plug/cement MPU D-01 50029206640000 181144 11/26/2024 AK E-LINE Perf PBU 13-24B 50029207390200 224087 9/26/2024 YELLOWJACKET CBL PBU 06-07A 50029202990100 224043 9/29/2024 BAKER MRPM PBU 06-18B 50029207670200 223071 10/1/2024 BAKER MRPM PBU 07-32B 50029225250200 204128 10/28/2024 BAKER SPN PBU 14-32B 50029209990200 224073 10/12/2024 BAKER MRPM PBU H-13A 50029205590100 209044 10/23/2024 BAKER SPN PBU L2-20 50029213760000 185134 10/7/2024 BAKER SPN PBU L3-22A 50029216630100 219051 10/9/2024 BAKER PEARL 10 50133207110000 223028 9/25/2024 YELLOWJACKET GPT-PERF PEARL 11 50133207120000 223032 8/29/2024 YELLOWJACKET GPT-PLUG-PERF SRU 241-33 50133206630000 217047 8/23/2024 YELLOWJACKET PERF Please include current contact information if different from above. T39863 T39864 T39865 T39868 T39869 T39870 T39871 T39872 T39873 T39875 T39874 T39867 T39866 T39876 T39877 T39880 T39878 T39879 T39881 T39882 T39883 T39884 T39885 T39886 T39887 BCU 25 50133206440000 214132 9/27/2024 YELLOWJACKET PLUG-PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.18 08:35:44 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Scott Warner Subject:RE: BCU-25 AOGCC 10-403 324-335 P&A PTD 214-132 Approved 07-29-24 Date:Friday, November 1, 2024 4:45:00 PM Hilcorp has approval to punch holes and attempt to circulate again at 2700’ MD. If unsuccessful at 2700’, check with AOGCC before punching shallower. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Friday, November 1, 2024 4:40 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Fw: BCU-25 AOGCC 10-403 324-335 P&A PTD 214-132 Approved 07-29-24 Bryan, As discussed, we attempted to establish circulation today without luck and am requesting approval to move up hole above ~2700' as a start and punch additional holes in attempt to establish circulation to pump the final cement surface p&a. Once we establish circulation we will proceed with the cement job. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 Image From: Donna Ambruz <dambruz@hilcorp.com> Sent: Monday, July 29, 2024 11:04 AM To: Scott Warner <Scott.Warner@hilcorp.com> Cc: Noel Nocas <Noel.Nocas@hilcorp.com> Subject: BCU-25 AOGCC 10-403 324-335 P&A PTD 214-132 Approved 07-29-24 FYI – Please distribute as necessary. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Scott Warner Cc:Regg, James B (OGC) Subject:RE: BCU-25 AOGCC 10-403 324-335 P&A PTD 214-132 - BCU-25 P&A Update Date:Friday, September 6, 2024 9:05:00 AM Scott, Hilcorp has approval to proceed with the plan outlined in your email below. Provide notice to inspectors for opportunity to witness the pressure test to 1500 psi. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Friday, September 6, 2024 7:25 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: BCU-25 AOGCC 10-403 324-335 P&A PTD 214-132 - BCU-25 P&A Update Bryan, We were able to get a successful casing test with the test packer last night and confirmed we have competent casing from 6002’ MD and above. We were never able to get a passing test on the casing or plugs below this point. I am requesting approval to lay in cement from the current top bridge plug at 6132’ to ~5500’ which is estimated to be about 18 bbls with 20% excess. This will bring cement into casing we know is competent based off of the test packer results last night and we will obtain a passing pressure test after the cement is laid in. After we achieve a passing pressure test the rest of the P&A will be done post rig as laid out in the sundry. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: Scott Warner Sent: Thursday, September 5, 2024 3:54 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Subject: BCU-25 AOGCC 10-403 324-335 P&A PTD 214-132 - BCU-25 P&A Update Bryan, As discussed on the phone this morning, the first plug we set at 6140’ did not pass a pressure test therefore a variance was requested to set a 2nd plug > 50’ above top of open perforations which was approved over the phone. That plug was set at 6132’ and unfortunately failed to pressure test also. I know you were out of office today so wanted to send this and you can give me a call whenever you have time to discuss further. We are currently gearing up to run a leak detect log via Eline on the rig and I wanted to discuss potential options going forward pending data we get back from the log. Assumptions: 1. Pre P&A, we had a plug/packer set at 3500’ that passed a 30 min 1500 psi pressure test. Assume the 5-1/2” has integrity down to 3500’ and the issue is between 3500’ and the new plugs/packers that are set at ~6140’. Potential Plan Forward: 1. We find the leak on Eline in between the suspected leak area of 3500’-6240’. Lay in cement from bottom plug at 6232’ up to 100-200’ above the known leak point. Pressure test and tag cement plug. 2. No leak point found and/or leak is presumed to be below where the well deviates out at ~5800’. a. Lay in cement from the plug at 6232’ to above deviation/5800’. Pressure test and tag cement plug. 3. No leak point found- lay in cement from the plug at 6232’ to ~3500’ where we achieved a passing pressure test with the original plug in the well. Pressure test and tag cement plug. 4. RDMO 401 rig- all future P&A work can be done without a rig at this point after retrieving the VS1x packer. A new sundry would be submitted for the new non rig P&A plan. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 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, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:McLellan, Bryan J (OGC) To:Scott Warner Subject:RE: [EXTERNAL] RE: BCU-25 AOGCC 10-403 324-335 P&A PTD 214-132 Approved 07-29-24 Date:Wednesday, September 4, 2024 9:59:00 AM Scott, Hilcorp has approval to not tag the inflatable plug at 6350’ MD and to set a mechanical plug at 6140’ MD, weight test the plug with 15klbs and proceed with the approved sundry 324-335 starting with step #9. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Wednesday, September 4, 2024 9:55 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Re: [EXTERNAL] RE: BCU-25 AOGCC 10-403 324-335 P&A PTD 214-132 Approved 07-29-24 Bryan, This was originally requested I believe after a prior procedure was submitted and before we changed the amount of cement that was going to be placed on the plug above the top of perfs. I agree this is not important due to the p&a plug that is being set above top perf. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Image From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, September 4, 2024 9:32:52 AM To: Scott Warner <Scott.Warner@hilcorp.com> Subject: [EXTERNAL] RE: BCU-25 AOGCC 10-403 324-335 P&A PTD 214-132 Approved 07-29-24 Scott, Can you remind me what is the point of tagging the plug at 6350’ MD? I don’t really see how it’s important for the P&A plug that will be set above the top perf. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Wednesday, September 4, 2024 9:03 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Re: BCU-25 AOGCC 10-403 324-335 P&A PTD 214-132 Approved 07-29-24 Bryan, We were able to unseat the tripoint vs-1x packer at 3500’ last night and attempted to tag the inflatable bridge plug at 6350’ per step 6 of the procedure attached but while running in hole we got hung up at 6172'. We were able to get the pipe and packer moving but continued out of hole due to not wanting to get hung up again. I am requesting to skip tagging the inflatable plug at 6350' and move forward with setting a new mechanical plug at 6140', pressure test the plug per step 9, and lay in the 15 bbls of cement on top of the plug per step 10. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 Image From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Tuesday, September 3, 2024 9:13:00 AM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Subject: FW: BCU-25 AOGCC 10-403 324-335 P&A PTD 214-132 Approved 07-29-24 Bryan, Attached is the updated BOP schematic that is being used. The 7” BOP stack is being used rather than the 13”. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: Donna Ambruz <dambruz@hilcorp.com> Sent: Monday, July 29, 2024 11:04 AM To: Scott Warner <Scott.Warner@hilcorp.com> Cc: Noel Nocas <Noel.Nocas@hilcorp.com> Subject: BCU-25 AOGCC 10-403 324-335 P&A PTD 214-132 Approved 07-29-24 FYI – Please distribute as necessary. Thank you. Donna Ambruz Operations/Regulatory Tech KEN Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 907.777.8305 - Direct dambruz@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________BEAVER CK UNIT 25 JBR 11/25/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 God test with no issues. Tested with 2 1/2 " Test joint. Test Results TEST DATA Rig Rep:Ryan ChabreOperator:Hilcorp Alaska, LLC Operator Rep:Harould Soule Rig Owner/Rig No.:Hilcorp 401 PTD#:2141320 DATE:9/3/2024 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopSTS240917085618 Inspector Sully Sullivan Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 3.5 MASP: 1690 Sundry No: 324-335 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 8 PNo. Valves 2 PManual Chokes 0 NAHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 7"P #1 Rams 1 2 3/8" x 3 1/2 P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16 P HCR Valves 1 2 1/16 P Kill Line Valves 2 2 1/16 P Check Valve 0 NA BOP Misc 0 NA System Pressure P2975 Pressure After Closure P2550 200 PSI Attained P15 Full Pressure Attained P32 Blind Switch Covers:Pall stations Bottle precharge P Nitgn Btls# &psi (avg)P6@1750 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P6 #1 Rams P7 #2 Rams P2 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill NA0 9 9 9 99999 9 PTD#2141320 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,208'N/A Casing Collapse Structural Conductor Surface 3,090psi Intermediate Production 7,460psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Swell Pkr; N/A 2,936' MD / 2,770' TVD; N/A, N/A 5,264'3,500'3,280' Beaver Creek Sterling Gas 16" 9-5/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beaver Creek Unit (BCU) 25CO 237D Same 5,264'5-1/2" ~1,690psi 8,196' 3500; 6350 Length June 20, 2024 N/A 8,196' Perforation Depth MD (ft): See Attached Schematic 5,750psi 78"78" 3,488' Size 78' 3,488' MD Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 10,640psi 3,270' Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028083 214-132 50-133-20644-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY Tubing Grade: scott.warner@hilcorp.com 907-564-4506 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writte n approval. Authorized Name and Digital Signature with Date: m n P s 66 t _ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:49 pm, Jun 06, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.06.06 14:12:07 - 08'00' Noel Nocas (4361) 324-335 10-407 Provide 24 hrs notice for AOGCC to witness weight and pressure test of plug set at 6140' MD. Provide 24 hrs notice for AOGCC to witness cut off casing, prior to welding on marker plate. Waiver to 20 AAC 25.112(c)(3) approved to not place cement plug across surface casing shoe, but instead place long plug from 500' above shoe to surface. Cement top outside production casing verified by CBL to be 13' above surface casing shoe. See attached email from Scott Warner 7/25/24. X Provide AOGCC with 10 days notice for final site clearance inspection. -bjm DSR-6/7/24 X SFD 6/10/2024 BOP test to 2500 psi. X BJM 7/29/24 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.29 10:51:58 -08'00' 07/29/24 RBDMS JSB 073024 Well Prognosis Well: BCU 25 Date: 06/4/24 Rev3 Well Name: Beaver Creek Unit #25 API Number: 50-133-20644-00 Current Status: Shut-In Gas Producer Permit to Drill Number: 214-132 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Casey Morse (907) 777-8322 (O) (603) 305-3780 (C) Current Bottom Hole Pressure: ~ 2,216 psi @ 5,264’ TVD (Calc from 9/10/19 fluid level) Maximum Expected BHP: ~ 2,216 psi @ 5,264’ TVD (Calc from 9/10/19 fluid level) Max. Potential Surface Pressure: ~ 1,690 psi (Based on the Calc. BHP and a 0.10 psi/ft gas gradient to surface) Brief Well Summary: BCU 25 was drilled in 2014 as a grassroots horizontal monobore completion to target the Sterling B4. The well was perforated with 20 sets of 10’ clusters spaced approximately 100’ apart. The well produced high water cut from the start. In 2014, a 2-7/8” tubing velocity string was run to help unload the water. Gas lift mandrels and a chemical injection line were installed and further attempts were made to unload the water. A survey was run in 2015 to identify the source of the water. In 2016 an inflatable bridge plug was set below the third set of perforations to attempt to shut off the water production. The gas production declined quickly, and the well was shut in on June 1, 2016. In 2019, a workover was performed to decomplete the well and swap the wellhead to enable drilling the BCU 19 sidetrack. The inflatable bridge plug was tagged at 6,351’ with tubing. A 5.5” VS1X packer was made up on tubing and set mechanically at 3,500’. The casing was filled with produced water and pressure tested to 1,500 psi for 30 minutes. The purpose of this Sundry is to permanently P&A the BCU 25 wellbore. Notes Regarding Wellbore Condition: x Inclination: vertical section ~25 degrees until kick-off point @ ~4,800’. Horizontal from ~6,150 – TD o Max DLS 7.0 @ 5,266’ x Cement: o 9-5/8” 40# L-80 Surface Casing set @ 3,488’ was cemented to surface. o Cement Bond Log (CBL) was run on tractor following the cementing of the 5-1/2” Production Casing (dated 11/14/14). The CBL shows good quality cement from ~8,115’ up to a TOC @ 3,475’. This places top of cement 13’ inside the 9-5/8” surface casing. Above that, there is a 21’ swell packer at 2,936’. Patchy cement continues up to the top of logged interval at 2,700’. BOP Usage during job: The rig will be operated with 1 shift per day. The BOP equipment will be used to shut the well in overnight, with blind rams or pipe in the pipe rams. The BOP components may also be used when circulating fluids, pressure testing plugs, pumping cement, etc. The BOP components will not be retested after use unless they are: x Purposely used to prevent the uncontrolled flow of fluids from the well x Specifically mentioned in the procedure to test at certain steps x They appear to be damaged from the work completed or use of them (eg, stripping pipe through them or closing on tool strings) TOC @ 3,475’Agree. SFD Well Prognosis Well: BCU 25 Date: 06/4/24 Rev3 General Notes: 1. Provide 24-hour notice to AOGCC and BLM for all mechanical integrity tests as noted in procedure below. Pre - Rig Work: 1. Provide 24-hour notice to AOGCC and BLM that Plug and Abandonment of well will commence per AOGCC regulations 20 AAC 112(h). 2. RU Pump Truck. RU on 5-1/2” x 9-5/8” annulus and perform a pressure test to 500 psi on chart for 30 min. Bleed down pressure. Rig #401: 3. MIRU Rig 401. 4. Set Back Pressure valve. ND wellhead, NU BOP and test 250 low & 2,500 psi high, annular to 250 psi low & 2,500 psi high. Record accumulator pre-charge pressures and chart tests. Notify AOGCC 24 hours in advance of test to extend the opportunity to witness. a. Perform Test. b. Test VBR rams on 2-7/8” test joint. c. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 5. PU packer retrieving on/off tool & RIH with 2-7/8” workstring to 3,500’. a. Latch and unseat Tripoint VS1X packer @ 3,500’. b. Allow packer elements to relax for 10 minutes or as necessary prior to TOH. 6. After verifying packer has released and freely moves, TIH and tag inflatable bridge plug at 6,350’. a. If packer does not move freely, POOH and LD packer and PU new mechanical plug. 7. PU to 6140’ and re set Tripoint VS1x Packer. 8. Unsting from packer and set 15k lbs of weight on top of packer to confirm a good set. 9. Perform pressure test to 1500 psi on 5-1/2” casing to confirm the packer has set. 10. RU cementers and lay in 15 bbls of cement on top of packer (estimated 612’ incl. excess). 11. PU above cement plug and clean out tubing. 12. TOOH laying down workstring, RDMO 401. 13. NU dryhole tree to pump cement through. 14. RU Eline. PU and RIH with GR/drift in prep for setting CIBP at 2936’ and tag/confirm cement top at ~5500’. POOH 15. PU and RIH w/ CIBP to ~2,936’. Set CIBP. POOH 16. PU Casing Punches and RIH to 2,930’. Punch casing from 2,930’ to 2,926’. POOH and RD E-line. 17. Rig up cementers to 5-1/2” casing on dryhole tree. Establish circulation down the 5-1/2” casing and up the 9-5/8”annulus through the casing punches. 18. Mix and pump 204 bbls of cement down the 5-1/2” casing and up the 9-5/8” annulus, pump until you get cement returns from the 9-5/8”. a. 5-1/2” casing volume from punches at 2930’ – 68 bbls b. 5-1/2” x 9-5/8” annular volume – 136 bbls 19. Once cement returns reach surface, SD pumps and close in casing and annular valves. 20. WOC Well Prognosis Well: BCU 25 Date: 06/4/24 Rev3 Post Rig Abandonment Procedures: 21. Cut off casing 6’ below current pad surface elevation. This will meet the cutoff depth requirement of 3’ below original ground elevation per survey results that were completed on BCU pad 3 for BCU #6 P&A in 2023. 22. Notify AOGCC & BLM 48hrs in advance. 23. Create well abandonment marker per 20 AAC 25.120. The following must be bead-welded directly to the marker plate: a. Hilcorp Alaska, LLC b. PTD: 214-132 c. Well Name: Beaver Creek 25 d. API: 50-133-20644-0000 24. Set marker plate per 20 AAC 25.120 and collect GPS coordinates. 25. Photo document casing cut-off, with cement tops, and Welded Plate install. 26. Backfill excavation if necessary, close out location. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic Provide AOGCC with 10 days notice for final site clearance inspection. -bjm State/Prov:Alaska Country:USA 160.6' 12/12/2014Revised By: Date Completed: 0.5º @ 659' RKB (above GL): Donna Ambruz County or Parish:Kenai Peninsula Borough 5/18/2023 90.6º @ 6,999' 18.6' Angle/Perfs: 12/6/2015 Downhole Revision Date:Schematic Revision Date: Well Name & Number:Beaver Creek #25 Angle @KOP and Depth:90ºMaximum Deviation: Ground Level (above MSL): Lease:A - 028083 Beaver Creek #25 Pad 3 1246' FNL, 1,656' FWL, Sec. 34, T7N, R10W, S.M. SCHEMATIC Perforations (Sterling B4): Zone MD TVD Size SPF Date Status Sterling B4 8,045'-8,055' 5,264'-5,264' 3-1/8" 6 11/19/14 Open Sterling B4 7,990'-8,000' 5,264'-5,264' 3-1/8" 6 11/19/14 Open Sterling B4 7,890'-7,900' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,790'-7,800' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,690'-7,700' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,590'-7,600' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,490'-7,500' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,390'-7,400' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,290'-7,300' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,190'-7,200' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Sterling B4 7,090'-7,100' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Sterling B4 6,990'-7,000' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,890'-6,900' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,790'-6,800' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,690'-6,700' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,590'-6,600' 5,262'-5,262' 3-1/8" 6 11/21/14 Open Sterling B4 6,490'-6,500' 5,260'-5,260' 3-1/8" 6 11/21/14 Open Sterling B4 6,390'-6,400' 5,260'-5,260' 3-1/8" 6 11/22/14 Open Sterling B4 6,290'-6,300' 5,260'-5,260' 3-1/8" 6 11/22/14 Open Sterling B4 6,190'-6,200' 5,260'-5,260' 3-1/8" 6 11/22/14 Open Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore TOC (CBL 11/14/14) - 3,472' Permit #:214-132 API #:50-133-20644-00 Prop. Des:FED A-028083 KB elevation:179.2' (18.6' AGL) Lat:N60°39' 29.694" Long:W151°1' 2.615" Spud:10/19/2014 21:30 hrs TD:11/02/2014 15:30 hrs Rig Released:11/07/2014 18:00 hrs Casing/Cementing Detail - 9.9 ppg Mud - 10.5 ppg Mud Push (45 bbl) - 15.3 ppg Cement (283 bbl) - 8.5 ppg 3% KCl (190 bbl) Conductor 16" X-56 109 ppf Top Bottom MD 0' 78' TVD 0' 78' Surface Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 3,488' TVD 0' 3,270' 12-1/4" hole Lead Cmt w/ 570 sks (250 bbls) of 12.0 ppg, Class G, Tail Cmt w/ 221 sks (48 bbls) of 15.4 ppg, Class G, cement to surface Jewelry 1. Swell Packer (21' Long) 2. Tripoint VS-1X Packer w/ Plug 5-1/2" 3. Weatherford Inflatable Bridge Plug 5-1/2" Depth 2,936' 3,500' 6,350' TD: 8,208' MD 5,264' TVD PBTD: 8,105' MD 5,264' TVD Casing Shoe @ 8,196' Production Casing 5-1/2" P-110 17 ppf GeoConn Top Bottom MD 0' 8,196' TVD 0' 5,264' 8-1/2" hole Cmt w/ 1,157sks (283 bbls) of 15.3 ppg, Class G. 11/14/14 CBL shows ToC = 3472' MD RA #8 1 Short RA Marker Joints #1 @ 6,183'-6,193' MD #2 @ 6,450'-6,460' MD #3 @ 6,680'-6,695' MD #4 @ 6,914'-6,924' MD #5 @ 7,186'-7,201' MD #6 @ 7,460'-7,470' MD #7 @ 7,686'-7,701' MD#8 @ 7,917'-7,927' MD RA #7RA #6RA #5RA #4RA #3RA #2RA #1 Tag (unset cement) @ 8,090' CTM w/ 2.0" Jet Nozzle (11/16/14) 3 2 8.5 ppg Water State/Prov:Alaska Country:USA 160.6' 12/12/2014Revised By: Date Completed: 0.5º @ 659' RKB (above GL): Scott Warner County or Parish:Kenai Peninsula Borough 6/4/2024 90.6º @ 6,999' 18.6' Angle/Perfs: 12/6/2015 Downhole Revision Date:Schematic Revision Date: Well Name & Number:Beaver Creek #25 Angle @KOP and Depth:90ºMaximum Deviation: Ground Level (above MSL): Lease:A - 028083 Beaver Creek #25 Pad 3 1246' FNL, 1,656' FWL, Sec. 34, T7N, R10W, S.M. PROPOSED SCHEMATIC Perforations (Sterling B4): Zone MD TVD Size SPF Date Status Sterling B4 8,045'-8,055' 5,264'-5,264' 3-1/8" 6 11/19/14 Open Sterling B4 7,990'-8,000' 5,264'-5,264' 3-1/8" 6 11/19/14 Open Sterling B4 7,890'-7,900' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,790'-7,800' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,690'-7,700' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,590'-7,600' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,490'-7,500' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,390'-7,400' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,290'-7,300' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,190'-7,200' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Sterling B4 7,090'-7,100' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Sterling B4 6,990'-7,000' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,890'-6,900' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,790'-6,800' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,690'-6,700' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,590'-6,600' 5,262'-5,262' 3-1/8" 6 11/21/14 Open Sterling B4 6,490'-6,500' 5,260'-5,260' 3-1/8" 6 11/21/14 Open Sterling B4 6,390'-6,400' 5,260'-5,260' 3-1/8" 6 11/22/14 Open Sterling B4 6,290'-6,300' 5,260'-5,260' 3-1/8" 6 11/22/14 Open Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore TOC (CBL 11/14/14) - 3,475' Permit #:214-132 API #:50-133-20644-00 Prop. Des:FED A-028083 KB elevation:179.2' (18.6' AGL) Lat:N60°39' 29.694" Long:W151°1' 2.615" Spud:10/19/2014 21:30 hrs TD:11/02/2014 15:30 hrs Rig Released:11/07/2014 18:00 hrs Casing/Cementing Detail - 9.9 ppg Mud - 10.5 ppg Mud Push (45 bbl) - 15.3 ppg Cement (283 bbl) - 8.5 ppg 3% KCl (190 bbl) Conductor 16" X-56 109 ppf Top Bottom MD 0' 78' TVD 0' 78' Surface Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 3,488' TVD 0' 3,270' 12-1/4" hole Lead Cmt w/ 570 sks (250 bbls) of 12.0 ppg, Class G, Tail Cmt w/ 221 sks (48 bbls) of 15.4 ppg, Class G, cement to surface Jewelry 1. Swell Packer (21' Long) 2. Weatherford Inflatable Bridge Plug 5-1/2" 3. Tripoint VS-1X Pkr w/ Plug 5-1/2" w/ 15 bbls cmt cap 4. CIBP 5. Casing punch, cmt to surface Depth 2,936' 6,350' 6,140' 2,936' 2,930' TD: 8,208' MD 5,264' TVD PBTD: 8,105' MD 5,264' TVD Casing Shoe @ 8,196' Production Casing 5-1/2" P-110 17 ppf GeoConn Top Bottom MD 0' 8,196' TVD 0' 5,264' 8-1/2" hole Cmt w/ 1,157sks (283 bbls) of 15.3 ppg, Class G. 11/14/14 CBL shows ToC = 3472' MD RA #8 Short RA Marker Joints #1 @ 6,183'-6,193' MD #2 @ 6,450'-6,460' MD #3 @ 6,680'-6,695' MD #4 @ 6,914'-6,924' MD #5 @ 7,186'-7,201' MD #6 @ 7,460'-7,470' MD #7 @ 7,686'-7,701' MD#8 @ 7,917'-7,927' MD RA #7RA #6RA #5RA #4RA #3RA #2RA #1 Tag (unset cement) @ 8,090' CTM w/ 2.0" Jet Nozzle (11/16/14) 3 2 1 4 5 7KHSLFWXUHFDQ WEHGLVSOD\HG7KHSLFWXUHFDQ WEHGLVSOD\HG7KHSLFWXUHFDQ WEHGLVSOD\HG7KHSLFWXUHFDQ WEHGLVSOD\HG ϭϯͲϱͬϴΗ ^ƉŚĞƌŝĐĂůŶŶƵůĂƌ ,ĞŝŐŚƚ͗ϰϲΗ tĞŝŐŚƚ͗ϭϮ͕ϴϬϲ ϭϯͲϱͬϴΗ DƵĚƌŽƐƐtͬϰͲ ϭͬϭϲΗŽƵƚůĞƚƐ ,ĞŝŐŚƚ͗Ϯϴ͘ϱΗ tŝĚƚŚϯϭΗ &Ƶůů DƵĚƌŽƐƐƐƐǇ͘ǁŝĚƚŚ ǁͬǀĂůǀĞƐŝŶƐƚĂůůĞĚ tĞŝŐŚƚ͗ ϮϮϬϬůďƐ͘ <ŝůůƐŝĚĞ ŚŽŬĞƐŝĚĞ ϭϯͲϱͬϴΗϱŵKW WĂĐŬĂŐĞ tͬ4-1/16"ϱDsĂůǀĞƐ ϭϯͲϱͬϴΗ hŽƵďůĞKW ,ĞŝŐŚƚ͗ϱϱ͘ϴϳϱΗ tŝĚƚŚ͗ϭϳϭ͘ϱΗ tĞŝŐŚƚϭϰ͕ϴϬϬůďƐ͘ dKWZD^ ϮͲϯͬϴΗyϮͲϳͬϴΗyϯͲϭͬϮΗ DERON FLEX RAMS KddKDZD^>/ND ϰͲϭͬϭϲΗϱDDĂŶƵĂů'ĂƚĞ ǀĂůǀĞΘϰͲϭͬϭϲΗ,Z ^ŽŶŽƵƚƐŝĚĞϰͲϭͬϭϲΗy ϮͲϭͬϭϲΗϱŵ ƵĂůϰͲϭͬϭϲΗϱDDĂŶƵĂů 'ĂƚĞǀĂůǀĞƐ ^ŽŶŽƵƚƐŝĚĞϰͲϭͬϭϲΗ yϮͲϭͬϭϲΗϱŵ ,ĞŝŐŚƚĚĚŝƚŝŽŶĨŽƌZŝŶŐ'ĂƐŬĞƚƐ͗ϬΗ KWdŽƚĂů ,ĞŝŐŚƚ͗ϭϯϬ͘ϯϳϱΗ KW dŽƚĂůǁĞŝŐŚƚ͗Ϯϵ͕ϴϬϲůďƐ͘ From:Scott Warner To:McLellan, Bryan J (OGC) Subject:Re: [EXTERNAL] BCU 25 (PTD 214-132) P&A sundry Date:Friday, July 26, 2024 5:17:35 PM Bryan, Yes, I am requesting no change to the original procedure that was submitted and alternatively requesting a variance from the cement plug across the surface casing shoe with the following justification. Due to the BLM requiring at least 50’ of cement up into the surface casing shoe and we only have 13’ currently per the CBL, the procedure was written to perform the 9-5/8” x 5-1/2” annulus squeeze and cement both the annulus and 5-1/2” to surface. This will ensure there are no leak paths even if the packer fails and with a plug set on top of open perforations, along with a more than required cement volume, this will prevent any contamination of fresh water from occurring. This is in response as to your original email sent on June 17th that I have copied below. Scott, I’m reviewing the sundry application for P&A on this well and have have the following comments. 1. Regulations require a cement plug across the surface casing shoe per 20 AAC 25.112(c)(3). Please send a revised procedure and proposed wellbore diagram to include this, or; 2. You could alternatively request a variance from this requirement. The request should be accompanied by justification, explaining why your plan is at least as good as the regulatory requirements in preventing the contamination of fresh water. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Image From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, July 26, 2024 4:48:02 PM To: Scott Warner <Scott.Warner@hilcorp.com> Subject: RE: [EXTERNAL] BCU 25 (PTD 214-132) P&A sundry Scott, Are you requesting no change to the sundry procedure that was submitted already? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Thursday, July 25, 2024 5:26 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] BCU 25 (PTD 214-132) P&A sundry Bryan, After receiving approval from the BLM for this procedure I am requesting a variance from placing a cement plug across the surface casing shoe per 20 AA 25.112(c)(3). The BLM requires at least 50’ of cement up into the surface casing shoe and we only have 13’ currently per the CBL which is why the procedure was written to perform the 9-5/8” x 5-1/2” annulus squeeze and cement both the annulus and 5-1/2” to surface. This will ensure there are no leak paths even if the packer fails and with a plug set on top of open perforations, along with a more than required cement volume, this will prevent any contamination of fresh water from occurring. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Monday, July 1, 2024 2:42 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] BCU 25 (PTD 214-132) P&A sundry Bryan, That’s correct- I plan to send you a revised procedure or request a variance but am waiting to hear back from the BLM so I can potentially make one change and/or ensure I don’t have any other changes based on BLM feedback. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, July 1, 2024 9:57 AM To: Scott Warner <Scott.Warner@hilcorp.com> Subject: RE: [EXTERNAL] BCU 25 (PTD 214-132) P&A sundry CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Hi Scott, I believe I’m waiting on a revised procedure from you on this. Are you planning to submit a revised procedure? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Wednesday, June 19, 2024 12:48 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] BCU 25 (PTD 214-132) P&A sundry Bryan, Apologies for the confusion. Was working through some blm requirements and in turn incorrectly/interchanged surface casing shoe when I meant packer. I’ll work up a plan on how I can satisfy the blm requirement of putting cement on top of the packer behind the 5-1/2” casing while ensuring we get cement on top of the plug if it’s set at 3588’ Thanks, From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, June 19, 2024 9:50 AM To: Scott Warner <Scott.Warner@hilcorp.com> Subject: RE: [EXTERNAL] BCU 25 (PTD 214-132) P&A sundry Scott, 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. Surface casing shoe is at 3488’ MD. Your revised diagram and procedure has you setting CIBP at 3036’ TVD. If you move your CIBP down to 3588’ (100’ below the casing shoe), how would you get cement down there if your circulation point is at 2930’ MD? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Scott Warner <Scott.Warner@hilcorp.com> Sent: Tuesday, June 18, 2024 1:33 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] BCU 25 (PTD 214-132) P&A sundry Bryan, Attached is the updated procedure and schematic with the CIBP set 100’ below the surface casing shoe and additional cement for extra 100’. Thanks, Scott Warner Kenai – Operations Engineer Office: (907) 564-4506 Cell: (907) 830-8863 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, June 17, 2024 10:16 AM To: Scott Warner <Scott.Warner@hilcorp.com> Subject: [EXTERNAL] BCU 25 (PTD 214-132) P&A sundry Scott, I’m reviewing the sundry application for P&A on this well and have have the following comments. 1. Regulations require a cement plug across the surface casing shoe per 20 AAC 25.112(c)(3). Please send a revised procedure and proposed wellbore diagram to include this, or; 2. You could alternatively request a variance from this requirement. The request should be accompanied by justification, explaining why your plan is at least as good as the regulatory requirements in preventing the contamination of fresh water. 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. 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If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently 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. 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 8,208 feet 3500; 6350 feet true vertical 5,264 feet N/A feet Effective Depth measured 3,500 feet 2,936 feet true vertical 3,280 feet 2,770 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth)Swell Pkr; N/A 2,936' MD 2,770' TVD N/A; 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: Contact Phone:777-8443 odd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 10,640psi 78' 3,270'5,750psi Collapse 3,090psi 7,460psi Casing Structural 16" 9-5/8" Length 78' 3,488' 8,196' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 0 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. 319-509 0 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-132 50-133-20644-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 00 Beaver Creek Unit (BCU) 25 N/A A028083 Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Beaver Creek / Sterling Gas PoolN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 5-1/2"8,196'5,264' WINJ WAG 0 Water-Bbl MD 78' 3,488' 0 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 9:17 am, Jan 05, 2021 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2021.01.05 08:51:06 -09'00' Taylor Wellman DSR-1/6/21 RBDMS HEW 1/5/2021 Pull TubingPlug Perforations gls 1/12/21 SFD 1/13/2021 Rig Start Date End Date 12/12/19 12/21/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU-25 50-133-20644-00 214-132 12/12/2019 - Thursday PJSM and PTW. Assess location Place pit liner, unload trucks and spot equipment. Truck carrier from SRU, continue to R/U Spot base beam and carrier. Stand and scope up derrick. Spot pits, accumulator, choke, generator, etc. Build rig berms & SDFN. 12/13/2019 - Friday 12/14/2019 - Saturday PJSM and PTW. Fire up rig, heaters, and light plants. Verify well was bled off. R/U to circulate down the tubing taking returns up the 5.5" annulus. Quadco technician installed block height encoder. Pump 150BBL of produced water at 2.2BPM ~200psi taking returns to pits. S/D and monitor well - static. Pressure test tree void to 5000psi for 15 min - test good. Set BPV and N/D tree N/U yellowjacket 7-1/16" BOPE stack consisting of 5M annular, 3.5" PR, 2.875"PR, blinds and mud cross. M/U accumulator lines Skirt and winterize the rig, R/U rig floor and hand rails. Spot pipe skate and containment. Calibrate block height. Build BOPE test joint. Secure well and SDFN. PJSM and PTW, fire up rig light plants and heaters. Verify 0psi on annulus (its on a vac) Check accumulator bottle precharge, R/U pollard SL on BCU-19 and pressure test lubricator. R/U tongs and handling equipment for 2-7/8" tubing. Grease and cycle choke valves. Perform full BOPE shell test 3,000psi high / 250 psi low. Replaced leaking TIW valve all components check good. R/U frost fighter heaters from FARM yard. Return Magtec rental heaters. Strap and tally 15jts 2-7/8" 6.5# L-80 8RD EUE tubing . Repair tong lift cylinder. Wired up change connex. Add 60BBL of produced water to the pits. Secure well and SDFN. Night watch on tour to monitor rig and heaters. 12/15/2019 - Sunday PJSM and PTW, fire up rig. Verify 0psi on the annulus. Service rig, service pipe wrangler and control line spooler. Repair frost fighter heaters, prime mud pump, fluid pack BOPE test joint and prepare for BOPE test. Test 7-1/6" 5M Yellowjacket BOPEs per Hilcorp and AOGCC standards to 250psi low /3,000psi high - TEST GOOD. Test witnessed by AOGCC inspector Austin McCloud Pull 2.875" test sub and BPV. M/U 2.875" landing joint. Back out LDS and pull hanger to rig floor. Hanger pulled free at 35k. Cut control line and L/D tubing hanger with 3ft pup jt. Fill annulus with 9BBL of produced water. RIH picking up single 2.875" 6.5# L-80 8RD joints and single in from 6004Ft to 6,351.5Ft tag IRBP and set down 8k twice to verify tag. Fill annulus with 12BBL produced water from the pits POOH racking back stands of 2.875" 6.5# L-80 8RD tubing from 6,351.5Ft to 4,412ft. Spooling chemical injection line and L/D GLM's. Blow down and freeze protect surface lines. Secure well and SDFN. Night watch on tour to monitor rig and heaters. pull tubing tag IBP at 6350ft 401 Rig Start Date End Date 12/12/19 12/21/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BCU-25 50-133-20644-00 214-132 12/17/2019 - Tuesday PJSM AND PTW, FIRE UP RIG AND CHECK PRES ON WELL 0 PRES WELL ON VAC CONTINUE RIH F/ 300'T/3,500' W/ 2- 7/8' WORK STRING DRIFT STDS AS GO F/ DERRICK W/1.750'OD DRIFT SPACE OUT PKR @ 3,500' ON DEPTH FILL HOLE AND DROP 1" BALL AND R/U TO TEST AND SET PKR LINE UP TEST PUMP ATTEMPT TO PRES UP ON PKR @ 700 PSI. PRES FAILED TO 0 PRES NOTICE RETURNS NO GO SEEMS TO BE ORING FAILED. POOH SLOW CHECK EVERY CONNECTION. NO ISSUE L/D TRIPOINT RUNNING TOOL NOTICE THE ORING LEAKING BY RUNNING TOOL C/O WITH NEW SETTING TOOL M/U SAME PKR ON RUNNING TOOL RIH T/2205' BLOW DOWN AND SECURE WELL AND NIGHT CREW ON TOUR TO MONITOR RIG. 12/21/2020 - Monday Research well position and workover rig access. 12/16/2019 - Monday PJSM and PTW, fire up rig and verify 0 psi on the well (well on vac). Pump 16BBL of produced water from pits to fill the well. POOH with 2.875" 6.5# L-80 8RD tubing from 4,412Ft to surface. Filling hole for pipe displacement. Spooling chemical injection line and laying down GLM's. Racked back 3,500Ft and laid down 84 single joints. 105 SS bands recovered, 7 SS bands were left in well (note: SS bands have steel crimps) Clean and clear rig floor, R/D pipe skate R/U Pollard SL with 4.50" OD magnet. RIH with 4.50"OD magnet to 4,000Ft SLM. POOH (1 SS bands recovered) RIH with 4.50"OD magnet to 4,000Ft SLM. POOH (No bands recovered). RIH with 4.75"OD gauge ring to 4,000Ft SLM. POOH. R/D Pollard slickline M/U Tripoint 4.625" OD 5.5" 14-20# casing VS1X big bore packer on 2.875" 6.5# 8RD work string RIH from surface to 660Ft with 2.875" 6.5# 8RD work string and Tripoint packer. Blow down and freeze protect surface lines. Secure well and SDFN. Night crew on tour to monitor rig and heaters. 12/18/2019 - Wednesday PJSM FIRE UP RIG AND CHECK PRES ON WELL 0 PRES CONTINUE RIH W/ 2-7/8' WORK STRING F/2,205' T/ 3,500' AND SPACE OUT ON DEPTH M/U TEST EQUIPMENT AND FILL HOLE W/ PRODUCED WATER AND PRES UP ON TRIPOINT 5.5 PACKER SET @ 3500' DUE TO TROUBLE TIME ON THE MUD PUMP AND TEST PUMP LOST 2 HOURS PRES UP ON PKR AND SET @ 1,100 PSI P/U PUW 20 K SHEAR OUT @ 46K ALL GOOD CLOSE IN VBR AND TEST CASING AND PKR T/ 1,500 PSI 30 MINS NO ISSUE . BLEED DOWN ALL PRES AND R/D TEST EQUIPMENT . POOH AND L/D ALL OF THE 2-7/8'' WORK STRING AND DOPE EVERY CONNECTION AS ON RACK R/D HILCORP TUBING EQUIPMENT FOSTER POWER TONG,ELEVATORS,BAILS,SLIPS AND MUD PUMP. R/U NOS TOOL AND SET BPV WELL 25 AND SET IN WELL 19 CONTINUE R/D 401 AND BLOW ALL WATER LINES DOWN , SECURE RIG FOR THE NIGHT CREW. 12/19/2019 - Thursday VERIFY NO PRESSURE ON WELL 0 N/D BOP STACK, R/D ALL GAS ALARMS, ELECTICAL LINES, ALL BOP HYDRAULIC HOSES AND RIG FLOOR N/U DRY HOLE TREE, W/ NOS AND TEST SEALS 5 MINS TO 500 PSI 10 MINS 5,000 PSI. ALL GOOD. START MOVING RIG F/BCU 25 T/ BCU-19 W/WEAVER BROS TRUCK, SCOPE DERRICK DOWN AND LAY OVER ON CARRIER MOVE PITS. PUMP HOUSE AND MOVE CARRIER F/25 T/19 OVER WELL 19 AND SET ALL RIG COMPONENTS. set tri-point at 3500 ft test to 1500 psi nipple up Dry hole try. clearance for rig 169 State/Prov:Alaska Country:USA 160.6' 12/12/2014Revised By: Date Completed: 0.5º @ 659' RKB (above GL): Donna Ambruz County or Parish:Kenai Peninsula Borough 10/12/2020 90.6º @ 6,999' 18.6' Angle/Perfs: 12/6/2015 Downhole Revision Date:Schematic Revision Date: Well Name & Number:Beaver Creek #25 Angle @KOP and Depth:90ºMaximum Deviation: Ground Level (above MSL): Lease:A - 028083 Directional Data KOP: 659' Hole angle at 9-5/8" shoe = 25 deg Max. Doglegs: 3,965' - 6.9 deg/100 ft 5,266' - 7.0 deg/100 ft 6,999' - 6.5 deg/100 ft Beaver Creek #25 Pad 3 1246' FNL, 1,656' FWL, Sec. 34, T7N, R10W, S.M. SCHEMATIC Perforations (Sterling B4): Zone MD TVD Size SPF Date Status Sterling B4 8,045'-8,055' 5,264'-5,264' 3-1/8" 6 11/19/14 Open Sterling B4 7,990'-8,000' 5,264'-5,264' 3-1/8" 6 11/19/14 Open Sterling B4 7,890'-7,900' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,790'-7,800' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,690'-7,700' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,590'-7,600' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,490'-7,500' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,390'-7,400' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,290'-7,300' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,190'-7,200' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Sterling B4 7,090'-7,100' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Sterling B4 6,990'-7,000' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,890'-6,900' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,790'-6,800' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,690'-6,700' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,590'-6,600' 5,262'-5,262' 3-1/8" 6 11/21/14 Open Sterling B4 6,490'-6,500' 5,260'-5,260' 3-1/8" 6 11/21/14 Open Sterling B4 6,390'-6,400' 5,260'-5,260' 3-1/8" 6 11/22/14 Open Sterling B4 6,290'-6,300' 5,260'-5,260' 3-1/8" 6 11/22/14 Open Sterling B4 6,190'-6,200' 5,260'-5,260' 3-1/8" 6 11/22/14 Open Sterling B4 6,090'-6,100' 5,256'-5,256' 3-1/8" 6 11/22/14 Open Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore TOC (CBL 11/14/14) - 3,472' Permit #:214-132 API #:50-133-20644-00 Prop. Des:FED A-028083 KB elevation:179.2' (18.6' AGL) Lat:N60°39' 29.694" Long:W151°1' 2.615" Spud:10/19/2014 21:30 hrs TD:11/02/2014 15:30 hrs Rig Released:11/07/2014 18:00 hrs Casing/Cementing Detail - 9.9 ppg Mud - 10.5 ppg Mud Push (45 bbl) - 15.3 ppg Cement (283 bbl) - 8.5 ppg 3% KCl (190 bbl) Conductor 16" X-56 109 ppf Top Bottom MD 0' 78' TVD 0' 78' Surface Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 3,488' TVD 0' 3,270' 12-1/4" hole Lead Cmt w/ 570 sks (250 bbls) of 12.0 ppg, Class G, Tail Cmt w/ 221 sks (48 bbls) of 15.4 ppg, Class G, cement to surface Jewelry 1. Swell Packer (21' Long) 2. Retrievable Bridge Plug 5-1/2" 3. Inflatable Bridge Plug 5-1/2" Depth 2,936' 3,500' 6,350' TD: 8,208' MD 5,264' TVD PBTD: 8,105' MD 5,264' TVD Casing Shoe @ 8,196' Production Casing 5-1/2" P-110 17 ppf GeoConn Top Bottom MD 0' 8,196' TVD 0' 5,264' 8-1/2" hole Cmt w/ 1,157sks ( 283 bbls) of 15.3 ppg, Class G cmt w/ EASYBLOK RA #8 1 Short RA Marker Joints #1 @ 6,183'-6,193' MD #2 @ 6,450'-6,460' MD #3 @ 6,680'-6,695' MD #4 @ 6,914'-6,924' MD #5 @ 7,186'-7,201' MD #6 @ 7,460'-7,470' MD #7 @ 7,686'-7,701' MD #8 @ 7,917'-7,927' MD RA #7RA #6RA #5RA #4RA #3RA #2RA #1 Tag (unset cement) @ 8,090' CTM w/ 2.0" Jet Nozzle (11/16/14) Tubing 2-7/8" L-80 6.5 ppf EUE Top Bottom MD 0' 6,004' TVD 0' 5,245' 3 2 tested RBP 1500 psi swell pkr 3500 ft IBP RBP 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, Sterling Gas Pool, BCU 25 Permit to Drill Number: 214-132 Sundry Number: 319-509 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 w .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, DATED this -1 day of November, 2019. 3SDMS±`:JN0V 14 2019 RECEIVED STATE OF ALASKA NOV 0 7 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 nnc 25 280 1. Type of Request: Abandon ❑ Plug Perforations E • 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: Hilcorp Alaska, LLC 4. Current Well Class: 5. Permit to Drill Number: Exploratory ❑ Development ❑' Stratigraphic ❑ Service ❑ 214-132 ^ 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, Alaska 99503 50-133-20644-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 237A Will planned perforations require a spacing exception? Yes ❑ No Beaver Creek (BCU) 25 9. Property Designation (Lease Number): 10. Field/Pool(s): , A028083 Beaver Creek / Sterling Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,208' 5,264' 6,350' 5,260'-1,847psi 6,350' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 78, 78, Surface 3,488' 9-5/8" 3,488' 3,270' 5,750 psi 3,090 psi Intermediate Production 8,196' 5-1/2" 1 8,196' 5,264' 10,640 psi 7,460 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5# / L-80 1 6,004 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Swell Pkr; N/A 2;936' MD - 2,770' TVD; N/A 12. Attachments: Proposal Summary Wellbore schematic 21 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: January 5, 2020 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended El 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: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerCdhilcoro com Contact Phone: 777-8420 Authorized Signature: Date: b Nb u 2 0 l 5 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �� Integrity Plug 9 y ❑ BOP Test [ Mechanical Integrity Test ❑ Location Clearance ❑ Other: IJ 300e /^ &)P •-'�' 7r Post Initial Injection MIT Req'd? Yes ❑ No ❑ ,. IBDMS«�NOV 14 2019 Spacing Exception Required? Yes ❑ No ✓� Subsequent Form Required: APPROVED BY Approved by: t COMMISSIONER THE COMMISSION Date: e� c- f (� (S it l i - I % BIN, 1 1 \I /..✓1 Submit Form and cX ,7- orm 10-4 3 e ise 4/2017 Approved application URI 1bbbAAAtttddd»�LhMM , rOOmRRt ate of approval.r �'! 1 Attachments in Duplicate H Hileaea Alaska. LL Well Prognosis Well: BCU -25 Date:10/29/2019 Well Name: BCU -25 API Number: 50-133-20639-00 Current Status: SI Gas Well Leg: N/A Estimated Start Date: January 5, 2020 Rig: 401 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-132 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Christina Twogood (907) 777-8443 (0) (907) 378-7323 (M) AFE Number: Current Bottom Hole Pressure: — 2,052 psi @ 5,264' TVD (Calc. F/ 9/10/19 Fluid Level) Maximum Expected BHP: — 2,052 psi @ 5,264' TVD (Calc. F/ 9/10/19 Fluid Level) Max. Potenital Surface Pressure: — 1,847 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summa Beaver Creek Unit #25 was drilled as a Grass roots horizontal monobore completion in 2014 to target the Sterling B4. The well was perforated via wireline tractor with 20 each 10' intervals, spaced roughly 100' apart. The well loaded up with fluid and has loaded up in the 5-1/2" casing. In late 2014, a 2-7/8" tubing velocity string without a packer was run to help unload the water while producing gas from the Sterling B4 by producing up the tubing x casing annulus. Gaslift mandrels were installed to allow running reverse gaslift valves that would allow gaslift gas to be injected down the tubing and help lift produced fluids up the annulus. At the time of being shut-in, BC 25 was producing 0.8-1.2 MMscfd and up to 3,600 bpd water. A PLT was run in late 2015. It was determined that gas was comingrom the top 3 perTo-rat-ionsa-h-dWe water was coming from the remaining lower perforations. An Inflatable Bridge Plug was set in March of 2016 in an effort to shut off some of the water. This helped for 3 months but the production over that time period had fallen off and by June 1, 2016 the well was again SI. The purpose of this sundry is to tag the inflatable bridge plug to insure it is still where it should be, and then set a Retrievable Plug/packer in the casing to isolate the wellbore from the perforations. The we3llbore will then be bled off above the packer and the wellhead changed to a low profile dry tree so that Rig 169 can be skidded over the well and on to BCU #19 for the side track of that well. Notes Regarding Wellbore Condition • Max doglegs of 6.9°/100' at 3,965' MD and 7.0°/100' at 5,266' MD. Procedure: 1. MIRU Rig 401. Circulate well W/ produced water and 2. NO Well head, NU BOPe and pressure test same to 250 low / 3,000 psi high. 3. PU on tubing hanger and pull to floor. 4. PU 2-7/8" Tubing and single in the well and tag inflatable packer. (Note: TO IRBP @ 6,347'. 1 Element Center @ 6,350'. If IRBP has moved up hole or is not there, Contact OPS Engineer.) (Note: If the inflatable packer has moved up hole, Hilcorp will want to run a tubing conveyed plug and set it in its place.) 5. PU RBP/packer and RIH to 3,500'. Set Same. POOH W/tubing laying down. L " les (_ l� psi f l �°a 1ffik.m Alaska, LL' ' 6. ND BOP, NU drytree and test same. 7. RDMO Rig 401. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Current Wellhead diagram 4. Proposed Wellhead Diagram Well Prognosis Well: BCU -25 Date:10/29/2019 ttileorp Alaska, LLC j 1 rOW 2 3 Beaver Creek #25 Pad 3 1246' FNL, 1,656' FWL, Sec. 34, TTN, R10W, S.M. 1 Conductor 16" X-56 109 ppf Tog Bottom MD 0' 78' ND 0' 78' 4 9-5/8" L-80 40 ppf BTC TOR Bottom MD 0' 3,488' ND 0' 3,270' 12-1/4" hole Lead Cmt w/ 570 sks (250 bbls) of 12.0 ppg, Class G, Tail Cmt w/ 221 sks (48 bbls) of 15.4 ppg, Class G, cement to surface TOC (CBL 11114/14) - 3,472' itLJ:�:�IL RA #1 RA #2 -- -- RA Casing/Cementing DetailOhectional Date - 9.9 ppg Mud KOP: 659' Hole aggk at 9-5/8• shoe = 25 deg 10.5 ppg Mud Push (45 bbl) Max. Doglegs: - 15.3 ppg Cement (283 bbl) 3,965' - 6.9 de91100 0 8.5 ppg 3% KCI (190 bbl) 5,266' - 7 o depn00 8 6,999' - 6.5 dey100 6 @ 6,183'-6,193' MD 6,450'-6,460' MD @ 600'-6,695' MD Ld 6,9W4 6,924' MD @ 7,186-7,201' MD @ 7,460'-7,470' MD LID 7,686'-7,701' MD Perforations (Alerting B4): Zone MD lVD Size SPF `6 Status Sterling B4 8,045'-8,055' 5,264'-5,264' 3-118" 6 11/19/14 Open Tree cxn = 9-112" DUs 7,990'-8,000' 5,264'-5,264' 3-1/8" 6 7 Open 8.0" Seal Diameter >., 3-118" 6 11120/14 Open 5-1/8" Modified ID Bore 7,790'-7,800' 5,264'-5,264' 3-1/8" 6 ;k,. 6 Steding B4 ✓ 3-1/8" 6 11/20/14 9 Sterling B4 7,590'-7,600' 5,264-5,264' 3-118" 6 10 11 12 Sterling 64 7,490'-7,500' 5,264'5,264' 1� 6 11/20/14 Open Storing B4 itLJ:�:�IL RA #1 RA #2 -- -- RA Casing/Cementing DetailOhectional Date - 9.9 ppg Mud KOP: 659' Hole aggk at 9-5/8• shoe = 25 deg 10.5 ppg Mud Push (45 bbl) Max. Doglegs: - 15.3 ppg Cement (283 bbl) 3,965' - 6.9 de91100 0 8.5 ppg 3% KCI (190 bbl) 5,266' - 7 o depn00 8 6,999' - 6.5 dey100 6 @ 6,183'-6,193' MD 6,450'-6,460' MD @ 600'-6,695' MD Ld 6,9W4 6,924' MD @ 7,186-7,201' MD @ 7,460'-7,470' MD LID 7,686'-7,701' MD Perforations (Alerting B4): Zone MD lVD Size SPF Date Status Sterling B4 8,045'-8,055' 5,264'-5,264' 3-118" 6 11/19/14 Open Steding B4 7,990'-8,000' 5,264'-5,264' 3-1/8" 6 11/19/14 Open Sterling B4 7,890'-7,900' 5,264'5,264' 3-118" 6 11120/14 Open Steding B4 7,790'-7,800' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Steding B4 7,690'-7,700' 5,264-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,590'-7,600' 5,264-5,264' 3-118" 6 11/20/14 Open Sterling 64 7,490'-7,500' 5,264'5,264' 3-1/8" 6 11/20/14 Open Storing B4 7,390'-7400' 5,264-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,290'-7,300' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,190'-7,200' 5,264'-5,264' 3-118" 6 11/21/14 Open Sterling B4 7,090'-7,100' 6,2645,264' 34/8" 6 11/21/14 Open Sterling B4 6,990'-7,000' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,890'-6,900' 5,265'-5,265' 3-118" 6 11/21/14 Open Sterling B4 6,790'-6,800' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,690'5,700' 5,265'5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,590'-6,600' 5,262'-5,262' 3-1/8" 6 11/21/14 Open Sterling B4 6,490'-6,500' 5,260'-5,269 3-118" 6 11/21/14 Open Sterling B4 6,390'-6,400' 5,260'-5,280' 3-1/8" 6 11/22/14 Open Sterling B4 6,290'-6,300' 5,260'-5,260' 3-1/8" 6 11/22/14 Open Sterling B4 6,190'-6,200' 5,260'-5,260' 3-1/8" 6 11/22/14 Open Sterling B4 6,090'-6,100' 5,2565,256 3-1/8" 6 11/22/14 Open SCHEMATIC #: 214-132 50-133-20644-00 )es: FED A-028083 ✓anon: 1792' (18.6'AGL) N60° 39' 29.694" W151° V 2.615" 10/19/2014 21:30 hrs 11/02/2014 15:30 his eased: 11/07/2014 18:00 hrs Production Casing Tag (unset cement) @ 8,090' CTM 5-1/2" P-110 17 ppf GeoConn 6.5 ppf EUE Top Bottom MD 0' 8,196' ND 0' 5,264' I8-1/2" hole Cmt w/ 1,157sks ( 283 bible) of 15.3 ppg, Class G cmtw/ EASYBLOK Tubing Tag (unset cement) @ 8,090' CTM w/ 2.0" Jet Nozzle (11/16/14) 2-7/8" L-80 6.5 ppf EUE Jewelry Top Bottom MD 0' 6,004' ND 0' 5,245' Casing She :a11, 41:-11sa-11 It A RA #4 RA #5 RA #6 RA #8.. .. Tag (unset cement) @ 8,090' CTM w/ 2.0" Jet Nozzle (11/16/14) PBTD: TD: 8,105' MD 8,208' MD 5,264'ND 5,264'ND Jewelry Depth 1. Tubing Hanger 18.6' 2 4.50" Gaslift Mandrel (wl Lift Valve, 3/16") 1,650' 3. 4.50" Gaslift Mandrel (w/ Dummy Valve) 2.570' 4. Swell Packer (21' Long) 2,936- 5 4 50" Gaslift Mandrel (w/ Lift Valve. 3/16") 3,070' 6 4 50" Gaslift Mandrel (w/ Dummy Valve) 3,667' 7 4.50" Gaslift Mandrel (w/ Lift Valve, 3/16") 4,167' 8 4.50" Gaslift Mandrel (w/ Lift Valve, Orifice) 4.732' 9. 1/4" Control line w/ Flow Control Valve fact@ rsooP°0 5,000' 10 X -Profile (2.313" ID) 5,583' 11. WLEG 6,004' 12. Inflatable Bridge Plug R sen' GLV Pon Temp @ Lease: I 9 TVD MD Size Depth State/Prov: Alaska Country: USA 1 1489 1650 16 83 0.953 895 1000 1050 IPOR-1 2 2439 2570 0 89 0.94137 Downhole Revision Date: 12/12/2014 Dummy Valve 3 2891'3070 76 91 0.9 870 941 1030 IPOR-1 4 3430 3667 0 94 0.932 Dummy Valve 5 3892i4167 16 96 0.928 845 878 1010 1POR-1 6 4440 4732 20 99 0.922 ORIFICE -1 Well Name & Number : Beaver Creek#25 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 0.5° @ 659' Angle/Perts: 90° Maximum Deviation: 90.6° @ 6,999' Date Completed: 12/6/2015 Ground Level (above MSL):1 160.6' 1 RKB (above GL): 18.6' Revised By: JEK Downhole Revision Date: 12/12/2014 Schematic Revision Date: 4/28/2016 H IfJ..q1L,•Ga. LIt Beaver Creek BC#25 26 x 95/8 x 5'h x 27/8 heaver ureex riew BC #25 Current 12/04/2014 Tubing hanger, S -EN -CCL, 7 1/16 x 2 7/8 EUE 8rd lift and susp, W/2 %type H BPV profile, 2. X CCL ports Tree cap, Otis, 2 9/16 SM FE X 6 %Otis quick Union Valve, Swab, WKM-M, 2 9/16 SM FE, HWO DO trim Valve, Wing, WKM-M, 21/16 5M FE, HWO, Valve, SM FIE Wing, WKM-M, bHW�\nn /Fgt DD trim V _ h Gas Li Valve, Master, WKM-M, 29/165M FE, HWO, DDtrim Valve, Master, WKM-M, 29/165M FE, HWO, 9D3trim �,l' Tubinghead,Seaboj yr+ 115M X71/16 W/ 2- 21/16 5M 7" P sealbotto Casing spool, Seaboard -S8, 163/43M X 11 SM, W/ 2- 21/16 SM SSO, 9 5/8 P seal bottom Starting head, Seaboard, 16 Y. 3M X 16" SOW BTM, w/ 2- 21/16 SM SSO u i 16" 9 5/8" 5 Y.„ 2 7/8" Valve, SSV, Barber, 31/85M FE, W/ Barber Hydraulic self contained operator E roduRion Ilne Valve, WKM-M, 21/165M FE, HWO Beaver Creek BC #25 16x95/8x51/2 Tubing head, Seaboard -S8, 16 3/4 3M X 11 SM, w/ 2- 2 1/16 SM SSO, 9 5/8 P seal bottom Starting head, Seaboard, 16 'Y4 3M X 16" SOW BTM, w/ 2- 2 1/16 5M SSO Beaver Creek Field BC #25 Proposed 11/06/2019 Tubing hanger, SMB -22 ported, 11 X 5'/:-17# DWC/C csg btm x 5.875-4 stub acme LH box top, 5" type H BPV prep, 17-4PH material Dry hole cap for Rig 169 rig up on pad 5 Y," rd -EN, 10M top, om Hilecrp Alaska, LL(: J I I I I _ 2 Beaver Creek #25 Pad 3 1246' FNL, 1,656' FWL, Sec. 34, T7N, R10W, S.M. Surface Casing Conductor 9-518" L-80 16" X56 109 ppf Reg Tog Bottom MD 0' MD 0' 78' TVD 0' TVD 0' 78' Surface Casing 8,045'-8,055' 5,264'5,264' 9-518" L-80 40 ppf BTC Reg Bottom MD 0' 3,488' TVD 0' 3,270' 12-114" hole Lead Cmt w/ 570 sks (250 bbls) of 12.0 ppg, Class G, Tail Cmt w/ 221 sks (48 Whit of 15.4 ppg, Class G, cement to surface TOC (CBL 11/14114) -3,472' Tree cul - 9.112" Ods 8.0" Seal Diameter 5-118" Modified ID Sore 3 I1:A Ea If --11 e� yoy -H j?6AA - II Hz'' RA #1 RA #2 RA Casing/Cementing Detail Dkae'"el Data - 9.9 ppg Mud WOW 659 - 10 5 Mud Push 45 bbl auk angle x195/8- shoe = 25 deg ppg ( ) Mag. Dooiwe: - 15.3 ppg Cement (283 bbl) 3,965' - 6.9 degft00 e - 8.5 ppg 3% KCI (190 bbl) 5,269 - 7.0 dey100It 6,999' - 6.5 deg/100It Stoning 84 8,045'-8,055' 5,264'5,264' 3-118" 6 11/19/14 Open Sterling B4 7,990'-8,000' 5,264'-5,264' 3-118" 6 11/19/14 Open Sterling B4 7,890'-7,900' 5,264'5,264' 3-1/8" 6 11/20/14 Open Sterling 64 7,790'-7,800' 5,2645,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,690'-7,700' 5,2645,264' 3-1/e" 6 11/20/14 Open Sterling B4 7,590'-7,600' 5,264'5,264' 3-1/8" 6 11/20/14 Open Steding 64 7,490'-7,500' 5,264-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,390'-7,400' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling 64 7,290'-7,300' 5,264'-5,264' 3-1/e" 6 11/20114 Open Steding B4 7,190'-7,200' 5,264'-5,264' 3-118" 6 11/21/14 Open Sterling 84 7,090'-7,100' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Sterling 84 6,990'-7,000' 5,265-5,265' 3-1/8" 6 11/21/14 Open Sterling 84 6,890'-6,900' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Staring 84 6,790'-6,800' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,690'-6,700' 5,265-5,265' 3 -VB" 6 11/21/14 Open Sterling 64 6,590'-6,600' 5,262'-5,262' 3-118" 6 11/21/14 Open Sterling 84 6,4901-6,500' 5,260'-5,260' 3-118" 6 11/21/14 Open Sterling B4 6,390'-6,400' 5,260'-5,260' 3-1/8" 6 11/22/14 Open Sterling B4 6,290'-6,300' 5,260'-5,260' 3-1/8" 6 11122/14 Open Sterling 84 6,190'-6,200' 5,260'-5,260' 3-1/8" 6 11/22/14 Open Sterling 84 6,090'-6,100' 5,256'-5,256' 3-1/8" 6 11/22/14 Open 6,10-4,193- MD 6,450'8,460' MD 6,660'8,695' MD 6,914'8,924' MD 7,186'-7,201' MD 7,460'-7,470' MO 7,686'-7,701' MD rn Top MD 0' TVD 0' PROPOSED SCHEMATIC #: 214-132 50-133-20644-00 )es: FED A-028083 vation: 179.2' (18.6' AGL) N60° 39' 29.694" W151° V 2.615" 10/19/2014 21:30 hrs 11/02/2014 15:30 hrs leased:. 11/07/2014 18:00 hrs 17 ppf GeoConn Bottom 8,196' 5,264' hole Cmt w/ 1,157sks ( 283 bbls) of 15.3 ppg, G cmt w/EASYBLOK Tubing Size Depth Beaver Creek#25 2-718" L-80. 6.5 ppf EUE 1 1481 1650 Top Bottom MD 0' 6,004' TVD 0' 6,245- RA #6 Tag (unset cement) @ 8,090' CTM w/ 2.0" Jet N=le (1 1116114) I 1. Swell Packer (21' Long) 2 Retrievable Bridge Plug 5-1/2" 3. Inflatable Bridge Plug 5-112" Casing Shoe @ 8,196' F" PBTD: TD: 8,105' MD 8,208' MD 5,264' TVD 5,264' TVD D_1 2,936' 3,500' 6,350' TVD MD Size Depth Beaver Creek#25 Lease: •1050 County or Parish: 1 1481 1650 16 83 0.953 895 7000 Angle CKOP and Depth: 1POR-1 2 2439 2570 O 89 0.941 Date Completed: 12/6/2015Ground Dummy Valve 3 2091 3070 16 91 0.937 870 941 1030 IPOR-1 4 3430 3667 O 94 0.932 1 Dummy Valve 5 3892 4167 16 96 0.928 845 878 1010 IPOR-1 6 4440 4732 20 99 0.922 ORIFICE -1 Well Name &Number: Beaver Creek#25 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: I USA Angle CKOP and Depth: 0.5° 659' Angle/Perfs: 90° Maximum Deviation: 90.6° @ 6,999' Date Completed: 12/6/2015Ground Level (above MSL): 160.6' IRKS (above GL): 18.6' Revised By: DMA I Downhole Revision Date: 12/12/2014 Schematic Revision Date: 1013112049 N M rl 1 N Lm N H � Q� ZIIV N Z Y m a: U `o OC � W Ln QY a` W i.V W > m U c O Lj w Zj a W � CL Y H fC CL L G U Barrels of Oil per Month or Barrels of Water per Month 0 0 0 0 0 0 o O 0 O 0 0 C O 0 rl N O N C N O O O O O O e0i O O O O O N O O N o!;ea I!O-seD ao y;uow aad („j:)w,,) seE);o yaaj 3!qn:) puesnoyl • • of 7,4 4. THE STATE Alaska Oil and. Gas of L3�` Conservation Commission x=_ _ . 333 West Seventh Avenue 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ��ALASY'� Fax: 907.276.7542 www.aogcc.alaska.gov April 13, 2016 Mr. Chad A. Helgeson Operations Manager Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99503 SCANNED MAY 1 9 2016 Re: Closeout-Notice of Violation Docket Number: OTH-15-032 Failure to Protect Safety Valve Systems Beaver Creek 24 (PTD 2141120) Beaver Creek 25 (PTD 21413-2Drj The Alaska Oil and Gas Conservation Commission (AOGCC) issued a notice of violation to Hilcorp Alaska, LLC dated November 25, 2015 for failing to protect the well safety valve systems to ensure reliable operation under the range of weather conditions expected at the well site. Hilcorp responded on December 14, 2015 with the requested information including the list of wells that do not have well houses or some suitable protection of the safety valve system components installed. Also provided was a description of corrective actions (to be)taken by Hilcorp. The AOGCC does not intend to pursue any further enforcement action regarding the two Beaver Creek wells noted above. Adequate protection from extreme cold temperatures remains a concern for the Hilcorp-operated wells that do not have well houses installed and will continue to be a focus of AOGCC safety valve system inspections during winter months. Sincerely, Cathy 17. Foerster Chair, Commissioner cc: Mr. David Wilkins (Hilcorp) • 214132 II Seth th Nolan Hilcorp Alaska 6 7 6 7 GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 Il Ivilrii 41,11t4;i.LI.( Fax: 907 777-8510 DATA LOGGED E-mail: snolan@hilcorp.com 1—AT2o1G M.K.BENDER DATE 02/02/2016 RECEIVED FEB 0 2 2016 To: Alaska Oil & Gas Conservation Commission Makana Bender AOGCC Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 25 scow JUL2 8 2016 Electric log prints and data Prints: RST-GR-CCL SCMT-GR-CCL CD: 1 CBL DATA cllis 2;11.12016 4:57 PM File folder las 2)1/2016 4:57 PM File folder logs 2/1120164:57 PM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received B 6 Date: • • • Regg, James B (DOA) From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Tuesday, December 22, 2015 5:23 PM To: Regg,James B (DOA) Cc: Bruce Hershberger;Joey Hensley; Pete Iverson; Christopher Walgenbach; Larry Greenstein Subject: Non Wellhouse SSV testing in cold weather Jim, As we discussed on the phone, below is a list of wells we have function tested the SVS in the last 2 days during colder temperatures. Some of these are the wells without wellhouses or any protection. We have ordered material for them, but to ensure we are in compliance we are testing them as the temperature or well conditions drop,to ensure they are functioning as designed. Kenai Gas Field @ 11 deg KBU 23-05, 32-08, KDU 10 Ninilchik @ 10 deg F GO-8 Happy Valley @ 13 deg F HV-2, HV-8, HV-9, HV 10, HV 13, HV 14& HV-15 Swanson tested all rod pumps @ 6 deg F SCU 12A-04, 13-34, 31-8, 32-8, 33-33, and 41A-08 Beaver Creek at-1 deg F BC 7, BC14, BC23, BC24, BC25 Red pad#1 @ 15 degF These wells all tripped at the low pressure set point, showing no indication of any freezing on the sense line or in the air or hydraulics to the valve. If the temperature in the fields drop below Odeg we will function test all the wells SVS that do not have wellhouses again to ensure there is no freezing in the SVS. GO-2 now has a wellhouse on it with heat and lights, so it is now protected. Chad • S Hilcorp Alaska, LLC AECEIVED Post Office Box 244027 Anchorage,AK 99524-4027 4 3800 Centerpoint Drive [TFC 14 2015 Suite 100 Anchorage,AK 99503 December 14, 2015 AOGGC Cathy P. Foerster Chair, Commissioner Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 Re: Docket No. OTH-15-032 Failure to Protect Safety Valve Systems Beaver Creek 24 (PTD 2141120) Beaver Creek 25 (PTD 2141320) Dear Chair Foerster: We respond to the AOGCC's request dated November 25, 2015, for a list of Hilcorp Alaska, LLC (Hilcorp Alaska) operated wells that do not have well houses or some other suitable protection of the safety valve system (SVS) components, with a timeline for resolution and the plan for retesting the SVS during cold temperatures and a written plan describing what has been or will be done in the future to prevent sense line freezing AOGCC Request: Provide "a written plan describing what has been or will be done in the future to prevent its reoccurrence at Hilcorp-operated fields in Alaska. Included in the requested response should be a list of Hilcorp-operated wells that do not have well houses or some other suitable protection of the safety valve system components, a timeline for resolution, and plans for retesting the safety valve systems to demonstrate the reliable operation during cold temperatures." Hilcorp Alaska Response: Beaver Creek 24 and 25. Immediately upon failure of the SVS function test on Beaver Creek 24 and 25 an indirect fired heater was installed on the SSVs and sensing lines, thawing any frozen fluids in the safety valve system. The following day heat trace and temporary insulation was installed on the 2 wells SVS. The SVS's were function tested to ensure the lines were not frozen and would properly function, and they passed a function test. Heat blankets were measured and ordered for these 2 wells on November 24th, the permanent insulating blankets are scheduled to arrive December 22nd Other Hilcorp Alaska Wells. We have reviewed all other Hilcorp Alaska-operated wells for suitable cold-weather protection of the SVS. Following this review, we determined the following: S Cathy P.Foerster Docket Number: OTH-15-032 December 14,2015 Page 2 of 4 • All Hilcorp Alaska-operated offshore wells on the platforms in Cook Inlet are protected from the environment and do not need any additional protection. • All Hilcorp Alaska-operated wells currently producing on the North Slope (311 total) have well houses and some form of heat (heater, heat trace, or a high flowing wellhead temp). • All Hilcorp Alaska-operated wells on the North Slope with the potential to be returned to production or injection have well houses on them. • Hilcorp Alaska operates 255 onshore producing wells in the Cook Inlet basin. The remainder of this response focuses on those wells. Cook Inlet Onshore Wells. Of the 255 onshore producing Cook Inlet wells, 73 wells do not have wellhouses. We show these wells in Attachment 1 with the following data: Field, PTD #, Wellbore Name, Status, Well type (Oil/Gas), and whether there is a wellhouse, heat trace, insulation blanket on SSV, or insulation blanket on sensing line, with the date of proposed completion, and any additional comments on the SVS protection. Twenty-four of the wells without wellhouses are oil wells in Swanson River. These wells have high wellhead temperatures (approx. 80° F) and have insulation blankets on the SVS. Hilcorp considers these SVS protected from weather. The other 49 wells that do not have wellhouses on them are gas producing wells or storage wells from several different fields. There are 20 wells in total on the Kenai Peninsula that do not have any protection on the SVS from the environment. Six of these wells are rod pump wells in Swanson River which have all passed no flow tests. The SVS on the rod pump wells have one pressure transmitter that shut down the motor in the event of low pressure. The other fourteen wells with no protection are gas wells located in the following fields: Happy Valley— 7, Kenai Gas Field— 3, Red Pad— 1, GO Pad—2, Ninilchik State Pad— 1. The other 29 wells without wellhouses have some sort of protection on the safety valve or the sensing lines as shown in Attachment 1. Insulation blankets will be installed on all safety valves and safety valve sensing lines to protect all the unprotected wells no later than January 31, 2016. We tested all of the unprotected wells during October and November in temperatures near 32° F. When the ambient temperature drops below 15° F, the SVS on the unprotected wells will be function tested to ensure there is no freezing in the system. If the temperature drops below 0° F, all wells without wellhouses on them will be function tested to ensure that the SVS functions properly without a wellhouse. If there are repeatable problems with the SVS below 0° F, other forms of protection will be evaluated to ensure compliance with 20 AAC 25.265. Should you have any additional questions, please contact Chad Helgeson (777-8405 or chelgeson@hilcorp.com) or Larry Greenstein(777-8322 or lgreenstein@hilcorp.com). • • S Cathy P. Foerster Docket Number: OTH-15-032 December 14,2015 Page 3 of 4 Sincerely, HILCORP ALASKA, LLC ;(//4,71/ .. Chad A Helgeson Operations Manager Attachment 1 —List of Wells on Kenai Peninsula without wellhouses cc: Chet Starkel Larry Greenstein David S Wilkins John Barnes Luke Saugier • • Cathy P. Foerster Docket Number: OTH-15-032 December 14,2015 Page 4 of 4 Beaver Creek (BC 24 & 25) PTD#2141120 & 2141320 Docket No. OTH-15-032 Hilcorp Alaska Response Attachment 1 List of Wells without Wellhouses 0 s • > > > E VI N E E Y C C c Y Y to O 0 0co to N 0 U1 Ln to C E E c c C O° 00 E E E E E E E 0.1 C Lfl Vt m m ¢] c C Y a0+ ✓ r ~ ~ in L>m m m Ln > > > > > > co co N Vt Vt co co co t m m a .1 C \\ m 110 " -0 'O 00 00 m m m m m C N N C C C = _ Fl , C CCC GEC `i > C C 00 00 Up> > > > > ? > > > > C ] > > > C C C C C C Vt m to > > N Vt Vt Vt Vt 01 01 C_ C_ C Vt Vt Vt Vt N V1 Vt Vt Vt Vt 01 Vt Vt Vt Vt V/ 01 01 01 01 01 01 V1 co co Vt Vt V) Vt co co Vt co co co Vt Vt co V1 N co co co co Vt co co V, Vt Vt C " c C C C C C C 3 3 3 C C C C C C C C C C C C C C C C C C C C C C O O 0`1 U1 U1 0 0 0 0 0 0 'j '3 'j 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a„ v w O o o a1 a1 v Y a1 w _. .c w a w a1 v Y Y .V V v Y v a1 w iii 111 V a1 v . a1 w Y d N Y Y Y Y C C C C C C X X X C C C C C C C C r@ C C C C to c C C C C C C to C C C C C CUL°E ° CO N [D Q 1 N N N 0 0 0 N N O1 t0 t0 0 t0 t0 t0 0 0 T N 6 t0 t0 N A N N 0 f� m "O ' " (� m (om m m C C C m CC m [� m m m m (� m m (b !� ¢] m m [o CO CO CO CO m E — cam — 3 3 .t O- m m m ,10. .2 .'O. .fO.. io �a 61 'd CU ,t ia m Fa fo �a la Y ro m m (o m 2 y .�a. m �o ro �o 3 c c c U . 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Box 244027 Anchorage, AK 99524-4027 Re: Docket No. OTH-15-032 Failure to Protect Safety Valve System Beaver Creek 24 (PTD 2141120) Beaver Creek 25 (PTD 2141320) Dear Mr. Helgeson: On November 18, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Inspector performed an unannounced inspection of the well safety valve systems at Beaver Creek. A Hilcorp Alaska LLC (Hilcorp) representative was contacted and cooperated fully with the unscheduled inspection. The surface safety systems on Beaver Creek wells 24 and 25 failed function tests because of frozen low pressure sensing lines. A copy of the Inspector's report is attached. The facts reported by the AOGCC Inspector indicate a failure to protect the well safety valve systems to ensure reliable operation under the range of weather conditions expected at the well site. Previous AOGCC Inspections at Beaver Creek production pads identified several wells that did not have well houses to provide protection from winter temperatures. At the time the AOGCC Inspector arrived at the Beaver Creek field ambient temperatures were -12° F, though they warmed to +4°F by the time the inspections were completed. Wells with the safety valve system protected by well houses, heat-traced sensing line and control panel, insulated blanket covering the transmitter, or a combination of these protections were randomly picked to compare with the wells with an unprotected safety valve system. Inspection revealed that Beaver Creek 24 and 25 had no protection from the subfreezing conditions. Both wells failed their respective low pressure sensor performance tests due to frozen pressure sensing lines, preventing the automatic actuation of the surface safety valve. None of the randomly selected wells that had the safety valve system components protected failed. Docket Number OTH-15-032• • Notice of Violation—Beaver Creek 24&25 November 25,2015 Page 2 of 2 Hilcorp is reminded that a producing well must be equipped with a functional safety valve system as described in 20 AAC 25.265. Paragraph (c)(7) requires the safety valve system to be maintained in good operating condition at all times and protected to ensure reliable operation under the range of weather conditions expected at the well site. Within 14 days of receipt of this letter, you are requested to provide for AOGCC review and approval a written plan describing what has been or will be done in the future to prevent its recurrence at Hilcorp-operated fields in Alaska. Included in the requested response should be a list of Hilcorp-operated wells that do not have well houses or some other suitable protection of the safety valve system components, a timeline for resolution, and plans for retesting the safety valve systems to demonstrate the reliable operation during-cold temperatures. Failure to comply with this request will be an additional violation. The AOGCC reserves the right to pursue additional enforcement action in connection with the failure to adequately protect the safety valve systems on Beaver Creek wells 24 and 25. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, Cathy P. Foerster Chair, Commissioner Attachment cc: P. Brooks AOGCC Inspectors RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. • . L 4.lJ is cy 3 o c 3 0 .0 > N O. N O. V U Nf' N .� cn V] �+ N ' N 7 o g n. d o c Ew c Ew /� j T N C r O i R by O N E o O C U �a' C U O I0. 3 �j E y 2O i 03 N Ct.- 7 d m,A 2 C H y- G g a; U O .d ten c 9 .a v oo> ..]. ea> et E. 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N i w - - - - x b s G,) 0 d 0 v' a 0 N C4 z d E r v �„ d t Z 3 z O N N C 0 w w z H •U.S. Postal Servicer' CERTIFIED MAIL° RECEIPT Domestic Mail Only Er For delivery information,visit our website at www.usps.com'. cr Certified Mail Fee @� $ C3 Extra Services&Fees(check box,add tee as appropriate) 0 Return Receipt(hardcopy) $ ❑Return Receipt(electronic) $ _ Postmark D ❑Certified Mail Restricted Delivery $ _ Here ® ❑Adult Signature Required ® 0 Adult Signature Restricted Delivery$— ® Postage $ _LI Total Postage and Fees Mr. Chad Helgeson $ Kenai Operations Manager Sent To Hilcorp Alaska, LLC OStreet and Apt.No.,or PO Box N P.O. Box 244027 City,State,ZIP+ab Anchorage,AK 99524-4027 PS Form 3800,April 2015 PSN 7x30.02-000-9047 See Reverse for Instructions SENDER: COMPLETE THIS SECTION COMPLETE THIS SECTION ON DELIVERY ■ Complete items 1,2,and 3. •. ignat r ■ Print your name and address on the reverse X,sif°- r- 'gent so that we can return the card to you. 0 Addressee II Attach this card to the back of the mailpiece, ed by Pr' r a� e) C. Date gf D livgry or on the front if space permits. \ ' D. Is delivery a.dress different fro�tem 1? 0 Yes If YES,enter delivery address elow: 0 No Mr. Chad Helgeson Kenai Operations Manager Hilcorp Alaska, LLC �EC ® 3 2015 • P.O. Box 244027 Anchorage,AK 99524-4027 III IIIIIII I III 3. ServiceType o Priority Mail Express®ss®III1I'IIIIII'II( I 11111111 Adult Signature ❑Registered MailT" ❑Adult Signature Restricted Delivery Registered Mail Restricted ted ®'Certified Mail® Delivery 9590 9403 0910 5223 5232 18 ❑Certified Mail Restricted Delivery WA-Return Receipt for ❑Collect on Delivery Merchandise 2. Article Number(Transfer from service label) 0 Collect on Delivery Restricted Delivery 0 Signature ConfirmationT"' red Mail 0 Signature Confirmation 7015 0640 0006 0779 5944 'ed Mail Restricted Delivery Restricted Delivery _ v $500) PS Form 3811,July 2015 PSN 7530-02-000-9053 Domestic Return Receipt • • Regg, James B (DOA) From: Warren Camp <wcamp@hilcorp.com> II2i��/� Sent: Monday, November 23, 2015 12:02 PM To: Regg, James B (DOA) Subject: Beaver Creek Mr. Regg, On Thursday Nov. 20th,we installed heat trace and temporary insulation on our safety valve systems (pressure transmitters,), on Beaver Creek 24 and 25 wells, which do not have well shelters over them. Permanent insulation blankets have been measured, sized and ordered and will be installed on (insert expected date of install). When the next cold temperature event occurs that is below zero deg, we will function test the SVS again on these wells to ensure that this was an effective fix to ensure 365 days/yrs.functionality. Let us know if you have any questions or need additional information. 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission l(( d5- TO: Jim Regg 1 DATE: November 19, 2015 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: SVS Cold Weather Function Tests Petroleum Inspector Hilcorp Alaska LLC - Beaver Creek Wednesday, November 18, 2015: I made an unannounced visit to the Beaver Creek Field operated by Hilcorp Alaska LLC. This was a Commission mandated inspection to - ascertain feasibility of operating wells in the Alaska environment without shelters (well houses). I had not notified the personnel prior to arriving at the lease gate. I called and spoke with Warren Camp and informed him I wanted to make an inspection and was given the OK to enter. It was very cold in the field, approximately -12F while coming in on the - lease road, this was a full 15 degrees colder than Kenai. It should be noted that by the time I finished my inspection the temperature had warmed to +4F at the same point on the road. Beaver Creek traditionally has colder temperatures than the surrounding area, usually 10 degrees colder than the city of Kenai. I explained to Mr. Camp that during my last inspection I had observed there were wells that did not have well houses and in discussions with my supervisor, James Regg, it was decided to come back here when the temperatures got well below freezing. Mr. Camp cooperated fully. Lease operator, Troy Galleguillos, performed the tests today. I tested the wells as follows; the test would be successful if the following were observed: 1. Low Pressure Sensor (LPS). These were tested as we would normally during - routine SVS tests (180 or 90 day). A test manifold with a digital test gage was attached to the LPS test port and opened to the LPS sensing line. Once flowing well pressure was observed the sensing line was blocked in from the flow line and the trapped pressure bled until the LPS tripped. 2. Once test manifold was connected and test port valve opened, flowline pressure would be observed on the test gage. Less than flowline pressure indicates frozen sensing line, fail. 3. If full flow line pressure is observed, bleed slowly and observe for activation of SVS pilot system allowing 3-way block and bleed (palm valve) to fall closed. No movement of palm valve = fail. - 4. Once palm valve operates observe for closure of Surface Safety Valve (SSV). Full closure would be indicated by increase in tubing pressure. No movement or less than full travel = fail. ' 5. Open flow line to test manifold, showing no frozen root valves. Less than full flow line pressure = fail. — 2015-1118_SVS_BeaverCk_cold-weather_function_lg.docx Page 1 of 2 • • It should be noted that a "function only" test was performed on the SSV's. This did not test the pressure sealing adequacy of the closure on the SSV, only the ability to close. The first two wells tested were Beaver Creek wells 24 and 25. They lacked well houses as well as any heat tracing or blankets. Both wells failed the LPS test by having frozen low pressure sensing lines. The SSV's were manually palmed and closed properly indicating if the sensor lines were clear most likely the system would have worked. On the same pad there were wells with wellhouses. I randomly picked one with the only criteria that the well be online. Beaver Creek 16RD was chosen and when we walked into the wellhouse it was noticeably warm. The test manifold was hooked up and the SVS system tested with passing results. We moved to a different pad and tested Beaver Creek 07A. This well had freezing problems in the past and was fitted with heat tracing on the sensor lines and an insulated blanket for the SSV. This test at first appeared to fail by a frozen sensing line but we noticed that the transmitter used to sense flowline pressure and trip the LPS was fluctuating mildly. I agreed to test the LPS in a modified manner. Instead of bleeding through the test manifold Troy closed the sensing line and "cracked" a fitting under the transmitter. As the pressure bled of the LPS tripped and triggered the SVS at passing pressure. The SSV went closed and sealed. I feel this system was in good working order with the exception of a frozen test port. Observations: The wells in Beaver Creek produce water along with the gas and oil. Protected by shelters, heat tracing, blankets or a combination of all Beaver Creek wells stand a reasonable chance of having a reliable operating SVS. Unprotected it is a safe bet that these wells' SVS will fail from freezing in the Alaska winter. Attachment: SVS Test Report (AOGCC Inspection # sysLG151119064021) 2015-1118_SVS_BeaverCk_cold-weather_function_lg.docx Page 2 of 2 •kiJ 3 c 3 .0 7 N^ N 9 N 7 oUNU V] d g ,. g c W L4o cd � � y0 a> a9 _ w • ti _ w ti g = • ° G N t 4 v , = co O N W O g �'' a IIua V = o > V ; • • Regg, James B (DOA) From: Grimaldi, Louis R (DOA) Sent: Wednesday, November 18, 2015 1:07 PM ‹Qig To: Warren Camp - Cc: Regg,James B (DOA); DOA AOGCC Prudhoe Bay Subject: Beaver Creek At Beaver Creek. Was -12 now 4 above. BC 24 & 25 failed the function test (both lacking well houses) appearance was frozen sensing points. I have been assured that the sensing lines will be heat traced and blankets obtained for the SVS as I required. =- Until Until the winterization is completed you will keep the heaters on these two wells. Please advise Mr. Regg when winterization is completed. Lou Grimaldi Lou Grimaldi(on cell) Petroleum Inspector Alaska Oil and Gas Conservation Commission (907)776-5402(Home) (907)252-3409(Cell) 1 STATE OF ALASKA • ALlikA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Set Plug w/CT ❑l 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑., Exploratory ❑ 214-132 3`Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-20644-00 7.Property Designation(Lease Number): 8.Well Name and Number: A028083 Beaver Creek(BCU)25 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Sterling Gas Pool 11.Present Well Condition Summary: EIVED Total Depth measured 8,208 feet Plugs measured 6,350 "feetR V true vertical 5,264 feet Junk measured N/A feet MAR 2 4 2016 Effective Depth measured 6,350 feet Packer measured N/A feet OGCC true vertical 5,260 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 78' 78' Surface 3,488' 9-5/8" 3,488' 3,270' 5,750 psi 3,090 psi Intermediate Production 8,196' 5-1/2" 8,196' 5,264' 10,640 psi 7,460 psi Liner Perforation depth Measured depth See Attached SchematicA-titocEp APR 1 9 2016 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 6,004'MD 5,245'TVD Packers and SSSV(type,measured and true vertical depth) Swell Pkr;N/A 2,936'MD 2,770'TVD N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 275 Subsequent to operation: 0 2923 53 1203 1203 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑✓ Exploratory El Development LI Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run U 16.Well Status after work: Oil ❑ Gas ❑ WDSPL Li Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ Li SUSP Li SPLUG U 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: 315-727 Contact Joe Kaiser-777-8393 Email jkaiser@hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature ' 1�//'" - Phone 907-777-8405 Date 77 / . e-/ Li' ''' .74/ Form 10-404 Revised 5/2015 1 elf/� RBDMS V 17 Ni iiia 4 5 2016 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU-25 CTU 50-133-20644-00 214-132 3/7/16 3/8/16 Daily Operations: 03/07/2016- Monday Obtain PTW. Hold safety meeting. Discuss job procedures and steps. Lay herculite. Spot coil equipment 1.5" CT. Spot return tank. Build containment. Start BOPE test. Test all rams and valves to 250 psi/4,500 psi. AOGCC 24 hr notification sent 3-6-16 @ 1900 hrs. Witness waived by Jim Regg on 3-7-16 @ 0900. Test completed 1700 hrs. Location secure. Crews off location. Unload Weatherford tool pallet. 03/08/2016-Tuesday Obtain PTW. Hold safety meeting. Discuss JSA and job operations. Fire equipment. Pick injector head. Stab 20' lubricator. Stabbed on well to pump reel volume to ensure coil is clear. Having troubles priming pump. Start SLB down time. Pumped primed. Start fluid packing coil. 11 bbls into reel volume noticed spikes in pressure. Looks to be ice plug in CT string. Pumped from well to pressure up on back side of ice plug. Continue with reel volume. Pop off well. Make up coil connector, check valves and disco. Pull test to 20K. Pressure test 250 low 3,500 high. Make up tool string. CC and DFCV, OD 2.2". HYD disco OD 2.125", X over 2.0" OD, ball lock circ sub 1.7" OD, down hole filter 1.689" OD, CT running tool 1.689" OD, IRBP 2.125" OD. BHA length 15.49'. Stab on well. Pressure test low 250 high 4,500 psi. Start running in hole. Initial WHP 900 psi. Stacking weight of 3K down at 215'. Confirmed stripper lube is not working. Weight stacked caused by stripper friction bite. Troubleshoot problem. Stripper fixed. Continue RIH at 50 ft/min. Park at 6,380'. Load 7/16" ball. Launch ball confirmed moving in coil. Pick up to 6,347' to put center of element at 6,350'. Depth encoder vs mechanical counter only 8 ft difference from surface to setting depth. Pump 12 bbls to get ball over gooseneck at 1.2 bbls/min. Drop rate to .25 bbls min to land ball on seat. Coil pressure 250 psi. Ball landed on seat and pressured up to 500 psi. Wait 30 minutes to allow for fluid temperatures to equalize from thermal expansion. Increase pressure to 900 psi. Pressure dropped. IBP set. Pick up 4K over string weight to release from IBP. Normal OOH weight 12,300 lbs. 17K free. POOH to surface. No issues passing through WLEG. Confirmed IBP in hole. Inhibit CT string with corrosion inhibitor. Close master and swab 900psi on wellhead. Online with N2 to blow reel dry. Let N2 bleed down. Start rigging down iron and data cables. Pop off well. Break down tools. Confirmed all screws sheered. Stack down injector. Continue rigging down. Crews off location. Fish left in hole is 6.96' in length with a fishing neck of 1" OD by 3.5" in length. Weatherford hydraulic release overshot needed to pull IBP. Crews will arrive following day to demobe equipment from location. . • 0 . inBeaver Creek #25 SCHEMATIC Pad 3 1246' FNL, 1,656' FWL, Sec. 34, Permit#: 214-132 T7N, R10W, S.M. API#: 50-133-20644-00 Hileocp Alaska, LL(; Prop.Des: FED A-028083 KB elevation: 179.2' (18.6'AGL) J - Conductor Lat: N60° 39' 29.694" IIIIMwIIIr 16" X-56 109 ppf Long: W151° 1' 2.615" Top Bottom Spud: 10/19/2014 21:30 hrs MD o' 78' TD: 11/02/2014 15:30 hrs I TVD 0' 78' Rig Released: 11/07/2014 18:00 hrs Surface Casing Production Casing 9-5/8" L-80 40 ppf BTC 5-1/2" P-110 17 ppf GeoConn Top Bottom Top Bottom MD 0' 3,488' MD 0' 8,196' I 71 4 ND 0' 3,270' TVD 0' 5,264' 12-1/4"hole Lead Cmt w/570 sks(250 bbls)of Fr 1 12.0 ppg,Class G, Tail Cmt wl 221 sks(48 bbls) 8-1/2"hole Cmt w/1,157sks(283 bbls)of 15.3 ppg, of 15.4 ppg,Class G, cement to surface Class G cmt w/EASYBLOK TOC(CBL 11/14/14)-3,472' Tubing 2-7/8" L-80 6.5 ppf EUE fit._ Top Bottom Tree cxn=9-1/2"Otis Il8.0"Seal Diameter 5-1/8" MD 6,004' Modified ID Bore ND 0' 5,245' ill I Casing Shoe @ 8,196' t 1 1111.7.11111,ryll ..1 . A II Ell' 11 11 .ILII Ilk ' II IIEI II. II II II .11E11:11 t14 _II1 M I. A Q4 ® I QC , .x 1 Q4 '4` I/I .9 RA#1 RA#2 RA#3 RA#4 RA#5 RA#6 R' • RA#8 Casing/Cementing Detail Tag(unset cement)@ 8,090'CTM - 9.9 ppg Mud w/2.0"Jet Nozzle(11/16/14) - 10.5 ppg Mud Push(45 bbl) PBTD: TD: - 15.3 ppg Cement(283 bbl) 8,105'MD 8,208'MD - 8.5 ppg 3%KCI(190 bbl) 5,264'ND 5,264'ND Perforations(Sterling B4): Zone MD ND Size SPF Date Status Short RA Marker Joints Sterling B4 8,045'-8,055' 5,264'-5,264' 3-1/8" 6 11/19/14 Open .. - Directional Data Sterling B4 7,990'-8,000' 5,264'-5,264' 3-1/8" 6 11/19/14 Open #1 @ 6,183'-6493'MD KOP:659' „' Sterling B4 7,890'-7,900' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #2 @ 6,450'-6,460'MD Hole angle at 9-5/8' shC44,4501thH Sterling B4 7,790'-7,800' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #3 @ 6,680'-6,695'MD Sterling B4 7,690'-7,700' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #4 @ 6,914'-6,924'MD Max.Doglegs: #5 Sterling B4 7,590'-7,600' 5,264'-5,264' 3-1/8" 6 11/20/14 Open @ 7,186'-7,201'MD 3,965'- 6.9 deg/100 ft -; •°°':#6 5,266'- 7.0 de /100 ft Sterling B4 7,490'-7,500' 5,264'-5,264' 3-1/8" 6 11/20/14 Open @ 7,460'-7,470'MD deg /100 B4 7,390'-7,400' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #7 @ 7,686%7,701'MD 6,999'- 6.5 deg/100 ft Sterling B4 7,290'-7,300' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,190'-7,200' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Jewelry Depth Sterling B4 7,090'-7,100' 5,264'-5,264' 3-1/8" 6 11/21/14 Open 1.Tubing Hanger 18.6' Sterling B4 6,990'-7,000' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 2,4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 1,650' Sterling B4 6,890'-6,900' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 3.4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 2,570' Sterling B4 6,790'-6,800' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 4.Swell Packer(21'Long) 2,936' Sterling B4 6,690'-6,700' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 5.4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 3,070' Sterling B4 6,590'-6,600' 5,262'-5,262' 3-1/8" 6 11/21/14 Open 6.4.50"Gaslift Mandrel(w/Reverse Lift Valve,orifice) 3,667' Sterling B4 6,490'-6,500' 5,260'-5,260' 3-1/8" 6 11/21/14 Open 7.4.50"Gaslift Mandrel(w/Dummy Valve) 4,167' Sterling B4 6,390'-6,400' 5,260'-5,260' 3-1/8" 6 11/22/14 Open 8.4.50"Gaslift Mandrel(w/Dummy Valve) 4,732' 9. 1/4"Control line w/Flow Control Valve(set@ t,soopsi) 5,000' Sterling B4 6,290'-6,300' 5,260'-5,260' 3-1/8" 6 11/22/14 Open 10.X-Profile(2.313"ID) 5,583' Sterling B4 6,190'-6,200' 5,260'-5,260' 3-1/8" 6 11/22/14 Open 11.WLEG 6,004' Sterling B4 6,090'-6,100' 5,256'-5,256' 3-1/8" 6 11/22/14 Open 12.Inflatable Bridge Plug 6,350' Well Name&Number: Beaver Creek#25 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska _ Country: USA Angle @KOP and Depth: 0.5°@ 659' Angle/Perfs: 90° Maximum Deviation: 90.6°@ 6,999' Date Completed: 12/6/2015 Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By: Donna Ambruz Downhole Revision Date: 12/12/2014 Schematic Revision Date: 3/16/2016 • • V OF Tiff, g�.\ I//7,- . A THE STATE Alaska Oil and Gas of LA sKA Conservation Commission 333 West Seventh Avenue " r GOVERNOR BILL WALKER Anchorage, Alaska 9905001-3572 572 w,'' OFALASFax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 sat* EU MAR 0 3201G Anchorage, AK 99503 Re: Beaver Creek Field, Sterling Gas Pool, BCU 25 Permit to Drill Number: 214-132 Sundry Number: 316-136 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this Ay of February, 2016. • RBDMS (,k, FEB Z 6 2016 RECEIVED • • FEB 19 2016 STATE OF ALASKA 07 S Z/Z.9/ 4 ALASKA OIL AND GAS CONSERVATION COMMISSION Aorcr APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations • Fracture Stimulate ❑ Repair Well p ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool LI Re-enter Susp Well ❑ Alter Casing ❑ Other: Set Plug w/CT E. 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5. Permit to Drill Number: Exploratory ❑ Development ❑✓ _ 214-132 . 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ElService ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20644-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 237A - Beaver Creek(BCU)25 Will planned perforations require a spacing exception? Yes 111No E 9.Property Designation(Lease Number): 10. Field/Pool(s): A028083 - Beaver Creek/Sterling Gas Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,208' 5,264' 8,105' 5,264' 1,517' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 78' 78' Surface 3,488' 9-5/8" 3,488' 3,270' 5,750 psi 3,090 psi Intermediate Production 8,196' 5-1/2" 8,196' 5,264' 10,640 psi 7,460P si Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#I L-80 6,004 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Swell Pkr; N/A 2,936'MD-2,770'TVD;N/A 12.Attachments: Proposal Summary p Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑I Exploratory ❑ Stratigraphic ❑ Development ❑ - Service ❑ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: March 7,2016 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0' WAG ❑ GSTOR LI SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Joe Kaiser-777-8393 Email jkaiser@hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature ,� Phone 907-777-8405 Date l711/1C COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number Plug Integrity ❑ Lr c BOP Test LTJ Mechanical �Integrity Test ❑ Location Clearance ❑ Other: `i coo f'S: /7c�l� ca/ C , f C C_r f--t.j Post Initial Injection MIT Req'd? Yes ❑ No ❑ I RBDMSU' FEB 1 6 2016 Spacing Exception Required? Yes Li No Subsequent Form Required: //.. "' P APPROVED BY J Approved by: a. �� COMMISSIONER THE COMMISSION Date: 2 - 24,-1,6 _ .2 _2.3.46. SubiForm and Form 10-403 Revised 11/2015 Approved application oiRrtGitNAhisiate Of approva/!/ ��Attachments in n Duplicate � • • Well Prognosis Well: BCU-25 Iiilcoru Alaska,LL Date: 2/19/2016 Well Name: BCU-25 API Number: 50-133-20639-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: March 7th, 2016 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-132 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: - 2,043 psi @ 5,264' TVD (Based on P/T survey on 11/23/14) Maximum Expected BHP: -2,043 psi @ 5,264' TVD (Based on P/T survey on 11/23/14) Max. Potenital Surface Pressure: - 1,517 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#25 was drilled as a Grass roots horizontal monobore completion in 2014 to target the Sterling B4.The well was perforated via wireline tractor with 20 each 10' intervals, spaced roughly 100' apart. The well loaded up with fluid and has loaded up in the 5-1/2" casing. In late 2014, a 2-7/8" tubing velocity string without a packer was run to help unload the water while producing gas from the Sterling B4 by producing up the tubing x casing annulus. Gaslift mandrels were installed to allow running reverse gaslift valves that would allow gaslift gas to be injected down the tubing and help lift produced fluids up the annulus. At the time of being shut-in, BC 25 was producing 0.8-1.2 MMscfd and up to 3,600 bpd water. A PLT was run in late 2015. It was determined that gas was coming from the top 3 perforations and the water was coming from the remaining lower perforations. The purpose of this sundry is set an inflatable through tubing bridge plug between the 3rd and 4th perforations to plugback water production. Notes Regarding Wellbore Condition • Max doglegs of 6.9°/100' at 3,965' MD and 7.0°/100' at 5,266' MD. Coiled Tubing Procedure: -1--"A'Y'- 1. —r`sY'-1. MIRU Coiled Tubing, PT BOPE to 4,500 psi Hi 250 Low for 5 min. 2. MU Coil Connector, Ball Lock Circ Sub, Screen, Running tool, and Inflatable Bridge Plug (IBP). 3. RIH with BHA at no more than 75 fpm (20fpm max through known restrictions). 4. Set IBP at -6,350'. 5. POOH. LD BHA. 6. RD Coiled Tubing. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Coil BOPE • • Beaver Creek #25 ACTUAL Pad 3 SCHEMATIC 1246' FNL, 1,656' FWL, Sec. 34, Permit#: 214-132 T7N, R10W, S.M. API#: 50-133-20644-00 Ilitem.p Alaska. LL(: Prop.Des: FED A-028083 KB elevation: 179.2' (18.6'AGL) J ,.i' Conductor Lat: N60° 39' 29.694" 16" x-56 109 ppf Long: W151° 1' 2.615" Top Bottom Spud: 10/19/2014 21:30 hrs MD 0' 78' TD: 11/02/2014 15:30 hrs TVD 0' 78' Rig Released: 11/07/2014 18:00 hrs Surface Casing Production Casing 9-5/8" L-80 40 ppf BTC 5-1/2" P-110 17 ppf GeoConn Top Bottom Top Bottom I 4 MD 0' 3,488' MD 0' 8,196' TVD 0' 3,270' TVD 0' 5,264' F I 12-1/4"hole Lead Cmt w/570 sks(250 bbls)of . IIIMF' 12.0 ppg,Class G, Tail Cmt wl 221 sks(48 bbls) 8-1/2"hole Cmt w/1,157sks(283 bbls)of 15.3 ppg, 1111 of 15.4 ppg,Class G, cement to surface Class G cmt w/EASYBLOK 11•11P I TOC(CBL 11/14/14)-3,472' Tubing 6 2-7/8" L-80 6.5 ppf EUE Tree cxn=9-1/2"Otis Top Bottom .,;) 7 8.0"Seal Diameter MD 0' 6,004' P` 5-1/8"Modified ID Bore TVD 0' 5,245' T 8 9 I 1 Q u • 11 Casing Shoe @ 8,196' 4 I Il II II -11E3111 11 ,11r-3.11 II 1 . II 11E1 II 1III- II ,I 11 \ .,,..;,...._,,.. 1 ' ITa11 II I Il II ea' H I1Lbv II II I lI IIS 11 1I 1 " II I RA#1 RA#2 RA#3 RA#4 RA#5 RA#6 R � RA#8 Casing/Cementing Detail Tag(unset cement)@ 8,090'CTM - 9.9 ppg Mud - 10.5 ppg Mud Push(45 bbl) w/2.0"Jet Nozzle(11/16/14) PBT- 15.3 ppg Cement(283 bbl) ,105TD: - 8.5 ppg 3%KCI(190 bbl) 8,105'MD 8,208'MD 5,264'TVD 5,264'TVD Perforations(Sterling B4): Zone MD TVD Size SPF Date Status Short RA Marker Joints Sterling B4 8,045'-8,055' 5,264'-5,264' 3-1/8" 6 11/19/14 Open Directional Data Sterling B4 7,990'-8,000' 5,264'-5,264' 3-1/8" 6 11/19/14 Open #1 @ 6,183'-6,193'MD KOP:659' Sterling B4 7,890'-7,900' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #2 @ 6,450'-6,460'MD Hole angle at 9-5/8"shoe=25 deg Sterling 84 7,790'-7,800' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #3 @ 6,680'-6,695'MD Sterling B4 7,690'-7,700' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #4 @ 6,914'-6,924'MD libit Doglegs: Sterling B4 7,590'-7,600' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #5 @ 7,186'-7,201'MD '- 6.9 deg/100 ft Sterling B4 7,490'-7,500' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #6 @ 7,460'-7,470'MD 7.0 deg/100 ft Sterling B4 7,390'-7,400' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #7 @ 7,686'-7,701'MD 6,999'- 6.5 deg/100 ft Sterling B4 7,290'-7,300' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,190'-7,200' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Sterling B4 7,090'-7,100' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Jewelry Depth Sterling B4 6,990'-7,000' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 1.Tubing Hanger 18.6' Sterling B4 6,890'-6,900' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 2.4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 1,650' Sterling B4 6,790'-6,800' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 3.4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 2,570' Sterling B4 6,690'-6,700' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 4.Swell Packer(21'Long) 2,936' Sterling B4 6,590'-6,600' 5,262'-5,262' 3-1/8" 6 11/21/14 Open 5.4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 3,070' Sterling B4 6,490'-6,500' 5,260'-5,260' 3-1/8" 6 11/21/14 Open 6.4.50"Gaslift Mandrel(w/Reverse Lift Valve,orifice) 3,667' Sterling B4 6,39U-6,400' 5,26U-5,260' 3-1/8" 6 11/22/14 Open 7.4.50"Gaslift Mandrel(w/Dummy Valve) 4,167' 8.4.50"Gaslift Mandrel(w/Dummy Valve) 4,732' Sterling B4 6,290'-6,300' 5,260'-5,260' 3-1/8" 6 11/22/14 Open 9.1/4"Control line w/Flow Control Valve(see@ 1,600 psi) 5,000' Sterling B4 6,190'-6,200' 5,260'-5,260' 3-1/8" 6 11/22/14 Open 10.X-Profile(2.313"ID) 5,583' Sterling B4 6,090'-6,100' 5,256'-5,256' 3-1/8" 6 11/22/14 Open 11.WLEG 6,004' Well Name&Number: Beaver Creek#25 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 0.5°@ 659' Angle/Perfs: 90° Maximum Deviation: 90.6°@ 6,999' Date Completed: 12/6/2015 Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By: Joe Kaiser Downhole Revision Date: 12/12/2014 Schematic Revision Date: 12/6/2015 • • . IliBeaver Creek #25 PROPOSED Pad 3 Cr"rMATIC 1246' FNL, 1,656' FWL, Sec. 34, Permit#: 214-132 T7N, R10W, S.M. API#: 50-133-20644-00 Hilcorp Alaska,LLC: Prop.Des: FED A-028083 KB elevation: 179.2' (18.6'AGL) J Conductor Lat: N60° 39' 29.694" T1AIM11► 16" X-56 109 ppf Long: W151° 1' 2.615" T� Bottom Spud: 10/19/2014 21:30 hrs , 1 MD 0' 78' TD: 11/02/2014 15:30 hrs TVD 0' 78' Rig Released: 11/07/2014 18:00 hrs 6 Surface Casing Production Casing I 9-5/8" L-80 40 ppf BTC 5-1/2" P-110 17 ppf GeoConn Top MD 0' Bottom 3,4 ' Top MD 0' Bottom I 11 . 78,196' ' 12-1/4"hole Lead Cmt w/570 sks(250 bbls)of TVD 0' 5,264' . 6 4 TVD 0' 3,270012.0 ppg,Class G, Tail Cmt w/221 sks(48 bbls) 8-1/2"hole Cmt w/1,157sks(283 bbls)of 15.3 ppg, of 15.4 ppg,Class G, cement to surface Class G cmt w/EASYBLOK . 0_ , ,, .,.,. EI TOC(CBL 11/14/14)-3,472' Tubing 2-7/8" L-80 6.5 ppf EUE • H-lb ,.�_ Tree cxn=9-1/2"Otis Top Bottom 8.0"Seal Diameter MD 0' 6,004' 5-1/8"Modified ID Bore TVD 0' 5,245' II Il I / Casing Shoe @ 8,196' llti Irill .Il . 1r:i II IMI 1111F-111 II i • II I II II _* IIII .Is l liA , \itaisii, r" II . .;'-'. '. '' 4" T `1''ll H IMI II Ca II IIS H II ani u " II I RA#1 r�-RA�' 2 RA#3 RA#4 RA#5 RA#6 / RA#8 Casing/Cementing Detail - 9.9 ppg Mud Tag(unset cement)@ 8,090'CTM w/2.0"Jet Nozzle(11/16/14) - 10.5 ppg Mud Push(45 bbl) PBTD: TD: - 15.3 ppg Cement(283 bbl) - 8.5 ppg 3%KCI(190 bbl) MD 8,6 5,,264264''ND 5,264' MD TVD Perforations(Sterling B4): Zone MD ND Size SPF Date Status Short RA Marker Joints Sterling B4 8,045'-8,055' 5,264'-5,264' 3-1/8" 6 11/19/14 Open Directional Data Sterling B4 7,990'-8,000' 5,264'-5,264' 3-1/8" 6 11/19/14 Open #1 @ 6,183'-6,193'MD KOP:659' Sterling B4 7,890'-7,900' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #2 @ 6,450'-6,460'MD Hole angle at 9-5/8"shoe=25 deg Sterling B4 7,790'-7,800' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #3 @ 6,680'-6,695'MD Sterling B4 7,690'-7,700' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #4 @ 6,914'-6,924'MD Max.Doglegs: Sterling B4 7,590'-7,600' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #5 @ 7,186'4,201'MD 3,965- 6.9 deg/100 ft iiiIMEESEE Sterling B4 7,490'-7,500' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #6 @ 7,480'-7,470'MD 5,266'- 7.0 deg/100 ft #7 @ 7,686'-7,701'MD 6,999'- 6.5 deg/100 ft Sterling B4 7,390'-7,400' 5,264'-5,264' 3-1/8" 6 11/20/14 Open ,,zu,..,„..,. Sterling B4 7,290'-7,300' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling 64 7,190'-7,200' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Jewelry Depth Sterling B4 7,090'-7,100' 5,264'-5,264' 3-1/8" 6 11/21/14 Open 1.Tubing Hanger 18.6' Sterling B4 6,990'-7,000' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 2.4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 1,650' Sterling B4 6,890'-6,900' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 3.4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 2,570' Sterling B4 6,790'-6,800' 5,265-5,265' 3-1/8" 6 11/21/14 Open 4.Swell Packer(21'Long) 2,936' Sterling B4 6,690'-6,700' 5,265-5,265' 3-1/8" 6 11/21/14 Open 5.4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 3,070' Sterling B4 6,590'-6,600' 5,262'-5,262' 3-1/8" 6 11/21/14 Open 6.4.50"Gaslift Mandrel(w/Reverse Lift Valve,orifice) 3,667' Sterling B4 6,490'-6,500' 5,260'-5,260' 3-1/8" 6 11/21/14 Open 7.4.50"Gaslift Mandrel(w/Dummy Valve) 4,167' Sterling B4 6,390'-6,400' 5,260'-5,260' 3-1/8" 6 11/22/14 Open 8.4.50"Gaslift Mandrel(w/Dummy Valve) 4,732' 9.1/4"Control line w/Flow Control Valve(set@ 1,600 psi) 5,000' Sterling B4 6,290'-6,300' 5,260'-5,260' 3-1/8" 6 11/22/14 Open 10.X-Profile(2.313"ID) 5,583' Sterling B4 6,190'-6,200' 5,260'-5,260' 3-1/8" 6 11/22/14 Open 11.WLEG 6,004' Sterling B4 6,090'-6,100' 5,256'-5,256' 3-1/8" 6 11/22/14 Open Well Name&Number: Beaver Creek#25 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 0.5°@ 659' Angle/Perfs: 90° Maximum Deviation: 90.6°@ 6,999' Date Completed: 12/6/2015 Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By: Joe Kaiser Downhole Revision Date: 12/12/2014 Schematic Revision Date: 2/19/2016 • • Beaver Creek Unit COIL BOPE BCU-25 02-19-2016 11;14,,r %l...L.,_I.I I BCU#25 3 16X10%X75/8X4'A 3 Coil Tubing BOP Lubricator to injection head 0 c rI 1.75"Tandem Stripper c_ _ _ Blind/Shear 4 1/16 10 . .'• Blind/Shear ' 1 iii C= Blind/Shear e Blind/Shead.'.'-1 - C 4= _ _ _ Slip Slip = e - Mud Cross = Pi = p G Pipe •L' 4 1/16 10M X 4 1/16 10M Outlet rt�9 w/2- 2 1/16 10M full opening FMC valves Lli - _ . 1ii1111\ • I GO i i 11 ® ,iii ______________ -: Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M 2 1/16 10M 2 1/16 10M Crossover spool 1•I 4 1/16 10M X 2 9/16 5M Valve,Swab, WKM-M, r�' -' .-'' .J .00 2 9/16 5M FE, HWO, {o,{ o. Valve, Wing,WKM-M, DD trim _ - , 2 1/16 5M FE, HWO, 4 Valve,Wing, WKM-M, DD trim , d 2 1/16 SM FE, HWO, iiinaMiiiis up DD trim ( 1 , U ` : . .� Gas Lift I I I ��,,• O • g O n 6), ?# Production tie in 1 C =o � 1 1 * 2 line siiimin isinowimme Valve, Master,WKM-M, 4f -.c, • 2 9/16 5M FE, HWO, �'` �V . DD trim FaMiGisms Valve,Master,WKM-M, ~' From Casing � O`©� 2 9/16 SM FE, HWO, t DD trim .. ' Valve r.il`anm RECEIVED STATE OF ALASKA DEC 17 2015 • AL OIL AND GAS CONSERVATION COM ION ' REPORT OF SUNDRY WELL OPERATIONS 4 OGGC 1.Operations Abandon L Plug Perforations Li Fracture Stimulate a Pull Tubing Li Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program n Plug for Redrill ❑ ..rforate New Pool ❑ Repair Well ❑ Re-enter Susp Wet❑ Other: Run PLT Survey ❑✓ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: s(Lj Name: Hilcorp Alaska, LLC Development ❑✓ Exploratory ❑ 214-132 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic Li Service ❑ 6.API Number: Anchorage,AK 99503 50-133-20644-00 7.Property Designation(Lease Number): 8.Well Name and Number: A028083 Beaver Creek(BCU)25 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Sterling Gas Pool 11.Present Well Condition Summary: Total Depth measured 8,208 feet Plugs measured N/A feet true vertical 5,264 feet Junk measured N/A feet Effective Depth measured 8,105 feet Packer measured N/A feet true vertical 5,264 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 78' 78' Surface 3,488' 9-5/8" 3,488' 3,270' 5,750 psi 3,090 psi Intermediate Production 8,196' 5-1/2" 8,196' 5,264' 10,640 psi 7,460 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic >C Ep FEB 0 32016 Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 6,004'MD 5,245'TVD Packers and SSSV(type,measured and true vertical depth) Swell Pkr; N/A 2,936'MD 2,770'TVD N/A; N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure. N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 162 1539 0 187 Subsequent to operation: 0 781 3206 0 295 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 ❑ Gas ❑ WDSPL Li Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Li 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: 315-727 Contact Joe Kaiser-777-8393 Email ikaiser@hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature Phone 907-777-8405 Date)tit /15 j:.- '- tel/ / / - Form 10-404 Revised 5/2015 `j Z-In-(S RBDMS DEC 2 12015 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU-25 CTU 50-133-20644-00 214-132 12/10/15 12/13/15 Daily Operations: 12/10/2015-Thursday Hold safety meeting and discuss JSA. AOGCC 24 hr BOPE test notification sent 12/9/15@ 1210. Witness waived by Jim Regg on 12/9/15 @ 1517 hrs. MIRU CTU #12. Spot return tank. Unload manlift, berm return tank. Rig up iron. Rig up BOP and wellhead xover. Stab 1.5in pipe. Pick injector head. Stab 10' lubricator. Make up CC 1.5" nozzle. Pull test 15K. Stab on well. Start BOPE test. Draw down test complete. Low pt 200-300 psi and high pt 4,500 psi on all valves and rams. Full body low pt 256 psi ending 250 psi. high body 4,655 psi end after 5 minutes at 4,641. Loss of 14 psi. Good test. Close top set B/S, low pt 270 psi 265 psi. Good test. High pt 4,574 psi. Start 5 minute test. 4,532 psi. Bleed down. Open top set B/S. Close second B/S. 271 psi start 5 minute test. 263 psi. Good to go. 4,619 psi. Start 5 minute test. 4,573 psi. Bleed down. Open B/S. RIH for pipe ram test. push 10k pull 20K. Low pt 297 psi. 5 minute test. 294 psi. Coming up for highpt. 4,551 psi 5 minute test 4,534 high pt good to go. Bleed down. Bleed down to 2,500 psi to test pump check. Eq ports tested. Choke valves all passed. BOP test complete. Blow down stack. Pop off well. Set down 10' lubricator. Install night cap on BOPE. Close all ground valves. Wellsite secure. Crews off location. 12/11/2015- Friday Obtain PTW. Hold safety meeting. Discuss JSA and job procedures. SLB memory installing BEI counter on injector head. Fire equipment. Pick injector head. Stab 30' of lubricator. Make up BHA, 1.5" CC, 1.75" CV, 1.75" Stinger, 2.1" xover, 2.0" xover, 1.75"jet swirl. 6.3' BHA length. Stab on well low pt 250 high pt 4,500 psi. Bleed down lubricator to 1,100 psi. Open swab valve 15.5 turns. RIH 1153 psi WHP. Exit tubing tail. Weight check 9,500 lbs. Clean RIH weight and up weights. RIH wt-3K. @ 7500'. PU weight at 7,500' 10.5K. Clean. No signs of fill. Tag PBTD 8,090' CTMD. 11.5K up weight clean. RIH to tag PBTD 2nd time. Pick up to 8,060' and paint flag. 1,153 psi WHP. POOH to surface. Up weight 10.6K . Tagged up at surface. SITP 1,156 psi. Bleed down stack. Pop off. Break down tools, stack down 30' lubricator. Set injector head down. Install night cap. Crews off location. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU-25 CTU 50-133-20644-00 214-132 12/10/15 12/13/15 Daily Operations: 12/12/2015-Saturday Obtain PTW. Hold safety meeting. Discuss JSA and job procedures. Fire equipment. Pick injector head. Make up memory logging tools and FSI tool. Tool OD 1.625". 26' length. Stab on well. Low pt 250 high pt 4,500 psi. Bleed down to 1,100 psi. Open swab 18.5 turns. Stop for memory to calibarate depth. Slow down for GLMs. Run past tubing tail. Pick up through tubing tail clean. Tag at 8,060'. Wait 5 minutes. Log OOH at 40 ft/min. WHP 1,155 psi. 1.685 mmcf day with tubing IA pressure 331 psi. Stopped logging at 6,120'. Wait 5 minutes. RIH. RIH logging at 40 ft/min. Stopped at 8,060'. Wait 5 minutes. Start logging OOH at 60 ft/min. Well flowing at 1.685M 331 psi IA pressure 1,155 WHP/injection pressure. Stopped at 6,120'. Hold for 5 minutes RIH and Log down at 60 ft/min. Parked at 8,060'. POOH logging at 80 ft/min. Log up to 6,120'. Wait 5 minutes, RIH logging down at 80 ft/min. Stopped at 8,060'. Start station stops between perfs for 5 minutes each. While POOH. Last stop at 6,144' wait 5 minutes. Beging POOH to surface. 1.945 MCFD. IA pressure 318 psi, tubing pressure 1,150 psi . POOH. Tagged up at I' surface. Blow down lubricator. Pop off well to break down memory/FSI tools. Tools look clean and intact. Download tool data. Stab back on well to blow reel dry. No data on tools. Pop off well rig back injector head. Change stripper/pack off rubbers. Wellsite secure. Crews off location. SLB testing headed to shop to check out tool. Tool powered up at shop. Looks to be a problem with battery. Will run with new battery tomorrow. 12/13/2015-Sunday Obtain PTW. Hold safety meeting discuss job procedure. Pop night cap. Pick injector head. Stab 30' of lubricator. Attempt to install memory FSI logging tool. Tool would not turn on. Break down tools and bring to shop and BC office. Attempt hardline start up. Re-program tools. Tools confirmed running. Install tools on CT. Stab on well. Pressure test 250/4,500. Bleed down. Open well 18.5 turns and RIH. Stop at 2,000'for memory to calibrate depth encoder. Continue RIH. Stop coil at 8,070'. Wait 5 minutes start logging OOH at 40ft/min from 8,0701-6,120'. Monitor well conditions. 1.611 MCFD, IA 323 psi, WHP/Gas INJ psi 1,150. Wait 5 minutes. RIH logging from 6,120' to 8,070' at 40 ft/min. LOG OOH at 60 ft/min from 8,070' to 6,120' well @ 1.540 MCFD, IA 327 psi. RIH for down pass at 60 ft/min from 6,120' to 8,070'. Log OOH from 8,070'-6,120' @ 80 ft/min. 1.510 MCFD, IA 319 psi. RIH from 6,120'- 8,070' at 80 ft/min. Start station stops between perf intervals 21 stops total every 100'. 3-5 minute stops per 100' stops. Starting from 8,075'-6,145'. Start POOH 110 ft/min. At surface swab closed. Bleed down stack. 1,150 psi WHP. Pop off well. Break down Memory FSI tool. Downlaoding data. Stab on well. Start cooling down N2. Blow down reel to open top tank. Down on N2. Bleed down CT reel. Pop off. Set down 30' lubricator. Lay down injector head. Install night cap on BOPE. Location secure. Crews will arrive at 0900 hrs to rig down CTU 12. i a ' ElBeaver Creek #25 ACTUAL Pad 3 SCHEMATIC 1246' FNL, 1,656' FWL, Sec. 34, Permit#: 214-132 T7N, R10W, S.M. API#: 50-133-20644-00 Hilcorp Alaska, LL(: Prop.Des: FED A-028083 KB elevation: 179.2' (18.6'AGL) J inow Conductor Lat: N60° 39' 29.694" If , t-L 16" x-56 109 ppf Long: W151° 1' 2.615" Top Bottom Spud: 10/19/2014 21:30 hrs MD 0' 78' TD: 11/02/2014 15:30 hrs TVD 0' 78' Rig Released: 11/07/2014 18:00 his Surface Casinq Production Casinq 9-5/8" L-80 40 ppf BTC 5-1/2" P-110 17 ppf GeoConn Top Bottom Top Bottom - MD 0' 3,488' MD 0' 8,196' I I f- . 4 ND 0' 3,270' ND 0' 5,264' 12-1/4"hole Lead Cmt w/570 sks(250 bbls)of I ppg,Class G, Tail Cmt w/221 sks(48 bbls) 8-1/2"hole Cmt w/1,157sks(283 bbls)of 15.3 ppg, of 15.4 ppg,Class G, cement to surface Class G cmt w/EASYBLOK g, a TOC(CBL 11/14/14)-3,472' Tubing 6 2-7/8" L-80 6.5 ppf EUE e � v Tree cxn=9-1/2"Otis Top Bottom o 7 8.0"Seal Diameter MD 0' 6,004' le aS 5-118 Modified ID Bore ND 0' 5,245' I ' , 9 a'k I I I: 1 D 11 Casing Shoe @ 8,196' 1 %1 r;it A AEI II ILtail ,ll HP- II II- i 'it ih ii. 11 Eli! Ii .l ill , _ ' .. : . A I A Q4 I I cep . Y. 'N ' 1 (�' ', . �;� � Qg ISI Q4 ., RA#1 RA#2 RA#3 RA#4 RA#5 RA#6 R• • RA#8 Casing/Cementing Detail Tag(unset cement)@ 8,090'CTM - 9.9 ppg Mud wl 2.0"Jet Nozzle(11/16/14) - 10.5 ppg Mud Push(45 bbl) PBTD: TD: - 15.3 ppg Cement(283 bbl) 8,105'MD 8,208'MD - 8.5 ppg 3%KCI(190 bbl) 5,264'ND 5,264'ND Perforations(Sterling 84): Zone MD ND Size SPF Date Status Short RA Marker Joints Sterling B4 8,045'-8,055' 5,264'-5,264' 3-1/8" 6 11/19/14 Open Directional Data Sterling B4 7,990'-8,000' 5,264'-5,264' 3-1/8" 6 11/19/14 Open #1 @ 6,183'-6,193'MD KOP:659' Sterling B4 7,890'-7,900' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #2 @ 6,450'-6,460'MD Hole angle at 9-5/8"shoe=25 deg Sterling B4 7,790'-7,800' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #3 @ 6,680'-6,695'MD Sterling B4 7,690'-7,700' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #4 @ 6,914"-6,924'MD Max.Doglegs: Sterling B4 7,590'-7,600' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #5 @ 7,186'-7,201'MD 3,965'- 6.9 deg/100 ft Sterling B4 7,490'-7,500' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #6 @ T,460'-7,470'MD 5,266'- 7.0 deg/100 ft #7 @ 7,686'-7,701'MD 6 999 &.S.C2t1013 tL Sterling B4 7,390'-7,400' 5,264'-5,264' 3-1/8" 6 11/20/14 Open .;:ilii .... •••••••••••••••••.min ii Sterling B4 7,290'-7,300' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Sterling B4 7,190'-7,200' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Sterling B4 7,090'-7,100' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Jewelry Depth Sterling B4 6,990'-7,000' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 1.Tubing Hanger 18.6' Sterling B4 6,890'-6,900' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 2.4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 1,650' Sterling B4 6,790'-6,800' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 3.4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 2,570' Sterling 134 6,690'-6,700' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 4.Swell Packer(21'Long) 2,936' Sterling B4 6,590'-6,600' 5,262'-5,262' 3-1/8" 6 11/21/14 Open 5.4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 3,070' Sterling B4 6,490'-6,500' 5,260'-5,260' 3-1/8" 6 11/21/14 Open 6.4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 3,667' Sterling B4 6,390'-6,400' 5,260'-5,260' 3-1/8" 6 11/22/14 Open 7.4.50"Gaslift Mandrel(w/Reverse Lift Valve,orifice) 4,167' 8.4.50"Gaslift Mandrel(w/Dummy Valve) 4,732' Sterling B4 6,290'-6,300' 5,260'-5,260' 3-1/8" 6 11/22/14 Open 9.1/4"Control line w/Flow Control Valve(ser@ 1,600 psi) 5,000' Sterling B4 6,190'-6,200' 5,260'-5,260' 3-1/8" 6 11/22/14 Open 10.X-Profile(2.313"ID) 5,583' 11.WLEG 6,004' Well Name&Number: Beaver Creek#25 Lease: A-028083 • County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country USA Angle @KOP and Depth 0.5°@ 659' Angle/Perfs 90° Maximum Deviation: 90.6°@ 6,999' Date Completed: 12/12/2014 Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 12/12/2014 Schematic Revision Date: 12/29/2014 oF r� 4. THE STATE l%%i� Alaska Oil and Gas OfLASKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 () '4LAS1 Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager ;C, Aqx Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 RVl 3 Anchorage, AK 99503 Re: Beaver Creek Field, Sterling Gas Pool, BCU 25 Sundry Number: 315-727 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. —7 ,/ Commissoiner DATED this / day of December, 2015 Encl. i69�� 1t015 RBDM Apsi STATE OF ALASKA ��\�`\ DEC U 2 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION• �^►�. APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well p ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Run PLTSurvey 0 2.Operator Name: Hilcorp Alaska, LLC 4.Current Well Class: 5.Permit to Drill Number: ' f/G`t • Exploratory ❑ Development 0- 214-132 - 3.Address. 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20644-00 - 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 237A ❑ Beaver Creek(BCU)25 - Will planned perforations require a spacing exception? Yes ❑ No 9. Property Designation(Lease Number): 10. Field/Pool(s): A028083 Beaver Creek/Sterling Gas Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,208' - 5,264' - 8,105' , 5,264' - 1,517' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 78' 78' Surface 3,488' 9-5/8" 3,488' 3,270' 5,750 psi 3,090 psi Intermediate Production 8,196' 5-1/2" 8,196' 5,264' 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80 6,004 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Swell Pkr; N/A 2,936'MD-2,770'TVD; N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigrapllic ❑ Development r] Service ❑ 14.Estimated Date for 15.Well Status after proposed work: December 16,2015 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS E - WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Joe Kaiser-777-8393 Email jkaiser@hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature L 74/-11‘ Phone 907-777-8405 Date 1Z-it if COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 16 ' 2:7 e Plug Integrity ❑ BOP Test j>1. Mechanical Integrity Test ❑ Location Clearance LI Other: it 41ScD ! s„. gee � 1G O M ��y(�c-r 1 1 LA Post Initial Injection MIT Req'd? Yes ❑ No ❑ D••'S; J My RB Spacing Exception Required? Yes ❑ No [g,' Subsequent Form Required: / 0 — (6)41 �� / APPROVED BY/ Approved by: COMMISSIONER THE COMMISSION Date: )2/7f S �•�'/ J/_y' j �p q Submit Form and Form 10-4 Revised 11/2015 �pvidiCtidnv lid for 12 months from the date of approval. Attachments in Duplicate e 0.0.0./// '' as vvVV 111 ��tltltl !!lrr��►►► /Gf' S; z. p> • • Well Prognosis Well: BCU-25 . Hilcorp Alaska,LL, Date: 12/01/2014 Well Name: BCU-25 API Number: 50-133-20639-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: December 15th, 2015 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-132 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: --2,043 psi @ 5,264' TVD (Based on P/T survey on 11/23/14) Maximum Expected BHP: —2,043 psi @ 5,264' TVD (Based on P/T survey on 11/23/14) Max. Predicted Surface Pressure: — 1,517 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#25 was drilled as a Grass roots horizontal monobore completion in 2014 to target the Sterling B4.The well was perforated via wireline tractor with 20 each 10' intervals, spaced roughly 100' apart. The well loaded up with fluid and has loaded up in the 5-1/2" casing. In late 2014, a 2-7/8"tubing velocity . string without a packer was run to help unload the water while producing gas from the Sterling B4 by producing up the tubing x casing annulus. Gaslift mandrels were installed to allow running reverse gaslift valves that would allow gaslift gas to be injected down the tubing and help lift produced fluids up the annulus.The well is currently producing 1.3-2.7 MMscfd and up to 4,000 bpd water. The purpose of this sundry is to run a PLT survey on the well to determine which perforation(s) are producing water and/or gas. Notes Regarding Wellbore Condition • Max doglegs of 6.9°/100' at 3,965' MD and 7.0°/100' at 5,266' MD. Coiled Tubing Procedure: 1. MIRU Coiled Tubing, PT BOPE to),56t^p si Hi 250 Low. 2. RIH w/2.0" wash nozzle BHA to"'8,090' MD and tag PBTD. 3. PU 10ft and displace well fluids with 8.4ppg produced water. a. Estimated volume of 5-1/2" casing is 188 bbl. 4. POOH w/coil. LD 2" wash nozzle BHA. 5. MU PLT BHA, RIH with well flow up annulus to"'8,060'MD, POOH, LD PLT BHA. 6. RD Coiled Tubing. Attachments: 1. Actual Schematic 2. Rig BOPE and Choke Schematic 3. Coil BOPE Schematic • .. ,, • .11Beaver Creek #25 ACTUAL Pad 3 SCHEMATIC 1246' FNL, 1,656' FWL, Sec. 34, Permit#: 214-132 T7N, R10W, S.M. API#: 50-133-20644-00 (iilc•orp Alaska, LLC - Prop.Des: FED A-028083 KB elevation: 179.2' (18.6'AGL) J . Conductor Lat: N60° 39' 29.694" 1 I ‘--1 16" X-56 109 ppf Lona: W151° 1' 2.615" Top Bottom Spud: 10/19/2014 21:30 hrs MD 0' 78' TD: 11/02/2014 15:30 hrs Tv() 0' 78' Rig Released: 11/07/2014 18:00 hrs Surface Casing Production Casing I 9-5/8" L-80 40 ppf BTC 5-1/2" P-110 17 ppf GeoConn T� Bottom Top Bottom , jj, MD 0' 3,488' MD 0' 8,196' I 4 TVD 0' 3,270' TVD 0' 5,264' 12-1/4"hole Lead Cmt w/570 sks(250 bbls)of12,0 ppg,Class G, Tail Cmt w/221 sks(48 bbls) 8-1/2"hole Cmt w/1,157sks(283 bbls)of 15.3 ppg,of 15.4 ppg,Class G, cement to surface Class G cmt w/EASYBLOK TOC(CBL 11/14/14)-3,472' Tubing • 6 2-7/8" L-80 6.5 ppf EUE Tree =9-1/2"Otis Top Bottom 7 8.0"Seal Diameter MD 0' 6,004' 5-1/8"Modified ID Bore TVD 0' 5,245' l1,4 89 ' Casing Shoe @ 8,196' Il II i r� . l it U UFA II IIP-311 II 11F-11 II II ib. r II U Fill iI II r.1iII 'II. IIF r, 41 i „ ft. III U.l . ; ,. ,. "" -H -11 -'11- - ''il -11 flea.U El- 't li Hel 11 II ' 1I2t lI " .II :.1 . 'txt., , RA#1 RA#2 RA#3 RA#4 RA#5 RA#6 R -#7 RA#8 Casing/Cementing Detail `., r}• ,.,/:__,,„_. _ Tag(unset cement)@ 8,090'CTM - 9.9 ppg Mud w/2.0"Jet Nozzle(11/16/14) - 10.5 ppg Mud Push(45 bbl) PBTD: TD: - 15.3 ppg Cement(283 bbl) 8,105'MD 8,208'MD - 8.5 ppg 3%KCI(190 bbl) 5,264'TVD 5,264'TVD Perforations(Sterling B4): Zone MD TVD Size SPF Date Status Short RA Marker Joints Sterling B4 8,045'-8,055' 5,264'-5,264' 3-1/8" 6 11/19/14 Open Directional Data Sterling B4 7,990'-8,000' 5,264'-5,264' 3-1/8" 6 11/19/14 Open #1 @ 6,183'-6,193'MD KOP:659' Sterling B4 7,890'-7,900' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #2 @ 6,450'-6,460'MD Hole angle at 9-5/8"shoe=25 deg Sterling B4 7,790'-7,800' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #3 @ 6,680'-6,695'MD Sterling B4 7,690'-7,700' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #4 @ 6,914'-6,924'MD Max.Doglegs: Sterling B4 7,590'-7,600' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #5 @ 7,186'-7,201'MD 3,965'- 6.9 deg/100 ft Sterling B4 7,490'-7,500' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #6 @ 7,460'-7,470'MD 5,266'- 7.0 deg/100 ft Sterling B4 7,390'-7,400' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #7 @ 7,686'-7,701'MD 6,999'- 6.5 deg/100 ft Sterling B4 7,290'-7,300' 5,264'-5,264' 3-1/8" 6 11/20/14 Open 1 Sterling B4 7,190'-7,200' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Sterling 84 7,090'-7,100' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Jewelry Depth Sterling 84 6,990'-7,000' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 1.Tubing Hanger 18.6' Sterling B4 6,890'-6,900' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 2.4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 1,650' Sterling B4 6,790'-6,800' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 3.4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 2,570' Sterling B4 6,690'-6,700' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 4.Swell Packer(21'Long) 2,936' Sterling B4 6,590'-6,600' 5,262'-5,262' 3-1/8" 6 11/21/14 Open 5.4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 3,070' Sterling B4 6,490'-6,500' 5,260'-5,260' 3-1/8" 6 11/21/14 Open 6.4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 3,667' 7.4.50"Gaslift Mandrel(w/Reverse Lift Valve,orifice) 4,167' Sterling B4 6,390'-6,400' 5,260'-5,260' 3-1/8" 6 11/22/14 Open 8,4.50"Gaslift Mandrel(w/Dummy Valve) 4,732' Sterling B4 6,290'-6,300' 5,260'-5,260' 3-1/8" 6 11/22/14 Open 9.1/4"Control line w/Flow Control Valve(set @ 1,600 ps4 5,000' Sterling B4 6,190'-6,200' 5,260'-5,260' 3-1/8" 6 11/22/14 Open 10.X-Profile(2.313"ID) 5,583' 11.WLEG 6,004' Well Name&Number: Beaver Creek#25 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth. 0.5°@ 659' Angle/Perfs: 90° Maximum Deviation: 90.6°@ 6,999' Date Completed: 12/12/2014 Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 12/12/2014 Schematic Revision Date: 12/29/2014 • • Di z , g� 41 F E W I t c.,N 9 3 z 3 1 ; 7 C II ' i' aaa ecce Q a! D • 4 a L. •41 ►• 0 u C o • a - r z'ss 3a$ =Y s', 3 aa`ia it;= = 1 $i t I tl , ,1 O i '6 i - in nn:m IF - usu 11011114. - . . N h D.1111 It III _. - w 11 Q'V Hoi" x$71 {Vi 0Z 3 A c 0 r n 0 r I d O 111 II ,_____ \..........._.)• ,. 0 ,,,, ........, , la E 0 § 'o a O Ulo 11 1 0 s 1 • Beaver Creek Unit COIL BOPE BCU-25 12-1-2015 IGh'„rp tl„•ku.1.1(_ BCU#25 16X10% X75/8X4%2 Coil Tubing BOP Lubricator to injection head s 1.75”Tandem Stripper I 1 4._ Ai41/161 _ _ Blind/Shear m Blind/Shear .1.14 is Blind/Shear Blind/5hearI.i.i.I: Slip Slip =E) __- -_moi '/� = PipePipe 11111114 Mud Cross - - in_ �i ``' 4 1/16 10M X 4 1/16 1OM Outlet w/2- 2 1/16 10M full ii,Am opening FMC valves I��I `..) t 1.11 IS )::ID c> ]IFIL. - n. - ,...4 Manual Manual I Manual Manual 2 1/16 10M 2 1/16 10M 1i 2 1/16 10M 2 1/16 10M Crossover spool 4 1/16 10M X 2 9/16 5M Valve,Swab, WKM-M, I u `ul 2 9/16 5M FE, HWO, '"- / Valve, Wing,WKM-M, DD trim L"_ 0_ 2 1/16 5M FE, HWO, Valve,Wing, WKM-M, O ©v DD trim 2 1/16 5M FE, HWO, �■ DD trim E r : 1I a To. ■ Gas Lift J mei ;3 �'1"`. Q Production • �J ■ i L' line tie in C [�> t i * i �aram m_ i -' Valve, Master,WKM-M, y, opp 2 9/16 5M FE, HWO, �OO ` DD trim (III Na 101 IN Valve, Master,WKM-M, 4• 6 , 2 9/16 5M FE, HWO, Ai �%, From Casing DD trim k-- �u�U� Valve mmun 0 STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT la.Test: Q Initial Li Annual ❑Special lb.Type Test: L]Stabilized Li Non Stabilized Multipoint LI Constant Time ❑Isochronal Q Other: Nodal 2.Operator Name: 5.Date Completed: 11.Permit to Drill Number: Hilcorp Alaska,LLC 11/22/2014 214-132 3.Address: 6.Date TD Reached: 12.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 11/3/2014 50-133-20644-00 4a.Location of Well(Governmental Section): 7.KB Elevation above MSL(feet): 13.Well Name and Number: Surface: 1246'FNL,1656'FWL,Sec 34,T7N,R1OW,SM,AK 6/27/1900 Beaver Creek(BCU)25 Top of Productive Horizon: 8.Plug Back Depth(MD+TVD): 14.Field/Pool(s): 874'FNL,1733'FWL,Sec 34,T7N,R10W,SM,AK 8,105'TMD/5,264'ND Total Depth: 9.Total Depth(MD+TVD): Beaver Creek/Sterling Gas 2957'FNL,2371'FWL,Sec 34,T7N,R1OW,SM,AK 8,208'TMD/5,264'TVD 4b.Location of Well(State Base Plane Coordinates NAD 27): 10,Land Use Permit: 15.Property Designation: Surface: x- 317473.83 y-2433936.29 Zone- 4 N/A A028083 TPI: x- 317477.0907 y- 2434707.8496 Zone- 4 16.Type of Completion(Describe): Total Depth: x- 318162.61 y- 2432214.79 Zone- 4 5-1/2"Production String,Perforated 17.Casing Size Weight per fool,lb. I.D.In inches Set at ft. 19.Perforations: From To 5-1/2" 17 4.892 8,197 8,045'-8,055' 7,390'-7,400' 6,690'-6,700' 18.Tubing Size Weight per foot,lb. I.D.in inches Set at ft. 7,990'4,000' 7,290'-7,300' 6,590'-6,600' 7,890'-7,900' 7,190'-7,200' 6,490'-6,500' N/A 7,790'-7,800' 7,090'-7,100' 6,390'-6,400' �� JAN ?�Ih 7,590'-7,600' 6,890'-6,900' 6,290'-6,200' 7,590'-7,600' 6,890'-6,900' 6,190'4,200' 7,490'-7,500' 6,790'-6,800' 6,090'-6,100' 20.Packer set at ft: 21.GOR cf/bbl: 22.API Liquid Hydrocardbons: 23.Specific Gravity Flowing Fluid(G): N/A N/A N/A 0.57 24a.Producing through: 24b.Reservoir Temp: 24c.Reservoir Pressure: 24d.Barometric Pressure(Pa): ❑Tubing Q Casing 110 F° 1882 psia a©Datum 5073 TVDSS psia 25.Length of Flow Channel(L): Vertical Depth(H): Gg: %CO2: %N2: %H2S: Prover: Meter Run: Taps: 0.57 0.1 0.86 0 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice Size(in.) Size(in.) psig 1-1w F° psig F° psig F° Hr. 1. X 2. X 3. ` X 4. X 5. X Basic Coefficient Flow Temp. Super Comp. Pressure Gravity Factor Rate of Flow No. (24-Hour) -I hwPm Factor Factor Q1 MGfd Fb or Fp Pm Ft Fg Fpv 1. 2. 3. 4. 5. Temperature for Separator for Flowing No. PrTr z Gg Fluid T 1. 2. 3. Critical Pressure 4. Critical Temperature 5. Form 10-421 Rev. 7/2009 CONTINUED ON REVERSE SIDE Submit In Duplicate • Pc pct Pf Pf2 No. Pt Pt2 Pc2-P12 Pw Pw2 Pc2-Pw2 Ps Pse Pf2-Ps2 1. 2. 3. 4. 5. 25. AOF (Mcfd) 9,824 n Remarks: I hereby certify that th0, oing is tr - : d correct to the best of my knowledge. Signed Title Reservoir Engineer Date 10/22/2015 DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfd/ ,l hwPm Fp Basic critical flow prover or positive choke factor Mcfd/psia Fg Specific gravity factor,dimensionless Fpv Super compressibility factor= dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid(air=1.000), dimensionless Gg Specific gravity of separator gas(air=1.00), dimensionless GOR Gas-oil ratio, cu. ft. of gas(14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet(TVD) L Length of flow channel, feet(MD) n Exponent(slope)of back-pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia Pf Shut-in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back-Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. 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O� V.G Nl'E C Y ltd• C•rY f MZZ W W W HH�V1lOHCOMCOfO 0iO00C11 4 0U'Ua} . r}WHV H X 1.OYG WHY. � W 6r1 HMOOMriOV00MNNNN00Hmyh.VO pp WW''CC--pp�� V Y•r2 �-N 01 . y L }f n ro NLL fi C1 1 �L C 6 N, Milt',OMtnIeNsnr- IpNMCT OpH1.[S00f t0j 01(.1tts yoOnn I C�O W L Y•r yp0 ZO [ryv : 0: y4� m rtli lOHNNNNMMMMgYV'IOnV M aN ~ {Y LLLL7W yY41 r\I F q1 HppH yNyNMmppt tlppupplCCl.D.�I4O gqhhoapQ x001 p1oQQO�IH ��ppp •ppW H ,ik W W'O .�-1tt10<pN'1..�t 0O NCO Hv�t0�Mm DOU rn L. Z N LL C YY\ OOh V1MNOpIh.DVMHp10rr0II,N�OyryU,1,,4'Nu110 HX L p ION HNMtlV1V1COh00 O10Mrl rl ritl•Iri.W•I-I Lli a 33 V V ✓ m"" /7 pN7uh0N == O T ...— Vp.- NNNNm0 -.1HDNh \ ArHNNMmVamm.N M1hhWW016fU N ' a S O 12/17/2015 • BCU-25AOGCC 10-421 Submitted 10-22-15[P -132] BCU-25 AOGCC 10-421 Submitted 10-22-15 [PTD 214-132] Donna Ambruz [dambruz@hilcorp.com] Sent: Thursday, October 22, 2015 9:37 AM To: AOGCC Reporting (DOA sponsored) Cc: Daniel Taylor [dtaylor@hilcorp.com]; Chad Helgeson [chelgeson@hilcorp.com]; Larry Greenstein [Igreenstein@hi lcorp.com] Attachments:BCU-25 AOGCC 10-421 Submit—l.pdf (423 KB) FYI— Per AOGCC Industry Guidance Bulletin 15-001 dated October 2, 2015: ...Effective immediately all forms listed above [10-421 (Gas Well Open Flow Potential Test Report)] and any correspondence related to these forms should be submitted to the following email: aogcc.reportingPalaska.gov... Please see the attached 10-421 (Gas Well Open Flow Potential Test Report) for BCU-25 [PTD 214-132]. Thank you. Donna Ambruz Operations/Regulatory Tech Kenai Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive,Suite 1400 Anchorage, AK 99503 907.777.8305- Direct 907.777.8310- Fax dambruz@hilcorp.com https://webmai la.alaska.gov/owa/?ae=Item&t=IPM.Note&id=RgAAAABKLne2zgP4SoM kepOhCxbSBwBUvQ964rjQTgYgn3632GdIAAAAhhLyAABU vQ964rjQT... 1/1 Zlt-4-132 Seth Nolan Hilcorp Alaska, LLC CJ?J GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 IId.urp thi&i.I.I.t. Fax: 907 777 8510 E-mail: snolan@hilcorp.com RECEIVED APR 16 2015 AOGCC DATE 04/15/2015 To: Alaska Oil & Gas Conservation Commission Meredith Guhl Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 25 SCAMMED PPR 1 7 20+5 6 boxes: Dry Cuttings Transmitted herewith are cuttings from BCU 25 WELL SAMPLE INTERVAL BCU 25 3520'—4300' BCU 25 4300'—4960' BCU 25 4960'—5720' BCU 25 5720'—6580' BCU 25 6580'—7740' BCU 25 7740'—8208' Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Receive. Date: • 0-6 24-(32. Regg, James B (DOA) From: Joe Grubb - (C) <jgrubb@hilcorp.com> Sent: Tuesday, October 28, 2014 10:28 AM \K4 161 Z6114 To: Regg,James B (DOA) Cc: Brooks, Phoebe L(DOA) Subject: RE: Resend Report Hey Jim, Phoebe, Saxon was having trouble with their test pump. I knew this, but I went and talked to the Toolpusher to verify it was Test #3. And it was Test#3, the pump kept stalling out. They messed with the pump and got it working. Any other issues let me know and sorry for your inconvience Joe From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, October 28, 2014 9:37 AM To: Joe Grubb - (C) Cc: Brooks, Phoebe L (DOA) Subject: RE: Resend Report Explain Test#3; chart shows several attempts at high pressure before get a good test (UPR; CM 2,4,5,6,8; Kill HCR; Lower IBOP; Dart) Jim Regg Supervisor, Inspections �SGWED MA 0 5 2015 AOGCC %W ED W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Joe Grubb - (C) [mailto:jgrubb©hilcorp.com] Sent: Tuesday, October 28, 2014 8:51 AM To: Regg, James B (DOA); Brooks, Phoebe L(DOA); DOA AOGCC Prudhoe Bay Subject: Resend Report Sorry Guys, Change a few things Joe 1 Regg, James B (DOA) From: Joe Grubb - (C) <jgrubb@hilcorp.com> Sent: Monday, October 27, 2014 7:34 PM To: Regg,James B (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: BOP Test Attachments: Inital BOP Test Chart.pdf; BCU-25 BOP Test Report.xlsx Any issues please let me know Joe • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.reqqalaska.qov AOGCC.Inspectors@alaska.gov phoebe.brooks aC�alaska.bov Contractor: Saxon Rig No.: 169 DATE: 10/25/14 Rig Rep.: Jay Compton Rig Phone: 907-776-6728 Operator: Hilcorp Alaska, LLC Op. Phone: 907-776-6776 Rep: Joe Grubb E-Mail jgrubb@hilcorp.com Well Name: BCU-25 • PTD# 2141320 Sundry# Operation. Drilling: X Workover: Explor.: Test: Initial: Weekly: Bi-Weekly: X Test Pressure(psi): Rams: 250/3500 Annular. 250/2500 ' Valves: 250/3500 "MASP: 1771 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen P - Well Sign P Upper Kelly 1 P - Housekeeping P • Rig P - Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P - Standing Order Posted P Misc. NA Inside BOP 1 P • FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 11" P Pit Level Indicators P . P #1 Rams 1 2 7/8"x 5" P • Flow Indicator P P #2 Rams 1 Blind P Meth Gas Detector P P #3 Rams 1 2 7/8"x 5" P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln.Valves 1 3 1/8" P Inside Reel valves 0 NA HCR Valves 2 3 1/8" P Kill Line Valves 2 2 1/16" P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) 3100 P CHOKE MANIFOLD: Pressure After Closure(psi) 1400 P Quantity Test Result 200 psi Attained(sec) 9 . P No.Valves 13 FP / Full Pressure Attained(sec) 89 P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P . Nitgn. Bottles Avg (#and psi): 4 @ 2650 P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 1 Test Time: 9.5 Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: Tested annular at 250/2500 psi, tested all other componants at 250/3500 psi for 10 min on each test. During this test we had one failure Choke valve#9 failed The Choke valve was flushed and worked and retested. Choke Valve#9 was retested and passed. Test pump issues during test. — z C,4-¢ 'ive( c t– AOGCC Inspection 24 hr Notice Yes Date/Time 9/25/14 6:29 PM "S-9c(� Idl1 t4 Waived By Jim Regg Test Start Date/Time: 10/25/2014 16.00 (date) (time) Witness Test Finish Date/Time: 10/25/2014 23:30 Form 10-424(Revised 06/2014) 2014-1025_BOP_Saxon169_BCU-25.xlsx as 4 15 30 - avrir t /�ir/ ,,• vA 5050 �I r `�. Wil �a� • tj S 5 ...iv 30 _.-- 30 .. 4500N �� 0p �=i4o `��4t$iq0t;rLATE _ 0� , _ 400 ...,"000 63,10 "0101 4.01100 1- $ °II mot -- • / A.,,,c4, -A4- 4. , Ict °A. A0.1.4:440,- 4N, I Mr!X%Wo. 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Well History File Identifier Organizing (done) Two-sided ❑ Rescan Needed RESC OVERSIZED: NOTES: olor Items: ❑ Maps: ayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Maria Date: / (3//S" /s/ l'Y P Project Proofing BY: Maria Date: (:)11 3 /s/ IT P Scanning Preparation 5 x 30 = ✓ + I I =TOTAL PAGES I `P _� (Count does not include cover sheet) BY: Maria Date: MAW /s/ I �' Production Scanning ��jj�� Stage 1 Page Count from Scanned File: 1 "'a, (Count does include cover heet) Page Count Matches Number in Scanning Pre aration: • YES NO BY: 411:0 Date: )3 `5j /s/ni to Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: IP 7,_ NO TOTAL PAGES: RD ________iit Digital version appended by: Meredith Michal I/17( Date: 2 17/1,— / i /s/ 1 Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: 1 9°D- Scanning is complete at this point unless rescanning is required. 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II Seth Nolan Hilcorp Alaska, LLC ��32 , GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 DATA LOGGED Hak,irp tia.k.I.1.11 Fax: 907 777-8510 / /201 E-mail: snolan@hilcorp.com K.BENDER DATE 01/23/14 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 25 Digital Survey Data CD: in BCU-25 Definitive Survey 1214/2014 10:05 AM PDF Document 1,281 KB BCU-25 Definitive Survey 1214/2014 934 AM Text Document 10 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of thl tra Grp' al or FAX to 907 777.8337 Received7,) Date: c./7) � 6 JAN 2 6 ZOi AOGCC RECEIVED STATE OF ALASKA ALA. .OIL AND GAS CONSERVATION COMMIS__ oN JAN 0 9 2015 L REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Repair Well U Plug Perforations U Perforate U Other J � Velocity String Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 214-132 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20644-00 7.Property Designation(Lease Number): 8.Well Name and Number: A028083 Beaver Creek(BCU)25 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): '10.Field/Pool(s): N/A Beaver Creek/Sterling Gas Pool 11.Present Well Condition Summary: Total Depth measured 8,208 feet Plugs measured N/A feet true vertical 5,264 feet Junk measured N/A feet Effective Depth measured 8,105 feet Packer measured N/A feet true vertical 5,264 feet true vertical N/A feet Casing Length Size MD ND Burst Collapse Structural Conductor 78' 16" 78' 78' Surface 3,488' 9-5/8" 3,488' 3,270' 5,750 psi 3,090 psi Intermediate Production 8,196' 5-1/2" 8,196' 5,264' 10,640 psi 7,460 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 6,004'MD 5,245'ND Packers and SSSV(type,measured and true vertical depth) Swell Pkr;N/A 2,936'MD 2,770'ND N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 11 0 0 159 Subsequent to operation: 0 2560 2310 390 577 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development E Service ❑ Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas 2 WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-651 Contact Stan Porhola Email sporhola(&..hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature fd""A A/6,- /Phone 907-777-8412 Date ( oq /I S RBDMS JAN 1 1 2015 Form 10-404 Revised 10/2012 -d - 0•05--- Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU-25 50-133-20644-00 214-132 12/9/14 12/14/14 Daily Operations: 12/09/2014-Tuesday Held JSA. Continue Spotting and RU equipment, RU flowline off Production Tree. RU Kelly Hose to Production tree and pumped 120 bbls down the csg. With well stactic we set a 5" BPV in csg hanger. ND the PT and NU the 7-1/16" Tbg head with hanger and TWC installed. NU the 7" BOP Stack and connected hydraulic lines Kommey to Stack. Secured well and SDFN. 12/10/2014-Wednesday Held JSA. Prep Rig for BOPE Test. Performed Shell test. Tested BOPE. Valves 250-3,000psi,Annular 250-3,000psi, Rams 250- ... _, 3,000psi. Witnessed by Lou Grimaldi, 12/10/14. Performed gas detection and Koomey drawdown test. 1 fail/pass record on Koomey unit. Pulled Tbg hanger and pumped 40 bbls thru the 5" BPV in the csg. With well on vacuum we pulled the BPV and secured well for night. 12/11/2014-Thursday Held JSA and Discussed work to be performed. SICP Opsi. Prepped rig to run Bit and Scraper. Racked and Tallied 190 jts of 2- 7/8" EUE 8rd. MU 4.75" Bit and 5-1/2" csg scraper,Tallied BHA. TIH w/ BHA and 186 jts to 6,018'. Did not see anything with scraper while TIH. SOOH w/91 stands and L/D 4 jts and the BHA. Secured well and SDFN. 12/12/2014- Friday Held JSA and discussed work to be performed. RU equipment to run 1/4" control line. MU 3/4" BHA onto the control line and tested-ok. Prep to RIH w/completion string. TIH w/Gas Lift Completion: 182 jts of 6.5#8rd EUE L-80, WLEG @ 6,004', X- nipple @ 5,584' (Loaded w/RHCP) Gas lift mandrels#6 @ 4,732', Gas lift mandrels#5 @ 4,167', Gas lift mandrels#4@ 3,667', Gas lift mandrels#3 @ 3,070', Gas lift mandrels#2 @ 2,570', Gas lift mandrels#1 @ 1,650'. Total of 112 3/4" Stainless Steel Bands to secure control line to tbg. Landed tbg hanger and dropped ball. Pressured up on tbg to 3,000psi and would not test. Bleed off was at 100psi per/min. Pulled landing jt. Set a BPV and ND BOPs, NU 2-9/16" 5m PT. Tested to 5k-test ok. Pulled BPV. Secured well and SDFN. 12/13/2014-Saturday No activity to report. 12/14/2014-Sunday RU Slickline Unit. NU lubricator and test to 3,500 psi -test OK. RIH w/2"JDC to 5,579' SLM and pull prong. RIH w/2-7/8" Daniels KOT and pull dummy valves from top 5 mandrels. RIH w/ KOT and set live valves in top 4 mandrels and orifice valve in the 5th mandrel. RIH w/2-7/8" GS and pull plug body at 5,571' SLM. RD Slickline Unit.Turn well over to production. I _ llBeaver Creek #25 ACTUAL Pad 3 SCHEMATIC 1246' FNL, 1,656' FWL, Sec. 34, Permit#: 214-132 T7N, R10W, S.M. .API#: 50-133-20644-00 Hilcorp Alaska. LLC Prop.Des: FED A-028083 KB elevation: 179.2' (18.6'AGL) J i„I I-,mul_ 1 Conductor Lat: N60° 39' 29.694" 16" X-56 109 ppf Lona: W151° 1' 2.615" Top Bottom Spud: 10/19/2014 21:30 hrs 1 MD 0' 78' TD: 11/02/2014 15:30 hrs I ND 0' 78' Rig Released: 11/07/2014 18:00 hrs Surface Casing Production Casing I 9-5/8" L-80 40 ppf BTC 5-1/2" P-110 17 ppf GeoConn Top Bottom Top Bottom MD 0' 3,488' MD 0' 8,196' I 11 . 4 ND 0' 3,270' ND 0' 5,264' 12-1/4"hole Lead Cmt w/570 sks(250 bbls)of 12.0 ppg,Class G, Tail Cmt wl 221 sks(48 bbls) 8-1/2"hole Cmt w/1,157sks(283 bbls)of 15.3 ppg, ,* of 15.4 ppg,Class G, cement to surface Class G cmt w/EASYBLOK +�+ 5 TOC(CBL 11/14/14)-3,472' Casing/Cementing Detail Tubing * - 9.9 ppg Mud 2-7/8" L-80 6.5 ppf EUE m' `,:l. 6 Tree cxn=9-1/2"Otis - 10.5 ppg Mud Push(45 bbl) Top Bottom ' 7 8 0'Seal Diameter - 15.3 ppg Cement(283 bbl) MD 0' 6,004' ., 8.5 ppg 3%KCI(190 bbl) ND 0' 5,245' l 1!8 Modified ID Bore • T1, 8• 9 +,:. It I I 1 1 Casing Shoe @ 8,196' IS 111Liami I- i ,,4',10.-*Il II 11 II Il lI II 11E1.11 II L • II Hui II II II II -.I :• ill ti4 u , N .. . . IIWII Ii IIS II .11.111 HII'''II II !' 11 II'' II II I " H 1 RA#1 RA#2 RA#3 RA#4 RA#5 RA#6 // RA#8 Perforations(SterlingB4►: Tag(unset cement)@ 8,090'CTM PBTD. TD: w/2.0"Jet Nozzle(11/16/14) 8,105'MD 8,208'MD Zone MD ND Size SPF Date Status 5,264'ND 5,264'ND Sterling B4 8,045'-8,055' 5,264'-5,264' 3-1/8" 6 11/19/14 Open Short RA Marker Joints Sterling B4 7,990'-8,000' 5,264'-5,264' 3-1/8" 6 11/19/14 Open Directional Data Sterling B4 7,890'-7,900' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #1 @ 6,183'-6,193'MD KOP:659' Sterling B4 7,790'-7,800' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #2 @ 6,450'-6,460'MD Hole angle at 9-5/8"shoe=25 deg Sterling B4 7,690'-7,700' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #3 @ 6,680'-6,695'MD Sterling B4 7,590'-7,600' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #4 @ 6,914'-6,924'MD Max.Doglegs: Sterling B4 7,490'-7,500' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #5 @ 7,186'-7,201'MD 3,965'- 6.9 deg/100 ft Sterling B4 7,390'-7,400' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #6 @ 7,460'-7,470'MD 5,266'- 7.0 deg/100 ft Sterling B4 7,290'-7,300' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #7® 7,686'-7,701'MD 6,999'- 6.5 deg/100 ft Sterling B4 7,190'-7,200' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Sterling B4 7,090'-7,100' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Jewelry Depth Sterling B4 6,990'-7,000' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 1.Tubing Hanger 18.6' Sterling B4 6,890'-6,900' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 2.4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 1,650' Sterling B4 6,790'-6,800' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 3.4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 2,570' Sterling B4 6,690'-6,700' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 4.Swell Packer(21'Long) 2,936' Sterling B4 6,590'-6,600' 5,262'-5,262' 3-1/8" 6 11/21/14 Open 5.4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 3,070' 6.4.50"Gaslift Mandrel(w/Reverse Lift Valve,3/16") 3,667' Sterling B4 6,490'-6,500' 5,260'-5,260' 3-1/8" 6 11/21/14 Open 7.4.50"Gaslift Mandrel(w/Reverse Lift Valve,orifice) 4,167' Sterling B4 6,390'-6,400' 5,260'-5,260' 3-1/8" 6 11/22/14 Open 8.4.50"Gaslift Mandrel(w/Dummy Valve) 4,732' 9.1/4"Control line w/Flow Control Valve 5,000' 10.X-Profile(2.313"ID) 5,583' 11.WLEG _ 6,004' Well Name&Number: Beaver Creek#25 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle©KOP and Depth: 0.5°@ 659' Angle/Perfs: 90° Maximum Deviation: 90.6°@ 6,999' Date Completed: 12/12/2014 Ground Level(above MSL): 160.6' RKB(above GL):_ 18.6' •Revised By: Stan Porhola Downhole Revision Date: 12/12/2014 Schematic Revision Date: 12/17/2014 RECEIVED STATE OF ALASKA flFC 1 " 9014 ALAS'.,OIL AND GAS CONSERVATION COMML ION 1a.Well StaWEoLL❑COMGas ❑PLETGO❑N OReRr ❑ECOMPLEAbandoned ❑TION nREded❑PORTlb.Well CAND4.( lass: 20AAC 25.105 20AAC 25.110 Development 2 • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: _ Service ElStratigraphic Test El 2.Operator Name: 5. Date Comp.,Susp.,or St 12. Permit to Drill Number: Hilcorp Alaska,LLC Aband.: ' 11/23/2014 :.Y./, 214-132/314-599 3.Address: 6. Date Spudded: 13.API Number: 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 10/19/2014 50-133-20644-00 • 4a. Location of Well(Governmental Section): 7. Date TD Reached: 14.Well Name and Number: Surface: 1246 FNL, 1656'FWL,Sec 34,T7N, R1OW.SM,AK 11/3/2014 Beaver Creek(BCU)25 • Top of Productive Horizon: 8. KB(ft above MSL): 179.2 15.Field/Pool(s): 874'FNL, 1733'FWL,Sec 34,T7N, R1OW,SM,AK GL(ft above MSL): 160.6. Total Depth: 9. Plug Back Depth(MD+TVD): Beaver Creek/Sterling Gas Pool . 2957'FNL,2371'FWL,Sec 34,T7N, R1OW,SM.AK , 8105'TMD/5264'TVD 4b. Location of Well(State Base Plane Coordinates, NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 317473.83 • y- 2433936.29 • Zone- 4 . 8208'TMD/5264'TVD • A028083 TPI: x- 317477.0907 y- 2434707.85 Zone- 4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth: x- 318162.61 y- 2432214.79 Zone- 4 N/A N/A 18. Directional Survey: Yes R] No ❑ 19.Water Depth, if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MC/TVD: ROP-DGR-ADR-EWR 2"/5"MD,DGR-ADR-EWR 2"/5"TVD, FEL 2"/5"MD, GRL 2"MD,DEL 2"MD N/A 23. CASING,LINER AND CEMENTING RECORD Wr. PER SETTING DEPTH MD SE!t ING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM ' HOLE SIZE CEMENTING RECORD PULLED 16" 109# X-59 18' 98' 18 98' Driven N/A 9-5/8" 40# L-80 18' 3,488' 18' 3.088' 12-1/4" 250bbl 12#L&48bb1 15.4 T 5-1/2" 17# P-110 18' 8,197' 18' 5,264' 8-1/2" 283bbIs 15.3#Class G 24.Open to production or injection? Yes 0 No ❑ 25. TUBING RECORD If Yes, list each interval open(MD+TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): Sterling B-4 Sand (see attached) N/A N/A N/A MD TVD Size SPF Date Status 8,045'-8,055' 5,264'-5,264' 3-1/8" 6 11/19/14 Open26: ACID, FRACTURE,CEMENT SQUEEZE, ETC. 7,990'-8,000' 5,264'-5,264' 3-1/8" 6 11/19/14 Open , I ,�' Was hydraulic fracturing used during completion? Yes❑ No 27,890' 7,900' 5,264'-5,264' 3-1/8" 6 11/20/14 Open `?,IL�DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 7,790'-7,800' 5,264'-5,264' 3-1/8" 6 11/20/14 Open 7,690'-7,700' 5,264'-5,264' 3-1/8" 6 11/20/14 Open 7,590'-7,600' 5,264'-5,264' 3-1/8" 6 11/20/14 Open >,\ 7,490'-7,500' 5,264'-5,264' 3-1/8" 6 11/20/14 Open 7,390'-7,400' 5,264'-5,264' 3-1/8" 6 11/20/14 Open 7 9Qn'_7 Inn' c 9Ad'_A 2Ad' I-1/A" A 11/9r1/1d Chan 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing,gas lift,etc.): N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A Test Period -* Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. N/A 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No❑✓ Sidewall Cores Acquired? Yes ❑ No❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. row'1u-40( Revlsea 10207.412 CONTINuED ON REVEa<St nail uiiyinal only �� 5 z -3./3--- RBE MS JAN - 9 20 b -�r .�"( I. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 11 No . If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base STERLING_B 5203 4858 BC_B1ST 5257 4898 BC_B1SB 5307 4934 BC_B1-L_ST 5346 4961 BC_B2ST 5388 4989 BC_B3ST 5575 5098 BC_B3-L_ST 5711 5160 BC B3-L SB 5818 5198 Formation at total depth: 31. List of Attachments: Well Schematic,MW vs Depth,Days vs Depth, Definitive Directional Survey,Drilling Composite Report,Casing and Cmt reports&MIT Report 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Stan Porhola Email: sporhola(C�hiIcorp.com Printed Name: Stan Porhola Title: Operations Engineer Signature:Werv6,......._ Phone: 907-777-8412 Date: /1 ��- 1 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and 1 analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 { Zone MD TVD 1Size SPF Date Status Sterling B4 8,045-8,055' 5,264'-5,264' 3-1/8" 6 11/19/2014 Open Sterling B4 7,990'-8,000' 5,264'-5,264' 3-1/8" 6 11/19/2014 Open Sterling B4 7,890'-7,900' 5,264'-5,264' 3-1/8" 6 11/20/2014 Open Sterling B4 7,790'-7,800' 5,264'-5,264' 3-1/8" 6 11/20/2014 Open Sterling B4 7,690'-7,700' 5,264'-5,264' 3-1/8" 6 11/20/2014 Open Sterling B4 7,590'-7,600' 5,264'-5,264' 3-1/8" 6 11/20/2014 Open Sterling B4 7,490'-7,500' 5,264'-5,264' 3-1/8" 6 11/20/2014 Open Sterling B4 7,390'-7,400' 5,264'-5,264' 3-1/8" 6 11/20/2014 Open Sterling B4 7,290'-7,300' 5,264'-5,264' 3-1/8" 6 11/20/2014 Open Sterling B4 7,190'-7,200' 5,264'-5,264' 3-1/8" 6 11/21/2014 Open Sterling B4 7,090'-7,100' 5,264'-5,264' 3-1/8" 6 11/21/2014 Open Sterling B4 6,990'-7,000' 5,265'-5,265' 3-1/8" 6 11/21/2014 Open Sterling B4 6,890'-6,900' 5,265'-5,265' 3-1/8" 6 11/21/2014 Open Sterling B4 6,790'-6,800' 5,265-5,265' 3-1/8" 6 11/21/2014 Open Sterling 84 6,690'-6,700' 5,265-5,265' 3-1/8" 6 11/21/2014 Open Sterling B4 6,590'-6,600' 5,262'-5,262' 3-1/8" 6 11/21/2014 Open Sterling B4 6,490'-6,500' 5,260'-5,260' 3-1/8" 6 11/21/2014 Open Sterling B4 6,390'-6,400' 5,260'-5,260' 3-1/8" 6 11/22/2014 Open Sterling B4 6,290'-6,300' 5,260'-5,260' 3-1/8" 6 11/22/2014 Open Sterling B4 6,190'-6,200' 5,260'-5,260' 3-1/8" 6 11/22/2014 Open Sterling B4 6,090'-6,100' 5,256'-5,256' 3-1/8" 6 11/22/2014 Open Alo Beaver Creek #25 ACTUAL Pad 3 SCHEMATIC 1246' FNL, 1,656' FWL, Sec. 34, T7N, R10W, S.M. Permit#: 214-132 Hilcorp Alaska,LLC API#: 50-133-20644-00 Prop.Des: FED A-028083 J 1 KB elevation: 179.2' (18.6'AGL) Ari . l Conductor Lat: N60° 39' 29.694" 16" X-56 109 ppf Long: W151° 1' 2.615" Top Bottom TVD 0' Spud: 10/19/2014 21:30 his MD 0' 78' TD: 11/02/2014 15:30 his 78' Rig Released: 11/07/2014 18:00 his Surface Casing Production Casing 9-5/8" L-80 40 ppf BTC 5-1/2" P-110 17 ppf GeoConn Tom Bottom Top Bottom 1 MD 0' 3,488' MD 0' 8,196' 5,264' TVD 0' 3,270' TVD 0' 12-114"hole Lead Cmt w/570 sks(250 bbls)of 12.0 ppg,Class G, Tail Cmt w/221 sks(48 bbls) 8-1/2"hole Cmt w/1,157sks(283 bbls)of 15.3 ppg, ;,' of 15.4 ppg,Class G, cement to surface Class G cmt w/EASYBLOK 1•, r "At TOC(CBL 11/14/14)-3,472' Tree cxn=9-1/2"Otis Casing/Cementing Detail ;'� 8.0"Seal Diameter - 9.9 ppg Mud 5-1/8"Modified ID Bore - 10.5 ppg Mud Push(45 bbl) - 15.3 ppg Cement(283 bbl) P ` - 8.5 ppg 3%KCI(190 bbl) 1 Tag(unset cement)@ 8,090'CTM IN/2.0"Jet Nozzle(11/16/14)401 Casing Shoe @ 8,196' " !' ' 11 :111 .II .I1 II II ! II uII ,II II CI .111 :• II II .11 l RA rik # El 1 i' 11 II RA II 111!. .11 RA#4II as#s 11 II RA 6 If II tall 11 11161"11 I PBTD: TD: Perforations(Sterling B4): Short RA Marker Joints 8,105'MD 8,208'MD Zone MD TVD Size SPF Date Status 5,264'TVD 5,264'ND Sterling 64 8,045'-8,055' 5,264'-5,264' 3-1/8" 6 11/19/14 Open #1 @ 6,183'-6,193'MD Sterling B4 7,990'-8,000' 5,264'-5,264' 3-1/8" 6 11/19/14 Open #2 @ 6,450'-6,460'MD Directional Data Sterling B4 7,890'-7,900' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #3 @ 6,680'-6,695'MD KOP:659' Sterling B4 7,790'-7,800' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #4 @ 6,914'-6,924'MD Hole angle at 9-5/8"shoe=25 deg Sterling B4 7,690'-7,700' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #5 @ 7,186'-7,201'MD Sterling B4 7,590'-7,600' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #6 @ 7,460'-7,470'MD Max.Doglegs: Sterling 64 7,490'-7,500' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #7 @ 7,686'-7,701'MD 3,965'- 6.9 deg/100 ft Sterling B4 7,390'-7,400' 5,264'-5,264' 3-1/8" 6 11/20/14 Open 5,266'- 7.0 deg/100 ft Sterling B4 7,290'-7,300' 5,264'-5,264' 3-1/8" 6 11/20/14 Open 6,999'- 6.5 deg/100 ft Sterling B4 7,190'-7,200' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Sterling B4 7,090'-7,100' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Sterling B4 6,990'-7,000' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Jewelry Depth Sterling 134 6,890'-6,900' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 1.Swell Packer(21'Long) 2,936' Sterling B4 6,790'-6,800' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,690'-6,700' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,590'-6,600' 5,262'-5,262' 3-1/8" 6 11/21/14 Open Sterling 64 6,490'-6,500' 5,260'-5,260' 3-1/8" 6 11/21/14 Open Sterling B4 6,390'-6,400' 5,260'-5,260' 3-1/8" 6 11/22/14 Open Sterling 84 6,290'-6,300' 5,260'-5,260' 3-1/8" 6 11/22/14 Open Sterling B4 6,190'-6,200' 5,260'-5,260' 3-1/8" 6 11/22/14 Open Sterling B4 6,090'-6,100' 5,256-5,256' 3-1/8" 6 11/22/14 Open Well Name&Number: Beaver Creek#25 _ Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle©KOP and Depth: 0.5°@ 659' Angle/Perfs: 90° - Maximum Deviation: 90.6°@ 6,999' • • Date Completed: 11/22/2014 Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 11/22/2014 Schematic Revision Date: 12/1/2014 • O) Y O O Q Y = o O a) O o = 0 09 = 0 > C as 3 'D O 0_Q N a (6 03 0 C U O U - -O N t o) N O .TD -0 N -O 0-. 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UU) U � U J U a)( Ia) O o I O U O X U 0 c X O J C J C a) 0 O C O O O O CO O C o C u) O OU o C '( a) N C C O (0 a.•C Q C a-U N a- •+- o- - U N ' L 0 N- -0 o U RS 0 O N y O I (0 10 NO W (1 ,- r X O Cr O X N O U (6 U (o U (b a. U -a U U - O_ -a „ 3 w 3 (h O 3 (0 0. as (O O o a n3 03 0 (o o- O 0) 0_ co H e H C 17 3 g 17 N 0 H M N • 3 o o -0 N p N (0 p N — c O N r O (O O (O '' CO O 0) 4_- (0 CC (0 U_ O O O O O O c 0 o C c U O Q O o_ Q 0 op O C co 0 X c o) Un a) Un a) I -o UT O ai rn O -o c 'O O O N- O (U r- a) ('7 D U U O C (0 U co U cfl *k (D x ((6i (o* u: o E E E ui E : a) E U oI oIN oc0, o .= cc 0 o) O N x c - (6 4- 2 a 4- c c0 4- c c N Q C C N C C O C (0 c a) C (0 X o C C U C C O 0 0 0) C U U C 7 U a) C 0) 0 C 0) 0 C 0) 0-— a) 92 0 U 0) a) Co 0 (t _o N U _ @ CO 3 O U O O U - 0 0 in O 0) O U CO S? (?- O. U 0. X 0. >- U) U u) _o a- (n Q U 13 X U X U -0 (0 C 0 U - U C • C C C C — C CO CO/)) C (6 I f0 @ 00 (2 C6 Q = N • 0 (0 6 Ch N 0) o C a. Q Q (n 0 L (0 (Z U CL C C (`) 0 7 co o c Q 7 . 2i U c Q -E-' -o n (� = (� aa90 = E - a 3 o a) o- 3 (o o- 3 co o- — co o- E Cr (o Cl_ E (O n (n C � E = -o EI o E O ,- Eo E o Eor O C� ' (co C� - m O > O ani O0) O ani (13 c N c C c c co �' coO) 4) co r- O C C a C a) CL 0 (V (0 0- *k 0) *k O *k U CD * H it *k iIi * 3 i- v 0 0 N N N N N fE I'P il Hilcorp Energy Company Beaver Creek Unit Beaver Creek Unit BCU-25 I If 501332064400 501332064400 1;I 1 Sperry Drilling Y Definitive Survey Report 11 November, 2014 • E HAL.LIBURTON Sperry Drilling Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 25 Project: Beaver Creek Unit TVD Reference: BCU-25 @ 178.50usft(Saxon169(160.5+18)) Site: Beaver Creek Unit MD Reference: BCU-25 @ 178.50usft(Saxon169(160.5+18)) Well: Beaver CK Unit 25 North Reference: True Wellbore: BCU-25 Survey Calculation Method: Minimum Curvature Design: BCU-25 Database: Sperry EDM-NORTH US+CANADA Project Beaver Creek Unit Map System: US State Plane 1927(Exact solution) ' System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Well Beaver CK Unit 25 Well Position +N/-S 0.00 usft Northing: 2,433,936.29 usft Latitude: 60°39'29.694 N +E/-W 0.00 usft Easting: 317,473.83 usft Longitude: 151°1'2.615 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: . 160.50 usft Wellbore BCU-25 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 1°l (0) (nT) BGGM2014 10/5/2014 16.91 73.63 55,440 Design BCU-25 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 18.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 18.00 0.00 0.00 157.98 Survey Program Date 11/11/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 97.28 843.63 MWD+SC+Sag(BCU-25) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 10/21/2014 905.61 1,091.55 MWD+Iterp Az+Sag(BCU-25) MWD_Interp Azi+sag Fixed:v2:std dec with interpolated azimuth+sag 10/21/2014 1,153.47 1,526.91 MWD+SC+Sag(2)(BCU-25) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 10/21/2014 1,590.19 1,590.19 MWD+lnterp Azi+Sag(2)(BCU-25) MWD_Interp Azi+sag Fixed:v2:std dec with interpolated azimuth+sag 10/21/2014 1,653.71 8,208.00 MWD+SC+Sag(3)(BCU-25) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 10/22/2014 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 18.00 0.00 0.00 18.00 -160.50 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 UNDEFINED 97.28 0.06 4.52 97.28 -81.22 0.04 0.00 2,433,936.33 317,473.83 0.08 -0.04 MWD+SC+sag(1) 162.13 0.25 4.52 162.13 -16.37 0.22 0.02 2,433,936.51 317,473.85 0.29 -0.19 MWD+SC+sag(1) 222.90 0.80 24.69 222.90 44.40 0.73 0.20 2,433,937.02 317,474.05 0.94 -0.60 MWD+SC+sag(1) 284.95 0.68 25.49 284.94 106.44 1.46 0.54 2,433,937.74 317,474.40 0.19 -1.15 MWD+SC+sag(1) 354.71 0.71 22.60 354.70 176.20 2.23 0.89 2,433,938.51 317,474.75 0.07 -1.74 MWD+SC+sag(1) 412.49 0.35 3.99 412.47 233.97 2.74 1.04 2,433,939.01 317,474.91 0.68 -2.15 MWD+SC+sag(1) 474.79 0.17 353.75 474.77 296.27 3.02 1.04 2,433,939.29 317,474.92 0.30 -2.41 MWD+SC+sag(1) 534.70 0.23 355.11 534.68 356.18 3.23 1.02 2,433,939.50 317,474.90 0.10 -2.61 MWD+SC+sag(1) 596.03 0.07 325.78 596.01 417.51 3.38 0.99 2,433,939.66 317,474.87 0.28 -2.76 MWD+SC+sag(1) 11/11/2014 8:15:11PM Page 2 COMPASS 5000.1 Build 70 • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 25 Project: Beaver Creek Unit TVD Reference: BCU-25 @ 178.50usft(Saxon169(160.5+18)) Site: Beaver Creek Unit MD Reference: BCU-25 @ 178.50usft(Saxon169(160.5+18)) Well: Beaver CK Unit 25 North Reference: True Wellbore: BCU-25 Survey Calculation Method: Minimum Curvature Design: BCU-25 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Fasting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 659.11 0.51 341.38 659.09 480.59 3.68 0.88 2,433,939.96 317,474.77 0.70 -3.08 MWD+SC+sag(1) 720.90 1.22 348.24 720.87 542.37 4.59 0.66 2,433,940.86 317,474.56 1.16 -4.00 MWD+SC+sag(1) 781.70 2.85 344.16 781.63 603.13 6.67 0.11 2,433,942.96 317,474.05 2.69 -6.14 MWD+SC+sag(1) 843.63 5.45 341.66 843.40 664.90 10.95 -1.23 2,433,947.25 317,472.77 4.21 -10.61 MWD+SC+sag(1) 905.61 6.59 347.52 905.03 726.53 17.21 -2.93 2,433,953.55 317,471.17 2.09 -17.06 MWD_InterpAzi+sag(2) 967.55 9.32 351.09 966.37 787.87 25.64 -4.47 2,433,962.00 317,469.75 4.48 -25.45 MWD_InterpAzi+sag(2) 1,029.63 11.62 353.13 1,027.42 848.92 36.81 -6.00 2,433,973.19 317,468.40 3.75 -36.38 MWD_InterpAzi+sag(2) 1,091.55 13.23 354.50 1,087.88 909.38 50.06 -7.43 2,433,986.46 317,467.18 2.64 -49.19 MWD_InterpAzi+sag(2) 1,153.47 16.16 355.50 1,147.77 969.27 65.71 -8.78 2,434,002.12 317,466.07 4.75 -64.21 MWD+SC+sag(3) 1,215.78 17.41 353.98 1,207.43 1,028.93 83.62 -10.44 2,434,020.06 317,464.69 2.13 -81.44 MWD+SC+sag(3) 1,277.34 19.60 351.99 1,265.80 1,087.30 103.01 -12.84 2,434,039.48 317,462.58 3.70 -100.31 MWD+SC+sag(3) 1,339.49 21.93 351.91 1,323.91 1,145.41 124.82 -15.93 2,434,061.35 317,459.83 3.75 -121.69 MWD+SC+sag(3) 1,402.41 22.87 351.41 1,382.08 1,203.58 148.55 -19.41 2,434,085.12 317,456.72 1.52 -144.99 MWD+SC+sag(3) 1,463.60 23.79 352.47 1,438.27 1,259.77 172.54 -22.80 2,434,109.16 317,453.70 1.65 -168.50 MWD+SC+sag(3) 1,526.91 24.31 354.15 1,496.08 1,317.58 198.16 -25.80 2,434,134.83 317,451.10 1.36 -193.38 MWD+SC+sag(3) 1,590.19 24.22 354.61 1,553.77 1,375.27 224.04 -28.35 2,434,160.74 317,448.95 0.33 -218.33 MWD_Interp Azi+sag(4) 1,653.71 24.61 355.06 1,611.61 1,433.11 250.19 -30.71 2,434,186.93 317,446.99 0.68 -243.46 MWD+SC+sag(5) 1,715.83 26.08 355.22 1,667.75 1,489.25 276.69 -32.97 2,434,213.45 317,445.15 2.37 -268.86 MWD+SC+sag(5) 1,777.78 25.69 356.60 1,723.49 1,544.99 303.66 -34.90 2,434,240.45 317,443.64 1.16 -294.59 MWD+SC+sag(5) 1,838.47 25.97 355.60 1,778.11 1,599.61 330.04 -36.70 2,434,266.86 317,442.25 0.85 -319.72 MWD+SC+sag(5) 1,901.37 25.88 354.10 1,834.68 1,656.18 357.43 -39.16 2,434,294.28 317,440.20 1.05 -346.04 MWD+SC+sag(5) 1,964.20 25.84 353.86 1,891.22 1,712.72 384.68 -42.04 2,434,321.58 317,437.75 0.18 -372.38 MWD+SC+sag(5) 2,026.44 25.99 354.18 1,947.20 1,768.70 411.73 -44.87 2,434,348.67 317,435.34 0.33 -398.52 MWD+SC+sag(5) 2,088.56 26.11 353.79 2,003.01 1,824.51 438.86 -47.73 2,434,375.84 317,432.90 0.34 -424.75 MWD+SC+sag(5) 2,150.93 25.53 353.15 2,059.16 1,880.66 465.85 -50.82 2,434,402.87 317,430.23 1.03 -450.92 MWD+SC+sag(5) 2,213.19 25.82 353.87 2,115.27 1,936.77 492.66 -53.87 2,434,429.72 317,427.60 0.68 -476.91 MWD+SC+sag(5) 2,274.61 25.10 353.41 2,170.72 1,992.22 518.90 -56.79 2,434,458.00 317,425.08 1.22 -502.34 MWD+SC+sag(5) 2,337.36 24.69 352.57 2,227.64 2,049.14 545.11 -60.01 2,434,482.27 317,422.26 0.86 -527.85 MWD+SC+sag(5) 2,398.89 25.44 351.94 2,283.38 2,104.88 570.94 -63.53 2,434,508.15 317,419.15 1.29 -553.11 MWD+SC+sag(5) 2,460.34 24.76 354.30 2,339.03 2,160.53 596.81 -66.66 2,434,534.06 317,416.42 1.97 -578.27 MWD+SC+sag(5) 2,522.96 24.97 354.10 2,395.84 2,217.34 623.01 -69.32 2,434,560.30 317,414.16 0.36 -603.55 MWD+SC+sag(5) 2,584.36 25.56 354.72 2,451.37 2,272.87 649.09 -71.87 2,434,586.42 317,412.02 1.05 -628.69 MWD+SC+sag(5) 2,646.41 24.51 355.14 2,507.59 2,329.09 675.25 -74.19 2,434,612.60 317,410.10 1.72 -653.80 MWD+SC+sag(5) 2,709.55 24.78 355.66 2,564.98 2,386.48 701.49 -76.30 2,434,638.88 317,408.40 0.55 -678.93 MWD+SC+sag(5) 2,770.17 25.64 356.76 2,619.82 2,441.32 727.25 -78.00 2,434,664.66 317,407.09 1.62 -703.45 MWD+SC+sag(5) 2,832.70 25.02 355.93 2,676.34 2,497.84 753.95 -79.71 2,434,691.38 317,405.80 1.14 -728.84 MWD+SC+sag(5) 2,893.82 25.36 355.93 2,731.65 2,553.15 779.90 -81.55 2,434,717.36 317,404.36 0.56 -753.58 MWD+SC+sag(5) 2,956.38 25.11 354.90 2,788.24 2,609.74 806.48 -83.68 2,434,743.97 317,402.64 0.81 -779.03 MWD+SC+sag(5) 3,018.37 24.76 354.36 2,844.45 2,665.95 832.50 -86.13 2,434,770.03 317,400.60 0.67 -804.07 MWD+SC+sag(5) 3,080.63 25.09 354.56 2,900.91 2,722.41 858.62 -88.66 2,434,796.18 317,398.47 0.55 -829.23 MWD+SC+sag(5) 11/11/2014 8:15:11PM Page 3 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 25 Project: Beaver Creek Unit TVD Reference: BCU-25 @ 178.50usft(Saxon169(160.5+18)) Site: Beaver Creek Unit MD Reference: BCU-25 @ 178.50usft(Saxon169(160.5+18)) Well: Beaver CK Unit 25 North Reference: True Wellbore: BCU-25 Survey Calculation Method: Minimum Curvature Design: BCU-25 Database: Sperry EDM-NORTH US+CANADA I Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,141.73 24.68 354.20 2;956.34 2,777.84 884.21 -91.18 2,434,821.80 317,396.35 0.72 -853.89 MWD+SC+sag(5) 3,204.76 25.58 354.31 3,013.40 2,834.90 910.84 -93.86 2,434,848.47 317,394.08 1.43 -879.59 MWD+SC+sag(5) 3,266.93 24.83 353.64 3,069.65 2,891.15 937.17 -96.64 2,434,874.84 317,391.71 1.29 -905.03 MWD+SC+sag(5) 3,328.73 25.60 353.09 3,125.56 2,947.06 963.32 -99.68 2,434,901.04 317,389.07 1.30 -930.42 MWD+SC+sag(5) 3,390.34 25.45 353.05 3,181.16 3,002.66 989.67 -102.88 2,434,927.44 317,386.28 0.25 -956.05 MWD+SC+sag(5) 3,453.77 24.72 354.04 3,238.61 3,060.11 1,016.39 -105.91 2,434,954.20 317,383.67 1.33 -981.96 MWD+SC+sag(5) 3,473.98 25.14 353.99 3,256.93 3,078.43 1,024.86 -106.80 2,434,962.68 317,382.91 2.08 -990.14 MWD+SC+sag(5) 3,530.39 25.47 354.68 3,307.93 3,129.43 1,048.86 -109.18 2,434,986.71 317,380.90 0.78 -1,013.28 MWD+SC+sag(5) 3,592.51 27.90 355.73 3,363.43 3,184.93 1,076.66 -111.50 2,435,014.54 317,379.01 3.98 -1,039.92 MWD+SC+sag(5) 3,654.94 27.80 356.23 3,418.63 3,240.13 1,105.75 -113.54 2,435,043.66 317,377.42 0.41 -1,067.66 MWD+SC+sag(5) 3,717.14 27.85 356.08 3,473.64 3,295.14 1,134.72 -115.49 2,435,072.66 317,375.92 0.14 -1,095.24 MWD+SC+sag(5) 3,779.23 27.57 358.23 3,528.61 3,350.11 1,163.52 -117.42 2,435,101.49 317,374.43 0.46 -1,122.67 MWD+SC+sag(5) 3,841.08 26.52 355.77 3,583.69 3,405.19 1,191.58 -119.38 2,435,129.57 317,372.90 1.73 -1,149.41 MWD+SC+sag(5) 3,903.29 25.04 354.74 3,639.71 3,461.21 1,218.54 -121.62 2,435,156.56 317,371.09 2.49 -1,175.25 MWD+SC+sag(5) 3,965.05 20.78 355.02 3,696.58 3,518.08 1,242.48 -123.77 2,435,180.54 317,369.31 6.90 -1,198.25 MWD+SC+sag(5) 4,026.99 18.37 355.90 3,754.94 3,576.44 1,263.16 -125.42 2,435,201.24 317,367.98 3.92 -1,218.04 MWD+SC+sag(5) 4,088.90 15.49 355.95 3,814.16 3,635.66 1,281.14 -126.70 2,435,219.24 317,366.98 4.65 -1,235.19 MWD+SC+sag(5) 4,149.39 12.23 359.59 3,872.88 3,694.38 1,295.61 -127.32 2,435,233.72 317,366.58 5.58 -1,248.84 MWD+SC+sag(5) 4,212.10 8.91 5.24 3,934.52 3,756.02 1,307.09 -126.92 2,435,245.19 317,367.16 5.54 -1,259.33 MWD+SC+sag(5) 4,272.74 5.90 8.49 3,994.65 3,816.15 1,314.85 -126.03 2,435,252.94 317,368.17 5.01 -1,266.19 MWD+SC+sag(5) 4,335.74 3.34 29.40 4,057.44 3,878.94 1,319.66 -124.65 2,435,257.72 317,369.62 4.80 -1,270.13 MWD+SC+sag(5) 4,398.59 2.92 89.69 4,120.22 3,941.72 1,321.26 -122.15 2,435,259.28 317,372.15 5.03 -1,270.68 MWD+SC+sag(5) 4,460.56 4.36 151.33 4,182.08 4,003.58 1,319.20 -119.44 2,435,257.18 317,374.82 6.34 -1,267.75 MWD+SC+sag(5) 4,522.06 7.40 171.32 4,243.25 4,064.75 1,313.23 -117.72 2,435,251.19 317,376.45 5.89 -1,261.57 MWD+SC+sag(5) 4,585.16 10.49 176.16 4,305.58 4,127.08 1,303.48 -116.72 2,435,241.42 317,377.30 5.04 -1,252.16 MWD+SC+sag(5) 4,646.73 13.35 174.53 4,365.82 4,187.32 1,290.81 -115.67 2,435,228.74 317,378.15 4.68 -1,240.02 MWD+SC+sag(5) 4,708.43 16.63 173.15 4,425.41 4,246.91 1,274.95 -113.94 2,435,212.85 317,379.64 5.35 -1,224.67 MWD+SC+sag(5) 4,770.92 19.61 170.01 4,484.80 4,306.30 1,255.74 -111.05 2,435,193.60 317,382.23 5.02 -1,205.78 MWD+SC+sag(5) 4,833.62 22.15 167.14 4,543.37 4,364.87 1,233.85 -106.60 2,435,171.64 317,386.35 4.37 -1,183.81 MWD+SC+sag(5) 4,895.12 25.07 166.61 4,599.72 4,421.22 1,209.87 -101.00 2,435,147.58 317,391.57 4.76 -1,159.48 MWD+SC+sag(5) 4,956.34 28.88 166.81 4,654.27 4,475.77 1,182.85 -94.62 2,435,120.46 317,397.53 6.23 -1,132.04 MWD+SC+sag(5) 5,019.79 31.66 166.14 4,709.06 4,530.56 1,151.75 -87.13 2,435,089.26 317,404.54 4.41 -1,100.41 MWD+SC+sag(5) 5,080.32 34.47 165.60 4,759.79 4,581.29 1,119.73 -79.06 2,435,057.11 317,412.11 4.67 -1,067.70 MWD+SC+sag(5) 5,142.49 36.62 164.40 4,810.37 4,631.87 1,084.83 -69.70 2,435,022.07 317,420.93 3.64 -1,031.83 MWD+SC+sag(5) 5,205.00 39.76 164.60 4,859.49 4,680.99 1,047.59 -59.38 2,434,984.68 317,430.68 5.03 -993.43 MWD+SC+sag(5) 5,266.36 43.45 167.96 4,905.37 4,726.87 1,008.02 -49.76 2,434,944.96 317,439.68 7.03 -953.14 MWD+SC+sag(5) 5,328.86 46.79 171.12 4,949.47 4,770.97 964.48 -41.76 2,434,901.30 317,447.01 6.43 -909.78 MWD+SC+sag(5) 5,389.83 49.51 171.25 4,990.15 4,811.65 919.60 -34.80 2,434,856.32 317,453.27 4.46 -865.57 MWD+SC+sag(5) 5,444.23 52.56 170.67 5,024.35 4,845.85 877.84 -28.15 2,434,814.46 317,459.27 5.67 -824.36 MWD+SC+sag(5) 5,504.99 55.53 169.40 5,060.03 4,881.53 829.41 -19.63 2,434,765.90 317,467.04 5.17 -776.26 MWD+SC+sag(5) 11/11/2014 8•15:11PM Page 4 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 25 Project: Beaver Creek Unit TVD Reference: BCU-25 @ 178.50usft(Saxon169(160.5+18)) Site: Beaver Creek Unit MD Reference: BCU-25 @ 178.50usft(Saxon169(160.5+18)) Well: Beaver CK Unit 25 North Reference: True Wellbore: BCU-25 Survey Calculation Method: Minimum Curvature Design: BCU-25 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical ' MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,569.27 58.89 168.19 5,094.83 4,916.33 776.41 -9.12 2,434,712.75 317,476.73 5.46 -723.19 MWD+SC+sag(5) 5,631.57 62.30 168.12 5,125.42 4,946.92 723.30 2.02 2,434,659,47 317,487.05 5.47 -669.78 MWD+SC+sag(5) 5,693.18 65.26 167.64 5,152.63 4,974.13 669.27 13.63 2,434,605.27 317,497.81 4.85 -615.34 MWD+SC+sag(5) 5,754.92 68.43 167.67 5,176.91 4,998.41 613.82 25.76 2,434,549.64 317,509.09 5.13 -559.39 MWD+SC+sag(5) 5,816.86 71.37 168.56 5,198.19 5,019.69 556.91 37.73 2,434,492.54 317,520.18 4.93 -502.13 MWD+SC+sag(5) 5,879.11 74.10 168.87 5,216.67 5,038.17 498.61 49.36 2,434,434.08 317,530.91 4.41 -443.73 MWD+SC+sag(5) 5,941.19 76.90 168.92 5,232.21 5,053.71 439.64 60.94 2,434,374.94 317,541.57 4.51 -384.72 MWD+SC+sag(5) 6,002.68 80.37 169.09 5,244.32 5,065.82 380.47 72.44 2,434,315.60 317,552.15 5.65 -325.56 MWD+SC+sag(5) 6,064.58 83.67 169.86 5,252.92 5,074.42 320.21 83.63 2,434,255.17 317,562.41 5.47 -265.50 MWD+SC+sag(5) 6,126.15 87.45 170.56 5,257.68 5,079.18 259.73 94.06 2,434,194.54 317,571.90 6.24 -205.52 MWD+SC+sag(5) 6,188.85 89.30 170.54 5,259.46 5,080.96 197.91 104.35 2,434,132.56 317,581.24 2.95 -144.35 MWD+SC+sag(5) 6,250.00 90.15 170.88 5,259.75 5,081.25 137.57 114.23 2,434,072.07 317,590.17 1.50 -84.70 MWD+SC+sag(5) 6,312.55 90.02 171.04 5,259.66 5,081.16 75.79 124.05 2,434,010.15 317,599.04 0.33 -23.75 MWD+SC+sag(5) 6,376.36 90.02 170.70 5,259.64 5,081.14 12.79 134.18 2,433,947.00 317,608.19 0.53 38.45 MWD+SC+sag(5) 6,439.45 90.27 171.13 5,259.48 5,080.98 -49.51 144.14 2,433,884.56 317,617.19 0.79 99.94 MWD+SC+sag(5) 6,503.90 88.72 171.10 5,260.05 5,081.55 -113.18 154.09 2,433,820.74 317,626.15 2.41 162.70 MWD+SC+sag(5) 6,565.75 88.60 171.31 5,261.49 5,082.99 -174.29 163.55 2,433,759.49 317,634.66 0.39 222.89 MWD+SC+sag(5) 6,627.83 88.47 170.74 5,263.08 5,084.58 -235.58 173.23 2,433,698.05 317,643.39 0.94 283.35 MWD+SC+sag(5) 6,688.28 88.73 170.68 5,264.56 5,086.06 -295.22 182.99 2,433,638.27 317,652.22 0.44 342.30 MWD+SC+sag(5) 6,751.21 90.03 170.40 5,265.24 5,086.74 -357.29 193.33 2,433,576.05 317,661.60 2.11 403.71 MWD+SC+sag(5) 6,814.02 89.96 170.06 5,265.24 5,086.74 -419.19 203.99 2,433,513.99 317,671.30 0.55 465.09 MWD+SC+sag(5) 6,876.86 89.90 169.26 5,265.32 5,086.82 -481.01 215.27 2,433,452.00 317,681.62 1.28 526.63 MWD+SC+sag(5) 6,937.58 90.46 166.44 5,265.13 5,086.63 -540.36 228.04 2,433,392.46 317,693.48 4.73 586.45 MWD+SC+sag(5) 6,998.86 90.64 162.47 5,264.54 5,086.04 -599.39 244.46 2,433,333.19 317,708.99 6.48 647.32 MWD+SC+sag(5) 7,062.36 90.02 159.04 5,264.17 5,085.67 -659.33 265.39 2,433,272.93 317,728.98 5.49 710.74 MWD+SC+sag(5) 7,125.02 90.21 155.84 5,264.05 5,085.55 -717.19 289.43 2,433,214.71 317,752.12 5.12 773.38 MWD+SC+sag(5) 7,187.22 89.83 154.19 5,264.03 5,085.53 -773.56 315.70 2,433,157.93 317,777.51 2.72 835.50 MWD+SC+sag(5) 7,248.87 89.96 153.76 5,264.14 5,085.64 -828.96 342.75 2,433,102.12 317,803.70 0.73 897.00 MWD+SC+sag(5) 7,310.76 90.15 153.41 5,264.08 5,085.58 -884.39 370.28 2,433,046.27 317,830.38 0.64 958.71 MWD+SC+sag(5) 7,364.15 90.14 153.06 5,263.95 5,085.45 -932.06 394.32 2,432,998.24 317,853.68 0.66 1,011.91 MWD+SC+sag(5) 7,434.57 90.14 152.87 5,263.77 5,085.27 -994.79 426.33 2,432,935.02 317,884.71 0.27 1,082.06 MWD+SC+sag(5) 7,496.40 89.89 152.62 5,263.76 5,085.26 -1,049.75 454.65 2,432,879.63 317,912.17 0.57 1,143.64 MWD+SC+sag(5) 7,558.90 89.59 153.70 5,264.04 5,085.54 -1,105.52 482.86 2,432,823.43 317,939.52 1.79 1,205.91 MWD+SC+sag(5) 7,621.53 89.71 154.00 5,264.42 5,085.92 -1,161.73 510.47 2,432,766.79 317,966.25 0.52 1,268.38 MWD+SC+sag(5) 7,683.49 90.33 155.74 5,264.40 5,085.90 -1,217.83 536.78 2,432,710.30 317,991.69 2.98 1,330.24 MWD+SC+sag(5) 7,745.89 89.83 158.04 5,264.31 5,085.81 -1,275.22 561.27 2,432,652.54 318,015.29 3.77 1,392.63 MWD+SC+sag(5) 7,806.69 89.77 159.36 5,264.53 5,086.03 -1,331.86 583.35 2,432,595.56 318,036.50 2.17 1,453.42 MWD+SC+sag(5) 7,868.64 89.96 159.05 5,264.67 5,086.17 -1,389.78 605.35 2,432,537.31 318,057.59 0.59 1,515.36 MWD+SC+sag(5) 7,930.32 90.15 158.54 5,264.61 5,086.11 -1,447.28 627.66 2,432,479.47 318,079.01 0.88 1,577.03 MWD+SC+sag(5) 7,994.07 89.71 159.65 5,264.69 5,086.19 -1,506.83 650.40 2,432,419.57 318,100.83 1.87 1,640.77 MWD+SC+sag(5) 11/11/2014 8•15:11PM Page 5 COMPASS 5000.1 Build 70 • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 25 Project: Beaver Creek Unit TVD Reference: BCU-25 @ 178.50usft(Saxon169(160.5+18)) Site: Beaver Creek Unit MD Reference: BCU-25 @ 178.50usft(Saxon169(160.5+18)) Well: Beaver CK Unit 25 North Reference: True Wellbore: BCU-25 Survey Calculation Method: Minimum Curvature Design: BCU-25 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 8,054.83 90.46 162.39 5,264.60 5,086.10 -1,564.28 670.16 2,432,361.82 318,119.70 4.68 1,701.44 MWD+SC+sag(5) 8,116.89 90.08 163.16 5,264.31 5,085.81 -1,623.56 688.54 2,432,302.27 318,137.16 1.38 1,763.28 MWD+SC+sag(5) 8,179.18 89.83 162.75 5,264.36 5,085.86 -1,683.11 706.80 2,432,242.44 318,154.49 0.77 1,825.33 MWD+SC+sag(5) 8,208.00 89.83 162.75 5,264.44 . 5,085.94 -1,710.63 715.34 2,432,214.79 318,162.61 0.00 1,854.05 PROJECTED to TD Checked By: Patrick Walker Et5F,7.--:::÷-,7:---�wApproved By: Car Taylor :.7�;7�„; ��— --r Date: 11/11/2014 8:15:11PM Page 6 COMPASS 5000.1 Build 70 BCU-25 Definitive survey H HEADER INFORMATION H COMPANY : Hilcorp Energy Company H FIELD : Beaver Creek Unit H SITE : Beaver Creek Unit H WELL : Beaver CK Unit 25 H WELLPATH: BCU-25 H DEPTHUNT: usft H SURVDATE: 11/11/2014 H H WELL INFORMATION H WELL EW MAP : 317473.83 H WELL NS MAP : 2433936.29 H DATUM ELEVN : 178.50 H VSECT ANGLE : 157.98 H VSECT NORTH : 0.00 H VSECT EAST : 0.00 H H SURVEY TYPE INFORMATION H 97.28 - 843.63 MWD+SC+SAG : MWD+SC+SAG H 905.61 - 1091.55 MWD+ITERP AZ+SAG : MWD_INTERP AZI+SAG H 1153.47 - 1526.91 MWD+SC+SAG (2) : MWD+SC+SAG H 1590.19 - 1590.19 MWD+INTERP AZI+SAG (2) : MWD_INTERP AZI+SAG H 1653.71 - 8179.18 MWD+SC+SAG (3) : MWD+SC+SAG H H SURVEY LIST H MD INC AZI TVD NS EW 18.00 0.00 0.00 18.00 0.00 0.00 97.28 0.06 4.52 97.28 0.04 0.00 162.13 0.25 4.52 162.13 0.22 0.02 222.90 0.80 24.69 222.90 0.73 0.20 284.95 0.68 25.49 284.94 1.46 0.54 354.71 0.71 22.60 354.70 2.23 0.89 412.49 0.35 3.99 412.47 2.74 1.04 474.79 0.17 353.75 474.77 3.02 1.04 534.70 0.23 355.11 534.68 3.23 1.02 596.03 0.07 325.78 596.01 3.38 0.99 659.11 0. 51 341.38 659.09 3.68 0.88 720.90 1.22 348.24 720.87 4.59 0.66 781.70 2.85 344.16 781.63 6.67 0.11 843.63 5.45 341.66 843.40 10.95 -1.23 905.61 6.59 347.52 905.03 17.21 -2.93 967.55 9.32 351.09 966.37 25.64 -4.47 1029.63 11.62 353.13 1027.42 36.81 -6.00 1091.55 13.23 354.50 1087.88 50.06 -7.43 1153.47 16.16 355. 50 1147.77 65.71 -8.78 1215.78 17.41 353.98 1207.43 83.62 -10.44 1277.34 19.60 351.99 1265.80 103.01 -12.84 1339.49 21.93 351.91 1323.91 124.82 -15.93 1402.41 22.87 351.41 1382.08 148.55 -19.41 1463.60 23.79 352.47 1438.27 172.54 -22.80 1526.91 24.31 354.15 1496.08 198.16 -25.80 1590.19 24.22 354.61 1553.77 224.04 -28.35 1653.71 24.61 355.06 1611.61 250.19 -30.71 1715.83 26.08 355.22 1667.75 276.69 -32.97 1777.78 25.69 356.60 1723.49 303.66 -34.90 1838.47 25.97 355.60 1778.11 330.04 -36.70 1901.37 25.88 354.10 1834.68 357.43 -39.16 1964.20 25.84 353.86 1891.22 384.68 -42.04 2026.44 25.99 354.18 1947.20 411.73 -44.87 2088.56 26.11 353.79 2003.01 438.86 -47.73 2150.93 25.53 353.15 2059.16 465.85 -50.82 2213.19 25.82 353.87 2115.27 492.66 -53.87 2274.61 25.10 353.41 2170.72 518.90 -56.79 Page 1 BCu-25 Definitive survey 2337.36 24.69 352.57 2227.64 545.11 -60.01 2398.89 25.44 351.94 2283.38 570.94 -63. 53 2460.34 24.76 354.30 2339.03 596.81 -66.66 2522.96 24.97 354.10 2395.84 623.01 -69.32 2584.36 25.56 354.72 2451.37 649.09 -71.87 2646.41 24.51 355.14 2507.59 675.25 -74.19 2709.55 24.78 355.66 2564.98 701.49 -76.30 2770.17 25.64 356.76 2619.82 727.25 -78.00 2832.70 25.02 355.93 2676.34 753.95 -79.71 2893.82 25.36 355.93 2731.65 779.90 -81. 55 2956.38 25.11 354.90 2788.24 806.48 -83.68 3018.37 24.76 354.36 2844.45 832.50 -86.13 3080.63 25.09 354.56 2900.91 858.62 -88.66 3141.73 24.68 354.20 2956.34 884.21 -91.18 3204.76 25. 58 354.31 3013.40 910.84 -93.86 3266.93 24.83 353.64 3069.65 937.17 -96.64 3328.73 25.60 353.09 3125.56 963.32 -99.68 3390.34 25.45 353.05 3181.16 989.67 -102.88 3453.77 24.72 354.04 3238.61 1016.39 -105.91 3473.98 25.14 353.99 3256.93 1024.86 -106.80 3530.39 25.47 354.68 3307.93 1048.86 -109.18 3592.51 27.90 355.73 3363.43 1076.66 -111.50 3654.94 27.80 356.23 3418.63 1105.75 -113.54 3717.14 27.85 356.08 3473.64 1134.72 -115.49 3779.23 27. 57 356.23 3528.61 1163.52 -117.42 3841.08 26. 52 355.77 3583.69 1191.58 -119.38 3903.29 25.04 354.74 3639.71 1218. 54 -121.62 3965.05 20.78 355.02 3696. 58 1242.48 -123.77 4026.99 18.37 355.90 3754.94 1263.16 -125.42 4088.90 15.49 355.95 3814.16 1281.14 -126.70 4149.39 12.23 359.59 3872.88 1295.61 -127.32 4212.10 8.91 5.24 3934.52 1307.09 -126.92 4272.74 5.90 8.49 3994.65 1314.85 -126.03 4335.74 3.34 29.40 4057.44 1319.66 -124.65 4398.59 2.92 89.69 4120.22 1321.26 -122.15 4460.56 4.36 151.33 4182.08 1319.20 -119.44 4522.06 7.40 171.32 4243.25 1313.23 -117.72 4585.16 10.49 176.16 4305.58 1303.48 -116.72 4646.73 13.35 174.53 4365.82 1290.81 -115.67 4708.43 16.63 173.15 4425.41 1274.95 -113.94 4770.92 19.61 170.01 4484.80 1255.74 -111.05 4833.62 22.15 167.14 4543.37 1233.85 -106.60 4895.12 25.07 166.61 4599.72 1209.87 -101.00 4956.34 28.88 166.81 4654.27 1182.85 -94.62 5019.79 31.66 166.14 4709.06 1151.75 -87.13 5080.32 34.47 165.60 4759.79 1119.73 -79.06 5142.49 36.62 164.40 4810.37 1084.83 -69.70 5205.00 39.76 164.60 4859.49 1047. 59 -59.38 5266.36 43.45 167.96 4905.37 1008.02 -49.76 5328.86 46.79 171.12 4949.47 964.48 -41.76 5389.83 49. 51 171.25 4990.15 919.60 -34.80 5444.23 52. 56 170.67 5024.35 877.84 -28.15 5504.99 55. 53 169.40 5060.03 829.41 -19.63 5569.27 58.89 168.19 5094.83 776.41 -9.12 5631.57 62.30 168.12 5125.42 723.30 2.02 5693.18 65.26 167.64 5152.63 669.27 13.63 5754.92 68.43 167.67 5176.91 613.82 25.76 5816.86 71.37 168.56 5198.19 556.91 37.73 5879.11 74.10 168.87 5216.67 498.61 49.36 5941.19 76.90 168.92 5232.21 439.64 60.94 6002.68 80.37 169.09 5244.32 380.47 72.44 6064.58 83.67 169.86 5252.92 320.21 83.63 6126.15 87.45 170.56 5257.68 259.73 94.06 Page 2 BCU-25 Definitive Survey 6188.85 89.30 170.54 5259.46 197.91 104.35 6250.00 90.15 170.88 5259.75 137.57 114.23 6312.55 90.02 171.04 5259.66 75.79 124.05 6376.36 90.02 170.70 5259.64 12.79 134.18 6439.45 90.27 171.13 5259.48 -49.51 144.14 6503.90 88.72 171.10 5260.05 -113.18 154.09 6565.75 88.60 171.31 5261.49 -174.29 163. 55 6627.83 88.47 170.74 5263.08 -235.58 173.23 6688.28 88.73 170.68 5264.56 -295.22 182.99 6751.21 90.03 170.40 5265.24 -357.29 193.33 6814.02 89.96 170.06 5265.24 -419.19 203.99 6876.86 89.90 169.26 5265.32 -481.01 215.27 6937. 58 90.46 166.44 5265.13 -540.36 228.04 6998.86 90.64 162.47 5264.54 -599.39 244.46 7062.36 90.02 159.04 5264.17 -659.33 265.39 7125.02 90.21 155.84 5264.05 -717.19 289.43 7187.22 89.83 154.19 5264.03 -773.56 315.70 7248.87 89.96 153.76 5264.14 -828.96 342.75 7310.76 90.15 153.41 5264.08 -884.39 370.28 7364.15 90.14 153.06 5263.95 -932.06 394.32 7434.57 90.14 152.87 5263.77 -994.79 426.33 7496.40 89.89 152.62 5263.76 -1049.75 454.65 7558.90 89.59 153.70 5264.04 -1105. 52 482.86 7621.53 89.71 154.00 5264.42 -1161.73 510.47 7683.49 90.33 155.74 5264.40 -1217.83 536.78 7745.89 89.83 158.04 5264.31 -1275.22 561.27 7806.69 89.77 159.36 5264. 53 -1331.86 583.35 7868.64 89.96 159.05 5264.67 -1389.78 605.35 7930.32 90.15 158.54 5264.61 -1447.28 627.66 7994.07 89.71 159.65 5264.69 -1506.83 650.40 8054.83 90.46 162.39 5264.60 -1564.28 670.16 8116.89 90.08 163.16 5264.31 -1623.56 688. 54 8179.18 89.83 162.75 5264.36 -1683.11 706.80 8208.00 89.83 162.75 5264.44 -1710.63 715.34 Page 3 - G g - -0o C _ N 9• u _ 9 9Nrs. a silo O r� N R .7," _ .., a U - pR - O a —O c• oo _ M S • m N - O a N 88 -_NN 8078. m• - N 0009 - - O —O - Z _ N 7 },LC) 009L O E C N O a) a)D - 'MI 22 22Y - cm UUULC)L-0 000 - O LO 45 N N —0 Y mm 00 mm 0 o o 0099_ _ p O U rKCp O O a ) i�� a) s N ^O 006. cq a)•- o._ h •o�›-Q ( N 00 0009 To - c) 0 a)0 N0 -c 00O a) N O o 000.99 —0 0 M9g - O 0 O OROS —o o . N m ' o n v Cn - rn - o —in N -- Opp —IA N —- 1 2 - I- O - 8 a —O 7 p - q W J a - J r - 4 ® I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I 1 1 I I I I I I I I I I I I I I I I o 0 0 0 0 0 0 0 0 0 p0 8 b In O r 0 N to N M V Y U) a (u!non 0006) 41daa ieowan anal • • HALLIBURTON Project: Beaver Creek Unit WELL DETAILS: Beaver CKUnit 25 SperryDrilling Services Beaver Creek Unit Ground Level: 160.50 Well: Beaver CK Unit 25 +N/-S +EJ-W Northing Fasting Latittude Longitude Slot Wellbore: BCU 25 0.00 0.00 2433936.29 317473.83 60.6582484 -151.0173929 Plan: BCU-25 REFERENCE INFORMATION Co-ordinate(N/E)Reference:Well Beaver CK Unit 25,True North Vertical(TVD)Reference:BCU-25 @ 178.50usfl(Saxon169(160.5+18)) Measured Depth Reference: BCU-25 @ 178.50058(Saxon169(160.5+18)) 1750— Calculation Method:Minimum Curvature 1500- - a y0 - i 1 360°- 1250_ `4500 = 1�0 1000— I 9 5/8" 5000 750— 2750" 2500 • 500— 2250 2000 5250 250 1750 1500 • 1250- 355° 0— 1000, 5° 500 7 – O -250— o yc -500- 0 \\65:\ C -750— 5° -1000- - -1250— -1500— \vh0 - 526a -1750— -- - gCV 5 -2000— 5 ,Cll - T M Azimuths to True North -2250— Magnetic North:16.91' Magnetic Field Strength:55439.7snT Dip Angle:73.63" -2500— Date:10/5/2014 Model:BGGM2014 I I I I I I I I I I I I I I I I l I l I I I I I I l I I I I I I l I l I I I l I I I I l I I I I l i I 1 I I I I I I 1 1 1 -1250 -1000 -750 -500 -250 0 250 500 750 1000 1250 1500 1750 2000 West(-)/East(+)(500 usft/in) 11t('ni O Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No BCU-25 Date 24-Oct-14 County Kenai Peninsula Borough State Alaska Supv Grubb/Sweetsir CASING RECORD TD 3510 00 Shoe Depth 3269 00 PBTD Casing(Or Liner)Detail _ Setting Depths No of Jts Size Wt Grade THD _ Make Length Bottom Top Shoe 9 5/8 BTC Davis Lynch 1.86 3,488.00 3,486.14 2 jts 9 5/8 40 1-80 BTC 85.06 3,486.14 3,405.05 Fit Clr 9 5/8 BTC Davis Lynch 1.57 3,405.05 3,403.48 81 9 5/8 40 L-80 BTC 3,377.93 3,403.48 25.55 Pup Jt 9 5/8 40 L-80 BTC 3.10 25.55 22.45 Hanger 0.90 22.45 21.55 RKB 21.55 21.55 0.00 Csg Wt On Hook 120k Type Float Collar Davis Lynch No Hrs to Run 8 Csg Wt On Slips Type of Shoe Bull Nose Casing Crew WFD Fluid Descnption 9 4 Spud Mud Liner hanger Info(Make/Model) Liner top Packer _Yes x No Liner hanger test pressure 3000 Centralizer Placement 1 centralizer on every other joint CEMENTING REPORT Preflush(Spacer) Type Mud Push II Density(ppg) 10 5 Volume pumped(BBLs) 35 Lead Slurry Type Lead Density(ppg) 12 Volume pumped(BBLs) 248 Mixing/Pumping Rate(bpm) 5 7 Tail Slurry Type Tail tzji Density(ppg) 15 4 Volume pumped(BBLs) 54 Mixing/Pumping Rate(bpm) 5 / N Post Flush(Spacer) y Type Density(ppg) Rate(bpm) Volume r Displacement: Type 9 4 Spud Mud Density(ppg) 9 4 Rate(bpm) 6 Volume(actual/calculated) 254/250 FCP(psi) 850 Pump used for disp Schlumberger Plug Bumped? x Yes No Bump press 1500 Casing Rotated' Yes x No Reciprocated? x Yes No 100%Retums dunng job 100% Cement returns to surface? x Yes No Spacer returns? x Yes No Vol to Surf 100 Cement In Place At 12 45 Date 10/24/2014 Estimated TOC Surface Method Used To Determine TOC Full Retums Preflush(Spacer) Type Density(ppg) Volume pumped(BBLs) Lead Slurry Type Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm) Tail Slurry w Type Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm) m Post Flush(Spacer) o o Type Density(ppg) Rate(bpm) Volume wDisplacement: Type Density(ppg) Rate(bpm) Volume(actual/calculated) FCP(psi) Pump used for disp Plug Bumped? _Yes No Bump press Casing Rotated? Yes _No Reciprocated? _Yes_No %Returns during job Cement returns to surface? Yes_No Spacer returns? Yes_No Vol to Surf Cement In Place At Date __ Estimated TOC Method Used To Determine TOC WELLHEAD Make CIW Type Serial No Size 16x11 W P 5000 Test Head To 250/5000 PSIG 15 MIN test good OK Remarks • Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No Beaver Creek Well BCU 25 Date 6-Nov-14 County Kenai Peninsula Borough State Alaska Supv Rance Pederson/Jimmy Greco CASING RECORD TD 8208 00 Shoe Depth 8196 22 PBTD 8105 62 Casing(Or Liner)Detail Setting Depths No of Jts Size Wt Grade THD Make Length Bottom Top Shoe 51/2 WFD model 301 1.54 8,196.22 8,194.68 2 5 1/2 17 P-110 GeoCon 87.78 8,194.68 8,106.09 Flt Clr 51/2 WFD model 40i 1.28 8,106.09 8,105.62 124 jts 51/2 17 P-110 GeoCon 5,147.35 8,105.62 2,958.27 Swell PKR Baker 21.00 2,958.27 2,937.27 67jts 51/2 17 P-110 GeoCon 2,915.26 2,937.27 2,89354 PUP 51/2 17 P-110 GeoCon 3.28 2,893.54 18.73 Hanger 5 1/2 x 11 0.73 18.73 18.00 Landing jt 18.00 18.75 18.75 Totals I 18.00 18.00 0.00 Csg Wt On Hook 136,489 Type Float Collar Model 402 No Hrs to Run 15 5 Csg Wt On Slips Type of Shoe Bull Nose/303 Casing Crew WFD Fluid Descnption 9 8 ppg/6%KCUPHPA Mud/ PV=13 YP=24 HTHP=15 2 Liner hanger Info(Make/Model) Liner top Packers _Yes X No Liner hanger test pressure 0 Centralizer Placement 1 free floating Valant centralizer per joint to int 91-1 every other jt from int 91 thru it 175 CEMENTING REPORT Preflush(Spacer) Type Mud Push II Density(ppg) 10 5 Volume pumped(BBLs) 45 Lead Slurry Type Class G EasyBlok I I S7 Sa( Density(ppg) 15 3 Volume pumped(BBLs) 283 Mixing/Pumping Rate(bpm) 5 5 Tail Slurry Type 16 Density(ppg) Volume pumped(BBLs) _Mixing/Pumping Rate(bpm) N Post Flush(Spacer) N Type Density(ppg) Rate(bpm) Volume � Displacement: Type 3%kcl Density(ppg) 8 5 Rate(bpm) _ 6 Volume(actual/calc - 190/189 FCP(psi) 1600 Pump used for disp Schlumberger Plug Bumped'? Yes Bump press 0 Casing Rotated' Yes X No Reciprocated' X Yes_No %Returns dunng job 100 Cement retums to surface? Yes X No Spacer returns? Yes X No Vol to Surf 0 Cement In Place At 15 15 Date 11/6/2014 Estimated TOC 3,000 —/J�f� Method Used To Determine TOC calculated volumes �Tc_ Preflush(Spacer) 3'7 7. r A4 Type Density(ppg) Volume pumped(BBLs) Lead Slurry Type Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm) Tall Slurry w Type Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm) y Post Flush(Spacer) a oType Density(ppg) Rate(bpm) Volume w Displacement: N Type Density(ppg) Rate(bpm) Volume(actual/calculated) FCP(psi) Pump used for disp Plug Bumped' _Yes No Bump press Casing Rotated? Yes _No Reciprocated' _Yes No %Returns during job Cement retums to surface? Yes_No Spacer returns'? Yes_No Vol to Surf Cement In Place At Date Estimated TOC Method Used To Determine TOC WELLHEAD Make Seaboard Type Multibowl System Sena!No Size 11" W P 5K Test Head To 5000 PSIG 15 MIN test good Remarks Sea Board Starting Head,Ser#353286-00,16 3/4 weld on X 16 3/4 Flange r \)0,<$.0••••••°$*4:-) . 1 • i" w ff .r ♦ r 'fir ,lr,.{,x `(tJ « _ kosk I I i t 1 I , 1� oc i i 1 1 1 1 t P y✓� 121 , t (. , t yC \\\>N1 I\ JV � JJ'i - `V BCU 24 Days Vs Depth 0 —BCU 025 D&C Drill Lateral \\ —BCU 25 Plan 1000 — 2000 3000 $ 4000 a v a 5000 _ — 2 6000 — AFE (Drilling):$4,667,620 7000 AFE (Compl):$300,000 AFE Days: 25 CDC:$ 8000 CCC: $ Actual Days:0 Total AFE/Wellez Variance: 00.0% 9000 0 5 10 15 20 25 30 Days BCU 25 MW Vs Depth 0 500 1000 1500 2000 2500 3000 3500 —MW vs Depth —BCU 25 Plan - 4000 r O. GJ v 4500 a, 5000 5500 6000 6500 7000 7500 8000 8500 9000 - — — 8 9 10 11 12 13 14 Mud Density(ppg) S _ Nolan Hilcorp Alaska, Li.GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 itie ori, 1,1.( Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 12/16/14 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 25 Elog data Prints: ROP Rate of Penetration, DGR Dual Gamma Ray, EWR-Phase 4, ALD Azimuthal Lithodensity MD DGR Dual Gamma Ray, EWR-Phase 4, ALD Azimuthal Lithodensity TVD CD: CGM 11/21/201411:43... File folder 4, ALIS+LAS 11/211201411:44 .., File folder 4, EMF 11/21/2014 11:44 ... File folder PDF 11/21/201411:44 ... File folder , TIFF 11/21/2014 11:44 ... File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: S _i Nolan Hilcorp Alaska, L. GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Hilnarp:Ilaarks.I.I.0 Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 12/16/2014 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 25 Mudlog data Prints: End of Well Report 2" MD Formation Evaluation Log 5" MD Formation Evaluation Log 2" MD Gas Ratio Log 2" MD Drilling Engineering Log • CD: Final Well Data A Files Currently on the Disc (5) BEAVER CREEK UNIT 25 FINAL LOGS 12/11/2014 8:31 AM File folder .4, BEAVER CREEK UNIT 25 LAS EXPORTS 12/11/2014 8:31 AM File folder J,. EMF Log Viewer 12/11/2014 8:31 AM File folder Halliburton Log Viewer 12/11/2014 8:31 AM File folder ®BEAVER CREEK UNIT 25 FINAL END OF W... 12/10/2014 2:42 PM PDF Document 2,719 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: 21 4 1 3 2 . Nolan Hilcorp Alaska, L. 5 7 2 GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 Hilrurp:Unrka.l.11.. Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATA LOGGED \2.in/20144 M.K.BENDER DATE 12/16/14 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 25 Elog data Prints: ROP Rate of Penetration, DGR Dual Gamma Ray, EWR-Phase 4, ALD Azimuthal Lithodensity MD DGR Dual Gamma Ray, EWR-Phase 4, ALD Azimuthal Lithodensity TVD CD: CGM 11/21/201411:43.., File folder DLIS-1.4.S. 11/21/2014 11:44 .., File folder EMF 11r'21r201411:44 ... File folder j. PDF 11/21/201411:44... File folder ,g TIFF 11/21/201411:44 .., File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received 8� c,#) FDate: 214132 S Nolan Hilcorp Alaska, IL 2 5 1 7 3 DATA LOGGED GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 \2/fl/201q 1(doirr(. th.k;,. Fax: 907 777-8510 M.K.BENDER E-mail: snolan@hilcorp.com DATE 12/16/2014 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 25 Mudlog data Prints: End of Well Report 2" MD Formation Evaluation Log 5" MD Formation Evaluation Log 2" MD Gas Ratio Log 2" MD Drilling Engineering Log CD: Final Well Data • es Currently on the Disc (5) 4. BEAVER CREEK UNIT 25 FINAL LOGS 12;11/2014 8:31 AM File folder BEAVER CREEK UNIT 25 LAS EXPORTS 12111/2014 8:31 AM File fclder EMF Lcg Vieoeer 12/11/2014 831 AM File fclder Halliburtcn Lcg Viewer 12111/2014 8:31 AM File fclder a BEAVER CREEK UNIT 25 FINAL END OF W. 12/10/2014 2:42 PM PDF Dccument 2,719 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Receive � O_e$k22tP Date: v �� :o r„.. Alaska Oil and Gas 0,4%,..,r-sox s� '1 111: S 1.• I: sw { �,'1 \.s1 A Conservation Commission 333 West Seventh Avenue i f�t ~///� Anchorage,Alaska 99501-3572 Main:907.279.1433 ()/•Al.AS*P. Fax:907.276.7542 www.aogcc.alaska.gov Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Beaver Creek Field, Sterling Gas Pool, Beaver Creek 25 Sundry Number: 314-651 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, l'° t-e_-(-ocZe _ Cathy P. oerster Chair DATED this day of December, 2014. Encl. . RECEIVED ' STATE OF ALASKA I)E L 0 1 20 4 • 01` \ ALASKA OIL AND GAS CONSERVATION COMMISSION £7 3 14 S/` T Q1.) q/14 APPLICATION FOR SUNDRY APPROVALS AGC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Weil❑ Change Approved Program El Suspend El Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate El Alter Casing Other: Run Velocity String❑✓ • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0 214-132 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20644-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 237A Beaver Creek(BCU)25 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): A028083 Beaver Creek/Sterling Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8,208 5,264 8,105' 5,264' N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 78' 16" 78' 78' Surface 3,488' 9-5/8" 3,488' 3,270' 5,750 psi 3,090 psi Intermediate Production 8,196' 5-1/2" 8,196' 5,264' 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)end TVD(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal Q '13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 7 /Exploratory f Stnatigraphic❑ Development P] -Service [_] 14.Estimated Date for 15.Well Status after proposed work: 12/05/14 Commencing Operations: Oil ❑ Gas 0- WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ 0 WAG ❑ Abandoned ❑ Commission Representative: GSTOR El SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Pothole Phone: 907-777-8412 Email sDorhola( hilcorD.com Printed Name Stan Porhola Title Operations Engineer Signature zAticr1/�laPhone 907-777-8412 Date 1 Zb (/iL( COMMISSION USE ONLY (l Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test MechanicalicIntegrity Test ❑ Location Clearance ❑/ 4 Other: -,K 3rt"C, fs,i 80/ e ( ��4-S P _ i& S L(' ISZ) Spacing Exception Required? Yes El No R' Subsequent Form Required: /E —L/C I APPROVED BY Approved by:"pi' P3 (4,.....___ COMMISSIONER THE COMMISSION Date: /Z- �/si Z' ORKlael4INISAllt:Or Submit Form and Form 10-403(Revis 0/201) S I 12 mo from the date of a proval. ttmenta in Duplicate CMS DEC 1010 ��i ./ /z z./ Well Prognosis Well: BCU-25 Hilcorp Alaska,LI) Date:12/01/2014 Well Name: BCU-25 API Number: 50-133-20639-00 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: December 5th, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-132 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228(M) Second Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) AFE Number: 1412521C Current Bottom Hole Pressure: —2,180 psi @ 5,264'TVD (Based on P/T survey on 11/25/14) Maximum Expected BHP: —2,180 psi @ 5,264'TVD (Based on PIT survey on 11/25/14) Max. Allowable Surface Pressure: — 1,654 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#25 was drilled as a Grass roots horizontal monobore completion in 2014 to target the Sterling B4.The well was perforated via wireline tractor with 21 each 10' intervals, spaced roughly 100'apart. The well loaded up with fluid and has loaded up in the 5-1/2" casing. The purpose of this work/sundry is to run a 2-7/8"tubing velocity string without a packer to help unload the water while producing gas from the Sterling B4 by producing up the tubing x casing annulus.Gaslift mandrels will be installed to allow running reverse gaslift valves that would allow gaslift gas to be injected down the tubing and help lift produced fluids up the annulus. Notes Regarding Wellbore Condition • Max doglegs of 6.9°/100'at 3,965' MD and 7.0°/100'at 5,266' MD. WO Rig Procedure: 1. MIRU Moncla#401 WO Rig. 2. Kill well w/8.4 ppg lease water. 3. Set BPV. ND Tree. 4. NU new tubing head. '-( 5. NU 7-1/16" BOPE.Set BPV.Test to 250 psi Low/3,000 psi High, annular to 250 psi Low/1,500 psi High (hold each valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. 6. Bleed any pressure off tubing. Kill well w/8.4 ppg lease water if needed. 7. Pull BPV. RU 2-7/8"tubing handling tools. 8. PU and RIH w/2-7/8"tubing and completion jewelry. 9. RIH and land tubing hanger with tubing tail at+/-6,000' MD. V a. Leave tubing tail to land+/- 100' above the top perforated interval at 6,090' MD. b. Space out Gaslift Mandrels per proposed schematic. c. Run dummy valves in all Gaslift Mandrels. 10. MIRU Slickline. • 11. RIH w/2.25"gauge ring to 6,000'. a. Maximum deviation is 60°at 5,600'. Maximum deviation is 80°at 6,000'. Well Prognosis Well: BCU-25 Hilcorp Alaska,LI) Date:12/01/2014 12. RIH and set RHCP plug body in X-profile. 13. RIH and set RHCP ball and rod. Keep setting tools latched. 14. Test tubing to 3,000 psi for 30 min and chart. Q . 15. Pull RHCP ball and rod. RD Slickline. 't K {�l' 10-IL—a- 0- 16. Lay down landing join . e BPV. ND BOPS. NU tree. Pull BPV. 17. Set TWC.Test hanger to 250/5,000 psi.Test tree to 250/5,000 psi. Pull TWC. 18. RD Moncla#401 WO Rig. 19. Turn well over to production in preparation of moving off the Moncla#401 WO Rig. 20. Replace IA x OA pressure gauge if removed (5-1/2"x 9-5/8"). Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic Beaver Creek #25 ACTUAL Pad 3 SCHEMATIC 1246' FNL, 1,656' FWL, Sec. 34, T7N, R10W, S.M. Permit#: 214-132 llil�ucp Alaska, LLC API#: 50-133-20644-00 Prop.Des: FED A-028083 J l KB elevation: 179.2' (18.6'AGL) Conductor Lat: N60° 39' 29.694" 16" X-56 109 ppf Lona: W151° 1' 2.615" Top, Bottom Spud: 10/19/2014 21:30 hrs MD 0' 78' TD: 11/02/2014 15:30 hrs TVD 0' 78' Riq Released: 11/07/2014 18:00 hrs Surface Casing Production Casing 9-5/8" L-80 40 ppf BTC 5-1/2" P-110 17 ppf GeoConn Top Bottom Top Bottom . 1 MD 0' 3,488' MD 0' 8,196' Ail TVD 0' 3,270' TVD 0' 5,264' 12-1/4"hole Lead Cmt wl 570 sks(250 bbls)of 12.0 ppg,Class G, Tail Cmt wl 221 sks(48 bbls) 8-112"hole Cmt w/1,157sks(283 bbls)of 15.3 ppg, of 15.4 ppg,Class G, cement to surface Class G cmt WI EASYBLOK TOC(CBL 11/14/14)-3,472' Tree cxn=9-1/2"Otis Casing/Cementing Detail dile 0.5 Mud Push(45 bbl 8.0"Seal Diameter 9.9 ppg Mud 5-1/8"Modified ID Bore - 15.3 ppg Cement(283 bbl)) a' - 8.5 ppg 3%KCI(190 bbl) /{ Tag(unset cement)@ 8,090'CTM w/2.0"Jet Nozzle(11/16/14) Casing Shoe @ 8,196' ' II Fill .11 11 :• . II 11.il .11 llr• .IL_ II Ci 11 Ile-i 11. 11 :. . _ 1 .• ' , - -11-IMII •H ,-111612=11 •11E111H 11 II II RA# RA#4 'S .11 II If 11 tall 11-� 1 I�" PBTD: TD: Perforations(Sterling B4): Short RA Marker Joints 8,105'MD 8,208'MD Zone MD TVD Size SPF Date Status 5,264'TVD 5,264'TVD Sterling B4 8,045-8,055' 5,264'-5,264' 3-1/8" 6 11/19/14 Open #1 @ 6,183'-6,193'MD Sterling B4 7,990'-8,000' 5,264'-5,264' 3-1/8" 6 11/19/14 Open #2 @ 6,450'-6,460'MD Directional Data Sterling B4 7,890'-7,900' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #3 @ 6,680'-6,695'MD KOP:659' Sterling B4 7,790'-7,800' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #4 @ 6,914'-6,924'MD Hole angle at 9-5/8"shoe=25 deg Sterling B4 7,690'-7,700' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #5 @ 7,186'-7,201'MD Sterling B4 7,590'-7,600' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #6 @ 7,460'-7,470'MD Max.Doglegs: Sterling 84 7,490'-7,500' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #7 @ 7,686'-7,701'MD 3,965'- 6.9 deg/100 ft Sterling B4 7,390'-7,400' 5,264'-5,264' 3-1/8" 6 11/20/14 Open 5,266'- 7.0 deg/100 ft Sterling B4 7,290'-7,300' 5,264'-5,264' 3-1/8" 6 11/20/14 Open 6,999'- 6.5 deg/100 ft Sterling B4 7,190'-7,200' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Sterling B4 7,090'-7,100' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Sterling B4 6,990'-7,000' 5,265-5,265' 3-1/8" 6 11/21/14 Open Jewelry Depth Sterling B4 6,890'-6,900' 5,265-5,265' 3-1/8" 6 11/21/14 Open 1.Swell Packer(21'Long) 2,936' Sterling B4 6,790'-6,800' 5,265-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,690'-6,700' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling B4 6,590'-6,600' 5,262'-5,262' 3-1/8" 6 11/21/14 Open Sterling B4 6,490'-6,500' 5,260'-5,260' 3-1/8" 6 11/21/14 Open Sterling B4 6,390'-6,400' 5,260'-5,260' 3-1/8" 6 11/22/14 Open Sterling B4 6,290'-6,300' 5,260'-5,260' 3-1/8" 6 11/22/14 Open Sterling 64 6,190'-6,200' 5,260'-5,260' 3-1/8" 6 11/22/14 Open Sterling B4 6,090'-6,100' 5,256'-5,256' 3-1/8" 6 11/22/14 Open Well Name&Number: Beaver Creek#25 Lease:_ A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle©KOP and Depth: 0.5°@ 659' Angle/Perfs: 90° Maximum Deviation: 90.6°@ 6,999' Date Completed:- 11/22/2014 Ground Level(above MSL): 160.6' - RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 11/22/2014 Schematic Revision Date: 12/1/2014 ‘ . 13 Beaver Creek #25 PROPOSED Pad 3 SCHEMATIC 1246' FNL, 1,656' FWL, Sec. 34, Permit#: 214-132 T7N, R10W, S.M. API#: 50-133-20644-00 llileorp Alaska,LLC Prop.Des: FED A-028083 1 J KB elevation: 179.2' (18.6'AGL)....... ... . Conductor Lat: N60° 39' 29.694" .1 ____L 16" X-56 109 ppf Lona: W151° 1' 2.615" T� Bottom Spud: 10/19/2014 21:30 hrs MD 0' 78' TD: 11/02/2014 15:30 hrs TVD 0' 78' Riq Released: 11/07/2014 18:00 hrs • Surface Casino Production Casing ., 9-5/8" L-80 40 ppf BTC 5-1/2" P-110 17 ppf GeoConn Top Bottom Top Bottom MD 0' 3,488' MD 0' 8,196' 3 TVD 0' 3,270' ND 0' 5,264' 411 12-1/4"hole Lead Cmt w/570 sks(250 bbls)of 12.0 ppg,Class G, Tail Cmt w/221 sks(48 bbls) 8-1/2"hole Cmt w/1,157sks(283 bbls)of 15.3 ppg, of 15.4 ppg,Class G, cement to surface Class G cmt w/EASYBLOK -,, .. :\ TOC(CBL 11/14/14)-3,472' - 9.9 ppg Mud Casing/Cementing Detail T2 2-7/8" L-80 6.5 ppf EUE - 10.5 ppg Mud Push(45 bbl) Top Bottom r, r Tree cxn=9-1/2"Otis 8.0"Seal Diameter - 15.3 ppg Cement(283 bbl) MD 0' 6,000' - 8.5 ppg 3%KCI(190 bbl) ND 0' 5,244' # 5-1/8"Modified ID Bore 9 i' , Casing Shoe @ 8,196' ' .31/111 .II i :• -1I"'II.Fi11 II 11E3LIL Il iii 'II 11F-• 11: 11F-311.--11..11F311: - `* 'al' ' 11''II II '11 - II 11''H .H HUH! II P-11 Ilmu If 11 t I " If RA#1 RA#2 RA#3 RA#4 RA#5 RA#6 / R RA#8 Tag(unset cement)@ 8,090'CTM PBTD. TD: Perforations(Sterling B4): w/2.0"Jet Nozzle(11/16/14) 8,105'MD 8,208'MD Zone MD TVD Size SPF Date Status5,264'TVD 5,264'TVD Sterling B4 8,045'-8,055' 5,264'-5,264' 3-1/8" 6 11/19/14 Open Short RA Marker Joints Sterling B4 7,990'-8,000' 5,264'-5,264' 3-1/8" 6 11/19/14 Open Directional Data Sterling B4 7,890'-7,900' 5,264'-5,264' 3-1/8" 6 11/20/14 Open KOP:659' SterlingB4 7,790'-7,800' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #1 @ 6,183'-6,193'MD #2 @ 6,450'-6,460'MD Hole angle at 9-5/8"shoe=25 deg Sterling B4 7,690'-7,700' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #3 @ 6,680'6,695'MD Sterling 84 7,590'-7,600' 5,264'-5,264' 3-1/8" 6 11/20/14 Open Max.Doglegs: Sterling 84 7,490'-7,500' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #4 @ 6,914'6,924'MD 3,965'- 6.9 de /100 ft SterlingB4 7,390'-7,400' 5,264'-5,264' 3-1/8" 6 11/20/14 Open #5 @ 7,186'-7,201'MD deg p #6 @ 7,460'-7,470'MD 5,266'- 7.0 deg/100 ft Sterling 84 7,290'-7,300' 5,264'-5,264' 3-1/8" 6 11/20/14 Open 6,999'- 6.5 deg/100 ft Sterling B4 7,190'-7,200' 5,264'-5,264' 3-1/8" 6 11/21/14 Open #7 @ 7,686'-7,701'MD Sterling 84 7,090'-7,100' 5,264'-5,264' 3-1/8" 6 11/21/14 Open Sterling 84 6,990'-7,000' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Jewelry Depth Sterling 84 6,890'-6,900' 5,265'-5,265' 3-1/8" 6 11/21/14 Open Sterling 84 6,790'-6,800' 5,265'-5,265' 3-1/8" 6 11/21/14 Open .. ,Ang Hanger Sterling 84 6,690'-6,700' 5,265'-5,265' 3-1/8" 6 11/21/14 Open 2.Gaslift Mandrel(w/Reverse Lift Valve) 2,000' Sterling B4 6,590'-6,600' 5,262'-5,262' 3-1/8" 6 11/21/14 Open 3.Swell Packer(21'Long) 2,936' Sterling 84 6,490'-6,500' 5,260'-5,260' 3-1/8" 6 11/21/14 Open 4.Gaslift Mandrel(w/Reverse Lift Valve) 0' Sterling B4 6,390'-6,400' 5,260'-5,260' 3-1/8" 6 11/22/14 Open 5.Gaslift Mandrel(w/Reverse Lift Valve) Sterling 84 6,290'-6,300' 5,260'-5,260' 3-1/8" 6 11/22/14 Open 6.X-Profile(2.313"ID) 5'600' t a---' Sterling 64 6,190'-6,200' 5,260'-5,260' 3-1/8" 6 11/22/14 Open 7.WLEG 0' t).r` Sterling B4 6,090'-6,100' 5,256'-5,256' 3-1/8" 6 11/22/14 Open Well Name&Number: Beaver Creek#25 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle©KOP and Depth: 0.5°@ 659' Angle/Perfs:1 90° Maximum Deviation: 90.6°@ 6,999' Date Completed: 11/22/2014 Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 12/1/2014 Beaver Creek ' 1 I 2014 Moncla Rig 401 Hiko?Maar.11.11A: Oil Tools BOP v ' fo III III iii III fit Int itt 2.57' / Shaffer 71/16 5000 III III III III I III 111 III I11 I!I ii401 _ 2 3/8 3'/:variable CAMERON3.68' ' l i I� - nd , . 1 7 1/16 5000 ' Blind ��— H III 71,11111III 2 1/16 10M Kill Valves 2 1/16 10M Choke Valves Manual and HCR Manual and HCR `1 III III III I' ' i , i €- 1.56' 1 I v�j,j� i II I; 7 1/16 5000 `' „ RV* *� III lir ItI lime' ' • Schwartz, Guy L (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Thursday, December 04, 2014 9:16 PM To: Schwartz, Guy L(DOA); Paul Chan Cc: Clint Chanley Subject: q!RE: BCU 25 Velocity string ( PTD 214-132) Attachments: BC 25 Current wellhead drawing.docx; BC 25 Proposed wellhead drawing.docx Guy, Attached is an updated current and proposed drawing for the BCU-25 velocity string install. The gaslift will tie into the opposite side of the tree as opposed to a conventional hookup would have a tie-in at the tubing head outlet. We do not run a separate SSV for the gaslift portion. The opposite wing valve on the tree would be closed while operating the gaslift system. Stan Porhola From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Thursday, December 04, 2014 2:18 PM To: Paul Chan Cc: Stan Porhola; Clint Chantey Subject: RE: BCU 25 Velocity string ( PTD 214-132) Paul, Still need Safety valve layout... Assume SSV on production out the tubing spool valve ? will there be anything on the gaslift side? If gas lift line is leaking on surface there would be leak path for that also. So two SSV's will be needed. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793-1226) or(Guy.schwartz@alaska.gov). From: Paul Chan [mailto:pchan@hilcorp.com] Sent:Thursday, December 04, 2014 10:31 AM To: Schwartz, Guy L(DOA) Cc: Stan Porhola; Clint Chantey Subject: RE: BCU 25 Velocity string ( PTD 214-132) Guy Attached are the current and proposed wellhead drawings for the BC-25 work. The new tubing spool will land out on the 5-1/2" casing hanger neck seals. After NU the tubing spool,the hanger neck seals and the lower flange connection will be tested through the port. Let me know if you need anything else. Thanks Paul Chan Senior Operations Engineer Kenai Asset Hilcorp Alaska LLC (907) 777—8333 (w) (907)444—2881 (c) (907) 345—3161 (h) From: Schwartz, Guy L(DOA) [mailto:guv.schwartz@alaska.gov] Sent: Wednesday, December 03, 2014 3:02 PM To: Stan Porhola Cc: Paul Chan Subject: BCU 25 Velocity string ( PTD 214-132) Stan, Please supply a proposed wellhead diagram showing the new wellhead configuration (with additional tubing head). Be sure to include position of SVS systems. Can you also elaborate on how you will test the lower flange break (of new tubing head) in step 4? This might just be a case of using two way check(TWC)vs BPV in lower tubing head. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). 2 Beaver Creek Field 11 BC #25 Current 12/04/2014 11.1co.p X1.4.1.4 1.1.1. Beaver Creek Tubing hanger,SMB-22 BC#25 ported,11 X 5 1/2-17# 16 x 9 5/8 x 51/2 DWC/C csg btm x5.875-4 stub acme LH box top,5" type H BPV prep, 17-4PH material Tree cap,Otis,5 1/8 10M FE X 9 Y2 Otis Quick Union 0 MI 4 IlrIV .. 11 �4) esti Valve,Swab,WKM-M, Cj 4 �4 t&� a�a� �ok 5 1/8 10M FE,HWO, 4 �e. �S��, 0a`�J Qe� DD trim C?1. Je, h� z�� J `fie Sao a 0, .QC) e� 0a .� I 1 1 Q•1 �► a e QQ ■ 1 s i ,O �a O 'ri Ti Valve,Upper Master, .7 C) WKM-M,5 1/8 10M FE, D HWO,DD trim � 4'I O G. 1h.,; . . •,i1 ........... 111PiAli.'411 Valve,Master,CIW-FC, 'O 10 5 1/8 10M FE,HWO, DV. rt EE trim QQ L, Is.,••, 1••1a Adapter,Seaboard-EN, 11 5M stdd x 5 1/8 10M top, ' w/7"PP bottom 1101111M ,rn-,. cac Ell1 =i �� iEms"��_ Tubing head,Seaboard-S8, IP] II i IP 16 3/4 3M X 11 5M, -F, 11. i 2 (-- w/2-2 1/16 5M SSO, 4 - C�. �' i I•.' 9 5/8 P seal bottom = `•— A n ha kiurrent Wellhead Setup (except for tree) 5-1/8 10M 11.9 7 DBL D SEALS yr o EST 11 5M BO It= CASING HANGER, I- --- II SMB-22 PORTED, —_ 11 X 5-1/2 s, W/PRIMARY SEAL C. - O 26.4 „______\___ 26.4 I 1 ® 11.I is EST ,_1-- c a° Uj� rillp 59.9 9-5/8 DBL D SEALS , O EST I 7 I -- f R I I anvil 2-1/16 5M EIVD t'�,l I nN:iG l c��l' fj, +W i�0 Ili_16-3/4 3M r L,..i 9 RRR CASING HANGER, `� II 1 r! SMB-22 SPEC,------ I , 16-3/4 X 9-5/8 !� _ �� l 21.6 W/PRIMARY SEAL EST I Motet• 1 . K) .jerj, ( 111/4107 k SIJ ,_____. 2-1/16 5M 16 CASING — ,---_ 9-5/8 CASING 5-1/2 CASING ---1--.P MIN OIL&GAS 10,000 PSI WELLHEAD ASSEMBLY NOTE: 16 X 9-5/8 X 5-1/2 DIMENSIONS SHOWN ON THIS DRAWING ARE ESTIMATES ONLY AND CAN VARY SIGNIFICANTLY RESTRICTED CONFIDENTIAL DOCUMENT DEPENDING ON RAW MATERIAL LENGTHS. rr" LAP '�` 1:7 '/26/2014 �/ NO GUARANTEE OF STAMP HEIGHT IS IMPLIED. ms ORATING MO maw.HEREON.m DAME ON A CO of MAL SAN&Y 1f INC MO we SUMMIED ON S �- DIMENSIONS SHOWN SHOULD BE CONSIDERED 1NOTNA m NNCLOSU DIE NGMK m NOUNS R uooi REQUEST.AND „N° `OI M N110 NM MOUT PRIM sINT1EN P—18509 FOR REFERENCE PURPOSES ONLY. !E mN nu Ne. "m"�""� VOWS Beaver Creek Field BC #25 Proposed 12/04/2014 11bh-09. ‘lawka.h A. Beaver Creek BC#25 16x95/8x5Y2x27/8 Tree cap,Otis, 2 9/16 5M FE X 6 Y2 Otis Quick Union r O , iiAALLiri ammommil Valve,Swab, WKM-M, 2 9/16 5M FE,HWO, " ,o 'i' . il U DD trim o( o O' Valve, Wing,WKM M, v� 2 1/16 5M FE, HWO, Valve,SSV, Barber, 3 1/8 5M Valve,Wing, WKM-M, undkrDD trim FE, w/Barber Hydraulic self 2 1/16 5M FE, HWO, contained operator DD trim : : t� : : € : K.fi• Gas Li tie in il 1 s ( (o I - -- i® �) is �* e o `'� ; . _)_. uni 11 1 Valve, Master, WKM-M, l-( ---\* 2 9/16 5M FE,HWO, _ 0• * DD trim aura WI 111JMEIMI Valve,Master,WKM-M, Production line O 2 9/16 5M FE, HWO, ik.(6-0 €0 DD trim P U U mI.i um me tl 0-1 L Tubing head, Sea board-S8, 7R wir• N / 115M X7 1/165M, 1 j ---T1 cCo; i l- /2 -2 1/16 5M SSO, 1 c O 7" P seal bottom ,iet — / Valve, WKM-M,2 1/16 5M U —1. - is. FE,HWO cam _ Casing spool, Sea board-S8, * i' - ;11 16 3/4 3M X 11 5M, IIIP €— w/2-2 1/16 5M SSO, 1 i 9 5/8 P seal bottom 1 4 11,: `ii:F °n 1 0 Proposed Wellhead/Tree (Addition of Tubing Spool) 19.8 Imo— EST ) i 2-9/16 5M rrlk21.3 ire4rilai ,,t EST 2-1/16 5M 41`x00 .n.- mile 1 `- I[41,41,1*°1� 10x1i J A' 1.40 ,..1.„ •Illini MINI. 2-1/16 5M all;01% 2-9/16 5M '•"• "•' 44.4 EST ..tow moat. r ry4 .I.� ADAPTER, TUBING HEAD •.,11,20... SM-E-2CLN 2-9/16 5M 7-1/16 SM X 2-9/16 SM 'al �-1 f 10.2.4..0 7-1/16 514 TUBING HANGER. SM-E-2CL MOM III Ji / 138.2 7-1/16 X 2-7/8 API MOD BOX BTM 'i1 1 _ i ISI ■■CO , ��`l��X 2-7/8 EU 8RD BOX TOP _ T.,�' ■■25.0 Y : Ea,i•1 EST O ` SECONDARY SEAL, 4-0 1.1 ■ MI 11 X 7 2-1/16 5M ' — -1 � � ' 11 5M CASING HANGER, SMB-22 PORTED ��I I �. 11 X 5-1/2 1�1� ii 2 - am 20# VAM DWC/C CSG BOX BTM X 5.875-4 STUB ACME-2G-LH ; ` , (Ali � 6 0 BOX TOP W/PRIMARY SEAL .: ■_ _■ 10•t. I .;•' IL. 9-5/8 DBL D SEALS Vili ' '�!�1111i. 1■1 2-1/16 5M �� 16-3/4 3M CASING HANGER, SMB-22 1„., g ri 16-3/4 x 9-5/8 21.6 W/PRIMARY SEAL EST - 7;4.1'4.t; 1-' 2-1/16 5M 16 CASING ir 9-5/8 CASING 5-1/2 CASING WEIN 2-7/8 CASING OIL&GAS 5,000 PSI WELLHEAD ASSEMBLY N01E 16 X 9-5/8 X 5-1/2 X 2-7/8 DIMENSIONS SHOWN ON THIS DRAWING ARE ESTIMATES ONLY AND CAN VARY SIGNIFICANTLY RESTRICTED CONFIDENTIAL DOCUMENT DEPENDING ON RAW MATERIAL LENGTHS. ,.,DRAMS r„.0 WORN/MON NI,,,HEREON..e n. " JS f°9` 1:12 "",/15/14 REV NO GUARANTEE OF STACKUP HEIGHT IS IMPLIED. cxI.KTM a x0•0Mn•.w•u.a'u•a A••late AMIG NO. DIMENSIONS SHOWN SHOULD BE CONSIDERED '� ��' ``100' �'..°...""rftror a,�"; .,t P-18244 1 FOR REFERENCE PURPOSES ONLY. WNW woe m.aro►.m.nnrt w.� 0,0 mars:wow....umuL.K .' .tea.. ®F ��. �.� ��.�� \� 0, '-\\\I/% �,,, THE STATE 1 e -,_;a �rc. '! ;i;� �:- _:r y. iE-1;-;,. -:- v ir\ -'-i -_\ / \ \. I , / \ - - - -. _ #3 I ' - - 333 ��esi Scvenl ; Avenue '%' t K, GC)\'Ll: 'oR cl, Ij:',R:'} l I- AncI urage, Alaska 99501-3572 =, r �. y .��uyuvr F Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Sterling Gas Pool, BCU 25 Sundry Number: 314-599 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, C-1 Daniel T. Seamount, Jr. Commissioner DATED this )2 day of November, 2014. Encl. • STATE OF ALASKA '' ' ) - _ ", ALASKA OIL AND GAS CONSERVATION COMMISSION QSM fly APPLICATION FOR SUNDRY APPROVALS ,t.r-�,f -.(`�',z N 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑✓ • Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other. Initial Completion 2 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number. • Exploratory ❑ Development ❑✓ 214-132 . 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20644-00 ' 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 237A Beaver Creek(BCU)25 - Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): A028083 Beaver Creek/Sterling Gas Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 8,208 5,264 8,105' 5,264' N/A N/A Casing Length Size MD TVD Burst Collapse Structural ' Conductor - 78' 16" 78' 78' Surface 3,488' 9-5/8" 3,488' 3,270' 5,750 psi 3,090 psi Intermediate • Production 8,196' 5-1/2" 8,196' 5,264' 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(It): N/A N/A N/A N/A N/A Packers and SSSV Type. Packers and SSSV MD(t)and ND(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development n . Service n 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 11/17/14 Oil ❑ Gas 0 - WDSPL ❑ Suspended 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative. GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email soorhola( hilcorD.cor>1 Printed Name -///Stan Porhola Title Operations Engineer Signature i�YGv Ari_____ Phone 907-777-8412 Date t( 0i/i JJJ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. \L ^- Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ "1\ Other: / 0 Spacing Exception Required? Yes ❑ No lU Subsequent Form Required: f+.__U C 7 , ""-t ( 1,K \ ?)11---C‘/7APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: /1 112.1 11- Form 10-403( evised 10/2012) /� A©o 6R tGl0PI#tIr RB ftMrSm Nell yf�pr;Q r r Attachments n Duplicate wJL�.'YY�1�V7 lYU Y 1 c7 LLLUUU1ffWWW�� 41r ;/./0.// Well Prognosis Well: BCU-25 Hilcorp Alaska,LL Date: 11/07/2014 Well Name: BCU-25 API Number: 50-133-20639-00 Current Status: New Grassroots Gas Well Leg: N/A Estimated Start Date: November 17th, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: _ 214-132 First Call Engineer: Stan Porhola (907) 777-8412 (0) _ (907) 331-8228(M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: 1412521C Current Bottom Hole Pressure: — 0 psi @ 5,264' TVD (No open perforations) Maximum Expected BHP: —2,100 psi @ 5,264' TVD (Based on offset wells BCU-09) Max. Allowable Surface Pressure: — 1,574 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#25 was drilled as a Grass roots horizontal monobore completion in 2014 to target the ' Sterling B4. The purpose of this work/sundry is to perforate the well for the initial completion in the Sterling B4. Notes Regarding Wellbore Condition • Will run Cement Bond Log before perforating. • MIRU Coil Tubing and perform BOPE Test to 250/4,500 psi to displace well over to Nitrogen. • Well will be displaced with Nitrogen before initial perforating at+/- 1,500 psi SITP. • Pressure test IA(5-1/2"x9-5/8")to 2,500 psi before perforating. E-line Procedure: 1. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 1,500 psi (Nitrogen pressure). 2. RU 3-1/8" 6 spf Connex HC wireline guns. 3. RIH and perforate the following intervals utilizing wellbore tractor: Zone Sands Top (MD) Btm (MD) FT SPF Sterling Sterling B4 8,090' 8,100' 10' 6 Sterling Sterling B4 7,990' 8,000' 10' 6 Sterling Sterling B4 7,890' 7,900' 10' 6 Sterling Sterling B4 7,790' 7,800' 10' 6 Sterling Sterling B4 7,690' 7,700' 10' 6 Sterling Sterling B4 7,590' 7,600' 10' 6 Sterling Sterling B4 7,490' 7,500' 10' 6 Sterling Sterling B4 7,390' 7,400' 10' 6 Sterling Sterling B4 7,290' 7,300' 10' 6 Sterling Sterling B4 7,190' 7,200' 10' 6 14 . • -: Well Prognosis Well: BCU-25 Hilcorp Alaska,LL Date:11/07/2014 Sterling Sterling B4 7,090' 7,100' 10' 6 Sterling Sterling B4 6,990' 7,000' 10' 6 Sterling Sterling B4 6,890' 6,900' 10' 6 Sterling Sterling B4 6,790' 6,800' 10' 6 Sterling Sterling B4 6,690' 6,700' 10' 6 Sterling Sterling B4 6,590' 6,600' 10' 6 Sterling Sterling B4 6,490' 6,500' 10' 6 Sterling Sterling B4 6,390' 6,400' 10' 6 Sterling Sterling B4 6,290' 6,300' 10' 6 Sterling Sterling B4 6,190' 6,200' 10' 6 Sterling Sterling B4 6,090' 6,100' 10' 6 a. Bleed tubing pressure to 1,500 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using Cement Bond Log(pending Tie-in log). e. Use Gamma/CCL/to correlate.. f. Record tubing pressures before and after each perforating run. g. Proposed intervals are in the Sterling Gas Pool. h. Distance to nearest well open in same sands= 1,400'to BCU-09. i. Spacing allowance is based on CO 237A(No spacing limits). / 4. RD E-line. 5. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic .... • iiiBeaver Creek #25 ACTUAL Pad 3 SCHEMATIC 1246' FNL, 1,656' FWL, Sec. 34, T7N, R10W, S.M. Permit#: 214-132 Hiicorp Alaska, LLC API#: 50-133-20644-00 Prop.Des: FED A-028083 J l KB elevation: 179.2' (18.6'AGL) Conductor Lat: N60° 39' 29.694" 16" X-56 109 ppf Lonq: W151° 1' 2.615" Top Bottom Spud: 10/19/2014 21:30 hrs MD 0' 78' • TD: 11/02/2014 15:30 hrs TVD 0' 78' Rip Released: 11/07/2014 18:00 hrs Surface Casing Production Casing 9-5/8" L-80 40 ppf BTC 5-1/2" P-110 17 ppf GeoConn Top Bottom Top Bottom 1 MD 0' 3,488' MD 0' 8,196' ND 0' 3,270' TVD 0' 5,264' 12-1/4"hole Lead Cmt w/570 sks(250 bbls)of 12.0 ppg,Class G, Tail Cmt w/221 sks(48 bbls) 8-1/2"hole Cmt w/1,157sks(283 bbls)of 15.3 ppg, ti.�' of 15.4 ppg, Class G, cement to surface Class G cmt w/EASYBLOK TOC(EST)-3,000' Tree cxn=9-1/2"Otis Casing/Cementing Detail ;w 8.0"Seal Diameter - 9.9 ppg Mud 5-1/8"Modified ID Bore - 10.5 ppg Mud Push(45 bbl) - 15.3 ppg Cement(283 bbl) - 8.5 ppg 3%KCI(190 bbl) ' Tag(unset cement)@ unknown depth Casing Shoe @ 8,196' • X .. . X X X : - W . X ,. X1\_. . X . , X (X X X . W ( Qc RA#1 RA#2 RA#3 RA#4 RA#5 RA#6 RA#7 RA#8 PBTD: TD: Perforations(Sterling B4): Short RA Marker Joints 8,105'MD 8,208'MD Zone MD TVD Size SPF Date Status 5,264'ND 5,264'ND #1 @ 6,183'-6,193'MD #2 @ 6,450'-6,460'MD Directional Data #3 @ 6,680'-6,695'MD KOP:659' #4 @ 6,914'-6,924'MD Hole angle at 9-5/8"shoe=25 deg #5 @ 7,186'-7,201'MD #6 @ 7,460'-7,470'MD Max.Doglegs: #7 @ 7,686'-7,701'MD 3,965'- 6.9 deg/100 ft 5,266'- 7.0 deg/100 ft 6,999'- 6.5 deg/100 ft Jewelry Depth 1.Swell Packer(21'Long) 2,936' Well Name&Number: Beaver Creek#25 Lease: A-028083 County or Parish. Kenai Peninsula Borough _ State/Prov: Alaska Country: USA Angle @KOP and Depth 0.5°@ 659' Angle/Perfs: 90° Maximum Deviation:- 90.6°@ 6,999' •Date Completed: 11/6/2014 Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 11/6/2014 Schematic Revision Date: 11/7/2014 • Beaver Creek #25 in PROPOSED Pad 3 SCHEMATIC 1246' FNL, 1,656' FWL, Sec. 34, T7N, R10W, S.M. Permit#: 214-132 API#: 50-133-20644-00 Ililrorp Alaska,LLC Prop.Des: FED A-028083 J l KB elevation: 179.2' (18.6'AGL) Conductor Lat: N60° 39' 29.694" 16" X-56 109 ppf Long: W151° 1' 2.615" Top Bottom Spud: 10/19/2014 21:30 hrs MD 0' 78' TD: 11/02/2014 15:30 hrs TVD 0' 78' Rig Released: 11/07/2014 18:00 hrs Surface Casing Production Casing 9-5/8" L-80 40 ppf BTC 5-1/2" P-110 17 ppf GeoConn Tom Bottom Top Bottom 1 MD 0' 3,488' MD 0' 8,196' TVD 0' 3,270' ND 0' 5,264' 12-1/4"hole Lead Cmt w/570 sks(250 bbls)of , r12,0 ppg,Class G, Tail Cmt w/221 sks(48 bbls) 8-1/2"hole Cmt w/1,157sks(283 bbls)of 15.3 ppg, of 15.4 ppg,Class G, cement to surface Class G cmt wl EASYBLOK • f,` TOC(EST)-3,000' Tree cxn=9-1/2"Otis Casing/Cementing Detail 8.0"Seal Diameter - 9.9 ppg Mud 5-1/8"Modified ID Bore - 10.5 ppg Mud Push(45 bbl) - 15.3 ppg Cement(283 bbl) - 8.5 ppg 3%KCI(190 bbl) Casing Shoe @ 8,196' tla1Eiie I •• •• • RA#1 RA#2 RA#3 RA#4 RA#5 RA#6 RA#7 RA#8 PBTD: TD: Perforations(Sterling B4): Short RA Marker Joints 8,105'MD 8,208'MD Zone MD ND Size SPF Date Status 5,264'ND 5,264'ND Sterling B4 8,090'-8,100' 5,264'-5,264' 3-1/8" 6 Proposed #1 @ 6,183'-6,193'MD Sterling B4 7,990'-8,000' 5,264'-5,264' 3-1/8" 6 Proposed #2 @ 6,450'-6,460'MD Directional Data Sterling B4 7,890'-7,900' 5,264'-5,264' 3-1/8" 6 Proposed #3 @ 6,680'-6,695'MD KOP:659' Sterling B4 7,790'-7,800' 5,264'-5,264' 3-1/8" 6 Proposed #4 @ 6,914-6,924'MD Hole angle at 9-5/8"shoe=25 deg Sterling B4 7,690'-7,700' 5,264'-5,264' 3-1/8" 6 Proposed #5 @ 7,186'-7,201'MD Sterling B4 7,590'-7,600' 5,264'-5,264' 3-1/8" 6 Proposed #6 @ 7,460'-7,470'MD Max.Doglegs: Sterling 84 7,490'-7,500' 5,264'-5,264' 3-1/8" 6 Proposed #7 @ 7,686'-7,701'MD 3,965'- 6.9 deg/100 ft Sterling B4 7,390'-7,400' 5,264'-5,264' 3-1/8" 6 Proposed 5,266'- 7.0 deg/100 ft Sterling B4 7,290'-7,300' 5,264'-5,264' 3-1/8" 6 Proposed 6,999'- 6.5 deg/100 ft Sterling 84 7,190'-7,200' 5,264'-5,264' 3-1/8" 6 Proposed Sterling B4 7,090'-7,100' 5,264'-5,264' 3-1/8" 6 Proposed Sterling B4 6,990'-7,000' 5,265'-5,265' 3-1/8" 6 Proposed Jewelry Depth Sterling 84 6,890'-6,900' 5,265'-5,265' 3-1/8" 6 Proposed 1.Swell Packer(21'Long) 2,936' Sterling 84 6,790'-6,800' 5,265'-5,265' 3-1/8" 6 Proposed Sterling 84 6,690'-6,700' 5,265'-5,265' 3-1/8" 6 Proposed Sterling 64 6,590'-6,600' 5,262'-5,262' 3-1/8" 6 Proposed Sterling B4 6,490'-6,500' 5,260'-5,260' 3-1/8" 6 Proposed Sterling B4 6,390'-6,400' 5,260'-5,260' 3-1/8" 6 Proposed Sterling 84 6,290'-6,300' 5,260'-5,260' 3-1/8" 6 Proposed Sterling B4 6,190'-6,200' 5,260'-5,260' 3-1/8" 6 Proposed Sterling 84 6,090'-6,100' 5,256'-5,256' 3-1/8" 6 Proposed Well Name&Number: Beaver Creek#25 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth: 0.5°@ 659' Angle/Perfs: 90° Maximum Deviation:- 90.6°@ 6,999' Date Completed: 11/6/2014 Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 11/7/2014 ��\ ��j�s, THE S`A r E l'..:. c j<`�.. C�' c'..li: C 1 EMT i4.1--;:--±-SSS " (; )� i'1<:�(;1� Si ;\:\ rAti\t.i.L hnchologe Ala Kc'SS5O, 5/2 ,) Monty Mack Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 999503 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek 25 Hilcorp Alaska, LLC Permit No: 214-132 (revised) Surface Location: 1246' FNL, 1656' FWL, SEC. 34, T7N, R1 OW, SM, AK Bottomhole Location: 1858' FSL, 2535' FWL, SEC. 34, T7N, R1 OW, SM, AK Dear Mr. Myers: Enclosed is the approved application for permit to drill the above referenced development well. This permit supersedes and replaces the permit previously issued for this well dated September 11, 2014. l' This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, / / /0)2,2,,,,4„__ Cathy P oerster Chair -- DATED this Zrrday of October, 2014. RECEIVED STATE OF ALASKA i .CA OIL AND GAS CONSERVATION COMN, )N OCT 10 2014 PERMIT TO DRILL - REVISED AOGCC 20 AAC 25.005 1a.Type of Work: 1b.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone a • 1c.Specify if well is proposed for: Drill Q• Lateral ❑ Stratigraphic Test ❑ Development-Gas❑✓ . Service-Supply ❑ Multiple Zone 0 Coalbed Gas ❑ Gas Hydrates ❑ Redril 0 Reentry❑ Exploratory ❑ Service- WAG 0 Service-Disp ❑ Geothermal ❑ Shale Gas 0 2.Operator Name: 5. Bond: Blanket O Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244 • Beaver Creek 25• 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage AK 99503 MD: 8,667' • TVD: 5,268' • Beaver Creek Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Beluga Gas Surface: 1246'FNL, 1656'FWL,Sec 34,T7N,R1OW,SM,AK A028083 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 217'FNL, 1616'FWL,Sec 34,T7N,R1OW,SM,AK NA 11/15/2014 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1858'FSL,2535'FWL,Sec 34,T7N,R1OW,SM,AK 1920 acres(A028083) 1600' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: .179.2 feet 15.Distance to Nearest Well Open Surface: x-317473.83 y-2433936.29 Zone-4 GL Elevation above MSL: •160.6 feet to Same Pool: EE�� 915'BCU-19 16.Deviated wells: ,t°pt axirrfiumlHole Angle: %, degrees Downhole:um 2 00 psi Surface: Pressures in Surface:sig 20 17AAC 25.035) i 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Gond 16" 109 X-56 Weld 80' Surface Surface 80' 80' Driven 12-1/4" 9-5/8" 40 L-80 BTC 3,500' Surface Surface 3,500' . 3,497' 305.3bbl/1713.9ft3 8-1/2" 5-1/2" 17-P-110 DWC/C HT 8,667' Surface Surface 8,667' 5,268' 284bb1/1594.5ft3 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): I Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat Q BOP Sketch ❑✓ Drilling Program Q Time v.Depth Plot Q Shallow Hazard Analysis Diverter Sketch Q Seabed Report 0 Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Monty Mack Myers Email mmyers(c�hilcorp.com Printed Name Monty Mack Myers Title Drilling Engineer Signature Phone (907)777-8431 Date 8/25/2014 Commission Use Only Permit to Drill API Numbe. .� �,\ , Permit Approval See cover letter for other Number: 2,V -k?jt QQvi 50- /33-L. ;- / -CC)-Date: 0(-\ -tet4 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: 12/ Other: V 3 cC,C S L 86 n X /e S. L-- Samples req'd: Yes❑ No[✓7 Mud log req'd:Yes❑ No Er I / H2S measures: Yes❑ No[Y. Directional svy req'd:Yes Er No❑ { _ / Spacing exception req'd: Yes 0 No Er Inclination-only svy req'd:Yes❑ No sr Approved by: N-iettiAPPROVED BY 9 3.1,1.44L4----- COMMISSIONER THE COMMISSION Date:/f/ — /C•�c•.,/4i w�� /rim' Submit Form and Form 10-401(Revised 10/2012) oRieGIN 9 months from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate Monty Myers Hilcorp Alaska, LLC 14 Drilling Engineer P.O. Box 244027 Anchorage,AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com Hilcorp Alaska,LLC October 10, 2014 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Beaver Creek (BCU) 25 revised PTD Dear Commissioner, I am requesting permission to modify the previously approved permit to drill for Beaver Creek #25. After drilling the Beaver Creek 23 and Beaver Creek 24 it is necessary to modify the BHL for the placement of the Beaver Creek 25 lateral in the B4 sand. After logging the B4 sand in the previous 2 wells, it was necessary to replan the lateral to drill around the Beaver Creek 13 well for anti-collision issues and to accommodate the lateral length needed in the B4 sand. Only the directional portion of the well has changed,which has slightly increased the overall TMD of the well. Drilling operations are expected to commence approximately October 20th, 2014. The Saxon Rig# 169 will be used to drill the wellbore then run casing and cement. General sequence of operations: 1. MOB Saxon Rig# 169 to well site 2. N/U 21-1/4" x 2M diverter. 3. Drill 12-1/4" hole to 3500' MD. Run and cmt 9-5/8" surface casing. 4. N/D diverter, N/U &test 11" x 5M T3-Energy BOP. 5. Drill 8-1/2" hole section to 8667' MD. Perform Wiper trip. 6. POOH laying down drill pipe. 7. Run and cmt 5-1/2" production casing . 8. N/D BOP, N/U temp abandonment cap, RDMO. Hilcorp Alaska, LLC Page 1 of 2 Monty Myers Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage,AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com Hilrorp Alrake,LIT Reservoir Evaluation Plan: 1. Surface hole: GR + Res LWD. 2. Production Hole: GR + Res + Den/Neu LWD. 3. Mud loggers from surface casing point to TD. If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777- 8369. Sincerely, Monty Myers Drilling Engineer Hilcorp Alaska, LLC Page 2 of 2 Hilcorp Energy Company Beaver Creek Unit Beaver Creek Unit Beaver CK Unit 25 BCU-25 Plan: BCU-25 WP9 Standard Proposal Report 09 October, 2014 1 /,. 111 • • HALLIBURTON h Sperry Drilling Services v v a ,a a' 00R 0 `4 w Lo o N N N '° O !'L rn ct cc re y z = d �v= SC o) 0 0 0I 0 ~_0 L i ... 3 CO m CO N6� UUU N N N LO N "'W 00 L L L in It) N a, > j 7 'crr a) a) a)N N �NN0 L 1 (°)N I- 0 0 0 0 z Ul)�2 RS RS 03» OED N O NNS a) a) dUU o .- T,o000r0(OccA co.- 1 500'' CO CO CO CO CO yoo.-r-ovWWOCo < 0 COOOCA W O CJ lM 1n W < Omm E CO LOCO O I,-N��C) m �c�r��N 0 —ccE ,O ' N O 0 0)O N 0 C)0 CO 0 z 0 0- N 0 O 010010001000)O d >= Li 004 01000 C)O CA O W N N Qj'O C 0) I- V)10 N- O) co 0 0 0 0 0 ,y L D 1002N C)C) W d d d 0 J of 1W° 2 a00000000000 �aoi)d2 y �' (ON W W 00000000000 •1 V) ��o Q 000Ciolricovoao W m m�o ay � �0 m 0 w III _W o«) Sia5 0 O 000010 N CA 1,-01--CO ?� O > d Z 00 N-10'Cf 010 W Tt C)(00 _( 0N J _)000 W W00WC)0010�00M(n0 C pvU - 0 N. 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W OOa aOOO)tOOO O\ A 0 1 O - ��OrrrLnLnmm .a .d U P. _ � � N W _ 000))OI0aMM IOa 0 0 C/) I _ h c 6Oaoaoo 6666Lc 0) ,� 1 N o OOvvrOOrnrnrnLn L _0 N N CO p)O CO CO 00 CO 0 W 1 I.a 0 0_ ❑00 M N LA O).-O LOM0 0 / 0 _ OOemor VNI000fN 1 1 COW - a000raLOMONNMr 1 1 —a),...01,..o..-...-..-...03a .NJ a)0Vt0 t0 I I - o o 1 1 —o 0 NMRLO tOra00)o,_ I N V) v I ,-r + 1 4,1I �..--der - ' 0 3 qD 1 ' 1 M - t- I -' 0 - O 0 1 ; -v) .-j 00 -$ L "0 olgli ..t.0 = M W - ° 0 • do0 UUUv, o \ - . L s.. �un un �` § - G> d d1NN g M ] - M0 1 $ CO• GiG• �/yU/y��/yU/y�� .ON:243 o 'MG —o W COW COW W 03 O C- Q .MM0 - N aa O W - ♦" Mm + a o i- -g - f� m 00-O ❑❑ C O H a t N 4 G a 0... N c.„0416y H22 0L0=m Cnm IR -g 00Jt0 oZ 0,-,- Z za: O QoNN m J J 0 Uaa g NN 6-0 g . - oM— O 00a›- r 00 mm Oo 0 UUm 3 Z vcao m cq M Z =cCO - O 1— LuOm3�^AO to 0 Lr w gaaU _i M Z E O —M - CC 7 NN W W .E w U 8 CNWN Oy2 _ iY) (nmm 03 01 ca O- ma da IawQZM - o —$ - Y i n(O co N (=4LO .....z.14......z.14.0.2 - p - o imi CIE.. O cgy L 200 + -Nm U> U I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I Y II :- ca n 9 0 0 o O o Q' $ 0 0 I M +0o N N 0 (ui/13sn 0001)(+)LpJoN/(-)ipnos Project: Beaver Creek Unit HAL.LIBURTON Site: Beaver Creek Unit Well: Beaver CK Unit 25 Wellbore: BCU-25 Sperry Drilling {� Design: BCU-25 WP9 �"'�✓�L t�✓ - 2000 BCU 5 BCU3 �J BCU 5RD BCU 3RD 1750— BCU 18 BCU II 1500— _ 4000 1250— 45( 3500 - 1000— - 3000 00 Iso= 2500 Soo- 2000 BCU 10 2so- 1 - 1000 Imo;`` 500 - o 0 ▪ -250— \� t _ -500— BCU 6 cID - -750— BCU 23 -1000- -1250— BCU 13 -1500— BCU 19 BCU 9 -1750— -- BCU-24 Rig Surveys BCU-24 WP6.0 -2000— BCU 16- 5269 -2250— BCU-25 WP9 BCU 16RD -2500- 1I I I 1 I l I I 1 I l I I 1 l l l l 1 l l l l 1 l l l l 1 l -1000 -750 -500 -250 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 West(-)/East(+)(500 usft/in) Halliburton HALLIBURTIA Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 25 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 25 @ 178.50usft Project: Beaver Creek Unit MD Reference: Plan:BCU 25 @ 178.50usft • Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 25 Survey Calculation Method: Minimum Curvature Wellbore: BCU-25 1 Design: ecu-25 WPs99i9pIpI110i��gi0°°�1 Project Beaver Creek Unit Map System: US State Plane 1927(Exact solution) • System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Site Beaver Creek Unit Site Position: Northing: 2,430,086.36 usft Latitude: 60.6475877 From: Map Easting: 314,428.19 usft Longitude: -151.0340284 Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.90 ° Well Beaver CK Unit 25 Well Position +N/-S 0.00 usft Northing: 2,433,936.29 usft• Latitude: 60.6582484 +E/-W 0.00 usft Easting: 317,473.83 usft. Longitude: -151.0173929 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: • 160.50 usft Wellbore BCU-25 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 9/1/2014 16.95 73.63 55,444 Design BCU-25 WP9 Audit Notes: Version: Phase: PLAN Tie On Depth: 18.00 (11!1uol�� - , Vertical Section: Depth From(TVD) +N/-S 1 ' +E/-W Direction�i (usft) �u' (usft) �) ��' (usft) � y, ii {°) �) 18.00 0.00 0.00 157.98 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°1100usft) (°/100usft) (°/100usft) (°) 18.00 0.00 0.00 18.00 -160.50 0.00 0.00 0.00 0.00 0.00 0.00 618.00 0.00 350.00 618.00 439.50 0.00 0.00 0.00 0.00 0.00 350.00 1,447.23 24.88 354.59 1,421.42 1,242.92 176.42 -16.70 3.00 3.00 0.00 354.59 3,889.62 24.88 354.59 3,637.19 3,458.69 1,199.29 -113.50 0.00 0.00 0.00 0.00 6,125.79 87.00 170.43 5,261.50 5,083.00 241.29 100.45 5.00 2.78 7.86 175.52 6,213.49 90.51 170.43 5,263.41 5,084.91 154.85 115.02 4.00 4.00 0.00 0.01 6,698.21 90.51 170.43 5,259.11 5,080.61 -323.10 195.59 0.00 0.00 0.00 0.00 7,052.69 89.63 156.28 5,258.68 5,080.18 -661.86 296.87 4.00 -0.25 -3.99 -93.53 7,571.05 89.63 156.28 5,262.04 5,083.54 -1,136.42 505.40 0.00 0.00 0.00 0.00 7,673.93 89.66 160.39 5,262.67 5,084.17 -1,232.01 543.37 4.00 0.03 4.00 89.53 8,667.10 89.66 160.39 5,268.50 5,090.00 -2,167.58 876.63 0.00 0.00 0.00 0.00 10/9/2014 5:48:43PM Page 2 COMPASS 5000.1 Build 70 HAL L I B U R TO Halliburton t ^ Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 25 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 25 @ 178.50usft Project: Beaver Creek Unit MD Reference: Plan:BCU 25 @ 178.50usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 25 Survey Calculation Method: Minimum Curvature Wellbore: BCU-25 Design: BCU-25 WP9 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +Nl-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -160.50 18.00 0.00 0.00 18.00 -160.50 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 100.00 0.00 350.00 100.00 -78.50 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 200.00 0.00 350.00 200.00 21.50 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 300.00 0.00 350.00 300.00 121.50 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 400.00 0.00 350.00 400.00 221.50 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 500.00 0.00 350.00 500.00 321.50 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 600.00 0.00 350.00 600.00 421.50 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 618.00 0.00 350.00 618.00 439.50 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 Start Build 3.00 @ 618'MD,618'TVD-TFO 350 700.00 2.46 354.59 699.97 521.47 1.75 -0.17 2,433,938.04 317,473.69 3.00 -1.69 800.00 5.46 354.59 799.72 621.22 8.63 -0.82 2,433,944.93 317,473.15 3.00 -8.30 900.00 8.46 354.59 898.98 720.48 20.69 -1.96 2,433,957.01 317,472.19 3.00 -19.91 1,000.00 11.46 354.59 997.46 818.96 37.91 -3.59 2,433,974.25 317,470.83 3.00 -36.49 1,100.00 14.46 354.59 1,094.90 916.40 60.23 -5.70 2,433,996.60 317,469.06 3.00 -57.97 1,200.00 17.46 354.59 1,191.03 1,012.53 87.60 -8.29 2,434,024.01 317,466.90 3.00 -84.32 1,300.00 20.46 354.59 1,285.60 1,107.10 119.94 -11.35 2,434,056.40 317,464.34 3.00 -115.45 1,400.00 23.46 354.59 1,378.33 1,199.83 157.17 -14.87 2,434,093.67 317,461.39 3.00 -151.28 1,447.23 24.88 354.59 1,421.42 1,242.92 176.42 -16.70 2,434,112.95 317,459.87 3.00 -169.81 End Dir @ 1447'MD 1,500.00 24.88 354.59 1,469.29 1,290.79 198.52 -18.79 2,434,135.08 317,458.12 0.00 -191.08 1,600.00 24.88 354.59 1,560.02 1,381.52 240.40 -22.75 2,434,177.01 317,454.80 0.00 -231.39 1,700.00 24.88 354.59 1,650.74 1,472.24 282.28 -26.72 2,434,218.95 317,451.49 0.00 -271.71 1,800.00 24.88 354.59 1,741.46 1,562.96 324.16 -30.68 2,434,260.89 317,448.17 0.00 -312.02 1,900.00 24.88 354.59 1,832.18 1,653.68 366.04 -34.64 2,434,302.82 317,444.86 0.00 -352.33 2,000.00 24.88 354.59 1,922.90 1,744.40 407.92 -38.61 2,434,344.76 317,441.54 0.00 -392.64 2,100.00 24.88 354.59 2,013.62 1,835.12 449.80 -42.57 2,434,386.70 317,438.23 0.00 -432.95 2,200.00 24.88 354.59 2,104.34 1,925.84 491.68 -46.53 2,434,428.63 317,434.91 0.00 -473.26 2,300.00 24.88 354.59 2,195.07 2,016.57 533.56 -50.50 2,434,470.57 317,431.60 0.00 -513.57 2,400.00 24.88 354.59 2,285.79 2,107.29 575.44 -54.46 2,434,512.50 317,428.28 0.00 -553.88 2,500.00 24.88 354.59 2,376.51 2,198.01 617.32 -58.42 2,434,554.44 317,424.97 0.00 -594.19 2,600.00 24.88 354.59 2,467.23 2,288.73 659.20 -62.39 2,434,596.38 317,421.65 0.00 -634.50 2,700.00 24.88 354.59 2,557.95 2,379.45 701.08 -66.35 2,434,638.31 317,418.34 0.00 -674.82 2,800.00 24.88 354.59 2,648.67 2,470.17 742.96 -70.31 2,434,680.25 317,415.02 0.00 -715.13 2,900.00 24.88 354.59 2,739.39 2,560.89 784.84 -74.28 2,434,722.19 317,411.71 0.00 -755.44 3,000.00 24.88 354.59 2,830.11 2,651.61 826.72 -78.24 2,434,764.12 317,408.39 0.00 -795.75 3,100.00 24.88 354.59 2,920.84 2,742.34 868.60 -82.20 2,434,806.06 317,405.08 0.00 -836.06 3,200.00 24.88 354.59 3,011.56 2,833.06 910.48 -86.17 2,434,847.99 317,401.77 0.00 -876.37 3,300.00 24.88 354.59 3,102.28 2,923.78 952.36 -90.13 2,434,889.93 317,398.45 0.00 -916.68 3,400.00 24.88 354.59 3,193.00 3,014.50 994.24 -94.10 2,434,931.87 317,395.14 0.00 -956.99 3,500.00 24.88 354.59 3,283.72 3,105.22 1,036.12 -98.06 2,434,973.80 317,391.82 0.00 -997.30 9 5/8" 3,600.00 24.88 354.59 3,374.44 3,195.94 1,078.00 -102.02 2,435,015.74 317,388.51 0.00 -1,037.62 3,700.00 24.88 354.59 3,465.16 3,286.66 1,119.88 -105.99 2,435,057.68 317,385.19 0.00 -1,077.93 3,800.00 24.88 354.59 3,555.89 3,377.39 1,161.76 -109.95 2,435,099.61 317,381.88 0.00 -1,118.24 10/9/2014 5:48:43PM Page 3 COMPASS 5000.1 Build 70 Halliburton HALLIBURTONI Standard Proposal Report r Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 25 li Company: Hilcorp Energy Company TVD Reference: Plan:BCU 25 @ 178.50usft11. Project: Beaver Creek Unit MD Reference: Plan:BCU 25 @ 178.50usft il Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 25 Survey Calculation Method: Minimum Curvature Wellbore: BCU-25 Design: BCU-25 WP9 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,458.69 3,889.62 24.88 354.59 3,637.19 3,458.69 1,199.29 -113.50 2,435,137.20 317,378.91 0.00 -1,154.37 Start Dir 5°1100 @ 3890'MD,3637'ND-TFO 176 3,900.00 24.36 354.69 3,646.63 3,468.13 1,203.60 -113.91 2,435,141.51 317,378.57 5.00 -1,158.51 4,000.00 19.38 355.89 3,739.40 3,560.90 1,240.70 -117.00 2,435,178.66 317,376.04 5.00 -1,194.07 4,100.00 14.41 357.88 3,835.06 3,656.56 1,269.71 -118.66 2,435,207.68 317,374.84 5.00 -1,221.57 4,200.00 9.48 1.88 3,932.86 3,754.36 1,290.39 -118.85 2,435,228.36 317,374.97 5.00 -1,240.82 4,300.00 4.69 14.17 4,032.07 3,853.57 1,302.58 -117.57 2,435,240.54 317,376.43 5.00 -1,251.65 4,400.00 2.01 101.16 4,131.94 3,953.44 1,306.21 -114.85 2,435,244.12 317,379.21 5.00 -1,253.98 4,500.00 6.01 152.34 4,231.70 4,053.20 1,301.23 -110.70 2,435,239.07 317,383.29 5.00 -1,247.81 4,600.00 10.87 160.67 4,330.59 4,152.09 1,287.68 -105.14 2,435,225.44 317,388.63 5.00 -1,233.17 4,700.00 15.82 163.87 4,427.86 4,249.36 1,265.68 -98.23 2,435,203.34 317,395.20 5.00 -1,210.18 4,800.00 20.79 165.56 4,522.77 4,344.27 1,235.38 -90.01 2,435,172.91 317,402.95 5.00 -1,179.01 4,900.00 25.77 166.63 4,614.60 4,436.10 1,197.02 -80.55 2,435,134.41 317,411.82 5.00 -1,139.90 5,000.00 30.76 167.36 4,702.65 4,524.15 1,150.88 -69.92 2,435,088.12 317,421.73 5.00 -1,093.15 5,100.00 35.75 167.91 4,786.24 4,607.74 1,097.33 -58.20 2,435,034.39 317,432.62 5.00 -1,039.11 5,190.73 40.28 168.31 4,857.71 4,679.21 1,042.66 -46.70 2,434,979.55 317,443.28 5.00 -984.11 BC_B1ST 5,200.00 40.74 168.34 4,864.75 4,686.25 1,036.76 -45.48 2,434,973.63 317,444.40 5.00 -978.19 5,300.00 45.74 168.69 4,937.58 4,759.08 969.65 -31.86 2,434,906.31 317,456.99 5.00 -910.86 5,377.93 49.63 168.93 4,990.03 4,811.53 913.12 -20.68 2,434,849.62 317,467.29 5.00 -854.27 BC_B2ST 5,400.00 50.73 168.99 5,004.16 4,825.66 896.49 -17.43 2,434,832.94 317,470.28 5.00 -837.63 5,500.00 55.73 169.25 5,064.00 4,885.50 817.85 -2.32 2,434,754.08 317,484.17 5.00 -759.06 5,557.79 58.62 169.38 5,095.32 4,916.82 770.13 6.68 2,434,706.23 317,492.43 5.00 -711.45 BC_B3ST 5,600.00 60.73 169.47 5,116.64 4,938.14 734.32 13.37 2,434,670.32 317,498.56 5.00 -675.74 5,700.00 65.72 169.68 5,161.67 4,983.17 646.54 29.51 2,434,582.30 317,513.35 5.00 -588.32 5,706.56 66.05 169.69 5,164.35 4,985.85 640.66 30.59 2,434,576.39 317,514.33 5.00 -582.46 BC_B3-L_ST 5,800.00 70.72 169.87 5,198.76 5,020.26 555.18 45.99 2,434,490.70 317,528.41 5.00 -497.44 5,900.00 75.72 170.05 5,227.63 5,049.13 460.94 62.68 2,434,396.20 317,543.63 5.00 -403.82 6,000.00 80.71 170.22 5,248.05 5,069.55 364.53 79.44 2,434,299.54 317,558.90 5.00 -308.15 6,007.59 81.09 170.23 5,249.25 5,070.75 357.14 80.71 2,434,292.14 317,560.06 5.00 -300.83 BC_B4ST 6,100.00 85.71 170.39 5,259.86 5,081.36 266.68 96.16 2,434,201.44 317,574.10 5.00 -211.17 6,125.79 87.00 170.43 5,261.50 5,083.00 241.29 100.45 2,434,176.00 317,578.00 5.00 -186.03 Cont Dir 4°1100 @ 6126'MD,5262'TVD-TFO 0 6,200.00 89.97 170.43 5,263.46 5,084.96 168.15 112.78 2,434,102.68 317,589.20 4.00 -113.60 6,213.49 90.51 170.43 5,263.41 5,084.91 154.85 115.02 2,434,089.34 317,591.23 4.00 -100.43 End Dir @ 6213'MD,5263'ND 6,300.00 90.51 170.43 5,262.64 5,084.14 69.55 129.40 2,434,003.83 317,604.29 0.00 -15.96 6,400.00 90.51 170.43 5,261.75 5,083.25 -29.06 146.02 2,433,904.98 317,619.39 0.00 81.68 6,500.00 90.51 170.43 5,260.87 5,082.37 -127.66 162.65 2,433,806.13 317,634.48 0.00 179.33 6,600.00 90.51 170.43 5,259.98 5,081.48 -226.26 179.27 2,433,707.28 317,649.58 0.00 276.97 10/9/2014 5:48:43PM Page 4 COMPASS 5000.1 Build 70 r. • Halliburton . HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 25 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 25 @ 178.50usft Project: Beaver Creek Unit MD Reference: Plan:BCU 25 @ 178.50usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 25 Survey Calculation Method: Minimum Curvature Wellbore: BCU-25 Design: BCU-25 WP9 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 5,080.61 6,698.21 90.51 170.43 5,259.11 5,080.61 -323.10 195.59 2,433,610.20 317,664.40 0.00 372.87 Start Dir 4°/100 TFO-94 6,700.00 90.50 170.36 5,259.09 5,080.59 -324.87 195.89 2,433,608.43 317,664.67 4.00 374.62 6,800.00 90.26 166.37 5,258.43 5,079.93 -422.79 216.06 2,433,510.20 317,683.32 4.00 472.96 6,900.00 90.01 162.37 5,258.20 5,079.70 -519.07 243.00 2,433,413.52 317,708.76 4.00 572.32 7,000.00 89.76 158.38 5,258.40 5,079.90 -613.25 276.57 2,433,318.83 317,740.87 4.00 672.21 7,052.69 89.63 156.28 5,258.68 5,080.18 -661.86 296.87 2,433,269.91 317,760.42 4.00 724.89 End Dir @ 7053'MD,5259'TVD 7,100.00 89.63 156.28 5,258.99 5,080.49 -705.18 315.91 2,433,226.31 317,778.78 0.00 772.18 7,200.00 89.63 156.28 5,259.64 5,081.14 -796.73 356.14 2,433,134.15 317,817.59 0.00 872.13 7,300.00 89.63 156.28 5,260.29 5,081.79 -888.28 396.36 2,433,041.99 317,856.40 0.00 972.09 7,400.00 89.63 156.28 5,260.93 5,082.43 -979.82 436.59 2,432,949.82 317,895.20 0.00 1,072.04 7,500.00 89.63 156.28 5,261.58 5,083.08 -1,071.37 476.82 2,432,857.66 317,934.01 0.00 1,171.99 7,571.05 89.63 156.28 5,262.04 5,083.54 -1,136.42 505.40 2,432,792.18 317,961.58 0.00 1,243.01 Cont Dir 4°/100 @ 7571'MD,5262'TVD-TFO 90 7,600.00 89.64 157.44 5,262.22 5,083.72 -1,163.04 516.78 2,432,765.39 317,972.54 4.00 1,271.95 7,673.93 89.66 160.39 5,262.67 5,084.17 -1,232.01 543.37 2,432,696.02 317,998.06 4.00 1,345.86 End Dir @ 7674'MD,5263'TVD 7,700.00 89.66 160.39 5,262.83 5,084.33 -1,256.57 552.12 2,432,671.32 318,006.43 0.00 1,371.91 7,800.00 89.66 160.39 5,263.41 5,084.91 -1,350.77 585.67 2,432,576.62 318,038.52 0.00 1,471.82 7,900.00 89.66 160.39 5,264.00 5,085.50 -1,444.97 619.23 2,432,481.91 318,070.62 0.00 1,571.73 8,000.00 89.66 160.39 5,264.59 5,086.09 -1,539.17 652.78 2,432,387.20 318,102.71 0.00 1,671.64 8,100.00 89.66 160.39 5,265.17 5,086.67 -1,633.37 686.34 2,432,292.49 318,134.80 0.00 1,771.55 8,200.00 89.66 160.39 5,265.76 5,087.26 -1,727.57 719.89 2,432,197.78 318,166.90 0.00 1,871.46 8,300.00 89.66 160.39 5,266.35 5,087.85 -1,821.77 753.45 2,432,103.07 318,198.99 0.00 1,971.37 8,400.00 89.66 160.39 5,266.93 5,088.43 -1,915.97 787.00 2,432,008.37 318,231.08 0.00 2,071.28 8,500.00 89.66 160.39 5,267.52 5,089.02 -2,010.17 820.56 2,431,913.66 318,263.17 0.00 2,171.19 8,600.00 89.66 160.39 5,268.11 5,089.61 -2,104.37 854.11 2,431,818.95 318,295.27 0.00 2,271.10 - 8,667.10 89.66 160.39 5,268.50 a 5,090.00 -2,167.58 876.63 2,431,755.40 318,316.80 0.00 2,338.14 TD at 8667'MD,5269'TVD 10/9/2014 5:48:43PM Page 5 COMPASS 5000.1 Build 70 Halliburton 4 HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 25 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 25 @ 178.50usft Project: Beaver Creek Unit MD Reference: Plan:BCU 25 @ 178.50usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 25 Survey Calculation Method: Minimum Curvature Wellbore: BCU-25 Design: BCU-25 WP9 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) BCU-25 BC T2 Rev 100914 0.00 0.00 5,259.11 -323.10 195.59 2,433,610.20 317,664.40 -plan hits target center -Circle(radius 100.00) BCU-25 Landing revised 100314 0.00 0.00 5,252.31 -606.40 621.16 2,433,320.35 318,085.53 -plan misses target center by 319.28usft at 7132.32usft MD(5259.20 TVD,-734.77 N,328.91 E) -Circle(radius 100.00) BCU-25 BC T3 Rev 100914 0.00 0.00 5,262.04 -1,136.42 505.40 2,432,792.18 317,961.58 -plan hits target center -Circle(radius 100.00) BCU-25 TD revised 100314 0.00 0.00 5,267.00 -2,116.85 1,955.70 2,431,789.42 319,396.53 -plan misses target center by 1080.27usft at 8667.10usft MD(5268.50 TVD,-2167.58 N,876.63 E) -Circle(radius 100.00) BCU-25 BC_B4ST revised 100314 0.00 0.00 5,250.64 -440.43 462.26 2,433,488.76 317,929.22 -plan misses target center by 232.95usft at 6883.35usft MD(5258.21 TVD,-503.18 N,238.05 E) -Circle(radius 100.00) BCU-25TD revised 100914 0.00 0.00 5,268.50 -2,167.58 876.63 2,431,755.40 318,316.80 -plan hits target center -Circle(radius 100.00) BCU-25 BC T1 Rev 100914 0.00 0.00 5,261.50 241.29 100.45 2,434,176.00 317,578.00 -plan hits target center -Circle(radius 100.00) BCU 25 Section Lines-1500'offset 0.00 0.00 0.00 -3,896.61 -2,985.68 2,430,086.36 314,428.19 -plan misses target center by 4908.99usft at 18.00usft MD(18.00 TVD,0.00 N,0.00 E) -Polygon Point 1 0.00 6,627.72 5,080.23 2,436,634.65 319,610.40 Point2 0.00 -1,651.58 5,133.02 2,428,355.52 319,535.03 BCU 25 Section Lines 0.00 0.00 0.00 -3,896.61 -2,985.68 2,430,086.36 314,428.19 -plan misses target center by 4908.99usft at 18.00usft MD(18.00 ND,0.00 N,0.00 E) -Polygon Point 1 0.00 5,151.12 6,603.27 2,435,134.65 321,110.40 Point2 0.00 -128.54 6,609.62 2,429,855.52 321,035.03 Point 3 0.00 -128.99 1,329.95 2,429,936.80 315,755.98 Point4 0.00 5,150.68 1,323.60 2,435,215.93 315,831.36 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 3,500.00 3,283.72 95/8" 9-5/8 12-1/4 8,667.10 5,268.50 5 1/2" 5-1/2 8-1/2 10/9/2014 5:48:43PM Page 6 COMPASS 5000.1 Build 70 Halliburton HALLIBURTh.d Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 25 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 25 @ 178.50usft Project: Beaver Creek Unit MD Reference: Plan:BCU 25 @ 178.50usft Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 25 Survey Calculation Method: Minimum Curvature Wellbore: BCU-25 Design: BCU-25 WP9 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (1 (0) 5,557.79 5,095.32 BC B3ST 5,377.93 4,990.03 BC_B2ST 6,007.59 5,249.25 BC_B4ST 5,190.73 4,857.71 BC_B1ST 5,706.56 5,164.35 BC_B3-L_ST Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 618.00 618.00 0.00 0.00 Start Build 3.00 @ 618'MD,618'TVD-TFO 350 1,447.23 1,421.42 176.42 -16.70 End Dir @ 1447'MD 3,889.62 3,637.19 1,199.29 -113.50 Start Dir 50/100 @ 3890'MD,3637'TVD-TFO 176 6,125.79 5,261.50 241.29 100.45 Cont Dir 4°/100 @ 6126'MD,5262'TVD-TFO 0 6,213.49 5,263.41 154.85 115.02 End Dir @ 6213'MD,5263'TVD 6,698.21 5,259.11 -323.10 195.59 Start Dir 4°/100 TFO-94 7,052.69 5,258.68 -661.86 296.87 End Dir @ 7053'MD,5259'TVD 7,571.05 5,262.04 -1,136.42 505.40 Cont Dir 4°/100 @ 7571'MD,5262'TVD-TFO 90 7,673.93 5,262.67 -1,232.01 543.37 End Dir @ 7674'MD,5263'TVD 8,667.10 5,268.50 -2,167.58 876.63 TD at 8667'MD,5269'TVD 10/9/2014 5:48:43PM Page 7 COMPASS 5000.1 Build 70 Z w 0 1- m a M L Q li I a N In E I e n aco dog d F Sia 0o 11 w N NO. 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UUUU UU U U U U U U U U U U > > > > > > > > > > > > >) >) >) N co ca ca D a) a)as a) aa)) a) a) a) a) a) a) a) a) aaca co a)) a) a) a) U Co Co oo oo oo m m co CO CO m m m m m a0 m - O _ rn 1 4 I - c0- N Ii 0 -o I NI -.-. to e--_____ !rte h ®_ CZ 1 � i - a o m - 1 ----- O u. u-, Q N m `�[j C) m ` o a7 Ln f.. - 5= N o C _+ -co C co a) CO C) m I - oM O °) co p - N 43ZCIAu acr L f „... —�W En 3 ........— -- _ o c I_ LOyas �`010...”" g . m o 43 O o.s - 0) CE � X.;-) ----, a - N ACL i+Oa C .yN O v 6 � -NmO `O .— . I , •v— a.. I I I I I II I I I I I I I I I I I I I O O — O O Cl O �) r O N- A N O O U) h O ,_ O Q () O to O O C p O r co M N O _ _ (u!/og'Z)Jo}oeI uogeiedeg < 0 Monty Myers Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage,AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com Ilileorp Alaska,LI.0 August 27, 2014 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Beaver Creek (BCU) 25 revised PTD Dear Commissioner, I am requesting permission to modify the previously approved permit to drill for Beaver Creek #25. After drilling the Beaver Creek 23 and Beaver Creek 24 it is necessary to modify the BHL for the placement of the Beaver Creek 25 lateral in the B4 sand. After logging the B4 sand in the previous 2 wells, it was necessary to replan the lateral to drill around the Beaver Creek 13 well for anti-collision issues and to accommodate the lateral length needed in the B4 sand. Only the directional portion of the well has changed, which has slightly increased the overall TMD of the well. Drilling operations are expected to commence approximately October 20th, 2014. The Saxon Rig# 169 will be used to drill the wellbore then run casing and cement. General sequence of operations: 1. MOB Saxon Rig# 169 to well site 2. N/U 21-1/4" x 2M diverter. 3. Drill 12-1/4" hole to 3500' MD. Run and cmt 9-5/8" surface casing. 4. N/D diverter, N/U &test 11" x 5M T3-Energy BOP. 5. Drill 8-1/2" hole section to 8667' MD. Perform Wiper trip. 6. POOH laying down drill pipe. 7. Run and cmt 5-1/2" production casing . 8. N/D BOP, N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: Hilcorp Alaska, LLC Page 1 of 2 I Monty Myers Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage, AK 99524-4027 1. e hole: GR + Res LWD. Tel 907 777 8431 Email mmyers@hilcorp.com Qa Ka gallon Hole: GR + Res + Den/Neu LWD. 3. Mud loggers from surface casing point to TD. If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777- 8369. Sincerely, Monty Myers Drilling Engineer Hilcorp Alaska, LLC Page 2 of 2 TRANSMITTAL LETTER CHECKLIST WELL NAME: 4 • PTD: - -/7 /3z- Development 3 -Development Service Exploratory Stratigraphic Test Non Conventional FIELD: "-f--k , POOL: ___„‘ �-- Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC _ to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are Well Lo m also required for this well: gg g Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. 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F- O ago ° 3 a) a) (O C -Cr) 0 0 E m 3 > o ° m m _ -oo o - o a 2 a 0 a) = C .° a3 Co Ca C) C U c O D U U 0 0 0 0 C) a) U Co o C U m o o a) t) ° r Ir; a E = N C �C,, - ati t/) J a ° 0 0 0 .� .> m io a a o ° U > > 3 co o a) o a) C) w w a) Co °_ E a) co 5 J 2 E N Q - - - a) a`) 02 E E C - 3 c 'C I- f- F- 'Co ami ami - _ a a o 22 U E :o N m c co L- M .c 71"71) o ° a a a a a) 0 a) — 2 o 0 ° 2 2 2 CO a a) a = O 0 L O 0- a) a) m '5 a), o a V @LLJcn4- OOwaUaaZ OU) 000U ¢ = a = ommU � ) 2 aacocoo I ° O N c'') C «) O N CO 0) O N M A- cf) (O N- CO 0) N M V LO (O to--; CO 0) V �- N co V up co r co 0) c- N N N N N N N N N N CC:,;' C) C) C) C) M M M (') M U VV •v c C o O a) G O C _ N w N "' N V O • N ° C N- D N in o 0 N- o)yr � C) o 0) c- N I- d V w O E O O i N•E 0 _N a) >+ J N • (7 0 W 1.-C C o C- a I-Ls 0) Q J 0 a 0 0 • a Q (n lL Q C7 C7 �° cn sof 1-7-„4,,,,\ iy ,vV,\AII%% -F STATE L_�c.S ' :i II ::.]1C. *t.-11:,;N:-_-::-) -. 7 ,, , (i011;RN n SI-AN 1 AR\' - i t Pnc orcycMasKoy/5 35 ,‘a n 9`)7 27% 2,33 Monty Mack Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 999503 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek 25 Hilcorp Alaska, LLC Permit No: 214-132 Surface Location: 1246' FNL, 1656' FWL, Sec. 34, T7N, R10W, SM, AK Bottomhole Location: 1605' FSL, 1651' FEL, Sec. 34, T7N, R10W, SM, AK Dear Mr. Myers: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the . Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, f4,,,,,z,_ Cathy . Foerster � F�- Chair DATED this /l day of September,2014. BEDEWED STATE OF ALASKA A OIL AND GAS CONSERVATION COMI N / AUG 2 7 2014 PERMIT TO DRILL AOGCC 20 AAC 25.005 1a Type of Work lb Proposed Well Class. Development-Oil ❑ Service- Winj ❑ Single Zone Q . 1c.Specify if well is proposed for Drill ❑✓ Lateral ❑ Stratigraphic Test ❑ Development-Gas❑., Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redril❑ Reentry 0 Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2 Operator Name 5. Bond Blanket Q Single Well ❑ 11 Well Name and Number Hilcorp Alaska,LLC Bond No 022035244- Beaver Creek 25 • 3 Address 6.Proposed Depth 12 Field/Pool(s) 3800 Centerpoint Drive,Suite 1400,Anchorage AK 99503 MD 8,200' - TVD 5,289' , Beaver Creek Field 4a. Location of Well(Governmental Section) 7 Property Designation(Lease Number). Beluga Gas Surface 1246 FNL, 1656'FWL,Sec 34,T7N,R1OW,SM,AK ' A028083 Top of Productive Horizon. 8 Land Use Permit 13 Approximate Spud Date 1695'FNL,2122'FWL,Sec 34,T7N,R1OW,SM,AK NA 11/15/2014 Total Depth 9.Acres in Property 14 Distance to Nearest Property 1605'FSL, 1651'FEL,Sec 34,T7N,R1OW,SM,AK 1920 acres(A028083) 1600' 4b.Location of Well(State Base Plane Coordinates-NAD 27) 10 KB Elevation above MSL 179.2 feet. 15.Distance to Nearest Well Open Surface x-317473.83 , y-2433936 29 . Zone-4 GL Elevation above MSL 160 6 feet • to Same Pool 915'BCU-19 16 Deviated wells Kickoff depth 4,,C.X) feet 44'2417.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle 90,Y3 degrees Downhole 2300 psi / Surface 1771 psi ' 18 Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c f or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Cond 16" 109 X-56 Weld 80' Surface Surface 80' 80' Driven 12-1/4" 9-5/8" 40 L-80 BTC 3,500' Surface Surface 3,500' . 3,497' 305 3bbl/1713 9ft3 8-1/2" 5-1/2" 17 P-110 DWC/C HT 8,200' Surface Surface 8,200' 5,289' 284bbl/1594 5ft3 19 PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft) Total Depth TVD(ft)• Plugs(measured) Effect.Depth MD(ft). Effect Depth TVD(ft): Junk(measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft) Perforation Depth TVD(ft) 20 Attachments: Property Plat ❑✓ BOP Sketch Q Drilling Program ❑✓ Time v Depth Plot ❑✓ Shallow Hazard Analysis❑ Diverter Sketch ❑✓ Seabed Report ❑Drilling Fluid Program Q 20 MC 25 050 requirements 21 Verbal Approval Commission Representative. Date - 22 I hereby certify that the foregoing is true and correct Contact Monty Mack Myers Email mnnyers(U7hiICOrp.com Printed Name Monty Mack Myers Title Drilling Engineer Signature .—'"••• • Phone (907)777-8431 Date 8/25/2014 Commission Use Only Permit to Drill t.-.5 z_. API Number '/�/ l� Permit Approval See cover letter for other Number ��y 50-/33�2 (7T �G!Date �_\`-'Lp\� requirements - Conditions of approval. If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales. LJ Other 4 3`jCO /�5;, f L,1 /C.>7 Samples req'd: Yes❑ No Q Mud log req'd Yes❑ No[s]' I / H2S measures Yes❑ No 7' Directional svy req'd.Yes Q No❑ $. C g / f /t i r [%4 7. pacing exception req'd Yes❑ No Di Inclination-only svy req'd Yes❑ No Zr APPROVED BY Approved by/ _� `r""q�_7(L‘...___ COMMISSIONER THE COMMISSION Date. q_-/1 I5( i,`?"4' 1 1 D aiN0A, Submit Form ane Form 10-401(Revised 10/2012) ThI I S r m the date of approval(20 AAC 25.005(g)) Attachments in Duplicate A s•5 i5/ Monty Myers Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com !literal),11a..6a,hLC RECEIVED August 27, 2014 AUG 2 7 2014 Commissioner AOGCC Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Beaver Creek (BCU) 25 Dear Commissioner, Beaver Creek #25 is a south easterly step-out development well of the lower Sterling gas sand on the Zt-to eastern flank of the field between the BCU 24 and BCU 16 wells. The base plan is an 8,200' horizontal wellbore with a slight nudge around 600', to build away from existing wells for AC issues. The curve of the well will start at'4400' MD and build at 7 deg/100' and land at 89 degrees in the top of the Sterling B4 sand. The objective is to then track the Sterling B4 sand to within 1600' of the unit boundary Drilling operations are expected to commence approximately November 15th, 2014. The Saxon Rig# 169 will be used to drill the wellbore then run casing and cement. Surface casing will be run to 3,500' MD/3,497' TVD and cemented to surface to ensure protection of any shallow freshwater resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6 — 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC and BLM authorities. All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal /beneficial reuse depending on test results. General sequence of operations: 1. MOB Saxon Rig# 169 to well site 2. N/U 21-1/4" x 2M diverter. 3. Drill 12-1/4" hole to 3500' MD. Run and cmt 9-5/8" surface casing. 4. N/D diverter, N/U &test 11" x 5M T3-Energy BOP. 5. Drill 8-1/2" hole section to 8200' MD. Perform Wiper trip. 6. POOH laying down drill pipe. 7. Run and cmt 5-1/2" production casing . 8. N/D BOP, N/U temp abandonment cap, RDMO. Hilcorp Alaska, LLC Page 1 of 2 Monty Myers Hilcorp Alaska, LLC 11 Drilling Engineer P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com !Limp Alaska.I,Lf. Reservoir Evaluation Plan: 1. Surface hole: GR + Res LWD. 2. Production Hole: GR + Res + Den/Neu LWD. 3. Mud loggers from surface casing point to TD. • If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777- 8369. Sincerely, Monty Myers Drilling Engineer Hilcorp Alaska, LLC Page 2 of 2 Hilcorp Alaska, LLC Beaver Creek #25 Drilling Program Beaver Creek Field ro d by: MF My Version 0 August 20th, 2014 Beaver Creek#25 Drilling Procedure Hilcorp Energy Company Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program: 4 4.0 Drill Pipe Information• 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling/Completion Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 11 10.0 N/U 21-1/4"2M Diverter 12 11.0 Drill 12-1/4" Hole Section 15 12.0 Run 9-5/8" Surface Casing 20 13.0 Cement 9-5/8" Surface Casing 23 14.0 BOP N/U and Test 26 15.0 Drill 8-1/2"Hole Section 27 16.0 Run 5-1/2"Production Casing 32 17.0 Cement 5-1/2"Production Casing 35 18.0 RDMO 38 19.0 BOP Schematic 39 20.0 Wellhead Schematic 40 21.0 Days Vs Depth 41 22.0 Geo-Prog 42 23.0 Anticipated Drilling Hazards 43 25.0 Saxon Rig 169 Layout 45 25.0 FIT Procedure 46 26.0 Choke Manifold Schematic 47 27.0 Casing Design Information 48 28.0 8-1/2" Hole Section MASP 49 29.0 Spider Plot(NAD 27)(Governmental Sections) 50 30.0 Surface Plat(As Staked)(NAD 27) 51 31.0 Surface Plat(As Staked) (NAD 83) 52 32.0 Directional Survey 53 .__..._ .. .._..... .. Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp I nergy Company 1.0 Well Summary Well Beaver Creek#25 Pad&Old Well Designation Beaver Creek#25 is a grass roots well on BCU Pad#3 Planned Completion Type 5-1/2"Production tubing Target Reservoir(s) Sterling Planned Well TD,MD/TVD 8,200 MD/5,289' TVD PBTD,MD/TVD 8,080' MD/5,289'TVD Surface Location(Governmental) 1246' FNL, 1656'FWL,Sec 34,T7N,R10W, SM,AK Surface Location(NAD 27) X=317473.83,Y=2433936.29 • Surface Location(NAD 83) X=1457494.994 Y=2433697.178 Top of Productive Horizon (Governmental) 1695' FNL,2122' FWL,Sec 34,T7N,R10W, SM,AK TPH Location(NAD 27) X=317929.22,Y=2433488.76 TPH Location(NAD 83) X=1457950.388,Y=2433249.623 BHL(Governmental) 1605'FSL, 1651'FEL, Sec 34,T7N,R10W, SM,AK BHL(NAD 27) X=319406.66,Y=2431486.04 BHL(NAD 83) X=1459427.831,Y=2431246.821 AFE Number 1412521D AFE Drilling Days 5 MOB,20 DRLG AFE Completion Days AFE Drilling Amount $4,667,620 AFE Completion Amount $600,000 Maximum Anticipated Pressure (Surface) 1771 psi(Drilling) - Maximum Anticipated Pressure (Downhole/Reservoir) 2300 psi Work String 4-1/2" l6.6# S-135 CDS-40(Saxon Owned String) RKB—GL 179.2'(160.6+ 18.6) Ground Elevation 160.6' BOP Equipment 11"5M T3-Energy Annular BOP 11"5M T3-Energy Double Ram 11"5M T3-Energy Single Ram Page 2 Version 0 July, 2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp Enemy Company 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp Compaq Changes to Approved Permit to Drill Date: August 20,2014 Subject Changes to Approved Permit to Drill for Beaver Creek #25 File#: Beaver Creek #25 Drilling Program Any modifications to the Drilling&Completion Program will be documented and approved below. Changes to an approved APD will be ee-Pmfteftielterkethe AOGCC &BLM- � "L- dirt Date Procedure Change Approved Approved BY By Approval: Drilling Manager Date Prepared: Drilling Engineer Date Page 3 Version 0 July, 2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp 3.0 Tubular Program: Hole AI ID(in) Drift Conn Wt Grade Inn Burst Collapse Tension Section (in) OD(in) (#/ft) (psi) (psi) (k-lbs) Cond 16" 15" - - 109 X-56 Weld 12-1/4" 9-5/8" 8.835" 8.679" 10.625" 40 L-80 BTC 5750 3090 916 8-1/2" 5-1/2" 4.892 4.767 6.050 17 P-110 DWC/C HT 10640 7480 546 4.0 Drill Pipe Information: Hole OD(in) ID(in) TJ ID TJ OD Wt Grade Conn Burst Collapse Tension Section (in) (in) (#/ft) (psi) (psi) (k-lbs) All 4-1/2" 3.826 2.6875" 5.25" 16.6 S-135 CDS40 17,693 16,769 468k All casing will be new, PSL 1 (100%mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 0 July,2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp NNW CestP 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area—this will not save the data entered, and will navigate to another data entry tab. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini@hilcorp.com, lkeller@hilcorp.com,mmyers@hilcorp.com andjbarrett@hilcorp.com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays,ensure to have this update in before 5am. Each rig will be assigned a username to login with. 5.4 EHS Incident Reporting • Notify EHS field coordinator. 1. This could be one of(3) individuals as they rotate around. Know who your EHS field coordinator is at all times,don't wait until an emergency to have to call around and figure it out!!!! a. John Coston: 0: (907)777-6726 C: (907)227-3189 b. Mark Tornai: 0: (907)283-1372 C: (907)748-3299 c. Thad Eby: 0: (907)777-8317 C: (907)602-5178 2. Spills:Kate Kaufman: 0:907-777-8329 C:907-254-8292 • Notify Drlg Manager 1. Paul Mazzolini: 0: 907-777-8369 C: 907-317-1275 • Submit Hilcorp Incident report to contacts above within 25 hrs 5.5 Casing Tally • Send final"As-Run"Casing tally to mmyers(c�hilcorp.com and jbarrett@hilcorp.com 5.6 Casing and Cmt report • Send casing and cement report for each string of casing to mmyers@hilcorp.com and jbarrett@hilcorp.com Page 5 Version 0 July, 2014 Beaver Creek#25 II Drilling Procedure Rev 0 Hilcorp Energy Company 6.0 Planned Wellbore Schematic Beaver Creek Unit PROPOSED Weil BCU#25 PTD; 000-000 API: 50-000-00000-00 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm P.'. Conductor —Driven 1E„ 109 X-56 Weld 16" Surf 80' to Set Depth 9-5; Surf.Csg 40 L-80 BTC 5.835" Surf 3500' 5.5 pp; ' 5-'1/2" Prod Csg 17 P-110 D HT C 4.892" Surf 8,200' 9.0 pp_ 9-518- Allill 11114L.: 1 s.- Drilling Info " Fc/e 5ect,c^ Casing MW Workstrir€ 12-1`4" 9-5/8" 8.8 ppg 4-1/2" w �' s.* 5-1/2" 5-1/2" 9.0-9.5 ppg 4-1/2" ', JEWELRY DETAIL fd=. Ce;_':in ID OD Item 1 3312' 4.892" 8.5" Baker Swell Packer 8-1 Hole .0. 5-112" ,,i,,,,:.„ 71f�C;„......„,,,,,......,„„7,,70:5„,:t.,:,:27,t P8TD=8,080'.PBTI,'D 289' TD=8,200'.TIT=;,289' • Page 6 Version 0 July, 2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp !mew Company 7.0 Drilling / Completion Summary Beaver Creek#25 is a south easterly step-out development well of the lower Sterling gas sand on the eastern flank of the field between the BCU 24 and BCU 16 wells. The base plan is an 8,200' horizontal wellbore with a slight nudge around 600',to build away from existing wells for AC issues. The curve of the well will start at 4400' MD and build at 7 deg/100' and land at 89 degrees in the top of the Sterling B4 sand.The objective is to then track the Sterling B4 sand to within 1600' of the unit boundary Drilling operations are expected to commence approximately November 15th,2014. The Saxon Rig# 169 will be used to drill the wellbore then run casing and cement. Surface casing will be run to 3,500' MD/ 3,497' TVD and cemented to surface to ensure protection of any shallow freshwater resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6— 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC and BLM authorities. All waste &mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal/beneficial reuse depending on test results. General sequence of operations: 1. MOB Saxon Rig# 169 to well site 2. N/U 21-1/4"x 2M diverter. 3. Drill 12-1/4"hole to 3500' MD. Run and cmt 9-5/8" surface casing. 4. N/D diverter,N/U&test 11"x 5M T3-Energy BOP. 5. Drill 8-1/2"hole section to 8200' MD. Perform Wiper trip. 6. POOH laying down drill pipe. 7. Run and cmt 5-1/2"production casing . 8. N/D BOP,N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: 1. Surface hole: GR+Res LWD. 2. Production Hole: GR+Res+Den/Neu LWD. 3. Mud loggers from surface casing point to TD. Page 7 Version 0 July,2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp En. y Company 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at (2)week intervals during the drilling of Beaver Creek#25. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 10/10 min(annular to 50%rated WP,2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements" • Ensure both AOGCC approved drilling permit and BLM sundry are posted on the rig floor and in Co Man office. Regulation Variance Requests: • Onshore Oil and Gas Order No. 1, Section III. D. 3. C. 0 S v o Hilcorp requests approval to install a 3-1/8"5M HCR valve on kill line in lieu of a check valve. �y�' Operator suspects a freeze plug risk associated with installation of a check valve in the kill line. (v " o Hilcorp requests approval to utilize flexible choke and kill lines in lieu of hard piping. Ork Page 8 Version 0 July, 2014 Beaver Creek #25 Drilling Procedure Rev 0 Hilcorp Energy Company Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 12-1/4" • 21-1/4"x 2M Hydril MSP diverter Function Test Only • 11"x 5M T3-Energy(Model 7082)Annular BOP • 11"x 5M T3-Energy Double Ram Initial Test:250/3500 .� o Blind ram in btm cavity (Annular 2500 psi) • Mud cross 8-1/2" • 11"x 5M T-3 Energy Single Ram • 3-1/8"5M Choke Line Subsequent Tests: • 2-1/16"x SM Kill line 250/3500 • 3-1/8"x 2-1/16"5M Choke manifold (Annular 2500 psi) • Standpipe,floor valves,etc • Primary closing unit: Control Technologies accumulator unit, 5 station, 120 gallon (12 x 11 gal bottles). • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: • Well control event(BOPs utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPs. • 24 hours notice prior to casing running& cement operations. • Any other notifications required in APD. Required BLM Notifications: • 48 hours before spud. Follow up with actual spud date and time. • 48 hours before casing running and cmt operations • 48 hours before BOPE tests • 48 hours before logging, coring, &testing • Any other notifications required in APD. Additional requirements may be stipulated on APD and Sundry. Page 9 Version 0 July,2014 Beaver Creek#25 11 Drilling Procedure Rev 0 H&c= Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.regg@alaska.gov Guy Schwartz/Petroleum Engineer/(0): 907-793-1226/(C): 907-301-4533 /Email: guv.schwartz@alaska.gov Victoria Ferguson/Petroleum Engineer/(0): 907-793-1257/Email: Victoria.ferguson@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone: 907-793-1236(During normal Business Hours) Notification/Emergency Phone: 907-659-2714 (Outside normal Business Hours) BLM Justin Miller/BLM Petroleum Engineer/ (0): 907-271-3406 (C): 907-717-4039 Use the below email address for BOP notifications to the BLM: BLM_AK_AKSQ_EnergySection Notifications@b1m.gov Page 10 Version 0 July, 2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcor 9.0 R/U and Preparatory Work 9.1 Set 16"conductor at 80' below ground level. 9.2 Dig out and set impermeable cellar. 9.3 Install Seaboard slip-on 16-3/4" 3M"A"section. Ensure to orient wellhead so that tree will line up with flowline later. 9.4 Level pad and ensure enough room for layout of rig footprint and R/U. 9.5 Layout Herculite on pad to extend beyond footprint of rig. 9.6 R/U Saxon Rig# 169, spot service company shacks, spot&R/U company man &toolpusher offices. 9.7 Mud loggers not required on surface hole section. 'J 9.8 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.9 Mix mud for 12-1/4" hole section. 9.10 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.11 Install 5-1/2"liners in mud pumps. • TSM 1000 mud pumps are rated at 3633 psi (85%)/333 gpm (100%)with 5-1/2"liners. Page 11 Version 0 July, 2014 Beaver Creek#25 11 Drilling Procedure Rev 0 Hilcar EOM U.OPMq 10.0 N/U 21-1/4" 2M Diverter 10.1 N/U 21-1/4" Hydril MSP 2M diverter System. • N/U 16-3/4" 3M x 21-1/4" 2M DSA (Hilcorp) on 16-3/4" 3M wellhead. • N/U 21-1/4"diverter"T". • Knife gate, 16"diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). r -7 atl c'c, 10.2 Function test diverter. Ensure that the Knife gate and ann.ilar are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked"warning zone" is established on each side and ahead of the vent line tip. "Warning Zone"must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials V • Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set 15.375" ID wearbushing in wellhead. Page 12 Version 0 July,2014 Beaver Creek#25 11 Drilling Procedure Rev 0 Hilcorp Energy co,pny 10.5 Rig and Diverter Line Orientation on Beaver Creek 3 pad: S ir t. s di i oir.P b t4a"+r I era .4., .-4,_p r s olif* # '' '-'-;---' ., ' .,,,".,..'2‘,IL,.\. - , ' - .,- 40 **i-- / , 4111k,` i ip 40 II Beaver Creek Unit Ar iintila90bet pad 3 Feet utrar 0 �6 100 Page 13 Version 0 July, 2014 Beaver Creek#25 II Drilling Procedure Rev 0 Hilcorp Encrgy Company 10.6 Diverter Schematic (1l 1#1 Ill I11 ill III (11 11 11111111111111111L s Annular Preventer rm _m__r_E-iyririLLIS1L______..,__ 21-W 2M . / , ([0] &man M n ia Kn fe Gate III 111111 III Ill tw NO 1 6" Diverter lint i Diverter Tee,21-W x 21-W x 2M w/16"ANSI 150 outlet l ... .. sap a III III III Ill III 16-%"3M x 21-W 2M DSA _ ,W. AVM1111111111 41111millo. icri(N!r !I ' ll Seaboard 16-%"3M i If i i 1 i Casing head Assy 16" Page 14 Version 0 July, 2014 Beaver Creek#25 II Drilling Procedure Rev 0 Hilcar Enmy 11.0 Drill 12-1/4" Hole Section 11.1 P/U 12-1/4" directional drilling assy: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Workstring will be 4.5" 16.6# S-135 CDS40 11.2 12-1/4"BHA(GR and Res LWD are included in below BHA): - Page 15 Version 0 July,2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp Energy Company .COMPONENT DATA em OD ID Gauge Weight Top Length Cumulat' Description Serial Number Connection lin) tin) tin) pm.) Connection MI HDBS-OHC I GRC Mil tooth 12.200 3.000 12250 374.30 P 6-5/8"REG 1.20 1.20 © 8"SperryDrill Lobe 4/5-5.3 stg 8.000 5.000 121.08 B 6-518"REG 28.99 30.19 - Stabilizer 11500 _--- © Integral Blade Stabilizer aillIllIllIll 8.000 2.813 12125 150.12 B 6-5'8'REG 6.00 36.19 E. 8"DM Collar(Directional) ® 8.000 3.500 147.40 B 6-518'REG 9.20 45.39 ® 8"DGR Collar (Gamma) IIIIIIIIIIII 8.000 1.920 142.70 B 6-518'REG 4.55 49.94 6 8"EWR-P4 Collar(Resistively) • ® 8.000 2.000 151.00 B 6-518"REG 12.19 62.13 8"HCIM Collar(Processor) 8.000 1.920 149.90 B 6-518'REG 4.97 67.10 KM 8"TM-HOC(Pulser) IIIIIIIIIII 8.150 4000 145.20 B 6-518'REG 9 Orienting Sub UBHO 8.000 3.000 147.22 B 6518"REG 3.50 86.37 Mil Non Mag Flex Drill Collar 8.000 3.000 147.22 B 6-518'REG 30.00 116.37 m Non Mag Flex Drill Collar 8.000 3.000 _® B 6-518"REG 30.00 MEI ® X-O 6-518 Reg Pin X 4-1/2"IF Box IIIIIIIIIIII 8.000 2.813 150.12 B 4-1/2"IF 3.50 149.87 ® 8 Joints 5"HWDP 5.000 3.000 49.30 240.00 389.87 ® Weatherford 6-1/4'Hyd Jar 6.250 2.250 91.01 B 4-112"IF 30.00 419.87 ® 19 Joints 5'HWDP 5.000 3.000 49.30 570.00 989.87 Tectal: 989 87 BITDATA ' Bit Number Nozzles 1x12.3x18 Bit Size (in) : 12.250 TFA (in2) :0.8560 Manufacturer : HDBS Dull Grade In . Model Dull Grade Out .• Serial Number .• MOTOR DATA Motor Number : 2 Bend (deg) : 1.'5 OD (in) : 8.000 Nozzles (32nd) . 0 0 Manufacturer . Sperry DrPng Avg Diff Press . Model : SperryDrif. Cumut Cir Hrs . Serial Number . Page 16 Version 0 July, 2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp Encrgy Company 11.3 Primary Bit: 12-1/4" (311MM) QHC1GRC PRODUCT SPECIFICATIONS IADC Code I I 7 " Total Tooth Count 67 Gage Row Tooth Count 39 Journal Angle 33" Offset(1:16") 6 Jet Nozzle Types Ifrf '4' :4 " Standard 83244 Extended 302447 Center let (If Center Jetted)501813 T.J.Connection 6-51"(API Reg.) Recommended Make-Up Torque* 2800032000 Ft•lbs. Bit Weight(Boxed) 250 Lbs.(1 13 Kg.) Bit Breaker (Mat.#/Legacy#) 515353/506463 PRODUCT FEATURES " R"�► . New patented Diamond"Claw R tooth bit design. . Tungsten carbide'surf inserts in gage teeth for added gage protection. . Newly formulated,proprietary hardfacing on cutting structure and gage maximizes carbide and diamond volume for ultimate wear resistance. �+ - . High-speed bearing designed for high rpm and high-•energy ':, applications. "' . Innovative mechanical pressure compensating system provides reliable pressure equalization and relief for maximum bearing and seal lite. . Raised tungsten carbide inserts and proprietary hardfacing provides maximum arm protection in abrasive and directional applications while minimizing drill string torque. . QuadPackt Plus Series incorporates its successful"longevity" features and patented engineered hydraulics system for optimal cleaning efficiency. . Center jet feature to prevent bit balling problems Material#622394 'C'alculations cased on recommendations from API and tool-joint manufacturers. C 2012 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. Page 17 Version 0 July, 2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcor 11.4 4-1/2" Workstring & HWDP will come from Saxon. Jars will come from Weatherford. 11.5 Begin drilling out from 16"conductor at reduced flow rates to avoid broaching the conductor. 11.6 Drill 12-1/4" hole section to 3,500' MD/3,497 TVD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 500 - 550 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. • TD the hole section in a good shale between 3400' MD and 3600' MD. • Take MWD surveys every stand drilled(60' intervals). 11.7 12-1/4" hole mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system(1)ppg above highest anticipated MW. We will start with a simple gel +FW spud mud at 8.8 ppg. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 8.8—9.5 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Depths ensity Viscosity Plastic Viscosity Yield Point API FL pH 80-3500' ' 8.8-9.5' 85-150 20-40 25-45 <10 8.5-9.0 Page 18 Version 0 July, 2014 Beaver Creek#25 111 Drilling Procedure Rev 0 Hilcoor amy System Formulation: Aquagel + FW spud mud Product Concentration Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL 12-15 ppb caustic soda 0.1 ppb (9 pH) BARAZAN D+ as needed BAROID 41 as required for weight PAC-L/DEXTRID LT if required for<12 FL ALDACIDE G 0.1 ppb X-TEND II 0.02 ppb 11.8 At TD; pump sweeps, CBU, and pull a wiper trip back to the 16" conductor shoe. 11.9 TOH with the drilling assy, handle BHA as appropriate. 11.10 No open hole logs are planned for the 12-1/4"hole section. ' Page 19 Version 0 July,2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp Energy Company 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull 15.375"wearbushing. 12.2 R/U Weatherford 9-5/8" casing running equipment. • Ensure 9-5/8" BTC x CDS 40 XO on rig floor and M/U to FOSV. • R/U fill-up line to fill casing while running. • Ensure all casing has been drifted on the location prior to running. • Be sure to count the total#of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U &thread locking shoe track assy consisting of: • (1) Shoe joint w/float shoe bucked on (thread locked). • (1) Joint with coupling thread locked. • (1) Joint with float collar bucked on pin end&thread locked. • Install (2) centralizers on shoe joint over a stop collar. 10' from each end. • Install (1) centralizer, mid tube on thread locked joint and on FC joint. • Ensure proper operation of float equipment. 12.5 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use"API Modified"thread compound. Dope pin end only w/paint brush. • M/U connections to the base of the triangle stamped on the pin end. Note M/U torque values required to achieve this position. Estimated torque to reach base of triangle: 10,750 ft-lbs. • After making up several connections, use the torque required to M/U to base of triangle as the M/U torque and continue running string. • Install (1) centralizer every other joint to 300'. Do not run any centralizers above 300' in the event a top out job is needed. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 9-5/8" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 9-5/8" 9,630 ft-lbs Page 20 Version 0 July, 2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp Energy COY Tenaris Casing and Tubing Performance Data Choose pipe size,wall thickness and steel grade to view API connection options and performance data. Size - Wall Grade Connection V Unit Pipe Body Data GEOMETRY Nominal OD 9.625 in Wall Thickness 0.395 in API Drift Diameter 8.679 in Nominal Weight 40.00 ibsift Nominal ID 8.835 in Alternate Drift Diameter 8.75 in Plain End Weight 38.97 lbstft Nominal Cross Section 11.454 sq in PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95.000 psi Body Yield Strength 916,000 lbs Internal Yield Pressure 5,750 psi Collapse Pressure 1080 psi • m 1— Connection Data GEOMETRY Regular OD 10.625 in Threads Per Inch 5 Make-Up Thread Turns 1 PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Joint Strength 947,000 lbs Internal Pressure 5,750 psi Resistance TenarisHydril Premium Connections rPrint I Contact Us Ver 8.6 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.7 Slow in and out of slips. 12.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at(1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. Page 21 Version 0 July,2014 Beaver Creek#25 II Drilling Procedure Rev 0 Hilco r 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. Page 22 Version 0 July,2014 Beaver Creek#25 111 Drilling Procedure Rev 0 HilEnmity corp 13.0 Cement 9-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. 13.2 Document efficiency of all possible displacement pumps prior to cement job 13.3 R/U cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.4 Pump 5 bbls 10 ppg spacer. Test surface cmt lines. 13.5 Pump remaining 30 bbls of 10 ppg spacer. 13.6 Drop bottom plug. Mix and pump cmt per below recipe. 13.7 Cement volume based on annular volume+ 50%open hole excess. Job will consist of lead& tail, TOC brought to surface. -� Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol(ft3) 12.0 ppg LEAD: 80' x .129 bpf= 10.3 57.8 16" Conductor x 9-5/8" casing annulus: 12.0 ppg LEAD: (3000' —80') x .0558 bpf x 1.5 = 254.4 1372 12-1/4" OH x 9-5/8" Casing annulus: Total LEAD: 254.7 bbl 1429.8 ft3 5`O "- TAIL: (3500'-3000') x .0558 bpf x 1.5 = 41.9 235.3 12-1/4" OH x 9-5/8" Casing annulus: TAIL: 90 x .096 bpf = 8.7 48.8 9-5/8" Shoe track: Total TAIL: 50.6 bbl 284.1 ft3 3 Page 23 Version 0 July,2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp Energy Company Cement Slurry Design: Lead Slurry (3000' MD to surface) Tail Slurry (3500'to 3000' MD) System Extended Conventional Density 12 lb/gal 15.4 lb/gal Yield 2.46 ft3/sk v 1.22 ft3/sk ✓ Mixed Water 14.349 gal/sk 5.507 gal/sk Mixed Fluid 14.469 gal/sk 5.507 gal/sk Code Description Concentration Code Description Concentration G Cement 94#/sk A Cement 94#/sk D110 Retarder 0.15 gal/sk BWOC D046 Anti Foam 0.2% BWOC Additives D046 Anti Foam 0.2% BWOC D065 Dispersant 0.4% BWOC D079 Extender 2.0% BWOC S002 CaCl2 0.35%BWOC D020 Extender 3.0% BWOC D177 CaCl2 0.1% BWOC 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug and displace cement with 9.0 ppg 6%KCL PHPA. 13.10 Ensure cement unit is used to displace cement so that volume tracking is more accurate. 13.11 Displacement calculation: 3500'- 80' = 3420' x .0758 bpf=259.2 bbls 13.12 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sacks of sugar available to retard setting of cement. Page 24 Version 0 July,2014 Beaver Creek#25 II Drilling Procedure Rev 0 Hilar Enemy 13.13 Do not overdisplace by more than %2 shoe track volume. Total volume in shoe track is 8.7 bbls. • Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log between 12— 18 hours after CIP. • Be prepared with small OD top out tubing in the event a top out job is required. The AOGCC will require us to run steel pipe through the hanger flutes. The ID of the flutes is 1.5". 13.14 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold,pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.15 R/D cement equipment. Flush out wellhead with FW. 13.16 Back out and L/D landing joint. Flush out wellhead with FW. 13.17 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.18 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail, volume&weight • Pump rate while mixing,bpm,note any shutdown during mixing operations with a duration • Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement,actual displacement volume,whether plug bumped&bump pressure, do floats hold • Percent mud returns during job,if intermittent note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Send final "As-Run"casing tally &casing and cement report to mmyers@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 25 Version 0 July,2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp Energy Company 14.0 BOP N/U and Test 14.1 N/D the diverter. 14.2 N/U Seaboard multi-bowl wellhead assy. Install 9-5/8"packoff P-seals. Test to 3000 psi. 14.3 N/U 11"x 5M T3-Energy BOP as follows: • BOP configuration from Top down: 11"x 5M T3-Energy annular BOP/11"x 5M T3-Energy Model 6011i double ram/11"x 5M mud cross/11"x 5M T3-Energy Model 6011i single ram • Double ram should be dressed with 2-7/8 x 5"VBRs in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8 x 5" VBRs • N/U bell nipple, install flowline. • Install (2)manual valves&a check valve on kill side of mud cross. • Install (1)manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.4 Run 4-1/2" BOP test assy, land out test plug(if not installed previously). • Test BOP to 250/3500 psi for 10/10 min. Test annular to 250/2500 psi for 10/10 min. • Ensure to leave"B" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 9.0 ppg 6%KCL PHPA mud system. 14.8 R/U mud loggers for production hole section. 14.9 Set 10"ID wearbushing in wellhead. 14.10 Rack back as much 4-1/2"DP in derrick as possible to be used while drilling the hole section. Page 26 Version 0 July,2014 Beaver Creek#25 Drilling Procedure Rev 0 xdoor 15.0 Drill 8-1/2" Hole Section 15.1 P/U 8-1/2"directional GeoPilot BHA. 15.2 Ensure BHA components have been inspected previously. 15.3 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.4 TF offset is measured accurately and entered correctly into the MWD software. 15.5 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. 15.6 Workstring will be 4.5" 16.6# S-135 CDS40. Page 27 Version 0 July,2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp Energy Company 15.7 8-1/2" BHA: HALLIBURTON I gam°"""+`""'r'"'"' WELL INFORMATION Created On:Aug 25 201: BHA TallCustomer : Hilcorp y Well Name : BC-25 8.5 RSS BHA Job Number : AK-XX-1111111111 Rig Name : Saxon 169 IADC Rig BHA# 0100 Field Name : Beaver Creek Run# 100 Country : USA COMPONENT DA Item Descriptioni 1 "M c Vfl1 " T y laetglly uiriiehi" . t # ) rtalNumber (in) (in) (in) (Ibpf) Connect`* (ft) Length (4, 1 HEMS MMD74D PDC 6.750 2.750 8.50) 101.71 8 4-112'IF 1.20 120 Stabilizer 8.500 2 Geo-Pilot 7600 7.625 1.490 8.375 113.00 B 4-1.2'IF 23.20 24.40 Ref Housing Stabilizer 8.375 3 6 314'DM Geo Collar(Directional) 6.750 2.875 99.83 B 4-12'IF 9 20 33.60 6-314'Smart Stabilizer 6.750 1.920 8.375 112.09 B 4-12'IF 3.00 36.60 5 6 34'AFR Collar 6.750 1.920 102 60 8 NC 50 10.75 47.35 Stabilizer 8.320 Stabilizer 8.320 6 6-34"Inline Stabilizer(ILS) 6.750 1.920 8.375 112.09 B 4-1/2'IF 3.00 50.35 7 6 34'DGR Collar(Gamma) 6.750 1.920 97.80 B NC 50 4.55 54.90 8 6 3!4'EWR-P4 Collar(Resistivity) , 6.750 2.000 104.30 B NC 50 12.10 67.01 9 6 314'PWD(Pressure) 6.750 1.905 112.24 B 4-1/2"IF 443 71.44 10 6 34"HCIM Collar(Processor) 6.750 1.920 112.09 B 4-112'IF 6.85 78.29 11 6 3,4"ALD Collar(Density) 6.750 1.920 8.250 104.30 B 4-1/2'IF 14.23 92.52 Stab:'iter 8.250 12 6 3'4"CTN Collar(Porosity) 6.750 1.905 102.30 B 4-112'IF 13.86 106.38 13 6-314"Inline Stabilizer(ILS) 6.770 1.920 8.250 112.81 B 4-112"IF 4.00 110.38 14 6 3/4'HOC(Telemetry) 6.750 2.870 99.91 B 4-1!2'IF 10.05 120.43 15 6 314"BAT Rec Collar IAcoust.cl 6.750 1.920 112.09 B 4-112'IF 22.04 142.47 Stabilizer 7.750 - Stabilizer 7.750 16 6-3i4"Non Mag Float Sub 6.650 2.812 97.20 B 4-1!2"IF 2 CO 144.47 17 6-34'Non .laq Flex Drill Collar 6.750 2.813 100.77 B 4-1J2'IF 30.00 174.47 18 6-3/4'Non Mag Flex Drill Collar 6.750 2.813 100.77 B 4-1/2'IF 30.00 204.47 19 6-3/4'non Mag Flex Drill Collar 6.750 2.813 100.77 B 4-1!2"IF 30.00 234.47 20 6 Joints 5"HWDP 5.000 3.000 49.30 180.00 414.47 21 6.25"Weatherford Jar 6.500 2.750 88.24 B 4-112"IF 30.00 444.47 22 14 Joints 5'HW DP 5.000 3.000 49.30 420.00 864.47 P:;14-./4*) ,. e 54.47 Page 28 Version 0 July, 2014 Beaver Creek#25 Drilling Procedure Rev 0 lcorp ecummy 15.8 Primary Bit: HALLIOURTON 8-1/2" (216mm) MME65D PRODUCT SPECIFICATIONS Cutter Type SelectCutter IADC Code M422 t I: Body Type MATRIX I Total Cutter Count 60 ja ! ^tr Cutter Distribution 13mm 16mm •°' >"*""' Face 11t Gauge 9 0 °, Up Drill 6 0 Number of Large Nozzles 0 Number of Medium Nozzles 0 ar Number of Small Nozzles 6 . ► It Number of Micro Nozzles 0 Number of Potts(Size) 0 �x Number of Replaceable Ports(Size) 0 Junk Slot Arca Isq in) 14.31 Normalized Face Volume 50.49% : API Connection 4-1.2 I.F.PIN Recommended Make-Up Torque' 23,743 FNlbs. Nominal Dimensions** •+ Make-Up Face to Nose 11.23 in-285 mm Gauge Length 2.5 in-64 mm Sleeve Length 0 in-0 mm Shank Diameter 6.5 in-165 mm Break Out Plate(Malta;Legacya) 18195444040 Approximate Shipping Weight 160Lbs.-73Kg. SPECIAL FEATURES TSP Gage.Optimized Dual Row-"D"Feature,EDL Tool Specific Gage,Combination Up-Drill•'Back Reamer Cutters Material#901009 "Bit specific recommended make-up torque is Is function of the bit I.D.and actual bit sub O.D.utilized as specified is API RP7ti Section A.11.2. ••Design dimensions are nominal and may vary slightly on manufactured product Nallborton Drill Bits and Services models are continuously reviewed and refined. Product specifications may change without notice. C 2014 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www.halliburton.corn Page 29 Version 0 July, 2014 Beaver Creek#25 Drilling Procedure Rev 0 Hmilcar no 15.9 8-1/2"hole section mud program summary: Weighting material to be used for the hole section will be salt and calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1)ppg above highest anticipated MW. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.0 ppg 6%KCL PHPA fresh water based drilling fluid. Properties: MD Mud Plastic Viscosity Yield Point pH HPHT Weight Viscosity 3500'-9;675' 9.0— 10.0 40-53 15-25 15-25 8.5-9.5 < 11.0 070 AA 9 3 K,pae. -•/-it-<it•f .46je System Formulation: 6/o KCL EZ Mud DP Product Concentration Water 0.905 bbl KCI 22 ppb (29 K chlorides) Caustic 0.2 ppb (9 pH) BARAZAN D+ 1.25 ppb (as required 18 YP) EZ MUD DP 0.75 ppb(initially 0.25 ppb) DEXTRID LT 1-2 ppb PAC-L 1 ppb BARACARB 5/25/50 15-20 ppb(5 ppb of each) BAROID 41 as required for a 9.0-10.5 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb (maintain per dilution rate) 15.10 TIH w/ 8-1/2"directional assy to TOC. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. s6" FS�Z 15.11 R/U and test casing to_3_0_0_0_ si/30 min. Ensure to record volume/pressure and plot on FIT graph. AOGCC reg is 50%or burst. 15.12 Drill out shoe track and 20' of new formation. 15.13 CBU and condition mud for FIT. Page 30 Version 0 July,2014 Beaver Creek#25 11 Drilling Procedure Rev 0 Hilc_orp 15.14 Conduct FIT to 11 ppg EMW. Note: Offset field test data predicts frac gradient at the 9-5/8"shoe to be btwn 15- 16 ppg EMW. An 11 ppg FIT results in a 2 ppg kick margin while drilling with the planned MW of 9 PPg• Z J �/�Z' -a sS (2-1(_7--) 15.15 Drill 8-1/2"hole section to 8,200' MD/ 5,289 TVD qv• BHL is 1570' West from Unit boundary, DO NOT OVERSHOOT BH TARGET! V • We will Geosteer withAzimuthal gamma to stay in the upper 10' of the B4ST • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 400 - 500 gpm. Ensure shaker screens are set up to handle this flowrate. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. • Take MWD surveys every other stand drld. Surveys can be taken more frequently if deemed necessary. 15.16 At TD; pump sweeps, CBU, and pull a wiper trip back to the 9-5/8" shoe. 15.17 TOH with the drilling assy, laying down drill pipe and BHA. 15.18 Install 5-1/2"pipe rams in BOP stack and RU and test. Page 31 Version 0 July,2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp Energy Company 16.0 Run 5-1/2" Production Casing 16.1. R/U Weatherford 5-1/2" casing running equipment. • Ensure 5-1/2" DWC/C HT x CDS 40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted prior to running. • Be sure to count the total#of joints before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor& model info. 16.2. P/U shoe joint,visually verify no debris inside joint. 16.3. Continue M/U&thread locking shoe track assy consisting of: • (1) Shoe joint w/shoe bucked on &threadlocked (coupling also thread locked). • (1)Joint with float collar bucked on pin end&threadlocked (coupling also thread locked). • Solid body centralizers will be pre-installed on shoe joint an FC joint. • Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe and float collar. • Utilize a collar clamp until weight is sufficient to keep slips set properly 16.4. Continue running 5-1/2"production casing • Fill casing while running using fill up line on rig floor. • Use"API Modified"thread compound. Dope pin end only w/paint brush. • Install solid body centralizers on every joint across zones of interest, TBD after LWD. • Install solid body centralizers on every other joint to 9-5/8" shoe. Leave the centralizers free floating. • Pick up swell packer and place in string at approximately 3000'. 16.5. Continue running 5-1/2"production casing 5-1/2" DWC/C HT M/U torques Casing OD Minimum Maximum Yield Torque 5.5" 12,000 ft-lbs 13,800 ft-lbs 18,700 ft-lbs Page 32 Version 0 July, 2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp Energy company Technical Specifications Connection Type: stze(O.D.): Weight(Wall): Grade: DWC/C-HT Casing 5-1/2 in 17.00 lb/ft(0.304 in) P-110 standard Material P-110 Grade 110,000 Minimum Yield Strength (psi) 411111111111111111111111rS►U SA 125.000 Minimum Ultimate Strength (psi) VAM USA 4424 W.Sam Houston Pkwy.Sute 150 Pipe Dimensions Houston.TX 77041 Phone:713-479-3200 5.500 Nominal Pipe Body O.D. (in) Fax:713-479-3734 4.892 Nominal Pipe Body I.D.(in) E-mail:VAMUS.Asalestvam-usa.com 0.304 Nominal Wall Thickness(in) 17.00 Nominal Weight(Ibstft) 16.89 Plain End Weight(Ibstft) • 4.962 Nominal Pipe Body Area(sq in) Pipe Body Performance PropertiesI, 546,000 Minimum Pipe Body Yield Strength(lbs) 7,480 Minimum Collapse Pressure(psi) 10,640 Minimum Internal Yield Pressure(psi) ', 9,700 Hydrostatic Test Pressure (psi) Connection Dimensions 6.050 Connection O.D. (in) 4.892 Connection I.D. (in) 4.767 Connection Drift Diameter(in) {;y 4.13 Make-up Loss(in) ' 4.962 Critical Area(sq in) 100.0 Joint Efficiency(%) Connection Performance Properties 546,000 Joint Strength (lbs) • 22,940 Reference String Length(ft) 1.4 Design Factor 568,000 API Joint Strength (lbs) ' 546,000 Compression Rating (lbs) ' 7,480 API Collapse Pressure Rating (psi) 10,640 API Internal Pressure Resistance (psi) 91.7 Maximum Uniaxial Bend Rating [degrees/100 ft) Appoxlmated Field End Torque Values 12,000 Minimum Final Torque (ft-lbs) 13,800 Maximum Final Torque(ft-lbs) 18,700 Connection Yield Torque (ft-lbs) For detailed information on performance properties.refer to DWC Connection Data Notes on following page(s). Page 33 Version 0 July, 2014 Beaver Creek#25 II Drilling Procedure Rev 0 Hilcar 16.6. Run in hole w/ 5-1/2" casing to the 9-5/8"casing shoe. 16.7. Fill the casing with fill up line and break circulation every 1,500 feet to the window or as the hole dictates. 16.8. Obtain slack off weight,PU weight, rotating weight and torque of the casing. 16.9. Circulate 2X bottoms up at shoe, ease casing thru shoe. 16.10. Continue to RIH w/casing no faster than 1 jt./minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.11. Set casing slowly in and out of slips. 16.12. PU 5-1/2"X 8-1/2" swell packer to be placed at approximately 3000'. Swell packer should have 10' handling pups installed on both ends with bow spring centralizers on pups. 16.13. Swedge up and wash last 2 joints to bottom. P/U 5' off bottom. Note slack-off and pick-up weights. 16.14. Stage pump rates up slowly to circulating rate. Circ and condition mud with casing on bottom. Circulate 2X bottoms up or until pressures stabilize and mud properties are correct and the shakers are clean. Reduce the low end rheology of the drilling fluid by adding water and thinners. 16.15. Reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 34 Version 0 July,2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp Energy Company 17.0 Cement 5-1/2" Production Casing 17.1. Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud&water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 17.2. Attempt to reciprocate the casing during cmt operations until hole gets sticky 17.3. Pump 5 bbls of 12.5 ppg Mud Push spacer. 17.4. Test surface cmt lines to 4500 psi. ✓ 17.5. Pump remaining 30 bbls 10.5 ppg Mud Push spacer. 17.6. Mix and pump lead and tail cement per below recipe. Ensure cement is pumped at designed weight. Job is designed to pump 35%OH excess. Section: Calculation: (BBLS) Vol(ft3) 9-5/8"x 5-1/2" Csg Overlap: 500' x 0.0464= 23.2 130.4 8-1/2"OH x 5-1/2" Casing: (8200—3500)x 0.0408 x 1.35 = 258.9 1453.6 Shoe Track: 80' x 0.02325 = 1.9 10.4 Total Volume : 284.0 1594.5 1`7 z St Page 35 Version 0 July, 2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilo EASYBLOK (8200' to 3000') System Conventional Density 15.3 lb/gal Yield 1.36 ft3/sk Mixed Water 5.93 gal/sk Mixed Fluid 5.93 gal/sk Code Description Concentration Class G Cement 94#/sk D046 Foam Preventer 0.2% BWOC D202 Dispersant 1.5% BWOC Additives D400 EASYBLOK 0.8%BWOC D154 Extender 8.0%BWOC D174 Expanding Additive 1.5%BWOC D198 Retarder 0.3%BWOC 17.7. Drop wiper plug and displace with produced water. 17.8. If hole conditions allow— continue reciprocating casing throughout displacement. This will ensure a high quality cement job with 100%coverage around the pipe. 17.9. If elevated displacement pressures are encountered, position casing at setting depth and cease reciprocation. Monitor returns&pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 17.10. Bump the plug and pressure up to 500 psi over final lift pressure. Hold pressure for 3 minutes. 17.11. Do not overdisplace by more than Y2 shoe track. Shoe track volume is 1.9 bbls. Page 36 Version 0 July, 2014 Beaver Creek#25 11 Drilling Procedure Rev 0 Hcorp Ena CoenPsnY 17.12. Bleed pressure to zero to check float equipment. Watch for flow.Note amount of fluid returned after bumping plug and releasing pressure. 17.13. RD cementers and flush equipment. 17.14. WOC minimum of 12 hours,test casing to 3000 psi and chart for 30 minutes. Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing,bpm, note any shutdown during mixing operations with a duration • Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement,actual displacement volume, whether plug bumped&bump pressure,do floats hold • Percent mud returns during job,if intermittent note timing during pumping of job.Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Send final "As-Run"casing tally&casing and cement report to mmyers@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 37 Version 0 July,2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcor 18.0 RDMO 18.1. Install BPV in wellhead 18.2. N/D BOPE 18.3. N/U temp abandonment cap 18.4. RDMO Saxon Rig#169 ei/(rt P Page 38 Version 0 July,2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp Energy Company 19.0 BOP Schematic III Iii III III III 1i1 11112 3.5, (5' Mndei 60111 It, iii lil till oil lli ......• ...._„: _,,,.. 3.0;]' Il a i�#' 1 3 riergy I ',WA �_ �L '+V Madel70E2 - Ill 11"S iJG y a.- aJ—' v_ or r IRI 111111 It" 111 2.00' • 1 FA.0 41 1! f• , _ -ft i r ' . 17. * °:41! . :,,,,,L IRI IRI 1111111 1St 2 1/16 SM Kill Side " 3 1/8 5M Choke Side T-3 Ene _ . _ _ 1.41' :— C..,i'MoModel7a82 ON —_ ttn Ill III IRI ISI Grade 2.1:,:rd til 111 1!1 foil Iii illi.,-77..-- j . rii,......:0 ama .ink : :vt...,414 :4° MI4111111_ IMP j, 111111111i1111 II I r - i,1«, 5/8" Page 39 Version 0 July,2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp Enotgy ConMIRY 20.0 Wellhead Schematic Beaver Creek New Drill-Saxon 169 16 X95/8 X51/2 Tree cap,Otis,51/8 5M FE X 9 X Otis Quick Union 11111 014 Valve,Swab,WKM-M, ..�.. ,§ - 51/85M FE,HWO, DD trim 5�/ .> VV.; 1111111111.13,„ Valve,Wing,WKM-M, °1., "A Valve,Wing,WKM-M, 31/8 SM FE,HWO, / �°+:ro �p.g 31/B SM FE,HWO, DD trim ° + ,_ . " DD trim Valve,Upper Master, WKM-M,5 1/8 5M FE,HWO, ��- DD trim L`�' Crossover spool, 5 1/8 5M FE X 5 1/8 10M FE ''.66'6Q1 .T Valve,Master,CIW-FC, C 51/810M FE,HWO, tu !' EE trim Ni •• _-_ R r Mr= e lei IP Tubing head,Seaboard-S8, Ig ` 163/43MX 115M, ,6"a �;J w/2-2 1 SSm 9 5/8 P sealeal bottom Starting head,Seaboard, 16X3MX 16"SOW BTM, ' 4. w/2-21/165M SSOf'1 �•'e SoT':44 'le.. •. 16"I, 9 5/8" S W' Page 40 Version 0 July, 2014 Beaver Creek#25 Drilling Procedure Rev 0 HilEDNITYo 21.0 Days Vs Depth Days Vs Depth 0 - -BEBver Creek 25 1000 -- - 2000 3000 -- — — X 4000 ---- - — r 5000 6000 -- — — 7000 — 8000 — -- 9000 --- 0 5 10 15 20 25 30 Days Page 41 Version 0 July, 2014 Beaver Creek#25 int Drilling Procedure Rev 0 Hilcorp F.ncrgy Company 22.0 Geo-Prog GEOLOGICAL PROGNOSIS WELL NAME: BCU 25 B4-Horizontal FIELD: k.Beaver Creek SURFACE X: 317473.8 )Alaska SURFACE Y: 2433936.3 1},'; (GR well from Pad 3) BHL X 319406.7 ND REF DATUM;KB BHL Y 2431486.0 ND REF ELEV '`',- 179 18.6'KB(Saxon 169) COORD REF. SYSTEM NAD27 GROUND ELEV 160.6 PROPOSED TD MD: 8200 PROPOSED TD TVD: 5289 Objective: Sterling B-4 Horizontal well Geo Summary/ .. Justification: The goal of the BCU 25 is to develop the B-4 sand. 30'of gas pay on water. The horizontal well will reduce drawdown and prevent the coning seen in several offset vertical producers I ANTICIPATED FORMATION TOPS&GEOHAZARDS EXPECTED Critical Intersection Point: TOP TOP NAME FORMATION FLUID MD TVD(FT) Est.Pressure X Y +/- SHALLOW_GAS1 Sand Gas 3025 3022 1200-1300 psi 317413.5 2434023.5 15 BC_B1ST Sand Gas 4869 4845 1900-2300 psi 317456.6 2433994.2 15 BC_B2ST Sand Gas 5038 4981 1900-2300 psi 317525.0 2433921.9 15 BC_B3ST Sand Gas 5201 5091 1900-2300 psi 317606.6 2433835.1 15 BC_B3-L_ST Sand Gas 5320 5154 1900-2300 psi 317675.8 2433761.2 15 BC_B4ST Sand Gas 5614 5245 1900-2300 psi 317865.4 2433558.1 15 TD 8200 leimir 5289 319406.7 2431486.0 =Primary Objective =Secondary Objective TARGET RADIUS 50 ft DATA COLLECTION REQUIREMENTS: Mud Logging: Full crew of 4 for production hole section. 2 sets of washed&dried samples collected every 20 ft from KOP to TD. Pixler plots ' LWD Data: Sperry Triple Combo-Geosteering package E-Line Log Data: COMPLETION TYPE ANTICIPATED RATES ARTIFICIAL LIFT EQUIPMENT OD TUBING SIZE 2-7/8" OTHER COMMENTS 1. SHL is an ESTIMATE! 2. We do not anticipate crossing any significant faults that would pose drilling problems. 3. BCU 14&01B drilled with 9.5 ppg mud through the Sterling and 9.3-9.9 ppg mud through the lower Beluga Page 42 Version 0 July, 2014 Beaver Creek#25 II Drilling Procedure Rev 0 Hilcor Estop 23.0 Anticipated Drilling Hazards 12-1/4" Hole Section: Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP btwn 25—45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole-cleaning problems. If encountered, be prepared to increase the viscosity. Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of—50 -—60 lbs/100ft2 to combat this issue. Maintain low flow rates for the intial 200' of drilling to reduce the likelihood of washing out the conductor shoe. To help insure good cement to surface after running the casing, condition the mud to a YP of 25 — 30 prior to cement operations. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheologies can be achieved. H2S: H2S is not present in this hole section. 't No abnormal pressures or temperatures are present in this hole section. Page 43 Version 0 July,2014 Beaver Creek#25 n _ Drilling Procedure Rev 0 Hile0,22 Emmy 8-1/2" Hole Section: Lost Circulation: Ensure 1000 lbs of each of the different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/viscosifier as necessary. Sweep hole w/20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP btwn 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain MW as necessary using additions of Calcium Carbonate as weighting material. A torque reduction lube may be used in this hole section in concentrations up to 3% if needed. Maintain 6%KCl in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt-type additives to further stabilize coal seams. • Increase fluid density as required to control running coals. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: H2S is not present in this hole section. No abnormal temperatures are present in this hole section. Page 44 Version 0 July, 2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp f acrgy Company 24.0 Saxon Rig 169 Layout N -_..r.:..,_ •1.. = IIII _ - IIIII F E T __II=I=I- Ej■ a1 ■ r71Yf■n ^�I�� •_ 1 [ EE �� I ■ ~�I� f I I lri� E N III':�.� IIII ..._.....1..r._, ___ter „..=.7... W T.. 1 •_ _ irl - ,� �---� �-� _ Ilii_ - �IlIII • . 3.. K. MMH• :.'i ■illlu 1 �� 1_ , t ulI ::, :, --71.1g..1; -5'45 i .nn4u1r, 11111111 11111011 . r .�— __ __ ita. i1 ,.. „„, I ■ Page 45 Version 0 July, 2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp Energy Company 25.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20'of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer(ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 46 Version 0 July,2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp E...C(.4Pm9 26.0 Choke Manifold Schematic ti 1 a 4 P _ !1y (---;-)m iy 4*) fi e 1 4:,,.., , 1 .1 ri ! ..... r• ,, _ _ c'''' 1141 ,t, labg i li - , , ' r;,.., is, n a m lo 4 �.I''a ly�0y� ,3 FFF++++ L � r r r A ev r rt� — f- AJ‘ p—, i is # -......,-0,...� wi ,R rl 11 MEM f�� `" aiIlIwo II!�y } n f'.' �� 6 Awl I/ r $ P II t filt! ill Itrit:•.. ,:-‘,4.11r..." li I4 1! A + b !I Ff i! 8 l L.' 0 1IR 771? iI cI r lit 144 Page 47 Version 0 July,2014 Beaver Creek#25 111 Drilling Procedure Rev 0 Hilcorp Encrgy Company 27.0 Casing Design Information Calculation&Casing Design Factors Beaver Creek Unit DATE:8/25/2014 WELL: Beaver Creek#25 FIELD: Beaver Creek DESIGN BY: Monty M Myers Design Criteria: Hole Size 12-1/4" Mud Density: 8.8 ppg Hole Size 8-1/2" Mud Density: 9.0 ppg Hole Size Mud Density: Drilling Mode MASP: 1180 psi(see attached MASP determination&calculation) MASP: Production Mode MASP: 1771 psi (see attached MASP determination&calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.435 psi/ft)and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 I 2 3 4- Casing OD --_.._.._._..._ 9-5/8" 1 5-1/2"� —....._..._._......_,.___._ Top(MD) ._. _._.. 0 0 i Top(TVD). _ Bottom(_MD) _ 3,500 8,200 r.___..._._.. Bottom _......D 3,497 5,289 ,,,__ Length 3,500 8,200 I W eightjppf) 40 17 Grade L-80 P-110 Connection BTC DWC/C HT Weight w/o Bouyancy Factor lbs) 140,000 139,400 Tension at Top of Section(lbs) 140,000 139,400 I — Min strength Tension(1000 lbs)_ 916 546 Worst Case Safety Factor(Tension) 6.54 3.92 Collapse Pressure at bottom(Flil 1,521 2,301 Collapse Resistance w/o tension,(Psi)_ _ 3,090 7,480 Worst Case SafetyFactor Colla se 2.03 3.25 '• r_••_••••_•__ MASP(psi) 1,040 1,771 Minimum Yield(psi) 5,750 10,640 Worst case safety factor(Burst) 5.53 6.01 Page 48 Version 0 July, 2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp Energy Company 28.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 8-1/2"Hole Section Hilcorp Beaver Creek#25 Beaver Creek Unit MD TVD Planned Top: 0 0 Planned TD: 8200 5289 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Shallow Gas 3022 1300 WATER/GAS 8.3 0.430 BC_B1ST 4845 2100 WATER/GAS 8.3 0.433 BC_B2ST 4981 2150 WATER/GAS 8.3 0.432 BC_B3ST 5091 2200 WATER/GAS 8.3 0.432 BC_B3-L_ST 5154 2225 GAS 8.3 0.432 BC_B4ST 5245 2275 GAS 8.3 0.434 TD 5289 2300 GAS 8.4 0.435 Offset Well Mud Densities Well MW range Top(TVD) Bottom(TVD) Date Beaver Creek 18 9.2-9.9 ppg 5,200 10,900 2014 Beaver Creek 11 8.8-9.6 ppg 400 8,684 2003 Beaver Creek 13 8.5-10.4 ppg 0 10,182 2003 Beaver Creek 14A 9.0-9.4 ppg 5,000 9,450 2014 BeaverCreek7A 9.0-9.3 2,400 8,929 2014 Beaver Creek 12A 9.0-9.4 4,500 9,578 2014 Assumptions: 1. Fracture gradient at shoe is estimated at 0.65 psi/ft based on field test data. 2. Maximum planned mud density for the 8-1/2"hole section is 9.5 ppg. 3. Calculations assume"Unknown"reservoir contains 100%gas(worst case). 4. Calculations assume worst case event is 100%evacuation of wellbore to gas. (� . K‘ CC ft Fracture Pressure at 9-5/8"shoe considering a full column of gas from shoe to surface: .-c7 3497(ft)x 0.65(psi/ft)= 2273 psi • 2273(psi)-[0.1(psi/ft)*3497(ft))= 1923 psi MASP from pore pressure(unknown gas sand at TD,at 8.4 ppg,encountered while drilling) 5,289(ft)x 0.435(psi/ft)= 2300 psi 2300(psi)-[(2/3)*0.1(psi/ft)*5289(ft)]+[(1/3)*0.435(psi/ft)*5289(ft)]= 1180 psi MASP from pore pressure during production mode(Complete evacuation to gas) ` , i 5,289(ft)x 0.435(psi/ft)= 2300 psi 2300(psi)-[0.1(psi/ft)*5289(ft)]= 1771 psi Summary: 1. MASP while drilling 8-1/2"production hole is governed by pore pressure and evacuation of 2/3 wellbore to gas at 0.1 psi/ft. Page 49 Version 0 July, 2014 Beaver Creek#25 Drilling Procedure Rev 0 E orp Cps 29.0 Spider Plot (NAD 27) (Governmental Sections) 1 i I 1 I KJ Legend & BCU 03RD 8HL s Other Surface Well Locations • Other Bottom Hole Locations I Well Paths BC).1005 BHL k BCU'B,glil* ' Oil and Gas Unit Boundary BCU,05RatiHt., BCU 11 BHt7• ,/� / / L t r / A028083 �'`� ________ S007N010W ,, i ,` BCU 25 SHL1 BCU 12-BF - acGoaB1 ,�bo ` _ }� . %,„.. [BCU 25 TPHj r1 \ BCu 06 X14 4 O BEAVER CREE UNIT NBCU 13 BA kiD BCU 19 BHLZ o to BCU 09BHL" t 0 BCU 14 BHL-BCU 14A B HL oQ ' / @3BCU 16 BHL), * /BCU 25 BHLj / 1 Bcu-16RD 844L° l4& 6/ I)b� 7t BC,!OlA BHL- BCU 1.5 BH.:,'� ``•-.,.,,` BCU 01B BCU 02 Blit.* BCU 07A 0L SOO6N01 OW__--- ---- BCU . BCU 07 BHL__ 4' ° A028118 @ f• I Page 50 Version 0 July, 2014 Beaver Creek#25 li Drilling Procedure Rev 0 Hilcorp Ery Company 30.0 Surface Plat (As Staked) (NAD 27) _._ - _ __ SECTION 34 T7N RUM SM,AK { I y `` �� II B.C.U.NO.25 IP s r, AS-STAKED 1 BEAVER CREEK UNIT N:2433936.29 .,. i '''''1 PAD 3 •�, E:317473.83 'L 4 . „ ' LAT:60'397'9.694'N 1 1.,_ ,.Ge"„,,,�" , / LONG:-151'01'02.615W �, I I -• .,,•": / NAD27 ASP Zone 4 / "e / ELEV:160 5' • 58 �/ •,.",w„ ,,,,,.., / NAVD88 °''"""` 1656'FWL 1F81YL ,\ ,<? ,. 7` 1246'FNL • - 4� NOTES .......-.-il Il BASIS OF GEODETIC CONTROL AND NAD83 POSITION(EPOCH 200311$AN OPUS SOLUTION FROM NGS COORDINATES STATIONS'KENT CORS ARP'.'TLKA TALKEETNA CORS ARP',AND 7073 POTATO POINT 3 ARP'TO ESTABLISH THE POSITION OF MCI BCT THE GEODETIC POSITION OF 001 WAS DETERMINED TO HAVE A LATITUDE OF 66'36'50 0271114 ANDA LONGITUDE OF 151'0222.30311 W.THE ALASKA STATE PLANE ```0. 111 L 1 COORDINATES(ASP)ZONE 4 ARE ••"4.,i,„.9-f-444++i !-:. 64.2429933.534 ,sp -.Srt, E=1453863065 co./- ELEV.131.31'(MAVD881 rn 9 /4 * NORTH ., I, - •.�++ 2)BASIS OF VERTICAL CONTROL IS NGS BM V81 F.,..• Vl• 744,44/21"...: - _- PIO T70506 LOCATED WITHIN THE KENAI SPLOl . .;AN A. i� ,� 4637-5 } HIGHWAY RIGHT OF WAY AT MILE POST 3.75 ,'s..,6/25/14u.A HAVING AN ELEVATION OF 164 55 FEET NAVD Ott �tTs�;,001.::.— , 8B ACCORDING TO NGS PUBLISHED DATA. ++1111V..r. I S()1LE 1 3)COORDINATES COVERTED TO HAD 27 USING CORPSCON CONVERSION SOFTWARE BCU $25 WELL AS-STAKED SURFACE LOCATION (NAD27) BEAVER CREEK UNIT PAD 3 ENGINEERING-TESTING + ATION:SECTION 34, TOWNSHIP 7 NORTF- SURVEYING-MAPPING P.o.Bax 468 ,.NGE 13 WEST,SEWARD F ERID)AN AL;%. 11.1,„rp ‘1. k. lit SOLDOTNA,A.K.99669 JOB NO. 143117 VOICE:(907)283-4218 228 34218 em_- FAX DRAWN 1W Consultinp Inc WWW.MCLANECG.COM rnsm DATE:8/25114 AGURE:1 Page 51 Version 0 July,2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp Energy Company 31.0 Surface Plat (As Staked) (NAD 83) 2434969 10 ' . • ' SECTION LINE NOT 1.:0 SCALE • • -- ' ' —i. ' ' — ' ' — ' • -- • • — 1455858.89 E 9 1 •1 I SECTION 34 T7N R1OW SM.AK vz L. tj .... t BEAVER CREEK UNIT k • \ PAD 3 , ` B.C.U.NO.25 r` I 4 z � AS-STAKED • 1 ,,,,,,,,,.•+ • a....� / N:2433697,18 1S / E:1457494.99 ° Y 6 / LAT:60°3927.647'N 5.:,�... I • ,..�• / LONG:-151°01'10.631'1N I\ / NAD83 ASP Zone 4 FWL 4 \ .1l. .. 7 ELEV.180.5' ,�i NAVD88 • /'. •�m r,.-Is 1656'FWL / I �N -.-• 1246'FNL I f . / � 'N``� ---/ NOTES 11 BASIS OF GEODETIC CONTROL AND NAD63 POSITION(EPOCH 2003)IS AN OPUS SOLUTION FROM NGS COORDINATES • STATIONS`KENI CORS ARP','TLKA ( TALKEETNA CORS ARP-.AND'POT3 POTATO POINT 3 ARP'TO ESTABLISH THE POSITION OF IX'BC 1.THE GEODETIC POSITION OF BC1 WAS DETERMINED TO HAVE A LATITUDE OF ``• `\\%%%%%I 60'3850.02777'N AND A LONGITUDE OF I OF 4J, —.'"7".''"--------:--::::7---. w 15110222 30311WTFC ALASKA STATE PLANE �P�; 5�P7 COORDINATES IASP12OI4E 4 ARE Gj� '�yS.I N42428933534 • -+•i4 721 .4,! NORTH E.1453863.035 • %^ i ,�,{G,I wuri"",i _-� ELEV 131.31'(NAVDS81 1 .. `STAN A.YcLAK l -..� 2) BASIS OF VERTICAL CONTROL IS NOS BM V80 44 -S /It s/isi11y PID TIMOR LOCATED WITHIN THE KENAI SPUR • �t '0004...... /°�` i •I HIGHWAY RIGHT OF WAY AT ME POST 3.75 • I111 i I,N% I S.C,LI F I HAVING AN ELEVATION OF 184.55 FEET NAVD Y\\\� 68 ACCORDING TO NGS PUBLISHED DATA. BCU +25 WELL AS—STAKED SURFACE LOCATION (NAD83) BEAVER CREEK UNIT PAD 3 lir 4 a ENGINEERING•TESTING [OCATK ON:SECTION 34, TOWNSHIP 7 NORTH, 1 SURVEYING-M PING RANGE lO b'�JEST,SE��`\RD t IERID)A 1 ALhSKA P.O.BOX 468 1(ILl4Irp 41s•l n,1,1,(- MC( k. SOLDOTNA,AK.99669 JOB NO. 143117 VOICE:(907)283.4218 FAX (997)283.3265 DRAWN BY Connultne Inc WWW.6ICLANECG.COM r11Sm I 8/25114 190/URE: 1 Page 52 Version 0 July, 2014 Beaver Creek#25 Drilling Procedure Rev 0 Hilcorp Enngy Company 32.0 Directional Survey Page 53 Version 0 July, 2014 Hilcorp Energy Company Beaver Creek Unit Beaver Creek Unit Beaver CK Unit 25 BCU 25 Plan: BCU 25 WP6.0 Standard Proposal Report 22 August, 2014 HALLIBURTON Sperry Drilling Services i,DETAILS: Beaver CB Unit 25 .1.� O Ground Le'elt 160.50 +N/-S +E/-W Northing Fasting Latittude Longitude Slot 0.00 0.00 2433936.29 317473.83 60.6582484 -151.0173929 9 5/8" _ _'� Project: Beaver Creek Unit Site: Beaver Creek Unit c _----- ,; Well: Beaver CK Unit 25 -700 BCU-25 BC_B4ST revised 82114 Wellbore: BCU 25 Plan: BCU 25 WP6.0 0 c) - HALLIBURTON o BCU-25 Landing revised 82114 -1400 Sperry Drilling Services o... T OM Azimuths to True North Magnetic North:16.94° Magnetic Field BCU-25 TD revised 82114 5 1/2" Strength:55443.6snT Dip Angle:73.63° _ -2100 --_-_ � Date:9/1/2014 _ - --_ ',--� i Model:BGGM2014 Th, BCU25 WP6.4------------- ,i'gc) 4 -700 0 700 1400 2100 2800 _ West(-)/East(+) (700 usft/in) o- 500— 500 _---___Start Dir 3°/100':600'MD,600'TVD - End Dir :685.05'MD,685.03'ND 1000— 1000 1500— 1500 REFERENCE INFORMATION " Co-ordinate(N/E)Reference: Well Beaver CK Unit 25,True North c Vertical(TVD)Reference: Plan:BCU 25 @ 179.10usft(169) 2000— 2000 Measured Depth Reference: Plan:BCU 25 @ 179.10usft(169) Calculation Method: Minimum Curvature 0 - 0 O - L 2500— 2500 -LI -' in - v 3000-- 3000 r a) - 9 518" 2 3500— '3500 Start Dir 7°/100':4401.54'MD,4397.83'TVD 4000^ 4000 Start Dir 4°1100':5709.04'MD.5252.26TVD Start Dir 7°/100':7973.22'MD,5285.14TVD ---- End Dir :5754.36'MD,5252.33'TVD --- ---- ' Start Dir 7°/100':5927.23'MD,5249.88TVD 4500— 4500 , End Dir :6043.69'MD,5250.74'ND End Dir :7973.53'MD,5285.15'ND 5000— h000 o �' o' p" 00 0 0 0 ------ - --BCU 25 WP6.0 co -o "-,n o 0 0 0"-" -- "' , to m h- N o :m -________ __ Total Depth:8200'MD,5289.1'TVD BCU-25 BC_B4ST revised 82114 BCU-25 Landing revised 82114 5 1/2" BCU-25 TD revised 82114 5500- 1l l l i i i l i r l i l r l l i t l t l l t l l l l t 1 t 1 1 1 t t t l 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 t 1 t 1 l t t 1 1 1 t t t 1 1 1 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 Vertical Section at 140.85°(1000 usftlin) jZw mmc ZNo -- O UUUVa tv > > >muC - CD Cl.) d .•N - 8 mC000 `V —o a • •• 0 CO avi='CD� - o a — -8 —N N M O —8 M N -- O 00 h IC N akCa ..'g" >N P L P -8 N 0.. - U o utri 3 co N - o -=-•3 1 N ..- IU N I _ 7 'O Ui / Ce 8 0 co —O CO0 U - .... I - r b I 4 I . N CD N W —o W .5 a..) C _ g way w _ o N —N Ocii; - N com00 I - U / - rn CO CO U 0] U Cq — U - o j 1 M I M I6 ,, _ _ U m O / m —. o O N/ - fl En 4/ - 3 En W - U• — nil o CO — _ l Ci 0 U C-) a Q J > U - J c, I I I I II I I� I S I I I IIIIII I I I T1 I l I l-, I I 1 1 o 0 QO O h O h O N 8 o O O o N_ in / n 005)(+4ioNU'4noS Halliburton HALLIBURTONJ Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 25 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 25 @ 179.10usft(169) Project: Beaver Creek Unit MD Reference: Plan:BCU 25 @ 179.10usft(169) Site: Beaver Creek Unit North Reference: True, Well: Beaver CK Unit 25 Survey Calculation Method: Minimum Curvature , Wellbore: BCU 25 Design: BCU 25 WP6.0 Project Beaver Creek Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Site Beaver Creek Unit Site Position: Northing: 2,430,086.36 usft Latitude: 60.6475877 From: Map Easting: 314,428.19usft Longitude: -151.0340284 Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.90° Well Beaver CK Unit 25 Well Position +N/-S 0.00 usft Northing: 2,433,936.29 usf • Latitude: 60.6582484 +E/-W 0.00 usft Easting: 317,473.83 usf . Longitude: -151.0173929 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usf Ground Level: 160.50 usft , Wellbore BCU 25 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2014 9/1/2014 16.95 73.63 55,444 Design BCU 25 WP6.0 Audit Notes: Version: Phase: PLAN Tie On Depth: 18.60 Vertical Section: Depth From(TVD) +NI-S +EI-W Direction (usft) (usft) (usft) (0) 18.60 0.00 0.00 140.85 Plan Sections Measured Vertical ND Dogleg Build Turn Depth Inclination Azimuth Depth System +NI-S +E/-W Rate Rate Rate Tool Face (usft) (0) (°) (usft) usft (usft) (usft) (.1100usft) (°/100usft) (°/100usft) (0) 18.60 0.00 0.00 18.60 -160.50 0.00 0.00 0.00 0.00 0.00 0.00 600.00 0.00 327.63 600.00 420.90 0.00 0.00 0.00 0.00 0.00 327.63 685.05 2.55 324.49 685.03 505.93 1.54 -1.10 3.00 3.00 0.00 324.49 4,401.54 2.55 324.49 4,397.83 4,218.73 136.23 -97.20 0.00 0.00 0.00 0.00 5,709.04 89.00 136.25 5,252.26 5,073.16 -440.43 462.26 7.00 6.61 13.14 171.75 5,754.36 90.81 136.25 5,252.33 5,073.23 -473.16 493.60 4.00 4.00 -0.01 -0.10 5,927.23 90.81 136.25 5,249.88 5,070.78 -598.01 613.13 0.00 0.00 0.00 0.00 5,938.83 90.00 136.25 5,249.80 5,070.70 -606.40 621.16 7.00 -7.00 0.03 179.77 6,043.69 88.98 143.52 5,250.74 5,071.64 -686.52 688.67 7.00 -0.97 6.93 98.02 7,973.22 88.98 143.52 5,285.14 5,106.04 -2,237.72 1,835.72 0.00 0.00 0.00 0.00 7,973.53 89.00 143.52 5,285.15 5,106.05 -2,237.97 1,835.90 7.00 6.99 0.44 3.64 8,200.00 89.00 143.52 5,289.10 5,110.00 -2,420.04 1,970.53 0.00 0.00 0.00 0.00 8122/2014 3:01:39PM Page 2 COMPASS 5000.1 Build 70 Halliburton HALLIBLiRTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 25 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 25 @ 179.10usft(169) Project: Beaver Creek Unit MD Reference: Plan:BCU 25 @ 179.10usft(169). Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 25 Survey Calculation Method: Minimum Curvature Wellbore: BCU 25 Design: BCU 25 WP6.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (0) (usft) usft (usft) (usft) (usft) (usft) -160.50 18.60 0.00 0.00 18.60 -160.50 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 100.00 0.00 327.63 100.00 -79.10 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 200.00 0.00 327.63 200.00 20.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 300.00 0.00 327.63 300.00 120.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 400.00 0.00 327.63 400.00 220.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 500.00 0.00 327.63 500.00 320.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 600.00 0.00 327.63 600.00 420.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 Start Dir 3°/100':600'MD,600'TVD 685.05 2.55 324.49 685.02 505.92 1.54 -1.10 2,433,937.85 317,472.75 3.00 -1.89 End Dir :685.05'MD,685.03'TVD 700.00 2.55 324.49 699.96 520.86 2.08 -1.49 2,433,938.40 317,472.38 0.00 -2.55 800.00 2.55 324.49 799.86 620.76 5.71 -4.07 2,433,942.06 317,469.85 0.00 -7.00 900.00 2.55 324.49 899.76 720.66 9.33 -6.66 2,433,945.72 317,467.32 0.00 -11.44 1,000.00 2.55 324.49 999.66 820.56 12.96 -9.24 2,433,949.39 317,464.79 0.00 -15.88 1,100.00 2.55 324.49 1,099.56 920.46 16.58 -11.83 2,433,953.05 317,462.26 0.00 -20.33 1,200.00 2.55 324.49 1,199.46 1,020.36 20.20 -14.41 2,433,956.71 317,459.73 0.00 -24.77 1,300.00 2.55 324.49 1,299.36 1,120.26 23.83 -17.00 2,433,960.38 317,457.20 0.00 -29.21 1,400.00 2.55 324.49 1,399.26 1,220.16 27.45 -19.59 2,433,964.04 317,454.67 0.00 -33.65 1,500.00 2.55 324.49 1,499.16 1,320.06 31.08 -22.17 2,433,967.71 317,452.14 0.00 -38.10 1,600.00 2.55 324.49 1,599.06 1,419.96 34.70 -24.76 2,433,971.37 317,449.61 0.00 -42.54 1,700.00 2.55 324.49 1,698.97 1,519.87 38.32 -27.34 2,433,975.03 317,447.08 0.00 -46.98 1,800.00 2.55 324.49 1,798.87 1,619.77 41.95 -29.93 2,433,978.70 317,444.55 0.00 -51.43 1,900.00 2.55 324.49 1,898.77 1,719.67 45.57 -32.51 2,433,982.36 317,442.02 0.00 -55.87 2,000.00 2.55 324.49 1,998.67 1,819.57 49.20 -35.10 2,433,986.02 317,439.50 0.00 -60.31 2,100.00 2.55 324.49 2,098.57 1,919.47 52.82 -37.69 2,433,989.69 317,436.97 0.00 -64.76 2,200.00 2.55 324.49 2,198.47 2,019.37 56.45 -40.27 2,433,993.35 317,434.44 0.00 -69.20 2,300.00 2.55 324.49 2,298.37 2,119.27 60.07 -42.86 2,433,997.02 317,431.91 0.00 -73.64 2,400.00 2.55 324.49 2,398.27 2,219.17 63.69 -45.44 2,434,000.68 317,429.38 0.00 -78.08 2,500.00 2.55 324.49 2,498.17 2,319.07 67.32 -48.03 2,434,004.34 317,426.85 0.00 -82.53 2,600.00 2.55 324.49 2,598.07 2,418.97 70.94 -50.61 2,434,008.01 317,424.32 0.00 -86.97 2,700.00 2.55 324.49 2,697.97 2,518.87 74.57 -53.20 2,434,011.67 317,421.79 0.00 -91.41 2,800.00 2.55 324.49 2,797.87 2,618.77 78.19 -55.79 2,434,015.33 317,419.26 0.00 -95.86 2,900.00 2.55 324.49 2,897.78 2,718.68 81.81 -58.37 2,434,019.00 317,416.73 0.00 -100.30 3,000.00 2.55 324.49 2,997.68 2,818.58 85.44 -60.96 2,434,022.66 317,414.20 0.00 -104.74 3,100.00 2.55 324.49 3,097.58 2,918.48 89.06 -63.54 2,434,026.33 317,411.67 0.00 -109.19 3,200.00 2.55 324.49 3,197.48 3,018.38 92.69 -66.13 2,434,029.99 317,409.14 0.00 -113.63 3,300.00 2.55 324.49 3,297.38 3,118.28 96.31 -68.71 2,434,033.65 317,406.61 0.00 -118.07 3,400.00 2.55 324.49 3,397.28 3,218.18 99.93 -71.30 2,434,037.32 317,404.09 0.00 -122.51 3,500.00 2.55 324.49 3,497.18 3,318.08 103.56 -73.89 2,434,040.98 317,401.56 0.00 -126.96 9 5/8" 3,600.00 2.55 324.49 3,597.08 3,417.98 107.18 -76.47 2,434,044.64 317,399.03 0.00 -131.40 3,700.00 2.55 324.49 3,696.98 3,517.88 110.81 -79.06 2,434,048.31 317,396.50 0.00 -135.84 3,800.00 2.55 324.49 3,796.88 3,617.78 114.43 -81.64 2,434,051.97 317,393.97 0.00 -140.29 3,900.00 2.55 324.49 3,896.78 3,717.68 118.06 -84.23 2,434,055.64 317,391.44 0.00 -144.73 4,000.00 2.55 324.49 3,996.69 3,817.59 121.68 -86.81 2,434,059.30 317,388.91 0.00 -149.17 8/22/2014 3:01:39PM Page 3 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 25 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 25 @ 179.10usft(169) Project: Beaver Creek Unit MD Reference: Plan:BCU 25 @ 179.10usft(169) Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 25 Survey Calculation Method: Minimum Curvature Wellbore: BCU 25 Design: BCU 25 WP6.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (0) (°) (usft) usft (usft) (usft) (usft) (usft) 3,917.49 4,100.00 2.55 324.49 4,096.59 3,917.49 125.30 -89.40 2,434,062.96 317,386.38 0.00 -153.61 4,200.00 2.55 324.49 4,196.49 4,017.39 128.93 -91.99 2,434,066.63 317,383.85 0.00 -158.06 4,300.00 2.55 324.49 4,296.39 4,117.29 132.55 -94.57 2,434,070.29 317,381.32 0.00 -162.50 4,400.00 2.55 324.49 4,396.29 4,217.19 136.18 -97.16 2,434,073.95 317,378.79 0.00 -166.94 4,401.54 2.55 324.49 4,397.83 4,218.73 136.23 -97.20 2,434,074.01 317,378.75 0.00 -167.01 Start Dir 7°/100':4401.54'MD,4397.83'TVD 4,500.00 4.38 131.48 4,496.21 4,317.11 135.52 -95.65 2,434,073.28 317,380.29 7.00 -165.49 4,600.00 11.37 134.44 4,595.21 4,416.11 126.08 -85.73 2,434,063.68 317,390.06 7.00 -151.90 4,700.00 18.37 135.15 4,691.80 4,512.70 107.98 -67.56 2,434,045.30 317,407.95 7.00 -126.39 4,800.00 25.37 135.48 4,784.54 4,605.44 81.50 -41.40 2,434,018.42 317,433.70 7.00 -89.34 4,900.00 32.37 135.68 4,872.06 4,692.96 47.03 -7.63 2,433,983.43 317,466.93 7.00 -41.29 5,000.00 39.37 135.81 4,953.05 4,773.95 5.09 33.23 2,433,940.86 317,507.13 7.00 17.04 5,100.00 46.37 135.91 5,026.29 4,847.19 -43.71 80.57 2,433,891.34 317,553.72 7.00 84.77 5,200.00 53.37 135.98 5,090.71 4,911.61 -98.62 133.70 2,433,835.61 317,605.99 7.00 160.90 5,300.00 60.37 136.05 5,145.33 4,966.23 -158.84 191.82 2,433,774.50 317,663.17 7.00 244.29 5,400.00 67.37 136.10 5,189.35 5,010.25 -223.47 254.06 2,433,708.92 317,724.40 7.00 333.70 5,500.00 74.37 136.15 5,222.11 5,043.01 -291.53 319.49 2,433,639.85 317,788.77 7.00 427.80 5,600.00 81.37 136.20 5,243.11 5,064.01 -362.03 387.15 2,433,568.31 317,855.33 7.00 525.18 5,700.00 88.37 136.25 5,252.05 5,072.95 -433.90 456.01 2,433,495.39 317,923.07 7.00 624.39 5,709.04 89.00 136.25 5,252.26 5,073.16 -440.42 462.26 2,433,488.76 317,929.22 7.00 633.40 Start Dir 4°/100':5709.04'MD,5252.26'TVD 5,754.36 90.81 136.25 5,252.33 5,073.23 -473.16 493.60 2,433,455.55 317,960.05 4.00 678.57 End Dir :5754.36'MD,5252.33'TVD 5,800.00 90.81 136.25 5,251.69 5,072.59 -506.12 525.16 2,433,422.10 317,991.09 0.00 724.06 5,900.00 90.81 136.25 5,250.27 5,071.17 -578.35 594.31 2,433,348.81 318,059.11 0.00 823.73 5,927.23 90.81 136.25 5,249.88 5,070.78 -598.02 613.14 2,433,328.86 318,077.64 0.00 850.87 Start Dir 7°/100':5927.23'MD,5249.88'TVD 5,938.83 90.00 136.25 5,249.80 5,070.70 -606.40 621.16 2,433,320.35 318,085.53 7.00 862.44 6,000.00 89.40 140.49 5,250.12 5,071.02 -652.10 661.78 2,433,274.02 318,125.44 7.00 923.53 6,043.69 88.98 143.52 5,250.74 5,071.64 -686.53 688.67 2,433,239.19 318,151.79 7.00 967.20 End Dir :6043.69'MD,5250.74'TVD 6,100.00 88.98 143.52 5,251.74 5,072.64 -731.80 722.15 2,433,193.40 318,184.56 0.00 1,023.44 6,200.00 88.98 143.52 5,253.52 5,074.42 -812.19 781.60 2,433,112.10 318,242.76 0.00 1,123.32 6,300.00 88.98 143.52 5,255.31 5,076.21 -892.58 841.04 2,433,030.80 318,300.95 0.00 1,223.19 6,400.00 88.98 143.52 5,257.09 5,077.99 -972.97 900.49 2,432,949.50 318,359.15 0.00 1,323.07 6,500.00 88.98 143.52 5,258.87 5,079.77 -1,053.36 959.94 2,432,868.19 318,417.35 0.00 1,422.94 6,600.00 88.98 143.52 5,260.66 5,081.56 -1,133.76 1,019.38 2,432,786.89 318,475.54 0.00 1,522.82 6,700.00 88.98 143.52 5,262.44 5,083.34 -1,214.15 1,078.83 2,432,705.59 318,533.74 0.00 1,622.69 6,800.00 88.98 143.52 5,264.22 5,085.12 -1,294.54 1,138.28 2,432,624.28 318,591.93 0.00 1,722.57 6,900.00 88.98 143.52 5,266.01 5,086.91 -1,374.93 1,197.72 2,432,542.98 318,650.13 0.00 1,822.44 7,000.00 88.98 143.52 5,267.79 5,088.69 -1,455.33 1,257.17 2,432,461.68 318,708.32 0.00 1,922.32 7,100.00 88.98 143.52 5,269.57 5,090.47 -1,535.72 1,316.62 2,432,380.38 318,766.52 0.00 2,022.20 7,200.00 88.98 143.52 5,271.36 5,092.26 -1,616.11 1,376.06 2,432,299.07 318,824.71 0.00 2,122.07 7,300.00 88.98 143.52 5,273.14 5,094.04 -1,696.50 1,435.51 2,432,217.77 318,882.91 0.00 2,221.95 7,400.00 88.98 143.52 5,274.92 5,095.82 -1,776.89 1,494.96 2,432,136.47 318,941.10 0.00 2,321.82 8/22/2014 3:01:39PM Page 4 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 25 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 25 @ 179.10usft(169) Project: Beaver Creek Unit MD Reference: Plan:BCU 25 @ 179.10usft(169) Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 25 Survey Calculation Method: Minimum Curvature Wellbore: BCU 25 Design: BCU 25 WP6.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (0) (°) (usft) usft (usft) (usft) (usft) (usft) 5,097.61 7,500.00 88.98 143.52 5,276.71 5,097.61 -1,857.29 1,554.40 2,432,055.16 318,999.30 0.00 2,421.70 7,600.00 88.98 143.52 5,278.49 5,099.39 -1,937.68 1,613.85 2,431,973.86 319,057.49 0.00 2,521.57 7,700.00 88.98 143.52 5,280.27 5,101.17 -2,018.07 1,673.30 2,431,892.56 319,115.69 0.00 2,621.45 7,800.00 88.98 143.52 5,282.06 5,102.96 -2,098.46 1,732.74 2,431,811.26 319,173.88 0.00 2,721.32 7,900.00 88.98 143.52 5,283.84 5,104.74 -2,178.86 1,792.19 2,431,729.95 319,232.08 0.00 2,821.20 7,973.22 88.98 143.52 5,285.14 5,106.04 -2,237.72 1,835.72 2,431,670.42 319,274.69 0.00 2,894.33 Start Dir 7°/100':7973.22'MD,5285.14'TVD 7,973.53 89.00 143.52 5,285.15 5,106.05 -2,237.97 1,835.90 2,431,670.17 319,274.87 6.99 2,894.64 End Dir :7973.53'MD,5285.15'TVD 8,000.00 89.00 143.52 5,285.61 5,106.51 -2,259.25 1,851.64 2,431,648.65 319,290.27 0.00 2,921.07 8,100.00 89.00 143.52 5,287.36 5,108.26 -2,339.64 1,911.08 2,431,567.35 319,348.47 0.00 3,020.95 8,199.99 89.00 143.52 5,289.10 5,110.00 -2,420.03 1,970.52 2,431,486.05 319,406.65 0.00 3,120.82 Total Depth:8200'MD,5289.1'TVD-5 1/2" 8,200.00 89.00 143.52 5,289.10 5,110.00 -2,420.04 1,970.53 2,431,486.04 319,406.66 0.00 3,120.83 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) BCU-25 BC B4ST revised 82114 0.00 0.00 5,252.26 -440.43 462.26 2,433,488.76 317,929.22 -plan hits target center -Circle(radius 100.00) BCU-25 Landing revised 82114 0.00 0.00 5,249.80 -606.40 621.16 2,433,320.35 318,085.53 -plan hits target center -Circle(radius 100.00) BCU-25 TD revised 82114 0.00 0.00 5,285.15 -2,237.97 1,835.90 2,431,670.17 319,274.87 -plan hits target center -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 3,500.00 3,497.18 9 5/8" 9-5/8 12-1/4 8,199.99 5,289.10 5 1/2" 5-1/2 8-1/2 8/22/2014 3:01:39PM Page 5 COMPASS 5000.1 Build 70 Halliburton HO LLIBURTO 1 Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 25 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 25 @ 179.10usft(169) Project: Beaver Creek Unit MD Reference: Plan:BCU 25 @ 179.10usft(169) Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 25 Survey Calculation Method: Minimum Curvature Wellbore: BCU 25 Design: BCU 25 WP6.0 --------------------------------------- Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 600.00 600.00 0.00 0.00 Start Dir 3°/100':600'MD,600'TVD 685.05 685.02 1.54 -1.10 End Dir :685.05'MD,685.03'TVD 4,401.54 4,397.83 136.23 -97.20 Start Dir 7°/100':4401.54'MD,4397.83'TVD 5,709.04 5,252.26 -440.42 462.26 Start Dir 4°/100':5709.04'MD,5252.26'TVD 5,754.36 5,252.33 -473.16 493.60 End Dir :5754.36'MD,5252.33'TVD 5,927.23 5,249.88 -598.02 613.14 Start Dir 7°/100':5927.23'MD,5249.88'TVD 6,043.69 5,250.74 -686.53 688.67 End Dir :6043.69'MD,5250.74'TVD 7,973.22 5,285.14 -2,237.72 1,835.72 Start Dir 7°/100':7973.22'MD,5285.14'TVD 7,973.53 5,285.15 -2,237.97 1,835.90 End Dir :7973.53'MD,5285.15'TVD 8,199.99 5,289.10 -2,420.03 1,970.52 Total Depth:8200'MD,5289.1'TVD 8/22/2014 3:01:39PM Page 6 COMPASS 5000.1 Build 70 2 1 m 0L r 15 a ao , moJ J a QL L Q N E .c in m N Wc o i O a U I— i rn U T, O d w Q ` I w N in O O = OC a Nm C d g o . 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N o0 11,;0,10 -/ _ m = o 0101. i V c a 7 41.4k-Iii a�1 ..1 0 p N mmi CI)= o � � c 8 O J = Q a CS) co c� Q J 0 c o CO 2 (uo4sn 00£) uoiTeaedeS aaqua° o; aaquej N Tfs _ 71_ 2 TO a 8 Q 0 > 8 8 = CO = '� CO CI Q CL 8 > 0 C L > U C...) v > > > . o 0 CO 0 0> > CA > > > > `° > > a CC W W O •T- `- v- U `- `- co co N N N > 7 > D > > D D > > m > > > D D co U co U co °) Q" a m m COCOm r m m m m m o m o m 0 0 0 Z o c 6c0 o_o m ri ri v m ct m m m m N N N W D D D D D D D D D D M CO 6. LO co 0 = CL m m m m m m m m m m U U U DU U DU -J O _ ri co c0 0 °i c+i c- V c° m cam O] m J _ _ _ _ _ N_ N N CO M 0 M m C C C C C 'C C 'C C C C C C C C C C1 YYYYYYYYYYYYYYY uO UN U UJ U U UN U UN UN UN U UN UN UN 0 S > > > > > > > > > > > > > > L4 N co co co co co co co co co co co C) C) co co co C) a) a) a) a) a) a) a a a a) a) a) a a a) a) U COOO CO m m m m m COCOCOCOCOCOCOO] CO - 0 - ; —o _ 0) I —to CV I — 0 I t U) _ to 0 - OO —� to 0. L _ 00 a) to _ —o N _0 p V c U L - N ° ,4 l 1 .,03 o ca _,,„ ,a,—, v L — O r _ r N U o A dile' M� m . - Z o O o c ___ o 0 CO N a — —v) I— ct' o _ co °'Et :: ¢ •�' _ CL . ° N.-- III 0 r°Va. U cg\ — N J = y iii � ciicicclimiiiiiim dill iiI � iii io J 0 0 Lt) 0 u7 O V) O u') 0 Q ` O N-. N O N- U) N 0 N Q V c co N- c0N U) C) N 0 N L I = ai (u!/09 Z)aoToed uoi}eaedag Q U Davies, Stephen F (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Wednesday, September 03, 2014 6:54 AM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: BCU 25 Permit to Drill Application (PTD # 214-132): Questions Good morning Steve. I named the well Beaver Creek#25 and left the "Unit" unit out on the well name because the BLM had issues with#23 and #24 when I submitted their permit to them with "Unit" in the name. For consistency, I should have named it Beaver Creek Unit#25 on the 10-401. Great catch on the 9675' depth! That was the old depth of the original plan and should have been modified to the correct depth of 8200'. MW will still range from 9-10 ppg throughout this hole section. Thank you! If you have any more questions, please let me know. Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Tuesday, September 02, 2014 5:30 PM To: Monty Myers Cc: Schwartz, Guy L (DOA) Subject: BCU 25 Permit to Drill Application (PTD # 214-132): Questions Monty, 1. Is the actual name/number of this proposed well Beaver Creek#25 or Beaver Creek Unit#25? 2. On page 30,the mud properties for the 8-1/2" hole section is given as: MD Mud Weight 3500'—9,675' 9.0—10.0 The TD of the well on Form 10-401 and in the directional survey is given at 8,200' MD. Please let me know the correct depth and mud weight ranges for this section of the planned well. Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 1 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST / WELL NAME: _ 1(7 l' 2__C PTD: % ` D Z v/ Development _Service Exploratory Stratigraphic Test Non-Conventional FIELD: CP-6(2A- POOL: / (211a-C7 Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are Well Lo ,n also required for this well: gg g Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. 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Technical Report Title Date Client: Hilcorp Alaska, LLC Field: Beaver Creek Rig: Saxon 169 Date: November 7, 2014 Surface Data Logging End of Well Report Beaver Creek Unit 25 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Mud Record 6. Bit Record 7. Morning Reports 8. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: Hilcorp Alaska, LLC Rig: Saxon 169 Well: Beaver Creek Unit 25 Field: Beaver Creek Borough: Kenai Peninsula Borough State: Alaska Country: United States API Number: 50-133-20644-00-00 Sperry Job Number: AK-XX-0901729762 Job Start Date: 23 October 2014 Spud Date: 26 October 2014 Total Depth: 8208’ MD, 5264’ TVD North Reference: True Declination: 16.928° Dip Angle: 73.633° Total Field Strength: 55441 nT Date of Magnetic Data: 21 July 2014 Wellhead Coordinates N: North 60° 39’ 29.695” Wellhead Coordinates W: West 151° 01’ 2.615“ Drill Floor Elevation 178.50’ Ground Elevation: 160.50’ Permanent Datum: Mean Sea Level SDL Engineers: Craig Amos, Jane Grundin, Jacob Hansen, Jeremy Tiegs, Hilary Garney SDL Sample Catchers: Hilary Garney, Leslie Hunter Company Geologist: John Serbeck Company Representatives: Rance Pederson, Joe Grubb, Jimmy Greco, James Sweetsir Sperry Mudlogging Unit Number: 117 Monitoring Gas Equipment Summary: Baseline 9000 Gas Analyzer Baseline 8900 Gas Chromatograph Matheson Chrysalis Hydrogen Generator Critical Spare Gas Equipment Summary: Baseline 9000 Gas Analyzer Baseline 8900 Gas Chromatograph Matheson Chrysalis Hydrogen Generator HOLE DATA Dates Drilled Hole Section Total Depth Mud Weight (ppg) Inclination (degrees) Casing Shoe Depth MD TVD MD TVD 10/26 – 11/2 8.5” 8208’ 5264’ 9.8 89.83° 5.5” DAILY SUMMARY 10/23/2014 SDL arrived on location and began to rig up unit and equipment. Connected communication cables and Pason data transfer system while the rig began running casing. 10/24/2014 Continued to rig up unit and equipment, installed 9000 and 8900 gas monitoring systems, as well as heat trace cables for gas transfer. Installed degasser and connected air hose to unit and system. Rig completed running casing and cements casing at 3488’ MD. 10/25/2014 Completed rig up, calibrated and bag tested gas systems. Rig nippling up and tested BOPs. 10/26/2014 Completed BOP test, tripped into hole with clean out BHA, drilled 30ft of new formation to 3540' MD, conditioned and circulated mud, and began tripping out of hole and preparing to pick up production BHA. Gas: The maximum formation gas was 28 units, there was no significant connection or trip gas. Fluids: 0 barrels of water-based mud lost down hole. 10/27/2014 Completed making up production run BHA, tripped into the hole and MWD performed a shallow pulse test then began drilling production section at 15:35. Control drilled from 3540' to 3839' MD. Gas: The maximum formation gas seen was 25 units at 3540’ MD; there was no significant connection or trip gas. Fluids: 0 bbls of mud lost down hole. Geology: Sandstone, occasionally clear, off white to white, black to light grey in places, predominantly translucent, rarely transparent, medium to fine grained, sub angular, occasionally sub rounded, hard, well sorted, trace coal, trace Glauconite. 10/28/2014 Drilled ahead in production section to 4488’ MD until the Kelly hose failed. Performed rig maintenance to fix the hose. Gas: The maximum formation gas was 33 units at 4154’ MD; there was no significant connection or trip gas. Fluids: 0 bbls of mud lost down hole. Geology: Light grey, white and occasional green, soft, medium to fine grained, sub-angular to sub- rounded, poorly sorted sandstone with occasional Glauconite with some coal and trace amounts of siltstone. 10/29/2014 Repaired the Kelly hose and pressure tested same, tripped back in the hole and continued to drill from 4488' MD to current depth of 5231' MD. Gas: The maximum formation gas was 64 units at 5194’ MD; there was no significant connection or trip gas. Fluids: 0 bbls of mud lost down hole. Geology: light to medium gray, firm siltstone with trace amounts of gray sandstone accompanied by abundant brown to black coal. 10/30/2014 Continued to drill from 5231' to 5895' MD while control drilling between 5624' and 5630' MD, pumped sweeps at 5550' and 5848' MD and had a max gas reading of 829 units seen at 5696' MD which was related to a coal bed and comprised entirely of C1 along with minimal connection and trip gas seen. Geology was predominantly a Silty Sandstone with occasional coals and Tuffaceous beds. Gas: The maximum formation gas was 829 units at 5696’ MD; there was no significant connection or trip gas. Fluids: 0 bbls of mud lost down hole. Geology: Sandstone: light to medium grey, off white, occasionally green, translucent to transparent, hard, sub angular to sub rounded, moderately sorted, predominantly unconsolidated, occasional weak arenaceous cement. Siltstone: light to medium grey, soft to firm, amorphous to blocky, heterogeneous, moderate cement, trace coal. 10/31/2014 Continued to drill from 5895' to 6779' MD while a max gas of 1223 units seen at 6094' MD along with minimal connection and trip gas. Pumped two sweeps and continued to drill ahead. Geology was predominantly sandstone with occasional coals and siltstones above 6022' MD. Gas: The maximum formation gas was 1223 units at 6094' MD; there was no significant connection or trip gas. Fluids: 0 bbls of mud lost down hole. Geology: Light to dark gray, white, cream, black, light green, translucent to transparent, clear sandstone with very fine to medium sized grains that are sub angular to sub rounded and well sorted with unconsolidated sand grains and a moderate amount of Glauconite. 11/1/2014 Continued to drill ahead from 6779’ MD to 7713’ MD and pumped sweeps at 6917’ MD and 7030’ MD with the sweep at 6917’ MD contributed a max gas peak of 269 units. Connection and trip gas were minimal and connection gas returns to back ground. Geology has been sandstone with trace Glauconite. Gas: The maximum formation gas was 269 units at 6942' MD; there was no significant connection or trip gas. Fluids: 0 bbls of mud lost down hole. Geology: Light to dark gray, white, cream, light green, translucent to transparent, clear and occasionally black sandstone with fine to medium sized grains that are sub angular to sub rounded and moderately well sorted with unconsolidated sand grains and a moderate amount of Glauconite. 11/2/2014 Continued to drill ahead from 7713’ MD to a TD of 8208’ MD at 15:30 then circulated bottoms up. Began to trip out of the hole at 18:00, from which a packed off at 6010’ MD occurred. Circulated mud to loosen up the stuck pipe and continued to trip out of the hole. Connection and trip gas were minimal. Geology has been sandstone with trace Glauconite. Gas: The maximum formation gas was 269 units at 6942' MD; there was no significant connection or trip gas. Fluids: 0 bbls of mud lost down hole. Geology: Light to dark gray, white, cream, light green, translucent to transparent, clear and occasionally black sandstone with fine to medium sized grains that are sub angular to sub rounded and moderately well sorted with unconsolidated sand grains and a moderate amount of Glauconite. 11/3/2014 Continued to trip out of the hole and laid down BHA #3, then picked up clean out assembly and began running into the hole. Circulated bottoms up at 5200' MD and 5700' MD and then continued to run into the hole with clean out assembly. Gas: The maximum formation gas was 243 units while circulating bottoms up; there was no significant connection or trip gas. Fluids: 0 bbls of mud lost down hole. 11/4/2014 Ran into the hole to 8209' MD and circulated bottoms up until shakers were clean. Pumped a low vis then a high vis sweep and waited until shakers were clean. Began to trip out of the hole to 5100' MD and circulated bottoms up, pumped another sweep then continued to clean out the hole. Mas Gas: 223 units while circulating bottoms up. Fluids: 0 bbls of mud lost down hole. 11/5/2014 Continued to pull out of the hole and laid down drill pipe and BHA. Began running into the hole with 5.5" casing. Circulated bottoms up at 3439' MD then continued to run into the hole with casing. Mas Gas: 6 units Fluids: 0 bbls of mud lost down hole. 3300 4300 5300 6300 7300 8300 0 5 10 15 20 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: Beaver Creek Unit 25 OPERATOR: Hilcorp Alaska, LLC MUD CO: Baroid RIG: Saxon 169 SPERRY JOB: AK-XX-0901729762 Days vs. Depth 23 October 2014 Sperry SDL Arrived on Location LOCATION: Beaver Creek AREA: Kenai Peninsular Borough STATE: Alaska SPUD: 26-Oct-2014 TD: 02-Nov-2014 Commenced 8.5" Production Hole Section On Bot: 15:35 26 Oct 2014 Landed 9.625" Casing 3488' MD, 3269' TVD 24 Oct 2014 TD Production Hole Section 8208' MD, 5264' TVD Off Bot: 15:30 02 Nov 2014 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: The Pason communication system failed which caused some data to be missing on the logs. The gas line between the trap and the unit became blocked but was caught quickly enugh to prevent any damage and minimal gas data missing on the logs. Recommendations: Check on the gas trap to make sure that it is at a level so that good data is collected and also to make sure no mud is sucked up in the lines. Innovations and/or cost savings: N/A Saxon 169 Production Hilary Garney 6-Nov-2014 What went as, or better than, planned: The gas equipment performed well and didn't fail except for when the hydrogen generator ran out of water but that was caught quickly enough were little data was compromised. BCU 25 Beaver Creek Unit Hilcorp Alaska LLC Kenai AK-XX-0901729762 Alaska Surface Data Logging After Action Review Beaver Creek Unit 25 Hilcorp Alaska, LLC Baroid Saxon 169 AK-XX-0901729762 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l mg/l 23-Oct 3510 9.40 68 26 27 10/23/39 7.9 79/53/42/29/9/7 2/0 8.0 0.0/91.8 0.50 0.00 7.5 17.5 0/0.6 500 30 Run casing 24-Oct 3510 9.60 49 22 8 2/4/6 8.0 52/30/22/13/2/1 2/0 8.8 0.0/91 0.40 0.00 7.3 17.5 0/0.5 500 30 Cement Casing 25-Oct 3510 9.65 52 22 8 3/8/10 8.0 52/30/22/13/2/1 2/0 9.2 0.0/90.6 0.25 0.00 7.8 17.5 0/1.75 600 80 Test BOP 26-Oct 3540 9.50 59 11 16 6/8/11 5.0 36/26/21/16/6/5 1/2 5.0 0.0/93.0 0.00 0.30 9.0 0.5 0.0/0.60 30000 480 Change to KCL/Polyer Mud 27-Oct 3839 9.55 52 10 18 7/12/15 4.8 38/28/23/18/7/6 1/0 5.1 0.15/92.5 0.50 0.40 9.6 1.5 0.15/0.90 29500 280 Drilling Production Section 28-Oct 4488 9.50 52 12 19 7/11/15 4.4 43/31/26/19/7/6 1/2 4.5 0.0/93.1 0.30 0.40 9.4 1.5 0.35/1.50 29500 40 Rig Maintenance 29-Oct 5135 9.50 65 15 21 7/10/14 4.0 51/36/30/22/7/6 1/2 4.3 0.0/92.9 0.35 0.50 9.4 1.8 0.80/2.20 34000 200 Drilling Ahead 30-Oct 5895 9.50 57 13 22 7/10/14 4.6 58/35/29/21/7/6 1/2 4.4 0.0/93 0.40 0.40 8.7 2.0 1.2/2.9 32000 120 Drilling Production Section 31-Oct 6778 9.90 57 16 23 8/10/15 4.6 55/39/33/24/8/6 1/2 6.1 0.0/91.5 0.40 0.40 9.4 3.0 1.20/2.20 30500 80 Drilling Production Section 1-Nov 7713 9.00 53 14 22 7/9/14 4.4 50/36/30/22/7/6 1/2 6.0 0.5/91.2 0.40 0.90 10.1 0.4 1.30/2.70 29000 40 Drilling Production Section 2-Nov 8209 9.80 46 13 22 6/9/13 4.3 48/35/29/21/7/5 1/2 6.0 0.4/91.1 0.35 0.95 10.4 3.3 1.30/2.80 31000 40 TD Production Section, TOH 3-Nov 8209 9.85 49 13 23 7/11/14 4.8 49/36/30/23/8/6 1/2 6.3 0.3/91.1 0.30 0.60 10.0 3.3 0.95/2.10 29000 80 RIH w/ Clean out assembly 4-Nov 8209 9.85 48 13 25 8/12/16 5.0 51/38/31/24/8/7 1/2 6.4 0.3/91.0 0.30 0.40 9.7 3.3 0.25/1.20 28500 80 Cleaning out hole 5-Nov 8209 9.85 53 13 24 8/13/17 4.4 50/37/31/23/9/7 1/2 6.5 0.3/90.9 0.3 0.4 9.8 3.5 0.15/1.00 28500 40 RIH w/ 5.5" Casing Casing Record SPERRY JOB:TD:2-Nov-2014 Remarks 9.625" Casing @ 3488' MD, 3269'TVD WELL NAME:LOCATION:Beaver Creek OPERATOR:AREA:Kenai Peninsula Borough MUD CO:STATE:Alaska RIG:SPUD:26-Oct-2014 W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 2 200 2RR Tricone 8.50 3510 3540 30 0.28 2.356 58.0 9 90 850 500 2-2-NO-A-E-1-NO-BHA Bit to Drill out the cement 3 300 3 HDBS SFE56 PDC 8.50 3540 8208 4668 77.38 0.752 60.0 12 120 1775 450 1-2-CT-G-X-1/16-PN-T Production Bit WELL NAME:Beaver Creek Unit 25 LOCATION:Beaver Creek OPERATOR:Hilcorp Alaska, LLC AREA:Kenai Peninsula Borough MUD CO: SPERRY JOB:AK-XX-0901729762 TD:2-Nov-14 Baroid STATE:Alaska RIG:Saxon 169 SPUD:26-Oct-14 B i t R e c o r d . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 24-Oct-2014 12:00 AM Current Pump & Flow Data: 0 Max 95% Depth MWD Summary ROP (ft/hr) 3.07 @ Mud Data to - Gallons/stroke - Morning Report Report # 01 Customer: Well: Area: Location: Rig: Beaver Creek 25 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Saxon 169 Report For: Tools -- Min ROP Avg SizeBit Type 100% Gas In Air=10,000 UnitsConnection RPM ECD (ppg) ml/30min API FL Avg Background (max)Trip Average 0 Mud Type Lst Production Type Ss (current) Units* Chromatograph (ppm) C-4i C-4n C-5i C-5n Gas Summary YP (lb/100ft2) ConditionWOB PV Depth in / out cP Footage Coal Conductor Comments Cement Lithology (%) Weight Job No.: Daily Charges: Total Charges: James Sweetsir Yesterday's Depth: Rigging UpRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0901729762 Depth ShClyst - Flow In (gpm) Flow In (spm) (ppb Eq) TFA Size Hours Set AtCasing Summary Bit # MBT pH Siltst Grade 3510' 3510' 0' Max @ ft Current Time: - SPP (psi) 24 hr Max 0 0 - C-2 9 5/8" Craig Amos/Jeremy Tiegs in 16.00'' 5.50'' Minimum (max) 0 907-283-1309Unit Phone:Craig Amos Maximum Report By:Logging Engineers: Depth Cly C-3 Sd Silt TuffGvl C-1 (current) Surface 24 hr Recap: SDL arrives on location and begin rig up. Rig currently running casing. Mas Gas: N/A Fluids: 0 downhole losses Geology: N/A . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 24-Oct-2014 12:00 AM Current Pump & Flow Data: 0 Max 95% Depth MWD Summary ROP (ft/hr) 3.07 @ Mud Data to - Gallons/stroke - Morning Report Report # 02 Customer: Well: Area: Location: Rig: Beaver Creek 25 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Saxon 169 Report For: Tools -- Min ROP Avg SizeBit Type 100% Gas In Air=10,000 UnitsConnection RPM ECD (ppg) ml/30min API FL Avg Background (max) Trip Average Mud Type Lst Production Type Ss (current) Units* Chromatograph (ppm) C-4i C-4n C-5i C-5n Gas Summary YP (lb/100ft2) ConditionWOB PV Depth in / out cP Footage Coal Conductor Comments Cement Lithology (%) Weight Job No.: Daily Charges: Total Charges: James Sweetsir Yesterday's Depth: Rigging UpRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-00901729762 Depth ShClyst - Flow In (gpm) Flow In (spm) (ppb Eq) TFA Size Hours Set At Casing Summary Bit # MBT pH Siltst Grade 3510' 3510' 0' Max @ ft Current Time: - SPP (psi) 24 hr Max 0 0 - C-2 9 5/8" Craig Amos/Jeremy Tiegs in 16.00'' 5.50'' Minimum (max) 907-283-1309Unit Phone:Craig Amos Maximum Report By:Logging Engineers: Depth Cly C-3 Sd Silt TuffGvl C-1 (current) Surface 24 hr Recap: Continue rigging up, rig complete casing and cement job and being to install and nipple up BOP. Minimal Communications issues. Mas Gas: N/A Fluids: 0 downhole losses Geology: N/A . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 25-Oct-2014 12:00 AM Current Pump & Flow Data: 0 Max 95% Depth MWD Summary ROP (ft/hr) 3.07 @ Mud Data to - Gallons/stroke - Morning Report Report # 03 Customer: Well: Area: Location: Rig: Beaver Creek 25 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Saxon 169 Report For: Tools -- Min ROP Avg SizeBit Type 100% Gas In Air=10,000 UnitsConnection RPM ECD (ppg) ml/30min API FL Avg Background (max) Trip Average Mud Type Lst Production Type Ss (current) Units* Chromatograph (ppm) C-4i C-4n C-5i C-5n Gas Summary YP (lb/100ft2) ConditionWOB PV Depth in / out cP Footage Coal Conductor Comments Cement Lithology (%) Weight Job No.: Daily Charges: Total Charges: James Sweetsir Yesterday's Depth: Rigging UpRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0901729762 Depth ShClyst - Flow In (gpm) Flow In (spm) (ppb Eq) TFA Size Hours Set At Casing Summary Bit # MBT pH Siltst Grade 3510' 3510' 0' Max @ ft Current Time: - SPP (psi) 24 hr Max 0 0 - C-2 9 5/8" Craig Amos/Jeremy Tiegs in 16.00'' 5.50'' Minimum (max) 907-283-1309Unit Phone:Craig Amos Maximum Report By:Logging Engineers: Depth Cly C-3 Sd Silt TuffGvl C-1 (current) Surface 24 hr Recap: Continue rigging up, rig continue to Install and Test BOP's. Sample catchers on location. No communication issues. Mas Gas: N/A Fluids: 0 downhole losses Geology: N/A Data Engineers Days/Nights: Jeremy Tiegs/Craig Amos Loggers Days/Nights: Leslie Hunter/ Hilary Gurney . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 31500 New 26-Oct-2014 12:00 AM Current Pump & Flow Data: 0 Max 95% Depth MWD Summary ROP (ft/hr) 3.07 @ Mud Data to 105.0 Gallons/stroke - Morning Report Report # 04 Customer: Well: Area: Location: Rig: Beaver Creek 25 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Saxon 169 Report For: Tools -- Min ROP Avg 5.1 8.5 9.50 Tricone 9.55 Size KCL/Polymer 3540' Bit Type 100% Gas In Air=10,000 Units0Connection RPM ECD (ppg) ml/30min API FL - - Avg - 4.4 Background (max) Trip Average 0 Mud Type Lst 90 Production Type 16 Ss (current) Units* Chromatograph (ppm) C-4i C-4n C-5i C-5n Gas Summary YP (lb/100ft2) 9.10 - ConditionWOB PV - Depth in / out 3510' cP 11 3540' 0.5 30' Footage Coal - Conductor Comments Cement Lithology (%) Weight - Job No.: Daily Charges: Total Charges: James Sweetsir - Yesterday's Depth: TOHRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0901729762 Depth ShClyst 128.0 Flow In (gpm) Flow In (spm) (ppb Eq) TFA PDC 3510' 3 Size Hours Set At Casing Summary Bit # 2 MBT pH 2.356 Siltst Grade 3 3510' 3540' 30' Max @ ft Current Time: 3514' SPP (psi) 24 hr Max 0 0 3540' - C-2 28 9 5/8" 0.7528.5 Craig Amos/Jeremy Tiegs 59 in 16.00'' 5.50'' Minimum 0 (max) 326 0 907-283-1309Unit Phone:Craig Amos Maximum Report By:Logging Engineers: Depth Cly 3071 C-3 10 Sd Silt TuffGvl C-1 (current) Surface 24 hr Recap: Completed BOP test, tripped into hole with clean out BHA, drilled 30ft of new formation to 3540' MD, conditioned and circulated mud, and currently tripping out of hole. Preparing to pick up production BHA. Mas Gas: 28 Fluids: 0 downhole losses Geology: Sand with trace shale Data Engineers Days/Nights: Jeremy Tiegs/Craig Amos Loggers Days/Nights: Leslie Hunter/ Hilary Garney . * (current) Surface C-1Depth Cly 3024 C-3 Sd Silt TuffGvl 10 907-283-1309Unit Phone:Craig Amos Maximum Report By:Logging Engineers: Minimum 0 (max) 1660 Craig Amos/Jeremy Tiegs 52 in 16.00'' 5.50'' 68.0 C-2 25 9 5/8" 0.7528.5 24 hr Max 410 141 3540' 12 3540' 3839' 299' Max @ ft Current Time: 3553' SPP (psi) MBT pH 2.356 Siltst Grade PDC 3510' 3 Size Hours Set At Casing Summary Bit # 2 Depth ShClyst 85.0 Flow In (gpm) Flow In (spm) (ppb Eq) TFA Yesterday's Depth: DrillingRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0901729762 Lithology (%) Weight - Job No.: Daily Charges: Total Charges: James Sweetsir - Coal - Conductor Comments Cement PV - Depth in / out 3510' cP 10 3540' 1.5 30' Footage YP (lb/100ft2) 9.60 - ConditionWOB C-5n Gas Summary C-4i C-4n C-5i Chromatograph (ppm) Ss (current) Units* Mud Type Lst 100 Production Type 3488' 81' 18 Average 0Background (max) Trip RPM ECD (ppg) ml/30min API FL - - Avg - 4.8 100% Gas In Air=10,000 Units0Connection 5.1 8.5 9.55 Tricone 9.55 Size KCL/Polymer 3540' Bit Type Saxon 169 Report For: Tools 9.699.86 Min ROP Avg Morning Report Report # 05 Customer: Well: Area: Location: Rig: Beaver Creek 25 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP (ft/hr) 3.07 @ Mud Data to 65.0 Gallons/stroke 10.05 Depth MWD Summary 27-Oct-2014 12:00 AM Current Pump & Flow Data: 1030 Max 95% mg/l 29500 New Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides 24 hr Recap: Complete making up production run BHA, trip in hole and shallow pulse test, being drilling production section at 15:35. Control drill frm 3540' to 3839' MD. Mas Gas: 25 units Fluids: 0 bbls of mud lost downhole. Geology: Sandstone, occasionally clear, off white to white, black to light grey in places, predominantly translucent, rarely transparent, medium to fine grained, sub angular, occasionally sub rounded, hard, well sorted, tr coal, trace glauconite. Data Engineers Days/Nights: Jeremy Tiegs/Craig Amos Loggers Days/Nights: Leslie Hunter/ Hilary Garney . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 29500 New 28-Oct-2014 12:00 AM Current Pump & Flow Data: 0 Max 95% Depth MWD Summary ROP (ft/hr) 3.07 @ Mud Data to 66.0 Gallons/stroke 10.12 Morning Report Report # 06 Customer: Well: Area: Location: Rig: Beaver Creek 25 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Saxon 169 Report For: Tools 9.669.89 Min ROP Avg 4.5 8.5 9.55 Tricone 9.50 Size KCL/Polymer 3540' Bit Type 100% Gas In Air=10,000 Units0Connection RPM ECD (ppg) ml/30min API FL - - Avg - 4.4 Background (max) Trip Average 0 Mud Type Lst 50 Production Type 3488' 81' 19 Ss (current) Units* Chromatograph (ppm) C-4i C-4n C-5i C-5n Gas Summary YP (lb/100ft2) 9.40 - ConditionWOB PV - Depth in / out 3510' cP 12 3540' 1.5 30' Footage Coal - Conductor Comments Cement Lithology (%) Weight - Job No.: Daily Charges: Total Charges: James Sweetsir - Yesterday's Depth: Rig MaintenanceRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0901729762 Depth ShClyst 95.0 Flow In (gpm) Flow In (spm) (ppb Eq) TFA PDC 4488' 3 Size Hours Set At Casing Summary Bit # 2 MBT pH 2.356 Siltst Grade 7 3839' 4488' 649' Max @ ft Current Time: 4428' SPP (psi) 24 hr Max 0 0 4154' 40 0.0 C-2 33 9 5/8" 0.7528.5 Craig Amos/Jeremy Tiegs 52 in 16.00'' 5.50'' Minimum 0 (max) 0 1023 0 907-283-1309Unit Phone:Craig Amos Maximum Report By:Logging Engineers: Depth Cly 4343 C-3 Sd Silt TuffGvl 10 C-1 (current) Surface Drilled from 3839' to current depth of 4488' MD. Kelly hose failed, rig is currently performing maintenance to repair the hose. Mas Gas: 33 units Fluids: 0 bbls of mud lost downhole. Geology: Sandstone,light grey to white, occ medium grey, translucent, rarely transparent, sub rounded, occasionally sub angular, predominantly medium grained, occasionaly fine to very fine grained, well sorted, moderatly sorted in places, trace Glauconite. Data Engineers Days/Nights: Jeremy Tiegs/Craig Amos Loggers Days/Nights: Leslie Hunter/ Hilary Garney . * (current) Surface 60 C-1Depth Cly 9253 C-3 Sd Silt TuffGvl 0 907-283-1309Unit Phone:Craig Amos Maximum Report By:Logging Engineers: Minimum 0 (max) 0 1692 Craig Amos/Jeremy Tiegs 65 in 16.00'' 5.50'' 66.0 C-2 64 9 5/8" 0.7528.5 24 hr Max 443 160 5193' 40 6 4488' 5231' 743' Max @ ft Current Time: 5206' SPP (psi) MBT pH 2.356 Siltst Grade PDC 5135' 3 Size Hours Set At Casing Summary Bit # 2 Depth ShClyst 104.0 Flow In (gpm) Flow In (spm) (ppb Eq) TFA Yesterday's Depth: Driiling AheadRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0901729762 Lithology (%) Weight - Job No.: Daily Charges: Total Charges: James Sweetsir - Coal - Conductor Comments Cement PV - Depth in / out 3510' cP 15 3540' 1.8 30' Footage YP (lb/100ft2) 9.40 - ConditionWOB C-5n Gas Summary C-4i C-4n C-5i Chromatograph (ppm) Ss (current) Units* Mud Type Lst Production Type 3488' 81' 21 Average 0Background (max) Trip RPM ECD (ppg) ml/30min API FL - - Avg - 4.0 100% Gas In Air=10,000 Units0Connection 4.3 8.5 9.55 Tricone 9.50 Size KCL/Polymer 3540' Bit Type Saxon 169 Report For: Tools 9.749.90 Min ROP Avg Morning Report Report # 07 Customer: Well: Area: Location: Rig: Beaver Creek 25 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP (ft/hr) 3.07 @ Mud Data to 69.0 Gallons/stroke 10.12 Depth MWD Summary 29-Oct-2014 12:00 AM Current Pump & Flow Data: 1265 Max 95% mg/l 34000 New Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides Repaired the kelly hose and pressure tested same, tripped back in the hole and continue to drill from 4488' MD current depth of 5231' MD. Mas Gas: 64 units Fluids: 0 bbls of mud lost downhole. Geology: light to medium gray, firm siltstone with trace amounts of gray sandstone accompanied by abundant brown to black coal. Data Engineers Days/Nights: Jeremy Tiegs/Craig Amos Loggers Days/Nights: Leslie Hunter/ Hilary Garney . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 32000 New 30-Oct-2014 12:00 AM Current Pump & Flow Data: 1388 Max 95% Depth MWD Summary ROP (ft/hr) 3.07 @ Mud Data to 28.0 Gallons/stroke 10.12 Morning Report Report # 08 Customer: Well: Area: Location: Rig: Beaver Creek 25 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Saxon 169 Report For: Tools 9.749.90 Min ROP Avg 4.4 8.5 9.50 Tricone 9.50 Size KCL/Polymer 3540' Bit Type 100% Gas In Air=10,000 Units0Connection RPM ECD (ppg) ml/30min API FL - - Avg - 4.6 Background (max) Trip Average 0 Mud Type Lst Production Type 3488' 81' 22 Ss (current) Units* Chromatograph (ppm) C-4i C-4n C-5i C-5n Gas Summary YP (lb/100ft2) 8.70 - ConditionWOB PV - Depth in / out 3510' cP 13 3540' 2.0 30' Footage Coal - Conductor Comments Cement Lithology (%) Weight - Job No.: Daily Charges: Total Charges: James Sweetsir - Yesterday's Depth: Driiling AheadRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0901729762 Depth ShClyst 143.0 Flow In (gpm) Flow In (spm) (ppb Eq) TFA PDC 5135' 3 Size Hours Set At Casing Summary Bit # 2 MBT pH 2.356 Siltst Grade 152 5231' 5895' 664' Max @ ft Current Time: 5786' SPP (psi) 24 hr Max 440 149 5696' 40 66.0 C-2 829 9 5/8" 0.7528.5 Craig Amos/Jeremy Tiegs 57 in 16.00'' 5.50'' Minimum 3 (max) 3215277' 1654 120 907-283-1309Unit Phone:Craig Amos Maximum Report By:Logging Engineers: Depth Cly 89563 C-3 Sd Silt TuffGvl 60 C-1 (current) Surface Continue to drill from 5231' to 5895' MD at report time, slow drilling between 5624' and 5630' MD, pumped sweeps at 5550' and 5848' MD, max gas of 829 units seen at 5696' MD this was related to a coal bed and comprised entirely of C1, minimal connection and trip gas seen. Geology was predominantly a Silty Sandstone with occasional coals and Tuffaceous beds. Mas Gas: 829 units at 5696' MD Fluids: 0 bbls of mud lost down hole. Geology: Sandstone: light to medium grey, off white, occasionally green, translucent to transparent, hard, sub angular to sub rounded, moderately sorted, predominantly unconsolidated, occasional weak arenaceous cement. Siltstone: light to medium grey, soft to firm, amorphous to blocky, heterogeneous, moderate cement, trace coal. Data Engineers Days/Nights: Jeremy Tiegs/Craig Amos Loggers Days/Nights: Leslie Hunter/ Hilary Garney . * (current) Surface C-1Depth Cly 146183 C-3 Sd Silt TuffGvl 82 907-283-1309Unit Phone:Craig Amos Maximum Report By:Logging Engineers: Minimum 0 (max) 05952' 40775 Craig Amos/Jeremy Tiegs 57 in 16.00'' 5.50'' 64.0 C-2 1223 9 5/8" 0.7528.5 24 hr Max 452 154 6094' 222 5895' 6779' 884' Max @ ft Current Time: 6553' SPP (psi) MBT pH 2.356 Siltst Grade PDC 6740' 3 Size Hours Set At Casing Summary Bit # 2 Depth ShClyst 76.0 Flow In (gpm) Flow In (spm) (ppb Eq) TFA Yesterday's Depth: Driiling AheadRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0901729762 Lithology (%) Weight - Job No.: Daily Charges: Total Charges: James Sweetsir - Coal - Conductor Comments Cement PV - Depth in / out 3510' cP 16 3540' 3.0 30' Footage YP (lb/100ft2) 9.40 - ConditionWOB C-5n Gas Summary C-4i C-4n C-5i Chromatograph (ppm) Ss (current) Units* Mud Type Lst 100 Production Type 3488' 81' 23 Average 264Background (max) Trip RPM ECD (ppg) ml/30min API FL - - Avg - 4.6 100% Gas In Air=10,000 Units80Connection 6.1 8.5 9.95 Tricone 9.90 Size KCL/Polymer 3540' Bit Type Saxon 169 Report For: Tools 9.7410.27 Min ROP Avg Morning Report Report # 09 Customer: Well: Area: Location: Rig: Beaver Creek 25 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP (ft/hr) 3.07 @ Mud Data to 65.0 Gallons/stroke 10.55 Depth MWD Summary 31-Oct-2014 12:00 AM Current Pump & Flow Data: 1694 Max 95% mg/l 30500 New Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides Continue to drill from 5895' to 6779' MD at report time, max gas of 1223 units seen at 6094' MD with minimal connection and trip gas of 264 units seen. Pumped two sweeps and currently drilling ahead. Geology was predominantly sandstone with occasional coals and silstones above 6022' MD. Mas Gas: 1223 units at 6094' MD Fluids: 0 bbls of mud lost down hole. Geology: Light to dark gray, white, cream, black, light green, translucent to transparent, clear sandstone with very fine to medium sized grains that are sub angular to sub rounded and well sorted with unconsolidated sand grains and a modeate amount of glauconite. Data Engineers Days/Nights: Jeremy Tiegs/Craig Amos Loggers Days/Nights: Leslie Hunter/ Hilary Garney . * (current) Surface C-1Depth Cly 23974 C-3 Sd Silt TuffGvl 84 907-283-1309Unit Phone:Craig Amos Maximum Report By:Logging Engineers: Minimum 0 (max) 07027' 6987 Craig Amos/Jeremy Tiegs 52 in 16.00'' 5.50'' 62.0 C-2 269 9 5/8" 0.7528.5 24 hr Max 437 149 6942' 67 6779' 7713' 934' Max @ ft Current Time: 7410' SPP (psi) MBT pH 2.356 Siltst Grade PDC 7651' 3 Size Hours Set At Casing Summary Bit # 2 Depth ShClyst 78.0 Flow In (gpm) Flow In (spm) (ppb Eq) TFA Yesterday's Depth: Drilling AheadRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0901729762 Lithology (%) Weight - Job No.: Daily Charges: Total Charges: James Sweetsir - Coal - Conductor Comments Cement PV - Depth in / out 3510' cP 14 3540' 3.0 30' Footage YP (lb/100ft2) 10.10 - ConditionWOB C-5n Gas Summary C-4i C-4n C-5i Chromatograph (ppm) Ss (current) Units* Mud Type Lst 100 Production Type 3488' 81' 22 Average 143Background (max) Trip RPM ECD (ppg) ml/30min API FL - - Avg - 4.4 100% Gas In Air=10,000 Units117Connection 6.0 8.5 9.85 Tricone 9.80 Size KCL/Polymer 3540' Bit Type Saxon 169 Report For: Tools 10.0410.36 Min ROP Avg Morning Report Report # 10 Customer: Well: Area: Location: Rig: Beaver Creek 25 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP (ft/hr) 3.07 @ Mud Data to 69.0 Gallons/stroke 10.55 Depth MWD Summary 1-Nov-2014 12:00 AM Current Pump & Flow Data: 1624 Max 95% mg/l 29000 New Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides Continuing to drill ahead from 6779' MD to 7713' MD. Pumped sweeps at 6917' MD and 7030' MD sweep at 6917' MD brought back a gas peak of 269 units. Connection and trip gas were minimal, connection gas returns to back ground. Geology has been sandstone with trace Glauconite. Mas Gas: 269 units at 6942' MD Fluids: 0 bbls of mud lost down hole. Geology: Light to dark gray, white to cream, clear, light green, translucent to transparent and occasionally black sandstone that is firm, fine to medium sized grains that are sub angular to sub rounded, sub spherical to sub elongated, moderately well sorted and moderate cement with unconsolidated grains with trace Glauconite. Data Engineers Days/Nights: Jeremy Tiegs/Craig Amos Loggers Days/Nights: Leslie Hunter/ Hilary Garney . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 31000 New 2-Nov-2014 12:00 AM Current Pump & Flow Data: 863 Max 95% Depth MWD Summary ROP (ft/hr) 3.07 @ Mud Data to 64.0 Gallons/stroke 10.42 Morning Report Report # 11 Customer: Well: Area: Location: Rig: Beaver Creek 25 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Saxon 169 Report For: Tools 10.0610.30 Min ROP Avg 6.0 8.5 9.85 Tricone 9.80 Size KCL/Polymer 3540' Bit Type 100% Gas In Air=10,000 Units0Connection RPM ECD (ppg) ml/30min API FL - - Avg - 4.3 Background (max) Trip Average 8 Mud Type Lst 100 Production Type 3488' 81' 22 Ss (current) Units* Chromatograph (ppm) C-4i C-4n C-5i C-5n Gas Summary YP (lb/100ft2) 10.40 - ConditionWOB PV - Depth in / out 3510' cP 13 3540' 3.3 30' Footage Coal - Conductor Comments Cement Lithology (%) Weight - Job No.: Daily Charges: Total Charges: James Sweetsir - Yesterday's Depth: TOHRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0901729762 Depth ShClyst 76.0 Flow In (gpm) Flow In (spm) (ppb Eq) TFA PDC 8209' 3 Size Hours Set At Casing Summary Bit # 2 MBT pH 2.356 Siltst Grade 66 7713' 8208' 495' Max @ ft Current Time: 8145' SPP (psi) 24 hr Max 287 98 8152' 0.0 C-2 224 9 5/8" 0.7528.5 Craig Amos/Jeremy Tiegs 46 in 16.00'' 5.50'' Minimum 0 (max) 07764' 6784 6 907-283-1309Unit Phone:Hilary Garney Maximum Report By:Logging Engineers: Depth Cly 29270 C-3 Sd Silt TuffGvl C-1 (current) Surface Continued to drill ahead to TD of 8208' MD at 15:30. Circulated bottoms up and began tripping out of the hole at 18:00. Experienced pack off at 6010' MD while tripping out. Currently circulating at time of report. Mas Gas: 224 units at 8152' MD Fluids: 0 bbls of mud lost down hole. Geology: Light to dark gray, white to cream, clear, orange to pink, translucent to transparent and trace black and green sandstone that is moderately hard, very fine to medium sized grains that are sub rounded, sub spherical to sub elongated, moderately sorted and poorly cemented with unconsolidated grains and trace Glauconite. Data Engineers Days/Nights: Jeremy Tiegs/Craig Amos Loggers Days/Nights: Leslie Hunter/ Hilary Garney . * (current) Surface C-1Depth Cly 31663 C-3 Sd Silt TuffGvl 6 907-283-1309Unit Phone:Hilary Garney Maximum Report By:Logging Engineers: Minimum 0 (max) 0- 550 Hilary Garney/Jeremy Tiegs 49 in 16.00'' 5.50'' 0.0 C-2 243 9 5/8" 0.7528.5 24 hr Max 0 0 - 4 8208' 8208' 0' Max @ ft Current Time: - SPP (psi) MBT pH 2.356 Siltst Grade PDC 8209' 3 Size Hours Set At Casing Summary Bit # 2 Depth ShClyst - Flow In (gpm) Flow In (spm) (ppb Eq) TFA Yesterday's Depth: RIH w/ Clean out AssemblyRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0901729762 Lithology (%) Weight 77.38 Job No.: Daily Charges: Total Charges: James Sweetsir 0.28 Coal 90 Conductor Comments Cement PV 8208' Depth in / out 3510' cP 13 3540' 3.3 30' Footage YP (lb/100ft2) 10.00 4668' Condition 2-2-NO-A-E-1-NO-BHA WOB C-5n Gas Summary C-4i C-4n C-5i Chromatograph (ppm) Ss (current) Units* Mud Type Lst 100 Production Type 3488' 81' 23 Average 7Background (max) Trip RPM ECD (ppg) ml/30min API FL 4 9 Avg 94 4.8 100% Gas In Air=10,000 Units0Connection 6.3 8.5 9.90 Tricone 9.85 Size KCL/Polymer 3540' Bit Type Saxon 169 Report For: Tools 10.1410.22 Min ROP Avg Morning Report Report # 12 Customer: Well: Area: Location: Rig: Beaver Creek 25 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP (ft/hr) 3.07 @ Mud Data to 0.0 Gallons/stroke 10.31 Depth MWD Summary 3-Nov-2014 12:00 AM Current Pump & Flow Data: 0 Max 95% mg/l 29000 1-2-CT-G-X-1/16-PN-T Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides Continued to trip out of the hole and laid down BHA #3, then picked up clean out assembly and began reaming into the hole. Circulated bottoms up at 5200' MD and 5700' MD then continued to ream into the hole at time of report. Mas Gas: 243 units while circulating bottoms up. Fluids: 0 bbls of mud lost down hole. Geology: Light to dark gray, white to cream, clear, orange to pink, translucent to transparent and trace black and green sandstone that is moderately hard, very fine to medium sized grains that are sub rounded, sub spherical to sub elongated, moderately sorted and poorly cemented with unconsolidated grains and trace Glauconite. Data Engineers Days/Nights: Jeremy Tiegs/Hilary Garney . * (current) Surface C-1Depth Cly 30940 C-3 Sd Silt TuffGvl 2 907-283-1309Unit Phone:Hilary Garney Maximum Report By:Logging Engineers: Minimum 0 (max) 0- 378 Hilary Garney/Jeremy Tiegs 48 in 16.00'' 5.50'' 0.0 C-2 223 9 5/8" 0.7528.5 24 hr Max 0 0 - 2 8208' 8208' 0' Max @ ft Current Time: - SPP (psi) MBT pH 2.356 Siltst Grade PDC 8209' 3 Size Hours Set At Casing Summary Bit # 2 Depth ShClyst - Flow In (gpm) Flow In (spm) (ppb Eq) TFA Yesterday's Depth: POOH LD 4.5 DPRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0901729762 Lithology (%) Weight 77.38 Job No.: Daily Charges: Total Charges: Jimmy Greco 0.28 Coal 90 Conductor Comments Cement PV 8208' Depth in / out 3510' cP 13 3540' 3.3 30' Footage YP (lb/100ft2) 9.70 4668' Condition 2-2-NO-A-E-1-NO-BHA WOB C-5n Gas Summary C-4i C-4n C-5i Chromatograph (ppm) Ss (current) Units* Mud Type Lst Production Type 3488' 81' 25 Average 9Background (max) Trip RPM ECD (ppg) ml/30min API FL 4 9 Avg 94 5.0 100% Gas In Air=10,000 Units0Connection 6.4 8.5 9.90 Tricone 9.85 Size KCL/Polymer 3540' Bit Type Saxon 169 Report For: Tools 10.1410.22 Min ROP Avg Morning Report Report # 13 Customer: Well: Area: Location: Rig: Beaver Creek 25 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP (ft/hr) 3.07 @ Mud Data to 0.0 Gallons/stroke 10.31 Depth MWD Summary 4-Nov-2014 12:00 AM Current Pump & Flow Data: 0 Max 95% mg/l 28500 1-2-CT-G-X-1/16-PN-T Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides Ran into the hole to 8209' MD and circulated bottoms up until shakers were clean. Pumped a low vis then a high vis sweep and waited until shakers were clean. Began to trip out of the hole to 5100' MD and circulated bottoms up, pumped another sweep. Continuing to clean out the hole at time of report. Mas Gas: 223 units while circulating bottoms up. Fluids: 0 bbls of mud lost down hole. Geology: N/A Data Engineers Days/Nights: Jeremy Tiegs/Hilary Garney . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 28500 1-2-CT-G-X-1/16-PN-T 5-Nov-2014 12:00 AM Current Pump & Flow Data: 0 Max 95% Depth MWD Summary ROP (ft/hr) 3.07 @ Mud Data to 0.0 Gallons/stroke 10.31 Morning Report Report # 14 Customer: Well: Area: Location: Rig: Beaver Creek 25 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Saxon 169 Report For: Tools 10.1410.22 Min ROP Avg 6.5 8.5 9.90 Tricone 9.85 Size KCL/Polymer 3540' Bit Type 100% Gas In Air=10,000 Units0Connection RPM ECD (ppg) ml/30min API FL 4 9 Avg 94 4.4 Background (max) Trip Average 2 Mud Type Lst Production Type 3488' 81' 24 Ss (current) Units* Chromatograph (ppm) C-4i C-4n C-5i C-5n Gas Summary YP (lb/100ft2) 9.80 4668' Condition 2-2-NO-A-E-1-NO-BHA WOB PV 8208' Depth in / out 3510' cP 13 3540' 3.5 30' Footage Coal 90 Conductor Comments Cement Lithology (%) Weight 77.38 Job No.: Daily Charges: Total Charges: Jimmy Greco 0.28 Yesterday's Depth: RIH w/ CasingRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0901729762 Depth ShClyst - Flow In (gpm) Flow In (spm) (ppb Eq) TFA PDC 8209' 3 Size Hours Set At Casing Summary Bit # 2 MBT pH 2.356 Siltst Grade 1 8208' 8208' 0' Max @ ft Current Time: - SPP (psi) 24 hr Max 0 0 - 0.0 C-2 6 9 5/8" 0.7528.5 Hilary Garney/Jeremy Tiegs 53 in 16.00'' 5.50'' Minimum 0 (max) 0- 50 1 907-283-1309Unit Phone:Hilary Garney Maximum Report By:Logging Engineers: Depth Cly 1008 C-3 Sd Silt TuffGvl C-1 (current) Surface Continued to pull out of the hole and laid down drill pipe and BHA. Began running into the hole with 5.5" casing. Circulated bottoms up at 3439' MD. Continuing to run into the hole at time of report. Mas Gas: 6 units Fluids: 0 bbls of mud lost down hole. Geology: N/A Data Engineers Days/Nights: Jeremy Tiegs/Hilary Garney